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
208-189
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# PBU 05-04A 50029201520100 196089 10/30/2025 BAKER RPM PBU F-18B 50029206360200 225099 11/4/2025 BAKER MRPM END 1-39A 50029218270100 206187 11/20/2025 READ PressTempSurvey END 1-55 50029217880000 188021 11/26/2025 READ PressTempSurvey END 1-57 50029218730000 188114 11/18/2025 READ CaliperSurvey END 1-63 50029219050000 189006 11/23/2025 READ PressTempSurvey END 1-65A 50029226270100 203212 11/29/2025 READ PressTempSurvey END 2-18 50029220320000 190043 11/19/2025 READ PressTempSurvey END 2-20 50029220480000 190060 11/24/2025 READ PressTempSurvey END 2-32 50029220840000 190119 11/30/2025 READ PressTempSurvey END 2-46B 50029219210200 197137 11/21/2025 READ PressTempSurvey NCI A-13 50883200870000 192106 11/27/2025 READ Caliper Survey NS-33A 50029233250100 208189 5/22/2025 READ EVCamera Please include current contact information if different from above. T41175 T41176 T41177 T41178 T41179 T41180 T41181 T41182 T41183 T41184 T41185 T41186 T41187NS-33A 50029233250100 208189 5/22/2025 READ EVCamera Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.05 11:03:29 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Northstar Well 33; PTD #208-189/Sundry #325-298 Date:Tuesday, June 10, 2025 2:23:14 PM Attachments:NSI NS-33A 10-403 May 2025 Approval.pdf From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Tuesday, June 10, 2025 10:43 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Anthony McConkey <amcconkey@hilcorp.com>; Justus Hinks <jhinks@hilcorp.com>; Nathan Williams <Nathan.Williams@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: RE: Northstar Well 33; PTD #208-189/Sundry #325-298 Jack, A further update on this project: We set the re-designed K-valve to close at 710 psi/60F as per below. However, we were still not able to get the valve to close when we dropped the WHP to common line. This morning we plan to pull the K-valve and set a new iteration of the K-valve set to close at 900 psi/60F and test the valve closure again. As noted below, we may need to choke the well back to keep the valve open when flowing the well. Please let us know if this additional change is acceptable within the approved Sundry. Thanks and Best Regards, Aras Worthington Sr. Operations Engineer, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: Aras Worthington Sent: Thursday, June 5, 2025 2:40 PM To: 'Lau, Jack J (OGC)' <jack.lau@alaska.gov> Cc: Anthony McConkey <amcconkey@hilcorp.com>; Justus Hinks <jhinks@hilcorp.com>; Nathan Williams <Nathan.Williams@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: RE: Northstar Well 33; PTD #208-189/Sundry #325-298 Jack, An update on this project: We set the retrievable packer/K-valve assembly yesterday but could not get the K-valve to close when tubing pressure was taken down to common line. We pulled the packer/K-valve assembly out and are currently re-configuring the K-valve to close at a higher pressure (710 psi vs. 630 psi for the first K-valve). This will mean we will need to choke the well back a little (from ~780 psi FWHP to ~910 psi FWHP) to keep the K-valve open when flowing the well. Please let us know if this change is acceptable within the approved Sundry. Thanks and Best Regards, Aras Worthington Sr. Operations Engineer, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: Aras Worthington Sent: Wednesday, June 4, 2025 12:00 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Anthony McConkey <amcconkey@hilcorp.com>; Justus Hinks <jhinks@hilcorp.com>; Nathan Williams <Nathan.Williams@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: Northstar Well 33; PTD #208-189/Sundry #325-298 Jack, As discussed via phone call earlier today: The attached Sundry was approved on 05/14/2025 for a K-valve installation in the subject well. The Sundry verbiage indicated that fishing attempts on the insert wireline retrievable SSSV (set inside the failed TRSSSV) were unsuccessful thus, the need for a K-valve. Since the time of Sundry approval, several more attempts were made to fish the wireline retrievable valve. On 5/26/2025, the wireline retrievable SSSV was successfully pulled from the well. Following other downhole work on the well (including failed attempts to recover two lost keys from the SSSV lock assembly), four attempts were made to set and test a new wireline retrievable valve. These attempts failed and control line integrity to the valve internals could not be achieved; most likely due to leaking packing stacks that need to seal against the polish bores in the well. The usual iterative arrangements of extended packing, etc. were tried to no avail. On 6/3/2025, a K-valve installation was attempted with the K-valve made up to the bottom of an X-lock, which landed in the failed TRSSSV profile. These attempts also failed, and the well would not pass a drawdown test, assumedly because the single packing stack on the lock would not seal against the lock polish bore in the TRSSSV profile. Today, 6/4/2025, we are planning to run a K-valve made up to the bottom of a retrievable packer, as prescribed in the approved Sundry. The only difference between this arrangement and what is in the approved Sundry is that a hold-open-sleeve will not be run into the wireline retrievable SSSV since that valve has already been pulled from the well. All of the K-valve testing procedures will follow the approved Sundry verbiage and the applicable AOGCC regulations. Please contact me if there are any questions or concerns regarding proceeding as described above. Thanks and Best Regards, Aras Worthington Sr. Operations Engineer, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Aras Worthington Cc:Anthony McConkey; Justus Hinks; Nathan Williams; Darci Horner Subject:RE: Northstar Well 33; PTD #208-189/Sundry #325-298 Date:Thursday, June 5, 2025 2:46:30 PM Approved. Thanks for the update. Jack From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Thursday, June 5, 2025 2:40 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Anthony McConkey <amcconkey@hilcorp.com>; Justus Hinks <jhinks@hilcorp.com>; Nathan Williams <Nathan.Williams@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: RE: Northstar Well 33; PTD #208-189/Sundry #325-298 Jack, An update on this project: We set the retrievable packer/K-valve assembly yesterday but could not get the K-valve to close when tubing pressure was taken down to common line. We pulled the packer/K-valve assembly out and are currently re-configuring the K-valve to close at a higher pressure (710 psi vs. 630 psi for the first K-valve). This will mean we will need to choke the well back a little (from ~780 psi FWHP to ~910 psi FWHP) to keep the K-valve open when flowing the well. Please let us know if this change is acceptable within the approved Sundry. Thanks and Best Regards, Aras Worthington Sr. Operations Engineer, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: Aras Worthington Sent: Wednesday, June 4, 2025 12:00 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Anthony McConkey <amcconkey@hilcorp.com>; Justus Hinks <jhinks@hilcorp.com>; Nathan Williams <Nathan.Williams@hilcorp.com>; Darci Horner <dhorner@hilcorp.com> Subject: Northstar Well 33; PTD #208-189/Sundry #325-298 Jack, As discussed via phone call earlier today: The attached Sundry was approved on 05/14/2025 for a K-valve installation in the subject well. The Sundry verbiage indicated that fishing attempts on the insert wireline retrievable SSSV (set inside the failed TRSSSV) were unsuccessful thus, the need for a K-valve. Since the time of Sundry approval, several more attempts were made to fish the wireline retrievable valve. On 5/26/2025, the wireline retrievable SSSV was successfully pulled from the well. Following other downhole work on the well (including failed attempts to recover two lost keys from the SSSV lock assembly), four attempts were made to set and test a new wireline retrievable valve. These attempts failed and control line integrity to the valve internals could not be achieved; most likely due to leaking packing stacks that need to seal against the polish bores in the well. The usual iterative arrangements of extended packing, etc. were tried to no avail. On 6/3/2025, a K-valve installation was attempted with the K-valve made up to the bottom of an X-lock, which landed in the failed TRSSSV profile. These attempts also failed, and the well would not pass a drawdown test, assumedly because the single packing stack on the lock would not seal against the lock polish bore in the TRSSSV profile. Today, 6/4/2025, we are planning to run a K-valve made up to the bottom of a retrievable packer, as prescribed in the approved Sundry. The only difference between this arrangement and what is in the approved Sundry is that a hold-open-sleeve will not be run into the wireline retrievable SSSV since that valve has already been pulled from the well. All of the K-valve testing procedures will follow the approved Sundry verbiage and the applicable AOGCC regulations. Please contact me if there are any questions or concerns regarding proceeding as described above. Thanks and Best Regards, Aras Worthington Sr. Operations Engineer, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Aras Worthington Cc:Anthony McConkey; Justus Hinks; Nathan Williams; Darci Horner Subject:RE: Northstar Well 33; PTD #208-189/Sundry #325-298 Date:Wednesday, June 4, 2025 12:47:08 PM Attachments:NSI NS-33A 10-403 May 2025 Approval.pdf Aras – Thanks for the update. You are approved for the K-Valve work on the existing approved sundry. Thanks Jack From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Wednesday, June 4, 2025 12:00 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Subject: Northstar Well 33; PTD #208-189/Sundry #325-298 Jack, As discussed via phone call earlier today: The attached Sundry was approved on 05/14/2025 for a K-valve installation in the subject well. The Sundry verbiage indicated that fishing attempts on the insert wireline retrievable SSSV (set inside the failed TRSSSV) were unsuccessful thus, the need for a K-valve. Since the time of Sundry approval, several more attempts were made to fish the wireline retrievable valve. On 5/26/2025, the wireline retrievable SSSV was successfully pulled from the well. Following other downhole work on the well (including failed attempts to recover two lost keys from the SSSV lock assembly), four attempts were made to set and test a new wireline retrievable valve. These attempts failed and control line integrity to the valve internals could not be achieved; most likely due to leaking packing stacks that need to seal against the polish bores in the well. The usual iterative arrangements of extended packing, etc. were tried to no avail. On 6/3/2025, a K-valve installation was attempted with the K-valve made up to the bottom of an X-lock, which landed in the failed TRSSSV profile. These attempts also failed, and the well would not pass a drawdown test, assumedly because the single packing stack on the lock would not seal against the lock polish bore in the TRSSSV profile. Today, 6/4/2025, we are planning to run a K-valve made up to the bottom of a retrievable packer, as prescribed in the approved Sundry. The only difference between this arrangement and what is in the approved Sundry is that a hold-open-sleeve will not be run into the wireline retrievable SSSV since that valve has already been pulled from the well. All of the K-valve testing procedures will follow the approved Sundry verbiage and the applicable AOGCC regulations. Please contact me if there are any questions or concerns regarding proceeding as described above. Thanks and Best Regards, Aras Worthington Sr. Operations Engineer, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install K-valve SSSV 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 26,090 NA Casing Collapse Conductor Surface 1479 Intermediate 3436 Liner 3045 Liner 5765 Liner 7496 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Aras Worthington Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8424 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312798, ADL0312799 208-189 NORTHSTAR UNIT NS-33A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23325-01-00 NORTHSTAR Hilcorp Alaska, LLC Length Size Proposed Pools: 11,350 25,890 11,176 3,922 NORTHSTAR OIL Same 190 190 12.6#, 13Cr-80 TVD Burst 23,162 7438 MD 5713 4335 6916 3,194 6,566 9,152 4,472 15,037 6-5/8" 190 24" 16" 11-3/4" 4,472 8-5/8"9,299 15,037 907-564-4763 aras.worthington@hilcorp.com Operations Manager May 15, 2025 25,9182,718 4-1/2" 11,200 Perforation Depth MD (ft): See Schematic 6-5/8"x4-1/2" Bkr ZXP LTP, 4-1/2" Swell Pkr, 4-1/2" TRMAXX-5E TRSSSV 23,182' MD/8,878' TVD, 25,410' MD/10,692' TVD, 1,129' MD/ 1,111' TVD C.O. 739 NA 25,582 23,540 15,605 4-1/2" See Schematic 10,902 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.05.12 15:31:49 -08'00' Justus Hinks (3691) 325-298 By Grace Christianson at 3:57 pm, May 12, 2025 10-404 SFD 5/12/2025JJL 5/13/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.14 14:17:01 -08'00'05/14/25 Page 1 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Well Name:NS-33 API Number:50-029-23325-01 Current Status:Operable PAL PTD #208-189 Estimated Start Date:05/15/2025 Rig:SL Reg.Approval Req’std?Yes - 403 Estimated Duration:1day Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure:5,022 psi @ 11,000’ ssTVD; SBHPS 3/4/2014; (8.8ppg EMW) Max. Anticipated Surface Pressure:3,922 psi Gas Column Gradient (0.1 psi/ft) History Rotary sidetrack drilled and completed in 2009. The TRSV was locked out in 2015 and an insert wireline retrievable SSSV was installed. In April of 2025 a downhole hydraulic leak developed, most likely in one of the packing stacks of the wireline retrievable SSSV. The control line pressure tracks tubing pressure but does not track IA pressure. Several attempts have been made to retrieve the SSSV, however the fishneck of the X-lock holding the SSSV swivelled off on the first run to retrieve the SSSV. Since then the threads of the expander mandrel were latched with a box tap but attempts to pull the valve have been unsuccessful. Objective Install mechanical operated / pressure operated SSSV also known as a K-valve or PB-valve. The valve will be set up with a closing pressure of 833psig at surface based on 119 degF flowing well head temperature (630 psi closing pressure @ 60F). The main production header at Northstar operates at 759psig, so the well will need to be choked back to ~850 psi to keep the valve open. To test the valve, the well choke will be opened to drop the wellhead pressure to main production pressure. To reset the valve, the well will be pressured up to above the trip pressure then gradually reopened to the normal operating range. Page 2 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 K-Valve Testing Procedure and Regulations The SVS testing of the K-valve shall be conducted following the regulations under 20 AAC 25.265 “Well safety valve systems”as well as AOGCC Guidance Bulletin 10-004 posted on 12/16/2010. The well should be online and flowing prior to the SVS testing at a WHP above the designed shut in pressure of the valve (630psi). To begin the testing, open the choke to the well until the WHP drops below 833 psi. The WHP response should be less than 5 minutes but be no more than 15 minutes. If after 15 minutes the WHP has not dropped below closure pressure, test is a fail and the K-Valve design needs re-evaluation. If the subsurface safety valve goes closed, the well will stop flowing and WHP should fall rapidly to common line pressure. Shut the wing valve to isolate the well from production header. Monitor and trend WHP with a calibrated pressure gauge for approximately 15 minutes. If WHP does not build, the test is a pass. If WHP builds, the test is a fail. Per 20 AAC 25.265(h)(1) performance-testing of the safety valve system must be accomplished using a calibrated pressure gauge of suitable range and accuracy; Per AOGCC Guidance Bulletin 10-004, the AOGCC further clarified this as below. “The use of a calibrated test gauge of suitable range and accuracy is required for SVS performance testing. Current calibration should be evident with a label or other documentation. Suitable range means the pressure readings are displayed within the center third of the full scale; suitable accuracy means the gauge is capable of measuring pressures that are less than or equal to 1 percent of the gauge's full scale pressure range.” Per 20 AAC 25.265(h)(12) not later than four minutes after the actuation of a mechanical or electrical detection device, a required subsurface safety valve must close; after valve closure with a measurable pressure differential across the valve, there must be no detectable leakage as evidenced by a stabilized, flat-line pressure response; Page 3 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Procedure REVIEW 10-403 SUNDRY PRIOR TO BEGINNING WORK Slickline 1. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 1. Set a hold open sleeve in the wireline retrievable SSSV to keep the valve open. 2. MU NS 4-1/2” retrievable packer with K valve threaded to the bottom of the packer. 3. Set the packer/K-valve assembly just above the SSSV at ~1100’ MD. 4. Turn well over to production. 5. Conduct a SVS test within 5 days after stabilized flow. Page 4 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Calculations "K" Valve Calculation Sheet Well #NS33 Date: 05/08/25 Test Data Test Date 02/01/25 Gross Fluid Rate 1750 BLPD Flowing Well Head Pressure 783 psi Flowing Well Head Temperature 119 deg F GOR 37369 scf/bbl TGLR 8776 scf/bbl K Valve design based on data gathered from "K" Valve Setting Depth TVD 1084 ft Flowing Tubing Pressure @ 833 Pwh 957 psi "K" Valve Set to Close at 833 psi Pwh "K" Valve Test Rack Set Pressure at 60 deg F 630 psi Remedial Plan - WIRELINE ACTION Install Halliburtion K-Valve SSSV as per attached data. Halliburton set K Valve to 630 psi @ 60 deg F. DSO flow well at FTP greater than 850 psi. Valve set to close at 833 psi FTP. _____________________________________________________________________________________ Revised By: DH 10/28/2024 Page 5 of 6 CURRENT SCHEMATIC Duck Island Unit Well: END 2-72 Last Completed: 6/19/2024 PTD: 224-016 _____________________________________________________________________________________ Page 6 of 6 PROPOSED SCHEMATIC Duck Island Unit Well: END 2-72 Last Completed: 6/19/2024 PTD: 224-016 D4-1/2” NS retrievable packer w/ K-valve 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install K-valve SSSV 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 26,090 NA Casing Collapse Conductor Surface 1479 Intermediate 3436 Liner 3045 Liner 5765 Liner 7496 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Aras Worthington Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8424 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312798, ADL0312799 208-189 NORTHSTAR UNIT NS-33A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23325-01-00 NORTHSTAR Hilcorp Alaska, LLC Length Size Proposed Pools: 11,350 25,890 11,176 3,922 NORTHSTAR OIL Same 190 190 12.6#, 13Cr-80 TVD Burst 23,162 7438 MD 5713 4335 6916 3,194 6,566 9,152 4,472 15,037 6-5/8" 190 24" 16" 11-3/4" 4,472 8-5/8"9,299 15,037 907-564-4763 aras.worthington@hilcorp.com Operations Manager May 15, 2025 25,9182,718 4-1/2" 11,200 Perforation Depth MD (ft): See Schematic 6-5/8"x4-1/2" Bkr ZXP LTP, 4-1/2" Swell Pkr, 4-1/2" TRMAXX-5E TRSSSV 23,182' MD/8,878' TVD, 25,410' MD/10,692' TVD, 1,129' MD/ 1,111' TVD C.O. 739 NA 25,582 23,540 15,605 4-1/2" See Schematic 10,902 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.05.12 15:31:49 -08'00' Justus Hinks (3691) 325-298 By Grace Christianson at 3:57 pm, May 12, 2025 10-404 SFD 5/12/2025JJL 5/13/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.14 14:17:01 -08'00'05/14/25 RBDMS JSB 0521625 Page 1 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Well Name:NS-33 API Number:50-029-23325-01 Current Status:Operable PAL PTD #208-189 Estimated Start Date:05/15/2025 Rig:SL Reg.Approval Req’std?Yes - 403 Estimated Duration:1day Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure:5,022 psi @ 11,000’ ssTVD; SBHPS 3/4/2014; (8.8ppg EMW) Max. Anticipated Surface Pressure:3,922 psi Gas Column Gradient (0.1 psi/ft) History Rotary sidetrack drilled and completed in 2009. The TRSV was locked out in 2015 and an insert wireline retrievable SSSV was installed. In April of 2025 a downhole hydraulic leak developed, most likely in one of the packing stacks of the wireline retrievable SSSV. The control line pressure tracks tubing pressure but does not track IA pressure. Several attempts have been made to retrieve the SSSV, however the fishneck of the X-lock holding the SSSV swivelled off on the first run to retrieve the SSSV. Since then the threads of the expander mandrel were latched with a box tap but attempts to pull the valve have been unsuccessful. Objective Install mechanical operated / pressure operated SSSV also known as a K-valve or PB-valve. The valve will be set up with a closing pressure of 833psig at surface based on 119 degF flowing well head temperature (630 psi closing pressure @ 60F). The main production header at Northstar operates at 759psig, so the well will need to be choked back to ~850 psi to keep the valve open. To test the valve, the well choke will be opened to drop the wellhead pressure to main production pressure. To reset the valve, the well will be pressured up to above the trip pressure then gradually reopened to the normal operating range. Page 2 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 K-Valve Testing Procedure and Regulations The SVS testing of the K-valve shall be conducted following the regulations under 20 AAC 25.265 “Well safety valve systems”as well as AOGCC Guidance Bulletin 10-004 posted on 12/16/2010. The well should be online and flowing prior to the SVS testing at a WHP above the designed shut in pressure of the valve (630psi). To begin the testing, open the choke to the well until the WHP drops below 833 psi. The WHP response should be less than 5 minutes but be no more than 15 minutes. If after 15 minutes the WHP has not dropped below closure pressure, test is a fail and the K-Valve design needs re-evaluation. If the subsurface safety valve goes closed, the well will stop flowing and WHP should fall rapidly to common line pressure. Shut the wing valve to isolate the well from production header. Monitor and trend WHP with a calibrated pressure gauge for approximately 15 minutes. If WHP does not build, the test is a pass. If WHP builds, the test is a fail. Per 20 AAC 25.265(h)(1) performance-testing of the safety valve system must be accomplished using a calibrated pressure gauge of suitable range and accuracy; Per AOGCC Guidance Bulletin 10-004, the AOGCC further clarified this as below. “The use of a calibrated test gauge of suitable range and accuracy is required for SVS performance testing. Current calibration should be evident with a label or other documentation. Suitable range means the pressure readings are displayed within the center third of the full scale; suitable accuracy means the gauge is capable of measuring pressures that are less than or equal to 1 percent of the gauge's full scale pressure range.” Per 20 AAC 25.265(h)(12) not later than four minutes after the actuation of a mechanical or electrical detection device, a required subsurface safety valve must close; after valve closure with a measurable pressure differential across the valve, there must be no detectable leakage as evidenced by a stabilized, flat-line pressure response; Page 3 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Procedure REVIEW 10-403 SUNDRY PRIOR TO BEGINNING WORK Slickline 1. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 1. Set a hold open sleeve in the wireline retrievable SSSV to keep the valve open. 2. MU NS 4-1/2” retrievable packer with K valve threaded to the bottom of the packer. 3. Set the packer/K-valve assembly just above the SSSV at ~1100’ MD. 4. Turn well over to production. 5. Conduct a SVS test within 5 days after stabilized flow. Page 4 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Calculations "K" Valve Calculation Sheet Well #NS33 Date: 05/08/25 Test Data Test Date 02/01/25 Gross Fluid Rate 1750 BLPD Flowing Well Head Pressure 783 psi Flowing Well Head Temperature 119 deg F GOR 37369 scf/bbl TGLR 8776 scf/bbl K Valve design based on data gathered from "K" Valve Setting Depth TVD 1084 ft Flowing Tubing Pressure @ 833 Pwh 957 psi "K" Valve Set to Close at 833 psi Pwh "K" Valve Test Rack Set Pressure at 60 deg F 630 psi Remedial Plan - WIRELINE ACTION Install Halliburtion K-Valve SSSV as per attached data. Halliburton set K Valve to 630 psi @ 60 deg F. DSO flow well at FTP greater than 850 psi. Valve set to close at 833 psi FTP. _____________________________________________________________________________________ Revised By: DH 10/28/2024 Page 5 of 6 CURRENT SCHEMATIC Duck Island Unit Well: END 2-72 Last Completed: 6/19/2024 PTD: 224-016 _____________________________________________________________________________________ Page 6 of 6 PROPOSED SCHEMATIC Duck Island Unit Well: END 2-72 Last Completed: 6/19/2024 PTD: 224-016 D4-1/2” NS retrievable packer w/ K-valve 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install K-valve SSSV 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 26,090 NA Casing Collapse Conductor Surface 1479 Intermediate 3436 Liner 3045 Liner 5765 Liner 7496 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Aras Worthington Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8424 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312798, ADL0312799 208-189 NORTHSTAR UNIT NS-33A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23325-01-00 NORTHSTAR Hilcorp Alaska, LLC Length Size Proposed Pools: 11,350 25,890 11,176 3,922 NORTHSTAR OIL Same 190 190 12.6#, 13Cr-80 TVD Burst 23,162 7438 MD 5713 4335 6916 3,194 6,566 9,152 4,472 15,037 6-5/8" 190 24" 16" 11-3/4" 4,472 8-5/8"9,299 15,037 907-564-4763 aras.worthington@hilcorp.com Operations Manager May 15, 2025 25,9182,718 4-1/2" 11,200 Perforation Depth MD (ft): See Schematic 6-5/8"x4-1/2" Bkr ZXP LTP, 4-1/2" Swell Pkr, 4-1/2" TRMAXX-5E TRSSSV 23,182' MD/8,878' TVD, 25,410' MD/10,692' TVD, 1,129' MD/ 1,111' TVD C.O. 739 NA 25,582 23,540 15,605 4-1/2" See Schematic 10,902 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.05.12 15:31:49 -08'00' Justus Hinks (3691) 325-298 By Grace Christianson at 3:57 pm, May 12, 2025 10-404 SFD 5/12/2025JJL 5/13/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.14 14:17:01 -08'00'05/14/25 RBDMS JSB 051425 Page 1 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Well Name:NS-33 API Number:50-029-23325-01 Current Status:Operable PAL PTD #208-189 Estimated Start Date:05/15/2025 Rig:SL Reg.Approval Req’std?Yes - 403 Estimated Duration:1day Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure:5,022 psi @ 11,000’ ssTVD; SBHPS 3/4/2014; (8.8ppg EMW) Max. Anticipated Surface Pressure:3,922 psi Gas Column Gradient (0.1 psi/ft) History Rotary sidetrack drilled and completed in 2009. The TRSV was locked out in 2015 and an insert wireline retrievable SSSV was installed. In April of 2025 a downhole hydraulic leak developed, most likely in one of the packing stacks of the wireline retrievable SSSV. The control line pressure tracks tubing pressure but does not track IA pressure. Several attempts have been made to retrieve the SSSV, however the fishneck of the X-lock holding the SSSV swivelled off on the first run to retrieve the SSSV. Since then the threads of the expander mandrel were latched with a box tap but attempts to pull the valve have been unsuccessful. Objective Install mechanical operated / pressure operated SSSV also known as a K-valve or PB-valve. The valve will be set up with a closing pressure of 833psig at surface based on 119 degF flowing well head temperature (630 psi closing pressure @ 60F). The main production header at Northstar operates at 759psig, so the well will need to be choked back to ~850 psi to keep the valve open. To test the valve, the well choke will be opened to drop the wellhead pressure to main production pressure. To reset the valve, the well will be pressured up to above the trip pressure then gradually reopened to the normal operating range. Page 2 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 K-Valve Testing Procedure and Regulations The SVS testing of the K-valve shall be conducted following the regulations under 20 AAC 25.265 “Well safety valve systems”as well as AOGCC Guidance Bulletin 10-004 posted on 12/16/2010. The well should be online and flowing prior to the SVS testing at a WHP above the designed shut in pressure of the valve (630psi). To begin the testing, open the choke to the well until the WHP drops below 833 psi. The WHP response should be less than 5 minutes but be no more than 15 minutes. If after 15 minutes the WHP has not dropped below closure pressure, test is a fail and the K-Valve design needs re-evaluation. If the subsurface safety valve goes closed, the well will stop flowing and WHP should fall rapidly to common line pressure. Shut the wing valve to isolate the well from production header. Monitor and trend WHP with a calibrated pressure gauge for approximately 15 minutes. If WHP does not build, the test is a pass. If WHP builds, the test is a fail. Per 20 AAC 25.265(h)(1) performance-testing of the safety valve system must be accomplished using a calibrated pressure gauge of suitable range and accuracy; Per AOGCC Guidance Bulletin 10-004, the AOGCC further clarified this as below. “The use of a calibrated test gauge of suitable range and accuracy is required for SVS performance testing. Current calibration should be evident with a label or other documentation. Suitable range means the pressure readings are displayed within the center third of the full scale; suitable accuracy means the gauge is capable of measuring pressures that are less than or equal to 1 percent of the gauge's full scale pressure range.” Per 20 AAC 25.265(h)(12) not later than four minutes after the actuation of a mechanical or electrical detection device, a required subsurface safety valve must close; after valve closure with a measurable pressure differential across the valve, there must be no detectable leakage as evidenced by a stabilized, flat-line pressure response; Page 3 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Procedure REVIEW 10-403 SUNDRY PRIOR TO BEGINNING WORK Slickline 1. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 1. Set a hold open sleeve in the wireline retrievable SSSV to keep the valve open. 2. MU NS 4-1/2” retrievable packer with K valve threaded to the bottom of the packer. 3. Set the packer/K-valve assembly just above the SSSV at ~1100’ MD. 4. Turn well over to production. 5. Conduct a SVS test within 5 days after stabilized flow. Page 4 of 6 Install Pressure Operated SSSV Well: NS-33 PTD: 208-189 Calculations "K" Valve Calculation Sheet Well #NS33 Date: 05/08/25 Test Data Test Date 02/01/25 Gross Fluid Rate 1750 BLPD Flowing Well Head Pressure 783 psi Flowing Well Head Temperature 119 deg F GOR 37369 scf/bbl TGLR 8776 scf/bbl K Valve design based on data gathered from "K" Valve Setting Depth TVD 1084 ft Flowing Tubing Pressure @ 833 Pwh 957 psi "K" Valve Set to Close at 833 psi Pwh "K" Valve Test Rack Set Pressure at 60 deg F 630 psi Remedial Plan - WIRELINE ACTION Install Halliburtion K-Valve SSSV as per attached data. Halliburton set K Valve to 630 psi @ 60 deg F. DSO flow well at FTP greater than 850 psi. Valve set to close at 833 psi FTP. _____________________________________________________________________________________ Revised By: DH 10/28/2024 Page 5 of 6 CURRENT SCHEMATIC Duck Island Unit Well: END 2-72 Last Completed: 6/19/2024 PTD: 224-016 _____________________________________________________________________________________ Page 6 of 6 PROPOSED SCHEMATIC Duck Island Unit Well: END 2-72 Last Completed: 6/19/2024 PTD: 224-016 D4-1/2” NS retrievable packer w/ K-valve • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, May 31,2016 10:59 AM To: 'Taylor Wellman' Cc: Loepp,Victoria T(DOA) Subject: RE: NS-33A(PTD#208-189/API#50-029-23325-01) Request Flare to Unload Taylor, You have approval to flare gas as requested to unload well NS-33A for up to 8 hrs once a month. All flared gas must be reported in the monthly flare reports. If the well requires additional unloading(more than once monthly) causing associated flare gas you must request approval in writing from the AOGCC. Regards, Guy Schwartz Sr. Petroleum Engineer0E0 JAN 0 6Z+ AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From:Taylor Wellman [mailto:twellman@hilcorp.com] Sent:Tuesday, May 31, 2016 7:49 AM To: Schwartz, Guy L(DOA) Subject: RE: NS-33A(PTD #208-189/API #50-029-23325-01) Request Flare to Unload Guy, Is there any further information that you would need to determine if this is an acceptable course of action for NS-33A? Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From:Taylor Wellman Sent: Thursday,April 28, 2016 10:56 AM To: 'Schwartz, Guy L(DOA); 'Loepp, Victoria T(DOA)' Subject: RE: NS-33A(PTD #208-189/API #50-029-23325-01) Request Flare to Unload Guy and Victoria, 1 • • Just wanted to check to see if you had had a chance to review this request. We are currently have NS-33A in test and it is showing signs of loading again so I thought I'd ask. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC-Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Taylor Wellman Sent: Wednesday, April 13, 2016 2:04 PM To: 'Schwartz, Guy L (DOA)'; Loepp, Victoria T(DOA) Subject: RE: NS-33A (PTD #208-189/ API #50-029-23325-01) Request Flare to Unload Guy and Victoria, I wanted to provide you with some feedback on how this operation went for NS-34A(PTD#208-189/API #50-029- 23325-01). It helped unload the well quite a bit and the well is flowing much better. The well tests below show a significant drop off from Nov 2015-Mar 2016. When we unloaded the well mid March,the WC has dropped and the well is flowing much better. Test Tubing Casing Water Date '7 ours Choke Press Press Oil Vol Gas Vol Gas Rate Gas Lift Water Vol Total Fluid Cut% GOR NSU NS-033A Northstar PA-50.0843.0022.00 04/02/2016 24 185 57.2 1,408.2 182.8 2,903.1 -217.8 3,120.9 924.5 1,087.4 85.0 -1.337.6 03/25/2016 24 165 761.1 1,949.4 239.2 5.384.9 504.0 4,880.9 1210.2 1,440_3 83.5 2,107.8 03/24/2016 24 165 754.8 1.807.1 234.5 4.888.2 536.8 4,351.4 1.181.4 1,415.9 83.4 2,289.6 03/23/2016 24 165 757.2 1.769.5 233.5 4.734.8 456.1 4,278.6 1.181.2 1,414.7 83.5 1,953.0 03/2212016 24 165 770.6 1.741.8 238.0 4,755.8 378.7 4,375.9 1.108.2 1,434.2 83.5 1.808.7 03121/2016 24 165 774.1 1,735.1 236.5 4,721.1 392.2 4,329.0 1,221.2 1,457.8 83.8 1,858.0 03/20/2016 24 185 771.9 1,548.5 209.0 3,454.5 476.2 2.978.3 1,098.3 1,305.2 84.0 2,278.9 03119/2016 24 185 760.4 1,409.1 218.9 3,448.2 441.1 3,005.1 1,128.3 1,345.2 83.9 2.033.6 0311812016 24 165 874.7 1,397.0 248.2 3,399.3 423.1 2,978.2 1,385.0 1,633.2 84.8 1,704.7 03/01/2016 24 758.1 1,358.8 59.1 2,717.4 -127.3 2.844.? 832.7 891_8 93.4 -2,153.3 02/08/2018 24 781.3 1,452.5 117.2 3,516.8 306.7 3,210.1 072.6 1,089.8 89.2 2,617.5 01103/2018 24 755.8 1,458.1 98.9 3,316.0 159.4 3,158.8 1,044.4 1,143.3 91.4 1,612.8 12/0112015 24 754.0 1,463.6 128.9 3,564.7 234.2 3,330.5 880.8 1,009.7 87.2 1.817.3 11/01/2015 24 740.8 1.489.9 177.0 3,481.2 185.4 3275.8 1,029.3 1,208.2 85.3 1,047.4 With this success we would like to move towards conducting this as a scheduled event to help keep the well unloaded. Requested Flare Schedule Frequency: Once per month (during 2"d welltest each month) Duration: 4 hours Expected Flare Rate: 0.3 MMscf per hour Expected Flare Vol: ^'1.2 MMscf per event We are aiming to have the more frequent intervals to keep the overall duration shorter each time. 2 • Reporting The reporting would fall under the normal flare volume reports already submitted. Attached are previous month's total flare volumes and the 12 month rolling average. All daily and 12 month rolling averages would be maintained under the flare limitations as per our air permit. If any further details on the well's unique wellbore configuration and challenges this completion poses or any questions with anything in the request please let me know and I will provide additional details. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Schwartz, Guy L(DOA) (mailto:guy.schwartz@alaska.gov] Sent:Thursday, March 17, 2016 5:24 PM To:Taylor Wellman Cc: Loepp, Victoria T(DOA) Subject: RE: NS-33A(PTD #208-189/API #50-029-23325-01) Request Flare to Unload Got it..thanks for the insite. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov). From:Taylor Wellman [mailto:twellman@hilcorp.com] Sent:Thursday, March 17,2016 3:51 PM To:Schwartz,Guy L(DOA) Cc: Loepp,Victoria T(DOA) Subject: RE: NS-33A(PTD#208-189/API#50-029-23325-01) Request Flare to Unload Guy, The piping is using the test separator header.The production header runs at—750psi.The test separator can be run at 3 different backpressures: -750psi+.This routes the gas and liquids back into the normal 1g stage separation in the facility. 3 si.A jumper was installed • to allow all roduction fluids& as to pushed down the li uid and 350 750p � p p ( g ) q leg ' routed into the 2nd stage separation in the facility.The downside to this is to continuously flow the well at this pressure,the test separator is completely taken by this well. -0-350psi.The gas leg of the separator is taken to flare and the liquids are routed to the well clean up tank and recovered. At all times,all the production is kept in permanent piping and does not require special temporary hardline to do this. Thanks, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From:Schwartz,Guy L(DOA) (mailto:guy.schwartz@alaska.gov] Sent:Thursday, March 17,2016 3:39 PM To:Taylor Wellman Cc: Loepp,Victoria T(DOA) Subject: RE: NS-33A(PTD#208-189/API#50-029-23325-01)Request Flare to Unload Taylor, Approval granted to flow well NS-33A and flare up to 2mmscf gas (8 hour flow period). As stated below report flared gas in monthly gas disposition report. What is your flowback piping look like? How does this decrease the FTP so you get more drawdown? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov). From:Taylor Wellman Finailto:twellman@hilcorp.com] Sent:Thursday, March 17,2016 11:18 AM To:Schwartz,Guy L(DOA) Subject: NS-33A(PTD#208-189/API#50-029-23325-01) Request Flare to Unload Guy, Northstar well NS-33A(PTD#208-189/API#50-029-23325-01) is a well that has a long stepout(reaches—70 deg from 3600'—21,000' md), high water cut("90%)and very inefficient artificial lift capabilities (deepest GLM @ 2934'md/2413' tvd).A schematic is included for reference. 4 Over a period of months the well IoaTs up and slowly kills itself while in the normal production header.We have been able to keep the well flowing by various means: backflushing,shut in and allow water to drain back into reservoir,or flow through our test separator at medium pressure for most of the month but all these have not been very effective in clearing the water from the tubing.The most effective way we found was to have a short term flaring period (with prior approval)to unload this well. We would like to request flowing through the test separator and flaring the gas to unload for a period of up to 8 hours. The max expected total gas volume during this timeframe is^'2mmscf.All true volumes would be recorded and submitted in the normal reports.All liquids will be captured through the test separator and routed through the well clean up tank. Thank you and please contact me with any additional information needed, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com 5 • • P7l,7 zoo-JR 7 Loepp, Victoria T (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Wednesday, April 13, 2016 2:04 PM To: Schwartz, Guy L(DOA); Loepp, Victoria T (DOA) Subject: RE: NS-33A(PTD#208-189/API#50-029-23325-01) Request Flare to Unload Attachments: Northstar Flaring Volumes.xlsx Follow Up Flag: Follow up Flag Status: Flagged SCAtiNED APR 2 9 2016 Guy and Victoria, I wanted to provide you with some feedback on how this operation went for NS-34A(PTD#208-189/API #50-029- 23325-01). It helped unload the well quite a bit and the well is flowing much better. The well tests below show a significant drop off from Nov 2015-Mar 2016. When we unloaded the well mid March,the WC has dropped and the well is flowing much better. Test Tubing Casing Water Date Hours Choke Press Press Oil Vol Gas Vol Gas Rate Gas Lift Water Vol Total Fluid Cut% GOR NSU NS-033A Northstar PA-50.0843.0022.00 04/02/2016 24 185 7572 1,408.2 162.8 2.903.1 -217.8 3,120.9 824.5 1,087.4 85.0 -1.337.8 03/25/2016 24 185 761.1 1,949.4 239.2 5,384.9 504.0 4,880.9 1210.2 1,449.3 83.5 2,107.8 03/24/2016 24 165 754.8 1,807.1 234.5 4.888.2 538.8 4,351.4 1,181.4 1,415.9 83.4 2,289.8 0312312018 24 165 757.2 1,760.5 233.5 4,734.8 456.1 4,278.6 1,181.2 1,414.7 83.5 1,953.0 03/2212016 24 165 776.8 1,741.8 236.0 4,755.8 379.7 4,375.9 1.198.2 1,434.2 83.5 1,808.7 03121/2016 24 165 774.1 1,735.1 238.5 4,721.1 392.2 4,329.0 1,221.2 1,457.8 83.8 1,858.0 03/20/2016 24 165 771.9 1,548.5 209.0 3.454.5 476.2 2,978.3 1,096.3 1,305.2 84.0 2,278.g 03119/7016 24 185 780.4 1,400.1 216.9 3,446.2 441.1 3,005.1 1.128.3 1,345.2 83.9 2033.8 03/1812016 24 185 874.7 1,387.0 248.2 3,399.3 423.1 2,978.2 1,385.0 1,833.2 84.8 1,704.7 03101/2016 24 758.1 1,358.8 59.1 2,717.4 -127.3 2,844.7 832.7 891.8 93.4 -2,153.3 02/0812016 24 761.3 1,452.5 117.2 3,516.8 306.7 3,210.1 872.6 1,089.8 89.2 2,617.5 01/0312016 24 755.6 1.458.1 98.9 3.316.0 159.4 3,158.6 1.044.4 1,143.3 91.4 1,512.8 12/0112015 24 754.0 1,483.6 128.9 3,584.7 234.2 3,330.5 880.8 1,009.7 87.2 1.817.3 11/01/2015 24 749.8 1,480.9 177.0 3.461.2 185.4 3,275.8 1.029.3 1,208.2 85.3 1,047.4 With this success we would like to move towards conducting this as a scheduled event to help keep the well unloaded. Requested Flare Schedule Frequency: Once per month (during 2nd welltest each month) Duration: 4 hours Expected Flare Rate: 0.3 MMscf per hour Expected Flare Vol: ^'1.2 MMscf per event We are aiming to have the more frequent intervals to keep the overall duration shorter each time. Reporting The reporting would fall under the normal flare volume reports already submitted. Attached are previous month's total flare volumes and the 12 month rolling average. All daily and 12 month rolling averages would be maintained under the flare limitations as per our air permit. 1 • • If any further details on the well's unique wellbore configuration and challenges this completion poses or any questions with anything in the request please let me know and I will provide additional details. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, March 17, 2016 5:24 PM To: Taylor Wellman Cc: Loepp, Victoria T(DOA) Subject: RE: NS-33A(PTD #208-189/ API #50-029-23325-01) Request Flare to Unload Got it..thanks for the insite. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at(907-793- 1226 )or(Guy.schwartz@alaska.gov). From:Taylor Wellman [mailto:twellman@hilcorp.com] Sent:Thursday, March 17, 2016 3:51 PM To:Schwartz,Guy L(DOA) Cc: Loepp,Victoria T(DOA) Subject: RE: NS-33A(PTD#208-189/API#50-029-23325-01) Request Flare to Unload Guy, The piping is using the test separator header.The production header runs at^'750psi.The test separator can be run at 3 different backpressures: -750psi+.This routes the gas and liquids back into the normal 15t stage separation in the facility. -350-750psi. A jumper was installed to allow all production(fluids&gas)to be pushed down the liquid leg and routed into the 2"d stage separation in the facility.The downside to this is to continuously flow the well at this pressure,the test separator is completely taken by this well. -0-350psi.The gas leg of the separator is taken to flare and the liquids are routed to the well clean up tank and recovered. At all times,all the production is kept in permanent piping and does not require special temporary hardline to do this. 2 • 0 Thanks, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From:Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, March 17, 2016 3:39 PM To:Taylor Wellman Cc: Loepp,Victoria T(DOA) Subject: RE: NS-33A(PTD#208-189/API #50-029-23325-01)Request Flare to Unload Taylor, Approval granted to flow well NS-33A and flare up to 2mmscf gas (8 hour flow period). As stated below report flared gas in monthly gas disposition report. What is your flowback piping look like? How does this decrease the FTP so you get more drawdown? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at(907-793- 1226 ) or(Guv.schwartz@alaska.gov). From:Taylor Wellman [mailto:twellman@hilcorp.com] Sent:Thursday, March 17, 2016 11:18 AM To:Schwartz,Guy L(DOA) Subject: NS-33A(PTD#208-189/API #50-029-23325-01) Request Flare to Unload Guy, Northstar well NS-33A(PTD#208-189/API #50-029-23325-01) is a well that has a long stepout(reaches^'70 deg from 3600'—21,000' md), high water cut(-90%)and very inefficient artificial lift capabilities (deepest GLM @ 2934' md/2413' tvd). A schematic is included for reference. Over a period of months the well loads up and slowly kills itself while in the normal production header.We have been able to keep the well flowing by various means: backflushing, shut in and allow water to drain back into reservoir, or flow through our test separator at medium pressure for most of the month but all these have not been very effective in clearing the water from the tubing.The most effective way we found was to have a short term flaring period (with prior approval)to unload this well. 3 • • We would like to request flowing through the test separator and flaring the gas to unload for a period of up to 8 hours. The max expected total gas volume during this timeframe is^2mmscf.All true volumes would be recorded and submitted in the normal reports. All liquids will be captured through the test separator and routed through the well clean up tank. Thank you and please contact me with any additional information needed, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com 4 • • Maximum Daily Monthly 12-Month Flare Volume Volume Rolling Volume Limit 200.5 - 1,332.00 Units MMscf MMscf MMscf Nov-14 0.47 2.6 116.0 Dec-14 7.82 75.6 181.1 Jan-15 2.924 15.9 189.0 Feb-15 2.916 10.0 193.9 Mar-15 1.673 10.1 198.5 Apr-15 3.641 15.9 194.9 May-15 3.781 17.5 202.2 Jun-15 12.866 18.7 215.2 Jul-15 0.978 7.5 194.9 Aug-15 4.829 16.6 202.2 Sep-15 1.578 7.7 215.2 Oct-15 2.654 10.3 70.2 Nov-15 0.333 6.1 76.4 Dec-15 1.234 8.6 85.0 Jan-16 0.408 5.80 85.33 Feb-16 0.409 5.60 90.93 Mar-16 0.891 6.67 97.59 1 0 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. aC i3 - 1 0 9 Well History File Identifier Organizing (done) Two -sided 111 111 11111111111 ❑ Rescan Needed 1!! !lull 111 II! RE AN DIGITAL DATA OVERSIZED (Scannable) 7 Gr for Items: ❑ Di ettes, No. ❑Maps: eys cale Items: Other, No/Type: G No, 1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: /or BY: Maria Date: a /s/ Project Proofing III 1111111 I III I BY: ACM Date: 41 1gill /s/ yV) Scanning Preparation s ii l x 30 =, `t' O + , w = TOTAL PAGES (Count does not include cover sheet) BY: Maria Date:. ! 7 // I /s/ Production Scanning 1111111111111 II II Stage 1 Page Count from Scanned File: D.5 (Count does include cover sheet) Page Count Matches Number in Scanning Pr paration: V YES NO BY: WO Date: / 7 1/ /s/ pop 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. I I I III ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111111111111111111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/8/2011 Permit to Drill 2081890 Well Name /No. NORTHSTAR UNIT NS -33A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23325 -01 -00 MD 26090 TVD 11350 Completion Date 5/22/2009 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: USIT / CCL, MWD, DIR, GR, RES, OWD, DWOB, DTOR, ACAL, DEN (data taken from Logs Portion of Master Well Data Maint • Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med /Frmt Number Name Scale Media No Start Stop CH Received Comments pt Report: Final Well R Open 6/18/2009 End of Well Report, Gen Info, Daily Summ, Morn Reps, Bit Rec, Mud Reps, Show Reps, Form Tops, Days vrs Depth, Survey Rec �D C 18175 ''keport: Final Well R Open 6/18/2009 End of Well Report, Gen Info, Daily Summ, Morn Reps, Bit Rec, Mud Reps, Show Reps, Form Tops, Days vrs Depth, Survey Rec w /PDS graphics for Mud Logs og Mud Log 2 Col 15060 26090 Open 6/18/2009 MD Formation Log Ilk o• , Mud Log 5 Col 15060 26090 Open 6/18/2009 MD Formation Log og Mud Log 2 Col 15060 26090 Open 6/18/2009 MD Drilling Dynamics og Myd Log "5: Col 15060 26090 Open 6/18/2009 MD acs D C Lis 18176 Induction /Resistivity 684 26089 Open 6/18/2009 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, RAM, NPHI, TRPM og - Induction /Resistivity 25 Blu 15000 26045 Open 6/18/2009 MD Vision Service ' og Caliper log 25 BIu 15000 26045 Open 6/18/2009 ROP, RES, Dens Caliper(Vert), Dens Caliper(Horiz) DATA SUBMITTAL COMPLIANCE REPORT 2/8/2011 Permit to Drill 2081890 Well Name /No. NORTHSTAR UNIT NS -33A Operator BP EXPLORATION (ALASKA) INC API No. 50 -029- 23325 -01 -00 MD 26090 TVD 11350 Completion Date 5/22/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N og Induction /Resistivity 25 Blu 15000 26045 Open 6/18/2009 TVD Vision Service og Pressure OTH Col 25567 26045 Case 6/18/2009 StethoScope475, Formation Pres while drilling FINAL 19- Apr -2009 ED C Pds 18188 Pressure 25567 26045 Case 6/18/2009 StethoScope475, • Formation Pres while - drilling FINAL 19- Apr -2009 Log Cement Evaluation 5 Col 200 14100 Case 6/18/2009 USIT, Corrosion Eval, GR, CCL, GPIT 14- Apr -2009 ED C Pds 18189 Cement Evaluation 200 14100 Case 6/18/2009 USIT, Corrosion Eval, GR, j CCL, GPIT 14- Apr -2009 L%g Temperature 5 Blu 0 11995 Case 8/10/2009 Temp Survey, UMT, GR< CCL, Pres, Temp 12-Jul- 2009 D C Las 18407 dfemperature 0 12003 Case 8/10/2009 Temp, Pres, CCL, GR ED C Lis 19176 ✓Feservoir Saturation 25532 15888 Case 1/13/2010 LIS Veri, RST, GR Log 19183 Reservoir Saturation 5 Blu 25873 25900 Case 1/13/2010 RST, WFL, PBMS, PILS I og Temperature 5 Blu 25380 25970 Case 1/13/2010 Mem Press - Temp Surv, PSP, CCL, GR ED C Pds 19184°'Temperature 25380 25970 Case 1/13/2010 Mem Press - Temp Surv, PSP, CCL, GR D C Directional Survey 0 26090 Open IIII *t Directional Survey 0 26090 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/8/2011 Permit to Drill 2081890 Well Name /No. NORTHSTAR UNIT NS -33A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23325 -01 -00 MD 26090 TVD 11350 Completion Date 5/22/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL INFORMATION Well Cored? Y t Daily History Received? N Chips Received? ¥41.N1-' Formation Tops Analysis ' TIT- • Received? Comments: ` Date: ` r' l Compliance Reviewed By: • • • bp BP Exploration (Alaska) Inc. _ Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 April 21, 2010 RECFPVED Mr. Tom Maunder MAY 0 5 2010 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue inks0181Giscons.commosion Anchorage, Alaska 99501 Anderele Subject: Corrosion Inhibitor Treatments of Northstar r1 ©$ 1 Dear Mr. Maunder, 6' .83 Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. N.. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Northstar Date 4/20/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020'70 50026230810000 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020'210' 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 _ na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 * na * na 2.6 5/2/2009 NS -26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 na * na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 I na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. • 1 bp Date: 01 -04 -2010 0 Transmittal Number: 93120 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Joe Lastufka at (907)564 -4091 Delivery Contents Bottom SW Name Date Contractor Run Top Depth Depth Description MEMORY PRODUCTION NS34A 12 -20 -2009 SCH 1 16000 19082 PROFILE PSP fq 1 CD -ROM - MEMORY NS34A 12 -20 -2009 SCH PRODUCTION PROFILE PSP MEMORY PRODUCTION 00 NS22 12 -16 -2009 SCH 1 12208 12826 PROFILE PSP 1 8135 CD -ROM - MEMORY NS22 12 -16 -2009 SCH PRODUCTION PROFILE PSP 9 0M/el CD -ROM - LDWG EDIT OF RST a NS33A DATA IN TIF FORMAT, NS33A 11 -10 -2009 SCH 25482 15961.5 WITH FINAL PDS DISPLAYS MEMORY PPROF WITH DEFT -1ist NS20 12 -15 -2009 SCH 1 17452 18489 AND GHOST Mi CD -ROM - MEMORY PPROF NS20 12 -15 -2009 SCH WITH DEFT AND GHOST MEMORY PPROF WITH DEFT .t NS21 12 -12 -2009 SCH 1 20520 22184 AND GHOST /91'n CD -ROM - MEMORY PPROF NS21 12 -12 -2009 SCH WITH DEFT AND GHOST { t Please ign d Re one copy of this transmittal. Thank You, ''', i Joe Lastufka Petrotechnical Data Center BPXA David Fair AOGCC Christine Mahnken DNR / Corazon Manaois Murphy Exploration Ignacio Herrera MMS Doug Chromanski ( Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage. AK 99519 -6612 STATE OF ALASKA (" NED -- ALASIPOIL AND GAS CONSERVATION COMMISSN REPORT OF SUNDRY WELL OPERATIONS _ :, ' 1 y in 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate h -, Performed: Alter Casing ❑ Pull Tubing El Perforate New Pool 10 Waiver ❑ Time A � lit `ti" t.: _.. c,. , L 40111f4 i;;Sii *.- Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0' Re nter Suspended WC] 4: ° .'. ~t 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development la Exploratory ❑ 208 -1890 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ API Number: Anchorage, AK 99519 -6612 50- 029 - 23325 -01 -00 8. Property Designation (Lease' umber) : 9. Well Name and Numb \ ADLO- 312799 \ NS33A , 10. Field/Pool(s): \ NORTHSTAR FIELD / NORTHSTAR OIL POOL 11. Present Well Condition Summary: Total Depth measure` 26090 feet Plugs (measured) None feet true vertical, 11349.52 feet Junk (measured) None feet Effective Depth measured 26090 feet Packer (measured) 23170 25409 25744 25841 true vertical 13349.52 feet (true vertical) 8869 10747 11046 11132 Casing Length Size MD TVD Burst Collapse Structural Conductor 190 24" 245.6# X -56 SURFACE - 190 SURFACE - 190 2436 Surface 4472 16" 84# HCL -80 SURFACE - 4472 SURFACE - 3194 4335 1479 Intermediate 15037 11 -3/4" 60# s -95 SURFACE - 15037 SURFACE - 6566 6916 3436 Liner 9299 8 -5/8" 32# 1 -80 14241 - 23450 6315 - 9152 5713 3045 Liner 15605 6 -5/8" 24# 1 -80 9977 - 25582 4963 - 10902 7438 5765 Liner 2748 4 -1/2" 12.6# 13cr80 23170 - 25918 8869 - 11200 8424 7496 Perforation depth: Measured depth: SEE ATTACHEQ - _ _ _ True Vertical depth: L ._ � _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR95 SURFACE - 23162 SURFACE -8864 3 -1/2" 9.2# 13CR80 23162 -23293 8864 -8958 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BKR ZXP PKR 23170 8869 4 -1/2" SWELL PKR 25409 10747 4 -1/2 "SWELL PKR 25744 11046 4 -1/2 "SWELL PKR 25841 11132 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 911 2185 2844 329 Subsequent to operation: 14. Attachments: , Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Servic❑ Daily Report of Well Operations X 6. Well Status after work: Oil Ei Gas ❑ WDSPL ❑ G TOR ❑ WAG ❑ GINJ ❑ WINJ❑ 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: 309 -402 Contact Gary Preble Printed Name Gary Preble / Title Data Management Engineer Signature . AllW� Phone 564 -4944 Date 1/12/2010 Form 10-404 Revised 7/2009 RBDMS JAN 1 4 201 / - /5. / Submit Original Only NS33A 208 -189 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS33A 5/20/09 SL / 25,778. 25,834. 11,076.3 11,125.92 NS33A 1/9/10 APF ✓ 25,785. 25,830. 11,082.5 11,122.37 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET • FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • NS33A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY y2717 t.;441114."` 1/7/2010; Prep for E -Line Assistance. (Perforating) Heat 350 bbls of seawater mixed with 110 gallons of Safe Lube and 20 gallons of Defoam -X. 1/7/2010 ' *WELL FLOWING ON ARRIVAL * ** (E -LINE WELLTEC TRACTOR/PERFORATING) TRIGGING UP E -LINE UNIT IN PROGRESS. I ** *JOB CONTINUED ON 8- JAN -10 * ** 1/8/2010 T/I/O = 660/1952/83 Assist E -Line (Perforating) Pumped a 3 bbl neat methanol spear followed by 350 bbls of Sea Water mixed with 110 gallons of Safe -Lube and 20 gallons of Defoam X followed by a 10 bbl neat methanol flush. Final [ WHP's = 650/1990/13 Turn well back over to E -Line. 1/8/2010 ** *JOB CONTINUED FROM 7- JAN -10 WSR * ** (E -LINE WELLTEC 'TRACTOR/PERFORATION) FINISHED RIGGING UP SURFACE EQUIPMENT. [ ILRS PUMP 350 BBLS SAFELUBE (SEE LRS LOG) 1CURRENTLY MAKING UP TRACTOR & PERF GUNS. ** *JOB CONTINUED ON 8-JAN-10 WSR*** 1/9/2010* *JOB CONTINUED FROM 8- JAN - 2010 * ** (E -LINE WELLTEC 1 TRACTOR/PERFORATION) RAN WELLTEC TRACTOR & 45' x 2" POWER JET OMEGA HSD PERF GUNS PERFORATED INTERVAL = 25,785' - 25,830' 'PENETRATION = 22 ", ENTRANCE HOLE = 0.22 ", CHARGE = 7.3G HMX USED THE FOLLOWING LOGS FOR TIE IN: (REF LOG = SLB. GR/RESISTIVITY DATED 16- APRIL -2009) ;(TIE IN LOG = SLB. RST/WATER FLOW LOG DATED 10 -NOV -2009) CURRENTLY PULLING OUT OF HOLE [ ** *JOB CONTINUED ON 10- JAN -2010 WSR * ** 1/10/2010; ** *JOB CONTINUED FROM 9- JAN -10 * ** (E -LINE WELLTEC TRACTOR/PERFORATION) PULLED OOH W/ TRACTOR & PERF GUNS. ALL SHOTS FIRED. RECOVERED ALL TOOLS. FINAL T /I /0= 900/2120/0 ** *JOB COMPLETE , GIVE WELL BACK TO N* * ** .__ PUMPED BBLS 17 METH 350 SEAWATER MIXED WITH 110 GLS SAFELUBE AND 20 GLS DEFOAM X 367 Total TREE = ABB - VGI 51/8" 5k SAFETY S: *4-1/2" CHROME TBG /LNR & WELLHEAD =ABB - VGI 13 5/8 "' . JEWELRY* ** CAUTION: 11-3/4" PACKOFFS MAX TEST ACTUATOR = 3500 PSI DUE TO COLLAPSE RATING OF 11 -3/4" CSG; KB. ELEV = 56.6 MIN IAP =1750 PSI DUE TO TRAPPED ANNULUS LEFT BF. ELEV = 0 FROM WELL CONSTRUCTION BETWEEN 6 -5/8" & 11- KOP = 300 3/4 SEE DW F OR ADW MOC 143 Max Angle = 78 @ 16261' NIP Datum MD = 25755' 1 1 1002' H 4.5" SLB TRMAXX -5E TRSSSV w /3.812" X Profile Datum TVD = 11000' SS / ST MD TVD DEV TYPE VLV LATCH PORT DATE 16" CSG, 844, HCL -80, BTC, ID= 15.010" 4472' , , 1 2808 2513 50 MMG DMY RK 05/21109 111 3/4" Whipstock H -15050 , ( 2922' 4.5" HES "X" Nipple Superl3Cr, D = 3.813" 1 L 9976' H11-3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR '''.% " ; 14241' 11 -3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR 11 3/4" HES EZSV — 15076 _ c L 14273 H9-5/8" X 8 -5/8" XO, ID = 8.6" 1 ' /2 13Cr95 12.6 #, 3.833" Drift - -6,500 m ID = 2. 20" 2 28 :`�� ��� ..�_ 6 -5/8" 24 #, L -80, HYD521 Scab Minimum 9 @ 3 0 ;,!r LNR (TOC -11,000' MD) TOP OF 3 -5/8" SEAL ASSY wIBALL SEAT SUB ', Note: When shearingout ball seat only 4 bbls maximum should be Estimated 10 5/8" CSG PBTD H 16243' I bull headed away to avoid push - li 39 BBLS placed on top of Retainer Ili, Ing away any oil behind the 4-1/2" CBU performed at 16,243' in green cement` production liner before the swell fi packer fully sets above the 6 -5/8" 11 3/4" HES EZSV Cement Retainer H 16415' 1 �F shoe, 4 bbls will push the ball `, " _ and seat —250' and to the lowest well bore inclination of —34deg. It 111 3/4" Csg, 60# S Hydril 563. ID = 10.772" 16491' ra a = will be able to fall the remaining -: lei distance to the rathole TD. -- 22,867' Est TOC 274 BBLS Squeezed below Retainer -2,431 feet ! ' * equivalent within 10 -5/8" hole or -18,846' MD ' . > �" NS33 KOP - 21,82: ' _ .", - NS33PB1 - 23,236' 1 , 4 -1/2" 12.6 #, 9Cr, X Nipple NS33 - 23,460' . m ID = 3.813" @ 23,005' 1 4 -1/2" 12.6 #, 9Cr, XN Nipple 14 1/2" TBG, 12.6 #, 13CR95 STL, ID = 3.958" 23162' 161 t I D = 3.725" @ 23,109' =� 4 -1/2" x 3 -1/2" XO, 7" 38# x 4 -1/2" BKR ZXP PKR/FL HGR w /Tieback 23170' / ID = 2.992" @ 23162' 13 1-2" TBG, 9.24, 13CR80 STL, ID = 2.992" H 23293' ` 3-1/2", 13Cr80 Baker 3 -5/8" Seal Assy with Bull Nose 16 5/8" Scab LNR, 24# L -80, Hydril 521. ID = 5.92" H 23359' Ball Shear sub with 2.50" ball 16 5/8" BKRTieBack Sleeve L -80 H 23341' I in place (2700psi to shear) @ 23,293', ID = 2.92" 8 5/8" LNR, 32# L -80, Hydril 521. ID = 7.921" 23540' 4- /2" Liner will have 2 x Baker 14 1/2" Swell Packer ID = 3.958" H 25409' PB` -'s below the liner hanger 16 5/8" LNR, 24# 13Cr80 / L -80, Hydril 521. ID = 5.92H 25582' , �` 5/$" Liner Lap Leaking Isolating Kuparuk from Sag (4 1/2" Solid LNR, 12.64, 13Cr 80,VamTop ID= 3.958' 25775' 1 ' g with a Swell Packer © — 25,409' � 4 112" Swell Packer ID = 3.958" H 25744' /, Top Kuparuk 23,367' 4 1/2" Slotted LNR ,12.6 #,13Cr- 80,VamToplD= 3.958'H 25834' (/ Top Sag River 25,574' 4 1/2" Sw ell Packer ID = 3.958" H 25841' 1 14 1/2" Solid LNR, 12.6 #, 13Cr- 80,VamTop ID= 3.958'H 25918' 1 DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/08 KWA SUSPENDED (NS33) WELL: NS - 33A 10/30/08 KWA NS33 P &A PERMIT No: ? ?? 05/20/09 N33E SIDETRACK (NS33A) I API No: 50 - 029 - 23325 - - 06/05/09 TLH HANDOVERCORRECTIONS SEC:11, T13N, R13E, 1369' FSL, 650' FEL 06/09/09 ATD /SV SAFETY NOTE BP Exploration (Alaska) • . Date: 12 -17 -2009 Transmittal Number: 931 14 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Joe Lastufka at (907)564 -4091 Delivery Contents Bottom SW Name Date Contractor Run Top Depth Depth Description MEMORY PRESSURE/ NS33A 11 -11 -2009 SCH 1 25380 25970 TEMPERATURE SURVEY CD -ROM - MEMORY PRESSURE/TEMPERATURE _NS33A 11 -11 -2009 SCH SURVEY a te; o9 MEMORY PPROF WITH DEFT NS05 11 -16 -2009 SCH 1 13101 13921 AND GHOST /9/31' CD -ROM - MEMORY PPROF NS05 11 -16 -2009 SCH WITH DEFT AND GHOST MEMORY PRODUCTION NS11 11 -20 -2009 SCH 1 14008 14616 PROFILE WITH DEFT CD -ROM - MEMORY ( , 6 N % PRODUCTION PROFILE WITH NS11 11 -20 -2009 SCH DEFT NS11 11 -20 -2009 SCH 1 13978 14614 MEMORY SBHPS NS11 11 -20 -2009 SCH CD -ROM - MEMORY SBHPS MEMORY PPROF WITH DEFT 4 NS30 11 -19 -2009 SCH 1 15495 16195 AND GHOST , �� CD -ROM - MEMORY PPROF NS30 11 -19 -2009 SCH WITH DEFT AND GHOST --�' RESERVOIR SATURATION A NS33A 11 -10 -2009 SCH 1 200 25873 AND WATER FLOW LOG 10 CD-ROM - RESERVOIR 5 SATURATION AND WATER 2C •6 `6% '6a NS33A 11 -10 -2009 SCH FLOW LOG ) Petroteehnical Data Center 2 -1 900 E n B p i ri 70 19! Anchorage, A K 99519 -6612 ,_ ,,. • I p ih\k, k d ‘11:1 � \ \ ` r t ', SEAN PARNELL, GOVERNOR ALASKA OIL AIVI) GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMi1IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Mr. Mark Sauve Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 t gq o c6 Re: Northstar Field, Northstar Oil Pool, NS33A Sundry Number: 309 -402 Dear Mr. Sauve: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Chair 1/4 DATED this 0day of December, 2009 Encl. H STATE OF ALASKA Q 1 ( c/�•�-G� ' ��� A LASWOIL AND GAS CONSERVATION COMMIS 111 APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cons. COMITII sp•: 20 AAC 25.280 Aneharnpo. 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate Ei .- Re -enter Suspended Well ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑ Specify: Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 Exploratory ❑ 208 -1890 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23325 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El NS33A 9. Property Designation (Lease 10. Field /Pool(s): /. ADLO- 312799 3 .Z 79S- NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 26090 - 11349.52 • 26090 - 11350 '- NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 190 24" 245.6# X -56 Surface 190 Surface 190 2436 Surface 4472 16" 84# HCL -80 Surface 4472 Surface 3194 4335 1479 Intermediate 15037 11 -3/4" 60# S -95 Surface 15037 Surface 6566 6916 3436 Liner 9299 8 -5/8" 32# L -80 14241 23450 6315 9152 5713 3045 Liner 15605 6 -5/8" 24# L -80 9977 25582 4963 10902 7438 5765 Liner 2748 4 -1/2" 12.6# 13CR -80 23170 25918 8869 11200 8424 7496 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SL 25778' - 25834' 11076' - 11126' 4 -1/2" 12.6# 13CR95 SURFACE - 23162' 3 -1/2" 9.2# 13CR80 23162'- 23293' Packers and SSSV Tvoe: 4 -1/2" BKR ZXP PKR Packers and SSSV MD and TVD (ft): 23170 8869 4 -1/2" SWELL PKR 25409 10747 4 -1/2" SWELL PKR 25744 11046 4 -1/2" SWELL PKR 25841 11132 12. Attachments: Description Summary of Proposal ig 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/17/2009 Oil El _ Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Mark Sauve Title Production Engineer /4 Signature Phone Date 564 -4660 12/3/2009 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY �1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 —1/w Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /Q • '/0 9 ` APPROVED BY Approved by , i C THE COMMISSION Date: / / / Q/ 7 • 1, I • �- 10 ,,,,- men J7R00 ► ` I GI N 7 /G • 7 0 7 Submit in Duplicate • • PERFORATING PROCEDURE Ver4006`0"0' ROW fYMYMIWwa111atl Well: NS33A API #: 50-029 - 2332501 Date: 12/2/09 Prod Engr Mark Sauve Office Ph: 564 -4660 H2S Level: Home Ph: 336 -6128 4 ppm Cell Ph: 748 -2865 CC or AFC: NSFLDWL33 Detail Code: Description: Add -Pert WBL Entries IOR Type Work Description I 500 I E IRe- perforate 25,785' - 25,830' MD - - Well Objectives and Logging Notes: NS33A is a 2009 development well at Northstar. Initial production peaked at 3000 bopd and has been decreasing since. The proposed Add -Perfs are an attempt to increase production by perforating past any damage and increase production. Please contact Mark sauve with any questions, comments, or concerns - 564 -4660 (w); 748 -2865 (c); 336 -6128 (h). Reference Log Tie in Log Add/Subtract feet Log: GR/Resistivity to the tie-in log to be on Date: 4/16/2009 depth with the reference log. Company: Schlumberger Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 25,785 - 25,830' - 45' 6 60° 0 Ivishak AddPerf 0 0 0 Gas Jetting Expected? No At what Depth? N/A Requested Gun Size: 2.0" Omega Charge: 7.39 HMX Desired Penetration: 22" Entry Hole Diam: 0.22 Is Drawdown Necessary/Desired/Unnecessary During Perforating Drawdown desirable but not necessary Describe below how to achieve drawdown (check w/ Pad Operator to see it necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) Tie in to Jewelry @ MD Tie in using: Minimum ID: 2.992 in Min ID Type: 4.5' x 3.5" crossover @ 23,293 'MD WLEG Depth: N/A ft MD Casing Size: 4.5 in 12.6# 13 -CR Liner Est Res. Pres. CO 25,871 MD 11100' SS 5,125 psi Last Tag: 25,900 ft SLMD on 11/12/2009 2" logging tool Well: NS33A Perforation Summary Date: API #: 50-029- 2332501 On -Site Prod Engr: PBTD General Comments: Depths Balance Referenced to BHCS Feet SPF Orient. Phasing Zone Aperf/Reperf 0/B/U - O O /B /U - O O /B /U - O O /B /U - 0 /B /U - O TREE= ABB VGI51/8" 5k SAFETY TES: `4 -1/2" CHROMETBGILNR& WELLHEA*= ABB - VGI 13 5/8" DRLG DR.' N S 33A JEWEL CAUTION: 11 -3/4" PACKOFFS MAX TEST ACTUATOR = 3500 PSI UE TO COLLAPSE RATING OF 11 -3/4" CSG; KB. 56 ELEV = .6 MIN IAP =1750 PSI DUE TO TRAPPED ANNULUS LEFT 566 BF. ELEV = KOP = 300 FROM WELL CONSTRUCTION BETWEEN 6 -5/8" & 11- 3/4" SEE DW F OR ADW MOC 143 Max Angle = 78 @ 16261' Datum MD = 25755' 1002' H 4.5" SLB TRMAXX-5ETRSSSV w /3.812" X Profile Datum TV D = 11000' SS / A. ST MD TVD DEV TYPE VLV LATCH PORT DATE 16" CSG, 84 #, HCL -80, BTC, ID= 15.010" H 4472' 1 \ 1 2808 2513 50 MMG DMY RK 05/21/09 111 3/4" Whipstock H -15050 1 , 2922' H 4.5" HES "X" Nipple Superl3Cr, ID = 3.813" 1 9976' H11-3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR 14241' H11-3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR 14273 H9-5/8" X 8 -5/8" XO, ID = 8.6" 1 111 3/4" HES EZSV H — 15076 1 'L /2" 13Cr95 12.6 #, 3.833" Drift -6,500 Minimum ID = 2.920" 23280' 6 -5/8" 24 #, L -80, HYD521 Scab LNR (TOC 11,000' MD) TOP OF 3 - 5/8" SEAL ASSY w /BALL SEAT SUB Note: When shearingout ball seat )nly 4 bbis maximum should be 1 Estimated 10 5/8" CSG PBTD H 16243' 1 ull headed away to avoid push - 39 BBLS placed on top of Retainer Ing away any oil behind the 4 -1/2" CBU performed at 16,243' in green cement productn fully s liner before the swell packer fets above the 6-5/8" /8" 1 11 3/4" HES EZSV Cement Retainer H 16415' 1 shoe. 4 bbis will push the ball and seat -250' and to the lowest ,veil bore inclination of - 34deg. It 60# S 95, Hydril 563. ID = 10.772" H 16491' Nill be able to fall the remaining 11 3/4" Cs g' y - Iistance to the rathole TD. 274 BBLS Squeezed below Retainer -2,431 feet - - 22,867 Est TOC equivalent within 10 -5/8" hole or -18,846' MD NS33 KOP - 21,82:'\ NS33PB1 - 23,236' 4 -1/2" 12.6 #, 9Cr, X Nipple NS33 - 23,460' 1 ID = 3.813" @ 23,005' 1 4 -1/2" 12.6 #, 9Cr, XN Nipple 4 1/2" TBG, 12.6 #, 13CR95 STL, ID = 3.958" 23162' . = 3.725" @ 23,109' 4 -1/2" x 3 -1/2" XO, 17" 38# x 4-1/2" BKR ZXP PKR/FL HGR w /Tieback 23170' ID = 2.992" @ 23162' 13 1 -2 °TBG, 9.2 #, 13CR80 STL, ID = 2.992" H 23293' 1 3 -1 /2 ", 13Cr80 Baker 3 -5/8" I ' ` Seal Assy with Bull Nose 16 5/8" Scab LNR, 24# L -80, Hydril 521. ID = 5.92" H 23359' Ball Shear sub with 2.50" ball 6 5/8" BKR TieBack Sleave L -80 H 23341' 1 in place (2700psi to shear) @ 23,293', ID = 2.92" 122/8" LNR, 32# L -80, Hydril 521. ID = 7.921" H 23540' , 4- /2" Liner will have 2 x Baker 4 1/2" Sw ell Packer ID = 3.958" H 25409' 1 _ PB 's below the liner hanger � -1 \ 6 -5/$" Liner Lap Leaking 6 5/8" LNR, 24# 13Cr80 / L -80, Hydril 521. ID = 5.92 25582' Isolating Kuparuk from Sag 4 1/2" Solid LNR, 12.6 #, 13Cr- 80,VamTop ID= 3.958'1- 25775' 1 _ with a Swell Packer / @ -25,409' 1222" Sw ell Packer ID = 3.958" H 25744' 1 ' ' ' 4 1/2" Slotted LNR,12.6 #,13Cr- 80,VamToplD= 3.958' 2 5834' Top Kuparuk 23,367' H 1 / Top Sag River 25,574' 14 1/2" Sw ell Packer ID = 3.958" H 25841' 1 14 1/2" Solid LNR, 12.6 #, 13Cr- 80,VamTop ID= 3.958'1 --1 25918' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/08 KWA SUSPENDED (NS33) WELL: NS -33A 10/30/08 KWA NS33 P &A PERMIT No: ? ?? 05/20/09 N33E SIDETRACK (NS33A) API No: 50- 029 - 23325 -01 -00 06/05/09 TLH HANDOVER CORRECTIONS SEC:11, T13N, R13E, 1369' FSL, 650' FEL 06/09/09 ATD /SV SAFETY NOTE BP Exploration (Alaska) • BPXA WELL DATA TRANSMITTAL Enclosed are the LL_hate ials listed below. If you have any questions, please contact Joe Lastufka at (907)564 -4091 Delivery Contents Bottom SW Name Date Contractor Run Top Depth Depth Description NS33A 07 -12 -2009 PDS 1 0 11995 TEMPERATURE SURVEY CD -ROM — TEMPERATURE NS33A 07 -12 -2009 PDS SURVEY Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center BPXA David Fair AOGCC Christine Mahnken MMS Doug Chromanski DNR Corazon Manaois Murphy Exploration Ignacio Herrera rTh Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519 -6612 NS33A /PTD 208 -189 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Stewman, Sondra D [Sondra.Stewman @bp.com] Sent: Thursday, August 06, 2009 1:19 PM To: Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: NS33A / PTD 208 -189 Gentlemen, Please reference the following well: Well Name: NS33A Permit #: 208 -189 API #: 50- 029 - 23325 -01 -00 Top Perf MD: 25778' (Slotted Liner) Bottom Perf MD: 25834' (Slotted Liner) This well began Production on June 10, 2009 Method of Operations is: Flowing Date of Test: June 9, 2009 Hours Tested: 4 24 -Hour Rate / OiI Bbl: 1408 24 -Hour Rate / Gas -Mcf: 716 24 -Hour Rate / Water -Bbl: 4805 Test Rate / OiI -Bbl: 235 Test Rate / Gas -Mcf: 119 Test Rate / Water -Bbl: 801 Choke Size: 165 Gas -Oil Ration: 508 Flow Tubing Pressure: 798 Casing Pressure: 2045 OiI Gravity -API: Unavailable Sondra Stewman ADW Drilling Technologist Be real, be present and most of all be POSITIVE! 8/6/2009 STATE OF ALASKA N ALASKA AND GAS CONSERVATION COMMIkION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: (Si Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ Suspended 1 b. Well Class: 2OAAC 25.105 20AAC 25.110 0 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ 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. 05/22/2009 208 -189 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519 -6612 02/09/2009 50- 029 - 23325 -01 -00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 04/16/2009 NS33A 1369' FSL, 650' FEL, SEC. 11, T13N, R13E, UM Top of Productive Horizon: 8. KB (ft above MSL): 55.91' 15. Field / Pool(s): 4143' FSL, 1743' FEL, SEC. 32, T14N, R13E, UM Ground (ft MSL): 15.6' Northstar Field / Northstar Pool Total Depth: 9. Plug Back Depth (MD +TVD) 4248' FSL, 1838' FEL, SEC. 32, T14N, R13E, UM 26090 11350 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x- 659821 t y- 6031141 • Zone- ASP4 26090 11350 ADL312799, ADL312798 TPI: x- 642595 y- 6044127 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 642498 • y- 6044230. Zone- ASP4 N/A LO -N96 -006 18. Directional Survey El Yes ❑ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) 39' ft MSL 370' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): USIT /CCL, MWD, DIR, GR, RES, PWD, DWOB, DTOR, ACAL, DEN, NEU, STETH /.11/4440/tie/.5 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE To 1 BOTTOM TOP 1 BOTTOM SIZE CEMENTING RECORD PULLED 24" 245.6# X -56 Surface 190' Surface 190' Driven 16" 84# HCL -80 Surface 4472' Surface 3194' 21" .887 SX ASL, 1906 sx Class 'G' 11 -3/4" 60# S -95 Surface 15037' Surface 6566' 14 -3/4" 1801 sx LiteCrete. 538 sx Class 'G' 8 -5/8" 32# L -80 14241' 23540' 6315' 9152' 10 -5/8" 315 sx Class 'G'. (1.09) 6 -5/8" 24# L -80 9977' 25582' 4963' 10902' 8- 5/8"x7 -7/8" 1128 sx LiteCrete, (2.30), 98 sx 'G', (1.2) 4 - 1/2" 12.6# 13Cr -80 _ 23170' 25918' 8869' 11200' 5 -7/8" Uncemented Slotted Liner 23. Open to production or injection? ® Yes ❑ No 24. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4-1/2" Slotted Liner 4 -1/2" x 3 -1/2 ", 12.6# / 13.5# / 9.2#, 23293' MD TVD MD TVD 13Cr - 80 / 13Cr - 95 25778' 25834' 11076' - 11126' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 1 AMOUNT & KIND OF MATERIAL USED Freeze Protected with 260 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A _ Date of Test: Hours Tested: PRODUCTION FOR OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: TEST PERIOD 4 ` Flow Tubing Casing Press: CALCULATED OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -HouR RATE 27. 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 lit as or water ° (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips , I nd labor yt ,• 2 AAC 250.071. None � a j i✓ i ' ' / ?:� ` jug 4 2009 '�� ' - --A Alaska Oil & Gas Con t,oriimi#"rsio Anchorage Form 10 - 407 Revised 02/2007 CONTINUED ON REVERSE SIDE /PI � l �iK4 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND M ENCOUNTERED): 29. . F ORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost To If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. West Sak 2 12981' 5920' WS2L 13471' 6073' None West Sak 1 14100' 6270' Coville Mudstone 3 16687' 6962' Top Kalubik 23040' 8781' Top Kuparuk D 23367' 9013' Top Kuparuk C 23651' 9244 Top Kuparuk B 23828' 9390' Top Kuparuk A -3 23900' 9450' Top Miluveach 23946' 9489' Top Kingak 24390' 9863' Top Sag River 25574' 10895' Top Shublik 25679' 10989' Top Shublik D 25787' 11084' Top Sadlerochit 25794' 11090' Top Northstar D 25836' 11128' Top Northstar C3 25875' 11162' Top Northstar C2 25928' 11209' Top Northstar C1 25995' 11268' Formation at Total Depth (Name): lvishak / Top Sadlerochit 25794' 11090' 30. List of Attachments: Summary of Daily Drilling Reports and Well Work Summary Report, Well Schematic Diagram, Survey and a Leak of Test Summary. 31. I hereby certify t -t the f• egoing is true and correct to the best of my knowledge. Signed So • ra Stew ig, /s■° Title Drilling Technologist Date( 61 5 NS33A 208 -189 Prepared By Name/Number Sondra Stewman, 564 - 4750 Well Number Permit No. / Approval No. Drilling engineer: Ken Allen, 564 - 4366 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 02/2007 Submit Original Only TREE = ABB -VGI5 1/8" 5k SAFETY ES: *4 -1/2" CHROME TBG/LNR & WELLHEAD = ABB - VGI 13 5/8" JEWELR * CAUTION: 11 -3/4" PACKOFFS MAX TEST ACTUATOR = 3500 PSI DUE TO COLLAPSE RATING OF 11 -3/4" CSG KB. ELEV = 56.6 BF. ELEV = 1002' H 4.5" SLB TRMAXX 5ETRSSSV w /3.812" X Profile 1 KOP = - 300 Max Angle = 78 @ 16261' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum MD = 25755' 1 2808 2513 50 MMG DMY RK 05/21/09 1 1 Datum TVD = 11000' SS / 2922' H 4.5" HES "X" Nipple Superl3Cr, ID = 3.813" I 116" CSG, 84 #, HCL -80, BTC, ID= 15.010" H 4472' 1 il N i 9976' H 11 -3/4" x 9 -5/8" BKRZXP/ Flex Lock PKR/HGR 1 11 3/4" Whipstock H — 15050 1 14241' H 11 -3/4" x 9 -5/8" BKR ZXP/ Flex Lock PKR/HGR 14273 H9-5/8" X 8 -5/8" XO, ID = 8.6" I 4 -1/2" 13Cr95 12.6 #, 3.833" Drift -6,500 111 3/4" HES EZSV H - 15076 1 *T 6 -5/8" 24 #, L -80, HYD521 Scab LNR (TOC -- 11,000' MD) Minimum ID = 2.920" @ 23280' Note: When shearingout ball seat . only 4 bbis maximum should be TOP OF 3 -5/8" SEAL ASSY w /BALL SEAT SUB : $ bull headed away to avoid push- - ing away any oil behind the 4 -1/2" ( Estimated 10 5/8" CSG PBTD 16243' production liner before the swell packer fully sets above the 6 -5/8" 39 BBLS placed on top of Retainer ` ' shoe. 4 bbls will push the ball CBU performed at 16,243' in green cemen x and seat -250` and to the lowest 1 11 3/4" HES EZSV Cement Retainer H 16415' I • m well bore inclination of - 34deg. It will be able to fall the remaining d distance to the rathole TD„ 111 3/4" Csg, 60# S -95, Hydril 563. ID = 10.772" 16491' I , , . — -22,867' Est TOC 274 BBLS Squeezed below Retainer -2,431 feet Q equivalent within 10 -5/8" hole or -18,846' MD NS33 KOP - 21,82:' - z -,r NS33PB1 - 23,236' A 4 -1/2" 12.6 #, 9Cr, X Nipple NS33 - 23,460' ID = 3.813" @ 23,005` ,.. 1 0 4-1/2" 12.6 #, 9Cr, XN Nipple 14 1/2" TBG, 12.6 #, 13CR95 STL, ID = 3.958" H 23162' ` ID = 3.725" @ 23,109' 7" 38# x 4-1/2" BKR ZXP PKR/FL HGR w /Tieback 23170' I 4 1 /2" x 3 -1 /2" ID= 2.992" @ 231 23162' 13 1 -2" TBG, 9.2 #, 13CR80 STL, ID = 2.992" H 23293' 1 3 -1 /2 ", 13Cr80 Baker 3 -5/8" Seal Assy with Bull Nose 16 5/8" Scab LNR, 24# L -80, Hydril 521. ID = 5.92" H 23359 Ball Shear sub with 2.50" ball 16 5/8" BKR TieBack Sleave L -80 H 23341' 1 in place (2700psi to shear) @ 23,293', ID = 2.92" 18 5/8" LNR, 32# L -80, Hydril 521. ID = 7.921" H 23540' 4- /2" Liner will have 2 x Baker 4 1/2" Sw ell Packer ID = 3.958' H 25409' PB - 's below the liner hanger 6 5/8" LNR, 24# 13Cr80 / L -80, Hydril 521. ID = 5.92 25582' ``` 6 518" Liner Lap Leaking Isolating Kuparuk from Sag 14 1/2" Solid LNR, 12.6 #, 13Cr- 80,VamTop ID= 3.958'H 25775' 1 IBI B with a Swell Packer @ -25,409' 4 1/2" Sw ell Packer ID = 3.958" H 25744' 1 /. 14 1/2" Slotted LNR ,12.6 #,13Cr- 80,VamTopID= 3.958'H 25834' I Top Sag River 23,367` Top Sag River 25,574' 1 4 1/2" Sw ell Packer ID = 3.958" H 25841' 4 1/2" Solid LNR, 12.6#, 13Cr- 80,VamTop ID= 3.958 ' H 25918' 1 / DATE REV BY COMMENTS I DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/08 KWA SUSPENDED (NS33) WELL: NS -33A 10/30/08 KWA NS33 P &A PERMIT No: ? ?? 05/20/09 N33E SIDETRACK(NS33A) API No: 50- 029 - 23325 -01 -00 06/05/09 TLH HANDOVERCORRECTIONS SEC:11, T13N, R13E, 1369' FSL, 650' FEL 06/06/09 ATD /SV SAFETY NOTE BP Exploration (Alaska) • BP Page 1 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/25/2009 00:00 - 00:01 0.02 BOPSUF P PRE Pre -Rig charges 00:01 - 01:30 1.48 PULL P DECOMP Lay Down 19 jts. of 4 1/2" NSCT Tubing *Absorbant in Pin and Box end with Thread Protectors to prevent MOB mud from dripping on location 01:30 - 03:30 2.00 PULL N SFAL DECOMP Bolts on Top of elevators sheared when plate that held inserts was set down on top of tubing collar. - Repair Elevators with Replacement from NOC in Deadhorse 03:30 - 06:00 2.50 PULL P DECOMP Lay Down 31 jts. of 4 1/2" NSCT Tubing *Absorbant in Pin and Box end with Thread Protectors to prevent MOB mud from dripping on location 06:00 - 07:00 1.00 PULL P DECOMP Rig Down Tubing Handling equipment and clear floor of excess equipment. -Clean MOB off Floor 07:00 - 08:00 1.00 CLEAN P DECOMP Set Wear Bushing -10 13/16" ID 08:00 - 10:00 2.00 CLEAN P DECOMP Make up 10 5/8" used rock bit, Boot Basket, Float Sub, Full Gauge string mill, XO, 1 x 5" HWDP, Jars 10:00 - 11:30 1.50 CLEAN P DECOMP Reprogram Top Drive PLC Board 11:30 - 12:30 1.00 CLEAN P DECOMP Finish Picking 5" HWDP 1 x 1 -Total of 17 joints and jars 12:30 - 14:30 2.00 CLEAN P DECOMP Pick 5" S -135 19.5# Drill Pipe 1 x 1 14:30 - 16:00 1.50 CLEAN P DECOMP PJSM -Slip and Cut Drilling Line 16:00 - 19:00 3.00 CLEAN P DECOMP Pick 5" S -135 19.5# Drill Pipe 1 x 1 19:00 - 20:30 1.50 CLEAN P DECOMP CBU 3 x -PJSM -Break Circ slowly @ 200 gpm to establish flow -Stage up to 550 gpm / 980 psi 110 PUW / 100k Sow / 102k Mud wts fluctuated 7.8 to 8.2 ppg, very little barite in fluid 20:30 - 00:00 3.50 CLEAN P DECOMP Pick 5" S -135 19.5# Drill Pipe 1 x 1 - training Rig Personnel on CanRig Tq -Matic Wrench (T2) 1/26/2009 00:00 - 04:30 4.50 CLEAN P DECOMP Pick Up 5" S -135 19.5# Drill Pipe 1 x 1 to 7000' and - training Rig Personnel on CanRig Tq -Matic Wrench (T2) 04:30 - 07:30 3.00 CLEAN P DECOMP Circulate and Condition MOB Mud -CBU 3 x -Break Circ slowly to establish flow -Stage up to 650 gpm / 1980 psi -80 rpm / 6000 ft/Is Torque -Final circ rate 700 gpm / 1820 psi 120 rpm / 7000 ft/lbs Torque 140 PUW / 100k SOW / 120k RtWt Mud wts fluctuated 7.9 to 10.5 ppg 07:30 - 09:00 1.50 CLEAN P DECOMP Pick Up 5" S -135 19.5# Drill Pipe 1 x 1 to 7396' and -Mud U- Tubing and flowing back out Drill Pipe 09:00 - 09:30 0.50 CLEAN P DECOMP Service TDS, Draw Works, Blocks & T2 -build weight pill 20 bbl 11.9 ppg pill -pump dry job to balance mud 09:30 - 16:30 7.00 CLEAN P DECOMP Pick Up 5" 5-135 19.5# Drill Pipe 1 x 1 to 11000' and 16:30 - 21:00 4.50 CLEAN P DECOMP Circulate and Condition MOB Mud -CBU 3 x -Break Circ slowly to establish flow -650 gpm / 3280 psi Printed: 6/3/2009 3:57:48 PM • BP Page 2 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/26/2009 16:30 - 21:00 4.50 CLEAN P DECOMP -120 rpm / 10,000 ft/Ibs Torque -Final Circ. Rate @ 650 gpm / 2800 psi (circ. at max to keep mud in trough going to L Pit bypass) 182 PUW / 121k SOW / 141k RtWt Mud wts fluctuated 9.1 to 11.9 ppg Metal shavings in cuttings during 1st bottoms up 21:00 - 22:00 1.00 CLEAN P DECOMP Test Kill Line going to the BOP's -Test to 5000 psi with water, Good Test 22:00 - 00:00 2.00 CLEAN P DECOMP Pick Up 5" S -135 19.5# Drill Pipe 1 x 1 to 12151' and -Rig Personnel on CanRig Tq -Matic Wrench (T2) 1/27/2009 00:00 - 06:30 6.50 CLEAN P DECOMP Pick Up 5" S -135 19.5# Drill Pipe 1 x 1, tagged at 16254' and 06:30 - 15:00 8.50 CLEAN P DECOMP Circulate and Condition MOB Mud at 525 gpm / 4100 psi, limited out on highline power, warm up 399 cats -CBU 3 x -Break Circ slowly to establish flow -125 rpm / 19,000 ft/Ibs Torque -Final Circ. Rate at 600 gpm / 4030 psi (circ. at max to keep mud in trough going to L Pit bypass) 265 PUW / 100k SOW / 170k RtWt Mud wts fluctuated 9.8 ppg - 13.0 ppg 1st Btms Up - Shaker screens blanking off with 80% metal shavings, MW out 13.0 ppg, mud thinned out and returns cleaned up after first btm's up Online with rig Gen 1 and 4 to assist highline power Second Btms Up - returns showed about 10 %metal, MW out 9.8 ppg, 560 gpm / 3950 psi, 127 rpm Third Btms Up - returns showed about 10% metal, MW out 10.5 - 12.5 ppg, 600 gpm / 4200 psi, 127 rpm Fourth Btm's Up - hole clean, MW in / out 10.1 ppg - 9.9 ppg, 600 gpm 3850 psi 15:00 - 15:30 0.50 CLEAN P DECOMP Circ while holding PJSM with mud eng, rig and G and I personnel, reviewed operational procedure, assigned and discussed specific job assignments, checked valve alignments and established good communication 15:30 - 16:00 0.50 CLEAN P DECOMP Circ while walking through job assignments, empty trip tank to pits, preparing to displace well to seawater with 1% safe lube 16:00 - 21:30 5.50 CLEAN P DECOMP Pump and emptied MOB mud from pits followed by OBM Spacer - 60 bbls LVT Base Oil Transition Spacer - 200 bbls water, 2 ppb Duovis, Weighted to 13.0 with bar, 5 drums Safe Solve OM (6 %v /v), 3 drums Safe Surf 0 (this will change the filter cake to wet ability from oil to water wet) Surfactant Spacer - 195 bbls of water treated with 5 drums Safe Surf 0 (this cleans the well bore) Printed: 6/3/2009 3:57:48 PM • ���| BP ' Page 3 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To V� Phase � '— �� Description 1/27/2009 10:00 21r0 5.50 CLEAN P DECOMP Viscous Space 150 bbls water with 2 ppb Duovis Seawater displacemertt with 1 % Safe Lube @ reduced rate as not to overload G&I & drag chain. '3oo gpm 11nopsi. -125 rpm, TQ19k -Up Nt2*Ok Dn Wt. 14ok Fn Wt. 1esx Torque increased to 26k 17000 stokes into displacement, increased Safe Lube concentration to 2% to combat torque 21:30 - 00:00 2.50 CLEAN P DECOMP -Clean seawater to surtace @ 29000 strokes, line U 10 active pits system and increase pump rate to 600 gpm 1970 psi. -Continue to circulate conditioning seawater to 2% Safe Lube concentration to surface. -Unable to rotate drill string without pipe movement. Suspend rotation. Mobflizing EP mud lube sweep. -Attempt to rotate drill string with 2% Safe Lube to surface, 26k TO with pipe movement, Unable 10 rotate without pipe movement. -Up Wt 240k, Dn Wt 140k 1/202008 00:00 - 03:30 3.50 CLEAN P DECOMP -Cont circulating 600 gpm, 1930 psi without rotation while building 100 bbl EP mud lube sweep and cleanirlg trip tanks of MOBM. 03:30 07:00 3s0 CLEAN P DECOMP -Pump 100 bbl viscous sweep with 10% EP Mud Lube @ 585 gpm 1915 psi. Start rotation 75 rpm and reciprocation when sweep turned the corner. Sweep back 10 surface, shut dowri pumps, established drilling parameters at 16240, Up Wt 230k, DnVVt15ok. Rot VVt1o0k.35,pm.1oKul 'OmainSPn's SPR. #1) 2BPM= 80 PSI / 3BPM= 135 PSI SPR. #2) 2BPM= 80 PSI / 3BPM= 135 PSI MD= 1O24O'/ Seawater Nt 07:00 12:30 5.50 CLEAN P DECOMP -Monitor well, stable, POH for E-Line Iogs, recorded PU and GO readings every 1UOu' from 10.u4O'vo1O.o24. 12:30 - 18:30 0.00 CLEAN P DECOMP -Secure well. Rig Team and Support personnel attend K&M ERD refresher class 18:30 - 00:00 5.50 CLEAN P DECOMP 'ConrpOH from 1o.se4'mS5o' recording PU and SOreadings every 1000' 1/29/200e 00:00 - 00:30 0.50 CLEAN P DECOMP 'POH from oon'mBHA 00:30 - 01:00 0.50 CLEAN P DECOMP -Stand back HWDP 01:00 03:00 2.00 CLEAN P DECOMP - PJSM & LD BHA, Break bit, LD Jar, 2x HWDP, boot basket & gauge mill. Mill in full gauge. 03:00 03:30 0.50 CLEAN P DECOMP -Clean & Clear rig floor of vendors tools 03:30 - 04:30 1o0 EVAL P DECOMP -PJSM & attempt to tes 11'3/4^ casing m4uoopsi. Casing failed at 4000 psi and fell off instantly to 1000 psi then bled to 0 psi in 35 min. OA pressure 0 psi 04:30 - 06:00 1a0 EVAL P DECOMP -Check surface equipment. Test surface lines 10 3800 psi. No leaks found on surface. Open well and monitor well bore, well static. Consult with Anchorage ODE. Mobilize HES 11-3/4' nTTG 06:00 - 07:30 1a0 EVAL N SFAL DECOMP -Blow down surface equipment. 4" isolation vaive in mezzanine leaked by causing rig floor manifold to freeze up. Thaw mud line and repair 4^ valve & test same to*000psi. 07:30 - 09:00 1.50 EVAL P DECOMP 'PJSM& attempt m re-test 11'3/4^ casing pumped 71 strokes Printed' om00000.57 .mpm • BP P age4of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig g Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/29/2009 07:30 - 09:00 1.50 EVAL P DECOMP 711 psi pumping fluid away. Monitored for 7 min, pressure bleed down from 711 psi to 295 psi. Test failed suspend test. Blow down lines. 09:00 - 11:00 2.00 EVAL P DECOMP -PJSM & spot SLB e-line unit & RU sheaves. Pick up USIT logging tools and function test same. Test good. 11:00 - 21:00 10.00 EVAL P DECOMP -RIH with Run #1 USIT / GR / CCL to 15,550' MD and log out of hole to surface. 21:00 - 22:00 1.00 EVAL P DECOMP -PJSM / LD logging tools & RD SLB e-line. Clear rig floor of vendors tools. 22:00 - 23:30 1.50 EVAL P DECOMP -PJSM / PU & MU HES 11 -3/4" RTTS tool and RIH with 5 stands 5" HWDP to 479'. Blow down kill line. 23:30 - 00:00 0.50 EVAL P DECOMP -RIH with RTTS on 5" DP from 479' to 1065' Losses to well bore while logging = 17 bbls Losses from testing = 26 bbls Total losses = 43 bbls. seawater 1/30/2009 00:00 - 03:30 3.50 EVAL P DECOMP -RIH with RTTS on 5" DP from 1065' to 5070' 03:30 - 05:00 1.50 EVAL P DECOMP -PJSM & set RTTS @ 5060', RU & test 11 -3/4" from above to 3025 psi. 69 strokes. Held. -Line up and attempt to test from below. Pressure up to 800 psi. 75 strokes. & shut in. Bled down to: 1 Min 650 psi 2 Min 550 psi 3 Min 500 psi 4 Min 450 psi 5 Min 400 psi - Release RTTS tool, RD & Blow Down surface equipment. 05:00 - 09:00 4.00 EVAL P DECOMP -RIH from 5070' to 10049', Up Wt 172k, Dn Wt 118k, PU, set 11 3/4" RTTS at 10037' 09:00 - 10:30 1.50 EVAL P DECOMP - Pressure test 11 3/4" from above to 2975 psi, 125 strokes, Held, OK -Line up and attempt to test from below. Pressure up to 975 psi. 65 strokes and shut in. Bled down to: Shut in 975 psi 5 Min 450 psi - Release RTTS tool, RD & Blow Down surface equipment. 10:30 - 14:30 4.00 EVAL P DECOMP -RIH from 10049' - 15214', Up Wt 230k, Dn Wt 130k, PU, set 11 3/4" RTTS at 15203' 14:30 - 16:30 2.00 EVAL P DECOMP - Pressure test 11 3/4" from above to 3022 psi, 183 strokes, Held, OK -Line up and attempt to test from below. Pressure up to 1040 psi. 45 strokes and shut in. Bled down to: Shut in 1040 psi 2 Min 600 psi - Release RTTS tool, RD & Blow Down surface equipment. 16:30 - 17:30 1.00 EVAL P DECOMP -POH with RTTS tool from 15,214 to 14,739' 17:30 - 19:30 2.00 EVAL N SFAL DECOMP -Top Drive rotary hose interference with pipe racking operations. -Held PJSM, Loosen top drive goose neck connection and turn hose to correct interference problems. Printed: 6/3/2009 3:57:48 PM • • BP Page 5 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/30/2009 19:30 - 21:00 1.50 EVAL P DECOMP -POH from 14,739' to 13,111' 21:00 - 00:00 3.00 EVAL N SFAL DECOMP -Top Drive rotary hose turned again interfering with pipe racking operations. -PJSM and attempt to correct as before. Found gland nuts loosening at both ends. Remove rotary hose from standpipe and tighten gland nuts and set screws. 24 hr losses to well bore = 25 bbls seawater 1/31/2009 00:00 - 10:00 10.00 EVAL N SFAL DECOMP - PJSM & Cont' correcting deficiency on top drive rotary hose and re- install / secure same. Adjust rotary hose for tracking through derrick. Secure electrical and hydraulic together. - Thawing out seawater line between pipe -rack and rig 10:00 - 12:00 2.00 EVAL P DECOMP -POH from 13,111' to 10,446' - Parameters @ 10,466' UP WT. 210k / DN WT. 110k -Tour Seawater Losses = 10 bbls 12:00 - 17:30 5.50 EVAL P DECOMP -POH from 10,446' to 479' 17:30 - 18:00 0.50 EVAL P DECOMP - Handle BHA Stand back 5 stands HWDP & LD RTTS tool. 18:00 - 19:00 1.00 BOPSUF P DECOMP -MU ported sub on stand of 5" HWDP & flush BOP stack. Function all rams and repeat flushing BOP. LD ported sub & blow down top drive and mud lines. 19:00 - 21:00 2.00 BOPSUF P DECOMP -MU running tool and pull wear bushing. -MU test plug to 5" test joint and RU test equipment. Fill BOP & choke manifold with 65 degree fresh water. 21:00 - 00:00 3.00 BOPSUF P DECOMP Test BOPE as per BP / AOGCC Regulations to 250 psi low / 5000 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Witness of test waived by Bob Noble (AOGCC State Inspector). Witnessed by Chris Clemens (WSL), Kelly Cozby (NAD Toolpusher), Kenny Sullivan (NAD Drillers). Test as follows with 5" Test Joint. Test as follows with 250 psi / 5000 psi. #1) Top Rams 4.5" x 7" VBR / NC -50 IBOP / Choke Valves # 9, 12 & 13 / Kill Line #2) NC -50 Floor Safety Valve / Kill HCR / Choke Valves # 8 & 11 #3) Choke Valves # 4, 7, & 10 #4) Super Choke #5) Choke Valve # 3 -5 -6 / Manual Kill Line Valve #6) Manual Choke Manifold Valve #7) Choke Valve #1, 3 & 5 #8) Choke Valve #2 #9) Choke HCR Valve -Tour Seawater Losses = 8bbls -24 Hrs Losses = 18 bbls 2/1/2009 00:00 - 02:30 2.50 BOPSUF P DECOMP -Cont' Test BOPE as per BP / AOGCC Regulations to 250 psi low / 5000 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Witness of test waived by Bob Noble (AOGCC State Inspector). Witnessed by Chris Clemens (WSL), Kelly Cozby (NAD Toolpusher), Kelly Haug (NAD Drillers). Printed: 6/3/2009 3:57:48 PM • • BP Page 6 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase . Description of Operations 2/1/2009 00:00 - 02:30 2.50 BOPSUF P DECOMP #10) Manual Choke Valve #11) Annular 250 psi / 3500 psi. #12) Bottom 3.5" x 6" VBR / Upper Top Drive Well Control Valve (UWCV Failed) #13) Bottom 3.5" x 6" VBR / Lower Top Drive Well Control Valve #14) Function / Draw Down Accumulator Test #15) Blind Shear Rams 02:30 - 03:00 0.50 BOPSUF P DECOMP -Pull test plug, RD / Blow down test equipment. Install 10- 15/16" ID Wear Bushing. RILDS 03:00 - 09:00 6.00 BOPSUF N SFAL DECOMP -PJSM & Change out failed Top Drive Upper Well Control Valve. -RU & test Upper Well Control Valve to 250 psi / 5000 psi. Test good. RD test equipment. 09:00 - 09:30 0.50 DHB P DECOMP -PJSM with all involved personnel on operational proceedures for running 11 3/4" CIBP 09:30 - 11:00 1.50 DHB P DECOMP -Make dummy run with 11 3/4" CIBP running tool, open circ sub, MWD and 1 std of HWDP below wellhead to confirm running tool clearance, POH, std bk HWDP 11:00 - 11:30 0.50 DHB N WAIT DECOMP - Waiting on 4 1/2" float sub, wrong sub on location with 5 1/2" Reg pin instead of 4 1/2" IF pin 11:30 - 13:00 1.50 DHB P DECOMP -MU float sub to circ sub and MWD, install 11 3/4" CIBP to running tool, RIH with 5" HWDP to 500' 13:00 - 13:30 0.50 DHB P DECOMP -RIH with CIBP on 5" DP from 500' to 1074' @ max 1 stand per stand 13:30 - 14:00 0.50 DHB P DECOMP - Shallow pulse test MWD @ 450 gpm 230 psi. Good Test. 14:00 - 14:30 0.50 DHB P DECOMP -RIH from 1047 to 1745' 14:30 - 18:30 4.00 DHB P DECOMP -D -1 Drill, Secure well. Line up trip on trip tank and circulate across top of well. Station well control certified personnel to watch well & hold rig team morale meeting in drilling office. 18:30 - 20:00 1.50 DHB P DECOMP -PJSM / Slip & Cut 126' of drilling line. 20:00 - 21:00 1.00 DHB P DECOMP - Service Draw -works / Top Drive / Block & Crown. 21:00 - 00:00 3.00 DHB P DECOMP -RIH from 1745' to 7006' UP WT. 135k / DN WT 108k -24 Hrs Losses = 15 bbls -Total losses to well bore = 101 bbls. Seawater 2/2/2009 00:00 - 05:30 5.50 DHB P DECOMP -RIH with CIBP from 7006' to 14,770' @ max 1 min per stand. -Fill DP every 3000' UP WT. 220k / DN WT 130k 05:30 - 08:30 3.00 DHB P DECOMP -MU TDS & stage pumps up to 500 gpm 1050 psi. -RIH Logging @ 300 fph from 14,770' to 15,129' UP WT. 220k / DN WT 135k 08:30 - 10:30 2.00 DHB P DECOMP -POH Logging @ 300 fph from 15,129' to 14,997' -500 gpm 1050 psi. & determine CIBP setting depth. 10:30 - 12:00 1.50 DHB P DECOMP -Kill pumps and RIH placing top of CIBP @ 15,065'. -PU drill string 5' to PU WT of 230k. S/O 2.5' - Engage Rotary and rotate 42 turns. -Pull to 240k and wait 2min. -Pull to 260k and wait 1 min. -Pull to 280k and wait 1 min. Printed: 6/3 /2009 3:57:48 PM • • BP Page 7 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/2/2009 10:30 - 12:00 1.50 DHB P DECOMP -Pull 295k & shear off of bridge plug & POH 30', RIH and tag top of CIBP @ 15,065' and SO 20k. POH 30' and rotate pipe 30 rounds to retract setting tool. -Close top set of rams and pressure test to 2000 psi and hold for 5 min. Held -Bleed of pressure and Blow down lines. -12 Hrs Losses = 35 bbls -Total losses to well bore = 136 bbls. Seawater 12:00 - 15:30 3.50 DHB P DECOMP -PJSM & displace well over to 9.2 ppg LSND milling fluid. - Pumped 55 bbl Hi Vis spacer followed by 1600 bbls 9.2 ppg - Pumping @ 490 gpm / 960 psi / 33 rpm / 7k TQ UP WT 212k / DN WT 148k / RT WT 175k 15:30 - 16:00 0.50 DHB P DECOMP -Cont' circulate and fill pits system and trip tank with new mud from G &I. - Obtain SPR's SPR. #1) 2BPM= 260 PSI / 3BPM= 310 PSI SPR. #2) 2BPM= 260 PSI / 3BPM= 310 PSI MD = 15040' / TVD = 6558' Mud Wt 9.2 ppg - Monitor well, Static. Pump Dry job & blow down TDS & mud line. 16:00 - 23:30 7.50 DHB P DECOMP -POH from 15,040' to 500' 23:30 - 00:00 0.50 DHB P DECOMP -POH stand back 5 stands HWDP & LD HES Setting tool. 2/3/2009 00:00 - 03:00 3.00 STWHIP P WEXIT -PJSM & MU 11 -3/4" Whipstock BHA #4 / MU Starter Mill / Lower Mill / Flex Jt / Upper Mill / X0 / 1 Jt. 5" HWDP / Flt Sub / MWD / UBHO Sub & Orient MWD to starter mill pin. -PU & MU whipstock slide to starter mill & RIH. PU Bumper Sub -RIH with 5 Stds 5" HWDP from Derrick. 03:00 - 04:00 1.00 STWHIP P WEXIT -RIH with whipstock on 5" drill pipe from 590' to 1057' 04:00 - 04:30 0.50 STWHIP P WEXIT - Shallow pulse test MWD tool, pump @ 480 gpm / 360 psi. Good Test, Blow Dn Mud Lines. 04:30 - 17:30 13.00 STWHIP P WEXIT -RIH from 1057' to 14,945' -Fill DP every 3,000' run 17:30 - 18:30 1.00 STWHIP P WEXIT -MU TDS & establish parameters -Pump 503 gpm / 1070 psi / Up Wt. 220k / Dn Wt. 140k - Orient and set Baker Gen II 11 -3/4" whipstock 42 degrees right of high side at 15,037' SO to 15,065 MD & tag CIBP with 20k set down weight & trip anchor. PU to 10k over Up Wt to 230k & confirm anchor set. S/O to 45k with no indication of shear. Pick up to confirm mills sheared from the whipstock assembly, mills free. T" Establish rotation Rt Wt. 175k / 100 rpm / TQ 10k. Shut down rotary. 18:30 - 19:00 0.50 STWHIP P WEXIT -Pump 100 bbl Lube pill surface to bit with 10% Steel Lube EP, 2.5% Low- Torque, 2.5% 776. 19:00 - 00:00 5.00 STWHIP P WEXIT -Mill 10 -5/8" window in 11 -3/4" casing from 15,037' to 15,041' -TOW at 15,037' MD -BOW at 15,060' MD -RT WT 175 / PUW 220k / SOW 140k -710 gpm / 1720 psi -100 rpm / 12 -16k TQ. / 2 -5k Wt on mill. Printed: 6/3/2009 3:57:48 PM • • Bp Page 8 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/3/2009 19:00 - 00:00 5.00 STWHIP P WEXIT Pumped 50 bbl Super Sweep around @ 15,040' 2/4/2009 00:00 - 06:00 6.00 STWHIP P WEXIT -Cont' Mill 10 -5/8" window in 11 -3/4" casing from 15,041' to 15,060' & New hole to 15,062' -TOW at 15,037' MD -BOW at 15,060' MD -RT WT 175 / PUW 220k / SOW 140k -760 gpm / 1925 psi -100 rpm / 12 -16k TQ. / 5 -10k Wt on mill. Pumped 50 bbl Super Sweep around @ 15,040 with 30% increase in metal cuttings seen at surface. Pumped 2nd 50 bbl Super Sweep around @ 15,050'. 06:00 - 09:30 3.50 STWHIP P WEXIT _ -Mill new hole form BOW @ 15,060' to 15,085' -RT WT 175 / PUW 220k / SOW 140k -580 gpm / 1360 psi -70 rpm / 11k TQ. / 8 -12k Wt on mill. -Work mills through the window several times with and without pumps. No problems. 09:30 - 13:00 3.50 STWHIP P WEXIT -Pump 50bbI SuperSweep @ 550 bpm / 1440 psi up through open hole and pull up above whipstock slide @ 15,037' and CBU 1.5 times @ 700 gpm / 1750 psi -RT 30 rpm / 8k TQ -PUW 240k / SOW 140k / RT WT 170k 13:00 - 13:30 0.50 STWHIP P WEXIT - Perform LOT OH MD 15,085' Mud Wt in and out 9.2 ppg 11 -3/4" Window 15,060' MD / 6,572' TVD Pumped 95 strokes 7.9 bbls. Leak off pressure 1332 psi. EMW = 13.1 ppg 13:30 - 16:30 3.00 STWHIP P WEXIT - Resume circulating & CBU 1.5 times @ 700 gpm / 1750 psi while reciprocating pipe without rotation. -PUW 240k / SOW 140k - Obtain SPR's SPR. #1) 2BPM= 270 PSI / 3BPM= 310 PSI SPR. #2) 2BPM= 260 PSI / 3BPM= 310 PSI MD = 15,010' / TVD = 6554' Mud Wt 9.2 ppg 16:30 - 17:00 0.50 STWHIP P WEXIT - Monitor well Static, Pump dry job & blow down TDS & mud lines. 17:00 - 19:30 2.50 STWHIP P WEXIT - Transfer 13 stands 5" DP from ODS to DS racking board & Cont' POH from 15,010' to 12,238'. 19:30 - 00:00 4.50 STWHIP P WEXIT -POH LD 5" DP 1x1 from 12,238' to 8,600' 2/5/2009 00:00 - 01:00 1.00 STWHIP P WEXIT -POH LD 5" DP 1x1 from 8,600' to 7,800' 01:00 - 02:30 1.50 STWHIP P WEXIT - Safety Stand Down - Secure well and held meeting with rig crew discussing job awareness levels and the need for focus on the job. Received safety commitment from rig team and resumed operations. 02:30 - 14:30 12.00 STWHIP P WEXIT -POH LD 5" DP 1x1 from 7,800' to 562' 14:30 - 16:00 1.50 STWHIP P WEXIT _ -POH LD Whipstock BHA / 15 Jts. 5" HWDP / Bumper Sub / UBHO /MWD /Flt Sub /1 jt 5" HWDP / X0 / Upper Mill / Flex Jt / Lower Mill / Starter Mill. -Upper Mill in Full Gauge 16:00 - 17:00 1.00 STWHIP P WEXIT -Clear rig floor of vendors tools. 17:00 - 18:30 1.50 BOPSUF P WEXIT -PJSM Pull wear bushing, MU BOP flushing tool and flush BOP stack, function all rams and repeat flushing cycle. LD flushing tool & blow down TDS & mud line. 18:30 - 00:00 5.50 BOPSUF P WEXIT -PJSM on leveling rig with all personnel. Open unit work permit, Printed: 6/3/2009 3:57:48 PM • • BP Page 9of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/5/2009 18:30 - 00:00 5.50 BOPSUF P WEXIT remove turnbuckles from BOP, release air from air boots, ready inner - connects and stairways to jack and level rig. Jack, position & level substructure due to settling. 2/6/2009 00:00 - 04:30 4.50 BOPSUF P WEXIT -PJSM on leveling rig with all personnel & Continue positioning & leveling substructure. Re- position inner - connects & stairways. RU turnbuckles to BOP and air up bell nipple boots. 04:30 - 07:00 2.50 BOPSUF P WEXIT -PJSM Change out top drive quill lower safety valve to 5 -7/8" service. 07:00 - 08:30 1.50 BOPSUF P WEXIT -RU test equipment and install test plug on 5 -7/8" test joint. 08:30 - 11:30 3.00 BOPSUF P WEXIT -Test BOPE to 250 psi / 4500 psi as per BP / AOGCC, Regulations with 5 -7/8" test jt. Top Rams 4.5" x 7" VBR Bttm Rams 3.5" x 6" VBR Top Drive Lower 5 -7/8" well control valve 5 -7/8" Floor safety valve 5 -7/8" IBOP Witness of test by Kelly Cozby (NAD Toolpusher) Brian Buzby (WSL) Kelly Haug (NAD Driller) 11:30 - 12:00 0.50 BOPSUF P WEXIT -Pull test plug, RD / Blow down test equipment. Install 10- 15/16" ID Wear Bushing. 12:00 - 12:30 0.50 STWHIP P WEXIT -PJSM Clear rig floor and ready rig to PU 5 -7/8" DP 12:30 - 22:00 9.50 STWHIP P WEXIT -RIH PU 126 jts. 5 -7/8" 26.3# S -135 XT -57 DP with 2 x WWT SuperSliders install 5' & 8' above pin end. Torque DP to 56,600 ft/Ibs 22:00 - 22:30 0.50 STWHIP P WEXIT -POH from 4006' to 3911' 22:30 - 00:00 1.50 STWHIP N RREP WEXIT -Rotary hose obstructing derrick alley way, Mud line frozen in inner - connect, thawing mud line. 2/7/2009 00:00 - 04:30 4.50 STWHIP N RREP WEXIT -Cont' Adjust rotary hose to top drive & thawing mud line in inner - connect. 04:30 - 06:30 2.00 STWHIP P WEXIT -POH from 3911' to 2865'. Rotary hose still obstructing ODS pipe rack alley. 06:30 - 18:30 12.00 STWHIP N RREP WEXIT -PJSM SIMOP for replacing draw -works traction blower motor and continue correcting tracking of top drive rotary hose & effect repairs on same. 18:30 - 19:30 1.00 STWHIP N RREP WEXIT - Circulate through mud line & warm up rotary hose. Run top drive through derrick and check tracking, Hooray! Test mud line to 4500 psi. Good test. Epoch pressure displays with pumps and standpipe not corresponding. 19:30 - 20:30 1.00 STWHIP N RREP WEXIT - Calibrate Epoch / CanRig Rigwatch pump & standpipe pressure gauges. 20:30 - 22:30 2.00 STWHIP P WEXIT -POH from 2865' racking back a total of 42 stands of 5 -7/8" 26.3# DP w/ 2x WWT SuperSliders per joint. 22:30 - 23:00 0.50 DRILL P WEXIT -PJSM, Change out handling equipment to 5" 23:00 - 00:00 1.00 DRILL P WEXIT -PJSM & PU / MU Directional Drilling BHA #5 / XP Motor w/1.15 deg BHM / NM IBS / ARC w/ ZINC 2/8/2009 00:00 - 02:30 2.50 DRILL P WEXIT -PJSM & Cont' PU / MU Directional Drilling BHA #5 Bit 10 -5/8 Hughes MX -1 X / XP Motor w/1.15 deg BHM / NM IBS / ARC w/ ZINC / MWD / ADN / NM IBS / 2x 8" MN DC's / 7 -3/4" Jars 02:30 - 03:00 0.50 DRILL P WEXIT -RIH With BHA #5 on 5" DP 203' to 684' 03:00 - 04:00 1.00 DRILL P WEXIT -MU TDS and shallow test MWD 650 gpm / 770 psi. Blow down Top Drive & mud line Printed: 6/3/2009 3:57:48 PM • • BP Page 10of91 Operations Summary Report Legal Well Name: NS33 1 2 /29/ 00 7 Common Well Name: NS33 Spud Date : Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/8/2009 04:00 - 06:00 2.00 DRILL P WEXIT -RIH on slick 5" DP from 684' to 4226' UP WT 115k/ DN WT 101k 06:00 - 07:00 1.00 DRILL P WEXIT -Fill DP, Blow down surface equipment. Change out handling equipment to 5 -7/8" 07:00 - 00:00 17.00 DRILL P WEXIT -PJSM RIH PU 5 -7/8" DP 1x1 from 4226' to 13,669' Slick 5 -7/8" 23.4# 6,105.75' 1 per jt. SS 5 -7/8" 23.4# 3,051.24' 2 per jt. SS 5 -7/8" 23.4# 286.27' Up Wt 235k / Dn Wt 140k 2/9/2009 00:00 - 02:30 2.50 DRILL P WEXIT -RIH PU 5 -7/8" DP 1x1 from 13,669' to 14,433' 2 per jt. SS 5 -7/8" 23.4# 763.25' 02:30 - 03:00 0.50 DRILL P WEXIT -RIH with Stands of 5 -7/8" 26.3# from 14,443' to 14,900' w/ 2 x jt. SuperSliders (SS) 03:00 - 04:00 1.00 DRILL P INT1 -Fill pipe and bring pump rate up to 489 gpm / 1020 psi - Orient BHA 40 deg RHS - Obtain SPR's SPR. #1) 2BPM= 300 PSI / 3BPM= 350 PSI SPR. #2) 2BPM= 290 PSI / 3BPM= 340 PSI MD = 14,910' / TVD = 6570' Mud Wt 9.2 ppg -Kill pumps and SO to 15,063' & taq with 5k 3' out of the window. PU up to 15,050' encountered 25k overpull. Work pipe up and down slide x3. Put 1 round to the right into drill string and worked pipe free up to 15,016', encountered another overpull, worked free and work up to 15,001' rack back 1 stand. 04:00 - 06:30 2.50 DRILL P INT1 -MU TDS, Circulate Rotate & reciprocate working full stand to clear / clean up debris Stage pumps up from 514 gpm / 1072 psi to 700 gpm 1650 psi 35 rpm/TQ 11k/ Up Wt 260k / Dn Wt 160k / RTW 190k 06:30 - 07:00 0.50 DRILL P INT1 - Obtain ECD Baseline - Orient BHA 40 deg RHS & Kill pumps -Log down obtaining recorded data from 15,001' to 15,063' @ 160 FPH 07:00 - 12:00 5.00 DRILL P INT1 - Directionally Drill from 15,063' to 15,190' -700 gpm / Off Bttm 1660 psi / On Bttm1830 psi -60 rpm / Tq Off 12k / Tq On 14k -Up Wt 275k / Dn Wt 165k / RTW 190k -Cal ECD = 9.68 ppg / Actual ECD = 9.7 ppg -AST = 1.93 hrs / ART = .35 hrs 12:00 - 00:00 12.00 DRILL P INT1 - Directionally Drill from 15,190' to 15,580' -700 gpm / Off Bttm 1717 psi / On Bttm1825 psi -100 rpm / Tq Off 11k / Tq On 16k -W / Pumps Up Wt 245k / Dn Wt 160k / RTW 190k -W/0 Pumps Up Wt 262k / Dn Wt 165k -Cal ECD = 9.72 ppg / Actual ECD = 9.71 ppg -AST = 4.58 hrs / ART = 1.5 hrs SPR. #1) 2BPM= 250 PSI / 3BPM= 280 PSI SPR. #2) 2BPM= 250 PSI / 3BPM= 290 PSI MD = 15,525' / TVD = 6703' Mud Wt 9.2 ppg Printed: 6/3/2009 3:57:48 PM • BP Page 11 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/10/2009 00:00 - 12:00 12.00 DRILL P INT1 - Directionally Drill from 15,580' to 16,144' 6760' tvd -WOB = 30 - 35k -700 gpm / Off Btm 1750 psi / On Btm1840 psi 120 rpm /Tg Off 16k /TgOn21k -W / Pumps Up Wt 255k / Dn Wt 163k / RtWt 200k -W/0 Pumps Up Wt 270k / Dn Wt 165k -Cal ECD = 9.75 ppg / Actual ECD = 10.03 ppg -AST = 2.45 hrs / ART = 3.95 hrs SPR. #1) 2BPM= 300 PSI / 3BPM= 340 PSI SPR. #2) 2BPM= 300 PSI / 3BPM= 350 PSI MD = 15,525' / TVD = 6703' Mud Wt 9.2 ppg 12:00 - 16:00 4.00 DRILL P INT1 - Directionally Drill from 16,144' to 16,466' 6913' tvd -WOB = 35 -40k -700 gpm / Off Btm 1800 psi / On Btm1950 psi -120 rpm / Tg Off 16k / Tg On 21k -W / Pumps Up Wt 262k / Dn Wt 152k / RtWt 192k -W/0 Pumps Up Wt 281 k / Dn Wt 165k -Cal ECD = 9.78 ppg / Actual ECD = 10.06 ppg 16:00 - 18:00 2.00 DRILL N SFAL INT1 Trouble shoot Top Drive Rotary stalling issue - Control sensor failure - Bypass encoder sensor and continue drilling while consulting with CanRig Technicians 18:00 - 19:00 1.00 DRILL P INT1 Directionally Drill from 16,466' to 16,526' -same parameters as before - prepare to repair TDS 19:00 - 22:00 3.00 DRILL N SFAL INT1 Repair CanRig Top Drive Tighten encoder sensor bracket - Change out encoder -Test encoder and perform Q & A tests 22:00 - 00:00 2.00 DRILL P INT1 - Directionally Drill from 16,526' to16,619' 6947' tvd - WOB= 35 -40k -700 gpm / Off Btm 1875 psi / On Btm1980 psi - 100 rpm /Tg Off 16k /TgOn21k -W / Pumps Up Wt 260k / Dn Wt 162k / RtWt 197k -W/0 Pumps Up Wt 278k / Dn Wt 170k -Cal ECD = 9.75 ppg / Actual ECD = 10.12 ppg -AST = 0.43 hrs / ART = 3.97 hrs SPR. #1) 2BPM= 340 PSI / 3BPM= 400 PSI SPR. #2) 2BPM= 350 PSI / 3BPM= 390 PSI MD = 16,619' / TVD = 6947' Mud Wt 9.1 ppg 2/11/2009 00:00 - 08:00 8.00 DRILL P INT1 - Directionally Drill from 16,619' to16,903' 7009' tvd -WOB = 35 - 40k -700 gpm / Off Btm 1875 psi / On Btm1990 psi -120 rpm / Tq Off 21k / Tq On 23k -W / Pumps Up Wt 265k / Dn Wt 165k / RtWt 200k -W/0 Pumps Up Wt 280k / Dn Wt 175k -Cal ECD = 9.82 ppg / Actual ECD = 10.07 ppg -AST = 0.53 hrs / ART = 5.23 hrs SPR. #1) 2BPM= 330 PSI / 3BPM= 390 PSI SPR. #2) 2BPM= 320 PSI / 3BPM= 390 PSI Printed: 6/3/2009 3:57:48 PM • BP Page 12 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/11/2009 00:00 - 08:00 8.00 DRILL P INT1 MD = 17038' / TVD = 7039' Mud Wt 9.2 ppg 08:00 - 15:00 7.00 DRILL P INT1 CBU 4x (Increase in cuttings after 1 1 /2x BU with shakers cleaning up after 4x) -700 gpm / 1780 psi -120 RPM / 21k Torque Reduced flowrate by 75% on down stroke, Work full stand, sitting back one stand back every hour Monitor Well, Static 9.2 ppg In / Out 15:00 - 16:30 1.50 DRILL P INT1 POH 6 stands on elevators to 16,410' MD without issues -Hole started to experience 40k overpulls from 16,410 - 16.385, and -Pull up to 40k over and then work back down, - Repeated this process for 6 -8x gaining aproximatly 4' each stroke _- Working stand down without issues -No Swabbing issues PUW - 275k SOW - 170k 16:30 - 18:00 1.50 DRILL P INT1 RIH with 2 stands and Circulate for 30 minutes -Broke circulation slowly, staging up and watching for any indication of packing off -No Packing off Issues -700 gpm / 1780 psi -120 RPM / 21k Torque Monitor Well, Static 9.2 ppg In / Out 18:00 - 22:00 4.00 DRILL P INT1 POH to 16,385 without overpulls, at 16,385 pulled 40k over - BackReam out to 15,285 at drilling parameters -700 gpm / 1700 psi -100 rpm / 17k Tq -No Problems Backreaming to 16,285' and 22:00 - 23:00 1.00 DRILL P INT1 POH on elevators into whipstock window at 11,060' -It took two attempts to pull into window, orienting toolface 23:00 - 00:00 1.00 DRILL P INT1 CBU 1.5 x -735 gpm / 1820 psi -120 RPM / 18k Tq 2/12/2009 00:00 - 01:00 1.00 DRILL P INT1 CBU 1.5 x - Showed a slight increase in cuttings after the first bottoms up -Circ. till shakers cleaned up -735 gpm / 1820 psi -120 RPM / 18k Tq Monitor Well, Static 9.2 ppg In / Out 01:00 - 14:30 13.50 DRILL P INT1 POH - Standing back 5 7/8" Drill Pipe in derrick -Stand Back 24 stds. of 5" Drill Pipe - Visually inspecting "SuperSliders" Printed: 6/3/2009 3:57:48 PM �� �� -�- BP Page 13 of 91 Operations Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25X2008 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To `� � — Code NPT ' 2/12/2009 01:00 - 14:30 13.50 DRILL P INT1 -No issues with swabbing 14:30 - 18`00 3.50 DRILL P INT1 POH laying down 54 jts of 5" Drill Pipe 18:00 21:00 3.00 DRILL P INT1 Laydown BHA '0 Drilling Jar, Set Back NM0C's.0MWD/LWD.LDPDM and Bit -Bit Grade 3'1-WTm's'|'ao'aHA -Clean Rig Floor and Clear excess BHA components from Rig Floor 21:00 - 22:00 1.00 BOPSUF P INT1 Flush BOP's and Function Tes Rams 22:00 23x0 1.00 BOPSUF P INT1 Pull Wear Bushing 23:00 00:00 1.00 BOPSUF P INT1 Rig to Tes BOP's -DraineoPGtack -Make Up 5 7/8 DP and Port sub and Tes Plug -Set Tes Plug 2/13/2008 00:00 08:00 8.00 BOPSUF P INT1 Test BOPE as per BP / AOGCC Regulations to 250 psi Iow / 45oO psi High for 5 min each u5o psi /3s0 psi on Arinular preventer. Witness of test waived by Chuck Sheve (AOGCC State Inspector). Witnessed by Dave Newion (WSL), Brian Tiodo,mon(NADToo|pvoxor). Kelly Haug (wADo,iUom). Test with 570' Test Joint. Test uoo psi low /4sOU psi high #1) Top Rams 4.a^x7^VgR/nTs7 Dart Valve/ Valves #e.10 & 13 / Kill Line #2)HTo7 Floor Safety Valve / Choke Valves wo&11 m3) Choke Valves #4.7.&1O #4) Super Choke and Manual Choke (250 psi / 1500 psi ws) Choke Valve #u'o'8/ Manual Kill Line Valve #0) Choke Valve w1.3&5 or) Choke Valve wu #8; Choke HCRValve #9) Manual Choke Vaive Function / Draw Down Accumulator Test, '3000 psi system, 1600 psi draw down, 39 sec 200 psi build up, full charge @ 3 min 09 secs, -4 nitrogon bottles with avg charge of 2612 psi #10> Bottom 3.5^x6^voR/ Upper Top Drive Well Control Valve w11) Bottom na^xO^VBR/ Lower Top Drive Well Control Valve Change out 5" Test Joint w1c) Top Rams *.5^x7^veR/wCoo Dart Valve #13) Bottom 3.5^x6^voR/NCno Floor Safety Vaive #14) Annular muao psi low and 3oOu psi high 08:00 - 08:30 0.50 BOPSUF P INT1 Set Wear Bushing (1o3/u^ID) 08:30 08:00 0.50 BOPSUF P INT1 Rig Down Tes Equipmerit and Prep Rig Floor to Pick Up BHA 0e:00 '10:00 1.00 DRILL P INT1 Service Top Drive, Draw Works and Crown -Finish bring equipment to rig floor 10:00 12:00 2.00 DRILL N SFAL INT1 Make Up BHA Printed: 6/3/2009 3.57:48 PM • . Bp Page 14of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/13/2009 10:00 - 12:00 2.00 DRILL N SFAL INT1 -Make up Anadrill Power Drive and Surface Test - Surface pressure was 1910 psi @ 550 gpm, 1100 psi too high -Check surface equipment for restriction, all good -Pick up stand of Drill Pipe and pump at same rate, 75 psi @ 550 gpm -Lay down Power Drive tool and pick up back up tool 12:00 - 16:00 4.00 DRILL P INT1 Make Up BHA -Make up Anadrill Power Drive and Surface Test - Surface pressure was 450 psi @ 550 gpm, good test - Finish Picking BHA, Stab, MWD /LWD„ Stab, NMDC, Jars and XO 16:00 - 17:00 1.00 DRILL P INT1 RIH - Picking up 5" Drill from Pipe Shed 1 x 1 17:00 - 17:30 0.50 DRILL P INT1 Shallow Test MWD -550 gpm = 540 psi, good test -Blow Down Lines 17:30 - 20:00 2.50 DRILL P INT1 RIH with 5" stands from derrick 20:00 - 00:00 4.00 DRILL P INT1 RIH - Picking up 5" Drill from Pipe Shed 1 x 1 2/14/2009 00:00 - 04:00 4.00 DRILL P INT1 RIH to 9762' - Picking up 5" Drill from Pipe Shed 1 x 1 04:00 - 05:30 1.50 DRILL P INT1 Prepare Rig for Handling 5 7/8" Drill Pipe - Change Out Elevators - Change out Dies in TDS back up wrench - Change out slips 05:30 - 08:30 3.00 DRILL P INT1 Service Rig - Service TDS, Draw Works and Crown -Slip and Cut 178' of Drilling line 08:30 - 12:00 3.50 DRILL P INT1 RIH with 5 7/8" Drill Pipe 12:00 - 16:00 4.00 DRILL P INT1 RIH with 5 7/8" Drill Pipe to iust above window - Adding 1 "Super Slider" per Joint on 32 stands (std 137 -168) -A total of 85 stands with 2 Super Slider per joint (std 137 -221) -Break Circulation at window -550 gpm / 1350 psi 16:00 - 17:30 1.50 DRILL P INT1 RIH to 16,700 -Ran through window without issues -Took 40k down drag at 16,740', Pick back up to 16,700' 17:30 - 23:30 6.00 DRILL P INT1 Break Circ. slowly to prepare to ream to bottom -500 gpm / 1274 psi 130 rpm's / 18k ft/Ibs of Torque - Staging Pumps up slowly to 500 gpm, started to pack off (50 -75 psi increase), reduce rate immediately to 400 gpm - Estabilish good circulation at 400 gpm and stage up pump rate slowly to 700 gpm without any problems and without hole trying to pack off 700 gpm / 2000 psi 130 rpm's / 19k ft/lb Torque ECD =10.1 At bottoms up maximum Mud Wt. increase to 9.4 pop with minimal cuttings Reamed to bottom (17,038') @ 150 to 300 ft/hr, no issues reaming to bottom 23:30 - 0.00 DRILL P INT1 - Directionally Drill from 17,038' to 17,104' 7055' tvd -WOB = 22 -25k Printed: 6/3/2009 3:57:48 PM • Bp Page 15 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/14/2009 23:30 - 0.00 DRILL P INT1 -700 gpm / 2035 psi -130 rpm / Tq Off 21k / Tq On 24k -W / Pumps Up Wt 253k / Dn Wt 150k / RtWt 190k -W /O Pumps Up Wt 270k / Dn Wt 160k -Cal ECD = 9.83 ppg / Actual ECD = 10.08 ppg -ADT = 0.80 hrs Total Time = 0.80 hrs. SPR. #1) 2BPM= 300 PSI / 3BPM= 350 PSI SPR. #2) 2BPM= 320 PSI / 3BPM= 370 PSI MD = 16,817 / TVD = 7019' Mud Wt 9.2 ppg 2/15/2009 00:00 - 12:00 12.00 DRILL P INT1 - Directionally Drill from 17,104' to 17,962' 7248' tvd -WOB = 22 -25k -700 gpm / 2165 psi -130 rpm / Tq Off 19k / Tq On 23k -W / Pumps Up Wt 260k / Dn Wt 157k / RtWt 200k -W /O Pumps Up Wt 279k / Dn Wt 164k -Cal ECD = 9.92 ppg / Actual ECD = 10.32 ppg -ADT = 7.1 hrs Total Time = 7.9 hrs. SPR. #1) 2BPM= 400 PSI / 3BPM= 460 PSI SPR. #2) 2BPM= 400 PSI / 3BPM= 460 PSI MD = 17,962' / TVD = 7248' Mud Wt 9.3 ppg 12:00 - 00:00 12.00 DRILL P INT1 - Directionally Drill from 17,962' to 18,912' 7462' tvd -WOB = 22 -25k -700 gpm / 2242 psi -130 - 170 rpm / Tq Off 18 -20k / Tq On 22 -25k -W / Pumps Up Wt 273k / Dn Wt 162k / RtWt 201k -W /O Pumps Up Wt 290k / Dn Wt 170k -Cal ECD = 10.04 ppg / Actual ECD = 10.47 ppg -ADT = 7.6 hrs Total Time = 14.70 hrs. SPR. #1) 2BPM= 350 PSI / 3BPM= 410 PSI SPR. #2) 2BPM= 370 PSI / 3BPM= 430 PSI MD = 18912' / TVD = 7462' Mud Wt 9.4 ppg 2/16/2009 00:00 - 12:00 12.00 DRILL P INT1 Directionally Drill from 18,912' to 19,569' 7671' tvd -WOB = 22 -25k -700 gpm / 2380 psi -130 - 170 rpm / Tq Off 18 -20k / Tq On 22 -25k -W / Pumps Up Wt 284k / Dn Wt 168k / RtWt 204k -W /O Pumps Up Wt 306k / Dn Wt 168k -Cal ECD = 10.26 ppg / Actual ECD = 10.57 ppg -ADT = 7.5 hrs Total Time = 22.20 hrs. SPR. #1) 2BPM= 380 PSI / 3BPM= 450 PSI SPR. #2) 2BPM= 380 PSI / 3BPM= 450 PSI MD = 19,763' / TVD = 7651' Mud Wt 9.6 ppg 12:00 - 14:00 2.00 DRILL P INT1 Directionally Drill from 19,569' to 20,048' 7714' tvd -WOB = 22 -25k -700 gpm / 2380 psi -130 - 170 rpm / Tq Off 18 -20k / Tq On 22 -25k -W / Pumps Up Wt 295k / Dn Wt 162k / RtWt 205k -W /O Pumps Up Wt 305k / Dn Wt 175k -Cal ECD = 10.26 ppg / Actual ECD = 10.61 ppg Printed: 6/3/2009 3:57:48 PM • �� �� � �0 � Operations Summ Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: ' Task Code NPT 2n6/2009 12:00 14:00 2.00 DRILL P INT1 -ADT = 1.4 hrs Total Time = 23.60 hrs Gpn.#1)usPm~u5u PSI /oopm~4noPSI SPR. #2) 2BPM= 350 PSI / 3BPM= 400 PSI MD=c0.O4o'/TVD~76s1' Mud Wt 9.6 ppg 14:00 - 21:30 7a0 DRILL P INT1 Circulate and Condition hole for Wiper Trip -CBU 3x -170 rpm / 20k ftflbs of torque -700 gpm / 2340 psi -Mud wts. in 9.4 ppg / Flowline 9.7 ppg -After 3x bottoms up minimal cuttings coming across shakers -Set Back 1 stand every bottoms up -Monitor hole for 30 minutes, Static 9.4 ppg In / Out 21:30 - 23:30 2.00 DRILL P INT1 pOHV19.7oo'19.ouO' Pulled 19,00'19,76m without issues -315k PUW / 174k SOW Pulled 18.7O5'19.07O '19,715' hole pulled tight with 4O-45kovomu| -Slacked off without issues Work stand up pulling slowly with a max overpull of 40k and then slacking otf to free Pulled 19,670 - 19.575 . -working pipe as on previous stand -Avg overpull on stand of 35 - 45k Pulled 1e.575'1o.soo - -Unable to work ast 19.5uU'withhom pulling over 4nk RIH to 19,670 and break circulation staging up slowly 23:30 - 00:00 0.50 DRILL P INT1 Circulate and Clean up hole -Staged up pumps to 700 gpm / 2420 psi '17O rpm /18kh8boo+torque -No issues in breaking Circulation e/17/2009 00:00 00:30 0.50 DRILL P INT1 Finish Circulating and Condition hole -Monitor well, Static 9.4 ppg in/out -BIow down Top Drive 00:30 - 01:00 0.50 DRILL P INT1 POH f/19670 - 19,523' -50k overpull at same spot as before -No swabbing issue -314k normal PUW / 174k Normal SOW -Max pull 365k Slack off to 19,570 and break circulation 01:00 - 12:00 11.00 DRILL P INT1 Back Reaming from 1n.o70 17.040' -700 gpm /2350 psi '13o rpm /15kM/|Uoo/torque -No Issues Back Reaming No Issues without hole trying to pacmoff @1n.on8'17.nS*' experience high torque, work through area without any packing off issues or trouble 12:00 13:00 1.00 DRILL P INT1 Cont. Back �'� � � Printed: 6/3/2009 3.57 48 PM Bp Page 17 °f 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date �'�—` ~�� � Hours Task Code NPT 2Y17/2009 12:00 - 13:00 1.00 DRILL P INT1 -700 gpm / 2265 psi -130k rpm / 14k torque 13:00 - 13:30 0.50 DRILL P INT1 POH 16,914 - 16,765' With .osFF Overpull Limit 'ConstantOverpu|ls of 40 -60k, -Pull up to 60k over than slack otf to free pipe -No Issues with Slacking off and freeing pipe -Unable to make significant progress puUing on the hook 13:30 20:00 8.50 DRILL P INT1 Cont. Back Reaming to POH -700 gpm / 2265 psi -130k rpm / 14kfNbemrquo 15.984'1n.914'md torque increase m2o'uok*NUa. Work through lx, O.K. 20:00 - 20:30 0.50 DRILL P INT1 POH 15, 285 15.011'mu -PuIIed into window without issues -Pick up drag reduce 30k when we pulled into casing 20:30 - 23:00 2.50 DRILL P INT1 Circulate Bottoms up lx -700 gpm / 2030 psi -130 rpm / 12k ttflbs torque -Before CsupUvv~uaox SOW ~1eox -After CBU PUW = 232k SOW = 162x Monitor WeII, Static 9.4 ppg In / Out on:oO OOou 1.00 DRILL P INT1 POH 15,0111 - 13,745 2n8/2009 00:00 02x0 2.00 DRILL P INT1 POH1o.7*5'11.90Omd 02:00 - 03:00 1o0 DRILL P INT1 Service Top Drive -Change Lube Filter & Pull "Y" Screen -Service Draw Works 03:00 - 03:30 0.50 DRILL P INT1 RIH -P/U 6 joints of 5 7/8 drill pipe 03:30 - 05:00 1.50 DRILL P INT1 RIH to 13,693' MD 05:00 08:00 3»0 DRILL N WAIT INT1 Wait on Weather Changed out crew on Tucker Track Vehicle -Crew Change delayed for 6 hrs due to phase 2 on shore and phase 3 on Ice Road 08:00 10o0 2.00 DRILL P INT1 R|Hm15.oOO'mD -Installing 2 Super Sliders per Joint 10:00 - 10:30 0.50 DRILL P INT1 Fill Pipe before going into open hole -Record Parameters -180k RtWt @ 130 rpm and 15k torque -600gpm / 1680 psi 10:30 15:30 5.00 DRILL P INT1 n|Hm18.sow'mo -Installed 2 Supe Sliders per Joint on Stands #145 - #166 -2 Super Sliders per joirlt from joint #14s'#ro1 @1e,494 Tag up with *Ok down, Pick up and work down m 19,590' No issues workinq down but decided to precautionary ream to bottom 15:30 - 18:00 2.50 DRILL P INT1 Ream 19,590 - 20,049 -Stage circulation up slowly until full circ rate '700 gpm / 2310 psi -120 ' No Issues with reaming to bottom Printed' 6/3/2009 3:57'48 PM • 1 1) BP Page 18of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/18/2009 15:30 - 18:00 2.50 DRILL P INT1 18:00 - 00:00 6.00 DRILL P INT1 Directionally Drill from 20,049' to 20,391' 7791' tvd -WOB = 22 -25k -700 gpm / 2380 psi 130 - 170 rpm / Tq Off 20 -24k / Tq On 24 -26k - -111// Pumps Up Wt 288k / Dn Wt 162k / RtWt 204k -W /O Pumps Up Wt 305k / Dn Wt 165k -Cal ECD = 10.00 ppg / Actual ECD = 10.29 ppg -ADT = 2.7 hrs Total Time = 26.30 hrs. SPR. #1) 2BPM= 380 PSI / 3BPM= 430 PSI SPR. #2) 2BPM= 380 PSI / 3BPM= 430 PSI MD = 20,048' / TVD = 7651' Mud Wt 9.4 ppg 2/19/2009 00:00 - 12:00 12.00 DRILL P INT1 Directionally Drill from 20,391' to 21,301' 7990' tvd -WOB = 22 -25k -700 gpm / 2490 psi -120 /130 rpm /Tg Off 26k /TgOn29k W / Pumps Up Wt 306k / Dn Wt 160k / RtWt 204k -W /O Pumps Up Wt 328k / Dn Wt 163k -Cal ECD = 9.97 ppg / Actual ECD = 10.46 ppg -ADT = 7.2 hrs Total Time = 33.5 hrs. SPR. #1) 2BPM= 470 PSI / 3BPM= 550 PSI SPR. #2) 2BPM= 470 PSI / 3BPM= 550 PSI MD = 21202' / TVD = 7974' Mud Wt 9.4 ppg 12:00 - 00:00 12.00 DRILL P INT1 Directionally Drill from 21301' to 22,255 8312' tvd -WOB = 22 -25k -700 gpm / 2584 psi -120 /130 rpm /Tg Off 26k /TgOn30k W / Pumps Up Wt 322k / Dn Wt 155k / RtWt 215k -W /O Pumps Up Wt 350k / Dn Wt 171 k -Cal ECD = 10.2 ppg / Actual ECD = 10.64 ppg -ADT = 7.4 hrs Total Time = 40.9 hrs. SPR. #1) 2BPM= 530 PSI / 3BPM= 580 PSI SPR. #2) 2BPM= 520 PSI / 3BPM= 580 PSI MD = 22,159' / TVD = 8265' Mud Wt 9.4 ppg 2/20/2009 00:00 - 02:00 2.00 DRILL P INT1 Directionally Drill from 22,255' to 22,349' 8362' tvd -WOB = 22 -25k -700 gpm / 2584 psi -120 /130 rpm /Tg Off 26k /TgOn30k -W / Pumps Up Wt 332k / Dn Wt 162k / RtWt 220k -W/0 Pumps Up Wt 355k / Dn Wt 177k -Cal ECD = 10.2 ppg / Actual ECD = 10.60 ppg 02:00 - 07:30 5.50 DRILL P INT1 Directionally Drill from 22,349' to 22,539 8470' tvd Begin Weight up from 9.4 ppg to 10.5 ppg Mud Wt. -WOB = 12 -15k Control Drill at 50' /hr ROP for weight up -700 gpm / 2970 psi -120 /130 rpm /Tg Off 26k /TgOn30k Monitor Well for 5 minutes after getting 10.5 ppg mud back, Static no breathing SPR. #1) 2BPM= 630 PSI / 3BPM= 780 PSI Printed: 6/3/2009 3:57:48 PM • 1 110 Bp Page 19 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase, Description of Operations 2/20/2009 02:00 - 07:30 5.50 DRILL P INT1 SPR. #2) 2BPM= 680 PSI / 3BPM= 780 PSI MD = 22539' / TVD = 8470' Mud Wt 10.5 ppg 07:30 - 12:00 4.50 DRILL P INT1 Directionally Drill from 22,539' to 22,824' 8641' tvd -W / Pumps Up Wt 355k / Dn Wt 163k / RtWt 222k -W /O Pumps Up Wt 385k / Dn Wt 180k -WOB = 22 -25k -680 gpm / 2970 psi -120 / 130 rpm / Tg Off 25k / Tg On 31k Monitor Well at connections, Static no breathing -Cal ECD = 11.22 ppg / Actual ECD = 11.84 ppg -ADT = 7.3 hrs Total Time = 48.2 hrs. While Back Reaming at22,700' a slight pressure increase was noted, the driller back ream stand 2x as a precaution without problems 12:00 - 00:00 12.00 DRILL P INT1 Directionally Drill from 22,824' to 23,488' 9105' tvd -W / Pumps Up Wt 390k / Dn Wt 175k / RtWt 230k -W /O Pumps Up Wt 420k / Dn Wt 190k -WOB = 22 -25k -680 gpm / 3135 psi on -120 / 130 rpm / Tg Off 25k / Tg On 31k Monitor Well at connections, Static no breathing -Cal ECD = 11.27 ppg / Actual ECD = 11.92 ppg -ADT = 7.0 hrs Total Time = 55.2 hrs. SPR. #1) 2BPM= 510 PSI / 3BPM= 600 PSI SPR. #2) 2BPM= 520 PSI / 3BPM= 610 PSI MD = 23488' / TVD = 9105' Mud Wt 10.5 ppg 23:30 hrs 2/21/2009 00:00 - 12:00 12.00 DRILL P INT1 Directionally Drill from 23,488' to 24,151' 9960' tvd TD of 10.625 Intemediate Hole Section -W / Pumps Up Wt 445k / Dn Wt 178k / RtWt 240k -WOB = 22 -25k -680 gpm / 3020 psi on -120 / 130 rpm / Tg Off 29k / Tg On 34k Monitor Well at connections, Static no breathing -Cal ECD = 11.23 ppg / Actual ECD = 11.56 ppg -ADT = 7.9 hrs Total Time = 63.1 hrs. SPR. #1) 2BPM= 520 PSI / 3BPM= 620 PSI SPR. #2) 2BPM= 530 PSI / 3BPM= 630 PSI MD = 23488' / TVD = 9660' Mud Wt 10.5 ppg 12:00 hrs 12:00 - 14:00 2.00 DRILL P INT1 Circ. & Condition hole while recieving the last of the spike fluid -680 gpm / 3040 psi -425k PUW / 190k SOW / 242k RtWt Reciprocating pipe 234,151 - 24,121' 14:00 - 19:30 5.50 DRILL P INT1 Weight up to 11.0ppg Mud Wt. / Using 12.5 ppg Spike Fliud -600 gpm / 2245 psi -130 rpm / 30k ft/Ibs of torque -ECD 11.9 => 12.2 ppg adjusting parameter to maintain under 12.0 ppg EMW ECD Printed: 6/3/2009 3:57:48 PM • • BP Page 20 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours, Task Code NPT Phase Description of Operations 2/21/2009 14:00 - 19:30 5.50 DRILL P INT1 Monitor well when 11.0 ppg mud back to surface, well static 11.0 ppg in 11.1 ppg out 19:30 - 00:00 4.50 DRILL P INT1 Precautionary Back Ream out of the hole 24151 - 23,488 and -POH to Run 8.625 casing -600 gpm / 3280 psi -120 rpm / 27k ft/lbs of torque - reduce pump rate to 600 gpm to keep ECD's under 12.0 ppg Some Torque Spikes coming through the Kuparuk Sands, Back Reamed slowly through areas without problems 2/22/2009 00:00 - 01:30 1.50 DRILL P INT1 Precautionary Back Ream out of the hole 23,488 - 23,085 and -600 gpm / 2400 psi -120 rpm / 27k ft/lbs of torque - reduce pump rate to 600 gpm to keep ECD's under 12.0 ppg At 23,085 experience high torque with stalling the drill string -with 50 to 100 psi packoff reduced flow rate and RIH 23,118'md, estabilish full circulation and rotation 01:30 - 04:00 2.50 DRILL P INT1 Work through tight hole @ 23085 - 23,055 -High torque with some 50 to 100 psi pack offs, -No mud loss during the increase in pressure while working thranph tight hole - Adjusted RPM's from 120 to 180 rpm / 29k - 35k ft/lbs torque -600 gpm / 2400 psi 11.9 -12.1 ppg ECD's Work trouble area 2x Reaming @ 180 rpm and 600 gpm Slide stand down without issues, backream out without issue, - continue backreaming out of hole 04:00 - 12:00 8.00 DRILL P INT1 Precautionary Back Ream out of the hole 23,013 - 21,206' and -700 gpm / 2990 psi -170 rpm / 29k ft/lbs of torque - ECD's under 12.2 ppg 12:00 - 00:00 12.00 DRILL P INT1 Precautionary Back Ream out of the hole 21,206' - 19,208 and -700 gpm / 2810 psi -170 rpm / 29 - 31k ft/lbs of torque - ECD's under 12.2 ppg After 20,040' and delta pressure return to normal and resume back reaming @ 600' /hr At 20,600' pump pill designed to unball Bit and BHA Sweep brought up no additional cuttings or improvement in parameters 2/23/2009 00:00 - 12:00 12.00 DRILL P INT1 Precautionary Back Ream out of the hole 19,208 - 17,604 and -700 gpm / 2810 psi -170 rpm / 29 - 31k ft/lbs of torque -ECD's under 12.2 ppg - Pulling Speed 300 - 600' /hr depending ECD's and Torque 12:00 - 21:30 9.50 DRILL P INT1 Precautionary Back Ream out of the hole 17500 - 15160 and -700 gpm / 2680 psi -130 rpm / 24 - 27k ft/lbs of torque Printed: 6/3/2009 3:57:48 PM • �� BP Page 21 of 91 %�u�0 ^ - O -_���__-- -'-^^ Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2008 Rig Name: NABORS 33E Rig Number: |Houra Task Code NPT ��~����������` 2/23/2009 12:00 - 21:30 e.50 DRILL P INT1 -ECD's under 12.2 ppg -Pull Speed 000'8OOYhr depending ECD's and Torque 21:30 - 22:30 1.00 DRILL P INT1 Wash throuqh window, no rotating. -20-30 PUW drag pulling into window -30k string weight reduction as soon bit was pulled into 11 3/4" casing 22:30 00:00 1a0 DRILL P INT1 Circulate hole clean -800 gpm / 3240 psi -W/O Pumps PUW = 250K SOW = 150K RtWt = 187K -With 700 gpm PUVV=230K SOW = 140K RtWt = 175 -130 RPM / 1ukFt/LbaTorque 11.83 ppg ECD with 800 gpm 2/24/200e 00:00 03:30 3.50 DRILL P INT1 Circulate hole clean 1o.Uoomd'14.7no' Initial Parameters -800 gpm / 3240 psi -Wu} Pumps PUW=2s0K SOW = 150K RtWt = 187K -With 700 gpm PUVV=230K SOW = 140K RtW = 175 -130 RPM / 18xFVLUoTorque Sit Back 1 stand every hour -11.83 ECD with 800 gpm CBU 3x 03:30 - 06:00 2.50 DRILL P INT1 Continue Circulating clean, Reaming 1^.7OO'14.o*1'mU -shakers still showing cuttings - apx. 50% Iess than when we started oimeTOW -standirlg back 1 stand every 30 minutes '800 gpm / 3130 psi -160 RPM / 17kFt/LboTorque Final Parameters -W/O Pumps PUW = 232K SOW =14UK RtWt = 163K -With 700 gpm PUVY=220K SOW = 132K RtWt = 173k -130 RPM / 21xPVLUoTorque -11.77 ECD with 800 gpm Shakers cleaned after 4 x CBU 06:00 87:30 1.50 DRILL P INT1 PJGM/ Slip & Cut 1nr'cd drilling line 07:30 08:30 1.00 DRILL P INT1 Service Draw-works, Top Drive Blocks & Crown 08:30 - 09:30 1.00 DRILL P INT1 Obtain Parameters @ 14,340' -W/O Pumps 'puW~unow/ SOW ~14oK/nrW~17on '10 RPM /1oxFvLuoTorque '1s RPM /1OuFt/LboTorque -2o RPM /11xrvLusTorque Obtain Parameters I@14.244' -With Pumps @ 700 gpm / 2525 psi 'PUVV=2uoK/ SOW ~1osx/nTW~17ox -10 RPM / 9k Ft/Lbs Torque '15 RPM /1nkR/LUoTorque '2O RPM /1UxFt/LboTorque 0e:30 '13:30 4.00 DRILL P INT1 POH Racking back n'n8^DP from 14.z44'm11.000' Pipe coming we 13:30 - 14:00 0.50 DRILL P INT1 Pump dry job & blow down top drive and mud line 14:00 - 15:00 1.00 DRILL P INT1 PO* Racking back s'7/8^op from 11.uan'me.7ou' Printed: am/2o09unr^opm �� �� BP Page 22 of 91 -, ' • Summary Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date To Hours Taahodo NPT ° "���^� �� of Operations � 2/24/2009 15:00 - 16:30 1.50 DRILL P INT1 n|HpU1sJm5-70^co.4*xT-57DP&POH rack back same 16:30 '17:30 1.00 DRILL P INT1 Change out handling equipment to 5" 17:30 - 00:00 6.50 DRILL P INT1 POHLDn^op1m from 8,7osvo3,3oa e/25/2009 00:00 - 03:30 3a0 DRILL P INT1 POHLDo^oP1m from 3.3Osm1m6' 03:30 06:00 2.50 DRILL P INT1 PJSM LD BHA # 6 06:00 - 07:00 1.00 DRILL P INT1 Clean & clear rig floor of vendors tools 07:00 - 08:30 1.50 BOPSUF P INT1 MU BOP flushing tool and flush BOP stack with mud, function rams and repeat flush with seawater. RD flushing tool and blow down all lines 08:30 - 09:30 1.00 BOPSUF P INT1 DnuinBOpotaokandpuUwearUunmng 09:30 - 11:30 2.00 BOPSUF P INT1 nxanOeout ton set ofoipo rams mV'5/n^ 11:30 13:00 1.50 BOPSUF P INT1 MU8-5/8^ test joint, install test plug & RU tes equipment and test regulations. Test pressure approved by AOGCC Tom Maunder 13:00 - 14:00 1.00 BOPSUF P INT1 no/8|mvUmwntootoqu|pmentunUmotan1U'3/4 bushing 14:00 - 19:30 5.50 CASE P LNR1 PJSM - RU 8-5/ ^VVoamodvdmrquomm000ingoquipmamt. Torque Turn equipment in-operatable, Consult with ODE and proceed without Torque Turn capability. 19:30 - 20:00 0.50 CASE P LNR1 PJSM with all personnel for 8-5/8" casing running operations 20:00 21:00 1.00 CASE P LNR1 Mum Run x'5/8^o2#L'oOHvd,i|521 Shoe track Baker Locking all connections up the the landing collar, Torque all connections m27.5OOfNbs pumped through with 4.sbpm& checkod floats, floats held. Joints #1-4 slick No LoTorq CentraUzers 21:00 - 23:00 2.00 CASE P LNR1 Cont Running Jtsw*'uoto7nO'of 8'5/8^32#L'80 Hyd,U5e1 Liner with 1 LoTorq Centralizer floating mid joint between super duty stop rings. Torque all connections to 27,500 ftllbs. Filling every joint on the fly 23:00 - 00:00 1.00 CASE N SFAL LNR1 Casing Hydraulic power unit failed. Mobilize backup power unit. 2/26/2009 00:00 - 00:30 0.50 CASE N SFAL LNR1 Casing Hydraulic power unit failed. Mobilize backup powe unit. 00:30 '1e:00 18.50 CASE P LNR1 Cont' Running from Jts #e1'234&XO Joint /n.2GO'/8-s0^ 32# L-80 Hydril 521 Liner with 1 LoTorq Centralizer floating mid joint between heavy duty tapered stop rings. Torque all connections to 27,500 ftflbs. Used Jet Lube Seal Guard Thread Compound and Unique Machine inspect all connections. Filling every joint on the fly & circulating every 25th joint down 214 gpm. Total 231 LoTorq Roller Centralizers &4n2 Heavy duty tapered stop rings Ran on Jts # 5- 235 19:00 20:30 1.50 CASE P LNR1 LD Franks fiII-up tool. BIow down top drive. RD 350 ton Casing elevators. Change out handling tools to 5" DP. 20:30 - 21:30 1.00 CASE P LNR1 PU/mU Baker 11-3/4^xe+5/8^HRDZXP Liner too packer a Fiex Lock Liner hanger MU Line wiper plug and Torque Hydril 513 Connection vo27.50O*Nbo Pull Flush mount slips and install master bushings. RIH Inspecting Liner Hanger / Packer assembly 21:30 - 22:30 1.00 CASE P LNR1 RD Casing equipment and RU 5-7/8" DP equipment Printed. 6/3/2009 3'57 48 PM • Bp Page 23of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/26/2009 21:30 - 22:30 1.00 CASE P LNR1 MU 5" XT -50 x XT -57 XO to liner running tool. 22:30 - 23:00 0.50 CASE P LNR1 RIH to 9,465' with 8 -5/8" liner on 5 -7/8" DP laying down top single of first stand run. 23:00 - 00:00 1.00 CASE P LNR1 Fill DP and break circulation staging pumps up to 7.5 bpm 788 psi. Calculated ECD @ window 12.6 ppg 2/27/2009 00:00 - 01:00 1.00 CASE P LNR1 Cont' Circulate 1.5 Liner / DP volume @ 7.5 bpm FCP 747 psi. Mud Wt in and out 11 ppg Obtain parameters with pumps off: UWT = 170k / SOW = 140k RTW = 150k @ 5 RPM / TQ = 5k ft/lbs RTW = 155k @ 10 RPM / TQ = 6k ft/Ibs RTW = 155k @ 15 RPM / TQ = 6k ft/lbs 01:00 - 12:00 11.00 CASE P LNR1 RIH with 8 -5/8" Liner on 5 -7/8" DP from 9,465' to 14,377' @ 3.5 min / stand filling pipe on the fly Circulate down every 5th stand c_ 2 bpm / 405 psi / S/0 @ 5 min / stand 12:00 - 13:30 1.50 CASE P LNR1 RIH with 8 -5/8" Liner on 5 -7/8" DP from 14,377' to 15,004' @ 5 min / stand filling pipe on the fly Circulate down every 5th stand @ 2 bpm / 380 psi / S/0 @ 5 min / stand Obtain parameters with pumps on: 1.5 bpp / 382 psi UWT = 236k Obtain parameters with pumps off: SOW = 159k RTW = 189k @ 18 RPM / TQ = 14k ft/Ibs 13:30 - 18:00 4.50 CASE P LNR1 Cont' RIH with 8 -5/8" Liner on 5 -7/8" DP from 15,004' @ 5 min / stand filling pipe on the fly. Stood up @ 16,084' with 29k DnWt to 125k worked pipe times picked up free at 280k & Cont' RIH with no problems to 16.912' 18:00 - 19:00 1.00 CASE P LNR1 MU TDS & Bk Circulation & wash down from 16,912' to 17,007' Staging pump rate up to 5 bpm / 688 psi / S/0 @ .1 ft / sec, 385fph 19:00 - 23:30 4.50 CASE P LNR1 Cont' RIH with 8 -5/8" Liner on 5 -7/8" DP from 17,007' to 18,819' - 800 -900 fph, filling pipe on the fly. 23:30 - 00:00 0.50 CASE P LNR1 MU TDS & Bk Circulation & wash down from 18,819' to 18,885' Staging pump rate up to 4.2 bpm / 665 psi / S/0 @ < / =.1 ft / sdc 2/28/2009 00:00 - 00:30 0.50 CASE P LNR1 Circulate & wash down from 18,885' to 18,914' Staging pump rate up to 4.2 bpm / 665 psi / S/O @ < / =.1 ft / sec 00:30 - 05:00 4.50 CASE P LNR1 RIH with 8 -5/8" Liner on 5 -7/8" DP from 18,914' to 20,723' 800 ft/hr filling pipe on the fly. 05:00 - 05:30 0.50 CASE P LNR1 MU TDS & Bk Circulation & wash down from 20,723' to 20,817' Staging pump rate up to 4.2 bpm / 700 psi / S/0 @ < / =.1 ft / sec 05:30 - 09:30 4.00 CASE P LNR1 RIH with 8 -5/8" Liner on 5 -7/8" DP from 20,817' to 22,626' @ 800 ft/hr filling pipe on the fly. 09:30 - 10:00 0.50 CASE P LNR1 MU TDS & Bk Circulation & wash down from 22,626' to 22,717' Staging pump rate up to 3.4 bpm / 861 psi / S/O @ < / =.1 ft / sec 10:00 - 11:00 1.00 CASE P LNR1 RIH with 8 -5/8" Liner on 5 -7/8" DP @ 800 ft/hr filling pipe on Printed: 6/3/2009 3:57:48 PM • Bp Page 24of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/28/2009 10:00 - 11:00 1.00 CASE P LNR1 the fly. from 22,717' to 23,050' where string took weight attempt to work down without success. Pull working up to 500k. Free up Wt 440k 11:00 - 11:30 0.50 CASE P LNR1 POH to 22,960' pumping 12 spm 287 psi UWT 440k / SOW 120k 11:30 - 16:00 4.50 CASE P LNR1 Stage pump rate up to 5.5 bpm 1095 psi working pipe from 22,970 to 22,955' UWT 380 - 410k / SOW 155 - 130k _2 Attempts to rotate up to 39k ft/Ibs TQ with 240k on the hook & while slacking off without success. 16:00 - 17:30 1.50 CASE P LNR1 Pump out of hole from 22,955' to 22,531' 2 bpm / 670 psi UWT 410k / SOW 130k 17:30 - 00:00 6.50 CASE P LNR1 Reciprocate pipe from 22,531 to 22,626'and stage pump rate up to 8 bpm in .5 bpm increments and condition mud. 8 bpm / 1030 psi UWT 380 - 410k / SOW 125 -110k Mud Weights up to 11.6+ ppg seen at bottoms up Started adding Lube 776 110 minutes prior to start of washing in the hole. 3/1/2009 00:00 - 11:30 11.50 CASE P LNR1 RIH / Wash liner down from 22,626' to 23,060' With intermittent packing off starting at 22.859' 80 spm /6.8 bpm /900psi UWT Break over 450k pull @ 415k / SOW 123 - 100k 11:30 - 13:30 2.00 CASE P LNR1 Packed off @ 23,060' Work pumps and regain circulation Work pumps up to 80 spm / 284 gpm / 887 psi Pull 560k broke over UWT 460k / SOW 130k 13:30 - 14:30 1.00 CASE P LNR1 Wash down from 23,055' to 23060' 84 spm / 299 gpm / 950 psi DWT 95k 14:30 - 16:30 2.00 CASE P LNR1 Packed off @ 23,060' Work pumps and regain circulation, Work pumps up to 60 spm / 214 gpm / 640 psi Pull 555k broke over UWT 460k / SOW 140k Worked liner from 23,060' to 23,095' 16:30 - 19:30 3.00 CASE P LNR1 Wash liner from 23,065' to 23,095' 60 spm / 214 gpm / 640 psi 19:30 - 23:00 3.50 CASE P LNR1 Liner packed off after connection @ 23,095' Work pumps and regain circulation Work pumps up to 60 spm / 214 gpm / 626 psi 23:00 - 00:00 1.00 CASE P LNR1 Worked pipe Pulling 410k / SO to 95k Racked back stand and PU single 26# DP Re- establish circulation 214 gpm 640 psi Pull working up to 520k broke free PU to 23,070' UWT 475k / SOW 145k 3/2/2009 00:00 - 12:00 12.00 CASE P LNR1 Wash liner down from 23,090' to 23,153' With intermittent packing off 70 spm / 249 gpm / 722 - 656 psi Bk over WT 540k / UWT 470k / SOW 140k 12:00 - 19:30 7.50 CASE P LNR1 Wash liner down from 23,153' to 23,227' With intermittent packing off 60 spm / 214 gpm / 687 - 605psi Bk over WT 480k / UWT 460k / SOW 140k 19:30 - 21:30 2.00 CASE P LNR1 Packed off @ 23,227' Printed: 6/3/2009 3:57:48 PM • �� - • BP Page 25 of 91 Operations Sum q Repor Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To H NPT Phase ru,^� ��� �� Task � naaeR�� - Operations 3/2/2008 19:30 - 21:30 2.00 CASE P LNR1 Regain circulation and stage pump rate up 60 opm/214gpm/605pai 21:30 - 00:00 2.50 CASE P LNR1 Wash liner down from 23.227' to 23.230' With intermittent packing off 60 spm / 214 gpm / 645 605 psi ax over YVTouUk/UVvT48Ok/ SOW 1snk 3/3/2008 00:00 - 04:30 4s0 CASE P LNR1 Wash liner down from uo.o3O'meo.o08' With intermittent packing oft 0Uopm/214gpm/045'62opsi SOW 150k - 140k 04:30 05:30 1.00 CASE P LNR1 Packed off @ 23.280' Regain circulation and stage pump rate up e0 opm/214gpm 05:30 - 12:00 6s0 CASE P LNR1 Wash liner down from 23.00e'm23.uno' With intermittent packing off With varying flow rates and pressures 12:00 - 14:00 2.00 CASE P LNR1 Wash liner down from 23.u85'tu23.31e' With intermittent packing off 5oopm/178 gpm/640 690 psi SOW 155k 14:00 - 15:30 1.50 CASE P LNR1 Packed off @ 23,312' Regain circulation arid stage pump rate up 00 opm/214 gpm/681pai 8k over VvT53Ok/UYVT4ewk/ SOW 1oOh 15:30 00:00 8o0 CASE P LNR1 Wash liner down from u3.312'mu3.309' With intermittent packinQ off workin centralizers into the tqp q the 'Kalubik 0Uopm/o14gpm/04opsi Bk over VYT52Ox/UVVT48Ok/ SOW 15ox 3/4/200e 00:00 12:00 12.00 CASE P LNR1 Wash liner down from 23.3ee'mu3.471' With intermittent packing off working ceritralizers into the top of the Kalubik 60 spm / 214 gpm / 640 710pa| SOW 153k 12:00 13:00 1.00 CASE P LNR1 Wash liner down form 23.471'mo3.47S' With intermittent packing off Working pumps 50 - 60 spm / 178 - 214 gpm / 700 750 psi SOW 150k Packed off at 23,479' 13:00 - 16:00 3.00 CASE P LNR1 Packed off @ 23,479' Regain circulation and stag pump rate up at 1 spm intervals to 55opm/770 psi Bk over WT 550k / SOW 150k 16:00 - 17:30 1s0 CASE P LNR1 Wash liner down form uo.479'muo.4en' With intermittent packing off Working pumps 55 - 60 spm / 195 214 gpm / 700 - 750 psi SOW 150k Packed off at 23,495' 17:30 19:00 1.50 CASE P LNR1 Regain circulation and stage pump rate upto 58 spm / 754 psi Printed: 6m/2009 3.57:4 PM • • BP Page 26 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/4/2009 19:00 - 19:30 0.50 CASE P LNR1 Wash liner down form 23,495' to 23,505' Working centralizer to the top of the Kalubik Working pumps 58 spm / 206 gpm / 755 psi SOW 150k - 130k 19:30 - 21:00 1.50 CASE P LNR1 Regain circulation and stage pump rate up to 55 spm / 750 psi 21:00 - 21:30 0.50 CASE P LNR1 Wash & worked liner down form 23,505' to 23,530' Working centralizer through the top of the Kalubik and reducing pump to reduce pump up force with pumps 55 spm / 196 gpm / 750 psi SOW 150k - 130k 21:30 - 23:00 1.50 CASE P LNR1 Stage pump rate up to 55 spm / 723 psi 23:00 - 00:00 1.00 CASE P LNR1 Wash liner down form 23,530' to 23,545' Working pumps 50 spm / 178 gpm / 674 psi SOW 150k 3/5/2009 00:00 - 00:30 0.50 CASE P LNR1 Wash liner down form 23,545' to 23,555' 50 spm / 178 gpm / 690 psi Reduced pump rate to 38 spm / 135 gpm / 600 psi to work centralizer through top of the Kalubik. Packed off SOW 150k - 130k PU Pulled 550k and pull up to 23,550' 00:30 - 06:00 5.50 CASE P LNR1 PU & Pull 550k x2 second attempt Pulled up to 23,550' S/O to 200k & stage pump rate up at 1 spm intervals to regain circulation 28 spm / 100 gpm / 643 psi 06:00 - 07:30 1.50 CASE P LNR1 Cont' Regain circulation Working pipe pulling to 300k S/0 to 150k 5 times Working pipe pulling to 500k S/0 to 125k 11 times 28 spm / 582 psi 07:30 - 11:00 3.50 CASE P LNR1 Wash down from 23,550' to 23,557' working centralizer # 8 into, Kalubik Dn Wt 162k S/O to 125k 43 spm / 153 gpm - 651 psi working up to 60 spm / 213 gpm -790 psi 11:00 - 12:00 1.00 CASE P LNR1 Pull liner up from 23,557' to 23,555' attempting to move liner UWT 550k / S/0 to 125k Pump 72 spm / 256 gpm - 944 psi on up stroke Pump 30 spm / 107 gpm - 542 psi on down stroke 12:00 - 14:00 2.00 CASE P LNR1 Continue working pipe pulling from 600k working up to 660k, pulled free Pump 40 spm / 142 gpm - 140 psi SOW 130k 14:00 - 17:30 3.50 CASE P LNR1 Stage pump rate up and clean up annulus. 60 spm / 213 gpm - 815 psi 75 spm / 266 gpm - 880 psi 84 spm / 298 gpm - 984 psi Printed: 6/3/2009 3:57:48 PM BP Page 27 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/5/2009 14:00 - 17:30 3.50 CASE P LNR1 UWT 450k / SOW 150 - 130k 17:30 - 18:30 1.00 CASE P LNR1 PU to neutral Wt 230k @ 23,523'& shut down pumps & attempt to rotate liner Rotate 19 rounds to the right with 45k ft/Ibs torque, stalled out. Ralease toraue. 14 rounds back. Attempt to rotate while slacking off while rolling pump @ 16 spm / 385 psi Rotate & slack off to 23,527' to 165k hook load 16 rounds to the right @ 40k ft/Ibs Torque, stalled out. Release torque, 14 rounds back. Stage pump up to 74 spm / 263 gpm - 912 psi PU to 23,495' Pulled to 610k bk over UWT 540k / SOW 145k 18:30 - 00:00 5.50 CASE P LNR1 Wash and Work liner down from 23,495' to 23,532' Held up repeatedly workina centralizer into top of Kalubik 23,512' to 23,520' Worked pumps from: 95 spm / 337 gpm - 1020 psi 50 spm /177 gpm - 643 psi Bk over Wt 510k / UWT 460k / SOW 140 - 130K 3/6/2009 00:00 - 13:30 13.50 CASE P LNR1 Wash and Work liner down from 23,532' to 23,540' Held up repeatedly working centralizer into top of Kalubik 23,540' with mild intermittent pack -offs then cleaning up. Continue working obstruction @ 23,540' working liner from 23,525' to 23,540' Worked with & without pumps from: 136 spm / 483 gpm - 1526 psi 93 spm / 330 gpm - 984 psi 40 spm / 142 gpm - 599 psi UWT 460k - 430k / SOW 150 - 145K Mobilize Schlumberger Cementers 13:30 - 16:00 2.50 CASE P LNR1 PJSM - LD Single 5 -7/8" DP Blow down top drive and mud line PU / MU Baker liner cement head & RU cement lines Resume circulation @ 243 gpm 840 psi 16:00 - 16:30 0.50 CEMT P LNR1 PJSM on cementing operations with all personnel 16:30 - 20:30 4.00 CEMT P LNR1 Switch over to Dowell and pump 5 bbl 13 ppg Mud Push. Test cement lines to 5000 psi. good test. Pump 71.6 bbls 13 ppg Mud Push II @ 5 bpm. Pump 60.9 bbl 15.8 ppg Class G Cement. Kick out wiper dart with 10 bbls 8.4 ppg sea water Switch over to rig pumps and displace @ 5 bpm, slowed to 3 bpm to latch up wiper plug CO 3846 strokes. No indication of latch, Resume 5 bpm @ 4200 strokes, slowed to 3.3 bpm € 10,440 strokes to bump, pumped total 11,124 strokes & shut down without plug bumping. Pumped job with full returns. RD cement hose and check floats, small 1/4" stream flowing back. Remove swing & plug cement head & open TIW valve. Printed: 6/3/2009 3:57:48 PM • • BP Page 28 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/6/2009 16:30 - 20:30 4.00 CEMT P LNR1 20:30 - 21:30 1.00 CEMT P LNR1 Consult with ODE on forward plan Set string with 200k hook load rotate to the left with 10k ft/Ibs torque and S/O to 100k. PU indication free from liner 220k, Release torque and S/O to 100k appeared that packer set with weight back to120k. Rotate to the right with with 20k ft/Ibs torque. HRD torque fingers still engaged. PU to 260k and pull 5' to expose HRD torque fingers. S/0 to 95k good indication packer set PU & repeated with rotation 20 rpm 10k ft/lbs Tq. PU to clear seals from RS nipple & engage rig pumps pressured up to 1343 psi. & held checked surface equipment & bleed off. PU 5 additional feet & engage pumps, pressured up to 1600 psi & cleared, ramped up pumps to 710 gpm / 1237 psi TOL 14,241' 21:30 - 00:00 2.50 CEMT P LNR1 Circulate hole clean with 710 gpm 1237 psi reciprocating pipe above TOL @ 14,241' 3/7/2009 00:00 - 01:30 1.50 CEMT P LNR1 Continue circulate 3x bottoms up reciprocating pipe until hole cleaned up with 710 gpm 1237 psi. Above TOL @ 14,241'. Monitor well, Static. Mud Wt 11 ppg in and out. Pump dry job. Large quantity of barite on first bottoms up cleaning up by third bottoms up. No mud push or cement noted while circulating. 01:30 - 03:00 1.50 CEMT P LNR1 Stand Back cement head assembly, POH 1 stand to 14,070'. RIH with Cement assembly on double DP & LD Cement head assembly & Clear floor. PU Single of 26# DP with 2x S Sliders. 03:00 - 07:00 4.00 CEMT P LNR1 POH with liner running tool from 14,070' to 8,620' WWT Hand inspecting condition of Super Sliders. 07:00 - 14:00 7.00 CEMT P LNR1 POH with liner running tool from 8,620' to 4,637' WWT / Remove 2x per joint Super Sliders. Total 264 laid down. 14:00 - 16:00 2.00 CEMT P LNR1 POH from 4,637' to 649' 16:00 - 17:00 1.00 CEMT P LNR1 PJSM - POH LD 19 jts 5 -7/8" 23# DP 17:00 - 18:00 1.00 CEMT P LNR1 Inspect / Make service breaks LD Baker Liner Running Tool. Running tool in good condition. 18:00 - 18:30 0.50 CEMT P LNR1 Clear rig floor of vendors tools 18:30 - 19:30 1.00 BOPSUF P LNR1 MU BOP flushing tool. Flush stack, functions rams, repeated flushing ops. LD flushing tool and blow down top drive & mud lines. 19:30 - 20:00 0.50 BOPSUF P LNR1 Drain Stack, MU Wear bushing running tool and retrieve wear bushing. 20:00 - 22:00 2.00 BOPSUF P LNR1 PJSM - Change out top set of pipe rams to 4 -1/2" x 7" VBR's Service top drive grabber dies. Change out Top Drive lower well control valve. 22:00 - 00:00 2.00 BOPSUF P LNR1 PJSM - MU Test plug, floor safety & IBOP valves to 5 -7/8" test joint & install same, RU test equipment, fill stack & choke Printed: 6/3/2009 3:57:48 PM BP Page 29 of 91 Operations Summary ~~ Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2089 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Description wn" , Code ��NPT � � 3/7/2009 22:00 - 00:00 2.00 BOPSUF P LNR1 manifold with sea water 3/8/2009 00:00 - 06:00 6.00 BOPSUF P LNR1 Test BOPE as per BP/AOGCC Regulations vu2oO psi low / 4500 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Test witnessed by Lou Grimaldi (AOGCC State Inspector) Chris Clemens (WSL), Brian Tiedemann (NAD Too|pusho4. Sean Holcomb (mAoDm|er). Test ao follows with 5'70^ Test Joint. Test as foliows with 250 psi / 4500 psi. #1) Top 4a^x7' VBn/*'n8^|BOP/ Choke Valves #8.1ca 13/ Kill Line &c^Domoo #2)s-7/8^ Floor Safety Valve / Kill HCR/ Choke Valves wu& 11 #3) Choke Valves # 4, 7, & 10 #4) Choke Valve # 3-5-6 / Manual Kill Line Valve #5) Super Choke & Manual Choke Manifold Valves #6) Choke Valve #1, 3 & 5 #7) Choke Vaive #2, Needle vaive leaking on test equipment #8) Choke Valve #2, Passed #9) Choke HCnValve #10) Lower Top Drive Well Control Valve / Manual Choke Line Vaive on stack w11) Bottom 3.5^x8^VBR/ Upper Top Drive Well Control Valve #12) Accumulator Function / Draw Down Test #13V Blind Shear Rams Note: 1 Hour time change DST 06:00 - 07:00 1.00 BOPSUF P LNR1 Change out Test equipment to 4-1/2" 07:00 - 08:30 1a0 BOPSUF P LNR1 Test witnessed by Lou Grimaidi (AOGCC State Inspector) Brian euzby(wS4. Bill Bixby (wADToo|puoher).Sean Holcomb (mAoDm|or). Test as foliows with 4'1/2^ Test Joint. # Top *.5rx7veR/4'1/2" Floor Safety Valve / Top V8R Pipe Rams Failed #15) Bottom 3.a^xO^VBR/4'1/e Floor Safety Vaive #16V4-1/2^\8OP #17) Annular 250 psi / 3500 psi 08:30 11:00 2.50 BOPSUF N SFAL LNR1 PJSM - Open top ram gate, remove and rebuild 4.5"x 7" VBR's and re-install same. 11:00 - 11:30 0.50 BOPSUF P LNR1 Test ao follows with 4'1/e^ Test Joint. #18) Top 4.o^x7^v8R/4-1/u^ Floor Safety Valve / Top VBR Pipe Rams Passed 11:30 12:30 1o0 BOPSUF P LNR1 Change out Test equipment to 5-7/8" 12:30 13:00 0.50 BOPSUF P LNR1 Test ae follows with a-7/8^ Test Joint. w19) Top 4.5"x7"VBR/o-7/o Floor Safety Valve / Top man Pipe Rams Passed 13:00 1*:00 1.00 BOPSUF P LNR1 Pull tes plug, RD / BIow down test equipment. 14:00 - 15:00 1.00 BOPSUF P LNR1 MU Wear bushing running too / Install 10'13n8^|DWear Bushing / LD running tool & test joint. 15:00 15:30 0.50 BOPSUF P LNR1 Clear and ready rig floo to PU BHA 15:30 - 16:30 1.00 DRILL P LNR1 PJSM on PU BHA #7 with crew, service personnel, WSL & Toolpusher Printed' 6/3/2009 3:57:48 PM • ��� ���) ���� �� � B p Page 30 of 91 op era ti ons summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1X25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - �N�'�" Hours Task ��ode`~NPT Operations 3/8/200e 10:30 18:00 1s0 DRILL P LNR1 PU/w0 BHA #7 Consisting m Bit 7-7/8" QHC1S / Bit Sub /XO/XD/3OxJts.4'1/u^ xTM-4oTn'Gpim|HvvoP/XO/ Jar /XD/ To 953' 18:00 ' 18:00 1.00 DRILL P LNR1 RIH PU4'1/u^ 18.8#CTM'43oP 1x1 to 1.474' 19:00 - 20:30 1a0 DRILL P LNR1 PJSM/ Service Rig Slip & Cut 1o*' drilling line 20:30 - 21:30 1.00 DRILL P LNR1 Service Draw-works, Top Drive, Blocks & Crown 21:30 - 00:00 2.50 DRILL P LNR1 R|MPU4'1/2"16.VwCTM-43DP1m from 1,474tou.00V 3/9/2008 00:00 08:30 9.50 DRILL P LNR1 FUMPU4'1/2"18.6#CTM-4oDP1m from u,6osm1U.1nr Fill DP every 3000 09:30 - 10:00 0.50 DRILL P LNR1 Change out handling tools to 5-7/8" 10:00 - 12:00 2.00 DRILL P LNR1 R|H from 1O.17o'm12.1U7 Fill pipe / break circulation & obtain parameters 350 gpm / 1010 psi Pumps on UWT 172k / SOW 122k Pumps off UVVT18Ox/ SOW 1usk 1eo0 '13:30 1a0 DRILL P LNR1 R|H from 1o.1o7m14.18O' 13:30 14:00 0.50 DRILL P LNR1 FiII pipe / break circulation & obtain parameters @14.1oV' 500 gpm / 1915 psi Pumps onUw7190x/ SOW 132x/RWT160k@m RPM / TQ 7k Pumps off UVVT2UOk/ SOW 14ok 14:00 14:30 0.50 EVAL P LNR1 Attempt to test 8's0^liner Pump 2O5 strokes /1o7S psi / Bled down toe5o psi m1omin Bleed off pressure, BIow down top drive & kill line 14:30 15:30 1o0 DRILL P LNR1 R|H from 14.18U'm1o.O81' 15:30 - 16:00 0.50 DRILL P LNR1 Fill pipe/ break circulation & obtain parameters @ 16.081' 5UOgpm/1o4opsi Pumps on UWTu1ok/ SOW 140u/RWT173k@0 RPM / TO 10k Pumps off UVYTouok/ SOW 1sou 16:00 - 17:00 1o0 DRILL P LNR1 R|H from 1e.O91'm1o.oe4' 17:00 - 17:30 0.50 DRILL P LNR1 Fill pipe / break circulation & obtain parameters @ 18,094 500 gpm / 2130 psi Pumps onUYvTuook/ SOW 135k/RYvT173k@7O RPM / TQ 12k Pumps off UVVTu4Ox/ SOW 15ok 17:30 - 18:30 1.00 DRILL P LNR1 R|* from 18.Ue^'m18.eee' 18:30 19:00 0.50 DRILL P LNR1 Fill pipe / break circulation & obtain parameters @ 18.9e2' aoogpm/uc35psi Pumps on UWT 260k / SOW 141k / RWT 194k @ 70 RPM / TQ 12k Pumps off UWT 280k / SOW 154k 19o0 20:30 1.50 DRILL P LNR1 R|H from 1e.aou't000.o8o' 20:30 21:00 0.50 DRILL P LNR1 Fill pipe / break circulation & obtain parameters @ 22,088' 500 gpm / 2442 psi Pumps onUw7295k/ SOW 148x/RWTuouk@7U RPM / TQ 14k Pumps off UvVTo21k/ SOW 1O5k Note: Pieces of solo wiper plug and wiper dart recovered off of shakers Printed: 6/3/2009 3:57 48 PM --- �� �� �� BP Page 31 of 91 Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NAB{}R8 ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: � ~� ��� �� '�UUUU�0 Date From To �«e '"r���L, Phase �,, �� Description of Operations 3/9/2009 2110 22:30 1.50 DRILL P LNR1 RIH from 22,088'm23,413'and tag up on landing collar with lOk confirm tag up. Pumps off UWT n5Ox/ SOW 1O5k/SOW 16uhon second tag 22:30 - 23:00 0.50 DRILL P LNR1 Fill pipe / break circulation 23,400' n0gpm/woopsi Circulate and hold PJSM for casing test 23:00 - 00:00 1.00 EVAL P LNR1 Test 8'sm^liner Pump o1a strokes /28OO psi / Held for 3O min and record on chart 3/10/2009 00:00 - 00:30 0.50 EVAL P LNR1 Bleed off pressure, Blow down top drive & kill line 00:30 02:00 1.50 DRILL P LNR1 Drill Plugs & Landing Collar from 23,413'm23.418' 600 gpm / 3160 psi UWT 330k / SOW 185k/ RWT 245k VYOB1O'15k/8O RPM /TQ off eoxM/|bu/n]onun'o4xo/|bo SPR. #1) 2BPM= 540 PSI / 3BPM= 640 PSI SPR. #2) 2BPM= 540 PSI / 3BPM= 640 PSI MD=z3.o73' Mud N 02:00 02:30 0.50 DRILL P LNR1 Wash from uo.418'mFC @23.4er'no firm cement found 525 gpm 2480 02:30 08:00 3.50 DRILL P LNR1 Drill Float CoIIar from 23.497' to 23,499' wash down to & drill shoe @ 23,538' 600 gpm / 3125 psi UWT 330k / SOW 165x / RWT 245k VVO81o'1ok/80 RPM /TQ off oUkMNUs/n]on21'u4k*NUa High PH & trace cement back to surface while drilling / washing float equipment shoe track. 06:00 - 12:00 6.00 DRILL P LNR1 Ream from un5*O'mdtoo3.981'mU -600 gpm / 3014 psi 1uo rpm /Tqo2'u3*NUo -PUW =360 / SOW = 190 / RtWt = 240 -Without Pump PUW = 375 / SOW = 190 Connections performed as per North Star connection practices 12:00 - 14:30 2.50 DRILL P LNR1 Ream from 23991'mdmu*.1*1'md -600 gpm / 3005 psi '12O rpm /Tqou'23nNbu -PUW =367 / SOW = 182 / RtWt = 242 -Without Pump PUW = 381 / SOW = 191 Connections performed as per North Star connection practices 14:30 - 16:00 1s0 DRILL P LNR1 Back Ream from 24,151 'u3.ouo'mU -500 gpm / 2250 psi -120 rpm /Tq uoknNUs Hole started packing off and torque increased 16o0 '18:00 2.00 DRILL P LNR1 POHf/uo.n8O'oo4no '30koveqpuo@23.725'md 18:00 18:30 0.50 DRILL P LNR1 Circulate upin casing at23.n18'md -600 gpm / 2820 psi -120 rpm / 20k ft/lbs of Torque 18:30 1e:30 1.00 DRILL P LNR1 Perform LOT / FIT m14.nppg EMW -17.3 bbls pump / 205 strokes Printed 6/3/2009 3.57 48 PM �� �m� Page 32 of 91 BP Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+C[}K4PLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: U � Cod��y8p7� Phase �,�� '���� Hours Task Code -�� 3n0/2009 18:30 - 19:30 1z0 DRILL P LNR1 -1650 psi -11 .oppg mud |n/Out -9152wU@shoe -Shut in pressure drop from 1e*om1400 psi over ten minutes LOT witness by8PvvGL Brian suzby/ Dave wmwon.wAoTP Bill Bixby & Brian Tiedemann 19:30 - 21:00 1.50 DRILL P LNR1 Prepare Active Pit system to weight up mud from 11.0 ppg to 13.0 ppg 21:00 00:00 3.00 DRILL P LNR1 Weight un from 11.Onnqm13.Onnn using spike fluid from G& '5OOgpm/ 2180 psi -80 rpm /17khNUoofTorque 3/11/2009 00:00 - 01:00 1u0 DRILL N FLUD LNR1 Weight up from 11.0 ppg to 13 13.0 ppg using spike fluid from 0 & -500 gpm / 2180 psi -80 rpm /17kft/lUuofTorque �vVhen1u.o'1o.8nnnmuUwoo,o«uminotosu�auonuvm� martod to decrease and hole started tajjjg fluid at 100 to 120 barrels per hour dynamic loss 01:00 - 02:00 1.00 DRILL N FLUD LNR1 Monitor static loss rate at 35 - 90 bph _ -after one hour loss rate had slowed to 24 boh Consult with Anchorage Rig Team to formulate forward plan 02:00 08o0 6.00 DRILL N FLUD LNR1 Continue monim,o�min|000�e u 20 up»|000mm rate 3:45 18bph loss rate 4:45 14 bph loss rate 5:45 oupx loss rate 8:45 8Uph loss rate 7:45 4 bph loss rate -Rig Building LCM P111, 80 barrels at 80 pounds per barrel LCM 'G&| Building uOO barrels of11.oppbmud -Mud Plant in Deadhorse buliding 580 barrels of 12.5 ppg fluid 08:00 - 09:00 1.00 DRILL N FLUD LNR1 Weight up surface pits to 12.5 ppg MW o:OOx,oUph loss rate 09:00 12:00 3.00 DRILL N FLUD Lm R1 Bui|d12.5ppgMuU 'VVoi�ingonoonUa,m|of1o.5ppg mud from mud plant -Building mud @G&| -Static mud loss = zero bph 12:00 14:00 2.00 DRILL N FLUD • LNR1 Build 12.5 ppg Mud -Waiting on 580 barrel of 12.5 ppg mud from mud plant -Building mud @G&| -Static mud loss = zero bph _'Hn|oo|o*�Uma�ingUook"daUUe�d 14:On'1aon 1.00 DRILL N FLUD LNR1 Attempt to break circulation and condition mud -staged up to 75 gpm / 250 psi 1oon,mud|oaa.noreturns -Blow Down TDS and Mud Line 15o0 20:00 5.00 DRILL N FLUD LNR1 POH from 24,480 to 22,613 Printed 6/3/2009 3:57.48 PM � � �� �� �� �� �� BP Pa 33 °f 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From U- ��� f��� i� Hou[s .��|oak Code NPT Phase ���� ,amnmmm 3n1/200e 15:00 'e0o0 5.00 DRILL N FLUD LNR1 -Hole swabbing -Filling Drill Pipe @ 2 bpm while POH -No flowback observed while pumping out 20:00 21:00 1.00 DRILL N FLUD LNR1 Attempt to establish Circulation and Condition Mud with full returns -30 rpm / 14k ffilbs torque -12.5 ppg Mud Weight -Staged up slowly -42 gpm 300 psi 0% flow no returns '8egpm 450 psi 0% flow no returns -126 gpm 594 psi 0% flow no returns -168 gpm 714 psi 0% flow no returns Pump 85 barrels with zero returns when we started to riet 2-3 netvna. increased flow rate m^oonnm/18OO psi and 11ya returns, building m1o% and a dynamic loss rate of00'ooUpo After 250ostrokes (212 barrels) Loss Rate increased to 160 - 190 bph, decrease flow rate 300 gpm / 1436 psi, flow rate 1u%. after 4uoo total strokes (3o7UU|o) flow rate reduced m 9% and Ioss rate rate increase to 170 190 bph, reduce flow rate to 240 gpm 1052 psi, 7 % flow rate, flow decrease to 4%, 90% Ioss, shut down pumping and observe well no flow or Ioss, -Total of 192 barrels loss for the hour 21:00 - 00:00 3.00 DRILL N FLUD LNR1 POH, pumping out CO 2 bpm -no issues pulling pipe -friction factors at .15 3/12/2009 00:00 - 01:45 1.75 DRILL N FLUD LNR1 POHto19.o4smd Pumping out @obpm -no issues POH 01:45 - 03:00 1.23 DRILL N FLUD LNR1 Attempt to establish Circulation and Condition Mud with full returns -30 rpm / 11xANbatorque -12.5 ppg Mud Weight -Staged up slowly -42 gpm 430 psi 0% flow no returns - 130 psi higher than previous circ Increase to 80 rpm /1akh8Uaoftorque -84 gpm 559 psi 0% flow no returns - 109 psi higher than previous circ -126 gpm 657 psi 0% flow no returns 61 psi higher than previous circ -168 gpm 785 psi 0% flow no returns - 71 psi higher than previous circ -210 gpm 909 psi spa flow '70001OoUpx loss rate dynamic loss rate Total 70 barrels Ioss 12.1 ppg mud wt coming out / 63 sec Vis Pnnted. 6/3/2009 3 57.48 PM • • BP Page 34of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/12/2009 01:45 - 03:00 1.25 DRILL N FLUD LNR1 Monitor well, well static with no loss or gain 03:00 - 12:00 9.00 DRILL N FLUD LNR1 POH, attempt to pull without pumping, no issues pulling -pipe not taking proper fill (1 barrel per 5 stands) POH pumping at 2 bpm 12:00 - 13:00 1.00 DRILL N FLUD LNR1 POH to 14,168' and -above Top of Liner(14.241') -POH Pumping @ 2 bpm 13:00 - 22:30 9.50 DRILL N FLUD LNR1 Circulate and Condition Mud -Stage up to 270 gpm / 720 psi - Pumped at 270 gpm for a full circulation to reduce loss rate -110 rpm / 15k ft/lbs of Torque - Barite on shakers reduced after 1.25 Bottoms Up - Gradual Loss initially but reduce to zero loss after Bottoms Up Staged up to drilling flow rate with 12.0 ppg mud wt. -500 gpm / 2013 psi -110 rpm / 15 ft/lbs of Torque -No Loss Down Hole, Shakers volume increased significantly at higher flow rate - Barite on shaker reduced to less than 10% of previous after bottoms up 22:30 - 00:00 1.50 DRILL N FLUD LNR1 RIH staging in 3000' before Circulating and Conditiion hole 3/13/2009 00:00 - 01:45 1.75 DRILL N FLUD LNR1 RIH to 17,317 01:45 - 12:00 10.25 DRILL N FLUD LNR1 Circulate and Condition Mud -Stage flow rate, monitor well for losses -110 rpm / 22k ft/Ibs -84 gpm / 387 psi / 3% flow - no loss to hole -128 gpm / 459 psi / 6% flow - no loss to hole - 200 gpm / 700 psi / 12% flow - no loss to hole -250 gpm / 850 psi / 15% flow - no loss to hole -300 gpm / 1060 psi / 19% flow - no loss to hole -350 gpm / 1276 psi / 21% flow - no loss to hole -400 gpm / 1490 psi / 22% flow - no loss to hole -500 gpm / 2131 psi / 26% flow - no loss to hole -550 gpm / 2425 psi / 26% flow - no loss to hole -600 gpm / 2715 psi / 27% flow - no loss to hole -650 gpm / 3028psi / 27% flow - no loss to hole The amount of Barite being cut by the shakers has been reduced to approximately 10% of previous discharge 12:00 - 14:30 2.50 DRILL N FLUD LNR1 Circulate and Condition Mud -700 gpm / 3363 psi / 28% flow - no loss to hole - Rotating with pump PUW 205k -120 rpm / 24k ft/Ibs of Torque Small amount of Barite coming off shaker screens 14:30 - 16:00 1.50 DRILL N FLUD LNR1 Circulate and Condition mud at a reduce rate while servicing Top Drive, Crown, and Draw Works -357 gpm / 1150 psi -no rotation 16:00 - 19:30 3.50 DRILL N FLUD LNR1 RIH with 30 stands of Drill pipe to 20,192' and Printed: 6/3/2009 3:57:48 PM • BP Page 35 of 91 Operations Summary Repor Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2009 16:00 - 19:30 3.50 DRILL N FLUD LNR1 - Filled pipe after 15 stands 19:30 - 00:00 4.50 DRILL N FLUD LNR1 Circulate and Condition Mud -Stage flow rate, monitor well for losses -30 rpm / 29k ft/lbs -50 gpm / 325 psi / 0% flow - no loss to hole -120 rpm / 29k ft/Ibs of torque -100 gpm / 445 psi / 4% flow - no loss to hole -200 gpm / 798 psi / 12% flow - no Toss to hole -250 gpm / 957 psi / 15% flow - no Toss to hole -300 gpm / 1180 psi / 18% flow - no loss to hole -350 gpm / 1416 psi / 20% flow - no loss to hole -400 gpm / 1654 psi / 22% flow - no loss to hole Circulate bottoms at 400 gpm after Bottoms up @ 400 gpm / 1574 psi / 23% flow - no loss to hole Small increase in Barite on shakers at bottom up Increase Pump rate to 500 gpm -500 gpm / 2070 psi / 25% flow - no loss to hole Circulate bottoms at 500 gpm after Bottoms up @ 500 gpm / 2189 psi / 25% flow - no loss to hole No increase in Barite on shakers at bottom up 3/14/2009 00:00 - 04:00 4.00 DRILL N FLUD LNR1 Circulate and condition mud 120 rpm / 29k ft/Ibs of Torque Increase Flow Rate to 650 GPM -650 gpm / 3140psi / 27% flow - no loss to hole Circulate bottoms at 650 gpm after Bottoms up @ 650 gpm / 3140 psi / 28% flow - no Incc to hnla No increase in Barite on shakers at bottom up Monitor Well 11.9+ In / Out 04:00 - 06:00 2.00 DRILL N FLUD LNR1 RIH with 15 stands 21,616 2 minutes / stand running speed 05:30 - 12:00 6.50 DRILL N FLUD LNR1 Circulate and Condition Mud Stage flow rate, monitor well for losses -123 rpm / 31k ft/Ibs -350 gpm / 1471 psi / 21% flow - no loss to hole Bottom uo unloaded Substantial amount of Barite off shakers -600 gpm / 2920 psi / 28% flow - no loss to hole Shakers cleaned up after 2nd botoms up 12:00 - 14:30 2.50 DRILL N FLUD LNR1 RIH with 15 stands 23,518' and 2 minutes / stand running speed 14:30 - 20:30 6.00 DRILL N FLUD LNR1 Circulate and Condition Mud Stage flow rate, monitor well for losses -500 gpm / 2365 psi / 28% flow - no loss to hole -PUW 350k / Sow 159k / RtWt 252k -120 rpm / 34k FULbs of Torque Bottom up unloaded Substantial amount of Barite off shakers, After bottoms up the barite coming off the end of the shakers was greatly reduced after 30 minutes after initial bottoms up with very little coming off shakers Printed: 6/3/2009 3:57:48 PM • BP Page 36 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/14/2009 20:30 - 00:00 3.50 DRILL N FLUD LNR1 Pump Steel Lube pill surface to surface to torque -80 barrel steel lube pill -500 gpm / 2300 psi -120 rpm / 38k ft/Ibs initially and a final of 35k ft/lbs of Torque Dump Pill to G & I when pill returned to surface 3/15/2009 00:00 - 00:30 0.50 DRILL N FLUD LNR1 Take Slow Pump Rates and Service the Rig SPR. #1) 2BPM =430 PSI / 3BPM =520 PSI SPR. #2) 2BPM= 450 PSI / 3BPM= 520 PSI MD = 23519' / TVD = 9135' Mud Wt 11.8 ppg 00:30 - 07:00 6.50 DRILL N FLUD LNR1 Ream Open Hole Slowly, 23,540 - 24,151 and -120 rpm / 33 -36k ft/Ibs of torque -450 gpm / 1980 psi / 26% of flow Bottom up unloaded Substantial amount of Barite off shakers, After bottoms up the barite coming off the end of the shakers continue with 50% coverage on the screens 07:00 - 10:30 3.50 DRILL P LNR1 Drill 30' of new hole 24,151 - 24,181md -ROP @ 10' /hr -120 rpm / 38k ft/Ibs of torque -450 gpm / 2020 psi / 26% of flow -10k WOB -390k PUW / 180k SOW / 240k RtWt - Maintaining 12.0 ppg mud weight 10:30 - 12:00 1.50 DRILL P LNR1 Circulate and Condition mud on bottom -450 gpm / 2020 psi -120 rpm / 37k ft/Ibs Torque 12:00 - 15:00 3.00 DRILL P LNR1 POH to inside casing at 23,518'md 15:00 - 16:00 1.00 DRILL P LNR1 Circulate and Condition Mud for LOT -450 gpm / 2020 psi -120 rpm / 37k ft/Ibs Torque 12.0 ppg In /Out 16:00 - 17:00 1.00 DRILL P LNR1 Perform LOT - Function Test BOP Rams 17:00 - 18:30 1.50 DRILL N DPRB LNR1 Monitor Well - Island Muster Drill with all personnel on island (Rig D -8 Drill) -Well "Breathed" back 2 barrels for one hour 18:30 - 19:30 1.00 DRILL N DPRB LNR1 Service Rig - Perform Maintenace on Top Drive Pipe handler - Service TDS, Draw Works, and Mud Pumps 19:30 - 21:30 2.00 DRILL N DPRB LNR1 Perform High Flow Test -Stage up pumps at 50 gpm increments monitoring loss rate -13.1 ECD = 600 gpm / 2907 psi with no rotation or pipe movement -Well started to take fluid at 13.1 ECD and 72 bph, -Ramp up pumps to pressure limit of 4300 psi / 778 gpm / 218 strokes -At 700 gpm Toss rate 72 bph to 180 bph, - No increase in loss rate from 700 gpm to 778 gpm 21:30 - 22:30 1.00 DRILL N DPRB LNR1 Wash and Ream from 23,540 - 23,894' and -80 rpm / 20k ft/lb of Torque Printed: 6/3/2009 3:57:48 PM • . BP Page 37 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/15/2009 21:30 - 22:30 1.00 DRILL N DPRB LNR1 -300 gpm / 1215 psi Attempted to wash in but hit obstruction at 23650' md, did not attempt to work through tight spot, Ream through with no problems, only indication at 23,650 was 2k torque spike 22:30 - 00:00 1.50 DRILL N DPRB LNR1 Break Circulation staging up to 420 / 2100 psi -Pump 78 bbl 80 ppb LCM Pill , 40 spm 729psi - Displace LCM pill at 420 gpm / 2150 psi -15 bbls of Pill left in Drill Pipe no change in return flow or loss rate while spotting pill 3/16/2009 00:00 - 02:15 2.25 DRILL N DPRB LNR1 POH to 22,665 to get above LCM Pill -40k overpull 23,645' md, pulled slow to get through - pumped 3 -4 barrel per stand pulling in to casing -No pump while pulling 9 stands up in casing 02:15 - 03:30 1.25 DRILL N DPRB LNR1 Stage up Circulation above LCM Pill - Staged up to 600 gpm / 2856 psi, loss rate 60 -72 bph -After pumping 30 minutes loss rate slowed to 24 bph -Stop pumping and let pill soak 03:30 - 04:00 0.50 DRILL N DPRB LNR1 Monitor Well -Well breathing back slightly with 3 - 4 bph gain, 04:00 - 09:00 5.00 DRILL N DPRB LNR1 Stage up Circulation above LCM Pill - Staged up to 450 gpm / 1827 psi, loss rate 27 bph bph -After pumping 30 minutes loss rate slowed to 24 bph -After pumping 60 minutes loss rate slowed to 15 bph -After pumping 90 minutes loss rate slowed to 6 bph -After pumping 120 minutes showed no loss No Loss for 2 hours Brought Pumps back up to 600 gpm / 2847 psi Loss Rate at 36 -42 bph Reduce Pump rate again to 450 gpm, no losses 09:00 - 10:00 1.00 DRILL N DPRB LNR1 RIH to Shoe 10:00 - 14:00 4.00 DRILL N DPRB LNR1 Stage up Circulation while making LCM Pill -LCM 100 bbl / 100 ppb / 12.8 ppg mud -20 ppb safecarb, 20 ppb G Seal, 15 ppb Mix II (med & Fine) -20 ppb MI Seal, 10 ppb nut plug fine Circulated @ 180 gpm / 639 psi 14:00 - 16:00 2.00 DRILL N DPRB LNR1 Pump 100 bbl 100 ppb LCM Pill , -40 spm 522 psi - Displace LCM pill at 350 gpm / 1410 psi no change in return flow or loss rate while spotting pill 16:00 - 18:00 2.00 DRILL N DPRB LNR1 POH to 21,712 to get above LCM Pill 18:00 - 22:30 4.50 DRILL N DPRB LNR1 Stage up from 250 gpm to 750 gpm -750 gpm / 4075 psi / 31% return flow - Initial Toss rate at 750 gpm 30 -45 bph, after 15 minutes increase to 80 -100 bph - Pumped 80 barrels away, Reduce flow to 500 gpm - no losses at 500 gpm Let Pill soak for a5' and increase flow again to 700 gpm, loss rate increase to 115 bph, pumped 30 bbls away and reduced rate to 450 gpm Printed: 6/3/2009 3:57:48 PM • Bp Page 38 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 t Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/16/2009 18:00 - 22:30 4.50 DRILL N DPRB LNR1 -No Losses at 450 gpm / 1886 psi / 26% return flow Total pump away 95 bbls 22:30 - 23:00 0.50 DRILL N DPRB LNR1 Monitor Well while servicing Top Drive Sensor Hole static , no breathing - Service Crown and Draw Works 23:00 - 00:00 1.00 DRILL N DPRB LNR1 Circulate and Condition hole while mixing EZ Squeeze LCM Pill -450 gpm / 1870 psi Hole gave back 27 bbls since 21:45 hrs 3/17/2009 00:00 - 00:30 0.50 LCR N DPRB LNR1 Circulate and Condition hole while mixing EZ Squeeze LCM Pill -450 gpm / 1870 psi 00:30 - 02:00 1.50 LCR N DPRB LNR1 RIH to Shoe -Ran in at 2 -3 min / stand 02:00 - 08:00 6.00 LCR N DPRB LNR1 Stage up circulation from 250 gpm to 500 gpm -500 gpm / 2277 psi / 25 % return flow / 42 -60 bph loss rate Started Rotating and Reciprocating loss increase to 130 to 180 bph - Reduce Pump to 400 gpm, Loss rate @ 80 bph Stop Rotating and Loss Rate at 400 gpm = 10 bph Continue pumping at 400 gpm / 1710 psi / 24% Return flow 08:00 - 09:00 1.00 LCR N DPRB LNR1 RIH to 23,895' and -50' above fault 27 at 23,947' RIH @ 2 -3 min / stand 09:00 - 15:00 6.00 LCR N DPRB LNR1 Stage up pumps to 400 gpm / 1790 psi - Reciprocate pipe 45' slowly -325k PUW / 180k SOW Continue to build EZ Squeeze pill in G & I Plant 15:00 - 16:00 1.00 LCR N DPRB LNR1 Pump EZ Squeeze Pill , -Pump 10 bbls of pill to pump, -Pill became unpumpable with charge pump feeding Rig Pump 16:00 - 19:00 3.00 LCR N DPRB LNR1 Stage up Pumps to 400 gom / 1643 psi and chase 10 barrel pill out of the hole -Thin Pill and Condition Pill make the EZ Squeeze Pill capable of being feed to the rig pump 19:00 - 21:00 2.00 LCR N DPRB LNR1 PJSM with all hands involved pumping Squeeze pill; NAD TP, Driller, Rig Crew, Swaco G &I Crew and BP WSL Start transferring Pill to Rig Pump - Initial rate of 3 bpm with only about 60% pump efficiency - Increase rate to 5 bpm and efficiency increase to 80% -Pump a total of 95 barrel into Drill Pioe Displace Pill at 5 bpm / 785 psi 21:00 - 00:00 3.00 LCR N DPRB LNR1 POH Displacing pill, -Pump 41 spm , 123 strokes per stand, pull 3 minutes per stand in open hole Printed: 6/3/2009 3 : 57 :48 PM • BP Page 39 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/17/2009 21:00 - 00:00 3.00 LCR N DPRB LNR1 -Pump 23 spm , 69 strokes per stand, pull 3 minutes per stand in case hole Pull 5 stands above calculated pill height of 22600' md, Pull to 22090' and 3/18/2009 00:00 - 01:00 1.00 LCR N DPRB LNR1 Rig to Perform Hesitation squeeze -Hold PJSM -Make up Surface safety valve, Head Pin, Cement Line, Bleeder line and position pipe in stack to upper pipe rams - Isolated Pits to Pit #1 E & 1D to monitor volume pumped -Rig Chart Recorder on Annulus side -Test Surface Line to 2000 psi, good test 01:00 - 02:40 1.67 LCR N DPRB LNR1 Start Hesitation Squeeze -Pump at 0.6 bpm - Pumped 20 bbls / 236 strokes -Final Pressure built up to 596 psi on drill pipe 490 psi on the casing side gauge - Monitor for 1 hour, with pressure bleeding down to 420 psi on the casing side gauge 02:40 - 03:30 0.83 LCR N DPRB LNR1 Pump 2.1 barrels and raise pressure to 550 psi on annulus side -Shut in , monitor pressure drop for 30 minutes, pressure loss 60 psi to 490 psi 03:30 - 04:00 0.50 LCR N DPRB LNR1 Pump 1.3 barrels and raise pressure from 490 psi to 630 psi on annulus side -Shut in , monitor pressure drop for 30 minutes, pressure loss 40 psi to 590 psi 04:00 - 04:45 0.75 LCR N DPRB LNR1 Pump 1.3 barrels and raise pressure from 590 psi to 730 psi on annulus side -Shut in , monitor pressure drop for 30 minutes, pressure loss 20 psi to 710 psi 04:45 - 05:30 0.75 LCR N DPRB LNR1 Pump 1.3 barrels and raise pressure from 710 psi to 840 psi on annulus side -Shut in , monitor pressure drop for 30 minutes, pressure bleed down 30 psi to 810 psi 05:30 - 06:00 0.50 LCR N DPRB LNR1 Pump 1.0 barrels and raise pressure from 810 psi to 900 psi on annulus side -Shut in , monitor pressure drop for 30 minutes, pressure bled down 25 psi to 875 psi 06:00 - 08:30 2.50 LCR N DPRB LNR1 Pump 1.2 barrels and raise pressure from 875 psi to 990 psi on annulus side -Shut in , monitor pressure drop for 2.15 hours, pressure bled down 140 psi to 850 psi 08:30 - 09:00 0.50 LCR N DPRB LNR1 Pump 1.3 barrels and raise pressure from 850 psi to 990 psi on annulus side -Shut in , monitor pressure drop for 30 minutes, pressure bled down 20 psi to 970 psi 09:00 - 09:30 0.50 LCR N DPRB LNR1 Pump 1.2 barrels and raise pressure from 970 psi to 1095 psi on annulus side -Shut in , monitor pressure drop for 30 minutes, pressure bled down 45 psi to 1050 psi 09:30 - 10:00 0.50 LCR N DPRB LNR1 Pump 1.2 barrels and raise pressure from 1050 psi to 1175 psi on annulus side -Shut in , monitor pressure drop for 30 minutes, pressure bled Printed: 6/3 /2009 3:57:48 PM • • BP Page 40of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/18/2009 09:30 - 10:00 0.50 LCR N DPRB LNR1 down 40 psi to 1150 psi 10:00 - 11:00 1.00 LCR N DPRB LNR1 -Shut in , monitor pressure drop for 1 hour, pressure bled down 75 psi to 1100 psi Pump 0.9 barrels and raise pressure from 1100 psi to 1185 psi on annulus side 11:00 - 14:00 3.00 LCR N DPRB LNR1 -Shut in , monitor pressure, bled down 60 psi to 1125 psi A total of 32.8 barrels squeezed 14:00 - 15:00 1.00 LCR N DPRB LNR1 Rig Down Surface Equipment used in Squeeze operation -Bleed off annulus and DP, Blow Down Lines -Rig Down Cement Line, Head Pin, Bypass bleed off line, and Surface safety valve 15:00 - 22:00 7.00 LCR N DPRB LNR1 Stage up from 125 gpm to 750 gpm slowly while Rotating and Reciprocating Pipe -120 rpm / 30k Torque -750 gpm / 4280 psi -RtWt 200k / PUW 280k (pumping) / SOW 150k (pumping) Mud Ranged from the lightest spot a first, was 11.1 ppg and heaviest at bottoms up, was 14 ppg Bottoms Up had heavy barite returns covering all of the shaker screens some LCM from previous pills 22:00 - 22:30 0.50 LCR N DPRB LNR1 RIH with 5 stands of pipe to 22,094 to 22,570' -PUW no pump 312k / SOW no pump 162k -No Mud Losses 22:30 - 00:00 1.50 LCR N DPRB LNR1 Stage up from 300 gpm (1136 psi) to 500 gpm (2193 psi) -120 rpm / 33k Torque -Ream from 22,570 - 22,640 -Ream in the hole slowly at 1 hour per stand monitoring shakers for LCM Pill - Balance Mud out to 12 ppg in and out -No Losses 3/19/2009 00:00 - 09:30 9.50 LCR N DPRB LNR1 Ream from 22,640 - 23,540' -120 rpm / 33k Torque -500 gpm / 2193 psi -Ream in the hole slowly, monitoring shakers for LCM Pill - Maintain Mud Weight to 12 ppg in -No Losses - With Pump 310k PUW / 160 k SOW / 210 k RtWt 09:30 - 12:00 2.50 LCR N DPRB LNR1 Circulate and Condition Mud at the Shoe -500 gpm / 2200 psi -120 rpm / 33k FULbs of Torque No Losses 12:00 - 13:00 1.00 LCR N DPRB LNR1 Circulate and Condition Mud at the Shoe -500 gpm / 2200 psi -120 rpm / 33k FULbs of Torque No Losses 13:00 - 14:00 1.00 LCR N DPRB LNR1 Service Top Drive, Crown, Draw Works 14:00 - 15:00 1.00 LCR N RREP LNR1 Repair Top Drive -PJSM with NAD TP, BP WSL and NAD Service Personnel - Replace PLC Cable - Function Test and Verify Functionality Printed: 6/3/2009 3:57:48 PM • • Bp Page 41 of 91 Operations ~���num Summary Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - ����' Hours Task Code NPT 3/19/2009 15:00 - 23:30 8.50 LCR N DPRB LNR1 Ream from 23,518 to 24,181 -500 gpm / 2257 psi -40 rpm / 19k ft/lbs of torque With Pumps -PUW 390k /18nkSOW / 240 k RtW 2k Torque spike reaming to bottom at 23.960 and at the top of the new 770^hole 23:30 '00:00 0.50 LCR N DPRB LNR1 Circulate and Condition atTDc4.181'mu -500 gpm / 2260 psi -40 rpm / 21k FtfLbs of Torque Reciprocate the bottom 30 feet slowly -Circulate 2 open hole volumes No Losses 3/20/200e 00:00 01:30 1.50 LCR N DPRB LNR1 POH. Pumping out atuUpm 'PUvvonsx /SOVY 170x -Reamed out of new hole (e*.1o1'e4.1u1)e|ow|y -Pull without rotating u4.1o1'23.o4o' -Pull at Maximum of 3 min / stand -2 tight spots, 40k overpulls, 24.14a'mU and 23.O0o'. did not work through 01:30 - 02:00 0.50 LCR N DPRB LNR1 CIrc. at the Shoe -5OOgpm / 2210 psi 120 rpm / 24k ftllbs of torque 02:00 - 02:30 0.50 DRILL P LNR1 Riq to perform FIT PJSM with BP WSL, NAD TP, and Rig Crew -Rig the TIW vavle, Pump in sub, , EZ Torq Vaive and Bleeder line -Position Pipe in BOP Stack and Close Top Pipe Rams 02:30 03:30 1.00 DRILL P LNR1 Perform FIT ' In/ Out -Pump 0.5 bpm -Shoe @o1eo'TVD/o3.s4n'md -Pump Down DP and Annulus Pressure up to 985 psi and hold for 10 minutes,Pressure bleed down from 985 to 970 psi over ten minutes EMW at shoe = 14.07 ppg 03:30 05o0 1.50 DRILL P LNR1 CIrc. at the Shoe -500 gpm / 1750 psi 120 rpm /u4k*Nbooftorque 05:00 08:30 3.50 DRILL P LNR1 PO*.mc1.008 found wash out in stand #u1ron top single -Washout @ 1o4o'174o' when bit ioatshoe -Pumped out at 2 bpm -Pull at 3 min / stand -WWT inspecting Super Sliders 08:30 09:30 1.00 LCR N DFAL LNR1 UDStand #217 due mwashout Washout @ 4.5' above tool joint, wash through the DP and the retaining ring on the Super Slider lower Clamp 09:30 - 00:00 14.50 DRILL P LNR1 POHm15.o42'mU -Pumped out at 2 bpm -Pull at3 min /stand -WWT inspecting Super Sliders 3/21&00e 00:00 - 01:30 1.50 DRILL P LNR1 POH, 14,184 Printed. 6/3/2009 3 57 48 PM i • BP Page 42 of 91 r tions Summary Report a y ort p Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/21/2009 00:00 - 01:30 1.50 DRILL P LNR1 - Pumped out at 2 bpm -Pull at 3 min / stand 01:30 - 06:00 4.50 DRILL P LNR1 CBU 3x at Top of Liner - Staged up from 300 gpm to 750 gpm -750 gpm / 2962 psi -120 RPM / 8k ft/Ibs of Torque -Stand back 1 stand / hour -Mud wt 12 ppg in /out First bottoms had a 40% increase in barite cuttings Second bottoms up had a 10% increase in barite cuttings Final Bottoms up had very little material coming across shakers 06:00 - 08:00 2.00 DRILL P LNR1 Slip and Cut Drilling Line -make a long cut, 170' 08:00 - 09:00 1.00 DRILL P LNR1 Service Rig Top Drive, Crown and Draw Works - Throughly Inspect TDS with CanRig Service Tech 09:00 - 12:00 3.00 DRILL P LNR1 POH to 11,030' 12:00 - 13:30 1.50 DRILL P LNR1 POH to 10,177' 13:30 - 22:30 9.00 DRILL P LNR1 POH Laying Down 4 1/2" Drill Pipe 22:30 - 23:30 1.00 DRILL P LNR1 POH Laying Down 4 1/2" HWDP 23:30 - 00:00 0.50 DRILL P LNR1 POH Laying Down BHA and Bit -No Damage to cone structure on the bit, bearings still in good shape, only damage to bit is in the start of the nozzle tubes, tubes started to washout on all three nozzle tubes 3/22/2009 00:00 - 01:00 1.00 DRILL P LNR1 Clear floor of excess tools and get ready to test BOP's 01:00 - 02:00 1.00 BOPSUF P LNR1 Pull Wear bushing 02:00 - 02:30 0.50 BOPSUF P LNR1 Flush Stack with Wash Tools 02:30 - 03:00 0.50 BOPSUF P LNR1 Make up test joint and Test Equipment 03:00 - 09:00 6.00 BOPSUF P LNR1 Test BOPE as per BP / AOGCC Regulations to 250 psi low/ 4500 psi High for 5 min each 250 psi / 3500 psi on Annular preventer.Witnessed of test waived by John Crisp (AOGCC State Inspector) Test Witnessed by Dave Newton (WSL), Brian Tiedemann (NAD Toolpusher), Kelly Haug (NAD Driller). Test Recorded on a chart recorder. Test as follows with 5 -7/8" Test Joint. Test as follows with 250 psi / 4500 psi. #1) Top 4.5" x 7" VBR / 5 -7/8" IBOP / Choke Valves # 9, 12 & 13 / Kill Line & Dart Valve #2) 5 -7/8" Floor Safety Valve / Kill HCR / Choke Valves # 8 & 11 #3) Choke Valves # 4, 7, & 10 #4) Choke Valve # 3 -5 -6 / Manual Kill Line Valve #5) Super Choke & Manual Choke Manifold Valves 250 low & 1500 psi high #6) Choke Valve #1, 3 & 5 #7) Choke Valve #2, #8) Choke HCR Valve #9) Lower Top Drive Well Control Valve / Manual Choke Line Valve on stack #10) Bottom 3.5" x 6" VBR / Upper Top Drive Well Control Valve Printed: 6/3/2009 3:57:48 PM BP P 43 of 91 Operations Summary Report Legal Well Name: NS33 :1/29/2007 Dte .N Spud a Well Name: NS33 Common Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/22/2009 03:00 - 09:00 6.00 BOPSUF P LNR1 #11) Accumulator Function / Draw Down Test #12) Blind Shear Rams Change out Test equipment to 4 -1/2" Test as follows with 4 -1/2" Test Joint. #13) Top 4.5" x 7" VBR / 4 -1/2" Floor Dart Valve #14) Bottom 3.5" x 6" VBR / 4 -1/2" Floor Safety Valve #16) Annular 250 psi / 3500 psi 09:00 - 10:00 1.00 BOPSUF P LNR1 Rig Down Test equipment -Pull test Plug -Set 10 3/4" Wear Bushing 10:00 - 12:00 2.00 BOPSUF P LNR1 Changeout Swivel Packing on Top Drive 12:00 - 23:00 11.00 BOPSUF N RREP LNR1 Repair Wash Pipe on Top Drive - Unable to make up Swivel Packing Tightening Nut - Changeout Swivel Packing and Goose Neck thread half 23:00 - 00:00 1.00 DRILL P INT2 Make Up BHA -PJSM with rig crew,Anadrill, Smith Rhino reamer tech -M /U Pwerdrive and Bit 3/23/2009 00:00 - 05:00 5.00 DRILL P INT2 Make up Power Drive, Rhino Reamer, LWD / MWD -450 gpm / 475 psi, 500 gpm / 617 psi, 550 gpm / 730 psi Surface Test Rhino Reamer - Sheared pins at 580 gpm / 1180 psi -Arms started to extend at 70 spm /220 psi Finish Picking up BHA - 05:00 - 14:30 9.50 DRILL P INT2 Pick Up 4 1/2" Drill Pipe 1 x 1 to 5801' -168 jts 14:30 - 16:00 1.50 DRILL P INT2 Ran in 39 stands of 4 1/2" DP from derrick -5801 - 9486' 16:00 - 19:00 3.00 DRILL P INT2 Pick Up 4 1/2" Drill Pipe 1 x 1 to 11717' -69 jts 237 Total Joints from Pipe Shed 19:00 - 20:00 1.00 DRILL P INT2 Change out handling equipment - Remove 4 1/2" Drill pipe Air Slips and Elevators - Install 5 7/8 Air Slips and Eleavators -Make Up Crossover to get from 4 1/2" CMT43 back to 5 7/8" DP XT57 20:00 - 22:00 2.00 DRILL P INT2 RIH with 5 7/8" DP from Derick 11,721' - 14,107 22:00 - 22:30 0.50 DRILL P INT2 Run through Top of 8 5/8" Liner without problems -200k PUW / 127k SOW - Position Rhino Reamer at 14,350'md (109' below TOL) 22:30 - 00:00 1.50 DRILL P INT2 Stage up Circulation Easy -No Rotation or Reciprocation due to Rhino Reamer - Initial Circ rate, 200 gpm, 567 psi, 17% flow -Final Circ rate, 450 gpm, 1921 psi, 29% flow As soon as we started pumping there was light mud coming back at 11.1 ppg up to 3500 stks, 3500 stks to 7300 stks 11.4 ppg, 7300 stks to13000 stks 11.5 ppg, 15000 stks bottoms up 11.7 ppg., No significant barite was seen coming over shakers, a Printed: 6/3/2009 3:57:48 PM • BP Page 44 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/23/2009 22:30 00:00 1.50 DRILL P INT2 maximum of 5% of shaker screens was covere 3/24/2009 00:00 - 03:00 3.00 DRILL P INT2 Continue with conditioning mud, balancing mud weights from 11.6 ppg to 12.0 ppg - Circulate two bottoms up -Very little barite coming over shaker screens 03:00 - 10:00 7.00 DRILL P INT2 RIH with 5 7/8" DP from Derick , 14,391 - 20,974' and - Control running rate to 1 -2 min / stand -Fill drill pipe every 3,000' 10:00 - 13:30 3.50 DRILL N RREP INT2 Change out top drive swivel packing & pressure test same to 4200 psi. 13:30 - 16:30 3.00 DRILL P INT2 RIH from 20,974' to 23,488' - Control running rate to 1 -2 min / stand 16:30 - 18:00 1.50 DRILL P INT2 Circulate & condition mud pumping one 8 -5/8" liner annular volume Stage pump rate up to 450 gpm 2643 psi Mud wt in 12.0 ppg / out 11.7 ppg 18:00 - 18:30 0.50 DRILL P INT2 RIH from 23,488' to 23,610' taking weight Set down 30k x 2 Pull up to 23,540 MD Up Wt 365k / SOW 155k 18:30 - 19:00 0.50 DRILL P INT2 MU TDS & start rotation 25 rpm / 17k ft / Ibs TQ. Stage pump up to39 spm / 138 gpm / 1084 psi Wash & ream from 23,540' to 23,612' where packing off was encountered. 19:00 - 19:30 0.50 DRILL P INT2 PU to 23,609 maintain 25 rpm & stage pump rate up to 39 spm / 138 gpm / 1058 psi 19:30 - 21:30 2.00 DRILL P INT2 Wash & ream from 23,609' to 23,733'. 25 -30 rpm / 18k ft / Ibs Tq. 39 spm / 138 gpm / 1058 psi 21:30 - 22:00 0.50 DRILL P INT2 RIH from 23,733' to 24,010' taking weight @ 24,010' Set down 30k x 3. Pull up to 23,985' MD Up Wt 380k / SOW 160k 22:00 - 23:30 1.50 DRILL P INT2 MU TDS & start rotating 30 rpm / 18k - 20k ft / Ibs TQ. Stage pump up to 29 spm / 103 gpm / 1184 psi Wash & ream from 23,985' to 23,990' oackina off Stage rate up to 25 -30 rpm / 18k ft / Ibs Tq. 39 spm / 138 gpm / 1155 psi 23:30 - 00:00 0.50 DRILL P INT2 Continue wash & ream from 23,990' to 24,005' 25 rpm / 20k - 23k ft / Ibs Tq. 38 spm /135 gpm/ 1132 psi Mud wt in 12. ppg ou t 12.2 ppg 3/25/2009 00:00 - 01:00 1.00 DRILL P INT2 Continue wash & ream from 24,005' to 24,019' 25 rpm / 20k - 23k ft / Ibs Tq. 38 spm /135 gpm/ 1144 psi RWT - 220k Mud wt in 12.0 climbing to 12.6 ppg / out12.2 climbing to 13.4 ppg 01:00 - 02:15 1.25 DRILL P INT2 Circulate & condition mud 25 rpm / 20k - 23k ft / Ibs Tq. 38 spm / 135 gpm / 1132psi pressure dropping to 881 psi w/ 40 spm / 142 gpm Shut down and pressure test surface equipment 2000 psi held Printed: 6/3/2009 3:57:48 PM BP Page 45 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/25/2009 01:00 - 02:15 1.25 DRILL P INT2 Resume circulation 39 spm / 136 gpm / 796psi Suspend Circulating due to solids control equipment centrifuges packed off. RWT - 232k Mud weight out 13.7 ppg and unable to knock back weight going in with solids control equipment. 02:15 - 03:30 1.25 DRILL N HMAN INT2 POH to 23,448' pumping 2 bpm 580 psi UWT 350k 03:30 - 11:00 7.50 DRILL N HMAN INT2 PJSM - Service / clean out centrifuges & service same Roll surface mud system conditioning same to 12.0 ppg 11:00 12:00 1.00 DRILL N HMAN INT2 Stage pump rate up to 105 spm / 373 gpm / 1910 psi to turn on MWD tool and test drill string for wash out. Tool kicked on 300 gpm 1350 psi / MWD turbine RPM @ 105 spm / 2695 rpm's / good signal AECD = 12.94 ppg 12:00 - 12:30 0.50 DRILL N HMAN INT2 RIH from 23,448' to 23,633' taking weight Set down 30k x 2 Pull up to 23,605' MD BK over wt 380k / Up Wt 360k / SOW 155k 12:30 - 16:00 3.50 DRILL N HMAN INT2 MU TDS & start rotation 24 rpm / 18k ft / lbs TQ. Stage pump up to38 spm / 135 gpm / 987 psi Wash & ream from 23,605' to 23,730' 16:00 - 16:30 0.50 DRILL N HMAN INT2 RIH from 23,733' to 24,013' taking weight Pull up to 23,991' MD BK over wt 420k / Up Wt 360k / SOW 160k 16:30 - 17:30 1.00 DRILL N HMAN INT2 MU TDS & start rotation 41 rpm / 23 -26k ft / Ibs TQ. Stage pump up to41 spm / 146 gpm / 1086 psi Wash & ream from 23,991' to 24,019' 17:30 - 18:30 1.00 DRILL P INT2 Wash & ream from 24,019' to 24,114' 41 rpm / 21k ft / Ibs TQ. 40 spm / 146 gpm / 1079 psi RWT - 237k 18:30 - 19:30 1.00 DRILL P INT2 PU to 24,108' Stage pumps up in 10 spm increments @ minimum 5 min intervals while rotating 41 rpm / 20k ft/Ibs TQ. 41 spm / 1073 psi 50 spm / 1256 psi 60 spm / 1469 psi Hole started packing off. Attempt to staae uo without success, 19:30 - 22:30 3.00 DRILL P INT2 PU to 24,079' Stage pumps up in 5 spm increments @ minimum 5 min intervals while rotating 41 rpm / 20 - 22k ft/Ibs TQ. 10 spm / 514 psi up to 120 spm / 2530 psi MWD turned on @ 110 spm / 393 gpm. Initial ECD 12.94 ppg. 22:30 - 23:30 1.00 DRILL P INT2 Reduced pump rate to 25 spm / 324 psi 15 rpm / 22k ftlbs TQ & process surface mud volume to maintain 12 ppg going in / 12.6 ppg coming out from bottoms up. 23:30 - 00:00 0.50 DRILL P INT2 Stage pump rate back up to 80 spm / 1265 psi 38 rpm / 19k ft/lbs TQ Mud Wt in 12. ppg / Out 12.1 3/26/2009 00:00 - 00:30 0.50 DRILL P INT2 Cont' stage pump rate up to 500 gpm @ 24,079' Printed: 6/3/2009 3:57:48 PM • Page 4 6 of 91 BP Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25X2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: ��� �^�odn�a�� ���^' �e����* -r�n�-o�on�"~'�una Task �xr/;���rn�se �����,~� ~`"�,�i�De=c, Operations 3/26/200e 00:00 00:30 0.50 DRILL P INT2 1*Qnpm/2973psi 39 rpm / 18k ft/lbslQ ECD = 12.99 ppg 00:30 01:30 1.00 DRILL P INT2 Circulate 8 condition mud 14Oopm/snngpm/2e48while staging up to 120 �mwhile m�� poi monitoring Final ECD =13.06 ppg 01:30 - 02:00 0.50 DRILL P INT2 Obtain parameters © 24,079 MD ECD base nno@ou'1uO rpm 'osoOgpm/uonopoi Cal soo1uonppu AECD 13.10 ppg Opn'o SPR. #1)uaPm~aoo PSI /oepm~e4uPSI GPn. wc)uoPm~suoPS|/ogPm~e5opa| MD 02:00 - 05:30 3a0 DRILL P INT2 Wash & ream from 24.O78'toc4.181' 1oU rpm /33 35kft/|UoTO. 147 spm / 520 gpm / 3000 psi Pumps on RWT - 225k / UWT - 400k / SOW 135x Pumps off UvVT'4u5/ SOW '1nnx ECD - 13.10 ppg 05:30 12:00 6a0 DRILL P INT2 Directionally Drill from u4.1u1'mo4.u7o' 9.770'wd ^woa~1ox -151 opm/538gpm/31n0 psi onbom '1eo rpm /TqO#27x/TqOn29�3x °/PumpoUYVTo8Ox/DWT10Ox/RWTucnx 'Ca|s�o~1u.e5ppg/ Actual Eno~1o.1uppg -ART = 5 hrs /wU8:ooUrs started adding Spike fluid m raise mud weigmm 1 u.*ppg over 2oimu|ouiunoountm|driUing holding ROPm fph 12:00 00:00 12.00 DRILL P INT2 Directionally Drill from e^.27O'mu4.n90' 9.802'wU -WOB = 10 - 15k '151opm/538gpm/33*n psi onUum/ off oonnpsi -120 rpm / Tq Off 25k / Tq On 28k �� PumpoUvVToonx/ovVT1sox/RYVTu4ox '��PumpnUVYT4nnx/DVVT1OOx -Cal sCo~1u.1oppg/ Actual ECo~1n.aoppg -ART = 10.8 hrs weight upm1uappg@1eooAmoontm| ho�inonOPou-O fph duhnoweight upo4.eeo' SPR's aPn�#1)uoPm~4no PSI /uopm~e1oPSI apn�#u)uoPm~^oo PSI /ospM~a1oPa| mo~u4.000'/TvD~n'7oa' Mud vvt1u.s ' ppg 3/27/2009 00:00 08:00 8.00 DRILL P INT2 Directionally from to yD,i||�mu4.ono'o4.sos -WOB = 10 - 15k '1mo'140 rpm /TqOmook/TqO#r7x '1s1opm/snSgpm/34uopgonbum/3u74 psi off bttm Printed: 6/3/2009 3 57.48 PM • • BP Page 47of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/27/2009 00:00 - 08:00 8.00 DRILL P INT2 -w/ Pumps UWT 385k / DWT 165k / RWT 245k -w /o Pumps UWT 420k / DWT 168k Notes: - Trouble shoot PWD ECD reading after connection @ 24,398'. Clerical error on depth was cause of incorrect ECD readings. 08:00 - 10:00 2.00 DRILL P INT2 Unable to obtain MWD data due to pump noise Checked pulsation dampeners - 825 psi pre- charge Clean out #1 & 2 mud pump suction and discharge screens Found fish eyed Duovis in #1 and EZ Squeeze in #2 mud pump suction strainers. 10:00 - 12:00 2.00 DRILL P INT2 Directionally Drill from 24,585' to 24,624' /TVD 10,061' -WOB = 10 - 15k -120 - 140 rpm / Tq On 30k / Tq Off 27k -151 spm / 539 gpm / 3428 psi on bttm / 3274 psi off bttm -w/ Pumps UWT 385k / DWT 165k / RWT 245k -w /o Pumps UWT 420k / DWT 168k -Cal ECD = 13.32 ppg / Actual ECD = 13.58 ppg -ART = 7.08 hrs SPR's SPR. #1) 2BPM= 700 PSI / 3BPM= 810 PSI SPR. #2) 2BPM= 690 PSI / 3BPM= 810 PSI MD = 24,608' / TVD = 10,048' Mud Wt 12.5 ppg Notes: - Pumped 100 bbl 5% EP Steel tube sweep @ 24,610'. No reductions in torque noted. -On connections, 30' wipe. Reduce pumps to 75% on down stroke. 12:00 - 14:00 2.00 DRILL P INT2 Directionally Drill from 24,624' to 24,682' -WOB = 10 - 15k -120 rpm / Tq On 32k / Tq Off 30k -150 spm / 536 gpm / 3434 psi on bttm / 3341 psi off bttm -w/ Pumps UWT 390k / DWT 155k / RWT 248k -w /o Pumps UWT 430k / DWT 160k -Cal ECD = 13.32 ppg / Actual ECD = 13.62 ppg 14:00 - 19:00 5.00 DRILL N SFAL INT2 Unable to maintain MWD signal. Trouble shoot same and discover pulsation dampener failure on #2 mud pump. Hold PJSM & affect repairs to same, pre- charge dampener to 900 psi and return pump to service Rotate 110 rpm / 29k ft/lbs TQ / Pump 78 spm / 278 gpm / 1385 psi & Reciprocate 30' keeping bit in pilot hole while performing pump service. 19:00 - 00:00 5.00 DRILL P INT2 Directionally Drill from 24,682' to 24,816' / TVD 10,226' -WOB = 10 - 15k -120 rpm / Tq On 33k / Tq Off 30k -150 spm / 536 gpm / 3435 psi on bttm / 3406 psi off bttm -w/ Pumps UWT 380k / DWT 162k / RWT 250k Printed: 6/3/2009 3:57:48 PM BP Page 48 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/27/2009 19:00 - 00:00 5.00 DRILL P INT2 -w /o Pumps UWT 430k / DWT 165k -Cal ECD = 13.32 ppg / Actual ECD = 13.58 ppg -ART = 5.07 hrs SPR's SPR. #1) 2BPM= 550 PSI / 3BPM= 690 PSI SPR. #2) 2BPM= 550 PSI / 3BPM= 610 PSI MD = 24,777' /TVD = 10,191' Mud Wt 12.5 ppg Notes: -On connections, 30' wipe. Reduce pumps to 75% on down stroke. 3/28/2009 00:00 - 02:00 2.00 DRILL P INT2 Directionally Drill from 24,816' to 24,872' - WOB= 15 -20k -120 rpm / Tq On 33k / Tq Off 30k 150 spm / 536 gpm / 3435 psi on bttm / 3406 psi off bttm w/ Pumps UWT 385k / DWT 162k / RWT 250k -w /o Pumps UWT 430k / DWT 165k -Cal ECD = 13.32 ppg / Actual ECD = 13.63 ppg 02:00 - 04:30 2.50 DRILL N DFAL INT2 While attempting to pump up a s @ 24,872' MWD tools quit and 200 psi pressure drop occ urred. Trouble shoot MWD and attempt to regain function of tools. MWD tools regained function at lower flow rates and shutting off at 460 to 470 gpm. Consult with ODE to continue drilling ahead with 450 gpm. 04:30 - 12:00 7.50 DRILL P INT2 Directionally Drill from 24,872' to 25,062' / TVD= 10,434' -WOB = 15 - 20k -120 rpm / Tq On 31 k / Tq Off 27k 127 spm / 451 gpm / 2742 psi on bttm / 2635 psi off bttm w/ Pumps UWT 385k / DWT 164k / RWT 252k -w /o Pumps UWT 425k / DWT 168k -Cal ECD = 13.53 ppg / Actual ECD = 13.44 ppg -ART = 8.05hrs SPR's SPR. #1) 2BPM= 550 PSI / 3BPM= 680 PSI SPR. #2) 2BPM= 550 PSI / 3BPM= 670 PSI MD = 25,051" / TVD = 10,191' Mud Wt 12.5 ppg Notes: -On connections, 30' wipe. Reduce pumps to 75% on down stroke. 12:00 - 20:00 8.00 DRILL P INT2 Directionally Drill from 25,062' to 25,251' -WOB = 15 - 20k -120 rpm / Tq On 33k / Tq Off 28k -127 spm / 451 gpm / 2791 psi on bttm / 2753 psi off bttm w/ Pumps UWT 415k / DWT 165k / RWT 262k -w /o Pumps UWT 430k / DWT 170k -Cal ECD = 13.25 ppg / Actual ECD = 13.32 ppg 20:00 - 21:00 1.00 DRILL N DFAL INT2 While attempting to pump up a survey @ 25,251' MWD tools Printed: 6/3/2009 3:57:48 PM BP Page 49 of 91 O pera ti ons summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+C(]K8PLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Description � �� m � Code ��K . Phose ;� 3/28/2009 20:00 - 21:00 1.00 DRILL N DFAL INT2 failed to start with 450 gpm. Trouble shoot MWD and regain function of tools with 520 gpm. pump up survey and continue operations with the 520 gpm range. 21:00 - 00:00 3.00 DRILL P INT2 Directionally Drill from u5.u51'mu5.o1n'/ TVD 1o.6Vr' -WOB = 15 - 20k '1uo rpm /TqOnook/Tq Off ouk -146 spm / 519 gpm / 3425 psi on bttm / 3361 psi off bttm -w/ Pumps UvvT41ak/ovVT16sx/RVYTueck -w/o Pumps UWT 430k / DWT 170k -Cal soo~1o.usppu/ Actual ECo~1oacppo -ART = 9.64hrs Notes: -On connections, 3o' wipe. Reduce pumps mramondown stroke. 3/29/200e 00:00 12:00 12.00 DRILL P INT2 Directionally Drill from uo.31o'/nu5.s66'/1o.000 TVD -WOB = 15 25k -120 rpm / Tq On 33-35k / Tq Off 29k '14onpm/s18gpm/3341 psi on bttm /33nu psi off bttm -w/ Pumps UVVT44Ou/DVYT1O8k/RVvTu7Ou -w/o Pumps UWT 465k / DWT 172k -Cal sco~1o.15ppn/ Actual sCo~1ua4ppn -ART ~1o.1ohm opn'o SPR. #1) 2BPM= 550 PSI / 3BPM= 670 PSI SPR. #2) 2BPM= 550 PSI / 3BPM= 670 PSI MD~os.53u^/ TVD ~1o.a*8' Mud VVt1uappg11:uoHnG Notes: -On connections, 3O' wipe. Reduce pumps m75mondown stroke 12:00 15o0 3.00 DRILL P INT2 Directionally Drill from cs.nOO'mTD@os.011'MD/1O.9eV' TVD -WOB = 20 - 25k -120 rpm / Tq On 32k / Tq Off 29k '146opm/s19gpm/331U psi on bttm /3eo7 psi off bttm -w/ Pumps UYVT41oh/DvvT165k/RVVTu64k 'w/b Pumps UVYT47ok/DvvT165x -Cal sCo~1u.1oppu/ Actual sCo= 13.54 ppg -ART ~u.1hrs 15:00 - 16:00 1.00 DRILL P INT2 Circulate 1.5 OH x 8-5/8" liner annular volume reciprocate pipe 3s' keeping bit m7-7/ ^pi|mho|o./w6200 stmmmimm circulation returns were Iost. 1uO rpm /o1xM/|boTQ 1o4spm/5Sogpm/3a1opsi -Cal soo~1n.1sppo/ Actual Eoo~1o.sappg Notes: -Reduce pumps to 75% on down stroke Printed. muooeo.or,mpm • • BP Page 50 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase " Description of Operations 3/29/2009 16:00 - 21:00 5.00 DRILL P INT2 Pump out of hole to 25,535' Stand back 1 stand DP & monitor well, no static losses. Stage pumps up to 26 spm / 348 psi Pull 540k / S/0 to 200k 3 times park at 214k & rotate 34k ft/lbs to bk over 26k ft/Ibs TQ free. Reciprocate pipe from 25,515' to 25,445' w/o rotation UWT 460k / DWT 170k Pump 11 spm / 39 gpm / 376 psi with approximately 55 BPH losses Pump 84 bbl with 40 bl /bbl LCM pill G -Seal 10 ppb Nut Plug Medium 10 ppb Mix II Medium 10 ppb MI Seal Medium 10 ppb staging pump up to 34 spm / 700 psi Slow rate to 23 spm @ 4530 strokes & continue pumping pill with partial returns until pill cleared bit. Total 7200 strokes 609 bbls. Monitor well, Well static with no losses Total Dynamic losses while pumping 649 bbls 21:00 - 23:30 2.50 DRILL P INT2 POH from 25,535' to 24,474' @ 15- 20 FPH. Pumping 17 spm / 61 gpm / 590 psi Minor packing off wit 40 -50k over pulls from 24,735'to 24,689' No losses observed while pumping out. 23:30 - 00:00 0.50 BOPSUF N HMAN INT2 Hand held mud stripper was pulled out of the hands of floor hand and dropped down the hole when driller slacked off and stripper was pinched between super slider and rotary bushings. Drained BOP stack and attempt to fish stripper out of well bore located at well head. 3/30/2009 00:00 - 01:00 1.00 BOPSUF N HMAN INT2 Continue fish pipe stripper without success 01:00 - 04:30 3.50 DRILL P INT2 POH from 24,474' to 23,448 @ 15- 20 FPH. Pumping 17 spm / 61 gpm / 590 psi Packing off with 60k over pulls from 24,428'to 24,398' re- establishing circulation with rotation 72 rpm / 25k ft/Ibs TQ. 50k over pulls @ 24,196' worked through without pack offs Pulled through 23,610' area without problems. No losses observed while pumping out. 04:30 - 06:00 1.50 DRILL P INT2 Monitor well, Static. Blow down top drive & mud lines. Build surface mud volume. Drain stack & fish pipe stripper out of BOPE successfully. 06:00 - 08:00 2.00 DRILL P INT2 PJSM - Cut & Slip 85' drilling line 08:00 - 12:00 4.00 DRILL P INT2 POH Pumping out to top of 8 -5/8" liner from 23,448' to 22,212' Pump rate 23 spm / 82 gpm / 640 psi Pulling speed 3 min / stand No losses to well bore while pumping out. 12:00 - 00:00 12.00 DRILL P INT2 POH Pumping out to top of 8 -5/8" liner from 22,212' to 16,015' Pump rate 24 spm / 86 gpm / 465 psi Pulling speed 3 min / stand Printed: 6/3/2009 3:57:48 PM • BP Page 51 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/30/2009 12:00 - 00:00 12.00 DRILL P INT2 No losses to well bore while pumping out. 19:00 hrs 18,830' mud weights out dropped to 12.1 ppg and fluctuated between the lowest of 11.8ppg and up to 12.5 ppg coming out. Maintaining 12.5 ppg going in. 3/31/2009 00:00 - 04:00 4.00 DRILL P INT2 POH Pumping out to top of 8 -5/8" liner from 16,015' to 14,230' Pump rate 24 spm / 86 gpm / 411 psi Pulling speed 3 min / stand No losses to well bore while pumping out. From 16,015' mud weights fluctuated between the lowest of 11.8 ppg to 11.9 ppg coming out. Maintaining 12.5 ppg going in. 04:00 - 12:30 8.50 DRILL P INT2 Pull Stripping rubbers & monitor well 10 min. Well static. Stage pump rate up to 55 spm / 196 gpm / 657 psi in 10 spm / 5 min increments Wash up to 14,202'. Stand back one stand and park pipe at 14,202' & Circulate staging pump rate up in 100 gpm / 15 min. increments to 600 gpm / 3228 psi instigate 950 bbls surface volume into system and circulated 2x surface x hole volumes 2450 bbls to shear new mud. 7500 strokes into first circulation noted the following on shakers 70% LCM: nut plug, g -seal, black & lube products 20% barite 10% disaggregated silt, very fine sand 12:30 - 16:30 4.00 DRILL P INT2 Drop 2 -1/8" CCV ball and pump down on seat with 35 spm / 125 gpm / 433 psi, ball on seat. Pressure up to 1500 psi and hold 1 min Pressure up to 2000 psi and hold 1 min Pressure up to 2500 psi where ball blew through seat, stage pump rate up to 610 gpm 3130 psi. and verify CCV failed to open. Repeated procedure for 3 attempts to open CCV without success. 16:30 - 17:00 0.50 DRILL P INT2 Monitor well, Static. Pump dry job, blow down top drive & mud line 17:00 - 17:30 0.50 DRILL P INT2 POH from 14,202' to 13,620' Pulling speed 3 min / stand 17:30 - 18:00 0.50 DRILL P INT2 Bindings on electrical service loop for top drive loosened up allowing lines to separate. Re- secure same. 18:00 - 20:30 2.50 DRILL P INT2 POH from 13,620' to 11,448' standing back 5 -7/8" DP Pulling speed 3 min / stand 20:30 - 21:00 0.50 DRILL P INT2 Change out handling tools to 4 -1/2" and LD XO 21:00 - 00:00 3.00 DRILL P INT2 POH from 11,448' to 8,770'standing back 4 -1/2" DP Pulling speed 3 min / stand Laid out stand # 93 & 97 of 4 -1/2" DP for inspection. 4/1/2009 00:00 - 01:00 1.00 DRILL P INT2 POH from 8,770' to 7,837' standing back total 38 stands 4 -1/2" DP Pulling speed 3 min / stand 01:00 - 12:00 11.00 DRILL P INT2 PJSM - POH LD 4 -1/2" DP 1x1 from 7,837' to 271' Pulling speed 1 min / jt. Printed: 6/3/2009 3:57:48 PM BP Page 52 cof 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2008 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 6/20/2808 Rig Name: NABORS 33E Rig Number: Date ` Code NPT Phase �� � ^ _ Operations ��~��� 4/1/2009 12:00 - 14:00 2.00 DRILL P INT2 PJuM `LD BHA wo Bit & Rhino reamer in good shape No external deficiencies found on CCV sub, Recovered 3 balis. 14:00 15o0 1o0 DRILL P INT2 Clean & Clear rig floor of vendors tools 15:00 16o0 1.00 BOPSUF P INT2 MU BOP flushing tool & flush BOP stack. Function Rams & repeat flushing. LD flushing tool. 16:00 - 16:30 0.50 BOPSUF P INT2 MU Wear Bushing Running Tool & Pull Wear Bushing. 16:30 - 17:30 1.00 BOPSUF P INT2 PU&MU Test plug m8'5/D^ test joint, RU test equipment &fill stack with water. 17:30 - 18:30 1z0 BOPSUF P INT2 Test high. Baker Locked connection on test joint leaking. High tes failed. RD Test equipment from test joint. 18:30 - 20:30 2.00 BOPSUF N INT2 PJSM - Heat Baker Iocked XO connection and cool with air, Break XO clean and inspect threads, Baker lock and MUxDm test 20:30 - 21:00 0a0 BOPSUF P INT2 Test Top set of4'1/2^xr'V8R'oto25O psi, held /*soopsi high. Held Test witnessed by Chris Clemens (WSL), KeIIy Cozby (NAD Too|puohod. Sean Holcomb (NADDriller) 21:00 - 21:30 0.50 BOPSUF P INT2 RD test equipment, MU Running tool and install wear bushing. LD running tools. 21:30 - 22:30 1.00 CASE P INT2 PJGM'PU Baker Top Drive Cement head G load u.uu^ nose x 6.2o^ fin liner wiper dart. MU 15' pup &T|VVvalve. LD assembly in pipe shed. 22:30 00:00 1o0 CASE P INT2 PJSM - RU 6-5/8 Torque Turn Casing equipment. 4/2/2009 00:00 - 04:30 4.50 CASE N HMAN LNR2 Inspection of EZC 404Z liner shoe showed drift of 5.796. unable to confirm equipment had been drifted to special drift of S.u7a^ Mobilized backup EZC4O4Z&T|Vv float equipment to rig. 04:30 05:00 0.50 CASE N HMAN LNR2 PUEZC*o4Z& Float collar m rig floor & drift same mo.o7o^. Check jets 4x1O'v.&u5no psi rupture disk. 05:00 - 11:30 6.50 CASE P LNR2 Run 6'e8'Hvdri|521o4#L'oO/13Cmo Liner me.2oO' MU L-80 Shoe track Baker lock first 4 joints up to insert landing collar. Toruqe Turn to connections to 17,500 ftllbs. Check each floatjoint, floats held. Run Jts # 5 - 29, 24# 13Cn0/SCr Transition XO/Jts # 30 - o6.24#L'oo Turn m connections to18.nUovv|Uo. Fill every joint ran. Jet Lube Seal Guard used on all connections. 11:30 - 12:00 0.50 CASE P LNR2 {/O handling equipment m4'1/u^8PU/MU Baker on.4o'Tie Back Extension, MU Liner wiper plug &mUm1n.soonNus Liner UWT 85k / DWT 85k 12:00 13o0 1D0 CASE P LNR2 RD 6-5/8 Torque tum casing equipment and clear floor of same 13:00 - 14:00 1.00 CASE P LNR2 Circulate one liner DP volume staging pump up to 600 gpm / 969 psi. BIow down top drive. 14:00 00:00 10.00 CASE P LNR2 R|H with O's0^ liner from u.o51'm6.11O' PU4'1/u^DP from pipe shed Filling pipe & Break circulation every 30 joints. Running speed 60- 90 fpm. a.u1s'eoogpm/1o47psi MW out 12.4 ppg 4.181'803gpm/1201 psi MW out 12.4 ppg Printed: 6/3/2009 3.57 48 PM • BP Page 53 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of O perations 4/2/2009 14:00 - 00:00 10.00 CASE P LNR2 5,150' 603 gpm / 1423 psi MW out 12.2 ppg Obtain parameters: UWT 110k / DWT 90k / RWT 102k / TQ @ 20 & 30 rpm 4k 6,118' 600 gpm / 15 ft/Ibs 15 psi MW out 12.3 ppg 4/3/2009 00:00 - 03:30 3.50 CASE P LNR2 RIH with 6 -5/8" liner from 6,118' to 7,782' PU 4 -1/2" DP 1x1 from pipe shed & Filling pipe & Break circulation every 30 joints. Running speed 60- 90 fpm. 7,125' 603 gpm / 1706 psi MW out 12.2 - 12.4 ppg 03:30 - 09:30 6.00 CASE P LNR2 Continue RIH With 4 -1/2" Stands from derrick from 7,782' to 11,467' Filling pipe & Break circulation every 10 stands. Running speed 60- 90 fpm. 8,073' 600 gpm / 1885 psi MW out 12.4 ppg 9,054' 600 gpm / 1972 psi MW out 12.3 ppg 10,010' 600 gpm / 2154 psi MW out 12.4 ppg Obtain parameters W/0 pumps: @ 10,010' UWT 145k / DWT 100k / RWT 115k / TQ @ 20 rpm 5k ft/lbs & 30 rpm 6k ft/lbs 09:30 - 10:30 1.00 CASE P LNR2 C/O handling equipment to 5 -7/8" MU XO & 1 Jt. 5 -7/8" 23# DP to 11,506' & Circulate. 11,506' 600 gpm / 2385 psi MW out 12.4 ppg 10:30 - 11:30 1.00 CASE P LNR2 RIH PU 9 more Jts 5 -7/8" 23# DP 1x1 from 11,506' to 11,790' 11:30 - 15:30 4.00 CASE P LNR2 Continue RIH With 4 -1/2" Stands from derrick from 11,790' to 14,175' Filling pipe & Break circulation every 10 stands. Running speed 60- 90 fpm. 12,458' 600 gpm / 2440 psi MW out 12.4 ppg 13,412' 600 gpm / 2463 psi MW out 12.4 ppg 15:30 - 18:30 3.00 CASE P LNR2 Break circulation @ 14,175' and stage pump up to 600 gpm / 2626 psi & circulated 30,000 strokes / 2540 bbls. Mud wt in 12.5 out 12.5 Reciprocate 90' & rotate on down stroke for 10 min @ 30 RPM / 8k ft/lbs TQ every hour Obtain parameters W/0 pumps: @ 14,175' UWT 200k / DWT 120k / RWT 161k / TQ @ 30 rpm 8k ft/lbs 18:30 - 00:00 5.50 CASE P LNR2 RIH With 4 -1/2" Stands from derrick from 14,175' to 16,751' Filling pipe every stand. Running speed 24- 32 fpm. Full returns while running, correct displacement. 4/4/2009 00:00 - 03:30 3.50 CASE P LNR2 RIH With 4 -1/2" Stands from derrick from 16,75110 18,945' Filling pipe every stand. Running speed 24- 32 fpm. Full returns while running, correct displacement. Printed: 6/3/2009 3:57:48 PM ��N� �� Page 54 of 91 BP Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Code '-' Hours Task ~ � �mPT� - Description 4/4/2009 00:00 - 03:30 3.50 CASE P LNR2 03:30 - 06:00 2.50 CASE P LNR2 At 18,945' Break Circulation & stage pump rate up to 1.5 bpm in.5Upmincrements 1oopm/04gpm/477 psi. & pump 14cUb|o fresh mud inthe 8'e8^x0'5/D^x4'1/u^ annulus. K&M Calculated ECo1o.e7 ppg@*a shoe 1o.s7 @ TD No Losses observed while circulating. Obtain parameters: @ 18.9*5' UWT 262k W/ pumps W/O Pumps DVVT135k/RWT180k/TQ @2o rpm 17xnmUo /3O rpm 18x*Nbo 00:00 14:00 8.00 CASE P LNR2 R|M With 4'1/2' Stands from derrick from 1n.S*5'meo.o17' FiIIing pipe every stand. Running speed 24- 32 fpm. Full returns while running, correct displacement. Obtain parameters: @ 20.934' W/O Pumps DVVT12ok/RVYT190k/TQCOoO rpm 2Ukft/lUa/ 30 rpm 22k ft/lbs Obtain parameters: @ 22,935' vvx] Pumps DVVT1u7x/RVvT2OOx/TQ @uo rpm 2OxMNba/ no rpm u1k*NUo 14:00 - 14:30 0.50 CASE P LNR2 /u23.s17' Break Circulation & stage pump rate vpto18opm/ 64 gpm / ICP 1198 psi. FCP 871 psi. & pump 650 strokes 55 bb|o fresh mud in the 8'50^xU'50^annulus. No Losses observed while circulating. Obtain parameters: @ 23,517' UWT 340k W/ pumps VV/0 Pumps DVVT142u/RVYT21Ox/TQ @oo rpm 23kh8Uo 14:30 16o0 1a0 CASE P LNR2 n|H from 23.s17'tnu3.000' 16:00 - 16:30 0.50 CASE P LNR2 Wash & Ream from oo.oO8vozo.nnV Start rotating no rpm /u4k*NUoTO. 18opm/57gpm /141opsi 18:30 17o0 0a0 CASE P LNR2 R|HVVx} rotation from uo.88U'toe4.O8U' 17o0 1e:30 2.50 CASE P LNR2 Wash & Ream from u^.o&6'u,u4.1s8' stalling rotary L 3O rpm /28'unkVNUoTQ. 17opm/61gpm /1u1opsi 19:30 - 21:30 280 CASE P LNR2 Pull vpmu4.11U' pulled 4nOxS/Ot0000k Rotate while G/)& break free . Acting like differential sticking. Wash & Ream 24,110' 24,158' os*5 rpm /ueuft/lbsTQ 2*spm/86 gpnn /1o95 psi Printed' 6/3/2009 3 57.48 PM • • BP Page 55 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/4/2009 19:30 - 21:30 2.00 CASE P LNR2 21:30 - 00:00 2.50 CASE P LNR2 Wash & Ream 24,158' to 24,276' 35 -40 rpm / 27 -30k Wlbs TQ 24 spm / 86 gpm / 1095 - 1026psi 4/5/2009 00:00 - 08:30 8.50 CASE P LNR2 Wash & Ream 24,276' to 24,415' 40 rpm / 29-31k ft/Ibs TQ 24 spm / 86 gpm / 1095 - 1150psi MW in 12.5 ppg @ 01:00 hrs MW out 12.7 climbing to high of 15.5 ppg by 06:00 hrs Control Reaming rate while circulating out heavy mud prior to entering Top of Kingak @ 24,390'. Running solids control equipment to combat weight. Mixed 100 bbls 5% Steel Lube EP pill in G &I. Slowly bled in 45 bbls into the active system @ 15 bbl /hr to combat torque, stopped lube pill addition due to heavy mud coming out. 08:30 - 12:00 3.50 CASE P LNR2 Wash & Ream 24,276' to 24,480' Stage pump rate up from 86 gpm to 200 gpm as mud wt coming out decreaed. 40 - 48 rpm / 29 -32k ft/Ibs TQ 56 spm / 200 gpm / 897psi Mud wt in / out 12.5 ppg Packed off and stalled rotary @ 24,479' PU to 24,465 / Bk over wt 420k regained rotation & circulation continued reaming. Dropped carbide bomb on connection @ 24,465' to gauge surface to surface strokes and gain confidence in drill string integrity due to pressure fluctuations. 12:00 - 00:00 12.00 CASE P LNR2 Wash & Ream 24,480' to 25,129' Stage pump rate up from 200 gpm to 225 40 - 48 rpm / 29 -32k ft/lbs TQ 63 spm / 225 gpm / fluctuated 995psi to 1050 psi 61 spm / 218 gpm / 967psi RWT 240k Carbide bomb back to surface @ 24,821 Strokes. Calculated Strokes. Encountered tight spots & erratic torque with & without pack off tendencies @ 24,530' 24,560' 24,619' Printed: 6/3/2009 3:57:48 PM • BP Page 56of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/5/2009 12:00 - 00:00 12.00 CASE P LNR2 24,680' 24'916' 25,040' - 25,074' 4/6/2009 00:00 - 12:00 12.00 CASE P LNR2 Wash & Ream 25,159' to 25,578' 42 - 45 rpm / 27 -30k ft/lbs TQ 60 spm /214 gpm / 915 psi Reducing pump rate @ 25,561' to 34 spm / 121 gpm / 626 psi RTW 228 -250k Encountered pack -off @ 24,459' Encountered pack -off @ 25,561' Encountered pack -off @ 25,576' 12:00 - 13:30 1.50 CASE P LNR2 Wash & Ream 25,578' working liner down to 25,581' where liner became packed off and differentially stuck 42 - 45 rpm / 28 -30k ft/lbs TQ 34 spm / 121 gpm / 629 psi RTW 228 -250k 13:30 - 17:00 3.50 CASE P LNR2 Worked pipe Pulling up to 500k & slumping to 95k Attempt to gain rotation with 37k ft/lbs Tq. Working pumps with up to 1229 psi. 17:00 - 00:00 7.00 CASE P LNR2 Attempt to establish injection rate Pressured up to 1500 psi in 500 psi increments. Pressure bled down to 1380 psi and dropped suddenly with returns at flow line. Start pumping at 17 spm 1010 psi. & continue to stage pump rate up to 63 spm / 225 gpm / 828 psi working repeated packing off through stage up process. No fluid losses encountered, 4/7/2009 00:00 - 00:15 0.25 CASE P LNR2 Circulate 63 spm / 225 gpm / 828 psi total of 5200 strokes 442 bbls No fluid losses encountered 00:15 - 00:45 0.50 CASE P LNR2 Continue circulating 63 spm / 225 gpm / 828 psi S/0 to 95k / Pull 400k / 8/0 to rotating Wt 250k, attempt to rotate with 35k ft/lbs TQ x 2 & released torque. S/0 to 95k / Pull 450k. While slacking off to neutral weight hole started packing off. 00:45 - 05:00 4.25 CASE P LNR2 Attempt to regain circulation working pipe up to 420k / slumping to 95k & rotating with 35k ft/lbs Tq. Worked pumps up to highest of 1280 psi 33 stks where hole broke down & pumped 1.5 bbls. Total 48 strokes. Pressure bled back to 840 psi. Continue to work pumps & pipe to regain circulation Consult with ODE. 05:00 - 09:30 4.50 CASE P LNR2 Emergency Release Liner - Rotate to left 2 turns with 8k Torque, SO pipe down to 80k block wt and PU to 350k -Work 2 more turns to the left, work pipe -Work 2 more turns to the left, work pipe (6 turns total) Printed: 6/3/2009 3:57:48 PM • BP Page 57 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/7/2009 05:00 - 09:30 4.50 CASE P LNR2 -Work 2 more turns to the left, work pipe 2 (8 turns Total) -Work 2 more turns to the left, work pipe 2 (10 turns Total) -Work 1.5 more turns to the left, work pipe (11.5 turns Total) -Work 1.25 more turns to the left, work pipe (12.75 turns Total) -Work 1.25 more turns to the left, work pipe (14 turns Total) -Work 0.75 more turns to the left, work pipe 50k down & 400k up(14.75 turns Total) -Work 0.75 more turns to the left, work pipe 50k down & 400k up(15.50 turns Total) -Work 1.00 more turns to the left, work pipe 50k down & 400k up(16.50 turns Total) Unsuccessful on backoff Release Torque and Blow Down Top Drive Work Torque out of string Set Torque Limit to 8k and work 15 turns down, increase torque limit to 10k, work 5 more turn for a total of 20 turns total, Release remaining trapped torque and PU, 390k PUW Attempt to circ., Established circulation immediatly at 228 gpmn / 755 ps, 1 flow, Establish Rotation @ 20 rpm 23k Torque, Slack off apx. 3', pressured up to 1100 psi, shut pumps off and pressuree held at 750 psi, Tq @ 19k neutral weight and 23k up wt., Release Torque, Pick to 350k and weight fell to 300k, move up the hole (PUW 340k) Rotate Down and re- engaged setting tool, Pipe Rotating free at 21kTq Blow Down Top Drive Pick up 5' and establish circulation while still stung into liner, PUW 405k (no Pump) Rotate down at 20 rpm with pump and slack off 6', pressured up to 1500 psi, continue slacking off 5' rotating @ stalled rotation at 26k Tq., Injecting at 1456 psi / 2 bpm Blled off Pressure and Blow down Top Drive 09:30 - 14:30 5.00 CASE N WAIT LNR2 Consult with Anchorage Rig Team and Developed the plan forward of POOH without pumping cement 4/7/09 13:46 hrs Tom Maunder, AOGCC PE and AOGCC t Commissioner Foerster has been apprised of the current plans concerning the 6 5/8" Liner plan forward and had no objections. 14:30 - 17:00 2.50 CASE P LNR2 Pull out of liner -Pick Up with 500 psi / 270k PUW - Pressure released as soon as running tool release from top of liner Establish circulation at 550 gpm / 2283 psi -Circ two liner volumes -Pump 14.5 ppg Dry Job Printed: 6/3/2009 3:57:48 PM • BP Page 58 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/7/2009 14:30 - 17:00 2.50 CASE P LNR2 Pulled 2 stands, dry job failed, mud out of balanced and flowing over top of drill pipe 17:00 - 19:00 2.00 CASE P LNR2 Circulate and condition mud -700 gpm / 2995 psi - reciprocate with no rotation -Pump 15.0 ppg Dry Job 19:00 - 00:00 5.00 CASE P LNR2 POH @ 3 min /stand Inspecting WWT Super Sliders 4/8/2009 00:00 - 00:30 0.50 CASE P LNR2 POH -Pipe Pulling Wet 00:30 - 01:30 1.00 CASE P LNR2 Break Circ and Pump 15.5 ppg Dry Job -Blow Down Mud Lines 01:30 - 08:30 7.00 CASE P LNR2 POH -Pipe Pulling Dry -Lay Down 2 stands of 5 7/8 26# and remove super sliders, LD from Derrick -Pipe started coming wet @ 11,156 08:30 - 09:00 0.50 CASE P LNR2 Service Blocks, TDS and Crown 09:00 - 09:30 0.50 CASE P LNR2 Break Circ and Pump 15.0 ppg Dry Job -Blow Down Mud Lines 09:30 - 11:30 2.00 CASE P LNR2 POH to 4 1/2" Drill Pipe - Change Over to 4 1/2" handling Equipment 11:30 - 20:30 9.00 CASE P LNR2 Lay Down 285 jts of 4 1/2" Drill Pipe -Pin End of Jt #284 and Box of Jt #285 showed indications of a backoff, Starting threads on pin galled and threads on box damaged 20:30 - 21:30 1.00 CASE P LNR2 UD Running Liner Tool *A Steel Piece of the collet broke off and left in hole -Piece 1 3/8" long x 3/4" wide 3/4" thick *Wiper Plug still attached 21:30 - 00:00 2.50 BOPSUF P PROD1 Flush Stack and Function Test BOP Rams -Pull Wear Bushing -P /U Jet Tool and Flush out stack -Blow Down surface lines 4/9/2009 00:00 - 01:00 1.00 BOPSUF P PROD1 Rig Up to Test BOP's -Pick Up 5 7/8" Test jt and test plug -Make up TIW and Dart valves 01:00 - 10:00 9.00 BOPSUF P PROD1 Test BOPE as per BP / AOGCC Regulations to 250 psi low / 4500 psi High for 5 min each 250 psi / 3500 psi on Annular preventer.Witnessed of test waived by Lou Grimaldi (AOGCC State Inspector) Test Witnessed by Dave Newton and Brian Buzby (BP WSL), Brian Tiedemann and Kelly Crosby(NAD Toolpusher), Kenny Sullivan (NAD Driller). Test Recorded on a chart recorder. Test as follows with 5 -7/8" Test Joint. Test as follows with 250 psi / 4500 psi. #1) Top 4.5" x 7" VBR / 5 -7/8" !BOP / Choke Valves # 9, 12 & 13 / Kill Line & Dart Valve Printed: 6/3/2009 3:57:48 PM • BP Page 59 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/9/2009 01:00 - 10:00 9.00 BOPSUF P PROD1 #2) 5 -7/8" Floor Safety Valve / Kill HCR / Choke Valves # 8 & 11 #3) Choke Valves # 4, 7, & 10 #4) Choke Valve # 3 -5 -6 / Manual Kill Line Valve #5) Super Choke & Manual Choke Manifold Valves 250 low & 1500 psi high #6) Choke Valve #1, 3 & 5 #7) Choke Valve #2, #8) Choke HCR Valve #9) Lower Top Drive Well Control Valve / Manual Choke Line Valve on stack #10) Bottom 3.5" x 6" VBR / Upper Top Drive Well Control Valve #11) Accumulator Function / Draw Down Test #12) Blind Shear Rams Change out Test equipment to 4 -1/2" Test as follows with 4 -1/2" Test Joint. #13) Top 4.5" x 7" VBR / 4 -1/2" Floor Dart Valve #14) Bottom 3.5" x 6" VBR / 4 -1/2" Floor Safety Valve #16) Annular 250 psi / 3500 psi 10:00 - 10:30 0.50 BOPSUF P PROD1 Install 10.75" Wear Bushing 10:30 - 12:00 1.50 BOPSUF P PROD1 Service Rig -Slip and Cut Drilling - Service Blocks, Crown, Draw Works and TDS 12:00 - 17:00 5.00 DRILL P PROD1 Make up Cleanout BHA -Flat Bottom Mill, 2 x Junk Baskets, Bit Sub, 6 x SDC, Jars, XO, $ 1/2" CTM Drill Pipe, XO 17:00 - 00:00 7.00 DRILL P PROD1 RIH Picking up 4 1/2" Drill Pipe -Fill every 3000' 4/10/2009 00:00 - 09:00 9.00 DRILL P PROD1 RIH Picking up 4 1/2" Drill Pipe -Fill every 3000' 09:00 - 11:30 2.50 DRILL P PROD1 RIH to 200' above Top of 8 5/8" Liner 11:30 - 15:30 4.00 DRILL P PROD1 Circulate and Condition mufd at Top of 8 5/8 Liner - Circulated 3x bottoms up - Staged pumps to 682 gpm / 3952 psi -120 rpm / 8k Torque -200k PUW / 112k SOW / 150k RtWt - Racked back one stand after each bottoms up. -Small amounts of barite were seen across shakers. - Highest mudweight coming back was 12.1 ppg, no big swings in Mud Wt -Mud Weight Going in 12.1 ppg 15:30 - 00:00 8.50 DRILL P PROD1 Change out Mud System to 9.7 ppg LSND mud -98 spm / 1480 psi ICP / 1030 psi FCP -120 RPM / 8k TO Once 9.7 ppg Isolated heavy mud in "L" Pits Circulate and Condition 9.7 ppg Mud circulating at Max Rate through "L" Pits Bypass Line -420 gpm / 1026 psi -120 rpm / 15k Tq - Standing Back 1 stand every Bottoms Up Printed: 6/3/2009 3:57:48 PM • BP Page 60 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/10/2009 15:30 - 00:00 8.50 DRILL P PROD1 Half way through second bottoms up barite coming off shakers increase to 3 -4 inches on the side of the shaker screens with intermittent "blobs" about the 8" in diameter unloading from the hole I 4/11/2009 00:00 - 01:30 1.50 DRILL P PROD1 Continue Circulating barite out of 11 3/4" casing - Building Volume to fill " L" Pits 420 gpm / 1030 psi 120 rpm / 14k Tq - Barite coming off shakers increase to 3 -4 inches on the side of the shaker screens with intermittent "blobs" 01:30 - 03:00 1.50 DRILL P PROD1 Continue Circulating barite out of 11 3/4" casing at Increase Pump Rate -700 gpm / 2075 psi 120 rpm / 15k Tq Barite cleaned up with very little coming off the shakers 03:00 - 12:00 9.00 DRILL P PROD1 RIH with 5 7/8" @ 2 minute / stand - Filling pipe on the Run 12:00 - 15:30 3.50 DRILL P PROD1 RIH with 5 7/8" e 2 minute / stand - Filling pipe on the Run Work through top of liner at 23,341 with rotation but no pump 20 rpm 29k Tq PUW 380k / SOW 120k / 220k 15:30 - 18:30 3.00 DRILL P PROD1 RIH with 5 7/8" 23,341 - 25,456 -2 minute / stand - Filling pipe on the Run Tag Landing Collar on depth © 25,456_, 18:30 - 23:00 4.50 DRILL P PROD1 Circulate and Condition Mud - Pumping 9.7 ppg mud in -Stage Circulation Rate up to 600 gpm -600 gpm / 3580 psi -PUW 440k / 192k SOW with pump , no rotation - Rotating weight up 273k / down 209k/ neutral 230k -120 rpm Torque 38 -40 k down and 40 -42k up Mud Wt. coming back at bottoms ranged from 12 - 17.4 ppg After 9.7ppg In / Out - Without rotation and pump 474k PUW / 177k SOW -With Rotation and pump 310k PUW / 202k SOW / 212k Neutral -120 rpm 45k Tq down / unable to rotate up 23:00 - 23:30 0.50 DRILL P PROD1 Drill Landing Collar (No Wioer Plugs), -80 rpm / 42 -44k -600 gpm / 2980 psi -5k WOB Drill from 25,456 - 24,561 Printed: 6/3/2009 3:57:48 PM • BP Page 61 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT ' `Phase Description of Operations 4/11/2009 23:30 - 00:00 0.50 DRILL P PROD1 Pump10% Steel Lube Pill -80 bbl pill at 10% Lube 4/12/2009 00:00 - 00:30 0.50 DRILL P PROD1 Pump Steel Lube Pill -80 bbl pill at 10% Lube After pill spotted in Liner, Torque reduced from 45k to 42k and was able to backream without stalling at 45k Without rotaion and pump 440kPUW / 190k SOW With Rotation 290k PUW / 212k SOW / 230k neutral wt 00:30 - 03:00 2.50 DRILL P PROD1 Drill Shoe Tract 25461' - 25,578'md -Float Collar © 25,536' -500 gpm / 2478 psi -80 rpm / 38k -10k WOB 03:00 - 05:00 2.00 DRILL P PROD1 Drill EZCase Shoe 500 gpm / 2430 psi -80 rpm / 36 -40k Drill with Torque Limit set with a low stall point 05:00 - 07:45 2.75 DRILL P PROD1 Clean out 7 7/8" Rat Hole From 25,585 - 25,611 -500 gpm / 2400 psi -80 rpm / 38k - 45k -0 - 5k WOB Experience Some Stalling and Packing off in "Old" Hole 07:45 - 08:00 0.25 DRILL P PROD1 Drill 6' of New Hole to help break up any Junk in the hole 80 rpm / 35k Tq 5600 gpm / 2400 psi 5k WOB Instant ROP's with Mill at 70' /hr 08:00 - 08:30 0.50 DRILL P PROD1 Work Junk Baskets on bottom and through Shoe without rotation several times 08:30 - 09:30 1.00 DRILL P PROD1 Circulate 2x Liner volumes -500 gpm / 2398 psi -Take Slow Pump Rates - Monitor Well 9.7 ppg In / Out 09:30 - 00:00 14.50 DRILL P PROD1 Pump out of Hole to 18,206' -Pump out eliminate Swab Pressure on Kuparuk -Pump at 260 gpm / 690 psi - Pulled at 3 min / stand 9.7 ppg Mud Wt In / Out 4/13/2009 00:00 - 00:30 0.50 DRILL P PROD1 Monitor Well and Pump Dry Job -9,7 ppg In / Out 00:30 - 06:00 5.50 DRILL P PROD1 POH to 8 5/8" TOL - Restrict Pulling Speeds to 4 min / stand 06:00 - 09:30 3.50 DRILL P PROD1 Circulate at Top of 8 5/8" Liner -CBU 2x 700 gpm / 1993 psi -120 rpm / 13k ft/Ibs Torque -192k PUW / 95k SOW / 155k RtWt Monitor well, Static 9.7 ppg In /Out Printed: 6/3/2009 3:57:48 PM • �� BP -�` Page 62 of 91 Operations Summary Re Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release. 5/20/2009 Rig Name: NABORS 33E Rig Number: Date Task Code NPT Phase Description of Operations 4/13/2009 09:30 10:30 1.00 DRILL P PROD1 POHon the Mookhom13�7O'11�7e* 10:30 - 11:30 1.00 DRILL P PROD1 POMw�h*1/2^DP -Change � �angoHandgsqupmom 11:30 12:00 0.50 DRILL P PROD1 Service the Draw Works, Crown, and Top Drive 12:00 13:30 1.50 DRILL P PROD1 PDHo�numg Back 41x�oP 1�oo'oo:on 6.50 DRIL L P PROD1 PDHLaym �gDn~n41�Dm| Pipe 1v1 -255 Jts uoxm 21z0 1.50 DRILL P PROD1 Handle BHA 'uoJam -Stand Back o stands of Spiral 43/4^SDC'n -Break off XO, 2 x Junk Baskets, and FIat Bottom Pilot Mill -Mill was wore on the gauge and edge uf Cut Right about 3U�� Recover apx. 1 gal of Shale Debris m Junk ouak�sand 1'/2 cup of Metal Debris Clear and Clean floor 21:30 - 22:00 0.50 DRILL P PROD1 Conduct Pre-Job Safety mooUngw�hNADTP. Rig Cm*.GwG vvina|inoCmw. and sPvvoL -Reviewed Procedure and address hazards associated with wire line operations -Designate Areas to have warning tape and signs placed 22:00 00:00 2.00 EVAL P PROD1 Rig Up Sheaves and Wireline -Make up Tools -Start Run #1 at Midnight 4/14/2009 00:00 04:00 4.00 EVAL P PROD1 RIH with E-Line -USIT Log Run #1 -Tool was able m get down m14.180'MD -Max Ooon tool ~u.1u Cleaning Mud Pits during Iogging operations 04:00 04:30 0a0 EVAL P PROD1 E'Lino Log up with US|T Tool m3OUo/hr -Log from 1*.15n'm13.ou1 04:30 - 07:00 2.50 EVAL N SFAL PROD1 Repair E-Line -Strand on the outside of the O.46"B|ne broke and unraveled apx 8 Conducted o Pre-Job G����MooUng with NADDhUCmwand GvVSVVi,o|ino crew onVVimnneRepair Clamped Wireline off and set down on rotary table to release tension on wire. Monitor for 10 minutes to assure the clamp is holding Repair wire 07:00 12:00 5.00 EVAL P PROD1 E'Lino Log up with US|T Tool ax3OonYhr -Log from 1o.no1'msurface 12:00 - 13:00 1.00 EVAL P PROD1 Rig Down Schlumberger E-Line Unit and Logging Tools 13:00 - 16:00 3.00 DRILL P PROD1 Make Uns70^PmUuotion Hole o,iUinqBHA _ 'a87a^Tn'Cono Insert Bit, 4m4^Gtmigm Mud M,.wmuC. wM|8s.87sS�U.MVVD.Sm�houuope.UmD�� om houu�o.0 xmM Flex oC'o.CCV.Ja�.8xSDC'o.XO. 16:00 - 00:00 8.00 DRILL P PROD1 n|H picking up41/o^ Drill Pipe 1 x1 Printed: 6/3/2009 3.57.48 PM BP P age 63 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours TaskCode NPT Phase Description of Operations 4/14/2009 16:00 - 00:00 8.00 DRILL P PROD1 - Shallow Hole IntergrityTest MWD / LWD / Motor at 1000' -250 gpm / 925 psi - Filling Pipe every 3000' 4/15/2009 00:00 - 01:30 1.50 DRILL P PROD1 RIH picking up 4 1/2" Drill Pipe - Filling every 3000' 01:30 - 03:30 2.00 DRILL P PROD1 Service Rig -Slip and Cut Drilling Line - Service Top Drive, Crown, Blocks and Draw Works 03:30 - 06:00 2.50 DRILL P PROD1 RIH picking up 4 1/2" Drill Pipe 1 x 1 to 8649' and - Filling every 3000' 06:00 - 08:30 2.50 DRILL P PROD1 RIH with 4 1/2" DP from derrick - Filled pipe at 10,000' 08:30 - 09:30 1.00 DRILL P PROD1 Change out slips, Elevators and Handling Equipment 09:30 - 21:30 12.00 DRILL P PROD1 RIH with 5 7/8" DP from derrick - Filled pipe every 3000' "Tag up with 10k at Top of 6 5/8" Liner (23.341'1. Pulled up above and broke circulation -1st Attempt to get in liner was unsuccessful, pumping at 42 gpm / 408 psi and no pipe rotation -2nd attempt was successful with 42 gpm and 20 rpm / 26 k Tq Continue RIH without issues 21:30 - 22:30 1.00 DRILL P PROD1 Break Cirulation at 25,414' and -250 gpm 1982 psi -40 rpm / 36k Tq / 80 rpm 42k Tq -PUW 445k SOW 150k / RtWt 245k Wash Down and Take Parameters With Pump PUW 329k -342k / Sow 212k - 209k / RtWt 249k Without Pump at 25,511' and PUW 475k SOW 175k RtWt 245k 60 rpm / 42k TQ 22:30 - 00:00 1.50 DRILL P PROD1 Displace to 9.7 ppg Flo -Pro -PJSM on displacing procedure with NAD Rig Crew, MI Mud Engineer, G &I Personnel and BP WSL Pump 160 bbl spacer at 232 gpm / 1805 psi Chase spacer with Flo -Pro Start Mad Passing with MWD for Tie -In Log from 25,540- 25,605 bit depth 40 rpm 34k Tq RtWt 228k 250 gpm / 2073 psi No Issues reaming out Rat Hole 60 rpm / 36k Tq 250 gpm 2240 psi ECD 10.92 ppg 4/16/2009 00:00 - 00:30 0.50 DRILL P PROD1 Drill 25,616 - 25,631 and -250 gpm / 2240 psi -70 rpm 39k off btm / 36 on btm Printed: 6/3/2009 3:57:48 PM �� �� �� �� Bp Page 64 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABOR8 ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: � Hours '�� �����/�'�` NPT S���~`�������� � �N� " N� ,. Date - Phase _�`�����1�;��" 4U0/200e 00:00 00:30 0.50 DRILL P PROD1 - With Pump 420k PUW / 175k SOW / 243k RtWt -Circ for 15 min. *Drilled a total of 20 feet of new hole befor performing FIT 00:30 '01:30 1.00 DRILL P PROD1 Perform FIT m1u.5ppgsMw ' 9.7 In 7 ppg/Ou -Pull up in to shoe at 25,564 -Conduct PJSM with personnel involve -1587 psi = 12.5 ppg EMW -Pump uu.4ubpm / 5 spm -Shoe atu5.582' / 10.902' wd -Pump 140 strokes -11.9 bbl / 11.9 bbls returned HeId Pressure for 10 minutes -Initial shut in pressure 1590 psi and the final shut in pressure of 1530 psi 01:30 07:00 5.50 DRILL P PROD1 Drill 25,631- 25,720 md -250 gpm / u1o4 psi on/ 2040 psi offUtm -70 rpm 30k on / 30k tq off -ECD 10.93 ppg -PUW 440k / SOW 1D1k / RtWt 255k 07:00 - 09:00 2.00 EVAL P PROD1 Conduct Formation Evaluation Pressure Tests with Anadrill's Stethoscope Too -Sample atuoeuo'aoa6eu' 09:00 11:00 2.00 DRILL P PROD1 Drill 25,720 - 25,760'md -250 gpm / 2191 psi on / 2061 psi ox Um -80 rpm 1ukon/1okxloff -ECD 10.47 ppg / 15k WOB -PUW 390k / SOW 1u*k / RtWt 250k SPR's 25.030'md / 10.e40wd SJppgmVV|n/Out #1noopm)7sOpsi 30) 920 psi wuu0opm)oOO psi oo)1O1npsi Connections performed as per NorthStar Practices 11:00 12:00 1.00 EVAL P PROD1 Conduct Formation Evaluation Pressure Test withAnuUm[u Stethoscope Too -Sample at 25,628'md 12:00 18:30 7.50 DRILL P PROD1 Drill 25,760 - 26,090'md TDe11.35o'wd) -250 gpm / 2154 psi on btm / 2048 psi off btm -80 rpm 27k on / 27k tq off -ECD 10.84 ppg / 15k WOB -PUW 440k / SOW 190k / RtWt 259k SPR's u6o9O'md/11.oaowd3.7ppgmVvm/Out #1 uOopm)81Opsi 30) 920 psi #o2Oopm)oO0psi 30) 930 psi ADT = 10.7 hrs Connections pertormed as per NorthStar Practices 19:30 - 20:30 1.00 DRILL P PROD1 Circulate Drill Cuttings Up from sample at 25990' -70 spm / 2050 psi '80 rpm /28xTO Printed 6/3/2009 3.57 48 PM �� �� �� �� Page 65 of 91 BP Operations Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: ' Task NPT ' ^'�~~'~ ' -- Phase ��������� '~�������������"��'' 4/18/200e 20:30 - 00:00 3.50 EVAL P PROD1 Conduct Formation Evaluation Pressure Tests withxnauril|'s Stethoscope Tool -Sample ux26.oe1mu_ 4/17/2009 00:00 - 09:00 9.00 EVAL P PROD1 Conduct Formation Evaluation Pressure Tests with Anadriil's Stethoscope Tool -Samples muaoo4.un000 .usn54.uoeuo.u5oo7.uaono.uso7s..uouos.00u4n.usoo4 25823, 25802, 25793, 25813, 28527, 25619, 25620 oa Total Tests Taken /10 Good Tests PUW 410k / SOW 180k 09:00 - 10:00 1»0 EVAL P PROD1 POH to 25350' -Pump out at 2 bpm / 3 min/stand 10:00 - 10:30 0.50 EVAL P PROD1 Case Hole Log - Real Time f/ JB Marker -25,350 - 25300 md @ 1uoYhr pulling speed -250 gpm / 1843 psi 1030 11:00 0.50 EVAL P PROD1 POHmu48OO'md -Pump out at 2 bpm / 3 min/stand 11:00 - 11:30 0.50 EVAL P PROD1 Case Hole Log - Real Time f/ JE Marker -24,806 - 24,770 md m 1oo'/hr pulling speed -250 gpm / 1789 psi 11:30 '13:30 2.00 DRILL P PROD1 R|Hmus.S84'md (1 staridfrom bottom) -TIH @omin/stand 13:30 - 14:00 0.50 DRILL P PROD1 Precautionary Ream to Bottom -250 gpm / 2085 psi -75 rpm / 24k Tq -RtWt = 250k 14:00 - 16:00 2.00 EVAL P PROD1 Perform Caliper Log 25.910 25,820 bit depth -250 gpm // 2038 psi -75 rpm / 26k Tq 16:00 - 16:30 0.50 DRILL P PROD1 R|Hos.O82'o8.O3o'md 16:30 - 17:30 1.00 EVAL P PROD1 Perform Caiiper Log 26030 25940 bit depth -250 gpnn //eo1Opsi -75 rpm / 27k Tq 17:30 - 18:00 0.50 DRILL P PROD1 Precautiortary Ream to Bottom -25Ogpm / 201Ops| -75 rpm / 26k Tq 18:00 19:30 1.50 DRILL P PROD1 Pump High Temp Vis Pill -pumped 80 bbl of PST-200 pilI consisting of extra 1 ppUFlo Vis and 1 ppb pGT'200. Pump till 5 bbl out of bit. 19:30 - 21:30 2.00 EVAL P PROD1 Pump Out of hole Iaying High Temp Vis Pill Pump out at 1.5 bpm / 540 psi *min/stand -Lay 28 barrels of pm in open hole -Continue pumping pill at1.5 bpm covering 500 ft of05/8" liner volume. o1:30'00:00 2.50 DRILL P PROD1 POHm��06' -Pumping at 1.5 - 2.0 bpm 1 -POH at 3 min / stan -Drop CCV Bali toaIlow time for it to fall before we get to 6 5/8 TOL -Ball on seat (2 hrs 20 min) Printed. 6/3/2009 3.57 48 PM • BP Page 66of91' Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/17/2009 21:30 - 00:00 2.50 DRILL P PROD1 -CCV pressure up to 1720 psi before shifting -250 gpm / 904 psi compared to 1900 psi earlier 4/18/2009 00:00 - 00:30 0.50 DRILL P PROD1 POH to Top of 6 5/8" Liner -Pump out at 2 bpm -Pull at 3 min / stand 00:30 - 02:30 2.00 DRILL P PROD1 Break Circulation -Pump 2x the 8 5/8" Liner Volume - staged up to 500 gpm, stop at 250 gpm to verify that there was minimal flow through MWD / LWD -500 gpm / 1835 psi -80 rpm / 25k Tq -239k RtWt Monitor Well, Static 9.7 ppg in /out 02:30 - 11:00 8.50 DRILL P PROD1 POH to 18,007' and -Pump out at 2.0 bpm -POH at 3 min / stand 11:00 - 17:00 6.00 DRILL P PROD1 POH to just before the top of 8 5/8" Liner to 14,460' bit depth -Pump out at 2 bpm -Pull at 3 min / stand 17:00 - 23:00 6.00 DRILL P PROD1 Break Circulation - Circulated Bottoms Up 3x to clean hole -Bit depth was placed at 14,455 to place the CCV across the Top of the 8 5/8 Liner at 14,241' - staged up to 550 gpm -550 gpm / 1400 psi -120 rpm / 12k Tq -169k RtWt -Set back one stand after the first bottoms up - Bit Depth was at 14,305' Pumping at the higher rate and rotation brought up a small amount of sand cuttings Shakers clean up by the end of the third bottoms up with very little sand coming off the end of the shaker Monitor Well, Static 9.7 ppg in /out -Pump Dry Job, blow down TDS and Mud Lines 23:00 - 00:00 1.00 DRILL P PROD1 POH on the hook standing back 5 7/8" DP -POH at 1 min / stand pulling speed 4/19/2009 00:00 - 01:30 1.50 DRILL P PROD1 POH (wet) standing back 5 7/8" DP -POH at 1 min / stand pulling speed -Dry Job did not work with Flo -Pro 01:30 - 04:30 3.00 DRILL P PROD1 POH (wet)with 4 1/2" Drill Pipe, standing back in derrick - Change Handling Equipment -Pull at 1 min /stand -POH to 8500' and 04:30 - 12:00 7.50 DRILL P PROD1 POH Laying Down 4 1/2" Drill Pipe 1 x 1 12:00 - 15:30 3.50 DRILL P PROD1 POH Laying Down 4 1/2" Drill Pipe 1 x 1 -Set Back two stands of 4 3/4" SDC's 15:30 - 18:00 2.50 DRILL P PROD1 Lay Down BHA -PJSM with Schlumberger MWD, LWD , DD and NAD Drill Crew on Laying Down BHA and removing source Printed: 6/3/2009 3:57:48 PM • 11111 BP Page 67 of 91 Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABOR8 ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date ��� From - To Hours Task Phase */19/200e 15:30 - 18:00 2.50 DRILL P PROD1 -L/oJum -UDNMDC's -Remove Source -Lay Down Stethoscope too and ADN, and MWD -Drain Motor and Break off bit and Lay Down Motor Bit u'4vvT'A's'|'u'Toulost teeth . Bit ingauge 18:00 19:00 1.00 BOPSUF P PROD1 Function Tes BOP Rams and Annular -Clear Floor of excess driIIing tools and clean floor to prepare to handle BHA 19:00 - 21:00 2.00 DRILL P PROD1 Service Top Drive -Change dies in pipe handier on the Top Drive -Service TDS, Draw Works and Crown 21:00 - 22:00 1.00 CASE P PROD1 Make Up EZ Drill Tool and Runninq tool, Float Sub and 2 stands of 4 3/4" SoC'a 22:00 - 00:00 2.00 CASE P PROD1 Tripping inm hole Picking up41/o'CTMDP1x1 -PJSM with Rig Crew 4/20200e 00:00 09:30 9.50 DHB P TIEB1 Tripping inm hole Picking up*1/o'CTMDP1 x1 -PJSM with Rig Crew -Checking Pipe Fill every 3000 08:30 11:00 1.50 DHB P TIEB1 Tripping in the hole with 4 1/2 CTM DPfrom derrick -PJSM with Rig Crew -90Yotand running speed -Checking Pipe Fill every 3000 11:00 - 14:00 3.00 DHB P TIEB1 Tripping in the hole with 5 7/8 DP from derrick -90'/stand running speed -Checking Pipe Fill every 3000 14o0 00:00 10.00 DHB P TIEB1 Tripping in the hole with o7/B^DP from derrick moo.3u8'mU TIH through Top of 8 5/8" Liner without issues -Reduce Running speed to 3-4 min/stand -PJSM with Rig Crew -Checking Pipe Fill every 3000' 4/21/2009 00:00 - 05:00 5.00 DHB P TIEB1 Tripping in the hole with 57/D^DP from derrick oau3.34o'md -Reduce Running speed to 3-4 min/stand -Checking Pipe Fill every 3000' PUW @ 23,300 md 375k up 150k down 05:00 - 09:30 4.50 DHB P TIEB1 Tripping in the hole with 5 7/8" DP from derrick & position CIBP @ 25.522'mu TIH through Top of 6e8^ Liner without issues -Reduce Running speed to 3-4 min/stand -Checking Pipe Fill every 3000' PUYV*/ Pumps *5ok/DvvT w/o Pumps 1Ouk 09:30 '10:30 1.00 DHB P TIEB1 Set C|sPatus.auu'_ Rotate @u5 rpm 31k0NUo breaking back mcnktNUs after 1n round to the right then applying 35 rounds to the right, release torque. PU & shear off of CIBP with 470k. UPW fell fell back to 4o5u. repeat ux'a with same results, G/Omuaok. rotate mright 25 turns to retrac setting tool dogs,S/0, tag CIBP, stacked 5k dn, saw weight indicator jump, continued to stack 30k dn on QeP. Repeated tag with ^nx.C|BPin place @es.5uu' Monitor Well, Static printeu 6/3/2009 3.57:48 PM • BP Operations Summary Rep Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: N/\B{}RS ALASKA DRILLING | RigRo|eaae: 5/20/2009 Rig Name: NAB(}R833E RigNumber: Date ' -�- Code NPT Phase ` Description of Operations 4/21/2ooe O9�U 10:30 1.00 DHB P TIEB1 10'30 15:00 4.50 DHB P TIEB1 POM from u5.n2utoun,341' Top oYO5/8 Liner -Pump out at 2 bpm -Pull at 3 min / stand -Mud wt in / out 9.7ppg 15:00 16:30 1a0 DHB P TIEB1 Break Circulation -Pump 2x the 8 5/8 Liner Volume. -500 gpm/1861 psi {WTo4uk/DVVT1*ux Monitor Well, Stati Mud wt 9.7 ppg in/ou 10:30 18:30 2.00 DHB P TIEB1 PJGM' Slip & Cut 153' drilling line. Service Draw Works & Top Drive 18:30 20:30 2.00 DHB P TIEB1 POH from 23.341'm2o.O16' -Pump out at 2 bpm -Pull at 3 min / stand -Mud wt in / out 9.7ppg 20:30 - 21:00 0.50 DHB P TIEB1 Draw Works brakes not functioning correctly suspend tripping opomnono. PJG� Ho|d review procedure un adjusting brakes &initiate work permits. 21:00 22:30 1.50 DHB P TIEB1 Inspect and adjust brake Iinkage & brake band kick back rollers. Function test brakes. Brakes still not functioning correctly. 22:30 00:00 1.50 DHB N RREP T|EB1 ConhnuoonuU|ouhoo and mpairU�wwmmmum�m. 4/22/2009 00:00 02:30 2.50 DH8 N SFAL TIEB1 PJS�8Continuotmub|oukom and repair dmwwm, |dontifyoqua|izor bar oh to ohingo#driUooiUo� Co,� pm�om�moqu�|zerbar, m�Uumkio� bands. 02:30 04:30 2.00 DHB P TIEB1 POH from uu.o1o'mu1.ouo' -Pump out at 2 bpm -Pull at 3 min / stand -Mud wt in / out 9.7ppg 0*30 05:30 1.00 DHB P TIEB1 Top Drive back up wrench grabbe slipping while breaking / making connections on XT-57 DP. Hold PJSM and change out back up wrench die blocks. 05:30 13:00 7.50 DHB P TIEB1 POH from u1.83O'tn17.n4o' -Pump out at 2 bpm -Pull at 3 min / stand -Mud wt in / out 9.7ppg 13o0 14:00 1.00 DHB P TIEB1 Monno,weU.G�t� Pump�Qu��8�gNaQ dry �m a|mw uowntopdhvo&muu|ineo Printed: 6/3/2009 3:57:48 PM • • BP Page 69 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/22/2009 14:00 - 18:00 4.00 DHB P TIEB1 POH on elevators std back 5 -7/8" DP from 17,945' to 14,200' -Pull at 3 min / stand 18:00 - 20:00 2.00 DHB P TIEB1 POH on elevators std back 5 -7/8" DP from 14,200' to 11,839' -Pull at 2 min / stand -LD XT -57 x CTM -43 XO -C /O handling tools to 4 -1/2" 20:00 - 23:00 3.00 DHB P TIEB1 POH on elevators std back 4 -1/2" DP from 11,839' to 6016' -Pull at 1.5 min / stand 23:00 - 00:00 1.00 DHB P TIEB1 PJSM - POH on elevators LD 4 -1/2" DP 1x1 from 6016' to 5,531' 4/23/2009 00:00 - 05:00 5.00 DHB P TIEB1 PJSM - POH on elevators LD 4 -12" DP 1x1 from 5,531' to 195' Monitor Well, Static 05:00 - 07:00 2.00 DHB P TIEB1 PJSM - LD BHA #11 Setting tool / Flt Sub / 6 x 4.75" DC's / XO Setting tool in good shape, no deficiencies 07:00 - 07:30 0.50 DHB P TIEB1 Clean and Clear rig floor of vendors tools 07:30 - 08:30 1.00 BOPSUF P TIEB1 Flush Stack and Function Test BOP Rams -Pull Wear Bushing -P /U Jet Tool and Flush out stack -Blow Down surface lines 08:30 - 10:00 1.50 BOPSUF P TIEB1 Rig Up to Test BOPE -Pick Up 5 7/8" Test joint -Pull Wear bushing -Make up test plug, Floor Safety and IBOP valves to test joint -Fill BOPE with water 10:00 - 11:00 1.00 BOPSUF P TIEB1 Test BOPE as per BP / AOGCC Regulations to 250 psi low / 4500 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Test Witnessed by Chuck Schieve (AOGCC State Inspector) Richard Bordes (BP WSL), Bill Bixby (NAD Toolpusher), Sean Holcomb & Kenny Sullivan (NAD Driller). Test Recorded on a chart recorder. Test as follows with 5 -7/8" Test Joint. Test as follows with 250 psi / 4500 psi. #1) Top 4.5" x 7" VBR / 5 -7/8" Floor Safety Valve / Choke Valves # 9, 12 & 13 / Kill Line 2" Demco #2) Kill HCR / Choke Valves # 8 & 11 #3) Choke Valves # 4, 7, & 10 11:00 - 12:00 1.00 BOPSUF P TIEB1 Safety Stand Down / Drilling Appreciation Meeting & Lunch with rig crew and Anchorage Rig Team 12:00 - 18:30 6.50 BOPSUF P TIEB1 Cont' Test BOPE as per BP / AOGCC Regulations to 250 psi low / 4500 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Test Witnessed by Chuck Schieve (AOGCC State Inspector) Richard Bordes (BP WSL), Bill Bixby (NAD Toolpusher), Sean Holcomb & Kenny Sullivan (NAD Driller). Printed: 6/3/2009 3:57:48 PM �� �� �� ~QU� u �� Page 70 of 91 BP y ��v~�~���' Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 f Operations Rig Name: NABORS 33E Rig Number: Date kJ �� Phase Description 4/23/2009 12:00 - 18:30 6.50 BOPSUF P TIEB1 Test Recorded on a chart recorder. #4) Super Choke & Manual Choke Manifold Vaives uso low & 1soo psi high #5) Choke Valve #3-5-6/5-7/8 !BOP #6) Choke Valve #1.3&s w7> Choke Valve #o. �o)CxoxoHCRVa|"a/Lnwe,TopD,ivovvo||Contm|va|vo #S)manua|ChokoLinova|veonotacx/Uppo,TopDrivovvon Control Valve #1o) Bottom 3a^x8^vBR Change out Test equipment to 4-1/2 Test �1)Amnubo� �pai/���i #12)Top4^x7~V8R/4'1/u Safety Valve w��smm Accumulator Function / Draw Down Tes #14) Blind Shear Rams Change out Tes equipment to 6-5/ ^ Test as foliows with 6-5/8" Test Joint. #1a) Top 4.s^x7^veR/4'1/2^ Floor Safety Valve 18:30 - 19:30 1.00 BOPSUF P TIEB1 Pull test plug, RD / BIow down test equipment. Install 1U'1un0^ Wear Bushing 19:30 20:00 0.50 BOPSUF P TIEB1 LD wear bushing running too and clear rig floor 20:00 21:30 1a0 DUMRN P TIEB1 PJGM'MUT8R Polish Mill BHA #10 ToR Polish Mill / Spacer Sub /2x5^DP Pup Jts/TanTop Dressing Mill /XO 21:30 - 00:00 2.50 DUMRN P TIEB1 RIH PU4'1/u^CTM-43oP 1m hommy»no.nos 4/24/2009 00 1.00 DUMRN P TIEB1 FUHPU4���CT��oDP1m1UsVuhum2��nmo�o�' U1� 3.00 DUMRN P TIEB1 RIH w/ 4-1/2" CTM-43 DP from derrick from 3,431'm9,346' Running spee 1.5 min / stan 04:00 04:30 0.50 DUMRN P TIEB1 Change om�ond|ingmooma�/ ^&�Uxo 04:30 08:30 4.00 DUMRN P TIEB1 n|Hw/s�0^XT�7DPfmmdomoxfmmSo4s'to top of*s0^ liner 14,240' Run at1s min /stand UvvTuuok/DVVT118 No problems running into 8-5/8" liner 08:30 16:00 7.50 DUMRN P TIEB1 n|H*y*-70^XT-57oP from derrick from 14.u4o'»oou.00n' Run at1a min /stand 16:00 - 17:30 1s0 DUMRN P TIEB1 MUTDG& stage pump upm7Oopm/ooOgpm/7n5psi. Enter Top '�s'a0^|mor@o3���wimnu rpm /uox*NbuTq a polish Tonugya1g_2l,3711. — Maxomv additional passes uu7O&1oo rpm /cokfNUoTq. Printed 6/3/2009 3 57 48 PM • • BP Page 71 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/24/2009 16:00 - 17:30 1.50 DUMRN P TIEB1 Set down 10k with top dressing mill on top of 6 -5/8" TBR & Dress off TOL. Pull above 6 -5/8" liner top and rack back 1 std DP UWT 395k / DWT 150k / RWT 220k 17:30 - 21:00 3.50 DUMRN P TIEB1 Circulate 2 x 8 -5/8" x 4 -1/2" Liner Annular volumes @ 70 spm / 250 gpm / 692 psi. @ 23,323' 9938 strokes / 845 bbls pumped while servicing rig. Slip & Cut 77' drilling line & adjust draw -works brakes while circulating. Mud Wt in / out 9.7 ppg 21:00 - 21:30 0.50 DUMRN P TIEB1 Service Top Drive Monitor well, Static 21:30 - 00:00 2.50 DUMRN P TIEB1 POH from 23,323' to 22,190' -Pump out at 250 gpm -Pull at 3 min / stand -Mud wt in / out 9.7ppg 4/25/2009 00:00 - 13:00 13.00 DUMRN P TIEB1 POH from 22,190' to 14,217' -Pump out at 250 gpm -Pull at 3 min / stand -Mud wt in / out 9.7ppg 13:00 - 17:00 4.00 DUMRN P TIEB1 14,217' CBU @ 141 spm / 500 gpm / 867 psi / 120 rpm / 12k ft/lbs Tq. / RWT 172k Stand back 1 stand after first bottoms up and continue circulating from 14,121' with same parameters for second bottoms up. First bottoms up showed minimum amount of sand across shakers cleaning up by second bottoms up. Mud wt in / out 9.7 ppg 17:00 - 18:00 1.00 DUMRN P TIEB1 Monitor well, Static. Pump 140 bbl 9.9 ppg NaCI dry job. Install stripping rubbers & air slips 18:00 - 18:30 0.50 DUMRN P TIEB1 POH on elevators from 14,121' to 13,454' Racked back total of 105 stds XT -57 DP Pulling speed 3.5 min / stand 18:30 - 21:30 3.00 DUMRN P TIEB1 PJSM - POH LD XT -57 DP 1x1 from 13,454' to 12,023' Pulling speed 27 ft/min 21:30 - 22:30 1.00 DUMRN P TIEB1 Discrepancy in hole fill. Monitor well for 30 min. well static. Flo -Pro mud aired up. Fill pit with fresh mud & treat system with de- foamer, circulate system to confirm problem resolved. 22:30 - 00:00 1.50 DUMRN P TIEB1 POH LD XT -57 DP 1x1 from 12,023' to 11,355' Pulling speed 27 ft/min 4/26/2009 00:00 - 04:00 4.00 DUMRN P TIEB1 POH LD XT -57 DP 1x1 from 11,355' to 9,751' Pulling speed 27 ft/min Monitored well for 15 min @ 10,265' Static. Printed: 6/3/2009 3:57:48 PM • BP Page 72 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From Code NPT Phase ^ ' ` Description of Operations 4/26/2009 00:00 - 04:0 4.00 DUMRN P TIEB1 04:00 - 04:30 0.50 DUMRN P TIEB1 Change out handling tools to 4-1/2 Monitor well. Static 0*30 20:30 16u0 DUMRN P TIEB1 PO*U}CTm-4oDP1m from 9,751'tom6' Pulling speed 30 ft/min 20:30 21:00 0.50 DUMRN P TIEB1 LD BHA #12 & inspec mills. Both milis showed good indication of dressing Hp on TBR, tattle tail & cut-rite on top dress mill showed good coritact with top of TBR 21:00 22:00 1.00 DUMRN P TIEB1 Clear rig floor of excess drilling tools and PU remaining casing equipment. 22:00 00:00 2.00 CASE P TIEB1 PJSM - RU 6-5/8 Torque Turn casing equipment 4/27/2009 00:00 02o0 2.00 CASE P TIEB1 PJSM RU 6-5/8' Torque Turn casing equipment 02:00 03:00 1.00 CASE P TIEB1 PU / MU 6-5/8" seal assembly to float collar jt. Torque Turn showed tread interference. Break out clean & inspect connections. TIW float collar failed to drift after inspection. Seal assembly in good condition. 03:00 06:30 3.50 CASE N SFAL TIEB1 Mobilize float collar to Baker Machine to drill 5/16" port and dispatch to rig. Inspect, clean 8 drift m5.a7o^ 06:30 07:00 0.58 CASE P TIEB1 Run 8-5/8'2*#HvUm5o1 L-80 scab liner sea assembly &float, . equipment. Seal Assembly /T|YV Flt Collar ,/ 5/16^ port /Jt # 1 slick / Jt # 2 w/ Baker insert landing collar 14^up from pin wNx7-5/8" OD straight blade centralizer locked mid jt betwe n stop rings. Baker lock all connections & torque turn connections to 8,500 m1bu. Pipe filling through ported FC. Top off pipe and checked float. 07:00 00:00 17.00 CASE P TIEB1 Run o'5/8'u4#Hydmou1 L'uo Liner from 11e'too.u4n' Used JLSG thread compound & Torque Turn all connections to 8.5oonmba. Run 1 x 7-5/8" OD straight blade centralizer free floating on Jts # 3-170 Fill every joint run. Running speed 60 1 pm. Break Circulation onJt#1UO4.00a'& pump aubb|o/187gpm/ 92 psi 4/28/200e 00:00 15:00 15.00 CASE P TIEB1 Run s-50' Total n,33eJm.c4# Hydril 521 L,em Liner from 0.840'»o13.345' Used JLSG thread compound & Torque Turn all connections to 8.soom|Uo. Run 1 x 7-5/8" OD straight blade centralizer free floating on Jts #171-228no centralizers onJm#uo7u28 Continue 1 per jt free floating on jts #230-275 Total 273 Centralizer ran. Fill every joint run. Running speed 60 fpm. Printed: 6/3/2009 3.57'48 PM • �� oP Page 73 of 9 Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: To NPT ph����1���� ��� �� �.�/' `' Code ==� -� , �" ' 4/28/2009 00:00 - 15:00 15.00 CASE P TIEB1 Break Circulation on Jt #uoo/u,0ou & pump oubUls/1n gpm / 165 psi Break Circulation on Jt #mm/1�00'& pump 62mbls/1m gpm/225 psi 15%0 17:30 2.50 CASE P TIEB1 Change out handling equipment to 5" PU/MU Baker 8-5/8^x11-3/4^ Flex-Lock liner hanger / HRD ZXP Liner Top Packer Assembly. MU Liner wiper plug & Torque e-5/ ^Hydh|513 oonnemionm 17.000 *Nbo. C/0 elevators to 5-7/8 R|Hw/ liner nn1 std 5-70^oPto1o.4V1' UVVT23Ox/DVVT1uUx 17:30 1e:00 1.50 CASE P TIEB1 Stage Pump rate upto*48gpm/370 psi & circulate 1.nxliner volumes 684 bbls pumped. No Iosses noted. RD Casing equipment while circulating. 19:00 - 00:00 5.00 CASE P TIEB1 RIH with 6-5/ ^|inaron5-70^DPfmm13.491'to18.635' Fill pipe every 10 std run. Note: Obtained Parameters @ 1*.18O' above o-5m^ Liner top No problems entering 8-5/8" liner top @ 14,241' UVYT2*0k/DWT13Oh 4/29/200e 00:00 - 08:30 8.50 CASE P TIEB1 RIH with o'o0' liner onn'70^DP from 16.Ooa'moo.co4' Fill pipe every 10 std run m17.u11' pipe filling on its own through port. Bkoim@oO.o7O'& stage rate upm171gpm/O39psi 08:30 15:30 7.00 CASE P TIEB1 CBU 1.5 times staging pump rate up to 53 spm / 188 gpm / 855 psi UWT 390k / DWT 140k RU Dowell & held PJSM for cementing whUe circulating. 15:30 18:30 1.00 CASE P TIEB1 MU Top Drive cementing head. Pump at 3 bpm / 750 psi and slack off stabbing seal assembly into TBR until pressure increase of 860 psi noted. Stop Pumps. Mark pipe open bleed off aS/O1oo'tnNoGoon top tuo's0" liner @ 23.341'& mark pipe. Pressure upm5Un psi Held. Pull Up3ook holding 400 psi on pipe until pressure drop noted. Pump 3 bpm 750 psi arid PU placing Ports -18' above TOL. S/0 & park pipe in neutral WT 230k 16:30 - 00:00 7.50 CEMT P TIEB1 Switch over to Dowell and pump 5 bbl 10 ppg Mud Push 11. Test cement lines to 5000 p51. good test. Pump 7oUU|o1oppg Mud Push ||@4.oupm. PUMP *82.2xm1xs wag Fxtpnapw/ end cemAm 45 »uu� Printed: 6/3/2009 3.57:48 PM • �� BP Page 74 of 91 Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NAB[)RS ALASKA DRILLING | Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: a� ��ode ��NPT Phase `�,� � 4/28/2009 16:30 00:00 7.50 CEMT P TIEB1 Puma uu.5bUls 15.0 nag Fmonxod Tail Cement *s»pnl Kick out wipe dart with 10 bbls 8.4 ppg sea water Switch over to rig pumps and displace @ 4.5 bpm for 150 bbls. slowed to 2 bpm for next 200 bbls, latch up wiper plug early @ 2482 strokes. Increased rate to 4 bpm for next 244 bbls. At 6900 Strokes pressure started climbing rapidly having to back off on pump rate to maintain pressure below 1650 psi,PU on strirtg 350k and move circ ports up hole with no relief in climbing pressure. By 6960 strokes pumps were down holding 1600 psi with no returns. S/0 & irisert seal assembly bleeding pressure off aliowing assembly to enter TBR. Able to insort seal assembl swallowins all to. seals, assembl 1 1' from No-Go. Pull 130k & Pressure up to 2650 psi to set hanger. S/Omsek& pressure upto30OO psi m release setting tool. 4/302009 00:00 00:30 0.50 CEMT P TIEB1 Bleed off pressure & PU, free from liner 240k PU 8' to expose torque fingers. Rotate uo rpm /1ukTq&G/O Good indication packer set @ ooxG/Otoosx PU and Repeat procedure w/ 60k down. PU to 150k, Stop rotary, & pressure up to 1000 psi. PU holding 1000 psi until seals clear and kick pumps up to 611 gpm 475 psi 00:30 - 01:30 1.00 CEMT P TIEB1 CBU while reciprocating pipe 1n'with 611 gpm 475 psi. Bottoms up showed trace amount Mud Push with pH -11 Continue circulating biozan out of hole 01:30 - 02:30 1.00 CEMT P TIEB1 LD top drive cementing head and double DPI RD blow down cement lines. 02:30 04o0 2.00 CEMT P TIEB1 MU TDS & C8U reciprocating full stand 611 gpm 460 psi while building Dry job. S8] Monitor well, Static. Mud Wt in / out 9.7 ppg Pump Dry job & blow down Top Drive. 04:30 - 12:00 7.50 CEMT P TIEB1 POH from 9883'm Liner running tool & LD same Dog Sub sheared, tool in good condition. 12:00 13:30 1a0 CEMT P TIEB1 PU Top drive cement head, Make service breaks & LD Same. Clean & clear rig floor of vendors tools. 13:30 - 14:30 1.00 BOPSUF P TIEB1 MU BOPE flushing 1001 on 5-7/8 test joint and flush BOP stack. Function tes all rams and repeat flushing ops. LD flushing 1001. 14:30 - 16:00 1.50 BOPSUF P TIEB1 PJSM' Change out top set cV pipe rams ou3-1x`^xo^vnn'n 16:00 - 20:00 4.00 BOPSUF P TIEB1 PJSM - Pull Wear bushing, & RU 5-7/8" Test equipment. Test BOPE as per BP / AOGCC Regulations 10 250 psi Iow / 4500 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Witness of Test Waived by Bob Noble (AOGCC Printed: 6/3/2009 3.57:48 PM • . BP _ Page 75 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/30/2009 16:00 - 20:00 4.00 BOPSUF P TIEB1 State Inspector) Test Witness by Chris Clemens (BP WSL), Kelly Cozby & Brian Tiedemann (NAD Toolpusher), Kenny Sullivan (NAD Driller). Test Recorded on a chart recorder. Test as follows with 5 -7/8" Test Joint. Test as follows with 250 psi / 4500 psi. #1) Top 3.5" x 6" VBR / 5 -7/8" Floor Safety Valve Test as follows with 4" Test Joint. #2) Top 3.5" x 6" VBR / 4" !BOP #3) Bottom 3.5" x 6" VBR / 4" Floor Safety Valve Test as follows with 250 psi / 3500 psi. #4) Annular 250 psi / 3500 psi 20:00 - 21:30 1.50 BOPSUF P TIEB1 RD - Blow down test equipment. Install 10- 13/16" ID Wear Bushing 21:30 - 22:30 1.00 CEMT P TIEB1 Service draw -works & Iron roughneck 22:30 - 00:00 1.50 CEMT P TIEB1 PJSM - PU MU Clean out BHA #13 5 -7/8" Bit / 4 -3/4" Motor w/ Flt / 5 x 4 -3/4" DC's 5/1/2009 00:00 - 01:00 1.00 CEMT P TIEB1 PJSM - PU MU Clean out BHA #13 5 -7/8" Bit / 4 -3/4" Motor w/ Flt / 6 x 4 -3/4" DC's / CCV / Jar / X0 01:00 - 13:30 12.50 CEMT P TIEB1 RIH PU 4" DP 1x1 from 252' to 9,212' Fill pipe every 3000' 13:30 - 14:00 0.50 CEMT P TIEB1 Safety Stand Down with WSL, Toopusher, Rig & G &I crew. Discussed hand safety, hazard recognition & mitigation 14:00 - 23:00 9.00 CEMT P TIEB1 RIH PU 4" DP 1x1 from 9,212' to 16,227' Fill pipe every 3000' Picked up a total of 498 jts 4" 15.7# XT -39 DP Obtain Parameters above 6 -5/8" Liner Top @ 9,976' UWT 152k / DWT 90k 23:00 - 00:00 1.00 CEMT P TIEB1 PSJM - Change out handling equipment to 5 -7/8" MU XO's from 4" to 5 -7/8" 5/2/2009 00:00 - 01:00 1.00 CEMT P TIEB1 Safety Stand Down with WSL, Toopusher, Rig & G &I crew. Discussed hand safety, hazard recognition & mitigation. 01:00 - 03:00 2.00 CEMT P TIEB1 RIH with 5 -7/8" DP from derrick from 16,227' to 18,522' 03:00 - 05:00 2.00 CEMT P TIEB1 PJSM - Slip & Cut 128' drilling line, Service Top Drive, Blocks & Crown 05:00 - 07:30 2.50 CEMT P TIEB1 RIH with 5 -7/8" DP from derrick from 18,522' & tag cement @ 21,065' MU TDS fill pipe & obtain parameters 250 gpm / 2136 psi 50 rpm / 11k ft/Ibs Tq. Printed: 6/3/2009 3:57:48 PM • BP Page 76of91 Operations Summary Repor Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/2/2009 05:00 - 07:30 2.50 CEMT P TIEB1 UWT 290k / DWT 125k / RWT 180k 07:30 - 08:30 1.00 CEMT P TIEB1 PJSM - Test 6 -5/8 scab liner to 3500 psi 162 strokes / 14 bbls with 9.7 ppg mud and hold for 10 min. Test held. Blow down test equipment. 08:30 - 09:30 1.00 CEMT N CEMT TIEB1 Displace well over to 8.6 ppg seawater w/ 1 lb/bbl Biozan. Start drilling on cement after 37 bbls rounded the corner. 09:30 - 12:00 2.50 DRILL N CEMT TIEB1 Drill Liner Wiper Plug @ 21,065' & Cement to 21,076' 215 gpm / 1280 psi 50 rpm / 23k ft/lbs Tq / WOB 15k UWT 290k / DWT 125k / RWT 180k 12:00 - 00:00 12.00 DRILL N CEMT TIEB1 Drill Cement from 21,076' to 21,362' 70 spm / 250 gpm / On Bttm 1670 psi / Off Bttm 1380 psi 70 - 80 rpm / On Bttm 27k ft/lbs Tq / Off Bttm 29k ft/lbs Tq / WOB 15k - 26k UWT 320k / DWT 100k / RWT 174k SPR's @ 21,191'md / 7,937tvd 8.5 ppg MW In / Out #1 24 spm = 460 psi / 35 spm = 680 psi 5/3/2009 00:00 - 12:00 12.00 DRILL N CEMT TIEB1 Drill Hard Cement from 21,362' to 21,580' 70 spm / 250 gpm / On Bttm 1875 psi / Off Bttm 1475 psi 70 - 80 rpm / On Bttm 27k ft/lbs Tq / Off Bttm 29k ft/lbs Tq / WOB 15k - 25k UWT 350k / DWT 100k / RWT 180k ROP's 10 - 30 FPH At 21,518' attempt to drill sliding without success, noted a pressure increase to 2100 psi. PU & started rotating noted erratic torque & weight indicator bobbling, pressure dropped and ROP's increasing to 80 -100 FPH. 12:00 - 19:00 7.00 DRILL N CEMT TIEB1 Drill Hard to Medium Hard Cement from 21,580' to 21,70Q ROP's 80 - 95 FPH Drill Soft Cement from 21,700' to 22,040' ROP's 150 - 300 FPH 70 spm / 250 gpm / On Bttm 1930 psi / Off Bttm 1650 psi 60 - 80 rpm / On Bttm 27 - 29k ft/lbs Tq / Off Bttm 27 - 29k ft/lbs Tq / WOB 5k - 18k UWT 360k / DWT 105k / RWT 180k Torque increasing to 30k ft/lbs until unable to maintain rotation. 19:00 - 21:00 2.00 DRILL N CEMT TIEB1 Circulate and drilled cement from 22,040' to 22,080' while treating mud system for torque,/ Air problems. Mixed & pumped 60 bbl w/ 3 ppg Biozan High Vis Sweep followed by increasing Safe -Lube Concentration to 1.5% in system. Additions of Defoam X to treat aired up surface mud system. 70 spm / 250 gpm / On Bttm 1960 psi / Off Bttm 1675 psi 60 - 80 rpm / On Bttm 30k ft/lbs Tq / Off Bttm 30k ft/lbs Tq / Printed: 6/3/2009 3:57:48 PM • • BP Page 77 of 91 Operations Summary Repor Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/3/2009 19:00 - 21:00 2.00 DRILL N CEMT TIEB1 WOB 5k - 18k UWT 380k / DWT 95 -100k / RWT 185k 21:00 - 00:00 3.00 DRILL N TIEB1 Drill Soft Cement from 22,080' to 22,336' ROP's 150 - 250 FPH 70 spm / 250 gpm / On Bttm 1960 psi / Off Bttm 1655 psi 60 - 70 rpm / On Bttm 28 - 29k ft/Ibs Tq / Off Bttm 27 - 28k ft/lbsTq /WOB10k -14k UWT 380k / DWT 105k / RWT 190k 5/4/2009 00:00 - 09:00 9.00 DRILL N CEMT TIEB1 Drill Soft Cement from 22,336' to 23,250' 70 spm / 250 gpm / On Bttm 2165 psi / Off Bttm 2025 psi 40 - 70 rpm / On Bttm 29 - 30k ft/Ibs Tq / Off Bttm 28 - 29k ft/Ibs Tq / WOB 10k - 15k UWT 420k / DWT 110k / RWT 195k SPR's @ 23,250'md / 8,926tvd 8.7 ppg MW In / Out #1) 24 spm = 490 psi / 35 spm = 810 psi #2) 24 spm = 490 psi / 35 spm = 800 psi 09:00 - 10:30 1.50 DRILL N CEMT TIEB1 Circulate 2 x 6 -5/8 x 4" DP Annular volumes reciprocate pipe 60' 70 spm / 250 gpm / Off Bttm 2145psi 70 rpm / 28k ft/Ibs Tq on down stroke 10:30 - 11:30 1.00 CASE P TIEB1 PJSM - Test 6 -5/8 scab liner to 4200 psi with 8.7 ppq mud and, hold for 10 min. Test held. Blow down test equipment. 11:30 - 14:00 2.50 DRILL P TIEB1 Drill Cement from 23 250' to LC @ 23 282' FC @ 23,325, Drill cement to 23'340' where cement cleared up. Took Wt @ 23,355' Ream down to 23,358' the RIH without pumps to 23,381' 70 spm / 250 gpm / On Bttm 2165 psi / Off Bttm 2025 psi 60 rpm / On Bttm 28k ft/Ibs Tq / Off Bttm 28k ft/lbs Tq / WOB 10k - 15k UWT 400k / DWT 90k / RWT 200k 14:00 - 15:00 1.00 CASE P TIEB1 RIH from 23,381 to 23,569' 15:00 - 16:00 1.00 CASE N DPRB TIEB1 PJSM - Test 6 -5/8 scab liner with 8.7 ppq mud pressure upt to 2580 psi. 210 stsk pumped to 216 storkes with no pressure increase. Monitor pressure 15 min. bleed down to 2200 psi. Bleed off pressure and monitor, flowinc�gained 3.1 bbl min. Shut in well. Made notifications to State inspector Bob Noble (AOGCC) 16:00 - 20:00 4.00 CASE N DPRB TIEB1 Monitor pressure for 30 min SIDDP = 0 psi / SICP = 180 psi Fill DP & bump open float. & Monitor Pressures & Weight up 1965 bbl Flo -Pro system between Rig & G &I to 9.7 ppg SIDDP = 270 psi / SICP = 230 psi 20:00 - 21:00 1.00 CASE N RREP TIEB1 EPOCH - PVT System down. Re- calibrate & check Printed: 6/3/2009 3:57:48 PM • • BP Page 78 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/4/2009 20:00 - 21:00 1.00 CASE N RREP TIEB1 Held PJSM on well kill operations while bringing PVT up. 21:00 - 00:00 3.00 CASE N DPRB TIEB1 Bring pumps up to 5 bpm / 58 spm = ICP 1920 psi. Holding FCP © 2060 psi. & pump 795 bbl kill weight fluid © 00:00 hrs 5/5/2009 00:00 - 02:00 2.00 CASE N DPRB TIEB1 Bring pumps up to 5 bpm / 58 spm = ICP 1920 psi. Holding FCP © 2060 psi. & pump 1407 bbl kill weight fluid pumped when 9.6+ ppg back to surface pumped total of 17095 stks © 02:10 hrs 02:00 - 02:45 0.75 CASE N DPRB TIEB1 Monitor pressure on closed choke 15 min. SIDPP = 0 / CICP =20. Open choke and monitor for returns, No returns. Open well and monitor well 10 min, trickle going down flow line. Blow down kill and Choke line and manifold. 02:45 - 03:30 0.75 CASE N DPRB TIEB1 Obtain SPR's #1) 24 spm - 620 psi / 36 spm - 850 psi / 58 spm - 1590 spm Continue to circulate until mud wt 9.6+ in / out 03:30 - 07:30 4.00 CASE N DPRB TIEB1 Monitor well, well static for 12 mins then started trickling down the flow line. Resume Circulation for bottoms up. -70 spm / 250 gpm / 2082 psi -380k PUW / 120k SOW / 190k RtWt 9.7 ppg Mud Wt In /Out -Well Static 07:30 - 09:00 1.50 FISH P TIEB1 RIH and Tag Up on CIBP at 25,522' and -550k PUW / 125k SOW 09:00 - 09:30 0.50 FISH P TIEB1 Circulate and Condition Mud -70 spm / 250 gpm / 2082 psi -550k PUW / 125k SOW Unable to rotate with a Torque Limit of 32k ft/lbs max. 09:30 - 10:00 0.50 CASE P TIEB1 Test Casing - Attempt to test casing and liner lap, Test Fail - Pressure up to 2300 psi, Bleed down to 1830 psi after 10 minutes 10:00 - 12:00 2.00 CASE P TIEB1 Tag up on CIBP with 20k down -Test to 2340 psi pressure bleed to 1790 psi in 10 minutes - Monitor Well, Static 12:00 - 17:00 5.00 FISH N WAIT TIEB1 Wait on Orders - Consult with Anchorage Rig team on Plan Forward - Circulate and Condition Mud while waiting -93 gpm / 797 psi/ 26 spm - Unable to rotate with Torque Limit set to 34k Max Torque 17:00 - 19:30 2.50 FISH N WAIT TIEB1 Continue to Wait on Forward plan - Brought circulation rate up to 250 gpm / 70 spm / 2263 psi - Conditioned Flopro with 0.5 ppb Flovis for LSRV= 15 -20K cP 19:30 - 20:00 0.50 FISH P TIEB1 Circulate and Condition Drilling Fluid - Pumped 80 bbls 10% Steel Lube EP to reduce metal to metal Printed: 6/3/2009 3:57:48 PM • • BP Page 79of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/5/2009 19:30 - 20:00 0.50 FISH P TIEB1 friction. 20:00 - 22:00 2.00 FISH P TIEB1 Circulate and Condition Drilling Fluids -spot lube in 6 5/8" liner annulus Before Lube pill -470 PUW / 140k SOW -Only able to rotate coming down at 30 ft/min with 32k torque Limit -69 spm / 250 gpm / 2360 psi After Lube pill 387k PUW / 170k SOW / RtWt 222k -able to rotate with movement with 27 -29k ft/Ibs of Torque 22:00 - 00:00 2.00 FISH P TIEB1 Establish Drilling Parameters for Drilling CIBP - Perform Slow Pump Rate @ 25,454 and MW 9.7 In /Out -2 bpm #1 = 1020 psi / #2 = 970si -5 bpm #1 = 2100 psi / #2 = 2050 psi -243 gpm / 70 spm / 2630 psi / 20% flow -60 rpm / 26 -29k Tq off / 29 -32 Tq Down -387k PUW / 170k SOW / 222k RtWt RIH and Tag CIBP on depth at 25,521.6 ft drill Oa measurement Start Drilling on plug with minumum weight as possible -Delta pressure on mud motor 75 - 150 psi 5/6/2009 00:00 - 01:30 1.50 FISH P TIEB1 Continue Drilling on plug with minimum weight as possible 25,521 - 25,523' and -Delta pressure on mud motor 75 - 150 psi -2 -4k WOB -243 gpm / 70 spm / 2630 psi / 20% flow -60 rpm / 26 -29k Tq off / 29 -32 Tq Down -387k PUW / 170k SOW / 222k RtWt 25,531 - 25,526' and -Delta pressure on mud motor 75 - 150 psi -2 -4k WOB -243 gpm / 70 spm / 2350 psi / 20% flow -60 rpm / 26 -29k Tq off / 29 -32 Tq Down -420k PUW / 170k SOW / 218k RtWt -7 stalls while drilling plug Drill to 25,526.4 ' and was able to push plug down -Push plug to 25,565' and with out pump or rotary - Monitor well for 10 minutes, static 9.7 ppg In / Out 01:30 - 05:00 3.50 FISH P TIEB1 Circulate Bottoms Up -No gas seen at bottoms up -70 spm / 250 gpm Printed: 6/3/2009 3:57:48 PM • • BP Page 80 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/6/2009 01:30 - 05:00 3.50 FISH P TIEB1 - Pressure increased from 2250 psi to 3200 psi from 3500 strokes to 7000 strokes then decrease back to 2280 psi at bottoms up -Small amount of fine metal filings seen on shakers during CBU Monitor well two times during CBU, well static with just a few bubbles at flow line -420k puw / 225k RtWt -60 rpm / / 29k torque - Perform Slow Pump Rate @ 26,090 and MW 9.7 In /Out -2 bpm #1 = 1020 psi / #2 = 970si -5 bpm #1 = 2100 psi / #2 = 2050 psi Monitor well for 10 minutes, Static 9.7 ppg In /Out 05:00 - 05:30 0.50 FISH P TIEB1 Push the Remainder of Bridge Plug to Bottom -No Issues going to bottom 05:30 - 08:30 3.00 FISH P TIEB1 Circulate Bottoms Up -70 spm / 250 gpm / ICP =2002 psi FCP =1650 psi -70 rpm / 29 -30k ft/Ibs of Tq No indication of gas or oil on bottoms up Monitor well for 10 minutes, Static 9.7 ppg In /Out 08:30 - 10:00 1.50 FISH P TIEB1 Pumped 100 bbl High Temp pill - Displace till 5 bbls of pill out of bit in open hole. -Pill consisted of 100 bbls FloPro Mud with 1 ppb PST -200, 2% Lube 776, and 1 ppb Flovis Plus 10:00 - 12:00 2.00 FISH P TIEB1 POH - pumping at 1.5 bbl / min 17 spm 382 psi -3 min / stand -PUW = 500k 12:00 - 14:00 2.00 FISH P TIEB1 Continue POH - pumping at 1.5 bbl / min 17 spm 382 psi -3 min / stand 14:00 - 15:00 1.00 FISH N DFAL TIEB1 Found washout in the middle joint of stand #21, Washout located between the bottom of the top slider clamp and the top of the bottom slider clamp. Clamp and Drill Pipe damaged from washout. UD 3 joints, all of stand # 250 15:00 - 00:00 9.00 FISH N TIEB1 Continue POH -@ 15:10 Drop ball to open CCV , 200 gpm = 2700 with ball not on seat Continue POH - pumping at 1.5 bbl / min presures varied from 870 psi to 1420 psi at 1.5 bpm - Pulled @ 3 min / stand -@ 18:20 Ball landed on seat, slowly increase pressure to 3500 psi and CCV open Printed: 6/3/2009 3:57:48 PM • 1 BP Page 81 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/6/2009 15:00 - 00:00 9.00 FISH N TIEB1 -200 gpm / 1340 psi 1360 psi less than before dropping ball Continue POH to 17,950' and - pumping at 1.5 bbl / min pressures ranged from 520 psi to 580 psi - Pulled @ 3 min / stand 5/7/2009 00:00 - 03:30 3.50 FISH P TIEB1 Continue POH to 16,227' and - pumping at 1.5 bbl / min - Pulled @ 3 min / stand 03:30 - 06:00 2.50 FISH P TIEB1 Change over Saver Sub on Top Drive to XT39 06:00 - 12:00 6.00 FISH P TIEB1 Continue POH - pumping at 1.5 bbl / min - Pulled @ 3 min / stand 12:00 - 18:30 6.50 FISH P TIEB1 Continue POH - pumping at 1.5 bbl / min - Pulled @ 3 min / stand 18:30 - 20:30 2.00 FISH P TIEB1 Slip and Cut Drilling Line - Service Rig, Draw Works, Top Drive and Crown 20:30 - 21:00 0.50 DHB P TIEB1 Set HES Storm Packer -Make u HES RTTS with Storm Valve and Hang off string at 102' below RKB - Pressure Test Packer to 1000 psi for 5 minutes, good test 21:00 - 00:00 3.00 BOPSUF P TIEB1 Rig up to Test BOP's -Flush Stack & Function Rams -Pull Wear Bushing -Blow Down Top Drive -Make up 4" Test Joint, Test Plug and Test Equipment 5/8/2009 00:00 - 10:00 10.00 BOPSUF P TIEB1 Test BOPE as per BP / AOGCC Regulations�o 250 psi low / 4500 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Witnessed of test waived by John Crisp (AOGCC State Inspector) Test Witnessed by Dave Newton and Brian Buzby (BP WSL), Brian Tiedemann and Bill Bixby(NAD Toolpusher), Kelly Haug (NAD Driller). Test Recorded on a chart recorder. Test as follows with 4"" Test Joint. Test 250 psi Low / 4500 psi High #1) Top 3.5" x 6" VBR / 4" IBOP / Choke Valves # 9, 12 & 13 / Kill Line & Dart Valve #2) 4" Floor Safety Valve / Kill HCR / Choke Valves # 8 & 11 #3) Choke Valves # 4, 7, & 10 #4) Choke Valve # 3 -5 -6 / Manual Kill Line Valve #5) Super Choke & Manual Choke Manifold Valves 250 low & 1500 psi high #6) Choke Valve #1, 3 & 5 #7) Choke Valve #2, #8) Choke HCR Valve #9) Manual Choke Line Valve on stack / Upper Top Drive Well Control Valve (fail) #10) Bottom 3.5" x 6" VBR / Lower IBOP #11)Annular 250 psi / 3500 psi #12) Accumulator Function / Draw Down Test Printed: 6/3/2009 3:57:48 PM • • BP Page 82 of 91 Operat Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/8/2009 00:00 - 10:00 10.00 BOPSUF P TIEB1 Change out Test equipment to 5 7/8" Test as follows with 5 7/8" Test Joint. #13) Lower 3.5" x 6" VBR / 5 7/8" Floor Dart Valve #14) Uppewr 3.5" x 6" VBR / 5 7/8" Top Drive Lower IBOP #15) Blind Shear Rams *Retested XT39 Upper Top Drive Well Control Valve - Pass 10:00 - 12:00 2.00 BOPSUF P TIEB1 Rig Down Test Equipment and Install Wear Bushing 12:00 - 13:30 1.50 DHB P TIEB1 Retrieve HES Strom Packer -M /U Retrieving tool -RIH with 1 stand -Screw into tool and check for pressure below packer, Zero Pressure - Release tool and pull to ri floor -UD Storm Packer 13:30 - 14:30 1.00 FISH P TIEB1 RIH and Place Circ. Valve at Top of 6 5/8" Liner 14:30 - 20:00 5.50 FISH P TIEB1 Circulate cutting out of 11 3/4" casing -710 gpm / 2475 psi -40 rpm / 5k ft/lbs of Torque Moderate to heavy cement & metal cuttings on first bottoms up. Second bottoms up cutting reduce by 30 %, increase to 750 gpm / 2540 psi, 45 rpm / 7k Tq. Third Bottoms up, cuttings 10 -20% of volume from orginal bottoms up. Circulate till shakers light to zero cuttings 20:00 - 20:30 0.50 FISH P TIEB1 Monitor Well, Static 9.7 MW In / Out -Pump 50 bbl Dry Job and Blow down Top Drive 20:30 - 00:00 3.50 FISH P TIEB1 POH 9685 - 7379' and - pulling at 5 min / stand, Pulling wet, - Attempt 2nd 50 bbl Dry job, No Joy, still pulling wet 5/9/2009 00:00 - 05:00 5.00 FISH P TIEB1 POH 7379' - 4008' and - pulling at 5 min / stand 05:00 - 13:00 8.00 FISH P TIEB1 Lay Down 4" Drill Pipe - pulling at 20' /min 13:00 - 16:30 3.50 FISH P TIEB1 UD BHA and Clear Floor of third party equipment -CCV ball was stuck in CCV -Bit Grade 7- 3- JD- 0- X- IN -PN -TD Nozzle was plugged with cement 16:30 - 17:30 1.00 CASE P RUNPRD Service Rig - Service Draw Works, Crown and Top Drive 17:30 - 18:30 1.00 CASE P RUNPRD Rig Up To Run Production Liner -PJSM with all personnel involved in the operation -Make Power Tongs, Elevators and Torque Turn Equipment 18:30 - 00:00 5.50 CASE P RUNPRD Run 4 1/2" 12.6# Vam Top 13Cr 80 Production Liner - Torque Turn Connection, -4440 ft/lbs make up torque -Jet Lube Thread Dope -PJSM with all personnel involved in the operation, NAD Rig Crew, NAD TP, BP WSL, Vam Techs, and Baker Techs 5/10/2009 00:00 - 03:00 3.00 CASE P RUNPRD Run 4 1/2" 12.6# Vam Top 13Cr 80 Production Liner - Torque Turn Connection, Printed: 6/3/2009 3:57:48 PM • . BP Page 83 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/10/2009 00:00 - 03:00 3.00 CASE P RUNPRD -4440 ft/lbs make up torque -Jet Lube Thread Dope 03:00 - 07:00 4.00 CASE P RUNPRD Make Up Inner String -PJSM with all personnel involved in the operation -Rig Up Handling Equipment -Pick up Anadrill Slim Pulse MWD, XO's, 15 jts of 2 3/8" STL Pipe, X/Os - Torque Turn Connections 07:00 - 08:00 1.00 CASE P RUNPRD Make 4.50" x 6.63" FlexLock Hanger and 4.50" x 6.63 "HRD ZXP Liner Top Packer and running tools -Mix and Install "PAL" Mix and let set up for 30 minutes -Rig Down Handling equipment 08:00 - 08:30 0.50 CASE P RUNPRD RIH with 3 joints of 4" drill pipe and shallow hole test MWD -100 gpm / 320 psi, good test 08:30 - 11:00 2.50 CASE P RUNPRD Pick up 36 jts of 4" from pipe shed - Running speed at 95' /min 11:00 - 12:00 1.00 CASE P RUNPRD RIH with 4 1/2" Production Liner - Running Speed of 1 min / stand -Fill Pipe every 10 stands - Record up and down weights every 10 stands 12:00 - 00:00 12.00 CASE P RUNPRD RIH with 4 1/2" Production Liner - Running Speed of 1 min / stand till TOP of 6 5/8" Liner Running Speed in 6 5/8" Liner at 20' /min -Fill Pipe every 10 stands - Record up and down weights every 10 stands -Test Mwd at 6000' and 12,000', good test 5/11/2009 00:00 - 01:00 1.00 CASE P RUNPRD RIH with 4 1/2" Production Liner Running Speed in 6 5/8" Liner at 20' /min -Fill Pipe every 10 stands - Record up and down weights every 10 stands 01:00 - 03:30 2.50 CASE P RUNPRD Change over Top Drive to XT57 Saver Sub -PJSM before operation -Test connections to 4000 psi, good test 03:30 - 04:00 0.50 CASE P RUNPRD Service Draw Works, Crown and Top Drive 04:00 - 12:00 8.00 CASE P RUNPRD RIH with 4 1/2" Production Liner to 21,006 Running Speed in 6 5/8" Liner at 20' /min -Fill Pipe every 10 stands - Record up and down weights every 10 stands 12:00 - 19:00 7.00 CASE P RUNPRD RIH with 4 1/2" Production Liner to 25,582 and Running Speed in 6 5/8" Liner at 20' /min -Fill Pipe every 10 stands - Record up and down weights every 10 stands 19:00 - 19:30 0.50 CASE P RUNPRD RIH with 4 1/2" Production Liner in open hole to 25,945 Running Speed at 20' /min No Issues Running Into bottom 430k PUW / 150k SOW Break Circulation on the Last Stand 42 gpm / 845 psi 19:30 - 23:30 4.00 EVAL P RUNPRD Mad Pass Log to Correlate Liner -121 gpm / 1305 psi -Log f/25,930 - 25,870 at 30 fph 23:30 - 00:00 0.50 EVAL P RUNPRD Make +9' correction and re -log -121 gpm / 1305 psi -Log 25,915 - 25,890 Original String MD Printed: 6/3/2009 3:57:48 PM • BP Page 84 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/11/2009 23:30 - 00:00 0.50 EVAL P RUNPRD 5/12/2009 00:00 - 01:30 1.50 EVAL P RUNPRD Make +9' correction and re -log -121 gpm / 1305 psi -Log 25,915 - 25,890 Original String MD Start weighting up to 9.9 ppg 01:30 - 10:00 8.50 CASE P RUNPRD Circulate and Condition Flo -Pro bring mud wt up to 9.9 ppg -121 gpm / 1350 psi 10:00 - 11:00 1.00 CASE P RUNPRD SPOT LVT in drill String - Install TIW valve to drop wiper dart -Pump 82 bbl of LVT Mineral Oil -107 gpm / 1435 psi 11:00 - 14:30 3.50 CASE P RUNPRD Set 4 1/2" Production Liner Hanger and Packer -PUW 444k / SOW 162k -Drop Dart and Displace to landing seat at 143 gpm / 1787 psi -Pump to calculated strokes to bump with no indication plug landing, - increase pump rate to 457 gpm / 3960 psi -Slack Off to 95k to set hanger, P/U to 440 k, Hanger did not release, Slack off 162k -Start Pumping at an increase pump rate to simulate the desired pressure, 430 spm / 4357 psi -Slack off to 90k, Pick up to 435k, while pumping at 89 gpm -Slack off to 112k and Initiate Left Hand Release with a max torque setting of 3500 ft/Ibs torque, - During the emergency release operation , Dart Landed - Pressure up to 4000 psi and set Packer ** *Calculated a minimum of 42 bbls of LVT outside the 4 1/2" Liner below ZXP Packer 14:30 - 15:00 0.50 CASE P RUNPRD Test 6 5/8" Liner and 11 3/4" casing to 3400 psi for 30 min. Chart Test -Good Test, Pressure bleed off 60 psi for the first 15 minutes and 20 psi the second 15 minutes 15:00 - 18:30 3.50 CASE P RUNPRD CBU -400 gpm / 3030 psi -395k PUW -Spot High Temp Flo -Pro Pill at Top of 4 1/2" Liner (covering the bottom 500' of the 6 5/8" Liner) Monitor well, Static 9.9 MW in & Out 18:30 - 00:00 5.50 CASE P RUNPRD POH - pumping at 1.5 bbl / min - Pulled @ 3 min / stand 5/13/2009 00:00 - 11:00 11.00 CASE P RUNPRD POH 22,473 - 14,628' and (standing back in the derrick) - pumping at 1.5 bbl / min - Pulled @ 3 min / stand 14,628 seem a 20k overpull and a slight increase in pump pressure, Slacked off and pull through without issues. 11:00 - 13:30 2.50 CASE P RUNPRD Circulate and Condition Mud -Raise Mud Wt to 9.9 to compensate for LVT -411 gpm / 2466 psi Printed: 6/3/2009 3:57:48 PM • • BP Page 85 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/13/2009 13:30 - 14:00 0.50 CASE P RUNPRD POH 1 stand to 14,560' and - pumping at 1.5 bbl / min - Pulled @ 3 min / stand Encoder Failed on TDS 14:00 - 15:00 1.00 CASE N RREP RUNPRD Encoder Failed on the torque function of the TOP Drive Change out encoder and function test -PJSM perform with NAD Personnel 15:00 - 16:30 1.50 CASE P RUNPRD POH to 4" Drill Pipe - pumping at 1.5 bbl / min - Pulled @ 3 min / stand 16:30 - 18:00 1.50 CASE P RUNPRD Change over to XT39 on Top Drive -PJSM with Rig Crew 18:00 - 19:30 1.50 CASE P RUNPRD POH to 13,045' and (standing back in the derrick) - pumping at 1.5 bbl / min - Pulled @ 3 min / stand 19:30 - 20:00 0.50 CASE P RUNPRD Pump 9.9 ppg weighted brine down Drill pipe for a dry job -284 gpm / 1176 psi 20:00 - 0.00 CASE P RUNPRD POH Laying Down 4" Drill Pipe 1 x 1 - Experience intermittent 10k overpulls 13,010 md - 12,290' -Pipe pulling dry 5/14/2009 00:00 - 08:00 8.00 CASE P RUNPRD POH Laying Down 4" Drill Pipe 1 x 1 -Pipe pulling dry - Pulling Pipe @ 32' /min till 6 5/8 Liner - Pulled at 90' /min in the 11 3/4" casing 08:00 - 08:30 0.50 CASE P RUNPRD RIH with the 9 stands of 4" from the derrick 08:30 - 11:00 2.50 CASE P RUNPRD POH Laying Down 4" Drill Pipe 1 x 1 -Pipe pulling dry - Pulled at 90' /min in the 11 3/4" casing 11:00 - 12:30 1.50 CASE P RUNPRD Lay Down Liner Running Tool. -The bottom set of PBR seals was missing off the bottom of the PBR Packoff - Missing seals have two teflon seals and apx 3.5" of 12 black "V" seals and 1 0 Ring No other visible damage to Running Tool 12:30 - 15:30 3.00 CASE P D Lay Down Inner String 15:30 - 16:00 0.50 CASE P RUNPRD Rig Down Handling Tools for the 2 3/8" SLT tubing 16:00 - 17:30 1.50 CASE P RUNPRD Change over the Top Drive to XT 57 17:30 - 00:00 6.50 CASE P RUNPRD Make Up 4" Mule Shoe, 1 Stand of 4" XT39, XO's -RIH with all the 5 7/8" Drill Pipe in the derrick -RIH at 95' /min 5/15/2009 00:00 - 04:30 4.50 CASE P RUNPRD Wash through Top of 6 5/8" Liner easy -34' inside Liner - Circulate at 212 SPM / 753 gpm -160 rpm / 13k ft/lbs torque for the first two bottoms up - Reduce rpm to 110 rm / 9k ft/lbs for the remaining circ time First Bottoms Up showed 75% coverage on the shaker screens with cement cutting's Second bottoms up showed 20% sccreen coverage with fine to very fine cuttings Third bottom up showed 5% screen coverage with fine cuttings Printed: 6/3 /2009 3:57:48 PM Bp Page 86of91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/15/2009 00:00 - 04:30 4.50 CASE P RUNPRD Fourth bottoms up showing small amount of cutting's Fifth Bottom up Very Little to No Cuttings coming across Shakers 04:30 - 06:00 1.50 CASE P RUNPRD Pull up above 6 5/8" Liner - Service Top Drive, Draw Works and Crown 06:00 - 07:30 1.50 CASE P RUNPRD Slip and Cut Drilling Line 07:30 - 10:00 2.50 CASE P RUNPRD Circulate above 6 5/8" Liner -400 gpm / 285 psi -Pump 100 bbls of clean 9.9 brine down pipe for a dry job - Monitor Well, Static 9.9ppg In & Out 10:00 - 11:30 1.50 CASE P RUNPRD POH Laying Down 5 7/8" Drill Pipe - Removing Super Sliders, 2 per joint PJSM with NAD and WWT Tool Hand on removing Super Sliders 11:30 - 14:00 2.50 CASE N RREP RUNPRD Lost Rig Power due to faulty Gas Sensor 14:00 - 00:00 10.00 CASE N RUNPRD POH Laying Down 5 7/8" Drill Pipe From 9694 - 6426' and - Removing Super Sliders, 2 per joint 5/16/2009 00:00 - 04:30 4.50 CASE P RUNPRD POH Laying Down 5 7/8" Drill Pipe From 6426' - 4400' and - Removing Super Sliders, 2 per joint 04:30 - 10:00 5.50 CASE P RUNPRD POH Laying Down 5 7/8" Drill Pipe From 4400' - 100' -No Super Sliders 10:00 - 11:00 1.00 CASE P RUNPRD Lay down 3 joints of 4" Drill Pipe and Mule Shoe -Clear Floor of Excess Equipment 11:00 - 13:00 2.00 RUNCOMP RUNCMP Change out Top Drive Saver Sub to 4 1/2" IF Connection -Ready Rig Floor for running completion equipment 13:00 - 14:00 1.00 BOPSUF P RUNCMP Flush Stack, Pull Wear Bushing and Make Dummy Run with Tubing Hanger 14:00 - 18:00 4.00 RUNCOMP RUNCMP Rig Up to Run 4 1/2" Chrome Tubing Completion -R/U Double Stack Tongs -R /U Compensator, Elevators -R/U Computer Torque Turn System -Rig Up Stabbing Board -P /U all Crossovers and misc. equipment Pre -Job Safety Meeting With NAD Drilling Crew, Casing Crew, Baker Production Hands, NAD Toolpusher and BP WSL 18:00 - 00:00 6.00 RUNCOMP RUNCMP Run 4 1/2" #12,6/ft 13cr80 VamTop Chrome Completion Make up -Seal Assembly, -4 x jts of Chrome 3 1/2" STL Tail Pipe, -XO, -1 jt 4.5" 12.6# Vam Top 13Cr -80 Tubing -4 1/2" Pup Jt, XN " Nipple, 4 1/2" Pup Jt -2 jts 4.5" 12.6# Vam Top 13Cr -80 Tubing -4 1/2" Pup Jt, X " Nipple, 4 1/2" Pup Jt - 56 x 4.5" 12.6# Vam Top 13Cr -80 Tubing Torque Turn all STL and Vam Top connection Printed: 6/3/2009 3:57:48 PM • • BP Page 87 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To H ours Task Code NPT Phase Description of Operations 5/16/2009 18:00 - 00:00 6.00 RUNCO P RUNCMP Baker -lock all connections between lower XN nipple assembly and seal assembly Use Jet Lube Seal Guard on all connections 3 1/2 9.2# STL make -up torque 1600 ft-lbs 4 1/2 12.6 #, 13Cr80 Vam Top make -up torque is 4440 ft-lbs Vam Thread Inspector verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at All Times 5/17/2009 00:00 - 11:30 11.50 RUNCO RUNCMP Run 4 1/2" #12,6/ft 13cr80 VamTop Chrome Completion -A Total of 233 jts of 4.5" 12.6# Vam Top 13Cr -80 Tubing Torque Turn all STL and Vam Top connection Baker -lock all connections between lower XN nipple assembly and seal assembly Use Jet Lube Seal Guard on all connections 4 1/2 12.6 #, 13Cr80 Vam Top make -up torque is 4440 ft-Ibs Vam Thread Inspector verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at All Times 11:30 - 14:00 2.50 RUNCO P RUNCMP Circulate Bottoms Up 2x -200 spm / 700 gpm / 1645 psi Up Wt without pumps - 108k Dn Wt without pumps - 75k No cuttings seen a shakers 14:00 - 22:00 8.00 RUNCO RUNCMP Run 4 1/2" #12,6/ft 13cr80 VamTop Chrome Completion -A Total of 354 jts of 4.5" 12.6# Vam Top 13Cr -80 Tubing - Encounter 5 -10k down drag every 40 - 42' from 10,150' to 10,850' when first tbg collar enter liner top at 9,976' Torque Turn all STL and Vam Top connection Baker -lock all connections between lower XN nipple assembly and seal assembly Use Jet Lube Seal Guard on all connections 4 1/2 12.6 #, 13Cr80 Vam Top make -up torque is 4440 ft-Ibs Vam Thread Inspector verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at All Times 22:00 - 23:30 1.50 RUNCO P RUNCMP Circulate two times the 4 1/2" x 6 5/8" volume - Circulate @ 225 gpm / 600 psi -1700 Total Strokes Circulated Nothing seen at shakers Up Wt without pumps - 150k Dn Wt without pumps - 80k 23:30 - 00:00 0.50 RUNCO P RUNCMP Run 4 1/2" #12,6/ft 13cr80 VamTop Chrome Completion -A Total of 364 jts of 4.5" 12.6# Vam Top 13Cr -80 Tubing Torque Turn all STL and Vam Top connection Baker -lock all connections between lower XN nipple assembly and seal assembly Use Jet Lube Seal Guard on all connections 4 1/2 12.6 #, 13Cr80 Vam Top make -up torque is 4440 ft -Ibs Printed: 6/3/2009 3:57:48 PM • • BP Page 88 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/17/2009 23:30 - 00:00 0.50 RUNCOMP RUNCMP Vam Thread Inspector verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at All Times 5/18/2009 00:00 - 03:00 3.00 RUNCOMP RUNCMP Run 4 1/2" #12,6/ft 13cr80 VamTop Chrome Completion -A Total of 408 jts of 4.5" 12.6# Vam Top 13Cr -80 Tubing Torque Turn Vam Top connection Use Jet Lube Seal Guard on all connections 4 1/2 12.6 #, 13Cr80 Vam Top make -up torque is 4440 ft-Ibs Vam Thread Inspector verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at All Times 03:00 - 04:00 1.00 RUNCOMP RUNCMP Run 4 1/2" #12,6/ft 13cr95 VamTop Chrome Completion -A Total of 2 jts of 4.5" 12.6# Vam Top 13Cr- 95Tubing Torque Turn Vam Top connection Use Jet Lube Seal Guard on all connections 4 1/2 12.6 #, 13Cr95 Vam Top make -up torque is 4820 ft -Ibs Vam Thread Inspector verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at All Times Double Stack tongs having a difficult time in making up 13cr95 pipe smoothly - Change Dies and still having some issues with the tong die grip 04:00 - 05:00 1.00 RUNCOMP RUNCMP Change Out Double Stack Tongs -PJSM on picking up the larger set of double stack tong - Larger set has a larger gripping area 05:00 - 12:00 7.00 RUNCOMP RUNCMP Run 4 1/2" #12,6/ft 13cr95 VamTop Chrome Completion -A Total of 66 jts of 4.5" 12.6# Vam Top 13Cr- 95Tubing Torque Turn Vam Top connection Use Jet Lube Seal Guard on all connections 4 1/2 12.6 #, 13Cr95 Vam Top make -up torque is 4820 ft-Ibs Vam Thread Inspector verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at All Times 12:00 - 13:00 1.00 RUNCOMP RUNCMP Rig up 200 Ton Elevators and Handling equipment 13:00 - 14:00 1.00 RUNCOMP RUNCMP Rig up head pin and circulate 2x 6 5/8 x 4 1/2" liner volumes -56 spm / 200 gpm / 825 psi -180k PUX / 80k SOW 14:00 - 21:00 7.00 RUNCOMP RUNCMP Run 4 1/2" #12,6/ft & 13.5# 13cr95 VamTop Chrome Completion -A Total of 116 jts of 4.5" 12.6# Vam Top 13Cr- 95Tubing and -Total of 3 jts of 4.5" 13.5# Vam Top 13Cr -95 Tubing Torque Turn Vam Top connection Use Jet Lube Seal Guard on all connections 4 1/2 12.6 #, 13Cr95 Vam Top make -up torque is 4820 ft-lbs 4 1/2 13.5 #, 13Cr95 Vam Top make -up torque is 5360 ft-lb Vam Thread Inspector verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at All Times Printed: 6/3/2009 3:57:48 PM • �� �� �� �� �� BP p age 89 o f 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING | Rig Release. 5/20/2009 Rig Name: NABORS 33E Rig Number: Description of Operations Date From Hours Task pT Code �wN Phase 5/18/2009 14:00 21:00 7.00 RUNCOMP RUNCMP Extra Care needed to insure Slips and Dies are biting on the 13cr95 Chrome Pipe 21:00 - 22:00 1.00 RUNCOMP RUNCMP PJSM on Rigging up to Run SSSV with NAD Rig Crew, NAD Toolpusher, BP WSL and HES SSSV Tec h -R/U Control line Sheave and Surface Equipmen t -Attach Line to SSSV -Test to 6000 psi fo 30 min, Good Test 22:00 - 00:00 2.00 RUNCOMP RUNCMP Run 41/u^ 13.5# 13cr95 VamTop Chrome Completion with Control line -Total of 12 jts of 4.5^13.5# Vann Top 1oC,e5Tubing -Install Cannon clamps on each jt Torque Turn Vam Top connection Use Jet Lubo Seal Guard on000nne�i U ono 41/213a�.13C,onVam Top make-up torque ios30Uh'|bo VamThmadmopecm, verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at Alt Times Extra Care needed to insure Slips and Dies are biting on the 13cr95 Chrome Pipe 5/19/2009 00:00 - 01:30 1.50 RUNCOMP RUNCMP Run 41/2^ 13.5# 13ore5 VamTop Chrome Completion with Control line -Total of 23 jts of *.o^1o.o#Vam Top 1oC,yaTubing -Install Cannon clamps on each jt Torque Turn Vam Top corinection Use Jet LuUo Seal Guard nnaoonnoun all connections 41/213�s�.13Cno ovam Top make-up mnquoioo38Uh'|Uu VamThmaUopamor verify thread condition and proper application of thread compound Baker Production Hand on the Rig Floor at Alt Times Extra Care needed to insure Slips and Dies are biting on the 13cr95 Chrome Pipe 01:30 - 02:00 0.50 RUNCOMP RUNCMP Rig up head pin to spot 100 bbl Lube Pill 02:00 04:30 2.50 RUNCOMP RUNCMP Pump 100 barrels of 9.9 ppg Flo-Pro with 10% Steel Lube EP 'uoogpm / 1030 psi 04:30 05o0 0.50 RUNCOMP RUNCMP Rig Down Circ Pin and Rig up to Circulate with Joint #140 of the 13cr95 05:00 - 05:30 0.50 RUNCOMP RUNCMP Wash Joint #140 down �wmvxDown v|mwyat1bpm|ooNng for the seals menter PBR -11 opm/*ugpm/4sopsi /wu31oo'mu PUW 200k SOW - 90k with pump PUW - 205k SOW - 85k without pumps 05:30 - 06:30 1o0 RUNCONP RUNCMP Wash Joint #141 down -Wash Down slowly at 1 bpm looking for the seals to enter_ PBR -11 upm/4egpnV45opsi /wuu1m7md PUW - 200k SOW - 90k with pump PUW - 205k SOW 85k without pumps Printed: 6/3/2009 3:57 PM • • BP Page 90 of 91 Operations Summary Report Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER +COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/19/2009 05:30 - 06:30 1.00 RUNCOMP RUNCMP Pressure increased 125 psi at 30 feet in on jt #141 of 13cr95 PU and clear seals to displace well to 9.5 ppg brine. 06:30 - 17:00 10.50 RUNCOMP RUNCMP Displace well with the following @ 132 gpm 484 psi 600 bbls 9.5 ppg clean brine followed by (861 bbls 9.5 ppg brine treated with 25 gallons per 100 bbls of EC1124A & 01VD121 corrosion inhibitor) followed by 352 bbls 9.5 ppg clean brine. Dropped 2.5" ball at 17,483 strokes into displacement, reduced pump rate to 63 gpm to seat ball, ball on seat 21,148 strokes and pressure up to 400 psi & confirm seat. Bleed off pressure and leave flow path open to bleed line. 17:00 - 18:30 1.50 RUNCOMP RUNCMP S/O on tubing string & MU 9.84' pup and tubing hanger assembly. Terminate control line and breed through tubing hanger control line port, splice control line and re- pressurize same to 6000 psi and hold for 15 min test. Test held. S/0 and land tubing with DWT 104k Total 23 Cannon Clamps & 2 Stainless Steel bands ran. 18:30 - 20:00 1.50 WHSUR P RUNCMP Run in lock down studs on tubing hanger and torque to 800 ft/lbs Test tubing hanger seals to 5000 psi and held for 15 min. Test Held. 20:00 - 21:30 1.50 WHSUR P RUNCMP Pressure up on tubing to 1500 psi 28 strokes and record on chart for 30 min. Test held Bleed tubing pressure down to 500 psi. & lock in. Pressure u• on T x IA to 3500 •si 151 strokes and record • 1 chart for 30 min. Test held. Bleed off IA & tubing to 0 psi 21:30 - 23:00 1.50 WHSUR P RUNCMP Back out and pull landing joint. Install TWC & re- install landing joint & test TWC from above tc, 1000 psi. Test held. Bleed off pressure and RD / LD landing joint & blow down surface equipment Bleed off and terminate control line. 23:00 - 00:00 1.00 WHSUR P RUNCMP Drain BOP stack. RD control line spooling unit & clear rig floor 5/20/2009 00:00 - 03:30 3.50 BOPSUF P RUNCMP Clear rig floor of vendors tools. Clean out from under rotary table and pipe racks drain pan system 03:30 - 09:30 6.00 BOPSUF P RUNCMP PJSM - Pull all rams form BOP and service gates for demobilization. 09:30 - 12:00 2.50 BOPSUF P RUNCMP Remove all accumulator lines & install plugs. Remove turnbuckles, choke line, kill line, pull riser / bell nipple. 12:00 - 14:00 2.00 BOPSUF P RUNCMP PJSM - inspect and RU bridge crane to stack. ND BOP and set back on rack. East side BOP bridge crane winch bleed off during pick on ND operations. Was able to complete pick and rack back without further problem. Equipment was locked out of service pending Printed: 6/3/2009 3:57:46 PM • 41/ Bp Page 91 of 91 Operations Summary Repor Legal Well Name: NS33 Common Well Name: NS33 Spud Date: 1/29/2007 Event Name: REENTER+COMPLETE Start: 1/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/20/2009 Rig Name: NABORS 33E Rig Number: Date From - T o H ou rs Task Code NPT Phase Description of Operations 5/20/2009 12:00 - 14:00 2.00 BOPSUF P RUNCMP further evaluation and repairs. 14:00 - 19:00 5.00 WHSUR P RUNCMP PJSM - Terminate control line into wellhead & energize to 6000 psi. 30 min test held. NU adapter flange & tree. Test adapter flange void to 5000 psi. 10 min test held. Fill tree with diesel and test tree to 5000 psi. 10 min test held. 19:00 - 00:00 5.00 WHSUR P RUNCMP PJSM - Install sweep & double valves on upper wellhead IA outlet & test same to 5000 psi . 10 min test held. Knuckle joints broke while attempting to remove VR plug from wellhead. Mobilize backup tools. Bleed control line and remove valves & gauges from control line outlet to remove sweep. Released Rig to Maintenance / DeMobilization @ 23:59 Hrs Printed. 6/3/2009 3:57:48 PM • • BP AMERICA Page 1 ivf4. Operations Summary Report Legal Well Name: NS RIG 33E MAINTENANCE /MOBILIZATION Common Well Name: NS RIG 33E MAINTENANCE /MOBILIZATION Spud Date: Event Name: MOBILIZATION Start: 5/20/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/24/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/21/2009 00:00 - 01:30 1.50 WHSUR N POST PJSM- ND sweep from wellhead & recover knuckle joint assembly. NU sweep & valves and retest to 5000 psi.10 min test held. Remove VR plug and secure wellhead. Install control line gauges, re- energize line to 6000 psi. 01:30 - 03:30 2.00 WHSUR P POST PJSM - RU Vetco lubricator and pull TWC. RD / LD lubricator. 03:30 - 09:00 5.50 WHSUR P POST PJSM - RU Schlumberger slick line unit, lubricator & wire line BOP. MU Junk Catcher tool string & test lubricator to 1000 psi. 09:00 - 11:00 2.00 WHSUR P POST Run #1 RIH & install junk catcher in X Nipple It 2,920' POH 11:00 - 13:00 2.00 WHSUR P POST Run #2 MU Kick over tool & RIH to retrieve Dummy GLM valve 2,808' POH. Miss -Run. 13:00 - 15:00 2.00 WHSUR P POST Run #3 RIH w/ Kick over tool to retrieve Dummy GLM valve 2,808' POH. Miss -Run. 15:00 - 16:30 1.50 WHSUR P POST Run #4 RIH w/ Kick over tool to retrieve Dummy GLM valve @ 2,808' POH. w/ Dummy valve. 16:30 - 18:00 1.50 WHSUR P POST Run #5 RIH w/ Kick over tool & install Circ Valve in GLM 2,808' POH. 18:00 - 00:00 6.00 WHSUR P POST PJSM w/ Little Red, Rig & G &I personnel. Test Lines to 4700 psi. Rev Circ 135 bbls diesel into IA Shut Dn. Re- load pumping unit with diesel from ,pipe rack. Cont' Rev Circ 125 bbls. For a total of 260 bbls ICP =150 psi / FCP = 400 psi © 2 bpm. 5/22/2009 00:00 - 01:30 1.50 WHSUR P POST PJSM - Line up and U -Tube diesel into tubing. T x IA holding 250 psi. 01:30 - 03:30 2.00 WHSUR P POST Bleed back 1 bbl T x IA pressure 150 psi & built to 175 psi in 15 min. Bleed back 1/2 bbl T x IA 125 psi & built to 150 psi in 15 min. Bleed back 1/2 bbl T x IA 100 psi &built to 150 psi in 12 min. Pressure stabilized © 150 psi. Monitor pressure and hold PJSM w/ SWL, Little Red, & Rig Personnel on Slick Line operations working under pressure. RU Little Red to manifold for testing &draining wire lin lubricator and Test line to 4800 psi. 03:30 - 05:00 1.50 WHSUR P POST Run #6 MU Kick over tool & RIH to retrieve Circ Valve in GLM It 2,808' holding 150 psi on well. POH. Miss -Run. 05:00 - 08:30 3.50 WHSUR P POST Run #7 Redress Kick over tool & RIH to retrieve Circ Valve in GLM © 2,808' holding 150 psi on well. POH w/ Circ Valve. 08:30 - 10:30 2.00 WHSUR P POST Run #8 Redress Kick over tool & RIH & install Dummy Valve in GLM © 2,808' holding 150 psi on well. POH 10:30 - 12:00 1.50 WHSUR P POST PJSM - Pressure test IA to 4200 psi for 30 min and record on chart. Test held. 12:00 - 13:30 1.50 WHSUR P POST Run #9 RIH & recover junk catcher in X Nipple © 2,920' holding 175 psi on tubing. POH 13:30 - 15:30 2.00 WHSUR P POST PJSM - RD Schlumberger slick line. RU Vetco Gray lubricator and install BPV. Secure tree. Clear rig floor of vendors tools. 15:30 - 18:00 2.50 DEMOB P POST PJSM & prep for rig move to north end of well row Printed: 6/15 /2009 4:32:00 PM • • BP AMERICA Page 2s- Operations Summary Report Legal Well Name: NS RIG 33E MAINTENANCE /MOBILIZATION Common Well Name: NS RIG 33E MAINTENANCE /MOBILIZATION Spud Date: Event Name: MOBILIZATION Start: 5/20/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/24/2009 Rig Name: NABORS 33E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/22/2009 18:00 - 19:00 1.00 DEMOB P POST PJSM with Well row operators, ACS, Toolpusher, Rig crew & WSL reviewing the rig procedures, ATP and discussing the hazards associated with rig move to stack out position and verification of energy isolation of wells and high line power source. 66i 19:00 - 21:30 2.50 DEMOB P POST Move rig north to stack out position and spot allowing wireline access to NS -33A & NS -34. 21:30 - 00:00 2.50 DEMOB P POST Clean location, RU walk / stairways, close cellar doors & inner - connects. Prep rig for maintenance & de- mobilization. 5/23/2009 00:00 - 12:00 12.00 DEMOB P POST RU walk / stairways, close cellar doors & inner - connects. Trim excess herculite and berm around rig & post rig location clean up. Store drilling riser / bet nipple Install VLE low level limit switch. Service choke manifold, & grease shock hose connections. Start Removal of BOP bridge crane winches for service. Inventory BOP expendable equipment & service rams for storage RD Rig floor equipment & drilling tools & service same. Change draw -works oil. Mud pump service - drain rod wash, remove inspection plates, pull suction strainers & drain plugs from charge pumps, Inventory all hydrocarbon volumes in rig service / storage tanks. Loading pipe shed with 5" drill pipe. 12:00 - 13:00 1.00 DEMOB P POST Cont' removal of BOP bridge crane winches for service. 13:00 - 14:30 1.50 DEMOB P POST Safety Stand Down - Follow up meeting held with rig team reviewing the Alaska HSE Basics. Discussions held on HSE expectations. 14:30 - 00:00 9.50 DEMOB P POST Cont' removal of BOP bridge crane winches for service. Loading pipe shed with 5" drill pipe. Total of 500 joints 5" DP Open & Service / inspect degasser Remove die blocks from iron roughneck service same. Start #1 Boiler / Shut down #2 Boiler for annual inspection 5/24/2009 00:00 - 01:00 1.00 DEMOB P POST Safety Stand Down - Follow up meeting held with rig team reviewing the Alaska HSE Basics. Discussions held on HSE expectations. 01:00 - 06:00 5.00 DEMOB P POST Cont' demob iron roughneck service same. Install blanking plate on rotary drain box flow line system Remove bails from top drive & Clean / inspect top drive / servicing same Disconnect rotary hose from top drive & service connections Service drilling subs and cover sub racks on rig floor & cellar. Service L- pits equipment, Install lid on degasser Loading 4" 17# XT- 39 DP into pipe shed Trouble shoot pipe shed hydraulic system Start installation of Academy Crown / Floor saver 06:00 - 00:00 18.00 DEMOB P POST Repair pipe shed hydraulic system line leak Remove 3" pipe -rack seawater line from rig and place in cellar area for inspection / replacement of heat -trace Printed: 6/15/2009 4:32:00 PM BP Page 1 of 1 Leak-Off Test Summary Legal Name: NS33 Common Name: NS33 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 2/8/2007 FIT (ft) (ft) (ppg) (psi) (psi) (PPg) 2/14/2007 FIT 4,471.0 (ft) 3,195.0 (ft) 9.00 (ppg) 420 (psi) 1,914 (psi) 11.53 (ppg) 3/5/2007 FIT (ft) (ft) (ppg) (psi) (psi) 11.53 (ppg) 3/13/2007 FIT 16,491.0 (ft) 7,032.0 (ft) 9.20 (ppg) 1,220 (psi) 4,581 (psi) 12.54 (ppg) 2/4/2006 LOT 15,060.0 (ft) 6,572.0 (ft) 9.20 (ppg) 1,332 (psi) 4,473 (psi) 13.10 (ppg) 40 2/10/2009 LOT 23,540.0 (ft) 9,152.0 (ft) 11.00 (ppg) 1,650 (psi) 6,880 (psi) 14.47 (ppg) 3/20/2009 LOT 23,540.0 (ft) 9,152.0 (ft) 12.00 (ppg) 985 (psi) 6,690 (psi) 14.07 (ppg) 4/15/2009 FIT 25,582.0 (ft) 10,902.0 (ft) 9.70 (ppg) 1,587 (psi) 7,080 (psi) 12.50 (ppg) • Printed: 6/3/2009 3:57:27 PM bp 0 NS33A Survey Report Schlumberger Report Date: 18- Apr -09 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 307.910° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Northstar PF / NS33 TVD Reference Datum: Rotary Table Well: NS33 TVD Reference Elevation: 55.91 ft relative to MSL Borehole: NS33A Sea Bed I Ground Level Elevation: 15.67 ft relative to MSL UWI /API #: 500292332501 Magnetic Declination: 22.910° Survey Name / Date: NS33A / April 18, 2009 Total Field Strength: 57713.748 nT Tort / AHD / DDI I ERD ratio: 317.693° / 21797.79 ft / 7.202 / 1.921 Magnetic Dip: 81.044° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 15, 2009 Location Lat/Long: N 70 29 29.845, W 148 41 36.037 Magnetic Declination Model: BGGM 2008 Location Grid WE YIX: N 6031141.300 ftUS, E 659820.740 ftUS North Reference: True North Grid Convergence Angle: +1.23166855° Total Corr Mag North •> True North: +22.910° • Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub•Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) (deg) (ft ) (ft) (ft) (ft ) (ft) (ft) (ft ) (deg /100ft ) (ftUS) (ftUS) RTE 0.00 0.01 18.25 -55.91 0.00 0.10 0.00 0.31 0.29 0.10 0.00 6031141.59 659820.83 N 70 29 29.848 W 148 41 36.034 GYD GC SS 49.31 0.70 18.25 -6.60 49.31 0.21 0.31 0.61 0.58 0.19 1.40 6031141.88 659820.92 N 70 29 29.851 W 148 41 36.032 99.31 0.62 18.15 43.39 99.30 0.40 0.88 1.19 1.13 0.37 0.16 6031142.43 659821.09 N 70 29 29.856 W 148 41 36.026 149.31 0.82 18.87 93.39 149.30 0.61 1.51 1.82 1.72 0.57 0.40 6031143.03 659821.27 N 70 29 29.862 W 148 41 36.020 207.31 1.14 324.05 151.38 207.29 1.30 2.43 2.61 2.58 0.37 1.63 6031143.89 659821.05 N 70 29 29.871 W 148 41 36.026 303.31 2.81 285.74 247.33 303.24 4.39 5.63 4.69 3.99 -2.46 2.13 6031145.24 659818.20 N 70 29 29.885 W 148 41 36.110 400.31 3.96 293.87 344.16 400.07 9.85 11.35 9.85 5.99 -7.81 1.28 6031147.12 659812.80 N 70 29 29.904 W 148 41 36.267 496.31 6.90 301.08 439.72 495.63 18.79 20.43 18.85 10.31 -15.78 3.14 6031151.27 659804.74 N 70 29 29.947 W 148 41 36.502 600.31 9.54 304.47 542.64 598.55 33.60 35.29 33.72 18.42 -28.24 2.58 6031159.11 659792.11 N 70 29 30.026 W 148 41 36.868 696.31 10.57 307.34 637.16 693.07 50.34 52.05 50.46 28.26 -41.80 1.19 6031168.65 659778.35 N 70 29 30.123 W 148 41 37.267 791.31 11.04 314.28 730.48 786.39 68.10 69.83 68.14 39.90 -55.24 1.46 6031180.00 659764.66 N 70 29 30.238 W 148 41 37.663 888.31 13.58 313.64 825.24 881.15 88.66 90.51 88.66 54.24 -70.13 2.62 6031194.02 659749.46 N 70 29 30.379 W 148 41 38.101 Last Gyro 983.31 16.40 309.47 917.01 972.92 113.17 115.07 113.18 70.47 -88.56 3.18 6031209.84 659730.69 N 70 29 30.538 W 148 41 38.643 First MWD +IFR +MS 1106.98 19.19 310.74 1034.75 1090.66 150.93 152.86 150.95 94.84 - 117.44 2.28 6031233.58 659701.29 N 70 29 30.778 W 148 41 40 3 1200.18 20.23 307.72 1122.49 1178.40 182.35 184.29 182.38 114.69 - 141.80 1.56 6031252.91 659676.52 N 70 29 30.973 W 148 41 0 1296.51 17.22 306.36 1213.71 1269.62 213.26 215.21 213.28 133.34 - 166.46 3.16 6031271.02 659651.46 N 70 29 31.157 W 148 41 40.936 1391.45 17.76 308.97 1304.26 1360.17 241.79 243.74 241.80 150.78 - 189.04 1.00 6031287.97 659628.52 N 70 29 31.328 W 148 41 41.600 1488.39 19.49 308.60 1396.12 1452.03 272.74 274.70 272.76 170.17 - 213.17 1.79 6031306.83 659603.98 N 70 29 31.519 W 148 41 42.311 1583.07 22.65 295.86 1484.51 1540.42 306.39 308.61 306.39 187.99 - 241.94 5.86 6031324.03 659574.83 N 70 29 31.694 W 148 41 43.157 1678.93 25.69 300.32 1571.96 1627.87 345.05 347.84 345.12 206.53 - 276.50 3.70 6031341.83 659539.89 N 70 29 31.876 W 148 41 44.174 1774.49 28.20 303.38 1657.14 1713.05 388.10 391.13 388.27 229.42 - 313.24 3.00 6031363.91 659502.66 N 70 29 32.101 W 148 41 45.255 1870.79 29.67 303.16 1741.42 1797.33 434.54 437.72 434.80 254.97 - 352.20 1.53 6031388.63 659463.17 N 70 29 32.353 W 148 41 46.402 1964.49 31.78 303.78 1821.96 1877.87 482.26 485.59 482.63 281.38 - 392.12 2.28 6031414.17 659422.69 N 70 29 32.612 W 148 41 47.577 2062.37 32.73 305.75 1904.74 1960.65 534.42 537.82 534.86 311.17 - 435.02 1.45 6031443.03 659379.16 N 70 29 32.905 W 148 41 48.840 2156.68 34.74 304.82 1983.17 2039.08 586.73 590.19 587.23 341.42 - 477.78 2.20 6031472.34 659335.77 N 70 29 33.203 W 148 41 50.098 2252.73 37.38 304.31 2060.81 2116.72 643.17 646.72 643.75 373.48 - 524.34 2.77 6031503.40 659288.53 N 70 29 33.518 W 148 41 51.468 2347.29 40.28 303.68 2134.46 2190.37 702.31 706.01 703.02 406.62 - 573.49 3.10 6031535.47 659238.68 N 70 29 33.844 W 148 41 52.915 SurveyEditor Ver SP 2.1 Bld( users) NS33 \NS33 \NS33A \NS33A Generated 6/2/2009 10:59 AM Page 1 of 7 2443.45 43.23 303.68 2206.19 2262.10 766.17 770.04 767.03 442.13 - 626.78 3.07 6031569.82 659184.65 N 70 29 34.193 W 148 41 54.483 2537.42 44.38 303.92 2274.01 2329.92 831.05 835.08 832.05 478.31 - 680.83 1.24 6031604.84 659129.84 N 70 29 34.549 W 148 41 56.074 2633.65 46.29 303.90 2341.65 2397.56 899.32 903.52 900.48 516.50 - 737.63 1.98 6031641.78 659072.24 N 70 29 34.924 W 148 41 57.745 2728.41 49.05 304.09 2405.45 2461.36 969.20 973.57 970.52 555.66 - 795.70 2.92 6031679.69 659013.34 N 70 29 35.310 W 148 41 59.455 2823.98 51.49 304.31 2466.53 2522.44 1042.54 1047.06 1044.00 596.97 - 856.48 2.56 6031719.68 658951.69 N 70 29 35.716 W 148 42 1.244 2917.76 54.73 304.69 2522.82 2578.73 1117.40 1122.06 1119.00 639.46 - 918.29 3.47 6031760.82 658888.99 N 70 29 36.134 W 148 42 3.063 3012.39 56.67 305.69 2576.15 2632.06 1195.48 1200.23 1197.16 684.51 - 982.16 2.23 6031804.49 658824.16 N 70 29 36.577 W 148 42 4.943 3107.09 58.29 307.05 2627.06 2682.97 1275.30 1280.07 1276.98 731.86 - 1046.45 2.10 6031850.45 658758.88 N 70 29 37.042 W 148 42 6.835 3203.63 60.50 307.14 2676.20 2732.11 1358.38 1363.16 1360.02 781.98 - 1112.72 2.29 6031899.12 658691.55 N 70 29 37.535 W 148 42 8.786 3299.19 61.24 306.69 2722.72 2778.63 1441.84 1446.63 1443.45 832.11 - 1179.46 0.88 6031947.81 658623.75 N 70 29 38.028 W 148 42 10.750 3394.67 63.15 307.33 2767.26 2823.17 1526.28 1531.09 1527.86 882.95 - 1246.90 2.09 6031997.18 658555.24 N 70 29 38.528 W 148 42 12.735 3491.94 65.24 306.99 2809.60 2865.51 1613.84 1618.65 1615.38 935.84 - 1316.68 2.17 6032048.56 658484.34 N 70 29 39.048 W 148 42 14.789 3587.75 67.89 307.18 2847.70 2903.61 1701.73 1706.55 1703.25 988.85 - 1386.80 2.77 6032100.04 658413.10 N 70 29 39.569 W 148 42 16.853 3684.81 69.42 307.17 2883.03 2938.94 1792.12 1796.95 1793.61 1043.47 - 1458.83 1.58 6032153.10 658339.92 N 70 29 40.106 W 148 42 18.973 3779.99 71.96 308.29 2914.50 2970.41 1881.93 1886.77 1883.36 1098.44 - 1529.87 2.89 6032206.52 658267.73 N 70 29 40.647 W 148 42 21.064 3876.20 72.34 306.40 2943.99 2999.90 1973.50 1978.34 1974.90 1153.99 - 1602.67 1.91 6032260.49 658193.76 N 70 29 41.193 W 148 42 23.207 3972.58 71.34 305.49 2974.03 3029.94 2065.03 2069.92 2066.48 1207.75 - 1676.80 1.37 6032312.64 658118.49 N 70 29 41.721 W 148 42 25 390 4068.44 70.63 306.64 3005.26 3061.17 2155.61 2160.55 2157.10 1261.10 - 1750.06 1.35 6032364.40 658044.10 N 70 29 42.246 W 148 42 4164.22 69.97 306.70 3037.55 3093.46 2245.76 2250.72 2247.27 1314.95 - 1822.39 0.69 6032416.68 657970.64 N 70 29 42.775 W 148 42 W 4259.99 70.28 305.65 3070.11 3126.02 2335.78 2340.79 2337.33 1368.11 - 1895.09 1.08 6032468.26 657896.82 N 70 29 43.298 W 148 42 31.816 4356.47 71.46 305.77 3101.73 3157.64 2426.87 2431.94 2428.48 1421.31 - 1969.11 1.23 6032519.86 657821.68 N 70 29 43.821 W 148 42 33.995 4418.53 71.45 306.12 3121.47 3177.38 2485.67 2490.78 2487.32 1455.85 - 2016.74 0.53 6032553.36 657773.32 N 70 29 44.160 W 148 42 35.397 16" © 4471'md 4549.15 72.93 304.83 3161.42 3217.33 2609.91 2615.13 2611.67 1528.01 - 2118.01 1.47 6032623.33 657670.53 N 70 29 44.870 W 148 42 38.378 4643.82 72.51 304.53 3189.54 3245.45 2700.16 2705.53 2702.05 1579.45 - 2192.35 0.54 6032673.15 657595.11 N 70 29 45.375 W 148 42 40.567 4740.41 71.93 304.18 3219.03 3274.94 2791.96 2797.51 2793.99 1631.35 - 2268.28 0.69 6032723.40 657518.09 N 70 29 45.886 W 148 42 42.802 4835.88 71.53 303.67 3248.96 3304.87 2882.40 2888.16 2884.61 1681.95 - 2343.50 0.66 6032772.37 657441.80 N 70 29 46.383 W 148 42 45.017 4931.41 68.50 304.40 3281.61 3337.52 2971.96 2977.93 2974.34 1732.19 - 2417.90 3.25 6032820.99 657366.35 N 70 29 46.877 W 148 42 47.207 5025.27 67.01 303.55 3317.14 3373.05 3058.63 3064.80 3061.18 1780.74 - 2489.93 1.80 6032867.98 657293.29 N 70 29 47.354 W 148 42 49.328 5121.75 69.31 304.05 3353.03 3408.94 3147.94 3154.35 3150.68 1830.55 - 2564.35 2.43 6032916.18 657217.83 N 70 29 47.844 W 148 42 51.519 5215.69 70.66 306.15 3385.19 3441.10 3236.10 3242.61 3238.94 1881.31 - 2636.55 2.54 6032965.37 657144.56 N 70 29 48.343 W 148 42 53.645 5312.18 70.92 306.71 3416.94 3472.85 3327.18 3333.73 3330.04 1935.42 - 2709.86 0.61 6033017.89 657070.10 N 70 29 48.875 W 148 42 55.803 5406.74 71.34 307.96 3447.52 3503.43 3416.65 3423.21 3419.48 1989.68 - 2781.00 1.33 6033070.61 656997.82 N 70 29 49.408 W 148 42 57.898 5502.70 71.91 307.63 3477.77 3533.68 3507.72 3514.28 3510.48 2045.49 - 2852.97 0.68 6033124.85 656924.68 N 70 29 49.957 W 148 43 0.017 5596.30 72.44 306.94 3506.42 3562.33 3596.82 3603.38 3599.55 2099.47 - 2923.86 0.90 6033177.29 656852.64 N 70 29 50.487 W 148 43 2.104 5693.95 72.64 307.22 3535.72 3591.63 3689.96 3696.53 3692.67 2155.63 - 2998.18 0.34 6033231.84 656777.14 N 70 29 51.039 W 148 43 4.292 5788.45 71.29 307.01 3564.98 3620.89 3779.81 3786.39 3782.50 2209.85 - 3069.83 1.44 6033284.50 656704.35 N 70 29 51.572 W 148 43 6.402 5883.31 70.30 307.40 3596.18 3652.09 3869.38 3875.97 3872.05 2264.02 - 3141.18 1.11 6033337.12 656631.86 N 70 29 52.105 W 148 43 8.503 5977.65 69.95 308.15 3628.25 3684.16 3958.10 3964.69 3960.72 2318.37 - 3211.30 0.83 6033389.94 656560.58 N 70 29 52.639 W 148 43 10.568 6073.89 70.12 309.43 3661.12 3717.03 4048.54 4055.14 4051.05 2375.03 - 3281.81 1.26 6033445.07 656488.88 N 70 29 53.196 W 148 43 .4 6169.72 70.28 311.10 3693.58 3749.49 4138.63 4145.31 4140.96 2433.31 - 3350.61 1.65 6033501.85 656418.85 N 70 29 53.769 W 148 43 0 6265.05 70.31 310.90 3725.72 3781.63 4228.25 4235.06 4230.37 2492.19 - 3418.34 0.20 6033559.26 656349.88 N 70 29 54.347 W 148 43 16.665 6359.67 70.61 311.11 3757.37 3813.28 4317.29 4324.23 4319.22 2550.69 - 3485.63 0.38 6033616.30 656281.35 N 70 29 54.923 W 148 43 18.647 6455.27 70.83 311.59 3788.93 3844.84 4407.36 4414.46 4409.10 2610.31 - 3553.37 0.53 6033674.44 656212.34 N 70 29 55.509 W 148 43 20.642 6549.36 70.85 311.66 3819.82 3875.73 4496.05 4503.34 4497.60 2669.35 - 3619.81 0.07 6033732.03 656144.66 N 70 29 56.089 W 148 43 22.598 6645.28 70.89 312.05 3851.25 3907.16 4586.46 4593.97 4587.82 2729.81 - 3687.31 0.39 6033791.03 656075.88 N 70 29 56.683 W 148 43 24.586 6738.88 70.49 312.16 3882.20 3938.11 4674.56 4682.30 4675.75 2789.04 - 3752.84 0.44 6033848.83 656009.09 N 70 29 57.265 W 148 43 26.516 6836.66 71.23 312.74 3914.26 3970.17 4766.64 4774.67 4767.65 2851.39 - 3821.00 0.94 6033909.70 655939.61 N 70 29 57.878 W 148 43 28.524 6931.57 71.74 310.90 3944.40 4000.31 4856.43 4864.67 4857.29 2911.39 - 3888.07 1.92 6033968.24 655871.28 N 70 29 58.468 W 148 43 30.499 7028.27 72.17 309.22 3974.36 4030.27 4948.30 4956.61 4949.09 2970.56 - 3958.44 1.71 6034025.88 655799.66 N 70 29 59.050 W 148 43 32.572 7123.26 71.44 307.13 4004.02 4059.93 5038.53 5046.85 5039.30 3026.34 - 4029.37 2.23 6034080.11 655727.55 N 70 29 59.598 W 148 43 34.661 7218.94 71.07 306.21 4034.77 4090.68 5129.12 5137.46 5129.90 3080.45 - 4102.04 0.99 6034132.64 655653.73 N 70 30 0.129 W 148 43 36.801 7315.44 70.65 305.64 4066.41 4122.32 5220.23 5228.62 5221.06 3133.94 - 4175.87 0.71 6034184.53 655578.78 N 70 30 0.655 W 148 43 38.976 SP 2.1 Bld users NS33 \NS33 \NS33A \NS33A Generated 6/2/2009 10:59 AM Pa e 2 of 7 SurveyEditor Ver S ( ) 9 7412.13 71.19 306.62 4098.02 4153.93 5311.56 5320.00 5312.42 3187.81 - 4249.67 1.11 6034236.81 655503.84 N 70 30 1.185 W 148 43 41.149 7508.75 70.64 307.21 4129.61 4185.52 5402.85 5411.31 5403.73 3242.66 - 4322.67 0.81 6034290.06 655429.68 N 70 30 1.723 W 148 43 43.299 7605.24 71.88 308.73 4160.61 4216.52 5494.22 5502.68 5495.09 3298.88 - 4394.70 1.97 6034344.72 655356.47 N 70 30 2.276 W 148 43 45.421 7700.21 71.02 308.49 4190.82 4246.73 5584.25 5592.71 5585.08 3355.06 - 4465.06 0.94 6034399.37 655284.93 N 70 30 2.828 W 148 43 47.493 7796.71 72.19 308.31 4221.27 4277.18 5675.81 5684.28 5676.62 3411.94 - 4536.82 1.23 6034454.69 655211.97 N 70 30 3.387 W 148 43 49.607 7892.40 72.17 305.76 4250.56 4306.47 5766.89 5775.38 5767.71 3466.80 - 4609.53 2.54 6034507.97 655138.10 N 70 30 3.926 W 148 43 51.749 7989.24 71.63 304.37 4280.65 4336.56 5858.83 5867.43 5859.71 3519.68 -4684.87 1.47 6034559.22 655061.65 N 70 30 4.446 W 148 43 53.968 8085.11 71.31 304.51 4311.12 4367.03 5949.56 5958.33 5950.52 3571.09 - 4759.84 0.36 6034609.00 654985.60 N 70 30 4.951 W 148 43 56.176 8181.85 70.94 306.30 4342.42 4398.33 6041.00 6049.86 6042.03 3624.12 - 4834.44 1.79 6034660.41 654909.87 N 70 30 5.472 W 148 43 58.373 8278.27 70.89 307.94 4373.94 4429.85 6132.11 6140.98 6133.14 3679.10 - 4907.10 1.61 6034713.82 654836.06 N 70 30 6.012 W 148 44 0.514 8375.18 71.04 309.37 4405.55 4461.46 6223.71 6232.59 6224.70 3736.33 - 4978.64 1.40 6034769.48 654763.31 N 70 30 6.575 W 148 44 2.621 8472.55 71.28 309.82 4437.00 4492.91 6315.83 6324.75 6316.76 3795.06 - 5049.65 0.50 6034826.67 654691.06 N 70 30 7.152 W 148 44 4.713 8569.61 71.41 309.93 4468.04 4523.95 6407.73 6416.71 6408.60 3854.02 - 5120.22 0.17 6034884.10 654619.24 N 70 30 7.731 W 148 44 6.792 8665.84 71.41 309.71 4498.72 4554.63 6498.89 6507.92 6499.69 3912.43 - 5190.27 0.22 6034940.98 654547.95 N 70 30 8.305 W 148 44 8.856 8762.74 71.27 309.92 4529.72 4585.63 6590.65 6599.72 6591.39 3971.21 - 5260.79 0.25 6034998.23 654476.19 N 70 30 8.883 W 148 44 10.933 8860.05 71.55 310.73 4560.75 4616.66 6682.80 6691.96 6683.48 4030.90 - 5331.11 0.84 6035056.39 654404.61 N 70 30 9.469 W 148 44 13.005 8956.91 71.95 310.33 4591.08 4646.99 6774.69 6783.94 6775.30 4090.67 - 5401.02 0.57 6035114.64 654333.43 N 70 30 10.057 W 148 44 1165 9053.07 72.16 310.11 4620.71 4676.62 6866.09 6875.43 6866.65 4149.75 - 5470.88 0.31 6035172.20 654262.33 N 70 30 10.637 W 148 44 9151.11 72.25 309.92 4650.67 4706.58 6959.38 6968.77 6959.89 4209.77 - 5542.37 0.21 6035230.66 654189.57 N 70 30 11.227 W 148 44 9 9245.29 72.09 308.62 4679.51 4735.42 7049.01 7058.43 7049.49 4266.52 - 5611.78 1.32 6035285.90 654118.96 N 70 30 11.784 W 148 44 21.274 9342.22 71.93 308.46 4709.44 4765.35 7141.20 7150.62 7141.65 4323.96 - 5683.89 0.23 6035341.78 654045.64 N 70 30 12.349 W 148 44 23.399 9437.78 72.03 308.19 4739.00 4794.91 7232.07 7241.49 7232.51 4380.31 - 5755.18 0.29 6035396.58 653973.16 N 70 30 12.902 W 148 44 25.499 9534.41 72.11 307.85 4768.75 4824.66 7324.00 7333.43 7324.44 4436.94 - 5827.61 0.34 6035451.63 653899.54 N 70 30 13.459 W 148 44 27.633 9631.30 71.35 307.66 4799.13 4855.04 7416.01 7425.44 7416.44 4493.27 - 5900.35 0.81 6035506.39 653825.61 N 70 30 14.012 W 148 44 29.776 9726.41 71.29 308.51 4829.59 4885.50 7506.11 7515.54 7506.53 4548.85 - 5971.26 0.85 6035560.42 653753.52 N 70 30 14.558 W 148 44 31.866 9821.29 71.96 308.44 4859.50 4915.41 7596.14 7605.58 7596.55 4604.87 - 6041.76 0.71 6035614.91 653681.85 N 70 30 15.109 W 148 44 33.943 9916.94 72.20 308.05 4888.93 4944.84 7687.15 7696.59 7687.55 4661.21 - 6113.23 0.46 6035669.69 653609.18 N 70 30 15.662 W 148 44 36.049 10013.42 72.37 307.39 4918.29 4974.20 7779.06 7788.49 7779.45 4717.43 - 6185.93 0.68 6035724.34 653535.30 N 70 30 16.215 W 148 44 38.191 10108.19 72.15 305.98 4947.16 5003.07 7869.29 7878.76 7869.71 4771.36 - 6258.31 1.44 6035776.69 653461.78 N 70 30 16.744 W 148 44 40.324 10204.90 72.00 305.86 4976.93 5032.84 7961.26 7970.77 7961.70 4825.34 - 6332.83 0.19 6035829.06 653386.12 N 70 30 17.275 W 148 44 42.519 10302.70 71.82 305.75 5007.30 5063.21 8054.16 8063.74 8054.63 4879.73 - 6408.23 0.21 6035881.81 653309.58 N 70 30 17.809 W 148 44 44.741 10368.89 71.61 305.82 5028.06 5083.97 8116.96 8126.59 8117.46 4916.48 - 6459.21 0.33 6035917.45 653257.82 N 70 30 18.170 W 148 44 46.243 10466.23 71.25 305.76 5059.06 5114.97 8209.17 8218.86 8209.70 4970.44 - 6534.06 0.37 6035969.79 653181.84 N 70 30 18.700 W 148 44 48.449 10560.87 70.75 306.78 5089.88 5145.79 8298.62 8308.34 8299.17 5023.37 - 6606.20 1.15 6036021.16 653108.58 N 70 30 19.220 W 148 44 50.574 10657.19 70.53 307.47 5121.81 5177.72 8389.48 8399.21 8390.04 5078.22 - 6678.66 0.71 6036074.43 653034.96 N 70 30 19.759 W 148 44 52.710 10752.86 70.95 308.27 5153.36 5209.27 8479.80 8489.53 8480.35 5133.66 - 6749.95 0.90 6036128.32 652962.50 N 70 30 20.303 W 148 44 54.810 10848.64 71.18 308.83 5184.44 5240.35 8570.39 8580.13 8570.92 5190.12 - 6820.80 0.60 6036183.24 652890.46 N 70 30 20.858 W 148 44 56.898 10942.73 70.49 309.50 5215.33 5271.24 8659.24 8669.00 8659.75 5246.25 - 6889.71 1.00 6036237.87 652820.36 N 70 30 21.409 W 148 44 58.929 11038.67 70.97 309.75 5247.00 5302.91 8749.76 8759.57 8750.24 5304.01 - 6959.47 0.56 6036294.11 652749.39 N 70 30 21.977 W 148 45.5 11132.96 71.81 310.13 5277.09 5333.00 8839.07 8848.92 8839.51 5361.38 - 7027.98 0.97 6036349.99 652679.66 N 70 30 22.540 W 148 45 4 11230.30 72.25 309.70 5307.12 5363.03 8931.60 8941.52 8932.00 5420.79 - 7099.00 0.62 6036407.86 652607.39 N 70 30 23.124 W 148 45 5.097 11323.83 71.95 309.61 5335.86 5391.77 9020.56 9030.52 9020.94 5477.58 - 7167.52 0.33 6036463.16 652537.67 N 70 30 23.682 W 148 45 7.117 11419.78 71.09 309.96 5366.28 5422.19 9111.51 9121.52 9111.86 5535.82 - 7237.45 0.96 6036519.88 652466.51 N 70 30 24.254 W 148 45 9.178 11513.26 71.34 309.82 5396.38 5452.29 9199.96 9210.02 9200.28 5592.57 - 7305.36 0.30 6036575.16 652397.40 N 70 30 24.811 W 148 45 11.179 11609.72 71.74 309.71 5426.92 5482.83 9291.41 9301.52 9291.70 5651.10 - 7375.69 0.43 6036632.15 652325.83 N 70 30 25.386 W 148 45 13.252 11703.76 71.18 309.07 5456.82 5512.73 9380.54 9390.68 9380.81 5707.68 - 7444.59 0.88 6036687.23 652255.73 N 70 30 25.942 W 148 45 15.283 11801.16 71.07 308.05 5488.33 5544.24 9472.69 9482.84 9472.95 5765.13 - 7516.66 1.00 6036743.11 652182.46 N 70 30 26.506 W 148 45 17.407 11895.73 70.67 307.24 5519.33 5575.24 9562.04 9572.18 9562.30 5819.70 - 7587.40 0.91 6036796.15 652110.56 N 70 30 27.042 W 148 45 19.492 11991.52 70.63 307.10 5551.07 5606.98 9652.41 9662.56 9652.68 5874.30 - 7659.42 0.14 6036849.19 652037.39 N 70 30 27.579 W 148 45 21.615 12085.84 69.77 307.40 5583.02 5638.93 9741.15 9751.31 9741.42 5928.02 - 7730.06 0.96 6036901.37 651965.62 N 70 30 28.106 W 148 45 23.697 12173.07 69.48 306.92 5613.39 5669.30 9822.91 9833.08 9823.19 5977.41 - 7795.23 0.61 6036949.35 651899.41 N 70 30 28.591 W 148 45 25.618 12266.94 71.06 306.77 5645.07 5700.98 9911.25 9921.44 9911.54 6030.39 - 7865.94 1.69 6037000.79 651827.58 N 70 30 29.112 W 148 45 27.702 SurveyEditor Ver SP 2.1 Bld( users) NS33 \NS33 \NS33A \NS33A Generated 6/2/2009 10:59 AM Page 3 of 7 12361.69 72.05 307.92 5675.05 5730.96 10001.13 10011.32 10001.42 6084.92 - 7937.39 1.55 6037053.77 651754.98 N 70 30 29.647 W 148 45 29.808 12457.08 72.08 307.69 5704.43 5760.34 10091.88 10102.07 10092.17 6140.55 - 8009.09 0.23 6037107.84 651682.10 N 70 30 30.193 W 148 45 31.922 12553.14 72.13 306.81 5733.94 5789.85 10183.29 10193.48 10183.58 6195.88 - 8081.86 0.87 6037161.59 651608.17 N 70 30 30.737 W 148 45 34.067 12647.15 72.14 305.84 5762.78 5818.69 10272.73 10282.96 10273.04 6248.88 - 8153.95 0.98 6037213.03 651534.96 N 70 30 31.257 W 148 45 36.191 12743.17 72.71 304.84 5791.78 5847.69 10364.18 10374.50 10364.52 6301.83 - 8228.62 1.16 6037264.35 651459.18 N 70 30 31.777 W 148 45 38.392 12837.16 72.16 304.78 5820.14 5876.05 10453.65 10464.10 10454.03 6352.98 - 8302.19 0.59 6037313.91 651384.53 N 70 30 32.279 W 148 45 40.561 12933.71 71.93 304.48 5849.91 5905.82 10545.35 10555.95 10545.77 6405.18 - 8377.76 0.38 6037364.46 651307.85 N 70 30 32.792 W 148 45 42.789 13028.24 72.49 304.47 5878.79 5934.70 10635.20 10645.96 10635.66 6456.12 - 8451.97 0.59 6037413.80 651232.58 N 70 30 33.292 W 148 45 44.976 13124.48 71.67 304.58 5908.40 5964.31 10726.61 10737.53 10727.12 6508.02 - 8527.41 0.86 6037464.06 651156.04 N 70 30 33.802 W 148 45 47.200 13220.90 71.81 305.14 5938.61 5994.52 10818.04 10829.10 10818.60 6560.36 - 8602.54 0.57 6037514.77 651079.81 N 70 30 34.316 W 148 45 49.414 13318.09 71.64 305.57 5969.09 6025.00 10910.24 10921.39 10910.83 6613.76 - 8677.81 0.46 6037566.53 651003.42 N 70 30 34.840 W 148 45 51.633 13413.72 71.65 306.02 5999.20 6055.11 11000.94 11012.15 11001.56 6666.85 - 8751.43 0.45 6037618.02 650928.68 N 70 30 35.361 W 148 45 53.803 13509.92 71.97 307.04 6029.23 6085.14 11092.31 11103.54 11092.95 6721.25 - 8824.87 1.06 6037670.83 650854.09 N 70 30 35.895 W 148 45 55.968 13609.04 71.61 307.56 6060.21 6116.12 11186.46 11197.70 11187.10 6778.31 - 8899.77 0.62 6037726.26 650777.99 N 70 30 36.456 W 148 45 58.176 13703.53 71.58 308.55 6090.04 6145.95 11276.11 11287.35 11276.75 6833.57 - 8970.36 0.99 6037779.99 650706.23 N 70 30 36.998 W 148 46 0.258 13801.31 71.97 308.74 6120.62 6176.53 11368.98 11380.23 11369.60 6891.57 - 9042.90 0.44 6037836.41 650632.47 N 70 30 37.568 W 148 46 2.396 13896.69 71.73 309.60 6150.34 6206.25 11459.59 11470.86 11460.18 6948.82 - 9113.17 0.89 6037892.13 650560.99 N 70 30 38.130 W 148 46 468 13999.29 71.58 309.86 6182.63 6238.54 11556.93 11568.25 11557.49 7011.06 - 9188.06 0.28 6037952.75 650484.78 N 70 30 38.741 W 148 4 7 14089.17 71.66 308.99 6210.97 6266.88 11642.19 11653.54 11642.72 7065.23 - 9253.95 0.92 6038005.48 650417.75 N 70 30 39.273 W 148 46 9 14186.15 71.48 308.59 6241.63 6297.54 11734.18 11745.55 11734.70 7122.87 - 9325.66 0.43 6038061.56 650344.82 N 70 30 39.839 W 148 46 10.734 14282.59 71.73 307.75 6272.06 6327.97 11825.69 11837.06 11826.20 7179.42 - 9397.61 0.87 6038116.55 650271.68 N 70 30 40.394 W 148 46 12.855 14379.34 71.51 307.06 6302.57 6358.48 11917.50 11928.88 11918.02 7235.19 - 9470.54 0.71 6038170.74 650197.57 N 70 30 40.942 W 148 46 15.005 14475.03 71.78 306.54 6332.70 6388.61 12008.31 12019.70 12008.83 7289.60 - 9543.26 0.59 6038223.56 650123.70 N 70 30 41.476 W 148 46 17.150 14572.08 71.67 306.00 6363.14 6419.05 12100.42 12111.85 12100.97 7344.11 - 9617.56 0.54 6038276.47 650048.25 N 70 30 42.011 W 148 46 19.340 14668.77 71.90 304.86 6393.36 6449.27 12192.18 12203.70 12192.76 7397.36 - 9692.40 1.14 6038328.08 649972.29 N 70 30 42.534 W 148 46 21.547 14765.95 71.94 305.35 6423.52 6479.43 12284.45 12296.08 12285.07 7450.48 - 9767.97 0.48 6038379.57 649895.60 N 70 30 43.056 W 148 46 23.775 14860.86 71.42 305.95 6453.35 6509.26 12374.48 12386.18 12375.13 7502.99 - 9841.19 0.81 6038430.49 649821.28 N 70 30 43.571 W 148 46 25.934 Tie -In Survey 14958.01 71.31 306.13 6484.40 6540.31 12466.49 12478.23 12467.17 7557.16 - 9915.63 0.21 6038483.04 649745.70 N 70 30 44.103 W 148 46 28.129 Top Window (Blind) 15037.00 71.30 305.62 6509.72 6565.63 12541.26 12553.06 12541.97 7601.00 - 9976.25 0.61 6038525.57 649684.15 N 70 30 44.533 W 148 46 29.917 Base Window (Blind) 15060.00 73.36 307.55 6516.70 6572.61 12563.17 12574.97 12563.88 7614.06 - 9993.85 12.01 6038538.25 649666.28 N 70 30 44.661 W 148 46 30.435 Inc +Trend 15117.08 72.36 310.32 6533.52 6589.43 12617.70 12629.51 12618.39 7648.34 - 10036.27 4.96 6038571.60 649623.13 N 70 30 44.998 W 148 46 31.686 15212.35 72.90 314.96 6561.98 6617.89 12708.29 12720.43 12708.90 7709.91 - 10103.13 4.68 6038631.72 649554.96 N 70 30 45.603 W 148 46 33.658 15307.83 73.20 319.60 6589.83 6645.74 12798.37 12811.76 12798.84 7776.99 - 10165.07 4.66 6038697.45 649491.60 N 70 30 46.261 W 148 46 35.486 MWD +IFR +MS 15403.53 74.15 323.03 6616.73 6672.64 12887.69 12903.60 12888.00 7848.67 - 10222.46 3.58 6038767.87 649432.69 N 70 30 46.966 W 148 46 37.179 15435.53 74.71 321.89 6625.32 6681.23 12917.53 12934.43 12917.78 7873.12 - 10241.24 3.85 6038791.90 649413.39 N 70 30 47.206 W 148 46 37.734 15499.34 76.25 323.24 6641.32 6697.23 12977.29 12996.20 12977.45 7922.16 - 10278.79 3.17 6038840.13 649374.80 N 70 30 47.688 W 148 46 38.842 15534.72 77.45 323.47 6649.37 6705.28 13010.49 13030.65 13010.61 7949.81 - 10299.35 3.45 6038867.32 649353.65 N 70 30 47.959 W 148 46 39.449 15594.35 77.60 321.93 6662.25 6718.16 13066.78 13088.87 13066.85 7996.12 - 10334.63 2.53 6038912.86 649317.38 N 70 30 48.414 W 148 46 40.490 15688.32 77.48 320.00 6682.53 6738.44 13156.17 13180.63 13156.18 8067.39 - 10392.42 2.01 6038982.87 649258.09 N 70 30 49.114 W 148 46 1115 15784.59 76.72 317.36 6704.03 6759.94 13248.34 13274.46 13248.34 8137.86 - 10454.37 2.79 6039051.99 649194.64 N 70 30 49.807 W 148 46 3 15878.95 76.49 316.57 6725.89 6781.80 13338.99 13366.26 13339.00 8204.96 - 10517.01 0.85 6039117.71 649130.57 N 70 30 50.466 W 148 46 45.871 15975.84 76.43 316.33 6748.57 6804.48 13432.14 13460.45 13432.17 8273.23 - 10581.91 0.25 6039184.57 649064.23 N 70 30 51.136 W 148 46 47.786 16070.70 76.51 316.63 6770.76 6826.67 13523.34 13552.68 13523.40 8340.10 - 10645.42 0.32 6039250.06 648999.30 N 70 30 51.793 W 148 46 49.660 16166.53 76.89 315.69 6792.81 6848.72 13615.63 13645.94 13615.74 8407.37 - 10710.02 1.03 6039315.92 648933.28 N 70 30 52.454 W 148 46 51.566 16261.42 77.80 315.56 6813.60 6869.51 13707.38 13738.53 13707.53 8473.55 - 10774.76 0.97 6039380.68 648867.13 N 70 30 53.103 W 148 46 53.476 16356.90 77.48 314.85 6834.04 6889.95 13799.89 13831.79 13800.11 8539.73 - 10840.48 0.80 6039445.43 648800.01 N 70 30 53.753 W 148 46 55.415 16451.73 77.39 314.52 6854.67 6910.58 13891.80 13924.35 13892.08 8604.82 - 10906.28 0.35 6039509.09 648732.82 N 70 30 54.393 W 148 46 57.357 16546.10 77.11 314.31 6875.49 6931.40 13983.25 14016.39 13983.60 8669.23 - 10972.03 0.37 6039572.07 648665.71 N 70 30 55.025 W 148 46 59.296 16641.39 77.31 314.63 6896.59 6952.50 14075.57 14109.32 14075.99 8734.33 - 11038.34 0.39 6039635.72 648598.02 N 70 30 55.664 W 148 47 1.253 16735.47 77.45 315.00 6917.14 6973.05 14166.71 14201.13 14167.22 8799.04 - 11103.47 0.41 6039699.01 648531.52 N 70 30 56.300 W 148 47 3.175 16830.03 77.83 315.80 6937.38 6993.29 14258.29 14293.49 14258.90 8864.81 - 11168.32 0.92 6039763.37 648465.28 N 70 30 56.946 W 148 47 5.088 16925.34 76.81 315.20 6958.30 7014.21 14350.46 14386.48 14351.19 8931.13 - 11233.50 1.23 6039828.27 648398.70 N 70 30 57.597 W 148 47 7.011 SurveyEditor Ver SP 2.1 Bld( users) NS33 \NS33 \NS33A \NS33A Generated 6/2/2009 10:59 AM Page 4 of 7 16964.71 76.69 314.99 6967.33 7023.24 14388.48 14424.80 14389.25 8958.27 - 11260.55 0.60 6039854.82 648371.07 N 70 30 57.864 W 148 47 7.810 17046.92 76.87 316.72 6986.13 7042.04 14467.74 14504.83 14468.63 9015.70 - 11316.29 2.06 6039911.03 648314.11 N 70 30 58.427 W 148 47 9.454 17142.30 77.05 317.03 7007.65 7063.56 14559.53 14597.75 14560.57 9083.52 - 11379.81 0.37 6039977.47 648249.16 N 70 30 59.093 W 148 47 11.329 17238.07 77.01 317.42 7029.15 7085.06 14651.62 14691.08 14652.85 9152.02 - 11443.19 0.40 6040044.59 648184.32 N 70 30 59.766 W 148 47 13.200 17333.07 76.96 317.99 7050.54 7106.45 14742.83 14783.64 14744.26 9220.49 - 11505.47 0.59 6040111.69 648120.58 N 70 31 0.439 W 148 47 15.038 17428.33 77.04 318.63 7071.97 7127.88 14834.12 14876.46 14835.79 9289.80 - 11567.21 0.66 6040179.66 648057.38 N 70 31 1.119 W 148 47 16.860 17523.96 77.04 319.31 7093.42 7149.33 14925.59 14969.65 14927.52 9360.10 - 11628.38 0.69 6040248.62 647994.71 N 70 31 1.810 W 148 47 18.666 17619.99 76.95 319.67 7115.03 7170.94 15017.25 15063.22 15019.48 9431.24 - 11689.16 0.38 6040318.43 647932.42 N 70 31 2.509 W 148 47 20.460 17711.52 76.99 320.24 7135.66 7191.57 15104.46 15152.39 15107.01 9499.50 - 11746.54 0.61 6040385.44 647873.60 N 70 31 3.179 W 148 47 22.154 17811.09 76.93 319.67 7158.13 7214.04 15199.33 15249.39 15202.24 9573.76 - 11808.95 0.56 6040458.34 647809.61 N 70 31 3.908 W 148 47 23.996 17899.91 76.82 319.69 7178.30 7234.21 15284.01 15335.89 15287.26 9639.71 - 11864.92 0.13 6040523.07 647752.24 N 70 31 4.556 W 148 47 25.648 18000.70 76.74 319.65 7201.35 7257.26 15380.07 15434.01 15383.72 9714.51 - 11928.42 0.09 6040596.48 647687.15 N 70 31 5.291 W 148 47 27.523 18095.93 76.46 318.89 7223.42 7279.33 15470.89 15526.65 15474.93 9784.71 - 11988.86 0.83 6040665.36 647625.21 N 70 31 5.980 W 148 47 29.307 18190.57 77.01 317.83 7245.13 7301.04 15561.47 15618.76 15565.88 9853.55 - 12050.07 1.24 6040732.86 647562.55 N 70 31 6.656 W 148 47 31.114 18285.72 77.13 317.09 7266.43 7322.34 15652.92 15711.50 15657.68 9921.88 - 12112.77 0.77 6040799.82 647498.40 N 70 31 7.327 W 148 47 32.965 18381.11 77.22 316.99 7287.60 7343.51 15744.76 15804.51 15749.85 9989.95 - 12176.15 0.14 6040866.50 647433.57 N 70 31 7.996 W 148 47 34.836 18476.25 77.16 316.57 7308.69 7364.60 15836.42 15897.28 15841.85 10057.55 - 12239.68 0.44 6040932.72 647368.61 N 70 31 8.659 W 148 47 3 12 18570.77 77.13 315.03 7329.72 7385.63 15927.69 15989.43 15933.43 10123.62 - 12303.93 1.59 6040997.38 647302.96 N 70 31 9.308 W 148 47 18666.11 77.07 313.37 7351.01 7406.92 16020.06 16082.37 16026.04 10188.40 - 12370.55 1.70 6041060.72 647234.97 N 70 31 9.944 W 148 47 . 4 18761.97 76.99 311.55 7372.53 7428.44 16113.18 16175.78 16119.33 10251.46 - 12439.46 1.85 6041122.28 647164.72 N 70 31 10.563 W 148 47 42.608 18855.87 77.01 309.98 7393.65 7449.56 16204.56 16267.27 16210.79 10311.20 - 12508.76 1.63 6041180.51 647094.16 N 70 31 11.150 W 148 47 44.653 18948.78 77.13 308.47 7414.44 7470.35 16295.08 16357.83 16301.34 10368.46 - 12578.90 1.59 6041236.25 647022.81 N 70 31 11.712 W 148 47 46.723 • 19044.23 77.21 307.05 7435.64 7491.55 16388.15 16450.89 16394.37 10425.45 - 12652.48 1.45 6041291.64 646948.03 N 70 31 12.271 W 148 47 48.894 19139.27 77.13 305.49 7456.74 7512.65 16480.77 16543.56 16486.88 10480.27 - 12727.19 1.60 6041344.83 646872.16 N 70 31 12.809 W 148 47 51.098 19234.47 77.16 303.98 7477.93 7533.84 16573.44 16636.38 16579.38 10533.15 - 12803.46 1.55 6041396.06 646794.78 N 70 31 13.327 W 148 47 53.349 19328.59 76.99 302.20 7498.98 7554.89 16664.85 16728.11 16670.55 10583.23 - 12880.31 1.85 6041444.47 646716.87 N 70 31 13.819 W 148 47 55.616 19423.24 77.28 302.28 7520.05 7575.96 16756.67 16820.38 16762.11 10632.46 - 12958.36 0.32 6041492.01 646637.79 N 70 31 14.301 W 148 47 57.919 19518.28 77.22 301.95 7541.03 7596.94 16848.90 16913.08 16854.07 10681.74 - 13036.87 0.34 6041539.58 646558.24 N 70 31 14.785 W 148 48 0.235 19613.60 77.30 301.78 7562.05 7617.96 16941.35 17006.05 16946.26 10730.82 - 13115.83 0.19 6041586.95 646478.25 N 70 31 15.266 W 148 48 2.565 19708.23 77.48 301.76 7582.71 7638.62 17033.17 17098.40 17037.81 10779.44 - 13194.34 0.19 6041633.87 646398.72 N 70 31 15.743 W 148 48 4.881 19801.41 77.46 301.66 7602.92 7658.83 17123.60 17189.36 17127.99 10827.25 - 13271.73 0.11 6041680.01 646320.33 N 70 31 16.212 W 148 48 7.164 19897.14 77.10 301.66 7624.00 7679.91 17216.42 17282.74 17220.57 10876.27 - 13351.21 0.38 6041727.30 646239.82 N 70 31 16.692 W 148 48 9.509 19992.01 77.02 301.74 7645.25 7701.16 17308.34 17375.20 17312.25 10924.85 - 13429.88 0.12 6041774.18 646160.13 N 70 31 17.169 W 148 48 11.830 20009.24 77.07 301.84 7649.11 7705.02 17325.04 17391.99 17328.90 10933.70 - 13444.15 0.64 6041782.71 646145.68 N 70 31 17.256 W 148 48 12.251 20104.35 77.19 301.71 7670.29 7726.20 17417.23 17484.72 17420.87 10982.52 - 13522.97 0.18 6041829.83 646065.83 N 70 31 17.734 W 148 48 14.577 20199.85 77.34 301.53 7691.35 7747.26 17509.82 17577.87 17513.23 11031.36 - 13602.29 0.24 6041876.95 645985.48 N 70 31 18.213 W 148 48 16.917 20294.84 77.30 301.53 7712.20 7768.11 17601.92 17670.54 17605.12 11079.82 - 13681.29 0.04 6041923.70 645905.47 N 70 31 18.688 W 148 48 19.248 20390.68 76.93 301.75 7733.57 7789.48 17694.78 17763.97 17697.78 11128.83 - 13760.83 0.45 6041970.98 645824.90 N 70 31 19.169 W 148 48 21.594 20485.42 76.85 301.31 7755.06 7810.97 17786.48 17856.24 17789.27 11177.09 - 13839.47 0.46 6042017.53 645745.24 N 70 31 19.642 W 148 48 20580.38 76.88 301.17 7776.64 7832.55 17878.33 17948.71 17880.92 11225.05 - 13918.54 0.15 6042063.78 645665.17 N 70 31 20.112 W 148 48 8 20674.84 76.75 301.07 7798.18 7854.09 17969.66 18040.68 17972.05 11272.58 - 13997.28 0.17 6042109.60 645585.43 N 70 31 20.578 W 148 48 28.571 20769.72 76.63 300.98 7820.03 7875.94 18061.32 18133.01 18063.53 11320.17 - 14076.40 0.16 6042155.48 645505.31 N 70 31 21.045 W 148 48 30.906 20864.01 76.72 301.08 7841.76 7897.67 18152.41 18224.76 18154.44 11367.46 - 14155.02 0.14 6042201.07 645425.70 N 70 31 21.509 W 148 48 33.225 20958.41 76.63 300.59 7863.52 7919.43 18243.57 18316.62 18245.43 11414.55 - 14233.89 0.51 6042246.44 645345.84 N 70 31 21.970 W 148 48 35.553 21053.99 76.72 300.49 7885.54 7941.45 18335.81 18409.63 18337.49 11461.81 - 14314.00 0.14 6042291.97 645264.74 N 70 31 22.433 W 148 48 37.916 21148.77 76.76 300.25 7907.28 7963.19 18427.27 18501.88 18428.78 11508.45 - 14393.59 0.25 6042336.88 645184.17 N 70 31 22.891 W 148 48 40.265 21244.09 76.87 300.79 7929.03 7984.94 18519.30 18594.69 18520.66 11555.58 - 14473.54 0.56 6042382.28 645103.23 N 70 31 23.353 W 148 48 42.624 21339.09 76.96 301.31 7950.53 8006.44 18611.17 18687.22 18612.39 11603.31 - 14552.81 0.54 6042428.29 645022.95 N 70 31 23.821 W 148 48 44.963 21434.34 77.08 301.99 7971.93 8027.84 18703.43 18780.04 18704.54 11652.01 - 14631.83 0.71 6042475.28 644942.92 N 70 31 24.298 W 148 48 47.295 21530.36 75.73 302.93 7994.50 8050.41 18796.34 18873.37 18797.34 11702.10 - 14710.57 1.70 6042523.66 644863.12 N 70 31 24.789 W 148 48 49.619 21624.62 74.16 303.23 8018.98 8074.89 18887.04 18964.39 18887.96 11751.78 - 14786.84 1.69 6042571.69 644785.81 N 70 31 25.276 W 148 48 51.870 21722.22 72.81 303.95 8046.73 8102.64 18980.34 19057.96 18981.19 11803.54 - 14864.79 1.55 6042621.76 644706.77 N 70 31 25.784 W 148 48 54.170 SurveyEditor Ver SP 2.1 Bld( users) NS33 \NS33 \NS33A \NS33A Generated 6/2/2009 10:59 AM Page 5 of 7 21816.79 70.98 304.70 8076.11 8132.02 19070.05 19147.84 19070.84 11854.23 - 14939.02 2.08 6042670.83 644631.47 N 70 31 26.281 W 148 48 56.361 21911.66 68.30 305.45 8109.12 8165.03 19158.87 19236.78 19159.62 11905.33 - 15011.81 2.92 6042720.35 644557.61 N 70 31 26.782 W 148 48 58.509 22006.38 65.44 305.07 8146.32 8202.23 19245.88 19323.88 19246.59 11955.61 - 15082.92 3.04 6042769.09 644485.44 N 70 31 27.275 W 148 49 0.609 22101.51 62.94 304.65 8187.74 8243.65 19331.39 19409.51 19332.06 12004.56 - 15153.19 2.66 6042816.51 644414.14 N 70 31 27.755 W 148 49 2.683 22196.52 60.89 304.54 8232.46 8288.37 19415.07 19493.33 19415.69 12052.15 - 15222.18 2.16 6042862.61 644344.14 N 70 31 28.222 W 148 49 4.719 22292.03 59.09 304.32 8280.23 8336.14 19497.62 19576.03 19498.20 12098.91 - 15290.40 1.90 6042907.89 644274.94 N 70 31 28.680 W 148 49 6.733 22387.11 57.11 303.34 8330.47 8386.38 19578.13 19656.75 19578.67 12143.85 - 15357.44 2.26 6042951.38 644206.95 N 70 31 29.121 W 148 49 8.712 22481.93 55.65 302.75 8382.97 8438.88 19656.80 19735.70 19657.29 12186.91 - 15423.63 1.62 6042993.00 644139.86 N 70 31 29.543 W 148 49 10.665 22576.84 54.32 302.24 8437.43 8493.34 19734.18 19813.43 19734.62 12228.67 - 15489.18 1.47 6043033.34 644073.43 N 70 31 29.952 W 148 49 12.600 22672.38 53.28 302.40 8493.86 8549.77 19810.91 19890.53 19811.30 12269.89 - 15554.34 1.10 6043073.14 644007.41 N 70 31 30.356 W 148 49 14.523 22767.63 52.00 302.35 8551.65 8607.56 19886.27 19966.23 19886.61 12310.43 - 15618.28 1.34 6043112.29 643942.62 N 70 31 30.754 W 148 49 16.410 22862.07 51.07 302.58 8610.40 8666.31 19959.88 20040.18 19960.18 12350.12 - 15680.66 1.00 6043150.63 643879.40 N 70 31 31.143 W 148 49 18.252 22955.67 49.77 302.62 8670.04 8725.95 20031.71 20112.32 20031.97 12388.98 - 15741.44 1.39 6043188.18 643817.81 N 70 31 31.524 W 148 49 20.045 23050.39 48.34 304.54 8732.11 8788.02 20103.04 20183.86 20103.27 12428.54 - 15801.04 2.15 6043226.44 643757.37 N 70 31 31.911 W 148 49 21.805 23145.27 46.55 305.56 8796.28 8852.19 20172.84 20253.75 20173.06 12468.67 - 15858.26 2.05 6043265.33 643699.30 N 70 31 32.305 W 148 49 23.494 23240.35 43.82 304.75 8863.28 8919.19 20240.20 20321.19 20240.40 12507.51 - 15913.40 2.93 6043302.97 643643.35 N 70 31 32.686 W 148 49 25.122 23335.95 41.05 304.48 8933.83 8989.74 20304.60 20385.69 20304.78 12544.15 - 15966.48 2.90 6043338.47 643589.50 N 70 31 33.045 W 148 49 2 9 23430.78 37.73 304.60 9007.11 9063.02 20364.66 20445.86 20364.83 12578.27 - 16016.04 3.50 6043371.50 643539.22 N 70 31 33.379 W 148 49 23525.64 34.36 306.38 9083.80 9139.71 20420.41 20501.67 20420.58 12610.64 - 16061.50 3.72 6043402.89 643493.08 N 70 31 33.697 W 148 49 2 . 4 8 -5/8" © 23540'md 23620.63 33.69 308.46 9162.53 9218.44 20473.56 20554.81 20473.72 12642.92 - 16103.71 1.41 6043434.26 643450.18 N 70 31 34.013 W 148 49 30.740 23715.63 34.12 307.96 9241.38 9297.29 20526.55 20607.81 20526.71 12675.70 - 16145.35 0.54 6043466.13 643407.85 N 70 31 34.335 W 148 49 31.970 23809.89 33.92 310.15 9319.51 9375.42 20579.27 20660.54 20579.43 12708.92 - 16186.30 1.32 6043498.46 643366.20 N 70 31 34.661 W 148 49 33.179 23904.36 33.45 311.84 9398.12 9454.03 20631.58 20712.93 20631.76 12743.29 - 16225.84 1.11 6043531.96 643325.93 N 70 31 34.998 W 148 49 34.347 23999.20 33.33 311.37 9477.31 9533.22 20683.67 20765.12 20683.85 12777.94 - 16264.87 0.30 6043565.77 643286.17 N 70 31 35.338 W 148 49 35.500 24095.09 33.37 310.50 9557.41 9613.32 20736.31 20817.84 20736.51 12812.48 - 16304.70 0.50 6043599.44 643245.62 N 70 31 35.677 W 148 49 36.676 24205.85 32.26 310.64 9650.49 9706.40 20796.27 20877.86 20796.48 12851.52 - 16350.29 1.00 6043637.49 643199.20 N 70 31 36.060 W 148 49 38.022 24300.69 31.74 310.57 9730.92 9786.83 20846.47 20928.12 20846.69 12884.23 - 16388.45 0.55 6043669.37 643160.35 N 70 31 36.380 W 148 49 39.149 24395.31 32.25 310.49 9811.16 9867.07 20896.55 20978.25 20896.78 12916.81 - 16426.55 0.54 6043701.12 643121.56 N 70 31 36.700 W 148 49 40.275 24489.34 32.02 309.85 9890.79 9946.70 20946.53 21028.27 20946.77 12949.07 - 16464.77 0.44 6043732.55 643082.66 N 70 31 37.016 W 148 49 41.404 24583.23 31.48 310.20 9970.63 10026.54 20995.90 21077.67 20996.15 12980.84 - 16502.60 0.61 6043763.50 643044.15 N 70 31 37.328 W 148 49 42.521 24678.69 30.99 310.26 10052.25 10108.16 21045.36 21127.18 21045.62 13012.81 - 16540.39 0.51 6043794.65 643005.68 N 70 31 37.642 W 148 49 43.637 24773.36 30.51 310.35 10133.61 10189.52 21093.72 21175.58 21093.99 13044.12 - 16577.31 0.51 6043825.15 642968.11 N 70 31 37.949 W 148 49 44.727 24869.34 30.03 310.38 10216.50 10272.41 21142.06 21223.96 21142.33 13075.46 - 16614.17 0.50 6043855.69 642930.58 N 70 31 38.256 W 148 49 45.816 24962.98 29.32 310.26 10297.86 10353.77 21188.38 21270.32 21188.66 13105.45 - 16649.52 0.76 6043884.91 642894.60 N 70 31 38.550 W 148 49 46.860 25058.10 28.68 309.65 10381.06 10436.97 21234.46 21316.43 21234.75 13135.07 - 16684.86 0.74 6043913.76 642858.63 N 70 31 38.841 W 148 49 47.904 25153.48 28.14 309.88 10464.95 10520.86 21279.82 21361.81 21280.12 13164.10 - 16719.75 0.58 6043942.03 642823.13 N 70 31 39.126 W 148 49 48.934 25248.25 27.64 309.79 10548.71 10604.62 21324.12 21406.14 21324.43 13192.49 - 16753.79 0.53 6043969.69 642788.49 N 70 31 39.404 W 148 49 49.940 25342.54 27.32 310.29 10632.36 10688.27 21367.60 21449.65 21367.92 13220.48 - 16787.10 0.42 6043996.95 642754.59 N 70 31 39.679 W 148 49 50. 24 25437.75 26.82 310.11 10717.14 10773.05 21410.89 21492.98 21411.22 13248.45 - 16820.19 0.53 6044024.20 642720.91 N 70 31 39.953 W 148 49 , 1 25512.57 26.76 310.08 10783.93 10839.84 21444.59 21526.70 21444.92 13270.17 - 16845.99 0.08 6044045.36 642694.65 N 70 31 40.166 W 148 49 3 6 -5/8" © 25582'md 25647.38 26.53 310.77 10904.42 10960.33 21504.99 21587.16 21505.34 13309.37 - 16892.01 0.29 6044083.56 642647.80 N 70 31 40.551 W 148 49 54.022 25741.92 27.73 310.04 10988.56 11044.47 21548.06 21630.27 21548.41 13337.31 - 16924.84 1.32 6044110.78 642614.38 N 70 31 40.825 W 148 49 54.992 25836.87 27.59 311.39 11072.66 11128.57 21592.08 21674.35 21592.45 13366.06 - 16958.25 0.68 6044138.80 642580.36 N 70 31 41.107 W 148 49 55.979 25930.90 28.62 318.21 11155.62 11211.53 21635.99 21718.60 21636.38 13397.26 - 16989.60 3.59 6044169.32 642548.35 N 70 31 41.413 W 148 49 56.905 Last Survey 26036.73 30.48 323.19 11247.70 11303.61 21686.83 21770.77 21687.30 13437.65 - 17022.59 2.91 6044208.99 642514.51 N 70 31 41.809 W 148 49 57.880 TD 26090.00 30.48 323.19 11293.61 11349.52 21712.89 21797.79 21713.41 13459.29 - 17038.78 0.00 6044230.27 642497.86 N 70 31 42.022 W 148 49 58.359 Survey Type: Definitive Survey NOTES: GYD GC SS - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - (In- field referenced MWD with mult- station analysis and correction applied in post - processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) SurveyEditor Ver SP 2.1 Bld( users) NS33 \NS33 \NS33A \NS33A Generated 6/2/2009 10:59 AM Page 6 of 7 Legal Description: Northing (Y) fftUS1 Eastinq (XI fftUS1 Surface : 1368 FSL 650 FEL S11 T13N R13E UM 6031141.30 659820.74 Tie -In : 1369 FSL 650 FEL S11 T13N R13E UM 6031141.59 659820.83 BHL : 4248 FSL 1838 FEL S32 T14N R13E UM 6044230.27 642497.86 • • SurveyEditor Ver SP 2.1 Bld( users) NS33 \NS33 \NS33A \NS33A Generated 6/2/2009 10:59 AM Page 7 of 7 I bp Date: 06 -16 -2009 Transmittal Number: 93076 • BPXA WELL DATA TRANSMITTAL RECENED Enclosed are the materials listed below. JUN 1 8 2009 Alaska Oil & Gas Cons. Commission If you have any questions, please contact Joe Lastufka at (907)564 -4091 Anchorage Delivery Contents Bottom SW Name Date Company Run Top Depth Depth Description i NS09 06 -07 -2009 PDS 1 12625 13349 CORRELATION LOG '� t STATIC TEMPERATURE/ �\ NS09 06 -07 -2009 PDS PRESSURE SURVEY CD -ROM — CORRELATION LOG AND STATIC TEMPERATURE /PRESSURE NS09 06 -07 -2009 PDS SURVEY MWD CALIPER MEASURED NS33A 04 -16 -2009 SCH 3 -6 684 26090 DEPTH LOG MWD TRUE VERTICAL NS33A 04 -16 -2009 SCH 3 -6 684 26090 DEPTH LOG 9915 �1`� MWD MEASURED DEPTH NS33A 04 -16 -2009 SCH 3 -6 684 26090 LOG CD -ROM - MWD CALIPER MEASURED DEPTH LOG, MWD TVD LOG, AND MWD 1/5 <° NS33A 04 -16 -2009 SCH MEASURED DEPTH LOG ULTRASONIC CEMENT/ 1 NS33A 04 -14 -2009 SCH 1 200 14100 CORROSION EVALUATION I i6 1° CD -ROM — ULTRASONIC CEMENT /CORROSION 1 i `D' NS33A 04 -14 -2009 SCH EVALUATION CD -ROM — LDWG EDIT OF USIT PDC GAMMA RAY IN TIF FORMAT WITH FINAL PDS NS33 01 -29 -2009 SCH DISPLAY STETHOSCOPE 475 FORMATION PRESSURE NS33A 04 -19 -2009 SCH 6 25567 26045 WHILE DRILLING CD -ROM — STETHOSCOPE 475 FORMATION PRESSURE NS33A 04 -14 -2009 SCH WHILE DRILLING DIRECTIONAL SURVEY NS33A 04 -18 -2009 SCH 1 0 26090 REPORT CD -ROM — DIRECTIONAL NS33A 04 -16 -2009 SCH SURVEY REPORT Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519 -6612 . • bp Date: 06 -16 -2009 Transmittal Number: 93077 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Joe Lastufka at (907)564 -4091 Delivery Contents Bottom SW Name Date Company Run Top Depth Depth Description NS33A P 4 -20 -2009 HAL END OF WELL REPORT RECEIVED Please Sign and Return one copy of this transmittal. JUN 1 8 2009 Thank You, Joe Lastufka Ai Oil & Gas Cons. Commission Petrotechnical Data Center Anchorage BPXA David Fair AOGCC Christine Mahnken DNR Corazon Manaois Murphy Exploration Ignacio Herrera MMS Doug Chromanski Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519 -6612 NS33A Proposed Completion 5 09 Page 1 of 2 • Maunder, Thomas E (DOA) From: Allen, Kenneth W [Kenneth.Allen @bp.comj Sent: Wednesday, May 06, 2009 9:43 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: RE: NS33A (208 -189) Proposed Completion 5/5/09 Thanks for reviewing our request. We will move ahead as outlined below and shown in the new completion schematic on the previous communication. All of the swell packers that will be run in this well will be hydrocarbon activated. We plan to spot a pill in the swell packer interval that contains hydrocarbons (in the form of lubricants) to ensure they are activated and swell. The swell packer material (rubber) will make contact and start the sealing in about 13 days with the hydrocarbons in our current mud and pill. A leak or flow will not be needed to activate the swell packer. If you have any further questions please feel free to contact me. Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen @BP.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, May 06, 2009 9:16 AM To: Allen, Kenneth W Cc: Kara, Danny T Subject: RE: NS33A (208 -189) Proposed Completion 5/5/09 Ken, Thanks for the information; lots of pieces and parts as we discussed. The intent of all the work accomplished so far and planned is to provide isolation between the various formations. Swell packers have been employed within productive intervals, but this may be the first application between intervals. How will the swell packer be activated; by the fluid in the hole or will a "leak" be needed for flow? Good luck with the work. Call or message with any questions. Tom Maunder, PE AOGCC From: Allen, Kenneth W [mailto:Kenneth.Allen @bp.com] Sent: Tuesday, May 05, 2009 2:26 PM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: NS33A Proposed Completion 5/5/09 Tom, We have recently ran and cemented the planned 6 -5/8" scab liner on the Northstar well NS33A. We just drilled 6/16/2009 NS33A Proposed Completion 5/,5,0 9 Page 2 of 2 • the shoe track of this scab liner and found the liner lap to be leaking around mid day today. From our previous correspondence earlier this year you'll remember the 6 -5/8" x 8 -5/8" liner lap is not sealed with a liner top packer. The plan was to isolate this with a cemented 6 -5/8" scab liner. BP would like to modify our completion plan to provide the required formation isolation. This plan will provide isolation between the Kuparuk and Sag River by utilizing a 30' Swell packer in the 6 -5/8" x 4 -1/2" annulus. The Inner Annulus will then be isolated from the Kuparuk by the liner top packer. Essentially we plan to bring the 4- 1/2" x 6 -5/8" liner top packer -150' above the leaking liner lap. The swell packer will be placed below the leaking liner lap, but above the 6 -5/8" shoe and top of Sag River. I have attached a schematic to help explain our new plan. Please review the new attachment. I would like to discuss this with you when you have a few spare moments this afternoon. I can be reached on my cell phone at 748 -3907. We currently have a CIBP just above the 6 -5/8" shoe isolating the well bore from the Sag and Ivishak formation. I have asked the rig to hold off drilling this plug up to make sure the AOGCC did not have any concerns about our new completion plan. Thanks in advance for your time, «NS33A Prop Comp DRAFT 5_5_09.ZIP» Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen@BP.com 6/16/2009 TREE= ABB-VGI 5 1/8" 5k 0 NS33A • WELLHEAD = ABB -VGI 13 5/8" ACTUATOR= DRAFT Propose" Completion KB. ELEV = 56.6 J BF. ELEV = 0 1000 H 4.5" SLB TRM4ETRSSSV KOP = 300 2866 H 4.5" HES "X" Nipple Superl3Cr, ID = 3.813" I Max Angle = 78 @ 15600' IIIN Datum MD = I I Datum TV D = / 1 –10000 H 11 -3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR 1 116" CSG, 84 #, HCL -80, BTC, ID= 15.010" H 4472' — – 14241 H 11 -3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR 1 111 3/4" Whipstock H – 15050 I 4 -1/2` 13Cr95 12.6 #, 3.833" Drift -6,500 11 3/4" HES EZSV H -15076 6 -5/8" 24 #, L -80, HYD521 Scab hilib LNR (TOC - 11,000' MD) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2766 2486 50 MMG Spr 13Cr DV 1.5 11/03/08 'Estimated 10 5/8" CSG PBTD H 16243' I 39 BBLS placed on top of Retainer CBU performed at 16,243' in green cemen 11 3/4" HES EZSV Cement Retainer H 16415' I 11 3/4" Csg, 60# S -95, Hydril 563. ID = 10.772" H 16491' I — -22,867' Est TOC 274 BBLS Squeezed below Retainer -2,431 feet equivalent within 10 -5/8" hole or - 18,846' MD NS33 KOP - 21,828' ; 4-1/2" 12.6 #, 9Cr, X Nipple NS33PB1 23,236' ID = 3.813" @ - 23,261' NS33 23,460' 4 -1/2" 12.6 #, 9Cr, XN Nipple 1 iiii. � ID = . 3.725" @ -23,321' [ 7" 38# x 4-1/2" BKR ZXP PKR/FL HGR w /Tieback H 23191' 1 3 - ", 1 al As Baker 3 5/8" Seal sy -23,111' 6 5/8" BKR TieBack Sleave L -80 H 23341' I / -1/2" Liner will have a Baker 18 5/8" LNR, 32# L -80, Hydril 521. ID = 7.921" H 23540' ] eal bore below the liner hanger 6 5/8" LNR, 24# L -80, Hydril 521. ID = 5.92" j--I 24447' I 4 1/2" Sw ell Packer ID = 3.958" H 25432' I 6 -5/8" Liner Lap Leaking 6 5/8" N 24# = 5/8" L NR, 2 # 13Cr80, Hydril 521. ID 5.92" H 25582' I Isolating Kuparuk from Sag P 9 4 1/2" Solid LNR, 12.6 #, 13Cr- 80,VamTop ID= 3.958'H 25743' I with a Swell Packer . 1 @ - 25,432` 4 1/2" Sw ell Packer ID = 3.958" H 25743' I , Top Kuparuk 23,367' 14 1/2" Swell Packer ID = 3.958" H 25844' I / Top Sag River 25,574' 14 1/2" Slotted LNR,12.6 #,13Cr- 80,VamTopID= 3.958' 25844' I 14 1/2" Solid LNR, 12.6 #, 13Cr- 80,VamTop ID= 3.958'1 –{ 25918' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/08 KWA SUSPENDED (NS33) WELL: NS -33A 10/30/08 KWA NS33 Proposed P &A PERMIT No: ? ?? 05/05/09 KWA NS33A Proposed Completion API No: 50- 029 - 23325 -01 -00 SEC:11, T13N, R13E, 1369' FSL, 650' FEL BP Exploration (Alaska) NS -33A Well Control • Page 1 of 2 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, May 05, 2009 2:27 PM To: Maunder, Thomas E (DOA); Aubert, Winton (DOA sponsored) Subject: FW: NS -33A Well Control Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSU, ADW DrIg Rig 33E [ mailto:NSUADWDrIgRig33E @BP.com] Sent: Tuesday, May 05, 2009 12:44 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Fleckenstein, Robert J (DOA) Cc: Allen, Kenneth W; Rall, John R; Kara, Danny T Subject: NS -33A Well Control Gents, On NS -33A we had ran in the hole with a clean out drilling assembly to clean out the 6 -5/8 scab liner. Cement was tagged 21,065 and a 3500 psi 10 min test was perform with 9.7 ppg FIo -Pro Mud system. Mud system was then displace to 8.6 ppg seawater Biozan system to drill out the cement. A successful 10 min pressure test had been performed at a MD of 23,250' 30' above the landing collar prior to drilling out the float equipment with 8.6 ppg Boizan system. Float equipment was then drilled out and the assembly was run in the hole to 23,569' MD where the well was observed flowing and shut in on 5/4/2009 at 14:00 hrs. Pressures were monitored and stabilized at SIDPP = 270 psi / SICP = 230 psi. FIo -Pro mud system was weighted up to 9.7 ppg. The 9.7 ppg kill weight fluid was circulated around using the wait & weight method with 9.6+ ppg fluid back to surface @ 02:10 hrs on 5/5/09. Choke was opened with no flow back. Well was opened up and monitored. A bottom up was then circulated until a solid 9.7 ppg mud weight in and out was recorded. Well was then monitored. Well Static. Notifications were made to AOGCC State inspector Bob Noble when well was shut in and at completion of well kill operations. Regards, Chris Clemens Well Site Leader - Nabors 33E Phone (907) 670 -3686 Fax (907) 670 -3687 6/16/2009 NS33A BOPE Test Extension e/09) • Page 1 of 5 Maunder, Thomas E (DOA) From: Allen, Kenneth W [Kenneth.Allen @bp.com] Sent: Tuesday, April 07, 2009 1:54 PM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T; Crane, Lowell R Subject: RE: NS33A BOPE Test Extension (4/3/09) Thank you sir. We will proceed as outlined below. Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen(a�BP.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, April 07, 2009 1:46 PM To: Allen, Kenneth W Cc: Kara, Danny T; Crane, Lowell R Subject: RE: NS33A BOPE Test Extension (4/3/09) Ken, et al, Thanks for the additional information. I have apprised Commissioner Foerster of you plans and there is no objection. Isolation of the annulus external to the liner should be achieved by the collapse of the shales and the scab cementing. Good luck with the operations. Tom Maunder, PE AOGCC From: Allen, Kenneth W [mailto:Kenneth.Allen @bp.com] Sent: Tuesday, April 07, 2009 1:01 PM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T; Crane, Lowell R Subject: RE: NS33A BOPE Test Extension (4/3/09) Tom, The majority of Kuparuk is below the 8 -5/8" shoe. The Mud Loggers reported no shows while the Kuparuk formation was drilled. There were slightly elevated gas readings (above background) in the thin sands. Gas was a few 100 units above background. The MWD tools used while drilling was GR, RES and a caliper. It is not interpreted to be a significant hydrocarbon bearing zone. The plan forward is as follows: ➢ POOH without pumping cement o We anticipate the Kingak to collapse around the 6 -5/8" liner once the mud weight is lowered to drill the production interval. There is a high likely hood the Kingak has already collapsed because 4/7/2009 NS33A BOPE Test Extension 1/09) • Page 2 of 5 we cannot circulate with returns at this time. ➢ Perform BOPE testing once on surface ➢ PU Drilling BHA and RIH as per original drilling permit We do not plan to pump cement to isolate the Sag River. The Kingak formation collapsing will provide isolation once hydrostatic pressure has dropped by reducing the mud weight from 12.5 ppg to 9.5 ppg. The Kuparuk will be isolated from the Sag by the Kingak formation. The Kuparuk will also be isolated from above by the 6 -5/8" scab liner that will be run and fully cemented at a later date. The attached schematic should help explain the plan. Please give me a call if this is not acceptable or you would like more information. Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen @BP.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, April 07, 2009 11:53 AM To: Allen, Kenneth W Cc: Kara, Danny T; Crane, Lowell R Subject: RE: NS33A BOPE Test Extension (4/3/09) Ken, Is there Kuparuk below the 8 -5/8" shoe? Was the Kuparuk hydrocarbon bearing? Tom From: Allen, Kenneth W [mailto:Kenneth.Allen @bp.com] Sent: Tuesday, April 07, 2009 11:42 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T; Crane, Lowell R Subject: RE: NS33A BOPE Test Extension (4/3/09) Tom, The e -mail below explains BP's plans after a day of trying to regain circulation that would allow a cement job to be pumped. I have attached a schematic as you requested. I have deleted a few items on the completion to allow you to see the formation depths and pertinent items for this 6 -5/8" job. Background Info • An underreamer was utilized drilling this interval that opened the hole to 9" y The underreamer was drilled to the Top Sag River o Top Sag River 25,570' ➢ The pilot hole below the underreamer was 7 -7/8" o The pilot hole is about 41' o TD of this hole section is 25,611' A summary of the operation since yesterday are listed below ➢ Run liner —12' into the Sag River formation 4/7/2009 NS33A BOPE Test Extension 609) • Page 3 of 5 The liner packed off stopping the ability to circulate • Circulation to a rate that would allow pumping cement has been unsuccessful to this point o The last attempt to circulate broke down the Sag with Zero returns to surface • The attempt to emergency release from the liner has been attempted, but due to a Drill Pipe stretch of 30' we are unable to confirm the ability to completely get off the liner without the possibility of pulling the "pack off tool" out of the liner tie back sleeve. The big concern from BP's perspective is pumping cement and ending up with it on the back side of our Drill Pipe. We are concerned about the ability to completely disconnect from the liner due to the Mud's Barite Sag issue you have seen in our drilling reports. The low flow rates we have been forced to use running this liner help to initiate Barite Sag. The annular clearance between 4 -1/2" DP and 8 -5/8" liner is rather tight. If Barite has accumulated in this liner it may impact our ability to pull away from the liner. If we have cement on the back side it could further complicate the issue. We also believe pumping / squeezing cement below the current 6 -5/8" shoe will not put cement behind the liner. It will just pumped into the Sag formation. We believe the Sag River is isolated from the Kuparuk formation with our current pack off situation. We further believe the Kingak will collapse on the 6 -5/8" liner (between the Sag and Kuparuk) as soon as the mud is swapped over to 9.5 ppg FloPro from the current 12.5 ppg LSND. This will further isolate the Kuparuk from the Sag. The Kingak will see this drop in hydrostatic pressure because there is not a Packer on the current liner. The 6 -5/8" scab liner stung into the tieback sleeve (with seals) will be fully cemented for —9,300' and a liner top Packer will be set on that. The 6 -5/8" scab liner will be run at a later date. The schematic on file along with the attached schematic should assist in explain what the well bore will look like at completion of this well. The proposed plan forward is as follows: ➢ Pull above the liner top and Circulate well bore clean • POOH without pumping Cement • Test BOPE y Pick up drilling BHA and get back on plan as per Drilling Permit Please give me a call as soon as you can review this or if you have any questions. The is rig is currently standing by awaiting orders from me. Thanks for your assistance, Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.AllenABP.com From: Allen, Kenneth W Sent: Monday, April 06, 2009 3:15 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)' Cc: NSU, ADW Drlg Rig 33E; Kara, Danny T; Crane, Lowell R; Rall, John R Subject: RE: NS33A BOPE Test Extension (4/3/09) Tom, As requested, below is a summary of our conversation. 4/7/2009 NS33A BOPE Test Extension 609) • Page 4 of 5 The Well Site Leader on Nabors 33 at Northstar requested and received a BOPE extension Friday (4/3/09) evening from the Northslope AOGCC inspector. We have run the 6 -5/8" drilling liner into the top Sag River, but packed after getting the shoe - 10' into the Sag formation. The good news is the Kingak formation is behind the liner. There is only about 30' of rat hole below the shoe current shoe depth. We are attempting to regain circulation and plan to pump the cement volume planned in the drilling permit. The volume we plan to pump would place the top of cement 500' above the Sag Formation. If you have any questions please give me a call on my cell phone (number listed below). Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen@BP.com From: Allen, Kenneth W Sent: Friday, April 03, 2009 2:28 PM To: 'Maunder, Thomas E (DOA)'; Regg, James B (DOA) Cc: NSU, ADW Drlg Rig 33E; Kara, Danny T; Crane, Lowell R; Rall, John R Subject: RE: NS33A BOPE Test Extension (4/3/09) Tom, We were on the bank on 4/1/09. At that time there did not appear to be an issue running short on time to get the liner to TD before the next BOPE test. We felt 5 days was plenty to run this liner to TD. We have had some unforeseen delays after picking, up the liner. The 4 -1/2" x 7" rams only had to be tested, not installed, so it was 1 hour vs 8 to 12 hours. We believe the Miluveach and Kingak are time sensitive and every hour counts. We would be willing to hang off on a storm packer after circulating out excess cement from the liner job if you felt that was required. Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.AllenRBP.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, April 03, 2009 2:06 PM To: Allen, Kenneth W; Regg, James B (DOA) Cc: NSU, ADW Drlg Rig 33E; Kara, Danny T; Crane, Lowell R; Rall, John R Subject: RE: NS33A BOPE Test Extension (4/3/09) Ken, et al, You point out that if all goes well, your request is a non - issue. However, it appears that it would have been appropriate to test the remainder of the BOPE when the 4 -1/2" x 7" rams were tested. It doesn't seem that a few 4/7/2009 NS33A BOPE Test Extension (0/09) . Page 5 of 5 additional hours could not have been spared there. Were you on the bank at some other time after 3/22? Tom Maunder, PE AOGCC From: Allen, Kenneth W [mailto:Kenneth.Allen @bp.com] Sent: Friday, April 03, 2009 1:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSU, ADW Drlg Rig 33E; Kara, Danny T; Crane, Lowell R; Rall, John R Subject: NS33A BOPE Test Extension (4/3/09) Tom / Jim, Nabors Rig 33E is currently drilling the Northstar well NS33A. The rig tested the top 4 -1/2" x 7" rams to 4,500 psi with a 6 -5/8" test joint on 4/1/05. Current operations are running in to the 7 -7/8" x 9" open hole with the 6 -5/8" liner. TD of this hole is in the top Sag River at 25,611' MD. If hole condition are good the estimated time line will be to have the 6 -5/8" liner to TD on Saturday 4/4/09. This interval at Northstar, through the Miluveach and Kingak, has historically been challenging and required washing and /or reaming to get to TD. The rig is due for a BOPE Test on 4/5/09 (Sunday). If operations go as planned, the rig may be back on surface by Sunday evening and an extension may not be required. As you know, this is a long reaching and challenging well. There is a chance operations could be delayed at some point while running the liner to TD. BP requests an extension to the 14 day BOPE testing interval on all the BOP equipment except the top 4 -1/2" x 7" variable rams. This will limit the time the hole is open and increase the chance to successfully run the 6 -5/8" liner through the Kingak formation. Once the liner is on bottom, cemented and liner running string is out of the hole, a full BOPE test will be conducted. Please let me know if you require further information before making a decision on this critical matter. I can be reached on my cell phone @ 748 -3907 if you would like to discuss anything. Thanks for your time, Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen@BP.com 4/7/2009 TREE= ABB-VG15 1/8" 5k WELLHEAD = ABB -VGI 13 5/8" NS33A ACTUATOR= Actual 6 -5/8" Liner KB. ELEV = 56.6 4 .5" SLB TRM4E TRSSSV BE ELEV = o L 1000 H I KOP = 300 Max Angle = 78 @ 15600' 2806 H HES "X" Nipple Super13Cr, ID = 3.813 Datum MD = • • DatumTVD= / -n4 -4 � – 14091 H 11 -3/4" x 9 -5/8" BKR ZXP/ Flex Lock PKR/HGR L6" CSG, 84 #, HCL -80, BTC, ID= 15.010" H 4472' — - -14244 H 11 -3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR I ll 3/4" Whipstock I — I 6 -5/8" 24 #, L -80, HYD521 Scab LNR full cemented 111 3/4" HES EZSV I I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2766 2486 50 MMG Spr 13Cr DV 1.5 11/03/08 Estimated 10 5/8" CSG PBTD I-- 16243' I 39 BBLS placed on top of Retainer CBU performed at 16,243' in green cement 11 3/4" HES EZSV Cement Retainer 16415' I 11 3/4" Csg, 60# S -95, Hydril 563. ID = 10.772" 16491' I — -- 22,867' Est TOC 274 BBLS Squeezed below Retainer -2,431 feet equivalent within 10 -5/8" hole or - 18,846' MD NS33 KOP - 21,828'\ NS33PB1 - 23,236' NS33 23,460' 1 A A Top Kup 23,367' I 6 5/8" BKR TieBack Sleave L -80 I 23332' I t Top Miluveach 23,946' 8 5/8" LNR, 32# L -80, Hydril 521. ID = 7.921" I– { I — Top Kingak 24,390' X — Collapse Kingak , 24,390`- 25,570' I 7" 38# BKR ZXP / FlexLock PKR/HGR w /Tieback I--I 25432' — Top Sag River 25,570' 6 5/8" LNR, 24# L -80, Hydril 521. ID = 5.92" H 25582' I ■ �4 1/2" Solid LNR, 12.6 #, 13Cr 80,VamTop ID= 3.958� 25791I1/2" Solid LNR, 12.6 #, 13Cr 80,VamTop ID= 3.95825791 I 4 1/2" Slotted LNR, 12.6 #,13Cr- 80,VamToplD= 3.958'H 25987' I J DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/08 KWA SUSPENDED (NS33) WELL: NS -33A 10/30/08 KWA NS33 Proposed P &A PERMIT No: ? ?? 11/03/08 KWA NS33A Proposed Completion API No: 50- 029 - 23325 -01 -00 SEC:11, T13N, R13E, 1369' FSL, 650' FEL BP Exploration (Alaska) NS33A 7 -7/8" x 9" FIT • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, March 23, 2009 11:08 AM To: 'Allen, Kenneth W' Cc: NSU, ADW Drlg Rig 33E; Kara, Danny T; Rall, John R; Crane, Lowell R Subject: RE: NS33A (208 -189) 7 -7/8" x 9" FIT Ken, et al, There is no regulatory requirement to test the OH integrity to leak off, either a LOT or a FIT is acceptable so long as the assessed integrity is sufficient for the anticipated conditions. It would appear that sufficient integrity has been established. Call or message with any questions. Tom Maunder, PE AOGCC From: Allen, Kenneth W [mailto:Kenneth.Allen @bp.com] Sent: Monday, March 23, 2009 10:53 AM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 33E; Kara, Danny T; Rall, John R; Crane, Lowell R Subject: NS33A 7 -7/8" x 9" FIT Tom, Attached is a rough outline of our operations on well Northstar 33A (NS33A). We have changed from a LOT to FIT due to encountering losses. Summary: 1. Could not run the 8 -5/8" Liner to TD of the 10 -5/8" hole 24,151' MD. The liner was cemented in place at 23,540' MD. 2. Drilled out 8 -5/8" shoe track and —611' of 10 -5/8" open hole with Dumb Iron BAH. No issue with losses or hole stability encountered. Performed a LOT to 14.5 ppg. 3. Weighted up the mud from 11 ppg to 13 ppg and encountered losses as the heavier mud was started to be seen at surface. There were some issues with Barite Sag and thick mud which increased ECD's to an unknown value above 14.5 ppg EMW. The BHA was pulled above the top of the 8 -5/8" liner to —14,100' in order to regain circulation. 4. The mud was dropped to 12 ppg and oil wet Barite was circulated out of the well bore. The BHA was staged into the hole circulating out Barite. An attempt to heal the losses with standard LCM (G -Seal, Calcium Carb and fibers) was initiated. 5. The first attempt appeared to have healed the losses to an acceptable rate. The BHA was RIH and 30' of new hole 7 -7/8" was drilled. A LOT was performed to 13.0 ppg. This is not high enough to drill TD through the Kingak. It appears that the fault was damaged with the high ECD spike during the weight up to 13ppg and started taking fluid. 6. A second attempt was made with standard LCM and the losses were still at an unacceptable rate. 3/23/2009 NS33A 7 -7/8" x 9" FIT • Page 2 of 2 7. A third LCM pill with new EZ Squeeze material was then pumped and squeezed into the loss zone. This pill was reamed out all the way to the TD of the new 30' of hole at 24,181' MD. A FIT was performed to 14.0 ppg. This is acceptable from a well control and max ECD perspective. BP plans to drill ahead with the 14.0 ppg FIT. A 14.00 ppg FIT will provide an Infinite Kick Tolerance. Please let me know if you have any concerns about our current plan forward of drilling to the Top of the Sag River with a 14.0 ppg FIT rather than taking it to leak off. We are afraid of damaging the fault zone again if it was taken to leak off pressure. Thanks, Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen @BP.com 3/23/2009 RE: BOPE test extension requ• • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, February 25, 2009 2:08 PM To: Allen, Kenneth W Cc: Lowell Crane (BP); Regg, James B (DOA) Subject: RE: BOPE test extension request Ken and Lowell, Jim and 1 have discussed your request. It is acceptable to proceed as you propose. This includes reducing the test pressure. This approval is for this action only. Good luck on getting the pipe run and cemented successfully. Tom Maunder, PE AOGCC From: Allen, Kenneth W [mailto:Kenneth.Allen @bp.com] Sent: Wednesday, February 25, 2009 8:33 AM To: Maunder, Thomas E (DOA) Subject: RE: BOPE test extension request Tom, I am sorry, but I forgot to request the change to the 8 -5/8" ram testing pressure in my previous e -mail. We would like to pressure test the 8 -5/8" rams to 3,700 psi rather than the BOPE test pressure of 4,500 psi. The reason behind this request is the 8 -5/8" 32# L -80 has a yield pressure rating of 5,710 psi. BP uses 80% of this number when we run our calculations. 80% of 5,710 psi is 4,568 psi. The maximum expected surface pressure for this interval is 3,676 psi (as per Drilling Permit Application). There has been no indication of hydrocarbons while drilling this interval. Please let me know if this is acceptable. Updated NS33A operations as of 6:00 am: The rig has just finished laying down the drilling BHA and preparing to install the 8 -5/8" rams. The trip out of the hole started on 2/21/09 and finished very early this morning. The 9,091' of open hole appears to be in decent shape, but it has been open since 2/9/09. I will call to follow up shortly and ensure you have all the information you require. Regards, Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen @BP.com 4/7/2009 RE: BOPE test extension requ• • Page 2 of 2 From: Allen, Kenneth W Sent: Tuesday, February 24, 2009 4:23 PM To: 'Maunder, Thomas E (DOA)' Subject: BOPE test extension request Tom, Rig Nabors 33E at Northstar is currently drilling NS33A. The rig has recently finished drilling the 1st intermediate 10 -5/8" hole section. The estimated time line will be to have the drilling BHA laid down late tonight. The rig will pull the 4 -1/2" x 7" VBR's from the top and install 8 -5/8" rams. Those will be tested prior to picking up the 8 -5/8" liner. The lower remaining VBR's will 3 -1/2" x 6 ". The rig is due for a BOPE Test on 2/27/09. If the liner running operations go as planned, the liner should be on bottom around the 27th or 28th of February. As you know, this is a very difficult well and the longest reaching well at Northstar. Running the 8 -5/8" liner to TD of this hole section is extremely critical to the success of this well. This was the hole section that was lost while drilling NS33 two years ago. BP requests an extension to the 14 day BOPE testing interval on all BOP equipment except the 8 -5/8" rams. This will limit the time the hole is open and allow the liner to be run in the open hole as quickly as possible. We have had no indication of hole breathing or other well control concerns while drilling this interval. Once the liner is on bottom, fully cemented and the liner running string is out of the hole, a full BOPE test will be conducted. Please let me know if you require further information before making a decision on this critical matter. I can be reached on my cell phone @ 748 -3907 if you would like to discuss anything. Thanks for your time, Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen_ BP.com 4/7/2009 RE: BOPE test extension request • Page 1 of 3 4 10 • Maunder, Thomas E (DOA) From: Allen, Kenneth W [Kenneth.Allen @bp.com] Sent: Wednesday, February 25, 2009 2:12 PM To: Maunder, Thomas E (DOA) Cc: Crane, Lowell R; Regg, James B (DOA); Kara, Danny T Subject: RE: BOPE test extension request . S-C Tom / Jim, ` Thank you for your help and review during this critical phase of operations on NS33A at Northstar. Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen @BP.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, February 25, 2009 2:08 PM To: Allen, Kenneth W Cc: Crane, Lowell R; Regg, James B (DOA) Subject: RE: BOPE test extension request Ken and Lowell, Jim and I have discussed your request. It is acceptable to proceed as you propose. This includes reducing the test pressure. This approval is for this action only. Good luck on getting the pipe run and cemented successfully. Tom Maunder, PE AOGCC From: Allen, Kenneth W [mailto:Kenneth.Allen @ bp.com] Sent: Wednesday, February 25, 2009 8:33 AM To: Maunder, Thomas E (DOA) Subject: RE: BOPE test extension request Tom, I am sorry, but I forgot to request the change to the 8 -5/8" ram testing pressure in my previous e -mail. We would like to pressure test the 8 -5/8" rams to 3,700 psi rather than the BOPE test pressure of 4,500 psi. The reason behind this request is the 8 -5/8" 32# L -80 has a yield pressure rating of 5,710 psi. BP uses 80% of this number when we run our calculations. 80% of 5,710 psi is 4,568 psi. The maximum expected surface pressure for this interval is 3,676 psi (as per Drilling Permit Application). There has been no indication of hydrocarbons while drilling this interval. Please let me know if this is acceptable. 2/25/2009 RE: BOPE test extension request Page 2 of 3 1. 1 Updated NS33A operations as of 6:00 am: The rig has just finished laying down the drilling BHA and preparing to install the 8 -5/8" rams. The trip out of the hole started on 2/21/09 and finished very early this morning. The 9,091' of open hole appears to be in decent shape, but it has been open since 2/9/09. I will call to follow up shortly and ensure you have all the information you require. - Regards, Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Alien @BP.com From: Allen, Kenneth W Sent: Tuesday, February 24, 2009 4:23 PM To: 'Maunder, Thomas E (DOA)' Subject: BOPE test extension request Tom, Rig Nabors 33E at Northstar is currently drilling NS33A. The rig has recently finished drilling the 1st intermediate 10 -5/8" hole section. The estimated time line will be to have the drilling BHA laid down late tonight. The rig will pull the 4 -1/2" x 7" VBR's from the top and install 8 -5/8" rams. Those will be tested prior to picking up the 8 -5/8" liner. The lower remaining VBR's will 3 -1/2" x 6 ". The rig is due for a BOPE Test on 2/27/09. If the liner running operations go as planned, the liner should be on bottom around the 27th or 28th of February. As you know, this is a very difficult well and the longest reaching well at Northstar. Running the 8 -5/8" liner to TD of this hole section is extremely critical to the success of this well. This was the hole section that was lost while drilling NS33 two years ago. BP requests an extension to the 14 day BOPE testing interval on all BOP equipment except the 8 -5/8" rams. This will limit the time the hole is open and allow the liner to be run in the open hole as quickly as possible. We have had no indication of hole breathing or other well control concerns while drilling this interval. Once the liner is on bottom, fully cemented and the liner running string is out of the hole, a full BOPE test will be conducted. Please let me know if you require further information before making a decision on this critical matter. I can be reached on my cell phone @ 748 -3907 if you would like to discuss anything. Thanks for your time, 2/25/2009 • Page 1 of 1 Maunder, Thomas E (DOA) From: Alien Kenneth W Kenneth.Allen b .com [ @ P ] Sent: Tuesday, December 09, 2008 10:45 AM To: Maunder, Thomas E (DOA) Subject: RE: NS -33A Attachments: Drilling Hazards and Contingencies.doc 151/ pkm -■.v Sorry for missing this on the original permit application. Attached is the H2S information and the NS33A Hazards sheet. Our estimated sidetracking operations start date is January 15, 2009. This date is estimated based on the Sundry 308 -401 work starting on or about January 1, 2009 and taking about 2 weeks to complete. The estimated time of starting pulling of the kill string operation is - January 7 2009. These dates are subject change depending on any delays while getting the N -33E rig warmed up for operations. Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen @BP,com From: Maunder, Thomas E (DOA) (mailto:tom.maunder @alaska.gov] Sent: Monday, December 08, 2008 3:49 PM To: Allen, Kenneth W Cc: Johnson, David A. (Fairweather); Kara, Danny T Subject: NS -33A Ken, I am reviewing the permit application. I don't find a drilling hazard sheet or any H2S information. Did I miss something? Could you please provide this information? When do you anticipate starting up the rig operations to pull the kill string? Thanks in advance. Tom Maunder, PE AOGCC 12/9/2008 Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 08, 2008 3:56 PM To: 'Allen, Kenneth W Cc: 'Johnson, David A. (Fairweather)'; 'Kara, Danny T' Subject: RE: NS -33A -- Again Ken, et al, Some good news; 1 believe the requested variance regarding liner rams is not necessary. Please examine the regulations. I believe the correct regulation is 20 AAC 25.035 (e)(1)(C) [(1) — (iv)] rather than 20 AAC 25.035 (e) ( Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, December 08, 2008 3:49 PM To: 'Allen, Kenneth W' Cc: 'Johnson, David A. (Fairweather)'; Kara, Danny T Subject: NS - 33A Ken, I am reviewing the permit application. I don't find a drilling hazard sheet or any H2S information. Did I miss something? Could you please provide this information? When do you anticipate starting up the rig operations to pull the kill string? Thanks in advance. Tom Maunder, PE AOGCC 12/8/2008 NS33A permitting question • Page 1 of 2 Maunder, Thomas E (DOA) From: Allen, Kenneth W [Kenneth.Allen @bp.com] Sent: Wednesday, November 19, 2008 10:11 AM To: Maunder, Thomas E (DOA) Subject: RE: NS33A permitting question Attachments: Completion Slide Question.ZIP Sorry, I forgot to add those depths to the schematic. I have added depths from our latest directional plan. The relative distances from the Sag, Shublik and Ivishak won't change much, but the actual MD's (due to up hole directional changes) will be different when we finalize it for the permit application. The short answers to your questions are listed below. The schematic has now been updated with depths of formations and liners etc to assist in explanation. None of the 4 -1/2" liner will be cemented There will be -183' MD / -152' TVD of solid, uncemented 4 -1/2" liner below the 6 -5/8" shoe. There will be -70' MD / -59' TVD of slotted 4 -1/2" liner below the solid pipe to TD above the Oil Water Contact. We anticipate the entire production hole to be about 250' - 300' if we stay above the Oil Water Contact on our final directional plan. Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.Allen @BP.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, November 19, 2008 9:41 AM To: Allen, Kenneth W Subject: RE: NS33A permitting question Hi Ken, should be in this afternoon. On first read, this doesn't sound out of bounds. Will the solid liner be cemented? How much length of solid liner will be below the 6 -5/8" shoe? Tom Maunder, PE AOGCC From: Allen, Kenneth W [mailto:Kenneth.Allen @bp.com] Sent: Wed 11/19/2008 9:38 AM To: Maunder, Thomas E (DOA) Subject: NS33A permitting question Tom, I decided I should send you a little background on the question so when we do get a chance to talk you have had 4/7/2009 NS33A permitting question • • Page 2 of 2 a little to time to think about my question. I do understand this is only a question and will NOT constitute an approval, but I wanted to discuss before wasting anyone's time with the official permit to drill application. As you know, we are planning to drill the NS33A sidetrack this year at Northstar. This will be the biggest and farthest reaching well at Northstar. I was told, but have not confirmed myself, it will be the longest Measured Depth well in Alaska at around 26,000' md. As you may remember we had some difficulty two drilling seasons ago and we are attempting to keep the complexity of all phases to minimum. We are using the KISS process as much as possible due to the fact we are pushing the capabilities (Torque & Drag wise) of the current NS33E rig etc. One risk we are trying to work through is the risked associated with running swell packers on the production liner to —26,000' md. I have been told the Sag and Ivishak are in the same pool for the state so we considering running a completion that is very similar to the Prudhoe slotted liner / non - cemented wells. My question is basically would the AOGCC have a problem with approving a permit at Northstar as follows: 6 -5/8" intermediate liner a the Top Sag River (6 -5/8" will be cemented) 4 -1/2" liner top packer / hanger —150' and above the 6 -5/8" shoe 4 -1/2" solid liner to the top of the Ivishak 4 -1/2" slotted liner to TD within the Ivishak I have attached a rough schematic to give you a picture and help explain what we are considering. «Completion Slide Question.ppt» Ken Allen Drilling Engineer Northstar Mobile: 907.748.3907 Office: 907.564.4366 e -mail: Kenneth.AIlen @BP.com 4/7/2009 __ _- ------ ---- _ __ __ __ 4-1/2" Tubing __ __ ____ __ ___ _ __ _: - :- - Baker ZXP ____ _= = ___- 6 -5/8" Liner Baker Flex -Lock _ T/Sa9 River , 0 T /Shublik =====" ===== 4 -1/2" Solid LNR ■ 111111 111111 111111 4 -1/2" Slotted LNR 111111 111111 • 111111 111111 TD 26,000' MD .....--------J Oil / Water Contact ____ _____ _____ _____ __ _ Kavik 41 llansE ) - SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Kara Engineering Team Leader BP Exploration Alaska Inc PO Box 196612 Anchorage AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS33A BP Exploration Alaska Inc Permit No: 208 -189 Surface Location: 1369' FSL, 650' FEL, SEC. 11, T13N, R13E, UM Bottomhole Location: 4300' FSL, 1881' FEL, SEC. 32, T14N, R13E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill 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). S' er y, .r� Daniel T. Seamount, Jr. f.� Chair DATED this / day of December, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • STATE OF ALASKA` • a' j � I ALAS IL AND GAS CONSERVATION COMM !ON PERMIT TO DRILL Wc.. 20 AAC 25.005 1 a. Type of work 1 b. Current Well Class ❑ Exploratory ❑ Development Gas le. Specify if well is proposed for: ❑ Drill ® Redrill ❑ Service ❑ Multiple Zone ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re - Entry ❑ Stratigraphic Test ® Development Oil ❑ Single Zone ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 NS33A 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 25987 TVD 11256 Northstar Field / Northstar Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL312799, ADL312798 1369' FSL, 650' FEL, SEC. 11, T13N, R13E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4215' FSL, 1786' FEL, SEC. 32, T14N, R13E, UM LO -N96 -006 January 15, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4300' FSL, 1881' FEL, SEC. 32, T14N, R13E, UM 2560 342' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool: Surface: x- 659821 y- 6031141 Zone -ASP4 (Height above GL): 56.6' feet 4205' 16. Deviated Wells: Kickoff Depth: 15078 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 77 degrees Downhole: 5123 Surface: 3998 18. Casino Program: Specifications Too - Settina Depth - Bottom Quantity of Cement. c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 10 -5/8" 8 -5/8" 32# L -80 Hydril 521 9123' 14900' 6522' 24023' 9600' 227 sx Class 'G' 7 -7/8" 6 -5/8" 24# L -80 Hydril 521 1740' 23873' , 9475' 25613' 10940' 108 sx Class 'G' 8 -5/8" 6-5/8" 24# L -80 Hydril 521 9123' 14750' 6475' 23873' 9475' 463 sx LiteCrite 5-7/8" 4 -1/2" 12.6# 13Cr -80 Vam Top 524' 5463' 10814' 25987' 11257' Uncemented Slotted Liner 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): 23460 945Q None 16243 6866 None Casing Length Len th Size Cement Volume MD TVD Conductor / Structural 190' 24" Driven 190' 190' Surface 4426' 16" 887 sx ASL. 1906 sx Class 'G' 4472' 3195' Intermediate 16491' 11 -3/4" 1801 sx LiteCrete. 538 sx Class 'G' 16491' 7032' Production Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ❑ Filing Fee, $100 ® BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ken Allen, 564 - 4366 Printed Name Dan Kara Title Engineering Team Leader Prepared By Name/Number Signature 7 4 _fo' if 4 /Rhone 564 -5803 Date 1a/ Sondra Stewman, 564 - 4750 Commission Use Onl Permit To Drill API Number Permit Approval See cover letter for Number: 0?08 /r9 50 - 029433254140 Date: 1 4' ID- cg I other requirements Conditions of Approval: 4gm , p,..,..k 1 d SOO ``p -- g,�' ,.,/ If box is checked, II may not be used to explore for, or produce coalbed methane, gas hydrates, or gas contained shales: 1Q Samples Req'd: ❑��'es t t o Mud Log Req'd: ❑ Yes L1rJ No �7 H Measures: Yes ❑ No Directional Survey Req'd: 1 Yes ❑ No Other: APPROVED BY THE COMMISSION / Q Date �,. , , COMMISSIONER Form 10 1 Ffevis 12/2 E E ,_ Submit In Duplicate i i L • 1 110 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control A. The Ivishak pressures in the target fault block are expected to be at 8.7 - 8.9 ppg EMW. This pressure is estimated based on offset well pressures and know reservoir pressure decline from the original reservoir pressure. B. The planned mud weight will be 9.5ppg while drilling the production interval. II. Fault Crossing 1 Lost Circulation / Breathing A. Lost circulation is not expected on this well. B. The fault labeled #27 is planned to be crossed in the Lower Kuparuk. This fault has about 200' of throw and will remove about 200' of the Kuparuk C and A sections prior to encountering the Miluveach. Once this fault is crossed the well bore will be in the same fault block as the previous NS33 well bores. C. The second fault labeled #26 is dying out in the lower Kingak -200' south of the well trajectory and is not expected to be encountered. D. Breathing is not expected on this well. III. Hole Stability A. The original NS33 well bore was lost due to hole stability issues in the Colville formation. The use of Oil Base Mud, Tripping / Drilling Practices and fluctuating drilling fluid properties exacerbated an unstable zone. The new NS33A well bore has been moved -300' from this trouble zone. The previous LSND mud system and ERD y pi u utilized threughout each section of this drilling program. IV. Hydrogen Sulfide A. Northstar is not designated a H location. There has been one H reading in the V. Kick Tolerance Kick Tolerance Table Casing set / Maximum Influx Mud Exp Pore Min LOT / FIT Interval Volume Weight Press Intermediate #1 121 10.5 9.45 (Kuparuk) 11.0 (LOT) 10 -5/8" Intermediate #2 Infinite 13.0 8.9 (Sag) 14.0 (LOT) 7 -7/8" Production Infinite 9.5 8.9 (Ivishak) 10.0 (LOT) 5 -7/8" NOTE: All LOT's will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous window / casing string CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION • BP Northstar • NS33A Permit Data NS33A Scope NS33A will be drilled -4,000' further Northwest of the current well NS21. This well will target the Ivishak Formation that was not reached when the original NS33 well bore was suspended due to hole stability problems. The original NS33 well bore was unable to reach the production zone due to formation instability encountered just below the current 11 -3/4" casing. The NS33A well will be the longest well drilled at Northstar to date. The planned total measured depth will be +/- 25,987' MD. A 16" surface casing string was set at 4,472' MD. An 11 -3/4" intermediate casing string was set at 16,491' MD. The two 10 -5/8" x 12 -1/4" well bores (NS33PB1 & NS33) were isolated by squeezing 274 BBLS below a mechanical retainer and by placing 39 BBLS of cement of o g - N this retainer. The mechanical retainer was set 16,415' MD. The NS33A well will use a whipstock to sidetrack out of the current 11 -3/4" casing at -15,050' MD. A 10 -5/8" hole will be drilled into the top of the Miluveach formation and an 8- 5/8" liner will be set and cemented over this interval. A 7 -7/8" hole opened to 9" with an under reamer will be drilled into the top of the Sag River Formation. A 6 -5/8" liner will then be run and cemented in place. A 5 -7/8" production hole will be drilled into the Ivishak formation. Due to the extend reach and associated difficulty of this well a uncemented 4- 1/2" chrome solid by slotted liner run over this interval. The difficulty in confidently placing a very small volume of cement and associated perforating operation has lead us to the uncemented option. The risk associated in running open hole packers to +/- 25,900' MD is also very high due to the time to run this string in the hole along with high bottom hole temperate. A 6 -5/8" scab liner will be run and fully cemented from the top of the 6 -5/8" drilling liner to -150' MD above the 8 -5/8" liner top. The well will be completed with 4 -1/2" chrome tubing. The well currently has 11.1 ppg OBM and 50 joints of 4 -1/2" tubing to 2,142' MD. The well was suspended in May 2007. A Sundry request was recently submitted to the AOGCC for P &A and prep for this sidetrack. Variance Request: The subsequent operations require two (2) drilling liners: +/- 9,000ft 8 -5/8" drilling liner, and +/- 1,800ft 6 -5/8" drilling liner. For these operations, we are requesting a variance to 20 AAC 25.35 (e)(2)(B)(iv) that requires 2 ram preventers for the liner AND 2 ram preventers for the DP. We propose instead to use one (1) casing ram for the liners when run and a VBR to cover any size drill pipe used in the running string. This proposal would provide one ram and the annular preventer for the liner, as well as, one ram and the annular preventer for the DP. This scheme does not necessitate changing both pipe rams after picking up the liners. In the event of a well control incident, our standard practice is to immediately cross- over to DP to allow annular to ram stripping (if required). roc, 12/4/2008 Page 1 of 10 BP N orthstar NS33A Permit Data Pre -Riq Work: 1. Pressure test T X IA to 4,200 psi for 30 minutes. Pressure test the OA to 2,000 psi for minutes. 2. Bleed OA, IA & TBG to zero. Test the 11 -3/4" pack -off to 2,300 psi and tubing hanger seals to 5,000 psi. Function all lock -down screws. Repair or replace as needed. 3. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 4. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MIRU Nabors 33E 2. Pull BPV. Circulate out freeze protection (OBM) and displace well to seawater. Monitor OA, IA and T for pressure to verify well is dead. Set TWC. 3. Test all down hole barriers: a. CMIT T x IA: 2,500 psi for 30 minutes. ,7 Ac \D. k b. MIT OA: 2,000 psi for 30 minutes. 4. Nipple down tree. Nipple up and test BOPE (250/5000 psi, Hydrill 3500psi). Pull TWC. 5. Pull and lay down 4 -1/2" tubing hanger. Pull and lay down 50 jts 4 -1/2" 12.6# L -80 NSCT tubing along with pups, XN Nipple and WLEG from 2,142' MD. 6. PU 10 -5/8" OD junk mill, 10 -5/8" Watermelon mill and boot baskets. RIH picking up of 5" DP to PBTD (-16,243') and tag TOC. Displace well to seawater and CBU a minimum 3x pumping >_700 gpm. POOH racking back DP for logging run. 7. Pressure Test the 11 -3/4" Casing to 4,200 psi for 30 minutes with seawater. Record test. 8. RU & Run oriented USIT /CBL CCL w /GR to -16,000' on DP. 9. PU HES EZSV with MWD /GR on DP. Correlate GR with previous GR/CCL run to set bridge plug -15,000' MD, as required to avoid cutting a casing collar while milling the window. POOH. ,,/ Sundry 308 -401 above this line Operations 1 - 9). 7 Day BOPE Test interval. 4 Permit to Drill Operations Below this line (Operations 10 - 50). 14 Day BOPE Test interval. + -606A-7- ^'1 U(c 10.Test BOPE (250 6 psi, Hydrill 2500psi). -c`v, 11. PU and RIH with 11 -3/4" Baker bottom -trip anchor whip stock assembly on 5" DP. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. (-►.`\ 12. Displace the well to 9.2 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 13. Mill window in 11 -3/4" casing at ±15,000' MD, plus 20' beyond middle of window. Circulate well bore clean. 14. Pull up into 11 -3/4" casing and conduct an LOT. (FIT /LOT procedure on file with AOGCC). POOH. 15. MU 10 -5/8" Dir /GR/Res /PWD /DWOB /DTOR/ACaI motor assembly. RIH, kick off and drill until the required directional work has been completed. POOH for RSS BHA. 16. MU 10 -5/8" Dir /GR/Res /PWD /DWOB /DTOR/ACaI (w /Ghost Reamers) RSS assembly. RIH & drill the 10 -5/8" section to -22,700' MD ( -200' TVD above the HRZ) with 9.2 - 9.5 ppg LSND fluid. 17. Perform a short trip to the 11 -3/4" window. 12/4/2008 Page 2 of 10 BP Northstar • NS33A Permit Data 18.Once the BHA is back on bottom weight up the entire circulating system to 10.5 ppg with spike fluid. 19. Continue drilling ahead to the 8 -5/8" liner point into the top of the Miluveach, as per the directional plan. The liner pick will be done using GR/RES LWD data. Circulate well clean, short trip to window, CBU and POOH. 20. Run and cement an 8 -5/8 ", 32.0 #, L -80 intermediate drilling liner. POOH for 7 -7/8" BHA. 21.Test to liner to 3,100 psi with 10.5 ppg mud. This test pressure may change based on the actual mud weight in the hole. 22. M/U 7 -7/8" RSS clean out BHA with Dir /Gr /Res /PWD /Dwob /DTor /Caliper & 7 -7/8" bit. RIH picking up 4 -1/2" DP. Continue RIH on 5 -7/8" to the 8 -5/8" landing collar. 23. Drill out the 8 -5/8" liner float equipment and cement to the shoe. 24. Weight up entire fluid system to 13.0 ppg. 25. Drill out the 8 -5/8" shoe plus -20' new formation, pull up into the shoe and conduct an LOT. (FIT /LOT procedure on file with AOGCC). 26. Drill ahead -50' or until Reamer on the next BHA will be at least 10' below the 8 -5/8" shoe. Circulate well bore clean. POOH for RSS BHA. 27. MU 7 -7/8" RSS BHA with Dir /GR/Res /PWD /DWOB /DTOR /ACaI and Rhino Reamer. RIH picking up enough 4 -1/2" DP to TD well bore. Continue in the hole on 5 -7/8" DP stands. 28. Drill to TD as per directional plan. TD will be picked when the Reamer is into the Top Sag River. Circulate well clean, short trip to window, CBU and weight up to 13.0 ppg. POOH for 6 -5/8" liner. BHA will be pumped out of the open hole and 8 -5/8" liner to avoid swabbing the Kingak. 29. Run and cement a 6 -5/8 ", 24.0 #, L -80 intermediate drilling liner with 2 pip tags. 30.Test to liner to 1,600 psi with 13 ppg mud. This test pressure may change based on the actual mud weight in the hole. 31. MU 5 -7/8" Dir /GR/Res /PWD /Den /Neu /Steth /DWOB /DTOR /ACaI Motor assembly. RIH picking up enough 4 -1/2" DP to TD well bore. Continue in the hole on 5 -7/8" stands to the 6 -5/8" liner landing collar. 32. Drill out the 6 -5/8" liner float equipment and cement to the shoe. 33. Displace the well to 9.5 ppg SF FloPro drilling fluid. 34. Drill out the 6 -5/8" shoe plus -20' new formation, pull up into the shoe and conduct a LOT. (FIT /LOT procedure on file with AOGCC). Drill ahead to TD per directional proposal. 35. Circulate well bore clean, short trip to shoe, circulate. POOH for 6 -5/8" CIBP. 36. MU 6 -5/8 HES CIBP with MWD GR tool. RIH picking up 4 -1/2" DP & 5 -7/8" DP stands. Set plug in 1 full joint of liner above the 6 -5/8" shoe 25,513' MD. GR tool and pip tag will be utilized to avoid setting CIBP in collar. POOH for 6 -5/8" polish mill BHA. 37. MU 6 -5/8" Polish Mill BHA. RIH picking up 4 -1/2" DP & 5 -7/8" DP stands. Polish 6 -5/8" tieback sleeve at -23,873' MD. POOH for 6 -5/8" Scab liner. 38. MU 6 -5/8" ported seal assembly, ported float collar and non - locking landing collar and enough 6 -5/8" liner to place the liner top -150' above the current 8 -5/8" liner top. 6 -5/8" liner top estimated to be - 14,750' MD. 39. RIH with scab liner on 5 -7/8" DP and cement in place. 40. Pressure test scab liner to 3,500 psi with 9.5 ppg mud. POOH for cleanout BHA. 41. MU 5 -7/8" cleanout BHA. RIH picking up enough 4 -1/2" x 4" DP to reach TD. Continue in the hole on 5 -7/8" stand to the 6 -5/8" scab shoe track. 12/4/2008 Page 3 of 10 BP Northstar • NS33A Permit Data 42. Drill out the scab shoe track. RIH to the 6 -5/8" CIBP. Drill out CIBP and RIH to TD. CBU a minimum of 4 times. Spot a clean liner running pill in the open hole. POOH for 4 -1/2" liner. BHA will be pumped out to top of 6 -5/8" liner. 43. RU and RIH with the 4 ", 12.6 #, 13Cr -80, Vam Top solid x slotted production liner with swell packers, a Flex -Lock Hanger and ZXP packer. A pusher tool will be utilized to set the ZXP. Displace the well to clean 9.5 ppg weighted brine above the liner top. POOH for completion. BHA will be pumped out to the top of 6 -5/8" liner. 44. R/U and run a 41/2", 12.6 #, 13Cr80/95, VamTop tubing completion, 4'/2" WLEG will be -100' above the liner tie back sleeve. Land tubing hanger and run in lockdown screws. 45. Drop Ball and set packer as per Baker recommendations. Individually test the tubing to 2,500 psi for 30 minutes to avoid shearing ball from seat. Then test the annulus to 4,200 psi for 30 minutes while recording on a chart. Bleed IA pressure to zero then continue pressuring up the tubing to shear ball +/- 3,500 psi 46. Install and test TWC to 1,000 psi from above. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 47. MIRU Slickline. Pull dummy GLV. Install GLV. RD Slickline. 48. Put well on Gas Lift to underbalance and bring well on production to clean up well bore. 49.Once well has sufficiently cleaned up shut in and secure well. 50. Rig down and move off. Post -Rig Work: 1. None planned General Information Type of Well (producer or injector): 1 Ivishak Producer Northstar Slot: NS33 Surface Location: 1369' FSL, 650' FEL, Sec. 11, T13N, R13E, UM X = 659,821 Y = 6,031,141 Target: 1064' FNL, 1786' FEL, Sec. 32, T14N, R13E, UM X= 642,550 Y= 6,044,198 11,056.60 TVDrkb (11,000' TVDss) Bottom Hole Location: 980' FNL, 1880' FEL, Sec. 32, T14N, R13E, UM X = 642,454 Y = 6,044,281 11,256.60 TVDrkb (11,200' TVDss) AFE Number: 1 TBA ( ( Rig: 1 Nabors 33E Estimated Start Date: 1 1/15/2009 1 1 Operating days to complete: 1 103 I MD: 1 25,987' I 1 TVDrkb: 1 11,256' I I RKB /Surface Elevation: (a.m.s.I.) 156.6'/15.6' 1 Well Design (conventional, slimhole, etc.): 1 Modified Big Bore Objective: 1 Ivishak Producer Well Name: NS33A API Number: 50029233250100 BHP: 5,100psi @ 11,100' TVDss EMW: 8.84 ppg BHT: 254 °F @ 11,100' TVDss 12/4/2008 Page 4 of 10 0 BP Northstar • NS33A Permit Data Distance to Nearest Property at TD: 342' South of the North lease line ADL312798 Distance to Nearest Well within NS21 in the Northstar pool is 4,205' Pool: Southeast of the BHL Cellar box: Elevation above MSL = 15.6' RKB to Cellar box: 41' (Estimated) Rig Elevation: RKB + MSL = 56.6' MECHANICAL CONDITION: Casing String Casing Description Measured Depth Vertical Depth Length Top Bottom Top Bottom Feet Conductor Pipe 24" 245.6# X -56 Welded Surface 190 Surface 190 190 Surface Casing 16" 84.0# HCL -80 BTC Surface 4,472 Surface 3,195 4,472 Intermediate Csg 11 -3/4" 60# S -95 Hydril 563 Surface 16,491 Surface 7,031 7,031 Formation Tops and Estimated Pore Pressures Estimated Tops Estimated Formation Hydrocarbon Pore TVD TVD MD Bearing Press. SS RKB RKB Y/N PSI PPG WS1 - Top Schrader Bluff _ 6,208 6,265 _ 14,080 N 2818 8.65 Top Window 6,514 6,571 15,050 N/A Top Colville 6,890 6,947 16,599 N 3125 8.65 THRZ - Top HRZ 8,750 8,807 23,023 N 3961 8.65 BHRZ - Base HRZ _ 8,800 8,857 23,093 N 3984 8.65 Kuparuk C F/O 4490 9.40 Fault 27 throw = 200' 9,300 _ 9,357 23,728 N TKA1 9,335 _ 9,392 23,771 N 4615 9.45 Top Miluveach 9,460 9,517 23,923 N 4573 9.24 8 -5/8" Intermediate Liner point 9,540 9,597 24,023 N Top Kingak 9,840 9,897 24,377 N TJD 10,354 10,411 24,985 N Not Fault 26 Expected Top Sag River 10,850 10,907 25,572 Yes 5043 8.89 6 -5/8" Intermediate Liner point 10,884 10,941 25,612 Yes 5051 8.88 Top Shublik "D "trop Reservoir 11,030 11,087 25,785 Yes 5084 8.82 Top Ivishak 11,035 11,092 25,791 Yes 5085 8.82 Oil - Water contact 11,100 _ 11,157 _ 25,868 Yes 5100 8.79 Total Depth [OWC +100' MD] 11,200 11,257 25,987 Yes 5123 8.75 12/4/2008 Page 5 of 10 • BP Northstar NS33A Permit Data CASING/TUBING PROGRAM: Casing String Hole Casing Description Measured Depth Vertical Depth Length Size Top Bottom Top Bottom Feet Intermediate I LNR 10 -5/8" 8 -5/8" 32# L -80 Hydril 521 14,900' 24,023' 6,522' 9,600' 9,123' Intermediate II LNR 7 -7/8" 6 -5/8" 24.0# L -80 Hydril 521 23,873' 25,613' 9,475' 10,940' 1,739' Scab LNR 8 -5/8" 6 -5/8" 24.0# L -80 Hydril 521 14,750 23,873' 6,475' 9,475' 9,123' liner Production Liner 5 -7/8" 4 -1/2" 12.6# 13 -CR80 Vam Top 25,463' 25,987' 10,814' 11,257 524' (Slotted Liner) Tubing Cased 4 -1/2" 12.6# 13- CR80/95 Surface 25,463' Surface 11,257 25,463' hole Vam Top Casing / Formation Integrity Testing: Test Point Depth Test Type Test Pressure 11 -3/4" Casing Top of Cement P &A to surface 30 min recorded 4,200 psi w/ 8.65 ppg mud 11 -3/4" Window 20' below mid window point LOT Test to formation breakdown 8 -5/8" Intermediate 1 Liner Float equipment to surface 30 min recorded 3,100 psi w /10.5 ppg mud 8 -5/8" Shoe 20' min below shoe LOT Test to formation breakdown 6 -5/8" Intermediate 2 Liner Float equipment to surface 30 min recorded 1,600 psi w/13.0 ppg mud 6 -5/8" Shoe 20' min below shoe LOT Test to formation breakdown 6 -5/8" Scab Liner Float equipment to surface 30 min recorded 3,500 psi w/9.5 ppg mud MUD PROGRAM SUMMARY: Intermediate 1 Hole Mud Properties: Seawater LSND Mud 10 -5/8" Hole Section From Surface Casing Shoe into the Top of the Miluveach (-17239' MD / 9656' TVD). Interval Density (ppg) PV YP API / HTTP FL pH Initial 9.2 -9.4 12 -18 22 -30 <9.0 9.0 -9.5 -200' TVD above Top HRZ 10.5 18 - 22 22 - 30 < 5.0 9.0 - 9.5 Intermediate 2 Hole Mud Properties: Seawater w /KCL LSND Mud 7 -7/8 "x9.0" Hole Section From Surface Casing Shoe into the Top of the Miluveach (-17239' MD / 9656' TVD). Interval Density (ppg) PV YP API / HTTP FL pH 24,023' - 25,613' 13.0 20 - 26 22 - 30 < 5.0 9.0 - 9.5 Production Hole Mud Pro erties: Seawater Flo Pro SF 5 -7/8" Hole Section Interval Density (ppg) PV YP API / HTTP FL pH • 25,613' - 25,987' 9.5 12 -18 25 -30 <9.0 9.0 -9.5 DIRECTIONAL: Approved Well plan: WP49 I Exit point: 15,050' MD / 6,570' TVD Maximum Hole Inclination: -77° in the planned intermediate section starting -15,600' MD Proximity Issues: All wells pass a Major Risk anti - collision scan except the parent plugged back well bore. Survey Program: MWD +IIFR +MS over entire well bore 12/4/2008 Page 6 of 10 • BP Northstar • NS33A Permit Data ANTI - COLLISION ISSUES: Note: All wells passed the major risk scan criteria except the parent NS33 well bore. The parent well bore has been risk based as per BP policy. Surface Shut -in Wells: See Northstar Anti - Collision and Well Shut -In checklist. WELL CONTROL: Equipment will be installed that is capable of handling maximum potential surface pressures. (Schematics r on file with e o e ith the AOGCC and MMS.) ■ 5000 psi working pressure pipe rams (2) ■ Blind /shear rams ■ Annular P reventer Based upon the calculations below, BOP equipment will be tested to 4,200 psi. Maximum Surface Pressure - Full Column of Gas Gradients - psi /ft Pressures 10 -5/8" Intermediate 1 Hole Section TVD Formation Gas BHP Surface Pressue TKA1 9,392' 0.495 0.1 4,615 BHP —Gas to Surf = 3,676 psi 8 1/2" Intermediate Hole Section: Sag River 10,907' 0.463 0.1 5,043 BHP —Gas to Surf 3,952 psi 5 -7/8" Production Hole Section: Total Depth 11,257' 0.455 0.1 5,123 BHP —Gas to Surf = 3,998 psi Planned BOP test pressure: 4,200 psi (annular to 2,500 psi) Planned completion fluid: 9.5 ppg Weighted Seawater Variance Request: The subsequent operations require two (2) drilling liners: +/- 9,000ft 8 -5/8" drilling liner, and +/- 1,800ft 6- 5/8" drilling liner. For these operations, we are requesting a variance to 20 AAC 25.35 (e)(2)(B)(iv) that requires 2 ram preventers for the liner AND 2 ram preventers for the DP. We propose instead to use one (1) casing ram for the liners when run and a VBR to cover any size drill pipe used in the running string. This proposal would provide one ram and the annular preventer for the liner, as well as, one ram and the annular preventer for the DP. This scheme does not necessitate changing both pipe rams after picking up the liners. In the event of a well control incident, our standard practice is to immediately cross -over too DP to allow annular to ram stripping (if required). , - 0 .r 'S \ ( c- 12/4/2008 Page 7 of 10 BP Northstar NS33A Permit Data LOGGING PROGRAM: Hole Section: Required Sensors / Service 11 -3/4" Casing A USIT /CCL log will be run after pulling the tubing to pick exact window point. 10-5/8" intermediate 1 Real time MWD Dir /GR /Res /PWD /DWOB /DTOR /ACaI throughout the interval. Sample Catchers, Mud Loggers and gas detection equipment throughout interval. 7 -7/8" x 9" intermediate 2 Real time MWD Dir /GR /Res /PWD /DWOB /DTOR /ACaI throughout the interval. Sample Catchers, Mud Loggers and gas detection equipment throughout interval. Real time MWD Dir /GR/ Res /PWD /Den /Neu /Steth /DWOB /DTOR /ACaI throughout the 5 -7/8" production interval. Sample Catchers, Mud Loggers and gas detection equipment throughout interval. Cased Hole: None Planned Open Hole: None planned CEMENT CALCULATIONS: Casing 8 -5/8" 32# Hydril 521 Intermediate 1 Liner Basis: Stage 1: Slurry: Based on 753' of 10 -5/8" open hole x 8 -5/8" Inr + 130' shoe joint + 30% excess Slurry TOC: At -23,270' MD (8,988' TVD) Stage 1: Total Cement / Spacer Spacer 56 bbls MudPush II Spacer Slurry 46.9 bbls / 227.1 sks of 15.8 ppg Class `G' mixed at 1.16 cf /sk Casing 6 -5/8" 24# Hydril 521 Intermediate 2 Liner Basis: Stage 1: Slurry: Based on 541' of 9" open hole x 6 -5/8" Inr + 90' shoe joint + 30% excess. Slurry TOC: At -25072' MD Stage 1: Total Cement / Spacer Spacer 57 bbls MudPush II Spacer Slurry 29.4 bbls / 107.8 sks of 15.8 ppg Class 'G' with Silica mixed at 1.53 cf /sk Casing 6 -5/8" 24# Hydril 521 Scab Liner Basis: Stage 1: Slurry: Based on 8,973' of 7.921" liner x 6 -5/8" liner + 150' of 10.772" casing x 6 -5/8" liner 40' shoe joint + 10% excess. Slurry TOC: At -14,750' MD (Top of 6 -5/8" Scab Liner - Fully cemented Scab liner) Stage 1: Total Cement / Spacer Spacer 30 bbls MudPush II Spacer Slurry 194.4 bbls / 462.5 sks of 11.8 ppg LiteCrete mixed at 2.36 cf /sk 12/4/2008 Page 8 of 10 • BP Northstar NS33A Permit Data Tubular Specifications Collapse Burst Tensile ID Make -up Torque Surface casing: 11 -3/4 ", 60 #, S -95, Hydril 563 100% 4,410 psi 6,920 psi 1,644,000 lbs 10.772" ID Already installed in 80% 3,528 psi 5,536 psi 1,315,000 lbs 10.625" Drift well bore. Intermediate casing 1: 8 -5/8 ", 32 #, L -80, Hydril 521 100% 3,050 psi 5,710 psi 498,000 lbs 7.921" ID 70,000 ft-lbs (Max) 80% 2,440 psi 4,568 psi 398,400 lbs 7.875" Drift 25,000 ft -lbs (NS33A) 8,600 ft-lbs (Min) Ensure a Baker representative is onsite during the liner make up and running operations. Drilling liner: 6 -5/8 ", 24 #, L -80, Hydril 521 100% 5,760 psi 7,440 psi 394,000 lbs 5.921" ID 41,000 ft-lbs (Max) 80% 4,608 psi 5,952 psi 315,200 lbs 5.875" Drift 20,000 ft-lbs (NS33A) 6,900 ft-lbs (Min) Ensure a Baker representative is onsite during the liner make up and running operations. Production liner: 4 -1/2 ", 12.6 #, 13Cr -80 Vam Top 100% 7,500 psi 8,430 psi 288,000 lbs 3.958" ID 4,880 ft-lbs (max) 4,440 ft-lbs (opt) 80% 6,000 psi 6,744 psi 230,400 lbs 3.833" Drift 4,000 ft-lbs (min) Completion: 4 12.6 #, 13Cr -80, VAM Top 100% 7,500 psi 8,430 psi 288,000 lbs 3.958" ID 4,880 ft-lbs (max) 4,440 ft-lbs (opt) 80% 6,000 psi 6,744 psi 230,400 lbs 3.833" Drift 4,000 ft-lbs (min) Completion: 4' ", 12.6 #, 13Cr -95, VAM Top 100% 8,410 psi 10,010 psi 342,000 lbs 3.958" ID 5,300 ft-lbs (max) 4,820 ft-lbs (opt) 80% 6,728 psi 8,008 psi 273,600 lbs 3.833" Drift 4,340 ft-lbs (min) 12/4/2008 Page 9 of 10 • BP Northstar S NS33A Permit Data Northstar Nabors Rig 33E Rig Floor Dric Pen I A. Bag 28.97' Hydril Type `GK' I l Double Gate Pipe Ram 32.40' Double Studded Blind Ram 34.27 IODIC) Mud Cross ®K I (.) Slagle s Gale Pipe Ram 38.03' 39.33' Spacer Ground Level Spool I 40.30' j 1�+1� SPoog ICI ®I CSpoo] asin 4IcI 41.20' 1 41.26' 12/4/2008 Page 10 of 10 :TREE ` HEAD = AB -VGI 3 5/8" • NS33 SA NOTES: Est CMT Top - 16,243' ACTUATOR = Current KB. ELEV = 56.6 BF ELEV = I 4.5" 12.6# L -80, NSCT Tbg, .0152 bpf KOP = 300 Max Angle = 73 @ 12743' I 2121 H 4.5" HES "XN" Nipple 9Cr, ID = 3.725" I Datum MD = Datum 1V D= 2142 HI 4.5" WLEG I 16" CSG, 84#, HCL -80, BTC, 10= 15.010" H 4472' I Minimum ID = 3.725" @ 2121' JEWELRY TYPE, XN Nipple [Estimated 10 5/8" CSG FBTD H 16243' I 39 BBLS placed on top of Retainer CBU performed at 16,243' in green cmt \ 111 3/4" HES EZSV Cement Retainer H 16415' I , ° . S 111 3/4" Csg, 60# S -95, Hydril 563. ID = 10.772" H 16491' I � N 274 BBLS Squeezed below Retainer" F`. -2,431 feet equivalent within . � d T 10 -5/8" hole or - 18,846' MD �141 h 16,940 Tight Hole r. Estimated 18,846' MD Bottom of Cement • - . , s ii NS33 KOP - 21,828' NS33P61 - 23,236' \ -------------j NS33 - 23,460' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/08 KWA SUSPENDED (NS33) WELL: NS-33 PERMIT No: 206 -138 API No: 50- 029 - 23325 -00 -00 SEC:11, T13N, R13E, 1369' FSL, 650' FEL BP Exploration (Alaska) - TREE =ABB-VGI 5 1/8" 5k NS33A WELLHEAD = ABB -VGI 13 5/8" 'ACTUATOR= Proposed Completion KB. ELEV = 56.6 .1 1 000 H 4.5" SLB TRM4ETRSSSV I KOP = 300 Angle = 78 @ 15600' 2806 1 - 1 4.5" HES "X" Nipple Superl3Cr, ID = 3.813" 1 Max M Datum MD= BF. ELEV = u ' Datum TV 'D = / Z z —I 14750 H 11 -3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR I 116" CSG, 84 #, HCL -80, BTC, ID =15.010" j--I 4472' —1 14900 _I--I 11 -3/4" x 9 -5/8" BKR ZXP/ FlexLock PKR/HGR I 111 3/4" Whipstock I l 15050 I 6 -5/8" 24 #, L -80, HYD521 Scab LNR full cemented 111 3/4" HES EZSV 1 I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2766 2486 50 MMG Spr 13Cr DV 1.5 11/03/08 'Estimated 10 5/8" CSG PBTD H 16243' I 39 BBLS placed on top of Retainer CBU performed at 16,243' in green cemen 1 11 3/4" HES EZSV Cement Retainer H 16415' I 111 3/4" Csg, 60# S -95, Hydril 563. ID = 10.772" H__1649' L 1649 I \ — -23,270' Est TOC 274 BBLS Squeezed below Retainer -2,431 feet equivalent within 10 -5/8" hole or -18,846' MD NS33 KOP - 21,828' NS33PB1 - 23,236' NS33 - 23,460' 1 4 -1/2" 12.6 #, 9Cr, X Nip ID = 3.813" @- 25270' / ► 1 6 5/8" BKR TieBack Sleave L -80 H 23873' I / _4 - 1/2" Baker S3 ZXP Packer @ - 25290' 8 5/8" LNR, 32# L -80, Hydril 521. ID = 7.921" I — I 24023' I 4 -1/2" 12.6 #, 9Cr, X Nip ID = 3.813" @- 25330' Est TOC -25,072` \4 -1/2" 12.6 #, 9Cr, XN Nip ID = 3.725" Est TOC -25,072/ \ @- 25350' 17" 38# BKR ZXP /FlexLock PKR/HGR w /Tieback H 25463' ( 4-1/2" WLEG @ - 25363' 6 5/8" LNR, 24# L -80, Hydril 521. ID = 5.92" H 25613' I ■ 4 1/2" Solid LNR, 12.6 #, 13Cr- 80,VamTop ID =3.958' 25791' I 4 1/2" Slotted LNR ,12.6 #,13Cr- 80,VamTopID =3.958'H 25987' I A ` DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/22/08 KWA SUSPENDED (NS33) WELL: NS -33A 10/30/08 KWA NS33 Proposed P &A PERMIT No: ? ?? 11/03/08 KWA NS33A Proposed Completion API No: 50- 029 - 23325 -01 -00 SEC:11, T13N, R13E, 1369' FSL, 650' FEL BP Exploration (Alaska) by 0 NS33A (P49) Proposal Schlumberger Report Date: November 20, 2008 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client BP Exploration Alaska Vertical Section Azimuth: 307.250° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Northstar PF / NS33 ;' ity Study TVD Reference Datum: Rotary Table Well: NS33 TVD Reference Elevation: 56.60 ft relative to MSL Borehole: Plan NS33A Fea s � Sea Bed 1 Ground Level Elevation: 15.57 ft relative to MSL UWIIAPI#: 500292332501 Magnetic Declination: 22.932° Survey Name 1 Date: NS33A (P49) / November 20, 2008 Total Field Strength: 57712.022 nT Tort 1 AHD I DDI I ERD ratio: 257.147° / 21806.49 ft / 7.112 / 1.937 Magnetic Dip: 81.043° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: January 30, 2009 Location LatiLong: N 70.49162367, W 148.69334368 Magnetic Declination Model: BGGM 2008 ID Location Grid NIE YIX: N 6031141.300 ftUS, E 659820.740 ftUS North Reference: True North Grid Convergence Angle: +1.23166855 Total Corr Mag North -> True North: +22.932° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Measured Vertical Mag 1 Gray Directional Comments Inclination Azimuth Sub -Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deg) (deg) (ft) (ft) (ft) I (ft) (ft ) (deg) (degl100ft ) Index (ftUS) (ftUS) Tie -in survey 14958.70 71.31 306.13 6484.40 6541.00 12467.06 7556.87 - 9915.72 91.01L 0.21 6.72 6038482.75 649745.61 N 70.51224997 W 148.77448100 15000.00 71.31 305.86 6497.63 6554.23 12506.17 7579.86 - 9947.37 90.93L 0.61 6.73 6038505.05 649713.47 N 70.51231267 W 148.77474025 Top Whipstock 15050.00 71.30 305.54 6513.66 6570.26 12553.52 7607.50 - 9985.83 70.00R 0.61 6.73 6038531.85 649674.43 N 70.51238803 W 148.77505527 Base Whipstock 15066.00 71.97 307.44 6518.70 6575.30 12568.70 7616.53 - 9998.04 - -- 12.00 6.73 6038540.62 649662.03 N 70.51241266 W 148.77515526 KOP Cry 2.5/100 15078.00 71.97 307.44 6522.42 6579.02 12580.11 7623.46 - 10007.10 69.61R 0.00 6.73 6038547.36 649652.83 N 70.51243157 W 148.77522948 15100.00 72.16 307.98 6529.19 6585.79 12601.04 7636.26 - 10023.66 69.44R 2.50 6.74 6038559.80 649636.00 N 70.51246648 W 148.77536512 15200.00 73.05 310.42 6559.09 6615.69 12696.40 7696.57 - 10097.60 68.71R 2.50 6.75 6038618.50 649560.78 N 70.51263097 W 148.77597083 15300.00 73.97 312.85 6587.47 6644.07 12792.00 7760.28 - 10169.26 68.02R 2.50 6.76 6038680.65 649487.78 N 70.51280474 W 148.77655789 15400.00 74.92 315.25 6614.29 6670.89 12887.65 7827.26 - 10238.49 67.38R 2.50 6.77 6038746.12 649417.13 N 70.51298745 W 148.77712518 15500.00 75.90 317.63 6639.48 6696.08 12983.18 7897.38 - 10305.17 66.78R 2.50 6.78 6038814.79 649348.96 N 70.51317877 W 148.77767164 15600.00 76.89 319.99 6663.00 6719.60 13078.39 7970.51 - 10369.18 66.22R 2.50 6.79 6038886.52 649283.40 N 70.51337832 W 148.77819 End Cry 15600.58 76.90 320.00 6663.13 6719.73 13078.94 7970.94 - 10369.54 - -- 2.50 6.79 6038886.94 649283.03 N 70.51337949 W 148.778199 Cry 2.5/100 15900.58 76.90 320.00 6731.13 6787.73 13363.93 8194.78 - 10557.36 91.53L 0.00 6.80 6039106.67 649090.46 N 70.51399025 W 148.77973872 16000.00 76.85 317.45 6753.71 6810.31 13458.81 8267.54 - 10621.22 90.95L 2.50 6.81 6039178.04 649025.05 N 70.51418878 W 148.78026223 16100.00 76.82 314.88 6776.50 6833.10 13554.99 8337.77 - 10688.66 90.36L 2.50 6.82 6039246.80 648956.13 N 70.51438038 W 148.78081488 16200.00 76.81 312.31 6799.31 6855.91 13651.75 8404.90 - 10759.16 89.78L 2.50 6.83 6039312.40 648884.20 N 70.51456350 W 148.78139266 16300.00 76.84 309.75 6822.10 6878.70 13748.90 8468.82 - 10832.61 89.19L 2.50 6.84 6039374.71 648809.40 N 70.51473781 W 148.78199447 End Cry 16355.30 76.86 308.33 6834.69 6891.29 13802.72 8502.73 - 10874.43 -- 2.50 6.84 6039407.72 648766.86 N 70.51483029 W 148.78233717 CM3 16598.63 76.86 308.33 6890.00 6946.60 14039.64 8649.68 - 11060.33 - -- 0.00 6.85 6039550.62 648577.86 N 70.51523098 W 148.78386027 Cry 2/100 21435.23 76.86 308.33 7989.46 8046.06 18748.79 11570.52 - 14755.27 179.42R 0.00 7.03 6042391.16 644821.27 N 70.52319280 W 148.81414675 21500.00 75.57 308.34 8004.89 8061.49 18811.68 11609.53 - 14804.61 179.42R 2.00 7.03 6042429.10 644771.10 N 70.52329912 W 148.81455136 21600.00 73.57 308.36 8031.50 8088.10 18908.05 11669.34 - 14880.20 179.41R 2.00 7.04 6042487.26 644694.25 N 70.52346209 W 148.81517121 21700.00 71.57 308.38 8061.46 8118.06 19003.43 11728.56 - 14954.99 179.41R 2.00 7.04 6042544.86 644618.21 N 70.52362346 W 148.81578455 21800.00 69.57 308.40 8094.74 8151.34 19097.71 11787.12 - 15028.90 179.40R 2.00 7.05 6042601.82 644543.06 N 70.52378305 W 148.81639061 21900.00 67.57 308.43 8131.28 8187.88 19190.77 11844.96 - 15101.83 179.39R 2.00 7.06 6042658.07 644468.91 N 70.52394064 W 148.81698867 WellDesign Ver SP 2.1 Bid( doc40x_100) NS33 \NS33 \Plan NS33A \NS33A (P49) Generated 11/20/2008 2:36 PM Page 1 of 2 I Measured Vertical Mag /Gray Directional Comments Inclination Azimuth Sub -Sea TVD ND NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deg) (deg) (ft) (ft ) (ft) (ft) (ft ) (deg) (degl100ft ) Index (ftUS) (ftUS) 22000.00 65.57 308.45 8171.04 8227.64 19282.50 11902.00 - 15173.69 179.38R 2.00 7.06 6042713.54 644395.85 N 70.52409606 W 148.81757800 22100.00 63.57 308.47 8213.99 8270.59 19372.78 11958.17 - 15244.40 179.37R 2.00 7.07 6042768.18 644323.95 N 70.52424912 W 148.81815787 22200.00 61.57 308.50 8260.06 8316.66 19461.51 12013.40 - 15313.87 179.36R 2.00 7.07 6042821.90 644253.32 N 70.52439961 W 148.81872757 22300.00 59.57 308.53 8309.20 8365.80 19548.58 12067.63 - 15382.01 179.35R 2.00 7.08 6042874.65 644184.03 N 70.52454737 W 148.81928643 22400.00 57.57 308.55 8361.35 8417.95 19633.87 12120.79 - 15448.75 179.33R 2.00 7.08 6042926.35 644116.17 N 70.52469222 W 148.81983374 22500.00 55.57 308.58 8416.44 8473.04 19717.30 12172.81 - 15514.00 179.32R 2.00 7.09 6042976.96 644049.82 N 70.52483397 W 148.82036885 22600.00 53.57 308.61 8474.42 8531.02 19798.75 12223.64 - 15577.67 179.30R 2.00 7.09 6043026.40 643985.07 N 70.52497246 W 148.82089110 22700.00 51.57 308.64 8535.20 8591.80 19878.13 12273.20 - 15639.71 179.28R 2.00 7.10 6043074.62 643922.00 N 70.52510751 W 148.82139986 22800.00 49.57 308.68 8598.71 8655.31 19955.34 12321.45 - 15700.02 179.26R 2.00 7.10 6043121.55 643860.67 N 70.52523896 W 148.82189451 22900.00 47.57 308.71 8664.88 8721.48 20030.29 12368.31 - 15758.53 179.24R 2.00 7.10 6043167.15 643801.16 N 70.52536665 W 148.82237444 23000.00 45.57 308.75 8733.63 8790.23 20102.88 12413.74 - 15815.18 179.21R 2.00 7.11 6043211.35 643743.56 N 70.52549043 W 148.8228 THRZ 23023.29 45.10 308.76 8750.00 8806.60 20119.44 12424.11 - 15828.10 179.20R 2.00 7.11 6043221.43 643730.42 N 70.52551868 W 148.82294 BHRZ 23093.27 43.70 308.78 8800.00 8856.60 20168.38 12454.77 - 15866.27 179.18R 2.00 7.11 6043251.27 643691.59 N 70.52560223 W 148.82325814 23100.00 43.57 308.79 8804.87 8861.47 20173.02 12457.68 - 15869.89 179.18R 2.00 7.11 6043254.10 643687.92 N 70.52561015 W 148.82328781 23200.00 41.57 308.83 8878.51 8935.11 20240.64 12500.07 - 15922.60 179.15R 2.00 7.11 6043295.34 643634.31 N 70.52572565 W 148.82372015 23300.00 39.57 308.88 8954.47 9011.07 20305.65 12540.87 - 15973.24 179.11R 2.00 7.12 6043335.04 643582.81 N 70.52583681 W 148.82413555 23400.00 37.57 308.93 9032.65 9089.25 20367.96 12580.02 - 16021.76 179.08R 2.00 7.12 6043373.13 643533.46 N 70.52594347 W 148.82453349 23500.00 35.57 308.98 9112.96 9169.56 20427.51 12617.48 - 16068.09 179.03R 2.00 7.12 6043409.58 643486.34 N 70.52604552 W 148.82491350 End Cry 23528.43 35.00 309.00 9136.17 9192.77 20443.92 12627.81 - 16080.85 - -- 2.00 7.12 6043419.64 643473.36 N 70.52607367 W 148.82501819 Fault Target / Drp 23728.43 35.00 309.00 9300.00 9356.60 20558.59 12700.00 - 16170.00 148.29R 0.00 7.12 6043489.89 643382.69 N 70.52627036 W 148.82574946 0.5/100 TKA1 23771.11 34.82 309.20 9335.00 9391.60 20583.00 12715.40 - 16188.96 148.13R 0.50 7.12 6043504.88 643363.41 N 70.52631233 W 148.82590495 23800.00 34.70 309.33 9358.74 9415.34 20599.46 12725.83 - 16201.71 148.02R 0.50 7.12 6043515.03 643350.43 N 70.52634073 W 148.82600956 23900.00 34.27 309.80 9441.17 9497.77 20656.03 12761.89 - 16245.36 147.64R 0.50 7.12 6043550.14 643306.03 N 70.52643899 W 148.82636761 Top Miluveach 23922.78 34.18 309.91 9460.00 9516.60 20668.83 12770.10 - 16255.19 147.55R 0.50 7.12 6043558.14 643296.02 N 70.52646136 W 148.82644829 24000.00 33.85 310.28 9524.01 9580.61 20711.97 12797.92 - 16288.24 147.24R 0.50 7.12 6043585.24 643262.38 N 70.52653717 W 148.82671938 8 -5/8" Csg Pt 24022.85 33.76 310.39 9543.00 9599.60 20724.67 12806.15 - 16297.93 147.14R 0.50 7.12 6043593.26 643252.52 N 70.52655959 W 148.82679889 24100.00 33.43 310.77 9607.26 9663.86 20767.28 12833.92 - 16330.35 146.83R 0.50 7.12 6043620.32 643219.51 N 70.52663526 W 148.82706484 24200.00 33.01 311.27 9690.91 9747.51 20821.95 12869.88 - 16371.68 146.41R 0.50 7.12 6043655.38 643177.42 N 70.52673325 W 148.82740 24300.00 32.60 311.79 9774.97 9831.57 20875.98 12905.80 - 16412.24 145.98R 0.50 7.12 6043690.42 643136.10 N 70.52683114 W 148.82773 End Drp 24365.98 32.33 312.13 9830.63 9887.23 20911.28 12929.48 - 16438.58 - -- 0.50 7.12 6043713.53 643109.26 N 70.52689566 W 148.82795282 Top Kingak 24377.06 32.33 312.13 9840.00 9896.60 20917.18 12933.46 - 16442.97 - -- 0.00 7.12 6043717.41 643104.78 N 70.52690650 W 148.82798888 TJD 24985.33 32.33 312.13 10354.00 10410.60 21241.26 13151.66 - 16684.18 - -- 0.00 7.12 6043930.36 642858.95 N 70.52750113 W 148.82996808 Top Sag 25572.30 32.33 312.13 10850.00 10906.60 21554.00 13362.22 - 16916.95 - -- 0.00 7.11 6044135.86 642621.74 N 70.52807492 W 148.83187808 6 -5/8" Csg Pt 25612.54 32.33 312.13 10884.00 10940.60 21575.43 13376.66 - 16932.90 - -- 0.00 7.11 6044149.94 642605.47 N 70.52811426 W 148.83200901 NS33A Target 25749.81 32.33 312.13 11000.00 11056.60 21648.57 13425.90 - 16987.34 -- 0.00 7.11 6044198.00 642550.00 N 70.52824845 W 148.83245572 Top Shublik 25785.31 32.33 312.13 11030.00 11086.60 21667.49 13438.64 - 17001.42 - -- 0.00 7.11 6044210.43 642535.65 N 70.52828315 W 148.83257125 Top Ivishak 25791.23 32.33 312.13 11035.00 11091.60 21670.64 13440.76 - 17003.76 - -- 0.00 7.11 6044212.50 642533.26 N 70.52828893 W 148.83259051 OWC 25868.15 32.33 312.13 11100.00 11156.60 21711.62 13468.35 - 17034.27 -- 0.00 7.11 6044239.43 642502.17 N 70.52836413 W 148.83284082 TD / 4 -1/2" Lnr 25986.49 32.33 312.13 11200.00 11256.60 21774.68 13510.80 - 17081.20 - -- 0.00 7.11 6044280.86 642454.34 N 70.52847981 W 148.83322593 Legal Description: Northing (Y) iftUS1 Eastinq (X) iftUS1 Surface : 1368 FSL 650 FEL S11 T13N R13E UM 6031141.30 659820.74 NS33A Target : 4215 FSL 1787 FEL S32 T14N R13E UM 6044198.00 642550.00 BHL : 4299 FSL 1880 FEL S32 T14N R13E UM 6044280.86 642454.34 WellDesign Ver SP 2.1 Bld( doc40x_100) NS33 \NS33 \Plan NS33A \NS33A (P49) Generated 11/20/2008 2:36 PM Page 2 of 2 by 0 Schlumberger , WELL NS33A (P49) I FIELD Northstar I G RD ARE Northstar PF Magnetic Parameters Surface Loc.. NAD22 Aleska State Planes. Zone 04. US Feet MCcellaneous Model. SGGM 2008 Dip 81.043° Date: January 30. 2009 Lat. 530 29 29.845 NoMing: 6031141 30 ftUS G00 Cony - 1.23166855° I Set NS33 TOO Ref: Rotary Table (56.60 fl above MSL) Mag Dec: e22932° FS: 5]]12.0 nT Lon: Wlee 4138030 Casting: 659820. 74 SUS Scale Fad: 09999290152 Plan: NS334 0.49) Ss, Date: November 20. 2008 12000 13200 14400 15600 16800 18000 19200 20400 21600 Tie-In survey 6000 6000 Top Whipstock Base Whipstock KOP Ctv 2.5/100 'c1 :End Cry Cry 2.5/100 End Cry 7200 7200 11 -3k6" @ 16491'rod Cry 2/1110 0 8400 8400 0 N • C _.._..:.._.._.._.._.._.._.._...:::.._.._.._..:.._.._.._..:..:..:..:..:. .:.. :.. :.. :.._ : ..:.. : : "- - - - -- :--- - ..: . . _ -... ::313/12: _ : RZ ....:. _End Cry .._.._..= Z.. .�.._.._.. _.. Tie -In Survey I I Fault Target I Grp 0.5 /100 03 V _.._._.._......_.._...._.._..-.._.._.._.._. ._.._.._..�.._..�.._.._.._..�.. _.._. ».._.. _.._.._.._.._.. _.._. _.._._. ._.._.._.._.._.._.._.. .._.. - .. _.. NS33PB1 �•:a"Tafgel 'Fault'.._.._.._.._.._.. -.._.. cn 0 9600 "'YDp FJ� fuveacl 960411 H NS33PB2 _.._.._. ... .._.._.._.._.._.._...._.._.._.._.._. .... _. ... .._.. _.._. ».._.. _.._.._.._.._.. _.. ._.._.._.._.._.._.._.. _.. �.._.._.._.._.. _.. _.._.._.. ._.._.._ .._.. TOE .._.. _.._.. _.._.. 8 -SIB" Csg P! End Dip TJQ 65/8" Csg Pt 10800 10800 _.._.._.._: _.._.._.._.._.._.._.._..� 70 sa _.._.._.._.._.. P 9 _....._...._.._.._......_.. .._.._......._.._.._.._- .._...._.._.._.._.. ..._. »...._.._...._.._.._.._. _.._.._.. -.._ ._.._.. ._.._.._.._.._.._.._.._.._..!i> f w61Tvopitai ::" .sc;Tartaer'sag OWC NS33A Target - S33A (P49) TD / 4 -1/2" Lnr 12000 12000 12000 13200 14400 15600 16800 18000 19200 20400 21600 Vertical Section (ft) Azim = 307.25 °, Scale = 1(in):1200(ft) Origin = 0 N / -S, 0 E / -V by Schlumberger WELL FIELD STRUCTURE NS33A (P49) I Northstar Northstar PF Magnet. Parameters I SSurface Locatron NAD27 Alaska Slate Planes, Zone 04. US Feet Miscel.nao Model' BGGM 2008 Dm 81 043 Date: January 30. 2009 Lal: N70 29 29 845 Northing. ing. 6031141 30 SUS Grid Cony: .23166855° Slot: NS33 ND Ref: Rotary Tab. (56.60 ft atom MSC) 8444 Dec: +22932° FS: 57712.0 nT Lon: W148 41 36 037 Easling : 859820.748US Scale Fad 03999290152 Plan: NS33A (P49) Stay Date: November 20, 2008 -16800 -15600 -14400 -13200 -12000 -10800 -9600 NS33A (P49) NS33A Target Sag TD 1 - 112" Lnr 1 1 N NS33A Target 13200 13200 • 6 -518" Csg Pt EfilfOlt 8 -5/8" Csg Pt Fault Tar @et / Drp 0.5/100 '41°4 End Cie NS33j■ Target Fa NS33PB2 NS33PB1 12000 12000 Cry 21100 A A A Z Tie jn Survey • 0 10800 0 10800 (NI • I I a) l) 9600 9600 V V V End Cry Cry 2.51100 8400 8400 End Cry 113/4" @ 16491'md • KOP Cry 2.5/100 Base Whipstock top Whipstock :Tie-in survey 7200 «-' 7200 • NS33PB1 -16800 -15600 -14400 -13200 -12000 -10800 -9600 «< W Scale = 1(in):1200(ft) E »> • • TRANSMITTAL LETTER CHECKLIST WELL NAME /1/5,f2A PTD# •?o, /1 Development Service Exploratory Stratigraphic Test Non - Conventional Well -- // FIELD: �,e1/oSTA4 POOL: /t�o,E'r, -/STA,e O /G. 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 WELL PERMIT CHECKLIST Field & Pool NORTHSTAR, NORTHSTAR OIL - 590100 Well Name: NORTHSTAR UNIT NS-33A Program DEV Well bore seg Ell PTD#: 2081890 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / PEND Geo Area 890 Unit 11500 On/Off Shore Off Annular Disposal 0 Administration 1 _Pormitfee attached NA 2 ,Leaso_number _appropriate Yes 3 Unique well name and number Yes 4 Well_located in a defined pool Yes 5 _Well_locateri proper distance from drilling unit boundary Yes 6 Well_located proper distance from other wells Yes 7 Sufficient _acreage_available in_d_ritling unit Yes 2560 acres. 8 _Ifdoviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit qan be issued _without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 12/8/2008 13 Can permit be approved before 15-day wait Yes • 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 _Pre-produced injector; duration_of pre-_production less_ than 3 months_ (Forseryice well only) NA 17 Nononven. gas c.onforms to AS31.05.030(j..1.A),(j.2.A-D) NA 18 Conductor string provided NA Conductor set in NS-33 (206-138). Engineering 19 Surface casing proteqts. all known_ =Ws NA 20 _C_MT vol adequate to circ_ulate o_n conductor & surf csg NA Surface casing set in NS-33. 21 _C_MT_v_ol adequate to tie-in long string to surf csg NA Intermediate casing set in NS-33. 22 CMT will over alt known productive horizons No Slotted liner completion planned. 23 Casing designs adequate for C, T, 8 & permafrost Yes 24 Adequate or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). 25 if_a_ re-drill, has_ a 10-403 for abandonment been approved Yes 308-401 26 Adequate wellbore separationproposed Yes Proximity analysis performed. Nearest segment is P&A portion of NS-3 and paths diverge. 27 _Ifdiverter required, does it meet regulations NA BOP stack will already be in place. Appr Date 28 Drilling fluid_ program schematip& equip list adequate Yes Maximum expected formation pressure 8.9 EMW. MW planned up to 13.0 ppg for shale control. TEM 12/9/2008 29 _BOPEs, dothey meet regulation Yes 30 _BO_PE_press rating appropriate; _test to,(put psig in comments) Yes MASP calculated at 3998 _psi, 5000 initial BOP test planned. 4200 p_sisuggested th_ere_after. 410 4( 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without_operation shutdown Yes 33 _Is presence of H2$ gas_ probable No Minor H28 is reported at N". Mud should preclu_de H2S on rig. Rig has sensors a_ncl alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 _Permit_ c_an be issued _w/o hydrogen sulfide measures No Minor H2S (4ppm) reported at N". Geology 36 Data presented on potential overpressure zones NA Appr Date 37 _Seisrnic_analysis_ of shallow gas zones NA ACS 12/8/2008 38 Seabed condition survey(if off-shore) No 39 _C_ontact_name/pho_ne for weekly_progress reports [exploratory only] Yes Ken Allen - 564-4366. Geologic . Public Date Date Date Commissioner: Commissioner Co- s' , n - eogiret,4/e-9-06 Vf / di 47-eno, 1 • • 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. I I ALLIBU T N Sperry Drilling I Surface Data Logging I END OF WELL REPORT I BP Exploration (Alaska) Inc. NS33A Sidetrack I I its! i w se AS ' u fie .t.,,, s „ :3 s1 i ' } I -: j , , • �►. a ► '. ,: ----. I �d , 1� ik I 1 TABLE OF CONTENTS 1 1. General Information 2. Daily Summary 1 3. Morning Reports 4. Bit Record 5. Mud Reports 6. Show Reports 7. Formation Tops 8. Days vs Depth ' 9. Survey Record 10. Data CD 11. Formation Evaluation Logs 1 12. Engineering Log 13. Gas Evaluation Log 1 1 HALLIBURTCIN Sperry Drilling 1 I I 1 ' W GENERAL E WELL INFORMATION G N 1 Company: n (Alaska) Inc. P Ex loratio a Y p � ) I Rig: Nabors 33 Well: NS33 A Field: Northstar I Borough: North Slope Borough State: Alaska Country: United States I API Number: 50- 02923 -3501 Sperry -Sun Job Number: AK -AM- 0006479766 Job Start Date: 05 Feb 2009 1 Spud Date: 01 Jan 2007 Total Depth: 16Apr 2009 at MD 26,090', TVD 11,349', 19:19 hrs Rig Release Date: 20 Apr 2009 1 North Reference: True Declination: 22.910° Dip Angle: 81.044° 1 Total Field Strength: 57713.748 nT Date Of Magnetic Data: 2/15/09 Wellhead Coordinates N: North 70° 29' 29.84" I Wellhead Coordinates W: West 148° 41.36.04" Drill Floor Elevation 55.9' Ground Elevation: 15.670' I Permanent Datum: Mean Sea Level SDL Engineers: Mark Lindloff, Chuck Stringer, Steven Jenkins, Danny Kane, Daniel Sherwood, Dennis Lee I Company Geologist: Randy Wallis, Dan Nice, Anthony Zak Company Representatives: Brian Buzby/ Chris Clemens 1 1 1 1 HALLIBURTCIN I 'perm Drilling 1 1 1 DAILY SUMMARY BP Exploration (ALASKA) NS33A 2_ DAILY SUMMARY 1 02 Feb 2009 Arrive at NorthStar, set unit and began rigging up. 1 03 Feb 2009 Continue Rigging up operations. 04 Feb 2009 Continue Rigging up operations. I 05 Feb 2009 Continue Rigging up operations. 1 06 Feb 2009 Continue Rigging up operations. 1 07 Feb 2009 Continue Rigging up operations. 08 Feb 2009 Continue Rigging up operations. I 09 Feb 2009 Ran in the hole with stands of 5 -7/8" DP from 14,443' to 14,900'. Filled pipe and brought pump rate up to 489 gpm. Killed pumps and SO to 15,063' & tagged with 5k 3 feet out of the window. Picked up to 15,050' encountered 25k overpull. Worked pipe up and down. Put one round to the right into drill string and worked pipe free up to 15,016', encountered another overpull, worked free and racked back 1 stand. Circulated 1.5x bottoms up rotating & reciprocating full stand to clear & clean up debris. Fine metal debris was observed on bottoms up Begin drilling at 15,090 ft. Drilled 510 feet of new hole to 15,600 feet; average Background gas was 45 units. Cuttings coming over the shakers were really low in volume mostly mud components. Avg ROP: 81.5 fph, Max ROP: 468 fph @ 15,303' MD Avg Gas: 20 units (10,000 units = 100 %), Max Gas: 50 Units 1 CLAYSTONE — [40 %]: medium gray, silty to sandy, non calcareous, no remnant structure survival, very soft. SILTSTONE — [40 %]: light to medium gray, slightly sandy with very fine to fine sub - angular to sub- round quartz to dk lith grains, argillaceous, non - calcareous, non to very poor indurated. SAND — [20 %]: very light to medium gray, very fine to occasional fine grain, sub angular to sub round, transparent to black chert, trace of bio mica, poorly indurated, no apparent porosity, no shows. 1 1 DAILY SUMMAY BP Exploration (ALASKA) NS33A P � ) 1 10 Feb 2009 Continued drilling to a depth of 16,640 feet; drilled 1040 feet of new hole. Average background gas of 56 units across the interval. Cuttings coming over the shakers were runny, fine, and sometimes sticky. g Y� very � kY . A little more cuttings are coming over the shakers, averaging between low and near normal; Mostly dissolved clay, and a trace of very fine, loose sandstone. Suspect most of the cuttings are going into solution Avg ROP: 162 fph, Max ROP: 578 fph @ 16,151' MD Avg Gas: 43 Units, Max Gas: 195 units @ 16,575' MD CLAYSTONE — [30 %]: medium gray, silty to sandy, non - calcareous, no remnant structure survival, very soft. SILTSTONE — [50 %]: light gray, very sandy, argillaceous, poorly indurated. SAND — [20 %]: light gray, very fine to fine grain, round to sub angular, translucent fair quartz, medium gray to black chert, traces of pyrite, silty, argillaceous coatings, cemented with clay, very poorly indurated, no show. 1 1 1 1 1 1 1 1 1 1 2 DAILY SUMMAY BP Exploration (ALASKA) NS33A 1 11 Feb 2009 Continued drilling to a depth of 17,037 feet; drilled 397 feet of new hole. The top of the Colville was encountered at 16,687 feet. Cuttings are coming over the shakers, averaging between very low to normal; Mostly soft claystone, some silt and a trace of very fine, loose sandstone. Suspect most of the cuttings are going into solution. Decision to trip out of hole to pick up new BHA was made when unable to continue to slide. Avg ROP: 16.5 fph, Max ROP: 433 fph @ 16,530' MD Avg Gas: was 57 units, Max Gas: 131 units @ 17,037' MD SILSTONE — [60 %]: light gray, very sandy with very fine grain, argillaceous with white clay, very poorly indurated. CLAYSTONE — [30 %]: medium gray, silty to sandy, non calcareous, no remnant structure survival, very soft. SAND — [10 %]: light gray, very fine to fine grain, round to sub angular, translucent fair quartz, medium gray to black chert, traces of pyrite, silty, argillaceous coatings, cemented with clay, very poor indurated, no show. 12 Feb 2009 Pulled out of the hole drilling assembly into whipstock window at 11,060' and circulated 1.5x bottoms up, showed a slight increase in cuttings after the first bottoms up. Wellbore was circulated till shakers cleaned up. Drilling assembly was pulled out of the hole and laid down. Testing BOP's at report time. Very little cuttings coming over shakers while circulating. Samples coming over were finely ground, thick and gummy. I 13 Feb 2009 Tested BOP's to 250 psi low /4500 psi high. Made up Anadril RSS and MWD tools per directional driller. Ran in the hole with MWD tool on 5" DP from pipe shed from 735' to 7150'. 14 Feb 2009 Conduct BOP Test. Pick up BHA and begin the trip back in the hole. Drilling bottom hole assembly was run from 7,150' to 15,011'. Then drilling assembly was run in the open hole. Tight spot was encountered at 16,740'. The holes was reamed and washed down from 16,705' to 17,000'. Very little cuttings coming over shakers while circulating. Claystone, mod sft, mushy, mostly disseminated, very sandy to silty. I 15 Feb 2009 Continue to ream to bottom. Directionally drilled 10 -5/8" hole from 17,039' to 18,962'. More cuttings coming over shakers while circulating. Mostly shale /claystone: dispersed clay, soft -mod frm, becmng more frm, silty, tr carb specs, Avg ROP: 174 fph, Max ROP: 325 fph @ 18,852' MD Avg Gas: 59 units, Max Gas: 126 units @ 18,437' MD CLAYSTONE — [95 %]: dark to medium gray, silty in places, amorph, moderately calcareous, hydrophilic, very soft and sticky. 1 3 DAILY SUMMAY BP Exploration (ALASKA) NS33A SILTSTONE — [5 %]: light gray, very sandy with very fine grain, argillaceous with white clay, amorph to blocky rnd- round, very poor indurated. I 16 Feb 2009 Directionally drilled 10 -5/8" hole from 18,962' to 20,049'. Run out of drill pipe, Circulated 3x bottoms up prior to wiper trip. Start pulling out of hole for a short trip. Drilling assembly was pulled out of the hole from 19,859' to 19,523', pulled 40k over. Ran in the hole to 19,625' and circulated hole clean. . Cuttings coming over shakers while circulating were about the same but by the end of the day the quantity coming over reduced to very low. Samples were mushy, predominately dissolved claystone, silty, trace very fine sand grain. Avg ROP: 134 fph, Max ROP: 288 fph @ 19,197' MD 1 Avg Gas: 81 units, Max Gas: 126 units @ 19,574' MD SAND — [30 %]: light gray, very fine to fine grain, round to sub angular, translucent fair quartz, medium gray to black chert, traces of pyrite, silty, argillaceous coatings, cemented with clay, very poor indurated, no show. SHALE — [10 %]: light gray with mottled white, slightly silty, slightly dolomitic to calcareous, fractured with calcareous fill, blocky to platy, moderately hard. 1 1 1 1 1 1 i 1 1 1 4 DAILY SUMMAY BP Exploration (ALASKA) ) NS33A 1 SILTSTONE — [30 %]: light gray, very argillaceous, amorph, trace of platy, sandy with very fine grain, calcareous, slight increase in metal pieces in sample. CLAYSTONE — [30 %]: light gray, sandy with very fine grain, moderately calcareous fracture fill, very 1 poor indurated. I 17 Feb 2009 Circulate hole at 20049' MD. 700 gpm, 170 rpm. POH w/ 50k overpull. Backream from 19572 ft. to window @ 700 gpm 130 rpm. Pull above window and CBU. Pump dry job and continue trip for pipe I management to 13745' MD. Cuttings coming over shakers while circulating were low -very low, with the solids and MBT increasing in the mud reology suspect most cuttings going into solution. Samples were mushy, predominately dissolved claystone, silty, trace very fine sand grain I 18 Feb 2009 Trip out of hole for DP management to 11928 ft and install super sliders. Wait on weather to change out crews, out of workable hours. Service rig and TIH. Wash to bottom from 19590 ft. Nothing unusual seen at shakers. Drilling ahead to 20447'. Cuttings coming over shakers while circulating increased, with the solids and MBT still increasing in the mud reology suspect most cuttings going into solution. Samples were uncons silt, dissolved clayst, minor tr loose sand 1 Avg ROP: 100 fph, Max ROP: 140 fph @ 20,315' MD Avg Gas: 86 units, Max Gas: 164 units @ 20,257' MD 1 SILTSTONE — [40 %]: light gray, very argillaceous, amorph, trace of platy, sandy with very fine grain, Calcareous. SHALE — [10 %]: light gray with mottled white, slightly silty, slightly dolomitic to calcareous, fractured I with calcareous fill, blocky to platy, moderately hard. 1 19 Feb 2009 Drill ahead from 20447 ft to 22,269 ft. Backream 90 ft on connections, reduce pump rate to 75% on downstrokes. Cuttings coming over shakers while circulating wavered from low to normal throughout the day, 1 solids and MBT still increasing in the mud reology. suspect most cuttings going into solution. Samples were generally unconsolidated silt, diseminated clay, trace of very fine grain sand 1 Avg ROP: 100 fph, Max ROP: 169 fph @ 21,339' MD Avg Gas: 81 units, Max Gas: 175 units @ 21,986' MD I SANDSTONE — [15 %]: light gray, very finer, translucent fair quartz, medium gray to black chert, traces of pyrite, silty, argillaceous coatings, cemented with clay, very poor indurated, no show CLAYSTONE — [85 %] light gray, gummy, sticky, amorph, very calcareous, soft. I 20 Feb 2009 Drill ahead from 22,269 ft to 23,488 ft MD. Start weight up to 10.5 ppg for the HRZ formation. Cuttings coming across shakers increased to normal as mud was weighted up to 10.5 ppg. Shale soft to moderately firm, blocky, slightly silty, platey, occasionally fissile, trace of pyrite, minor trace of splintery elongated slivers. I 5 DAILY SUMMAY BP Exploration (ALASKA) � ) NS33A Avg ROP: 85 fph, Max ROP: 148 fph @ 22,957' MD Avg Gas: 81 units, Max Gas: 138 units @ 22,800' MD CLAYSTONE — [100 %]: light gray, dark brown -brn in places, slightly calcareous, moderately hard, blocky - platy, fissile in places, slightly silty. I 21 Feb 2009 Drill ahead to TD at 24151 ft. Cuttings coming over shakers while circulating wavered between very low to normal throughout the day. Cuttings were fine, coffee grounds, predominately shale and siltstone, blocky to subsplintery with minor loose sand grains Formation Tops: - Colville 16,687' MD - 6,907' TVDSS - Kalubik 23,041' MD - 8,726' TVDSS - KUP C 23,651' MD - 9,188' TVDSS - LCU 23,782' MD - 9,297' TVDSS - KUP B 23,829' MD - 9,336' TVDSS - KUP A3 23,897' MD - 9,392' TVDSS - Fault 27 23,924' MD - 9,415' TVDSS - TMLV 23,946' MD - 9,433' TVDSS - MLV1 24,060' MD - 9,528' TVDSS Avg ROP: 91 fph, Max ROP: 154 fph @ 23,490' MD Avg Gas: 197 units, Max Gas: 694 units @ 23,902' MD SANDSTONE — [90 %]: dark brown to brown, very fine grain grading to silt, well sorted, sub angular to sub round, tan, transparent to opaq, mostly qtz grains, unconsolidated, loose, calcareous, traces of glaucanite and pyrite, any fluorescence masked by steel lube EP. SILTSTONE — [10 %]: light gray, gray /brown, dark brown ip, soft, grading to sandy in places, calcareous, firm- moderately hard. I 22 Feb 2009 Backream out f/23,488 ft to 19,208 ft. Increased torque and pump press at 23085 ft. Cuttings coming over shakers while circulating were very low all day. Still maintaining the consistency of coffee grounds, predominately silty shale, siltstone, trace of sand and silt grains. I 23 Feb 2009 Continue to back ream from 19,109 ft to 14,531 ft. Cuttings coming over shakers while circulating remained very low. Still maintaining the consistency of coffee grounds, predominately silty shale, siltstone, trace of sand and silt grains. Sample catchers went off the island today. 1 1 6 DAILY SUMMAY BP Exploration (ALASKA) NS33A 24 Februa ry -12 March Mud Loggers are off the island. While gone rig landed 8.625" liner at 23,540 ft. I 13 Mar 2009 Clean out assembly was run from 16,200' to 17,325'. Circulated and conditioned mud to 12.0 ppg mud weight in & out. Continued running in the hole from 17,331' to 20,192'. Circulate and conditioned mud, 12.0 ppg mud weight in/out. Total LSND losses over shakers: 106 bbls. LSND losses to formation: 0 bbls. I 14 Mar 2009 Circulated and conditioned mud at 20,192'. Circulated bottoms up at 400, 500 and 650 gpm. No losses to hole and small increase in barite to none across shakers after each bottom up. Mud weight @ 11.9+ In/Out. Ran in the hole 15 stands to 21,616'. Circulated bottoms up at 400, 500 and 600 gpm. No losses to hole and no increase in barite after each bottom up. Ran in the hole clean out assy to 23,518', circulated 3x bottoms up. Pumped 80 bbl 8% Steel Lube EP sweep, Torque before sweep = 35k ft/lbs, torque after sweep = 30k ft/lbs. 1 15 Mar 2009 Washed & reamed open hole slowly from 23,540' to 24,151'. Bottoms up brought up 50% excess barite across shakers and after bottoms up barite diminished considerably. Drilled 30' of new hole from 24,151' to 24,181'. Pulled clean out assembly inside the 8 -5/8" shoe and circulated mud. Performed Leak Off Test and calculated tolerance to 13.0 ppg EMW. Performed high flow test with 775 gpm that showed 180 -210 bbl/hr dynamic loss rate. Ran in the hole to 23,900' and spotted 78 bbl LCM pill. I 16 Mar 2009 Pulled out of the hole to 22,665' to get above LCM pill. Pumped 3 -4 bbl per stand pulling into casing. Staged up circulation above LCM pill, with 600 gpm observed 60 -72 bbl/hr loss rate decreasing to 24 bbl/hr after 30 min. Pumps were stopped and pill soaked for a while. Staged up to 450 gpm, 27 bbl/hr loss rate and then slowed to none after 120 min. Ran in the hole to 23,540' & spotted 100 bbl, 100 ppb LCM pill. Pulled out of the hole to 21,712'. Staged up to 750 gpm with 100+ bbl/hr loss rate. Prepared G &I mix pit for EZ squeeze pill I 16 Mar 2009 Circulated and condition hole while mixing EZ squeeze LCM pill. Ran in the hole to the shoe and stage up circulation from 250 gpm to 500 gpm. Started rotating and reciprocating, loss rate increased from 130 bbl/hr to 180 bbl/hr. Pumped 95 bbl EZ Squeeze slurry down hole with 62 ppb EZ Squeeze final concentration. Added 0.2 ppb bicarb to pretreat mud for hardness that EZ Squeeze pill carries. No barite was mixed throughout the day with a consistent 12.0 ppg in and out. Total losses for past 24 hrs : 120 bbls. Total Losses for the well: 1,427 bbl. 18 Mar 2009 Rig performed hesitation squeeze. Made up Surface safety valve, Head Pin, Cement Line, Bleeder line and position pipe in stack to upper pipe rams. Isolated Pits to Pit #1E & 1D to monitor volume pumped. Rig Chart Recorder on Annulus side & tested surface line. Pumped 20 bbls. Final Pressure built up to 596 psi on drill pipe, 490 psi on the casing side gauge. Monitor for 1 hour, with pressure bleeding down to 420 psi on the casing side gauge. Total losses for past 24 hrs: 33 bbls. Total Losses for the well: 1,460 bbl. 1 7 r 1 DAILY SUMMAY BP Exploration (ALASKA) NS33A I 19 Mar 2009 Washed and reamed from 22,640' to 24,181'. Reamed in the hole slowly at 1 hour per stand monitoring I shakers for EZ squeeze LCM pill. Mudweight was maintained at 12.0 ppg in and out. No losses were encountered while reaming downhole. EZ squeeze was cleaned out without any sign of it coming across shakers. Mud was pretreated with 1/4 ppb Soda Ash, carefully watched for greasing problems and calcium contamination while 1 reaming and washing the ez squeeze pill with no adverse effect to the mud system. No mud losses for today. I 20 Mar 2009 Finish circulating on bottom and trip out 7 stands to the 8 5/8" liner shoe. Stage pumps & establish circulation to condition mud & perform FIT to 14.0ppg EMW at the 23930' MD fracture. Establish circulation I and condition mud. Start tripping out at 3min/stand while pumping 2bpm from 23550' MD to 14761' MD as of midnight. Trip gas from open -hole section averaged 30 -50 units with one peak of 83 units centered on 24139'MD. After open hole lag surfaced, background gas fell and averaged 15 -20 units. 1 21 Mar 2009 Continue tripping out at 3 min/stand from 14761' to 14050' MD while pumping 2bpm. Reciprocate at I — 14050' MD, 13945' MD, and 13855' MD while circulating at 760gpm to condition mud. Continue tripping out racking back stands to 6387' MD. Start laying down singles from 6387' MD to 891' MD as of report time. 1 22 Mar 2009 Finished laying down BHA, tested the BOPE and repaired the swival packing, picking up the 7 7/8" BHA I at report time. ii 23 Mar 2009 II Continue & finish building BHA. Shallow test MWD motors /tools as well as function -test Rhino Reamer. Tripped in picking up singles until 11756' MD upon which started running with racked -back stands to 14390' MD. Stage pumps and establish circulation at 455gpm while conditioning mud to a homogeneous I 12.0ppg as of report cut -off. I 24 Mar 2009 Continue circulating & condition mud at the 8 7/8" liner (bit depth 14390' MD) to 12.0ppg. Resume tripping in stands to 20975' MD filling pipe occasionally. Repaired washpipe on top drive. Continue tripping in I to 23440' MD running in stands and start staging pumps to circulate & condition mud. Continue tripping in experience tight spot at 23605' MD that required washing & reaming down to 23728' MD. Trip in to 24000' MD on elevators before tight spot required washing & reaming. Circulating at 140gpm with string rotation of 22gpm I at 23993' MD as of midnight. l 1 25 Mar 2009 Circulated & conditioned mud at 24000' MD. Mud from open -hole section varied from 11.95ppg to 13.7ppg with surface equipment unable to condition mud before going downhole. Ceased circulation & pulled up I within the 8 5/8" liner shoe to condition surface mud. Trip back in open hole having to wash & ream through tight hole conditions. Trip in while reaming and circulating to 24078' MD at 150gpm. Stage circulation up to 415gpm experiencing occasional packing off. Condition mud on surface and staging circulation rate as of midnight report time. Minimal trip gas with max of 22 units. I 1 8 DAILY SUMMAY BP Exploration (ALASKA) NS33A P � ) 26 Mar 2009 Stage pumps to 500gpm while reaming from 24078' MD to bottom. Trip gas averaged 55 units with a max of 114 units associated with bit depth 24146' MD. Tagged bottom at 06:00 and drilled 9" hole from 24181' to 24396' MD / 9868' TVD. ROP averaged 25 -35 fph except while weighting up mud from 12.0 to 12.5 where ROP averaged 5 fph. g p p g g P 12.5ppg g p Drilled gas averaged 42 units with a peak of 89 units from 24202' MD with no connection gasses observed. Drilled lithology primarily a silty -shale with some siltstone. ECDs are 13.78ppg on bottom with a 12.5ppg WBM pumping at 545 gpm. Cuttings coming over shakers while circulating wavered between very low throughout the day. Cuttings were fine, coffee grounds, predominately shale and siltstone, occasional loose sand and tr ace barite. Avg ROP: 23 fph, Max ROP: 66 fph @ 24,303' MD Avg Gas: 42 units, Max Gas: 89 units @ 24,202' MD SHALE — [80 %] dark brow to- brown/dark brown, silty, fine- medium pieces, blocky to sub platey. medium gray/brown, soft in places SILTSTONE — [20 %]: medium gray/brown, soft in places. I 27 Mar 2009 Continue drilling 9" hole from 24396' MD to 24586' MD at an average ROP of 35fph. Replaced screens I on both pumps in an attempt to alleviate MWD detection problems. Continued drilling to 24687' MD before shutting in Pump #2 to repair the pulsation dampener. Continued drilling to 24181' MD (10228' MD). ROP averaged 40fph across all drilled intervals consisting of primarily silty- shales with a few siltstone stringers interbedded. Gas (and normalized gas) have remained relatively steady at 50 -70 units with no connection gasses observed. No Mud Report as of 05:00. Cuttings coming over shakers while circulating wavered between low and very low throughout the day. Cuttings were fine, coffee grounds, predominately shale and siltstone, occasional loose sand and trace of barite. Toward the end of the day samples turned more splintery, platety and firmer. Avg ROP: 40 fph, Max ROP: 79 fph @ 24,700' MD Avg Gas: 43 units, Max Gas: 78 units @ 24,571' MD SHALE — [80 %]: light brown to brown, gray to dark gray in places, dark brown in places, Silty to very silty, sandy in places, blocky, splintery, firm, Scattered mica and carb specs, abundant loose glaucanite grains, slightly calcareous. SILTSTONE — [20 %] medium gray /brown, soft in places... I 28 Mar 2009 Continue drilling 9" hole from 24818' MD to 24873' MD where MWD detection was lost. Changed flow rate from 450 to 515gpm while pumping surveys. Continued drilling from 24873' MD to 25319' MD (10668' TVD) with an average interval ROP of 32fph and recurring survey detection problems. Drilling through the shale- dominant Kingak formation while seeing a gradual rise in the average background gas from 75 units to 105 units with no connection gasses observed. Chromatograph analysis indicates increasing heavy hydrocarbons [Occasional chromatograph extended run times increased from 50 to 150 seconds indicates the presence (concentrations unknown) of C6 -C8 hydrocarbon gasses) while drilling through the interval. Maximum Sperry - calculated ECDs of 13.93ppg on bottom and at the shoe. Cuttings coming over shakers while circulating stayed low throughout the day. Cuttings were very minor mush - coffee grounds, predominately shale and a trace of siltstone, occasioanlly fissile splintery pieces were seen. 1 9 DAILY SUMMAY BP Exploration (ALASKA) NS33A P � ) Avg ROP: 32 fph, Max ROP: 61 fph 24,967' MD g P P Avg Gas: 69 units, Max Gas: 108 units @ 25,319' MD SHALE — [85 %]: light brown to brown, lightt gray to gray, silty, angular to platety, soft, firm in laces grading to siltstone, scattered mica and carb specs, very p ,tn' g p slightly calcareous. SILTSTONE — [15 %]: medium gray/brown, amorph, moderately soft, argillaceous, occosionaly sandy, generally grading to silty shale. it 29 Mar 2009 Continue drilling 9" hole from 25319' MD to section TD of 25612' MD (10929' TVD) averaging 25fph with background gas averaging 80 -125 units with no significant peaks nor shows. A connection gas of 104 units over a 61 unit background (43 units over background) was observed from the last drilled connection at 25535' MD. Upon reaching TD, started circulating 1.5x open -hole volume while conditioning the open -hole section. Circulation lost at bit depth 25599' MD after circulating —6200 strokes with no ECD anomaly; formation lag from 25595' MD to 25612' MD was lost or is of marginal quality from lost circulation. Pulled up one stand and spotted LCM pill while dropping pump rate to 123gpm to control losses before starting to trip to the 8 5/8" shoe. Trip gas while pumping averaged 100 units with a max of 155 units 45 minutes after calculated bottom's up lag came to surface (Calculated lag DOES NOT account for losses). Approximate losses as of midnight 650bbls. Cuttings coming over shakers while circulating wavered between very low to normal throughout the day. Cuttings Were fine to coffee grounds, Shale, firm, platey- fissile, splintery, with siltstone, sand, disaggregated very fine to fine grained, trace of glaucanite and pyrite Formation Tops: - Kingak 24,390' MD - 9,807' TVDSS - TJF 24,505' MD - 9,904' TVDSS - TJE 24,734' MD - 10,156' TVDSS - TJD 24,927' MD - 10,267' TVDSS - TJC 25,125' MD - 10,440' TVDSS - TJB 25,270' MD - 10,569' TVDSS - Sag River 25,569' MD - 10,835' TVDSS Avg ROP: 25 fph, Max ROP: 59 fph @ 25,442' MD Avg Gas: 88 units, Max Gas: 146 units @ 25,592' MD SHALE — [60 %]: brown to dark brown, gray to dark gray, platey, thin angular cuttings, fim to hard, brittle, non calcareous.. SILTSTONE — [30 %]: medium gray/brown, amorph, moderately soft, argillaceous, occosionaly sandy, generally grading to silty shale. SANDSTONE — [10 %]: clear to opaque, brown, fine to medium grains, coarse in places, sub angular to sub round, moderately sorted, loose, trace glaucanite.. 1 1 1 10 DAILY SUMMAY BP Exploration (ALASKA) NS33A 30 Mar 2009 Trip out from 24484' MD to 23444' MD (within 8 5/8" liner shoe) having to stop and ream through tight spot from 24428' to 24398' MD. Hole taking proper fill while pumping out and no static losses observed. Continue tripping out from 23444' MD to 16010' MD while pumping 2bpm with no losses observed. Trip gas has steadily dropped from an average of 100 units to 35 units as of report time. 31 Mar 2009 Continue tripping out while pumping 2bpm from 16010' MD to 14230' MD. Stage pumps and establish circulation to 200gpm experiencing no losses. Pull out one more stand and stage pumps to 600gpm to shear the mud across the bit. Attempted to open CCV -- unsuccessful. Once new mud sheared twice through bit, continued tripping out and racking back stands on elevators from 14196' MD to 8807' MD as of midnight. Trip while pumping stands out averaged 30 -35 stands slowly diminishing over time. Trip gas while shearing new mud averaged 50 -65 units initially before slowly dropping to 30 units by the end of the circulation with no peaks nor anomalies. Cuttings coming over shakers while circulating wavered between very low to above normal throughout the day. Cuttings ranged from 20 to 70 percent Loss circulation material throughout the day. The content of the samples ranged from 20% to 40% Barite and the rest ranged between 10 to 50% unconsolidated, very fine sand and silt 01 April 2009 Continue pulling stands from 8770' MD to 7837' MD. Pull out and lay down singles from 7837' MD to 1000' MD. Break down and lay down drilling BHA. Rig up, test, and rig down BOPE equipment and rip up liner running equipment. 02 April 2009 Finished rigging up liner running tools when the EZC 404Z liner shoe showed a drift of 5.796 ", not 5.875 ". Mobilized additional EZC 404Z from Prudhoe and drifts checked out. Run 6 5/8" liner followed by 4" DP to 6133' MD as of report time, circulating every 1000' MD at 600gpm. No losses while static or circulating. 03 April 2009 RIH with 6 5/8 liner on 4 1/2" dp, to 7782' , washing down every 10 stds. Clrculate at 7782' at 600 gpm. RIH to 11,467 cont to wash down every 10 stds. M/u x/o and change air slips and cont to RIH with 6 5/8 dp to 14,175. continue to fill dp every 10 stds circulating at 14,175 at 600 gpm. Continue to RIH with a depth of 16779' at the time of report. No recorded losses or significant gas peaks were noted. 04 April 2009 RIH with 6 5/8 liner to 18,935' filling every stand. Circulate and condition and cont to RIH the hole to 22,470' and encounter tight hole. Continue to RIR to 22,900' filling every stand. M/U T/D and continue to RIB rotating and washing to 23,517. RIH to 24,137 at wich point tight hole is encountered begin rotating and washing to a current depth of 24,272' at the time of report. No notable gas peaks or fluid losses have occured. A increase in MW out was recorded from a 12.5 to a 12.6 at approx 23:15. 1 1 11 DAILY SUMMAY BP Exploration (ALASKA) NS33A I 05 April 2009 RIH with 6 5/8" liner washing and reaming to 24,415' and pump a 100 bbl steel lube pill. Continue to RIH to 24,480' and stalled p/u and ream back to 24,465. RIH to 25,129 and encounter tight spot while working 1 through a slight pack off occurred. Reduce pump rates and returned good circulation. Continue to RIH to BTM to a depth of 25,122 st the time of report. Increase in BG gas was recorded correlating to the increase in Mud Weight out of the hole. A max gas of 247 units was recorded with a BG gas of 156 units. Gas gradually decreased I roughly following the MW trend currently RIH with a BG gas of 18 units. A fluid caliper test was conducted with Calcium Carbide. Test resulted in a gas peak of 405 units @ 25,342 strokes. Calculated BTM's Up was 24,247 strokes and the first sign of carbide were detected at 23,905 strokes. I Cuttings coming over shakers while circulating were mostly very low, occasionally in the beginning of the day they were normal to moderately normal. The content of the samples ranged from predominately to a trace of Barite and the rest ranged between a trace to all loose very fine sand and silt. 1 06 April 2009 RIH with 6 5/8" liner to 25,459' and encountered pack off. Reduced pump rates and worked through, I continued to wash and ream to 25,575'. Packed off and observed increased torque . Reduced pump rates and increase pressure in 5001b increments, regain circulation and continue to circulate gradually increasing pump pressure. Continuing to circulate at the time of report. Max gas recorded was 177 units and an average I background gas while circulating of approx 18 -20 units. Cuttings coming over shakers while circulating remained very low throughout the day. The content of the samples ranged from coffee grounds to fine cuttings. 80% shale, 20% loose sand and silt with traces of LCM. I 07 April 2009 RIH to 25578' and establish circulation attempt to rotate and work liner down, torqued up and packed off. Attempt to regain circulation with no success. Attempt to release from liner and await decesion from town for I further instruction while performing basic rig maintenace. Release from hanger and circulate 2x liner volume. Pump slug and POOH 2 stnds, dry job was deemed ineffective. Circulate while reciprocating and pump another slug and begin POOH of hole.Currently tripping out of the hole with a depth fo 19880' at the time of report. No 1 significant losses or gas peaks were recorded while circulating. 08 April 2009 I P0011 to 19,788' and pump slug cont to POOH to 11,156' and pump another pill. Continue to nd L/D BHA and prepare for BOP test I 09 April 2009 Complete BOP test and L/D test tool, slip and cut drill line. P/U dumb iron BHA w/ junk baskets and mill assy and begin RIH w/ 4.5" dp filling pipe every 3000 ft. I 10 April 2009 RIH with c/o assy on 4.5" dp to 11,686' filling dp every 3,000 ft one joint at a time. M/U x/o to 5 I 7/8" dp and necessary slips and continue to RIH to 14,067'. Stage pumps to 700 gpm and circulate 3 btms up racking back one stnd per btms up. Continue to circulate to change mud from a 12.5 to a 9.7 ppg racking back one stand after every btms up. No significant gas peaks were observed while circulating and mud solids consist of predominatly barite with very fine sand and siltsones. I 1 11 April 2009 RIH to 13,563 and displace hole with 9.7 ppg mud then continue to RIH to 23,341' tagging liner top. I continue to R11-1 to 25,456' filling every stand and tag 8 5/8" liner top. Stage pumps up to 430 gpm and continue I 1 12 DAILY SUMMAY BP Exploration (ALASKA) NS33A changing mud to 9.7 ppg. Continue to RIH to 25,461' and begin to mill out landing collar. Max gas recorded was 20 units coinciding with the return of heavier mud during displacement. Gas readings were then insignificant as the flow was diverted from across the shakers. 1 12 April 2009 Wash and ream to 25534' and tag float collar and drill out continue to wash and ream to 25,582' tag shoe drill out shoe and begin packing off work pipe to free. Continue to wash and ream rathole and drill 5' of new formation to 25,617' md. Cycle pumps trying and move debris to junk basket and circ. 2x 8 5/8" liner volume and begin POOH. Pump out of hole to 8,255" at the time of report. A max gas of 34 units was recorded at btms up, gas peak was most likely diluted due to nature of circulation (ie. pumps on and off). Cuttings lithology was predominantly It gy - gy sh, flky, pity w tr of v. f sd and asst lcm and barite and metal shavings. No significant losses or gains occurred while circulating or static. 1 13 April 2009 Pump slug and POOH to 13,976' circulate 2x btms up. Pump another slug and continue to POOH L/D BHA and prepare to run USIT log. Currently rigging up USIT log on Schlumberger wireline at the time of report. Max gas recorded while circulating was 10 units with a bg gas of 4 units. No losses were recorded. I 14 April 2009 Continue to run USIT log on Schlumberger wireline. P/U BHA and begin RIH, shallow pulse test MWD tools at 1,000 md. Contiune to TIH. 1 15 April 2009 RIH to 6955' and and slip and cut drill line. Cotinue to RIH to 12,070 remove 4.5 airslips and m/u 5 7/8' airslips. M/U x/o for 5 7/8' pipe and continue to RIH to 25,511 and begin washing and MAD passing to btm.Pump spacer pill and 9.7 ppg flow pro mud to begin swapping active system. Mud is being dumped and diverted from the shakers disabling gas monitoring equipment. Currently MAD passing with a bit depth of 25,609' md. 1 16 April 2009 Complete MAD pass to 25,611' and perform FIT and drill new formation from 25611' - 25,720'. Retrieve samples w/ Schlumberger stethescope at 25,686' and 25,692'. Drill ahead to 26,090' final TD 11,349 TVD. TD well at 19:19 4/16/09. Circulate btms up and begin logging open hole w/ Schlumbeger stethescope to obtain pressure points. Formation tops were called at 25,680' and for the top of Shublik, 25,786' and for the top of Shublik D 25,794' md, top of Ivishak and 25,868' md, at the Oil to Water contact point. Gas peaks occured at the top of the Shublik D formation at 153 units and a BG gas of approx 140 units. This seemed to be centered on a mod srtd, sb rd- ang, pred qtz sd which comprised the production zone lithology. Recorded gas at the oil to water contact point was 57 units with a BG gas of approx 50 units. No connection gasses or significant mud losses were recorded. 17 April 2009 Running Schlumberger Stethoscope to obtain pressure points ang begin POOH to 25,350' and begin looking for casing marker to 25,300'. Continue to POOH to 24,806' and look for casing marker at 24,470. Rill to btm washing and reaming occassionally and log with Schlumberger caliper tool to 25,820'. RIH to 26,032' and log to 25,940'. Ream and wash back down to btm and pump pill. Begin pumping out of hole to 25,036' and drop circ sub ball to activate circ. sub and continue to pump out of hole. 18 April 2009 POOH from 23,706' to 22,325' and circulate 3x the 8 5/8" liner volume. Pump out of hole from 23,225' to 18,007'. I Continue to POOH from 18,007' to 14,460 not pumping. Continue pumping out of hole to 14,241 and circulate lx btms up, rack back one std and continue to circulate 2x btms up to 14,3654'. Pump slug and POOH to a current bit depth of 13,792' at the time of report. No significant gas peaks or mud losses occured, max gas was recorded at 14 units while circualting. 1 13 DAILY SUMMAY BP Exploration (ALASKA) � ) NS33A 1 19 April 2009 POOH wet from 13,792 to 12,074' L/D X/O sub install 4.5" airslips and cont to POOH wet 2,995'. L/D 4.5 DP and POOH I to 430' and L/D BHA. Test BOP's and P/U bridge plug BHA and RIH to 1,172' at the time of report. 20 April 2009 I Sperry Rigged Down and off premises. 1 1 1 1 1 1 t 1 1 1 1 1 1 1 1 14 Customer: B.P. Exploration Report No.: 16 Well: NS33 A Date: 3/14/2009 - 00:00 ' i iii IT`' Area: Beaufort Sea Depth 24152' Lease: North Star Is. F ootage Last 24 hrs: 0' it Rig: Nabors 33E Rig Activity: Circ & Cond Mud �' • et a Job No.: AK- AM- 0006479766 Report For: Distribution List • A Mudlogge Morning Report Daily Cost: $2,871.00 Total Cost: $97,806.51 Current 24 hr Avg 24 hr Max Pu and Flow Data k R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 140 spm Flow rate 503 gpm Gas* 8 units 5 unit ( 56 units @ —23500 ) Pump Capacity 3.7 gps N Pump Liner & Stroke Lengths 5.5x12 in Sample Quality 0 Good ❑ Fair ❑ Poor Pump Pres 2224 psi a f : `• - �x - : t , m , m ,.., . .fit " v: ., .. > . c sae s IA Mud Wt In 11.90 ppg Visc 47 secs A PI filt 3.9 ml HTHP 9.9 ml Mud Wt at Max Gas 11.9 ppg < Mud Wt Out 11.90 ppg PV 14 cP YP 34 Ibs /100ft2 Gels 9 \ 13 \ 17 MBT 8.0 pH 8.7 Sd - % Bit No.: 4 Type: Sec QHC1S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x - x - x - TFA: 1.3250 4' Wt On Bit: N/A RPM: N/A Hrs. On Bit: N/A Total Revs on Bit: Footage for Bit Run 0 ': Trip Depth: 23500 ft Trip Gas: 56 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm g Tight Spots: to to to Feet of Fill on Bottom: * ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal ft Lmstn Dol Chrt ;:..,, K . 10 20 70 Connection Gas and Mud Cut ft units ppg ppg ft units ppg ppg ft units ft units ppg ` ft units ft units rira ft units ppg `¢ u nits ppg ft units ppg ft ppg if units units ppg A ppg ft units ppg Azi > > r, :; ; * w . ..� r. , . K -N wo .. ... ,x .. - - �"`•`." . v A - ,:w. . . , _ ... fir .< s .. ? . . i, i trf:Wilk Of • e GAS PEAKS Depth Gas in units Chromatograph in ppm i 0-•? Max Background C1 C2 C3 C4 Tot C5 Tot AI to to u to to to to tfi • � asp v s a 4 .> s . t , v . „ 5.,r- f , s �. k 'us`�rg -. 3 ..,_ : `� '`a a ... ., � , ,: #�.` s ' '*. `. ">c.rc, •c: t ...: 3„'� �_ �. • �k Mudloggers recalled 03 -12 -09 after 8.625" liner set at 23540' MD. Continue running in hole from 20180' MD to 23500' MD . as of midnight cut -off. Tripped in on elevators except at 21150' MD and 23500' MD where the rig circulated and conditioned # mud while rotating and reciprocating the drillstring. Average background gas while circulating ranged from 5 to 25 units with N a max trip gas peak of 56 units while circulating at 23500' MD. iE G & I Magnets: 1.0 Ibs Rig Magnets: 0.25 Ibs Total Metal cuttings: 1.25 Ibs Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air it ,;. � =a P-.Y .t �. v ,+ .s „ �.• , $. 3 �- *xc ":�.5.�, 'E.� -�; y;.'a... 2 . <�'`>."_.. 3 a�Y'#aa. , ..z� • � .. „ ..f � ��x.. 3 _ aFa��= Customer: B.P. Exploration Report No.: 17 It Well: NS33 A Date: 3/15/2009 - 00:00 HALLISLATON °' - Area: Beaufort Sea D epth 2 4181' ti, 1. Lease: North Star Is. F ootage Last 24 hrs: 3 0' Rig: Nabors 33E Rig Activity: Circulating fig Mudlogger's Morning Report Job No AK -AM -0006479766 Report For: Distribution List it F 11-1 Daily Cost: $2,871.00 Total Cost: $100,677.51 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 11.18 ft/hr ( ft/hr ( @ 24177' ) Pumps 44 spm Flow rate 158 gpm :i Gas* 15 units 27 unit; ( 106 units @ 24186' ) Pump Capacity 3.7 gps °` Pump Liner & Stroke Lengths 5.5x12 in. - A Sample Quality El Good 0 Fair © Poor Pump Pres 705 psi 1 , .N ..: ._i : 4 . *�_. - .. :::,;,,'''',.L:'--;t fr �� Mud Wt In 12.00 ppg Visc 46 secs API tilt 3.7 ml HTHP 11.1 ml Mud Wt at Max Gas 12.0 ppg t Mud Wt Out 12.00 ppg PV 15 cP YP 30 Ibs /100ft2 Gels 9 \ 14 \ 16 MBT 8.0 pH 8.7 Sd - % '.; 4 �� _ ' Bit No.: 4 Type: Sec QHC1S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x - x - x - TFA: 1.3250 Wt On Bit: 20 -25 RPM: 120 Hrs. On Bit: 2.7 Total Revs on Bit: 2070 Footage for Bit Run 30 Tr Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to * t g p to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt .i 10 20 70 Connection Gas and Mud Cut (BG = Background) 23505 ft 86 units 9 BG units 12 ppg ` 23988 ft 67 units 44 BG units 12 ppg " 23609 ft 100 units 59 BG units 12 ppg „ 24082 ft 68 units 48 BG units _ 12 ppg 23797 ft 69 units 45 BG units 12 ppg ft units BG units ppg 23891 ft 44 units 26 BG units 12 ppg ft units BG units ppg -0 h,`,_g1'§',:. :', -b 4--�' - .. _ >t ., is its. * x ;i. _ ... >Q � _ , _,4 r43g _ .-„ :-x, .4` _,,.,1 . - - 1 � A . _ � „3: --< ..,_ . '.` GAS PEAKS I. Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 24152' to 24181' 103 41 3133 151 74 24 10 to to lk t. to to Circulated and conditioned mud at -23500' MD before tripping to bottom while washing and rotating the drillstring. Minor connection gasses seen at all but one connection while tripping averaging -1.5 to 2 times background gas levels of 25 -50 units. Drilled 30' new formation with average background gas of 35 to 50 units and pulled into shoe to perform LOT. Performed LOT twice with formation stabilizing at 13.0ppg. Performed fast flow -rate test and observed 180- 210bbI /hr Iti st dynamic losses at 775gpm with a 13.68ppg ECD. Tripped to bottom and spotting 78bb1 LCM pill as of report time. si G & 1 Magnets: 2.5 Ibs Rig Magnets: 0.5 Ibs Total Metal cuttings: 3.0 Ibs Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air = r ` X ,. .. z 'a '- dot ; i. .- f tt kil Customer: B.P. Exploration Report No.: 18 1 4 Well: NS33 A Date: 3/16/2009 - 00:00 Rill j Area: Beaufort Sea Depth 24181' Lease: North Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig Activity: Circulating A Mudlogger's Morning Report Job No.: AK- AM- 0006479766 Re For: Distribution Li i a. Daily Cost: $2,871.00 Total Cost: $103,548.51 it 4,7,1- Current 24 hr Avg 24 hr Max Pump and Flow Data ' g> R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 126 spm Flow rate 456 gpm Gas' 12 units 24 unit: ( 69 units @ N/A ) Pump Capacity 3.7 gps Pump Liner & Stroke Lengths 5.5x12 in Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 1842 psi s = Mud Wt In 12.10 ppg Visc 44 secs API filt 3.8 ml HTHP 10.7 ml Mud Wt at Max Gas 11.9 ppg 1] Mud Wt Out 12.00 ppg PV 14 cP YP 35 Ibs /100ft2 Gels 8 \ 13 \ 16 MBT 8.0 pH 9.0 Sd Bit No.: 4 Type: Sec QHC1 S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x x x TFA: 1.3250 tgi Wt On Bit: 20 -25 RPM: 120 Hrs. On Bit: 2.7 Total Revs on Bit: 2070 Footage for Bit Run 30 ,n Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm y -4 Tight Spots: to to to Feet of Fill on Bottom: * ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt 10 20 70 °l Connection Gas and Mud Cut (BG = Background) ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg I V ft units BG units ppg ft units BG units ppg il ft units BG units PP9 ' ft units BG units ppg it GAS PEAKS � Depth Gas in units Chromatograph in ppm : Max Background C1 C2 C3 C4 Tot C5 Tot t. to , to to to ii to ill I to . �3` ,. -TVN. ,z`� , tiji 3_�,, " ' r'=- �.-,. . r` , ' #O a`- " t' - ' "tee z g- k Spot LCM pill, pull up within shoe and stage pumps to establish Toss rates. Trip back to bottom, condition mud, and spot another LCM pill before tripping back up within the shoe. Circulate within the shoe and stage pumps to establish Toss rates over time. Circulating in shoe as of cut -off time preparing to trip back down to spot another LCM pill. Background trip gas over the past 24 hours has averaged 20 -45 units with a maximum gas of 69 units. G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs "' Costs Are Carried Up to March 16, 2009 "' „.4'4„. Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air v 4''m w- „- f ' a -• - 4a a r a s Customer: B.P. Exploration Report No.: 19 Well: NS33 A Date: 3/17/2009 - 00:00 IN ':::'''' Area: Beaufort Sea Depth 24181' it Lease: North Star Is. Footage Last 24 hrs: 0' z. t Rig : Nabors 33E Rig Activity: Trip Out 19 Stands Job No.: AK -AM- 0006479766 Report For: Distribution List Mudlogger s Morning Report Daily Cost: $2,871.00 Total Cost: $1 06,419.51 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm Gas* 0 units 8 unit ( 35 units @ N/A ) Pump Capacity 3.7 gps - Pump Liner & Stroke Lengths 5.5x12 in. F Sample Quality ❑ Good ❑ Fair 0 Poor Pump Pres 0 psi ` =ter.. k .. _A re. e . igs.a.. `� , , . - ;:,-,:= ._ . _ . .k.,. ._ ..;.-:'' +,"sue-, . .. `.' _ '. ,. ,:a. rt Mud Wt In 12.00 ppg Visc 42 secs API filt 3.7 ml HTHP 9.8 ml Mud Wt at Max Gas 12.0 ppg x_ Mud Wt Out 12.00 ppg PV 14 cP YP 33 Ibs/100ft2 Gels 8 \ 14 \ 15 MBT 6.0 pH 8.9 Sd - % Bit No.: 4 Type: Sec QHC1S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x - x - x - TFA: 1.3250 , Wt On Bit: 20 25 RPM: 120 Hrs. On Bit: 2.7 Total Revs on Bit: 2070 Footage for Bit Run 30 r. Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm 1 Tight Spots: to to to Feet of Fill on Bottom: * ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt 10 20 70 _ a t4, Connection Gas and Mud Cut (BG = Background) ft units BG units ppg : ft units BG units ppg , ft units BG units ppg ft units BG units ppg : ft units BG units ppg ft units BG units pP9 ft units BG units Pp9 ft units BG units t, I GAS PEAKS ? Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to 1 a F�s t0 t0 1 to t0 1==,,t44k4 , ':,i%::r:4WS'-'4-t ,- #;s,a*,;-br*Affgt:,':P . 2V.-=4..t , Ak -7,4 trz - r'rf , I3':'Zi41ZT-riiVg4tr4-irf-er , ;7::'az.n-MZV- ,4 Er:t -, T re- Trip down to shoe and circulate and condition mud. Trip into open hole, circulate and condition to establish Toss rates of 130 if F�, 180 bbls /hr before spotting EZ- Squeeze LCM pill at - 23870' MD. Tripping out and racking back 19 stands as of report time " in preparation for a hesitation squeeze. Background gas remained benign at 5 -15 units while circulating. G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs ***Costs Are Carried Up to March 17, 2009 " ** Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air Customer: B.P. Exploration Report No.: 20 Well: NS33 A Date: 3/18/2009 - 00:00 ili LOUT " - Area: Beaufort Sea Depth 24181' Lease: North Star Is. Footage Last 24 hrs: 0 1 Via; Rig: Nabors 33E Rig Activity: Washing /Reaming Job No.: AK- AM- 0006479766 Report For: Distribution List titi Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $109,290.51 Ai ;44 04 c. Current 24 hr Avg 24 hr Max Pump and Flow Data • R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 140 spm Flow rate 503 gpm ' i. Gas* 6 units 8 unit: ( 20 units @ 22087 ) Pump Capacity 3.7 gps Pump Liner & Stroke Lengths 5.5x12 in Sample Quality 0 Good El Fair 1:1 Poor Pump Pres 2153 psi t 1 Mud Wt In 12.10 ppg Visc 43 secs API filt 3.7 ml HTHP 10.7 ml Mud Wt at Max Gas 12.0 ppg iti Mud Wt Out 12.10 s ppg PV 12 cP YP 30 Ibs /100ft2 Gels 9 \ 12 \ 14 MBT 8.0 pH 8.9 Sd - Bit No.: 4 Type: Sec QHC1S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x - x - x - TFA: 1.3250 ip Wt On Bit: 20 -25 RPM: 120 ` Hrs. On Bit: 2.7 Total Revs on Bit: 2070 Footage for Bit Run •30 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm a. Short Trip Depth 22087 ft Short Trip Gas: 20 Mud Cut: ppg Short Trip CI: ppm fl Tight Spots: to to t F eet of Fill on Bottom: * ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt 10 20 70 Connection Gas and Mud Cut (BG = Background) k ft units BG units Pp9 ft units BG units ppg n. ft units BG units ppg j- ft units BG units ppg =' • . ft units BG units ppg `' ft units BG units PP9 • it ft units BG units ppg ft units BG units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot . to to il to liv• t to t to 4 • M . ..... ,... . . ... . . .... ..„... . ... . . . .. ..,..... .................... „..,. .....,......................,... 0....,........„............,.......... „.. „........„...,..........................................,0,.„....„.,_. Continue hesitation squeeze of EZ Squeeze LCM pill by cycling of the pumps periodically to pressure up the wellbore wit a . bit depth of 22087' MD- -ended up with 420psi on the casing side from 490psi over the course of one hour. Start rotating, w reciprocating, and staging pumps to establish circulation to condition mud within the casing to an even 12.0ppg. Stop Ilt kAz circulation and trip in 5 stands on elevators. Start washing and rotating stands down thereafter with a bit depth of 22633 MD olij VI as of report time. Background gas averaged 5 -15 units with no anomalous readings. G & 1 Magnets: X.X lbs Rig Magnets: X.X lbs Total Metal cuttings: X.X Ibs ***Costs Are Carried Up to March 17, 2009*** r Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air A' Customer: B.P. Exploration Report No.: 21 Well: NS33 A Date: 3/19/2009 - 00:00 =t Area: Beaufort Sea Depth 24181' Lease: North Star Is. Footage Last 24 hrs: 0 :- Rig: Nabors 33E Rig Activity: C irc on Bottom 1 -.: Job No.: AK- AM- 0006479766 Report For: Distribution List a Mudlogger's Morning Report , Daily Cost: $2,871.00 Total Cost: $112,161.51 7 . Current 24 hr Avg 24 hr M ax P ump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 139 spm Flow rate 500 gpm Gas* 31 units 16 unit: ( 44 units @ 23550' ) Pump Capacity 3.7 gps Pump Liner & Stroke Lengths 5.5x12 in. { Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 2227 psi ii Mud Wt In 12.00 ppg Visc 42 secs API filt 3.9 ml HTHP 10.8 ml Mud Wt at Max Gas 11.9 ppg ;11 Mud Wt Out 12.00 ppg PV 14 cP YP 29 Ibs/100ft2 Gels 8 \ 12 \ 14 MBT 8.0 pH 9.2 Sd - % oaf 'i: A. Bit No.: 4 Type: Sec QHC1 S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x - x _x - T FA: 1.325 - Wt On Bit: 20 -25 RPM: 120 Hrs. On Bit: 2.7 Total Revs on Bit: 2070 Footage for Bit Run 30 �$ Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm li Short Trip Depth 23550 ft Short Trip Gas: 44 Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft LithOlogy ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol C 10 20 70 �, a Connection Gas and Mud Cut (BG = Background) 'Er ft units BG units ppg ft units BG units ppg ft units BG units PP9 ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units .,- .1 PPg ft units BG units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to }- to to to El 1 VI to to SI Oil -` Continue tripping while washing and rotating within the casing to circulate out any LCM. Trip down to just within the shoe to circulate and condition the mud to a homogeneous 12.0ppg while rotating and reciprocating. Resume tripping in through the shoe and into the open hole section down to bottom. Background gas 5 -10 units while in casing and jumped to 44 units € ; when moving through the open hole. Open -hole section gas has since averaged 15 -35 units - -still waiting on bottom's up A. lag. No losses while reaming through the open hole section. G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs * ** Costs Are Carried Up to March 19, 2009 * ** f Logg Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air �'�r,, F` .> °.�{; .si � �£ �;s �_ 'Sr .,..q w 1't' ziv 3, f k "AB'sr a - 3y..8 P ,`�,i" ,l M s fi , > - ," a y . s m a t - ,,, -,� v,^° x Customer: B.P. E xploration R eport No.: 22 44 Well: NS33 A Date: 3/20/2009 - 23:59 H Ji O ='` ` j Area: Beaufort Sea Depth 24181' V Lease: North Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig Activity: Trip Out ti Job No.: AK- AM- 0006479766 Report For: Distribution List Mudlogger's Morning Re Daily Cost: $2,871.00 Total Cost: $115,032.51 C A An ,'a,,, 5 ".xt .` t , . 004,.. . S §: x'11 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm ,_ �' Gas* 0 units 10 unit: ( 83 units @ 24139' ) Pump Capacity 3.7 gps .y Pump Liner & Stroke Lengths 5.5x12 in �, . Sample Quality ❑ Good 0 Fair 0 Poor Pump Pres 60 psi ,x rte.._..., s .._ ,.. .. _, r, _ ". - — av3 Mud Wt In 12.00 ppg Visc 43 secs API Tilt 3.4 ml HTHP 9.6 ml Mud Wt at Max Gas 11.9 ppg Mud Wt Out 12.00 ppg PV 14 cP YP 28 Ibs/100ft2 Gels 9 \ 11 \ 13 MBT 8.0 pH 9.2 Sd - % Bit No.: 4 Type: Sec QHC1 S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x - x - x - TFA: 1.3250 LI Wt On Bit: 20-25 RPM: 120 Hrs. On Bit: 2.7 Total Revs on Bit: 2070 Footage for Bit Run 30 irk a x r , .,i . . _ ;4 > . fi r --- ` .r "' 4 - _ t= , c gI 4 * :c H . i' , r „ Z Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm ' Short Trip Depth 24139 ft Short Trip Gas: 83 Mud Cut: ppg Short Trip CI: ppm n. 4 Tight Spots: to to to Feet of Fill on Bottom: ft _t 2 .. , _ _ of , ;t. ,, .V . ,.,.ott , z , ... ,. tz 5 t Lithology ( %) Sd -x _ Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt ii 10 20 70 , i i Connection Gas and Mud Cut (BG = Background) - ft units BG units Ppg ft units BG units ppg ri ft units BG units Ppg ` °" ft units BG units ppg' . : ft units BG units P1 ft units BG units ppg ft units BG units Ppg ft units BG units - „ PI "' .'' . t ,* -;,-i ... _. 4$¢ r . r O ! 'ln K ej <' GAS PEAKS %' -.k Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot of to i to to ' to ::4,.1,, to g to t ` *: � . " '`.� t ss -:4" 'V°4 ,',,Z . r O "^'* - V's3 �" i ' ,} k : _�.....' � 41 't a m ,s ` � � -'" -" �:. Finish circulating on bottom and trip out 7 stands to the 8 5/8" liner shoe. Stage pumps & establish circulation to condition i mud & perform FIT to 14.0ppg EMW at the 23930' MD fracture. Establish circulation and condition mud. Start tripping out il t. at 3min /stand while pumping 2bpm from 23550' MD to 14761' MD as of midnight. Trip gas from open -hole section averaged 0 kl 30 -50 units with one peak of 83 units centered on 24139' MD. After open hole lag surfaced, background gas fell and mil I averaged 15 -20 units. G & I Magnets: 1.5 Ibs Rig Magnets: 0.5 Ibs Total Metal cuttings: 2.0 Ibs * ** Costs Are Carried Up to March 20, 2009 * ** I Logging Engineers: Mark Lindloff/ Danny Kane ** 10000 units = 100% Gas In Air * °' -' f i ;-� 10,v -emu *14*x ,- 11 11 ^^r"°*'T',� a �x�,� W r ..: � `4;' 7 P - g J § fie°?- 4 - ., ` -' - ' , =_: - :"' , - -- ---' ,-, '; ': '1.:' , '" , ::: - 4.. Customer: B.P. Explorat Report No. 23 Well: NS33 A Date: 3/21/2009 23:59 ''' Area: Beaufort Sea Depth 24181' Lease: North Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig Activity: Trip Out Psi ,lp Job No.: AK-AM-0006479766 P, ' Report For: D istribution List 9 Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $117,903.51 ti iii - Current 24 hr Avg 24 hr Max Pump and Flow Data P R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm k Gas* 0 units 5 unit! ( 22 units @ N/A ) Pump Capacity 3.7 gps Pump Liner & Stroke Lengths 5.5x12 in. ',. Sample Quality 0 Good 0 Fair El Poor Pump Pres 60 psi ,grt ; � - , . F . Zi.-Jt : Wit' „"- sx.. .t'=i` ; . :��. _ .._.�. ?' . * Y: - ,. , 4. ,-_ ��. , ^o , i —t. . ;nr '' _ .. _ �k.? - 3 f 11 } �Mud Wt In 12.00 ppg Visc 50 secs API felt 3.4 ml HTHP 9.8 ml Mud Wt at Max Gas 11.9 ppg � Mud Wt Out 12.00 ppg PV 14 cP YP 30 Ibs/100ft2 Gels 9 \ 11 \ 14 MBT 8.0 pH 9.5 Sd - % _ . -. , • L B it No.: 4 Type: Sec QHC1 S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x - x - x - TFA: 1.3250 Wt On Bit: 20-25 RPM: 120 ' Hrs. On Bit: 2.7 Total Revs on Bit: 2070 Footage for Bit Run 30 r z------.,,,stlyg;--sft.i.4-,-o:4,7*--;;:w-4tAft!',4-01---if*,,,,:!,_:,:-; k - .,11.." , ,, :..,:t. t.- „. - .,74 ,;,:.:-.-: =si,-. 5,1,-1'.r...tifk,R,--;.g.:L?';',...'=',.;'';',-.:1`;,-.7 ':" Tri p Depth: Trip De the ft Tri Gas: Mud Cut: ppg Trip Cl. ppm 4, Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm �e 1 °' r. Tight Spots: to to to Feet of Fill on Bottom: ft ig Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt A 1= 1 0 20 70 ; __ _ ,ti. . . .�._ .n F ., n Connection Gas and Mud Cut (BG = Background) ft units BG units ppg ft units BG units ppg ft units BG units PPg ft units BG units ppg At ft units BG units ppg ft units BG units ppg ill g=` ft units BG units _ ft u nits BG units ppg ppg o a GAS PEAKS RI fi Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot „, to gt to to �' to E' to to Continue tripping out at 3 min /stand from 14761' to 14050' MD while pumping 2bpm. Reciprocate @ - 14050' MD, -13945' MD, and 13855' MD while circulating at 760gpm to condition mud. Continue tripping out racking back stands to 6387' MD Start l aying down singles from 6387' MD to 891' MD as of report time. g G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs * ** Costs Are Carried Up to March 21, 2009 * ** Logg Engineers: Mark Lindloff / Danny Kane - kg- ** 10000 units = 100% Gas In Air g Z- #1 __ - - €_ s. ,... '* `,:s ., `... ?-? s l a `' te .r.. ..: ..a� Customer: B.P. Exploration Report No.: 24 Well: NS33 A Date: 3/22/2009 - 23:59 1 su Area: Beaufort Sea Depth 24181' Lease: North Star Is. Footage Last 24 hrs: 0' �a Rig: Nabors 33E Rig Activity: Picking Up BHA ; 4' Job No.: AK- AM- 0006479766 Report For: Distribution List :: Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $120,774.51 ; Current 24 hr Avg 24 hr Max Pump and Flow Data t. R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm N� Gas* 0 units 2 unit ( 3 units @ N/A ) Pump Capacity 3.7 gps ' Pump Liner & Stroke Lengths 5.5x12 in. y Sample Quality I] Good ❑ Fair ❑ Poor Pump Pres 28 psi Mud Wt In 12.00 ppg Visc 47 secs API filt 3.4 ml HTHP 10.2 ml Mud Wt at Max Gas - ppg 4. Mud Wt Out 12.00 ppg PV 13 cP YP 26 Ibs /100ft2 Gels 9 \ 11 \ 13 MBT 7.5 pH 9.7 Sd - % M. -fli ti Bit No.: 4 Type: Sec QHC1 S Bit Size: 7 7/8 Jets: 24 x 24 x 24 x - x - x - TFA: 1.3250 k . Wt On Bit: 20 -25 RPM: 120 Hrs. On Bit: 2.7 Total Revs on Bit: 2070 Footage for Bit Run 30 . H Ilk Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm � T Spots: to to t o Feet of Fill on Bottom: ft LlthOlOgY ( %) Sd Sst Silt Siltst Cly Clyst S Lst Coal Lmstn Dol Chrt t. 10 20 70 Connection Gas and Mud Cut (BG = Background) ft units BG units ppg ft units BG units ppg 7 ft units BG units ppg ft units BG units ppg ft units BG units Ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg �i_ Ez . -.. � � ._ _ 4 =� V ,� -., s � ix_, .. � _�?r. "a t r 2�, <_ � .._ ham_-' > : GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot ` to to -' to to ,,,,.?),:. to ( , t !, to ` ' �e' . _ �--;� ``�._ ��.,���,�.�*,.� "``: o'���� 4 � ., t . z � .� �' , � .�, �s .�»�..� ^r"'..: . �� �'���. %�' �.� s;. � mow. ^'a:�' . , '�'�'.^'�. .. '� r� �?�z�z ,-„ �..: Continue laying down BHA. Rig up & test BOPE equipment, rig down same. Make top drive repairs. Picking up new 7 7/8' k , BHA as of report time. M1 t.. G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs * ** Costs Are Carried Up to March 22, 2009*** Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air r mo Customer: B.P. Exploration Report No.: 25 4 Well: NS33 A Date: 3/23/2009 23:59 iii 'I Area: Beaufort Sea Depth 24181' , Lease: North Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig Activity: Ciro & Cond Mud v Job No.: AK- AM- 0006479766 Report For: Distribution List ' ' M u dl ogger ' s M orn i ng R epo rt Daily C $2,871.00 Total Cost: $123,645.51 ri t Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A fUhr ( N/A ft/hr @ N/A ) Pumps 455 spm Flow rate 129 gpm Gas* 0 units 3 unit: ( 10 units @ N/A ) Pump Capacity 3.7 gps Pump Liner & Stroke Lengths 5.5x12 in Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 1971 psi . : ix. Mud Wt In 12.00 ppg Visc 45 secs API filt 3.7 ml HTHP 10.8 ml Mud Wt at Max Gas 11.5 ppg ra Mud Wt Out 12.00 ppg PV 13 cP YP 28 Ibs /100ft2 Gels 10 \ 11 \ 13 MBT 8.0 pH 9.5 Sd - % ,. .a, ,z, . -�A - ., . _,f�... -._ ?, n _. .g_. -, Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 '.'..ti Wt On Bit - RPM: - Hrs. On Bit: - Total Revs on Bit: Footage for Bit Run - M Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm 6 `hf Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm r Tight Spots: to to to Feet of Fill on Bottom: ft p 7'A Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt ki 1 0 20 70 el Connection Gas and Mud Cut (BG = Background) ft units BG units ppg R. ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg !. E GAS PEAKS e f:; Depth Gas in units Chromatograph in ppm * 1 Max Background Cl C2 C3 C 4 Tot C5 Tot to 0 to CI to Z. ti to to to k Continue & finish building BHA. Shallow test MWD motors /tools as well as function -test Rhino Reamer. Tripped in picking ii up singles until 11756' MD upon which started running with racked -back stands to 14390' MD. Stage pumps and establish 11 circulation at 455gpm while conditioning mud to a homogeneous 12.0ppg as of report cut -off. ti G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs * ** Costs Are Carried Up to March 23, 2009 * ** te e Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air .. _.' .� ..- . .. r 'g'{ � � � '. - �' - h.�:.= , r' of ..s= ¢+, '- $ �g -..rzi �'E � `` x.� � P . t-i �' liZ - rr "fit s W �" r' 3' �.. 'eE ' . -A . . ' , r .�4 . _ ; dz" "' ,a g `-�. ..t Customer: B. P. Exploration Report No.: 26 Well: NS33 A Date: 3/24/2009 - 23:59 .: E y HALL ,U - Area: Beaufort Sea Depth 24181' L ease: N orth Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig Activity: Circ & Cond Mud Job No.: AK - 0006479766 Report For: Distribution List Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $127,955.51 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 39 spm Flow rate 137 gpm I Gas* 5 units 3 unit: ( 6 units @ N/A ) Pump Capacity 3.7 gps Ft Pump Liner & Stroke Lengths 5.5x12 in , Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 1183 psi A Mud Wt In 12.00 ppg Visc 47 secs API filt 3.4 ml HTHP 10.0 ml Mud Wt at Max Gas 11.9 ppg a Mud Wt Out 11.95 ppg PV 13 cP YP 29 Ibs/100ft2 Gels 11 \ 14 \ 16 MBT 8.0 pH 9.3 Sd - j, — Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 Wt On Bit: RPM: - Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: -23540 ft Trip Gas: 6 Mud Cut: 11,9 ppg Trip CI: N/A ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Ifi Tight Spots: 23600' to 23610' to to Feet of Fill on Bottom: ft .' Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt 10 20 70 Connection Gas and Mud Cut (BG = Background) ft units BG units ppg ft units BG units ppg ft units B un ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg if units BG units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 0 4 to v . to 4 to to to to s,4 4 v � ,, ta P Continue circulating & condition mud at the 8 7/8" liner (bit depth 14390' MD) to 12.0ppg. Resume tripping in stands to 20975' MD filling pipe occasionally. Repaired washpipe on top drive. Continue tripping in to 23440' MD running in stands -- and start staging pumps to circulate & condition mud. Continue tripping in experience tight spot at 23605' MD that required i washing & reaming down to 23728' MD. Trip in to 24000' MD on elevators before tight spot required washing & reaming. t Circulating at 140gpm with string rotation of 22gpm at 23993' MD as of midnight. G & 1 Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs * ** Costs Are Carried Up to March 24, 2009 * ** Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air .r= a i 4frt.. -S-F ' £4 3r i AAQ ��,... N gr .ZftS£ ig *�s�'A" t :,,�,.�,,. �,t,� ,. .a Customer: B.P. Exploration Report No.: 27 rf Well: NS33 A Date: 3/25/2009 - 23:59 .' � `' 'Y Area: Beaufort Sea Depth 24181' ,, Lease: North Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig Activity: Circ & Cond Mud Job No.: AK -AM- 0006479766 Report For: Distribution List Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $130,826.51: � ;,� `*.M_ �` _ ,. �^�_�i� .. _.�2 rte.. _. � _ _. _ _ . _� r a � �.�� ..�.w. _ Current 24 hr Avg 24 hr Max Pump and Flow Data . ' R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 80 spm Flow rate 287 gpm Gas'' 8 units 8 unit ( 22 units @ N/A ) Pump Capacity 3.7 gps Pump Liner & Stroke Lengths 5.5x12 in 4: Sample Quality 0 Good 0 Fair 0 Poor P ump Pres 1295 psi ! Mud Wt In 12.30 ppg Visc 46 secs API filt 4.0 ml HTHP 10.6 ml Mud Wt at Max Gas - ppg wig 0 Mud Wt Out 12.35 ppg PV 11 cP YP 32 Ibs /100ft2 Gels 8 \ 11 \ 14 MBT 7.5 pH 9.3 /o iti Sd - Mud Weights Called Out as of Midnight** - v°= w Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 1 1 / 32" 2 x 12 / 3 TFA: 0.6850 4 Wt On Bit: - RPM: - Hrs. On Bit: - Total Revs on Bit: Footage for Bit Run - te Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Tri CI: Short Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Trip pp m AA Tight Spots: 23621' to 23634' 27078' to 24107' to Feet of Fill on Bottom: ft M Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt 10 20 70 Connection Gas and Mud Cut (BG = Background) ft units BG units PP9 ft units BG units ppg ig ft units BG units PP9 if units BG units ppg tia kk A ft units BG units PP9 ft units BG units ppg `4 ft units BG units PP9 P.T ft units BG units ppg GAS PEAKS `R Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to ip t to R i to LA _ ,,, .. .` t' y . f a , . a s ° , ;' 44`'.x,: _ . , ., ta . >., >r V W .t , A a. F.. ,,,,,,,,,. ,, ,, ;# ... '" : 7 1 , E. ' ' ' . • " Circulated & conditioned mud at 24000' MD. Mud from open -hole section varied from 11.95ppg to 13.7ppg with surface equipment unable to condition mud before going downhole. Ceased circulation & pulled up within the 8 5/8" liner shoe to "' condition surface mud. Trip back in open hole having to wash & ream through tight hole conditions. Trip in while reaming • #j and circulating to 24078' MD at 150gpm. Stage circulation up to 415gpm experiencing occasional packing off. Condition : 1, mud on surface and staging circulation rate as of midnight report time. Minimal trip gas with max of 22 units. G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs * "* Costs Are Carried Up to March 25, 2009 * ** Logging Engineers: Mark Lindloff / Danny Kane ** 1 0000 units = 100% Gas In Air s-: .r� -`p- wez Z . , y a fa n FM + ,� � f z2- a W R -' .` - ,A ; s _ f 6"4, - - -'„ '. -i - mss? `'x ' ,° 's" a ,,:.4 *v4IN .7.r.. _ 3. ' _:`'t ;, a. . " • 1"., Customer: B.P. Exploration Report No.: 28 Well: NS33 A Date: 3/26/2009 - 23:59 �_ "'i'` 'a Area: Beaufort Sea Depth 24396' Lease: North Star Is. Footage Last 24 hrs: 215' 6. Rig Activity: Drilling 9" Hole Rig: Nabors 33E R g 9 g Y� " Job No.: AK- AM- 0006479766 Report For: Distribution List l . Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost $1 33697 51 � _...�. a � �w"ea.d °�", �_. �3.�. .r,u� s � , _ �'�'.�. n.� _ .. ._. �_va�:��...�._,_... � _..� A a s ... - � x, � ..cam" -�.. r _ ,� � ' : Pump � 4 and Flow Data Current 24 hr Av 24 hr Max g 4 gpm m s 151 spm Flow rate 540 r 24303' Pumps 9p 2 ft/hr 2 303' . .P. 16 ft/hr 23 ft/hr 66 p p RO ( @ ) i • 242 2 Pump Capacity 3.55 gps Ell::: units 42 unit. 89 units 0 Gas* 34 is ( @ ) p p Y Pump Liner & Stroke Lengths 5.5x12 in. r - Sample Quality ❑ Good 0 Fair 0 Poor Pump Pres 3307 psi : Mud Wt In 12.50 ppg Visc 45 secs API Tilt 3.8 ml HTHP 10.4 ml Mud Wt at Max Gas 12.5 ppg ', Mud Wt Out 12.45 ppg PV 15 cP YP 34 Ibs /100ft2 Gels 10 \ 14 \ 16 MBT 7.5 pH 9.1 Sd % hx - � - „ -' , � � ru. "el. is ae• • ut as o , i•ni• t ... ��_1. -. :�,��_, ._ .y.�;�,� x� � s 1 Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 Wt On Bit: 20 -30 RPM: 120 Hrs. On Bit: 16.6 Total Revs on Bit: 1.96 Footage for Bit Run 216' ° " 7 a "C 's. Z-.. :-. .: - - . .: `fit -''' a .'7 - - t � t .: § m Trip Depth: 24146 ft Trip Gas: 114 Mud Cut: 12.0 ppg Trip CI: pp ry i 1 Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ' T ight Spots: to to to Feet of Fill on Bottom: ft M . '--ssc:. q - . . r ,,,,, g `..,„v tea - = .,0 •i -.. . L._. w'.", e. ='r , -*WW- , ; ,- .e.,- 1,' Lit ( % ) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt __ 15 5 80 - ___: Connection Gas and Mud Cut (BG = Background) {:1 f t ft units BG units PP9 ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units , EL if units BG units ppg ft units BG units ppg GAS PEAKS Rd, a D epth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total ,, 24190' to 24209' 89 40 8120 348 215 75 23 1 24210' to 24233' 85 35 7682 328 203 71 22 Ci I to to k` to gi. i to 4 Stage pumps to 500gpm while reaming from 24078' MD to bottom. Trip gas averaged 55 units with a max of 114 units -� 1 associated with bit depth 24146' MD. Tagged bottom at 06:00 and drilled 9" hole from 24181' to 24396' MD / 9868' TVD. ROP averaged 25 -35 fph except while weighting up mud from 12.0 to 12.5ppg where ROP averaged 5 fph. Drilled gas kg i averaged 42 units with a peak of 89 units from 24202' MD with no connection gasses observed. Drilled lithology primarily a 1 silty-shale with some siltstone. ECDs are 13.78ppg on bottom with a 12.5ppg WBM pumping at 545 gpm. = r G & I Magnets: 2.0 Ibs Rig Magnets: 1.0 Ibs Total Metal cuttings: 3.0 Ibs ***Costs Are Carried Up to March 26, 2009 ""` . Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air ify, 3 � 2 ,P ;'-,. .^ , , , k'v .. ._ . , . %: ';. '. t$ - wn. , ` zs- "'r-.itf '8 ' `S'' ; k , . , ,M # we ._ . ft x . ` -.,. Customer: B.P. Exploration Report No.: ��� 29 Well: NS33 A Date: 3/27/2009 - 23:59 1: ; ` ; " Area: Beaufort Sea De 24818' 1 Lease: North Star Is. Footage Last 24 hrs: 422' t Rig: Nabors 33E Rig Activity: Drilling 9" Hole k Job No.: AK -AM- 0006479766 Report For: Distribution List °' Mudlogger's Morning Re Daily Cost: $2,871.00 Total Cost: $136,568.51 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 40 ft/hr 40 ft/hr ( 79 ft/hr @ 24700' ) Pumps 147 spm Flow rate 524 gpm VI - Gas* 74 units 43 unit: ( 78 units @ 24751' ) Pump Capacity 3.55 g Pump Liner & Stroke Lengths 5.5x12 in Sample Quality 0 Good El Fair El Poor Pump Pres 3373 psi V ° :i _ ,. _ ' om'-` -v ' - '- °�'. , , r*2 . ` v/f&- Fm, t��" . ., ' 4 ,.. t .,,, , T , r. - ,-" . ' _.. ,;.. .- : — ,, ... :.- ;' .,. F. 4` j; o `t._ Mud Wt In 12.50 ppg Visc 43 secs API filt 3.8 ml HTHP 10.2 ml Mud Wt at Max Gas 12.5 ppg VI Mud Wt Out 12.55 ppg PV 16 cP YP 36 Ibs/100ft2 Gels 10 \ 15 \ 17 MBT 9.0 pH 9.2 Sd - Bit No.: 5 Type: RSX516M • Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 Xil Wt On Bit: 20-30 RPM: 120-135 Hrs. On Bit: 28.7 Total Revs on Bit: 6 Footage for Bit Run 638' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm r Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ri F ., it:* .;., 1 ° _,,- --,; , , , *.,- . .., . .. , n, ...., V . -i :% _ku .f. A V-14 Li t h ology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt '' 20 80 is s «.* ='s : lr- : . ..r_ v ^� r w `. . W . .. 1W - ,._, i.. .,' i Connection Gas and Mud Cut (BG = Background) ft units BG units ppg . ft units BG units ppg A ft units BG units ppg ft units BG units ppg al :` ft units BG units ppg ft units units BG units ppg ft units BG units ppg a ft BG units ppg �, ms 4" 1 a' N ' �" w " ? gr v . 4 Kl,:i GAS PEAKS t, mi Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total 24400' to 24433' 73 42 6517 310 266 118 46 ril Lr, t 1 to to to to J-i.: .E'. * �: ... ' . ;? s - ma,' x ,„ '':> ".'; „ .. ., szb "'i Continue drilling 9" hole from 24396' MD to 24586' MD at an average ROP of 35fph. Replaced screens on both pumps in an attempt to alleviate MWD detection problems. Continued drilling to 24687' MD before shutting in Pump #2 to repair the pulsation dampener. Continued drilling to 24181' MD (10228' TVD). ROP averaged 40f ph across all drilled intervals consisting of primarily silty-shales with a g ( ) 9 P 9 P Y Y ft few siltstone stringers interbedded. Gas (and normalized gas) have remained relatively steady at 50 -70 units with no connection gasses ; observed. ** *Mud Data Added 03- 28 -09 * ** G & I Magnets: 0.6 Ibs Rig Magnets: 0.55 Ibs Total Metal cuttings: 1.15 Ibs * ** Costs Are Carried Up to March 27, 2009 * ** ; , Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air -7e .-7, 4e a7�x a a `T^. r `"-i. � :f v - .- ` z. ` � �.�� 1,;• * �:X ' 7 ;x w s ms ` s. Customer: B.P. Exploration Report No.: 30 l Well: NS33 A Date: 3/28/2009 - 23:59 ' L 1 U T ' "- Area: Beaufort Sea Depth 25319' L ease: N orth Star Is. Fo otage Last 24 hrs: 50 Rig: Nabors 33E Rig Activity: Drilling 9" Hole t�: Mudlogger's Morning Report Job No.: AK- AM- 0006479766 Report For: Distribution List Daily Cost: $2,871.00 Total Cost: $139,439.51 Current 24 hr Avg 24 hr Max Pump and Flow Data r R.O.P. 22 ft/hr 31.85 ft/hr ( 61 ft/hr @ 24967' ) Pumps 145 spm Flow rate 534 gpm Gas* 110 units 69 unit: ( 108 units @ 25319' ) Pump Capacity 3.55 gps gx Pump Liner & Stroke Lengths 5.5x12 in N. Sample Quality 0 Good © Fair 0 Poor Pump Pres 3380 psi Mud Wt In 12.40 ppg Visc 46 secs API filt 3.9 ml HTHP 10.2 ml Mud Wt at Max Gas 12.5 ppg er. Mud Wt Out 12.45 ppg PV 19 cP YP 35 Ibs/100ft2 Gels 9 \ 15 \ 17 MBT 7.5 pH 9.3 Sd - ,.. .V kV f w it m om, *g° . ru. rreia is a e. •utaso �i.niq - � ;� y. _.,, _ ..,,_� .4. ;� �:�... ., �,." Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 Wt On Bit: 20 -30 RPM: 120 -135 ` Hrs. On Bit: 46.5 Total Revs on Bit: 11.16 Footage for Bit Run 1139 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm m ' S hort Tri : Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Trip CI: pP ti I ` Tight Spots: to to to Feet of Fill on Bottom: ft A Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt Connection Gas and Mud Cut (BG = Background) A ft units BG units pp9 . ft units BG units ppg ft units BG units PP9 ft units BG units ppg :1 ft units BG units PP9 ft units BG units ppg ..,.t,:,, ft units BG units PP9 ft units BG units ppg GAS PEAKS (Background Gas Samples Shaded Gray) Depth Gas in units Gas Chromatograph *. Max Background C1 C2 C3 C4 Total C5 Total 24777' to 24807' 68 54 5077 342 278 125 56 25061 to 25087' 71 62 4807 418 330 157 80 25156' to 25182' 106 91 7349 641 488 217 100 `: 25252' to 25265' 108 83 7044 634 534 257 121 ' to t0 mo . ,,," -' C- �.c ? ",.. .44 't s'.a. `xT er4r-W. Y,,,42 ..i'f`s -'':�" _ - ' `. +.., -6W1.: +�..,' - z.'k Sc.4 -..: L4.s�Li,S nf,+i. _ .�"s `'` x Al Continue drilling 9" hole from 24818' MD to 24873' MD where MWD detection was lost. Changed flow rate from 450 to 515gpm while pumping surveys . V` Continued drilling from 24873' MD to 25319' MD (10668' TVD) with an average interval ROP of 32fph and recurring survey detection problems. Drilling through the shale- dominant Kingak formation while seeing a gradual rise in the average background gas from 75 units to 105 units with no connection e' gasses observed. Chromatograph analysis indicates increasing heavy hydrocarbons [Occasional chromatograph extended run times increased from 50 '; Hi to 150 seconds indicates the presence (concentrations unknown) of C6 -C8 hydrocarbon gasses) while drilling through the interval. Maximum Sperry- rl calculated ECDs of 13.93ppg on bottom and at the shoe. G & I Magnets: 0.0 lbs Rig Magnets: 0.625 Ibs Total Metal cuttings: 0.625 lbs ***Costs Are Carried Up to March 28, 2009 * ** PI Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air Customer: B.P. Exploration Report No.: 31 Well: NS33 A Date: 3/29/2009 - 23:59 AIL' - Area: Beaufort Sea Depth 25612' N h Star Is. Foota a Las 24 hrs• 293 Lease: North 9 Rig: Nabors 33E Rig Activity: Trip Out to Shoe Job No.: AK -AM- 0006479766 Report For: Distribution List y_ '''r Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $142,310.51 T _ Current 24 hr Avg 24 hr Max Pump and Flow Data 0 s m Flow rate 0 m ' -> R. .P. 0 ft/hr 25 ft/hr 59 ftlhr 25442' Pumps p 9P 88 unit 146 units 25592' Pump Capacity 3.55 gps .<, V.:; Gas 12 units ( @ ) P P Y ga Pump Liner & Stroke Lengths 5.5x12 in Sample Quality E:1 Good 0 Fair © Poor Pump Pres 69 psi Mud Wt In 12.50 ppg Visc 48 secs API filt 4.5 ml HTHP 10.9 ml Mud Wt at Max Gas 12.5 ppg Mud Wt Out 12.50 ppg PV 18 cP YP 32 Ibs /100ft2 Gels 11 \ 19 \ 24 MBT 8.0 pH 9.2 Sd - £4 '= 1= iii_ ____ 1LTINOM7iMITIM - . , *.ter a. *'1 "vim:,_ .. ,,, i gas Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 ki Wt On Bit: 20 -30 RPM: 120-135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 I- ; 1 44.,. ta' . -.,*F . ;.,, . _ ,a `'._ . _ _ .W .,,,`' ,;. :``,., -- ry . ,3vP:.::A .;;,v.. .<>.. "kF,'' w ',`" Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ri Lithology (%) Sd Sst Silt Siltst Cly Clyst r Sh Lst Coal Lmstn Dol Chrt b 10 40 60 q -,. ri, - tt * , 7, ,. . a i Connection Gas and Mud Cut (BG = Background) :31::: IA 25535 ft 104 units 61 BG units 12.5 ppg' ft units BG units ppg ft ft units BG units ppg ft units BG units ppg g '1 ft units BG units ppg ' ft units BG units ppg _1 tei ft units B units ppg ft units BG units ppg '. r >, s � -: . _-, eir 4A;4k -,.F' '. ° �v _. s ` ' *. ., -.5,. .. ..:: �a,:,,`;,C�£..,_. i ce " ;>3. ";-IM ,. . 0 i .'"` , .. 't` 4 GAS PEAKS (Background Gas Samples Shaded Gray) Vi p Depth G as in units Gas Chromatograph gsi II Max Background C1 C2 C3 C4 Total C5 Total 25304' to 25319' 127 103 8340 868 656 283 143 i 25559' to 25568' 100 95 4988 566 472 264 144 1 25569' to 25587' 114 100 7324 784 478 245 142 25588' to 25594' 146 126 9816 1024 629 322 171 i s K to ` -4 to i I Continue drilling 9" hole from 25319' MD to section TD of 25612' MD (10929' 11/D) averaging 25fph with background gas averaging 80 -125 units with n s; significant peaks nor shows. A connection gas of 104 units over a 61 unit background (43 units over background) was observed from the last drilled connection at 25535' MD. Upon reaching TD, started circulating 1.5x open -hole volume while conditioning the open -hole section. Circulation lost at bit F j depth 25599' MD after circulating —6200 strokes with no ECD anomaly; formation lag from 25595' MD to 25612' MD was lost or is of marginal quality from .. r1, lost circulation. Pulled up one stand and spotted LCM pill while dropping pump rate to 123gpm to control losses before starting to trip to the 8 5/8" shoe. 1 Trip gas while pumping averaged 100 units with a max of 155 units 45 minutes after calculated bottom's up lag came to surface (Calculated lag DOES NOT account for losses). Approximate losses as of midnight 650bbIs. r i 1 s G & I Magnets: 0.25 lbs Rig Magnets: 0.25 Ibs Total Metal cuttings: 0.5 Ibs ***Costs Are Carried Up to March 29, 2009 "` ) Logging Engineers: Mark Lindloff / Danny Kane "" 10000 units = 100% Gas In Air ..^ >`' a . -c ' ; - lg2:2 -" a`z.. ; _ 'ta, �..., '... - ..ms Igkij _..._:: i.a y. ....�, :-4 ; Customer: B.P. Exploration Report No.. 32 Well: NS33 A Date: 3/30/2009 - 23:59 :14 U TDB ,' '' Area: Beaufort Sea Depth 25612' � Lease: North Star Is. Footage Last 24 hrs: 0 ' • Rig: Nabors 33E Rig Activity: Tripping Out J ob No.: A K -AM- 0006479766 R eport For: Di stribution List 0 Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $144,433.60 te I N Current 24 hr Avg 24 hr Max Pump and Flow Data Rii R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 24 spm Flow rate 85 gpm ` ; Gas* 38 units 18 unit N/A units @ N/A ) Pump Capacity 3.55 gps s<_ k ( Pump Liner & Stroke Lengths 5.5x12 in Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 501 psi ii Mud Wt In 12.50 ppg Visc 46 secs API filt 4.8 ml HTHP 1 1.2 ml Mud Wt at Max Gas - ppg Mud Wt Out 11.90 ppg PV 21 cP YP 29 Ibs /100ft2 Gels 9 \ 15 \ 19 MBT 5.5 pH 9.3 Sd % r. W * * *Mud Called Out as of1Viidni.ht* - a -x-.. .. *. :. ter ,- t.. t4v11 Ix Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 3T 2 x 12 / 32 TFA: 0.6850 Wt On Bit: 20 -30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 n 1 Trip Depth: 2 5600 ft Trip Gas: 95 Mud Cut: 12.5 ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: M ud Cut: ppg Short Trip CI: ppm IT Tight Spots: 24428' to 24398' to to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt 10 40 60 Connection Gas and Mud Cut (BG = Background) ft units BG units ppg �1 if units BG units ppg ft units BG units ppg ft units BG units ppg ', ft units BG units ppg ft units BG units ppg 4` ft units BG units pp9 ft units BG units Li, rl GAS PEAKS (Background Gas Samples Shaded Gray) Oi Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total fil tr, to 7 4 t o to to to 1 1 to z e .' . '- roof yg WE� 'A," �. ' 41Trip out from 24484' MD to 23444' MD (within 8 5/8" liner shoe) having to stop and ream through tight spot from 24428' to 24398' MD. Hole taking proper fill while pumping out and no static losses observed. Continue tripping out from 23444' MD to 16010' MD while pumping 2bpm with no fosses observed Trip gas has steadily dropped from an average of 100 units to 35 units as of report time. `i j G & I Magnets: 0.1 Ibs Rig Magnets: 0.1 lbs Total Metal cuttings: 0.2 Ibs ***Costs Are Carried Up to March 30, 2009*** Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Airw s _ ti r a ,., I s = .�.z cC..3. ,. ma, ,.zs'- v'u"� � �w .�s�.� «`� .�:f.'«ffi.-.za�' ..'�. � '..i i� _..�yg.., = :. �n .�n:.,r 3�. r..au,� Customer: B.P. Exploration Report No.: 33 Well: NS33 A Date: 3/31/2009 - 23:59 ' Area: Beaufort Sea Depth 25612' Lease: North Star Is. Footage Last 24 hrs: 0' iLl Rig: Nabors 33E Rig Activity: Tripping Out 4, ' Mu d lo gger ' Daily Morning Report Job No.: AK -AM- 0006479766 Report For: Distribution List , Cost: $2,871.00 Total Cost: $147,304.60 it 1 Current 24 hr Avg 24 hr Max Pump and Flow Data t, R.O.P. N/A ft/hr N/A ft/hr ( N/A fUhr @ N/A ) Pumps 0 spm Flow rate 0 gpm ,, Iv, Gas* 0 units 36 unit; ( N/A units @ N/A ) Pump Capacity 3 gps F. `i Pump Liner & Stroke Lengths 5.5x12 in 4 Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 43 psi Mud Wt In 12.50 ppg Visc 45 secs API filt 4.9 ml HTHP 11.4 ml Mud Wt at Max Gas ppg 5 Mud Wt Out 12.50 ppg PV 20 cP YP 31 Ibs/100ft2 Gels 9 \ 12 \ 16 MBT 5.5 pH 9.4 Sd - % , 4 7 U. "e19 is a e. out as o ' i. nig t >, 4 .. = .g => a , . , r =. ,. . .,, ? * i .. ., . u=s Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32 2 x 12 / 32" TFA: 0.6850 �' Wt On Bit: 20-30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 1 4.14 F ootage for Bit Run 1 432 , Li „, , Trip Depth: 14300 ft Trip Gas: 60 Mud Cut: 12.5 ppg Trip CI: ppm T Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt rk 10 40 60 b. f Connection Gas and Mud Cut (BG = Background) ft un BG units ppg ft un BG units ppg ti ,,, i ft units BG units PP9 ft units BG units ppg ft units BG units Pp9 ft units BG units ppg ft units BG units ppg ft units BG units ppg ."*_chi- `rt - t7- - - ,, --1 - 7 , ''.....,. „ *Vt �., t ' ;_ b ` , z= V – _ tz . #.._” _ Nvvi - .:& _�, . , " 'zv,, - ,s w^ ,c' .., e w o. , , ,:*. , ..., ,..,,.. • x GAS PEAKS (Background Gas Samples Shaded Gray) r Depth Gas in units Gas Chromatograph I Max Background C1 C2 C3 C4 Total C5 Total i to L-!i.:1':;:' g N to to K r 4 to t0 to i . Continue tripping out while pumping 2bpm from 16010' MD to 14230' MD. Stage pumps and establish circulation to 200gpm experiencing no losses. Pull out one more stand and stage pumps to 600gpm to shear the mud across the bit. Attempted to open CCV -- unsuccessful. Once new mud sheared twice k':,.1 through bit, continued tripping out and racking back stands on elevators from 14196' MD to 8807' MD as of midnight. Trip while pumping stands out :I averaged 30 -35 stands slowly diminishing over time. Trip gas while shearing new mud averaged 50 -65 units initially before slowly dropping to 30 units by a l the end of the circulation with no peaks nor anomalies. t : g. G & I Magnets: X.X lbs Rig Magnets: X.X lbs Total Metal cuttings: X.X lbs ***Costs Are Carried Up to March 31, 2009 * ** Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air , ,, _ , a - ui: • • z .� - ..x .. , e- . m7v's �. " ak.--24- ,-' ._. gaL..2.s ,.x:2,3, .._..i s ._,_ 7.A 1 „z , r - .Y �. �.. .Y. ,3: -._,: .., it ,�u_ £�°§ . €;e , r.� ., a .'4'u ,.i ..�, ` _. .f` Customer: B.P. Exploration Report No.: 34 Well: NS33 A Date: 4/1/2009 - 23:59 HALL. 1=' ' "' =' Area: Beaufort Sea Depth 25612' V Le Lease: North Star Is. F ootage Last 24 hrs: 0' i" Rig: Nabors 33E Rig Activity: R/U Liner Tools Job No.: AK- AM- 0006479766 Report For: Distribution List Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $150,175.60 iN ft' WA Current 24 hr Avg 24 hr Max Pump and Flow Data io ig R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm Gas'' 0 units 0 unit: ( N/A units @ N/A ) Pump Capacity 3.55 gps Pump Liner & Stroke Lengths *,. 5.5x12 in ti Sample Quality 0 Good 0 Fair 0 Poor Pum Pres 74 psi . Mud Wt In 12.50 ppg Visc 47 secs API felt 5.0 ml HTHP 11.4 ml Mud Wt at Max Gas - ppg Mud Wt Out 12.50 ppg PV 17 cP YP 28 Ibs /100ft2 Gels 9 \ 13 \ 15 MBT 5.5 pH 9.1 Sd - % iiidartrimiiSimmutzi iSiJirRmiiii . - , _ _ ' * <. - .. , . --- , aw r a ,. if Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 Wt On Bit: 20 -30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 , , ,.., §.: ,Ta s, W . ..- ,a- - ,` _:x. -ea .x;z,A r4 , 't .� Z' . Y ' ... -', :` _.w ., ? , ..�,, , =3 i '`a..i ;.,; Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm P , ' A: Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm g. Tight Spots: to to to Feet of Fill on Bottom: ft -i rz fr L ( %) Sd Sst Sift Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt 0 10 40 60 r ,- Connection Gas and Mud Cut (BG = Background) if units BG units ppg ft units BG units ppg �` ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg 4 '1 ft units BG units ppg GAS PEAKS (Background Gas Samples Shaded Gray) - Depth Gas in units Gas Chromatograph Max Background 01 C2 C3 C4 Total C5 Total to to �; k to f` to " to to< 1 ..a.. .. 5 . shy ,. - 5 ` . Continue pulling stands from 8770' MD to 7837' MD. Pull out and lay down singles from 7837' MD to 1000' MD. Break down and lay down dr BHA. 1 = Rig up, test, and rig down BOPS equipment and rip up liner running equipment. 3 9 G & I Magnets: X.X lbs Rig Magnets: X.X lbs Total Metal cuttings: X.X Ibs * ** Costs Are Carried Up to April 1, 2009 *** 1 Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units 100% Gas In Air '7 7 ` . rt : 7 - v _ - f"S.. , -€, 7 - a' 7 ' " , ' a, - rte tf-?' �;:: Customer: B.P. Exploration Report No.: 35 Well: NS33 A Date: 4/2/2009 23:59 : HALIJSUATON Area: Beaufort Sea Depth 25612' Lease: North Star Is. Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Run In 6 5/8 Liner Job No.: AK AM 0006479766 Report For: Distribution List ii'' Mudlogger's Morning Report y Total Cost: $153,046.60 ,,,,:, _ Daily Cost: $2,871.00 Totaost: $,. Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm j Gas" 0 units 0 unit ( N/A units @ N/A ) Pump Capacity 3.55 gps Pump Liner & Stroke Lengths 5.5x12 in : Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 74 psi il , Mud Wt In 12.50 ppg Visc 45 secs API 1 2.30 filt 5.0 ml HTHP 11.4 ml Mud Wt at Max Gas - ppg j Mud Wt Out ppg PV 21 cP YP 31 Ibs/100ft2 Gels 10 \ 15 \ 16 MBT 5.5 pH 9.1 Sd - % 1 _ _ - n hill rtrg tCIiTi3iF. ,. Silll Rnl1 _ ", -, ._`.:x ,�,... , , _. 1 Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 Wt On Bit: 20-30 RPM: 120-135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 l Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm ii iii: Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm p. Tight Spots: to to to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt P' 10 40 60 IP Connection Gas and Mud Cut ft units BG units ppg (BG = Background) s ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg ,•. ft units BG units ppg ,=� � '. ft un its BG units ft units BG units ppg ppg �.� t. - _.. _ ._,vim _ is ; GAS PEAKS (Background Gas Samples Shaded Gray) t Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total °, to ` . to ¢, .< to F to 1 to � .1 to ; 1 itl I Finished rigging up liner running tools when the EZC 404Z liner shoe showed a drift of 5.796 ", not 5.875". Mobilized additional EZC 404Z from Prudhoe ^ „_ j and drifts checked out. Run 6 5/8" liner followed by 4" DP to 6133' MD as of report time, circulating every 1000' MD at 600gpm. No losses while static or 1 • circulating. t 4 fi G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs ***Costs Are Carried Up to April 2, 2009 * ** r Logging Engineers: Mark Lindloff / Danny Kane ** 10000 units = 100% Gas In Air pi 1.‘ „tr i i ,, ,. c,c..v_ -ZZSZ: =m*k_ . k u 'piili22:Zi,a -- -. . ., .,L _.:. ',Za T.ss`1 --1 ,' .� :Lit i al ifiZ -D aY�.3:..,_ : ,,., :5*. - .ss a;:il z s.,:'Z .vc ::, , ` ' ,r__ .x _ _` :.. _.l's > ,;; _ _ ri Customer: B.P. Exploration Report No.: 36 Well: NS33 A Date: 4/3/2009 - 23:59 = • A ` _ . '` j' "'l Area: Beaufort Sea Depth 25612' Lease: North Star Is. Footage Last 24 hrs: 0' VA 1 Rig: Nabors 33E Rig Activity: Run In 6 5/8" Liner el Job No.: AK -AM- 0006479766 Report For: Distribution List 0 ii Mudlogger Morning Report Daily Cost: $4,038.00 Total Cost: $157,084.46 el lI Ti Of. _ Current 24 hr Avg 24 hr Max Pump and Flow Data ,. R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm F Gas 0 units 4 unit ( N/A units @ N/A ) Pump Capacity 3.55 gps kai Pump Liner & Stroke Lengths 5.5x12 in. : Sample Quality Good Fair Poor Pump Pres 4 psi Vil Mud Wt In 12.50 ppg Visc 44 secs API filt 5.0 ml HTHP 11.4 ml Mud Wt at Max Gas - ppg .11' Mud Wt Out 12.30 ppg PV 19 cP YP 33 Ibs /100ft2 Geis 9 \ 13 \ 17 MBT 5.5 pH 9.0 Sd - % 1 4 ru• n eip s a e. •utaso Ti.ni4 t _ �� ` _ ,: . : • Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 LI • Wt On Bit: 20 -30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 qt Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm VI Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm r e o F Tight Spots: to to to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cl Cl Sh Lst Coal Lmstn Dol Chrt „,„ .. - -Y _ .. � . ;_ _ r u_ ,. .. , Connection Gas and Mud Cut (BG = Background) ft units BG units ppg ft units BG units ppg d ft units BG units ppg ft units BG units ppg � a ft units BG units ppg ft units BG units ppg ft units BG units pp9 ; ft units BG units ppg ` i GAS PEAKS (Background Gas Samples Shaded Gray) = 1 Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total to i ':J to . to, 1 to to i j to r „, RIH with 6 5/8 liner on 4 1/2” dp, to 7782' , washing down every 10 stds. Circulate at 7782' at 600 gpm. RIH to 11,467 cont to wash down every 10 stds M/u x/o and change air slips and cont to RIH with 6 5/8 dp to 14,175. continue to fill dp every 10 stds circulating at 14,175 at 600 gpm. Continue to RIH 1 with a depth of 16779' at the time of report. No recorded losses or significant gas peaks were noted. g id �- G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs "' Costs Are Carried Up to April 3, 2009 "' Logging Engineers: Mark Lindloff / Daniel Sherwood * " 10000 units = 100% G In Air _ F7 - ;T>`TF + 7 i ce 77 _.�_ 7777 r s v a *. -•" :: s ��7f 77 7wYr _ i Customer: B.P. Exploration Report No.: 37 Well: NS33 A Date: 4/4/2009 - 23:59 r' I U _ ` '`-' Area: Beaufort Sea D 25612' Lease: North Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig Activity: Run In 6 5/8" Liner z Job No.: AK -AM- 0006479766 Report For: Distribution List lif til Mudlogger's Morning Re Daily Cost: $2,871.00 Total Cost: $159,955.46 ill A C urrent 2 4 hr Avg 24 hr Max P ump and Flow Data 4 ii R.O.P. N/A ft/hr N/A fUhr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm 1 Gas" 0 units 4 unit ( N/A units @ N/A ) Pump Capacity 3.55 gps Pump Liner & Stroke Lengths 5.5x12 in ' , Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 4 psi fl Mud Wt In 12.50 ppg Vise 46 secs API filt 5.0 ml HTHP 11.6 ml Mud Wt at Max Gas - ppg 0 Mud Wt Out 12.50 ppg PV 31 cP YP 33 Ibs /100ft2 Gels 9 \ 16 \ 18 MBT 5.5 pH 8.9 Sd 1 .. - I ** *Mud Weights Called Out as of Midnight * ** F .. . _ . 1, = . - . - < t = _ - ft Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 Wt On Bit: 20-30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 1 4.14 F ootage for Bit Run 1432 1 ,-, , ., . .� Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm M it Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Spots: Tight Spot 23420 to 23470 23820 to 23860 24080 to curren Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt :- , , ._ f' ,,, Connection Gas and Mud Cut (BG = Background) ft units BG units PP9 ft units BG units ppg` Na ft units BG units ppg �> ft units BG units PPg ft units BG units ppg ) ft units BG units ppg ii k ft units BG units PP9 ft units BG units ppg 1 GAS PEAKS (Background Gas Samples Shaded Gray Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total t to t gia to > ? to k t to ri: to to 1 < � -tt ti' ,f '4€ S4' ' .q ,1.:. � 4. a „ u ° , Ash: . ,i ,r*- m. . V.V. ` €.�� ° ,ice . „a.. - . " a0t1 �. . . ..a . _ . . x '�1 RIH with 6 5/8 liner to 18,935 filling every stand. Circulate and condition and cont to RIH the hole to 22,470' and encounter tight hole. Continue to RIH to 22,900' filling every stand. M/U T/D and continue to RIH rotating and washing to 23,517. RIH to 24,137 at with point tight hole is encountered begin *,- pl rotating and washing to a current depth of 24,272' at the time of report. No notable gas peaks or fluid losses have occured. A increase in MW out was recorded from a 12.5 to a 12.6 at approx 23 :15. Pi 4 G & I Magnets: X.X Ibs Rig Magnets: X.X Ibs Total Metal cuttings: X.X Ibs ***Costs Are Carried Up to April 4, 2009 * ** Logging Engineers: Mark Lindloff / Daniel Sherwood ** 10000 units = 100% Gas In Air ,_ Customer: B P Exploration Report No.: 38 Well: NS33 A Date: 4/5/2009 - 23:59 ;:l ,, . , Area: Beaufort Sea Depth 25612' Lease: North Star Is. Footage Last 24 hrs: 0' e r Rig: Nabors 33E Rig Activity: In Run 65/ 8' ' Liner Job No.: AK- AM- 0006479766 Report For: Distribution List Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $162,826.46 ti 4 Current 24 hr Avg 24 hr Max Pump and Flow Data rp. R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 6 0 spm Flow rate 213 gpm ` y- II Gas* 18 units 39 unit ( 274 units @ 24375' ) Pump Capacity 3.55 gps , Pump Liner & Stroke Lengths 5.5x12 in. ` Sample Quality 0 Good 0 Fair © Poor Pump Pres 1013 psi t Mud Wt In 12.50 ppg Visc 46 secs API filt 5.6 ml HTHP 11.7 ml M ud Wt at Max Gas - ppg Y ppg p o., Mud Wt Out 12.50 PV 17 cP YP 28 Ibs /100ft2 Gels 8 \ 13 \ 16 MBT 5 5 H 9 4 Sd /o , ,, 4 ru. neig is a e. •utaso YI.nig t 'FG: € _ , C ,e . . ..._;. . , v. 4 . ..� ' 0 , B No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 L =. Wt On Bit: 20-30 RPM: 120-135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 4 Trip Depth: 24735 ft Trip Gas: 247 Mud Cut: ppg Trip CI: ppm gf Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm x.. Tight Spots: to to to current Feet of Fill on Bottom: ft a Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt - .. 10 90 Connection Gas and Mud Cut (BG = Background) ft units BG units Pp9 r ' ft units BG units ppg ft units BG units PP9 l ft units BG units ppg ' O ft units BG units PP9) ( ft units BG units ppg * , ` ft units BG units ppg ft units BG units ppg rg GAS PEAKS (Background Gas Samples Shaded Gray) VI Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total ., : r1-' ::: ,-, to to - to ri to Y to I to , -, ill tw1 RIH with 6 5/8" liner washing and reaming to 24,415 and pump a 100 bbl steel lube pill. Continue to RIH to 24,480' and stalled p/u and ream back to -" 24,465. RIH to 25,129 and encounter tight spot while working through a slight pack off occurred. Reduce pump rates and returned good [lq circulation.Continue to RIH to BTM to a depth of 25,122 st the time of report. Increase in BG gas was recorded correlating to the increase in Mud Weight 0�a out of the hole. A max gas of 247 units was recorded with a BG gas of 156 units. Gas gradually decreased roughly following the MW trend currently RIH ff with a BG gas of 18 units. A fluid caliper test was conducted with Calcium Carbide. Test resulted in a gas peak of 405 units @ 25,342 strokes. Calculated : d BTM's Up was 24 strokes and the first sign of carbide were detected at 23,905 strokes. _ i 4 gl G & I Magnets: 3.0 Ibs Rig Magnets: 1.5 Ibs Total Metal cuttings: 4.5 Ibs ***Costs Are Carried Up to April 5, 2009*** L ogg i ng Engineers: M ark Lindloff / Daniel Sherwood ** 1 0000 units = 100% Gas In Air -rmfv _ - 4" w4-4 g •� ;a 2 w ._ ,4 te: wi '�' —', � �` " 5 w a . a.. . "{ a . . 1 �.. tl Customer: B.P. Exploration Report No.: 39 :1 Well: NS33 A Date: 4/6/2009 - 23:59 A IVAT s Area: Beaufort Sea Depth 25612' Lea se: Nort Star Is. Foo tage Last 24 hrs: 0' / " Liner ; , � Rig: Nabors 33E Rig Activity: Run In 6 5 8 No.: AK -AM- 0006479766 Re gin Job No Report For: Distribution List p I er s Morning Report Mud o - 9g 9 P Daily Cost: $2,871.00 Tot Cost: $165,697.46 5C Current 24 h Avg 24 hr Max P ump and Flow Data m R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 65 spm Flow rate 228 gpm ' Gas 19 units 17 unit ( 177 units @ * 25576' ) Pump Capacity 3.55 gps VA Pump Liner & Stroke Lengths 5.5x12 in ±s Sample Quality 0 Good 0 Fair © Poor Pump Pres 879 psi Mud Wt In 12.50 ppg Visc 45 secs API filt 5.6 ml HTHP 11.8 ml Mud Wt at Max Gas - ppg Mud Wt Out 12.50 ppg PV 17 cP YP 26 Ibs/100ft2 Gels 7 \ 12 \ 15 MBT 8.0 pH 9.5 Sd - % r u. ne1. is a e. •utaso Ti. ni. t .,. i _ ..U . "'s ofi le Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32 TFA: 0.6850 ij Wt On Bit: 20 -30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432` -: Tr Depth: ft Trip Gas: Mud Cut: ppg T rip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ' Tight Spots: to to to current Feet of Fill on Bottom: ft 4 LithOlOgy ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt Connection Gas and Mud Cut (BG = Background) ft units BG units Ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg ' ft units BG units ppg ft units BG units ppg ft units BG units Ppg ft units BG units l ; i'il GAS PEAKS (Background Gas Samples Shaded Gray) Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total to ,!.,,1 to S to to F. to Tn to RIH with 6 5/8" liner to 25,459' and encountered pack off. Reduced pump rates and worked through, continued to wash and ream to 25,575'. Packed off 0 and increased torque . Reduced pump rates and increase pressure in 500 lb increments, regain circulation and continue to circulate gradually increasing pump pressure. Continuing to circulate at the time of report. Max gas recorded was 177 units and an average background gas while circulating of approx 18 -20 units. Aq .. vi 11 1s G & I Magnets: 1.2 lbs Rig Magnets: .01 Ibs Total Metal cuttings: 1.21 lbs * *" Costs Are Carried Up to April 6, 2009 * *" ii Logging Engineers: Mark Lindloff / Daniel Sherwood ** 10000 units = 100% Gas In Air ' =; ,'Pt _ ,4 4 _ter . nT* .` r. x� _. �.�, .Z :3 ,;. a i4'-gak.c - .4 1 p nn ,. Customer: B.P. Exploration Report No.: 40 W ell: N S33 A D ate: 4 /7/2009 - 23:59 _U Area: Beaufort Sea Depth 25612' Lease: North Star Is. Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: POOH Job No.: AK- AM- 0006479766 Report For: Distribution List ati i l Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $168,568.46 1 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm _: Gas' 0 units 3 unit ( 28 units @ 25484' ) Pump Capacity 3.55 gps Iv Pump Liner & Stroke Lengths 5.5x12 in Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 40 psi I Mud Wt In 12.50 ppg Visc 45 secs API filt 5.6 ml HTHP 11.8 mI Mud Wt at Max Gas - ppg 0 Mud Wt Out 12.50 ppg PV 17 cP YP 28 Ibs /100ft2 Gels 8 \ 13 \ 15 MBT 7.5 pH 9.4 Sd - % 4 , — sd YU* "el* is a e. •utaso 7 i.ni. t , _ ' ... ` .. i .. . E .T Q lG Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 1 1 / 32" 2 x 12 / 32" TFA: 0.6850 Wt On Bit: 20 -30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 x_.� .�� 3,...,_ _�. �,. ;' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm 1 Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm i t Tight Spots: to to to current Feet of Fill on Bottom: ft 1 L i th o l ogy ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt - ;:-.i‘• Connection Gas and Mud Cut (BG = Background) Pi) ft units BG units ppg e ft units BG units ppg ft units BG units PP9 ft units BG units ppg ft units BG units ppg f ft units BG units ppg f W I ft units BG units ppg 1'1 ft units BG units ppg D. GAS PEAKS (Background Gas Samp Shaded Gray) ,„ Depth Gas in units Gas Chromatograph 44 Max Background C1 C2 C3 C4 Total C5 Total IT to to t to 5 to ' to to f RIH to 25578' and establish circulation attempt to rotate and work liner down, torqued up and packed off. Attempt to regain circulation with no success. .; Attempt to release from liner and await decesion from town for further instruction while performing basic rig maintenace. Release from hanger and O circulate 2x liner volume. Pump slug and POOH 2 stnds, dry job was deemed ineffective. Circulate while reciprocating and pump another slug and begin `: POOH of hole tripping out of the hole with a depth fo 19880' at the time of report. No significant losses or gas peaks were recorded while rcirculating. k 4 � Y S%?iv G & I Magnets: xx Ibs Rig Magnets: xx Ibs Total Metal cuttings: )c< Ibs * *` Costs Are Carried Up to April 7, 2009 * ** Vi 41 Logging Engineers: Mark Lindloff / Daniel Sherwood ** 10000 units = 100% Gas In Air 11 .y �' ;� .€` �'' .a� i ..�t� y�� -� �' r�- ,..,tttf aL* :w.h.. -.. ._ Vr .. i ,.x -... , °ms`s Customer: B.P. E xploration R eport No.: 41 Well: NS33 A Date: 4/8/2009 - 23:59 ; I U "1 Area: Beaufort Sea Depth 25612' F Lease: North Star Is. Footage Last 24 hrs: 0' R ig: N abors 33E R ig Activity: P OOH 4 Job No.: AK -AM- 0006479766 Report For: Distribution List ` Mudlogger Morning Report Daily Cost: $2,871.00 Total Cost: $171,439.46 i PI Current 24 hr Avg 24 hr Max Pump and Flow Data 4 R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm 4 :. Gas' 0 units 0 unit; ( 0 units @ 0' ) Pump Capacity 3.55 gps is Pump Liner & Stroke Lengths 5.5x12 in Sample Quality ❑ Good 0 Fair 0 Poor Pump Pres 0 psi - Mud Wt In 12.50 ppg Visc 46 secs API filt 5.6 ml HTHP 11.8 ml Mud Wt at Max Gas - ppg ti t'l Mud Wt Out 12.50 ppg PV 17 cP YP 29 Ibs /100ft2 Gels 8 \ 12 \ 15 MBT 7.5 pH 9.4 Sd r u . r reig is a e. • ut as o ' i. nig �, _ _ x . _ ,- . _ t :. Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 l Wt On Bit: 20-30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm 4, a Tight Spots: to to to current Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt Connection Gas and Mud Cut (BG = Background) 3 ft unit BG units ppg ft units BG units ppg fit fl ft units BG units PP9 ft units BG units ppg ft units BG units ppg ` ft units BG units ppg ft units BG units ppg ft units B G units ppg 4_ ,.. x ifAt0 .' ...y - ( .' f.' V..� ...'l . . - % - WIt 3 4,# , 11 per =I:,, _.* 4. , _ . .:� . , pe - tt. ,. GAS PEAKS (Bac Gas Samples Shaded Gray) . , Depth Gas in units G as Chromatograph 1 r Max Background C1 C2 C3 C4 Total C5 Total 'a to .4 . j to 1 r to to to z I t0 POOH to 19,788' and pump slug cont to POOH to 11,156' and pump another pill. Continue to POOH and UD BHA and prepare for BOP test. 3 G & I Magnets: xx Ibs Rig Magnets: xx Ibs Total Metal cuttings: xx Ibs * ** Costs Are Carried Up to April 8, 2009 *"* LI .i Logging Engineers: Mark Lindloff / Daniel Sherwood * * 10000 units = 100% Gas In Air r. Customer: B.P. Exploration Report No.: 42 Well: NS33 A Date: 4/9/2009 - 23:59 1 � , J II '`' Area: Beaufort Sea Depth 25612' Lease: North Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig Activity: RIH V ,..,:ti Job No.: AK- AM- 0006479766 Report For: Distribution List - . Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $174,310.46 . . .:4:1. -...' ._ ,L. .. '-` c ` . :... ... . ..E , .,,k:- , >, ._.. 5LiK ... !i'. ' ,.... K+.'°�.:: z,. f Current 24 hr Avg 24 hr Max Pump and Flow Data il v. R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm 0 Gas* 0 units 0 unit ( 0 units @ 0' ) Pump Capacity 3.55 gps El ftl Pump Liner & Stroke Lengths 5.5x12 in el j Sample Quality 0 Good 0 Fair Poor Pump Pres 0 psi ig CX , r : €cc1, r ` :fi - - `' .ter.. . 5' 4, .. „ , > ., .z - , . . ,_..� ' y . .. �. . _ r . �'_ . ... - x� :. '« rf - . Mud Wt In 12.10 ppg Visc 41 secs API filt 5.6 ml HTHP 11.8 ml Mud Wt at Max Gas - ppg Mud Wt Out 12.50 ppg PV 18 cP YP 24 Ibs/100ft2 Gels 8 \ 11 \ 14 MBT n/a pH 9.3 Sd - % itk z. Yu. "e19 is ae. •utaso 'I.nl9 t r .a;..,.v ~ .,,. - _`?.A„ -. -s ,. . ..:" , ,. 3',`"ppg �,.14 _ Bit No.: 5 Type: RSX516M Bit Size: 7 7/8 Jets: 5 x 11 / 32" 2 x 12 / 32" TFA: 0.6850 Ri4 Wt On Bit: 20-30 RPM: 120 -135 Hrs. On Bit: 58.9 Total Revs on Bit: 14.14 Footage for Bit Run 1432 t Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm 3 p Tight Spots: to to to current Feet of Fill on Bottom: ft 4. Li t h O l Ogy ( % ) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt Connection Gas and Mud Cut (BG = Background) ft un BG un ppg ft un BG un ppg k :4' d ft units BG units ft units BG units PP9 ft units BG units ft units BG units PP9 , PP9 ft units BG units ppg ft units BG units ppg fir . , ry `°*>".u:.m, A r,.,.. ?� ,ate"°,° s ,3 ',, - , .., ,,. „ . . . ant. ,-4:",o;::,::,.sh I, , . . «.. t _...` -fie .., , ._ w - -,;z t3 GAS PEAKS (Background Gas Samples Shaded Gray) Depth Gas in units Gas Chromatograph ,,,: Max Background C1 C2 C3 C4 Total C5 Total to r1 to a to _ fr- to ivi 1 to ,~ I to 1. Complete BOP test and UD test tool, slip and cut drill line. P/U dumb iron BHA w/ junk baskets and mill assy and begin RIH w/ 4.5" dp filling pipe every ,t A ' 3000 ft.Currently RIH with single joints with a bit depth of 4339'. , 1 i t r G & I Magnets: xx Ibs Rig Magnets: xx Ibs Total Metal cuttings: xx Ibs ***Costs Are Carried Up to April 9, 2009 * ** Logging Engineers: Mark Lindloff / Daniel Sherwood * * 10000 units = 100% Gas In Air u a as._ z ..,. ..�. E., .7.77: . -E = .a E..r? , m : i.'; .. :x ' R . ' 7 .-„ i fi % t W_,W W.. r, £ ._ :3 1 Y �m . . 5-.„ ., : WW1..,:',7 s tt o er: B.P. B eport No.: 43 T; Well: NS33 A Date: 4/10/2009 - 23:59 r9 9 ' ' Area: Beaufort Sea Depth 25612' a_ 1 Lease: North Star Is. F oo t age L ast 24 hrs: 0' . I Rig: Nabors 33E Rig Activity: RIH ' Job No.: AK -AM- 0006479766 Report For: Distribution List .. Mudlogger's Morning Report Daily Cost: $2 o 871. To Cost: $177,181.46 _ .. vow., : ..1M--- 1. - .�:. -- . . .�4 u : r. ......3a :c � s �, Mzi-L. `�. E:.: .. = ,=77 -7, Cu 0 � I . r Current 24 hr Avg 2 4 hr Max P ump and Flow Data t R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 117 spm Flow rate 416 gpm 1 Gas'` 0 units 0 unit ( 0 units @ 0' ) Pump Capacity 3.55 gps Pump Liner & Stroke Lengths 5.5x12 in. =l Sample Quality 0 Good 0 Fair E Poor Pump Pres 1083 psi 1 Mud Wt In 9.70 ppg Visc 52 � secs API filt 7.9 ml HTHP n/a ml Mud Wt at Max Gas - ppg I Mud Wt Out 9.70 ppg PV 10 cP YP 26 Ibs/100ft2 Gels 10 \ 14 \ 19 MBT n/a pH 9.4 Sd - - r .n u ei • is a e. • ut as o 11.n]. ` t °`' °`� �.�_- : ..� f �,�;� � � 4- ' ..:�.° - � ��` Bit No.: 6 Type: Flt Btm Mill Bit Size: 5 7/8" Jets: x / — x / TFA: N/A j Wt On Bit: n/a RPM: 100 -120 Hrs. On Bit: 0.0 Total Revs on Bit: n/a Footage for Bit Run n/a : i Tr ip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm r; Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to current Feet of Fill on Bottom: ft LI k= Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt V s .'°'41 .ixr - Connect Gas and Mud Cut (BG = Background) E ft units BG units ppg ft units BG units ppg rfr ,, . ft units BG units ppg ft units BG units ppg 1 ft units BG units ppg f t units BG units ppg 1 ft units BG units pp9 ft units BG units ppg c Vfl GAS PEAKS (Background Gas Samples Shaded Gray) Depth Gas in units Gas Chromatograph ' Max Background C1 C2 C3 C4 Total C5 Total : I to V ,. A to E l to . to H to I H ; RIH with c/o assy on 4.5" dp to 11,686' filling dp every 3,000 ft one joint at a time. M/U x/o to 5 7/8" dp and necessary slips and continue to RIH to 14,067'. ; I Stage pumps to 700 gpm and circulate 3 btms up racking back one stnd per btms up. Continue to circulate to change mud from a 12.5 to a 9.7 ppg � =:I racking back one stand after every btms up. No significant gas peaks were observed while circulating and mud solids consist of predominatly barite with 1 ; I very fine sand and siltsones. , i `, G & I Magnets: 2.5 Ibs Rig Magnets: 2.0 Ibs Total Metal cuttings: 4.5 Ibs ***Costs Are Carried Up to April 10, 2009 "" ;Logging Engineers: Mark Lindloff / Daniel Sherwood ** 10000 units = 100% Gas In Air : Customer: B.P. Exploration Report No.: 44 4 ` Well: NS33 A Date: 4/11/2009 - 23:59 ) 1 .A R '' - ""' '` £ Area: Beaufort Sea Depth 25612' ` Lease: North Star Is. Footage Last 24 hrs: 0 R ig: N abors 33E R ig Activity: R IH Job No.: AK -AM- 0006479766 Report For: Distribution List , Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $182,923.46 Fl '-,. 5x �` F .. ,=is" ' ". .t , .- �.. -mac'_ ....z < ,e..' r_z..,-'..,.. .._v�`a°uT-�, ...'- ... 4 ,, 4 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 168 spm Flow rate 586 gpm : .• Gas* 1 units 2 unit ( 20 units @ 25422' ) Pump Capacity 3.55 gps Y Pump Liner & Stroke Lengths 5.5x12 in. k- • Sample Quality 0 Good 0 Fair El Poor um Pres 1 83 psi P p 0 , iN Mud Wt In 9.70 ppg Visc 48 secs API filt 7.5 ml HTHP n/a ml Mud Wt at Max Gas 4.0 ppg Mud Wt Out 9.70 ppg PV 11 cP YP 25 Ibs /100ft2 Gels 11 \ 16 \ 19 MBT n/a pH 9.7 Sd - %-1 Z,11 `1 U. "el* is a e. ut as o T le ni. t W - _ i Bit No.: 6 Type: Flt Btm Mill Bit Size: 5 7/8" Jets: 5 x 15 / x / TFA: 0.8600 rte" EA Wt On Bit: n/a RPM: 100 -120 Hrs. On Bit: 0.0 Total Revs on Bit: n/a Footage for Bit Run 0 R R Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm 01 Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm i, Tight Spots: to to to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt `r : :4 s : A;ik . ,`r �,f, n" f ` , '� . ='1*3_ 474 . r ... , ,, ', z " •" *..", 67, -, . . '"..�", ,. 5 ..,z"10,;, MA, : fir .<; � . R ,3 . El Connection Gas and Mud Cut (BG = Background) ft units BG units PP9 ft units BG units ppg ft units BG units ppg ' ft units BG units ppg SKr ft units BG units PP9 ft units BG units ppg i ft units BG units ppg ft units BG units ppg Eif.:1 id { GAS PEAKS (Background Gas Samples Shaded Gray) Depth Gas in units Gas Chromatograph f Max Background C1 C2 C3 C4 Total C5 Total to to E ? to '' to `, to to a RIH to 13,563 and displace hole with 9.7 ppg mud then continue to RIH to 23,341 tagging liner top. Continue to RIH to 25,456' filling every stand and tag 8 1 5/8" liner top. Stage pumps up to 430 gpm and continue changing mud to 9.7 ppg. Continue to RIH to 25,461 and begin to mill out landing collar. Max gas i recorded was 20 units coinciding with the return of heavier mud during displacement. Gas readings were then inaccurate as the flow was diverted from across the shakers. k i G & I Magnets: 2.0 lbs Rig Magnets: 1.5 lbs Total Metal cuttings: 4.5 lbs ***Costs Are Carried Up to April 11, 2009 * ** 1 Logging Engineers: Mark Lindloff / Daniel Sherwood ** 10000 units = 100% Gas In Air v g ' _. ._..:, : 2 �,_ 511: - . .<a , .., 4 . . . w. r _,.... _ ._ .. , <: Y e: ,. ,.-_ _ . ._.,. ; __y am ..,, ' ;':. 4 _3.._ ,s _...11 $V - . ' :6,2∎1;a:?. '1:v.�I . z .;,; - ;-"x'Sv� a °.-'1 r s x . . 7 - x ,;- - ,- r *�::, r try Z i ,"+.w ..., -', . tit .,. S, 3' > t- - - �;'#a?. -4 -- �• ... "Y '` -�., ���� Customer: B.P. Exploration Report No.: 45 f.: Well: NS33 A Date: 4/12/2009 - 23:59 im - " Area: Beaufort Sea Depth 25617' WI ,_ Lease: North Star Is. Footage Last 24 hrs: 5' �) Rig: Nabors 33E Rig Activity: POOH Job No.: AK- AM- 0006479766 Report For: Distribution List `M Mudlogger's Morning Report Daily Cost: $4,036.00 Total Cost: $186,961.46 : ' ° .�. y -::. ..�":'„��", .� ` --;= kK.., �� --�.s �: >* =t�....,qr4�:r-: .�..?a>s , . .._ . s ,. i r " " .* 1 . Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr 43 ft/hr ( 70 ft/hr @ 25616' ) Pumps 0 spm Flow rate 0 gpm Gas* n/a units 5 unit ( 34 units @ 25616' ) Pump Capacity 3.55 gps P ump Liner & Stroke Lengths 5 .5x12 in 71 4 Sample Quality E] Good 0 Fair © Poor Pump Pres 42 ps1 g ill m 2 k til Mud Wt In 9.70 ppg Visc 49 secs API felt 7.4 ml HTHP n/a ml Mud Wt at Max Gas ppg Mud Wt Out 9.70 ppg PV 11 cP YP 25 Ibs/100ft2 Gels 10 \ 15 \ 19 MBT n/a pH 9.5 Sd - M. d Wei. hts Called Out as of Will. ht e , E ' w � � . � . -, , 4 i ; . �. Bit No.: 6 Type: Flt Btm Mill Bit Size: 5 7/8 Jets: 5 x 15 / _ x / TFA: 0.8600 f Wt On Bit: 5.00 RPM: 70 -80 Hrs. On Bit: 0.3 Total Revs on Bit: 40 Footage for Bit Run 5 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm g itt 2, Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ,h. Tight Spots: to to to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn DoI Chrt 10 _____ 80 -___ ij � S za.a" :.> .� - # e ' °' a , `tr c m3 r3 x ur` S > . ? „ P. ,:g- rv1f -A ,� , t 1-: Connection Gas and Mud Cut (BG = Background) F ft units BG units ppg ft units BG units ppg t ft units BG units ppg ft units BG units ppg ; ft units BG units PP9 ft units BG units ppg t ft units BG units PP9 ft units BG units ppg t v Nil t GAS PEAKS (Background Gas Samples Shaded Gray) �ri Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total 25612' to 25617' 34 25 2430 190 111 59 25 r to i� to to kj to ':i:1-ii to Vi Efl id Wash and ream to 25534' and tag float collar and drill out continue to wash and ream to 25582 and tag shoe drill out shoe packing off and working pipe to free. Continue to wash and ream rathole and drill 5' of new formation to 25617' md. Cycle pumps to try and move debris to junk basket and circ 2x 8 5/8" '_ liner volume and begin POOH. Pump out of hole to 8255" at the time of report. A max gas of 34 units was recorded at btms up, gas peak was most likely 1 diluted due to nature of circulation. Cuttings lithology was predominantly It gy - gy shale flky pity with tr of v fine sd and asst Icm and barite and metal 'E shavings. No significant losses occurred while circulating or static. 1 G & I Magnets: 2.8 Ibs Rig Magnets: 1.8 Ibs Total Metal cuttings: 4.5 Ibs * ** Costs Are Carried Up to April 11, 2009 *** Logging Engineers: Mark Lindloff / Daniel Sherwood ** 10000 units = 100% Gas In Air '.._ -4 :^> i, w 'i, ,.c.._ ._�.._�.�..: x- .,.�v5 s.. `, 3.,. ' '., " , �s; �.:: "�.,,.z'as >,j Customer: B.P. Exploration Report No.: 46 Well: NS33 A Date: 4/13/2009 - 23:59 S AL U „`, ' l ,5 Area: Beaufort Sea Depth 25617' PI f Lease: North Star Is. Footage Last 24 hrs: 0' Rig: Nabors 33E Rig A ctivity: Running USIT Log Job No.: AK- AM- 0006479766 Report For: Distribution List Tr Mudlogger's Morning Re Daily Cost: $2,871.00 Total Cost: $189,832.46 Pi it Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm PI Gas* N/A units 4 unit ( 10 units @ 3943' ) Pump Capacity 3.55 gpsr Pump Liner & Stroke Lengths 5.5x12 in ti Sample Quality 0 Good 0 Fair © Poor Pump Pres 42 psi y - . A.: s. „ '. ,&I >�if a-s .�_: r . k v DTs ,. , sue,. ,' .. ,.. ., ._ ,. _ . * , r Mud Wt In 9.70 ppg Visc 49 secs API filt 7.2� ml HTHP n/a mI Mud Wt at Max Gas _ PP9 it'iji Mud Wt Out 9.70 ppg PV 11 cP YP 24 Ibs /100ft2 Gels 10 \ 13 \ 16 MBT n/a pH 9.3 Sd - Fu. //el• is a e. •utaso VI. ni. .. .. ST , .. .,_ , _ _.". n'. .,s a,..4 : Bit No.: 6 Type: Flt Btm Mill Bit Size: 5 7/8" Jets: 5 x 15 / _ x _/ _ TFA: 0.8600 Wt On Bit: 5.00 RPM: 70 -80 Hrs. On Bit: 0.3 Total Revs on Bit: 40 Footage for Bit Run 5, ti Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm I. Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm � Tight Spots: to to to Feet of FiII on Bottom: ft Li t h ology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt 4 ri 44 Connection Gas and Mud Cut (BG = Background) fzi ft units BG units ppg -i ft units BG units ppg < , ft units BG units ppg ft units BG units ppg ft units BG units ppg ft units BG units ppg t. ft units BG units ppg ft units BG units ppg Fi .`; . , e, - 'u, 2fi. .. ; `:=Mt � - 0:.,... 4 ,., 14 -: 1e _.,:' . ate . zesaa* . 5M ...;- €r 7. ,WAtifak i N AI IA GAS PEAKS (Background Gas Samples Shaded G ray) Depth Gas in units Gas Chromatograph ,t Max Background C1 C2 C3 C4 Total C5 Total to t o to �� to to V rl to ki • .I - .,r -- ,` x:, i31 "'"- 44 -&4;'- , ; = ..°4-€ .. N .,•, 3 7,,. .'.'. b ;;' .±.,--,, - £. f;',--:-, e ., -.. 1 Pump slug and POOH to 13,976' circulate 2x btms up. Pump another slug and continue to POOH UD BHA and prepare to run USIT log. Currently rigging t, up USIT log on Schlumberger wireline at the time of report. Max gas recorded while circulating was 10 units with a bg gas of 4 units. No losses were F 1 recorded. c G & I Magnets: xx Ibs Rig Magnets: xx Ibs Total Metal cuttings: xx Ibs * ** Costs Are Carried Up to April 12, 2009 * * * - 1 Logg Engineers: Mark Lindloff / Daniel Sherwood ** 10000 units = 100% Gas In Air Customer: B.P. Exploration Report No.: 47 Well: NS33 A Date: 4/14/2009 23:59 ,. - Area: Beaufort Sea Depth 25617' Lease: N orth Star Is. Fo otage Last 24 hrs: 0 P. Rig: Nabors 33E Rig Activity: RIH Job No.: AK -AM- 0006479766 Report For: Distribution List Mudlogger's Morning Re Daily Cost: $2,871.00 Total Cost: $192,703.46 11 M Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm s Gas* N/A units N/A unit ( N/A units @ N/A ) Pump Capacity 3.55 gps 1 P ump Liner & Stroke Lengths 5 in. 1 i Sample Quality ❑ Good 0 Fair © Poor Pump Pres 42 psi 41 Mud Wt In 9.70 ppg Vise 49 secs API filt 7.2 ml HTHP n/a ml Mud Wt at Max Gas ppg - LI Mud Wt Out 9.70 ppg PV 11 cP YP 24 Ibs /100ft2 Gels 10 \ 13 \ 16 MBT n/a pH 9.3 Sd - 4. 7 u. "el• is a e. out TLni. t _,..;_� _,._. _,.,x_ - .,; _.. ..,.. R ir ,:' Bit No.: 7 Type: Tricone Bit Size: 5 7/8" Jets: 3 x 5 / _ x / TFA: 0.5180 Wt On Bit: n/a RPM: N/A Hrs. On Bit: N/A Total Revs on Bit: N/A Footage for Bit Run o, Trip Depth: ft Trip Gas: Mu C u t : , ppg Trip CI: ppm I '. Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ; Tight Spots: to to to Feet of Fill on Bottom: ft 7 -: Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt =t Connection Gas and Mud Cut (BG = Background) r ft units BG units PP9 ft units BG units ppg . ft units BG units ppg a ft units BG units ppg w ft units BG units PP9 � . ft units BG units ppg ft units BG units PP9 ' ft units BG units ppg ''M GAS PEAKS (Background Gas Samples Shaded Gray) 'a Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total' to to il ': to , tO A f. tl tO :1 to 0,11 � -r : -�^ v . , -,,, a , r't: i�'='--;4'.''; . $ . ' a',xs.. - ... : t.., :, .,.„ _, z.., 's„ _ ..„ -„,. t •+'*�c-a:„„ :. s ._ _... c , ' �.�` rr. �,.. _ .a- �r .,, - Continue to run USIT log on Schlumberger wireline.P /U BHA and begin RIH, shallow pulse test MWD tools at 1,000 md. Currently RIH with a bit depth of 5468' at the time of report. i 1 , G & I Magnets: xx Ibs Rig Magnets: xx Ibs Total Metal cuttings: xx lbs ***Costs Are Carried Up to April 13, 2009 * ** vit Logging Engineers: Dennis Lee / Daniel Sherwood ** 10000 units = 100% Gas In Air Vi 0;T.7° ,sn.,i.„ .,x - ° � ?�' .._ t %T?'�r ,. '�'t'.,`�,. __ IF:W::,u.'�;�� r n, Customer B.P. Exploration Report No : 48 Well: NS33 A Date: 4/15/2009 23:59 � Area: Beaufort Sea Depth 25617' ri Lease: North Star Is. Footage Last 24 hrs: 0' r. Rig: Nabors 33E Rig Activity: MAD Pass J No.: A K- AM- 0006479766 R eport For: D istribution List t i,‘.. M udlogger's Morning Report Daily Cost: $2 ,871.00 To tal Cost: $1 95,574.46 1 .),., ..„,,..,„,,,,,„:„,„...,,,,:::....,,,_,.,,,,,m„.„..,„:„_,,.,„„.:...„,,..,::„,,„(,„,,,:„.,,,,:_,....*.,.,„..:,,,,r.,._,,„,,:„,.._;.::„,,,_:..:„,:.,:,„..:,„.:„:„„,,,„„,„,,„,,„,„,a,w.,,,,,,,,,:„.,,,„:,,,.,..,,,„,,.,,,.„:.,„:„,:!:,„,,.,,,,„.„.„, Current 24 hr Avg 24 hr Max Pump and Flow Data -f ° :,.,' R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 70 spm Flow rate 250 gpm ; Gas* N/A units N/A unit; ( N/A units @ N/A ) Pump Capacity 3.55 gps Pump Liner & Stroke Lengths 5.5x12 in , Sample Quality 0 Good El Fair © Poor Pump Pres 2254 psi mod Mud Wt In 9.70 ppg Visc 57 secs API filt 6.8 ml HTHP n/a ml Mud Wt at Max Gas ppg 1 Mud Wt Out 9.70 ppg PV 12 cP YP 24 Ibs /100ft2 Geis 11 \ 13 \ 14 MBT n/a pH 9.5 Sd - % x x ru. rreiq is a e. •utaso ►i.niq t 6: W _. _ .. _ . - _ , _ s . _ ..,.. e_ _.. 4 ' .. qtif Bit No.: 7 Type: Tricone Bit Size: 5 7/8" Jets: 3 x 5 / _ x / TFA: 0.5180 1 L. ., Wt On Bit: n/a RPM: 30 -40 Hrs. On Bit: 0.0 Total Revs on Bit: N/A Footage for Bit Run o , ' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm .. Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn _ Dol Chrt iit q4 Connection Gas and Mud Cut (BG = Background) ft units BG units pp9 ft units BG units pP9 � ft units BG units ppg . ft units BG units ppg :r. ), ,..t ft units BG units ppg ft units BG units ppg ift ft units BG units ppg ft units BG units ppg * . ,. -t -:.?I f- ..... 7 - `::, , x - "_. , 3. _ ii , f' ._ Y.' .>, , ,_, _. i,- nom' 1 " GAS PEAKS (Background Gas Samples Shaded Gray) 4, Depth Gas in units Gas Chromatograph Ff Max Background C1 C2 C3 C4 Total C5 Total oil to �` iT -1 to : te to to kg, i :.; to ' to RIH to 6 955' and and slip and cut drill line. Cotinue to RIH to 12,070 remove 4.5 and m/u 5 7/8' airslips. M/U x/o for 5 7/8' pipe and continue to RIH to 25,511 and begin washing and MAD passing to btm.Pump spacer pill and 9.7 ppg flow pro mud to begin swapping active system. Mud is being dumped fir; and diverted from the shakers disabling gas monitoring equipment. CUrrently MAD passing with a bit depth of 25609' md. rt G & I Magnets: xx Ibs Rig Magnets: xx Ibs Total Metal cuttings: xx Ibs * ** Costs Are Carried Up to April 14, 2009 * ** L ogging Engineers: Dennis Lee / Daniel Sherwood ** 10000 units = 100% Gas In Air -: J 1.: — "A r Rte" ry + r " u , ,,. •b 9." y , ; , i" _n a x _ 16 4 t"e -< , ' "`°-� o fi - mm , :ri r i c T ., ir .,-,--, , ,,,, i ;_ :; -,y. t - : , : ,=?,,- : , ,r, , , , ,,r,: : --,mtsj-::,-*:..:4,'-;:,..,.-:,- , -:•::: - _,. - -,-- - , ,, : . ; ;:i,::::::: -'-' =M Customer: B.P. Exploration Report No.: 49 Well: NS33 A Date: 4/16/2009 - 23:59 HALLISUPTON -- Area: Beaufort Sea Depth 26090' Lease: North Star Is. Footage Last 24 hrs: 473' Rig: Nabors 33E R Activity: T ool Press Test Job NO.: AK -AM- 0006479766 Report For: Distribution List Mudlogger s Morning Report Daily Cost: $2,871.00 Total Cost: $198,445.00 I < x mot, ; ,,.very„€ 4 M. , .__ *.S=0 x ,' .,. ., .* si _mss- *r .... ...,- ti , ..,. asa-- 8 as . ,.- s Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr 54.78 ft/hr ( 97 ft/hr @ 25898' ) Pumps 64 spm Flow rate 228 gpm ` Gas* 21 units 43 unit: ( 153 units @ 25800' ) Pump Capacity 3.55 gps Pump Liner & Stroke Lengths 5.5x12 in. 4 Sample Quality © Good Ei Fair D Poor Pump Pres 1780 psi p`,> 4 Mud Wt In 9.70 ppg Visc 59 secs API filt 5.4 ml HTHP n/a ml Mud Wt at Max Gas ppg tO Mud Wt Out 9.70 ppg PV 14 cP YP 14 Ibs /100ft2 Gels 12 \ 13 \ 15 MBT 0.3 pH 9.5 Sd - % 1u. Tv el. is a e. •utaso ∎ Lni. t ._ ' r. ,kf4 �1 . N. .. _ of - t . `CI A Bit No.: 7 Type: Tricone Bit Size: 5 7/8" Jets: 3 x 5 / _ x / TFA: 0.5180 Wt On Bit: 15 -20 RPM: 30 -50 Hrs. On Bit: 11.4 Total Revs on Bit: 4 F ootage for Bit Run 473 ftl: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft F • r4 - Lith0Iogy ( %) ..; Sd Sst Silt Siltst Cly Clyst Sh Lst Coal L mstn Dol Chrt r I 70 10 20 rit Connection Gas and Mud Cut (BG = Background) ft units BG units ppg = ft units BG units ppg A t ' ft units BG units ppg ft units BG units ppg fi ft units BG units PP9 ft units BG units ppg ft units BG units ppg ft units BG units ppg 'k a te J - =o-; , gc=74? a, . 1 , l ' : ' FlaR?":`,,1 - Wi *' .''n^." . :" . _ N . ` GAS PEAKS (Background Gas Samples Shaded Gray) ' `= Depth Gas in units Gas Chromatograph Max Background C1 C2 C3 C4 Total C5 Total 1 25794' to 25829' 153 140 12239 1138 488 173 55 OWC to 25868' 57 50 4781 435 183 67 22 R., to '� to � 1 to . to y Complete Mad pass to 25,611 and perform FIT and drill new formation from 25611 - 25,720'. Retrieve samples w/ Schlumberger stethescope at 25,686 and 25,692'. Drill ahead to 26,090' final TD. TD well at 19:19 4/16/09. Circulate btms up and begin logging open hole w/ Schlumbeger stethescope to .'; obtain pressure points. Formation tops were called at 25,680 and for the top of Shublik, 25,786 and for the top of Shublik D 25,794 md, top of Ivishak and - 25,868 md, a t the Oil to Water contact point. Gas peaks occured at the top of the Shublik D formation at 153 units and a BG gas of approx 140 units. k This seemed to be cetered on a mod srtd, sb rd- ang, pred qtz sd which comprised the production zone lithology. Recorded gas at the oil to water contact point was 57 units with a BG gas of approx 50 units. No connection gasses or significant mud losses were recorded. k 1 G & I Magnets: xx Ibs Rig Magnets: .5 Ibs Total Metal cuttings: 0.5 Ibs ***Costs Are Carried Up to April 15, 2009 * ** VI Logging Engineers: Dennis Lee / Daniel Sherwood ** 10000 units = 100% Gas In Air F .h ' -rte- .'F 5.. �=' s omas; : ' ;r � „s , . x i a' E ' a .,.. .,. �' , s ax t s .<. �..�_zrr .,�.- ,� c�3e°�&�,r�a..... ��. ���..�° .?a. r- �+�..L�' 1 . _ 1" ., r Y. , - : _ t . _ ,, . f P. , .. - -- ., yr . , ivy '.. A Customer: B.P. Exploration Report No.: 50 A Well: NS33 A Date: 4/17/2009 - 23:59 1. - . t U "` Area: Beaufort Sea Depth 26090' Lease: North Star Is. Footage Last 24 hrs: 0' - Rig: Nabors 33E Rig Activity: POOH Job No.: AK- AM- 0006479766 Report For: Distribution List 41 .... Mudlogger's Morning Report Daily Cost: $2,871.00 Total Cost: $201,316.00 ti t •''t a''.., , , ,.,. , ,? . ,. 4ww r: r .,i:t :, ,`.` :'; . € - tr _ 0!t % .;,... _, `.x„ ; - a . . e y r Current 24 hr Avg 24 hr Max Pump and Flow Data ' °' R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm Ci Gas* 0 units 8 unit: ( 18 units @ 25611' ) Pump Capacity 3.55 gps Pump Liner & Stroke Lengths 5.5x12 in Sample Quality 0 Good El Fair El Poor Pump Pres 64 psi .. _>.,_ .. 5w:..- '_-f 2 ur, imeei, .,f ,r , .. yea_, _Z ', _. . .. ,.. _ :.. . ..,_, i < . Mud Wt In 9.70 ppg Visc 58 secs API filt 5.6 ml HTHP n/a ml Mud Wt at Max Gas ppg ' Mud Wt Out 9.70 ppg PV 13 cP YP 23 Ibs /100ft2 Gels 10 \ 13 \ 15 MBT 0.3 pH 9.4 Sd - % :1 . iiiiidJiR 4�[ C: IiTiF11 [�:[el1f5i�rdGril6�if _: _ ,' „ B No.: 7 Type: Tricone Bit Size: 5 7/8" Jets: 3 x 5 / _ x / TFA: 0.5180 Wt On Bit: 15 -20 RPM: 30 -50 Hrs. On Bit: 11.4 Total Revs on Bit: 48k Footage for Bit Run 473 ifi Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of FiII on Bottom: ft MI Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt ii ii ,,,t. Connection Gas and Mud Cut (BG = Background) WI ter. ft units BG units PPg :a ft units BG units ppg Liil -,-ti " ft units BG units PP9 if units BG units ppg ki ;z k ft units BG units PP9 ft units BG units ppg ", ft units BG units PP9 ft units BG units ppg , - t .. �C.;. . ^ VOSI , , s� .'.. : t' :,..:'.:rte+ 5 eVcfs ... ._ te; r „ »:. -' ikw ,...:ik.i' - : - n- .,._ _ :'` GAS PEAKS (Background Gas Samples Shaded Gray) M Depth Gas in units Gas Chromatograph M ax Background C1 C2 C3 C4 Total C5 Total to gl Sr to r to r kel ' to , i to tf t0 ... ,' °}„` °'1 - �' . -,,', .... s, ,--- .„ ^fi# , _ . , ., — v _ .i : ;. , r ...4 Running Schlumberger Stethescope to obtain pressure points ang begin POOH to 25,350 and begin looking for casing marker to 25,300. Continue to { POOH to 24,806 and look for casing marker at 2,4470. RIH to btm wahing and reaming occassionally and log with Schlumberger caliper tool to 25,820 RIH to 26,032 and log to 2,5940. Ream and wash back down to btm and pump pill. Begin pumping out of hole to 25,036 and drop circ sub ball and x continue to pump out of hole. Currently pumping out of hole with a bit depth of 23,706 at the time of report. No significant trip gasses were recorded. : PM G & I Magnets: xx Ibs Rig Magnets: xx lbs Total Metal cuttings: xx Ibs **" Costs Are Carried Up to April 16, 2009*** j Logging Engineers: Dennis Lee / Daniel Sherwood ** 10000 units 100% Gas In Air .z �a''t" p ' k °'. , ;:,,:. _ , tip., . = -, fj :: . f �` ., : _, s..,lW ,: ig iZ:i:;a11 Customer: B.P. Exploration Report No 51 Well: NS33 A Date: 4/18/2009 - 23:59 M l Area: Beaufort Sea Depth 26090' IA Lease: North Star Is. Footage Last 24 hrs: 0' IA : Rig: Nabors 33E Rig Activity: POOH =. Job No.: AK- AM- 0006479766 Report For: Distribution List A Mudlogger's Morning Report I Dail y Cost: $2,871.00 Total Cost: $204,187.00 e ak'it _�:> 'e fits .. . , ` k : ,. .. t , °'' s ,. '. -. °. a " - i! , a i t Current 24 hr Avg 24 hr Max Pump and Flow Data fir: R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm qi Gas* 0 units 2 unit: ( 14 units @ 14356' ) Pump Capacity 3.55 gps P ump Liner & Stroke Lengths 5 .5x12 i n 0 Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 64 psi n r x ","s;:; r g ; r 1 .}. _w .< , ; . -. . ? ?, , . , .. : it, a'A r: 4 il A Mud Wt In 9.70 ppg Visc 57 secs API filt 5.8 ml HTHP n/a ml Mud Wt at Max Gas ppg Mud Wt Out 9.70 ppg PV 13 cP YP 25 Ibs /100ft2 Geis 13 \ 14 \ 15 MBT 0.3 pH 9.5 Sd - % V r n • r . - iiiii Bit No.: 7 Type: Tricone Bit Size: 5 7/8" Jets: 3 x 5 / _ x / TFA: 0.5180 -� Wt On Bit: 15 -20 RPM: 30 -50 Hrs. On Bit: 11.4 Total Revs on Bit: 48k Footage for Bit Run 473 F ` Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: to to to Feet of Fill on Bottom: ft Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol Chrt i Connection Gas and Mud Cut (BG = Background) iN ft units BG units PP9 ft units BG units ppg , V!, ft units BG units ppg ft units BG units ppg 1 Lri k_:. ft units BG units ppg ft units BG units ppg ti ft units BG units r ° ft units BG units ppg ppg .::'�.i`@"z "'., s�.,°... .> ' °' #� �- °.'3 -�, _ 5..; .in. ,.. ����., °' Via; ,�' +- ;� s. -,.,,. ::a � ^_.;:�`A :"�7 mv hl 1 .,-„!:: GAS PEAKS (Background Gas Samples Shaded Gray) ' Depth Gas in units Gas Chromatograph Background C C2 C3 C4 • • . tO • x -°z POOH from 23,706 to 22,325 and circulate 3x the 8 5/8" liner volume. Pump out of hole from 23,225 to 18,007'. Continue to POOH from 18,007 to 14,460 7 ",1 not pumping. Continue pumping out of hole to 14,241 and circulate 1x btms up, rack back one std and continue to circulate 2x btms up to 14,3654'. Pump d 1 slug and POOH to a current bit depth of 13,792 at the time of report. No significant gas peaks or mud losses occured, max gas was recorded at 14 units while circualting. i `r1 G & 1 Magnets: xx Ibs Rig Magnets: xx Ibs Total Metal cuttings: xx Ibs * ** Costs Are Carried Up to April 17, 2009 * ** £v Logging Engineers: Dennis Lee / Daniel Sherwood ** 10000 units = 100% Gas In Air [1 M -� A F a em u - a' -: 7.77 a i .: Customer: B.P. Exploration Report No.: 52 Well: NS33 A Date: 4/19/2009 - 23:59 Area: Beaufort Sea Depth 26090 . Lease: North Star Is. Footage Last 24 hrs: 0' ,, ii Rig: Nabors 33E Rig Activity: RIH Job No.: AK- AM- 0006479766 Report For: Distribution List N . Mudlogger's Morning Report Daily Cost: $2,017.00 Total Cost: $206,204.00 tk Current 24 hr Avg 24 hr Max Pump and Flow Data Til R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm .' Gas* N/A units N/A unit ( N/A units @ N/A ) Pump Capacity 3.55 gps r ,Eti v_ Pump Liner & Stroke Lengths 5.5x12 in �' Sample Quality El Go od El Fair ci P oor Pump Pres 64 psi ,x >. -:-_, " 7 ,"mss$ .. .,J; _ ',: .. , .., . r _ .' , .' .,> 0: .. l "` V* t Mud Wt In 9.80 ppg Visc 54 secs API filt 6.8 ml HTHP n/a ml Mud Wt at Max Gas ppg Mud Wt Out 9.70 ppg PV 11 cP YP 24 Ibs /100ft2 Gels 10 \ 13 \ 14 MBT 0.3 pH 9.5 Sd f r u . "el* is a e. •u aso '1.ni. t _,.,. _' 9 ,t .._,_.. -z...; .�. . . .. .,- at` , =' fi Bit No.: 7 Type: Tricone Bit Size: 5 7/8" Jets: 3 x 5 / x / TFA: 0.5180 t` !fit, Wt On Bit: 15-20 RPM: 30 Hrs. On Bit: 11.4 Total Revs on Bit: 48k Footage for Bit Run 473 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm � ' Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: p Tight Spots: to to to Feet of Fill on Bottom: ft e w� - � .g - ,. . k . . _A ._ .. ,u _ . , ,. , 4 ; iPA Lithology ( %) Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Lmstn Dol C h rt i Connection Gas and Mud Cut (BG = Background) kil ft units BG units PP9 ft units BG units ppg ': ri ft units BG units ppg ft units BG units ppg il ft units BG units PP9 1 ft units BG units ppg ft units BG units PP9 ft units BG units ppg 1 * `< . � - . re o., „ ,'.fv:. -- .. ". L _” i a - ;Apr- .; l. , -�- . 3' ' . . ? ,: . .0 '1-, -. a„ r' .: ., &rIft` e l ; GAS PEAKS (Background Gas Samples Shaded Gray) OK Depth Gas in units Gas C hromatograph 1 Max Background C1 C2 C3 C4 Total C5 Total to n to :' ; l to 1 to 3 to I to ,i r: § U : a 441MM ° . ' 14 . ,gym • . 'ji POOH wet from 13,792 to 12,074' UD X/O sub install 4.5" airslips and cont to POOH wet 2,995'. UD 4.5 DP and POOH to 430 and UD BHA. Test BOP s'. I and P/U bridge plug BHA and RIH to 1,172' at the time of report. ,i1 li 1 ki G & I Magnets: xx lbs Rig Magnets: xx Ibs Total Metal cuttings: xx Ibs ***Costs Are Carried Up to April 19, 2009*** Logging Engineers: Dennis Lee / Daniel Sherwood ** 10000 units = 100% Gas In Air IIMI NM MB M l i M r- MO E w A■■ - ■M r ME - M '''' ' Northstar NS33A LOCATION: North Star Is. HALLIBURTON Sperry Drilling BP Exploration (Alaska) AREA: NothSlope Nabors 33 E STATE: Alaska BIT RECORD BHA Bit Bit Bit Depth Depth Footage Bit TFA AVG WOB RPM PUMP PUMP Bit Grade Remarks # Type Size IN OUT Hours ROP Press GPM 5 2 HUGHES MX -1X 10.63 16060 17037 977 24.50 0.942 39.9 39.5 84 1751 663 3- 1- WT- M- E -1 -NO -BHA POOH to change to Rotary Steerable 6 3 Hycalog RTX616M -A5 10.63 17037 24152 7114 63.11 0.778 112.7 22.6 133 2472 678 1 -0- CT- C- X- 1- NO -DSF TD 10 5/8" Section 3 4 Security QHC1S 7.88 24152 24181 29 2.68 1.325 10.8 5 -10 80 -120 2020 750 0 -0- ER- A- E -I -NO -BHA POOH to change to Rotary Steerable 4 5 Hycalog RSX516M 7.88 24181 25612 1431 58.90 0.685 24.3 20-30 120 -135 3400 450 -550 1- 0- CT- N- X- 1 -NO -TD TD 7 7/8" (w/ 9" Reamer) Section 5 6 Flat Bottom Milltooth 5.87 25612 25616 4 0.30 0.860 44.0 5 70-80 2430 495 1 -0- CT- N- X- 1 -NO -TD Milled liner top and drilled 5' 6 7 MXR18HDX 5.87 25616 26090 474 10.70 0.520 54.8 13 70-80 2186 237 3- 4- WT- A- E- 1 -LT -D Drilled to Well TD 7 8 9 10 11 all MN MI MI i i all MI MI Ili - MN MN ! MI ! • Page 1 of 2 HALLIBU TON 1 Sperry Qrilling Company: BP Alaska Exploration Area North Slope, Alaska Casing Record Well BP Alaska NS33A Job No: AK -AM- 0006479766 11.725" from surface to 15037' MD Rig Nabors 33E Spud Date 1/25/2009 8.625" from 14241' to 23540' MD Water -based Mud Record Mud Co Mi Swaco TD Date: ii Date Depth Wt Vis - YP Gels Filt R600 /R300 Cake Solid- Water Sd pH DTI HTHP Chlor Hard Remarks ft - MD ppg sec lb/100 Ib /100ft` nn/30m 32nds % % % cc/30min kmg /I Ca ++ 9 -Feb 15596 9.20 48 8 23 9/13/15 4.6 39/31 © 5.0 90 0.01 0.3 9.1 ® 0 20 140 Drilling ahead 10 -Feb 16525 9.20 48 8 25 10/12/15 4.2 41/33 © 5.0 90 0.30 0.1 9.1 3.8 0 20 142 Drilling ahead 11 -Feb 17038 9.20 49 9 25 11/15/17 3.8 43/34 © 5.0 89 0.30 0.3 9.1 MI 0 20 120 POOH 12 -Feb 17038 9.20 48 8 21 9/12/14 3.8 37/29 © 6.0 89 0.30 0.2 9 MI 0 20 120 Test BOP's 13 -Feb 17038 9.20 46 8 24 10/12/14 3.8 40/32 © 6.0 89 0.30 0.2 9.1 0 0 20 120 RIH 14 -Feb 17104 9.20 49 8 25 10/13/16 4.4 41/33 © 6.0 89 0.20 0.2 9.1 mg 0 20 120 Drillin. ahead 15 -Feb 18912 9.40 46 8 28 10/14/17 4.0 44/36 Q® 88 0.20 0.2 8.9 ® 0 18 100 Drillin. ahead 16 -Feb 20049 9.50 m 8 27 9/11/15 5.0 42/34 0 8.0 87 0.10 0.3 9.1 ® 0 18 100 Drillin. ahead 17 -Feb 20049 9.40 mm 22 10/11/14 5.0 36/29 0 8.0 87 0.10 0.2 9 ® 0 18 100 Short Tri• to add •i•e 18 -Feb 20391 9.40 48 8 24 9/12/16 4.4 40/32 0 9.0 86 0.10 0.5 9.5 m 0 18 N/A Drillin. ahead ' 19 -Feb 22158 9.40 ® 9 30 13/17/19 4.4 48/39 0 8.4 87 0.10 0.1 8.7 to 0 18 - Drillin. ahead 20 -Feb 23468 10.50 ® 16 30 11/16/19 2.4 62/46 0 11.8 83 0.00 0.1 8.8 8 7.6 16 Drillin. ahead 4 21 -Feb 24151 11.00 50 m 31 11/13/16 2.4 65/48 0 13.0 82 0.00 0.1 9 9.5 6.2 11 - Backreamin. out 22 -Feb 24151 11.00 mm 27 9/11/14 2.4 55/41 0NEM 81 - 0.0 9.1 ® 6.6 13 280 Backreamin• out 23 -Feb ME - M.1111111 - 24 Feb 24151 11.00 mm 32 11/12/15 2.6 60/46 0 15.0 80 - 0.1 9 16 6.8 13 300 La Down 5" DP 25 -Feb 24151 11.00 mm 28 10/12/15 2.6 54/41 0 15.0 80 - 0.0 8.8 16 6.8 13 300 Run 8 5/8" Liner 26 -Feb 24151 11.00 m® 28 10/13/15 2.5 52/40 0 15.0 80 - 0.1 9.2 16 6.8 13 300 Run 8 5/8" Liner 27 -Feb 24151 11.00 m® 27 10/13/15 2.6 53/40 Q 15.0 80 - 0.0 8.9 16 6.8 13 300 Run 8 5/8" Liner 28 -Feb 24151 11.00 48 ® 29 9/10/11 2.7 53/41 ©® 80 - 0.0 8.9 ® 7.0 13 280 Conditionin• Mud 1 -Mar 24151 11.00 mm 27 9/10/11 2.7 51/39 ©® 80 - 0.1 9.2 ® 7.0 13 280 Run 8 5/8" Liner 2 -Mar 24151 11.00 49 ® 29 9/10/10 2.7 59/44 MERE]] 80 - 0.1 8.9 16 7.4 13 280 Run 8 5/8" Liner 3 -Mar 24151 11.00 mm 31 8/10/11 2.4 59/45 Q® 80 - 0.3 9.3 ® 7.2 14 300 Run 8 5/8" Liner tri 4 -Mar 24151 11.00 50 ® 3 0 8/10/11 2.8 56/43 0 15.0 80 - 0.4 9.2 ® 7.8 14 280 Run 8 5/8" Liner 5 -Mar 24151 11.00 ®m 28 10/11/12 2.8 56/42 0 15.0 80 - 0.4 9.2 ® 7.8 14 280 Run 8 5/8" Liner 6 -Mar 24151 11.00 50 ® 30 10/11/12 2.8 56/43 0 15.0 80 - 0.3 9 ® 7.8 14 280 Circulate Bottom's U. 7 -Mar 24151 11.00 m® 30 10/11/11 2.8 56/43 0 15.0 80 - 0.3 9 ® 7.8 14 300 BOPS Test 8 -Mar 24151 11.00 ®® 29 9/11/12 2.8 55/42 0 15.0 80 - 0.2 8.9 ® 7.8 14 300 Run Clean -Out Assembl 9 -Mar 24151 11.00 50 m 26 9/11/13 2.8 54/40 0 15.0 80 - 0.3 8.8 ® 7.8 14 300 Test Casin• 10 -Mar 24151 11.00 m® 23 9/10/12 3.0 47/35 0EE0 81 - 0.2 9.2 ® 8.0 12 260 Wei. ht U. Mud 11 -Mar 24151 12.30 58 19 26 8/14/19 4.6 64/45 © 20.0 76 - 0.0 8.5 ® 8.5 55 600 POOH Clean -Out Assembl 12 -Mar 24151 12.20 mm 35 7/12/15 4.2 65/50 © 18.5 79 - 1.6 9 8 8.6 49 400 Run Clean -Out Assembl 13 -Mar 24151 12.00 46 16 29 8/11/14 4.0 61/45 © 19.0 79 - 0.8 8.9 8 9.6 48 360 Conditionin• Mud 14 -Mar 24151 11.90 mm 34 9/13/17 3.9 62/48 ® 18.5 80 - 0.3 8.7 8 9.9 48 376 Conditionin• Mud 15 -Mar 24181 12.00 46 ® 30 9/14/16 3.7 60/45 © 18.0 80 - 0.1 8.7 8 11.1 47 320 Circulatin• Mud 16 -Mar 24181 12.10 mm 35 8/13/16 3.8 63/49 © 18.0 80 - 0.1 9 8 10.7 336 Circulatin. Mud i 17 -Mar 24181 12.00 mm 33 8/14/15 3.7 61/47 © 18.5 80 - 0.2 8.9 6 9.8 46 300 Performin• Hesitation S•ueeze 18 -Mar 24181 12.10 m® 30 9/12/14 3.7 54/42 ® 18.0 80 - 0.1 8.9 8 10.7 46 260 Washin./Reamin. to Bottom 19 -Mar 24181 12.00 mm 29 8/12/14 3.9 57/43 © 18.2 80 - 0.3 9.2 8 10.8 41 180 Circulatin. on Bottom 20 -Mar 24181 12.00 mm 28 9/11/13 3.4 56/42 0 18.0 80 - 0.3 9.2 8 9.2 37 140 Tri • Out while Pum • in 21 -Mar 24181 12.00 50 in 30 9/11/14 3.4 58/44 0 18.0 80 - 0.3 9.5 8 9.8 38 200 La in• Down BHA 22 -Mar 24181 12.00 m® 26 9/11/13 3.4 52/39 Q® 81 - 0.7 9.7 ® 9.8 36 320 Pickin. U. BHA 23 -Mar 24181 12.00 m® 28 10/11/13 3.7 54/41 0 16.5 83 - 0.5 9.5 8 10.8 36 300 Circulate & Condition Mud i s NM M MB ■■11 r N N MI - MI - E- SS NM r MN 1 1'd , -_ ,. . ,' , Page 2 of 2 HALLIBURTON 1 Sperryprlling Company: BP Exploration (Alaska) Area North Slope, Alaska Casing Record Well BP Alaska NS33A Job No: AK- AM- 0006479766 11.725" from surface to 15037' MD Rig Nabors 33E Spud Date 1/25/2009 8.625" from 14241' to 23540' MD Water -based Mud Record Mud Co Mi Swaco TD Date: 4/16/09 6 5/8" liner 25,578' MD Date Depth Wt Vis VW YP Gels Filt R600 /R300 Cake Solid Water Sd I • HTHP Chlor Hard Remarks ft - MD ppg sec lb/100 Ib /100ft` m /30m 32nds % % % c c /30min kmg /I Ca ++ 24 -Mar 24181 12.00 78 ® 29 11/14/16 3.4 55/42 0 17.8 81 - 0.4 9.3 8 10.0 36 280 Washin. /Reamin• to Bottom 25 -Mar 24181 12.00 46 m 32 8/11/14 4.0 54/43 0 18.0 80 - 0.1 9.3 ® 10.6 38 200 Circulate & Condition Mud 26 -Mar 24396 12.50 m® 34 10/14/16 3.8 64/49 0 19.2 80 - 0.1 9.1 ® 10.4 39 120 Drillin. 9" Hole 27 -Mar 24808 12.50 m 16 36 10/15/17 3.8 68/52 © 20.0 79 - 0.1 9.2 9 10.2 43 104 Drillin. 9" Hole 28 -Mar 25319 12.50 46 19 35 9/15/17 3.9 73/54 © 20.5 79 - 0.5 9.3 ® 10.2 43 70 Drillin. 9" Hole 29 -Mar 25612 12.50 48 18 32 11/19/24 4.5 68/50 © 20.5 79 - 0.5 9.2 8 10.9 40 60 Pum. Out Of Hole 30 -Mar 25612 12.50 46 ® 29 9/15/19 4.8 71/50 © 18.0 81 - 0.6 9.3 ® 11.2 36 40 Pum. Out Of Hole 31 -Mar 25612 12.50 m 20 31 9/12/16 4.9 71/51 © 18.5 81 - 0.5 9.4 m 11.4 38 20 Tri. Out of Hole 1 - 25612 12.50 m 20 36 9/13/15 5.0 76/56 © 18.5 81 - 0.4 9.1 ® 11.4 38 20 jaeura dm. n•uwt•mW 2 -A.r 25612 12.50 m® 31 10/15/16 5.0 73/52 © 18.5 81 - 0.4 9.1 ® 11.4 38 20 Run 6 5/8" Liner 3 -A•r 25612 12.50 m 19 33 9/13/17 5.0 71/52 © 18.5 81 - 0.4 9 ® 11.4 38 20 Run 6 5/8" Liner 4 -A.r 25612 12.50 46 ® 31 9/16/18 5.0 73/52 © 20.0 81 - 0.4 8.9 ® 11.6 38 20 Run 6 5/8" Liner 5 -A• r 25612 12.50 46 m 28 8/13/16 5.6 62/45 © 20.0 81 - 0.4 9.4 ® 11.7 40 20 Run 6 5/8" Liner 6 -A.r 25612 12.50 mm 26 7/12/15 5.6 60/43 © 20.0 81 - 0.5 9.5 8 11.8 40 12 Run 6 5/8" Liner 7 -A•r 25612 12.50 mm 28 8/13/15 5.6 62/45 © 20.0 81 - 0.4 9.4 ® 11.8 40 12 POOH 8-Air 25612 12.50 46 m 29 8/112/15 5.6 63/46 Q 20.0 80 - 0.4 9.4 ® 11.8 40 12 Testin. BOP's 9 -A.r 25612 12.10 m 18 24 8/11/14 5.6 60/42 © 19.5 80 - 0.4 9.3 Mill 11.8 40 12 C/O Run 10 -A•r 25612 12.30 m 19 23 9/11/14 5.8 61/42 © 19.2 80 - 0.4 9.2 MI 12.0 40 12 C/O Run 11 -A.r 25612 9.70 48 m 25 11/16/19 7.5 47/36 1 /N /A 6.0 94 - 0.3 9.7 MD n/a 14 8 Circulate & Condition Mud 12 -A•r 25616 9.70 49 m 25 10/15/19 7.4 47/36 1 /N /A 6.0 94 - 0.3 9.5 IIIEI n/a 14 10 Pum• Out of Hole 13 - 25616 9.70 49 m 24 10/13/16 7.2 46/35 1 /N /A 8.5 92 - 0.1 9.3 © n/a 17 40 Pum. Out of Hole; USIT Lo.- Wireline 14-Air 25616 9.70 49 m 25 10/13/16 7.2 47/36 1 /N /A 8.5 96 - 0.1 9.2 ® n/a 17 40 Runnin. USIT LOG 15 -A.r 25616 9.70 m® 24 11/13/14 6.8 48/36 1 /N /A 12.0 92 - 0.3 9.5 0 n/a 13.5 40 RIH 16 -A.r 26090 9.70 59 m 27 12/13/15 5.4 55/41 1 /N /A® 87 - ® 9.5 0.3 n/a 14 60 Drill from 25616 -26090 17-Air 26090 9.70 58 ® 23 10/13/15 5.6 49/36 1 /N /A ® 87 - ® 9.4 0.3 n/a 14 60 Lo. w /Schlumber.er tools, POOH 18-Air 26090 9.70 m® 25 13/14/15 5.8 51/38 1 /N /A ® 87 - ® 9.5 0.3 n/a 14.2 60 Circulate & Condition Mud & POOH ,,,::, 19 -A. r 26090 9.80 mm 24 10/13/14 6.8 46/35 1 /N /A ® 87 - ® 9.5 0 n/a 13.5 80 POOH, L/D Drillin. Assy, Test BOP's, RIH MEM MEM MEM MIN MIME IIMMIE EIMMIE .11.111M=11 IIMIIIM MIIMIIIM IMIIIMME 0; MEM MEM 111.1 1 M= 111111111 1=111= 11=11111. MilliMIM L....._...,..„, 1 HALLIBURTON Well Name: NS33A Depth (MD) 23650 to 23734 if ' IIIIIII Location: Northstar, Alaska (TVD) to ft 11111:1 I op Show Report Operator: BP Alaska Show Report No. 1 1111111 Report Prepared By M. Lind loff Date/Time: 14-Mar-09 .11111:: Report Delivered To: Jerry Siok I .. ' .................. "- —...... „. " "" -- - ---- •••••••• -------- I !!!!!!!! Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. !!!!!!!! SST: Dark brown to brown, very fine grain grading to siltstone, moderately well sorted, subangular-subrounded, transparent-opaq quartz !!!1!!!1 grains, unconsolidated, loose ip, calcarious, traces of pyrite and glaucanite, any fluoresence masked by mud additive Steel Lube EP I ! ! ! ! ! ! ! ! Ratios show light gas to non-producible hydrocarbons. ::::: .............. , , . . ........ ...:...,.................................... . , ....,.................. „ ,,,,,,,.......... . .............................. . , ... .: : , „.....„...„„„„„:::: „„,„„„....,„!:!y! 11111111 . 1 _% Hydrocarbon Ratios Depth 23650 ft Gas x Units 156 Mud Chlorides (1000's) C1 01 01 01 'i11 I HO Flowline Background Show C2 03 04 C5 11111:1 :e PPm ppm ppm di4 Hydrocarbon Ratios 1000 U1111 01 16285 - = 16285 01/02 = 31 it 11111111 02 528 - = 528 C1/C3 = 94 I 11111111 03 174 - = 174 C1/C4 = 276 11111 04 59 = 59 C1/C5 = 857 NPH 1 • 05 19 - = 19 Production ,i,,,i;, Analysis nGas nOil nWater FINon-Producible Hydrocarbons 100 .... _ ...---- '''' .... .. _% 1:1]... Depth 23658 ft Gas x Units 359 Mud Chlorides (1000's) G I Flowline Background Show ------- - PPm ppm ppm ------ Hydrocarbon Ratios 10 ...... ;.,... i ON 01 39614 - = 39614 01/02 = 24 11111: 02 1621 - = 1621 01/03 = 74 11111111 C3 533 - = 533 01/04 = 243 0 11111111 04 163 - = 163 C1/C5 = 808 I 11111111 05 49 - 49 NPH ::111 11111111 Production 1 1111111 Analysis nGas nod nWater p Non-Producible Hydrocarbons 1111111131 _ % Hydrocarbon Ratios 111111 I 11111111 Depth 23715 ft Gas _Units 360 Mud Chlorides (1000's) 01 01 01 01 I:illi IMF Flowline Background Show C2 C3 04 05 11 PPm ppm PPm gl Hydrocarbon Ratios 1000.0 ,..1 • 11000 01 40658 - = 40658 C1/C2 = 26 11111111 02 1574 - = 1574 01/03 = 82 11! C3 496 - = 496 C1/C4 = 295 NPH , 111! ca 138 - = 138 C1/C5 = 924 ... .,, 1 1111111: C5 44 - = 44 ,.... ''' .., ,,, Production 100.0 - -----"' 111110 Analysis nGas nOil nWater n _ -- I Depth 23734 ft Gas x Units 378 Mud Chlorides (1000's) . Gas 11111111 Flowline Background Show ,.. _ ......— — -------- PPm PPm PPm Hydrocarbon Ratios 10.0 I C1 42411 - = 42411 C1/02 = 26 :1T:: 02 1663 - = 1663 C1/C3 = 77 Oil 11111111 03 552 - = 552 01/04 = 251 „. ,..... .,..,. I 111111!1 04 169 - = 169 01/05 = 848 NPH 0111 C5 50 - = 50 Ail Production 1.0 _ 1.111111 Analysis nGas nod nWater [Non-Producible Hydrocarbons „ I ' ....................... 1 1 ....m.;.... .m ?iiiiiiiiii :r k iiiiiiiiiii i ".i: . :.,. :i.` ' : ,,. ..,.,,s:iiiiiiTiiiiiiii,,,, yii iiyii'! ,. "'.. z,,,i` "iiiiS.iiiiiiiiii� iiiiiiiiii �'' :':`i�.:.:ii:: ,,,....,,, ii •• HALLIBURTON ' Well Name: NS33A Depth (MD) 23832 to 23902 ft ,:.: Location: Northstar, Alaska (TVD) to 8 I in Show Report Operator: BP Alaska Show Report No 2 IIIIIII Report Prepared By: M. Lindloff Date/Time: 14- Mar -09 Report Delivered To: Jerry Siok I illli 11 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. SST: Dark brown to brown, very fine -fine grain, medium grains ip, moderately well sorted, subangular subrounded, transparent -opaq quartz. lipllii grains, unconsolidated, loose ip, calcarious, traces of pyrite and glaucanite, any fluoresence masked by mud additive Steel Lube EP I Sample anylis indicates a possiple gas zone. 11 °' Hydrocarbon Ratios Depth 23832 ft Gas Units 319 Mud Chlorides (1000's) 01 01 01 C1 I 1111 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 - - 01 31519 - = 31519 C1/02 = 24 I C2 1322 _ = 1322 01/03 = 67 C3 467 467 C1 /C4 = 214 = = C4 147 147 C1 /C5 700 NPH iiiiiii C5 45 - = 45 Production 100 - �- - 2 ( Analysis nGas nOil nWater [Non- Producible Hydrocarbons - - . kli Depth 23850 ft Gas �x Units 362 Mud Chlorides (1000's) G Flowline Background Show PPm PPm PPm -------------- - 1 , Hydrocarbon Ratios 10 Iiill 01 36362 - = 36362 C1/02 = 22 pilill C2 1617 - = 1617 C1/03 = 62 1 11111111 C3 586 - = 586 01/04 = 203 OiI "ii (iii C4 179 - = 179 C1/05 = 649 — `'> C5 56 = 56 NPH NH 1 Production 1 Analysis nGas nOil nWater [Non- Producible Hydrocarbons 0 i° Hydrocarbon Ratios I Depth 23861 ft Gas _ Units 350 Mud Chlorides (1000's) 01 01 01 01 IVO Flowline Background Show C2 C3 C4 C5 PPm PPm PPm Hydrocarbon Ratios 1000.0 I Ilit C1 35151 - = 35151 C1 /C2 = 22 C2 1574 1574 C1 /C3 = 72 • 11 C3 490 - = 490 C1 /C4 = 300 NPH C4 117 - = 117 C1 /C5 = 1302 C5 27 = 27 _ _ Production 100.0 _ _ Analysis [Gas Oil nWater [Non- Producible Hydrocarbons - Hu T Depth 23902 ft Gas x Units 674 Mud Chlorides (1000's) Gas ___, 1111111 iiii Flowline Background Show _ _ _ _ _ _ - ppm PPm PPm -------- - - - Hydrocarbon Ratios 10.0 I 11111111 01 59122 - = 59122 01/02 = 19 C2 3190 3190 C1/03 = 45 OiI C3 1310 - = 1310 01/04 = 165 I 11:11111 C4 358 - = 358 C1/05 = 537 C5 110 110 NPH • Production 00011 1.0 Analysis ni Gas nn Oil nWater [Non- Producible Hydrocarbons 1 1 li NO HALLIBURTON Well Name: NS33A Depth (MD) 23902 to 23930 ft 1111: Location: Northstar, Alaska (TVD) to ft i ' Show Report Operator: BP Alaska Show Report No 3 Report Prepared By M. Lindloff Date/Time: 14- Mar -09 Report Delivered To: Jerry Siok I 11111111 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. SST: Dark brown to brown, very fine -fine grain, medium grains ip, moderately well sorted, subangular - subrounded, transparent -opaq quartz. grains, unconsolidated, loose ip, calcarious, traces of pyrite and glaucanite, any fluoresence masked by mud additive Steel Lube EP I 11111111 Sample analysis indicates a possible gas zone. J % Hydrocarbon Ratios ou Depth 23907 ft Gas NUnits 674 Mud Chlorides (1000's) C1 C1 C1 C1 I In Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 01 66127 - = 66127 01/C2 = 19 I 11111111 C2 3486 - = 3486 01/C3 = 47 C3 1419 - = 1419 C1 /C4 = 174 C4 379 - = 379 C1 /C5 = 551 NP r C5 120 - = 120 - - - • 1111 I 11111111 Production 100 ...... _ - Analysis nGas noil nWater [xi Non-Producible Hydrocarbons 2J % - I !III Depth 23911 ft Gas N Units 510 Mud Chlorides (1000's) Ga Flowline Background Show ::::::: - - - PPm PPm PPm --------- ..i Hydrocarbon Ratios 10 I 11114 01 54096 - = 54096 01/02 = 19 C2 2843 - = 2843 C1/03 = 47 C3 1156 - = 1156 C1/04 = 160 0 C4 338 - = 338 01/05 = 530 - C5 102 - = 102 NP Production 1 Analysis G W r x N n -Pr i t Hydrocarbons y n as n it n ate n o oduc b e 21 % Hydrocarbon Ratios Depth 23923 ft Gas HUnits 257 Mud Chlorides (1000's) 01 01 01 01 I Flowline Background Show . C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios I 01 25985 25985 1000.0 = C1 /C2 = 19 — 02 1381 - = 1381 C1/03 = 44 C3 597 - = 597 C1/04 = 141 NPH C4 184 - = 184 C1 /05 = 394 1 .... C5 66 = 66 .- _. - Production 100.0 Analysis nGas nOil nWater nNon- Producible Hydrocarbons .. - -- - _ - 1 Depth 23929 ft Gas liU 204 Mud Chlorides (1000's) Gas Flowline Background Show - - - - - PPm PPm PPm - - - Hydrocarbon Ratios 10.0 01 20680 20680 01 /02 = 19 C2 1113 1113 C1/03 = 42 oil C3 492 - = 492 01/C4 = 131 1 11111111 04 158 - = 158 01/05 = 363 EN 05 57 57 NPH ii • Production 1.0 - ' 11111111 "t Analysis ni Gas DOH nWater nNon - Producible Hydrocarbons 1 1 1 giv sperry-sun Well Name: NS33A Depth (MD) 25587 to 25594 ft NIM Location: Northstar, Alaska (TVD) 10906 to 10913 ft 1 1 Hil DRILLING SERVICES Operator: BP Alaska Show Report No 3 111111: 1 :11111:1 Show Report Report Prepared By D. Kane/ M. Lindloff Date/Time: 29-Mar-09 'MI ..,.. Report Delivered To Jerry Siok 1 ,!,!,„ Interpretation: Chromatograph gas in air analysis from gas trap at possum belly [Medium Gain setting on Chromatograph] !!!!!!!! SH : brn-dk brn, gy-dk gy, pity, thn ang ctgs, fm-hd, brit, n calc. SST : clr-opq, brn, f-m gr, tr crs, sub ang - sub rnd, mod srt, Ise, tr glauc. !!!!!!!! Gas analysis as well as well as wetness & balance ratios suggest a producible gas with possible NGLs. Extended runs on the I ! I :: ! ! ! !: 1 chromatograph (3x Normal Run Time) showed presence of C6-C8 pairs (Normal & !so) at unknown concentrations. NO1111 °A Hydrocarbon Ratios nu Depth 25590 ft Gas Units 127 Mud Chlorides (1000's) : 43 C1 C1 C1 C1 I :::::::: Flowline Background Show P C2 C3 C4 C5 Pm ppm ppm Hydrocarbon Ratios 1000 - 111 C1 8376 - 2574 = 5802 C1/02 = 9 I D11111. C2 881 - 234 = 647 01/03 = 18 1011 C3 536 - 206 = 330 C1/C4 = 51 Ell C4 277 - 164 = 113 01/05 = 132 NPH V111111 C5 150 - 106 = 44 .- ■• '''' ..' . I 11111111 Production 100 - - ....... "" --- 11111111 Analysis FIGas soil nWater nNon-Producible Hydrocarbons .., -- Hydrocarbons ___ _____ iIIIII.:1 °A 1 !! 1!1! Depth 25591 ft Gas HUnits 142 Mud Chlorides (1000's) 43 Gas Flowline Background Show - - - - - - - - - - - PPm PPm PPm - Hydrocarbon Ratios 10 I pq 01 9318 - 2574 = 6744 C1/02 = 9 11111111 02 971 - 234 = 737 01/03 = 17 lillilii 03 592 - 206 = 386 01/04 = 49 ON 111!! 04 302 - 164 = 138 C1/C5 = 123 • 1 1„„ 05 161 - 106 = 55 NPH 111 Production 1 Ili] Analysis FIGas nOil nWater nNon-Producible Hydrocarbons MI _3_1 % Hydrocarbon Ratios I 11111111 Depth 25592 ft Gas x Units 146 Mud Chlorides (1000's) . 43 C1 01 01 C1 Flowline Background Show C2 C3 04 C5 ppm ppm ppm Hydrocarbon Ratios 1000.0 ■ 01 9816 - 2574 = 7242 01/02 = 9 I 02 1024 - 234 = 790 01/03 = 17 • • 03 629 - 206 = 423 C1/04 = 46 NPH I:111111 04 322 - 164 = 158 01/05 = 111 , 1 171 - 106 = 65 II 100.0 ___..-- -- .------• ... --. - NIII Production _ __ filiN Analysis 171( Gas nu' nWater n Non-Producible Hydrocarbons .., •-• - Show - - - 4 —1 % III Depth 25594 ft Gas x Units 128 Mud Chlorides (1000's) , 43 Gas _ - Flowline BackgrourTd ..... -- ppm ppm ppm _ - - - I Hydrocarbon Ratios 10.0 NN 01 8125 - 2574 = 5551 01/02 = 9 HU 02 869 - 234 = 635 C1/C3 = 16 Oil 11111111 03 544 - 206 = 338 01/04 = 47 I 11111111 04 281 - 164 = 117 01/05 = 132 III 05 148 - 106 = 42 NPH Hill Production 1.0 Analysis [Gas ROil [ nNon-Producible Hydrocarbons . 1 1 i's;!ii: '� ii i iiiiki !� i; ziiiiisiiiiiiiiiiiisiiiiii iiiiii ieli� ;;� i 1 i � i;i •�� II Well Name: NS33A Depth (MD) 25616 to 25640 ft laill Location: Northstar, Alaska (TVD) 10928 to 10950 ft Show Report Operator: BP Alaska Show Report No. 1 Report Prepared By D. Lee/ D. Sherman Date/Time: 16- Apr -09 Report Delivered To Jerry Siok ...............:....... ............................... 1 111111 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly [Medium Gain setting on Chromatograph] SST : clr -opq, brn, f -m gr, tr crs, sub ang - sub rnd, mod srt, Ise, tr glauc. Hydrocarbon ratio analysis indicates gas show, with steep incline of plotted ratios implying a "tight" formation. ii> 1111111_11 _ ° i Hydrocarbon Ratios lit iiiiiiii Depth 25626 ft Gas x Units 28 Mud Chlorides (1000's) 01 01 01 01 I Flowline Background Show C2 C3 C4 C5 iliwil MIN ppm ppm ppm Hydrocarbon Ratios 1000 01 2541 0 = 2541 C1 /C2 = 15 I ill r C2 172 - 0 = 172 C1 /C3 = 40 ;;;! C3 63 0 = 63 C1 /C4 = 121 C4 21 - 0 = 21 01/05 = 2541 NPH III i 11111111 C5 1 - 0 = 1 � �� ' oiDi Production 100 2 ( - - - -- _ „, .0---- [ Analysis [Gas nOil nWater n Non- Producible Hydrocarbons Depth 25630 ft Gas Units 45 Mud Chlorides (1000's) Gas El Flowline Background Show - - - - - _ ----- - ppm ppm ppm --- ! iiii Hydrocarbon Ratios 10 01 3993 0 = 3993 01/02 = 15 02 273 0 = 273 01/03 = 40 C3 100 - 0 = 100 01/04 = 114 Oil iiiiiiii C4 35 - 0 = 35 C1/05 = 363 — • C5 1 ION 11 - 0 = 11 NPH „ : Production `ii i . Analysis [Gas nOil nWater nNon- Producible Hydrocarbons 1111111131 % Hydrocarbon Ratios I Depth 25640 ft Gas Units 22 Mud Chlorides (1000's) 01 01 C1 C1 °° Flowline Background Show ' 02 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000.0 01 1974 - 0 = 1974 01/02 = 15 iii C2 133 - 0 = 133 01/03 = 39 11111111 C3 50 - 0 = 50 01/04 = 110 NPH C4 18 - 0 = 18 C1/05 = 1974 05 1 0 = 1 Production 100.0 n -Pr ible Hydrocarbons W r No oduc Analysis x Gas nail ate - Y n n n n QI I NI ii J N % / Depth 25650 ft Gas Lx Units 25 Mud Chlorides (1000's) Gas Flowline Background Show ----- ppm ppm ppm -- Hydrocarbon Ratios 10.0 I 111 01 2115 - 0 = 2115 C1/02 = 14 11111111 C2 147 0 = 147 C1/03 = 37 Oil C3 57 - 0 = 57 01/04 = 101 i I C4 21 - 0 = 21 01/05 = 2115 C5 1 0 = 1 NPH • L'' Production 1.0 Analysis © Gas I Oil II Water II Non - Producible Hydrocarbons 1 1 ::..:.:..... . .........................:::. .... . . . . . . . . . . . . . . . :: .: . M . ... . . . . . . . 25660 25690 ft a '. 1 Well Name: NS33A Depth (MD) to 1 Location: Northstar, Alaska (TVD) 10968 to 10994 ft gl I 'h Show Report Operator: BP Alaska Show Report No 2 Mill Report Prepared By D. Lee/ D. Sherwood Date/Time: 16- Apr -09 ii'11 t�'ji�l Report Delivered To Jerry Siok lii':, 111 ON Interpretation: Chromatograph gas in air analysis from gas trap at possum belly [Medium Gain setting on Chromatograph] SST : clr -o brn f -m r tr crs sub an - sub rnd, mod srt, Ise, tr lauc. I V111:11 P4: 9 : 9 9 Hydrocarbon ratio analysis indicates gas show, with steep incline of plotted ratios implying a "tight" formation. — Hydrocarbon Ratios Hydrocarbon Depth 25660 ft Gas x Units 24 Mud Chlorides (1000's) 0 01 01 01 01 I Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 01 2064 - 0 = 2064 C1/02 = 15 I 02 142 - 0 = 142 C1 /C3 = 38 C3 54 0 = 54 C1 /C4 = 103 C4 20 - 0 = 20 01/05 = 2064 NPH 10 C5 1 - 0 = 1 ..... I IN Production 100 - - ..- Analysis {Gas nOil nWater nNon- Producible Hydrocarbons - - - 1111111121 HUnits % 1 I Depth 25670 ft Gas 19 Mud Chlorides (1000's) 0 Gas - - - - - - - - Flowline Background Show PPm PPm PPm Hydrocarbon Ratios 10 01 1617 - 0 = 1617 01/02 = 14 I C2 114 - 0 = 114 C1/03 = 38 C3 43 - 0 = 43 C1/04 = 101 ON Ell C4 16 - 0 = 16 C1/05 = 1617 - - • C5 1 - 0 = 1 NP 1 Production Op Analysis { Gas nOil nWater nNon- Producible Hydrocarbons 11111111 % Hydrocarbon Ratios I - Depth 25680 ft Gas x Units 17 Mud Chlorides (1000's) 0 C1 C1 01 C1 Illaiii Flowline Background Show C2 C3 C4 C5 Irip ppm ppm ppm Hydrocarbon Ratios 1000.0 ll I III 01 1426 - 0 = 1426 01/02 = 14 ' C2 104 - 0 = 104 01/03 = 41 C3 35 - 0 = 35 C1/04 = 110 NPH C4 13 - 0 = 13 C1 /05 = 1426 1 D111111 C5 1 - 0 = 1 Production 100.0 Analysis {Gas nod nWater nNon- Producible Hydrocarbons - - - - 1 101111 Depth 25690 ft Gas x Units 15 Mud Chlorides (1000's) 0 Gas _ - - - PPm PPm PPm Flowline Background Show --------- - _ _ _ - - - Hydrocarbon Ratios 10.0 01 1315 - 0 = 1315 C1/02 = 13 EV C2 102 - 0 = 102 C1/03 = 42 Oil ' C3 31 - 0 = 31 C1/04 = 120 111 1 C4 11 - 0 = 11 01/05 = 1315 - - - - C5 1 0 = 1 NPH • Production 011 1 ' 0 Analysis © Gas I Oil I Water • Non - Producible Hydrocarbons 1 1 IP Ili ..... .... ...... ....... _::::...............:. ........... ........., ., '. .............. ............... :.................... • Eii�, �iN a€ u5iziiiiiiiiiiz�i�riii1 :'.ii4': » '.` :. :.'.r`'`. .'.."`.'.::::.'::.'. . .. . :::.`:':"".: aaf .: ' . . ....:. ....... �..... .. _ .. , HALLIBURTON Well Name: NS33A Depth (MD) 25790 to 25820 ft i j ' 'ir ` „I 13 Location: Northstar, Alaska (TVD) 11083 to 11110 ft I 1011111 Show Report Operator: BP Alaska Show Report No 3 0 Report Prepared By D. Lee/ D. Sherman Date/Time: 17- Apr -09 Report Delivered To Jerry Siok Interpretation: Chromatograph gas in air analysis from gas trap at possum belly [Medium Gain setting on Chromatograph] SD : Lt br -br, It gy ip, clr, trsl, op, m - f gr, sb rnd - ang, v ang ip, mod srtd, pred qt z , a bdnt carb mat abndt chrt tr slst , tr sh. Hydrocarbon ratio analysis indicates gas show, with steep incline of plotted ratios implying a moderately permeable formation. Hydrocarbon Ratios HIMI Depth 25790 ft Gas Nx Units 87 Mud Chlorides (1000's) C1 C1 C1 C1 I 1111111! Flowline Background Show C2 C3 C4 C5 €, ppm ppm ppm Hydrocarbon Ratios 1000 01 7293 - 0 = 7293 C1 /C2 = 11 II NM: C2 691 - 0 = 691 C1 /C3 = 26 UN C3 280 0 = 280 01/C4 = 76 C4 96 - 0 = 96 C1/05 = 235 NPH C5 31 - 0 = 31 .... I IMO Production 100 ..- — _ ...' N Analysis nGas Oil nWater n Non- Producible Hydrocarbons 121 Hunits —I •-• I Depth 25800 ft Gas 143 Mud Chlorides (1000's) Gas — — — — — — — — — - ppi Flowline Background Show PPm PPm PPm — — — Hydrocarbon Ratios 10 I 111 01 12430 - 0 = 12430 C1 /C2 = 11 C2 1171 0 = 1171 C1/03 = 25 UU C3 507 - 0 = 507 C1 /C4 = 69 Oil UU C4 179 - 0 = 179 C1 /C5 = 218 — 1 C5 57 - 0 = 57 NP i Production 1 Analysis nGas pi Oil nWater n Non- Producible Hydrocarbons ?i j % Hydrocarbon Ratios Depth 25810 ft Gas UUnits 145 Mud Chlorides (1000's) C1 01 01 01 - 11111M Flowline Background Show C2 C3 C4 C5 PPm PPm PPm Hydrocarbon Ratios 1000.0 I 11111111 01 12722 - 0 = 12722 C1/02 = 11 C2 1186 - 0 = 1186 C1/03 = 25 On C3 511 - 0 = 511 C1/04 = 70 NPH C4 181 - 0 = 181 01 /05 = 219 I 111100 C5 58 - 0 = 58 — — — — — — Production 100.0 Analysis nGas 171011 Oil nWater n Non- Producible Hydrocarbons o ,„ _ -- - % k A Depth 25820 ft Gas Units 138 Mud Chlorides (1000's) Gas Flowline Background Show ----- — — ppm ppm ppm — Hydrocarbon Ratios 10,0 UM 01 12040 - 0 = 12040 C1/02 = 11 C2 1107 - 0 = 1107 C1/03 = 26 Oil .., C3 471 - 0 = 471 C1/04 = 72 1 fi, I Ho C4 167 0 167 01 /05 = 223 — — C5 54 0 = 54 NPH • INV Production 1 . 0 pliN Analysis • Gas © Oil • Water • Non - Producible Hydrocarbons 1 1 25830 25860 11. IN HALLIBURTO(V W ell Name: NS33A Depth (MD) to ft Location: Northstar, Alaska (TVD) 11119 to 11145 ft I Show Report Operator: BP Alaska Show Report No 4 Report Prepared By: D. Lee/ D. Sherwood Date/Time: 17- Apr -09 Report Delivered To Jerry Siok 1 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly [Medium Gain setting on Chromatograph] iiiiiiii SD : Lt br -br, It gy ip, clr, trsl, op, m - f gr, sb rnd - ang, v ang ip, mod srtd, pred qtz, abdnt carb mat, abndt chit, tr slst, tr sh. Hydrocarbon ratio analysis indicates gas show, with steep incline of plotted ratios implying a moderately permeable formation. 11111111 1 I _ % Hydrocarbon Ratios nu Depth 25830 ft Gas x Units 123 Mud Chlorides (1000's) 0 01 C1 01 01 I Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 01 10585 - 0 = 10585 C1 /C2 = 11 I C2 968 - 0 = 968 C1/03 = 26 C3 407 - 0 = 407 C1/04 = 74 C4 144 - 0 = 144 01 /05 = 221 NPH z €s C5 48 - 0 = 48 1 Production 100 . -- - . -- �" Analysis nGas moil nWater n Non- Producible Hydrocarbons - Depth 25840 ft Gas Units 97 Mud Chlorides (1000's) 0 Gas I Flowline Background Show _ _ _ - - - _ _ _ _ _ - ppm ppm ppm ----------- _ Hydrocarbon Ratios 10 I 11111111 01 8253 - 0 = 8253 01/02 = 11 C2 756 - 0 = 756 C1/03 = 26 C3 319 - 0 = 319 C1/04 = 72 Od C4 115 - 0 = 115 01/05 = 217 1 11111111 C5 38 - 0 = 38 NPH Production 1 Analysis nGas N Oil nWater nNon- Producible Hydrocarbons 1111111131 LI% Hydrocarbon Ratios I 11111:1 Depth 25850 ft Gas x Units 52 Mud Chlorides (1000's) 0 C1 01 01 01 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000.0 _ I 91 C1 4693 - 0 = 4693 C1/02 = 12 l 'ille C2 406 0 = 406 C1/03 = 29 li , C3 163 - 0 = 163 01/04 = 78 NPH C4 60 - 0 = 60 C1 /05 = 235 1 IN lifil C5 20 0 = 20 x - _. - . Production 100.0 Analysis nGas Oil nWater nNon- Producible Hydrocarbons - - 3 J I MI Depth 25860 ft Gas x Units 60 Mud Chlorides (1000's) 0 Gas - - _ - _ _ Flowline Background Show ------ ppm ppm ppm Hydrocarbon Ratios 10.0 iilliiil 01 5315 0 5315 C1 /C2 = 12 iliiiiii C2 450 0 450 C1/03 = 31 Oil 111 C3 170 - 0 = 170 01/04 = 89 I la C4 60 - 0 = 60 C1/05 = 253 - 1 F la C5 21 0 21 NPH Prod 1 . 0 Analysis liGas MOil Water Non - Producible Hydrocarbons ............ ....:::........::::::::.........:.: :::......................:i[�i� iii �iiiiiiiiiiii�..... .........., is5 :............... �.. . �............................:............:..:..............:..:..................... ........ .um . .............,................. . 1 I Marker MD INC AZ ND TVDSS X Y +1- toPROG Comment CM3 16687.00 77.37 316.47 6963 6907 648574 6039674 17' low Kalubik 23040.00 48.49 304.35 8781 8725 643769 6043229 25 high TKUD 23367.00 39.96 304.60 9014 8958 643578 6043356 not prog ICP (8 518" liner) 23540.00 34.26 306.72 9152 9096 643492 6043414 TKUC 23651.00 33.83 308.30 9244 9188 643442 6043451 not prog LCU 23782.00 33.98 309.50 9353 9297 643384 6043495 not prog TKUB 23828.00 33.83 310.47 9391 9335 643364 6043512 not prog KUP A3 23897.00 33.49 311.71 9448 9392 643334 6043536 not prog Fault 27 23930.00 33.42 311.71 9476 9420 643320 6043548 120' low TMLV 23946.00 33.40 311.63 9489 9433 643314 6043554 27' high M LV1 24060.00 33.36 310.82 9584 9528 643266 6043594 not prog TKNG 24390.00 32.18 310.96 9863 9807 643130 6043706 43' high same mrkr as NS21 TJF 24505.00 31.89 310.28 9960 9904 643082 6043745 not prog TJE 24734.00 30.16 310.87 10156 10100 642991 6043821 20' low TJD 24927.00 29.56 310.80 10323 10267 642916 6043883 133' high based on NS21 TJC 25125.00 28.27 310.19 10496 10440 642842 6043943 10' low TJB 25270.00 27.49 310.19 10624 10569 642789 6043986 9' low TSGR 25574.00 26.70 310.63 10895 10839 642679 6044070 11' high ' ICP (6 518" liner) 25584.00 26.69 310.72 10904 10848 642675 6044072 TSHU 25680.00 26.63 311.28 10990 10934 642642 6044100 not prog TSHD 25786.00 27.66 312.31 11084 11028 642605 6044132 2' high TSAD 25794.00 27.65 312.45 11091 11035 642602 6044134 Even Top Ivishak OWC 25868.00 27.93 315.38 11156 11100 642576 6044157 Proj TD 26090.00 30.44 324.43 11350 11294 642507 6044241 I I I I 1 1 . . . BP Exploration (Alaska) Northstar NS33A 1 Days -vs- U����� �� Chart ~~-�- Depth 1 14000 l j Mill Window, POOH to , — _ . I 15000 mow ---------------- I 17000 '------------ | - i Short Trip to 10,000ft 19000 Pipe Management ���'wo/�n*rvo I oxB�.w�1ouxomo On Bot: 18:5 02/18m9 +—�f-- ~ 02000" --------- --- --------------- ~ Tr I ' Run -- �w-------------- --------- --------- m Hang Liner wx41'Mo (1) L ��Shoe u�*' MD I 22000 -------- -------------------- - rorrw'' Hole wm''reamer �� 2n�1r MD, /1oorr.m'rvo ~~ ' ost circulation a T--. _ _ 24000 TO 10.625" Section k On bottom with 6 508" Liner. Off Bot: 11:58 02021009 I \ Liner packed off and cannot On Bot: 07:39 03115009 Off Bot: 12:16 03115009 I 26000 Final TD v 10 20 30 40 no 60 70 80 90 ____...____ ss 71 .. P 77.4 011 7 I, 77.477.WASA 1 �� Rig Days NM - I E MI i = - - MO - MI • - MI MN NOV MN • by $chlumberger NS33A Final Surveys Report Date: April 18, 2009 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 309.720° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Northstar PF / NS33 TVD Reference Datum: Rotary Table Well: NS33 TVD Reference Elevation: 55.9 ft relative to MSL Borehole: Plan NS33A Sea Bed / Ground Level Elevation: 15.670 ft relative to MSL UWIIAPI #: 50- 029 - 23325 -01 -00 Magnetic Declination: 22.910° Survey Name/Date: NS33A full shifted survey to KOP / February 15, 2009 Total Field Strength: 57713.748 nT Tort/ AHD 1 DDI 1 ERD ratio: 317.693° / 21797.79 ft / 7.202 / 1.921 Magnetic Dip: 81.044° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 15, 2009 Location LatlLong: N 70 29 29.845, W 148 41 36.037 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 6031141.300 ftUS, E 659820.740 ftUS North Reference: True North Grid Convergence Angle: +1.23166855° Total Corr Mag North -> True North: +22.910° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Measured Vertical Closure Survey Tool Comments Depth Inclination Azimuth TVD Section NS EW Closure Azimuth DLS Model (ft) (deg) (deg) (ft) (ft) (ft ) (ft) (ft) (deg) (deg /100ft ) Tie -In 0.00 0.01 18.25 0.00 0.11 0.29 0.10 0.31 19.03 0.00 BP_CB GYRO SS - Depth Only 49.31 0.70 18.25 49.31 0.22 0.58 0.20 0.61 18.64 1.40 BP_CB GYRO SS 99.31 0.62 18.15 99.31 0.43 1.13 0.38 1.19 18.43 0.16 BP_GYD SS 149.31 0.82 18.87 149.30 0.66 1.72 0.58 1.82 18.47 0.40 BP_GYD SS 207.31 1.14 324.05 207.29 1.37 2.58 0.37 2.61 8.18 1.63 BP_GYD SS 303.31 2.81 285.74 303.24 4.44 3.99 -2.45 4.69 328.43 2.13 BP_GYD SS ' 400.31 3.96 293.87 400.07 9.84 5.99 -7.81 9.84 307.52 1.28 BP_GYD SS 496.31 6.90 301.08 495.63 18.73 10.31 -15.78 18.85 303.17 3.14 BP_GYD SS 600.31 9.54 304.47 598.55 33.49 18.42 -28.24 33.71 303.12 2.58 BP_GYD SS 696.31 10.57 307.34 693.07 50.21 28.26 -41.80 50.45 304.07 1.19 BP_GYD SS 791.31 11.04 314.28 786.39 67.98 39.90 -55.24 68.14 305.84 1.46 BP_GYD SS 888.31 13.58 313.64 881.16 88.60 54.24 -70.13 88.66 307.72 2.62 BP_GYD SS 983.31 16.40 309.47 972.92 113.15 70.47 -88.56 113.17 308.51 3.18 BP_GYD SS 1106.98 19.19 310.74 1090.66 150.94 94.84 - 117.44 150.95 308.92 2.28 BP_MWD +IFR +MS 1200.18 20.23 307.72 1178.40 182.36 114.69 - 141.79 182.37 308.97 1.56 BP_MWD +IFR +MS 1296.51 17.22 306.36 1269.62 213.24 133.34 - 166.46 213.28 308.70 3.16 BP_MWD +IFR +MS 1391.45 17.76 308.97 1360.17 241.75 150.78 - 189.03 241.80 308.58 1.00 BP_MWD+IFR+MS 1488.39 19.49 308.60 1452.03 272.71 170.17 - 213.17 272.76 308.60 1.79 BP_MWD +IFR +MS 1583.07 22.65 295.86 1540.42 306.22 187.99 - 241.94 306.39 307.85 5.86 BP_MWD +IFR +MS DDToolBox Ver SP 2.1 Bld( users) \\ \NS33A full shifted survey to KOP Generated 4/28/2009 4:35 PM Page 1 of 8 NM •! MB all MI all NB UM - MI MO MI MI NB INN 1678.93 25.69 300.32 1627.87 344.66 206.53 - 276.49 345.12 306.76 3.70 BP_MWD +IFR +MS 1774.49 28.20 303.38 1713.05 387.54 229.42 - 313.24 388.26 306.22 3.00 BP_MWD +IFR +MS 1870.79 29.67 303.16 1797.33 433.83 254.97 - 352.19 434.80 305.90 1.53 BP_MWD +IFR +MS 1964.49 31.78 303.78 1877.87 481.42 281.38 - 392.12 482.63 305.66 2.28 BP_MWD +IFR +MS 2062.37 32.73 305.75 1960.65 533.46 311.17 - 435.02 534.86 305.58 1.45 BP_MWD +IFR +MS 2156.68 34.74 304.82 2039.08 585.67 341.42 - 477.78 587.23 305.55 2.20 BP_MWD +IFR +MS 2252.73 37.38 304.31 2116.72 641.97 373.48 - 524.33 643.75 305.46 2.77 BP_MWD +IFR +MS 2347.29 40.28 303.68 2190.37 700.96 406.62 - 573.49 703.02 305.34 3.10 BP_MWD +IFR +MS 2443.45 43.23 303.68 2262.10 764.64 442.13 - 626.77 767.02 305.20 3.07 BP_MWD +IFR +MS 2537.42 44.38 303.92 2329.92 829.33 478.31 - 680.82 832.05 305.09 1.24 BP_MWD +IFR +MS 2633.65 46.29 303.90 2397.56 897.42 516.50 - 737.62 900.47 305.00 1.98 BP_MWD +IFR +MS 2728.41 49.05 304.09 2461.36 967.12 555.66 - 795.70 970.51 304.93 2.92 BP_MWD +IFR +MS 2823.98 51.49 304.31 2522.45 1040.27 596.97 - 856.48 1044.00 304.88 2.56 BP_MWD +IFR +MS 2917.76 54.73 304.69 2578.73 1114.96 639.46 - 918.28 1118.99 304.85 3.47 BP_MWD +IFR +MS 3012.39 56.67 305.69 2632.06 1192.88 684.51 - 982.16 1197.16 304.87 2.23 BP_MWD +IFR +MS 3107.09 58.29 307.05 2682.97 1272.59 731.87 - 1046.45 1276.98 304.97 2.10 BP_MWD +IFR +MS 3203.63 60.50 307.14 2732.11 1355.59 781.98 - 1112.72 1360.01 305.10 2.29 BP_MWD +IFR +MS 3299.19 61.24 306.69 2778.63 1438.96 832.11 - 1179.46 1443.45 305.20 0.88 BP_MWD +IFR +MS 3394.67 63.15 307.33 2823.17 1523.32 882.95 - 1246.89 1527.86 305.30 2.09 BP_MWD +IFR +MS 3491.94 65.24 306.99 2865.51 1610.80 935.84 - 1316.68 1615.38 305.40 2.17 BP_MWD +IFR +MS 3587.75 67.89 307.18 2903.61 1698.60 988.85 - 1386.80 1703.24 305.49 2.77 BP_MWD +IFR +MS 3684.81 69.42 307.17 2938.94 1788.91 1043.47 - 1458.83 1793.60 305.58 1.58 BP_MWD +IFR +MS 3779.99 71.96 308.29 2970.41 1878.68 1098.44 - 1529.86 1883.36 305.68 2.89 BP_MWD +IFR +MS 3876.20 72.34 306.40 2999.90 1970.17 1153.99 - 1602.66 1974.90 305.76 1.91 BP_MWD +IFR +MS 3972.58 71.34 305.49 3029.94 2061.55 1207.75 - 1676.80 2066.47 305.76 1.37 BP_MWD +IFR +MS 4068.44 70.63 306.64 3061.18 2151.99 1261.10 - 1750.06 2157.10 305.78 1.35 BP_MWD +IFR +MS 4164.22 69.97 306.70 3093.46 2242.04 1314.95 - 1822.39 2247.26 305.81 0.69 BP_MWD +IFR +MS 4259.99 70.28 305.65 3126.02 2331.93 1368.11 - 1895.09 2337.32 305.83 1.08 BP_MWD +IFR +MS 4356.47 71.46 305.77 3157.64 2422.86 1421.31 - 1969.10 2428.47 305.82 1.23 BP_MWD +IFR +MS 4418.53 71.45 306.12 3177.38 2481.57 1455.85 - 2016.73 2487.31 305.82 0.53 BP_MWD +IFR +MS 4549.15 72.93 304.83 3217.33 2605.58 1528.01 - 2118.01 2611.66 305.81 1.47 BP_MWD +IFR +MS 4643.82 72.51 304.53 3245.45 2695.63 1579.45 - 2192.34 2702.04 305.77 0.54 BP_MWD +IFR +MS 4740.41 71.93 304.18 3274.95 2787.20 1631.35 - 2268.28 2793.99 305.72 0.69 BP_MWD +IFR +MS 4835.88 71.53 303.67 3304.87 2877.39 1681.95 - 2343.50 2884.60 305.67 0.66 BP_MWD +IFR +MS 4931.41 68.50 304.40 3337.52 2966.72 1732.19 - 2417.89 2974.34 305.62 3.25 BP_MWD +IFR +MS 5025.27 67.01 303.55 3373.05 3053.15 1780.74 - 2489.93 3061.17 305.57 1.80 BP_MWD +IFR +MS 5121.75 69.31 304.05 3408.94 3142.22 1830.55 - 2564.34 3150.68 305.52 2.43 BP_MWD +IFR +MS 5215.69 70.66 306.15 3441.10 3230.19 1881.31 - 2636.55 3238.94 305.51 2.54 BP_MWD +IFR +MS 5312.18 70.92 306.71 3472.85 3321.16 1935.42 - 2709.86 3330.04 305.53 0.61 BP_MWD +IFR +MS 5406.74 71.34 307.96 3503.43 3410.56 1989.68 - 2781.00 3419.47 305.58 1.33 BP_MWD +IFR +MS 5502.70 71.91 307.63 3533.68 3501.57 2045.49 - 2852.96 3510.47 305.64 0.68 BP_MWD +IFR +MS 5596.30 72.44 306.94 3562.33 3590.60 2099.47 - 2923.86 3599.54 305.68 0.90 BP_MWD +IFR +MS 5693.95 72.64 307.22 3591.63 3683.65 2155.63 - 2998.17 3692.67 305.72 0.34 BP_MWD+IFR+MS DDTooIBox Ver SP 2.1 Bld( users) \ \ \NS33A full shifted survey to KOP Generated 4/28/2009 4:35 PM Page 2 of 8 IIIIIII MI OM r r MN I MI Mw M 1 r r MN M- N M MN 5788.45 71.29 307.01 3620.89 3773.41 2209.85 - 3069.82 3782.50 305.75 1.44 BP_MWD +IFR +MS 5883.31 70.30 307.40 3652.09 3862.91 2264.02 - 3141.17 3872.05 305.78 1.11 BP_MWD +IFR +MS 5977.65 69.95 308.15 3684.16 3951.58 2318.37 - 3211.30 3960.71 305.83 0.83 BP_MWD +IFR +MS 6073.89 70.12 309.43 3717.03 4042.02 2375.03 - 3281.80 4051.05 305.89 1.26 BP_MWD +IFR +MS 6169.72 70.28 311.10 3749.49 4132.17 2433.31 - 3350.60 4140.95 305.99 1.65 BP_MWD +IFR +MS 6265.05 70.31 310.90 3781.63 4221.90 2492.19 - 3418.33 4230.37 306.09 0.20 BP_MWD +IFR +MS 6359.67 70.61 311.11 3813.28 4311.05 2550.69 - 3485.63 4319.22 306.20 0.38 BP_MWD +IFR +MS 6455.27 70.83 311.59 3844.85 4401.25 2610.31 - 3553.37 4409.10 306.30 0.53 BP_MWD +IFR +MS 6549.36 70.85 311.66 3875.73 4490.08 2669.35 - 3619.80 4497.60 306.41 0.07 BP_MWD +IFR +MS 6645.28 70.89 312.05 3907.16 4580.64 2729.81 - 3687.30 4587.82 306.51 0.39 BP_MWD +IFR +MS 6738.88 70.49 312.16 3938.11 4668.89 2789.04 - 3752.84 4675.74 306.62 0.44 BP_MWD +IFR +MS 6836.66 71.23 312.74 3970.17 4761.16 2851.39 - 3821.00 4767.65 306.73 0.94 BP_MWD +IFR +MS 6931.57 71.74 310.90 4000.31 4851.10 2911.39 - 3888.07 4857.29 306.83 1.92 BP_MWD +IFR +MS 7028.27 72.17 309.22 4030.27 4943.03 2970.56 - 3958.44 4949.09 306.89 1.71 BP_MWD +IFR +MS 7123.26 71.44 307.13 4059.93 5033.24 3026.34 - 4029.37 5039.30 306.91 2.23 BP_MWD +IFR +MS 7218.94 71.07 306.21 4090.68 5123.71 3080.45 - 4102.04 5129.90 306.90 0.99 BP_MWD +IFR +MS 7315.44 70.65 305.64 4122.32 5214.68 3133.94 - 4175.86 5221.05 306.89 0.71 BP_MWD +IFR +MS 7412.13 71.19 306.62 4153.93 5305.87 3187.82 - 4249.67 5312.42 306.87 1.11 BP_MWD +IFR +MS 7508.75 70.64 307.21 4185.52 5397.07 3242.66 - 4322.67 5403.73 306.88 0.81 BP_MWD +IFR +MS 7605.24 71.88 308.73 4216.52 5488.40 3298.88 - 4394.70 5495.08 306.89 1.97 BP_MWD +IFR +MS 7700.21 71.02 308.49 4246.73 5578.42 3355.06 - 4465.05 5585.08 306.92 0.94 BP_MWD +IFR +MS 7796.71 72.19 308.31 4277.19 5669.96 3411.94 - 4536.81 5676.62 306.95 1.23 BP_MWD +IFR +MS 7892.40 72.17 305.76 4306.47 5760.95 3466.80 - 4609.53 5767.71 306.95 2.54 BP_MWD +IFR +MS 7989.24 71.63 304.37 4336.56 5852.69 3519.68 - 4684.86 5859.70 306.92 1.47 BP_MWD +IFR +MS 8085.11 71.31 304.51 4367.03 5943.21 3571.09 - 4759.83 5950.52 306.88 0.36 BP_MWD +IFR +MS 8181.85 70.94 306.30 4398.33 6034.48 3624.12 - 4834.44 6042.02 306.86 1.79 BP_MWD +IFR +MS 8278.27 70.89 307.94 4429.86 6125.50 3679.10 - 4907.09 6133.14 306.86 1.61 BP_MWD +IFR +MS 8375.18 71.04 309.37 4461.46 6217.09 3736.33 - 4978.63 6224.70 306.89 1.40 BP_MWD +IFR +MS 8472.55 71.28 309.82 4492.91 6309.25 3795.06 - 5049.64 6316.75 306.93 0.50 BP_MWD +IFR +MS 8569.61 71.41 309.93 4523.95 6401.21 3854.02 - 5120.22 6408.59 306.97 0.17 BP_MWD +IFR +MS 8665.84 71.41 309.71 4554.63 6492.42 3912.43 - 5190.27 6499.69 307.01 0.22 BP_MWD +IFR +MS 8762.74 71.27 309.92 4585.63 6584.22 3971.21 - 5260.79 6591.39 307.05 0.25 BP_MWD +IFR +MS 8860.05 71.55 310.73 4616.66 6676.45 4030.90 - 5331.10 6683.47 307.09 0.84 BP_MWD +IFR +MS 8956.91 71.95 310.33 4646.99 6768.43 4090.67 - 5401.02 6775.30 307.14 0.57 BP_MWD +IFR +MS 9053.07 72.16 310.11 4676.62 6859.91 4149.75 - 5470.87 6866.65 307.18 0.31 BP_MWD +IFR +MS 9151.11 72.25 309.92 4706.58 6953.25 4209.77 - 5542.37 6959.88 307.22 0.21 BP_MWD +IFR +MS 9245.29 72.09 308.62 4735.42 7042.91 4266.52 - 5611.77 7049.48 307.24 1.33 BP_MWD +IFR +MS 9342.22 71.93 308.46 4765.35 7135.08 4323.96 - 5683.88 7141.65 307.26 0.23 BP_MWD +IFR +MS 9437.78 72.03 308.19 4794.92 7225.92 4380.31 - 5755.17 7232.51 307.28 0.29 BP_MWD +IFR +MS 9534.41 72.11 307.85 4824.66 7317.82 4436.94 - 5827.60 7324.44 307.28 0.34 BP_MWD +IFR +MS 9631.30 71.35 307.66 4855.04 7409.77 4493.27 - 5900.34 7416.44 307.29 0.81 BP_MWD +IFR +MS 9726.41 71.29 308.51 4885.50 7499.83 4548.85 - 5971.26 7506.53 307.30 0.85 BP_MWD +IFR +MS 9821.29 71.96 308.44 4915.41 7589.85 4604.87 - 6041.75 7596.55 307.31 0.71 BP_MWD+IFR+MS DDTooIBox Ver SP 2.1 BId( users) \ \ \NS33A full shifted survey to KOP Generated 4/28/2009 4:35 PM Page 3 of 8 MI MI NB In NM i r I NM - i- MI MN - OM 1 Ina r 9916.94 72.20 308.05 4944.84 7680.83 4661.21 - 6113.23 7687.55 307.32 0.46 BP_MWD +IFR +MS 10013.42 72.37 307.39 4974.20 7772.68 4717.43 - 6185.93 7779.45 307.33 0.68 BP_MWD +IFR +MS 10108.19 72.15 305.98 5003.08 7862.82 4771.36 - 6258.31 7869.71 307.32 1.44 BP_MWD +IFR +MS 10204.90 72.00 305.86 5032.84 7954.63 4825.34 - 6332.83 7961.69 307.31 0.19 BP_MWD +IFR +MS 10302.70 71.82 305.75 5063.21 8047.38 4879.73 - 6408.22 8054.63 307.29 0.21 BP_MWD +IFR +MS 10368.89 71.61 305.82 5083.97 8110.08 4916.48 - 6459.21 8117.45 307.28 0.33 BP_MWD +IFR +MS 10466.23 71.25 305.76 5114.97 8202.13 4970.44 - 6534.05 8209.70 307.26 0.37 BP_MWD +IFR +MS 10560.87 70.75 306.78 5145.79 8291.45 5023.37 - 6606.20 8299.17 307.25 1.15 BP_MWD +IFR +MS 10657.19 70.53 307.47 5177.72 8382.23 5078.22 - 6678.65 8390.04 307.25 0.71 BP_MWD +IFR +MS 10752.86 70.95 308.27 5209.28 8472.50 5133.66 - 6749.95 8480.35 307.25 0.90 BP_MWD +IFR +MS 10848.64 71.18 308.83 5240.36 8563.08 5190.12 - 6820.80 8570.92 307.27 0.60 BP_MWD +IFR +MS 10942.73 70.49 309.50 5271.24 8651.95 5246.25 - 6889.71 8659.75 307.29 1.00 BP_MWD +IFR +MS 11038.67 70.97 309.75 5302.91 8742.51 5304.01 - 6959.46 8750.24 307.31 0.56 BP_MWD +IFR +MS 11132.96 71.81 310.13 5333.00 8831.87 5361.38 - 7027.98 8839.50 307.34 0.97 BP_MWD +IFR +MS 11230.30 72.25 309.70 5363.03 8924.46 5420.79 - 7098.99 8932.00 307.37 0.62 BP_MWD +IFR +MS 11323.83 71.95 309.61 5391.77 9013.46 5477.59 - 7167.52 9020.93 307.39 0.33 BP_MWD +IFR +MS 11419.78 71.09 309.96 5422.19 9104.46 5535.82 - 7237.45 9111.86 307.41 0.96 BP_MWD +IFR +MS 11513.26 71.34 309.82 5452.29 9192.96 5592.57 - 7305.35 9200.27 307.44 0.30 BP_MWD +IFR +MS 11609.72 71.74 309.71 5482.83 9284.46 5651.10 - 7375.68 9291.70 307.46 0.43 BP_MWD +IFR +MS 11703.76 71.18 309.07 5512.74 9373.62 5707.68 - 7444.59 9380.80 307.48 0.88 BP_MWD +IFR +MS 11801.16 71.07 308.05 5544.25 9465.76 5765.13 - 7516.65 9472.95 307.49 1.00 BP_MWD +IFR +MS 11895.73 70.67 307.24 5575.24 9555.05 5819.70 - 7587.40 9562.30 307.49 0.91 BP_MWD +IFR +MS 11991.52 70.63 307.10 5606.98 9645.34 5874.30 - 7659.42 9652.67 307.49 0.14 BP_MWD +IFR +MS 12085.84 69.77 307.40 5638.93 9734.00 5928.02 - 7730.06 9741.41 307.48 0.96 BP_MWD +IFR +MS 12173.07 69.48 306.92 5669.30 9815.69 5977.41 - 7795.22 9823.19 307.48 0.61 BP_MWD +IFR +MS 12266.94 71.06 306.77 5700.99 9903.93 6030.39 - 7865.93 9911.54 307.48 1.69 BP_MWD +IFR +MS 12361.69 72.05 307.92 5730.96 9993.73 6084.92 - 7937.39 10001.42 307.47 1.55 BP_MWD +IFR +MS 12457.08 72.08 307.69 5760.34 10084.44 6140.55 - 8009.09 10092.17 307.48 0.23 BP_MWD +IFR +MS 12553.14 72.13 306.81 5789.86 10175.76 6195.88 - 8081.85 10183.58 307.48 0.87 BP_MWD +IFR +MS 12647.15 72.14 305.84 5818.70 10265.08 6248.88 - 8153.94 10273.04 307.47 0.98 BP_MWD +IFR +MS 12743.17 72.71 304.84 5847.69 10356.35 6301.83 - 8228.61 10364.51 307.45 1.16 BP_MWD +IFR +MS 12837.16 72.16 304.78 5876.05 10445.63 6352.98 - 8302.18 10454.02 307.42 0.59 BP_MWD +IFR +MS 12933.71 71.93 304.48 5905.82 10537.12 6405.18 - 8377.76 10545.76 307.40 0.38 BP_MWD +IFR +MS 13028.24 72.49 304.47 5934.70 10626.75 6456.13 - 8451.96 10635.66 307.37 0.59 BP_MWD +IFR +MS 13124.48 71.67 304.58 5964.31 10717.94 6508.02 - 8527.40 10727.12 307.35 0.86 BP_MWD +IFR +MS 13220.90 71.81 305.14 5994.52 10809.18 6560.36 - 8602.54 10818.59 307.33 0.57 BP_MWD +IFR +MS 13318.09 71.64 305.57 6025.00 10901.20 6613.76 - 8677.81 10910.83 307.31 0.46 BP_MWD +IFR +MS 13413.72 71.65 306.02 6055.11 10991.75 6666.85 - 8751.43 11001.56 307.30 0.45 BP_MWD +IFR +MS 13509.92 71.97 307.04 6085.15 11083.00 6721.25 - 8824.86 11092.94 307.29 1.06 BP_MWD +IFR +MS 13609.04 71.61 307.56 6116.12 11177.07 6778.31 - 8899.76 11187.10 307.29 0.62 BP_MWD +IFR +MS 13703.53 71.58 308.55 6145.96 11266.69 6833.57 - 8970.36 11276.75 307.30 0.99 BP_MWD +IFR +MS 13801.31 71.97 308.74 6176.54 11359.55 6891.57 - 9042.89 11369.59 307.31 0.44 BP_MWD +IFR +MS 13896.69 71.73 309.60 6206.25 11450.18 6948.82 - 9113.16 11460.18 307.33 0.89 BP_MWD +IFR +MS DDToolBox Ver SP 2.1 Bld( users) \ \ \NS33A full shifted survey to KOP Generated 4/28/2009 4:35 PM Page 4 of 8 NB MI NM On MO MI 1 r IN r i s In - i M MI - 13999.29 71.58 309.86 6238.54 11547.56 7011.06 - 9188.06 11557.48 307.35 0.28 BP_MWD +IFR +MS 14089.17 71.66 308.99 6266.88 11632.85 7065.23 - 9253.94 11642.72 307.36 0.92 BP_MWD +IFR +MS 14186.15 71.48 308.59 6297.54 11724.85 7122.87 - 9325.66 11734.70 307.37 0.43 BP_MWD +IFR +MS 14282.59 71.73 307.75 6327.97 11816.33 7179.42 - 9397.60 11826.20 307.38 0.87 BP_MWD +IFR +MS 14379.34 71.51 307.06 6358.48 11908.06 7235.19 - 9470.53 11918.01 307.38 0.71 BP_MWD +IFR +MS 14475.03 71.78 306.54 6388.62 11998.77 7289.60 - 9543.26 12008.83 307.37 0.59 BP_MWD +IFR +MS 14572.08 71.67 306.00 6419.05 12090.75 7344.11 - 9617.56 12100.97 307.37 0.54 BP_MWD +IFR +MS 14668.77 71.90 304.86 6449.27 12182.34 7397.36 - 9692.39 12192.76 307.35 1.14 BP_MWD +IFR +MS 14765.95 71.94 305.35 6479.43 12274.42 7450.48 - 9767.97 12285.07 307.33 0.48 BP_MWD +IFR +MS 14860.86 71.42 305.95 6509.26 12364.29 7502.99 - 9841.18 12375.13 307.32 0.81 BP_MWD +IFR +MS Tie in Survey 14958.01 71.31 306.13 6540.31 12456.16 7557.16 - 9915.62 12467.16 307.31 0.21 BP_MWD +IFR +MS TOW interpolated 15037.00 71.30 305.62 6565.63 12530.82 7601.00 - 9976.25 12541.96 307.30 0.61 BP _ BLIND BOW interpolated 15060.00 73.36 307.55 6572.61 12552.69 7614.07 - 9993.84 12563.87 307.30 12.01 BP _ BLIND Interpolated Azimuth 15117.08 72.36 310.32 6589.43 12607.23 7648.34 - 10036.27 12618.39 307.31 4.96 BP_INC +TREND Interpolated Azimuth 15212.35 72.90 314.96 6617.89 12698.00 7709.91 - 10103.13 12708.89 307.35 4.68 BP_INC +TREND Interpolated Azimuth 15307.83 73.20 319.60 6645.74 12788.51 7776.99 - 10165.07 12798.84 307.42 4.66 BP_INC +TREND First good survey 15403.53 74.15 323.03 6672.65 12878.46 7848.67 - 10222.46 12887.99 307.52 3.58 BP_MWD +IFR +MS 15435.53 74.71 321.89 6681.24 12908.53 7873.12 - 10241.24 12917.78 307.55 3.85 BP_MWD +IFR +MS 15499.34 76.25 323.24 6697.23 12968.75 7922.16 - 10278.78 12977.45 307.62 3.17 BP_MWD +IFR +MS 15534.72 77.45 323.47 6705.28 13002.23 7949.81 - 10299.35 13010.61 307.66 3.45 BP_MWD +IFR +MS 15594.35 77.60 321.93 6718.16 13058.96 7996.12 - 10334.63 13066.85 307.73 2.53 BP_MWD +IFR +MS 15688.32 77.48 320.00 6738.44 13148.95 8067.39 - 10392.41 13156.18 307.82 2.01 BP_MWD +IFR +MS 15784.59 76.72 317.36 6759.94 13241.64 8137.86 - 10454.36 13248.34 307.90 2.79 BP_MWD +IFR +MS 15878.95 76.49 316.57 6781.80 13332.70 8204.95 - 10517.01 13338.99 307.96 0.85 BP_MWD +IFR +MS 15975.84 76.43 316.33 6804.48 13426.25 8273.23 - 10581.91 13432.16 308.02 0.25 BP_MWD +IFR +MS 16070.70 76.51 316.63 6826.67 13517.83 8340.10 - 10645.41 13523.39 308.08 0.32 BP_MWD +IFR +MS 16166.53 76.89 315.69 6848.72 13610.50 8407.37 - 10710.01 13615.73 308.13 1.03 BP_MWD +IFR +MS 16261.42 77.80 315.56 6869.51 13702.60 8473.55 - 10774.76 13707.53 308.18 0.97 BP_MWD +IFR +MS 1 16356.90 77.48 314.85 6889.95 13795.43 8539.73 - 10840.47 13800.10 308.23 0.80 BP_MWD +IFR +MS 16451.73 77.39 314.52 6910.58 13887.65 8604.82 - 10906.28 13892.08 308.27 0.35 BP_MWD +IFR +MS 16546.10 77.11 314.31 6931.40 13979.38 8669.24 - 10972.03 13983.60 308.31 0.37 BP_MWD +IFR +MS 16641.39 77.31 314.63 6952.50 14071.99 8734.33 - 11038.34 14075.99 308.35 0.39 BP_MWD +IFR +MS 16735.47 77.45 315.00 6973.05 14163.43 8799.04 - 11103.47 14167.22 308.40 0.41 BP_MWD +IFR +MS 16830.03 77.83 315.80 6993.29 14255.34 8864.81 - 11168.32 14258.90 308.44 0.92 BP_MWD +IFR +MS 16925.34 76.81 315.20 7014.22 14347.86 8931.13 - 11233.49 14351.18 308.49 1.23 BP_MWD +IFR +MS 16964.71 76.69 314.99 7023.24 14386.01 8958.27 - 11260.55 14389.25 308.50 0.60 BP_MWD +IFR +MS Bha06 17046.92 76.87 316.72 7042.04 14465.58 9015.70 - 11316.28 14468.62 308.54 2.06 BP_MWD +IFR +MS 17142.30 77.05 317.03 7063.56 14557.78 9083.52 - 11379.80 14560.57 308.60 0.37 BP_MWD +IFR +MS 17238.07 77.01 317.42 7085.06 14650.30 9152.02 - 11443.18 14652.85 308.65 0.40 BP_MWD +IFR +MS 17333.07 76.96 317.99 7106.45 14741.96 9220.49 - 11505.47 14744.26 308.71 0.59 BP_MWD +IFR +MS 17428.33 77.04 318.63 7127.88 14833.74 9289.80 - 11567.20 14835.79 308.77 0.66 BP_MWD +IFR +MS 17523.96 77.04 319.31 7149.33 14925.72 9360.10 - 11628.38 14927.52 308.83 0.69 BP_MWD +IFR +MS 17619.99 76.95 319.67 7170.94 15017.93 9431.24 - 11689.16 15019.48 308.90 0.38 BP_MWD +IFR +MS DDToolBox Ver SP 2.1 Bld( users) \\ \NS33A full shifted survey to KOP Generated 4/28/2009 4:35 PM Page 5 of 8 all i N 1 M s V ■M NM NS - IN MN NM NM - MI EN 17711.52 76.99 320.24 7191.58 15105.69 9499.50 - 11746.53 15107.00 308.96 0.61 BP_MWD +IFR +MS 17811.09 76.93 319.67 7214.04 15201.14 9573.76 - 11808.94 15202.24 309.03 0.56 BP_MWD +IFR +MS 17899.91 76.82 319.69 7234.21 15286.34 9639.71 - 11864.91 15287.26 309.09 0.13 BP_MWD +IFR +MS 18000.70 76.74 319.65 7257.26 15382.98 9714.51 - 11928.41 15383.72 309.16 0.09 BP_MWD +IFR +MS 18095.93 76.46 318.89 7279.33 15474.34 9784.71 - 11988.86 15474.93 309.22 0.83 BP_MWD +IFR +MS 18190.57 77.01 317.83 7301.05 15565.40 9853.55 - 12050.06 15565.88 309.27 1.24 BP_MWD +IFR +MS 18285.72 77.13 317.09 7322.34 15657.30 9921.88 - 12112.76 15657.67 309.32 0.77 BP_MWD +IFR +MS 18381.11 77.22 316.99 7343.51 15749.55 9989.95 - 12176.15 15749.85 309.37 0.14 BP_MWD +IFR +MS 18476.25 77.16 316.57 7364.61 15841.62 10057.55 - 12239.68 15841.85 309.41 0.44 BP_MWD +IFR +MS 18570.77 77.13 315.03 7385.64 15933.25 10123.62 - 12303.92 15933.43 309.45 1.59 BP_MWD +IFR +MS 18666.11 77.07 313.37 7406.92 16025.89 10188.40 - 12370.54 16026.04 309.47 1.70 BP_MWD +IFR +MS 18761.97 76.99 311.55 7428.44 16119.20 10251.46 - 12439.46 16119.32 309.49 1.85 BP_MWD +IFR +MS 18855.87 77.01 309.98 7449.56 16210.67 10311.20 - 12508.75 16210.79 309.50 1.63 BP_MWD +IFR +MS 18948.78 77.13 308.47 7470.35 16301.22 10368.46 - 12578.90 16301.34 309.50 1.59 BP_MWD +IFR +MS 19044.23 77.21 307.05 7491.55 16394.23 10425.45 - 12652.47 16394.36 309.49 1.45 BP_MWD +IFR +MS 19139.27 77.13 305.49 7512.66 16486.72 10480.27 - 12727.18 16486.88 309.47 1.60 BP_MWD +IFR +MS 19234.47 77.16 303.98 7533.84 16579.18 10533.15 - 12803.45 16579.38 309.44 1.55 BP_MWD +IFR +MS 19328.59 76.99 302.20 7554.89 16670.30 10583.23 - 12880.31 16670.55 309.41 1.85 BP_MWD +IFR +MS 19423.24 77.28 302.28 7575.97 16761.79 10632.46 - 12958.36 16762.11 309.37 0.32 BP_MWD +IFR +MS 19518.28 77.22 301.95 7596.94 16853.67 10681.74 - 13036.87 16854.07 309.33 0.34 BP_MWD +IFR +MS 19613.60 77.30 301.78 7617.96 16945.77 10730.82 - 13115.83 16946.25 309.29 0.19 BP_MWD +IFR +MS 19708.23 77.48 301.76 7638.62 17037.23 10779.44 - 13194.34 17037.81 309.25 0.19 BP_MWD +IFR +MS 19801.41 77.46 301.66 7658.84 17127.31 10827.25 - 13271.72 17127.99 309.21 0.11 BP_MWD +IFR +MS 19897.14 77.10 301.66 7679.91 17219.76 10876.27 - 13351.21 17220.57 309.17 0.38 BP_MWD +IFR +MS 19992.01 77.02 301.74 7701.16 17311.32 10924.85 - 13429.87 17312.25 309.13 0.12 BP_MWD +IFR +MS 20009.24 77.07 301.84 7705.02 17327.95 10933.70 - 13444.14 17328.90 309.12 0.64 BP_MWD +IFR +MS 20104.35 77.19 301.71 7726.21 17419.78 10982.52 - 13522.97 17420.86 309.08 0.18 BP_MWD +IFR +MS 20199.85 77.34 301.53 7747.26 17512.00 11031.36 - 13602.29 17513.23 309.04 0.24 BP_MWD +IFR +MS 20294.84 77.30 301.53 7768.11 17603.73 11079.82 - 13681.28 17605.11 309.00 0.04 BP_MWD +IFR +MS 20390.68 76.93 301.75 7789.48 17696.23 11128.83 - 13760.82 17697.77 308.96 0.45 BP_MWD +IFR +MS 20485.42 76.85 301.31 7810.97 17787.56 11177.09 - 13839.47 17789.27 308.93 0.46 BP_MWD +IFR +MS 20580.38 76.88 301.17 7832.55 17879.02 11225.05 - 13918.54 17880.92 308.89 0.15 BP_MWD +IFR +MS 20674.84 76.75 301.07 7854.10 17969.96 11272.58 - 13997.27 17972.05 308.85 0.17 BP_MWD +IFR +MS 20769.72 76.63 300.98 7875.94 18061.23 11320.17 - 14076.39 18063.53 308.81 0.16 BP_MWD +IFR +MS 20864.01 76.72 301.08 7897.67 18151.93 11367.46 - 14155.01 18154.44 308.77 0.14 BP_MWD +IFR +MS 20958.41 76.63 300.59 7919.43 18242.68 11414.55 - 14233.89 18245.42 308.73 0.51 BP_MWD +IFR +MS 21053.99 76.72 300.49 7941.46 18334.50 11461.81 - 14313.99 18337.49 308.69 0.14 BP_MWD +IFR +MS 21148.77 76.76 300.25 7963.20 18425.53 11508.45 - 14393.59 18428.78 308.64 0.25 BP_MWD +IFR +MS 21244.09 76.87 300.79 7984.94 18517.14 11555.58 - 14473.54 18520.66 308.60 0.56 BP_MWD +IFR +MS 21339.09 76.96 301.31 8006.45 18608.62 11603.31 - 14552.81 18612.39 308.57 0.54 BP_MWD +IFR +MS 21434.34 77.08 301.99 8027.84 18700.51 11652.01 - 14631.82 18704.53 308.53 0.71 BP_MWD +IFR +MS 21530.36 75.73 302.93 8050.41 18793.09 11702.10 - 14710.57 18797.34 308.50 1.70 BP_MWD +IFR +MS 21624.62 74.16 303.23 8074.89 18883.50 11751.78 - 14786.84 18887.95 308.48 1.69 BP_MWD+IFR+MS DDToolBox Ver SP 2.1 Bld( users) \ \ \NS33A full shifted survey to KOP Generated 4/28/2009 4:35 PM Page 6 of 8 gm mg En No M - i 11111 all 1 r MI MI MI an In MI i s 21722.22 72.81 303.95 8102.64 18976.54 11803.55 - 14864.78 18981.19 308.45 1.55 BP_MWD +IFR +MS 21816.79 70.98 304.70 8132.03 19066.02 11854.23 - 14939.02 19070.84 308.43 2.08 BP_MWD +IFR +MS 21911.66 68.30 305.45 8165.03 19154.66 11905.33 - 15011.80 19159.62 308.42 2.92 BP_MWD +IFR +MS 22006.38 65.44 305.07 8202.23 19241.50 11955.61 - 15082.92 19246.58 308.40 3.04 BP_MWD +IFR +MS 22101.51 62.94 304.65 8243.65 19326.82 12004.56 - 15153.18 19332.05 308.39 2.66 BP_MWD +IFR +MS 22196.52 60.89 304.54 8288.38 19410.31 12052.15 - 15222.18 19415.69 308.37 2.16 BP_MWD +IFR +MS 22292.03 59.09 304.32 8336.14 19492.66 12098.91 - 15290.40 19498.20 308.35 1.90 BP_MWD +IFR +MS 22387.11 57.11 303.34 8386.39 19572.94 12143.85 - 15357.44 19578.66 308.34 2.26 BP_MWD +IFR +MS 22481.93 55.65 302.75 8438.88 19651.37 12186.91 - 15423.62 19657.29 308.31 1.62 BP_MWD +IFR +MS 22576.84 54.32 302.24 8493.34 19728.48 12228.67 - 15489.18 19734.62 308.29 1.47 BP_MWD +IFR +MS 22672.38 53.28 302.40 8549.77 19804.93 12269.89 - 15554.33 19811.30 308.27 1.10 BP_MWD +IFR +MS 22767.63 52.00 302.35 8607.57 19880.02 12310.43 - 15618.27 19886.60 308.25 1.34 BP_MWD +IFR +MS 22862.07 51.07 302.58 8666.31 19953.37 12350.12 - 15680.66 19960.17 308.22 1.00 BP_MWD +IFR +MS 22955.67 49.77 302.62 8725.95 20024.95 12388.98 - 15741.43 20031.97 308.20 1.39 BP_MWD +IFR +MS 23050.39 48.34 304.54 8788.02 20096.08 12428.54 - 15801.04 20103.27 308.19 2.15 BP_MWD +IFR +MS 23145.27 46.55 305.56 8852.19 20165.73 12468.67 - 15858.26 20173.05 308.18 2.05 BP_MWD +IFR +MS 23240.35 43.82 304.75 8919.20 20232.96 12507.51 - 15913.39 20240.40 308.17 2.93 BP_MWD +IFR +MS 23335.95 41.05 304.48 8989.75 20297.21 12544.15 - 15966.47 20304.78 308.16 2.90 BP_MWD +IFR +MS 23430.78 37.73 304.60 9063.02 20357.13 12578.27 - 16016.04 20364.83 308.14 3.50 BP_MWD +IFR +MS 23525.64 34.36 306.38 9139.72 20412.78 12610.64 - 16061.49 20420.57 308.14 3.72 BP_MWD +IFR +MS 23620.63 33.69 308.46 9218.44 20465.88 12642.92 - 16103.71 20473.71 308.14 1.41 BP_MWD +IFR +MS 23715.63 34.12 307.96 9297.29 20518.85 12675.70 - 16145.35 20526.70 308.14 0.54 BP_MWD +IFR +MS 23809.89 33.92 310.15 9375.42 20571.58 12708.92 - 16186.30 20579.43 308.14 1.32 BP_MWD +IFR +MS 23904.36 33.45 311.84 9454.03 20623.96 12743.29 - 16225.84 20631.75 308.15 1.11 BP_MWD +IFR +MS 23999.20 33.33 311.37 9533.22 20676.12 12777.94 - 16264.87 20683.85 308.15 0.30 BP_MWD +IFR +MS 24095.09 33.37 310.50 9613.32 20728.83 12812.48 - 16304.69 20736.50 308.16 0.50 BP_MWD +IFR +MS 7 7/8 hole 24205.85 32.26 310.64 9706.40 20788.84 12851.52 - 16350.29 20796.47 308.17 1.00 BP_MWD +IFR +MS 24300.69 31.74 310.57 9786.83 20839.09 12884.23 - 16388.44 20846.69 308.17 0.55 BP_MWD +IFR +MS 24395.31 32.25 310.49 9867.08 20889.22 12916.81 - 16426.55 20896.78 308.18 0.54 BP_MWD +IFR +MS 24489.34 32.02 309.85 9946.70 20939.24 12949.07 - 16464.76 20946.76 308.18 0.44 BP_MWD +IFR +MS 24583.23 31.48 310.20 10026.54 20988.64 12980.84 - 16502.60 20996.14 308.19 0.61 BP_MWD +IFR +MS 24678.69 30.99 310.26 10108.16 21038.14 13012.81 - 16540.39 21045.61 308.19 0.51 BP_MWD +IFR +MS 24773.36 30.51 310.35 10189.52 21086.54 13044.12 - 16577.30 21093.98 308.20 0.51 BP_MWD +IFR +MS 24869.34 30.03 310.38 10272.42 21134.92 13075.46 - 16614.17 21142.33 308.20 0.50 BP_MWD +IFR +MS 24962.98 29.32 310.26 10353.77 21181.28 13105.45 - 16649.51 21188.66 308.21 0.76 BP_MWD +IFR +MS 25058.10 28.68 309.65 10436.97 21227.39 13135.07 - 16684.86 21234.75 308.21 0.74 BP_MWD +IFR +MS 25153.48 28.14 309.88 10520.86 21272.77 13164.10 - 16719.74 21280.11 308.21 0.58 BP_MWD +IFR +MS 25248.25 27.64 309.79 10604.62 21317.10 13192.49 - 16753.78 21324.43 308.22 0.53 BP_MWD +IFR +MS 25342.54 27.32 310.29 10688.28 21360.61 13220.48 - 16787.10 21367.91 308.22 0.42 BP_MWD +IFR +MS 25437.75 26.82 310.11 10773.05 21403.94 13248.45 - 16820.19 21411.22 308.23 0.53 BP_MWD +IFR +MS 25512.57 26.76 310.08 10839.84 21437.66 13270.17 - 16845.99 21444.92 308.23 0.08 BP_MWD +IFR +MS 5 7/8 hole 25647.38 26.53 310.77 10960.34 21498.11 13309.37 - 16892.01 21505.33 308.23 0.29 BP_MWD +IFR +MS 25741.92 27.73 310.04 11044.47 21541.22 13337.31 - 16924.84 21548.41 308.24 1.32 BP_MWD+IFR+MS DDToolBox Ver SP 2.1 Bld( users) \ \ \NS33A full shifted survey to KOP Generated 4/28/2009 4:35 PM Page 7 of 8 NM MN Nil OM 1111111 MI 1111111 NMI • ION • IIIIII 25836.87 27.59 311.39 11128.57 21585.28 13366.06 - 16958.25 21592.45 308.24 0.68 BP_MWD +IFR +MS 25930.90 28.62 318.21 11211.54 21629.34 13397.26 - 16989.60 21636.38 308.26 3.59 BP_MWD +IFR +MS 26036.73 30.48 323.19 11303.61 21680.52 13437.65 - 17022.58 21687.30 308.29 2.91 BP_MWD +IFR +MS Projection to TD 26090.00 30.48 323.19 11349.52 21706.80 13459.29 - 17038.77 21713.41 308.31 0.00 BP BLIND Survey Type: Non -Def Survey Survey Error Model: BP ISCWSA version 10 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft) MD To (ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 40.24 Act -Stns BP_CB GYRO SS -Depth Only Plan NS33A -> NS33A full shifted survey to KOP 40.24 49.31 Act -Stns BP_CB GYRO SS Plan NS33A -> NS33A full shifted survey to KOP 49.31 983.31 Act -Stns BP_GYD SS Plan NS33A -> NS33A full shifted survey to KOP 983.31 14958.01 Act -Stns BP_MWD +IFR +MS Plan NS33A -> NS33A full shifted survey to KOP 14958.01 15060.00 Act -Stns BP_BLIND Plan NS33A -> NS33A full shifted survey to KOP 15060.00 15307.83 Act -Stns BP_INC +TREND Plan NS33A -> NS33A full shifted survey to KOP 15307.83 26036.73 Act -Stns BP_MWD +IFR +MS Plan NS33A -> NS33A full shifted survey to KOP 26036.73 26090.00 Act -Stns BP_BLIND Plan NS33A -> NS33A full shifted survey to KOP DDToolBox Ver SP 2.1 Bld( users) \\ \NS33A full shifted survey to KOP Generated 4/28/2009 4:35 PM Page 8 of 8
