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Home My WebLink About206-120Nolan 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: 1/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240107 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # END 2-72 50029237810000 224016 11/16/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 END 2-74 50029237850000 224024 8/13/2024 DarkVision HADES (Down hole camera) KGSF 1A 50133101600100 220063 12/5/2024 HALLIBURTON EPX-MFC40 MPU F-13 50029225490000 195027 12/22/2024 HALLIBURTON WFL-TMD3D PU F-40 50029222150000 191117 11/9/2024 READ CaliperSurvey MPU I-04A 50029220680100 201092 11/22/2024 HALLIBURTON COILFLAG MPU J-02 50029220710000 190096 12/22/2024 READ CaliperSurvey PBU L-04 50029233190000 206120 11/23/2024 HALLIBURTON WFL-TMD3D PBU L-221 50029233850000 208031 12/11/2024 HALLIBURTON WFL-RMT3D PBU Z-ϯϰ 50029234690000 212061 12/15/2024 HALLIBURTON WFL-RMT3D PBU Z-2ϯϱ 50029237600000 223055 9/24/2024 READ InjectionProfile PBU Z-ϮϮϯ 50029237200000 222080 11/24/2024 HALLIBURTON WFL-TMD3D SCU 42-05Y 50133205700000 207082 12/7/2024 HALLIBURTON EPX-MFC24 TBU D-16RD 50733201830100 180110 12/19/2024 READ CaliperSurvey TBU D-17RD 50733201680100 181023 12/21/2024 READ CaliperSurvey Please include current contact information if different from above. T39915 T39916 T39916 T39917 T39918 T39919 T39920 T39921 T39922 T39923 T39924 T39925 T39926 T39927 T39928 T39929 PBU L-04 50029233190000 206120 11/23/2024 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 15:26:55 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 13, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-04 PRUDHOE BAY UN L-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2024 L-04 50-029-23319-00-00 206-120-0 N SPT 8507 2061200 2500 715 2753 2700 2683 664 669 669 669 OTHER P Kam StJohn 10/15/2024 2 Year CMIT-TxIA Per CO 736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN L-04 Inspection Date: Tubing OA Packer Depth 336 2755 2698 2679IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS241016123711 BBL Pumped:2.6 BBL Returned:2.8 Friday, December 13, 2024 Page 1 of 1 9 9 9 9 9 9 999 999 99 9 9 9 CMIT-TxIA Per CO 736 James B. Regg Digitally signed by James B. Regg Date: 2024.12.13 16:02:27 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 13, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-04 PRUDHOE BAY UN L-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2024 L-04 50-029-23319-00-00 206-120-0 N SPT 8507 2061200 2500 705 2745 2647 2618 661 662 665 663 OTHER P Kam StJohn 10/15/2024 2 Year AOGCC MIT-T per CO 736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN L-04 Inspection Date: Tubing OA Packer Depth 327 476 485 481IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS241016123148 BBL Pumped:1.6 BBL Returned:1.5 Friday, December 13, 2024 Page 1 of 1 9 9 9 9 99 999 9 9 9 9 9 9 9 MIT-T per CO 736 James B. Regg Digitally signed by James B. Regg Date: 2024.12.13 16:04:06 -09'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 11/16/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU L-04 PTD: 206120 API: 50-029-23319-00-00 WFL-TMD3D 08NOV22 SFTP Transfer Please include current contact information if different from above. By Meredith Guhl at 3:44 pm, Nov 16, 2022 206-120 T37264 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.16 15:45:26 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-04 PRUDHOE BAY UNIT L-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2022 L-04 50-029-23319-00-00 206-120-0 N SPT 8507 2061200 2127 60 3264 3105 3064 658 657 656 657 OTHER P Kam StJohn 10/13/2022 2 Year AOGCC MIT-T Per CO 736 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UNIT L-04 Inspection Date: Tubing OA Packer Depth 428 664 675 670IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221013184046 BBL Pumped:2.6 BBL Returned:2.4 Tuesday, December 13, 2022 Page 1 of 1 2 Year AOGCC MIT-T Per CO 736 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-04 PRUDHOE BAY UNIT L-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2022 L-04 50-029-23319-00-00 206-120-0 N SPT 8507 2061200 2127 425 3260 3179 3152 656 661 664 664 OTHER P Kam StJohn 10/13/2022 2 Year AOGCC CMIT-TxIA Per CO 736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT L-04 Inspection Date: Tubing OA Packer Depth 449 3249 3165 3138IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221013184631 BBL Pumped:3.6 BBL Returned:3.6 Tuesday, December 13, 2022 Page 1 of 1              PU- L-0+ P7)�'2e, C',)zoo Regg, James B (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Tuesday, December 22, 2020 8:52 AM To: Regg, James B (CED) Cc: Alaska NS - PB W - GC2 - Field Lead Operator Subject: FW: [EXTERNAL] PBU L-04 Wellhouse sign Deficiency Attachments: 1875_001.pdf; Res ized_20201217_000747002.jpeg Mr. Regg, Please see attached signed Deficiency Report and picture of the new sign. Let me know if you have any questions or concerns. Thanks, Andy Ogg Hilcorp Alaska LLC Field Well Integrity /Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com> Sent: Thursday, December 17, 2020 5:03 PM To: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Cc: Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com> Subject: FW: [EXTERNAL] PBU L-04 Wellhouse sign Deficiency Andy, The new wellhouse sign for L-04 was installed today. Attached is a copy of the deficiency report and a picture of the sign in place. I have not sent this to the AOGCC. Thanks, Dave David Kindred GC2 Field Lead Operator 659-4128 H440 Alt: Rick Roberts From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity _ hilcorp.com> Sent: Sunday, November 29, 2020 12:43 PM To: Regg, James B (CED) <iim.reg (cDalaska.gov> Cc: Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieIdLO@hi1corp.com>; Alaska NS - PB - Field Well Integrity<PBFieldWelllntegrity@hilcorp.com> Subject: RE: [EXTERNAL] PBU L-04 Wellhouse sign Deficiency Mr. Regg, It appears to me that a wellhouse sign for L-104 was transferred over by a party that was not aware of 20 AAC 24.040. Communication of 20 AAC 24.040 has been relayed to the Field Lead Operators to ensure the Field Operators understand the regulatory requirement of proper Well Identification moving forward. Any signs found to be missing or displaying incorrect information are to be ordered with the proper information outlined in 20 AAC 24.040. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LOP hilcorp.com> Sent: Wednesday, November 25, 2020 2:24 PM To: Alaska NS - PB - Field Well Integrity<PBFieldWelllntegrity@hilcorp.com> Cc: Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieIdL0@hilcorp.com> Subject: FW: [EXTERNAL] PBU L-04 Wellhouse sign Deficiency Andy, FYI. The new wellhouse sign should be here soon. I don't know if you want to respond for Hilcorp about an explanation and what is being done. I cannot explain how the incorrect sign was installed. From: Regg, James B (CED) <iim.regg alaska.gov> Sent: Thursday, October 29, 2020 2:36 PM To: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Fie1dLO hilcorp.com>; Herrera, Matthew F (CED) <matthew. herrera@aIaska.gov> Cc: Alaska NS - PB - Field Well Integrity<PBFieldWelllntegrity@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com> Subject: RE: [EXTERNAL] PBU L-04 When the permanent sign is installed, include with the signed Deficiency Report an explanation of how this happened and what is being done to resolve well sign issues. Wrong information on well signs is a recurring problem. Jim Regg Supervisor, Inspections AOGCC 333 W. 711 Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LO@hilcorp.com> Sent: Monday, October 26, 2020 9:07 AM To: Herrera, Matthew F (CED) <matthew.herrera@alasl<a.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcarp.com> Subject: RE: [EXTERNAL] PBU L-04 Matt, A new wellhouse sign has been ordered for L-04. Attached is a photo of the sign with the correct well info on it until the permanent sign arrives. Regards, Dave David Kindred GC2 Field Lead Operator 659-4128 H440 Alt: Rick Roberts From: Herrera, Matthew F (CED) <matthew.herrera@alaska.gov> Sent: Sunday, October 25, 2020 2:14 PM To: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LO@hilcorp.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL] PBU L-04 Dave could you take care of this ASAP please and confirm by email upon completion. Thank You MATT II17RRI', RA PETROL173UH INSPI3 JOR AOGCC Matthew.herrera@alasl<a.gov 907-659-2714 Slope Office 907-229-2417 Work Cell 907-953-7966 Personal Cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: PBU L -Pad L-04 Date: 10/25/2020 PTD: 2061200 Operator: Hilcorp North Slope LLC Type Inspection: MIT Operator Rep: David Kindred Inspector: Matt Herrera Position: Lead Operator Op. Phone: 907-659-4128 Correct by (date): Op. Email: gc2fieldlo a hilcorp com Follow Up Required: Yes Detailed Description of Deficiencies Date Corrected While witnessing an MIT -T for well PBU L-04 PTD# 2061200 it was observed that the well house sign on well L-04 was actually a wellsign from L-104 PTD 201238 with the 1 marked out to look like 04. Operator is instructed to order and install the correct sign with all the correct well information ASAP �2 r 4-U Operator Rep Signatures: Matt Herrera AOGCC Inspector *After signing, a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must requested and accompanied byjustification (Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 1/14/2015 o J � H � M Z r N CIO 00 CY) C\j < m N N � UNC LU O (p a O� Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL L-04 (PTD 206-120) Water Flow Log 11/24/2020 Please include current contact information if different from above. Received by the AOGCC 12/02/2020 PTD: 2061200 E-Set: 34313 Abby Bell 12/02/2020 P6t,C L, -v4 Regg, James B (CED) M�� Z From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Sunday, November 29, 2020 12:43 PM To: Regg, James B (CED) Cc: Alaska NS - PB W - GC2 - Foreman; Alaska NS - PB W - GC2 - Field Lead Operator; Alaska NS - PB - Field Well Integrity Subject: RE: [EXTERNAL] PBU L-04 Wellhouse sign Deficiency Mr. Regg, It appears to me that a wellhouse sign for L-104 was transferred over by a party that was not aware of 20 AAC 24.040. Communication of 20 AAC 24.040 has been relayed to the Field Lead Operators to ensure the Field Operators understand the regulatory requirement of proper Well Identification moving forward. Any signs found to be missing or displaying incorrect information are to be ordered with the proper information outlined in 20 AAC 24.040. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LO@hilcorp.com> Sent: Wednesday, November 25, 2020 2:24 PM To: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Cc: Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com> Subject: FW: [EXTERNAL] PBU L-04 Wellhouse sign Deficiency Andy, FYI. The new wellhouse sign should be here soon. I don't know if you want to respond for Hilcorp about an explanation and what is being done. I cannot explain how the incorrect sign was installed. From: Regg, James B (CED) <jim.reE@alaska.gov> Sent: Thursday, October 29, 2020 2:36 PM To: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LO@hilcorp.com>; Herrera, Matthew F (CED) <matthew.herrera alaska. ov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcoM com> Subject: RE: [EXTERNAL] PBU L-04 When the permanent sign is installed, include with the signed Deficiency Report an explanation of how this happened and what is being done to resolve well sign issues. Wrong information on well signs is a recurring problem. Jim Regg Supervisor, Inspections AOGCC 333 W. 7`^ Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LOPhilcorp com> Sent: Monday, October 26, 2020 9:07 AM To: Herrera, Matthew F (CED) <matthew.herrera@alaska.gov> Cc: Regg, James B (CED) <iim.regg@alaska.gov>; Alaska NS - PB - Field Well Integrity <PBFie ldWelIIntegritV hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieIdLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com> Subject: RE: [EXTERNAL] PBU L-04 Matt, A new wellhouse sign has been ordered for L-04. Attached is a photo of the sign with the correct well info on it until the permanent sign arrives. Regards, Dave David Kindred GC2 Field Lead Operator 659-4128 H440 Alt: Rick Roberts From: Herrera, Matthew F (CED) <matthew.herrera@alaska.gov> Sent: Sunday, October 25, 2020 2:14 PM To: Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com> Cc: Regg, James B (CED) <iim.regg@alaska.gov> Subject: [EXTERNAL] PBU L-04 Dave could you take care of this ASAP please and confirm by email upon completion. Thank You MATT II17,RR17RA P1:TROL7UM INSPI?CTOR AOGC,C Matthew.herrera@alaska.gov 907-659-2714 Slope Office 907-229-2417 Work Cell 907-953-7966 Personal Cell above. If you are not an intended recipient or if you have received The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named y p' y ed this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 3 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-120 6.50-029-23319-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12330 10190 8979 8949 None 10190 8506 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31 - 111 31 - 111 1490 470 Surface 2668 9-5/8" 31 - 2699 31 - 2698 5750 3090 Intermediate 9130 7" 28 - 9158 28 - 8660 7240 5410 Production Perforation Depth: Measured depth: 9685 - 12237 feet True vertical depth:8895 - 8976 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 26 - 9015 25 - 8555 8949 8506Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Prod Packer Liner 3323 4-1/2" 9007 - 12330 8549 - 8996 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): HES pumped the following down the Tubing taking returns from the IA: 10-bbls of 60/40, 5-bbls of surfactant wash and mutual solvent, 88-bbls of 15.8 ppg Class G cement, 1-bbl of fresh water. Launch 1.75" phenolic ball & (2) 6" foam wiper balls, 2-bbls of fresh water. Chase cement with 124-bbls of diesel (final circulating pressure = 2700-psi) when ball landed on seat (pressure up to 3750-psi). Bled 2 bbls back thru choke to 0 psi. Observe no flow to tank. Estimated TOC: IA = 4612', Tubing = 8290'. Bottom in T& IA = 8882' Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 98009440 13540 0 0 0 1356 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Aras Worthington aras.worthington@hilcorp.com Authorized Name: Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-4763 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8996 Sundry Number or N/A if C.O. Exempt: 319-582 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 IA Cement Squeeze Operations shutdown Change Approved Program 5 IA cemented from 4060' to 8949' Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028239 PBU L-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): WFL Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Bo York By Samantha Carlisle at 1:52 pm, Nov 24, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.11.24 13:44:48 -09'00' Bo York MGR30NOV20 DSR-11/24/2020 SFD 11/24/2020RBDMS HEW 11/25/2020 ACTIVITY DATE SUMMARY 8/17/2020 ***WELL SHUT IN ON ARRIVAL*** PULLED 3.725" PXN PLUG FROM 8993' MD. (subsidence drift). ***WELL LEFT SHUT IN; READY FOR E-LINE*** 8/18/2020 T/I/O=300/800/650 Temp=SI Assist ELine (CEMENT SQUEEZE (OA/IA DWNSQZ) Pumped 140 bbls DSL down Tbg for load. Pumped 1.5 bbls DSL down Tbg to take it to 2761 psi. Tbg lost 67 psi in 5 min PT. PASS. Bled Tbg to 1300 psi and got back ~1 bbl. Eline in control of well per LR departure. FWHP's=1300/750/660 IA,OA=OTG 8/18/2020 ***WELL S/I ON ARRIVAL*** (HES E-Line CBP, TBG Punch, Cmt. Retainer) LRS LOADED THE TBG W/ 140 BBL'S OF DSL. SET 4-1/2" BAKER CBP AT 8,885' MD. LRS PT PLUG TO 2750 PSI (lost 67 psI in 5 minutes). PUNCH TBG 8878' - 8883' W/ 2", 4 SPF, 0 DEG PHASE GUN (no TxIA pressure response). ALL LOGS CORRELATED TO PDS COIL FLAG DATED 04-APR-2014. LAY DOWN EQUIPMENT FOR THE NIGHT. ***JOB CONTINUED ON 19-AUG-2020*** 8/18/2020 T/I/O = SSV/800/650. Temp = SI. IA FL (EL Request). IA FL @ surface. WS in control of well head & valves upon departure. 00:45 8/19/2020 ***JOB CONTINUED FROM 18-AUG-2020*** (HES E-Line TBG Punch) PUNCH TBG 8877.1' - 8882.1' W/ 2", 4 SPF, 0 DEG PHASE GUN (very minimal TxIA pressure response). ALL LOGS CORRELATED TO PDS COIL FLAG DATED 04-APR-2014. ATTEMPT UNSUCCESSFULLY TO CIRC-OUT WITH LRS. ***JOB INCOMPLETE ON 19-AUG-2020*** 8/19/2020 ***Job Cont from 08-18-2020 WSR*** (CEMENT SQUEEZE (OA/IA DWNSQZ)) Pumped 1 bbls DSL down Tbg to try and confirm communication with IA. Pressured up to 2500 psi. No communucation w/ IA. Bled down IA to 0 psi and still no communication. ELine to perf again. ***Job Cont from earlier WSR*** Pumped 7.5 bbls in attempt to pump down Tbg, up IA taking returns to OTT. Was not sucessful. Could pump about .6 bbls per bump up after intial pressure up. Pumped 6.5 bbls trying to circ down IA and up Tbg. Could pump ~.4 bbls per bump up after inital pressure up. ELine in control of well per LRS departure. FWHP's=670/2200/660 8/22/2020 T/I/O = 1320/680/650. Temp = SI. LLR TBG & IA (Eval T x IA). TBG FL @ surface. IA FL @ surface. Flowline disconnected behind wellhouse. P-Sub rigged up with kelly hose in wellhouse. Bled the IAP from 680 psi to 50 psi in 5 minutes (1.2 bbls, all fluid). Used 2.3 bbls of DSL to LLR TBG x IA to 2500 psi (.06 BPM @ 2500 psi, 4.5 bbls returned from IA). Used 2.7 bbls of DSL to LLR the TBG x IA to 4000 psi (.09 BPM @ 3950 psi, 7.6 bbls returned from IA). Used 3.76 bbls of DSL to LLR the IA x TBG to 2500 psi (.12 BPM @ 2450 psi, Job continued on next AWGRS dated 08-22- 20/ 8/22/2020 T/I/O = 1400/830/650. Temp = SI. LLR IA (Eval PC leak). Established a LLR down the IA at an average of 2.79 GPM at 2990 psi with 3000 psi on the tubing. See log for details. Shut down pump and monitor pressures for 30 min. TP decreased 890 psi and the IAP decreased 1020 psi. Final WHPs = 2100/1470/650. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:59 Daily Report of Well Operations PBU L-04 Daily Report of Well Operations PBU L-04 9/1/2020 T/I/O= 500/500/650. LRS Unit 72 Assist E-Line (CEMENT SQUEEZE) post TBG punch. Pumped 180 bbls of diesel into the TBG while taking IA returns to OTT. Got back 188 bbls of returns through micro motion sensor. 6.9 ppg returns when the pump was shut down. Final T/I/O= 0/0/650. 9/1/2020 ...Well shut in on arrival... (HES Eline - Tubing Punch, Cement Retainer) PUNCH TUBING FROM 8,877' - 8,882' WITH 5' x 2" PUNCHER. SET 4-1/2" MAGNUM OIL TOOLS POPPET STYLE COMPOSITE CEMENT RETAINER AT 8,870'. ***Job Complete. Well shut in on departure. Ready for cement.*** 9/10/2020 HES Cementing Services Objective: IA cement squeeze. HES pumped the following down the tbg taking returns from the IA, 10 bbls of 60/40, 5 bbls of surfactant wash and mutual solvent, 88 bbls of 15.8 ppg Class G cement, 1 bbl of fresh water. Launch 1.75" phenalic ball & (2) 6" foam wiper balls, 2 bbs of fresh water. Chase cement with 124 bbls of diesel when ball landed on seat. Volumetrically the ball landed 9 bbls early indicating cement top in tbg will be at 8278'. Bled 2 bbls back thru choke to 0 psi. Observe no flow to tank. Grease crew service tree. RDMOL EST TOC: IA = 4612' Tbg 8290' Bottom in T& IA 8882' 9/15/2020 ***WELL S/I ON ARRIVAL*** RIG UP SLICKLINE. RUN 2-1/2" PUMP BAILER. TAG TOC @ 8715' SLM, ~ 155' ABOVE CMT RETAINER. BAIL CONTAMINATED/GREEN CEMENT DOWN TO 8744' SLM. ***WSR CONTINUED ON 9-16-20*** 9/16/2020 T/I/O=499/vac/641. Pre AOGCC MIT-IA PASSED to 2580 psi [Cement Squeeze]. IA lost 21 psi in 1st 15 min and lost 19 psi in 2nd 15 min for total loss of 40 psi in a 30 minute test. Pumped 2 bbls diesel to reach test pressure, bled back ~1.5 bbls. Tags hung on WV and IA FWHP-500/0/642. 9/16/2020 ***WSR CONTINUED FROM 9-15-20*** BAILED CEMENT FROM 8744' TO 8753' SLM. DECISION MADE TO RIG DOWN & TURN OVER TO COIL. ***WELL LEFT S/I*** 10/10/2020 CT #9 1.75" Coil Tubing - Job Scope: Mill cement/Mill CMT retainer & CBP MIRU. MU & RIH w/ BOT 3.8" milling BHA. Tag TOC at 8759' ctm, Begin Milling ***Job Continued on 10/11/2020*** 10/11/2020 T/I/O = SSV/VAC/770. Temp = SI. IA FL (post CT cement millout). IA FL @ 60' (2 bbls). SV = C. WV, SSV, MV = O. IA, OA = OTG. 21:30 10/11/2020 CT #9 1.75" Coil Tubing - Job Scope = Mill Cement/Retainer/CBP Milling ahead using sweeps. Mill to 8875'. Dry tag XN at 8987'. POH. RIH w/ 3.70" mill BHA. Tag at 9371' & push to 10182ft. POH. FP well w/ diesel. Issues with diesel transport. FP well w/ 60/40. RDMO. ***Job Complete*** Daily Report of Well Operations PBU L-04 10/12/2020 T/I/O=540/vac/740 SI MIT IA PASSED to 2500 psi. Max applied 2750 psi Target pressure 2500 psi (CEMENT SQUEEZE OA/IA DWNSQZ) Pumped 2.36 bbls DSL down IA to achieve test pressure of 2740 psi. 15 min loss of 166 psi, 30 min loss of 46 psi, for total loss of 212 psi in 30 mins. Bled back ~1.1 bbls. Tags hung on IA/WV WSL/Pad Op notified Valve positions=SV WV SSV closed MV open CVs OTG FWHP=470/0/740 10/19/2020 T/I/O = 550/0/740. Temp = SI. MIT x IA Passed to 2633 psi (AOGCC witnessed by Bob Noble). Max applied pressure = 2700 psi. Test pressure = 2500 psi. On the second attempt, used 1.25 bbls of DSL to increase the IA to 2699 psi. The IA lost 44 psi in the first 15 minutes and 22 psi in the second 15 minutes for a total 30 minute loss of 66 psi. Bled the IAP (1.25 bbls) Tag hung. AFE sign already in place. FWPs = 550/0/750. SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:50 10/24/2020 T/I/O= 580/20/775. LRS unit 72 Assist Slickline (CEMENT SQUEEZE) Pumped 177 bbls of crude into the TBG. S/L set plug. Bump test it t0 1340 psi with 0.67 bbls of crude. S/L POOH. MIT-T to 2500 psi *PASSED* at 2643 psi (2750 psi max applied). TBG lost 75 psi during the 1st 15 minutes and 24 psi during the 2nd 15 minutes. TBG lost 99 psi during the 30 minute test. Pumped 1.3 bbls to achieve test pressure. Bled back 2.1 bbls to T/I/O= 266/141/735. MIT-IA to 2500 psi *0ASSED* at 2538 psi (2750 psi max applied). IA lost 155 psi during the 1st 15 minutes and 43 psi during the 2nd 15 minutes. IA lost 198 psi during the 30 minute test. Pumped 1.2 bbls to achieve test pressure. Bled back 1.3 bbls to Final T/I/O= 341/170/735. 10/24/2020 ***WELL S/I ON ARRIVAL*** (cement squeeze) BRUSH & DRIFT TO XN @ 8993' MD SET 4.5" PXN PLUG @ 8993' MD SET PXN PRONG @ 8993' MD ***CONT. TO 10/25/20 WSR*** 10/25/2020 T/I/O= 420/240/720. LRS unit 72 Assist Slickline (CEMENT SQUEEZE). AOGCC Matt Herrera witnessed MIT-T to 2500 psi *PASSED* at 2594 psi (2750 psi Max Applied) TBG lost 104 psi during the 1st 15 minutes and 37 psi during the 2nd 15 minutes. TBG lost 141 psi during the 30 minute test. Pumped 1.9 bbls to achieve test pressure. Bled back 1.8 bbls to Final T/I/O= 407/258/725. 10/25/2020 ***CONT. FROM 10/24/20 WSR*** (cement squeeze) LRS PERFORM STATE WITNESS MIT-T (Matt Herrera) LOG READ CBL TOOLS FROM 8955' SLM TO 3,000'. TOC FOUND AT 4060' MD. ***CONT. TO 10/26/20 WSR*** 10/26/2020 *** CONT. FROM 10/25/20 WSR*** (cement squeeze) PULL PXN PLUG AND PRONG FROM 8993' MD ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 10/31/2020 T/I/O = 1220/940/250. Temp = 112°. Bleed IAP (UIC). On PWI. IA FL @ near surface. Bled IAP to BT from 940 psi to 400 psi in 5 min (Gas to energized fluid, 5 gal). OAP unchanged. Monitored for 30 min. IAP increased 30 psi. Final WHPs = 1220/430/250. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:10 11/2/2020 T/I/O=1353/697/260 AOGCC MIT IA PASSED to 2500 psi (Witnessed by Brian Bixby) Pumped 1 bbl diesel to test @ 2780 psi. IAP lost 113 psi 1st 15 min and 19 psi 2nd 15 min. Blrd back 1 bbl FWHPs=1351/700/261 Daily Report of Well Operations PBU L-04 11/23/2020 ...Well Injecting on Arrival... (HES Eline - WFL) PERFORM WFL STOP COUNTS WITH TMD3D AT 9,000', 8,500', 8,000', and 7,500' WHILE ON INJECTION. NO UPWARD FLOW DETECTED. LOG BASELINE TEMPERATURE PASS DOWN FROM 6,500' to 9,000'. LOG 1HR WARMBACK TEMPERATURE PASS FROM 9,000' to 6,500'. LOG 3HR WARMBACK TEMPERATURE PASS FROM 9,000' to 6,500'. ***Job Complete. Well Injecting on depature.*** Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well L-04 (PTD 206-120)Sundry #:319-582Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCCby the rig workover (RWO) “first call” engineer.AOGCC written approval of the change is required before implementing the change. SecPageDateProcedure ChangeNew 403 Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC Written Approval Received (Person and Date)N/AN/A07/22/2020Changed program from pumping cement with Coiled Tubing to pumping cement FullboreNAJWAJWMel Rixse 07/22/2020N/AN/A08/24/2020Changed program to allow for punching tubing ~200’higher (if needed) due to failed tubingpunches and uncertainty about fill in the IANAJWAJWMel Rixse08/24/2020Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer DateDigitally signed by ArasWorthington (4643)DN: cn=Aras Worthington (4643),ou=UsersDate: 2020.10.29 13:11:53 -08'00'ArasWorthington(4643)Digitally signed by Stan GolisDN: cn=Stan Golis,ou=UsersDate: 2020.10.29 15:53:47 -08'00'Stan Golis MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name PRUDHOE BAY UNIT L-04 IInsp Num: mitBDB201102155506 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 3, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-04 PRUDHOE BAY UNIT L-04 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-23319-00-00 Inspector Name: Brian Bixby Permit Number: 206-120-0 Inspection Date: 11/2/2020 Tuesday, November 3, 2020 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-04 Type Inj u' TVD 8507g TUbin 1353 1355 1352 - 1351 _ PTD 2061200 Type Test SPT Test psi 2500 IA 697 2780 _ 2667 2648 _ BBL Pumped: 1 BBL Returned: I - OA 260 262 263 , 262 - Interval OTHER Notes: MIT -IA as per SUNDRY 319-582 and also under CO 736 3�& s l La z Tuesday, November 3, 2020 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, November 3, 2020 P.1. Supervi�4� 1�,� Z�� sor SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-04 FROM: Bob Noble PRUDHOE BAY UNTP L-04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -Z-9'p— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT L-04 Insp Num: mitRCN201019164604 Rel Insp Num: API Well Number 50-029-23319-00-00 Inspector Name: Bob Noble Permit Number: 206-120-0 Inspection Date: 10/19/2020 Tuesday, November 3, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-04 ''T a In N TVD 8507 - Tubin g (Test ss3 558 - - Sag - sal . - PTD - 2061200 Type Test _ psi 2L00 IA 2487 2699 - 2655 � 2633 ' BBL Pum p ed � 0 iBBL RetlUrned' OA 752 752 - 750 - 752 Interval OTHER �P/F P Notes: AOGCC MIT -IA per Sundry 319-582 of 2500 psi, Second attempt. lir Tuesday, November 3, 2020 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Tuesday, November 3, 2020 P.I. Supervisor ' \g a� c61�, SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-04 FROM: Bob Noble PRUDHOE BAY UNIT L-04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprvi 3L NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT L-04 API Well Number 50-029-23319-00-00 Inspector Name: Bob Noble Permit Number: 206-120-0 Inspection Date: 10/19/2020 - Insp Num: mitRCN201019164035 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-04 Type Inj I N TVD 8507 Tubing 550 614 565 553 PTD 2061200'Type�TePT Test psi 2500 IA 0 2691 2531 248BBL Pumped- 1.3 Returned: 0 OA 743 755 752752 Interval OTHER P/F F � --- Notes: AOGCC MIT -IA as per Sundry 319-582 of 2500 psi. Test pressure dropped below 2500 psi in the last 30 min so well was bumped up and done over. —_- V C�v-"SO'tee-e,-,e— Tuesday, November 3, 2020 Page 1 of 1 fl�C L-o4- Reqq, James B (CED) From: Regg, James B (CED)�� Sent: Thursday, October 29, 2020 2:36 PM To: Alaska NS - PB W - GC2 - Field Lead Operator; Herrera, Matthew F (CED) Cc: Alaska NS - PB - Field Well Integrity; Alaska NS - PB W - GC2 - Foreman Subject: RE: [EXTERNAL] PBU L-04 When the permanent sign is installed, include with the signed Deficiency Report an explanation of how this happened and what is being done to resolve well sign issues. Wrong information on well signs is a recurring problem. Jim Regg Supervisor, Inspections AOGCC 333 W. 7" Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LO@hilcorp.com> Sent: Monday, October 26, 2020 9:07 AM To: Herrera, Matthew F (CED) <matthew.herrera@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2 Field LO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com> Subject: RE: [EXTERNAL] PBU L-04 Matt, A new wellhouse sign has been ordered for L-04. Attached is a photo of the sign with the correct well info on it until the permanent sign arrives. Regards, Dave David Kindred GC2 Field Lead Operator 659-4128 H440 Alt: Rick Roberts From: Herrera, Matthew F (CED) <matthew.herreraQalaska.gov> Sent: Sunday, October 25, 2020 2:14 PM To: Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com> Cc: Regg, James B (CED) <iim.regg@alaska.gov> Subject: [EXTERNAL] PBU L-04 Dave could you take care of this ASAP please and confirm by email upon completion. MEMORANDUM TO: Jim Regg �06� (pl Zsi �7czc P.I.Supervisor FROM: Bob Noble Petroleum Inspector Well Name PRUDHOE BAY UNIT L-04 Insp Num: mitRCN201019164035 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 26, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L4pt PRUDHOE BAY UNIT 404 Bre: Inspector Reviewed By: P.I. Sup" -3-512— Comm API Well Number 50-029-23319-00-00 Inspector Name: Bob Noble Permit Number: 206-120-0 Inspection Date: 10/19/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L -o4 , Type Inj N ITVD 8502 Tubing 550 614 565 553 ' PTD 2061200 Type Test I spr Test psi 2500 IA 0 2691 - 2531 2489 - BBL Pumped: 0.2 BBL Returned: 0 OA 243 _ 255 252 252 Interval OTHER P/F F Notes: AOOCC MIT -IA as per Sundry 319-582 of 2500 psi. Test pressure dropped below 2500 psi in the last 30 min so well was bumped up and done over. V�OSi' -�- C2.MPn'F S�iti2P�. e Sf z010Ict Monday, October 26, 2020 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector 10IZ,1(2{ zz. NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Monday, October 26, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC W4 PRUDHOE BAY UNIT L-04 Src: Inspector Reviewed By: P.I. Sup" 10-6f2— Comm Well Name PRUDHOE BAY UNIT L-04 API Well Number 50-029-23319-00-00 Inspector Name: Bob Noble Permit Number: 206-120-0 Inspection Date: 10/19/2020 Insp Num: mitRCN201019164604 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-04 - Type Inj N 'TVD 8507 Tubing 553 1 558 549 - 547 PTD 2061200 'Type Test SPT Test psi 2500 IA 2487 - 2699 - 2655 2633 - BBL Pumped: 10.1 BBL Returned. 0.2 OA 7sz - 7sz • 750- 752 . Interval OTHER - IP/F P Notes: AOGCC MIT -IA per Sundry 319-582 of 2500 psi, Second attempt. U Sn fug A1�rq�5d - Srts� Rpt" w1'>Lvio1°lle4o35 Monday, October 26, 2020 Page I of 1 MEMORANDUM TO: JimRegg (t�Za(�ru, P.I. Supervisor Z FROM: Matt Herrera Petroleum Inspector I Well Name PRUDHOE BAY UNIT L-04 Insp Num: mitMFH2O1025122650 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 28, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-04 PRUDHOE BAY UNIT L-04 Ste: Inspector Reviewed By: P.J. Supry 1399— Comm API Well Number 50-029-23319-00-00 Inspector Name: Matt Herrera Permit Number: 206-120-0 Inspection Date: 10/25/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1,-04 Type Inj N - TVD sso7 -Tubing PTD 1061200 - Type Test SPT•'Test psi 2500 J�Z�A BBL Pumped: `> BBL Returned: 1 Interval OTHER P/F P Notes: %IIT -T Performed by Operations per Sundry 319-582 R)5}- 415 - 2735 2631' 2694 241 413 - 420 - 417 -� lis _Ts-. 7zs�-- _ �zs_ I Wednesday, October 28, 2020 Page 1 of I P66C L-04 Prb Zof-Izoo Regg, James B (CED) From: Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com> Sent: Monday, October 26, 2020 9:07 AM 2!�' q 10��1(�d110 To: Herrera, Matthew F (CED) Cc: Regg, James B (CED); Alaska NS - PB - Field Well Integrity, Alaska NS - PB W - GC2 - Field Lead Operator; Alaska NS - PB W - GC2 - Foreman Subject: RE: [EXTERNAL] PBU L-04 Attachments: Resized_Resized_20201025_182107001J peg; L-04 Final Jpg; Deficiency Report PBU L-04.xlsx Matt, A new wellhouse sign has been ordered for L-04. Attached is a photo of the sign with the correct well info on it until the permanent sign arrives. Regards, Dave David Kindred GC2 Field Lead Operator 659-4128 H440 Alt: Rick Roberts From: Herrera, Matthew F (CED) <matthew.herrera@alaska.gov> Sent: Sunday, October 25, 2020 2:14 PM To: Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LO@hilcorp.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL] PBU L-04 Dave could you take care of this ASAP please and confirm by email upon completion. Thank You MATT Ii13RRIIILA PETRIILRIJM INSPIN'TOR AOGCC Matthew. herreraC@alaska.Rov 907-659-2714 Slope Office 907-229-2417 Work Cell 907-953-7966 Personal Cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/29/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GPB L-04 (PTD 206-120) RCBL Radial Cement Bond Log 10/25/2020 Please include current contact information if different from above. PTD: 2061200 E-Set: 34138 Received by the AOGCC 10/29/2020 Abby Bell 10/30/2020 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Wednesday, October 28, 2020 10:38 AM To: Wallace, Chris D (CED) Cc: Regg, lames B (CED); Stan Golis; Aras Worthington; Oliver Sternicki Subject: OPERABLE: Injector L-04 (PTD #2061200) passed MITs post IA cement squeeze Mr. Wallace, Injector L-04 (PTD #2061200) was made Not Operable on 08/01/19 after it failed a MIT -IA. A leak detect log was performed on 10/02/19 and identified a production casing leak. Coil tubing performed an Inner Annulus cement squeeze on 09/10/20 in accordance with Sundry #319-582. An offline AOGCC witnessed MIT -IA passed on 10/19/20 and an AOGCC witnessed MIT -T passed on 10/25/20. The passing MITs confirm two competent barriers and the well will now be classified as Operable. Once the well is on stable injection, a water flow log and an AOGCC witnessed MIT -IA will be performed. Note the fluid packed annulus when bringing the well online. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance and rew.ogg@hilcorp.com P:(907)659-5102 M: (307)399-3816 AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: rsday, August 1, 2019 10:50 AM To: AK, GWell Integrity Engineer<AKGWOWellSiteEnginee@bp.com>;'chris.wallace@alaska.gov' <chris.wallace aska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2Facilit @bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.co • AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com K, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad OFT N2 <AKOPSWeliPadDFTN2@bp.com>; AY,.OPS Well Pad HUQ <AKOPSWeliPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPad LV@bp.com>; AK, OPS VkU.Pad MN <AKOPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPad RJ@bp.com>; AK, OPS WELL P <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeliPadSW@bp.com>; AK, OPS WELL PAD KOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <Ak0 estAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Nottingham, Derek erek.Nottingham@bp.com>; Peru, Cale <Cale.Peru@bp.com> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHD ntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPTI Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWeIIOp ompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Hibbert, Michael <Michael. ert@BP.com: Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrige 'tch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, ArasJ State of Alaska v� Oil and Gas Conservation Commission I01vil zek Deficiency Report Location: PBU L-Pad L-04 Date: 10/25/2020 PTD: 2061200 Operator: Hilcorp North Slope LLC Type Inspection: MIT Operator Rep: David Kindred Inspector: Matt Herrera Position: Lead Operator Op. Phone: 907-659-4128 Correct by (date): Op. Email: gc2fieldlo@hilcorp.com Follow Up Required: Yes Detailed Description of Deficiencies Date Corrected While witnessing an MIT-T for well PBU L-04 PTD# 2061200 it was observed that the well house sign on well L-04 was actually a wellsign from L-104 PTD 201238 with the 1 marked out to look like 04. Operator is instructed to order and install the correct sign with all the correct well information ASAP Operator Rep Signatures: Matt Herrera AOGCC Inspector *After signing, a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must requested and accompanied by justification (Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 1/14/2015 r� ■ s• cu m O t CL 0 0 O /0 (D M N N 9 V. T cc z N T LY, i Cl) Co N r N I THE STAATE, c e 0fALASKA GOVERNOR MIKE DUNLEAVY Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU L-04 Permit to Drill Number: 206-120 Sundry Number: 319-582 Dear Mr. Obrigewitch: Alaska Oil and Orals Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l a s ka. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �>>V, J e Price C r DATED this S— day of January, 2020. IBDMS L& JAN 0 3 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 da.J rZG.3��/5 DEC 9 °3M3 a'R2G D�-1 Form 10-403 Revised 04/2017 Approved application alip fir I G1slydRlhletlL appni Submit Form and Attachments in Duplicate 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate RI - Other Stimulate ❑ Pull Tubing ❑ AR QQC cram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter -Casing ❑ Other IA Cement Squeeze 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 206-120 - 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612Stratigrephic ❑ Service 0 6. API Number: 50-029-23319-00-00 - 7. If perforating: C.O. 341H What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 - PBU L-04 - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028239 PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (R): Total Depth TVD(f0: Effective Depth MD' Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12330 8996 8993 8539 8993.10190 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31 - 111 32-112 1490 470 Surface 2668 9-5/8" 31-2699 31-2699 5750 3090 Intermediate 9130 7" 28-9158 28-8660 7240 5410 Production Liner 3323 4-1/2" 9007-12330 8549-8996 1 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (K)' 9685-12237 8895 - 9017 4-1/2" 12.6# L-80 L-80 26-9015 Packers and SSSV Type: 4-1/2" Baker S-3 Prod Packer Packers and SSSV MD (ft) and TVD (ft): 8949 / 8507 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 - 14. Estimated Date for Commencing Operations: 1/20/2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0. GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name. Obrigewitch, Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCH@bp.00m Authorized Name: Obrigewitch, Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integnty Engineer Authorized Signature: Date. G Cl COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / I., `"� Plug Integrity ❑ BOP Test ❑ Mechanical Integnty Test rdr Location Clearance E]_ Other. /�-ttt'ri3L'S S M !T --X—A i--. 25-6 (5 t4 v 4- ko•r r 1C,P4 (l Rr,D E'2 c© r7 39 Post Initial Injection MIT Req'd? Yes ❑ No ❑ MMS.9/'"IAN 0 3 2020 Spacing Exception Required? Ye No 2 Subsequent Form Required. `�- y� `/ APPROVED BYTHE I „ Approved by: ♦, COMMISSIONER COMMISSION (�(J Date. I a'R2G D�-1 Form 10-403 Revised 04/2017 Approved application alip fir I G1slydRlhletlL appni Submit Form and Attachments in Duplicate 30-403 Sundry Application for Well PBU L-04 PTD #206-120 Expected Start Date: January 20, 2020 Current condition of well: WAG Injection Well, Not Operable, Offline: Water Injection Rate: 0 bw d Gas Injection Rate: 0 Mscf/Da Injection Pressure: 28 psi Reservoir Pressure -04 Offset): 3850 psi Program Objective(s): Well L-04 was found to have a PC leak at 6,750' MD and has been shut-in since 7/18/19. This appears to be the only leak. By repairing this well with an IA cement squeeze, it is estimated that an incremental 270 mbo can be produced over the next several years. Without an IA remedial squeeze, the well has no utility in the foreseeable future. Our plan is to perform a cement squeeze to address the PC leak and return the well to operable. Proposed Program Details: 1. Pull TTP and Subsidence drift 2. Set composite plug 3. MIT -T 4. Punch Tbg e 5. Confirm injectivity into IA; swap well to dsl a °� 6. Set composite retainer �Q S 7. Cement IA to 4,200' 8. Mill retainer / composite plug and CIBP b 9. Push CIBP as deep as possible "C 10. Add perfs 11. Cement Bond Log 12. MIT -IA 13. Set TTP 14. MIT -T 15. Set MCX, 8MM target 16. Classify Well as Under Eval and POI on MI 17. AOGCC MIT -IA to 2,500 psi 18. Add well to recurring MIT -IA, MIT -T and WFL schedule every 2 years. Proposed Perforating Procedure: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Here is the information you requested for the IA cement job on GBP Well L-04. With the exception of the service line, as listed in the second column, I have highlighted the requested information. Summary Service Line Activity Ste # P 1 Slickline a. Pull TTP b. Subsidence drift a. Set composite plug @ 3,8952 b. MIT -T 2500 psi 2 Eline c. Punch Tbg across collar @^'8,877' d. Confirm injectivity into IA; swap well to dsl e. Set composite retainer @8,855' Assist Eline: 3 Fullbore a. Load as needed b. MIT c. Circ to Diesel a. Cement IA to 4,200` b. WOc —� c. Mill retainer / composite plug and CIBP 4 Coiled Tubing d. Push CIBP as deep as possible e. Add perfs: 10,187'-10,118'; 10,164'-10,.195'; 10,297'-10,328'; 10,326'-10,393- a. Cement Bond Log - Submit log tQQ AOGCC ,F.e Zi �eL b. MIT -IA to 2,500 psi 5 Slickline c. Set TTP d. MIT -T (test squeeze holes) to 2,500 psi e. If pass pull TTP f. Set MCX @ 2,009'; 8MM target 6 Fullbore Assist SL: a. MITs 7 Well Diagnostics Classify Well as Under Eva] and POI 8 Well Diagnostics AOGCC MIT -IA to 2,500 psi ss 30-403 Sundry Application for Well PBU L-04 PTD 13206-120 Proposed Perforating Procedure: wOPROPOSED PERFORATING PROCEDURE global wells organization well. L-04 API e: Date: Prvd Engineer: eeeeaaease Primary% Peru Secondary% (907)564.4522 (532)M-5774 H2S Level: 125ppm_ _70!3012019- __Cale ."_ CC or AFE: WEIL Entries IDR _ _ . 7YPE block D _ " _____r____________ ---S! -tion ______________-_______ ---- ;See Procedure --------------- L________________L_---- __________________"_____________________________"____"...____________. ----------- _..__._ ----- — Nell Objectives and Perforating Notes: See Procedure Attachment: Tie -Into wdhwor,osedperfsamotated. Reference Log Tien Log Add -2 feet MWD Coil Flag to the tie-in log .......... to be on depth LOG: _ _ wNh the reference log DATE: Company:. Depths(from - to) De hs (hom-to) Feet SPF Orientation Phasing Zone PERFTYPE 1p,360' 10,391' 10,362 _"__"__._._____" 70,393 31' 6 .___""____.______. _ random 60' 43 ADD PERF ,326__ ___""_______ ________"______ ____ 10,295' 10,326' " - -- ----' 70,328'----. ----- 31_ " "_""__6 _ _ "___. ..____.__ .._______ random 60 43 ADD PERF 10,162_" , 10,193' 10,184' _ "___"__________ _____"__ ____ __ ._ 10.195'" ....3T-_.. -__---- - ,_-_- _..._..___"________.. random 44 ______._______ ADD PERF 70:085_.._ 10,716' ___--i 7___.. ._______ .____%716'_ ___31. ____6 ___ _---... "_"" r3!'d4!n "___6Q_ ____"__"_"_. ______._______. ___44_"_ ADD PERF 3406 PowerJet Requested Gun Size -- --------- ----'----, Charge .HMX Min Wellbore 10: 3,73 Max Swenin Liquid::3.66" Max Swigin Gas' Is Drawdown NecesmarylDeslredlUnnecessary During Perforating --------------_ __ ------ _____Unnecessa�_ Preferred Amovmof DrawdownlSu99estions to Achieve Drawdown -_"_ _ _ ----------- ---""""""""__"-"" '"_"" Last Drift: 10187_-, fIMDon 1012312015 Est Res, Pressure @ 8,800'TVDss Misr psi N- opsi BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU L-04 PTD #206-120 Tie In Log: V. PaoAcrivE K>iAcmosvic StrtwlcEs Company B Well L < Field P .2 >1 Borough N ro 0- 0 0 Surface Location CL 0 CO Wo -0r = 1= 5 2380 w C) -0 t� CO 0 co CL z < SEC 34 >1 Permanent Datum CL E :2 0 Log Measured From 0 0, u ir con (-0 API Serial Number Time COIL FLAG UMT-GR-CCL 04 -Apr -2014 D EXPLORATION (ALASKA) -04 10204254( RUDHOE BAY 1111111111 DRTH SLOPE state ALASKA 118' FSL & 1,566.17' FWL TWP' 12N RGE: 11117 MSL T Elevation 0.0 RK8 76.5 FT. Above Perm. Datum 50-029-23319-00 io.556' -- 6,806, - ----- FI I T Surface2 E6 �0E Surface BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 30-403 Sundry Application for Well PBU L-04 PTD #206-120 lzk Composite Main Up Pass a` -' Start Pass @ 1212 PwM�.�ly� Ol�pwer s Sew Database Fidd lwarriaWata4-� coiftg 4 144nain_3.db Dataset Pathname passu Presentation Format codttq Dataset Creabon. Fn Apr 04 15.01:15 2014 by Calc Warrior 8.0 STD Cas Charted by. Depth in Feet sewed 1.240 .. �....o, _ .,.__,.,._...,,,,_„._ ..mow.. __ .___, .. ................ .�.:,�.,...,.. .. _.._ . (8000 CCL -1965) 0 Gamma Ray (GaPry 100: �0 Cal Sneed tlUntinl -200° 8900 -X- µppte Packer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU L-04 PTD #206-120 ) r t 10 1 i �s s *'—ECP @ F" CVM f 1� 12212's "_ 4 ---CCI NF (y` Fiaq STepNi a i^v,GS: CY ;. e I Add perfs: 10,087 to 10,118' 10100 j Add perfs: 10,164 to 10,195' / BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU L-04 PTD #206-120 4 f a f Add per`s: 10,297 to 10,328' j z s - Add perfs: 10,362 to 10,393' i t w cooSO e BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 i 10-403 Sundry Application for Well PBU L-04 PTD 4206-120 Current Wellbore Schematic: 9-5/8' CSG, 40I, L-80 DTC. D- 8.835' H 2WV :Minimum ID =3.725" @ 8993' j4-112- HES XN NIPPLE r_.. -r..—_..__-..._6._---._,_' r--.__. ESTMATEO TOPOf CEMEHI'(OSR2tl71 '-I _410T _. 7' CSO, 289, L -W DTC -K D=9270' 8168' FE14XMTDN SLNWARY RFF LOG: NFNDON 10!09(06 AWASAT TOPPER: 79' Q WAV Ner to Production DS for eetorcal D FOR F EWORATDN DATA es72• a-1rcHaxNP,D-a41r D=4.40' IiADTT LOGGED NOT LOGO I P9tD r1 12243' 41? WR fa 84, L-00 BAd, of 52 -{' —PRUDHOESAYLM WELL L-04 PE.RWW:'2W1270 API W: 50029-23319-M SEC 34, T12K R11E,238U FSL 81566' FAM. OP EVIomdw OAbska1 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 L-04 SAFETY NOTE: WELL ANGLE>70-094W-H2S REQUIRES A SSSV WHEN ON MFWA13W-S AVERAGE 125 PPMMI-NOTE E WATCH NBLiAD= ii'FAC ACTUATOR_ LEO - CW. E.EV78S IBF. �v= --7 FDR COMPOS TE PLUG DEBRS(4 PLUGS MILD KCPo.. .. 3909' Od?NOTI'.. '.., Ar4eMD 99' 10828' Qwt CatwnAO= 9578' 20'CCFDLICT'CR 74' 2DOW 4 -IW HESX W. D=3.Bfr LLuxnNO= BBDO SS 9-5/8' CSG, 40I, L-80 DTC. D- 8.835' H 2WV :Minimum ID =3.725" @ 8993' j4-112- HES XN NIPPLE r_.. -r..—_..__-..._6._---._,_' r--.__. ESTMATEO TOPOf CEMEHI'(OSR2tl71 '-I _410T _. 7' CSO, 289, L -W DTC -K D=9270' 8168' FE14XMTDN SLNWARY RFF LOG: NFNDON 10!09(06 AWASAT TOPPER: 79' Q WAV Ner to Production DS for eetorcal D FOR F EWORATDN DATA es72• a-1rcHaxNP,D-a41r D=4.40' IiADTT LOGGED NOT LOGO I P9tD r1 12243' 41? WR fa 84, L-00 BAd, of 52 -{' —PRUDHOESAYLM WELL L-04 PE.RWW:'2W1270 API W: 50029-23319-M SEC 34, T12K R11E,238U FSL 81566' FAM. OP EVIomdw OAbska1 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU L-04 PTD #206-120 Proposed Wellbore Schematic: TT4T- 4IMWCNV 4SRd" CSG. 40I, L-80 BTC, O - 8.695' 2998• Minimum ID =3,725" @ 8993' 14-112" HES XN NIPPLE ESTMATED TOP OFCEMENT (OWMA17�-1�91D2— 7" CNG, M . L -OO GT M710---G-2-76---j 9168' FHSORATIONSUTAMRY Rff LOG: MAD ON 1009M ANGLE AT TOP PBS. 79' Q 9685• PBTD SAFETY NOTES: WELL ANGLE>7(W t1 4498'»•WS READINGS AVERAGE 125 ppm W HEN ON MI "' WELL REQUIRES A SSSV WHEN ON MR ^ NOTE: WATCH FORCOMPOSITE PLUG OEM (4 PLUGS MILLED 86fffi07) ^ a&V z,'ypb OD � &972' 4-ird' HEs x N�, w 9.a13• : i _ I ii 4-1R'HESXNW.0-3725'. PXNpLUO(Wg011@) 80OT T•x 5-irz•hRD ZXr IIR• wf TEDACK SLV, D= 4.40' 8919' 4- AFWE6:6-4.00' 8028' 7'X5" SKR FLEX LOCK LNR HGR, D=4.400' ® 5-X4-1?XO, O=3.958' i 8A®Tf LOGGED NOT LOGGED BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 PRUHEIEBAYLNR -_- WELL L-04 PERMITW:'GWl 00 APIW 5DO29-233190D SEC 34, T12K RI IE. 2380 FSL& 1565 FVA 8P Expkaom (Nash) 10-403 Sundry Application for Well PBU L-04 PTD #206-120 Proposed P&A Wellbore Schematic: mg -b- k mn MD= irculated into All Strings I Minimum lD = 3.726" @ 8993' 4-1t2" HES XN NIPPLE Er, S1 ' D TOP OF CIE MENT(p5N -7 —j-- - 9107 T' CSC, 260, L40 BTC K D+6276• 91W PERFORATION SLNTNIRY REF LOG: MND ON 10N9M6 ANGLEAT TOP PE F: 79• @ 9665' PLIe: Refer to Pmduc 0a (or his d A e (PBro_,h 1224T_-6wvvci '4�1?LNR1284:L-00 BT#1_0192 Mop 9858_, 11233e' f,—DO•omon0Q0C1o� SAFETY NOTES: WELL ANGLE a 70° Q 94W—H26 ISA ONGS AVERAGE 125 pP16 WHEN ON MI "' WELL REQUIRES A SSSV WHEN ON Mr — NOTE: WATCH FOR COMPOSITE PL UG OEifiS (4 PLUGS MILLED 0622107( " gaze' tilrrrsxNlP.D=3bi3• ; ease' 7-xa12•eKRsaPRODPKR,D=3.ers 6977 412"�axrr, D=3.e13• ' —j R.1Q•HE8 %N NP.D•7TM• `_ Wa3' ;R1/C P%N PLUG (OTOO/18) � �� 7'%61te'HRD 2XPLTP � Ln' M0-1SLV,D=4.40' 9016' a-ur�M FG.n=anrc L� 7-% 5• BKR FLEX LOCI( LN2 TICK D=6.400• �--�—I S' %4-12' XO, D=1858• ELhDTr LOGG®NOTLOG6 PRLOFDEBAyLmT _.. VAUL: LM PERMIT PL:8161200 s API W. 50029123319-00 SEC 34, T12rt R11E, 2380 FSL 61566' T V& SP Eq*o" 6(AMeka( BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Rixse, Melvin G (CED) From: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Sent: Thursday, December 26, 2019 12:34 PM To: Rixse, Melvin G (CED) Subject: RE: Incomplete Sundry Request PTD206-120, Sundry Request 319-582 Mel, The top of the UG4 is at 2,790' MD This well is vertical to the proposed TOC in the IA, 4,200'. Beau From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Thursday, December 26, 2019 9:46 AM To: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Subject: RE: Incomplete Sundry Request PTD206-120, Sundry Request 319-582 Beau, Where is the top of the UG4? Rule 2 The TOC in the IA is limited to no shalloxver titan 500' MD above the UG4 formation top that con -elates to the UG4 formation top of 38.13' 7Z'Dss in Well PBU GC -2C and the TOC in the I4 umst be at least 1500 TVD below the surface casing shoe. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 1 907-793-1231 Office 907-223-3605 Cell CONnDENTIALITY 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 Mel Rixse at (907-793-1231) or (Melvin. Rixse(@alaska.govI. From: Obrigewitch, Beau <8EAU.OBRIG EWITCH@bp.com> Sent: Thursday, December 26, 2019 8:51 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.eov> Subject: RE: Incomplete Sundry Request PTD206-120, Sundry Request 319-582 Mel, Here is the information you requested for the IA cement job on GBP Well L-04. With the exception of the service line, as listed in the second column, I have highlighted the requested information. Summary Service Line Activity Step # 1 Slickline a. Pull TTP b. Subsidence drift a. Set composite plug @ 8,895' b. MIT -T 2500 psi 2 Eline c. Punch Tbg across collar @ —8,877' d. Confirm injectivity into IA; swap well to dsl e. Set composite retainer @8,855' Assist Eline: a. Load as needed 3 Fullbore b. MIT c. Circ to Diesel Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Thursday, August 1, 2019 10:50 AM To: AK, GWO Well Integrity Engineer, Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Nottingham, Derek, Peru, Cale Cc: Regg, lames B (CED); AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity, AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J; AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Injector L-04 (PTD #2061200) failed AOGCC MIT -IA, well secured with tubing plug All, Injector L-04 (PTD #2061200) was made under evaluation on 7/19/2019 for failing an AOGCC witnessed MIT -IA. On 7/30/2019 slickline secured the well with a tubing tail plug and performed a passing MIT -T to 2,645psi. At this time the well is reclassified as Not Operable and will remain shut in and secured. A leak detection log will be performed after the GC2 Tar. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: A , WO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Friday, Ju 2.019 10:36 AM To:'chris.wallace@alas . v' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOP 2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.c • AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; A , S Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeliPadDFTN2@bp.com>; AK,ell Pad HUQ <AKOPSWeliPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeI[Pad LV@bp.com>; AK, OPS WelllnPad M OPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELL S@bp.com>; AK, OPS Well Pad SW <AKOPSWeliPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPAD bp.com>; AK, OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp. >; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRES WestWellsOpt2@bp.com>; Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, July 19, 2019 10:36 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Nottingham, Derek; Peru, Cale Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A, Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Injector L-04 (PTD #2061200) failed AOGCC MIT -IA All, WAG Injector L-04 (PTD # 2061200) failed it's required 4 -year AOGCC MIT -IA on 07/18/19 and was subsequently shut-in and freeze protected. The failed MIT -IA indicates a failure in one or more well barriers. The well is now classified as Under Evaluation and is on the 28 day clock for diagnostics. Please keep the well shut in. Plan forward: 1. Town Engineering: Evaluate for diagnostics or secure Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, July 18, 2019 l) (�, P.I. Supervisor ��(' L�l(�'C� SUBJECT: Mechanical Integrity Tests — BP Exploration (Alaska) Inc. 8502 " Tubing L-04 FROM: Guy Cook PRUDHOE BAY UNIT L-04 Petroleum Inspector PTD 2061200 -TYPe Test SST Test psi Sire: Inspector 246 Reviewed By: 1862 - P.I. Suprv'_ BBL Pumped: NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT L-04 Insp Num: mi[GDC190718133214 Rel Insp Num: API Well Number 50-029-23319-00-00 Inspector Name: Guy Cook Permit Number: 206-120-0 Inspection Date: 7/18/2019 - Thursday, July 18, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L 04 - - -- — Type Inj w `TVD -- 8502 " Tubing r_67 1202 1?06- 1206- PTD 2061200 -TYPe Test SST Test psi 2127 IA 246 2498 - 1862 - 1353 BBL Pumped: 2 BBL Returned: I OA 796 803 803 - 709 Interval _ -4YRTST - P/F 1' -- - ----- - - - _ Notes: Testing was completed with a triplex pump, calibrated gauges and a bleed trailer. Thursday, July 18, 2019 Page I of 1 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate Vf Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ElRe-enterSusp Well 0 Other: my d A C144 V 11' 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-120 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-23319-00-00 7. Property Designation(Lease Number): ADL 0028239 8. Well Name and Number: PBU L-04 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12330 feet Plugs measured 10190 feet true vertical 8996 feet Junk measured feet N O V 2 4 2015 Effective Depth: measured 10190 feet Packer measured See Attachment feet true vertical 8979 feet Packer true vertical See Attachment feet AOG Casing: Length: Size: MD: TVD: Burst: Collapse: 1 Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 2671 9-5/8"40#L-80 29-2700 29-2700 5750 3090 Intermediate 9132 7"26#L-80 28-9160 28-8662 7240 5410 Production Liner 3323 4-1/2"12.6#L-80 9009-12332 8551 -8997 8430 7500 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-9017 25-8556 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9685-10485 Treatment descriptions including volumes used and final pressure: 268 Bbls NH4CL+F103,84 Bbls 9:1 Mud Acid(Titration:9.2%HCL,1.3%HF) 2 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 667 500 1782 Subsequent to operation: 662 340 1793 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG m GINJ 0 SUSP 0 SPLUG 0 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: 315-549 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 11 (1,41/11,. Phone +1 907 564 4424ViriiDate 11/23/15 Form 10-404 Revised 5/2015 �� /,�16 RBDMS��C 0 11015 Submit Original Only • • Packers and SSV's Attachment PBU L-04 SW Name Type MD TVD Depscription L-04 PACKER 9021.06 8559.12 5" Baker ZXP Top Packer L-04 PACKER 11004.89 8990.48 4-1/2" Baker ECP Packer • • a, N co OD _ t LO N N Tr 0) O CO CD L O CO CSO co 0 N- O CLC) 00) 0 '- CO0N d 0) of O N r ui I� 0) r CO 0 r In I� 0 M O m CA O O ' N N N C'r) Cr) Tr Tr co 0 0 CC) 0 CO r- Tr N- o, CO 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 00 0) 0) 0) CO 0) co O 0) 0) 00000000000 OOO CO 0) OO O. O L M N N O N- O M LU O 00 LU UD L O LU ' L CNO (D up 00 Tr 0 CO T- O T1' 0) CD OI- ONCDOO) 0 m 0) O O ' T- N N N CO) CO Nr co 0 0 0 N- co st W O O 0) 0 0 0) 0) 0) 0) 0) 0) 0) 0) co 0) CA 0) 0 0) O 0 0) > p OOOOOOOOao Oa LU LULU 00 030) OLU 0 CD w Z w LU ° o Y U O m O O < Y Y g s O CC70N 00000000LUo00LU000N- --1 Q Q W W 4-I a 0 N 0 N- r- CO Tr r O T- Tr CO 4*- O N C) LU CCS co N- M J J W J a 0_ Cn Z 0000 ' � 0) N Q Q Q W = p 0) CD ti CD 0 0000) 0) CCD CD 000000 — N U U U J W W O O 0) 0000) 000) 000)) 0) 0) Z Z Z _ 00 d w d 2 II I W ce ve Z O Z 2 2 2 O co co co en N Q J a V3 Nr C +L G0 0 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LU 0 0 co0. 0 s- 411 443 0) '- C') 't N- 0 Tr CO O O N T- 0 0 0 O d CD N- N- ti N- 00000) 0) 0) 0) 0) 000CDCDI- O • 43 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N � aU co M 0 co co co co co d EL O 0 c O LL LL u_ LL LL u_ LL LL LL N LL u_ LL LL LL u_ u_ LL (n cn cn d < < < < < < QQQcn < < < < < < QQmmm 0. O m a as I- rnvvv � °' vvv8v °) vvvrnTrrncn1nu) V- C 0 0 0 (TS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W 1.1 Z¢ O N N N N N N CV CV N N N N N N N N N N N N ZO w 0. W W W ` LL � NNNLU LULULU m 4 4 m ) N O a :7Ww') J WO N 'crN i) tt ' "4" 't MMC\7 Z r, JO V W W W Q W 11 0 m 0mDm W -� —IDR 0 W w ¢ mamcn L LT_ u_ cn o_ cc a, E R z 3 vTrvvvvTrvvV TrvTtTrTrvvvr [FTrTw N 2' LL N 000000000000000000000 W 0_ coCn 0 O N W 0- -11 J J J J J -J -I J J J J J J J J J J J J J Q Q co co <L LL U) U) 0_ 0 • CL • kd 22 % R Ok � . E o \ / . o 3 k $ Ek T. ci- `t / m 9 u_ § k k b 0 CO ca k co CU < $ � � �p Ew CD f / 5 $ / 0 _ o 2 a § @w I- - e c t ° 2@ 2 c L o : o £ o = o . L - 7 o_ _ � 2 E : = E / EK � 2 •E � / / $ W � � I 2 e -0 f3 - o <0 b � � / £ kj � � I Ce $ k \ kk $ k / f \ ) 2 eL § \ k 42 m / CU w H 2 : -q S -0 t 0 t g 0@ 0 2 2 O@ m -0 ; f t 1--- 0E2 c w E -0 al - w f k co ID ® Ot &Ua % %� � a2 %_ $ $ q � ƒ / / $ kk �� k / mak k � k45 ® o •- 0 Q q ° co al _I c M —I _ $ \ f % f � fc/ D2 � / % ? � � 2 / I- E.:_. e - 1 Lsr w : IQ , a : I m - o < : O 2 2 cL : O 4 z 2 : co o z o O w r m r / \ Loom # � 5 q CO CN CO C\I / o q q q TREE= 41!16"CM/ • _ A NOTES WILL ANGLE>70°@ 9496''**H2S VVELUfA4= 11"FMC ACTUATOR= LEO L-04 READINGS AVERAGE 125 ppm WHI9I ON MI'*`WELL REQUIRES A SSSV WHEN ON MI*'*NOTE WATCH OKB.H_EV= 76.5' FOR COMPOSITE PLUG DEf3f9S(4 PLUGS MILLED BF.ELEV= KOP= 3900 I I 05/22/07)**• Max Angle= 99"@ 10828' Datum MD= 9578" 20"CONDUCTOR 74" 2009' —14-112"HES X NP,D=3.813" Datum ND= 8800'SS 9-5/8"CSG,40#,L-80 BTC,D=8.835" H 2699' r CSG,26#,L-80 TCI X0 TO BTC-M H 3927 (—>< X a D--j 4712' —7"MES ES Ca#ENTExt,D=6.188" Minimum ID = 3"726" @ 8993' 4-112" HES XN NIPPLE ' ' 8928' H4-1/2"FESX NP,D=3.813" Z X 8949' Hr x 4-1/2"BKR S-3 PROD PKR,D=3.875" I ' 8972' H4-1/2"HES X NP,D=3.813" I I 8993' --14-1/2"HES XN NP,D=3.725" TOP OF 4-1/2"LNR — 900T 900T 17"X 5-1/2"HRD ZXP LTP 2 r w/T133ACKSLV,D=4.40" 4-112"TBG, 12.68,L-80 TCI,.0152 bpf,D=3.958" — 9015' 9015' -4112"VYLEG,D=4.00" ESTIMATECEMENT — ATED TOP OF CEMENT(05122/07) - 9102' H9029' 7"X 5"BKR FLEX LOCK LNR HGR D=4.400" • �% 9039' —15"X 4-1/2"XO,D=3958" • • 7"CSG,26#,L-80 BTC-M,D=6.276" — }-4:• ►• { 9158' • H Ma TT LOGGED NOT LOGGED • •• i•ii ••• ••• • •• • ii 110 S L-04 I] I J L' X • D ►zI S PERFORATION SlANW1RY I REF LOG:MJUD ON 10/09/06 ANGLE AT TOP PERE:79°@ 9685' Note:Refer to Production DB for historical perf data I I SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 12 9102-9107 S 10/18/06 10/18/06 3-3/8" 6 9685-9705 0 04/14/09 2-7/8" 6 9710-9725 0 04/07/14 t i, /� 2-7/8" 6 9730-9755 0 04/07/14 2-7/8" 6 9762-9772 0 04/07/14 2-7/8* 6 9790 9810 0 04/06/14 3-3/8" 6 9810-9830 0 04/14/09 0i• i i� 2-7/8" 6 9830-9870 0 04/06/14 0• 0•• ►�i ♦• • 2-7/8" 6 9870-9900 0 04/05/14 •• 04,�•�4 2-112" 4 9900-9910 S 05/17/07 05/22/07 ,i•i 0i�i 2-7/8" 6 9910-9940 0 04/05/14 j••• 3-3/8" 6 9940-9960 0 04/14/09 040.•. 2-7/8" 6 9960-9975 0 04/04/14 04141111 •2-7/8" 6 9980-10000 0 04/04/14 �•�i 2-7/8" 6 10000-10020 0 04/03114 •�•� 3-3/8" 6 10020-10040 0 04/14/09 ••• • 2-7/8" 6 10040-10055 0 04/03/14 •i• i 3-3/8" 6 10140-10150 0 04/14/09 •••• • '�'i 3-3/8" 6 10485-10490 C 04/14/09 �•�� ••�i 2-1/7 4 11700-11970 C 10/24/06 •�•• • 2-1/7 4 12050-12237 C 10/24/06 •••• V*4 .ASA i�•� I I DATE REV BY COMMENTS DATE REV BY COW/TENTS PRUDHOE BAY INT 10/26/06 MIES INIT1AL COMPLETION 02/15/11 MB/JIM ADDED SSSV SAFETY NOTE WH-L: L-04 01/04/07 JAFITLH C ONFOSHTE BP SET(12/30/06) 01/17/12 TMWJM7 ADDED H2S SAFETY NOTE PERMT I'io:'2061200 05/22/07 AHWTFIL ADF /CMT SOZ/MLL PLUGS 11/25/13 KAB/JM]EKED PERF SUMMARY DATE AR No: 50-029-23319-00 06/25/07 ?/PJC DRLG DRAFT CORRECTIONS 04/08/14 JC/PJC ADPHRFS(4/3 TI-RU 4/7/47) SEC 34,T12N,R11E,2380'FSL&1566'FWL 12/07/08 OBRJSV PERE OORR 03/23/15 JCF/PJC SET CSP 06/01/09 KEY RIM CTU ADPE FS(04/18/09) BP Exploration(Alaska) ` OF T�� \��77,cv THE STATE Alaska Oil and Gas s�-s��—'�, ofALASKA Conservation Commission _ =_-- ` tt' t __ _ 333 West Seventh Avenue • 0 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1433 Off"4LASY`PFax. 907.276 7542 www.aogcc.alaska gov SCANNED Kaity Burton Pad Engineer a06 -- OC, BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU L-04 Sundry Number: 315-549 Dear Ms. Burton: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, l°443C& Cathy P oerster Chair 4\1DATED this y of September, 2015 RBDMS SEP 0 9 2015 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COP. 310N , APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate 13• Alter Casing 0 Change Approved Program 0 / Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other rv/ui1 4C(CI lir''' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 206-120• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service ®• 6. API Number: 50-029-23319-00-00 • 7, If perforating: 8. Well Name and Num What Regulation or Conservation Order governs well spacing in this pool? Yes 0 No ® PBU L-04 • RECEIVED Will planned perforations require a spacing exception: 9. Property Designation(Lease Number): 10. Field/Pools: SEP 0 2 2015 S L ADL 0028239 • PRUDHOE BAY,PRUDHOE OIL ' I 'lig i S 11. PRESENT WELL CONDITION SUMMARY AO G Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12330 • 8996 . 10190 8979 10190 Casing Length Size MD TVD Burst collapse Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 2671 9-5/8"40#L-80 29-2700 29-2700 5750 3090 Intermediate 9132 7"26#L-80 28-9160 28-8662 7240 5410 Production Liner 3323 4-1/2"12.6#L-80 9009-12332 8551 -8997 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9685-10150 8895.38-8973.9 4-1/2"12.6#L-80 L-80 25-9017 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 12I Exploratory ❑ Stratigraphic 0 Development 0 Service ®• 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL❑ Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG ® • Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Burton,Kaity Email Kaity.Burton@bp.com Printed Name Burton,Kaity Title Pad Engineer Signature - _ ' t �� Phone Al 907 564 5554 Date tl O t LO COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3(6' 614Ct Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No 11 Subsequent Form Required: `(J - 4-C IF P90(444°. � COMMISSIONER APPROVED BYTHE Approved by: COMMISSION Date:9-8-/S' I L 4/4/l.- O R I G I N A L RBDMS SEP o 0 2011 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachment Duplicate a> Y U CO 0_ C O 1- • C 0 - a) .13 N ` o d a a�? H U o � aLU m a`) m �..i (V m LV C r r Tr to 4 E C.) O N CO Ca J Cl) :, 'al RS cs) CN1 CD co L CO O . O O O_ ✓ CO O a CCL O.YYY 000 Z000 J J J N ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: L-04 Well Type: WAG Injection Well API Number: 50-029-23319-00 Well Activity Conventional 3 Classification: Activity Description: CT Mud Acid Stimulation Cost Code/AFE: ABPBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job Type: Acid-Mud Estimated Cost, $K: AWGRS Job Scope: ACID Other regulatory None requirements? _ Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Kaity Burton Contact numbers: (907)564-5554 (907)360-6002 Well Intervention Engineer: Jerry Lau Contact numbers: (907) 564-4090 (907)360-6233 Lead Engineer: Laurie Derrick Contact numbers: (907)564-5952 (720)308-3386 Date Created: August 25, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 7/26/2015 528 0 1,762 Current Status: Operable Flowing Inclination>70°at Depth (ft) 9500' MD Recent H2S (date,ppm) None On PWI Maximum Deviation (Angle and 10828' MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 15.6 9226' MD Reservoir pressure(date, 2/18/2007 3,870 psi Minimum ID and Depth 3.725'@ 8893' MD psig) Reservoir Temp,F 230°F Shut-in Wellhead Pressure 2,500 psi Known mech.integrity SC shoe communicates with shallow gas hydrates(OA reaches equilibrium at 800 psi) problems(specifics) Last downhole operation (date, 3/23/2015 CT Pull MCX/FCO SCHMOO/IPROF/Set CIBP operation) Most recent TD tag(date,depth, 3/23/2015 10190' CTMD 3.56"max OD CIBP toolstring toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, Well drilled and completed as an injector to support V-04 and L-01. The well is drilled across a north south background information, fault and currently has perfs on both sides of the fault to support the offtake from V-04 which is also on etc: both sides of the fault. Before the CIBP was set in March '15, —90% of the injectivity was going in the toe , perfs on one side of the fault with minimal injectivity on the other. The plan is to increase injectivity in the heel with the toe isolated,which should work towards the overall objective of balancing injectivity between the toe and heel perfs once the CIBP is finally removed.This well has historically taken pigging returns(schmoo)for the L-Pad PWI line(EWE 69 pipeline). Happenstance,the date of the last pigging job coincided with the day that the CIBP was set,therefore, it is difficult to differentiate between the effects of schmoo on the injectivity versus existing formation damage. A CT Matrix stimulation treatment using Mud Acid is expected to repair formation damage and clean up schmoo in the near wellbore area. oiISEEKER was chosen for diversion since the BHT of this WAG well doesn't allow for wax beads. Musol has been added to the final overflush stage to ensure oiISEEKER breakdown. Suspected Well Problem: Formation damage in heel perfs Specific Intervention or Well Objectives: 1 Remove damage from heel perforations by acidizing with mud acid to increase WAG injectivity 2 Restoring natural permeability in the heel to balance injectivity between toe/heel perfs 3 Key risks,critical issues: Mitigation plan: 1 Acid Handling See RP in PE Manual 2 Damage SqueezeCrete Cement Job(low risk) Resqueeze(unlikely) 3 Loss of injectivity Pump above frac gradient(0.65 psi/ft) Summary Service Line Activity Step# 1 S Drift to Deviation 2 C Acidize 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 See attached detailed procedure 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production BOPD: MMSCFD: BWPD: Rates: FTP(psi): Choke setting: Post job POP instructions: Place back on PWI to assist in overflush Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE= 4-1116-COW VIELLFEAD- 11"WIG i�� SAFETY NOTES: 70' 9496"'FES ACTUATOR= L® READINGS AVERAGE 1255 ppm ppm WHEN ON MI•"WELL REQUIRES A SSSV WHEN ON Ml"'NOTE WATCH OKE.ELEV= 76.5' FOR COMPOSITE PLUG DEMES(4 PLUGS MLLED BF 0.EV= ? I I 05/22/07)"° KOP- 3900' Mix Angle= 99'010628'p i 200@' J—4-112'HES X NP,ID=3 013"j DiNum ms, ib 9578'120'COPDUCTOR — 74' I ' Whim TVD= 88005$ 9-5/3"CSG,40 0,L-80 DEC,0-0.036' -- ' T CSG,26#,L-90 TCS XO TO BTC-M — 3$22 }C 4- 4712 r I-I s ES GRONV@R D'6.11/r Minimum ID=3.726"©8993' 14-1112"HES XN NIPPLE ' 6926' —{a-1n•HES xNP,D=3.a13- �._ • $949' r x 4-1/2'BKR S-3 ROD PARR D:3Jf75' I INR? —4-117 HES X NP,D■9.819" I 9993' 4-112'HE3XNNP,ID 3725'1 TOP OF 4-1R"LNR9007 900T TX5.12 tRDZhPLTF' /4 '' wt TEBACK SLV D=4 40- I4-112'16G,12 6#,L-80 TIO, 0152 bpf,D:3.956" I 9016' 9015' IH4-1/2'WLEG,D=400' 8027 7'X5'BKRRIXLOCKL142HGF{D=4.400" I [ESTIMATED D TOP OF CRONE(05122/07) 910'_ y Cli 4* •• 90375 X 4112"XO,D=3.058" I7-CSC,,2Rt.9-R0 RTMPA,II=R 27R- 01581 •••• �fl-6 f3 TT l()CSC ED NOT OCC J • •• II* • •• -. • S. ♦♦ ._•. • PEFIFORATIONSL IMARY •+j ..4 RS LOG:MIND CM 10109/06 • •1• .... ANGLE AT TOP Imo.79°tt 9686' •••• ••• 'a•. 10197 —4.1/TTACT CUP( 23t15) Note.Refer to Roduotion DB for historical part data •♦• 1••4 SIZE SPF( INTERVAL 1 CpNSgz 1 SHOT I SOZ :i • SEE PAGE 2 FOR FERFORATX)N MTA *•1*e 1y• 10947 —4-1/T HES ES CEMENTER D=3.987 ••• �•• 11003' I—PA ViONE EXTRINAL RM.,0=3.900' I I P5101 12243' 1 4 t 11111111111 4-12'Lift,12.89,1-80 BT-M.0152 bp/,D'3.958" H 123.10' MTF RFV RY IY1M:NTS MTF RN BY COMMIS PR=OE BAY UNE 1021006 WS MLTIAL COMPLETION 02115/11 M13/J1.I+AWED SSSV SAFETY IOW WELL L-04 01104107 JAF/TLH HE BP SET(12/30(06) 01/17112 TALION l ADDED H2S SAFETY NOTE EMT No:"1061200 05/22107 AHWT}t AL U F/CMTSCOWL.PLUGS .11/25113 KA& FD31)T$2F SUMMARY DATE AR No:50-029-23319-00 06/25107 21 RIC Inc CRAFT CORRECTIONS 04/08/14 JD PJC AI S(413 THRI14/7/47+ SEC 34,T12tq R11F,2380'FSI &1566'FW 12/07(08 Dili/SV nERF cow 03/23/15 JCW—JCISETCEP 06/01109 KEY/TLH CTU AOPERFS(04/18/00) 8P Exploration(Alaska) L-04 II 11 4 x b I I I:74 X PE RFORAT,ON SUMMARY I I REF LOU:AMA)ON 10/09006 A FL LE AT TOP PERF:79.6 9685' Note Refer to Production OB for historical perf data IIII SBE SW NIERVAL OprdSgzSHOT Sal 13-38' 12 9102-9107 S 110/18/06 10/18(06 I 3.3/8' 6 9685-9705 0 '01114109 2-718' 6 9710-9725 0 01107(14 ~''i 2-78' 6 9730-9755 0 04(07/14 12 7F9' 6 9762 9772 0 04,07(14 2-7/8' 6 9790-9810 0 04(06114 13-3/8" 6 9810-9830 0 04114/09 %i �% 2-7/8' 6 9830-9870 0 04106114 •4 �•i 2-7/8' 6 9870 9900 0 0005114 , j 2-1/2 4 9900-9910 S 05/17/07 05(22107 48•' f4•4 2.718' 6 9910-9940 0 04(05114 •••• 3318' 6 9940.9960 0 804/14109 .0411 1,,r12-78' 6 9960-9975 0 D/04(14 0•, 04 111041 2-7/8' 6 9980-10000 0 04(04114 y•• 2-7/8' 6 10000-10020 0 04/03114 • e,,,,�•4 r • 3-303- 0 10020-10040 0 04(14109 •••• . 2-7/8' 6 10040-10055 0 04/03/14 j•••• -rim- 3-3e 6 10140-10150 0 04/14/09 i4i Mek 338' 6 10485-10490 C 04/14/09 i pp Injector Minilog El TCChIog Project PEW WEST Well: L-04 Author Laura J.Larson Scale 1 4000 Date 8/1012015 Elston 79.5 S 593202.67 SPX ori 20090923 000090 US A Elevator door RT Y 0970101.52 Ca:aeon Ogee 2006.16200000:00 0..K0r JC B.r, total 75454,12330 lm7note-14.324002 Slant. A4zsk.i Caranate System 10027 PFT Latta*70.350143 OcerrMa OPXA I BPSA r 2 21 BEST.GR 0 API 2«02 PE Notes a � Rote ivy. MO i RES_OtE ErE' E BEST.ROP (FEET) (FEET) (pQ jVQSS BEST.ROEt 1:1000 14000 "' 9000 {t 8650 0.2 °1OMW CI Al i $790- z.-g- 1- '}- A 1790.. 11120 f 0 9500- — i C's-f Tot } ... -1110= - tor_ 1890 0910 i 61P — .191011 -1920 - -1910.. 46P _1960— -9960 10000 tj -8900 1 .1970 J wo _may GIBP@10190' wP '1990-I ') tt -9000. 9500. — :9010 -9020_r 10500- t—, ,1-:,..,:_„„i_ 441 t 9010 1 ; _9020! 425 __r _._. r_ -9010-5 -_ M ...AI. j 9000 42 __ ,EJB 1 9990 4-11000 43N ;�I ^1110r ----S-- 8970-,460 TSAR . 1960' 46P -1950 . .....___ ,..c." 1---- . 8900-. - 11503 460 `[ `-11500' •46P - 1900 • �� .' . SOP 46P /SAD .-.... 1 — 4611t 11000. —, _ - „0950 S 46P ---• 1860SOP 1.. U. r1 O 1 f 000 I I VI ......... t.r) C) -,,_ Q VI O l0 i✓ cu W CO O o 0 m = V cr O w .- cn / VI I CNJ rsM Lin i O Ln Q S 8 8 0 8 N N r-i r-i O O Detailed Work Scope for L-04 Mud Acid Pre Job Notes: • Ivishak WAG injector BHT too low to use wax beads, oiISEEKER chosen as diverter. • Musol added to NH4C1 Final Overflush to ensure oiISEEKER breaks. • Formation very tight, injection is around 700 BWPD/ @ 1794 psi (-0.5 bpm). • No need for initial fluid packing with NH4CI since already fluid packed from PWI. • No need for loading IA or performing TIFL (WAG injector, No GLVs). PC/TBG integrity verified via AOGCC MITIA to 2500 psi (7/20/15). • No need for ASRC acid flowback, put on injection post job to support overflush • Do not add friction reducer to stimulation fluids that will enter the perforations. • Do not exceed 0.65 psi/ft gradient throughout the job. The exception to this is if the diverter works very well at plugging up the perforations; ok to go up to 3000 psi wellhead pressure if necessary to complete the job after the diverter is in place. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • 10-403 Sundry required for job Reference Documents • Guidance Document: Risk Analysis -Acidizing • Recommended Practice: Acidizing • Recommended Practice: Pumping Fluids Stimulation Targets Zone MDT MDB H Eileen 9685 9705 20 46P 9710 9960 210 45P 9960 10055 90 44P 10140 10150 10 Total Footage 330 Pre-Acid Ops: 1. Review Well Integrity history to ensure no integrity issues have developed since AOGCC MIT-IA passed to 2500 psi on 7/20/15 . 2. Coordinate with Pad Op to put well back on injection after job to assist with overflush. If not possible,order an additional amount of NH4CI for adequate overflush. SL Ops: 3. Drift to deviation. CT Ops: 4. MU JSN. RIH to 9500' MD or per WSL discretion 5. Pump 30 BBL (2400') of diesel down the backside or per WSL discretion 6. Pump per pump schedule. Recommended pump rates and running speeds are provided, but may be adjusted per WSL discretion. 7. During Final Overflush, perform post job injectivity test for 0.5, 1.0, 1.5, 2.0 bpm- holding each stage for 5 minutes to establish stable injection 8. 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O. 0. :., O sz m 0- on o a 00 00 M 00 00 0. 00 0. 00 @ CO 00 a 00 c. 00 00 CO ss On O N 0 N O c Tt O O N O u1 c Troohiosno c 0 L+1 N vs a1 LA 1.11 QJ N a1 N Lf1 a) Lf1 N U N u N u u U N C C C c C o U U U 0 as Tss co as raUU 00 00 DO 00 00 N O Ln Ln 0 N et esi Q1 r-1Nr-I Tr LD N N to to 0) aJ 0) a) 0) -0 -0 -0 -0 0 U• Ln M U Ln M N U l• O LMA M Co LLA U Tr O u1 m co uii lND U ill O Ca o0 0 m CO 0 m 0 Ln 0�j m 0 LA 0 CO CO N Ln ; LL VI ; � � QQQILLI. 1 r) < < < U.. J - N —, 13 T CU L O CO L O N CO 3 cc 3 cu c : L C +, Q. m O t O +-. O. - L -p L +' •v = CO LL Lel 3 U. a) U O t -Ocu cs= U c0 -c W a) •U0C al C 0 2 c y Y -0 OL c 0J Y O O W 0: 0J .+= U fp *' U fp = p u v O C -0 U a1 G u V O 7, _0 CU 0J 0 W u U W ▪c `t `t *' c v a c r I C a t v 3 c �, N c Ln DO < = cn LL < z cnn .e .N-I ' < 0 C LO 0 < ori LL < U° . u0. ° < 2 o u = 5 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,July 23,2015 ��5I P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-04 FROM: Bob Noble PRUDHOE BAY UNIT L-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -:116,2— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT L-04 API Well Number 50-029-23319-00-00 Inspector Name: Bob Noble Permit Number: 206-120-0 Inspection Date: 7/20/2015 Insp Num: mitRCN150723120043 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-04 - Type Inj W'TVD 8507 - !Tubing 1459 -1 1475 - 1446 -' 1440 - PTD 2061200 Type Test SPT Test psi 2127 IA 7 2500 -. 2443 - 2436 ' i Interval i4YRTST P/F _i_ P - OA 287 ' 287 288 - 288 - Notes: SCANNED 2 ;.i:, Thursday,July 23,2015 Page 1 of 1 0 el I—. 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LL J Z Q' x J J Z^ i i C y fil N .. a Q STATE OF ALASKA RECEIVED ` 3KA OIL AND GAS CONSERVATION COMN...,SION APR 13 2015 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon Lf Repair Well L1 Plug Perforations U Perforate H Other O Gt" Performed. Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Developments Exploratory ❑ 206-120-0 3 Address P.O Box 196612 Stratigraphic❑ Service ❑✓ 6 API Number Anchorage,AK 99519-6612 50-029-23319-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028239 PBU L-04 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071). 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12330 feet Plugs measured 10190 feet true vertical 8996 18 feet Junk measured None feet Effective Depth measured 10190 feet Packer measured See Attachment feet true vertical 8979.21 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 29-109 29-109 1490 470 Surface 2670 9-5/8"40#L-80 29-2699 29-2698 22 5750 3090 Intermediate 9132 7"26#L-80 26-9158 26-8660 38 7240 5410 Production None None None None None None Liner 3323 4-1/2"12 6#L-80 9007-12330 8548 82-8996 18 8430 7500 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet CANNED MAS I 2O1• Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#L- 23-9015 23-8554.68 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 2749 0 320 Subsequent to operation 0 0 534 0 320 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil Li Gas LJ WDSPLLJ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP H SPLUt 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhays(a�bp corn Printed Name Nita Sup m/ys Title Petrotechnical Data Engineer / `;5 Signature-///mt,, y #,4_/, / Phone 564-4035 Date 4/13/2015 VTC 51,, RBDMSJC, APR 1 8 1015 ////----- Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028239 rim} sz.r!;". ✓` sd y*`F fi , CTU-6 1.75" CT Objective: Pull MCX SSSV/ Drift/ FCO SCHMOO/ IPROF LOG Rig up. RIH with 4.5" G-Spear and pull MCX at 2009'. RIH with 3.5" JSN at 90 fpm while pumping SBG at 1.75 bpm. Jet tubing to TD and tag at 12236' CTMD. Pick up 20' and paint white/red TD flag at 12216'. Put well back on injection at 3000 bpd and POOH.At surface begin making up logging tools for (PROF. 3/21/2015 ...Continued on WSR 3-22-15... CTU #6 - 1.75" Coil ***Continued from WSR 3-21-15*** Job Objective: Pull MCX, !PROF with cont. CBP Make up IPROF logging BHA with spinner/XY/temp/GR/CCL. RIH with well on injection at 3000 bpd. Log up/down passes from 9500'-TD flag at 12215' at 40, 60, and 80 fpm. Shut in injection and log at 60 fpm from 9500-TD at 1, 3 and 5 hr. Place well back on injection and began POOH with logging tools. Painted a white flag at 10,000'. LD logging tools. Good data and confirm +5'. Notice injectivity into Cementer at 10949'. Decision made to set CIBP at 10,200'. Make up WFT 4 1/2" CIBP. 3/22/2015 ...Continued on WSR 3-23-15... CTU#6- 1.75" Coil ***Continued from WSR 3-22-15*** Job Objective: Pull MCX, !PROF with cont. CIBP Shut-in injection and RIH with 4 1/2" CIBP. Tie in to mid-element of CIBP at at coil flag, correct depth to 9998.5'. RIH and set CIBP ME at 10190.2', 10189.7'top of plug. Confirm injectivity of 0.5 bpm and 1430 psi whp, POOH. Perform step rate test at surface: 1317 psi © 0.5 bpm, 1528 psi © 1.0 bpm, 1711 psi @ 1.5 bpm, 1803 psi @ 2.0 bpm , 1867 psi @ 2.5 bpm, 1922 psi @ 3.0 bpm, 1921 @ 3.5 bpm, and 1965 psi @ 4.1 bpm. Place well back on inj. and RDMO CTU. 3/23/2015 ***Job Complete*** FLUIDS PUMPED BBLS 13760/40 METH 191 SCHMOO-B-GONE 182 1% KCL 510 TOTAL i m N m CO N L V 00 — (0 00 CO N- LU CO L V N- a a m LU t N N V 0) O CO a O O (soa (6 N- O a `- O O - 00 N a 0) M O N ,- a N 4 O) a Vi = a N. 0 c- ,_ N- 0 0 W m 0) O O V N N N CO M c1 O LU LU L O (fl 0) r- ct I,- > 0 CO 6) 0) 0) 0) 0) 0) 0) 6) 0) 0) co O 0) 0) co d7 co O a1 O 0 CO 00 CO CO CO 00 CO 00 CO 00 CO CO CO CO CO 6) 00 00 > WO Z W . LU LU LU 0 O W 0 g Q J 0 > J Y U 0 O O W Y Y I- g CO (Ni I� O O co CO N- 10 OM r CO N U) (/) J 0 0 L M N N CO N O M LU O CO U L O V O L LU O Cfl V J J J Q Q W Su.) O V O a .- a 0) = CO O N (f) I� O (Ni O O O < < < w W d U Z 0 COM M M M M M M CO CO M ( MC) ( ( C N.- o CO rn z z z 0 0 0 a a a O CO a0 CO a0 CO aO 00 aO a0 C o oO aO oO CO CO a7 M < < < 0 N 0 0 0 W 0 0 0 0 W W W a H H < _1 < 2 2 0 u) cn u) u) Cn m m m m ELU LU LU N 0 0 0 0 0 0 0 0 LU 0 0 O (() O O O I� ++ a 0 N LU N- CO v- I- O V O N O N V LO U) O N- CO C 0 r CO CO CO CO O O 07 O O O O 0 0 0 0 ,- N 0 0) 4) M d) O O M O O M O MM = = = = = = E N m m M E Oaa U gig (T) 1(7) I-(7) (515 &51 % Q N F O C a L LU O O N 0 0 0 0 0 0 0 aa 08 (V v v oo O C) J a CO M CO O CO cl I- O ace, CO O O O N- N- N- N- CO 00 CO C10 O 07 0) 0) O) O O O V N. O a 0 O O O O O O O O O O O O O O O 0 0 0 0 '— N m L m O 2 t C) a. m lo O 0 c o LL LL LL LL LL LL LL LL LL N LL LL LL wit_ LL LLL U)LU) U) mQ_ a_ a_ a_ 0 a_ IZa. a_ 0a. a. a. a. a. n_ O a_ a. a_ a_ O < < < < < < < < < U) < < < < < < < < c0mm a 0 t m O_ 0 W J m a W )LU ~ W W D J0 ' ' Oj D 0 _Q0 O V V V V 0 V V V 0 0 VV •V C dO .c- r 0 O O O O O O O O O O O O O O O O O 0 0 0 O WLL J J Z LL • N N N N N N N N N N N NNNN N N N N N N Z d Q < N LU W m C C\O CO (\O n N ,- v M CO M '- N N_ N 0 d 0 0 0 W W W a .4. .1- v v v ,n v .4- V � V M CO M Q a (2 0 J J D O Q D_ O < < m m -1 -100 U LL cn a cC m E m z .• 1vvvvvvV- vvV- vvvv V V V V VV W a W 0 LL N O W co 00000000000 OOOO 000000 COa a a 0 --' 0 0 W a J J J J J J J J J J J J J J J J J J J J J Q Q CO CO LL W u) (n a cc Packers and SSV's Attachment ADL0028239 SW Name Type MD TVD Depscription L-04 PACKER 8949 8506.5 4-1/2" Baker S-3 Production Packer L-04 PACKER 9019 8557.61 5" HRD ZXP Packer L-04 PACKER 11003 8990.7 Payzone External Casing Packer TREE= • 4-1/16"CNV WELLHEAD= 11"FMC L-0 n NOTPS: WELL ANGLE>70°19496'*" 2S ACTUATOR= LED RIDINGS AVERAGE 125 ppm WHEN ON MI"'WELL REQUIRES A SSSV WHEN ON Ml '""NOTE:WATCH OKB.ELEV= 76.5' FOR COMPOSITE PLUG DEBRIS(4 PLUGS MILLED BF.ELEV= ? I I 05122!07)"' KOP 3900' Mix Angle= 99'@ 10828' 20°CONDUCTOR —I 74' I 2009' 0—4-1/2"HES X NP,D=3.813" Datum MD= � 9578" Datum TV D= 8800'SS 9-5/8"CSG,40#,L-80 BTC,D=8.835" 1— 2699' 7"CSG,26#,L-80 TCN XO TO BTC-M H 3922' >G X a D— 4712' —{7'HES ES Ca/ENTER,D=6.188" Minimum ID = 3.726" @ 8993' 4-1/2" HES XN NIPPLE ' ' 8928• 4-1/2"HESXNP,ID=3.813" X x 8949' —7"X 4-1/2"BKR S-31:11200 RIR,ID=3.875" I I 8972' H4-1/2"HES X NP,D=3.813" I ' 8993' —{4-1/2"FES XN NP,D=3.725" TOP OF 4-1/2"LNR — 9007' 9007' 7"X 5-1/2"PRD ZXP LIP ..-------- C w/TRACK SLV,D=4.40" 4-1/2"TBG,12.6#,L-80 TCI,.0152 bpf,D=3.958" H 9015' 9 9015' H4-1/2"WLEG,D=4.00' ESTIMATED TOP OF CEMENT(05/22/07) —I 9102' 9029' H °X 5"BKR FLEX LOCK LNR HGR,D=4.400" ►•i 0. 9039' —f5"X 4-1/2"XO,D=3.958" • 7"CSG,26#,L-80 BTC-M,D=6.276" —{ 9158' -•: •• --11314)TT LOGGED NOT LOGGED •• �•�4 �• •••� •� •• ♦• ♦ PERFORATION SUMMARY :. 4...-I •• REF LOG:MWD ON 1 fl/09!06 •• • ANGLE AT TOP PERF:79°n 9685' , iii '•4 10190' —I4-112"WET CEP(0/23/15) Nate:Refer to Roduction DB for historical perf data A SEI SW NJTE3RVAL Opn/Sqz SHOT SQZ ••41 SEE PAGE2 FOR PERFORATION DATA :4 t; 10949' —I4-1/2"HES ESCEMENTER,D=3.980' t• . � . 11003' HPAYZONE EXTERNAL FCR,ID=3.900" I I PBTD —{ 12243' I.N 4-1/2"LMR,12.6#,L-80 BT-M,.0152 bpf,D=3,958" —{ 12330' DATE REV BY COMMENTSDATE REV BY COMMENTS _ E BAY UNIT 10/26/06 N9E5 IMTIAL COMPLETION 02/15/11 NB/JMJ ADDED SSSV SAFETY NOTE _ WELL: L-04 01/04/07 JAF/TLH COMPOSITE BP SET(12/30XE) 01/17/12 TMJ'JMDADDED EQSSAFETY NOTE PEI AT No:'2061200 05/22/07 AHWTFN_ADPERF/CMT SQZ/MILL PLUGS 11/25/13 KAB/JMJ FIXED PERF SUMMARY(ATE AR Na: 50-029-23319-00 06/25/07 ?/PJC DRLG DRAFT CORRECTIONS 04/08/14 JC/PJC ADPEFFS(4/3 11- RU 4/7/47) SEC 34,T12N,R11 E,2380'FSL&1566'FWL 12/07/08 OBR/SV FEW CORR 03/23/15 JCF/PJC SET CEP 06/01/09 KEY/TLH CTU ADPERFS(04/18/09) BP Exploratioi11(Alaska) L-04 I J 1 1 x x a D I I PERFORATION SUMMARY 1 RB LOG:MM)ON 10/09/06 ANGLE AT TOP PAF:79"@ 9685' Nate:Refer to Phoduction CO for historical perf data I I SIZE SFF INTERVAL Opn/Sgz SHOT SOZ 3-3/8" 12 9102-9107 S 10/18/06 10/18/06 3-3/8" 6 9685-9705 0 04/14/09 2-7/8" 6 9710-9725 0 04/07/14 // 2-7/8" 6 9730-9755 0 04/07/14 I 2-7/8" 6 9762-9772 0 04/07/14 2-7/8" 6 9790-9810 0 04/06/14 3-3/8" 6 9810-9830 0 04/14/09 �� •� 2-7/8" 6 9830-9870 0 04/06/14 ►��•• 1moi ♦• • 2-7/8" 6 9870-9900 0 04/05/14 0•• 1•��4 2-1/2" 4 9900-9910 S 05/17/07 05/22/07 0• •••• ►�•� 2-7/8" 6 9910-9940 0 04/05/14 0••4• 3-3/8" 6 9940-9960 0 04/14/09 *•••• '"`" • 2-7/8" 6 9960-9975 0 04/04/14 •�•• 2-7/8" 6 9980-10000 0 04/04/14 ••�4 2-7/8" 6 10000-10020 0 04/03/14 6��. 3-3/8" 6 10020-10040 0 04/14/09 j STATE OF ALASKA • AL A OIL AND GAS CONSERVATION COMMi iN RECEIVED REPORT OF SUNDRY WELL OPERATIONS MAY 0 1 2014 • 1.Operations Abandon U Repair Well Li Plug Perforations ❑ Perforate H Other LI �(� Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ ® v Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development❑ Exploratory 1:1N. 206-120-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑✓ 6.API Number: Anchorage,AK 99519-6612 • 50-029-23319-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: • ADL0028239 • PBU L-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured • 12330 feet Plugs measured None feet true vertical 8996.18 feet Junk measured None feet Effective Depth measured . 12243 feet Packer measured See Attachment feet true vertical 8977.51 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 2670 9-5/8"40#L-80 29-2699 29-2698.22 5750 3090 Intermediate 9132 7"26#L-80 26-9158 26-8660.38 7240 5410 Production None None None None None None Liner 3323 4-1/2"12.6#L-80 9007-12330 8548.82-8996.18 8430 7500 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SCANNED JUN 1 9 2014 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-9015 23-8554.68 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMS� MAY 1 v 2014 Treatment descriptions including volumes used and final pressure: I 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2855 1430 Subsequent to operation: 3526 1484 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator10 Development❑ Service❑✓ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPL❑ • GSTOR 111WINJ ❑ WAG ❑✓ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry CatronEmail Garry.Catront BP.Com Printed Name Garry Catron Title PDC PE Signature ��PJ "`"'".- Phone 564-4424 Date 5/1/2014 a C VGf ,5/ZZ/J4- )`-7x/'y Form 10-404 Revised 10/2012 Submit Original Only U N N a 0 N C 0 d O v m N CD C.M C C d N Y � W CD m p c 4-1 c 2 >, v in d E t v Q C o o 5. N O O J 13 Q .Y acooli ea CL cc ce cc WWW C.YYY QQQ 000 z999 3 J J co a) Y U a) L U C CO • 2 d O U m .U, w a U Q.M N C cu `• m Y N W cd CO o C CN N 4 u') D- E Q C. N- al. - O ci N N co 2 co 5. N co O O co G1 0 vo co V CL ct O. >i >i0 0 Q Q Q aaa a) co z999 J J J N N m m N u) Tr Co T- 0 CO CO N- u) 00 C4 u) st r- u) O u) 0 u) Z N N Tr CD O CO u) O 00 0 u) Ns O u) CD T- OD N ❑ p, O ('MONi— u) CrCD - CO ,r u) N- upT- N- OOCO > w O) OOi— NNNMMTrTrOu) u) u) OCID OF Tr r- 0 p CO O) CD CD CD Q) CD CD CDC)) Oa) CD O) O OO C)) 0 CO CO Co CO CO 00 CO 00 00 CO 00 Co CO CO 00 Co 00 Co C D CO 03 W m a W Z W w w O a w gY U O > 0 O O W 1C g F' CO N N- CD u) '— CD Co M N- u) Co CO T' N Co N u) - - J 0 U W m W r M N N co N- O M u) O 00 CO 0 . 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QQ ¢ QQQQQ ¢ a < ¢ QQ ¢ Q < QQaa 0 t M 0 a. w J r co cn O (O a co 0 W C] O Tr Tr Tr Tr CD Tr Tr TM CD CD ' O Tr c) Tr Tr Tr co Tr CD CD O O ❑ > > O Q O O O cp O TS TS O `- O O O O W J J Z LL O O O O O O O O O O O O N N Z LL a a w N N (L Y N N N N M N N N N M N N N M N M N O w W W J W W Ce O � � � � � 4 � v � � � 4v � � 4 � 4 400 m O J J C7 C) W W Q Q m m LL ti Cn Cn a Cr d E co z 3000000000000000000000 N i i i i i i i i i i i i i i m a Q. a. 0 J 0 a W a J J J J J J J J J J J J J J J ....1 J J J J J < Q m m LL lL U) Cn a [L' a 0 o / \ Z [ ® 3 0) 2= eo O - et I I = e \ - e ± k < § / 0 \ » 7 0 G o W E + a s 2 > 7 6 E \ \ f z - 0 \ / C \ \ / ( 0- \ / 3 E / 7 > E / / \ / - 7 % $ $ _ o p » E t To e o 12 � $ E cl .� o / •cC § \ w / § b x / W % / * % / 2 / e 4 o I o A E g 2 0 0 Vill o ® E E % a ± § E G$ \ ƒ O ® k % 4- / E GNU C 00 \ CD / / \ / / C / e .KpO -a ® = O RS 0 0 / o \ $ \ \ \ k \ 0 CL _1 / \ _ ® a % O E t / _$t 0 Oco ± � w \FCD � � / % � ƒ k ƒ E - N ° o \ 2\ / c / § \ o I -o I a) co o ± /`� o E » 7 c _1 4- 0 H / / b 0 09 § / / f \ : % 0C, - - 0 � Ion ± \ / / CCD D oma # Oct D / _E o e # / § / C 2 G 0 ± 2 c = o = w. o o 5 -0 / 0 k \ / o r = ƒt a e_ \w \ / # a) 00 Ti / 5 E0a) _ \ c0 o _0 ƒ m ± / > E \ 9 as E q \ = .- -o \ / 2 k $ \ q / a- _a), q E / \'\ / ƒ t % ƒ / / E / \ / t CM \ 2 / $ Eek/ § 2 = k U G 2 \/_ $ \ c e = \ 7 / 2 0 0 0 \ ± E � _ ƒ § = 2 7 \ g � o a 2 o e o D a w t & 3 D e e 2 e f * (NJa » 7� o .0 & 6r9km a .Cr 0E / e ± II > .E # / � il > # m c �� .- # CD a > .0 = . _ § > -e C _ > \ _ c O Cl # ± 0 e - D o 0 o = = c .= o = I 0 / CO ID O § / * \ / co / \ \ k / co o *0 CD\ )o co ¥ 0 - Q § t r4' H R O k 2 p E o U \ i U c: G : Et f * : # # # cp cy \ / / / / k / r # # # t) 2 ao " N m b' > ao W a0 00 r co ao• 2 co r 0 IPco o J N M a N D _ C M Ni fo - M (n (o TD 0 o a -0 = II m + J — a L co co 4_ O • O a) L O 0 al a) d U) 0 0)Q N- N CU O X0_ 45 03000_ =. p 4- _C a) a) N O 81 u) � a) a) O-2a2 = n3 O u) -0 � � 't 03 0 - D (U 0 p a O a) M ao d Ni _ - i TREE= 4-1/16"CNV _ SAl NOTES: WELL ANGLE>70°@ 9496'""WS MC ACTUATOR= 11" EO L-0 4 READINGS AVERAGE 125 ppm WHEN ON MI""WELL REQUIRES A SSSV WHEN ON M/ NOTE WATCH OKS ELEV= 76_5' FOR COMPOSITE PLUG DEBRIS(4 PLUGS MILLED ELEV= ? I 05/22/07)'"' KOP= 3900' . -Ii_i Max Angle= 99"@ 10828' 20"CONDUCTOR 74' _2009' 1--14-1/2"HES X NP,D=3.81 1 Datum MT= 9578" 1� Datum TVD= 8800'SS 9-58"CSG,40#,L-80 BTC,D=8.835" H 2699' 7"CSG,26#,L-80 TCN XO TO BTC-M -1 3922' ,< x a D--f 4712' -I 7"FES ES CEMENTER,D=6.188" Minimum ID = 3.725" @ 8993' 4-1/2" HES XN NIPPLE ' ' 8928' -ja-1r2"IIxNIP,ID=3.813• Z X 8949' H7"X 4-1/2"BKR S-3 PROD PKR,D=3.875" I I 8972' -14-1/2"HES X NP,D=3.813" I I 8993' H4-1/2'HES XN NP,D=3.725' TOP OF4-1/2"LIR H 9007' 9007' 7"X 5-1/2"HRD ZXP LW V w/T1133ACKSLV,D=4.40" 4-1/2'TBG,12.6#,L-80 TCN, .0152 bpt,D=3.958' H 9015' 8 9015' H41/2'WLEG,D=4.00" 9029' H7"X 5"BKR FLEX LOCK LNIR HGR,D=4.400' ESTMATED TOP OF CEMENT(05/22/07) -i 9102' \ - •�i .':, 90 '395"X 4-1/2"XO,D=3.958" ♦• •7'CSG,26#,L-80 BTC-M,D=6.276" -I 9158' 0�� • �4• EL&D Tr LOGG®NOT LOGGED •• �•�• •�• • ♦# • ASA FEF ORATION SUMIAAR' ••� REF LOG:MAD ON 10/09106 • •4 ANGLE AT TOP PEFF:79°@ 9685' ••j • lAIY Note:Refer to Production DB for historical perf data �•� SIZE SPF INTERVAL Opn/Sqz SHOT SQZ •j 4 ••�4 SEE PAGE 2 FOR PERFORATION(DATA :�4 6, 10949' -14-1/2"FIGS ES CEMENTER,D=3.980" � � ��•• 11003' -{PAYZOPE EXTERNAL PKR,D=3.900" I I MID . 2243-1 .... 4 ,ii Watt 4-1/2'LNR, 12.6#,L-80 I3T-M,.0152 bpf,D=3.958" H 12330' IOVAVAVAVAVAW DATE REV BY COMi.BNTS DATE REV BY COMVENTS PRUDHOE BAY IHT 10/26/06 N9ES INITIAL COMPLETION 02/15/11 M3/JMO ADDED SSSV SAFETY NOTE WELL: L-04 01/04/07 JAF/TLH COMPOSITE BP SET(12/30/06) 01/17/12 TMNIJMO ADDED HRS SAFETY NOTE FERMI No:'2061200 05/22/07 AI+VTI-L ADPERF/CMT S07/MLL PLUGS 11/25/13 KAB/JMIS FIXED PERF SUMMARY DATE AR No: 50-029-23319-00 06/25/07 ?/PJC DRLG DRAFT CORRECTIONS 04/08/14 JC/PJC ADFERFS(4/3 Ti-RU 4/7/47) SEC 34,T12N,R11 E,2380'FSL&1566'FWL 12/07/08 DBRSV PERF CORR 06/01/09 KEY/TLH CTU ADMIRES(04/18/09) BP Exploration(Alaska) L-04 r 1 Li 1 x x a D I I .S Z PERFORATION SLJv AARP I I FEF LOG:MO ON 10/09/06 ANGLE AT TOP PERF:79"@ 9685' We:Refer to Adduction DB for historical perf data , I SEE SPF INTERVAL OpnlSgz SHOT SOZ 3-3/8" 12 ' 9102-9107 S .10/18706 10118/06 3-3/8" 6 9685-9705 0 04/14/09 2-718" 6 9710-9725 0 04/07/14 0 tib,„ 2-7/8" 6 9730-9755 0 04/07/14 I I 2-7/8" 6 9762-9772 0 04/07/14 2-7/8" 6 9790-9810 0 04/06/14 3-3/8" 6 9810-9830 0 04/14/09 Vii STATE OF ALASKA RECEIVED 1 ALA OIL AND GAS CONSERVATION COMMI•N AUG 2 2017 REPORT OF SUNDRY WELL OPERATIONS / G 1. Operations Abandon u Repair Well U Plug Perforations L Perforate U Other Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other 0 Re -enter Suspended WeIFJ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: BP Exploration (Alaska), Inc Name: Development❑ Exploratory ❑ • 206 -120 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ffil 6. API Number: Anchorage, AK 99519 -6612 50 -Og9- 23319 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ` ADL0028239 PBU L -04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): 1 To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12330 feet Plugs measured None feet true vertical 8996.18 feet Junk measured None feet Effective Depth measured 12243 feet Packer measured See Attachment feet true vertical 8977.51 feet true vertical See Attachment feet 0 4 Casing Length Size Burst BAR Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 28 - 108 28 - 108 1490 470 Surface 2670 9 -5/8" 40# L -80 29 - 2699 29 - 2698.22 5750 3090 Intermediate None None None None None None Production 9132 7" 26# L -80 26 - 9158 26 - 8660.38 7240 5410 Liner 3323 4 -1/2" 12.6# L -80 9007 - 12330 8548.82 - 8996.18 8430 7500 Perforation depth Measured depth 9685 - 9705 feet 9810 - 9830 feet 9900 - 9910 feet 9940 - 9960 feet 10020 - 10040 feet 10140 - 10150 feet 10485 - 10490 feet 11700 - 11970 feet 12050 - 12237 feet True Vertical depth 8895.38 - 8899.22 feet 8921.01 - 8925.36 feet 8939.87 - 8941.65 feet 8946.58 - 8949.6 feet 8957.57 - 8960.1 feet 8972.58 - 8973.9 feet 9016.62 - 9017.15 feet 8946.6 - 8948.86 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 23 - 9015 23 - 8554.68 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9685 - 9705, 9810 - 9830, 9900 - 9910, 9940 - 9960, 10020 - 10040, 10140 - 10150, 10485 - 10490, 11700 - 11970, 12050 - 12237 Treatment descriptions including volumes used and final pressure: 101 Bbls 7.5% HCL, 500 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2078 0 1388 Subsequent to operation: 0 0 2232 0 1295 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 19 • Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG © GINJ ❑ SUSP ❑ SPLUCJ 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: 311 -077 Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature Phone 564 -4424 Date 8/24/2012 QQ V .1-' IZ rl R S AUG 8 X012 d� Z �� Form 10 -404 Revised 10/2010 Submit Original Only • • Packers and SSV's Attachment ADL0028239 SW Name Type MD TVD Depscription L -04 PACKER 8949 8430 4 -1/2" Baker S -3 Production Packer L -04 PACKER 9019 8481.11 5" HRD ZXP Packer L -04 PACKER 11003 8914.2 Payzone External Casing Packer • • Daily Report of Well Operations ADL0028239 ACTMTYDATE 1 SUMMARY Objective -Fluff and stuff, Schmoo -be -gone, 7..5 %,HCI w /20% Xylene acid, injectivity test and (PROF. MIRU. MU 1.75" DJN. OAL = 9.12'. PT to 300/4000 psi. Injectivity Test down tubing w /1% KCI. Final @ 3.1 bpm/WHP of 1476 psi. Pump 10 bbl m/w down backside. Jet SBG from surface © 1 bpm /80 fpm. to 9000'. SD pumping. Dry drift to 12232' (up). PU 10' to 12222', flag CT. Continued on 06/9/12 WSR. 6/8/2012 Continued from 06/08/12 WSR. Pull up from flag @ 12222' to 9000'. Resume jetting SBG from 9000' © 0.9 bpm /40 fpm. Jet to hard tag @ 12232'. Recip on tag. no change. Pull to 9000', let SBG soak 1 hr. Jet remaining SBG from 9000'- 12232'. Pull to 9000', let SBG soak. Flush tubing w/ 260 bbls of KCI. SRT down the CT © 1 bpm @ 872 psi WHP, 1.2 bpm © 900 psi WHP. Lay 7.5% HCI w /20% Xylene from 12,222' to 9050'. Soak for 30 min. POOH to 9015'. Pump 25 bbls 1% KCI slick down tubing to flush remaining acid. Pump down CT for injectivity test: 1 bpm © 825 psi WHP, 1.5 bpm @ 950 psi WHP. POOH. Repeat backside SRT. Displace fluids to perfs. Final injectivity was 1485 psi © 4 bpm. (Result is 3.88 bwpd /psi WHP). Continued on 6/9/2012 06/10/12 WSR. Continued from 06/09/12 WSR. Let well stabilize on PWI injection. MU SWS mem IPROF string. Have PCC set choke to manual to stabilize injection. RIH w/ mem IPROF string. Log (PROF from 9000' - 12202' up /down passes @ 40, 60 and 80 fpm. Stop counts @ 12179, 12000, 11000, 10300, 10090, 9990, 9925, 9860, 9750, 9400, and 9000' @ 3001 BWPD @1386 psi WHP. POOH. Close crown and swab valve. Pop off and download log data. Good data. Install night cap. PT to 500/3500 psi. Wait on wind. 35+ mph gusts. Switch to weather standby WSR. 6/10/2012 TREE= 4 -1/16" CNV • -- SAID NOTES: H2S READINGS AVERAGE 125 ppm WELLHEAD = 11" FMC WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR = LEO L-04 MI. ""WELL ANGLE> 70° la 949V ""***NOTE WATCH KB. ELEV = 76.5' BF. ELEV = ? FOR COMPOSITE PLUG DEBRIS (4 PLUGS MILLED _ ._ .... ___ I KOP = 3900' Max Angle = 99° @ 10828' " CONDUCTOR 74' 2009 HES X NIP, ID = 3.813" 1 Datum MD = 9578" ( 20 Datum TVD = 8800' SS 19 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" --I 2699' 7" CSG, 26 #, L -80 TCII X0 TO BTC-M —I 3922' • • 4712' --17" HES ES CEMENTER, ID = 6.188" I Minimum ID = 3.726" @ 8993' 4 -1/2" HES XN NIPPLE ' 1 8928' 1— {4- 112 " HES X NIP, ID = 3.813" 0 M 8949' H7" X 4-1/2" BKR S -3 PROD PKR, ID = 3.875" I 1TOP OF 4-1/2" LNR 9007' • 8972' H4 -12" HES X NIP, ID = 3.813" 8993' H4-1/2" HESXN NIP, ID = 3.725" I I 1 9007' 1-- X 5 -12" HRDZXP LTP w / TIEBACK SLV, ID =4.40" 4-1/2" TBG, 12.6#, L -80 TCII, .0152 bpf, ID = 3.958" 1 9015' 9015' H4-1/2' WLEG, ID = 4.00" 9029' H7" X 5" BKR FLEX LOCK LNR HGR, ID = 4.400" ESTIMATED TOP OF CEMENT (05/22/07) H 9102' 4. v. � i 9039' --I 5" X4 -112" XO, ID= 3.958" I �i�i 4 17" CSG, 26 #, L -80 BTC-M, ID = 6.276" 9158' �i0 H TT LOGGED NOT LOGGED PERFORATION SUM • • NM !! • REF LOG. MWD ON 10/09/09 � • , • • • ANGLE AT TOP PERF: 79° @ 9685' •�•• • Note: Refer to Production DB for historical perf data j �r SIZE SPF INTERVAL Opn /Sqz DATE •••• 3 -3/8" 12 9102 - 9107 S 10/18/06 3 -3/8" 6 9685 - 9705 0 04/14/09 • • • 3 -318" 6 9810 -9830 0 04/14/09 !••# - 2-1/2" 4 9900 - 9910 S 05/22/07 • •! • 3 -3/8" 6 9940 - 9960 0 04/14/09 ! * i 10949' H4-1/2" HES ES CEMENTER, ID = 3.980" 1 ••• ,P• 3 -3/8" 6 10020 - 10040 0 04/14/09 •••. �•�� 3 -3/8" 6 10140 - 10150 0 04/14/09 I ∎' ∎.j 11003' —1 PAYZONE EXTERNAL PKR, ID = 3.900" I 3 -3 /8" 6 10485 - 10490 0 04/14/09 2-1/2" 4 11700 - 11970 0 10/24/06 1 2 -1/2" 4 12050 - 12237 0 1024/06 1 I PBTD H 12243' Vccff 4-1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" H 12330' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/26/06 N9ES ORIGINAL COMPLETION 06/01/09 KEY/TLH CTU ADPERFS (04/18/09) WELL L -04 01/04/07 JAF/TLH COMPOSITE BP SET (12/30/06) 02/15/11 ' MB/JMD ADDED SSSV SAFETY NOTE PERMIT No: J t061200 05/22/07 AHI-VTHL ADPERF /CMT SQZ /MILL RUGS 03/27/11 JNUPJC KB/ LOCATION CORRECTION API No: 50- 029 - 23319 -00 06/25/07 ?/ PJC DRLG DRAFT CORRECTIONS 01/17/12 TMN/JMD ADDED H2S SAFETY NOTE SEC 34, T12N, R11 E, 2380' FSL & 3714' FEL 09/19/07 DRS /PJC PERF CORR 12/07/08 DBR/SV PERF CORR BP Exploration (Alaska) DATE: 27- Jul -12 Stephanie Pacillo TRANS #: 6020 � Data Delivery Seru cis Technician - / Makana K Bender Schlumberger Oilfield Services Natural Rf sourcF Te hrleya 11 WIRELIKE y 2525 Gambell St, Ste, 400 MED BAR 2 8 Z0 Anchorage, AK 99503 r r te: ��; (�':r ;r ;' r aPPAV IVl !d �'b!'M� • . 111: Office: (907) 273 -1770 WELl , . , , * ` z.., . SeRvIc , ' +.> k .--R S ERV , .' CNL MEGA LOG DESCRIPTION - DATE B/W ' • ° COLOR °; :` $ CD's NAME ORDER# DIST DIST DIST DIST LOGGED PRINTS PRINTS GNI -03 C600 -00012 X MEMORY TEMP PRESS SURVE' 13- Jun -12 1 GNI -04 COT4 -00019 1 CD X MEMORY TEMP PRESS SURVE' 19- Jun -12 1 1 CD MPL -12 BAUJ -00133 X MEMORY LEAK DETECTION LO 8- Jun -12 1 1 CD • Z -06A C2JC -00021 X SCMT 7" 31- May -12 1 1 CD 14 -33A C5X1 -00006 X MEMORY DEPTH DETERMINAT 12- Jun -12 1 Z -06A C2JC -00021 1 CD X SCMT 4.5 31- May -12 1 1 CD 02 -35B C5XI -00008 X MEMORY PPROF W/ GHOST 18- Jun -12 1 L -04 C5XI -00005 1 CD X MEMORY (PROF 10- Jun -12 1 1 CD V -207 C600 -00013 X MEMORY PPROF 15- Jun -12 1 J -26 BZ81 -00019 X 1 CD RST WFL LOG 9- Jun -12 1 1 CD MPB -15 C2JC -00028 X PPROF W DEFT 25- Jun -12 1 MPG -14 C5XI -00007 1 CD X MEMORY LEAK DETECTION LO 15- Jun -12 1 1 CD GNI -02A COT4 -00035 X MEMORY TEMP PRESS SURVE' 7- Jul -12 1 09 -18 C3NA -00021 1 CD X INJECTION PROFILE 14- Jun -12 1 1 CD ilk X X Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 900E Benson Blvd DCS 2525 Gambell St, Suite 400 Anchorage AK 99503 nchorage AK 99508 Q �l D N G • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 23, 2011 TO: Jim Regg '7 P.I. Supervisor 1 e tt( Zl ? / 11 SUBJECT: Mechanical Integrity Tests !!! BP EXPLORATION (ALASKA) INC L -04 FROM: Bob Noble PRUDHOE BAY UNIT L -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry jge---- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT L - 04 API Well Number: 50 029 - 23319 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110822163920 Permit Number: 206 - 120 - Inspection Date: 8/22/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. L -04 T 8507 , IA 454 I 2611 ' 2583 2576 ' ' Well _ Type Inj TVD __` ___ _ P.T.D 2061200 TypeTest SPT I Test psi 2126 _ , OA 680 680 680 680 Interval 4YRTST p/F P Tubing i 1746 1750 1747 1747 Notes: Tuesday, August 23, 2011 Page 1 of 1 • • VETE OFF AlISUEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Carolyn Kirchner Petroleum Engineer BP Exploration (Alaska), Inca (D 6 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU L -04 Sundry Number: 311 -077 MAR 2 2 nil Dear Ms. Kirchner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. : 11.1 . s : one DATED this /7 of March, 2011. Encl. STATE OF ALASKA % ` ALASKA•AND GAS CONSERVATION COMMISSION (I `� /� // APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate 0 - Alter Casing ❑ Other: FLUFF'N'STUFF /Af, n - 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 206 -1200 3. Address: P.O. Box 196612 Stratigraphic ❑ Service is - 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23319 -00 -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 ❑ PBU L -04 - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028239 - PRUDHOE BAY Field / PRUDHOE BAY 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): 12330 - 8996.18 - 12243 _ 8978- NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 28 108 28 108 1490 470 Surface 2670' 9 -5/8" 40# L -80 29 2699 29 2698 5750 3090 Production 9132' 7" 26# L -80 25 9158 25 8660 7240 5410 Liner 3323' 4 -1/2" 12.6# L -80 9007 12330 8549 8976 8430 7500 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6 #1 L -80 SURFACE 9015 Packers and SSSV Tvoe: 7" X 4 -1/2" BKR S -3 PROD PKR Packers and SSSV MD and TVD (ft): 8949 8507 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/28/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG IS - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Carolyn Kirchner Printed Name Carolyn Kirchner Title PE Signature / / / Phone Date 564 -4190 3/14/2011 Prepared by Joe Lastufka r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\k-M Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED' Other: MAR 14 2011 Alaska DO & Om Cons. Commission Subsequent Form Required: lO y� nCHQra 'f � � APPROVED BY Appr @tt;MC M 21 � �+ , . � MISSIONER THE COMMISSION Date: '"/ '" /( 1''��(J .7 � 2011 I / /,� 3. • �� Form 10-403 Revised 1/2010 , O G 1 NI L Pr #0, Submit in Duplicate L -04 _ 206 -120 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L -04 10/24/06 PER 11,700. 11,970. 8,946.6 8,948.86 L-04 10/24/06 PER 12,050. 12,237. 8,949.45 8,976.25 L-04 5/17/07 PER 9,900. 9,910. 8,939.87 8,941.65 L-04 5/21/07 SQZ 9,102. 11,003. 8,618.8 8,990.7 L -04 4/12/09 APF 10,485. 10,490. 9,016.62 9,017.15 L -04 4/13/09 APF 9,810. 9,830. 8,921.01 8,925.36 L -04 4/13/09 APF 9,940. 9,960. 8,946.58 8,949.6 L -04 4/13/09 APF 10,020. 10,040. 8,957.57 8,960.1 L-04 4/13/09 APF 10,140. 10,150. 8,972.58 8,973.9 L -04 4/14/09 APF 9,685. 9,705. 8,895.38 8,899.22 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 • • • Memorandum To: Tyler Norene /Clark Olsen Date: March 14, 2011 GPB Well Ops Team Leaders From: Carolyn Kirchner Code: APBLPDWL04 Petroleum Engineer Subject: L -04i CT SBG, Fluff'n'Stuff, Acid, IPROF AAIOR: 150 Est. Cost: Please perform the following procedure: 1 S Pull MCX Drift to deviation 2 C Fluff'n'Stuff, Schmoo -be -gone, Acid, IPROF — run on water injection Current Status: WAG injector — online MI — plan to swap to water soon r Last Test: 02/27/11 3000 SCFD, 3000 psi WHIP Max Deviation: 99 deg CP 10828' MD Perf Deviation: 79 deg @ 9685' MD Minimum ID: 3.725" © 8993' 4 -1/2" HES XN Profile Last Downhole Op: 10/05/10 C/O MCX at 1990' MD 04/12/09 CT Acid Stim Last Drift: 04/12/09 Unable to drift past 12,033' ctMD Latest H Value: N/A SBHP /SBHT: 02/18/07 3870 psi, 230 degF at 8800 TVDss Reference Log: 10/09/06 SWS Vision Service MWD — Final Print Program Objectives: Use coiled tubing to perform a Fluff'n'Stuff to push away fill in the bottom of the well. This will be V followed up with schmoo -be -gone and acid to ensure that fill is broken up in the formation. An injection profile will be run while on water to determine the relative injection contributions. Perforations were added in 2008 and 2009 and it will be valuable to see the new injection splits along with the benefit of thermal fracturing. Well History: L -04i is a WAG injector for the NWE area that clearly supports well V -04. Drilled in 2007, it has a 3000 ft horizontal section that crossed several faults resulting in losses while drilling and cementing the liner. A / remedial cement job was carried out and confirmed with an SCMT. Due to variability in permeability, the tighter horizons at the toe were brought online first so that they could be thermally fractured with colder water. Following successful thermal fracturing, perforations were added uphole and the well was acidized. The well was put on MI 8/2009 and has almost completed the first slug. Please contact Carolyn Kirchner at 564 -4190 (W), 227 -6169 (C) with any questions or comments. • • cc: Well File Ann Comm: Problem _ Status ;New Well Drilled 10/06 > 10/25/06: Rig MITIA Passed to 4000 psi 'OA Pressure assumed to be > 09/03/07: AOGCC MIT -IA Passed to 2360 psi from shallow gas source per > 05/26/09: Set MCX @ 2009' MD APE - 3/30/09 > 12/05/10: Re -set SSSV Conductor treated w/ 15.3 gals of RG -2401 - 06/25/09 Risks & Discussion • A sundry will be required for the stimulation of this injector. • The Fluff'n'Stuff method is planned for this operation. • The ideal cleanout depth would be 12240'. The total volume of fill to be fluffed and stuffed away is —3.2 bbls. • The IA has inhibited 8.9 ppg brine to —1880' MD and 35bbls of diesel to surface. • SBG is a basic solution and when mixed with HCL, could create a hazardous condition. Avoid commingling of these fluids on surface and use large 1 % KCL spacers when changing from one to the other during the course of the job. • Estimated Fluid Summary — Confirm by Slope for Order Form o 125 bbls 7.5% HCL with 20% xylene and additives as per SLB o 100 bbls SBG o 30 bbls of diesel plus diesel for liquid packing IA based on fluid levels o — 700 bbls of 1% KCL, —300 BBLS 1% XS KCL ✓ o — 150 bbls 60/40 methanol water PROCEDURE Slickline Drift to Deviation 1. MIRU SL. Pull MCX. No need to re -run MCX as well will be swapped to water injection. 2. Drift to deviation with 3.65" OD drift na d sample bailer. If unsuccessful with 3.65" OD toolstring, run smaller OD toolstrings. Attempt to get a sample of fill for analysis. 3. Recover any material in sample bailer; label with well name, date, collection depth and APE contact (Carolyn Kirchner) and drop off at SLB lab in Deadhorse for solubility testing. Have sample tested for solubility in SBG and acid system to be pumped. At this same time, confirm the test results of SBG and the HCL system for any precipitation issues in the unlikely event downhole interaction occurs. Contact APE with lab results or if precipitation problems are found. Coiled Tubing Schmoo -Be -Gone Fluff'n'Stuff & Acid Wash Last SBG pumped 5/22/09. Target swap to water is March /April 2011 so this is good timing for the SBG. DIMS indicates that IA is loaded with 8.9 ppg inhibited brine and a 34 bbl diesel cap. No GLVs in well. NOTE: Contact the facility ahead of the job to ensure SBG can be taken to the plant as a contingency if injectivity is lost. 4. Stage transports and necessary equipment and tanks to pump job. • • 5. MIRU 1.75" CT. Ensure well is SI and FP by operator. MU MHA BHA with 2.25" JSN and PT. Monitor all wellhead and annulus gauges. 6. Open well and line up down the production tubing with 1% KCL. Perform an injectivity test at 1.0, 2.0, 3.0, and 4.0 BPM. Make last rate at maximum pump rate. Do not exceed 1500 psi WHP. Note results in WSR. 7. With the well shut -in, pump 10 bbls of McOH into the production tubing. 8. Jet from surface to 9000' with SBG at maximum rate while displacing the coil. This will leave SBG in the tubing and the well freeze protected during the jetting and fluff and stuff operation. Once the nozzle is at 9000', SD and RIH to dry tag top of fill. Correct CT depth for the cleanout. This tie -in is important to ensure the perfs are completely uncovered. Note depths and corrections in WSR. 9. Once back to 9000', come back on line with SBG at — 2.5 BPM and continue jetting down to the top of fill. Once at the top of fill, continue jetting with SBG as necessary while fluffing and stuffing into the formation. Take small bites and chase up to above the perfs to ensure all debris has been pushed into the formation. Use SBG while jetting and 1% XS KCL while chasing up through the perfs. If well appears to be locking up with debris, then it may be necessary to continue the cleanout the long way taking returns. Maximum WHP for fluff and stuff operations should not exceed 3000 psi. Attempt to cleanout to 12,240' MD. NOTE: During the fluff and stuff, SBG will be soaking in the tubing to clean any remaining schmoo from the tubing. This will be displaced into the formation once the liner has been cleaned out. 10. If a hard crust is encountered that can not be jetted through with SBG or 1% KCL, perform the following steps: a. PUH to 9050' while pumping 35 bbls of 1% KCL down the tubing, then pump 10 bbls of 7.5% HCL, follow acid with at least 35 bbls of 1% XS KCL. These 1% KCL spacers will keep the HCL from being neutralized by the SBG. b. Once 1% KCL is at the nozzle, RIH displacing all SBG from the liner down to the crust and into the perfs before the HCL gets to the nozzle. 1% KCL ahead and behind is to keep acid away from the SBG in the coil and downhole. Use -10 bbls of the 50 bbls of 7.5% HCL w /xylene on location to jet with. Let soak and resume jetting. (additional acid does not need to be ordered as remaining 40 bbls will be sufficient for stimulation later in the job) c. If this is unsuccessful then POOH and pick up down jet nozzle. d. -or- as a last resort, a motor and mill. CAUTON: in the event a motor and mill is required, ensure the wellbore has been sufficiently • displaced to remove any SBG or acid as returns may need to be taken. The recommended method utilizing the motor and mill would be to make hole while suspending solids in gel and taking small bites to avoid getting stuck. If return rates are good, debris and solids may be circulated out other wise they can be bullheaded back into the formation once tools are above the top of the suspended debris. If bullheading is necessary, re -tag TD to ensure that at least the minimum depth of 9730' has been reached after any remaining solids in the sump have had time to settle out. 11. Once the well has been cleaned out, PUH above the perfs with the nozzle and freeze protect the coil as necessary to prepare to pump acid. • • • 12. Bullhead 140 bbls of 1% KCL down the backside at maximum rate to flush all SBG from the tubing prior to the acid job. Slowly PUH while displacing the backside volume to keep pipe moving. 13. Follow with 2 bbls of 60/40 methanol water spear and underbalance with —30 bbls of diesel in preparation for the acid job. This should result in — 100 psi WHP. 14. Come on down the coil with 1% KCL while preparing for acid. Once coil has been displaced with 1% KCL, perform injectivity test at 1.0, 1.5 and 2.0 BPM. Do not exceed a maximum WHP of 1500 psi. Note results in WSR. 15. Follow 1% KCL with 7.5% HCL with 20% xylene. Jet with —75 bbls of acid across perforated interval. (SIBHT =230 Deg F). Make one up /dn pass across the entire perforated interval with 50 bbls and let acid soak for 15 to 30 minutes, depending on ambient temperature constraints. 16. Make second pass at max rate with remaining 7.5% HCL. Displace coil with 1% KCL while pulling up above the perforations to 9050' and allowing the acid to soak. 17. After soak period, pump 50 bbls 1% KCL while RBIH to over displace 7.5% HCL from the near wellbore and sump. PUH to 9050' and perform a post acid injectivity test down the coil at 1.0, 1.5, 2.0 BPM as before to understand the acid stimulation. Freeze protect coil on way OOH. Once coil is freeze protected, start loading the well for a final injectivity test. 18. Pump at least 140 bbls of 1% KCL, and once at surface perform final injectivity test as before at 1.0, 2.0, 3.0, and 4.0 BPM. Make last rate at maximum pump rate. Do not exceed 1500 psi WHP. This is the final maximum rate injectivity test to evaluate the entire job. Note results in WSR. Bleed down IA to 0 psi. 19. Place well on injection if possible, notifying operator that the IA is fluid packed, otherwise freeze protect well and request it to be placed on injection as soon as possible. RDMO CTU. Schedule the S/L work for one week after well is placed on injection. Hang CAUTION tag on IA to watch for thermal expansion. Coiled Tubing IPROF on Water Infection Allow injection to stabilize prior to logging. Normal injection should be 1700 psi, 2000 bwpd. Tie -in log: 10/09/06 SWS Vision Service MWD — Final Print 20. MU FSPL BHA with sr. innerlT /P /GR /CCL/XY- Caliper. 21. RIH and ensure well is on stable injection, either MI or water. Log up & down dynamic passes at 40, 80, 100 fpm over the interval of 9000'- 12240' MD or as deep as possible based on tag depth. The last CT tag (4/12/09) was only able to reach 12,033' ctMD. Hopefully the schmoo -be -gone fluff'n'stuff treatment will have improved tag depths. 22. Obtain the following stop counts: Stop Count Depths (MD) 9000' 9400' 9750' 9860' 9925' 9990' 10090' 10300' 11000' 12000' • • 12240' or as deep as possible 23. Record injection rate, choke, WHIT, WHIP, IBHP, IBHT. 24. RDMO Log Presention: Depth shift final log presentation to 10/09/06 SWS Vision Service MWD — Final Print. The following information should be presented on the final print: 1. Job comments. operating steps in sequence, logging passes made, injection splits, basic field interpretation. 2. Present all up pass data in overlays. 3. Present up /down overlay from speed with best data. 4. Stop counts. Schlumberger Company: BP Exploration (Alaska) Inc. FINAL Well. L -04 VISION' Service Field: Prudhoe Bay Rig: Nabors 9ES S'=: Alaska Measured Depth 1 og - Recorded Mode FINAL PRINT a Scale 1:600 ' Y c Total deptr _... - - 123301 - K NWA Top Down m S Iii t g w Strad date: 23-Sep-06 y Ci L. 411,0 ft °) 2G `- Flans. 1 To 5 le DV /Wilt F'crrnananl datum Mean Stas I ever Hey • 0 t1 Z 11 X - � H Loy measured from: Dell Floor 76 k above term. datum c c lath reference.' 1MIler's Pipe sally is tU _ E API serial no. • 23130 FSL 3/14 1-EL L e t.Maude 1 LL - 5(1-025- 233f90 Sec. 34, T12N, RI 1E I W 449.32449 11 7035014 Depth logged: 45 ft To 12330 ft Mag dect. 24.10 deg- I Otter services: -- Date logged. 23- Sep-08 Ti r 1TOct 05 Mao dip. 80.110 rie g I DD. D &J, DWORiO TOR Bore hole record Casing recent Hole sue from 1r z• I Dcn.Ma 1 from to 1225 in Li - - � f 12.. t _... 1 1 91P^1,111/(1111 ''L --- _LID ft- R 715 41_ - -._ 27121. 01t6 L S t><., r l r t 2095 `t ... .51ts'S f. 1:::3:K; ?!. r or !i 7 t. _._ 0166'1 I f - .._ ..,.__ • .er.. f , rr , 591- .; i• tion record h ue --_.. from..._ __. ,.. Ma. hfa7C _. et• a . •, ..udMini Oft 2/12ft ∎.. L:,1 ,. ?' d_ ... Oft 2T1 f LSM.) 2/12 ft 9165ft !`1:.'e' 1'?d..:. 2712ft 61868 Flo Pro 9166 ft 12330ft t , If .1. i;. .. 91tz>11 1 Surface equipment k ttware record Unit 1 POIJ _-- __.._.._.... - -. I Of 4v' i , a � Ot Depth system 1 n ; CA 1 S$'M TRE= 4- 1/16" CM/ I SAFETY I : WELL REQUIRES SSSV WHEN WELLHEAD = 11" FMC ON Ml. "**WELL ANGLE> 70° @ 9496' 'NOTE: ACTUATOR = LEO L _p 4 WATCH FOR COMPOSITE PLUG DEBRIS (4 PLUGS KB. ELEV = 28.5 MILLED 05/22/07) BF. ELEV = 73.5 ' KOP = 3900' Max Angle = 99° @ 10828' Datum MD = 9578" 120" CONDUCTOR I 74' 2009' H 4-1/2" HES X NIP, ID = 3.813" I Datum TVD = 8800' SS 19 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" 1-1 2699' 17" CSG, 26 #, L -80 TCII XO TO BTC-M H 3922' • • 4712' H 7" HES ES Cev1ENTER, ID = 6.188" I Minimum ID = 3.725" @ 8993' 4-1/2" HES XN NIPPLE I 8928' I- I a -u2 HES X NIP, ID = 3.813° 8949' H 7" X 4-1/2" BKR S -3 PROD PKR, ID = 3.875" I kTA I 8972' H 4-1/2" HES X NIP, ID = 3.813" I 8993' 1-1 -112" HES XN NIP, ID = 3.725" I ITOP OF 4-1/2" LNR H 9007' I 9007' I- 7" X 5 -1/2" HRD ZXP LIP w/ TIEBACK SLV, ID = 4.40" 14-1/2" TBG, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" I 9015' 9015' I- I 4 -1/2" WLEG, ID = 4.00" 9029' 1-17" X 5" BKR FLEX LOCK LNR HGR, ID = 4.400" I ESTIMATED TOP OF CEMENT (05/22/07) H 9102' AV. • -• • • i 9039 1-1 5" X 4 -1/2" XO, ID = 3.958" I • ••• ••• �•�• I I-1 ELMD TT LOGGED (DATE) I 17" CSG, 26#, L -80 BTC-M, ID = 6.276" H 9158 ∎ • • ! *!A! PERFORATION SUMMARY •• PERFORATION %� REF LOG: MWD ON 10/09/09 ∎ • � I - • ANGLE AT TOP PERF: 79° @ 9685' •�•� Note: Refer to Production DB for historical perf data � SIZE SPF INTERVAL Opn /Sqz DATE ∎ •• � • • '41. 3-3/8" 3-3/8" 12 9102 - 9107 S 10/18/06 •• 4 - 3 -3 /8" 6 9685 - 9705 0 04/14/09 •• 3 -3/8" 6 9810 - 9830 0 04/14/09 1 2 -1/2" 4 9900 - 9910 S 05/22/07 •i 3 -3/8" 6 9940 - 9960 0 04/14/09 v • * .4 10949' — 14 -1/2" HES ES CEMENTER, ID = 3.980" I 3-3/8" 6 10020 10040 0 04/14/09 41 • * 4 "•�• 3 -3/8" 6 10140 - 10150 0 04/14/09 j�j j1j 11003' I-I PAYZONE EXTERNAL PKR, ID = 3.900" 3 -3/8" 6 10485 - 10490 0 04/14/09 2 -1/2" 4 11700 - 11970 0 10/24/06 I 2 -1/2" 4 12050 - 12237 0 10/24/06 I I PBTD H 12243' 1- VC•VCI 14 -1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf , ID = 3.958" I-1 12330' I- � ' � ' � *' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/26/06 N9ES ORIGINAL COMPLETION 06/01/09 KEY/TLH CTU ADPERFS (04/18/09) WELL: L -04 01/04/07 JAF/TLH COMPOSITE BP SET (12/30/06) 02/15/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: "2061200 05/22/07 AHH/THL ADPERF /CMT SQZ /MILL PLUGS API No: 50- 029 - 23319 -00 06/25/07 ?/ PJC DRLG DRAFT CORRECTIONS SEC 34, T12N, R11 E, 2380' FSL & 3714' FEL 09/19/07 DRS /PJC PERF CORR 12/07/08 DBR/SV PERF CORR BP Exploration (Alaska) _ .. ; +1F ~ - « .F \ ter.: ~~. ~, °~ dw ~,- - ~~:; ~; MICROFILMED 6/30/2010 D 4 NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE + ~ ~ ~~. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~~:~X `tl ~ { ~ ~~v~i i~ i,y ~~ :rar , .. , ... Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, ~ bp ~ i~~ i~++l~~ ~ 0 C T 0~ 2009 ~ll~sic~ ~il ~ Gas Cons. Cotr~r~i~~ion Anchorage ao~ ~ ~~-a ~ '~ ~ ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator i BP Exploretion (Alaska ) Inc. i Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date L pad 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibftor Corcosion inhibitor/ sealant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29{2009 1-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 102 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 5U029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L•109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6l27/2009 L-114A 2051120 50029230320700 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 ~-176 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L•121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA t NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L413 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 0.25 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6M28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L•51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS EIVED~~ ~~,~~~Y 4 ~ 2009 Si~o9 -;I,~+~ ii ~4 (;a~ Cnns. Commission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate 0 Other 04~iC~COCatlB Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development I~ Exploratory Im 2os-12oo - 3. Address: P.O. Box 196612 Stratigraphic Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-23319-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 76.5 RT , PBU L-04 - 8. Property Designation: 10. Field/Pool(s): _ ADLO-028239 ~ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 12330 - feet Plugs (measured) None true vertical 8996.18 - feet Junk (measured) None Effective Depth measured 12243 ' feet true vertical 8978 - feet . .v Casing Length Size MD ND Burst Collapse CONDUCTOR 110 20" 91.5# H-40 28 - 108 28 - 108 1490 470 SURFACE 2670 9-5/8" 40# L-80 29 - 2699 29 - 2698 5750 3090 PRODUCTION 9132 7" 26# L-80 25 - 9158 25 - 8660 7240 5410 LINER 3323 4-1/2" 12.6# L-80 90073; ~ ~~ ~~4 $;~7~U 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# L-80 SURFACE - 9015' 0 0 c " " ' Pa kers and SSSV (type and measured depth) 7 x4-1/2 BKR S-3 8949 0 0 0 0 0 0 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: 1916 1800 Subsequent to operation: 3492 1624 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory Development i`° Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~~ WAG GINJ ~ WINJ WDSPL 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: 308-301 Contact Gary Preble Printed Name Gary Prebl ~ Title Data Management Engineer Signature Phone 564-4944 Date 5/7/2009 Form 10-404 Revised 04/2006 a. ..~_~,,., , g Submit Original Only L-04 206-120 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top. Meas Depth Base Tvd Depth Top Tvd Depth Base L-04 10/24/06 PER 11,700. 11,970. 8,946.6 8,948.86 L-04 10/24/06 PER 12,050. 12,237. 8,949.45 8,976.25 L-04 5/17/07 PER 9,900. 9,910. 8,939.87 8,941.65 L-04 5/21/07 SQZ 9,900. 9,910. 8,939.87 8,941.65 L-04 4/14109 APF 9,685. / 9,705. 8,895.38 8,899.22 L-04 4/13/09 APF 9,810. / 9,830. 8,921.01 8,925.36 L-04 4113/09 APF 9,940. f 9,960. 8,946.58 8,949.6 L-04 4/13/09 APF 10,020. / 10,040. 8,957.57 8,960.1 L-04 4/13/09 APF 10,140. / 10,150. 8,972.58 8,973.9 L-04 4/12/09 APF 10,485. 10,490. 9,016.62 9,017.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 LJ L-04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE I SUMMARY 4/11/2009 CTU#5 1.75" CT: Scope: acid wash/adperf standby for roads and pads to clear L pad road Preform weekly BOP test. freeze protect well w/ 38 bbls 50/50 meth. Road to pad inaccessible again due to snow drifts. "*continued on WSR 04-12- 09** ~. 4/12/2009~continued from WSR 04-11-09 CTU #5 Scope; acid wash/ adperf «interact i publishing» Perform step rate test w/ KCI 1 bpm @ 1212 psi, 1.5 bpm @ 1402 I ~ psi, 2 bpm @ 1580 psi, 2.5 bpm @ 1720 psi, 3 bpm @ 1812 psi, 3.5 bpm @ 1900 I psi, 4 bpm @ 1992 psi, 4.5 bpm @ 2110 psi, 5 bpm @ 2124 psi.. cap tbg w/ 15 ~bbls 50/50 meth. Having trouble getting thru SSV stroked SSV all the way open ~ ~ RIH. Pumped 50 bbls of 12% HCL 90:10 DAD Acid out the nozzle let it soak for 20 i ~mms. Pump the remaining 50 bbls of acid.Pump 200 bbls 1%KCL down BS for I over flushing acid. Perform second step rate test after acid w / 1 %KCL 1 bpm @ ~ '.927 psi 1.5 bpm @ 1166 psi 2 bpm @ 1224 psi 2.5 bpm @ 1415 psi 3 bpm 1638 ~ psi 3.5 bpm @ 1722 psi 4 bpm @ 1807 psi 4.5 bpm @ 1900 psi 5 bpm 1970 psi. I RIH nipple locator and 5' x 3.375" pert gun: PJ 3406 6spf. Shoot interval (a) €10 485- 10490'. start ooh. "*'ob continued on WSR 04-113-09"" _ ' 4/13/2009 U 5 w / 1.75" CT continued fron WSR 04-12-09 CTU 5 1.75" CT«interact publishing» pooh after gun run # 1. all shot fired. recovered ball. RIH w/ gun# 2. ~ locate xn nipple and tie into top shot @ 10140. good indication of firing. pooh. Gun ~ #2 10' (3.38" PJ3406) 6 SPF Top shot ~ 10140' Bottom shot ~ 1015Q all shots ~ .fired and recovered 1/2" ball. (Run #3) 20' (3 3/8" PJ3406) 6 SPF Top shot @ 10020' bottom shot @ 10040' all shots fired recovered 1/2" aluminum ball. (Run I ~#4) 20' (3 3/8" PJ3406) 6 SPF Top shot @ 9940" bottom shot @ 9960' all shots Mired recovered 1/2" aluminum ball. RIH gun # 5 shoot pert interva 9i~' U-9830' w/ E20' x 3.375" 6spf PJ3406 charge. Pooh. MU gun #6 ""job continued on WSR 04- 3 ~ 14-09** 4/14/2009acontinued from WSR 04-13-09 CTU #5 w/ 1.75" CT «interact publishing»RIH w/ gun # 6 locate ite inot xn nipple. Shoot pert interval 9685-9705. good indication of firing. (see pert data) pooh. (all shots fired) Perform step rate test w/ 1 %KCL; 1 bpm @ 692 psi, 1.5 bpm @ 886 psi, 2 bpm @ 1068 psi, 2.5 bpm @ 1260 psi, 3 'bpm @ 1390 psi, 3.5 bpm @ 1588 psi, 4 bpm @ 1700 psi, 4.5 bpm @ 1790 psi, 5 bpm @ 1844 psi.. pad operator cannot bring well online. Freeze protect well w/ 38 bbls 50/50 meth. ''"job complete** FLUIDS PUMPED BBLS 112 KCL 71 50/50 METH 183 Total WALL LAG TR~4~1/~>~II/T=TL ProAative Diagnostic Services, Ina. To: AOC~C Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspectian(Caliper/ MT17 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnicai Data Center Attn: Joe Lastuflca LA2-1 900 Benson Blvd. Anchorage, Alaska 99508 3 r.`r ~ ~%' ~.' i and ProActive Diagnostic Services, Inc. ~ ~ T ~ ~b ~ - "l. J C f, ~ ``~' Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile 25-Dec~08 L-04 1 Color Log / EDE 50-029-23319-00 2j Leak Detection - WLD 05,Jan-09 P-07A 1 Color Log / EDE 50-029-22535-01 ^~ Signed . ' `~...% Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245$8952 E-MAIL : ~~sanchor~gena lraer~orylog.~ora~ WEBSITE : v~v~rs.~aerrtorVlog.corl~ .!' C:~DocumenLS and Setdngsl0wner~DesktoplTransmit BP.docx a~c ~~~ DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061200 Well Name/No. PRUDHOE BAY UNIT L-04 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23319-00-00 MD 12330 TVD 8996 Completion Date 10/24/2006 Completion Status WAGIN Current Status WAGIN UIC Y~~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR / GR, GR /RES / PWD, USIT, GR /RES /DEN / NEU, SCMT (data taken fro m Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T e Med/Frmt umber Name Scale Media No Start Stop CH Received Comments ED D As Directional Survey 0 12330 Open 10/19/2006 Rpt Directional Survey 0 12330 Open 10/19/2006 ~ / Q°~ Log Cement Evaluation 5 Col 1 200 9126 Case 10/25/2006 USIT, CCL, GR 10-Oct- 2006 / v L / / og Cement Evaluation . 5 Col 1 9000 11900 Case 10/25/2006 SCMT, Spin, Temp, Pres, / ~ GR, CCL 21-Oct-2006 , Log Cement Evaluation 5 Col 1 9000 10900 Case 10/25/2006 SCMT, MaxTrac Tractor 16- Oct-2006 Log Cement Evaluation / 5 Col 1 9000 11900 Case 11/29/2006 SCMT, Spin, Temp, Pres, GR, CCL 21-Oct-2006 ~ Log / Leak ~ 5 Blu 1 8801 11572 Case 2/20/2007 Mem LDL, GR, CCL, CNL, Temp, Pres, Spin 30-Dec- 2006 Log / Temperature ~ 2 Blu 1 8790 11592 Case 4/20/2007 Mem Spin, Temp, Pres, GR, CCL, STP 18-Feb-2- D C L 15158 r'S N 2007 as ee ot 8798 11607 Case 5/24/2007 Coil Flaging, GA, CCL w/Graphics PDF, Tif, LAS D C Lis 15205 ~ amma Ray 51 12329 Open 6/11/2007 LIS Veri, GR, ROP, FET w/Graphics TIF Log ~ 15205 Induction/Resistivity~ 25 Blu 49 12330 Open 6/11/2007 TVD Vision Service 9-Oct- , / ! ~ 2006 Log 15205 Induction/Resistivit 25 Blu 49 12330 Open 6/1.1/2007 MD Vision Service 9-Oct- 2006 Log Cement Evaluation 5 Col 1 8914 12177 Case 9/28/2007 MCBL, GR, CCL, SCMT L 26-Aug-2007 og / Neutron 2 Blu 1 8801 11572 Open 10/26/2007 MCNL, GR, CCL, Temp, Pres, Spin 30-Sep-2007 DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061200 Well Name/No. PRUDHOE BAY UNIT L-04 Operator BP EXPLORATION (ALASKA) INC MD 12330 TVD 8996 Completion Date 10/24/2006 Completion Status WAGIN Current Status WAGIN Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments UIC Y ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? ~ Chips Received? ~.1.Pl~ / Formation Tops 1 Y `N ~C/ Analysis ~(~ Received? Comments: Compliance Reviewed By: ____ _ Date: _ ~ © _._ API No. 50-029-23319-00-00 r'"; ~ ~, ,,.~ `_.a ~M'~ „ , I f 1 1 ~ ~ ~I ~ l t ~ 1~ Ff d~! ~ .:-, ~ , r ~ . ~ ~ ~ ~,..a ~ t~( kh .t a. _ ~ 1 s ~ ~ ~ _~ i-1r ~.. 1~-~~~ ~...}~ S ~-.~M~.~ CO1~T5ER~TIO CO11~III5SIO15~T Daniel Robertson PE BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PAL1N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBLI L-04 Sundry Number: 308-301 Dear Mr. Robertson: 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, Jr. ~1 Chair DATED this~day of August, 2008 Encl. ~cXP-~av .~~~ ~.~i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO 5 LC7~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Co~missior+ Othe 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ Al1 ~d ~ ~I~J Alter casing^ Repair well ^ Plug Pertorations^ Stimulate ~""Time Extension Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^ Exploratory ^ 206-1200 . 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-23319-00-00 - 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: PBU L-04 - Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ff): 11. Field/Pools(s): ADLO-028239 ~ 76.5 RT ~ PRUDHOE BAY Field / PRUDHOE BAY 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): 12330 - 8996.18 12243 , 8978 - NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 91.5# H-40 28' 108' 28' 108' 1490 470 Surace 2670' 9-5/8" 40# L-80 29' 2699' 29' 2698' 5750 3090 Production 9132' 7" 26# L-80 25' 9158' 25' 8660' 7240 5410 Liner 3323' 4-1/2" 12.6# L-80 9007' 12330' 8549' 8976' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 SURFACE - 9015' Packers and SSSV Type: 7"x4-1/2" bkr S-3 Packers and SSSV MD (ft): 8949' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/28/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^~ ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel Robertson Printed Name Daniel bertson Title P.E. Signature Phone 564-5546 Date 8/14/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: g ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: APPROVED BY ~/ ~ F%~ Approved by: COMMISSIONER THE COMMISSION Date: QQ ~~ ~~ ~~ Form 10-403 evised 06/2006 n R ~ G I N A L - ~~~ ~ ~ ~~~~ Submit in Duplicate L-04 206-1200 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L-04 10/24/06 PER 11,700. 11,970. _ 8,946.6 8,948.86 L-04 10/24/06 PER 12,050. 12,237. 8,949.45 8,976.25 L-04 5/17/07 PER 9,900. 9,910. 8,939.87 8,941.65 L-04 5/21/07 SQZ 9,900. 9,910. 8,939.87 8,941.65 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED 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 • by ~' ,~~,. To: Clark Olsen/Jerry Bixby, GPB Well Ops TL From: Dan Robertson: Area PE Kirsten Schultz: Engineering Intern Subject: L-04i Add Perf and (PROF PBLPDWL04-R Sundry #: This procedure includes the following steps: Date: 08/13/2008 Est. Cost: $200 M IOR: 350 BOPD Type Operation 1. S Drift to deviation with 2.5" dummy gun 2. C Acid perf wash, add perfs (115') Current Status: WAG injection well, currently on produced water injection Typical injection: 2000 bwpd at 2200 psi Max Deviation: 99 degrees at 10828' MD Min. ID: 3.725" @ 8993' (4'/z " HES XN NIPPLE) Last TD tag: 08/24/2007 C~ 12241' MD Last Downhole Ops: 08/24/2007 Cement Bond Log Latest H2S level: N/A Ref Log: 10/9/06 SWS GR/Resisitivity MWD Objective: 1. Stimulate existing perforations 2. Add perfs toward the heel of the well Well L-04i was originally perforated at the toe of the well and water injection commenced with the intent of thermally fracturing the lower permeability intervals at the toe. The well has been on water injection for several months. Infectivity appears to have declined recently, possibly due to perforation plugging. It is now planned to perform any acid pert wash of the existing perfs and add perforations toward the heel of the well to improve conformance with offset producers L-01 and V-04. It is planned to inject water for a few months to thermally fracture the new perforations also, then swap the well to MI injection. • If you have any questions or comments regarding this procedure, please call Dan Robertson at 564-5546 (W), 346-3714 (H), 529-5818 (C). cc: w/a: Well File Procedure• Slickline: 1. RU slickline. Drift to deviation with 2.5" dummy gun. CT: Shut in well and allow pressure to drop to 500 psi or less. This may take a few hours, so may want to shut the well in upon arrival. RU 1.75" service CT, tanks, fluids, associated equipment for acid perf wash and additional perforations. PU 2.5" OD nozzle BHA (2.5" OD minimum to confirm no restrictions for later perforating). If possible, run memory GR/CCL in this BHA, flag pipe for later perforating. If this is not feasible it will be necessary to make an additional trip with amemory GR/CCL for depth control. Prior to RIH, perform step rate injection test with ct tractor pump pumping down backside (not down the coiled tubing). Pump 120 F 1% KCI at 1, 1.5, 2, 2.5, 3, 3.5, 4, 4.5, 5 bpm. Allow pressures to stabilize a few minutes at each rate. Note rate and pressure on job report. Prior step rate injection data is attached below. 2. RIH to below the bottom perforation to confirm liner is clear of obstructions. 3. Pump 100 bbls 12% HCI 90:10 DAD acid (9 gpf) with standard additives for carbon steel tubulars while reciprocating across the existing perforation intervals (pump at maximum rate at 0.65 psi/ft maximum gradient). Pump 50 bbls of HCL out the nozzle, shut down for 20 minutes to allow it to soak, then pump the remaining 50 bbls, shut down again for ~20 minutes. Then overflush with 200 bbls of 1 %KCL, or just use the injection water down the backside along with 50 bbls 1 %KCL out the ct nozzle. POH. 4. Repeat step rate injection test in step one either when at surface with this BHA, or immediately prior to RIH with next BHA, whichever is convenient. Perform both step rate tests without ct in the well so they can be compared directly. Consider freeze protecting well if needed following step rate test as multiple perf gun runs will be required. 5. After memory gr/ccl has been run and pipe flagged, PU perf gun, RIH. Proceed with perforating per attached excel perforating form. Rerun GR/CCL as needed to maintain depth control. 6. After final gun run, repeat step rate injection test as in step 1. 7. RD, return well to water injection at 5 MBWPD target rate. It is planned to leave well on water injection for ~2 months, then swap to MI injection. 12% HCI A261 Corrosion 0.6% 2 • Inhibitor Corrosion A153 Inhibitor 8 ppt Corrosion A179 Inhibitor 4 ppt W54 NonEmulsifier 0.5% W60 Anti-Sludge 0.5% F103 Surfactant 0.2% L58 Iron Stabilizer 20 ppt 2000 1500 1000 • L-04i Step Fate Ir>yec~ion Tests, Pre and Post Water Injection (DBF~ 2/18/0 ?J~6/OB Step Rate Test, after 300 NBUV injection Frac4.re at 1800 ps, 34 bpn~ 0.646 psi/ft patient 34 blxn~1900 lrropd -j Solid line i ~~. ~~ 924/07 step Rate Test, Pre Injection FiaCQre at 1800 psi, 34 bpr~ 0.646 psi/it gaciert 34 bprr>~1900 buulxl L~slled line _.. r Ir ~ ~t- ~ -- ~~ . A r '~ O /L_ 0."" 1.00 2.00 3.00 4.00 V1~6er injection rai6e, bprn i .~'~•' .r I 5.00 6.00 • V~t-P PSI, x'24/07 ^ VIP PSI, 2/1608 3 • Well: L-04i .......................................... Date: 08/13/08 Cost Est: $200M .......... ......................................... CC or AFE: PBLPDWL04-C PERFORATING PROCEDURE Ver1.2,Rev10/21/01 API #: 50-029-23319-00 Prod Engr Dan Robertson Office Ph: 564-5546 H2S Level: Home Ph: 346-3714 N/A Injector .............................................................................. Cell/Pager: 529-5818 WBL Entries IOR Type Work Desciption . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . :..........350 ` ...............-S ;Drift. with 2.5" dummy..dun...................................................... ' i 2.5" nozzle drifU acid wash, add erfs ..........350 ..........:................. C .....P..................................................................................................... € .............................i......................................€.....................................................................................................................................................................................€ Well Objectives and Perforating Notes: Last SBHPS- 02/18/2007 3,870 psi, 230 F ~ 8800' SS Last Tag 08/24/2007 ~ 12241' MD Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log ~ Tie in Log Add/Subtract NA feet Log: GR/RES MD l09 .......................... . to the tie-in log to be on Date: 10/9/2006 depth with the reference log. ............................. Company: SWS ............................. .............................. Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/ReAperf 11,355' - 11,375' ................................ ............................. .............................. .......................... 20' .... ................ 6 .................... random 60 de ,..............................9........... 46 .... ................... re erf .................P......................... 10,485' - 10,490' 5' 6 random 60 de 43 re erf 10,140' - 10,150' .................. ............................. .............................. ............... 10' .... 6 . . . . random 60 de ,. ~........... 44 .... re erf P 1.0,020' - 10,040' ............................. ............ .............................. ........................... ................ 20' .................... . . ............... 6 .................... . ......... .random 60 de .. ........................9........... .. 45 .... ................... re erf .................P....................... .9,940' - 9,960' 20' 6 .. . random 60 de 45 re erf .9,810' - 9,830' 20' 6 . random 60 de 46 re erf .9,685' - 9,705' ........................... .............. . ....... ,20' 6 .......... ......... .random 60 de . .....................9........... . . 46 .... ................... re erf .................P......................... .... . ...............total.foota.9e.............. ... .... ...115.. . ..... . . Requested Gun Size: 2.5" Charge: 2506 Powerjet Omega Is Drawdown Necessary/Desired/Unnecessary During Perforating .Desired.but,not easily achievable ................................................................................................. Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Shoot well shut in. Should be balanced with reservoir due to open perfs.., ................................................................................................................................................ Last Tag: 12.241 ft MD on Well: L-04i Date: --------------- API #: .............................. General Comments: 8/24/2007 Est Res. Pres. C~ 10,080 MD is 3870 psi Perforation Summary 50-029-23319-00 Gun Dia. Orient. SPF Phasing Summary Dist Town: Prod Engr: Anch Prod Engr .................................................................... P. D. Center PBTD Zone Adperf/Reperf Add perfs in 43P through 46P as follows: Zone Top MD Base MD Length MD Comments 46P 11.355 11,375 20 43P 10,485 10,490 5 44P 10,140 10,150 10 45P 10,020 10,040 20 45P 9940 9960 20 46P 9810 9830 20 46P 9685 9705 20 TOTAL FOOTAGE 115 L-04: Add Perfs • u KS / DBR / JNF 08/13/2008 TREE= 4-1/16" CNV WELLHEAD =• 11" FMC ACTUATOR = LEO KB. ELEV...- 28.5 _. _ BF. ELEV = 73.5 KOP = 3900' Max Angle = 99° @ 10828' Datum MD = 9578" Datum TVD = 8800' SS 120" CONDUCTOR I 9-5/8" CSG, 40 #, L-80 BTC, ID = 8.835" ~--~ 2699' 7" CSG, 26#, L-80 TCII XO TO BTGM ~-~ 3922' Minimum ID = 3.725" @ 8993' 4-1 /2" HES XN NIPPLE 4-1/2" HES X NIP. ID = 3.813" 4712' ~ 7" HES ES CEMENTER, ID = 6.188" $92$' 4-1/2" HES X NIP, ID = 3.813" $949' 1 7" X 4-1/2" BKR S-3 PROD PKR, ID = 3.875" $972' ~-i4-1/2" HES X NIP, ID = 3.813" 8993' ~4-1/2" HES XN NIP, ID = 3.725" TOP OF 4-1l2" LNR 9007' 9007' 7" X 5-1/2" HRD ZXP LTP w / TIEBACK SLV, ID = 4.40" 4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 9015' 9015' ID = 4 ~4-1l2" WLEG 00" . , 9029 7" X 5" BKR FLEX LOCK LNR HGR, ID = 4.400" ESTIMATED TOP OF CEMENT (05/22/07) 9102' 9039' 5" X 4-1/2" XO, ID = 3.958" 7" CSG, 26#, L-80 BTGM, ID = 6.276" 9158' ELMD TT LOGGED (DATE} PERFORATION SUMMARY REF LOG: MWD ON 10/09/09 ANGLE AT TOP PERF: 89° @ 11700' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 9900 - 9910 S 05/22/07 2-1/2" 4 11700 - 11970 O 10/24/06 2-1/2" 4 12050 - 12237 O 10/24/06 PBTD 12243' 4-1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 12330' ~ 10949' --~ 4-1/2" HES ES CEMENTER, ID = 3.980" 11003' PAYZONE EXTERNAL PKR, ID = 3.900" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/26/06 N9ES ORIGINAL COMPLETION 01!04/07 JAF/TLH COMPOSffE BP SET (12/30/06) 05/22/07 AHH/THL ADPERF, CMT SOZ & MILL PLUGS 06/25/07 ?/ PJC DRLG DRAFT CORRECTIONS 09/19/07 DRS/PJC PERFORATION CORRECTIONS PRUDHOE BAY UNff WELL: L-04 PERMIT No: ®2061200 API No: 50-029-23319-00 SEC 34, T12N, R11 E, 2380' FSL & 3714' FEL BP Exploration (Alaska) S NOTES:*"`*WELL ANGLE> 70° @ 9496' L -O /~ ***NOTE: WATCH FOR COMPOSITE PLUG DEBRIS ~1' (4 PLUGS MILLED 05/22/07) 1..rl Preble, Gary B (SAIC) From: Robertson, Daniel B (Alaska) Sent: Wednesday, August 13, 2008 5:39 PM To: Preble, Gary B (SAIC) Subject: FW: L-04i additional perforations Attachments: L-04i Acid wash and add perfs 081308.doc; L-04i add perfs 081308.x1s; L-04_Add_Perfs_ 081308.ppt Can you please generate a sundry for this? Thanks. Am planning to be out the next 4 days, back next Monday. From: Robertson, Daniel B (Alaska) Sent: Wednesday, August 13, 2008 5:29 PM To: Hilton, Glyn G II (ConocoPhillips); 'hank.d.bensmiller@exxonmobil.com' Cc: cameron.k.cheal@exxonmobil.com; Flight, Jennifer N; Vandergon, Mark A; Patil, Santosh; Panda, Manmath N (PRA); Flight, Jennifer N; Schultz, Kirsten Subject: L-04i additional perforations Hank, Glyn, Your concurrence is requested for the attached additional perforations in WAG injection well L-04i. It is a horizontal injection well that supports producers L-01 and V-04. The perforations should improve vertical and lateral conformance along the length of the horizontal injector to the offset producers. Thanks, Dan 1. ~ 1. 1 ~- 04i Acid wash and L-04i add perfs L-04_Add_Perfs_08 add perfs ... 081308.x1s (41... 1308.ppt (146... ~p~, i2~ 10/19/07 Sch[umber~ger NO.4449 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambelt Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Lo Descri lion Date BL Color CD MPL-09 11767141 MEM INJECTION PROFILE T 09/16/07 1 S-400A 40015442 OH MWD/LWD EDIT 09/14/07 1 12-12A 40015307 OH MWD/LWD EDIT 06/18/07 3 1 G-17A 40013619 OH MWD/LWD EDIT - 'R 06/18/07 3 1 S-400A 11855508 CH EDIT PDC GR (USIT) ~ 09/18/07 1 G-266 10942213 MCNL '-_ C ~ 05/23!05 1 1 C-32C 11628756 MCNL ~ 02/18/07 1 1 E-04A 11801079 RST J ~ 06/23/07 1 1 07-076 11216202 MCNL (p - ~ 06/28/06 1 1 L2-11 11209603 MCNL ~ p 04/30/06 1 1 E-32A 11767130 MCNL - ~ 157ep~} ~ 06/19/07 1 1 L-04 11603118 MCNL - 12/30/06 1 1 E-19B 11767134 _ MCNL ~- - ~'~ 'a )57,pV ( 07/21/07 1 1 2-76/M-16 11846803 RST U - L' d~ 08/13/07 1 1 1-39A/N-16 11628769 MCNL ~ ~ 04/15/07 1 1 rLtAJt HI.RNVWLtulat KtIaIY I t5Y 51GNING AND KETURNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - ,' ~" 900 E. Benson Blvd. ~: _ ,, .~, T Anchorage, Alaska 99508 ,- -,- Date Delivered: ` ,I ~ ~~ ~~i ~ r~ Alaska Data & Consulting Services 2525 Gambelt Street, Suite 4 0 Anchorage, AK 99503- 3 ATTN: Beth ~ Received by: 09/24/07 i r ~ L:_J ~~~IUIn~~~~~ NO.4414 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK s9so3-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job;x Loe Descriation Date BL Color CD 09-25 11695072 LDL „~„ ~ _ 08/17/07 1 L-04 11661166 SCMT - 08/25/07 1 15-26B 11661165 MEM PROD PROFILE - / 08123/07 1 02-12B 11628789 MEM PROD PROFILE Q 08/20/07 1 02-11A 11428266 MCNL ~ .. / L 10/03/06 1 1 18-24AL2 11209591 MCNL C ~ s 03/23/06 1 1 14-07 11637334 RST ~ - / L 05108/07 1 1 B-14 11637349 RST "~-- ! ~/ 07/04/07 1 1 Z-08A 11630483 RST ~ 06/21/07 1 1 Z-46 40012671 OH EDIT MWD/LWD - ~ 1 ~ < 12112105 2 1 Z-46A 40012671 OH EDIT MWD/LWD '~ / _ - 01/03/06 2 1 E-37A 10928640 MCNL a p~ -O(~ '! 06/14/05 1 1 B-34 11594510 RST u q- ~ ~ 06114/07 1 1 MPH-17 11813063 CBUUSIT ~PDC) CH EDIT ~p3 -- ! S S~ 07/21/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ _„ - f~ti ;,'; i~ , ; i' ~1; 900 E. Benson Blvd. ~r" ~ I! ~ r Anchorage, Alaska 99508 ~~ ~~ (> Date Delivered: `,.;e{° ~-~' J ~ I__U~J ~ Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth Received by: ',fw.`.,~{.~k~1~ ff :.I_r{.~tl11a4ii?3k~8C16i STATE OF ALASKA ~ ~ ~ 2~~' ~;~~ ALASK~OIL AND GAS CONSERVATION O ~, ,~ ommiss-on REPORT OF SUNDRY WELL O~tAT'I~ISf ~~ ~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q ' Other Q CEMENT SQUEEZE Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 2os-12oo 3. Address: P.O. Box 196612 Stratigraphic Service iv" 6. API Number: Anchorage, AK 99519-6612 50-029-23319-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 76.5 RT -- PBU L-04 8. Property Designation: 10. Field/Pool(s): ADLO-028239 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12330 ~ feet Plugs (measured) None true vertical 8996.18 ~ feet Junk (measured) None Effective Depth measured 12243 ~ feet true vertical 8978 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 91.5# H-40 28' - 108' 28' - 108' 1490 470 Surface 2670' 9-5/8" 40# L-80 29' - 2699' 29' - 2698' 5750 3090 Production 9132' 7" 26# L-80 26' - 9158' 26' - 8660' 7240 5410 Liner 3323' 4-1/2" 12.6 # L-80 9007' - 12330' 8549' - 8995' 8430 7500 ' Y` Perforation depth: Measured dept S z 9900' - 9910' 11700' - 11970' 12050' - 12237 True Vertical depth: Sgz 8940' - 8942' 8947' - 8949' 8949' - 8976' Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9015' Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 8949' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 2720 0 1206 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory (~' Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ WINJ ~ WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-176 307-102 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/6/2007 Form 10-404 Revi>~d 04/2006~~ ~ i ~a° ~ ~ ~ ~7 11~~~ $~~ ~ ~ 2~0 Submit ~ inal~ ly d a,•.~ L-04 • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 130 50/50 meth 50 NH4CL 73 60/40 METH 165 2% KCL 25 12'h% HCL 40 DIESEL 10 15% HCL 493 TOTAL `- ~ • C~ ACTIVITYDATE SUMMARY ~ 4/24/2007: T/I/0= 470NAC/270. Temp= SI. TBG, IA and OA FL's (Pre CT-Cement). No AL line. TBG FL C«3 438' (7 bbls). IA FL near surface (? ). OA FL C 48' (2 bbls). 5/15/2007, CT 9 -Coil Flag/Set CBP - MURI - PDS - GR/CCL for coil flag. Tag plug @ 11603', log GR/CCL from 11603'-8800'. Paint flag #1 @ 10900', flag #2 @ ', ' 9900'. Bleed gas off backside. Fluid pack backside w/ KCL. Perform SRT @ 0.5 bpm/374 WHP, 1 bpm/700 WHP, 1.5 bpm/942 WHP,2 bpm/ 1245 WHP,2.5 ` ', 'bpm/1500 WHP. Continued on 05/16/07 WSR. 5/16/2007: CTU# 9. Set CBP, Continued from 05/15/07 WSR. Get tie-in data. Perform !,weekly BOP test. RIH with 1st 4 1/2 composite bridge plug and set at 10980'. POOH to set 2nd composite bridge plug. MU BHA # 3 with 2nd composite ',Bridge plug, could not get test, determined that CV's not holding. Repait CV's 'and retest. RIH with 2nd composite bridge plug "" Continue on 5/17/07'*" 5/17/2007' CTU # 9, 15540' 1.75 CT, Continued from 5/16/07. RIH with 2nd CBP, set at 10930' CTM. SSRT .5 bpm C~ 620 psi, 1 bpm @ 1414 psi, 1.5 bpm C~ 1780 psi, ', 2 bpm @ 1861 psi, 2.2 @ 1927 psi, POOH. Pick up 2.5"x 10' 2506 PF, HMX, 6 ', spf, 60 deg phasing and RIH to 9900'. Perforate 9900' - 9910'. Start step rate 'test with Static WHP= 179 psi, 0.5 bpm@515 psi, 1 bpmC«3960 psi, 1.5 ', bpm C 1370 psi, 2 bpm @ 1650 psi, 2.7 bpm @ 1750 psi then went back to 1 bpm and stabled at 1400 psi. Discussed rate with APE and decided to proceed with -Acid Job. POOH and pick up 2.5" JSN and RIH for acid job. Begin pumping acid -Job in progress Continue on 5/18/07 _. ~ . _. 5/18/2007 CTU #9 ,continued from 5/17/07, Pumping 25 bbls 12 1/2 % HCL, 25 bbls 9.1 ,Mud acid, over displace with 40 bbls of NH4CL. Saw -- 200 psi decrease when 'acid hit perfs. SRT .5 bpm @ 425 psi, 1 bpm C 703 psi, 1.5 bpm @ 1106 psi, 2 bpm C 1472 psi, 2.5 bpm @ 1579 psi. TOOH, Pickup BHA# 4 with 4 1/2"' CBP and RIH. Sat CBP at 9935'. POOH. and did infectivity test - SRT # 2 after setting the 3rd plug SWHP 66 0.5 bpm @430 psi 1 bpm C«~ 630 psi 1.5 bpm C~ 930 psi 2.0 bpm C«~ 1340 psi 2.5 bpm C~ 1480 psi 3 bpm @ 1590 psi POOH and MU BHA#5 (1.9" OD x 1.5" CRC, 2 x 2" (66" +67") stingers,2" OD x 4" Xover, 2.5" OD x 7 "Drop Ball Cement Nozzle (13/16") Ball size). OAL 12.25', RIH to 9000. wait for Cement test to. Mix a total of 44 bbls of 14 ppg Squeezecrete Cement. Lay in from 9945', PUH and displace cement behind pipe a 0.5 bpm with pressure starting at 450 psi and going to 1960 psi with 33 bbfs behind pipe and dropping to 1796 psi on remaining 9 bbls ,shut down monitor pressure for 24 mins WHP dropped from 1796 psi- 1172 psi, Pumped 1 bbl more pressure increased to 1465 psi with ~ 43 bbls behind pipe. ., -.. "`"'Continue on 5/19/07"**' 5/19/2007'', CTU # 9 15440' 1.75" CT, Continued from 5/18/07, TOOH Filling CT ;displacement, Wait on Cement. Cement reached 500 psi compressive strength 24 hrs.. Continued on 5/20/07 5/20/2007 CTU # 9 15440' 1.75" CT, Continued from 5/19/07, MU BHA #5 with 3.70 5 blade junk mill, Test squeeze to 1033 psi ,lost 73 psi in 5 min. RIH Milling cement from 9409' to 9940'. Pressure test wellbore to 1000 psi, lost 180 psi in first 5 minutes, 120 psi in second 5 minutes, 80 psi in the third 5 minutes, 380 psi in 15 minutes. RIH milled the first plug at 9948'. RBIH to second plug at 10925'. Pressure test wellbore to 1500 psi, Well lost 480 psi first 5 minutes, 260 psi, second 5 minutes, 160 psi in 3rd 5 minutes, 900 psi/15 minutes. Tried to establish injection at minimum rate but pressure built up to 1500 psi and kept building so stopped. Called APE and decided pressure test is good. RBIH mill the 3rd plug and push to bottom at 12238' CTM. Sweep with Biozene. TOOH, Started pulling over about 10700' to 9439', Jarred up and down, was able to move -- 20 ft up hole.Still able to circulate but motor is stalled "Continue on 5/21/07*'` 5/21/2007iCTU # 9, Continued from 5/20/07, CT stuck at - 9409. Freese protect CT and surface lines. Pump 10 bbls acid, 40 diesel. Pumped 50 bbls Flo pro with 3% Lotorc & 2 % 776, Became unstuck after Flo Pro was circulated around the .:BHA. TOOH chasing the Flo Pro to surface. Performed a SRT .5 bpm - 1326 :psi, 1 bpm 2285 psi ,Pressure would not level out Freeze well to 2500 ft. '****Job continued on 5/22/07"*** 5/22/2007'CTU# 9, Continued from 5/21/07, TOOH, Freeze protect well to 2500', Left well 'shut in. Notify Pad operator of well status. '`**Job Complete."*~ Road unit to ',shop for planned maintenance and swap to 1.5" coil. Page 1 of 1 Saltmarsh, Arthur C (DOA). From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, September 05, 2007 3:01 PM To: Saltmarsh, Arthur C (DOA) Cc: Preble, Gary B (SAIC) Subject: PBU L-04 / PTD # 206-120 H i Art, Please reference the following well: Well Name: PBU L-04 Permit #: 206-120 API #: 50-029-23319-00-00 Top Perf MD: 9102' Bottom Perf MD: 12237' This well began Injection on August 26, 2007 Method of Operations is: Water Injection There is no test data fior injectors. Note: Some perfs were added in May 2007. Gary Preble will be submitting a 10-404 shortly. Thanks, Terrie 9/7/2007 MEMORANDUM TO: Jim Regg ~ l(~d 7 P.I. Supervisor ~Q( FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, September O5, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-04 PRUDHOE BAY UN PBU L-04 Src: Inspector NON-CONFIDENTIAL Reviewed B~• P.I. SuprvJ Comm Well Name• PRUDHOE BAY UN PBU L-04 Insp Num: mitJJ070904202607 Rel Insp Num: API Well Number 50-029-23319-00-00 Permit Number: 206-120-0 Inspector Name• Jeff Jones Inspection Date: 9/3/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-oa Type Inj. W TVD 8507 ~ 10 2360 2310 2310 P.T. zo6lzoo TypeTest sPT Test psi 21z6.7s pA aoo soo ago ago Interval ~T~- p/F P / Tubing 13so 1380 laoo laoo NOtes• 1 well house inspected; no exceptions noted. Wednesday, September O5, 2007 Page 1 of I r, ~; F~~I t~-. ~- r Schlumberger `^~ ~~°, ~~ ~. ~~~~~ ~ k Iw~~~~3~6~~tl Schlumberger-DCS _ ,~u ~- .,- S' ~~?.~ 2525 Gambell St, Suite 400 ±~r ~~ Anchorage, AK 99503-2838 ~. ''~~~~ ATTN: Beth Well Job # Log Description NO. 4292 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Orion Borealis Date BL Color CD V-218 11661147 MEMORY TEMP SURVEY 05/19107 1 Z-102 11637125 CEMENT IMAGE/BOND LOG 05116/07 1 V-04 V-214 L-250 40014377 40014208 40012593 OH EDIT MWD/LWD OH EDIT MWD/LWD OH EDIT MWDILWD 11128/06 10/30/06 11/09105 2 2 2 1 1 1 V-122 40014531 OH EDIT MWD/LWD 12/30/06 2 1 V-122P81 40014531 OH EDI7 MWDILWD 72/16106 2 1 V-122PB2 40014531 OH EDI7 MWDILWD 12/28107 1 1 L-250L7 40012593 OH EDIT MWDILWD 11/15105 1 1 L-250PB1 L-04 OWDW-NW 40012593 40014142 11477941 OH EDIT MWDILWD OH EDIT MWD/LWD RST 10/26105 10/09/06 11/14106 2 2 1 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99500-4254 Dato Delivered: (~(~ ' [ate ~ 1 Sam Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Received by: oslono~ s ~:~ ,~ -~?~~RECEIVED ~ ~ l s~ STATE OF AL~ ~~31~A, ~ S -~ ~I~oio~ ~p ALA A OIL AND GAS CONSERVATION COMM1~10N Jgf~' MAY 2 g 2007 APPLICATION FOR SUNDRY APPROVALp~aska qil & Gas Cons. Commission 20 AAC 25.280 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver c orage Other Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate Q Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 206-1200 - 3. Address: P.O. Box 196612 6 Stratigraphic ^ Service ~ . API Number: Anchorage, AK 99519-6612 50-029-23319-00-00 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: PBU L-04 Spacing Exception Required? Yes ^ No ^ ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028239 ~ 76.5 RT ~ Prudhoe Field / Prudhoe Bay 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): 12330 ~ 8996 - 12243 - 8978 11600 None Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 91.5# H-40 28' 108' 28' 108' 1490 470 Surface 2670' 9-5/8" 40# L-80 29' 2699' 29' 2698' 5750 3090 Production 9132' 7" 26# L-80 26' 9158' 26' 8660' 7240 5410 Liner 3323' 4-1/2" 12.6# L-80 9007' 12330' 8549' 8996' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9102' - 12237' 8619' - 8976' 4-1/2" 12.6# I-80 8884' - 8973' Packers and SSSV Type: Bakert S-3 7"X4.5" Packers and SSSV MD (ft): 8948' 0 0 0 0 0 0 12. Attachments: Descriptive Sum mary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/7/2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ is. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: Prepared by nary rreule 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel Robertson Printed Name Daniel Robertson Title Petroleum Engineer Signature Phone 564-5546 Date 5/24/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~ r Plug Integrity ^ BOP Test ~ Mechanical Integrity Test [~ Location Clearance ^ ~ ttG~%c+mce ~ `~0}~~ ~~C"C .~n C~c^ Gib- ~Fe~~ Ztt ~~srz-v- Other: C~~~DOf ~'la,nt,~ -G-~ w w~v~PS s Subsequent Form Required: ~~^40 APPROVED BY A roved b : MMISSIONER THE COMMISSION Date: ~ ~/Q~ pp y Form 10-403 Revised 06/2006 (/ Submi in Duplicate ~R1G~ AL . .. by • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (9071 561-5111 DESCRIPTIVE SUMMARY OF PROPOSAL L-04 5-24-07 1. RU CTU. Test BOPs. RIH and nitrogen lift to clean up well prior to injection. Route returns through portable separator and into adjacent producer flowline. 2. After flowback is complete, RIH with ct and perform cleanout to ensure wellbore is clean prior to injection. 3. Pump 100 bbls mud acid while reciprocating across perforations. Overflush. 4. Run coiled tubing conveyed memory cement bond log. 5. Place well on water injection 6. AOGCC witnessed MITIA after stabilized injection. TREE = A-fl16" 5K CIW 1AFELL•'~AtS = FMc ACTIiATQR = ~ e..LEO KB. E;LEV - 28.5 BF. ELEV = 73.5 KOP _ _.3903 Max A Ie - 99° ~ 10,741' Datum MD = 12330'' Datum. TVA = 8919.68''.. ~ 9-51'8" CSC. 40#, L-B0..U758 bnf. {D= 8.835" I Minimum ID = 3.725" @ 8992' JEWELRY TYPE 4.5' "XN" Nipple I 7" ES Cementer, 1D= fi.276' ~ 4-112" L-80,12.& Ibtft,TC-11,.0152 bpf ID= 3.558" i 9015' 4-1 t2" t1t~EG, ID = 3.9'58" - 7" CSCa, 2fi#, L-80, .£1383 bpf., ID=fi.27fi' -~ ~ ~ 1 PERFORATION SUMMARY REF LOG: ????? ANGLE AT TOP PERF: 89° ~o., 11700' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sq2 DATE 2-112" 4 9102 - 9107 S 05!22;07 2-112'° 6 9900 - 9910 S 05/22!07 2~~ 112'° 4 11700 •• 11970 O 10124106 2-112" 4 12050 - 12237 O 10124/06 Pem ~-I' 9~24~" L -O ~ s~Y NOTES: "'TWC installed on 10t26t20f16"` WATGM FOR C4lM'Rf}StTE PLLIGF RHVI HANTS (4 RLUGS F MiLLf335t22tQ7) ' E5 Cementer, ID = 3.958" T scl'Q ustzzta7 .Baker Pazorle external Packer, I[l= 3:9130" ~ 4-112", L-~, 12.b~, IBT-M1CfD .[115 bpf ~ DATE REV BY COMMENTS [7ATE REV BY COMMEVTS ~7t11tQ6 BJP Proposed Com pletlan Ftev,1 1At25/p& B.IIJB RresentGamp~eta» tOf26;06 /PAC CORRECTIf}NS _Q1t04/07 JAF/TLFI COMPOSiTEBP SET (12!30!06 QS122107 AF~-UTLFI AflPERF, GAtfl' SQZ & MILL PLUGS PRUD#t3E BAY UtJIT WELL: L-04f PERNUf Na: 206-120 API t'Ja: 54-Q2J-23315-Otl Sec Tw p Rge BP Expto€afioti (Ataskaj 2009' F-"l4-t2" HES x Nippple , ID= 3.s13" 8927' 14112" XNipfde {3.81"' ID) $ ~-- {Baker S-3 Packer, 7" x 4,5" $972' 4-1t2" X Nile (3.813" ID) wt RHC-M Plug F3992' 4-ill" XN Nipple {3.725.., 1b) 900T 5"x7" Liner top Packer w t xx' T~back Sleeve 9102' EST~+W TED TC?P OF C8IAENT {05!22/47) LI SARAH PAL-N, GOVERNOR oilDi7~~ Ou/ ~l`~ ~ 333 W. 7th AVENUE, SUITE 100 C011T5ERQA-7'I011T COMI~IISSI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Daniel Robertson Petroleum Engineer BP Exploration Alaska PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU L-04 Sundry Number: 307-176 Dear Mr. Robertson: 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. DATED thi~~ day of May, 2007 Encl. Sincerely, -. __ . ;_ ProActive Diagnostic Se~ices, Inc. To: QOGCC Christine Mahnken 333 W. 7th qVe Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole ~~pen Hole/IVlechanical IAgs and/or Tubing lnspection(CaG er p ~~ The technical data listed below is being submitted here -'eturning a signed copy of this t+'ansmittal letter to ~• Please acknowledge receipt by ~ attention of : ProActive Diagnostic Services, Inc. Awn: Robert A, Richey 130 Wei international Airport Road Suite C Anchorage, qK 99518 Fay (907) 2g5.g952 1 J EDE Disk L - 04 Coil Flag 15-May{~7 2) 3) 4) 5) s) ~~Cab~-i~o ~ 15th , .,~ ~ ~, . Signed : ~`'a;~~' ~ ~~ir i~ Print Name: '~`~ ~~ ~~ ~~ ~~s~~a~~ ~~ ~.~ ~:e PROACTNE DWGNO$TIC SERViCES~ prC ~ 130 W ~~ ERNa17ONgL,,q~RppRT RD SUITE C, ANCHORAGE, AK 99518 E-NA1l: ~~ ~ PHONE: (907)245-8951 FAX; (907)245-8952 St1iJC~l~(~,~,~ adtEYt0 ~a ~ R: rvG.a~s'3~19 WEBSRE : '~J!J~J?iaJ.;'tESy7~~~ ° ~ ~ 4-~„f • ~Y~`~ ~~~ ~~~4/~~/i/I®1~7e4L D:1l~fay~q C°PY 4o PbSANC-2~~-w~~~.shibutionlT ya i iansmittat Sheetsl'Ikanymit OnBmsl.doc Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR ~ ~ 2007 `~`~°~ iii ~ fps 14~,n5. ~;~triiirt ` , S a .--• ~ wan ~..ti ~ ~ ,....,____:_.:-- NO 4214 Company: State of Alaska Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 04/16/07 02-15 11661130 MEM PROD PROFILE 02125/07 U-06B 11469946 MEM PROD PROFILE 02/24/07 1 P-09L1 11676933 LEAK DETECTION LOG 03118/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-326L1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL1 11660526 MEM PROD PROFILE 02/08/07 1 03-336 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-116 11649954 MEM PROD PROFILE 03/22/07 1 P2-37A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y-06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-206 11649952 MEM DEPTH DETERMINATION 03/20/07 1 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: .. ....v ,mac, v~~nn~aa vnc vvr ~ ce~a.n iv. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: SARAFf PALInI, GOVERiVOR Jim Ambrose Reservoir Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU L-04 Sundry Number: 307-102 Dear Mr. Ambrose: 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 goon 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. DATED this ~ay of March, 2007 Encl. Sincerely, STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMISSI N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~~~f Y G~ MAR 2 0 2007 iS14Ci 1. Type of Request: Abandon Suspend Operational shutdown Perforate A~a~~q Gas Cons. Alter casing ^ Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ A~z ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ v 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 206-1200 3. Address: P.O. Box 196612 6. API Number: Stratigraphic ^ Service ~ Anchorage, AK 99519-6612 50-029-23319-00-00 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: PBU L-04 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028239 76.5 RT Prudhoe Bay Field / Prudhoe Bay 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): 12330 8996.18 12243 8978 11600' None Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 91.5# H-40 28' 108' 28' 108' 1490 470 Surface 2670' 9-5/8" 40# L-80 29' 2699' 29' 2698' 5750 3090 Production 9132' 7" 26# L-80 26' 9158' 26' 8660' 7240 5410 Liner 3323' 4-1/2" 12.6# L-80 9007' 12330' 8549' 8996' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9102' - 12237' 8619' - 8976' 4-1/2" 12.6# L-80 8884'-8973' Packers and SSSV Type: Baker S-3 7"x4.5" Packers and SSSV MD (ft): 8948' 0 0 0 0 0 0 12. Attachments: Descriptive Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/29/2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG 0 GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by nary rreule 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Ambrose Printed Name 'm A brose Title Reservoir Engineer Signature Phone 564-4375 Date 3/15/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~~ /Da, Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: `~ S~C'~ pS ~ '~~ v~r ~Vv` ~~'~S`~ ~!"~- ~~~ ~ ~ ~~Q/ Subsequent Form Required: `\~t-~ APPROVED BY : COMMISSIONER THE COMMISSION Date: ~ ~~~" roved b A pp y Form 10-403 Revised 06/2006 o R ~ ~~! Submit in Duplicate b i • p BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (9071561-5111 Descriptive Summary of Proposal L-04 3/15/07 Objective of the coiled tubing cement squeeze is to remediate a poor primary cement job. Diagnostic logging has indicated there is flow behind pipe from 9105 MD to 11,200 MD. Scope of work: 1. RU CT. 2. Run memory gr/ccl for depth control, flag ct. 3. Install 4.5" composite bridge plugs 15' above and below ES cementer at 10,949 MD. 4. Install 4.5" composite bridge plug at 9120 MD, just below squeeze perfs at 9102-9107 MD. 5. Perform CT cement squeeze by downsqueezing squeezecrete cement into existing perfs near liner lap. Cleanout excess cement 6. Pressure test wellbore at 2500 psi. 7. Mill out top to composite bridge plugs, exposing ES cementer. 8. Pressure test wellbore at 2500 psi. 9. If pressure test successful, mill out remaining composite plugs, rig down ct, and place well in WAG injection service. 10. If pressure test unsuccessful, perform cement squeeze via ES cementer. 11. After successful pressure test obtained, mill out composite plugs, rig down ct, and place well in WAG injection service. TREE = 41 d16" 5K ClVii WEIE_Hf=At?= F(v1C] Ai; I'oSAT~)3i - _~ . -_- .LEO I{8. ELEV = ~~ ~8 5I SE, ELEV = ~ 7:~ S~ _ tC4P = __ _. 3:X10) fL1ax Angle _ 99° ~ 1{i r~,t' Dates MD- O ~ 32330'1 ~ atim TVD = 8919_~'j - 3-si~" cs~. aott, L-s0, .0758 bpt, tD= s.e35" !-1 ao~y 1 Minimum ID = 3.725" @ 8992' JEWELRY TYPE 4.5' "XN" Nipple ~pp® ~. ~ sal~rir r~~res: '~~°rwt: ins~all~d tsn 1dr~~rzoos... F(i~~ ~I~L~ DR~~T 2049' ~4-112" HES X Nippple , ID= 3.813" _._____-_-.__- r._- - _.-_ __ ._ _.----__._ _ _ _ ______-~ _ _-- 7° ES Cementer, !D= 6.276" ~ 4711' $ J27~)--4112" X Nipple (3.813" ID) $Qd$' Baker S-3 Packer, 7" x 4.5" $g72' 4'1/2" X Nipple {3.Si3" ID) w/ RHC-M Pkrg ---e_____- __, - ___ J-...--.-------- _ 4112" L-80,12 6 Ibdit,3C II .0152 bpt IQ= 3.358"1 901 S' $9$2' A-112" XN Nipple (3.725' ID) 4 41/2" V1h.EG, D =3.958" 90'!5' _ ~7. 5'. x T' Liner tap Packer w/ xx' Tieback Sleeve 7" CSC, 26#. L-80, .0383 bpf, ID=6.276" 9151' PERFORATION SUMMARY REF LOG: ????? ANGLE AT TOP PERF: 42° @ 9102 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 9102 - 9107 O 10/18/06 2-112" 4 11700 - 11970 C 10124106 2-1(2" 4 12050 - 12237 C 10(24(06 14,949' 4.5` ES Cementer 3,358' 10 ~ 1442' Baker Pazone external Packer, ED= 3.900" 91644' CTM 4 t t2" wFD coMPOSrrE PLUG { t 2t3tU FBTD ~ 41/2", L-80, 12.6'#, IBT-MOD .0152 bpf I DATE REV BY CtAENfS DATE 471'11ffl8 BJP Proposed Completion 1i+eer_1 10t25tfl6 BJBtl2JB Present Completion 10/26J06 tPAG CORRECTIONS 01 /04f07 ,!A FlTLH GOAttPOSfTE BP SET (12d30i06 I 12334' ! PRUDHOE BAY UNrf WELL: L-04i PERMfr No: 206-120 A f'I No: 50-02%3-23819-00 Sec Tw p Rge t3P Exploration {Alaska} 02/12/2007 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 4131 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 wau i..ti ~ Field: Prudhoe Bay LS-25 11538589 -- --~- - LDL 12/28/06 vVIVI liY Y-16 11626467 LDL 01/19/07 1 L-04 11603118 MEM LDL 12/30/06 1 11-24A 11638611 USIT 01/24/07 1 1-33 11631645 USIT 01/09107 1 A-05A 11533393 USIT 01/04/07 1 DS 05-108 11626469 SCMT 01/22/07 1 W-29 11536193 USIT 01/05/07 1 R-15A 11626266 USIT (CEMENT EVALUATION) 01/11/07 1 R-15A 11626266 USIT (CORROSION) 01/11/07 1 MPF-99 11637306 CEMENT EVALUATION/CBL 01/14!07 1 R-12 11414757 RST 09/01/06 1 1 NK-38A 40011271 OH EDIT MWDILWD 03/11/05 3 1 NK-38A PB1 40011271 OH EDIT MWD/LWD 02/26/05 2 1 MPC-28A 11649937 MEM INJECTION PROFILE 01/05/07 1 DS 07-04A 11533394 LDL 01/05/07 1 F-23A 11626066 LDL 01!08/07 1 P2-19 11630449 LDL 01/14/07 1 Y-09A 11630450 LDL 01/16/07 1 DI CACC Af ~1J 11\AII CII/~C OG /+GI[]T e . __...,_ .~.......... ~....,.,,~ ..~,,.-„- 1 .,, 1 „Lal. n.~a r\Iw Icc 1 NR1711Yb vrvc I.VYT tHl.rl ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 CSate Delivered: Alaska Data & Cons I 2525 Gambell Street, i Anchorage, AK 99503-2838 ATTN: Beth ~ o ~aa7 Received by: ~A~~ ~A~ , ~~,G (~tIS. i~t~ai~~~t~l~ ~~~; ~ . ~~ 11 /21 /06 Sc~~un~erger NO.4047 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ~ j j~ i ',~ ` ~ " Anchorage, AK 99503-2838 ~/ -+-~ ~.. / t-1 r ' ~ l ~~ ~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Lo Descri tion Date BL Color CD E-17A 11285948 MEM PROD PROFILE 10/21/06 E-17A 11285948 SCMT 10/21/06 1 L-04 N/A SCMT (REDO) 10/21/08 1 PLEASE ACKNOWLEDGE RE CEIPT BY SIGN ING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: to ° ~'~ gp Y Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 38 '~ ATTN: Beth ~ Received by: • STATE OF ALASKA ~ ~.E~~~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 2 4 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Cotrlrnissiolt 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 1 b. Well Class: nC OCagi? 20AAC 25.105 20AAC 25.110 ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ^ Stratigraphic ®Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1 /~68 a z. ' p 206-120 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/23/2006 50-029-23319-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 10/9/2006 PBU L-04i 2380 FSL, 3714 FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 8. KB Elevation (tt): 15. Field /Pool(s): 2617' FSL, 978' FEL, SEC. 34, T12N, R11 E, UM 76.5' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 2243' FSL, 305' FEL, SEC. 34, T12N, R11E, UM 12243 + 8978 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 583203 y- 5978102 Zone- ASP4 12330 + 8996 Ft ADL 028239 TPI: x- 585935 y- 5978369 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 586613 y- 5978003 Zone- ASP4 None MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ®Yes ^ No N/A MSL 1900' (Approx.) 21. Logs Run: DIR / GR, GR /RES / PWD, USIT, GR /RES /DEN / NE U, SCMT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM. SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surfa 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 2699' 29' 2698' 12-1/4" 436 sx ASLite sx Class 'G' "~ 7" 26# L-80 2 ' 9158' 26' 8-3/4" 51 x LiteCrete 2 x Cla ~~ 4-1/2" 12.6# L-80 9007 12330' 8549' 8996' 6-1/8" 117 sx Class 'G' 4 cc c~ >, l 23. Perforations open to Production (MD + TVD of Top and 24` TUBING RECORD ~- Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9015' 8949' MD TVD MD TVD 11700' - 11907 8947 - 8948' ETC. ACID FRACTURE CEMENT SQUEEZE 25 12050' - 12237' 8949' - 8976' , , . , DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 9102' - 9107' Perf for Remedial Cement Job of 4-1/2" Liner; Pumped 53.7 Bbls Class'G' Freeze Protect w/ 30 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE .SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORK) Press. 24-HOUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none"' !~ ~.. ter j £I Z~Q~ None 6' Form 1 ~~,,,Y 12/2~vy ~ ~~ ~ ~"~ ~„,„ CONTINUED ON REVERSE SIDE ~~ 3`Z ~~ ~~ 28. GEOLOGIC MARKERS 29. TION TESTS Include and briefly summarize test results. List intervals tested, Nave MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 2798' 2797 None Ugnu M 3944' 3943' Schrader Bluff N 4186' 4184' Schrader Bluff O 4340' 4335' Base Schrader Bluff /Top Colville 4717' 4698' HRZ 6316' 6238' Kalubik 6547' 6461' Kuparuk D 6682' 6594' Kuparuk C 6705' 6616' Kuparuk B 6870' 6780' Kuparuk A 6965' 6874' Miluveach 7005' 6913' Sag River 9159' 8661' Shublik 9219' 8705' Sadlerochit 9674' 8893' Sadlerochit 11402' 8940' Sadlerochit 11554' 8937' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. I (/ 2`7~ Signed Terrie Hubble Title Technical Assistant Date PBU L-04i Z06-120 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Brandon Peltier, 564-5912 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only a i T p n a a a ~ a n ~ ~ ~ ~n o 0 c[S i W '~ r ~ I~ r , a x m ~ o ¢ o ; a . 3; N N ~ O ~ ~ N d N a ~' ~ Y R d' J d y N N d N d y d v a . ° o0 ~j ~ rn U tC 3 ~ N r- L ~ ~ Z ; 3 Q g n ~ ~ a ao of a cn O N ~ ~ ~ F- I O ~ ~ o o ~ m Y t' ~ ~~ ~ N 00 J ~, o: i ~ ~ ., L o 0 ~ Q ', ~ ~ ~ [) 4 CV of w F- I y~ ~ ~ ~ i O O H ~ H O H O ~ ~ ~ ~ ~ Z - c~ c Z ~ . E. a> ~ co co co ~ O N N N y ~ r N ~ J U H rn i rn ° BP EXPLORATION Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date ~ From - To Hours ~ Task ~ Code NPT 9/17/2006 ~ 05:00 - 18:00 13.00 ~ RIGU ~ P 18:00 - 21:00 I 3.001 RIGU I P 21:00 - 23:30 I 2.50) RIGU I P 23:30 - 00:00 I 0.501 RIGU I P 9/18/2006 00:00 - 01:00 1.00 ~ RIGU P 01:00 - 03:00 2.00 RIGU P 03:00 - 04:00 1.00 RIGU P 04:00 - 05:30 1.50 RIGU P 05:30 - 08:00 I 2.501 RIGU I P Start: 9/17/2006 Rig Release: 10/26/2006 Rig Number: Page 1 of 24 Spud Date: 9/20/2006 End: Phase i Description of Operations PRE PRE PRE PRE PRE PRE PRE PRE PRE 08:00 - 17:00 I 9.001 RIGU I P I I PRE 17:00 - 21:00 4.00 RIGU N WAIT PRE 21:00 - 21:30 0.50 RIGU P PRE 21:30 - 00:00 2.50 RIGU N WAIT PRE 9/19/2006 00:00 - 01:00 1.00 RIGU N WAIT PRE 01:00 - 03:00 2.00 RIGU P PRE 03:00 - 12:00 9.00 RIGU N WAIT PRE 12:00 - 16:00 I 4.001 RIGU I P I I PRE 16:00 - 00:00 I 8.001 RIGU I N I WAIT I PRE 9/20/2006 100:00 - 00:00 I 24.001 RIGU I N I WAIT I PRE MU interconnect and prep DP to PU and stand back in the derrick. RU the rig up the rig floor and install variable speed control for the drag chain. Install top drive wash pipe and clean the floor. Change out the driller's side tugger line. PU mule shoe on 4" DP and RIH to stand back. Tagged up on ice plug at 39'. LD DP. RU to pick up dumb iron and used 12-1/4" bit to clean out the ice plug. PU 12-1/4" bit on 5" HWDP. Drill ice plug from 39' to 60'. Saw fresh water was coming out the INSIDE of the conductor between L-116 and L-110 (called L-SI - 45' away to the west) -out the holes cut to handle the conductor. Stopped drilling ice plug and notified the pad operator. Once the pumps were shut down, we observed the fluid level in the stack was about the same height as the fluid level in the L-SI conductor -about 2' below the 4" conductor handling holes. All the fluid that went into the cellar area of L-SI was sucked up and placed in the rig pit system. Lost - 5 bbls of fresh water. LD 5" HWDP and 12-1/4" bit. PU and stand back 4" DP. PU 2 joints of DP and screw in with the top drive. Circulate to see if fluid was also coming out the outside of the L-SI conductor -fluid only coming out the inside. Continue to PU 4" DP. Attempt to find cause of fluid coming out of the L-SI conductor. Suck out 33 bbls of fresh water from the diverter stack - observed the fluid level dropping in both of the conductors. Drop a plumb bob down the L-SI conductor to 108' MD rkb - clear. Review findings and develop plan forward with town personnel. Continue to PU 4" DP and stand back in the derrick -total of 97 stands. Clean the BOP stack while waiting on truck availability. Function test the diverter -good. Witness of the test was waived by Chuck Shieve of the AOGCC. Clean and paint the rig while waiting on truck availability. Clean and paint the rig while waiting on truck availability. PU and stand back the HWDP and jar stand. Clean and paint the rig while waiting on truck availability. Drift and strap the 9-5/8" 40# casing Build 138 bbls of 8.6 ppg spud mud with a 225 FV with Mix II at 10 ppb. PU and RIH with used 12-1/4" bit, near bit stab and jar stand. Stage up to 14 bpm, 455 psi and clean ice out of the conductor to 90' MDrkb -lost 30 bbls to the well without seeing any fluid rise in the L-SI conductor. Shut down the pumps - fluid level static. Stand back the jar stand and LD the near bit stab and the bit. Clean and paint the rig while waiting on truck availability. Drift and strap the 9-5/8" 40# casing Clean and paint the rig while waiting on truck availability. Service the gen-set air filters, weld hole in drip pan, changeout the hydraulic filter on the iron roughneck. Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 2 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALAS KA DRI LLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: ~ Date ~ i From - To Hours ' Task ; Code i NPT Phase Description of Operations 9/21/2006 00:00 - 00:00 24.00 RIGU N WAIT PRE Clean and paint the rig while waiting on truck availability. Calibrate the weight indicator, console and choke manifold gauges. 9/22/2006 00:00 - 23:00 23.00 RIGU N WAIT PRE Clean and paint the rig while waiting on truck availability. 23:00 - 00:00 1.00 RIGU P PRE PU and stand back 1 stand of drill collars. 9/23/2006 00:00 - 10:30 10.50 RIGU N WAIT PRE Clean and paint the rig while waiting on truck availability. 10:30 - 20:00 9.50 RIGU P PRE Bring fresh water into the pits and mix spud mud. Simops: 12:00 - 12:30: Service the rig and the top drive. 12:30 - 13:00: Hold pre-spud meeting 13:00 - 14:00: RU Gyrodata and Halliburton E-line. 19:00 - 20:00: Hold PJSM. MU BHA#1 components which were not able to be stood back in the derrick in advance. 20:00 - 23:00 3.00 DRILL P SURF Spud L-04i and drill from 108' to 360' taking gyro surreys, PU - 60k, SO - 58k, ROT - 58k, 610 gpm, 925 psi, 80 rpm, 1,100 ftlbs TO on, 675 ftlbs TO off, ART - 0.93. Lost -90 bbls of spud mud to the formation. Had some fresh water return to the L-SI conductor. Removed - 60 bbls of fresh water from the inside of the L-SI conductor. Fluid slowed and then stopped at 300' MD while we were drilling ahead -trickling in Mix II LCM. Saw a considerable amount of larger gravel in the returns. 23:00 - 00:00 1.00 DRILL P SURF POH to pick up the jar stand -pulled tight at 340'. Pump out from 340' to 170'. PU jar stand and run back to bottom. 9/24/2006 00:00 - 07:00 7.00 DRILL P SURF Drill from 360' to 1,285', PU - 80k, SO - 72k, ROT - 75k, 700 gpm, 2,455 psi on, 2,270 psi off, 3.4k TO on, 1.3k TO off. 07:00 - 08:30 1.50 DRILL P SURF Gyro from 1,200' to surface. RD Gyrodata and Halliburton E-line. 08:30 - 10:30 2.00 DRILL P SURF Drill from 1,285' to 1,580', PU - 80k, SO - 72k, ROT - 75k, 700 gpm, 2,455 psi on, 2,270 psi off, 3.4k TO on, 1.3k TO off. AST - 0.54, ART - 6.53 from 0000 to 1030. 10:30 - 11:30 1.00 DRILL P SURF Circulate 3 bottoms up at 700 gpm, 80 rpm, 1.3 k TO, 2,270 psi. 11:30 - 13:00 1.50 DRILL P SURF POH from 1,580' to surface to look at the bit. LD the UBHO sub. Hole in good shape. 13:00 - 13:30 0.50 DRILL P SURF Inspect the bit. Clear and clean the floor. Reed 12-1/4" M4252C graded: 1-1-WT-A-E-I-NO-BHA. 13:30 - 15:00 1.50 DRILL P SURF RIH with BHA#2 on 4" DP from the derrick. Precautionary wash last stand down to 1,580' - no fill seen. BHA#2: 12-1/4" M4252C RR, motor, nm lead collar, nm stab, MWD, nm stab, nm xo, nm dc, nm stab, 2 x nm dc's, saver sub, 1 x 5" HWDP, jar, 1 x 5" HWDP, xo, 24 x 4" HWDP. 15:00 - 20:00 5.00 DRILL P SURF Drill from 1,580' to 2,712' (TD), PU - 100k, SO - 80k, ROT - 92k, 710 gpm, 3,300 psi on, 3,120 psi off, 3.3k TO on, 1.Ok TO off. AST - 0.63, ART - 2.86. Started to see hydrates at -1,800'. Continued to have hydrates breaking out at the surface from 1,800' to TD. 20:00 - 21:30 1.50 DRILL P SURF Circulate 3 bottoms up at 710 gpm, 100rpm, 0.8k TO, 3,040 psi - shakers look clean. 21:30 - 22:30 1.00 DRILL P SURF Monitor the well -hydrates breaking out at the surface. Short trip the hole from 2,712' to 1,381' without problems. 22:30 - 23:00 0.50 DRILL P SURF RIH from 1,381' to 2,712'. Precautionary wash last stand down to 2,712' - no fill seen. Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Operations Summary Report Pale 3 of 24 Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To 'Hours Task Code NPT Phase ; Description of Operations 9/24/2006 23:00 - 00:00 1.00 DRILL P SURF Circulate and conditiorrthe mud for the trip out of the hole and to run 9-5/8" casing - 100 rpm, 710 gpm, 2,960 psi. 9/25/2006 00:00 - 00:30 0.50 DRILL P SURF Continue to circulate and condition the mud for the trip out of the hole and to run 9-5/8" casing - 100 rpm, 710 gpm, 2,960 psi. ~, 00:30 - 02:30 2.00 DRILL P SURF Monitor the well -hydrates breaking out at the surface. POH standing back the 4" DP and the 4" HWDP from 2,712' to the top of the jar stand at 268'. 02:30 - 03:30 1.00 DRILL P SURF Stand back the jar stand and the drill collar stand. 03:30 - 05:30 2.00 DRILL N RREP SURF While resetting the Crown-o-matic, the parking brake locked up and would not allow movement of the blocks. Troubleshoot and repair. 05:30 - 07:30 2.00 DRILL P SURF LD the remainder of BHA#2. 07:30 - 08:00 0.50 DRILL P SURF Clear and clean the floor. 08:00 - 10:00 2.00 CASE P SURF RU casing handling tools to run 9-5/8" 40# L-80 BTC surface casing. Changeout the bales and make a dummy run with the hanger and landing joint. 10:00 - 13:00 3.00 CASE P SURF PJSM. Changeout the elevators. PU and RIH with the 9-5/8" 40# L-80 BTC shoe tract - bakerloc'd all connections below the float collar and torqued to the mark with 9,400 ftlbs. PU and RIH with 9-5/8" 40# L-80 BTC casing to 697' using BOL2000NM thread lubricant and torquing to mark with 9,400 ftlbs. 13:00 - 15:00 2.00 CASE N HMAN SURF Wedged an elevator die in the box of joint #18 -damaging the box. LD Joint #18 and PU spare. Changeout the elevators. 15:00 - 18:30 3.50 CASE P SURF Resume PU and RIH with 9-5/8" 40# L-80 BTC casing from 697' to 2,699' using BOL2000NM thread lubricant and torquing to mark with 9,400 ftlbs. Washed the last 2 joints to bottom as a precaution prior to making up the cement head. 18:30 - 19:00 0.50 CASE P SURF RD the casing equipment and MU the cement head. 19:00 - 22:00 3.00 CEMT P SURF Break circulation and stage the pumps up to 8 bpm, 430 psi. Circulate and condition the mud prior to pumping cement - reciprocating with a 15' stroke. Hold PJSM for the cement job while circulating. 22:00 - 00:00 2.00 CEMT P SURF Switch over to Dowell. Pump 5 bbls of water. Pressure test lines to 3,500 psi - OK. Pump 80 bbls of 10.2 ppg MudPush II spacer ~ 6 bpm, 150 psi ICP, 125 psi FCP. Shut down and drop bottom plug. Mix and pump 350 bbls of 10.7 ppg of Arctic Set Lite lead cement slurry ~ 7.7 bpm, 200 psi ICP, 360 psi FCP. Mix and pump 85 bbls (the last 15 bbls with DuraSTONE metal fibers) of 15.8 ppg Class "G" tail cement slurry ~ 4 bpm, 250 psi ICP, 150 psi FCP. 9/26/2006 00:00 - 01:00 1.00 CEMT P SURF Shut down and drop top plug. Kick out plug with 10 bbls of water. Switch over to rig. Displace cement with 190 bbls of 9.5 ppg mud pumped at 6 bpm average, 300 psi tCP, 750 psi FCP. Bumped plug with 1400 psi @ 96% pump efficiency. CIP ~ 00:30 hr. Bleed off pressure and check floats - OK. Stopped reciprocating and set casing on landing ring with 162 bbls of displacement away. Saw -102 bbls of cement back to surface. Had full returns throughout cementing and displacement. 01:00 - 02:00 1.00 CEMT P SURF Flush the diverter lines. Break out and LD the cement head and landing joint. 02:00 - 03:00 1.00 CEMT P SURF RD the casing handling tools, clear and clean the floor. Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Operations Summary Report Page 4 of 24 Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 9/26/2006 03:00 - 05:00 2.00 DIVRTR P SURF ND the diverter. 05:00 - 05:30 0.50 WHSUR P SURF Bring casing head and tubing spool into cellar. 05:30 - 06:30 1.00 WHSUR P SURF Nipple up casing head and tubing spool. Test to 1,000 psi for 10 minutes - OK. 06:30 - 10:30 4.00 BOPSU P SURF Nipple up BOPE. 10:30 - 11:30 1.00 BOPSU P SURF Install test plug. Rig up to test BOPE. 11:30 - 13:00 1.50 BOPSU N SFAL SURF Attempt 1st test. Trouble shoot leak. Change out valve #16 on choke manifold. 13:00 - 16:30 3.50 BOPSU P SURF Test BOPE to 250 low pressure and 4,000 high pressure for 5 minutes each. Test annular preventer to 250 low pressure and 3,500 high pressure for 5 minutes each. Perform accumulator test. Test witnessed by AOGCC rep John Crisp and NAD TP Bill Bixby. 16:30 - 17:30 1.00 BOPSU P SURF Rig down test equipment. Install wear bushing. 17:30 - 18:30 1.00 BOPSU P SURF Service top drive and drawworks. 18:30 - 19:00 0.50 DRILL. P INTi Pick up BHA tools to rig floor. 19:00 - 19:30 0.50 DRILL P INT1 Pick up and make up BHA #3. New 83/4" Hycalog DTX619M, 1.5 deg PDM, float sub, NM Stab, LWD/ARC, MWD. Orient MWD. 19:30 - 20:00 0.50 DRILL P INT1 Run in hole with remainder of BHA plus HWDP from 88' to 1,008'. 20:00 - 20:30 0.50 DRILL P INT1 Shallow hole test MWD. 566 gpm, 1,220 psi - OK. 20:30 - 21:30 1.00 DRILL P INT1 Continue running in hole with BHA #3 on 4" drill pipe from 1,008' to 2,538'. 21:30 - 22:30 1.00 DRILL P INT1 Cut and slip drilling line 65'. Clean out under drawworks, adjust brakes, and calibrate block position. 22:30 - 23:00 0.50 DRILL P INT1 Circulate air out of system prior to casing test. 23:00 -00:00 1.00 DRILL P INT1 Pressure test 9 5/8 casing to 3,500 psi - 30 minutes - OK. 9/27/2006 00:00 - 01:00 1.00 DRILL P INT1 Drill out float equipment and cement from the float collar ~ 2,613' to shoe ~ 2,699'. Clean out rathole to 2,712'. 500 gpm, 1,760 psi on, 1,530 psi off, 60 rpm, 2.1 k TO on, 1.3k TO off. PU - 101 k, SO - 94k, RT - 98k. 01:00 - 01:30 0.50 DRILL P INT1 Drill 20' of new ho-e from 2,712' to 2,732'. 500 gpm, 1,760 psi on, 1,530 psi off, 60 rpm, 2.1 k TO on, 1.3k TO off. PU - 101 k, SO - 94k, RT - 98k. 01:30 - 01:45 0.25 DRILL P INT1 Circulate bottoms up. 500 gpm, 1,530 psi, 60 rpm, 1.3k TO. PU - 101 k, SO - 94k, RT - 98k. 01:45 - 02:00 0.25 DRILL P INT1 Build spacer in pill pit. 02:00 - 03:15 1.25 DRILL P INT1 Displace hole from 9.4 ppg spud mud to 8.8 ppg LSND mud. 500 gpm, 930 psi FCP. 03:15 - 03:30 0.25 DRILL P INT1 Perform LOT. TVD - 2,699' MW - 8.8 Pp9 Test Pressure - 870 psi EMW - 15.0 ppg 03:30 - 04:30 1.00 DRILL P INTi Pick up Ghost reamer and run it in hole below casing head. Obtain slow pump rates and benchmark ECD's. CECD without rotating - 9.28 ppg. CECD rotating - 9.29 ppg. Lay down Ghost reamer. 04:30 - 12:00 7.50 DRILL P INT1 Drill 8 3/4" hole from 2,732' to 3,881'. 580 gpm, 1,848 psi on, 1,456 psi off, 80 rpm, 3.1 k TO on, 1.1 k TO off. PU - 117k, SO - 109k, RT - 116k, WOB - 5-15k. CECD - 9.74 ppg, AECD - 9.85 ppg. AST - 0 hrs, ART - 2.72 hrs. Backream each stand Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 9/27/2006 ~ 04:30 - 12:00 L-04 L-04 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 9ES Start: 9/17/2006 Rig Release: 10/26/2006 Rig Number: Hours Task ~ Code I NPT Phase _ ~ _ 7.50 ~ DRILL ~ P ~ INT1 12:00 - 00:00 12.00 DRILL P 9/28/2006 100:00 - 12:00 12.00 DRILL P 12:00 - 00:00 I 12.001 DRILL I P 9/29/2006 100:00 - 12:00 I 12.001 DRILL I P INT1 INT1 INT1 INT1 12:00 - 21:00 I 9.001 DRILL P INT1 21:00 - 21:30 I 0.501 DRILL I P I I INT1 21:30 - 23:00 1.501 DRILL N RREP ~ INT1 23:00 - 00:00 I 1.001 DRILL I N I RREP I INT7 Page 5 of 24 Spud Date: 9/20/2006 End: Description of Operations prior to connections ~ drilling rate up, 75% down. Pumped 25 bbl 2 Ib weighted high vis sweep ~ 3,316' with 30% increase in cuttings with sweep back to surface. Drill 8 3/4" hole from 3,881 to 5,507'. 585 gpm, 2,590 psi on, 2,190 psi off, 80 rpm, 4.5k TO on, 1.9k TO off. PU - 135k, SO - 120k, RT - 130k, WOB - 5-15k. CECD - 9.69 ppg, AECD - 9.91 ppg. AST - 3 hrs, ART - 3.92 hrs. Backream each stand prior to connections @ drilling rate up, 75% down. Pumped 25 bbl 2 Ib weighted high vis sweep ~ 4,167' with 10% increase in cuttings with sweep back to surface. Pumped 25 bbl high vis sweep ~ 5,220' with no increase in cuttings with sweep back to surface. Drilt 8 3/4" hole from 5,507 to 6,558'. 585 gpm, 3422 psi on, 2,958 psi off, 80 rpm, 5.1 k TO on, 2.4k TO off. PU - 148k, SO - 133k, RT - 145k, WOB - 10-20k. CECD - 11.22 ppg, AECD - 11.48 ppg. AST - 7.13 hrs, ART - 2.08 hrs. Backream each stand prior to connections ~ drilling rate up, 75% down. Started mud weight up with spike fluid ~ 5,818' to 10.6 ppg by 5,920'. Drill 8 3/4" hole from 6,558' to 7,228'. 585 gpm, 3500 psi on, 3,250 psi off, 80 rpm, 5.1 k TO on, 2.6k TQ off. PU - 155k, SO - 140k, RT - 150k, WOB - 10-20k. CECD - 11.25 ppg, AECD - 11.59 ppg. AST - 8.03 hrs, ART - 1.75 hrs. Backream each stand prior to connections ~ drilling rate up, 75% down. Pumped 35 bbl 2.5 Ib weighted high vis sweep ~ 6,800' with 10% increase in cuttings with sweep back to surface. Reduced pump rate to 525 gpm, 3,170 psi on, 2,800 psi off ~ 7,100' and started treating mud with 1.5 ppb MIX II Med LCM to prevent seepage losses. Drill 8 3/4" hole from 7,228' to 7,706'. 525 gpm, 3380 psi on, 2,950 psi off, 80 rpm, 5.5k TO on, 3.6k TO off. PU - 165k, SO - 145k, RT - 155k, WOB - 10-20k. CECD - 11.09 ppg, AECD - 11.09 ppg. AST - 9.45 hrs, ART - .49 hrs. Backream each stand prior to connections ~ drilling rate up, 75% down. Drill 8 3/4" hole from 7,706' to 8,193'. 525 gpm, 3640 psi on, 3,200 psi off, 80 rpm, 6.1 k TO on, 3.9k TO off. PU - 174k, SO - 148k, RT - 165k, WOB - 10-20k. CECD - 11.05 ppg, AECD - 11.10 ppg. AST - 5.88 hrs, ART - 1.28 hrs. Backream each stand prior to connections ~ drilling rate up, 75% down. Circulate and reciprocate while trouble shooting #2 mud pump. Examination of mud end showed cracked pot on #1 cylinder. 294 gpm, 1,110 psi, 80 rpm, 4k TO, 150k RWT. Observe well - OK. 10.6 ppg MW. Start short trip to shoe for mud pump repair. Pulled first 4 stands without any overpull, but hole not taking proper displacement. Observed gas breaking out of mud in bell nipple. Pump 1 stand out to 7,706' without displacement. Observe hole -slight flow down flowline. Trip back in hole. Wash last stand down to 8,185'. Circulate 1 1/2 bottoms up. 294 gpm, 1,110 psi, 80 rpm, 4k TO, 150k RWT. Observed good amount of gas breaking out at bell nipple for appx 8 minutes that calculated out to come from the Kuparuk. Gained 3.5 bbls while gas circulated out then returned to normal after Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 6 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours ~ Task I Code I NPT Phase I ~ 9/29/2006 23:00 - 00:00 1.00 DRILL N RREP INT1 9/30/2006 00:00 - 03:00 3.00 DRILL P INT1 04:00 - 102:00 I 8.00 ~ DRILL P I RREP INT1 INT1 12:00 - 00:00 I 12.001 DRILL I P I I INT1 10/1/2006 100:00 - 05:00 I 5.001 DRILL I P I I INTi 05:00 - 06:00 I 1.001 DRILL I P I I INT1 06:00 - 06:30 ~ 0.501 DRILL P I INTi 06:30 - 08:00 I 1.501 DRILL I P I I INTi 08:00 - 08:30 I 0.501 DRILL I P I I INT1 08:30 - 11:00 I 2.501 DRILL I P I I INT1 11:00 - 15:00 4.00 DRILL P INT1 15:00 - 15:30 0.50 DRILL P INT1 15:30 - 18:00 2.50 DRILL P INTi 18:00 - 20:00 2.00 DRILL P INTi 20:00 - 20:30 0.50 DRILL P INT1 20:30 - 23:30 3.00 DRILL P INTi Description of Operations gas was out of hole Circulate and condition mud. Bump mud weight up from 10.6 ppg to 10.8 ppg. 290 gpm, 1,110 psi, 80 rpm, 4k TQ, PU- 150k, SO - 140k, 148k RWT. Continue circulate and reciprocate at reduced rate while replacing mud end on #2 mud pump. 294 gpm, 1,060 psi. Drill 8 3/4" hole from 8,193' to 8,472'. 525 gpm, 3615 psi on, 3,180 psi off, 80 rpm, 6.1k TO on, 4.2k TQ off. PU - 175k, SO - 145k, RT - 170k, WOB - 10-20k. CECD - 11.20 ppg, AECD - 11.28 ppg. AST - 3.70 hrs, ART - .93 hrs. Backream each stand prior to connections ~ drilling rate up, 75% down. Drill 8 3/4" hole from 8,472' to 8,855'. 525 gpm, 3625 psi on, 3,180 psi off, 80 rpm, 6.7k TQ on, 4.6k TQ off. PU - 185k, SO - 149k, RT - 167k, WOB - 10-20k. CECD - 11.16 ppg, AECD - 11.26 ppg. AST - 8.13 hrs, ART - .96 hrs. Backream each stand prior to connections ~ drilling rate up, 75% down. Directionally drill 8 3/4" hole from 8,855' to 9,076'. 525 gpm, 3,500 psi on, 3,300 psi off, 80 rpm, 6.8k TQ on, 4.9k TO off. PU - 185k, SO - 150k, RT - 169k, WOB - 10-20k. CECD - 11.16 ppg, AECD - 11.22 ppg. Backream each stand prior to connections @ drilling rate up, 75% down. Pumped a 50 bbls, 21b weighted high vis sweep ~ 8,900' with a 20% increase in cuttings returned back to surface. Circulate bottoms up for samples. 525 gpm, 3,350 psi, 80 rpm, 4.9k TO. Drill from 9,076' to 9,142'. 525 gpm, 3,500 psi on, 3,350 psi off, 80 rpm, 6.8k TO on, 4.9k TO off. PU - 185k, SO - 150k, RT - 169k, WOB - 10-20k. CECD - 11.16 ppg, AECD - 11.22 Pp9• Circulate bottoms up for samples. 525 gpm, 3,350 psi, 80 rpm, 4.9k TO. Drill from 9,142' to TD ~ 9,165' MD, 8,666' TVD. 525 gpm, 3,500 psi on, 3,200 psi off, 80 rpm, 6.8k TO on, 4.9k TQ off. PU - 185k, SO - 150k, RT - 169k, WOB - 10-20k. CECD - 11.16ppg, AECD - 11.22 ppg. Bit hours from midnight: AST - 4.55 hrs, ART - .83 hrs. Circulate for samples plus 4 bottoms up. 525 gpm, 3,350 psi, 80 rpm, 5.ik TQ, 174k RTW. CECD - 11.18 ppg, AECD - 11.16ppg. MW - 10.8 ppg. Monitor well - OK. POH from 9,165' to 7,738' without problem. PU - 215k, SO - 152k. Pump dry job and continue POH from 7,738' to 2,666' without problem. PU - 88k, SO - 85k @ shoe. Service topdrive, drawworks, crown, and blocks. Trip in hole from 2,666' to 7,700'. Set down ~ 7,700'. Wash and ream from 7,700' to 8,695'. 475 gpm, 3,085 psi, 80 rpm, 5.1 k TQ, 165k RTW. Had 10 ppg gas cut mud while reaming for apex 10 minutes. No pit gain. Run in hole without pumping from 8,695' to 9,078' without problem. Wash last stand down from 9,078' to 9,165'. Circulate bottoms up 3 1/2 times before shakers cleaned up. 525 gpm, 3,650 psi, 80 rpm, 5.1k TO, 165k RTW. First bottoms up had normal cuttings across shaker. After 1-1/4 bottoms up normal cuttings stopped and splintered shale Printed: 11/6/2006 6:05:11 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date ~ From - To ~ Hours Task Code ~ NPT 10/1/2006 120:30 - 23:30 3.00 DRILL P 23:30 - 00:00 I 0.501 DRILL I P 10/2/2006 100:00 - 06:00 I 6.001 DRILL I P 06:00 - 07:30 I 1.501 DRILL I P 08:30 - 09:30 1.00 BOPSURP 09:30 - 10:30 1.00 BOPSU~ P 10:30 - 13:30 3.00 CASE P 13:30 - 18:00 I 4.50 I CASE I P 18:00 - 18:30 I 0.501 CASE I P 18:30 - 21:00 2.501 CASE I P 21:00 - 22:00 I 1.00 I CASE I P 22:00 - 00:00 I 2.001 CASE I P 10/3/2006 100:00 - 00:30 0.50 ~ CASE P 00:30 - 01:00 I 0.501 CASE I P 01:00 - 03:00 I 2.001 CASE I P Start: 9/17/2006 Rig Release: 10/26/2006 Rig Number: Phase INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Page 7 of 24 Spud Date: 9/20/2006 End: Description of Operations started coming over shakers covering appx 90 % of shaker surface. Continued to circulate until shale covered appx. 10% of shaker area. CECD - 11.16 ppg, initial AECD - 11.5 ppg, final AECD - 11.18 ppg. MW - 10.8 ppg. Monitor well - OK. POH from 9,165' to 8,633' without problem. PU - 215k, SO - 150k. Continue POH to run 7" casing from 8,633' to 7,650' without problem. Pump dry job and continue POH from 7,650' to 3,309' without problem. Laydown ghost reamer. Well started taking overdisplacement after ghost reamer was layed down. POH from 3,309' to 2,701'. Observe well ~ shoe - 10 min - 1.5 bbls loss. Continue POH from 2,701' to 272'. Laydown jars, 5" HWDP, XO, saver sub, alt DC's, STAB's, MWD, LW D, float sub, motor and bit. Total losses for trip - 17 bbls. Well static when BHA was out of hole. Clear and clean rig floor Pull wear bushing, install test plug. Change out top pipe rams from 3.5" x 6" VBR's to 7". Install 7" test joint. Test 7" rams to 250 / 4,000 psi - 5 minutes - OK. Laydown test joint and rig down test equipment. Rig up to run 7' casing. Make dummy hanger run, change out bales. PJSM. Make up and Baker Lok 7" 26# L-80 BTC-M casing shoe track to 8,400 fUlbs of make up torque. Make up casing fill-up tool. Check float equipment - OK. Continue run in hole with 7" casing to 2,670', lubricated with Best-O-Life 2000 NM. Fill every joint and circulate down every 5 joints at 4 bpm for 3 minutes. Ran at 1 1/2 minutes perjoint in cased hole. Record pickup and slack of weights every 10 joints. No mud losses. Circulate bottoms up 1 1/2 times. 184 gpm, 256 psi. PU - 96k, SO - 90k. No mud losses. Run in hole with 7" BTC-M casing from 2,670' to 4,487. Started out of shoe at 2 minutes per joint and started losing partial displacement. Slowed running speed to 3 minutes per joint, filling every joint and circulate down every 5 joints at 4 bpm for 3 minutes each. Returns diminished gradually to no returns. Lost 80 bbls of mud. Circulate bottoms up. Returns returned to 100% after circulating for 5 minutes with no losses for the rest of circulation. 171 gpm, 310 psi. PU - 130k, SO - 128k. Continue running in hole without losses from 4,487' to 5,102. Running speed - 3 minutes per joint, filling every joint and circulate down every 5 joints at 4 bpm for 3 minutes each. Lost 80 bbls 10.8 ppg LSND mud for tour. Lost 97 bbls 10.8 ppg LSND mud for day. Continue running in hole with 7" 26# L-80 BTC casing from 5,102' to 5,235'. Make up cross-over pup joint to TCII. No mud losses. Ran total of 128 joints of BTC casing. Rig up TCII running equipment. Circulate and reciprocate while rigging up. 166 gpm, 430 psi. No mud losses. Continue running in hole with 7" 26# L-80 BTC-M X TCII casing from 5,235' to 6,082'. Running speed - 3 minutes per joint, filling every joint and circulate down every 5 joints at 4 bpm for J Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 8 of 24 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To L-04 L-04 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 9ES i Task TE A DRI Code LING NPT Start I Rig Rig Phase Spud Date: 9/20/2006 : 9/17!2006 End: Release: 10/26/2006 Number: Description of Operations 10/3/2006 01:00 - 03:00 2.00 CASE P INT1 3 minutes each. Started losing 1 bbl of displacement per 5 joints. Lost 3 bbls. 03:00 - 07:00 4.00 CASE P INT1 Continue running in hole with 7" 26# L-80 BTC-M X TCII casing from 6,082' to 7,529'. Running speed - 3 minutes per joint, filling every joint and started circulating down every 3 joints at 4 bpm for 3 minutes each. Total loss from midnight - 8 bbls. 105 bbls total loss for casing run. 07:00 - 08:30 1.50 CASE P INT1 Circulate down 5 joints from 7,529' to 7,726' for 10 minutes each ~ 4 bpm, 430 psi prior to running through Kingak. 08:30 - 11:30 3.00 CASE P INT1 Continue running in hole with 7" 26# L-80 BTC-M X TCII casing from 7,726' to 9,157'. Running speed - 3 minutes per joint, filling every joint with no circulating through Kingak. Total loss from midnight - 8 bbls. 105 bbls total loss for casing run. Land casing on depth ~ 9,158'. PU - 275k, SO - 170k. Ran total of 128 jts 7" 26# L-80 BTC-M casing. 97 jts 7" 26# L-80 TCII casing. 159 7-1/8" x 8-1/4" Rigid Staight Blade Centralizers. 52 Stop Rings. 2 Centralizers locked next to shoe. Starting with Jts #35 - #128, and TCII Jts #1 - #11, odd #'s - 1 per jt, even # 's - 2 per jt separated by stop ring. Float shoe ~ 9,158' Tops: Float Collar C~ 9,116' Baffle collar C~? 9,074' ES Cementer C~3 4,712' 7" BTC-M x TCII XO jt ~ 3,922' Top Centralizer ~ 3,480' 11:30 - 12:00 0.50 CEMT P INT1 Rig down casing fill-up tool. Slowdown topdrive. Make up cementing head. 12:00 - 15:00 3.00 CEMT P INT1 Circulate and condition mud for 1st stage cement job. Stage pumps up in 1/2 bbl increments to 5 bpm, 620 psi ICP, 575 psi FCP. Circulated 3 bottoms up. Did not reciprocate casing. No mud losses. Held cementing PJSM while circulating. 15:00 - 17:30 2.50 CEMT P INTi Pump 1st stage cement job. Pump 5 bbls H2O. Pressure test cement lines to 4,000 psi - OK. Pump 70 bbls of 11.5 ppg MudPush II followed by 116 bbls of 12.5 ppg Litecrete lead cement with 2 ppb CemNET, followed by 42 bbls 15.8 ppg Class "G" tail cement. Drop plug and kick out with 5 bbls H2O. 600 maximum pressure while pumping cement. Switch to rig and displace cement with 10.8 ppg mud @ 7 bpm until mud caught cement. Continue displacing ~ 5 bpm, up to 280 bbls of mud away, 450 psi ICP, 1,350 FCP, slow pump to 2.5 bpm until 325 bbls away, 1,180 psi ICP, 1,310 psi FCP. Slow pump to 1.5 bpm for remaining 18 bbls, 1,175 psi ICP, 1,235 psi FCP. Bump plug on schedule with 343 bbls ~ 95% effc. and 2,050 psi. CIP ~ 17:20 hr. Bleed off pressure, check floats - OK. Did not reciprocate casing. No mud losses, 17:30 - 18:00 0.50 CEMT P INT1 Load and lockin ES cementer closing plug. Pressure up on casing to 3,350 psi to open ES cementer. Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 9 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase 10/3/2006 118:00 - 19:00 1.001 CEMT I P 19:00 - 00:00 I 5.001 CEMT I P 10/4/2006 100:00 - 01:30 I 1.501 CEMT I P 01:30 - 03:30 i 2.00 ~ CEMT ~ P 03:30 - 04:30 1.00 CEMT P 04:30 - 07:00 2.50 CEMT P 07:00 - 08:30 1.50 WHSUR P 08:30 - 10:30 2.00 BOPSU P 10:30 - 12:00 I 1.501 CEMT P 12:00 - 13:30 I 1.501 DRILL I P 13:30 - 14:30 I 1.001 DRILL I P 15:00 - 16:00 I 10.001 DRILL P 16:00 - 16:30 0.50 DRILL P 16:30 - 18:30 2.00 DRILL P 18:30 - 19:00 0.50 DRILL P INTi INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Description of Operations Circulate bottoms up. Stage pumps up to 5 bpm, 440 psi. Returned spacer and 20 bbls of contaminated cemenUmud mix to surface on bottoms up. Slow pump to 73 gpm, 190 psi while waiting on cement to reach 100 Bc. Continue circulating at reduced rate while waiting on cement. Dowell Schlumberger back on location @ midnight to rig up and batch mix cement. Increased pump rate to 5 bpm, 290 psi prior to cement job. Held PJSM while circulating. Pump 2nd stage cement job. Pump 5 bbls H2O. Pressure test cement lines to 4,000 psi - OK. Pump 30 bbls of 11.5 ppg MudPush II followed by 24 bbls of 12.5 ppg LiteCrete lead cement, followed by 21 bbls 15.8 ppg Class "G" tail cement. Drop closing plug and kick out with 5 bbls H2O. 360 maximum pressure while pumping cement. Switch to rig and displace cement with 10.8 ppg mud @ 5 bpm, up to 120 bbls of mud away, 190 psi ICP, 460 FCP, slow pump to 2 bpm until 160 bbls away, 315 psi ICP, 695 psi FCP. Slow pump to 1 bpm for remaining 16 bbls, 635 psi ICP, 760 psi FCP. Bump plug on schedule with 176 bbls ~ 95% effc. and 2,000 psi. CIP ~ 03:30 hr. Hold pressure for 5 minutes. Bleed off pressure, confirm that cementer closed - OK. Clean ice build up out of derrick. Rig down cementing and casing equipment. Rig down cementing head. Laydown landing joint, elevators and long bales. Install short bales and drill pipe elevators. Install 9 5/8" x 7" packoff and test to 5,000 psi - 10 minutes - OK. Install test plug. Change out top pipe rams from 7" to 3.5" x 6'' VBR's. Test top pipe rams to 250 psi low, 4,000 psi - 5 minutes each - OK. Pull test plug and install wear bushing. Clean and clear rig floor. Pick up drilling tools to rig floor. 'SIM OPS. Perform 7" annulus LOT. TVD - 2,699', MW - 10.9 ppg, LOP - 330 psi, EMW - 13.25 ppg. Injection rate of 1/2 bpm - 330 psi. PROD1 PJSM on nuclear source. Pick up and make up BHA #4, drilling assembly. 6.125" HTC MX-18HDX bit, 1.5 deg PDM, NM STAB, MWD, ADN, 3 ea NM Flex DCs, Circ sub, XO, 1 jt 4" DP, JARS. PROD1 Run in hole with BHA #4 on 4" HT-40 drill pipe by picking up single joints out of pipe shed to 1,197'. PROD1 Shallow hole test MWD. 275 gpm, 1,580 psi - OK. PRODi Continue running in hole picking up singles from pipe shed from 1,197'to 1,963' PROD1 Clean ice build up out of derrick. PROD1 Run in hole with drill pipe out of derrick from 1,963' to 4,633'. *SIM OPS. Inject 50 bbls of 10.9 ppg mud down 7" annulus. 3 bpm, 750 psi ICP, 650 psi FCP. Freeze protect 7" annulus with 65 bbls 80 deg dead crude ~ 2 bpm, 650 psi, ICP, 1 bpm, 1,000 psi FCP. PROD1 Wash down to top of cement at 4,701'. Drill cement to 4,711'. Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Event Name: DRILL+COMPLETE Start: 9/17/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To ~ Hours Task Code NPT Phase i 10/4/2006 118:30 - 19:00 19:00 - 19:30 19:30 - 21:30 21:30 - 23:00 0.50 DRILL P 0.50 DRILL P 2.00 DRILL P 1.50 DRILL P PRODi PROD1 PROD1 PROD1 23:00 - 23:30 23:30 - 00:00 10/5/2006 00:00 - 01:00 01:00 - 01:30 01:30 - 02:45 02:45 - 03:30 03:30 - 04:30 0.50 DRILL P 0.50 DRILL P 1.00 DRILL P PROD1 PROD1 PROD1 0.501 DRILL P I PROD1 1.251 DRILL I P I I PROD1 0.751 DRILL I P I I PROD1 1.001 DRILL I P I I PROD1 Page 10 of 24 Spud Date: 9/20/2006 End: Description of Operations Drill out ES Cementer on depth from 4,711' to 4,714'. 275 gpm, 2,190 psi, 60 rpm, 1.4k TO. PU - 100k, SO - 90k, RTW - 100k, WOB - 10-20k. Circulate bottoms up working bit through ES cementer without problem. 275 gpm, 2,190 psi, 60 rpm, 1.1k TO. PU - 100k, SO - 90k, RTW - 100k, WOB - 10-20k. Continue running in hole from 4,725' to 8,626'. Perform unannounced D-1 drill with WSL on flow paddle and TP observing crew. 1 stand was run in the hole with no noticeable increase in flow noticed by driller as it appeared to have no change from the regular flow rate. WSL increased the flow pressure on the flow paddle and was noticed after the second stand was ran in. The crew responded well with the floor valve stabbed, and the well shut in with men in position in 1 min, 50 sec. Only one misstep as one of the hands could not locate the valve wrench immediately. A meeting was then held in the doghouse to discuss the reaction of the crew, the improvements that could be made and the importence of early kick detection. We then discussed well kill principles of circulating out a kick using the Driller's method. A D-5 Well Kilt Drill was then performed by applying 200 psi on the well. Crew then took turns on the choke and driller's console practicing bringing up to kill rate speeds and ICP's and then maintaining drill pipe pressure while simulating circulating up a kick out of the hole. A few mistakes were made, formations were fractured and extra kicks were induced, but as the crew practiced, fewer mistakes were made as the simulation progressed. During the simulation, it was stressed on the importance of early kick detection to keep the shut in pressures down and how mistakes made on the pump and choke operation can lead to more problems. 'Note. Anew floorhand was the last one on the choke and out performed everyone with the smoothest start up with the relief driller on the pump console. Flush out choke manifold with water. Slowdown kill line and choke manifold. Run in hole from 8,626' to 9,009' Rig up and pressure test 7" 26# L-80 casing to 4,000 psi - 30 minutes - OK. 25 psi loss. Rig down test equipment. Pull up hole to 8,974' and MadPass log down per Geology from 8,974'to 9,073'. 200 fph, 220 gpm, 1,980 psi, 50 rpm, 4.5k TO. PU - 195k, SO - 145k, RTW - 175k. Top of cement ~ 9,053'. Continued MadPass while drilling cement to top of Baffle Collar ~ 9,073'. Drill out Baffle collar ~ 9,073', cement to Float Collar ~ 9,116', cement to Float Shoe ~ 9,158', and rat hole to TD ~ 9,165'. Started mud swap 20' above Float Shoe. 220 gpm, 1,980 psi, 60 rpm, 6.1 k TO. Did not drill new hole due to proximity of the Sag River sand with 10.8 ppg mud in annulus. Finish displacing from 10.8 ppg LSND mud to 9.0 ppg FlowPro mud. 235 gpm, 2,340 psi ICP, 1,800 psi FCP. 60 rpm, 6.9k initial TO, 2.6k final TO. Cut and slip drilling line 84' while cleaning mud surface Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 11 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date ,From - To Hours Task Code NPT Phase Description of Operations 10/5/2006 03:30 - 04:30 1.00 DRILL P nt. 04:30 - 05:00 0.50 DRILL P opdrive, crown, and blocks. 05:00 - 06:00 1.00 DRILL P from derrick. 06:00 - 06:30 0.50 DRILL P f new hole from 9,165' to 9,185'. 275 gpm, 2,200 psi 06:30 - 07:30 I 1.001 DRILL I P 07:30 - 12:00 I 4.501 DRILL I P 12:00 - 23:30 I 11.501 DRILL I P 23:30 - 00:00 I 0.501 DRILL I P 10/6/2006 100:00 - 00:30 I 0.501 DRILL I P 00:30 - 01:00 ~ 0.50 ~ DRILL ~ P 01:00 - 01:30 I 0.501 DRILL I P 01:30 - 06:30 ~ 5.001 DRILL P 06:30 - 07:30 I 1.001 DRILL I P 07:30 - 08:30 1.00 BOPSU P 08:30 - 12:00 3.50 BOPSU P 12:00 - 12:30 I 0.501 BOPSUR P 12:30 - 13:00 0.50 DRILL P 13:00 - 14:30 1.50 DRILL P 14:30 - 20:30 I 6.001 DRILL I P 20:30 - 21:00 I 0.501 DRILL 1 P 21:00 - 21:30 0.50 DRILL P 21:30 - 00:00 2.50 DRILL P PROD1 equipme PROD1 Service t PROD1 Clear ice PROD1 Drill 20' o on, 2,050 psi off, 60 rpm, PU - 171 k, SO - 145k, RTW - 160k, WOB 15k. PROD1 Pull up hole to 9,134' and perform FIT. 8,661' TVD, MW - 9.0 ppg, FIP - 900 psi, EMW - 11.0 ppg. PROD1 Directional drill 6.125" hole from 9,185' to 9,296'. 275 gpm, 2,225 psi on, 1,960 psi off, 60 rpm, 6.5k TO on, 3.1k TO off, PU - 171 k, SO - 145k, RTW - 160k, WOB 15k. AST - 2.28 hrs, ART - .38 hrs. PROD1 Directional drill 6.125" hole from 9,296' to 9,730' looking for Sadlerochit. TSAD ~ 9,674 MD @ 79 deg inclination. 275 gpm, 2,365 psi on, 2,130 psi off, 60 rpm, 3.9k TO on, 2.4k TO off, PU - 173k, SO - 150k, RTW - 160k, WOB 10-15k. AST - 6.75 hrs, ART - 3.54 hrs. PROD1 Backream out of hole from 9,730' to 9,583' ~ 1,000 fph, 250 gpm, 1,830 psi, 60 rpm, 3.3k TO. PROD1 Continue backreaming out of hole from 9,583' to 9,295' ~ 1,000 fph, 250 gpm, 1,835 psi, 40 rpm, 2.7k TO. PROD1 MadPass log from 9,295' to 9,225' ~ 300 fph, 250 gpm, 1,835 psi, 40 rpm, 2.7k TO. PROD1 Continue POH pumping out without rotating from 9,225' to 9,134'. Observe well - OK. MW 9.1 ppg. PROD1 Pump dry job and POH from 9,134' to BHA ~ 241'. PU - 175k, SO - 165k. PROD1 PJSM. Stand back BHA, pull nuclear source, breakout and laydown bit and motor. Bit grade: 1-4-LT-G-E-I-ER-BHA. PROD1 Pull wear bushing and install test plug. Rig up to test BOPE. PROD1 Pressure test BOPE to 250 psi low / 4,000 psi high. Test annular preventer to 250 psi low / 3,500 psi high. Tested pipe rams with 4" and 4.5" test joints. Perform (D4) accumulator test. State witnessing of test waived by AOGCC rep Chuck Sheve. Test witnessed by BP WSL Alan Madsen and NAD TP Kelly Cozby. PROD1 Pull test plug and instatl wear bushing. Rig down test equipment. PROD1 Clear ice buildup out of derrick. PROD1 Pick up and make up BHA # 5. Picked up 1.5 deg PDM-AIM and RR 6.125" Hycalog DSX613M-64. PRODi RIH with BHA # 5 from 226' to 9,664'. Shallow hole tested MWD ~ 1,182', 275 gpm, 840 psi. Fill pipe ~ shoe and orient high side. PU - 165k, SO - 150k. Finished running in hole without problem to 9,664.. Pick up last stand and wash down from 9,664' to 9,730'. PROD1 Directional drill 6.125" hole from 9,730' to 9,760'. 275 gpm, 2,130 psi on, 1,750 psi off, 60 rpm, 3.5k TO on, 2.4k TO off, PU - 175k, SO - 150k, RTW - 160k, WOB 10k. PROD1 Circulate and condition mud due to shakers blinding off with clay that had peanut butter consistency with bottoms up. PROD1 Directional drill 6.125" hole from 9,760' to 9,870' MD, 8,934' Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Event Name: DRILL+COMPLETE Start: 9/17/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To I Hours Task !Code NPT Phase - --- ---- 10/6/2006 21:30 - 00:00 2.50 DRILL ~ P ~ PROD1 10/7/2006 100:00 - 12:00 I 12.001 DRILL I P I I PROD1 12:00 - 00:00 I 12.001 DRILL I P I I PROD1 10/8/2006 100:00 - 04:00 4.00 I DRILL I P I I PROD1 04;00 - 05:00 I 1.00 DRILL I N DPRB PROD1 05:00 - 08:30 3.501 DRILL N DPRB I PROD1 08:30 - 09:00 0.501 DRILL N I DPRB PROD1 09:00 - 09:30 0.501 DRILL I P PROD1 09:30 - 10:00 I 0.501 DRILL I N I DPRB I PROD1 10:00 - 11:00 I 1.001 DRILL I N I DPRB I PRODi Page 12 of 24 Spud Date: 9/20/2006 End: Description of Operations TVD. 275 gpm, 1,990 psi on, 1,750 psi off, 60 rpm, 3.1k TO on, 2.4k TO off, PU - 175k, SO - 150k, RTW - 160k, WOB 10k. ART - 1.44 hrs, AST - .33 hrs. Directional drill 6.125" hole from 9,870' to 10,467' MD, 9,015' TVD. 275 gpm, 2,230 psi on, 2,080 psi off, 60 rpm, 4.7k TO on, 3.3k TO off, PU - 173k, SO - 150k, ROT - 162k, W OB 10-20k. AST - 1.28 hrs, ART - 6.50 hrs. Survery every 30'. Backream 30' prior to connections. Directional drill 6.125" hole from 10,467' to 11,063' MD, 8,983' TVD. 275 gpm, 2,250 psi on, 2,150 psi off, 60 rpm, 4.4k TO on, 3.4k TO off, PU - 173k, SO - 143k, ROT - 163k, WOB 20k. AST - 3.90 hrs, ART - 5.92 hrs. Survery every 30'. Backream 30' prior to connections. Pumped a 20 bbls, 21b over sweep ~ 10,830' with a 10% increase in cuttings when back to surface. Directional drill 6.125" production hole from 11,063'to 11,247'. 275 gpm, 2,250 psi on, 2,000 psi off, 60 rpm, 4.7k TO on, 3.7k TO off, PU - 181 k, SO - 146k, ROT - 160k, W OB 20k. Survey every 30'. Backream 30' prior to connections. Crossed a fractured fault from 11,138' to appx 11,150'. Hole started taking mud ~ 60 bph, slowing down to 25 bph while treating mud with Calcium Carbonate. No static losses. Cross second fault from appx 11,212' to 11,247'. Lost circulation ~ 11,212' with no retums and attempted to drill out of fault. Stopped drilling ~ 11,247' when surface mud volume was CAB -300 bbls. Flow rate increased to 8% while drilling. Dynamic mud loss rate ~ 180 bph. Started building LCM pill while drilling. POH from 11,247' to 11,099'. Pump and spot 40 bbls, 32 ppb LCM pill ~ 2 bpm, 470 psi. Pill consisted of 40 bbls 9.1 ppg mud, 18 sacks MIX II MED, 12 sacks MIX II FINE, 10 sacks SAFE CARB 20. Hole stayed full of mud while pumping pill with no noticeable difference when pill exited the bit. Circulate over the top of the hole monitoring static losses. Losses at 40 bph. Build volume in mud pits and wait on new mud from mud plant. Mud to be here C~ appx 08:00 hr. Total losses from midnight - 385 bbls. Take on 290 bbls of new 9.0 ppg mud mixed at the mud plant and 290 bbls.of 9.1 ppg. from 7-ES. Mix up a 50 bbl. LCM pill ~ 46 ppb. with the following products: 9 ppb. MI SEAL Course, 9 ppb MI SEAL MED, 18 ppb MIX II MED and 10 ppb. medium nut plug. RIH with 2 stands of DP while mixing pill Start 50 bbl. LCM pill around and drill ahead in 6.125" production hole from 11,247' to 11,287' while showing 9% returns ~ 280 GPM, 2,000 psi, 60 rpm, 5k TO on, 4.3k TO off. (260 BPH loss rate) Picked up off bottom as sweep exited pipe. Spot LCM outside pipe and clear with additional 200 stks. Lost 21 bbls. to the formation while spotting the LCM outside. Loss rate at 45 BPH while pumping on bottom at 2 BPM. Pull 10 stands from 11,287' to 10,238'. Hole took proper displacement during trip out. Stage pumps up to 260 gpm, 2,170 psi, and rotate 1 stand out at 32 rpm , 4k TO, while monitoring Gain/Loss. Once staged up, the hole lost 18.9 bbls. in 20 minutes for a loss rate of 57 Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Paget 3 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date I From - To I Hours I Task ~ Code I NPT I Phase 10/8/2006 10:00 - 11:00 1.00 DRILL N DPRB PROD1 11:00 - 11:30 0.50 DRILL N DPRB PROD1 11:30 - 12:00 0.50 DRILL P PROD1 12:00 - 15:30 3.50 DRILL P PROD1 15:30 - 16:00 0.50 DRILL N DPRB PROD1 16:00 - 00:00 8.00 DRILL P PROD1 10/9/2006 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 04:00 1.50 DRILL P PRODi 04:00 - 08:30 4.50 DRILL P PROD1 08:30 - 10:00 1.50 DRILL P PROD1 10:00 - 10:30 0.50 DRILL P PROD1 10:30 - 12:00 1.50 DRILL P PRODi 12:00 - 13:30 1.50 DRILL P PROD1 13:30 - 14:00 0.50 DRILL P PROD1 Description of Operations BPH. Run in hole from 10,143' to 11,287'. Lost 3 bbls. Directional drill 6.125" production hole from 11,287' to 11,397'. 275 gpm, 2,250 psi on, 2,000 psi off, 60 rpm, 4.7k TO on, 3.7k TO off, PU - 181 k, SO - 146k, ROT - 160k, W OB 20k, AST - 0 hrs, ART - 3.41 hrs. Total loss for tour - 538 bbls 9.1 ppg FlowPro mud. Directional drill 6.125" production hole from 11,397' to 11,435' with 150 bph loss rate ~ 275 gpm, 2,260 psi on, 2,150 psi off, 60 rpm, 4.7k TO on, 4k TO off, PU - 173k, SO - 140k, ROT - 163k, WOB 20k. Adding in LCM with 3 sx/hr MIX II MED, 6 sx/hr MI SEAL MED. Added 290 bbls of 9.1 ppg FloPro mud to active system while drilling. Circulate and condition mud by adding 250 bbls seawater to active system for MW going in ~ 8.8 ppg. Shut down and observe well -static. Directional drill 6.125" production hole from 11,435'to 11,800' MD, 8,941' TVD with loss rate ~ 70-100 bph. 275 gpm, 2,550 psi on, 1,900 psi off, 60 rpm, 8.ik TO on, 6.3k TO off, PU - 180k, SO - 160k, ROT - 165k, WOB 10-20k, AST - 5.25 hrs, ART - 2.75 hrs. 100% 8.5 ppg seawater ~ 21:30 hr, ~ 11,640' with an 8.7 ppg coming out. Drilled out of TSAD into Eileen ~ 11,403' MD. Drilled back into TSAD ~ 11,555'. Total loss for tour - 918 bbls 9.1 ppg FlowPro mud. 530 bbls 8.5 ppg seawater. Directional drill 6.125" production hole from 11,800' to 11,980' MD, 8,938' TVD with loss rate ~ 70-100 bph. 275 gpm, 1,925 psi on, 1,600 psi off, 60 rpm, 7k TO on, 6k TO off, PU - 198k, SO - 146k, ROT - 170k, WOB 10-20k, AST - .17 hrs, ART - 1.36 hrs. Last 100 ft of rathole was all sand. Lost 230 bbls while drilling. Circulate 25 bbls high vis sweep back to surface ~ 275 gpm, 1,650 psi, 60 rpm, 5.8k TO. No increase in cuttings with sweep back to surface. Lost 150 bbls. Shut down and monitor well - static. SW WT - 8.7 ppg. Backream from 11,980' to 9,472'. PU - 205k, SO - 148k, (without pumps) 275 gpm, 1,585 psi, 60 rpm, 3.6k TO. Pull up into shoe without rotating from 9,472' to 9,157'. Pump 2 high vis sweeps while backreaming. Monitor well. Static loses ~ 2 bph. Pump and circulate a 50 bbl high vis sweep ~ 275 gpm, 1,500 psi, 60 rpm, 3.5k TO. Trace of LCM and sand in returns. Discussion in town about changing well depth. Service topdrive. Pump 2nd 50 bbls high vis sweep ~ 275 gpm, 1,480 psi, 60 rpm, 3.8k TO. Saw sweep but did not bring up LCM or sand. "Lost 772 bbls of seawater for tour. Decision made to drill to 12,330' Orient high side and run in hole from 9,157' to 11,682' without problem. Run in hole picking up 9 single joints of drillpipe out of pipe Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 14 of 24 Operations Summary Report Legal Wefl Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code j NPT Phase Description of Operations 10/9/2006 13:30 - 14:00 0.50 DRILL P PROD1 shed from 11,682' to 11,911'. Wash down last stand to bottom to 11,980'. 14:00 - 22:00 8.00 DRILL P PROD1 Directionally drill from 11,980' to new TD ~ 12,330' MD, 8,995' TVD. 275 gpm, 1,940 psi on, 1,515 psi off, 60 rpm, 9.3k TO on, 5.7k TO off. AST - 3.96 hrs, ART - 1.85 hrs. Pumped 2 50 bbl high vis sweeps with no increase in cuttings. 22:00 - 23:30 1.50 DRILL P PROD1 Monitor well - OK. Backream 4 stands from 12,330' to 11,980' to cover new hole. 275 gpm, 1,500 psi. Run in hole dry to 12,246'. Washed down last stand to bottom ~ 12,330'. PU - 220k, SO - 140k. 23:30 - 00:00 0.50 DRILL P PRODi Pump 50 bbls high vis sweep ~ 275 gpm, 1,395 psi, 60 rpm, 8k TO. 'Lost 691 bbls of seawater for tour. 'Lost 1463 bbls of seawater for the day. 10/10/2006 00:00 - 01:00 1.00 DRILL P PROD1 Continue pumping high vis sweep ~ 275 gpm, 1,395 psi, 60 rpm, 8k TO. No increase in cuttings with bottoms up. Circulated until shakers were clean. 8.7 ppg seawater weight. 01:00 - 02:00 1.00 DRILL P PROD1 Monitor well -well static. POH from 13,330' to 11,568' for 8 stands without hole taking proper fluid except by working pipe. No excess drag up or down. PU - 223k, SO - 146k. 02:00 - 05:00 3.00 DRILL P PROD1 Backream from out of hole from 11,568' to 9,377'. PU - 182k, 275 gpm, 1,250 psi, 60 rpm, 5-6k TO. Pull up into shoe without rotating to 9,090'. Monitor well - OK. .5 bph loss rate. 05:00 - 05:30 0.50 DRILL P PROD1 Service topdrive and crown. 05:30 - 06:30 1.00 DRILL P PROD1 Cut and slip drilling line 72'. 06:30 - 09:30 3.00 DRILL P PRODi POH from 9,090' to 5,266'. 09:30 - 10:30 1.00 DRILL P PROD1 POH laying down HWDP from 5,256' to 4,434'. 10:30 - 12:30 2.00 DRILL P PROD1 POH standing back drillpipe from 4,434' to 2,425'. 'Lost 414 bbls SW from midnight to noon. 12:30 - 15:00 2.50 DRILL P PRODi POH laying down 4" drillpipe from 2,425' to BHA ~ 226'. 15:00 - 16:00 1.00 DRILL P PROD1 Laydown BHA #5. Jars, XO, Circ sub, flex collars, MWD, NM STAB, bypass sub, motor and bit. Bit grade: 1-1-CT-G-X-I-NO-TD. 16:00 - 16:30 0.50 DRILL P PRODi Clear and clean rig floor. 16:30 - 19:00 2.50 EVAL P OTHCMP PJSM with Schlumberger WL. Rig up to run USIT. Rig up sheaves and 5.5" lubricator with pack-off. Make up USIT tools. Rigged up to keep hole full by pumping through kill line and taking returns through choke. 19:00 - 00:00 5.00 EVAL P OTHCMP Run in hole with USIT to 7" casing shoe ~ 9,158' and log up to inside of 9 5/8" X 7" annulus. Logs showing cement stringers all the way up in annulus. Top of good cement @ 3,480'. 'Lost rate - 38-40 bph while logging. 'Lost 288 bbls SW for tour. 10/11/2006 00:00 - 00:30 0.50 EVAL P OTHCMP Continue USIT log up to 200' MD. Log showed cement stringers all the way. 00:30 - 02:00 1.50 EVAL P OTHCMP PJSM. Rig down Schlumberger WL. Rig down sheaves and 5.5" lubricator. Laydown logging tools. 02:00 - 04:00 2.00 CASE P RUNPRD Rig up to run 4.5" liner. 04:00 - 05:00 1.00 CASE P RUNPRD PJSM. Pick up, Baker-Lok, and make up 4.5" 12.6# L-80 IBT-M shoe track. 05:00 - 05:30 0.50 CASE P RUNPRD Clear snow and ice out of derrick. 05:30 - 15:00 9.50 CASE P RUNPRD Finish making up shoe track. Check floats - OK. Run in hole with 4.5" liner with ECP, HES cementer . Ran total of 78 jts to Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 15 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task i Code NPT Phase ~ Description of Operations 10/11/2006 05:30 - 15:00 9.50 CASE P RUNPRD 3,286'. Make up torque - 3,400 ft/Ibs, lubricated with Best-O-Life 2000NM pipe dope. Baker-Lok'd shoe track and each side of HES cementer. Fill every joint and circulate over top of the hole while running in hole. 20 bph average loss rate. 15:00 - 16:00 1.00 CASE P RUNPRD Make up BOT "HRD" ZXP liner top packer. Mix polymer for tool, allow to set for 30 minutes. Rig down liner running equipment and circulate 1 pipe volume while polymer was setting up. 4 bpm, 130 psi, PU - 70k, SO - 70k. 16:00 - 20:00 4.00 CASE P RUNPRD Run in hole with 4.5" liner on 4" drillpipe from 3,329' to 9,163' ~ 90 fpm, filling pipe and circulating down every 10 stands. Fill pipe C~3 7" shoe. Check circulating rates ~ 30 spm - 90 psi and 50 spm - 165 psi. PU - 165k, SO - 145k. Loss rate slowed to 10 bph. 20:00 - 21:30 1.50 CASE P RUNPRD Continue running in open hole from 9,163' to 10,340' C~ 90 fpm, filling pipe and circulating down every 10 stands. Set down ~ 10,340'. Attempt to work down without success. Screw topdrive into drillpipe and work string down circulating past tight spot after staging up to 55 spm, 123 gpm, 250 psi. Pressure would increase while working up and down through tight spot then cleaned up. Continued washing down from 10,340' to 10,425'. 21:30 - 00:00 2.50 CASE N DPRB RUNPRD Set down ~ 10,425' with pressure increase. Stage pumps from 3 bpm, 350 psi to 5 bpm, 550 psi watching pump pressure up to 750 psi when setting down ~ 10,425'. Pressure would return to normal after pick up weight broke over. Attempt to work through with and without pumps without success. Pumped and spotted a 25 bbl 2.5 ppb FlowVis pill around 4.5" shoe. Shut down pumps and attempt to work through tight spot with no changes in parameters. PU - 200k, SO - 145k. Loss rate increased to 38 bph. Total loss for day - 632 bbls. 10/12/2006 00:00 - 01:00 1.00 CASE N DPRB RUNPRD Observe well - 5 bph static. Pump dry job and POH with 4.5" liner standing back drillpipe from 10,425' to 9,072'. Off bottom PU - 195k, SO - 146k, MW - 8.6 ppg. 01:00 - 02:00 1.00 CASE N DPRB RUNPRD Break down and lay down liner cementing head and pup joint. 02:00 - 04:00 2.00 CASE N DPRB RUNPRD Continue POH from 9,072' to 3,335'. Losses slowing down to less than 1 bph. 04:00 - 05:00 1.00 CASE N DPRB RUNPRD PJSM. Laydown drillpipe pup and XO. Rig up liner equipment. Laydown BOT liner top packer. 05:00 - 05:30 0.50 CASE N DPRB RUNPRD Prepare rig floor to laydown 4.5" liner. 05:30 - 13:30 8.00 CASE N DPRB RUNPRD Laydown 4.5" liner from 3,286' to surface. Stood back cementer & 2 joints in derrick. Nose on shoe was broken off and missing. 30 bbls total loss from midnight to noon. 13:30 - 14:30 1.00 CASE N DPRB RUNPRD Heat joint #1 with torch and back out float collar joint out. Remaining float equipment can be re-run. Laydown shoe joint, stand back joints with FC and LC. 14:30 - 15:00 0.50 CASE N DPRB RUNPRD Rig down liner running equipment. 15:00 - 15:30 0.50 CLEAN N DPRB CLEAN PJSM. Bring BHA tools to rig floor. Strap and caliper same. *No losses while out of the hole. 15:30 - 18:30 3.00 CLEAN N DPRB CLEAN Pick up and make up dumb iron, BHA #6: Used 6 1/8" HTC MX-18HDX, NB STAB, 4 3/4" slick DC, String STAB, 2 ea 4 3/4" slick DC's, XO, 3 ea 4" HWDP, Jars. 18:30 - 23:00 4.50 CLEAN N DPRB CLEAN Run in hole with cleanout assembly, picking up 4" drillpipe and 4" HWDP out of pipeshed from 226' to 5,079'. Printed: 11/6/2006 8:05:77 AM BP EXPLORATION Page 16 of 24 Operations. Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 1 - 10/12/2006 -- 23:00 - 00:00 1.00 CLEAN - N DPRB CLEAN Continue running in hole with drillpipe out of derrick from 5,079' to 6,013'. Fill pipe. Lost 17 bbls running in hole from 15:30 hr. *Total lost for day - 47 bbls. 10/13/2006 00:00 - 01:30 1.50 CLEAN N DPRB CLEAN Continue running in hole with cleanout assembly from 6,013' to 9,130' with drillpipe out of derrick. 01:30 - 02:00 0.50 CLEAN N DPRB CLEAN Fill pipe and obtain parameters and slow pump rates. PU - 178k, SO - 160k, RTW - 171 k,. 200 gpm, 340 psi, 50 rpm, 3-4k TO 250 gpm, 500 psi, 75 rpm, 2.6k TO 280 gpm, 620 psi, 120 rpm, 2.7k TO 300 gpm, 695 psi *No mud losses. 02:00 - 03:00 1.00 CLEAN N DPRB CLEAN Run in hole from 9,130' to 10,245'. No mud losses. 03:00 - 05:00 2.00 CLEAN N DPRB CLEAN Set down ~ 10,245', 25k under slack-off weight. Pick up above with 25k overpull. Start reaming from 10,225' to 10,977' C~3 300 gpm, 800 psi, 120 rpm, 4.5 - 6.8k TQ. Ream out tight spots ~ 10,240', 10,425', 10,528, 10,700', 10,735'. No mud losses prior to 10,425'. Bridge ~ 10,425' was hardest, but took about a minute to clean up. Loss rate immediately increased to 100- 290 bph after reaming out ra? 10,425'. Also had gas on bottoms up after reaming and 50% increase of sand ~ 10,425'. Reamed and backreamed through all tight spots then ran in dry to check - ok. When tight spots were encountered running in dry, would take 25k overpull to free up. Mud loss rate ~ 100 bph average while reaming. 05:00 - 12:00 7.00 CLEAN N DPRB CLEAN Start reaming every stand from 10,735' to 11,544'. PU - 215k, SO - 145k. 300 gpm 830 psi, 120 rpm, 7.6k TO. Had pressure spike to 950 psi going through fracture zone f~ 11,140'. Torque increased to 10-12k. Pumped tea 25 bbl viscosified seawater sweeps and one 25 bbl mud sweep @ 11,181'. Start viscosifying seawater system. Torque was reduced to 8.5 - 9.5k. Mud loss rate ~ 95 bph average while reaming. Lost 645 bbls from 03:30 to noon. 12:00 - 15:00 3.00 CLEAN N DPRB CLEAN Continue reaming from 11,544' to TD ~ 12,330'. 300 gpm, 1,000 psi, 120 rpm, 7.4k TO. Reamed hard from 11,975' to 12,020'. Pumped 25 bbls high vis sweep ~ 12,000' that returned 50% increase of sand to surface. 15:00 - 17:00 2.00 CLEAN N DPRB CLEAN Circulate and condition viscosified seawater. PU - 195k, SO - 140k, RTW - 165k with pumps. PU - 200k, SO - 182k without pumps. 295 gpm, 975 psi, 120 rpm, 7.5k TO. Mud loss rate 100 bph average while circulating. 17:00 - 19:00 2.00 CLEAN N DPRB CLEAN Pump 30 bbl 5 ppb Magma Fiber sweep ~ 285 gpm, 935 psi, 125 rpm, 8-9k TO. Loss rate briefly slowed to 60 bph with sweep in open hole then went to 90 bph average when sweep was out of open hole. Returned majority of sweep back to surface with no extra sand imbedded in sweep. 19:00 - 20:30 1.50 CLEAN N DPRB CLEAN Pump 2nd 30 bbl, 8 ppb Magma Fiber, 9 SX MIX II MED, 9 SX MI SEAL MED, 32 ppb total sweep ~ 285 gpm 900 psi, 125 rpm, 8-9k TO. Sweep had no results in loss rate during whole circulation. Returned most of sweep back to surface. 20:30 - 22:00 1.50 CLEAN N DPRB CLEAN Displace well from 8.7 ppg viscosified seawater to 8.8 ppg FlowPro SF mud with 2% tube properties. Mud returned to Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 1 ~ of 24 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: L ell Name: L e: Name: From - To -04 -04 DRILL+C NABOR NABOR Hours OMPLE S ALASK S 9ES Task TE A DRI Code LING NPT Start I Rig Rig Phase ' Spud Date: 9/20/2006 : 9/17/2006 End: Release: 10/26/2006 Number: Description of Operations 10/13/2006 20:30 - 22:00 1.50 CLEAN N DPRB CLEAN surface 70 bbls past calculated strokes. Torque was reduced from 8-9k to 6.5k. Lost 70 bbls. 22:00 - 22:30 0.50 CLEAN N DPRB CLEAN Monitor well for 15 minutes while cleaning out from under shakers. No static losses!!. Get new slow pump rates and dynamic loss rate ~ 100+ bph. 22:30 - 00:00 1.50 CLEAN N DPRB CLEAN Pump out of the hole from 12,330' to 11,489' without problem and minimal losses ~ 42 gpm, 190 psi. Lost 715 bbls total from noon to midnight. PU - 185k, SO - 152k. 10/14/2006 00:00 - 02:30 2.50 CLEAN N DPRB CLEAN Continue pumping out to shoe from 11,489' to 9,098' without problem ~ 1 bpm, 105 psi. Lost total of 21 bbls while pumping out of hole. 02:30 - 03:30 1.00 CLEAN N DPRB CLEAN Monitor well -Well static. PJSM. Cut and slip drilling line. 03:30 - 04:00 0.50 CLEAN N DPRB CLEAN Service topdrive, crown, blocks, and drawworks. Check well before going in hole -Lost 4 bbls in 1 1/2 hrs. 04:00 - 06:00 2.00 CLEAN N DPRB CLEAN Run in hole without pumping from 9,098' to 12,330'. Worked through several times @ 10,425' and 12,000'. No overpull when pulling back up off of tight spots. No down drag after working tight spots. Rest of trip was smooth. Washed last stand down. First 5 stands pushed mud away. Rest of trip lost pipe displacement. Lost total of 38 bbls. 06:00 - 07:30 1.50 CLEAN N DPRB CLEAN Circulate 30 bbl, 5 ppb Magma Fiber sweep ~ 286 gpm, 1,100 psi, 120 rpm, 4k TO. PU - 190k, SO - 155k, RTW - 160k. Lost 186 bbls while circulating. Had small amount of gas and no increase in cuttings back to surface on bottoms up. Dynamic loss rate - 88 bph average. 07:30 - 12:00 4.50 CLEAN N DPRB CLEAN Pump out to shoe from 12,330' to 9,086' without problem ~ 1 bpm, 100 psi. PU - 190k, SO - 155k. At shoe - PU - 175k, SO - 165k without pump. Monitor well -static. Lost 22 bbls while pumping out to shoe. Lost 260 bbls from midnight to noon. 12:00 - 15:00 3.00 CLEAN N DPRB CLEAN Pump dry job and POH from 9,086' to 4,987'. Loss rate ~ 24 bph. 15:00 - 16:00 1.00 CLEAN N DPRB CLEAN Laydown HWDP from 4,987' to 4,435'. 16:00 - 17:30 1.50 CLEAN N DPRB CLEAN Continue POH from 4,435' to BHA ~ 226' 17:30 - 19:00 1.50 CLEAN N DPRB CLEAN Laydown bit, collars, HWDP and Jars. 19:00 - 19:30 0.50 CLEAN N DPRB CLEAN Clear and clean rig floor. 19:30 - 20:30 1.00 CASE N DPRB RUNPRD Rig up to re-run 4.5" liner. Static loss rate ~ 6 bph. 20:30 - 00:00 3.50 CASE N DPRB RUNPRD PJSM. Pick up new "Silver Bullet" float shoe and shoe jt. Make up and BakerLok shoe joint to remainder of float track. Check floats - OK. Continue running in hole with 4.5" 12.6# L-80 IBT-M production liner to 1,422'. Make-up TO - 3,000 ft/Ibs, lubricated with Best-O-Life NM2000. Fill every joint while running in hole. 'Lost total of 187 bbls from noon to midnight. 447 bbls total for the day. 10/15/2006 00:00 - 02:30 2.50 CASE N DPRB RUNPRD Continue running in hole with 4.5" 12.6# L-80 IBT-M production liner from 1,422' to 3,285'. Ran total of 78 joints. 02:30 - 03:00 0.50 CASE N DPRB RUNPRD Pick up Baker ZXP liner top packer. Let polymer barrier set up 03:00 - 03:30 0.50 CASE N DPRB RUNPRD Rig down liner running equipment. 03:30 - 04:00 0.50 CASE N DPRB RUNPRD RIH 1 stand of drillpipe and circulate liner volume ~ 184 gpm, 300 psi, PU - 70k, SO - 70k. 96 bph loss rate while circulating. 04:00 - 08:30 4.50 CASE N DPRB RUNPRD Run in hole with 4.5" liner on drillpipe from 3,430' to 9,072' ~ 60-90 fpm, filling pipe and breaking circulation every 10 stands. Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 18 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: i Date From - To ~ Hours Task Code NPT Phase Description of Operations 10/15/2006 04:00 - 08:30 4.50 CASE N DPRB RUNPRD 08:30 - 09:00 0.50 CASE N DPRB RUNPRD Make up cementing head and secure on pipe skate. Filled pipe and check parameters ~ 9,072'. 73 gpm, 330 psi, 125 gpm 420 psi, PU - 160k, SO - 145k. 09:00 - 10:00 1.00 CASE N DPRB RUNPRD Run into open hole from 9,072' to first liner run trouble depth 10,425' without problem. 10:00 - 11:30 1.50 CASE P RUNPRD Continue running liner from 10,425' to TD ~ 12,330' without problem. One bobble ~ 12,000'. PU - 187k, SO - 150k. 11:30 - 12:00 0.50 CEMT P RUNPRD Make up liner cementing head joint to string. Rig up circulating lines. "Lost 324 bbls from midnight to noon. 12:00 - 14:30 2.50 CEMT P RUNPRD Stage pumps up to 203 gpm, 906 psi, PU - 180k, SO - 150k. Dynamic loss rate - 98+ bph. Hold PJSM on cement job while circulating. 14:30 - 15:30 1.00 CEMT P RUNPRD Change over to Dowell. Pump 5 bbls CW-100. Pressure test lines to 4,000 psi - OK. Pump 30 bbls 13.0 ppg MudPush II, followed by 32 bbls 15.8 ppg Class "G" tail cement. Wash up lines to rig floor. Drop bottom plug. Had circulation while pumping slurries. 15:30 - 17:00 1.50 CEMT P RUNPRD Switch over to rig pumps and displace cement ~ 242 gpm, 220 psi until mud caught up with cement, then slow displacement to 206 gpm, 780 psi, then to 73 gpm, 260 psi prior to plug latch-up. Latch plug ~ calculated strokes with 1,500 psi with no shear out. Bleed off and repressure up to 1,500 psi two more times without shearing liner plug. Attempt same @ 1,800 psi and bleed pressure back down. Stage pressure up and stopping ~ 2,000 psi, 2,100 psi, 2,500 psi, 3,000 psi, and 4,000 psi. Bleed off pressure. Pressure up to 3,900 psi when plug shear out was observed. Pressure bled off to 93 psi. Resume pumping (still had returns) ~ 190 gpm 1,030 psi. Slow pump rate to 58 gpm 450 psi prior to plug going through ES Cementer. Observed 100 psi spike when going through cementer. Continue pumping @ 58 gpm, 460 psi for remainder of displacement. Plug bumped with total of 139 bbls of mud ~ calculated strokes. Had returns throughout cement operation. Bumped plug with 900 psi. Hold pressure 5 minutes. Set down 60k and pressure up to 1,500 psi to set liner hanger. Switch over to Dowell and stair step pressure up to 2,000 psi and hold to inflate ECP. Bleed pressure down to 1,500 psi. 17:00 - 18:00 1.00 CEMT N DFAL RUNPRD Pressure up to 3,600 psi to attempt shearing out the cementer without success. Bleed pressure to 0 psi. Pull up to 140k. Pressure up and bleed off @ pressures of 4,000 psi, slack back down to 90k. Pressured up twice each ~ 4,200 and 4,400 psi. Bring pressure up to 4,600 psi and sheared cementer. Dowell pumped 3.5 bpm 2,300 psi with no returns. Switched to rig and pumped ~ 4 bpm 2,000 psi with no returns for total of 4.6 bbls. 18:00 - 19:00 1.00 CEMT N DFAL RUNPRD Re-group and trouble shoot. Pressure up annulus to check pumpability past liner top packer. Pumped 2.6 bbls ~ 1 bpm, pressuring up to 2,700 psi with same pressure/stroke ratio while pressuring up. Pressure rock solid. Bleed off pressure. 19:00 - 19:30 0.50 CEMT P RUNPRD Release from hanger and CBU ~ 300 gpm, 1,000 psi. No Printed: 17/6/2006 8:05:11 AM ~ ~ BP EXPLORATION Page 19 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To ~ Hours Task Code NPT Phase ~ Description of Operations 10/15/2006 19:00 - 19:30 0.50 CEMT P RUNPRD cement or sand to surface. Lost appx 5 bbls while circulating. 19:30 - 20:30 1.00 CEMT P RUNPRD Laydown liner cementing head and rig down lines. 20:30 - 00:00 3.50 CEMT P RUNPRD Pump dry job and POH from 9,007' to 2,965' losing 1 bbl over displacement per 5 stands. 10/16/2006 00:00 - 02:00 2.00 CEMT P RUNPRD Continue POH with liner running tool from 2,965' to surface. Dogs were out and confirmed liner top packer setting. Second plug was still attached to running tool. Lost 42 bbls total on trip out of hole. 02:00 - 03:00 1.00 CEMT P RUNPRD Service break running tool. Clear and clean rig floor. 03:00 - 03:30 0.50 CEMT N DFAL RUNPRD Prepare and rig up to pickup 2 7/8" PAC. 03:30 - 05:30 2.00 CEMT N DFAL RUNPRD Rig service. Lubricate rig, topdrive. Inspect brakes, change out topdrive quill. 05:30 - 06:30 1.00 CEMT N DFAL RUNPRD Run in hole with excess drillpipe out of derrick while waiting on pert guns for squeeze job. 06:30 - 09:00 2.50 CEMT N DFAL RUNPRD Laydown drillpipe back to surface. 30 bbls loss on trip in and out. 09:00 - 10:30 1.50 CEMT N DFAL RUNPRD Pick up pert guns and tools to rig floor. Prepare 2 7/8" PAC. 4-16 bph static loss. 10:30 - 12:00 1.50 CEMT N DFAL RUNPRD Laydown pert guns and tools. 'Lost 134 bbls from midnight to noon. 12:00 - 14:30 2.50 CEMT N DFAL RUNPRD Wait on Schlumberger E-line for 4.5" USIT w/ tractor. 14:30 - 15:00 0.50 CEMT N DFAL RUNPRD PJSM. Pick up WL running tools. 15:00 - 17:00 2.00 CEMT N DFAL RUNPRD Pick up and make up USIT tools with SCMT tractor. 17:00 - 19:00 2.00 CEMT N DFAL RUNPRD Run in hole to and start logging from 9,150' to 9,510' without tractor. 19:00 - 21:00 2.00 CEMT N DFAL RUNPRD Used tractor to USIT log from 9,510' to 10,910'. Log back up from 10,910' to 9,150'. Log indicated that no cement was in annulus and lap. POH to surface. 21:00 - 21:30 0.50 CEMT N DFAL RUNPRD Laydown USIT tools and rig down Schlumberger E-line 21:30 - 22:30 1.00 CEMT N DFAL RUNPRD Rig up to run 2 7/8" PAC. 22:30 - 00:00 1.50 CEMT N DFAL RUNPRD Pick up and make up 3.813" MM mill, bit sub, float sub, circ sub, bumper jar, oil jar. Assemby to be used for closing ES Cementer and drilling out same. "Lost 40 bbls from noon to midnight. Lost 174 bbls total for the day. 10/17/2006 00:00 - 05:00 5.00 CEMT N DFAL RUNPRD Run in hole picking up single joints of 2 7/8" PAC to f ,972'. 05:00 - 11:30 6.50 CEMT N DFAL RUNPRD Continue running in hole with mill assy on drill pipe to 8956, fill pipe every 2000' 11:30 - 12:00 0.50 CEMT N DFAL RUNPRD Clear air f/ pipe, get parameters in csg w/ pumps, up wt 155k, do wt 144k, rot wt 150k, w/o pumps, up wt 150k, do wt 140k GPM PSI RPM TO 42 280 20 1.2 - 1.7 84 435 30 1.2 - 1.9 200 1180 40 1.2 - 1.9 Tour Losses 84 bbls 12:00 - 13:00 1.00 CEMT N DFAL RUNPRD RIH w/mill assy to 10935' 13:00 - 15:00 2.00 CEMT N DFAL RUNPRD Displace well to 8.5 ppg seawater at 200 gp, 81 spm, 2200 psi, 70 rpm, 1.7k tq, parameters w/ pumps, up wt 170k, do wt 157k, rt wt 165k, w/o pumps, up wt 176k, do wt 160k GPM PSI RPM TO Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 20 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date I From - To I Hours I Task ! Code I NPT I Phase 10/17/2006 113:00 - 15:00 I 2.001 CEMT I N 15:00 - 15:30 0.50 CEMT N 15:30 - 17:30 2.00 CEMT N DFAL RUNPRD 42 84 200 Description of Operations 115 20 1.3 - 1.8 440 30 1.4 - 1.7 2137 40 1.5 - 1.6 50 1.6 - 1.8 70 1.6 - 1.9 DFAL RUNPRD Monitor well, fill lines for infectivity test DFAL RUNPRD Est Inj Rates SPM GPM PSI 17 42 613 34 83 1205 51 125 1998 Pumped total of 483 stks, 32.5 bbls, observed leak off, bleed back 2 bbls 17:30 - 20:30 3.00 CEMT N DFAL RUNPRD POH to 8986' slowly, up wt 178k, do wt 161 k, MW 8.5 ppg 20:30 - 21:00 0.50 CEMT N DFAL RUNPRD Monitor well at liner top, avg loss rate at 7.5bph, pump dry job 21:00 - 23:30 2.50 CEMT N DFAL RUNPRD POH to BHA at 1976' 23:30 - 00:00 0.50 CEMT N DFAL RUNPRD Monitor well at BHA, hole stable, RU 2 7/8" handling tools 10/18/2006 100:00 - 02:00 I 2.00 I CEMT I N 02:00 - 03:00 I 1.001 PERFOBI N 03:00 - 04:30 I 1.501 PERFOBI N 04:30 - 06:00 I 1.501 PERFOBI N 06:00 - 08:00 2.00 08:00 - 16:30 8.50 16:30 - 17:00 0.50 17:00 - 19:00 2.00 19:00 - 21:00 2.00 21:00 - 21:30 0.50 21:30 - 22:30 I 1.00 22:30 - 23:30 I 1.00 Losses for tour 85bbls Losses for day 169bb1s Losses to well 7629 bbls DFAL RUNPRD POH w/ BHA, Std Bk 2 7/8' PAC, LD mill, BS, FS, CS, BS, Jar, X-O, RD Handling Tools DFAL OTHCMP PJSM w/SLB and rig crew on RU and Perforating, Install 5 1/2" lubricator in VBR's, MU, RIH w/ 5' of 3 3/8" big hole pert gun, 12 spf and CCL DFAL OTHCMP RIH, run strip log f/ 8950' to 9228', confirmed TOL at 9007', ran repeat log positon bottom shot at 9107', top shot at 9102' in middle of joint, fired pert gun had good surface indication of gun firing DFAL OTHCMP POH with pert gun, Static loss rate at 7.5bph, RD SLD, blow down circ lines and choke DFAL RUNPRD MU EZSV for 4 1/2" 12.6" liner, RIH w/ 2 7/8" PAC DP DFAL RUNPRD RIH w/ 4' DP to 10823', pu wt 175k, do wt 160k, RIH position and set EZSV in 4 1/2" liner at 10908', unsling f/ EZSV , brk circ at 2bpm, 306psi, increased rate to 5bpm, 1675psi, stung into EZSV w/ 15k set do wt, staged up pumps f/ 1 to 3bpm at 350, 1450, and 2525 psi, respectively, continue pumping at 3 bpm, pressure decreased to 1320psi, initial loss rate at 46bpm, final loss rate 36bpm, RU cmt line w/ pump in sub DFAL RUNPRD Service top drive and crown, static loss at 12bph DFAL RUNPRD Circ at 27spm, 354psi, while waiting on cement lab results DFAL RUNPRD Increase rate to 3bpm, 1228psi, spot and RU SLB cementers DFAL RUNPRD PJSM w/ all involved personnel on cement job procedures, safety hazards, conditions and precautions DFAL RUNPRD Batch mix cement and spacer while continuing to circ, losses at 20bph DFAL RUNPRD Pumped cement job, 5bbls of FW, Test lines, 30 bbls 12.5ppg mud push, 53.7bbls of 15.8ppg slurry w/ latex/gasbloc plus 1.5ppb cem net Icm, lose rate at 7-10bph Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 21 ~f 24 Operations Summary Report Legal Well Name: L-04 Common W ell Name: L-04 Spud Date: 9/20/2006 Event Nam e: DRILL+C OMPLE TE Start : 9/17/2006 End: Contractor Name: NABOB S ALASK A DRI LLING 1 Rig Release: 10/26/2006 Rig Name: NABOB S 9ES Rig Number: ~ Date i From - To Hours Task Code I NPT Phase Description of Operations 10/18/2006 23:30 - 00:00 0.50 REMCM N DFAL RUNPRD Switched to rig pumps, displaced cement at 3bpm w/ 8.5 ppg seawater, at 58bbls pumped, caught cmt, pressure increase f/ 31 - 450psi, at 88bbls, pressure increase to 1500psi, shut down pumps w/ 10 bbls remaining in workstring 10/19/2006 00:00 - 01:30 1.50 REMCM N DFAL RUNPRD Pump next 8 bbls of seawater in 2 bbl increments at 1bpm, monitoring well 10, 15, 20 and 30 minutes between pump cycles w/ 420, 339, 311 and 300 psi on final hesitation, CIP at 01:19 hours, had no returns during hesitation rates, well was taking 30 bph while circ and 20 bph w/ monitoring well 01:30 - 03:30 2.00 REMCM N DFAL RUNPRD Unstung f/ EZSV 90 psi on DP, well u-tbg, circ remaining 2 bbls of cement f/ DP, RD circ lines, POH to 8941' above 4 1/2" liner, loses at 8bbls/ 5stds over displace 03:30 - 05:30 2.00 REMCM N DFAL RUNPRD Circ hole clean at 4bpm, 900psi, loss rate at 6 bph, increased rate to 6 bpm, 1925 psi, loss rate at 12 bph, no cmt returns 05:30 - 09:30 4.00 REMCM N DFAL RUNPRD POH to BHA, Loss rate at 6 bph, found cmt on last std of 4" 09:30 - 11:30 2.00 REMCM N DFAL RUNPRD C/O handling, R/U tongs for 2 7/8" PAC, POH, std bk 2 7/8" PAC, found cmt on 2 7/8" tool joints, LD mill assy, clean rig floor 11:30 - 12:00 0.50 REMCM N DFAL RUNPRD Flush and cleanout stack 12:00 - 12:30 0.50 BOPSU N DFAL RUNPRD RU test equipment for BOP's 12:30 - 17:00 4.50 BOPSU N DFAL RUNPRD Test BOP's, all rams, lines and valves f/ 250 psi to 4000 psi and annular f/250 psi to 3500 psi w/ 2 7/8", 4" and 4 1/2" test joints, test were held for 5 minutes each, AOGCC Jeff Jones waived witnessing test, test witnessed by BP rep Brain Buzby, Tool Pusher Bill Bixby, Pump Operator/Driller Sean Holcomb 17:00 - 17:30 0.50 BOPSU N DFAL RUNPRD RD test equip, blow down lines 17:30 - 18:00 0.50 CASE N DFAL RUNPRD RU handling equipment for cleanout assy 18:00 - 21:30 3.50 CASE N DFAL RUNPRD MU cleanout Assy w/ 3.81 mill, 3 1/8" motor, FS, CS, 2 Jnk Bskts, BS, Jar, X-O, 21 stds of 2 7/8" DP, filled pipe 21:30 - 00:00 2.50 CASE N DFAL RUNPRD PU 42 jts of 2 7/8" PAC DP 10/20/2006 00:00 - 00:30 0.50 REMCM N DFAL RUNPRD Circ DP volume 00:30 - 05:00 4.50 REMCM N DFAL RUNPRD RIH w/ 4" DP, fill pipe every 2000', loss rate at 4bph, 150 up wt, 140 do wt, pump thru liner top w/ 23spm, 457 psi, parameters in 4 1/2" liner - up wt 152k, do wt 142k 05:00 - 06:00 1.00 REMCM N DFAL RUNPRD Brk Circ, est inj rates at 1 bpm, 404psi, 2bpm, 864psi, 3bpm, 1400psi, pump 8.8ppg Flo-Pro sweep 06:00 - 08:00 2.00 REMCM N DFAL RUNPRD RIH to EZSV at 10908', 450spm, 1270 psi, up wt 168k, do wt 152k, rt wt 156k 08:00 - 13:30 5.50 REMCM N DFAL RUNPRD Drilled EZSV at 10908' w/ 45spm, 110gpm, 1500psi, 40 rpm, tq 1.9k ft-Ibs, washed do to 10939', pushed plug to es cementer at 10949' 13:30 - 18:00 4.50 REMCM N DFAL RUNPRD Drill ES cmtr f/ 10949' to 10952' w/ 42spm, 105gpm, 1050psi, 40rpm, 1.9k tq, 0-1 k wob, 164k Rt wt 18:00 - 22:00 4.00 REMCM N DFAL RUNPRD Washed dn, tagged up at 12239', no cmt encountered, loss rate at 8bph 22:00 - 00:00 2.00 REMCM N DFAL RUNPRD Circ 50 bbl 8.8 ppg Flo-Pro Hi-Vis sweep at 49 spm, 120 gpm, 1370psi, 40rpm 10/21/2006 00:00 - 01:00 1.00 REMCM N DFAL RUNPRD Fin Circ 50 bbl 8.8 ppg Flo-Pro Hi-Vis sweep around at 49 spm, 120 gpm, 1370psi, 40rpm, dumped sweep, little to no junk in returns 01:00 - 02:30 1.50 REMCM N DFAL RUNPRD Circ, Spot 55 bbls of 8.9ppg pert pill in 4 1/2" liner, Slug pipe 02:00 - 04:00 2.00 REMCM N DFAL RUNPRD POH to 8979', loses at 1.5bbls/ 5stds over displace 04:00 - 06:00 2.00 REMCM N DFAL RUNPRD Drop 3/4" steel ball, open circ sub, circ 50 bbl hi-vis sweep Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 22 of 24 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To I 10/21 /2006 04:00 - 06:00 06:00 - 07:00 07:00 - 10:00 10:00 - 11:30 11:30 - 13:00 13:00 - 13:30 13:30 - 15:00 15:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 20:30 20:30 - 21:00 21:00 - 22:30 22:30 - 00:00 10/22/2006 00:00 - 03:00 03:00 - 03:30 03:30 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 13:00 13:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 19:00 19:00 - 22:00 L-04 L-04 Spud Date: 9/20/2006 DRILL+COMPLETE Start: 9/17/2006 End: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 NABOBS 9ES Rig Number: Hours Task Code NPT ~ Phase j Description of Operations 2.00 REMCM N DFAL RUNPRD around at 102spm, 2420psi, 250gpm, 60rpm, 1.3 tq, 138k rwt 1.00 REMCM N DFAL RUNPRD Slip and cut 92' of drlg line, service TD, Blocks and Crown 3.00 REMCM N DFAL RUNPRD POH to BHA 1.50 REMCM N DFAL RUNPRD RU and LD 15 jts of 2 7/8" PAC DP 1.50 REMCM N DFAL RUNPRD RU and Std Bk 2 7/8" PAC 0.50 REMCM N DFAL RUNPRD LD x-o, jar, bumper sub, 2 junk basket, circ sub, tloat sub, motor and mill, mill in gauge, recovered 4 pieces of iron and 3 pieces of brass out of junk basket f/ EZSV, also recovered heavy thick tar like substance f/junk baskets 1.50 EVAL N DFAL RUNPRD PJSM w/SLB, RU a-line, surface test SCMT tools 2.00 EVAL N DFAL RUNPRD RIH w/ SCMT on a-line, hole sticky f/ 8000' - to 8100', rih to 9000', unable to work past the top of liner, repeat trip f/ 8000' to 9000', had same results 1.00 EVAL N DFAL RUNPRD POH w/ SCMT, tool was covered with a heavy thick tar like substance, bow centrailizers were packed off w/ heavy tar balls not allowing centralizers to close 1.00 EVAL N DFAL RUNPRD Cleaned black tar substance off tools w/ diesel, would not wash off with steam and soap water, LD SCMT, performed surface test w/ 140 deg SW and Surf Safe Surf "O" detergent, results showed tar like substance breaking down and dissolving 1.50 CASE N DFAL RUNPRD PU BHA to rig floor, strap, OD and ID BHA 0.50 CASE N DFAL RUNPRD MU Cleanout BHA w/ 6 1/8" bit and scraper 1.50 CASE N DFAL RUNPRD RIH w/ bit and scraper, MU junk baskets, 1 std - DC's, 15 jts of HWDP, Jar, 5 jts of HWDP 1.50 CASE N DFAL RUNPRD PU, RIH w/ 18 jts of 4" DP, RIH w/ 4" DP f/ derrick to 2758, loss rate at 6bph 3.00 CASE N DFAL RUNPRD RIH, Tag Top of 4 1/2" Liner at 9007' 0.50 CASE N DFAL RUNPRD Circ 140 degree SW w/ 1.5 percent of Safe Surf "O" to 7500' up annulus at 200 spm, 2400 psi, 500gpm, up wt 170k, do wt 150k, no solids across shakers, just discoloration of returns 1.00 CASE N DFAL RUNPRD W iper to 7930', RIH to 9007', top of 4 1/2" liner 0.50 CASE N DFAL RUNPRD Circ BTU's w/ 140 degree SW w/ 1.5 percent of Safe Surf "O" at 200 spm, 2400 psi, 500gpm, 60rpm, up wt 170k, do wt 150k, Moniotr well, no solids across shakers, just discoloration of returns 1.00 CASE N DFAL RUNPRD Wiper to 7930', RIH to 9007', top of 4 1/2" liner 1.00 CASE N DFAL RUNPRD Circ BTU's 2X's w/ 140 degree SW w/ 1.5 percent of Safe Surf "O" and soda ash at 200 spm, 2400 psi, 500gpm, 60rpm, up wt 170k, do wt 150k, Monitor well, no solids across shakers, just discoloration of returns 1.00 CASE N DFAL RUNPRD Wiper to 7930', RIH to 9007', top of 4 1/2" liner 1.00 CASE N DFAL RUNPRD Circ around 50 bbl Hi-vis sweep at 206 spm, 504 gpm, 2350 psi, 60 rpm, 2.6 tq, no solids across shakers, just discoloration of returns 4.00 CASE N DFAL RUNPRD POH to BHA 1.50 CASE N DFAL RUNPRD STD BK HWDP, DC's, LD BS, 2 -junk baskets, scraper and bit, BHA was clean, junk baskets were empty - no junk 0.50 EVAL N DFAL RUNPRD PJSM w/ SLB, RU top sheave, MU tool string, surface test SCMT, ok 1.00 EVAL N DFAL RUNPRD RIH w/ SCMT on tractor, no problems passing thru 4 1/2" liner top, loss rate at 8 bph 3.00 EVAL N DFAL RUNPRD Log Dn f/ 9100' to 12220' 3.00 EVAL N DFAL RUNPRD Log Up f/ 12220' - 9100', sent logs to town engineer, approved Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 23 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To Hours Task Code NPT Spud Date: 9/20/2006 Start: 9/17/2006 End: Rig Release: 10/26/2006 Rig Number: Phase Description of Operations 10/22/2006 19:00 - 22:00 3.00 EVAL N DFAL RUNPRD pert picks 22:00 - 23:00 1.00 EVAL N DFAL RUNPRD POH w/ SCMT, found small amount of black tar between centralizers on tractor along with some metal cuttings f/ EZSV, loss rate at 8bph 23:00 - 00:00 1.00 EVAL N DFAL RUNPRD LD SLB tools, RD a-line 10/23/2006 00:00 - 02:30 2.50 EVAL N DFAL RUNPRD LD excess pipe f/ derrick, 4" DP, HWDP, and DC's 02:30 - 03:00 0.50 PERFO P OTHCMP PJSM on running pert guns with the rig crew. PU perf gun tools to the floor and load the perf guns in the pipe shed. RU the floor to run perf guns. 03:00 - 04:00 1.00 PERFO P OTHCMP PU 13 - 40', 2.5" 4 spf Schlumberger PowerJet Omega perf guns and blanks 572' 04:00 - 06:30 2.50 PERFO P OTHCMP RIH w/ 2-7/8" PAC DP, up wt 58k, do wt 58 k 06:30 - 11:30 5.00 PERFO P OTHCMP RIH w/ 4" DP , taggged at 12239', PU, spotted btm shot at 12237', top shot at 11700', up wt 173k, do wt 151 k 11:30 - 12:00 0.50 PERFO P OTHCMP Attempt to fire guns, pressured up do DP to 2800 psi, drilfstring plugged 12:00 - 14:30 2.50 PERFO N DPRB OTHCMP Discussed plugged pipe with Anchorage office, serviced drawworks 14:30 - 16:00 1.50 PERFO N DPRB OTHCMP Rev circ 1 DP vol, staged pumps up f/ 1 to 3 bpm at 95 to 800psi 16:00 - 16:30 0.50 PERFO N DPRB OTHCMP Circ do DP at 2bpm, 990 psi, after pumping 24 bbls 16:30 - 17:00 0.50 PERFO N DPRB OTHCMP Rev circ 58 bbls, staged pumps up to 3bpm, 445psi 17:00 - 17:30 0.50 PERFO P OTHCMP PJSM w/ SLB and crew on perforating, fired guns with pressure sequence, had good surface indication that guns fired, also fluid dropped a couple feet in bell nipple 17:30 - 18:00 0.50 PERFO P OTHCMP POH wet f/ 12237' to 11646', up wt 175k, monitor well, 6bph loss rate 18:00 - 20:00 2.00 PERFO P OTHCMP Rev circ DP vol at 31spm, 76gpm, 1080psi, Loss rate at 108 bph, monitor well for 15 minutes, OK 20:00 - 21:30 1.50 PERFO P OTHCMP POH wet, LDDP to 10724' 21:30 - 22:00 0.50 PERFO P OTHCMP RIH w/ 6 stds of DP 22:00 - 00:00 2.00 PERFO P OTHCMP POH wet, LDDP to 9500', loss rate at 6bph 10/24/2006 00:00 - 06:30 6.50 PERFO P OTHCMP POH wet, LD 4" DP, loss rate at 10bph 06:30 - 11:00 4.50 PERFO P OTHCMP RU handling tools for 2 7/8" DP, POH, LD 2 7/8' PAC pipe, Firing Head was packed with finely ground brass, chunks of cement and iron, loss rate at 10 bph 11:00 - 15:00 4.00 PERFO P OTHCMP PJSM on Handling and LD perf gun assy, RU handling tools for 2 1/2" perf guns, LD 2 1/2" perf guns and blanks, all shots fired, clear and clean rig floor 15:00 - 16:30 1.50 BUNCO RUNCMP Pulled wear ring, Make dummy run with tbg hgr, C/O bales, RU torque turn, power tongs and handling equipment for 4 1/2" tbg 16:30 - 17:00 0.50 BUNCO RUNCMP PJSM on handling and running tbg 17:00 - 00:00 7.00 BUNCO RUNCMP PU, RIH w/ tbg tail and Baker S-3 packer, baker-lok all connections below packer, continue PU, RIH w/ 4 1/2" completion string, torque turn all 4 1/2" tbg to MU torque of 3850 ft-Ibs, used jet tube seal guard thread dope on box ends, loss rate at 10bph 10/25/2006 00:00 - 11:00 11.00 BUNCO RUNCMP PU 217 jts of 4 1/2" 12.6#, L-80 TC11 tbg, RIH w/ 4 1/2" completion string, Space out & land w/ WLEG ~ 9015'ft. P/U Wt 133k, S/O Wt 114k, torque turn all 4 1/2" tbg to MU torque of 3850 ft-Ibs, used jet tube seal guard thread dope on box ends, loss rate at 8bph, FMC rep RILDS 11:00 - 14:00 3.00 BUNCO RUNCMP PJSM w/ all involved, discussing RU and pumping schedule, Printed: 11/6/2006 8:05:11 AM BP EXPLORATION Page 24 of 24 Operations Summary Report Legal Well Name: L-04 Common Well Name: L-04 Spud Date: 9/20/2006 Event Name: DRILL+COMPLETE Start: 9/17/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/26/2006 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours Task ~ Code ~ NPT ~ Phase Description of Operations 10/25/2006 11:00 - 14:00 3.00 BUNCO RUNCMP RU Hot Oil pump unit, test lines, Reverse circ 130bb1s of clean 8.9 ppg brine w/corrision inhibitor in annulus, followed by 34bbls of diesel freeze protect at 3bpm ICP - 100 psi, FCP 500psi 14:00 - 15:30 1.50 BUNCO RUNCMP Drop 1 7/8" ball & rod, allow to fall on seat in 'X' nipple ~ 8,972', Set Baker 'S 3' pkr w/ 1200 psi. Increase pressure to 4200 psi hold for 30 min tbg test. Bleed down tbg to 1500 psi. Pressure test csg to 4000 psi for 30 mins. Bleed off annulus and tbg pressure to 0 psi 15:30 - 16:00 0.50 WHSUR P RUNCMP Dry rod TWC. Test to 1000 psi f/ above. O-K. 16:00 - 19:00 3.00 BOPSU P RUNCMP Blow down all surface lines to stack, ND BOPE. 19:00 - 23:00 4.00 WHSUR P RUNCMP Move adapter and tree into cellar, NU adapter flange, reposition electric motor on actuator valve to face down, NU tree. Test to 5000 psi 23:00 - 00:00 1.00 WHSUR P RUNCMP PJSM, RU DSM, pull TWC, RD DSM 10/26/2006 00:00 - 01:30 1.50 BUNCO RUNCMP PJSM w/ slickline crew on RU and operational procedures,. PU slickline equipment to rig floor, RU lubricator, BOP's, pump-in-sub and tool string, test to 1000 psi 01:30 - 03:30 2.00 BUNCO RUNCMP RIH w/ 2" JDC pulling tool, tagged up at 8970', set down twice, POH, recovered ball and rod, LD tool string 03:30 - 04:00 0.50 BUNCO RUNCMP RD slickline, LD equipment from rig floor 04:00 - 04:30 0.50 BUNCO RUNCMP RD long bails, LD f/ rig floor 04:30 - 05:00 0.50 BUNCO RUNCMP RU surface line to tree, test, bullhead 30 bbls of diesel down tbg at 2bpm 1200psi, RD pump truck 05:00 - 07:00 2.00 WHSUR P WHDTRE RU DSM lubricator, Set TWC, Test to 1000 psi, RD DSM. Remove secondary annulus valves, secure well and cellar. RDMO. Release Rig ~ 07:00 hrs 10/26/2006 Printed: 17/6/2006 8:05:11 AM r~ _ _ _ _ _ Schlumberger ~,,,;, , ~~- ~-u4 survey Kepvri - Report Date: October 12, 2006 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 88.180° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: L-PAD / S-L TVD Reference Datum: Rotary Table Well: L-04 TVD Reference Elevation: 76.50 ft relative to MSL Borehole: L-04 Sea Bed /Ground Level Elevation: 48.00 ft relative to MSL UWI/API#: 500292331900 Magnetic Declination: 23.922° Survey Name /Date: L-04 /September 26, 2006 Total Field Strength: 57624.238 nT Tort /AHD / DDI / ERD ratio: 297.541 ° / 5047.97 ft / 6.312 / 0.559 Magnetic Dip: 80.886° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 26, 2006 Location LaULong: N 70.35014174, W 149.32449105 Magnetic Declination Model: BGGM 2006 Location Grid NIE Y/X: N 5978101.530 ttUS, E 583202.660 ftUS North Reference: True North Grid Convergence Angle: +0.63617416° Total Corr Mag North -> True North: +23.922° Grid Scale Factor: 0.99990786 Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft tt ft ft tt de 100 ft ftUS itUS ~n n nn n nn n nn n nn n nn n nn n n0 5978101.53 583202.66 N 70.35014174 W 149.32449105 Nlt GYD CT DMS U.UV 100 00 V.VV 0 32 v.vv 76 08 -i v.ov 23 50 v.vv 100.00 ....... 0.27 ~•~~ 0.28 -•~•- 0.28 -•-- 0.07 ---- 0.27 --- 0.32 5978101.60 583202.93 N 70.35014192 W 149.32448884 . 200.00 . 0.36 . 109.04 . 123.50 200.00 0.84 0.86 0.84 0.03 0.84 0.20 5978101.57 583203.50 N 70.35014183 W 149.32448423 300.00 0.25 81.82 223.50 300.00 1.35 1.38 1.35 -0.04 1.35 0.18 5978101.51 583204.01 N 70.35014163 W 149.32448007 400.00 0.15 301.65 323.50 400.00 1.46 1.60 1.46 0.06 1.46 0.38 5978101.61 583204.12 N 70.35014190 W 149.32447922 500.00 0.40 287.79 423.49 499.99 1.02 2.08 1.04 0.24 1.01 0.26 5978101.78 583203.67 N 70.35014238 W 149.32448282 600.00 0.60 277.95 523.49 599.99 0.17 2.95 0.45 0.41 0.16 0.22 5978101.95 583202.82 N 70.35014287 W 149.32448973 700.00 0.79 287.46 623.48 699.98 -0.99 4.16 1.23 0.69 -1.01 0.22 5978102.21 583201.64 N 70.35014363 W 149.32449928 800.00 0.68 289.05 723.48 799.98 -2.20 5.44 2.49 1.09 -2.23 0.11 5978102.60 583200.42 N 70.35014473 W 149.32450917 900.00 0.93 286.90 823.47 899.97 -3.52 6.85 3.88 1.52 -3.57 0.25 5978103.01 583199.07 N 70.35014590 W 149.32452003 1000.00 0.81 295.18 923.45 999.95 •4.92 8.36 5.40 2.06 -4.99 0.17 5978103.53 583197.65 N 70.35014737 W 149.32453152 Last GYD CT DMS 1100.00 0.69 293.30 1023.45 1099.95 -6.09 9.67 6.70 2.60 -6.18 0.12 5978104.06 583196.45 N 70.35014884 W 149.32454121 First MWD+IFR+MS 1136.05 0.92 289.76 1059.49 1135.99 -6.56 10.18 7.21 2.78 -6.65 0.65 5978104.24 583195.98 N 70.35014934 W 149.32 4 1232.36 0.87 289.62 1155.79 1232.29 -7.96 11.68 8.71 3.29 -8.07 0.05 5978104.73 583194.56 N 70.35015073 W 149.32 ,,3 1328.14 0.54 321.76 1251.56 1328.06 -8.90 12.83 9.83 3.89 -9.03 0.53 5978105.32 583193.59 N 70.35015236 W 149.32456436 1423.54 0.43 308.82 1346.96 1423.46 -9.44 13.63 10.58 4.47 -9.59 0.16 5978105.89 583193.02 N 70.35015394 W 149.32456889 1519.84 2.71 129.27 1443.23 1519.73 -8.00 15.65 8.74 3.25 -8.11 3.26 5978104.69 583194.52 N 70.35015062 W 149.32455686 1612.51 3.25 131.82 1535.77 1612.27 -4.45 20.47 4.46 0.11 -4.45 0.60 5978101.59 583198.21 N 70.35014205 W 149.32452720 1707.79 3.20 129.72 1630.90 1707.40 -0.50 25.83 3.41 -3.39 -0.40 0.13 5978098.14 583202.30 N 70.35013249 W 149.32449426 1803.69 3.09 129.40 1726.66 1803.16 3.44 31.09 7.67 -6.74 3.66 0.12 5978094.83 583206.39 N 70.35012333 W 149.32446133 1899.25 2.15 112.57 1822.12 1898.62 7.01 35.42 11.64 -9.06 7.31 1.26 5978092.55 583210.07 N 70.35011699 W 149.32443173 1995.08 1.95 109.31 1917.89 1994.39 10.17 38.85 14.71 -10.29 10.50 0.24 5978091.36 583213.28 N 70.35011363 W 149.32440577 2090.55 0.65 76.80 2013.33 2089.83 12.22 40.97 16.51 -10.70 12.57 1.51 5978090.97 583215.34 N 70.35011250 W 149.32438904 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-L\L-04\L-04\L-04 Generated 11/16/2006 10:34 AM Page 1 of 6 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure it de de n n ft n ft it ft de 00 ft nUS ftUS b1 U:i.tf4 10.2818 L/if.3U 0y00.4V 0U3'L.yU -0115./U OtSy.03 0L0.01 04.151 -0[1.00 C.4L 0y/01t5V.03 025L0t5V.14 IV /U.30U3/3325 VV 74y.3Ltt/L0C4 6200.11 14.74 267.54 6049.04 6125.54 -544.72 615.69 554.49 86.30 -547.73 3.76 5978181.74 582654.05 N 70.35037745 W 149.32893751 6295.82 14.63 265.46 6141.63 6218.13 -568.96 639.95 578.20 84.82 -571.95 0.56 5978179.99 582629.86 N 70.35037340 W 149.32913408 6390.69 14.68 271.69 6233.42 6309.92 -592.93 663.93 601.83 84.23 -595.91 1.66 5978179.13 582605.91 N 70.35037177 W 149.32932859 6485.91 15.79 294.42 6325.37 6401.87 -616.62 688.65 626.28 89.94 -619.79 6.34 5978184.58 582581.97 N 70.35038739 W 149.32952244 6581.92 12.44 319.21 6418.55 6495.05 -634.86 711.72 646.74 103.19 -638.46 7.12 5978197.61 582563.16 N 70.35042357 W 149.32967403 6677.73 8.01 336.07 6512.84 6589.34 -643.87 728.61 658.41 117.11 -647.91 5.53 5978211.43 582553.55 N 70.35046161 W 149.32975080 6773.03 6.91 2.76 6607.36 6683.86 -645.91 740.76 662.99 128.91 -650.33 3.77 5978223.20 582551.00 N 70.35049384 W 149.32977044 6869.54 8.79 24.90 6702.98 6779.48 -642.13 753.79 662.22 141.40 -646.95 3.65 5978235.73 582554.24 N 70.35052797 W 149.32974297 6964.56 9.85 28.32 6796.75 6873.25 -634.78 769.17 658.57 155.14 -640.03 1.26 5978249.54 582561.00 N 70.35056551 W 149.32968686 7060.42 11.05 37.01 6891.02 6967.52 -624.91 786.52 653.05 169.70 -630.61 2.06 5978264.20 582570.26 N 70.35060527 W 149.32961039 7156.23 13.20 45.24 6984.69 7061.19 -611.14 806.61 644.37 184.74 -617.32 2.87 5978279.38 582583.39 N 70.35064635 W 149.3 7252.86 15.09 54.78 7078.40 7154.90 -592.56 830.18 631.62 199.76 -599.20 3.10 5978294.61 582601.33 2 N 70.35068741 W 149.32 7344.48 18.35 62.20 7166.15 7242.65 -569.63 856.50 614.90 213.37 -576.69 4.25 5978308.47 582623.69 N 70.35072459 W 149.32917270 7443.29 22.61 66.89 7258.70 7335.20 -537.93 891.04 591.22 228.09 -545.45 4.62 5978323.53 582654.76 N 70.35076480 W 149.32891906 7538.85 25.80 68.90 7345.85 7422.35 -501.17 930.22 564.07 242.79 -509.14 3.45 5978338.63 582690.90 N 70.35080497 W 149.32862433 7634.69 30.26 72.11 7430.43 7506.93 -458.26 975.23 533.12 257.72 -466.68 4.91 5978354.03 582733.19 N 70.35084578 W 149.32827962 7732.00 36.64 74.38 7511.58 7588.08 -406.44 1028.84 497.07 273.09 -415.33 6.68 5978369.97 582784.37 N 70.35088777 W 149.32786274 7826.66 39.60 74.32 7586.04 7662.54 -349.71 1087.27 460.83 288.85 -359.07 3.13 5978386.35 582840.44 N 70.35093084 W 149.32740600 7921.74 39.05 73.43 7659.60 7736.10 -291.33 1147.52 429.06 305.59 -301.18 0.83 5978403.72 582898.13 N 70.35097655 W 149.32693611 8018.21 39.67 72.33 7734.18 7810.68 -232.32 1208.70 404.51 323.60 -242.72 0.97 5978422.38 582956.39 N 70.35102577 W 149.32646147 8113.31 39.44 71.58 7807.51 7884.01 -174.17 1269.26 389.21 342.36 -185.13 0.56 5978441.78 583013.75 N 70.35107702 W 149.32599401 8207.54 41.08 71.65 7879.41 7955.91 -115.80 1330.15 383.33 361.56 -127.35 1.74 5978461.62 583071.32 N 70.35112949 W 149.32552489 8302.99 42.00 70.43 7950.86 8027.36 -55.32 1393.45 388.05 382.13 -67.49 1.28 5978482.85 583130.94 N 70.35118569 W 149.32503895 8399.43 43.52 68.35 8021.67 8098.17 6.65 1458.92 405.24 405.19 -6.22 2.15 5978506.59 583191.94 N 70.35124869 W 149.32454154 8495.21 42.41 67.94 8091.75 8168.25 67.98 1524.20 432.92 429.49 54.37 1.20 5978531.56 583252.25 N 70.35131507 W 149.32404967 8591.28 41.36 68.16 8163.28 8239.78 128.20 1588.34 467.54 453.47 113.86 1.10 5978556.19 583311.46 N 70.35138057 W 149.32356672 8686.55 40.47 68.28 8235.27 8311.77 186.85 1650.73 506.64 476.62 171.80 0.94 5978579.98 583369.14 N 70.35144381 W 149.32309633 8783.35 41.45 68.09 8308.37 8384.87 246.48 1714.19 550.84 500.20 230.71 1.02 5978604.21 583427.78 N 70.35150823 W 149.32261807 8878.18 4329 67.28 8378.43 8454.93 306.33 1778.09 599.22 524.47 289.82 2.02 5978629.14 583486.61 N 70.35157453 W 149.32 4 8973.99 43.21 69.05 8448.22 8524.72 368.01 1843.74 651.39 548.89 350.75 1.27 5978654.23 583547.27 N 70.35164123 W 149.32 9069.79 42.50 70.60 8518.45 8594.95 429.85 1908.89 704.36 571.36 411.91 1.33 5978677.38 583608.16 N 70.35170262 W 149.32114697 9093.92 42.02 70.67 8536.30 8612.80 445.32 1925.12 717.74 576.74 427.22 2.00 5978682.93 583623.41 N 70.35171732 W 149.32102268 9193.68 42.16 71.55 8610.34 8686.84 509.24 1991.99 773.72 598.39 490.48 0.61 5978705.27 583686.42 N 70.35177645 W 149.32050905 9226.14 45.82 76.77 8633.69 8710.19 531.10 2014.52 792.30 604.51 512.16 15.86 5978711.63 583708.03 N 70.35179315 W 149.32033304 9256.45 49.05 78.50 8654.19 8730.69 553.05 2036.84 810.15 609.28 533.97 11.45 5978716.64 583729.78 N 70.35180618 W 149.32015603 9288.27 51.45 82.73 8674.55 8751.05 577.29 2061.30 829.18 613.25 558.09 12.70 5978720.88 583753.86 N 70.35181703 W 149.31996015 9319.15 53.61 85.88 8693.33 8769.83 601.74 2085.80 847.54 615.67 582.48 10.70 5978723.57 583778.21 N 70.35182364 W 149.31976219 9352.30 56.00 88.03 8712.44 8788.94 628.81 2112.89 867.37 617.10 609.52 8.95 5978725.30 583805.24 N 70.35182754 W 149.31954261 9383.58 58.28 90.42 8729.41 8805.91 655.08 2139.16 886.27 617.45 635.79 9.71 5978725.94 583831.50 N 70.35182849 W 149.31932935 9415.37 60.50 91.11 8745.60 8822.10 682.41 2166.52 905.85 617.08 663.15 7.23 5978725.88 583858.85 N 70.35182748 W 149.31910726 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-L\L-04\L-04\L-04 Generated 11/16/2006 10:34 AM Page 3 of 6 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude longitude Depth Section Departure ft de de ft ft n ft tt ft ft de tm ft ftUS ftUS 9448.64 64.72 91.76 8760.90 8837.40 711.90 2196.05 927.18 616.34 692.67 12.80 5978725.47 583888.38 N 70.35182544 W 149.31886757 9479.82 68.16 93,18 8773.36 8849.86 740.39 2224.63 947.90 615.11 721.22 11.80 5978724.55 583916.94 N 70.35182206 W 149.31863579 9511.32 71.79 94.79 8784.15 8860.65 769.83 2254.22 969.24 613.04 750.74 12.48 5978722.81 583946.48 N 70.35181642 W 149.31839616 9544.63 76.48 96.30 8793.25 8869.75 801.60 2286.25 992.23 609.94 782.62 14.74 5978720.07 583978.38 N 70.35180794 W 149.31813734 9575.53 80.18 96.62 8799.50 8876.00 831.54 2316.51 1014.07 606.54 812.68 12.02 5978717.00 584008.48 N 70.35179863 W 149.31789326 9608.05 79.93 96.79 8805.12 8881.62 863.21 2348.54 1037.56 602.80 844.49 0.93 5978713.61 584040.33 N 70.35178840 W 149.31763500 9639.64 80.05 96.41 8810.61 8887.11 893.99 2379.65 1060.84 599.22 875.40 1.24 5978710.38 584071.27 N 70.35177862 W 149.31738412 9670.10 79.25 96.25 8816.08 8892.58 923.65 2409.61 1083.73 595.92 905.18 2.68 5978707.41 584101.08 N 70.35176959 W 149.31714234 9690.75 79.05 97.28 8819.97 8896.47 943.70 2429.89 1099.32 593.53 925.32 4.99 5978705.24 584121.24 N 70.35176306 W 149.31697884 9712.31 78.41 97.53 8824.18 8900.68 964.57 2451.04 1115.58 590.81 946.29 3.18 5978702.75 584142.24 N 70.35175560 W 149.31680862 9743.79 78.02 97.81 8830.61 8907.11 994.97 2481.85 1139.47 586.69 976.83 1.51 5978698.98 584172.82 N 70.35174436 W 149.31656068 9775.99 77.96 98.31 8837.31 8913.81 1026.00 2513.35 1164.10 582.28 1008.01 1.53 5978694.91 584204.05 N 70.35173228 W 149.31 9808.47 77.61 98.34 8844.18 8920.68 1057.24 2545.09 1189.16 577.68 1039.42 1.08 5978690.66 584235.51 N 70.35171971 W 149.31 9841.37 77.10 98.99 8851.39 8927.89 1088.81 2577.20 1214.71 572.85 1071.16 2.47 5978686.18 584267.29 N 70.35170649 W 149.3157 488 9873.81 78.22 99.48 8858.32 8934.82 1119.91 2608.89 1240.05 567.76 1102.43 3.75 5978681.44 584298.62 N 70.35169258 W 149.31554095 9903.45 79.70 99.15 8863.99 8940.49 1148.45 2637.98 1263.53 563.05 1131.14 5.11 5978677.05 584327.38 N 70.35167971 W 149.31530789 9935.67 80.95 99.96 8869.41 8945.91 1179.59 2669.74 1289.35 557.78 1162.46 4.60 5978672.13 584358.75 N 70.35166529 W 149.31505363 9968.97 81.81 98.57 8874.40 8950.90 1211.90 2702.66 1316.49 552.48 1194.96 4.87 5978667.19 584391.30 N 70.35165080 W 149.31478984 9995.53 82.71 99.24 8877.98 8954.48 1237.76 2728.98 1338.46 548.40 1220.96 4.21 5978663.40 584417.34 N 70.35163966 W 149.31457876 10032.12 82.75 99.75 8882.61 8959.11 1273.35 2765.27 1368.81 542.42 1256.75 1.39 5978657.81 584453.20 N 70.35162328 W 149.31428814 10064.39 83.03 98.92 8886.60 8963.10 1304.76 2797.30 1395.87 537.22 1288.35 2.70 5978652.97 584484.85 N 70.35160908 W 149.31403163 10095.64 82.96 99.23 8890.41 8966.91 1335.22 2828.31 1422.35 532.33 1318.98 1.01 5978648.42 584515.52 N 70.35159570 W 149.31378298 10127.75 82.50 100.09 8894.48 8970.98 1366.44 2860.16 1449.57 526.99 1350.38 3.02 5978643.43 584546.98 N 70.35158108 W 149.31352807 10159.53 82.37 100.36 8898.66 8975.16 1397.25 2891.67 1476.51 521.39 1381.38 0.94 5978638.18 584578.04 N 70.35156579 W 149.31327638 10191.00 82.34 100.66 8902.85 8979.35 1427.72 2922.86 1503.28 515.70 1412.05 0.95 5978632.83 584608.76 N 70.35155023 W 149.31302742 10223.19 82.03 101.08 8907.22 8983.72 1458.83 2954.75 1530.72 509.69 1443.37 1.61 5978627.17 584640.15 N 70.35153379 W 149.31277317 10254.84 81.50 101.72 8911.76 8988.26 1489.32 2986.07 1557.69 503.50 1474.07 2.61 5978621.32 584670.91 N 70.35151686 W 149.31252391 10287.06 81.26 101.15 8916.59 8993.09 1520.33 3017.93 1585.28 497.18 1505.30 1.90 5978615.35 584702.20 N 70.35149959 W 149.31227043 10318.39 82.23 103.15 8921.09 8997.59 1550.41 3048.93 1612.09 490.66 1535.61 7.04 5978609.16 584732.58 N 70.35148174 W 149.31202439 10350.69 82.80 103.54 8925.29 9001.79 1581.32 3080.96 1639.60 483.27 1566.77 2.13 5978602.11 584763.82 N 70.35146153 W 149.31 2 10382.00 83.21 102.74 8929.11 9005.61 1611.35 3112.04 1666.51 476.20 1597.03 2.85 5978595.39 584794.15 N 70.35144221 W 149.311 5 10414.07 83.60 103.34 8932.79 9009.29 1642.14 3143.89 1694.28 469.01 1628.07 2.22 5978588.54 584825.27 N 70.35142256 W 149.31127380 10445.79 84.51 103.49 8936.07 9012.57 1672.58 3175.44 1721.81 461.69 1658.75 2.91 5978581.57 584856.03 N 70.35140254 W 149.31102468 10477.47 83.78 104.69 8939.31 9015.81 1702.89 3206.96 1749.27 454.02 1689.32 4.42 5978574.24 584886.68 N 70.35138156 W 149.31077655 10509.08 84.11 104.34 8942.64 9019.14 1733.05 3238.39 1776.68 446.14 1719.75 1.52 5978566.70 584917.19 N 70.35136002 W 149.31052952 10542.08 84.20 105.78 8946.00 9022.50 1764.46 3271.22 1805.29 437.61 1751.45 4.35 5978558.52 584948.98 N 70.35133670 W 149.31027218 10572.95 84.17 105.60 8949.13 9025.63 1793.75 3301.93 1832.03 429.31 1781.02 0.59 5978550.54 584978.63 N 70.35131399 W 149.31003216 10604.40 85.67 105.20 8951.91 9028.41 1823.67 3333.26 1859.50 420.99 1811.22 4.93 5978542.56 585008.92 N 70,35129125 W 149.30978700 10637.10 88.52 104.13 8953.57 9030.07 1854.99 3365.91 1888.46 412.72 1842.81 9.31 5978534.65 585040.60 N 70.35126864 W 149.30953056 10668.71 91.62 102.10 8953.53 9030.03 1885.52 3397.52 1916.98 405.55 1873.59 11.72 5978527.82 585071.45 N 70.35124903 W 149.30928069 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-L\L-04\L-04\L-04 Generated 11/16/2006 10:34 AM Page 4 of 6 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure n de de ft n tt n n n n de oo n nus nus lU7UU.4y y4.t3/ 1UU.L4 Hybl./:i yU1ti.1:i 1ylEi.4:i :341y.14 ly4(i.14 ;iyy.41 lyU4./1 11./t3 by/tfb11.U"L bt3b1VLEi4 N /U.:iblL:i~~1 W 14y.;iUyULt3U4 10732.70 97.34 99.17 8948.31 9024.81 1947.81 3461.27 1975.96 394.01 1936.28 8.35 5978516.97 585134.26 N 70.35121745 W 149.30877179 10764.96 98.14 99.13 8943.96 9020.46 1979.19 3493.23 2005.90 388.92 1967.84 2.48 5978512.24 585165.87 N 70.35120354 W 149.30851560 10795.21 98.18 99.94 8939.67 9016.17 2008.55 3523.18 2033.94 383.96 1997.37 2.65 5978507.61 585195.45 N 70.35118996 W 149.30827588 10828.23 98.55 98.80 8934.87 9011.37 2040.60 3555.84 2064.62 378.64 2029.60 3.59 5978502.65 585227.74 N 70.35117541 W 149.30801421 10860.03 97.66 97.96 8930.38 9006.88 2071.58 3587.33 2094.42 374.06 2060.74 3.83 5978498.41 585258.93 N 70.35116285 W 149.30776138 10891.10 96.16 99.62 8926.64 9003.14 2101.90 3618.17 2123.59 369.34 2091.22 7.17 5978494.03 585289.46 N 70.35114995 W 149.30751395 10923.74 96.34 98.88 8923.09 8999.59 2133.74 3650.62 2154.24 364.13 2123.25 2.32 5978489.17 585321.53 N 70.35113568 W 149.30725398 10956.00 96.44 98.60 8919.50 8996.00 2165.26 3682.67 2184.68 359.26 2154.93 0.92 5978484.65 585353.27 N 70.35112235 W 149.30699675 10988.09 96.46 98.79 8915.90 8992.40 2196.61 3714.56 2215.00 354.44 2186.45 0.59 5978480.18 585384.84 N 70.35110915 W 149.30674087 11020.17 96.72 99.30 8912.21 8988.71 2227.90 3746.43 2245.28 349.43 2217.93 1.78 5978475.52 585416.36 N 70.35109544 W 149.30648538 11052.03 96.88 100.26 8908.44 8984.94 2258.89 3778.07 2275.27 344.05 2249.10 3.03 5978470.50 585447.59 N 70.35108073 W 149.30623230 11084.50 97.11 100.23 8904.49 8980.99 2290.41 3810.29 2305.77 338.32 2280.82 0.71 5978465.12 585479.37 N 70.35106505 W 149.3 11116.16 97.27 100.59 8900.52 8977.02 2321.11 3841.71 2335.52 332.64 2311.71 1.24 5978459.79 585510.32 0 N 70.35104952 W 149.30 11147.44 97.34 100.03 8896.55 8973.05 2351.44 3872.73 2364.96 327.09 2342.24 1.79 5978454.57 585540.90 N 70.35103432 W 149.3054 27 11178.87 97.59 100.24 8892.46 8968.96 2381.93 3903.89 2394.61 321.61 2372.91 1.04 5978449.43 585571.63 N 70.35101931 W 149.30522724 11210.95 98.15 100.43 8888.07 8964.57 2413.00 3935.67 2424.84 315.91 2404.18 1.84 5978444.08 585602.95 N 70.35100371 W 149.30497346 11242.55 97.99 100.34 8883.64 8960.14 2443.57 3966.96 2454.64 310.27 2434.95 0.58 5978438.78 585633.79 N 70.35098828 W 149.30472364 11273.83 97.57 101.10 8879.40 8955.90 2473.83 3997.95 2484.13 304.50 2465.40 2.76 5978433.36 585664.30 N 70.35097250 W 149.30447645 11306.36 97.40 100.75 8875.16 8951.66 2505.29 4030.20 2514.83 298.39 2497.07 1.19 5978427.60 585696.03 N 70.35095577 W 149.30421938 11337.74 97.26 101.28 8871.16 8947.66 2535.63 4061.33 2544.48 292.44 2527.62 1.73 5978421.99 585726.64 N 70.35093950 W 149.30397138 11369.33 97.19 100.86 8867.19 8943.69 2566.18 4092.67 2574.36 286.43 2558.37 1.34 5978416.31 585757.46 N 70.35092303 W 149.30372172 11401.02 97.20 101.07 8863.22 8939.72 2596.84 4124.11 2604.38 280.44 2589.24 0.66 5978410.68 585788.38 N 70.35090667 W 149.30347116 11433.25 95.41 103.93 8859.68 8936.18 2627.88 4156.14 2634.75 273.51 2620.51 10.42 5978404.09 585819.73 N 70.35088769 W 149.30321731 11465.49 92.21 106.99 8857.53 8934.03 2658.59 4188.31 2664.71 264.94 2651.51 13.72 5978395.86 585850.81 N 70.35086424 W 149.30296570 11497.44 89.39 107.83 8857.09 8933.59 2688.75 4220.25 2694.12 255.38 2681.99 9.21 5978386.64 585881.40 N 70.35083810 W 149.30271829 11529.04 85.80 108.95 8858.41 8934.91 2718.37 4251.82 2723.03 245.42 2711.94 11.90 5978377.02 585911.46 N 70.35081086 W 149.30247514 11560.65 84.41 113.51 8861.11 8937.61 2747.34 4283.31 2751.26 ~ 234.02 2741.29 15.03 5978365.95 585940.93 N 70.35077969 W 149.30223692 11593.15 84.45 116.03 8864.27 8940.77 2776.26 4315.66 2779.42 220.47 2770.66 7.72 5978352.72 585970.44 N 70.35074264 W 149.30199854 11625.04 84.71 116.40 8867.28 8943.78 2804.29 4347.40 2806.74 206.44 2799.14 1.41 5978339.02 585999.07 N 70.35070430 W 149.30176737 11657.09 88.31 117.86 8869.23 8945.73 2832.27 4379.39 2834.11 191.86 2827.61 12.12 5978324.75 586027.70 N 70.35066442 W 149.30 11689.03 89.13 118.24 8869.94 8946.44 2859.96 4411.32 2861.26 176.84 2855.79 2.83 5978310.05 586056.04 N 70.35062337 W 149.30 0 11720.82 89.44 115.69 8870.34 8946.84 2887.82 4443.11 2888.69 162.43 2884.12 8.08 5978295.95 586084.53 N 70.35058397 W 149.30107767 11753.09 88.52 119.10 8870.92 8947.42 2915.98 4475.37 2916.50 147.59 2912.76 10.94 5978281.43 586113.33 N 70.35054339 W 149.30084520 11784.66 89.82 116.16 8871.37 8947.87 2943.46 4506.94 2943.73 132.95 2940.72 10.18 5978267.11 586141.45 N 70.35050337 W 149.30061824 11816.34 88.90 119.56 8871.73 8948.23 2970.98 4538.62 2971.07 118.15 2968.72 11.12 5978252.62 586169.61 N 70.35046290 W 149.30039097 11847.83 90.03 120.30 8872.02 8948.52 2997.76 4570.11 2997.76 102.44 2996.01 4.29 5978237.21 586197.07 N 70.35041995 W 149.30016949 11880.37 90.18 119.67 8871.96 8948.46 3025.41 4602.64 3025.43 86.18 3024.20 1.99 5978221.27 586225.43 N 70.35037550 W 149.29994074 11911.91 89.62 120.22 8872.02 8948.52 3052.22 4634.18 3052.34 70.43 3051.53 2.49 5978205.83 586252.93 N 70.35033246 W 149.29971894 11942.88 89.74 119.39 8872.19 8948.69 3078.59 4665.15 3078.89 55.04 3078.40 2.71 5978190.74 586279.97 N 70.35029037 W 149.29950084 11975.55 89.51 117.70 8872.40 8948.90 3106.78 4697.82 3107.35 39.43 3107.10 5.22 5978175.45 586308.83 N 70.35024769 W 149.29926793 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-L\L-04\L-04\L-04 Generated 11/1 6/2006 1 0:34 AM Page 5 of 6 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft n n ft de 100 ft ftUS ftUS 11UU/.Ll 5U.5L 115.15/ 1515/L.Lti 155415. /t5 31:i4.U:i 4/"L5.415 31:14.54 "L4.11S :11:14.154 15.1/ 55/t1115U.S7 btfti:i:ili./5 N /U.:ibU"LUtiUL W 145.155U4"L/5 12038.56 88.36 117.26 8872.48 8948.98 3161.07 4760.83 3162.38 9.20 3162.37 11.66 5978145.83 586364.44 N 70.35016504 W 149.29881933 12071.02 84.28 119.44 8874.57 8951.07 3189.07 4793.21 3190.88 -6.18 3190.87 14.24 5978130.78 586393.10 N 70.35012300 W 149.29858802 12102.29 83.34 120.27 8877.94 8954.44 3215.52 4824.30 3217.91 -21.65 3217.83 4.00 5978115.60 586420.23 N 70.35008069 W 149.29836920 12133.52 83.60 120.13 8881.49 8957.99 3241.83 4855.33 3244.86 -37.26 3244.65 0.94 5978100.30 586447.22 N 70.35003802 W 149.29815157 12165.49 81.04 120.45 8885.76 8962.26 3268.66 4887.01 3272.44 -53.24 3272.01 8.07 5978084.62 586474.75 N 70.34999434 W 149.29792955 12198.13 78.13 121.86 8891.66 8968.16 3295.59 4919.11 3300.21 -69.85 3299.47 9.88 5978068.33 586502.40 N 70.34994894 W 149.29770662 12230.42 77.88 121.45 8898.37 8974.87 3321.94 4950.69 3327.48 -86.42 3326.36 1.46 5978052.05 586529.46 N 70.34990363 W 149.29748843 12263.12 77.81 121.21 8905.26 8981.76 3348.70 4982.66 3355.25 -103.04 3353.67 0.75 5978035.74 586556.95 N 70.34985819 W 149.29726682 Last MWD+IFR+MS 12282.24 77.50 121.95 8909.34 8985.84 3364.29 5001.34 3371.47 -112.82 3369.58 4.11 5978026.13 586572.97 N 70.34983144 W 149.29713769 TD (Projected) 12330.00 77.50 121.95 8919.68 8996.18 3403.06 5047.97 3411.91 -137.50 3409.14 0.00 5978001.90 586612.80 N 70.34976399 W 149.29681661 Survey Type: Definitive Survey NOTES: GYD CT DMS (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot su rveys with continuous tool (RGS-CT) in drill-pipe. ) MWD +IFR + MS - (In-fie ld referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 2379 FSL 3714 FEL S34 T12N R11 E UM 5978101.53 583202.66 BHL : 2241 FSL 305 FEL S34 T1 2N R11 E UM 5978001.90 586612.80 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-L\L-04\L-04\L-04 Generated 11/16/2006 10:34 AM Page 6 of 6 TR~~ : 4.1r1+~ ~ c~ WELLHEAD-- FMC -- ACTUATOR - _. LEO K8. ELEV = 28S 8F_ ELEV = 73.5 KOP _ _ 390Q _-- - Max Angle = 39° @ 19,741' v '~ Datum MO = 123.39'. Datum ND = 13919.68'. { 9518" GSG, 40#, L-BtS, .tI758 6pf, tfk 8.:835" { ~ L-04 FRO D LC - D T sA~rY~rl~; ~ irifta{{~a on ~onsrzoos- 2999` }.-.4112" FiES X t~kp{~le . IC's 3.813... Minimum ID = 3.725" @ 8992' JEWELRY TYPE 4.5' "XN" Nipple 8927" ~4-i[2" X Plip~e {3,813' ID) 7" ES Cementer, If3= 6.278" 4-112" t_-8,12.6 ttalft,TC-II,.D1 S2' bpf ID= 3.958" I +g01 S' 4112" WLEG, !D = 3.958" 9015' 7" CSG, 26#, L-80, bpf, ID=5.275' 9157' PERFORATION SUMMARY REF LOG: '~'???? ANGLE AT TOP PERF: 42° cz 9192 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 4 9192 - 9197 Q' 1t)118i96 2-112" 4 11799 - 11979 O 1ffi24196 2-1l2°' 4 12059- 12237 O 1C3124rt16 8948' Baker 5-3 Packer, 7" x 4.5" 8'972' 4112" X t+~ppie (3.813" IC3) w1 RMC-AA Plug 8992' 4-112" xN Nippta ~~.7.s- If1} 90tlT '"' x ~" Lnertop Packer wt xx" Tietsack Sfee~~ "{~,'~~~' 4.5" ES Cementer 3.958' 10 . i 1 ao2• aver Pazone extefnal Parker, iD= ~. PBT[3 I-) '! 2243' ~ ~-1rz", t.-eo, ~a., IaT-Moo .o1s~ ~pf BATE REV SY COMMENTS DATE REV BY COM(L1EMS 07/11/4ti BJP Proposed Comptetian t2ev.1 1612510b t3JB/RJB PresentGornptetion 101261t~i /PAG DRLGt~+4FTCORRECTIOf~iS I 1233Q' I PRUDI-bE BAY UNfC WELL: L-44i PERMfT No: 2#I&-120 APt 59-C}29-23319-00 Sec Tw p P.ge t3P 6tplnration {Ataskaj R ~G ~c i SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Prudhoe Bay Well ...................... L-04 API number ................ 50-029-23319-00 Engineer .................. St. Amour RIG :...................... Nabors 9ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 48.00 ft KB above permanent.......: 76.50 ft DF above permanent.......: 76.50 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 88.18 degrees [(c)2006 IDEAL ID10 2C O1] 10-Oct-2006 07:50:32 Page 1 of 8 Spud date ................. 23-Sep-06 Last survey date.........: 10-Oct-06 Total accepted surveys...: 197 MD of first survey.......: 0.00 ft MD of last survey........: 12330.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............. 22-Sep-2006 Magnetic field strength..: 57579.99 LAMA Magnetic dec (+E/W-).....: 24.10 degrees Magnetic dip .............: 80.86 degrees ----- MWD survey Reference Reference G ............... Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57580.00 GAMA 80.86 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.10 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.10 degrees (Total az corr =magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • SCHLUMBERGER Survey Report 10-Oct-2006 07:50:32 Page 2 of 8 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical --------- --------- Displ ------- ------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- --- (ft) -------- -------- (deg) ------ --- (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) --------- (f t) ------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ 1 0.00 --- 0.00 ------- 0.00 ------ 0.00 -------- 0.00 -------- 0.00 --------- 0.00 ------- 0.00 ------- 0.00 -------- 0.00 ----- 0.00 ----- ------ TIP None 2 100.00 0.32 76.08 100.00 100.00 0.27 0.07 0.27 0.28 76.08 0.32 BP _GYD CT DMS 3 200.00 0.36 109.04 100.00 200.00 0.84 0.03 0.84 0.84 87.82 0.20 BP _GYD CT DMS 4 300.00 0.25 81.82 100.00 300.00 1.35 -0.04 1.35 1.35 91.68 0.18 BP _GYD CT DMS 5 400.00 0.15 301.65 100.00 400.00 1.46 0.06 1.46 1.46 87.64 0.38 BP GYD CT DMS 6 500.00 0.40 287.79 100.00 499.99 1.02 0.24 1.01 1.04 76.91 0.26 BP _GYD CT DMS 7 600.00 0.60 277.95 100.00 599.99 0.17 0.41 0.16 0.45 21.32 0.22 BP - GYD CT DMS 8 700.00 0.79 287.46 100.00 699.98 -0.99 0.69 -1.OI 1.23 304.37 0.22 BP _GYD CT DMS 9 800.00 0.68 289.05 100.00 799.97 -2.20 1.09 -2.23 2.49 296.11 0.11 BP _GYD CT DMS 10 900.00 0.93 286.90 100.00 899.97 -3.52 1.52 -3.57 3.88 293.11 0.25 BP GYD CT DMS 11 1000.00 0.81 295.18 100.00 999.95 -4.92 2.06 -4.99 5.40 292.45 0.17 BP _GYD CT DMS 12 1100.00 0.69 293.30 100.00 1099.94 -6.09 2.60 -6.18 6.70 292.82 0.12 BP _GYD CT DMS 13 1136.05 0.92 289.76 36.05 1135.99 -6.56 2.78 -6.65 7.21 292.71 0.65 BP _MWD+IFR+MS 14 1232.36 0.87 289.62 96.31 1232.29 -7.96 3.29 -8.07 8.71 292.19 0.05 BP _MWD+IFR+MS 15 1328.14 0.54 321.76 95.78 1328.06 -8.90 3.89 -9.03 9.83 293.30 0.53 BP MWD+IFR+MS 16 1423.54 0.43 308.82 95.40 1423.46 -9.44 4.47 -9.59 10.58 294.98 0.16 BP _MWD+IFR+MS 17 1519.84 2.71 129.27 96.30 1519.73 -8.00 3.25 -8.11 8.74 291.85 3.26 BP _MWD+IFR+MS 18 1612.51 3.25 131.82 92.67 1612.27 -4.45 0.11 -4.45 4.46 271.46 0.60 BP _MWD+IFR+MS 19 1707.79 3.20 129.72 95.28 1707.40 -0.50 -3.39 -0.40 3.41 186.66 0.13 BP _MWD+IFR+MS 20 1803.69 3.09 129.40 95.90 1803.16 3.44 -6.74 3.66 7.67 151.49 0.12 BP MWD+IFR+MS 21 1899.25 2.15 112.57 95.56 1898.62 7.01 -9.06 7.31 11.64 141.12 1.26 BP _MWD+IFR+MS 22 1995.08 1.95 109.31 95.83 1994.39 10.17 -10.29 10.50 14.70 134.41 0.24 BP _MWD+IFR+MS 23 2090.55 0.65 76.80 95.47 2089.83 12.22 -10.70 12.57 16.51 130.43 1.51 BP _MWD+IFR+MS 24 2186.27 0.44 67.57 95.72 2185.55 13.10 -10.44 13.43 17.01 127.85 0.24 BP _MWD+IFR+MS 25 2281.63 0.23 74.57 95.36 2280.90 13.62 -10.25 13.96 17.32 126.29 0.22 BP MWD+IFR+MS 26 2378.11 0.94 283.05 96.48 2377.38 13.05 -10.02 13.37 16.71 126.84 1.19 BP _MWD+IFR+MS 27 2473.65 1.09 285.83 95.54 2472.91 11.42 -9.59 11.73 15.16 129.27 0.17 BP _MWD+IFR+MS 28 2569.73 1.10 290.45 96.08 2568.97 9.70 -9.02 9.99 13.46 132.08 0.09 BP _MWD+IFR+MS 29 2651.29 1.10 284.78 81.56 2650.51 8.22 -8.55 8.50 12.06 135.16 0.13 BP _MWD+IFR+MS 30 2754.21 0.73 301.84 102.92 2753.42 6.73 -7.95 6.99 10.59 138.69 0.44 BP MWD+IFR+MS [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 10-Oct-2006 07:50:32 Page 3 of 8 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (f t) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (f t) -------- (ft) -------- (f t) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ --- 31 -------- 2849.63 ------ 0.72 ------- 284.13 ------ 95.42 -------- 2848.83 -------- 5.65 -------- -7.48 -------- 5.89 ------- 9.52 -------- 141.79 ----- 0.23 - BP ---- ------ _MWD+IFR+MS 32 2944.87 0.74 287.03 95.24 2944.06 4.49 -7.16 4.72 8.58 146.59 0.04 BP _MWD+IFR+MS 33 3040.23 0.74 287.85 95.36 3039.42 3.33 -6.79 3.55 7.66 152.41 0.01 BP _MWD+IFR+MS 34 3136.51 0.80 290.56 96.28 3135.69 2.12 -6.36 2.33 6.77 159.92 0.07 BP _MWD+IFR+MS 35 3231.66 0.91 282.54 95.15 3230.83 0.78 -5.96 0.97 6.04 170.80 0.17 BP MWD+IFR+MS 36 3333.14 0.79 288.40 101.48 3332.29 -0.66 -5.57 -0.48 5.59 184.97 0.15 BP _MWD+IFR+MS 37 3429.19 0.57 287.49 96.05 3428.34 -1.73 -5.22 -1.57 5.45 196.73 0.23 BP - MWD+IFR+MS • 38 3524.77 0.46 283.57 95.58 3523.91 -2.55 -4.98 -2.39 5.53 205.66 0.12 BP _MWD+IFR+MS 39 3618.75 0.52 263.74 93.98 3617.89 -3.34 -4.94 -3.18 5.88 212.80 0.19 BP _MWD+IFR+MS 40 3714.89 0.42 242.64 96.14 3714.03 -4.09 -5.15 -3.93 6.48 217.35 0.21 BP MWD+IFR+MS 41 3808.65 0.42 244.06 93.76 3807.79 -4.72 -5.46 -4.55 7.10 219.78 0.01 BP _MWD+IFR+MS 42 3904.43 0.40 236.55 95.78 3903.56 -5.32 -5.80 -5.14 7.75 221.56 0.06 BP _MWD+IFR+MS 43 3999.84 1.99 286.48 95.41 3998.95 -7.18 -5.51 -7.01 8.91 231.82 1.84 BP _MWD+IFR+MS 44 4095.43 5.77 289.14 95.59 4094.30 -13.24 -3.46 -13.14 13.59 255.23 3.96 BP _MWD+IFR+MS 45 4190.82 8.59 289.80 95.39 4188.94 -24.35 0.52 -24.38 24.38 271.23 2.96 BP MWD+IFR+MS 46 4286.34 12.21 288.10 95.52 4282.87 -40.48 6.08 -40.69 41.15 278.50 3.80 BP _MWD+IFR+MS 47 4381.98 14.33 290.15 95.64 4375.95 -60.97 13.30 -61.42 62.84 282.22 2.27 BP _MWD+IFR+MS 48 4478.05 15.74 289.13 96.07 4468.73 -84.16 21.67 -84.89 87.61 284.32 1.49 BP _MWD+IFR+MS 49 4573.67 16.14 284.13 95.62 4560.68 -109.06 29.16 -110.04 113.84 284.84 1.50 BP _MWD+IFR+MS 50 4669.35 16.05 283.77 95.68 4652.61 -134.58 35.56 -135.78 140.36 284.67 0.14 BP MWD+IFR+MS 51 4765.23 16.78 278.22 95.88 4744.59 -160.98 40.69 -162.35 167.37 284.07 1.80 BP _MWD+IFR+MS • 52 4860.74 16.79 274.97 95.51 4836.03 -188.25 43.86 -189.74 194.74 283.01 0.98 BP _MWD+IFR+MS 53 4956.07 16.36 273.90 95.33 4927.40 -215.28 45.96 -216.85 221.67 281.97 0.55 BP _MWD+IFR+MS 54 5052.14 15.89 273.37 96.07 5019.69 -241.85 47.65 -243.48 248.10 281.07 0.51 BP _MWD+IFR+MS 55 5147.64 15.42 272.46 95.50 5111.65 -267.53 48.97 -269.22 273.63 280.31 0.56 BP MWD+IFR+MS 56 5243.22 14.68 271.60 95.58 5203.95 -292.29 49.85 -294.02 298.22 279.62 0.81 BP _MWD+IFR+MS 57 5338.89 15.36 273.63 95.67 5296.35 -317.00 50.99 -318.78 322.84 279.09 0.90 BP _MWD+IFR+MS 58 5434.84 15.34 280.34 95.95 5388.88 -342.06 54.08 -343.95 348.18 278.93 1.85 BP _MWD+IFR+MS 59 5530.34 15.58 281.13 95.50 5480.93 -366.91 58.82 -368.96 373.62 279.06 0.33 BP _MWD+IFR+MS 60 5627.06 16.22 281.45 96.72 5573.95 -392.72 64.01 -394.95 400.10 279.21 0.67 BP MWD+IFR+MS [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 10-Oct-2006 07:50:32 Page 4 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (f t) (f t) (f t) (ft) (ft) (deg) 100f) type (deg) 61 5721.56 14.85 279.21 94.50 5664.99 -417.45 68.57 -419.84 425.40 279.28 1.58 BP _MWD+IFR+MS 62 5818.20 13.69 276.68 96.64 5758.65 -440.91 71.88 -443.42 449.21 279.21 1.36 BP _MWD+IFR+MS 63 5913.86 14.20 278.16 95.66 5851.49 -463.67 74.86 -466.28 472.25 279.12 0.65 BP _MWD+IFR+MS 64 6008.23 18.93 281.79 94.37 5941.92 -489.96 79.63 -492.74 499.13 279.18 5.13 BP _MWD+IFR+MS 65 6103.84 16.88 278.30 95.61 6032.90 -518.70 84.81 -521.66 528.51 279.23 2.42 BP MWD+IFR+MS 66 6200.11 14.74 267.54 96.27 6125.54 -544.72 86.30 -547.73 554.49 278.95 3.76 BP MWD+IFR+MS 67 6295.82 14.63 265.46 95.71 6218.13 -568.96 84.82 -571.95 578.20 278.44 0.56 BP - MWD+IFR+MS 68 6390.69 14.68 271.69 94.87 6309.91 -592.93 84.23 -595.91 601.83 278.05 1.66 BP _MWD+IFR+MS 69 6485.91 15.79 294.42 95.22 6401.87 -616.62 89.94 -619.79 626.28 278.26 6.34 BP _MWD+IFR+MS 70 6581.92 12.44 319.21 96.01 6495.05 -634.86 103.19 -638.46 646.74 279.18 7.12 BP MWD+IFR+MS 71 6677.73 8.01 336.07 95.81 6589.34 -643.87 117.11 -647.91 658.41 280.25 5.53 BP _MWD+IFR+MS 72 6773.03 6.91 2.76 95.30 6683.86 -645.91 128.91 -650.33 662.99 281.21 3.77 BP _MWD+IFR+MS 73 6869.54 8.79 24.90 96.51 6779.48 -642.13 141.40 -646.95 662.22 2.82.33 3.65 BP _MWD+IFR+MS 74 6964.56 9.85 28.32 95.02 6873.24 -634.78 155.14 -640.03 658.57 283.63 1.26 BP _MWD+IFR+MS 75 7060.42 11.05 37.01 95.86 6967.52 -624.91 169.70 -630.61 653.05 285.06 2.06 BP MWD+IFR+MS 76 7156.23 13.20 45.24 95.81 7061.19 -611.14 184.74 -617.32 644.37 286.66 2.87 BP _MWD+IFR+MS 77 7252.86 15.09 54.78 96.63 7154.90 -592.56 199.76 -599.20 631.62 288.44 3.10 BP _MWD+IFR+MS 78 7344.48 18.35 62.20 91.62 7242.65 -569.63 213.37 -576.69 614.90 290.30 4.25 BP _MWD+IFR+MS 79 7443.29 22.61 66.89 98.81 7335.20 -537.93 228.09 -545.45 591.22 292.69 4.62 BP _MWD+IFR+MS 80 7538.85 25.80 68.90 95.56 7422.34 -501.17 242.79 -509.14 564.07 295.49 3.45 BP MWD+IFR+MS 81 7634.69 30.26 72.11 95.84 7506.93 -458.26 257.72 -466.68 533.12 298.91 4.91 BP _MWD+IFR+MS • 82 7732.00 36.64 74.38 97.31 7588.08 -406.44 273.09 -415.33 497.07 303.33 6.68 BP _MWD+IFR+MS 83 7826.66 39.60 74.32 94.66 7662.54 -349.71 288.85 -359.07 460.83 308.82 3.13 BP _MWD+IFR+MS 84 7921.74 39.05 73.43 95.08 7736.09 -291.33 305.59 -301.18 429.06 315.42 0.83 BP _MWD+IFR+MS 85 8018.21 39.67 72.33 96.47 7810.68 -232.32 323.60 -242.72 404.51 323.13 0.97 BP MWD+IFR+MS 86 8113.31 39.44 71.58 95.10 7884.01 -174.17 342.36 -185.13 389.21 331.60 0.56 BP _MWD+IFR+MS 87 8207.54 41.08 71.65 94.23 7955.91 -115.80 361.56 -127.35 383.33 340.60 1.74 BP _MWD+IFR+MS 88 8302.99 42.00 70.43 95.45 8027.36 -55.32 382.13 -67.49 388.05 349.98 1.28 BP _MWD+IFR+MS 89 8399.43 43.52 68.35 96.44 8098.16 6.65 405.19 -6.22 405.24 359.12 2.15 BP _MWD+IFR+MS 90 8495.21 42.41 67.94 95.78 8168.25 67.98 429.49 54.37 432.92 7.21 1.20 BP MWD+IFR+MS [(0)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 10-Oct-2006 07:50:32 Page 5 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Sr~,ry Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) (ft) (f t) (ft) (deg) 100f) type (deg) 91 8591.28 41.36 68.16 96.07 8239.77 128.20 453.47 113.86 467.54 14.09 1.10 BP _MWD+IFR+MS 92 8686.55 40.47 68.28 95.27 8311.77 186.85 476.62 171.80 506.64 19.82 0.94 BP _MWD+IFR+MS 93 8783.35 41.45 68.09 96.80 8384.87 246.48 500.20 230.71 550.84 24.76 1.02 BP _MWD+IFR+MS 94 8878.18 43.29 67.28 94.83 8454.93 306.33 524.47 289.82 599.22 28.92 2.02 BP _MWD+IFR+MS 95 8973.99 43.21 69.05 95.81 8524.71 368.01 548.89 350.76 651.39 32.58 1.27 BP MWD+IFR+MS 96 9069.79 42.50 70.60 95.80 8594.94 429.85 571.36 411.91 704.36 35.79 1.33 BP _MWD+IFR+MS 97 9093.92 42.02 70.67 24.13 8612.80 445.32 576.74 427.22 717.74 36.53 2.00 BP _MWD+IFR+MS 98 9193.68 42.16 71.55 99.76 8686.83 509.24 598.39 490.48 773.72 39.34 0.61 BP _MWD+IFR+MS 99 9226.14 45.82 76.77 32.46 8710.19 531.10 604.51 512.16 792.30 40.27 15.86 BP _MWD+IFR+MS 100 9256.45 49.05 78.50 30.31 8730.69 553.05 609.28 533.97 810.15 41.23 11.45 BP MWD+IFR+MS 101 9288.27 51.45 82.73 31.82 8751.04 577.29 613.25 558.09 829.18 42.30 12.70 BP _MWD+IFR+MS 102 9319.15 53.61 85.88 30.88 8769.83 601.74 615.67 582.48 847.54 43.41 10.70 BP _MWD+IFR+MS 103 9352.30 56.00 88.03 33.15 8788.94 628.82 617.10 609.52 867.37 44.65 8.95 BP _MWD+IFR+MS 104 9383.58 58.28 90.42 31.28 8805.91 655.08 617.45 635.79 886.27 45.84 9.71 BP _MWD+IFR+MS 105 9415.37 60.50 91.11 31.79 8822.10 682.41 617.08 663.15 905.85 47.06 7.23 BP MWD+IFR+MS 106 9448.64 64.72 91.76 33.27 8837.40 711.90 616.34 692.67 927.18 48.34 12.80 BP _MWD+IFR+MS 107 9479.82 68..16 93.18 31.18 8849.86 740.39 615.11 721.22 947.90 49.54 11.80 BP _MWD+IFR+MS 108 9511.32 71.79 94.79 31.50 8860.65 769.83 613.04 750.74 969.24 50.77 12.48 BP _MWD+IFR+MS 109 9544.63 76.48 96.30 33.31 8869.75 801.60 609.94 782.62 992.23 52.07 14.74 BP _MWD+IFR+MS 110 9575.53 80.18 96.62 30.90 8876.00 831.54 606.54 812.68 1014.07 53.26 12.02 BP MWD+IFR+MS 111 9608.05 79.93 96.79 32.52 8881.61 863.21 602.80 844.49 1037.56 54.48 0.93 BP _MWD+IFR+MS 112 9639.64 80.05 96.41 31.59 8887.11 893.99 599.22 875.40 1060.84 55.61 1.24 BP _MWD+IFR+MS 113 9670.10 79.25 96.25 30.46 8892.58 923.65 595.92 905.18 1083.73 56.64 2.68 BP _MWD+IFR+MS 114 9690.75 79.05 97.28 20.65 8896.47 943.70 593.53 925.32 1099.32 57.32 4.99 BP _MWD+IFR+MS 115 9712.31 78.41 97.53 21.56 8900.68 964.57 590.81 946.29 1115.58 58.02 3.18 BP MWD+IFR+MS 116 9743.79 78.02 97.81. 31.48 8907.11 994.97 586.69 976.83 1139.47 59.01 1.51 BP _MWD+IFR+MS 117 9775.99 77.96 98.31 32.20 8913.81 1026.00 582.28 1008.01 1164.10 59.99 1.53 BP _MWD+IFR+MS 118 9808.47 77.61 98.34 32.48 8920.68 1057.24 577.68 1039.42 1189.16 60.94 1.08 BP _MWD+IFR+MS 119 9841.37 77.10 98.99 32.90 8927.88 1088.81 572.85 1071.16 1214.71 61.86 2.47 BP _MWD+IFR+MS 120 9873.81 78.22 99.48 32.44 8934.82 1119.91 567.76 1102.43 1240.05 62.75 3.75 BP MWD+IFR+MS • .] [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 10-Oct-2006 07:50:32 Page 6 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) (f t) (ft) (f t) (deg) 100f) type (deg) 121 9903.45 79.70 99.15 29.64 8940.49 1148.45 563.05 1131.14 1263.53 63.54 5.11 BP _MWD+IFR+MS 122 9935.67 80.95 99.96 32.22 8945.91 1179.59 557.78 1162.46 1289.35 64.37 4.60 BP _MWD+IFR+MS 123 9968.97 81.81 98.57 33.30 8950.90 1211.90 552.48 1194.96 1316.49 65.19 4.87 BP _MWD+IFR+MS 124 9995.53 82.71 99.24 26.56 8954.48 1237.76 548.40 1220.96 1338.46 65.81 4.21 BP _MWD+IFR+MS 125 10032.12 82.75 99.75 36.59 8959.11 1273.35 542.42 1256.75 1368.81 66.65 1.39 BP MWD+IFR+MS 126 10064.39 127 10095.64 128 10127.75 129 10159.53 130 10191.00 131 10223.19 132 10254.84 133 10287.06 134 10318.39 135 10350.69 136 10382.00 137 10414.07 138 10445.79 139 10477.47 140 10509.08 141 10542.08 142 10572.95 143 10604.40 144 10637.10 145 10668.71 146 10700.49 147 10732.70 148 10764.96 149 10795.21 150 10828.23 83.03 98.92 32.27 8963.10 1304.76 537.22 1288.35 1395.87 82.96 99.23 31.25 8966.91 1335.22 532.33 1318.98 1422.35 82.50 100.09 32.11 8970.97 1366.44 526.99 1350.38 1449.57 82.37 100.36 31.78 8975.16 1397.25 521.39 1381.38 1476.51 82.34 100.66 31.47 8979.34 1427.72 515.70 1412.05 1503.28 82.03 101.08 32.19 8983.72 1458.83 509.69 1443.37 1530.72 81.50 101.72 31.65 8988.25 1489.32 503.50 1474.07 1557.69 81.26 101.15 32.22 8993.08 1520.33 497.18 1505.30 1585.28 82.23 103.15 31.33 8997.58 1550.41 490.66 1535.61 1612.09 82.80 103.54 32.30 9001.79 1581.32 483.27 1566.77 1639.60 83.21 102.74 31.31 9005.60 1611.35 476.20 1597.03 1666.51 83.60 103.34 32.07 9009.29 1642.14 469.01 1628.07 1694.28 84.51 103.49 31.72 9012.57 1672.58 461.69 1658.75 1721.81 83.78 104.69 31.68 9015.80 1702.89 454.02 1689.32 1749.27 84.11 104.34 31.61 9019.14 1733.05 446.14 1719.75 1776.68 84.20 105.78 33.00 9022.50 1764.47 437.61 1751.45 1805.29 84.17 105.60 30.87 9025.63 1793.75 429.31 1781.02 1832.03 85.67 105.20 31.45 9028.41 1823.67 420.99 1811.22 1859.50 88.52 104.13 32.70 9030.07 1854.99 412.72 1842.81 1888.46 91.62 102.10 31.61 9030.03 1885.52 405.55 1873.59 1916.98 94.87 100.24 31.78 9028.23 1916.43 399.41 1904.71 1946.14 97.34 99.17 32.21 9024.81 1947.81 394.01 1936.28 1975.96 98.14 99.13 32.26 9020.46 1979.19 388.92 1967.84 2005.90 98.18 99.94 30.25 9016.17 2008.55 383.96 1997.37 2033.94 98.55 98.80 33.02 9011.36 2040.60 378.64 2029.60 2064.62 67.36 2.70 68.02 1.01 68.68 3.02 69.32 0.94 69.94 0.95 70.55 1.61 71.14 2.61 71.72 1.90 72.28 7.04 72.86 2.13 73.40 2.85 73.93 2.22 74.45 2.91 74.96 4.42 75.46 1.52 75.97 4.35 76.45 0.59 76.91 4.93 77.38 9.31 77.79 11.72 78.16 11.78 78.50 8.35 78.82 2.48 79.12 2.65 79.43 3.59 BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS • [(0)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 10-Oct-2006 07:50:32 Page 7 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (f t) (ft) (f t) (ft) (ft) (deg) 100f) type (deg) 151 10860.03 97.66 97.96 31.80 9006.88 2071.58 374.06 2060.74 2094.42 79.71 3.83 BP _MWD+IFR+MS 152 10891.10 96.16 99.62 31.07 9003.14 2101.90 369.34 2091.22 2123.59 79.98 7.17 BP _MWD+IFR+MS 153 10923.74 96.34 98.88 32.64 8999.59 2133.74 364.13 2123.2$ 2154.24 80.27 2.32 BP _MWD+IFR+MS 154 10956.00 96.44 98.60 32.26 8996.00 2165.26 359.26 2154.93 2184.68 80.54 0.92 BP _MWD+IFR+MS 155 10988.09 96.46 98.79 32.09 8992.39 2196.61 354.44 2186.45 2215.00 80.79 0.59 BP MWD+IFR+MS 156 11020.17 96.72 99.30 32.08 8988.71 2227.90 349.43 2217.93 2245.28 81.05 1.78 BP _MWD+IFR+MS 157 11052.03 96.88 100.26 31.86 8984.94 2258.89 344.05 2249.10 2275.27 81.30 3.03 BP _MWD+IFR+MS 158 11084.50 97.11 100.23 32.47 8980.98 2290.41 338.32 2280.82 2305.77 81.56 0.71 BP _MWD+IFR+MS 159 11116.16 97.27 100.59 31.66 8977.02 2321.11 332.64 2311.71 2335.52 81.81 1.24 BP _MWD+IFR+MS 160 11147.44 97,34 100.03 31.28 8973.04 2351.44 327.09 2342.24 2364.96 82.05 1.79 BP MWD+IFR+MS 161 11178.87 97.59 100.24 31.43 8968.96 2381.93 321.61 2372.91 2394.61 82.28 1.04 BP _MWD+IFR+MS 162 11210.95 98,15 100.43 32.08 8964.57 2413.00 315.91 2404.17 2424.84 82.51 1.84 BP MWD+IFR+MS 163 11242.55 97.99 100.34 31.60 8960.13 2443.57 310.27 2434.95 2454.64 82.74 0.58 BP _MWD+IFR+MS 164 11273.83 97.57 101.10 31.28 8955.90 2473.83 304.50 2465.40 2484.13 82.96 2.76 BP _MWD+IFR+MS 165 11306.36 97.40 100.75 32.53 8951.66 2505.29 298.39 2497.07 2514.83 83.19 1.19 BP MWD+IFR+MS 166 11337.74 97.26 101.28 31.38 8947.66 2535.63 292.44 2527.62 2544.48 83.40 1.73 BP _MWD+IFR+MS 167 11369.33 97.19 100.86 31.59 8943.68 2566.18 286.43 2558.37 2574.36 83.61 1.34 BP _MWD+IFR+MS 168 11401.02 97.20 101.07 31.69 8939.71 2596.84 280.45 2589.24 2604.38 83.82 0.66 BP _MWD+IFR+MS 169 21433.25 95.41 103.93 32.23 8936.17 2627.88 273.51 2620.51 2634.75 84.04 10.42 BP _MWD+IFR+MS 170 11465.49 92.21 106.99 32.24 8934.03 2658.59 264.94 2651.51 2664.71 84.29 13.72 BP MWD+IFR+MS 171 11497.44 89.39 107.83 31.95 8933.59 2688.75 255.38 2681.99 2694.12 84.56 9.21 BP _MWD+IFR+MS 172 11529.04 85.80 108.95 31.60 8934.91 2718.37 245.42 2711.94 2723.03 84.83 11.90 BP _MWD+IFR+MS 173 11560.65 84.41 113.51 31.61 8937.61 2747.34 234.02 2741.29 2751.26 85.12 15.03 BP _MWD+IFR+MS 174 11593.15 84.45 116.03 32.50 8940.77 2776.26 220.47 2770.66 2779.42 85.45 7.72 BP _MWD+IFR+MS 175 11625.04 84.71 116.40 31.89 8943.78 2804.29 206.44 2799.14 2806.74 85.78 1.41 BP MWD+IFR+MS 176 11657.09 88.31 117.86 32.05 8945.73 2832.27 191.86 2827.61 2834.11 86.12 12.12 BP _MWD+IFR+MS 177 11689.03 89.13 118.24 31.94 8946.44 2859.96 176.84 2855.79 2861.26 86.46 2.83 BP _MWD+IFR+MS 178 11720.82 89.44 115.69 31.79 8946.84 2887.82 162.43 2884.12 2888.69 86.78 8.08 BP _MWD+IFR+MS 179 11753.09 88.52 119.10 32.27 8947.41 2915.98 147.59 2912.76 2916.50 87.10 10.94 BP _MWD+IFR+MS 180 11784.66 89.82 116.16 31.57 8947.87 2943.46 132.95 2940.72 2943.73 87.41 10.18 BP MWD+IFR+MS [(0)2006 IDEAL ID10 2C O1] } SCHLUMBERGER Survey Report 10-Oct-2006 07:50:32 Page 8 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 181 11816.34 88.90 119.56 31.68 8948.22 2970.98 118.15 2968.72 2971.07 87.72 11.12 BP _MWD+IFR+MS 182 11847.83 90.03 120.30 31.49 8948.52 2997.76 102.44 2996.01 2997.76 88.04 4.29 BP _MWD+IFR+MS 183 11880.37 90.18 119.67 32.54 8948.46 3025.41 86.18 3024.20 3025.43 88.37 1.99 BP _MWD+IFR+MS 184 11911.91 89.62 120.22 31.54 8948.51 3052.23 70.43 3051.53 3052.34 88.68 2.49 BP _MWD+IFR+MS 185 11942.88 89.74 119.39 30.97 8948.69 3078.60 55.04 3078.40 3078.89 88.98 2.71 BP MWD+IFR+MS 186 11975.55 89.51 117.70 32.67 8948.90 3106.78 39.43 3107.10 3107.35 89.27 5.22 BP MWD+IFR+MS 187 12007.21 90.92 119.87 31.66 8948.78 3134.03 24.18 3134.84 3134.94 89.56 8.17 BP _ _MWD+IFR+MS 188 12038.56 88.36 117.26 31.35 8948.98 3161.07 9.20 3162.37 3162.38 89.83 11.66 BP _MWD+IFR+MS 189 12071.02 84.28 119.44 32.46 8951.06 3189.07 -6.18 3190.87 3190.88 90.11 14.24 BP _MWD+IFR+MS 190 12102.29 83.34 120.27 31.27 8954.43 3215.52 -21.65 3217.83 3217.91 90.39 4.00 BP MWD+IFR+MS 191 12133.52 83.60 120.13 31.23 8957.98 3241.83 -37.26 3244.65 3244.86 90.66 0.94 BP _MWD+IFR+MS 192 12165.49 81.04 120.45 31.97 8962.26 3268.66 -53.24 3272.01 3272.44 90.93 8.07 BP _MWD+IFR+MS 193 12198.13 78.13 121.86 32.64 8968.16 3295.59 -69.85 3299.47 3300.21 91.21 9.88 BP _MWD+IFR+MS 194 12230.42 77.88 121.45 32.29 8974.87 3321.94 -86.42 3326.36 3327.48 91.49 1.46 BP _MWD+IFR+MS 195 12263.12 77.81 121.21 32.70 8981.75 3348.70 -103.04 3353.67 3355.25 91.76 0.75 BP MWD+IFR+MS 196 12282.24 77.50 121.95 19.12 8985.84 3364.30 -112.82 3369.58 3371.47 91.92 4.11 BP _MWD+IFR+MS 197 12330.00 77.50 121.95 47.76 8996.18 3403.06 -137.50 3409.14 3411.91 92.31 0.00 Projected to TD [(c)2006 IDEAL ID10 2C O1] • Ssh~m~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503.2838 ATTN: Beth Wpll .Inh ~f !^"~~ ~ ~ -, ~.. ~'~ 1g,~~.~,.-,ti ~~ . , ., a~ RY~rags8~s; L~~yjr? 1 .... 1'1.. wH.. N0.4018 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 10/24/06 L-04 11212895 SCMT 10/18/08 v 1v~ vV L-04 N/A SCMT 10/21/06 1 L-04 11422897 USIT 10/10/06 1 F-12 11434752 USIT 10/19/06 1 X-28 N/A USIT 10/20/08 1 AGI-10 N/A USIT 10/23/06 1 of owes wnvunun ~ni.c n .,.... .... BP Exploration (Alaska) Inc. y Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: .+••....c ..,....n.v v..c vvr • cra,.n . v. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN; Beth Received by: • • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No L-04 Installation/Rig Nabors-9ES Dispatched To: Helen Warman (AOGCC) Date Dispatched: 18-Oct-06 Dispatched By: Emil Guliyev Data No Of Prints No of Flo ies Surveys 2 1 Please sign and return to: dames H. Johnson R2C@IVed By: ~ BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) O ~a~ p 900 E. Benson Blvd. I~D_ Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@bp.com LWD Log Delivery V1.1, 10-02-03 L-04i FIT ~ ~ ~ ~ ~ ,~ Subject: L-04i FIT From: "Peltier, Brandon" <Brandon.Peltier@bp.com> Date: Mon, 11 Sep 2006 13:26:52 -0800 To: winton_aubert@admin.state.ak.us Winton I noticed that on page 2 of the PTD for L-04i, that I indicated we will perform a LOT. This will actually bean FIT, as I have stated on pages 8 and 9. Please fet me know if you need further clarification or explanation. Thank you. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907} 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon. Peltier@bp.com 1 of 1 9/11/2006 2:08 PM _~ kk 5 ~~ ~~~~ ~~ ~~.4 ~y~N~~: gd~Vj~ ~~ ~~a~~ ~:. pit f~~~~ ~, @ f,3 5 ~.y ~ ::_~ : ~~ (~ ~. ~' ~ _~ ~. _ -~ ~ (c, ~- ~ ~ ~ ~ u ~ d ~. ~. FRANK H. MURKOWSKI, GOVERNOR ~~ ~ ~+ u' ~~ ~~ ~ ~ ~, 333 W. T" AVENUE, SUITE 100 COI~TSFiRQA'I'IO1~T CU1-II-iISSIUI~T ~•~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU L-04i BP Exploration (Alaska) Inc. Permit No: 206-120 Surface Location: 2380' FSL, 3714' FEL, SEC. 34, T12N, Rl lE, UM Bottomhole Location: 2474' FSL, 715' FEL, SEC. 34, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907)fz~`~-3607 (pager). DATED this day of August, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 RE1~~-Loot AUG 0 9 2006 Alaska Oil & Gas Cons. Commissi~R 1 a. Type of work ® Drill ^Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is pro t?18 QC ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L-04i 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11871 TVD 8977 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2380' FSL 3714' FEL T12N SEC 34 R11E UM 7. Property Designation: ADL 028239 Pool , , . , , , Top of Productive Horizon: 2983' FSL, 3218' FEL, SEC. 34, T12N, R11E, UM 8. Land Use Permit: 13. Approximate Sp Dat Augus 25, 06 Total Depth: 2474' FSL, 715' FEL, SEC. 34, T12N, R11 E, UM 9. Acres in Property: 2560 14. Distance to N rest Property: 8,700' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583203 y-5978102 Zone-ASP4 10. KB Elevation Plan (Height above GL): 76,5 feet 15. Distance to Nearest Well Within Pool: 1,080' 16. Deviated Wells: Kickoff Depth: 3900 feet Maximum Hole An le: 97 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4000 Surface: 3106 18 Casin P ram: S ecificatio ns To -'Seth ih - Bo om uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD ND MD ND includin sta a data 42" 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BRC .2742' Surface Surface 2742' 2742' 446 sx ASLite 402 sx Class 'G' 8-3/4" 7" 26# -80 TC-II 942' Surface urface 3942' 3942' sx LiteCrete ~t'sx Class 'G' Z/ 8-3/4" 7" 26# L-80 BTC-M 5252' 3942' 3942' 9194' 8687' x LiteCrete 184 sx Class'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2827' 9044' 8572' 11871' 8977' 314 sx Class 'G' Z9o sK 19. PRESE NT 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): Easing kength: ize GemenYVolume MD D Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Brandon Peltier, 564-5912 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Si nature / Phone 564-4166 Date CF Terrie Hubble, 564-4628 Commission: Use Onl Permit To Drill Number: `~.Z~ API Number: 50-02p-~ .Z 3319 Permit Approval See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ~n =~/ C.Z.IM-~Pi•~t_f ~,~,i; L o y'~ wt ~ 0 ,Samples Req'd: Yes ~No Mud Log Req'd: ^ Yes ~No ~~--~ S~ ~3 0 Q C- ..~.Y A ~ ~ ~ S~ , ~ HZS Measures: Yes ^ No irectional Survey Req'd: Yes ^ No Other. ~rsucwcr~- {~ ~ ~C Z5. 03 s LGL) (~) a.~~r~-2 Y~oPE ~Sf" L~ ~ i S ~r~ rle~(. APPROVED BY THE COMMISSION Date ~ d Q ,COMMISSIONER ~r1G!} Form 10-401 Revised 12/2005 O ~ ~ ~ ./ / ~/ Submit In Duplicate 1(V`~ A L • Well Name: L-04i Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Injector ~ Tar et X Y Z TVDss Section Townshi Ran a FSL FEL Surface As-built 583203 5978102 NA 34 12N 11 E 2380 3714 T t1: TSGR 583690 5978710 8600 34 12N 11 E 2983 3218 T t2: TSAD 584176 5978716 8860 34 12N 11 E 2977 2733 BHL: 46P 586200 5978230 8900 34 12N 11 E 2474 715 AFE Number: PBDxxxxxx Ri Nabor 9ES Estimated Start Date: August 25, Operating days to complete: 25 2006 MD 11871' TVD rkb: 8977' Max Inc. 97° RTE 76.5' Well Design: USH Grassroots Ivishak Horizontal Injector. 4-'/z" L-80 TC-II com letion. General Well Information Distance to Nearest Property Line: Distance to Nearest Well in Pool: Well Type: API Number: Current Status: Conductor: Estimated BHP: Estimated BHT: Materials Needed 8,700 ft to the Sou~west 1080 ft from L-50 Developement -Ivishak Horizontal Injector TBD New well. The conductor is set. The conductor is set. 402~~psi, 8.6 ppg EMW at 9000 ft TVDss ~O deg Fat 9000 ft TVDss urface Casing: 2,742' 9-5/8", 40#, L-80 BTC Casing 1 each 9-5/e", BTC Float Shoe and Float Collar 1 each 9-5/e", 40#, BTC Type TAM Port Collar 25 each 9 5/e" x 12 ~/a" Bow Spring Centralizers 1 assembly FMC 11" 5m Gen 5 Wellhead System 1 lot 9-5/e" casing pups 5', 10', 20'. ntermediate Casing: 5053' 7" 26# L-80 BTC-M Casing 4241' 7" 26# L-80 TC-II Casing 1 each 7" BTC-M Float Shoe and Float Collar 140 each 7'/e" x 8 Ya" Rigid Straight Blade Centralizers 2 lots 7" casing pups 5', 10', 20' 1 each 7" Halliburton ES Cementer (with plugs) roduction Liner: 2827' 4-'/z", 12.6#, L-80, IBT-M Solid Liner 100 each 4 5/e" x 5-3/a" Straight Blade Centralizers 1 each 7" x 4'/2" Baker FLEXLOCWZXP Liner Top Hanger/Packer (HR running tool) 1 assembly Baker Liner Cementing Assembly l L-04i Permit application Page 1 • • 1 lot 4-'h", 12.6#, L-80, IBT-M; 10' Solid Short Joints -80 Completion: 9044' 4-'/2" 12.6 Ib/ft, L-80, TC-II 1 each 7" X 4-~/z" Baker S-3 Packer 3 each 4-'/2" Halliburton X-Nipple (3.813" Packing Bore) 1 each 4-~/z" Halliburton XN-Nipple (3.813" Packing Bore) 1 each 11" X 4-'/z" FMC tubing hanger 1 each 4-'/is", 5m Cameron Tree with LEO Actuator 1 each 4-'/z" L-80 Standard Half Muleshoe WLEG Well Control: Surface hole will be drilled with a diverter. The intermediate and production hole sections will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Due to anticipated surface pressures exceeding 3,OOOpsi it will be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Section Kick Toler; • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • Surface Casing TOC: • Leak Off Test - 8-3/4" hole: once and Integrity Testing 3,900 psi -Top Sag River (8.7 ppg EMW C~ 8610' TVDss) 3,039 psi -Based on a full column of gas C«2 0.10 psi/ft 4,000 psi/250 psi Rams 2,500 psi/250 psi Annular 4,000 psi The surface casing will be cemented to surface LOT 20' - 50' from 9 5/8" shoe • Kick Tolerance: Calculated '41.,~ bbl KT with a 10.6 ppg mud with 12.5 ppg LOT ~._ Production Section Kick Tolerance and Integrity Testing • Maximum anticipated BHP: 4,000 psi - Ivishak 44P (8.6 ppg @ 8935' TVDss) • Maximum surface pressure: 3,106 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 4,000 psi/250 psi Rams 2,500 psi/250 psi Annular • 4'/z" Casing Test: 4,000 psi • Intermediate Casing TOC: The 7" casing will be cemented to 500' MD above the Ma sand • Integrity Test - 6-'/a" hole: LOT 20' - 50' from 7",shoe • Kick Tolerance: Calculated an'Infinit~KT with a 9.0 ppg mud with 11.0 ppg LOT • Planned completion fluid: Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Surface and Anti-Collision Issues: Surface Shut-in Wells: L-109 and L-116 will need to be shut-in for the rig move on and off L-04i. Close Approach Shut-in Wells: No wells will require subsurface shut-in during drilling operations. Risk Basing: All wells have passed the major risk scan L-04i Permit application Page 2 • • Close Approach Well List (Center to Center distance <100'): Well Name Ctr-Ctr Distance ft Reference MD ft Allowable Deviation ft Precautionary Comment L-01 59 635 48 Use Travelin C tinder G ro L-03 86 498 76 Use Travelin C tinder G ro L-107 72 169 68 Use Travelin C tinder G ro) L-109 15 495 5 Use Travelin C tinder G ro) L-110 61 464 52 Use Travelin C tinder G ro L-116 32 760 20 Use Travelin C tinder G ro) L-121 92 385 85 Use Travelin C tinder G ro) See directional plan (P6) for ful l list of offset wells. Surface and Anti-Collision Issues Well name wellhead Current Production Precautions/Risk Separation status Priority Based Information L-01 55.5' Producing 600 BOPD NA L-1091 15 Injecting High Shut-in and remove wellhouse L-116 30 Producing 700 BOPD Shut-in and remove wellhouse wells within a'/a mile of this infection well from the top of the reservoir to TD Mud Program 12 ~/a" Surface Hole Mud Pro erties: 0 - 2,742' Spud -Freshwater Mud (LSND) Interval /Densit De th Funnel vis YP PH Plastic Vis FL Initial-BPRF 8.8-9.2 0-1767 300 50-70 9.0-9.5 20-45 NC-8 BPRF-TD 9.0-9.5 1767-2742 200-300 45-60 9.0-9.5 20-40 <7.5 Interval TD < 9.5 2742 200 - 225 40 - 45 9.0 - 9.5 14 - 20 < 7.5 _ Interval Specific Provide adequate viscosity to clean and stabilize the hole Objectives: Ensure fluid loss below permafrost is below 7.5 Maintain mud tem erature below 60 F 8 3/a" Intermediate Hole Mud Pro erties: 2,742' - 9,194' Freshwater Mud LSND PH: 9.0 - 9.5 Interval /Densit De th Funnel vis YP PV API Filtrate MBT Initial 8.8 2742 - 2792 45 20 12 4 < 15 U nu / Colville ;3:2 2792 - 6375 45 - 60 20 - 26 12 - 18 4 - 7 < 15 THRZ -TMLV ,10.6 6375 - 7112 40 - 50 18 - 25 14 - 22 HTHP < 10 < 20 TMLV-TD ;10.6 7112-9194 40-50 18-25 14-22 HTHP<10 <20 Maintain wellbore stability with MW and "black product" additions Interval Specific Maintain proper fluid rheology & lubricant concentration to achieve the directional Objectives: requirements Optimize mud rheology to maximize ROP while following ECD guidelines Reduce shaker blindin while drillin the UGNU EMI 697 L-04i Permit application Page 3 • • 6'/e" Production Hole Mud Pro erties: 9,194' -11,871' FloPro-NT PH: 8.5 - 9.0 Density (ppg) LSRV YP MBT PV HTHP @235° LG Solids Initial 9.0 >20,000 22 - 32 < 3.0 5 - 8 < 8 <3 Minimize solids/liquid invasion by maintaining optimum theology and utilizing an NT system. Interval Specific Maintain minimal ECD's by reducing drill solids accumulation through utilization of Objectives: the rigs solids control system and effective dilution. Maintain fluid properties to provide efficient hole cleaning and reasonable torque and dra conditions hvaraui~cs: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA (in ) GPM Pipe (fpm) ppg-emw ("/32) 0-1767' 550 4" 15.7# 90 1800 10.0 N/A 18,18,18,16 .942 1767'-2742' 650 4" 15.7# 110 2400 10.2 N/A 18,18,18,16 .942 Production Hole: 8-3/a" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA (in ) GPM (fpm) ppg-emw ("/32) 2742'-9194' 550 4" 15.7# 215 3500 TBD N/A TBD TBD Production Hole: 6-1/8" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA (in ) GPM (fpm) ppg-emw ("/32) 9194'-11871' 275 4" 15.7# 275 2800 TBD N/A TBD TBD Casina/Tubina Praaram~ Hole Size Csg/ Tb O.D. ~ Wt/Ft Grade Conn / Length Top MDRVD Btm MD/TVD 42" Insulated 20" 91.5# H-40 WLD 80' GL 110'/110' 12-~/a" 9-5/8" 40# L-80 BTC 2742. GL 2742/2742 8-3/a" 7" 26# L-80 TC-II 3942 GL 3942/3942 8-3/a" 7" 26# L-80 BTC-M 5252 3942/3942 9194/8687 6-%8' 4-'/z" 12.6# L-80 IBT-M 2827 9044/8572 11871/8977 Tubin 4-'/z" 12.6# L-80 TC-II 9044 GL 9044/8572 5urvev and Loaginq Program: 12-'/a" Hole Section: Surface Gyro until MWD surveys are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-3/a" Hole Section: Sample as required by well site Geologist MWD /LWD: GR/RES/PWD real time O en Hole: None Cased Hole: USIT -log from 7" shoe to surface casing shoe '' 6-'/8" Hole Section: Sample as required by well site Geologist L-04i Permit application Page 4 • • MWD / LWD: GR/RES real time for entire interval and Den/Neu (recorded) for Sag River only O en Hole: None Cased Hole: Optional SCMT depending on production cement job Cement Calculations Casin Size 9 5/6-in 40-Ib/ft L-80 BTC -Single Stage Basis 250% excess over gauge hole in permafrost interval, 40% excess over gauge hole below perm s Total Cement Volume: Tam Port collar located at 1,000' as a contin enc for cement to rfa Wash 10 bbls CW100 S acer 75 bbls of ~ sh II wei hted to 10.10 Lead 353 bbls s 10.7 Ib/ al Arctic Set Lite cement - 4 ft/sk Tail 83 bbls 4 sks 15.8 Ib/ al Class G + DURASTONE - .17~uft/sk Tem BHST = 80° F from SOR, BHCT 60° F In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size 7" 26 Ib/ft L-80 BTC-M x TC-II -Two Sta e Basis 30% excess over gauge hole A Sta a Tool will be laced at the base OBf at 4700' MD Total Cement Volume: 1 Stage : TOC (tail at 819 ' ) 1,000' MD above the 7" shoe TOC (lead at 0 ' D) ES cementer at base OBf Wash None S acer 30 bbl of USH XL S acer wei hted to 11-Ib/ al Lead 122 bbl s 11.5 LiteCRETE + Latex + Silica - 3 ft/sk; Tail 38 bbl 1 ks 15.8 ss G cement + Latex - 1.1 cuft/sk 2" Stare : TOC tail ,442' MD 500' MD above the Ma Wash 15 bbl Freshwater S acer 40 bbl of MUDPUSH XL S acer wei hted to 11-Ib/ al Lead NA .., _ _, Tail 44 bbl 1 ks 15.8 Class G cement + Latex 1.1 uft/sk - Tem BHST = 230° F for first sta e, BHST = 145° F for second sta e Casin Size 4-'/z" 12.6 Ib/ft L-80 IBT-M -Solid Liner Basis 30% excess + 200' MD above the top of the Liner Top Packer + 150' of liner lap + 80' of shoe. TOC: Liner To Packer ~ 9044' MD Total Cement Volume: Wash 20 bbls CW100 S acer 30 bbls of d ush II Wei hted to 12.5 Tail 67 bbls ( 14 ks) 15.8 Ib/gal Class G Cement (Gasblok and Silica) - .5 cuft/sk - -- Temp BHST ~ 230° F from SOR, BHCT xxx° F estimated by Dowell 9 5/e" Casing Centralizer Placement a) Run (25) 9 5/e" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 1,742' MD (1,000' MD above the shoe). b) Run 2 bow-spring centralizers, one on either side of a TAM Port Collar, if run. 7" String Centralizer Placement L-04i Permit application Page 5 • • a) Place 2 centralizers rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, alternate 1 rigid straight blade centralizer floating across a full joint and 2 rigid straight blade centralizers, one floating on the upper half of the joint and one floating on the lower half of the joint separated by a stop collar. Run these centralizers from TD (note exception above) to 500' over Ma sands. Zonal isolation with cement is required across the Kuparuk and Schrader sands. The centralizer program is subject to change pending hole conditions. 4'/z" Solid Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint, floating between the collars. Formation To s TVDss and Estimated Pore Pressures Est: Formation Tops (WP 6) Est. Formation To s Uncertab~ Commercial Hydrocarbon Bearin Est Pore Press_ Est. Pore Press. Formation (M©~ TVDss feet Yes/No Psi EMW G1 337 -260 +/-20' No 117 8.7 SV6 962 -885 +/-20' No 398 8.7 Fault #1 1377 -1300 +/-100 No 585 8.7 EOCU 1407 -1330 +/-30' No 599 SV5 1537 -1460 +/-30' No 657 8.7 SV4 1667 -1590 +/-30' Gas H dr. 716 8.7 BPRF 1767 -1690 +/-30' Gas H dr. 761 8.7 SV3 2017 -1940 +/-30' Gas H dr. 873 8.7 SV2 2177 -2100 +/-30' Gas H dr. 945 8.7 SV1 2502 -2425 +/-30' Gas H dr. 1091 8.7 9-5/8" Surf Casin 2742 -2665 UG4 2792 -2715 +/-30' Thin Coal 1260 8.9 UG4A 2822 -2745 +/-30' Yes -Hea Oil 1280 9.0 UG3 3157 -3080 +/-30' No -Coals and wet sds 1386 8.7 UG1 3632 -3555 +/-30' Yes -Minor Hea Oil 1600 8.7 Ma 3942 -3865 +/-30' Yes -Minor Hea Oil 1750 8.7 Mb1 3982 -3905 +/-30' No 1765 8.7 Mb2 4052 -3975 +/-30' n/a 1790 8.7 Mc 4147 -4070 +/-30' Yes -Minor Hea Oil 1820 8.6 Na 4187 -4110 +/-30' No 1865 8.7 Nb 4213 -4135 +/-30' No -Wet sds 1870 8.7 Nc 4238 -4160 +/-30' No 1895 8.8 OA 4335 -4255 +/-30' No -Wet sds 1915 8.7 OBa 4402 -4320 +/-30' No -Wet sds 1940 8.6 OBb 4449 -4365 +/-30' No -Wet sds 1960 8.6 OBc 4506 -4420 +/-30' No -Wet sds 1980 8.6 OBd 4558 -4470 +/-30' No -Wet sds 2000 8.6 OBe 4626 -4535 +/-30' Yes 2030 8.6 OBf 4667 -4575 +/-30' Yes 2045 8.6 L-04i Permit application Page 6 • OBf_Base 4714 -4620 +/-30' No 2060 8.6 Fault #2 4902 -4800 +/-100' CM-2 4874 -4870 +/-30' CM-1 5734 -5600 +/-30' n/a THRZ 6375 -6215 +/-30' n/a TKLB 6595 -6430 +/-30' K_1 6636 -6470 +/-30' Yes TKD 6701 -6535 +/-30' Yes 3400 9.9 TKC4 6716 -6550 +/-30' Yes 3400 9.9 LCU 6888 -6720 +/-30' n/a TMLV 7112 -6940 +/-30' n/a Fault #3 7180 -7005 +/-100' TKNG 7882 -7605 +/-30' TJ F 7887 -7685 +/-30' n/a TJ E 8372 -7980 +/-30' TJD 8548 -8115 +/-50' TJC 8688 -8230 +/-30' Fault #4 8842 -8340 +/-100' TJB 8933 -8410 +/-30' n/a TJA 8018 -8475 +/-30' TSGR - T t 1 8181 -8600 +/-30' Yes 3880 8.7 To Sa 9194 -8610 +/-30' 7" Int Casing Point 9194 -8610 TSHUA 8247 -8650 +/-30' n/a TSHUB 9360 -8725 +/-30' TSHUC 9394 -8745 +/-30' TSHUD 9431 -8765 +/-30' TEIL 9473 -8785 +/-30' n/a TSAD (46P) - T t 2 9754 -8860 +/-30' Yes 3899 8.5 45P 9939 -8890 +/-30' Yes 3915 8.6 POWC 10154 -8925 +/-30' 44P 10216 -8935 +/-30' Yes 3932 8.6 43P 10437 -gg71 +/-30' Invert - T t 3 10662 -9000 +/-30' 43P -8975 +/-30' 44P -8947 +/-30' 45P -8918 +/-30' Tgt 4 -mid 46P downthrown 11419 -8910 +/-30' Tgt 6 - BHL - 46P 11871 -8900 +/-30' Comments: TD in upper zone 46P according to directional plan. 1. Sag river pressure based on offset well L-50 11/12/05 static pressure of 3842 psi at 8500 MD. 2. Offset L-01 Ivishak pressure of 3872 psi, 238 F, at 8800 TVDSS (8.5 ppg EMW) 3. Note that L-04i passes within 476 feet from L-111 i Kuparuk injector. Some potential for higher pressures. However, well L-50 drilled within 222' of the well with no apparent problem. L-04i Permit application Page 7 • Drilling Hazards and Contingencies -POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: Interval Tf? Psi TVDss! ~ - Comments _ Schrader 2,060 8.6 4,620 NA Ku aruk 3,400 9.9 6,550 NA Ivishak 3,932 8.6 8,935 Based on L-01 offset well ressures Hydrates and Shallow gas: Gas Hydrates are expected at L-pad near the base of the permafrost. Setting casing through the SVi should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. III. Lost Circulation /Breathing: Lost circulation is considered moderate at the faults in the intermediate hole section. The Shublik phenomenon could occur on this well, however all lessons learned have been applied within the plan to mitigate this potential. Follow the RP guidelines for dealing with it if it occurs. IV. Kick Tolerance /Integrity Testing: The 9 5/8" casing will be cemented to surface. The 7" casing will be cemented to 500' MD above the Ma sand. NOTE: If the LOT /FIT is less then the minimum notify the ODE immediately Kick Tolerance ! Inte ri Testin Summa Table ... _ _ . Casfn / Interval Acce table Influx Volume Mud Wei ht Ex Pore Press Min LOT /FIT Surface / 8-3/a" 41.7 / 25.4 10.6 9.9 Ku aruk 12.5 / 11.6 LOT Intermediate / 6-%8" Infinite 9.0 8.6 11.0 FIT NOTE: All LOT /FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the previous casing string L-Pad development wells may have "kick tolerances" in the 25 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. V. Stuck Pipe There could be slight differential sticking across the open hole while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at L pad as a result of the use of Ivishak gas lift gas. All L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the water flood matures. H2S Summa Table Well Name H2S Level Date of Readin #1 Closest SHL Well H2S Level L-01 10 m 4-Nov-2004 #2 Closest SHL Well H2S Level L-109i 10 m ossible NA #1 Closest BHL Well H2S Level L-01 10 m 4-Nov-2004 #2 Closest BHL Well H2S Level L-03 10 m ossible NA VII. Faults F utt Location ~`` MDt . -,=-TVDss . Thruw~ ~ . f9irection '.. ' Wncertain ' Fault #1 - SV6'L Pad' Fault 1377 1300 50 West +/- 100' MD Fault #2 -Colville, above CM2 4902 4800 65 North +/- 100' MD Fault #3 - Miluveach 7180 7005 190 South +/- 100' MD Fault #4 - TJC 8842 8340 80 West +/- 100' MD L-04i Permit application Page 8 • • CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION L-04i Drill and Complete Procedure Summary Pre-Riq Work: 1. A 20" conductor has been set. Weld a landing ring for the USH Gen 5 well head. 2. If necessary, level the pad and prepare location for rig move. Move well houses as necessary. Riq Operations: 1. MIRU Nabors 9ES. NU diverter spool & riser and function test. PU 4" DP as required and stand back in derrick. ~ 2. MU 12'/a" drilling assembly with MWD/GR and directionally drill surface hole to TD at 2742' md. The TD will be +/-240' TVD below the top of the SV1 sand. This section will be drilled w/one BHA as there is no directional work required in the surface hole. Short trip as necessary. 3. Run and cement the 9-5/e", 40#, L-80, BTC surface casing baekto surface. A TAM port collar will be placed at 1000' if hole conditions warrant. Use Durastone in the last 15 bbls of the tail cement. 4. ND diverter and riser. NU casing and tubing heads and test. NU BOPE and test to 4,000 psi. PU 4" DP as needed. 5. MU 8-3/a" drilling BHA with MWD / GR /RES / PWD and Ghost Reamer at 3841' from the bit. RIH to float collar. Test the 9-%" casing to 3,500 psi for 30 minutes. 6. Drill out shoe track. Circulate and condition mud. Displace well to new 8.8 ppg LSND drilling fluid. Drill 20' of new formation below rat-hole and perform a LOT. 7. Drill to +/-200' and above the HRZ, weight up mud to 10.6 ppg and perform short trip as needed. During this time hold the pre-reservoir meeting highlighting kick tolerance and detection (Kuparuk C~ 9.9 ppg EMW). 8. Directionally drill ahead to +/-200' and above the Kingak and ensure mud weight of 10.6 ppg. Continue drilling to TD maintaining sail angle & direction to the Top SAG at 9194' md. After TD, CBU, perform long trip to wipe the Kingak. 9. POOH. Stand back 4" DP. Spot G-Seal across the UGNU/Schrader if losses are prevalent.. 10. MU and run 7" 26# L-80 BTC-m x TC-II long string casing to TD - DO NOT CIRCULATE DOWN CASING IN KINGAK, BRING PUMPS UP SLOWLY WHEN CONDITIONIN ~~ FOR CEMENT. Cement in two stages ~ to 500' MD above the Ma. The ES cementer will be placed at~~U-p',dnd. Freeze protect the 7" x 9 5/s" annulus w/dead crude to 2,200' TVD. X66 ~ WGrt~- 11. PU 6-%8" build BHA with a roller cone bit and MWD / GR /RES /Azm-Dens / Neu and RIH to the ES Cementer. Drill up the ES cementer, then RIH to the landing collar, then test the 7" casing to 4,000 psi for 30 minutes. 12. Drill out shoe track. Circulate and condition mud. Displace well to new 9.0 ppg Flo-Pro NT fluid. Drill 20' of new formation below rat hole and perform an FIT to 11 ppg EMW. Drill the 10.5 deg/100' DLS build section and land the well in the TSAD. MAD pass to acquire Neu/Azm-Dens logs across the Sag River. POOH. 13. PU 6-%e' drilling BHA with a PDC bit and MWD / GR /RES and RIH. Geo-steer through Zone 46 to TD (11871' md). Perform a wiper trip if needed, circulate and condition the mud. POOH laying down excess drill pipe. Stand back required DP and lay down BHA. 14. RU E-line and log USIT from landing collar to surface casing shoe or TOC, whichever is higher. Upload data to InterAct so that town engineers can evaluate log. 15. MU and run 4-'/2" 12.6# L-80 BTC-M solid liner to TD and cement (ensure 150' overlap). Displace cement with drilling fluid and spot a pert pill across the liner. PU off liner hanger and circulate and condition mud. Displace over to 9.0 ppg brine. 16. PU 2.875" PAC and 2.5" 4 spf PJ Omega tapered perforation assembly and pert 300' of liner in overbalance. POH, LD perf guns. 17. MU and run the 4-'/z" 12.6#, L-80, TC-II completion. See completion schematic and running detail. Land tubing hanger and test hanger pack-off to 5,000 psi. Reverse in brine with corrosion inhibitor to protect the annulus. Reverse in diesel freeze protect to 2000' md, allow to u-tube. Note: There will not be a circulating valve in the completion. 18. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 4,000 psi and annulus ~~' to 4,000 psi. Notify AOGCC of tubing and casing test. 19. Install a plug in the X-nipple at 2000' md. Note: The well will be under balanced at this point because of the diesel freeze protect. L-04i Permit application Page 9 • 20. Install TWC and test from above to 1,000 psi. ND the BOPE. NU and test the tree to 5,000 psi. 21. Pull TWC then install BPV. Secure the well and rig down /move off Nabors 9ES. Post-Rig Work: 1. MIRU slickline. Pull plug from X-nipple at 2000' md. Pull the ball and rod / RHC plug. 2. Conduct static survey. 3. CT TCP will occur over the next several months (separate AFE). L-04i Permit application Page 10 I 2741' i Prop~d CompletionL-04i ~'' XXXX' F-{9-5/8" TAM Port Collar 2000' 4-1/2' HES X Nipppls . ~' 3.813" I 9-5/8' CSG, 40f, L-80, ~ 8.835" I 7" ES Cementer, IDS xxx" I 4-1/2' L-80, 12.8 Ib/ft, TGA, ~ xxxx' ~- 4.5' VVLEG, ~ 3.958" 17" CSG, 28t, L-80, 0.0383 bPf, 108.276"1 I xxxx' 1 na I 9184' I PERFORATION SL~-RY REF LOG: ANGLEAT TOP PERF: xx• Nye: Refer to Production DB for F~atorical serf data SIZE SPF UYTEftVAL OpnfSgz DAATE 2.5" 4 Opn ~.~qo ± Mit"ymLliTl ID = )000' XN Nipples XXX' 4-1/2" X Nippk+ (3.813' ~ XXX' Baker S-3 Packer, 7' x 4.5" XXXX' ~' 9044' ~4-1/2" XN Nipple (3.813" I~ 5`x7' Lk~er top tacker w/ xx' Tieback Sleeve ~ 4-1/2", L-a,0. 12.61. IBT Mt3D ~ ]ATE REV BY COMIIB~CTS DATE REV BY CC81111ABVTS r/11/OB BJP R'oposed Completion Rev.1 t-1 /16" 5K GW V+/ELLHEAD= FMC ACTUATOR = L~ KB. ELEV = 28.5 BF. ELEV = xxx KOP = 3900 Mex Angle = 99• Q 10,741' Datum MD = xxxx' Datum ND = xxxx' 1 PRtr~HOE BAY UNIT WH.L: L-04i PERMIT No: xxxxx AR No: 50.029-xxxxx Sec Tier p ire ~ : , Variance Request Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Re uest The AOGCC is in the process of developing a guideline document clarifiing the intent of the regulations pertaining to function pressure testing ram type BOP's, BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement afiter the use of BOP ram type equipment for other than well control or equivalent purposes, ex_ cept when the routine use of BOP ram type equipment may have compromised their effectiveness, (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore..•.for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be fiunction pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent ofi its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (t)(2) TUBING WORKOVERS: 20 AAC 25.286(e)(i) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type equipment only, The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse _ofi operations. The regulations allowing a variance are at 20 AAC 25,035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h}... Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPS requirements in (e) of this section if the variance provides at least an equally effective means of well control; by Schiumberger L-04 (P6) Proposal Report Date: June 28, 2006 Survey 1 DLS Computation Method: Minimum Curvature / LulNnski Client: BP Exploration Alaska Vertical Section Azimuth: 88.180° Field: Structure 1 Slot: Prudhoe Bay Unit - WOA L-PAD / S-L ~ Vertical Section Origin: 'O6 ND Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table Well: Plan L-04 (S-L) O~ ND Reference Elevation: 76.50 ft relative to MSL Borehole: Plan L-04 ro ~~ Sea Bed 1 Ground Level Elevation: 48.00 ft relative to MSL UWIIAPI#: 50029 Magnetic Declinaton: 23.905° Survey Name 1 Date: L-04 (P6) /June 28, 2006 Total Field Strength: 57625.075 nT Tort 1 AND 1 DDI 1 ERD ratio: 155.396° / 4537.88 ft 15.965 / 0.500 Magnetic Dip: 80.887° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 10, 2006 Location La1lLong: N 70.35014174, W 149.32449105 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5978101.530 ftUS, E 583202.660 ftUS North Reference: True North Grid Convergence Angle: +0.63617416° Total Corr Mag North -> True North: +23.905° Grid Scale Factor: 0.99990786 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS Klt U.UU V.UU L/O.UU -/b.bU U .UU U.UU U.UU U.UU U.UU U.UU G1 336.50 0.00 275.00 260.00 336. 50 0.00 0.00 0.00 0.00 0.00 SV6 961.50 0.00 275.00 885.00 961. 50 0.00 0.00 0.00 0.00 0.00 Fault 1 Crossing 1376.50 0.00 275.00 1300.00 1376. 50 0.00 0.00 0.00 0.00 0.00 EOCU 1406.50 0.00 275.00 1330.00 1406. 50 0.00 0.00 0.00 0.00 0.00 SV5 1536.50 0.00 275.00 1460.00 1536. 50 0.00 0.00 0.00 0.00 0.00 SV4 1666.50 0.00 275.00 1590.00 1666. 50 0.00 0.00 0.00 0.00 0.00 Base Perm 1766.50 0.00 275.00 1690.00 1766. 50 0.00 0.00 0.00 0.00 0.00 SV3 2016.50 0.00 275.00 1940.00 2016. 50 0.00 0.00 0.00 0.00 0.00 SV2 2176.50 0.00 275.00 2100.00 2176. 50 0.00 0.00 0.00 0.00 0.00 SV1 2501.50 0.00 275.00 2425.00 2501. 50 0.00 0.00 0.00 0.00 0.00 9-5/8" Csg Pt 2741.50 0.00 275.00 2665.00 2741. 50 0.00 0.00 0.00 0.00 0.00 UG4 2791.50 0.00 275.00 2715.00 2791. 50 0.00 0.00 0.00 0.00 0.00 UG4A 2821.50 0.00 275.00 2745.00 2821. 50 0.00 0.00 0.00 0.00 0.00 UG3 3156.50 0.00 275.00 3080.00 3156. 50 0.00 0.00 0.00 0.00 0.00 UG1 3631.50 0.00 275.00 3555.00 3631. 50 0.00 0.00 0.00 0.00 0.00 KOP Bld 1.5/100 3900.00 0.00 275.00 3823.50 3900 .00 0.00 0.00 0.00 0.00 0.00 Ma 3941.50 0.62 275.00 3865.00 3941. 50 -0.22 0.23 0.23 0.02 -0.22 Mbl 3981.51 1.22 275.00 3905.00 3981. 50 -0.86 0.87 0.87 0.08 -0.87 Bld 3.5/100 4000.00 1.50 275.00 3923.49 3999 .99 -1.30 1.31 1.31 0.11 -1.30 Mb2 4051.56 3.30 277.43 3975.00 4051. 50 -3.44 3.47 3.47 0.37 -3.45 4100.00 5.00 278.12 4023.31 4099 .81 -6.89 6.97 6.97 0.84 -6.92 Mc 4146.93 6.64 278.45 4070.00 4146. 50 -11.57 11.73 11.73 1.53 -11.63 Na 4187.26 8.05 278.63 4110.00 4186. 50 -16.65 16.89 16.88 2.30 -16.73 U.UU 5y/tS1U1.5:S 5tfS1UC.titi N /U.S5U141/4 W 14y.3144y1U5 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 0.00 5978101.53 583202.66 N 70.35014174 W 149.32449105 1.50 5978101.55 583202.44 N 70.35014179 W 149.32449287 1.50 5978101.60 583201.79 N 70.35014195 W 149.32449808 1.50 5978101.63 583201.35 N 70.35014205 W 149.32450163 3.50 5978101.86 583199.21 N 70.35014274 W 149.32451904 3.50 5978102.30 583195.73 N 70.35014404 W 149.32454723 3.50 5978102.93 583191.02 N 70.35014592 W 149.32458544 3.50 5978103.64 583185.91 N 70.35014802 W 149.32462683 WeIlDesign Ver SP 2.1 Bid( doc40x_100) S-L\Plan L-04 (S-L)\Plan L-04\L-04 (P6) Generated 7/28/2006 11:08 AM Page 1 of 3 Comments Measured Inclination Azimuth Subsea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft RUS ftUS 4LVV.VU iSAU L/i5 .gl 41LZ .0U 4"I`JS1 .1U -1tl.45 125 ./Z 125 ./Z L.5/ -1tl .54 3.5U 5yR51U3.yU Nb 4212.54 8.94 278. 71 4135. 00 4211. 50 -20.32 20. 62 20. 62 2.86 -20. 42 3.50 5978104.16 Nc 4237.88 9.82 278. 78 4160. 00 4236. 50 -24.37 24. 75 24. 75 3.49 -24. 50 3.50 5978104.75 4300.00 12.00 278 .91 4220 .99 4297 .49 -35.93 36 .50 36 .50 5.30 -36 .11 3.50 5978106.43 OA 4334.85 13.22 278. 96 4255. 00 4331. 50 -43.40 44. 11 44. 10 6.48 -43. 63 3.50 5978107.52 4400.00 15.50 279 .03 4318 .12 4394 .62 -59.26 60 .26 60 .26 9.00 -59 .58 3.50 5978109.87 OBa 4401.96 15.56 279. 04 4320. 00 4396. 50 -59.78 60. 79 60. 78 9.09 -60. 10 3.50 5978109.95 End Bld 4417.91 16.12 279 .05 4335 .35 4411 .85 -64.06 65 .14 65 .14 9.77 -64 .40 3.50 5978110.59 OL3b 4448.78 16.12 279. 05 4365. 00 4441. 50 -72.47 73. 71 73. 71 11.12 -72. 86 0.00 5978111.84 OBc 4506.03 16.12 279. 05 4420. 00 4496. 50 -88.09 89. 61 89. 61 13.62 -88. 56 0.00 5978114.17 013d 4558.08 16.12 279. 05 4470. 00 4546. 50 -102.28 104. 07 104. 06 15.89 -102. 84 0.00 5978116.28 OBe 4625.74 16.12 279. 05 4535. 00 4611. 50 -120.73 122. 85 122. 85 18.85 -121. 39 0.00 5978119.03 OBf 4667.37 16.12 279. 05 4575. 00 4651. 50 -132.09 134. 42 134. 41 20.67 -132. 81 0.00 5978120.72 OBfBase 4714.22 16.12 279. 05 4620. 00 4696. 50 -144.86 147. 43 147. 42 22.72 -145. 66 0.00 5978122.63 Fault 2 Crossing 4901.59 16.12 279. 05 4800. 00 4876. 50 -195.96 199. 46 199. 45 30.90 -197. 04 0.00 5978130.24 CM2 4974.45 16.12 279. 05 4870. 00 4946. 50 -215.83 219. 69 219. 69 34.08 -217. 03 0.00 5978133.20 CM1 5734.34 16.12 279. 05 5600. 00 5676. 50 -423.07 430. 71 430. 71 67.28 -425. 42 0.00 5978164.08 Top HR2 6374.52 16.12 279. 05 6215. 00 6291. 50 -597.65 608. 49 608. 48 95.25 -600. 98 0.00 5978190.09 Crv 4/100 6397.18 16.12 279 .05 6236 .77 6313 .27 -603.83 614 .78 614 .77 96.24 -607. 20 0.00 5978191.01 6400.00 16.02 279 .21 6239 .48 6315 .98 -604.60 615 .56 615 .56 96.36 -607. 97 4.00 5978191.13 6500.00 12.42 286 .39 6336 .41 6412 .91 -628.37 640 .09 640 .03 101.61 -631. 91 4.00 5978196.10 TKLB 6595.30 9.30 298. 13 6430. 00 6506. 50 -644.78 657. 99 657. 50 108.13 -648. 54 4.00 5978202.44 6600.00 9.16 298 .91 6434 .64 6511 .14 -645.43 658 .74 658 .21 108.49 -649. 21 4.00 5978202.80 K-1 6635.77 8.15 305. 67 6470. 00 6546. 50 -649.89 664. 12 663. 17 111.34 -653. 76 4.00 5978205.60 6700.00 6.73 322 .35 .6533 .70 6610 .20 -655.71 672 .38 670 .05 116.98 -659. 76 4.00 5978211.17 TKD 6701.31 6.71 322. 76 6535. 00 6611. 50 -655.80 672. 53 670. 16 117.10 -659. 85 4.00 5978211.29 TKC4 6716.41 6.48 327. 63 6550. 00 6626. 50 -656.74 674. 26 671. 38 118.53 -660. 84 4.00 5978212.70 6800.00 6.22 358 .13 6633 .10 6709 .60 -659.15 683. 30 675. 57 127.04 -663. 51 4.00 5978221.18 LCU 6887.52 7.68 24. 81 6720. 00 6796. 50 -656.53 693. 70 675. 28 137.09 -661. 21 4.00 5978231.25 6900.00 7.99 27 .67 6732 .36 6808 .86 -655.73 695. 40 674. 85 138.61 -660. 46 4.00 5978232.79 7000.00 11.00 43 .92 6831 .00 6907 .50 -645.47 711. 79 668. 05 151.64 -650. 62 4.00 5978245.93 7100.00 14.49 52 .86 6928 .53 7005 .03 -628.43 733. 80 655. 41 166.07 -634. 02 4.00 5978260.54 TMLV 7111.86 14.92 53. 65 6940. 00 7016. 50 -625.96 736. 81 653. 54 167.87 -631. 61 4.00 5978262.36 Fault 3 Crossing 7179.54 17.42 57. 39 7005. 00 7081. 50 -610.08 755. 65 641. 39 178.50 -616. 06 4.00 5978273.16 7200.00 18.19 58 .32 7024 .48 7100 .98 -604.68 761 .90 637 .25 181.82 -610. 76 4.00 5978276.55 7300.00 21.99 61 .96 7118 .38 7194 .88 -574.34 796 .23 614 .03 198.83 -580. 94 4.00 5978293.88 7400.00 25.85 64 .57 7209 .78 7286 .28 -537.55 836 .76 586 .35 217.00 -544. 72 4.00 5978312.45 7500.00 29.74 66 .53 7298 .23 7374 .73 -494.51 883 .37 555 .05 236.24 -502. 27 4.00 5978332.16 7600.00 33.66 68 .08 7383 .30 7459 .80 -445.41 935 .91 521 .25 256.48 -453. 79 4.00 5978352.93 7700.00 37.59 69 .34 7464 .57 7541 .07 -390.50 994 .14 486 .49 277.59 -399. 52 4.00 5978374.64 End Crv 7761.14 40.00 70 .00 7512 .22 7588 .72 -354.18 1032 .44 465 .65 290.90 -363. 60 4.00 5978388.34 5i5:f7iS4.1U N /U.J5U1425// W 149.:i14fi4154 583182.21 N 70.35014955 W 149.32465679 583178.13 N 70.35015127 W 149.32468992 583166.49 N 70.35015621 W 149.32478421 583158.97 N 70.35015944 W 149.32484520 583142.99 N 70.35016634 W 149.32497471 583142.47 N 70.35016656 W 149.32497891 583138.16 N 70.35016843 W 149.32501384 583129.68 N 70.35017212 W 149.32508255 583113.96 N 70.35017895 W 149.325210 583099.66 N 70.35018516 W 149.32532s~ 583081.08 N 70.35019323 W 149.32547651 583069.64 N 70.35019820 W 149.32556920 583056.77 N 70.35020379 W 149.32567349 583005.30 N 70.35022615 W 149.32609062 582985.29 N 70.35023485 W 149.32625284 582776.56 N 70.35032551 W 149.32794456 582600.71 N 70.35040188 W 149.32936979 582594.49 N 70.35040458 W 149.32942024 582593.72 N 70.35040492 W 149.32942650 582569.72 N 70.35041924 W 149.32962091 582553.02 N 70.35043706 W 149.32975591 582552.35 N 70.35043805 W 149.32976128 582547.77 N 70.35044584 W 149.32979823 582541.71 N 70.35046124 W 149.32984694 582541.61 N 70.35046158 W 149.32984770 582540.61 N 70.35046546 W 149.3298557 582537.84 N 70.35048871 W 149.32987 582540.03 N 70.35051616 W 149.32985 582540.76 N 70.35052033 W 149.32985269 582550.46 N 70.35055593 W 149.32977276 582566.89 N 70.35059535 W 149.32963805 582569.29 N 70.35060027 W 149.32961847 582584.72 N 70.35062931 W 149.32949222 582589.98 N 70.35063840 W 149.32944922 582619.60 N 70.35068486 W 149.32920719 582655.61 N 70.35073450 W 149.32891314 582697.85 N 70.35078709 W 149.32856850 582746.10 N 70.35084237 W 149.32817495 582800.12 N 70.35090007 W 149.32773441 582835.89 N 70.35093642 W 149.32744281 WeIlDesign Ver SP 2.1 Bld( doc40x_100) S-L\Plan L-04 (S-L)\Plan L-04\L-04 (P6) Generated 7/28/2006 11:08 AM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft R k de 100 ft ftUS ftUS mIVU /ooL.L0 4U.UU /U.UU /OVJ.UU /00 LJV -L6U.L1 117 U.3U 43U.3L JI/AL -L`JV.44 U.VU OJ/0410./6 OOLJVO./4 IV /V.371UU`JI/ VV 14J.3L0646JV TJF 7986.69 40.00 70.00 7685.00 7761.50 -216.43 1177.43 409.42 340.48 -227.36 0.00 5978439.44 582971.55 N 70.35107190 W 149.32633682 TJE 8371.79 40.00 70.00 7980.00 8056.50 18.74 1424.96 425.18 425.15 5.25 0.00 5978526.67 583203.18 N 70.35130320 W 149.32444846 TJD 8548.02 40.00 70.00 8115.00 8191.50 126.37 1538.24 477.15 463.89 111.69 0.00 5978566.59 583309.18 N 70.35140904 W 149.32358429 TJC 8698.14 40.00 70.00 8230.00 8306.50 218.05 1634.74 536.52 496.89 202.37 0.00 5978600.59 583399.48 N 70.35149920 W 149.32284813 Fault 4 Crossing 8841.73 40.00 70.00 8340.00 8416.50 305.74 1727.04 602.37 528.46 289.10 0.00 5978633.12 583485.85 N 70.35158543 W 149.32214398 TJB 8933.11 40.00 70.00 8410.00 8486.50 361.55 1785.77 647.65 548.55 344.30 0.00 5978653.82 583540.81 N 70.35164031 W 149.32169587 TJA 9017.96 40.00 70.00 8475.00 8551.50 413.37 1840.32 691.51 567.20 395.55 0.00 5978673.04 583591.85 N 70.35169126 W 149.32127978 L-04 Tgt 1 SAG 9181.14 40.00 70.00 8600.00 8676.50 513.02 1945.20 779.65 603.08 494.11 0.00 5978710.00 583690.00 N 70.35178925 W 149.32047958 Top Sag 9194.19 40.00 70.00 8610.00 8686.50 520.99 1953.59 786.88 605.95 502.00 0.00 5978712.96 583697.85 N 70.35179709 W 149.32041557 7" Csg Pt 9194.21 40.00 70.00 8610.01 8686.51 521.00 1953.60 786.88 605.95 502.01 0.00 5978712.96 583697.86 N 70.35179709 W 149.32041 Crv 10.5/100 9206.14 40.00 70.00 8619.15 8695.65 528.28 1961.27 793.51 608.57 509.21 0.00 5978715.66 583705.04 N 70.35180426 W 149.320356 TSHUA 9247.42 43.30 74.24 8650.00 8726.50 554.64 1988.70 816.83 616.96 535.32 10.50 5978724.34 583731.04 N 70.35182717 W 149.32014507 9300.00 47.69 78.93 8686.86 8763.36 591.35 2026.17 847.52 625.60 571.77 10.50 5978733.38 583767.40 N 70.35185075 W 149.31984908 TSHUB 9359.69 52.88 83.51 8725.00 8801.50 636.90 2072.07 883.71 632.53 617.13 10.50 5978740.82 583812.67 N 70.35186969 W 149.31948087 TSHUC 9394.06 55.94 85.86 8745.00 8821.50 664.79 2100.01 905.16 635.11 644.95 10.50 5978743.70 583840.45 N 70.35187673 W 149.31925502 9400.00 56.47 86.25 8748.30 8824.80 669.73 2104.94 908.92 635.45 649.87 10.50 5978744.10 583845.38 N 70.35187765 W 149.31921503 TSHUD 9431.41 59.31 88.23 8765.00 8841.50 696.32 2131.55 928.97 636.72 676.44 10.50 5978745.66 583871.93 N 70.35188112 W 149.31899932 TE/L 9472.94 63.11 90.68 8785.00 8861.50 732.70 2167.93 956.01 637.05 712.82 10.50 5978746.40 583908.30 N 70.35188202 W 149.31870395 9500.00 65.60 92.19 8796.71 8873.21 757.05 2192.32 973.93 636.44 737.21 10.50 5978746.05 583932.69 N 70.35188033 W 149.31850598 9600.00 74.93 97.32 8830.46 8906.96 850.40 2286.34 1041.81 628.53 830.86 10.50 5978739.18 584026.41 N 70.35185869 W 149.31774567 End Crv 9650.68 79.70 99.73 8841.58 8918.08 899.02 2335.77 1076.95 621.19 879.74 10.50 5978732.39 584075.36 N 70.35183864 W 149.31734886 Crv 10/100 9745.57 79.70 99.73 8858.55 8935.05 990.50 2429.14 1144.92 605.42 971.76 0.00 5978717.64 584167.55 N 70.35179551 W 149.31660178 L-04 Tgt 2 TSAD 9754.06 80.55 99.80 8860.00 8936.50 998.69 2437.50 1151.18 604.00 980.00 10.00 5978716.32 584175.80 N 70.35179164 W 149.31653490 TSAD 9754.12 80.55 99.80 8860.01 8936.51 998.75 2437.55 1151.22 603.99 980.06 10.00 5978716.31 584175.86 N 70.35179161 W 149.31653443 End Crv 9755.25 80.65 99.87 8860.19 8936.69 999.84 2438.67 1152.06 603.80 981.15 10.00 5978716.13 584176.96 N 70.35179109 W 149.31652553 45P 9938.63 80.65 99.87 8890.00 8966.50 1177.03 2619.61 1293.19 572.78 1159.42 0.00 5978687.09 584355.54 N 70.35170628 W 149.31507829 POWC 10153.98 80.65 99.87 8925.00 9001.50 1385.10 2832.09 1470.09 536.36 1368.76 0.00 5978653.00 584565.25 N 70.35160668 W 149.3133788 44P 10215.50 80.65 99.87 8935.00 9011.50 1444.55 2892.80 1522.31 525.95 1428.57 0.00 5978643.26 584625.16 N 70.35157821 W 149.31289 43P 10437.00 80.65 99.87 8971.00 9047.50 1658.57 3111.35 1714.92 488.49 1643.88 0.00 5978608.19 584840.86 N 70.35147574 W 149.31114 Crv 10/100 10568.52 80.65 99.87 8992.38 9068.88 1785.65 3241.13 1832.06 466.24 1771.74 0.00 5978587.37 584968.94 N 70.35141489 W 149.31010744 10600.00 83.79 99.98 8996.64 9073.14 1816.18 3272.31 1860.44 460.86 1802.45 10.00 5978582.33 584999.72 N 70.35140018 W 149.30985807 L-04 Tgt 3 10662.12 90.00 100.20 9000.00 9076.50 1876.84 3334.31 1917.05 450.00 1863.49 10.00 5978572.15 585060.86 N 70.35137046 W 149.30936257 10700.00 93.79 100.14 8998.75 9075.25 1913.87 3372.16 1951.76 443.32 1900.75 10.00 5978565.88 585098.19 N 70.35135218 W 149.30906009 End Crv 10736.42 97.43 100.08 8995.19 9071.69 1949.33 3408.40 1985.11 436.96 1936.43 10.00 5978559.92 585133.93 N 70.35133478 W 149.30877049 Crv 10/100 11314.63 97 .43 100.08 8920 .43 8996 .93 2510 .36 3981 .76 2523 .48 336.60 2500. 93 0.00 5978465 .85 585699.47 N 70 .35106017 W 149.30418791 11400.00 94 .64 108.19 8911 .44 8987 .94 2591 .91 4066 .65 2602 .42 315.87 2583. 18 10.00 5978446 .03 585781.93 N 70 .35100346 W 149.30352028 L-04 Tgt 4 11419.11 94 .00 110.00 8910 .00 8986 .50 2609 .70 4085 .70 2619 .54 309.64 2601. 18 10.00 5978440 .00 585800.00 N 70 .35098641 W 149.30337415 11500.00 91 .48 117.70 8906 .13 8982 .63 2682 .47 4166 .49 2689 .32 276.99 2675. 02 10.00 5978408 .18 585874.19 N 70 .35089715 W 149.30277481 End Crv 11517.40 90 .93 119.35 8905 .76 8982 .26 2697 .48 4183 .88 2703 .68 268.69 2690 .30 10.00 5978400 .04 585889.56 N 70 .35087445 W 149.30265078 TD / 4-1/2" Lnr 11871.44 90 .93 119.35 8900 .00 8976 .50 3000 .37 4537 .88 3000 .37 95.19 2998 .86 0.00 5978230 .00 586200.00 N 70 .35040015 W 149.30014637 WeIlDesign Ver SP 2.1 Bld( doc40x_ 100) S -L\Plan L-04 (S-L)\Plan L-04\L-04 (P6) Generated 7/28/2006 11:08 AM Page 3 of 3 by • Schlumberger wEU FIELD sraucruRE L-04 (P6) Prudhoe Bay Unit - WOA L-PAD Ma9ne0c Parameters Surface Locatgn NAD21 AlasXa Slate Plates. Zone M. US Faet Miacallaneoua Motel: BGGM 200fi Dip 8068]° Date: Ocla6ar 10. 2006 Lat. N]02t0510 nMng: 69]8101 5]'tU5 GM COnv •06Jfit ]dt6' Sld. S-L ND ReI: Rotary Table t]fi 50 XaEOVe MSLt Mag Dec: •23.905' FS- 5]8351 nT Lon: Wt691928.188 Easutg: 58J20266 M1G Srata Fac1:09999016fid Plan: L~Od 1P6) Srvy Date: June 26. 200fi -1200 0 1200 2400 3600 0 1200 2400 3600 0 O N C I I ~ 4600 U Cn O H 6000 7200 8400 0 1200 2400 3600 4800 6000 7200 8400 RTE . _.. _.._. _.._.._.._.._.._.._.._ ~.._..-.._.._.._.._.._..r. _.._.._.._..-..-..-..- -.-.._..-..-..-..-.._.._ .................:....................................................................:..................................:..................................:.. Fauk 1 Crossin ._.._.._.._.._.._.. b~0'.._.._.._.._.._. ._.._.._. _.._.._.._.._.._.._.._va'._.._.._.._.._.._..- - -.._.._.._.._.._.._.._ ._.._.._.._.._.._.._.._ .~. _ .. _.._.._..:.._.._.._.._.._.._.._.._.. ._.. .._.._.._.._.._.._..:.._.._.._.._..-..-.._..-.5-..-.._.._.. _..-.._.._.._.E ase Bann ................. ~.................................................................... h..................................~.................................. ~.. 9-SIB' Csg Pt ::~::~:: ~:: ~:~::~:: ~:: ~:: ~::~:: ~::~:: ._.. _.. _..-.._.: ~::.::7::R::S:::S:: S:: S::3::3::5:3::.::.:::5::.::.::.::.::.. d A_ ._.._.._.._. ._.._.._. _.._.._.._.._.._.._.._ ~i._.._.._.._.._.._.._..s.._..-..-..-.._..-..-..- ._.._.._.._.._.._.._.._ Kov lard t.snoo _ _._.._.._.._.._.._.._.._...ti .._.._.:_.._.._.._.._..-.._..-.._.._.._.._.._.._.~.._.._.._.._.._.._.._.._.. .. _.. _.. _..:.. _.. _.. _.. _.. _.. _.. _ .. _.. .. ~.~ 0e.. _ .. _.. _.. ~.. _ .. _.. _.. _.. _.. _.. _.. _.:_.. _.. _.. _ .. _.. _.. _.. _.. _.: ??!??!::!!?61!?Ili!!?I!E?!??liisii'sii ??!:?!??!?I!?I!??!?!/3311!?!!?l?lliiliSli?!??!?Slit!??l??!??lii~ii~:?!i?!??!SI .. _.._.._.._:. _.._.._.._.._.. _.. _.. _. .. _.. _.. _.. _.._.._.._.. _..t.._.. _.. _.._.._.._.._.._.:_.._.. _.._.._.. _.. _.. _.. _.: .......... _.._.._.._.._.._.._ :ase_ .~.._..:.._..:.._ _ .~..~..~..~..~..~..~..~ ,_ ....................... Fault 2 Crossing ._.._.._.. _.. _.. _.._.._ .M ~.._ _ _.._.._.._.. _.. _.._.._ _..-..-.._.._.._..-.._ ._..-.._.._.._.._.._.._ Crv u100 ._.._.._. _.._..-. aP~~.._ - -.._.._.._.._.._.._..- - -.._.._.._.._.._.._..- .-.._.._.._.._.._.._.._ .--- ---. :~:::--::::--------::F:--- - ::_-------:: .:..:..:::~:;::::;;:.: 4 ..:..:..r...:..:..:..:..:..:..:..:....::.a:..:..:...............:::::::::::::.:::::::.:.., ........Fault 3 Gosaing ....... ...............:.................................. p..................................:..................................:.. .. _.._.._..:..._.._.tnd'Crv.._.. ~a~.._.._.._.._.._.._.._.._..~.._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._ Fault 4 Crosalnq • ~~~~_~~-~ L-04 Tgt ];SAG .a.. ._.._. ..T'Lra9~t._.._.._.._.._. ._.._.._.._ .: ._.._.._. _.._.._.. _.._.._.._.._ .._ .._._._.._L-04 Tgf4 End Crv IIlIIlIIlIIRIIlIIlIIlIIliilllllllllll1~11111lIIlII! 'ltl!~IIlIIlIIlIIlIIlllllllll• ! I 11!11! 11lIIlIIl1~ crv tonog Ena crv L-04 Tgt 2 TSAD End Crv Crv 10H 00 L-04 Tgt 3: -1200 0 1200 2400 3600 Vertical Section (ft) Azim = 88.18°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E/-V • ~ 0 0 0 M N a J ~ f 3 e a ~` Z ~ _ a ~N ~ : w O O N o ~ 0 N m ~ i8 `m ~ m Q ~Yo s q O ~ ~"LL ~~~ o r+ ~ a~ ~ ~a W €' °' N p 0 z O r ~ L ~ a ~z3 9 v,39 0 s 0 ~~ o~ 8~ 0 ~ ~~ ~ as a a o ~ a s ° `~ J ~~ i ~m ~~ 0 0 0 0 0 o 0 0 0 0 0 0 0 0 M O O N °o O N n A n 0o W o 0 I I N O ~ O U O ~ V °o 0 0 0 u> o in ^ ~n o ~ PLANT - ~15'00'00•• GRID ---------- -----------------~ ~ I L-PAD 1 I I I I r r I I I ~ I ~ N-L (NWE-1) I I I I I I N~ ~~ o o I I I L-1111 (i g ~ N-A (NWE-2) I I L-51 ~ L-2181 I i L-114 ~ L-124 I I L-50 ~ ~ L-1121 I I L_0Y I I L-121 ~ ~ L-1231 I I ~ L-122 I I I L-110 ~ ~ L-2111 I I L-SI ~ ~ L-1151 ~ L-116 ~ ~ L-117 ~ I L-109 ~ L-118 L-041 I (i L-250 I I I 1-01 (• ~ L-200 I 1-107 ~ ~ L-202 SKID 50 L-03 ( L 2121 ® I • ~ ~ - ~ L-2171 o I ~ L-2131i~ ~ L-203 ~ L-1081(• N (• L-2161 L-1051(1 ~ L-1031 I L-106 (i ~ ~' ~ L-2151 I L-204 ^ ^ L-201 I I L-104 ~ ~ L-1191 I I L-2141 ~ ~ L-2101 I ~ I I L-102 ~ '° ~ L-120 ~N ~ I I ~ SKID 506 SKID 513 I i ~ i i i NOTES 1. DATE OF SURVEY: APRIL 18-19, 2001. 2. REFERENCE FIELD BOOK: W001-13 PAGES 36-47. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS OPERATOR MONUMENTS, WOA L-PAD MONUMENTATION. 5. BASIS OF ELEVATION IS WOA L-PAD OPERATOR MONUMENTS ELEVATIONS ARE BPX MEAN SEA LEVEL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. ~ .., ' ~.r: 34 ~'~ X35 s .r ~1N L-PAD . _,- l PROJECT r _AREA `' ~' T12N T11 N v ~~ _ ~ w ~ = ~~~~ ~ 3 ~ 2 r (~' VICINITY MAP N.T.S. WELL N0. L-041 REVISION NOTE THIS AS-BUILT DRAWING IS A RE-ISSUE OF A PREVIOUS CONDUCTOR AS-BUILT FOR WELL SLOT L-SL DATED 4/19/2001. WELL SLOT L-SL IS BEING RENAMED TO WELL L-041. OF ~E A~ ,`P° °°°° °° °°qs~ ~ _°° °9 ~0°49~ °o~ ° °°°°°°°°°°°°°°°°°°°°°°°°°°°° °~ °, °Leonard J. °0'Hanley ° ° ° ~ ° 11386 °°° °° °°°(~ '°s`slorw- `' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING [N THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 13, 2006. EL GEND ~-RENAMED CONDUCTOR (i EXISTING CONDUCTOR LOCATED W[THIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATE POSITION DMS POSITION D.DD BOX ELEV. OFFSETS L-041 Y= 5,978,101.53 N 9,819.98 70'21'00.510" 70.3501417' 48 0' 2 380' FSL X= 583,202.66 E 5,164.87 149'19'28.168" 149.3244911' 3,714 FEL f~~ 1 CHECKED:O'HANLEY by DATE: 7/13/06 DRAWING: WOA L`PAD SHEET: yy~~ FR806 WOL 05-00 ®19J~~OO ~o JO6 ND. RENAMED AS-BUILT CONDUCTOR SCALE: 1 OF 1 e ~ is ee IssuEO Faa 1NEanunoN ,u LaN 1•a 150• WELL L-SL TO L-041 NO. DALE REVISION RV CHK ,xaanMC ~ spa • • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Thursday, July 28, 2006 Brandon Peltier BP Exploration (Alaska) Inc. Schlumberger Prudhoe Bay L-04 (P6) Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survev Program: Instrument Type Start Depth End Depth GYD GC SS 28.50'md 800.00'md MWD 800.00'md 2,200'md MWD + IFR + MS 800.00'md 11,871.44'md Close Approach Analysis results: Under method (2), note. All wells pass major risk. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 07/27/06 BP Alaska Anticollision Report Company: BP Amoco Field: Prudhoe Bay Reference Sife: PB L Pad Reference Well: Plan L-04 (S-L) Reference Wellpath: Plan L-04 ' NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 5.00 ft Depth Range: 28.50 to 11871.44 ft ~I Maximum Radius:10000.00 ft ~ Survey Program for Definitive Wellpath Date: 4!19/2006 Validated: No Planned From To Survey !~ ft ft it ~~ -- - - -_ _.___._-__._------ 28.50 800.00 Planned: Plan #6 V1 800.00 2200.00 Planned: Plan #6 V1 800.00 11871.44 Planned: Plan #6 V1 Casing Points ~~ MD 'IVD Diameter HoleSeze Naroe ft ft Date: 7/28/2006 Time: 11:11:32 Page: t Co-ordinate(NE) Reference: Well: Plan L-04 (S-L), True North Vertical (TV D) Reference: L-04 Plan S-L 76.5 Db: Oracle - -- ---- - Reference: Principal Plan ~ PLANNED PROGRAM ', Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North ~, Error Surface: Ellipse + Casing Vernon: 3 Toolwde Tool Name GYD-GC-SS Gyrodata gyro single shots MWD MWD -Standard MWD+IFR+MS MWD +IFR + Multi Station ~n in 2716.50 2716.50 9.625 12.250 9 5/8" 9194.19 8686.50 7.000 8.750 7" 1111871.44 8976.50 4.500 6.125 41/2" Summary - - <-------- ---- OtTset Wellpath - -------> - - Site ~ ~'1'ell Wellpath PB LPad - - - - L-01 - L-01 V14 PB L Pad L-02 L-02 V1 ', PB L Pad L-02 L-02A V5 '~ PB L Pad L-02 L-02AP61 V2 PB L Pad L-02 L-02P61 V21 PB L Pad ~ L-03 L-03 V5 I PB L Pad L-101 L-101 V4 ', PB L Pad L-102 L-102 V2 PB L Pad L-102 L-102P61 V10 !, PB L Pad L-102 L-102P62 V2 PB L Pad L-103 L-103 V23 PB L Pad L-104 L-104 V7 PB L Pad L-105 L-105 V4 ', PB L Pad L-106 L-106 V14 ', PB L Pad L-107 L-107 V14 ', PB L Pad L-108 L-108 V18 ', PB L Pad L-109 L-109 V12 PB L Pad L-110 L-110 V11 PB L Pad L-111 L-111 V24 PB L Pad L-112 L-112 V8 PB L Pad L-114 L-114 V15 PB L Pad L-114 L-114A V4 PB L Pad L-115 L-115 V7 PB L Pad L-116 L-116 V10 PB L Pad L-117 L-117 V11 PB L Pad L-118 L-118 V9 1 PB L Pad L-119 L-119 V9 PB L Pad L-120 L-120 V8 PB L Pad L-121 L-121 V14 '; PB L Pad L-121 L-121A V1 ~~ PB L Pad L-122 L-122 V5 '; PB L Pad L-123 L-123 V5 j PB L Pad L-123 L-123P61 V3 j PB L Pad L-123 Plan L-123L1 V1 Plan: PB L Pad L-124 L-124 V13 !~ PB L Pad L-124 L-124P61 V5 ', PB L Pad L-124 L-124P62 V4 PB L Pad L-200 L-200 V7 PB L Pad L-200 L-200L1 V3 PB L Pad L-200 L-200L2 V6 PB L Pad L-201 L-201 V6 Reference Offset Ctr-Ctr No-Go Allowable ~MD MD Distance .Area Deviation Warning ft ft ft ft ft ~ 634.58 635.00 58.57 10.87 47.71 Pass: Major Risk 819.11 825.00 200.73 13.16 187.56 Pass: Major Risk 819.91 820.00 200.74 13.28 187.45 Pass: Major Risk 819.91 820.00 200.74 13.28 187.45 Pass: Major Risk 819.11 825.00 200.73 13.27 187.45 Pass: Major Risk 497.94 500.00 85.86 9.37 76.49 Pass: Major Risk 955.69 960.00 242.88 16.95 225.93 Pass: Major Risk 272.50 275.00 220.69 4.41 216.28 Pass: Major Risk 272.50 275.00 220.69 4.51 216.19 Pass: Major Risk 272.50 275.00 220.69 4.51 216.19 Pass: Major Risk 593.08 595.00 231.19 9.54 221.65 Pass: Major Risk 432.38 435.00 188.99 7.06 181.92 Pass: Major Risk 467.68 470.00 148.50 8.49 140.01 Pass: Major Risk 706.47 710.00 159.98 11.94 148.04 Pass: Major Risk 169.19 170.00 71.56 3.78 67.78 Pass: Major Risk 817.40 820.00 126.44 14.54 111.90 Pass: Major Risk 494.99 495.00 15.39 9.99 5.40 Pass: Major Risk 464.25 465.00 61.03 8.54 52.49 Pass: Major Risk 295.29 295.00 166.49 5.29 161.20 Pass: Major Risk 718.92 725.00 209.58 13.94 195.63 Pass: Major Risk 909.99 910.00 134.47 14.44 120.03 Pass: Major Risk 909.99 910.00 134.47 14.44 120.04 Pass: Major Risk 929.08 930.00 164.60 14.95 149.65 Pass: Major Risk 760.03 760.00 32.32 12.13 20.19 Pass: Major Risk 629.38 630.00 185.96 10.19 175.77 Pass: Major Risk 254.57 255.00 182.80 4.74 178.05 Pass: Major Risk 442.58 445.00 265.25 7.48 257.77 Pass: Major Risk 257.39 260.00 286.19 4.44 281.75 Pass: Major Risk 384.82 385.00 91.50 7.00 84.50 Pass: Major Risk 384.82 385.00 91.50 7.00 84.50 Pass: Major Risk 389.49 390.00 195.98 6.48 189.50 Pass: Major Risk 180.49 180.00 201.93 3.40 198.53 Pass: Major Risk 180.49 180.00 201.93 3.40 198.53 Pass: Major Risk 180.49 180.00 201.93 3.40 198.53 Pass: Major Risk 349.65 350.00 226.32 5.98 220.34 Pass: Major Risk 349.65 350.00 226.32 5.98 220.34 Pass: Major Risk 349.65 350.00 226.32 5.98 220.34 Pass: Major Risk 218.89 220.00 189.59 3.89 185.70 Pass: Major Risk 218.89 220.00 189.59 3.89 185.70 Pass: Major Risk 218.89 220.00 189.59 3.89 185.70 Pass: Major Risk 252.80 255.00 251.61 4.46 247.15 Pass: Major Risk • • BP Alaska Anticollision Report _ -- Company: BP Amoco Field: Prudhoe Bay Reference Site: PB L Pad ! Reicrencc Well: Plan L-04 (S-L) Reference Wellpath: Plan L-04 Summary <----- Offset Wellpath ---> Site Well Wellpath ~~ PB L Pad ', PB L Pad ~ PB L Pad ~, PB L Pad 'I PB L Pad PB L Pad ~ PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad i PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad I, PB L Pad '~ PB L Pad i PB L Pad PB L Pad !, PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad ~ PB L Pad ', PB L Pad '! PB L Pad 'I PB L Pad PB L Pad ~, PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad Date: 7f2812006 Time: 11:11:32 Page: 2 Co-ordinute(NN:) Reference: Well: Plan L-04 (S-L), True North Vertical (TVD)12eference: L-04 Plan S-L 76.5 Db: Oracle Reference Offset 'b1D NiD ft ft L-201 L-201 L1 V9 252.80 255.00 L-201 L-201 L1 PB1 V10 252.80 255.00 L-201 L-201 L2 V5 252.80 255.00 L-201 L-201 L3 V2 252.80 255.00 L-201 L-201 L3P61 V6 252.80 255.00 L-201 L-201 P61 V12 252.80 255.00 L-201 L-201 P62 V3 252.80 255.00 L-202 L-202 V5 689.19 690.00 L-202 L-202L1 V7 689.19 690.00 L-202 L-202L2 V6 689.19 690.00 L-202 L-202L3 V6 689.19 690.00 L-204 L-204 V5 402.81 405.00 L-210 L-210 V6 356.98 360.00 L-210 L-210P61 V8 356.98 360.00 L-211 L-211 V6 649.34 650.00 L-211 L-211 PB1 V6 649.34 650.00 L-212 L-212 V11 343.69 345.00 L-212 L-212P61 V9 343.69 345.00 L-212 L-212P62 V2 343.69 345.00 L-213 L-213 V8 398.36 400.00 L-214 L-214 V9 337.57 340.00 L-214 L-214A V4 337.57 340.00 L-215 L-215 V7 348.18 350.00 L-215 L-215P61 V4 348.18 350.00 L-215 L-215P62 V2 348.18 350.00 L-216 L-216 V6 233.10 235.00 L-217 L-217 V3 698.27 700.00 L-218 L-218 V4 749.54 750.00 L-250 L-250 V4 514.19 515.00 L-250 L-250L1 V14 514.19 515.00 L-250 L-250L2 V10 514.19 515.00 L-250 L-250P61 V3 514.19 515.00 L-50 L-50 Test VO 4214.58 4200.00 L-50 L-50 Test2 VO 4214.58 4200.00 L-50 L-50 V1 4209.37 4195.00 L-50 L-50P61 V4 4209.37 4195.00 L-51 L-51 V6 480.09 480.00 NWE1-01 L-100 V2 309.48 310.00 NWE1-01 NWE1-01 V5 309.48 310.00 Plan L-52 (S-E) Plan L-52 V1 Plan: Pla 2697.93 2700.00 Ctr-Ctr 'Vo-Go Allowable Distance Area Deviation Warning ft ft ft 251.61 4.46 247.15 Pass: Major Risk 251.61 4.46 247.15 Pass: Major Risk 251.61 4.46 247.15 Pass: Major Risk 251.61 4.46 247.15 Pass: Major Risk 251.61 4.46 247.15 Pass: Major Risk 251.61 4.46 247.15 Pass: Major Risk 251.61 4.46 247.15 Pass: Major Risk 196.79 11.64 185.15 Pass: Major Risk 196.79 11.64 185.15 Pass: Major Risk 196.79 11.64 185.15 Pass: Major Risk 196.79 11.64 185.15 Pass: Major Risk 178.74 6.93 171.81 Pass: Major Risk 273.95 6.03 267.92 Pass: Major Risk 273.95 6.03 267.92 Pass: Major Risk 189.93 11.41 178.52 Pass: Major Risk 189.93 11.41 178.52 Pass: Major Risk 200.56 5.84 194.72 Pass: Major Risk 200.56 5.84 194.72 Pass: Major Risk 200.56 5.84 194.72 Pass: Major Risk 115.47 6.53 108.94 Pass: Major Risk 204.58 6.30 198.29 Pass: Major Risk 204.58 6.30 198.29 Pass: Major Risk 241.44 6.44 235.00 Pass: Major Risk 241.44 6.44 235.00 Pass: Major Risk 241.44 6.44 235.00 Pass: Major Risk 222.08 4.15 217.93 Pass: Major Risk 212.26 12.50 199.76 Pass: Major Risk 221.43 12.88 208.55 Pass: Major Risk 184.81 9.31 175.50 Pass: Major Risk 184.81 9.31 175.50 Pass: Major Risk 184.81 9.31 175.50 Pass: Major Risk 184.81 9.37 175.44 Pass: Major Risk 123.46 46.64 76.83 Pass: Major Risk 123.46 46.64 76.83 Pass: Major Risk 123.44 47.15 76.28 Pass: Major Risk 123.44 47.15 76.28 Pass: Major Risk 149.87 7.66 142.21 Pass: Major Risk 295.89 5.44 290.45 Pass: Major Risk 295.89 5.44 290.45 Pass: Major Risk 108.72 40.32 68.40 Pass: Major Risk • Field: Prudhoe Bay '~, Site: PB L Pad W~11~ -Plan-L-AA {~-L} ', Wellpath: Plan L-04 Target: L-04 Poly Site: PB L Pad Well: Plan L-04 (S-L) Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 8600.00 ft below Mean Sea Level Map Northing: 5978690.00 ft Local +N/-S: 578.02 ft Map Easting : 584145.00 ft Local +E/-W: 948.90 ft Latitude: 70°21'06.194N Longitude: 149° 19'00.435 W Polygon X ft Y ft Map E ft Map N ft 1 -592.91 196.61 583550.00 5978880.00 2 57.56 229.40 584200.00 5978920.00 3 1664.38 -78.49 585810.00 5978630.00 4 2249.96 -485.05 586400.00 5978230.00 5 2147.74 -683.95 586300.00 5978030.00 6 1471.05 -376.39 585620.00 5978330.00 7 -76.56 -139.17 584070.00 5978550.00 8 -596.57 -133.40 583550.00 5978550.00 • 4-00 0 O O O O O O O O O O O O 0 0 O O O O O O O O O O O 0 D N ~ oo cv ~o o ~ o~ cv ~o o ~- 0 ~ ~ - cv c~ cv m m ~- ~- ~ ~ L-04i Variance Request and Permit Correction • Subject: L-04i Variance Request and Permit Corrections From: "Peltier, Brandon" <Brandon.Peltier@bp.com> Date: Tue, 15 Aug 2006 15:00:18-0800 To: Winton_aubert@admin.sta#e,ak.us Winton Following our phone conversation this morning, here is the variance request and clarification of the 7" casing cement plan. This email serves as the official variance request from placing a production packer within 200' of the top perforation. The top shot will be in the TSAD (46P) sands at 9754' MD. The 7" casing point will be at 9194' MD, the liner top 150' above that at 9044' MD, and the production packer 80' above that at 8964' MD. This spacing will place the production packer approximately 790' AAD (415' TVD) above the top perforation. Please approve this request in the corresponding permit application. The 7" casing cement volumes listed on the permit should be as follows: Stage 1:290 sks Lead and 184 sks of tail ES Cementer @ 4700' MD (base OBf) Stage 2: 212 sks of tail TOC: 3442' MD (500' above Ma) Please let me know if you have any further questions. Thank you. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon. Peltier@bp. com 1 of 1 8/15/2006 3:05 PM • Terri Hubble BP Explaxatian AK Inc. PO Box 196612-MB ?-5 Anchorage, AK 99519 PAY TO THE "~ ORDER. OF ~ • ss-si z5z 294 "Mastercard Check" g'~ ^ DATE ~ D ` "`~ ~ ~/~ ~ $ ~~~ ~~ ~ ~5L ~ first NationaL$ank Alaska Anchorage, AK 99501 MEMO: ^' ~~o ~~ ?~IE~C~~~~ V~.t'~ ~: L 25 200060:9,9 L46 2 2`7 L 556~~' 0 294 • • TRANSMITTAL LETTER CI3ECKLIST WELL NAME ~~~// C/ ~'"(~ ~'-f j ~ Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT ~ (OPTIONS) APPLIES MliLTI LATERAL (If last two digits in API number are between 60-69) TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing wel l ~ Permit No. , API No. 50- - - Production should continue to be reported as a function of the ' original API number stated above. PLOT HOLE In accordance with 20 A.AC 25.00~(f), all records, data and logs ' acquired for the pilot hole must be clearly differentiated in both (well name ( PH} and API number (30- - -~ from records, data and logs acquired for well ~ ;SPACING ~ The permit is approved subject to full compliance with 20 AAC , !EXCEPTION ~ 25.0». Approval to perforate and produce % infect is contingent upon issuance of a conservation order approving a spacing ! i ~ exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH i 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 weld until after (Company Name) has designed and j ~ i implemented a water well testing program to provide baseline data I on water quality and quantity. (Company Name} must contact the ~ ~ Commission to obtain advance approval of such water well testing Rev: 1125/06 C:`~jody'~transmittal checklist • ~ N ~ ! m ° ! ~, Q ! .~ ~ o ~ o ~ ~ ~ i~ ~ c ~ Q : c OI ~ ~ ~ o I ! ~ ~ ~ ! ~ ~ : ! , ! i E O ° ! ~ m o ` I~ !I a I 'I ~I ~ ? I ! I o I ~ I ' m, ! a I z : Q, o, ! m', i o W I o I O th o' a ~ ~': ~ ~: I a' . 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