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209-164
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API # PTD # Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC AGI-01A PRUDHOE BAY UNIT AGI-01A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 AGI-01A 50-029-22307-01-00 209-164-0 G SPT 7843 2091640 1961 3333 3333 3333 3333 83 104 104 105 4YRTST P Guy Cook 8/12/2025 Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 AGI-01A Inspection Date: Tubing OA Packer Depth 81 2400 2374 2374IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250813141221 BBL Pumped:3.8 BBL Returned:3.3 Monday, September 22, 2025 Page 1 of 1 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU AGI-01A Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-164 50-029-22307-01-00 10623 Conductor Surface Intermediate Production Liner 8497 80 3883 10130 641 10377 20" 13-3/8" 9-5/8" 7" 8264 35 - 115 34 - 3917 32 - 10162 9980 - 10621 35 - 115 34 - 3491 32 - 8062 7890 - 8495 10402 470 2260 4760 5410 None 1490 5020 6870 7240 10220 - 10496 7-5/8" 29.7# x 7" 26# L-80 29 - 9986 8116 - 8376 Structural 7" Baker S-3 Packer 2216, 2186 9945 7858 Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907-564-4672 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028301, 0034628 29 - 7986 N/A N/A 269879 293796 3453 3484 325-168 13b. Pools active after work:Prudhoe Oil 7" Camco A-1 9945, 7858 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 3:38 pm, May 08, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.08 13:55:38 - 08'00' Bo York (1248) DSR-5/9/25JJL 6/13/25 ACTIVITY DATE SUMMARY 4/27/2025 T/I/O=2630/15/85 Water Wash Pump 5 bbls 60/40, 50 bbls 180* diesel & 455 bbls fresh water + surfactant down tbg. Soak for 2 hours. Pump add'l 160 bbls fresh water + surfactant & 15 bbls 60/40 down tbg FWHPs=480/26/135 Daily Report of Well Operations PBU AGI-01A 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU AGI-01A Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-164 50-029-22307-01-00 ADL 0028301 , 00234628 10623 Conductor Surface Intermediate Production Liner 8497 80 3883 10131 641 10377 20" 13-3/8" 9-5/8" 7" 8264 35 - 115 34 - 3917 31 - 10162 9980 - 10621 35 - 115 34 - 3491 31 - 8062 7890 - 8495 10402 470 2260 4760 5410 none 1490 5020 6870 7240 10220 - 10496 7-5/8" x 7" L-80 29 - 99868116 - 8376 Structural 7"Baker S-3 7" Camco A-1 9945 / 9980 2216 / 2186 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907-564-4672 PRUDHOE BAY 4-30-2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:21 am, Mar 25, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.03.25 07:02:18 - 08'00' Bo York (1248) 325-168 JJL 4/7/25 SFD 4/10/2025 10-404 ADL0034628 SFD DSR-4/1/25*&: 4/10/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.10 14:11:41 -08'00' RBDMS JSB 041025 Well Work Prognosis Well Name:AGI-01a API Number:50-029-22307-01 Current Status:Gas Injector Leg: Estimated Start Date:April 30th 2025 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:209-1640 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Jerry Lau Cell: 907-360-6233 Gas Injection Rate: 243,516 Mscf/Day Injection Pressure: 3,392 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): AGI-01a is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2021. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis a MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday, August 5, 2021 Jim Rper E11,110�� P.I. Supervisor �� SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC AGI -01A FROM: Brian Bixby PRUDHOE BAY UNIT AGI -01A Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry ` NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-0IA API Well Number 50-029-22307-01-00 Inspector Name: Brian Bixby Permit Number: 209-164-0 Inspection Date: 8/4/2021 ' Insp Num: mitBDB210804150127 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ' 3293 3294 3294' 3293 — Well AGI -01 TYPe Inj � G .TVD 7sa3 Tubing I--�- -- ---- - 1961 IA 99 2210 2186 zlso ' BBL Pumped: 3.6 BBL Returned: _ YP P 1 _..,_p - I 3.6 OA 150 175 ' 175 175 I -- PTD 2091640 Type est SPT est SI Interval'; 4YRTST P/F P Notes: Thursday, August 5, 2021 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:209-164 6.50-029-22307-01-00 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 10623 10377 8264 9945 10402 none 9980 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 35 - 115 35 - 115 1490 470 Surface 3883 13-3/8" 34 - 3917 34 - 3491 5020 2260 Intermediate 10131 9-5/8" 31 - 10162 31 - 8062 6870 4760 Production Perforation Depth: Measured depth: 10220 - 10496 feet True vertical depth:8116 - 8376 feet Tubing (size, grade, measured and true vertical depth)7-5/8" x 7" L-80 29 - 9986 29 - 7897 Packers and SSSV (type, measured and true vertical depth) Liner 641 7" 9980 - 10621 7890 - 8495 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 342024000 0290,670 600 3385 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: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564 - 4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 5 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 measured8497 Sundry Number or N/A if C.O. Exempt: 209-164 6" CA A1 ISSSV 2216 2186 Junk Packer Printed and Electronic Fracture Stimulation Data 5 water wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 034628 ,028301 PBU AGI-01A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 278,165 By Samantha Carlisle at 5:29 pm, Dec 02, 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: 2020.12.02 15:40:51 -09'00' Bo York DSR-12/2/2020 RBDMS HEW 12/3/2020 MGR22DEC2020 320-455 ACTIVITYDATE SUMMARY 11/14/2020 T/I/O= 2620/200/110. LRS Unit 72 Tubing Wash (TUBING WASH/PICKLE). Pumped 10 bbls of 60/40 Meoh, 50 bbls of COTU diesel at 120* F, and 357 bbls of fresh water with 0.02% F-103 surfactant into the TBG. Pumped 2 bbls of 60/40 Meoh to FP surface equipment. Let the treatment soak for 2 hours. Pumped 230 bbls of fresh water with 0.02% F-103 surfactant and 15 bbls of 60/40 Moeh into the TBG. Final T/I/O= 500/260/210 Daily Report of Well Operations PBU AGI-01A Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:209-164 6.API Number:50-029-22307-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 034628 Property Designation (Lease Number):10. n/a 8. PBU AGI-01A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown water wash Op Shutdown GAS GSTOR WAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10623 Effective Depth MD: L-80 11. 11-7-2020 Commission Representative: 15. Suspended Contact Name: Dave Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 6" CA A1 ISSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8497 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9945, 9980 2216, 2186 Date: Liner 641 7"9980 - 10621 7890 - 8495 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 34 - 3917 34 - 3491 14. Estimated Date for Commencing Operations: BOP Sketch 35 - 115 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7"Baker S-3, 7" Baker ZXP 10220 - 10496 8116 - 8376 7-5/8" x 7"29 - 9986 Production 10377 8264 none 10402 35 - 115 470 13-3/8" 9-5/8" Contact Phone:907-564-4672 Date: 4760 80 149020"Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3883 5020 Intermediate 10131 31 - 10162 31 - 8062 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:27 am, Oct 26, 2020 320-455 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.10.23 16:35:50 -08'00' Bo York 2500 DLB10/26/2020MGR26OCT2020 ADL0028301 X 10-404 SR-10/27/2020 Yeon Required? Comm. 10/27/2020 dts 10/27/2020 JLC 10/27/2020 RBDMS HEW 11/9/2020 Well Work Prognosis Well Name:AGI-01a API Number:50-029-22307-01 Current Status:Gas Injector Leg: Estimated Start Date:Nov 7, 2020 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:209-1640 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Gas Injection Rate: 237,004 Mscf/Day Injection Pressure: 3,381 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): AGI-01a is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2014. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,September 11,2017 Jim Regg I t(7 SUBJECT: Mechanical Integrity Tests P.I.Supervisor (e_lG BP EXPLORATION(ALASKA)INC. AGI-01A FROM: Guy Cook PRUDHOE BAY UNIT AGI-01A Petroleum Inspector Src: Inspector Reviewed By:--� P.I.Supry p NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-01A API Well Number 50-029-22307-01-00 Inspector Name: Guy Cook Permit Number: 209-164-0 Inspection Date: 8/5/2017 Insp Num: mitGDCl70805182158 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI-01A ' Type Inj G TVD 7843 Tubing 3340 3341 - 3378 - 3402 3310 - 3270 PTD 2091640 Type Test SPT Test psi 1961 IA 3 2495 2524 2592 2612 2614 BBL Pumped: 4.5 ' BBL Returned: 3.2 OA 136 172 178 187 195 200 Interval 4YRTST - P/F P ✓ Notes: MIT-IA. Due to thermal expansion of the cooler diesel pumped into the well that was at 100 degrees fahrenheit,the entire testing time was 1.5 hours.75 min.-3272/2601/202;90 min.-3303/2605/203 = AA EO 22( 13 Monday,September 11,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission F DATE: Wednesday,August 09,2017 TO: Jim Regg P.I.SupervisorT?etilD/ 144�7 SUBJECT:Mechanical Integrity Tests ` BP EXPLORATION(ALASKA)INC. AGI-0 1 A FROM: Guy Cook PRUDHOE BAY UNIT AGI-01A Petroleum Inspector Src: Inspector Reviewed By:� P.I.Supry J' L NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-01A API Well Number 50-029-22307-01-00 Inspector Name: Guy Cook Permit Number: 209-164-0 Inspection Date: 8/5/2017 Insp Num: mitGDC170805182158 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI-01A - Type Inj G 'TVD 7843 Tubing 3340 3270 " 3272 3303 PTD 2091640 Type Test SPT Test psi 1961 IA ! 3 2614 2601 2605 BBL Pumped: 4.5 ' 1BBL Returned: 3.2 ' OA 136 • 200 202 - 203 - Interval 4YRTST P/F P v Notes: MIT-IA. Due to thermal expansion of the cooler diesel pumped into the well that was at 100 degrees fahrenheit,the entire testing time was 1.5 — hours. • SCANNED Wednesday,August 09,2017 Page 1 of 1 STATE OF ALASKA A ,KA OIL AND GAS CONSERVATION COMM _ION REPORT OF SUNDRY WELL OPERATIONS �// 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other LK (4)0.01-4,1114,414 Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat Shutdown El Stimulate-Other 0 Re-enter Suspended W❑ 2 Operator 4.Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory 209-164-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service2 6.API Number Anchorage,AK 99519-6612 50-029-22307-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0034628 PBU AGI-01A 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL ECEIVED 11 Present Well Condition Summary Total Depth measured 10623 feet Plugs measured None feet true vertical 8496 71 feet Junk measured None feet FEB 0 3 2015 Effective Depth measured 10377 feet Packer measured See Attachment feet ®��� true vertical 8263 85 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 34 7-114 7 34 7-114 7 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 10130 52 9-5/8"47#L-80 31 4-10161 92 31 4-8061 77 6870 4760 Production None None None None None None Liner 641 26 7"26#L-80 9979 64-10620 9 7890 4-8494 71 7240 5410 Perforation depth Measured depth 10220-10430 feet 10465-10496 feet True Vertical depth 8116 3-8313.81 feet 8346 87-8376 2 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 6"CA Al ISSSV 2216 2185 36 SSSV 12.Stimulation or cement squeeze summary Intervals treated(measured) 10220'-10430', 10465'-10496' SCANNED FEC 2 0 L U I'} Treatment descriptions including volumes used and final pressure 55 Bbls Diesel,55 Bbls Xylene,700 Bbls Fresh Water,2100 psi. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 211102 0 400 3351 Subsequent to operation: 0 211102 0 400 3391 14 Attachments. 15 Well Class after work -. Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 2 Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ 2 SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt: 314-168 Contact Garry Catron Email Garry.CatronaBP.Com Printed Name Garry Catron Title PDC PE Signature jj 6A_, Phone 564-4424 Date 2/2/2015 1/-7A- 2/10//5- RBDMS•3FEB - 4 2015 , W.5-- Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0034628 SW Name Type MD ND Depscription AGI-01A SSSV 2216 2185.36 6" CA Al ISSSV AGI-01A PACKER 9944.62 7857.48 7" Baker S-3 Packer AGI-01A PACKER 9979.64 7890.4 7" Baker ZXP Packer CO p,oCD0o0CD0000 UD T- toCO - 0) e- 0) r- O N Tr T Tr Tr in " N 0 Tr LC) Tr L[) V 0) N- to N 0) 0) m CTr 00 ti M CD N- C00 N- C00 N- QD0) CDNN- CDN00) T- O T Tr co • OD OD OD OD M N N N- r- CO C- c6 N OODD 7 N eN-- Y7 Nr N- 0) a0 0 ) M co CC)rs. M T- OD N I� 0 0) N (N N M r- T- OD N N N 4.0 CDT-0 CD N O N- to N- N CO 0 T- C) N O N 0) CC) T- 0 0 T- CM) co CV N 0) ) _ T- N N CA C0A I . Q CO Ln T- 00 Tr O 0) N O N C)M co coco M N00 NCV Cco D C Q : QLoCD inco 0 0 _ CO CO TCD ODYZFl CDJU) JOOD Z 4) it 4 J op qk J J J 44 Lo 4t CO27,), 4krnl# rn *k '�+ y cn a, N OD N N N N N VN p ) c- M M C r- r- M r N- CO N C OOD Nr O0D CO - N oo CO ti J 0 M N N- W OC Co 0 Q C WLu Lu CD CD CD CD CD V p a u_ u_ Z Z Z Z Z Z W W CCCLm m m m m OF- Z » » » > • c 5 _ f \ \ ) \ / Y q C 2 _0 . / 9o r ¥ � \ c eoo0 0a) @ ? ° O 023 % 0 § / - a �/ CO / > a coni : e n o > // / / / � � ® 755 � D + £ / % / / ° t D 7 CO = 5 O < a) $ @ \ \ $ / E/ co 00 \ p co _ _ II 0- o o > I LU 7 .% 13.) / o = a / 2 / \ I- LOO ▪ t • \ \ \ \ � a a TFC_` CMN S_ Y NOTES: WELL REQUIRES A SSSV "' �ACTUATAD �'"c AGI-01A INITIAL WELLBORE NOT SHOWN'•' ACTUATOR= BAKERC WTIAL KB.RI 49' BF.ELEV= KOP= 1851' I Y X I Max Angle= 48'@ 5893' Datum MD= 9357' Datum TVD= 8800'SS 2205' —{ "X 7' ,D=6.276" 2216' —{7"CAMOO7-5/8DBXO6 NP,D=6.00' 13-3/8"CSG,68#,K-55 XO TO NT-80 —I 122' 2227' —7'X 7-5/8'XO,O=6.276' 13-3/8"CSG,68#,NT-80,D=12.415' H 3911' I I Minimum ID = 5.770" @ 9965' 7" HES RN NIPPLE 7-5/8"PC TBG,29.7#,L-80 VAM TOP, H 9912' I-- \ / - 9912' H7-5/8'X 7'XO,D=6.276' .0459 bpf,D=6.875" 9924' —Jr HES R NP,O=5.963' p p 9945' H9-5/8"X 7"BKR S-3 PKR,D=6.000' ' ' 9965' —17'FES RN NP,O=5.770' TOP OF 7'LINER 9980' 9980' 9-5/8"X 7"BKR F#iD ZXP LIP w/BKR FMC HGR,D=6.276' 7'Ft TBG,26#,L-80 TCI,.0383 bpf,D=6276' --I 9986' I / 9986' —17"MULE SHOE,D=6.276" 9-5/8"CSG,47#,L-80 HYD 563,O=8.681' H 10162' • PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON 02/08/10 ANGLE AT TOP PERE 20'0 10220' Note:Refer to Production DB for historical perf data SIZE SFF INTERVALN z DATE OP Sq 3-3/8' 6 10220-10430 0 03/01/10 3-3/8' 6 10465-10496 0 03/01/10 FBTD H 10536' ` 7"LNR,26#,L-80 VAMTOPHC, —I 10621' .0383 bpf,D=6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 04/05/93 AUDI 2 INITIAL COMPLETION 11/11/12 PJC DRLG FRES CORRECTIONS WELL: AGI-01A 02/12/10 D14 SIDETRACK(AGI-01A) FERMTT No:"2091640 02/14/10 TLH DRLG HO CORRECTIONS API No: 50-029-22307-01-00 03/17/10 JED/SV FERFS(03/01/10) SEC 36,T12N,R14E,1583'FSL&2390'FEL 03/29/10 JR/JI41) DRLG DRAFT CORRECTIONS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. C)q - 1 6 4 Well History File Identifier 7 Organizing(done) ❑ Two-sided III IIIIIIIIIII IIIII ❑ Rescan Needed III 1111111 IIIIII RES N DIGITAL DATA OVERSIZED (Scannable) C for Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: Other Items Scannable by a Large Scanner L" (rS ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: P ` /s/ if P Project Proofing 11111111111111111 BY: Maria Date: 1 I ci /s/ (Y.ft Scanning Preparation x 30 = icad + 0 (D = TOTAL PAGES /4 6 (Count does not include cover sheet) . BY: Mari) Date: 0 / /s/ 4 I Production Scanning III I IIII IIIII III I Stage 1 Page Count from Scanned File: 1 Li.7 (Count does include cover sheet) Pa.e Count Matches Number in Scanning Preparation: YES NO BY: Date: t a I (,f. Is' 1/14f) 1 Stage I If NO in stage 1, page(s) discrepancies/were found: YES NO Date: /s/ BY: Maria ate' Scanning is complete at this point unless rescanning is required. III IIIIIIIIIIIII ReScanned 111111111i II 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked I liii IIIII')III 10/6/2005 Well History File Cover Page.doc MOO OF Th. y\\I%%c' s THE/STATE / k a ka 1. net 1 a , 2as S t _ — 333 West Seventh A.""enue � :�• t GOVERNOR SEAN PAIZNI;I.L � �O�f Anchorage, Alaska 99501-3572 `t Main: 907 279 1433 SCpNNEp JUL 2 Fr'. 907.27<>. 5 Javier Farinez Petroleum Engineer ca0/— lG/ BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI-01A Sundry Number: 314-168 Dear Mr. Farinez: 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, AP Daniel T. Seamount, Jr. G Commissioner DATED this I G day of March, 2014. Encl. s< ,. "4- Y .w D '+. 'Naar G:C✓ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS -� C20 AAC 25.280 ' i4 n'� 1.Type of Request: Abandon E Plug for Redrill❑ Perforate New Pool E Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ I Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate Q ' Alter Casing❑ Other ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 209-164-0 • 3.Address: Stratigraphic ❑ Service 24 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22307-01-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU AGI-01A • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034628' PRUDHOE BAY, PRUDHOE OIL • 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): 10623 . 8497 • 10536 8414 None None Casing Length Size MD TVD Burst Collapse Structural 80 20"91.5#H-40 36-116 6-116 Conductor3 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10130 9-5/8"47#L-80 32-10162 32-8061.84 6870 4760 Liner 641 7"26#L-80 9980-10621 7890.74-8494.81 7240 5410 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 6"CA Al ISSSV 2216',2185.36' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ Q ' WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is t -and co ,-ct to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez@BP.Com Printed Name Javier rinez Title Petroleum Engineer ' Signature —% Phone 564-5043 Date `1 •-•\ ` Prepared by Garry Catron 564-4424 COMMISSION USE ONLY gl Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\Lk"- \LC Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑i] t�AY 1 A Other: RBDMe ryl~I 1 1 201`t Spacing Exception Required? Yes ❑ No d Subsequent Form Required: f U — 4- U 4" )./.....-----,/,--) APPROVED BY Approved by: °� COMMISSIONER THE COMMISSION Date: 31 i 1 I a �1,, :,jigj.20�4 � D 6s: 3 / ./i Form 10-403 Revised 10/2012 Aprtolle�p�IGI i Ii r 2 months from the date of approval. Sub it Form and Attachments in Aplicate Perforation Attachment ADL0034628 Well Date Perf Code 1 MD Top MD Base TVD Top _ TVD Base AGI-01A 3/1/10 PER 10220 10430 8116 8314 AGI-01A 3/1/10 PER 10465 10496 8347 8376 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF -0000cotno0000 Cp co co • to co co co co co = J J Z Y J J J J J a) Q O 0 0 0 0 0 0 0 0 0 (B ' CD CD U) O 0) — s— N- N O V' N- U N o 0 0 0 0 0 0 0 0 0 � Ov (- Nt - 0) 0) j • `7 N co 0 Nr N CO CO N N m •- N- (0 U) M N- CD CD N- N- a) N Cd to N co co N- to m 0 co ON O N- N 0) co co co O co ch N- N N- N Q N- tt7 (O • CD O N Cf) N .41- O N- O co co co N co co co (NI N- N N ENr C N- CO U) N N Nr CO co N co CO O N Cl) O 0 O O () ' 00) N 0) N • O C1 O CU HCO co N N- co :11 N N O O U Q M M co co M N N N O O L O O to tf) co co d Z X C J J C70 ID O CO (J� • N 00 CO N (Ni CO CD O N 5 M N - N- N- N O (+) N- 0 0 M 0) '— U) N O It O MCO N- N CO N in Z O O a) f- w > Q Q 0 0 0 0 0 U Q 12 Q W W Z Z Z Z Z Z W O CLCLm m m m m OZWDDDDDDD 0 = 0_ cAcnNHHHF- Packers and SSV's Attachment ADL0034628 Well Facility Type MD Top _ Description TVD Top AGI-01A SSSV 2216 6"CA Al ISSSV 2185 AGI-01A PACKER 9945 7" Baker S-3 Packer - 7858 AGI-01A PACKER 9980 7" Baker ZXP Packer 7891 TREE LWE.LFEAD FMS AGI-01A Sw Y NOTES: WELL REQUIRES A SSSV "' ACTUATOR= BAF C INITIAL WELLBORE NOT SHOWN*** INITIAL KB.ELE 49' BF.ELEV= KOP= 1851' Y < Max Angle= 48"@ 5893' 2205' 1-1H7-5/8"X 7"XO,D=6-D27=6"6.00" 276' Datum MD= 935T Datum TVD= 8800'SS 2216' 7'CA MCO DB 6 NP,D=6.00' 13-3/8'CSG,68#,K-55 XO TO NT-80 H 122' 2227' -17"X 7-5/8'XO,D=6.276" 13-3/8'CSG,68#,NT-80,D=12.415" H 3911' Minimum ID = 5.770" @ 9965' 7" HES RN NIPPLE 7-5/8"PC TBG,29.7#,L-80 VAM TOP, —{ 9912' }—^ / 9912' H7-5/8"X 7'X0,D=6.276" .0459 bpf,D=6.875" 9924' FES R NP,D=5.963' 9945' —19-5/8*X 7"BKR S-3 TKR D=6.000' ' 9965' H7' - 10=5.770" TOP OF 7'LINER 9980' 9980' —19-518'X 7'BKR FRD ZXPLTP w/BKR HMC FIGR D=6.276' T PC TBG,26#,L-80 TC/,.0383 bpi,D=6.276' —I 9986' -{7'MULE SHOE,D=6.276" 9-5/8'CSG,47#,L-80 HYD 563,D=8.681" H 10162' • PERFORATION SUMMARY R13=LOG: SFERRY SUN MMI)ON 02/08/10 ANGLE AT TOP PERF: 20'@ 10220' Note:Refer to Production DB for historical perf data SIZE SW NNIB2VAL Opn/Sqz DATE 3.3/8" 6 10220-10430 0 03/01/10 3-3/8" 6 10465-10496 O 03/01/10 FBTD —{ 10536' 1.4-4?" " 7"LNR,26#,L-80 VAM TOP HC, 10621' .0383 bpf,ID=6.276" DATE 1 REV BY COMMENT" DATE FEV BY COMMENTS FRUDHOE BAY UNIT 04/05/93 ADD 2 IMTIAL COMPLETION 11/11/12 PJC DRLG PREP CORRECTIONS WELL: AGI-01A 02/12/10 D14 SIDETRACK(AGI-01A) PBIfNT No:"2091640 02/14/10 TLII DRLG HO CORRECTIONS API No: 50-029-22307-01-00 03/17/10 JEO/SV FERFS(03/01/10) SEC 36,T12N,R14E,1583'FSL&2390'FEL 03/29/10 JR/JMD DRLG DRAFT CORRECTIONS 02/11/11 M13/JMD ADDED SSSV SAFELY NOTE BP Exploration(Alaska) Ful ' �F - Pumping Program for Field Well Ianie ` AGI-01 Job Scope Select Job Scope Well Type GI AFE APBinjec Date 3/11/2014 IOR 30 Engineer Javier Farinez Phone 564-5043 H2S ?' Job Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate(bpm) Max Pressure 1 Pre-Flush Methanol (60/40) Tbg 10 5 2500 2 Solvent Select Fluid Type Tbg 100 5 2500 3 Load Select Fluid Type Tbg 700 5 1500 4 Freeze Protect Methanol (60/40) Tbg 10 5 1500 5 Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel/xylene 3 700 bbls of fresh water with 0.02% F-103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level(ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level(ft) No Input Depth If Applicable Recent OA Fluid Level(ft) O C m ' U to 0) O ° . 2 c g a s U °� > > rs W Oa W 0 0 U i el ja pp 0 to °� 0 o c _w m co Eo LL d) a U n� a a.mos O U U Om pOm ° o �a2 D ai ai m E J E a aa m a w U aa ~ �a 0 � � i C7 ��' �c'm ° n m Z I i 0 m Uate a a > 0 9 ° N D U)-I- c O E aa s N c OE aa n N U o E v) c OawC0 M I-- Ma -)a M D w2cr0 w2a0 2 < . To o m o o >0 0 0 0 0 0 0 0 0 0 0 a .,8 0 0 0 0 y Z a m N N N N N N N N N N U o cc Z J M M M M M M M M 4 E C Q � 2 C C C C ) ) a) 0) C C O Y '� £ c 0 0 a a a a m m coo m a a OU 0 0 0 0 0 0 0 0 0 0 E Ce a `� U C ! M M M (p (0 M CO CO N N To- N N U 1 i., 'O N O O O co O O O O O o o O.+r d z tN E W g a, (n z c Co CO 0 0 0 0 0 0 v v Co Co 0 0 0 0 0 0 a. f/0) M M M M 00) a) r-N. N M W W v V a - t > Z m 0I o < CC z _ = i 0 O) N O O c O O C A- I c p I Z o U U m 0 U T.. la O O 0 o , N 5=-1 O E o 4 0 (0 N CO 0 E. I J V) N N to ti') N V co a 0 (n H < 1 a C� z 0 0 �a U) G o ':1 /�y� Q N a d W 03 0 m _ m 1 a y o o Q 0 I co a _ w CC a 21 cc z o 0 .> > '> o o a) a) 0 d U p C N N N f0 N E Rs I I J a' O m N N O m C) Z j co a Cr a CO CO > > C C C C C W W (L it a) d C O O O N N o c E j .v '� .0 a a ac) m o o J 0 co 1 I CC Z 111 c _ c U 0 0 0 CL X g o 0 o) ,_ I E NI. >0 0 _ r y a 1 o rte) v o ,o ~ F- m d R E 0)) a) co m c Tr; 2 10 0 ° w 0 z B.N O O 1 F- C R a+ O.E M Z y u .'p o a) R 0 (° o O u rn J a. a y Z O W LL d p 1 Ni uj U \ \, \ \o \ �U U Z 0 I, y J — a a a 07 O) o O) d1 y a y . J 0 0 0 J 3 0! H a W p �- 3 J O W X W 9 4 1 , /' o � , Nco ›- I ..r o) U_ N 5 o N o z Y. a z_ O 0 z -.41 N hi • N R rN J � ❑ Lim Q N 0 z Z Ce o a W w > U pap n Z Ce o �g a) cn o= I!J o = CL o gN� o L CO o U oo U J 4 Q 0 I H a- it H z— o N CO m co 0 cn I 0 � Qo a) II ..if.i....3' o p .r E 1 • v 1 co z o O c a z m N 0 1 N Z c• N N ce ❑ • co N Q C, , V O o Z ai �. ns P U • . £ a £ ❑ acn ❑ Q d a U ¢ � j U U STATE OF ALASKA . AL _KA OIL AND GAS CONSERVATION COMM. ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other .11 Water Wash Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other IS Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Developments Exploratory IS 209-164-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99519-6612 50-029-22307-01-00 7.Property Designation(Lease Number): - in 8.Well Name and Number -- ADL0034628 r `y tv/4 g I PBU AGI-01A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 10623 feet Plugs measured None feet RECEIVED true vertical 8496.71 feet Junk measured None feet JAN 3 1 2013 Effective Depth measured 10577 feet Packer measured See Attachment feet true vertical 8453.02 feet true vertical See Attachment feet AOG CC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 30 20"91.5#H-40 45-75 45-75 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10130 9-5/8"47#L-80 32-10162 32-8061.84 6870 4760 Liner 641 7"26#L-80 9980-10621 7890.74-8494.81 7240 5410 Perforation depth Measured depth 10220-10430 feet 10465-10496 feet True Vertical depth 8116.3-8313.81 feet 8346.87-8376.2 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED MAR 0 5 2013 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 0 0 0 14.Attachments: 15.Well Class after work: . Copies of Logs and Surveys Run Exploratory❑ Development❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ Q - 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: 312-225 Contact Nita Summerhays Email Nita.Summerha s. b•.com Printed Name Nita Summerhays , Title Petrotechnical Data Technician Allwoodyi Signature %A ��., �i __ / Phone 564-4035 Date 1/31/2013 RBDMS FEB 012013 z/ / Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0034628 ACTIVITYDATE •= • • • emp= I Tubing Wash ( Solvent Treatment) Speared into 10/2/2012 Tbg w/ 10 bbls neat methanol. ***WSR continued on 10-03-12*** ***WSR continued from 10-02-12*** I ubing Wash ( Solvent Treatment) Pumped 100 bbls 50/50 diesel/xylene followed by 708 bbls fresh water w/ 0.02% F-103 surfactant down Tbg. Pumped 10 bbls neat methanol to freeze protect surface lines. FWHP's=vac/20/40 SV, WV, SSV= SI MV= 0 IA& 10/3/2012 OA= OTG. FLUIDS PUMPED BBLS 20 METH 50 DIESEL 50 XYLENE 708 FRESH WATER W/0.02% F-103 SURFACTANT 828 TOTAL CD a 0 0 0 0 0 0 CO N- CD O CD 0) 1- C in N � C.) C)) O N CO � CD M 1.11 CD CD s- CO O ti O co Lo o co - 0 00NC)) V 0 O 1' CO CO CO f- CO co ir)Nr co M co N O a) 4 N C '- N O N co N ' N .0 O O M 0 O V r r CU 03 I I O N N CAM vC)C CI a) C p El O H 0 ▪ Q o 0 ao 0 0 Lo I co ' ZJco U N _ 00 ' NN O c? Cj I� N O CO co 5 r M Q) N 0 CNI CO CO CD O CO M N O J Z O jz Li] H co O 0 D ° ° 00 R 0 a a u LL Z Z V Z W O Q Q m OZCC » » UJacnv) HI- , Packers and SSV's Attachment ADL0034628 SW Name Type MD TVD Depscription AGI-01A PACKER 9945 7810.13 7" Baker S-3 Packer AGI-01A PACKER 9980 7843.04 7" Baker ZXP Top Packer } = _ S. Y NOTES: WELL REQUIRES A SSSV "•TREE ACTUATOR= BAKED C A G I-0 1 A INITIAL W ELMORE NOT SHOWN':' INTIAL KB.ELE 49'': BF.ELEV= KOP= 1851' I X f Max Angle= 48°@ 5893' ______---I 2206' H7-5/8"X 7"XO,D=6276" I Datum MD= 935T 2216' 7 CAMCO DB-6 NP,D=6.00' Datum TVD= 8800'SS, I I� " 13-3/8"CSG,68#,K-55 XO TO NT-80 H 122' ---------1 2227' J-17"X 7-5/8"XO,D=6.276" 13-3/8"CSG,68#,NT-80,D=12.415" —I 3911' IA ■ Minimum ID = 5.770" @ 9965' 7" HES RN NIPPLE 7-5/8"PC TBG,29.7#,L-80 VAM TOP, -E._ 9912' _ ' \ /—1 9912' HT-5/8"X 7"XO,D=6.276" I .0459 bpf,D=6.875" ' ' 9924' H 7'IES R NP,D=5.963" I X Z 9946' H9-5/8"X 7"BKR S-3 PKR,D=6.000' I I I 9965' H7"HES RN NP,D=5.770' I TOP OF 7"LINER 99802' 41. 9980' 119-5/8"X 7"BKR HRO ZXP LTP w BKR HMC HGR,D=6.276" 7"PC TBG,26#,L-80 TCI,.0383 bpf,D=6.276" H 9986' 9986' , ,r MULE SHOE,D=6.276" I 9-5/8"CSG,47#,L-80 HY D 563,D=8.681" H 10162' I A ■ PERFORATION SUMMARY REF LOG: SFERRY SUN MIND ON 02/08/10 ANGLE AT TOP PERF: 20°@ 10220' Note:Defer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8' 6 10220-10430 0 03/01/10 3-3/8" 6 10465-10496 0 '03/01/10 PBTD —I 10636' Alooko 7"LNR,26#,L-80 VAM TOP HC, H 10621' a_ _ -►i .0383 bpf,D=6.276' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MIT 04/05/93 AUDI 2 INTIAL COMPLETION 11/11/12 PJC DRLG FRER CORRECTIONS WELL: AGE01A 02/12/10 D14 SIDETRACK(AGI-01A) PE2MITP3:' 091640 02/14/10 TLH DRLG HO CORRECTIONS AR Nb: 50-029-22307-01-00 03/17/10 JED/SV PERFS(03/01/10) SEC 36,T12N,R14E,1583'FSL&2390'FEL 03/29/10 JR/JMD DRLG DRAFT CORRECTIONS 02/11/11 MB/JMD'ADDED SSSV SAFETY NOTE BP Ekploration(Alaska) , 9-7 1i e > ; �; � ' L h I SEAN PARNELL, GOVERNOR t N !, �T ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Javier Farinez 6 Petroleum Engineer ao 6/— ` if BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI-01A Sundry Number: 312-225 Dear Mr. Farinez: 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. Sincerely, (-- 2'efig-' Cat y P Foerster Chair DATED this� day of June, 2012. Encl. 4- STATE OF ALASKA �1,` RECEIVED AL ,:A OIL AND GAS CONSERVATION COM14. ,ION ' APPLICATION FOR SUNDRY APPROVALS JUN 1 4 2012 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ CAQG y� jogram❑ Suspend❑ Plug Perforations ❑ Perforate Pull Tubing❑ X j 6-4"--¢Time Extension❑ Operation Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing ❑ Other: Water Wash + El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska), Inc. Development ❑ Exploratory ❑ 209-1640 3.Address: P.O.Box 196612 Stratigraphic ❑ Service Ei . 6.API Number: Anchorage,AK 99519-6612 50-029-22307-01-00, 7. If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 PBU AGI-01A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-034628 . 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): 10623 8497 10577 8453 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 30' 20"91.5#H-40 45' 75' 45' 75' 1490 470 Surface 3871' 13-3/8"68#NT-80 40' 3911' 40' 3487' 5020 2270 Intermediate 10130' 9-5/8"47#L-80 32' 10162' 32' 8062' 6870 4760 Production 641' 7"26#L-80 9980' 10621' 7891' 8495' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): SEE ATTACHED- - 7-5/8"29.7# L-80 30 9912 - 7"26# L-80 9912 10621 Packers and SSSV Tvoe: 7"BKR S-3 PKR Packers and SSSV MD and TVD(ft): 9945' 7858' 12.Attachments: Description Summary of Proposal Ell 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: 6/28/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ 0 ' WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the forego'•• is tr - . d correct to the best of my knowledge. Contact Javier Farinez Printed Name Javier arine Title PE Signature ' /� Phone Date / 564-5043 6/14/2012 Prepared by Nita Summerhays 564-4035 COMMISSION USE ONLY ?� 2.--21 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: J I 6 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / 0 —q('`' APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: t —2/-/L PMs JUN 25 1012 N G.a.rL .s i-,� 0/ Form 10 403 Revised 1 1 . Submit in Duplicate ;1q ���CCC i e- Cl O 03 co till m,MiM, t co r+ 00 Q. p I > i- °-eh O~p co H e-ier = rt. Z.' 0° 0 p NIZ W. H O. V Oo co. 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'�' Z O N co `� Z 0 Q a Q Q Q a co y on a) ' c m c o Z a U N c 3 co I- U Fullbore Pumping Program for Field Well Name AGI-01 Job Scope Select Job Scope Well Type GI AFE APBinjec Date 6/12/2012 IOR 100 Engineer Javier Farinez Phone 564-5043 H2S Job Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Pre-Flush Methanol (60/40) Tbg 10 5 2500 2 Solvent Select Fluid Type Tbg 100 5 2500 3 Load Select Fluid Type Tbg 700 5 1500 4 Freeze Protect Methanol (60/40) Tbg 10 5 1500 5 Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear L- 2 100 bbls 50/50 diesel/xylene 3 700 bbls of fresh water with 0.02% F-103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level(ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level(ft) No Input Depth If Applicable Recent OA Fluid Level(ft) Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L-80) dimensions mechanical inner capacity outer capacity size lb/ft od id drift id collapse burst bbls/ft ft/bbls bbls/ft ft/bbls 2.375 4.60 2.38 2.00 1.90 11780.00 11200.00 0.00387 258.6 0.00548 182.5 2.875 6 50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6.40 3.19 2.81 2.68 11111.00 11111.00 0.00769 130.1 0.00987 1013 3.500 9.30 3.50 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4.500 12.60 4.50 3.96 3.83 7500 00 8430.00 0.01522 65.7 0.01967 50.8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5.500 17.00 5.50 4.89 4.77 6280.00 7740 00 0.02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7.000 29.00 7.00 6.18 6.06 7020 00 8160.00 0.03715 26.9 0 04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47.00 9.63 _ 8.68 8.53 4760 00 6870.00 0.07321 13.7 0.08999 11.1 13.375 72 00 13.38 12.35 12.19 2670.00 5380.00 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 4 1/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 . 55 133# 3060 • CD L M 03 U m � ` Z UI Y Z CO CO ' �I O Z co + I co C c _ E c O N 5 C L a o) 3 O _Q w (I) _ o .X a) Q p U E -c 4- ca -g U CD CO s o C LID m E § c o o o_ ° a) O O o c co E t a �— G o O Q.c C U cz O , p O W CO i1 O N O E W p I. CD W a.) >,-o Z .)o 0)U) w c6 �� O ` _ E 2 � cm L -0 CO o N p Q In >, 0 L. / _ 7 C N CO = R O = O X �' a) O � U C O ,0 U / o N a) -o co . . 0 �s t fA O conU O .0) •N O d -o c) ca 0)•- _c § - � ++ o .C -0 C -2 ` O a N / O c o N p a) w C i z as as C 7 a) o C a) U 744 - Z / a In i Q) a) O a) O O a) / o CI O03D000Zai ` I0 Lo O CO N c- CO O) O CO CD CO I 1— ♦ CO N N ' c— c- c- r- LO CO n co LO O LO CD LO CD LO I— O 0) O L() N- c0 O O O O c- V- c— c— V- (Ni (Ni N :1115 7 O N O CA CO N- Ln O CO Cr) N s— ' CO LC.) LO CO v- CO V— UIn O If) CD I!) f— CO 0) O If) 00 (A CA 0 0 0 0 0 U) ++ ,— O N- (0 C)) LO LO CO O CO CO N N r CO Z O U lb C Y V IS) N- 0) r-- M In CO � O cd ccicd wCicri crirn ' Cl)' LO N __ /7• O 0 0 0 0 c, CD 0) IN CO "Y N 0) N. r- 6) CO co .- In In In v N N 1' c0 Q N N N N N N— 0 N a) (I) C.) (ho al C .' Z L!") CO f� 00 O O c— N c') V Ln CO N- CO O O LL Q) 00 cd co 00 00 C)) C)) C)) C)) 6) o) O) 0) O) O) O W N c , TREE.= CM/ WELLHEAD= FMC ` FY NOTES: WELL REQUIRES A SSSV. ACTUATOR= BAKER C AG 1-01 A **"ORIGINAL WELL NOT SHOWN*** KB.ELEV= 49' BF.ELEV= 1 - KOP= 1851' X Max Angle= 48°@ 5893' - I 2205' 1-17-5/8"X 7"XO,ID=6.276" Datum MD= 9357' Datum TV D= 8800'SS I I 2216' IH 7"CAMCO DB-6 NIP,ID=6.00" I 13-3/8"CSG,68#,K-55 XO TO NT-80 H 122' ( --I 2227' H 7"X 7-5/8"XO, ID=6.276" I 13-3/8"CSG,68#,NT-80, ID=12.415" H 3911' I-A ■ Minimum ID = 5.770" @ 9965' 7" HES RN NIPPLE 9912' H 7-5/8"X 7"XO,ID=6.276" I 7-5/8"IPC TBG,29.7#, L-80 VAM TOP, H 9912' .0459 bpf,ID=6.875" 9924' 117"HES R NIP, ID=5.963" , I 9945' H9-5/8"X 7"BKR S-3 PKR,ID=6.000" I \\ 9965' H 7"HES RN NIP,ID=5.770" 9980' 1 7x/p8"X 7"BKR HRD LTP w/BKR HMC LNR HGR, ID=6.276" 9986' 1--17"MULE SHOE, ID=6.276" I 7"IPC TBG,26#, L-80 TCII, .0383 bpf, ID=6.276" H 9986' f 9-5/8"CSG,47#, L-80 HYD 563,ID=8.681" 10162' PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON 02/08/10 ANGLE AT TOP PERF: 20°@ 10220' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10220- 10430 O 03/01/10 3-3/8" 6 10465-10496 0 r 03/01/10 PBTD -1 10536' I ��04 7"LNR,26#,L-80 VAM TOP HC, H 10621' I .0383 bpf,ID=6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/29/92 AUDI 2 ORIGINAL COMPLETION WELL: AGI-01A 02/12/10 014 SIDETRACK(AGI-01A) PERMIT No: 2091640 02/14/10 TLH DRLG HO CORRECTIONS API No: 50-029-22307-01-00 03/17/10 JED/SV PERFS(03/01/10) SEC 36,T12N,R14E, 1583'FSL&2390'FEL 03/29/10 JR/JMD DRLG DRAFT CORRECTIONS _ 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) r ok STATE OF ALASKA RECEIVED R ALASKA OIL AND GAS CONSERVATION COMMISSION MAR Z 5 2010 WELL COMPLETION OR RECOMPLETION REPORT AND pfL�tOG la. Well Status: ❑Oil ❑Gas ❑SPLUG ❑Other ❑Abandoned ❑Suspended 1b. v1 �843§ ' 20AAC 25.105 20AAC 25.110 ❑ Developm ploratory ® GINJ ❑WINJ ❑WAG ❑WDSPL ❑Other No.of Completions One El Service ❑Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska)Inc. 3/1/2010 209-164 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 1/26/2010 50-029-22307-01-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number. Surface: 2/7/2010 AGI-01 A 1583'FSL,2390'FEL,SEC.36,T12N, R14E, UM 8. KB(ft above MSL): 47 7' 15.Field/Pool(s): Top of Productive Horizon: 1210'FSL,3080'FWL, SEC.31,T12N, R15E, UM GL(ft above MSL): 13.4' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 1196'FSL,3213'FWL, SEC.31,T12N, R15E, UM 10577' 8453' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 688901 y- 5979224 Zone- ASP4 10623' 8497' ADL 028301 &034628 TPI: x- 694379 y- 5978991 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 694513 y- 5978980 Zone- ASP4 None 18.Directional Survey: Yes ❑No ' 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/ VD: DIR/GR/RES/PWD, DIR/GR 3915' 3490' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 75' Surface 75' 30" 11 cu vds Arcticset 13-3/8" 68# NT-80 40' 3911' 40' 3487' 16" 1500 sx Permafrost'E'.400 sx Class'G' 9-5/8" 47# L-80 32' 10162' 32' 8062' 12-1/4" 552 sx Class'G' 7" 26# L-80 9980' 10621' 7891' 8495' 8-1/2" 154 sx Class'G' 24. Open to production or injection? ®Yes ❑No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND) (MD+TVD of Top&Bottom;Perforation Size and Number): 1 3-3/8"Gun Diameter,6 spf 7-5/8",29.7#, L-80 2205' MD ND MD ND 7",26#, L-80 2205'-9986' 9945'/7858' 10220'-10430' 8116'-8314' Y6. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10465'-10496' 8347'-8376' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Freeze Protected w/144 Bbls of Diesel 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): March 4,2010 Gas Injection Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? ❑ Yes El No Sidewall Core(s)Acquired? ❑Yes IN No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas_or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 2Q AAC?250v071. None 21& :v 2010 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only k 29. GEOLOGIC MARKERS(List all formations and :ers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 4 5954' 4917' None Ugnu 3 6662' 5404' Ugnu 1 7310' 5859' West Sak 2 8035' 6360' West Sak 1 8210' 6482' Colville Mudstone 3 8380' 6601' Colville Mudstone 2 9189' 7188' Colville Mudstone 1 9740' 7666' Top HRZ 9976' 7887' Base HRZ 10200' 8098' Sadlerochit/LCU 10218' 8114' 43SB 10232' 8128' 42SB/Zone 4A 10262' 8156' Top CGL/Zone 3 10279' 8172' Base CGL/Zone 2C 10344' 8233' 23SB/Zone 2B 10420' 8304' 22TS 10444' 8327' 21 TS/Zone 2A 10474' 8355' 21P 10534' 8412' Zone 1B 10560' 8437' Formation at Total Depth(Name): Zone 1B 10560' 8437' 31.List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. 03/Q406 Signed: Terrie Hubble ''1 j 1 � ���(,4'6 Title: Drilling Technologist Date: AGI-01A 209-164 Prepared By Name/Number. Tome Hubble, 564-4628 Well Number Permit No./Approval No. Drilling Engineer: Frank Roach,564-4373 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only ! kk 0) 0 § a a a \ @ 7 c § ( I cri 0.1 ■ k k a k ) \ CD N CO * ® § k0. q o § f k k 0. \ \ \ CO Co ) 9a z a a f O E § 8 S g « a a a • Cn O 0_ I- X 0_ 0 o 0 0 $ £ Q @ g o } \ $ 43) J 2 2 F e F o o o _ 4 a 4 $ \ $ ® % k / 7 < < ( -J \ C 2 z E e o = o \ E ° d \ \ / cu• § % \ BP EXPLORATION Page 1 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/7/2010 21:00-00:00 3.00 MOB N WAIT PRE RIG RELEASED FROM CONOCO PHILLIPS WELL 2L-326 ON 6 JANUARY 2010 AT 14:30 HRS. MOVE RIG TO MILNE POINT TURN-OFF. ARRIVE AT TURN-OFF AT 21:00 HRS 7 JANUARY 2010. WAIT ON BP SECURITY AT THE MILNE POINT TURN-OFF IN ORDER TO CONTINUE THE RIG MOVE TOWARDS AGI-01A. 1/8/2010 00:00-00:00 24.00 MOB N WAIT PRE WAITING ON BP SECURITY AT THE MILNE POINT TURN-OFF DUE TO THE NABORS 16E RIG MOVE ON SPINE ROAD. 1/9/2010 00:00-04:00 4.00 MOB N WAIT PRE WAIT ON SECURITY AT THE MILNE POINT TURN-OFF DUE TO THE NABORS 16E. 04:00-12:00 8.00 MOB P PRE MOVE THE RIG FROM THE MILNE POINT TURN-OFF TO IN FRONT OF MOBIL PAD AND STOPPED.UNABLE TO CROSS THE KUPARUK RIVER BRIDGE DUE TO AMBIENT TEMPERATIRE BEING BELOW-35 DEG F. 12:00-00:00 12.00 MOB N WAIT PRE STOPPED IN FRONT MOBIL PAD. UNABLE TO CROSS THE KUPARUK RIVER BRIDGE DUE TO AMBIENT TEMPERATIRE BEING BELOW-35 DEG F. 1/10/2010 00:00-00:00 24.00 MOB N WAIT PRE WAIT IN FRONT OF MOBIL PAD FOR THE WEATHER TO WARM UP ABOVE-35 DEG F IN ORDER TO PLACE RIG MATS ACROSS THE KUPARUK RIVER BRIDGES AND THEN MOVE THE RIG ACROSS THE BRIDGE. WORKED ON ITEMS FROM BILL HOPKINS AUDIT. 1/11/2010 00:00-00:00 24.00 MOB N WAIT PRE WAITING IN FRONT OF MOBIL PAD FOR THE WEATHER TO WARM UP ABOVE-35. DURING A BREAK IN THE WEATHER TODAY WHEN IT WARMED UP TO-31 CH2MHILL WAS ABLE TO PLACE SOME OF THE RIG MATS ACROSS THE KUPARUK BRIDGE BUT HAD TO SHUT DOWN WHEN THE WEATHER WENT BELOW-35. RIG CREWS STILL WORKING ON SOME ITEMS FROM THE BILL HOPKINS AUDIT AND DOING TABLE TOP DRILLS. 1/12/2010 00:00-03:00 3.00 MOB N WAIT PRE WAITING ON THE WEATHER TO WARM UP IN ORDER TO MOVE THE RIG ACROSS THE KUPARUK RIVER BRIDGES. CH2MHILL BEGAN TO LAY MATS ON THE BRIDGES AGAIN BECAUSE THE WEATHER WARMED UP ABOVE-35. 03:00-22:30 19.50 MOB P PRE MOVE RIG FROM IN FRONT OF MOBIL PAD AND CROSS KUPARUK RIVER BRIDGE.CONTINUE MOVE ON SPINE ROAD.TURN ON TO OXBOW ROAD.TURN ON WEST DOCK AND CONTINUE MOVE TO AGI PAD. ARRIVE AT AGI PAD. 22:30-23:00 0.50 WHSUR P DECOMP START CHARGING RIG DAY RATE TO AFE. POSITION RIG. 23:00-23:30 0.50 WHSUR P DECOMP PJSM ON REMOVING BOOSTER WHEELS(REAR ONLY FOR RIG MOVE). 23:30-00:00 0.50 WHSUR P DECOMP REMOVE REAR BOOSTER WHEELS.TAKE ON FUEL AND WATER. POSITION BOP STACK TO BE LOADED INTO CELLAR 1/13/2010 00:00-02:00 2.00 WHSUR DECOMP CONTINUE TO TAKE ON FUEL AND WATER. POSITION BOP STACK TO BE LOADED INTO CELLAR LAY RIG MATS IN FRONT OF BOP CRADLE.WARM UP RIG. 02:00-03:00 1.00 WHSUR DECOMP POSITION RIG OVER BOP CRADLE AND LOAD BOP STACK INTO CELLAR. 03:00-03:30 0.50 WHSUR DECOMP PJSM FOR EXTENDING CONVEYOR. Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 2 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/13/2010 03:30-06:00 2.50 WHSUR DECOMP EXTEND CONVEYOR AND LOCK INTO PLACE.HOOK UP KOOMEY LINES TO BOP STACK. 06:00-09:00 3.00 WHSUR DECOMP LAY HERCULITE AROUND WELL AND SET RIG MATS TO COVER RIG FOOTPRINT. 09:00-10:00 1.00 WHSUR DECOMP MOVE RIG ONTO RIG MATS AND PREPARE TO MOVE OVER WELL. 10:00-12:00 2.00 WHSUR N WAIT DECOMP WAIT ON DSM TO BLEED WELLHEAD PRESSURES. WHILE WAITING ON DSM,CHANGE OUT DRIVE BEARING ON#1 CONVEYOR. 12:00-18:00 6.00 WHSUR DECOMP BLEED WELL PRESSURES TO ZERO. PRESSURE KEPT BUILDING AFTER ANNULI SHUT-IN.ULTIMATELY BLED 10 BBLS BACK AND PRESSURES STABILIZED AT ZERO. 18:00-20:30 2.50 WHSUR DECOMP SPOT AND SHIM RIG OVER WELL. LAY RIG MATS FOR ROCK WASHER AND CUTTINGS TANK.LAY HERCULITE ON TOP OF RIG MATS AND SPOT ROCKWASHER AND CUTTINGS TANK. 20:30-21:00 0.50 WHSUR DECOMP PJSM ON SKIDDING RIG FLOOR OVER WELL. 21:00-00:00 3.00 WHSUR DECOMP SKID RIG FLOOR OVER WELL. PROBLEMS WITH HYDRAULICS WHILE SKIDDING RIG FLOOR.HOOK UP SERVICE LINES TO RIG FLOOR.THAW OUT PITS WITH 290 BBLS HOT WATER.HOOK UP SUCTION LINES IN PITS. CH2MHILL HARDLINE CREW TO LAY HARDLINE FROM CELLAR TO OPEN TOP TANK. 1/14/2010 00:00-07:00 7.00 WHSUR DECOMP CONTINUE TO WARM UP AND THAW PITS AND LINES IN RIG.TAKE ON BRINE AS PITS BECOME READY.CLEAN RIG FLOOR IN PREPARATION FOR RIG OPERATIONS. 07:00- 11:30 4.50 WHSUR DECOMP CONDUCT RIG INSPECTION/PERSONAL SAFETY AUDIT WITH BILL HOPKINS AND ALLEN GRAFF. DURING INSPECTION,LOAD AND STRAP 5"DRILLPIPE AND TAKE ON BRINE. 11:30-12:30 1.00 WHSUR DECOMP PRE-SPUD/SAFETY MEETING WITH BOTH CREWS. EMPHASIS ON ADDITIONAL MEASURES/PRECAUTIONS FOR THIS WELL AND NEW SITE CONTROL POLICIES FOR ADW. 12:30-16:00 3.50 WHSUR DECOMP FINISH RIG INSPECTION/PERSONAL SAFETY AUDIT WITH HOPKINS/GRAFF. RIG ACCEPTED 16:00 HRS. 16:00-20:00 4.00 WHSUR DECOMP RU SWAB VALVE AND SWAB CAP TO TREE. RU TO TEST TX IA AND OA. 20:00-21:30 1.50 WHSUR DECOMP PRESSURE TEST T X IA TO 500 PSI.LLR 1 BPM AT 500 PSI. 16 BBLS PUMPED ON TEST. RU LINES TO OA AND TEST OA(OPEN SHOE). LLR 1.5 BPM AT 900 PSI.7.5 BBLS PUMPED ON TEST. 21:30-23:00 1.50 WHSUR DECOMP RU LUBRICATOR AND TEST TO 500 PSI. PULL BPV WITH LUBRICATOR. RD LUBRICATOR. 23:00-23:30 0.50 WHSUR DECOMP LINE UP TO PUMP DOWN IA AND TAKE RETURNS UP THE TUBING AND OUT TO THE OPEN TOP TANK.REVERSE CIRCULATE 50 BBL 9.8 PG BRINE AT 3 BPM,400 PSI TO CLEAR TUBING OF DIESEL FREEZE PROTECT. 19 BBLS DIESEL RECOVERED 23:30-00:00 0.50 WHSUR DECOMP LINE UP TO PUMP DOWN TUBING AND TAKE RETURNS UP THE IA AND OUT TO THE OPEN TOP TANK. CIRCULATE 50 BBL SAFE-SURF-O PILL FOLLOWED BY 9.8 Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 3 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/14/2010 23:30-00:00 0.50 WHSUR DECOMP PPG BRINE.CIRCULATE 80 BBLS TOTAL THE LONG WAY AT 3 BPM, 150 PSI TO CLEAR IA OF DIESEL FREEZE PROTECT. 12 BBLS DIESEL RECOVERED. 1/15/2010 00:00-02:30 2.50 WHSUR DECOMP CIRCULATE 9.8 PPG BRINE SURFACE TO SURFACE, THROUGH TUBING CUT AT 7152'.CIRC RATE 3 BPM AT 250 PSI. 02:30-03:00 0.50 WHSUR DECOMP RUN AND SET TWC IN WELLHEAD WITH T-BAR. 03:00-06:30 3.50 WHSUR DECOMP RU AND PERFORM ROLLING TEST ON TWC FROM BELOW TO 500 PSI. FLUID LEAKING BY TWC.LINE UP TEST PUMP AND TEST TWC FROM ABOVE TO 4000 PSI. HOLD TEST FOR 10 MINUTES.GOOD TEST. LINE UP AND ATTEMPT ROLLING TEST ON TWC FROM BELOW AGAIN TO 500 PSI. FLUID STILL LEAKING PAST TWC WITH FLOW DIMINISHING.SHUT DOWN,BLEED OFF AND RU TO TEST THIRD TIME. 500 PSI ROLLING TEST GOOD.TOTAL VOLUME PUMPED FOR BELOW TEST: 12.6 BBLS. 06:30-08:00 1.50 WHSUR DECOMP N.P TREE AND ADAPTER FLANGE. REMOVE FROM CELLAR(NEW TREE TO BE INSTALLED AT COMPLETION OF WELL). 08:00-10:00 2.00 WHSUR DECOMP INSPECT WELLHEAD AND TUBING HANGER.CLEAN LIFT THREADS ON TUBING HANGER.CHECK NSCC LIFT THREADS BY SCREWING ON CROSSOVER.9-TURNS SUCCESSFUL. 10:00-18:00 8.00 WHSUR DECOMP NU BOPE. INSTALL HCR CHOKE AND KILL VALVES.RU CHOKE LINE,RISER AND FLOWLINE. 18:00-23:00 5.00 WHSUR DECOMP INSTALL REDRESSED 4-1/2"X 7"VBR'S IN TOP OF STACK. INSTALL REDRESSED 3-1/2"X 6"VBR'S IN BOTTOM OF STACK. 23:00-00:00 1.00 WHSUR DECOMP RU TO TEST BOPE. 1/16/2010 00:00-11:30 11.50 WHSUR P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH WITH 5"AND 7"TEST JOINTS.TEST ANNULAR TO 250 PSI LOW,3500 PSI HIGH WITH 5"TEST JOINT ONLY. NEEDED TO THAW TEST MANIFOLD,TROUBLESHOOT TOP DRIVE ISSUES, FUNCTION VBR THREE TIMES BEFORE SOLID TEST,TIGHTEN LEAKING CHOKE HCR LINE HOSE. TEST WITNESSED BY AOGCC REP JOHN CRISP,BP WSLS FERGUSON,HEFLEY,BUZBY AND ROACH,AND DOYON TPS EGHOLM AND GOCHENAUER. 11:30- 12:00 0.50 WHSUR P DECOMP RD TEST EQUIPMENT.BLOW DOWN CHOKE AND KILL LINES. 12:00-14:30 2.50 WHSUR P DECOMP RU DSM LUBRICATOR.TEST LUBRICATOR TO 500 PSI FOR 5 MINUTES.PULL TWC. RD DSM. 14:30-16:00 1.50 WHSUR P DECOMP MAKE UP CROSSOVER TO LANDING JOINT.MAKE UP TO HANGER.BACK OUT LOCK DOWN SCREWS. -UNSEAT HANGER WITH 205K UP WT. -PULL HANGER TO RIG FLOOR WITH 202K UP WT. 16:00-18:00 2.00 WHSUR P DECOMP CIRCULATE BOTTOMS UP. 250 GPM © 190 PSI.LOSSES DURING CIRC-40 BBLJHR. -WHILE CIRCULATING, RU TO LD 7"INJECTION TUBING AND DUAL CONTROL LINE 18:00- 19:00 1.00 PULL P DECOMP LD LANDING JOINT AND HANGER.HOOK UP DUAL Printed: 2118/2010 4:55:50 PM BP EXPLORATION Page 4 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/16/2010 18:00-19:00 1.00 PULL P DECOMP CONTROL LINE TO SCHLUMBERGER SPOOLER. 19:00-22:00 3.00 PULL P DECOMP LD 7",26#,L-80 TUBING AND DUAL CONTROL LINE FROM 7,152'TO 4,950'. FILL HOLE EVERY 10 JOINTS. -STOP AT SSSV. -51 BBLS LOST TO PC LEAK WHILE LD TO SSSV.AVG LOSS RATE: 15 BBUHR. 22:00-22:30 0.50 PULL P DECOMP RD SCHLUMBERGER CONTROL LINE SPOOLER. 22:30-00:00 1.50 PULL P DECOMP LD 7",26#,L-80,NSCC TUBING FROM 4,950'TO 3,470'. 1/17/2010 00:00-00:30 0.50 PULL P DECOMP INSPECT AND SERVICE TOP DRIVE, BLOCKS,AND DRAWWORKS. 00:30-03:30 3.00 PULL P DECOMP LD 7",26#,L-80,NSCC TUBING FROM 3,470'TO SURFACE. -RECOVERED 28 SS BANDS, 180 JOINTS, 1 SSSV,2 FLOW COUPLINGS,2 PUP JOINTS, 1 CUT JOINT -CUT JOINT LENGTH 16.99' -CHEMICAL CUT LOOKED GOOD -GENERAL CONDITION OF TUBING IS GOOD. -262 BBLS FLUID LOST WHILE LD TUBING FROM SSSV TO CUT. 03:30-04:30 1.00 PULL P DECOMP RD 7"HANDLING TOOLS,CLEAN AND CLEAR RIG FLOOR. 04:30-06:00 1.50 BOPSUF P DECOMP RU TO TEST LOWER 3-1/2"X 6"VBR AND BLIND RAMS. 06:00-09:00 3.00 BOPSUF P DECOMP TEST LOWER 3-1/2"X 6"VBR AND BLIND RAMS TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH. 09:00-09:30 0.50 BOPSUF P DECOMP RD TEST EQUIPMEMNT. BLOW DOWN CHOKE AND KILL LINES. 09:30-20:30 11.00 CLEAN P DECOMP JU, BHA#1 8 1/2"BIT,CASING CSRAPER, B_QQT BASKET, FLOAT SUB AND RIH ON 5"DP PICKING UP SINGLES FROM THE PIPE SHED TO 7,151' -TAG UP ON 7"TUBING STUB AT 7,151' -PU WT: 175K,SO WT: 145K. -FILL PIPE EVERY 25 STANDS 20:30-21:30 1.00 CLEAN P DECOMP CIRCULATE BOTTOMS UP AT 390 GPM,550 PSI. -18 BBLS LOST DURING CIRC. 21:30-00:00 2.50 CLEAN P DECOMP POH FROM 7,151'TO 2,130'. 1/18/2010 00:00-01:30 1.50 CLEAN P DECOMP POH FROM 2,130'TO SURFACE. -BOOT BASKETS WERE CLEAN 01:30-02:30 1.00 CLEAN P DECOMP LD BHA#1.CLEAN AND CLEAR RIG FLOOR. 02:30-06:30 4.00 EVAL P DECOMP PJSM WITH SLB E-LINE CREW.MOBILIZE E-LIN EQUIPMENT TO RIG FLOOR AND RIG UP LUBRICATOR WITH PUMP-IN SUB AND PACKOFF. 06:30-09:30 3.00 EVAL P DECOMP RIH WITH USIT TO 5,100'ELM. LOG UP FROM 5,100'TO 200'IN CEMENT EVAULATION AND CORROSION MODE. 09:30-11:00 1.50 EVAL P DECOMP LAY DOWN USIT TOOLS. 11:00-13:00 2.00 DHB P DECOMP PREP FIRING HEAD FOR EZSV.MAKE UP EZSV TO FIRING HEAD. 13:00-14:30 1.50 DHB P DECOMP RIH WITH EZSV ON E-LINE.,SET EZSV.POOH. -TOP OF PLUG AT 4.150'ELM„ 14:30- 16:00 1.50 DHB P DECOMP RD E-LINE AND LUBRICATOR. 16:00- 16:30 0.50 DHB P DECOMP CLOSE BLIND RAMS AND TEST EZSV TO 2,500 PSI FOR 10 MINUTES.GOOD TEST. 16:30-19:30 3.00 BOPSUF P DECOMP PULL WEAR RING.INSTALL TEST PLUG AND 9-5/8"TEST JOINT.CHANGE TOP RAMS TO 9-5/8"FIXED PIPE RAMS. 19:30-20:00 0.50 BOPSUF P DECOMP TEST 9-5/8"RAMS TO 250 PSI LOW,4,000 PSI HIGH FOR 5 MINUTES EACH TEST. BOTH TESTS GOOD. Printed: 2/18/2010 4:55:50 PM 11) BP EXPLORATION Page 5 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/18/2010 20:00-21:00 1.00 BOPSUP P DECOMP RIG DOWN BOP TESTING EQUIPMENT. LD 9-5/8"TEST JOINT.CLEAN AND CLEAR RIG FLOOR. 21:00-21:30 0.50 STCTPL P DECOMP PU COMPONENTS FOR BHA#2 -CASING CUTTER -8-1/2"STABILIZER 21:30-00:00 2.50 STCTPL P DECOMP RIH FROM SURFACE TO 3,875'. 1/19/2010 00:00-00:30 0.50 STCTPL P DECOMP INSPECT AND SERVICE TOP DRIVE, BLOCKS,AND DRAW W ORKS. 00:30-01:00 0.50 STCTPL P DECOMP RIH FROM 3,875'TO 4,155'AND TAG EZSV. -PU WT: 120 SO WT: 116 01:00-01:30 0.50 STCTPL P DECOMP PJSM ON FLUID SWAP,CASING CUT,AND OA CIRC OUT. 01:30-02:30 1.00 STCTPL P DECOMP DISPLACE 9.8 PPG BRINE OUT OF WELL WITH 9.2 PPG LSND. -DISPLACE 250 GPM AT 900 PSI 02:30-03:00 0.50 STCTPL P DECOMP POH 2 STANDS. PU SINGLE JOINT. ENGAGE PUMPS TO OPEN KNIVES.SLACK OFF AND LOCATE COLLAR AT 3,975'.SLACK OFF 11'TO CUT DEPTH AT 3,986'.WITH PUMPS OFF, ESTABLISH CUTTING PARAMETERS -PU WT: 120K;SO WT: 116; ROT WT: 120K,3K TORQUE AT 40 RPM. -OA PRESSURE 110 PSI 03:00-04:00 1.00 STCTPL P DECOMP LINE UP TO TAKE RETURNS FROM OA VALVE TO OPEN TOP TANK.BLEED OFF OA PRESSURE PRIOR TO CASING CUT. -OA PRESSURE AT ZERO BEFORE CUTTING CASING. BEGIN CASING CUTTING. -ROTATING 80 RPM CONTSTANT -STAGE UP PUMP PRESSURE FROM 350 PSI TO 900 PSI FINAL TO FULLY EXTEND KNIVES. -TORQUE BOUNCED FROM 1-5K.SETTLED AT 2K WHEN KNIVES FULLY EXTENDED. -CLOSE BAG AND PUMP DOWN DRILLPIPE,LOOKING FOR RETURNS OUT OA.84 GPM CO 150 PSI TAKING RETURNS OUT OA.SHUT DOWN PUMPS AND OPEN BAG. 04:00-06:00 2.00 STCTPL P DECOMP SPOT SAFE-SURF-O AND HIGH VIS SWEEP DOWN DRILLPIPE. -190 GPM CO 850 PSI. CLOSE BAG AND PUMP SWEEP TAKING RETURNS OUT OA AND TO OPEN TOP TANK. -150 GPM @ 500 PSI -DIESEL FREEZE PROTECT INITIAL RETURNS. 150 BBLS RECOVERED -BRINE RETURNS AFTER 180 BBLS DISPLACEMENT -OLD MUD IN RETURNS AT 222 BBLS DISPLACEMENT -NEW LSND MUD RETURNS AT 253 BBLS DISPLACEMENT -280 BBLS TOTAL DISPLACEMENT SHUT DOWN PUMPS.CONFIRM WELL DEAD. 06:00-08:30 2.50 FISH P DECOMP BLOW DOWN TOP DRIVE AND HARDLINE TO OPEN TOP TANK.ATTEMPT TO OPEN PUMP-OUT SUB. NO SUCCESS. Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 6 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/19/2010 06:00-08:30 2.50 FISH P DECOMP POH FROM 3,986'TO SURFACE. 08:30-09:30 1.00 FISH P DECOMP LAY DOWN CUTTER ASSEMBLY.CLEAN AND CLEAR RIG FLOOR. -KNIFE WEAR PATTERN SHOWED EVEN WEAR. 09:30-10:00 0.50 FISH P DECOMP PICK UP AND MAKE UP SPEAR ASSEMBLY WITH PACKOFF. 10:00-10:30 0.50 FISH P DECOMP RIH AND SPEAR CASING HANGER.VERIFY GRAPPLE IS SET 10:30-11:00 0.50 FISH P DECOMP BACK OUT LOCK DOWN SCREWS AND ATTEMPT TO UNSEAT HANGER. -P/U TO 225K.SLACK OFF. -WORK P/U WT TO 300K.SLACK OFF. -WORK PIPE BETWEEN 225K-350K WHILE PUMPING 84 GPM @ 250 PSI. RETURNS AT SURFACE. -CONTINUE TO WORK PIPE, INCREASING PUMP RATE TO 120 GPM @ 500 PSI. -PIPE BROKE LOOSE. PU WT NOW 280K. 11:00- 11:30 0.50 FISH P DECOMP CIRCULATE BOTTOMS UP THROUGH SPEAR,TAKING RETURNS OVER SHAKERS. -STAGE UP PUMPS TO FINAL RATE 550 GPM @ 450 PSI. WHILE CIRCULATING,MOBILIZE CASING HANDLING EQUIPMENT TO RIG FLOOR. 11:30-12:00 0.50 FISH P DECOMP PULL HANGER TO FLOOR. -CIRCULATE WHILE PULLING TO FLOOR. 120 GPM @ 180 PSI. 12:00-13:30 1.50 FISH P DECOMP RELEASE SPEAR AND LAY DOWN SAME. BACK OUT HANGER AND PUP JOINT.AND LAY DOWN SAME. RIG UP TO CIRCULATE. 13:30-15:30 2.00 FISH P DECOMP RU DOUBLE STACKED TONGS AND CASING HANDLING EQUIPMENT. -WHILE RIGGING UP,CIRCULATE 170 GPM @ 150 PSI. 15:30-22:30 7.00 FISH P DECOMP ,LAY DOWN 9-5/8",47#, L-80, NSCC CASING TO CUT AT 3,986'. -INTIAL CASING LOOKED GOOD -FROM JOINT 80 TO CUT JOINT,THICK MUD CAKED ON OD OF CASING. -CUT JOINT LENGTH:5.75' -CUT FLARE OD: 10.25" -TOTAL JOINTS RECOVERED: 101 PLUS CUT JOINT. 22:30-00:00 1.50 FISH P DECOMP RIG DOWN CASING HANDLING EQUIPMENT.CLEAN AND CLEAR RIG FLOOR. 1/20/2010 00:00-02:00 2.00 FISH P DECOMP CONTINUE TO RIG DOWN CASING HANDLING EQUIPMENT. CLEAN AND CLEAR RIG FLOOR. 02:00-04:00 2.00 BOPSUF P DECOMP INSTALL TEST PLUG AND 5"TEST JOINT.CHANGE TOP RAMS TO 4-1/2"X 7"VBR. FILL STACK AND RIG UP TEST EQUIPMENT. Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 7 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/20/2010 04:00-04:30 0.50 BOPSUR P DECOMP TEST 4-1/2"X 7"VBR TO 250 PSI LOW,500 PSI HIGH FOR 5 MINUTES EACH. -GOOD TEST 04:30-05:00 0.50 BOPSUF P DECOMP RIG DOWN BOP TEST EQUIPMENT. PULL TEST JOINT AND TEST PLUG. 05:00-08:30 3.50 STCTPL P DECOMP MOBILIZE 3-1/2"HANDLING EQUIPMEMT TO RIG FLOOR. MAKE UP 3-1/2",9.2#,NSCT STINGER BHA TO 937', 08:30-10:30 2.00 STCTPL P DECOMP RIH ON DRILLPIPE FROM 937 TO 3,986'.SLOWLY ENTER 9-5/8"CASING STUB.CONTINUE TO RIH. TAG EZSV AT 4,150' PULL UP TO HAVE CEMENT HEAD AT GOOD WORKING HEIGHT.MULESHOE AT 4,145'. 10:30-12:30 2.00 STCTPL P DECOMP MAKE UP HEAD PIN AND CEMENT LINE.CIRCULATE 390 GPM @ 350 PSI. 12:30-13:00 0.50 STCTPL P DECOMP PRE-JOB SAFETY MEETING WITH RIG CREW AND SCHLUMBERGER CEMENTERS. 13:00-14:30 1.50 STCTPL P DECOMP BEGIN BATCH MIXING 17.0 PPG CEMENT -PUMP 5 BBLS MUD PUSH II -PRESSURE TEST LINES TO 4500 PSI -PUMP 36 BBLS MUDPUSH II;3.9 BPM,205 PSI -PUMP 81 BBLS 17.0 PPG CEMENT PLUG --30 BBLS AWAY 4.8 BPM,340 PSI --40 BBLS AWAY 4.8 BPM,301 PSI --50 BBLS AWAY 4.7 BPM,310 PSI --70 BBLS AWAY 4.8 BPM,333 PSI --81 BBLS AWAY 1.8 BPM,228 PSI -PUMP 5 BBLS MUDPUSH II;2.7 BPM,255 PSI SWITCH TO RIG PUMPS AND BEGIN DISPLACEMENT WITH 9.2 PPG LSND MUD -DISPLACE AT 9.2 BPM; INITIAL PRESSURE 190 PSI. --45 BBLS AWAY 9.1 BPM,590 PSI --55 BBLS AWAY 9.1 BPM,590 PSI SHUT DOWN PUMPS.RIG DOWN SCHLUMBERGER CEMENTERS. 14:30- 16:30 2.00 REMCMTP DECOMP SLOWLY PULL STINGER OUT OF CEMENT PLUG TO 34Q' 16:30-18:00 1.50 REMCM-P DECOMP DROP FOAM WIPER BALL DOWN DRILLPIPE AND CIRCULATE 1.5 BOTTOMS UP WHILE RECIPROCATING PIPE. -380 GPM @ 270 PSI -PU WT 100K;SO WT 100K -NO CEMENT OBSERVED IN RETURNS,BUT INCREASED PH WAS NOTED. 18:00- 19:30 1.50 REMCM-P DECOMP FLOW CHECK WELL.ZERO FLOW. POH TO 937' 19:30-22:00 2.50 REMCMTP DECOMP RU 3-1/2"HANDLING EQUIPMENT. PULL 3-1/2"STINGER BHA FROM 937 TO SURFACE. 22:00-00:00 2.00 REMCMTP DECOMP LAY DOWN 3-1/2"HANDLING EQUIPMENT.CLEAN AND Printed: 2/18/2010 4:55:50 PM ..._. _. .._ .._. BP EXPLORATION Page 8 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/20/2010 22:00-00:00 2.00 REMCM-P DECOMP CLEAR RIG FLOOR. 1/21/2010 00:00-02:00 2.00 REMCM-P DECOMP CLEAN RIG WHILE WAITING ON CEMENT TO BUILD 500 PSI COMPRESSIVE STRENGTH. 02:00-03:00 1.00 REMCM-P DECOMP PJSM ON PICKING UP DRILLPIPE. PU HEAVY WEIGHT AND DRILLPIPE SINGLES FOR DRILLPIPE MANAGEMENT AND IN PREPARATION FOR STRIPPING DRILL 03:00-03:30 0.50 REMCM-N RREP DECOMP REPAIR HYDRAULIC LEAK IN PIPE SKATE. 03:30-04:00 0.50 REMCM-P DECOMP CONTINUE TO PICK UP DRILLPIPE SINGLES. 04:00-04:30 0.50 REMCMTP DECOMP PRE-JOB MEETING FOR STRIPPING DRILL. 04:30-08:00 3.50 REMCM-P DECOMP CONDUCT STRIPPING DRILL WITH BEATTY CREW. -STRIPPED IN TWO STANDS OF DRILLPIPE POST DRILL DEBRIEF WITH ALL PARTIES INVOLVED. 08:00-09:00 1.00 REMCM-P DECOMP POH. RACK BACK DRILLPIPE. 09:00-09:30 0.50 REMCM-P DECOMP INSPECT AND SERVICE TOP DRIVE,BLOCKS,AND DRAW WORKS. 09:30-13:00 3.50 REMCMTP DECOMP RIH ON SINGLES TO 3,000'. -BUILDING STANDS IN PREPARATION FOR STRIPPING DRILL 13:00-14:00 1.00 REMCMTP DECOMP POH TO 1,200',RACKING BACK STANDS. 14:00-14:30 0.50 REMCMTP DECOMP PRE-JOB MEETING FOR STRIPPING DRILL. 14:30-16:30 2.00 REMCMTP DECOMP CONDUCT STRIPPING DRILL WITH SMITH CREW. -STRIPPED IN TWO STANDS OF DRILLPIPE POST DRILL DEBRIEF WITH ALL PARTIES INVOLVED. 16:30-17:00 0.50 REMCM-P DECOMP LUBRICATE RIG AND INSPECT TOP DRIVE. 17:00-17:30 0.50 REMCM-P DECOMP POH TO HEAVY WEIGHT AT 270'. 17:30-18:30 1.00 REMCM-P DECOMP RIH WITH LAST 21 JOINTS OF DRILLPIPE FROM PIPE SHED. 18:30-19:30 1.00 REMCM-P DECOMP POH TO SURFACE, RACKING BACK STANDS AND HEAVY WEIGHT. 19:30-22:30 3.00 BOPSUF P DECOMP RIG DOWN RISER, BELL NIPPLE,AND FLOW LINE. MOBILIZE EQUIPMENT AND PARTS TO RIG FLOOR AND CELLAR TO CHANGE ANNULAR ELEMENT. 22:30-00:00 1.50 BOPSUR P DECOMP NIPPLE DOWN TOP OF ANNULAR AND REMOVE ELEMENT. 1/22/2010 00:00-02:30 2.50 BOPSUPP DECOMP CONTINUE TO NIPPLE DOWN TOP OF ANNULAR. PULL ANNULAR ELEMENT. -ELEMENT IN GOOD CONDITION.ONE SMALL TEAR IN RUBBER. 02:30-04:30 2.00 BOPSUP P DECOMP INSTALL NEW ANNULAR ELEMENT AND RING GASKETS. NU TOP OF ANNULAR. 04:30-06:30 2.00 BOPSUF P DECOMP NIPPLE UP BELL NIPPLE, RISER,AND FLOW LINE. 06:30-09:00 2.50 BOPSUF P DECOMP PULL WEAR BUSHING. INSTALL NEW TEST PLUG. _FUNCTION TEST NEW ANNULAR ELEMENT_RU BOPE TEST EQUIPMENT. 09:00-14:30 5.50 BOPSUF P WEXIT TEST RAMS, BODY,CHOKE MANIFOLD,AND VALVES TO 250 PSI LOW,4,000 PSI HIGH FOR 5 MINUTESrEACH. PERFORM KOOMEY DRAWDOWN-GOOD TEST. TEST ANNULAR TO 250 PSI LOW,2,500 PSI HIGH FOR 5 Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 9 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/22/2010 09:00-14:30 5.50 BOPSUF P WEXIT MINUTES EACH. -CHART ALL TESTS -TEST WITNESSED BY WSL HEFLEY AND BORDES AND DOYON TP EGHOLM -AOGCC REP JOHN CRISP WAIVED WITNESS 14:30-15:30 1.00 BOPSUP P WEXIT RIG DOWN BOP TEST EQUIPMENT AND INSTALL WEAR RING 15:30-16:30 1.00 STCTPL P WEXIT MOBILIZE BHA#4 TO FLOOR 16:30-17:00 0.50 STCTPL P WEXIT PRE-JOB SAFETY MEETING ON MAKING UP 12-1/4" INTERMEDIATE BHA. 17:00-21:00 4.00 STCTPL P WEXIT MAKE UP BHA#4. UPLOAD TO MWD AND CONTINUE MAKING UP BHA. SHALLOW TEST MWD TOOLS. -710 GPM @ 1,050 PSI MAKE UP REMAINING BHA WITH HEAVY WEIGHT DRILLPIPE FROM DERRICK. 21:00-23:30 2.50 STCTPL P WEXIT RIH TO 3,383'ON STANDS 23:30-00:00 0.50 STCTPL P WEXIT CUT AND SLIP DRILLING LINE. 1/23/2010 00:00-01:00 1.00 STCTPL P WEXIT CONTINUE TO CUT AND SLIP DRILLING LINE -CUT AND SLIPPED 59' 01:00-02:00 1.00 STCTPL P WEXIT RUN IN HOLE ON STANDS AND TAG CEMENT TOP AT 3,419' -SLACKED OFF 15K TO CONFIRM TOP. 02:00-02:30 0.50 STCTPL P WEXIT ESTABLISH WASHING PARAMETERS: -PU WT 135K -SO WT 120K -ROT WT 130K W/4K FT-LBS TORQUE @ 50 RPM -1560 PSI @ 660 GPM WASH DOWN ONE STAND TO 3,473' -5KWOB -5-7K FT-LBS TORQUE CP 50 RPM -300 PSI @ 200 GPM 02:30-04:00 1.50 STCTPL P WEXIT BEGIN TO CIRCULATE WELL CLEAN. -510 GPM;980 PSI -RECIPROCATE STAND FULL 90'STROKES--15 MIN/STK -ROTATING 50 RPM;5K FT-LBS -MUD PUSH CONTAMINATED MUD SEEN AT 4,000 STKS. -HEAVILY CONTAMINATED MUD RETURNS AT 4,400 STROKES--APPEARS TO BE OLD MUD. -CIRCULATE 2X SURF TO SURF WHILE ROTATING 50 RPM,STROKING ONE FULL STAND 04:00-06:00 2.00 STCTPL P WEXIT DRILL CEMENT FROM 3,473'TO 3,600' -15-20K WOB -5-7K FT-LBS TORQUE @ 50 RPM -1400 PSI @ 650 GPM 06:00-11:30 5.50 STCTPL P WEXIT DRILL CEMENT FROM 3,575'TO 3,811' -PU WT; 140 SO WT; 123 -ROT WT 130 AT 60 RPM -14K WOB -TORQUE:4-6K ON BTM;3-7K OFF BTM Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 10 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/23/2010 06:00-11:30 5.50 STCTPL P WEXIT -700 GPM;2040 PSI 11:30- 13:00 1.50 STCTPL P WEXIT CIRCULATE NUT-PLUG SWEEP SURFACE TO SURFACE -700 GPM; 1910 PSI -ROTATE AND RECIPROCATE AT 60 RPM 13:00-14:00 1.00 STCTPL P WEXIT RIG UP AND PRESSURE TEST 13-3/8",68#L-80 BTC 30 MINUTES. TEST FAILED. REACHED 1,200 PSI AND PRESSURE FELL OFF -CHECK ALL SURFACE EQUIPMENT,AREA AROUND RIG, AND ADJACENT WELLHOUSES FOR POTENTIAL LEAKS. -LOST 700 PSI DURING INITIAL 10 MINUTES STOPPED TEST. RIG DOWN TEST EQUIPMENT. 14:00-14:30 0.50 STCTPL P WEXIT PULL FIVE STANDS AND FLOW CHECK WELL. -NO FLOW. PUMP DRY JOB. 14:30-16:00 1.50 STCTPL P WEXIT POOH FROM 3,811'TO 1,100'. 16:00-00:00 8.00 STCTPL N RREP WEXIT TROUBLESHOOT IRON ROUGHNECK. -JAWS ON IRON ROUGHNECK NOT CLAMPING HARD ENOUGH TO MAKE CONNECTIONS. -WHEN JAWS WOULD CLAMP,TORQUE WAS ERRATIC AND COULD NOT GUARANTEE CONSISTENT MAKE-UP TORQUE. -FLUCTUATING HYDRAULIC PRESSURE SEEN ON IRON ROUGHNECK PRESSURE GAUGE(FLUCTUATING PRESSURE NOT SEEN ON REST OF RIG HYDRAULIC SYSTEM). -ROUGHNECK HAVING DIFFICULTY RAISING UP. 1/24/2010 00:00-06:00 6.00 STCTPL N RREP WEXIT CONTINUE TO TROUBLESHOOT IRON ROUGHNECK. -CHECKING SUPPLY PRESSURE AT IRON ROUCHNECK -CHANGED OUT REGULATOR VALVE -WHILE REPAIRING IRON ROUGHNECK,LOAD 9-5/8",47#, HYD-563 CASING INTO PIPE SHED. NUMBER AND STRAP JOINTS. 06:00-15:00 9.00 STCTPL N RREP WEXIT CONTINUE TO TROUBLESHOOT IRON ROUGHNECK. -TIGHTEN UP FITTINGS -CHANGE OUT LIFT CYLINDER -CHANGE OUT AND ADJUST COMPENSATOR 15:00-18:00 3.00 STCTPL N RREP WEXIT CONTINUE TO TROUBLESHOOT IRON ROUGHNECK -INSPECT COUNTERBALANCE VALVE -INSPECT CHECK VALVES -TROUBLESHOOT WITH QUADCO MECHANIC OVER TELEPHONE WHILE TROUBLESHOOTING,CIRCULATE SURF TO SURF FROM 1,100'TO CLEAN AND CONDITION MUD -48-250 GPM @ 120-310 PSI -20 RPM @ 1K FT-LBS TORQUE -INITIAL MUD CONDITION WAS THICK AND HEAVILY CONTAMINATED 18:00-22:00 4.00 STCTPL N RREP WEXIT CONTINUE TO TROUBLESHOOT IRON ROUGHNECK -QUADCO MECHANIC ON RIG ADVISING AND Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 11 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/24/2010 18:00-22:00 4.00 STCTPL N RREP WEXIT TROUBLESHOOTING WITH RIG MECHANIC -INTERNAL HYDRAULIC LEAK. -ELIMINATED CYLINDERS AND SPINNERS AS POSSIBLE SOURCES OF LEAK. -CONTINUE SEARCHING FOR SOURCE OF LEAK. 22:00-00:00 2.00 STCTPL N RREP WEXIT CONTINUE TO TROUBLESHOOT IRON ROUGHNECK -PILOT VALVE ON TORQUE WRENCH UPPER CLAMP VALVE IS HEATING UP. POTNTIAL LEAK POINT. -MOBILIZING REPLACEMENT ASSEMBLY TO RIG. 1/25/2010 00:00-02:30 2.50 EVAL N RREP WEXIT CONTINUE TO TROUBLESHOOT IRON ROUGHNECK -INSTALL NEW TORQUE WRENCH UPPER CLAMP PILOT VALVE 02:30-03:00 0.50 EVAL N RREP WEXIT CONTINUE TO TROUBLESHOOT IRON ROUGHNECK -NEW PARTS UNSUCCESSFUL IN RESOLVING PRESSURE ISSUE -CONSULT WITH TOWN ODE AND PROCEED WITH PLAN TO POH USING RIG TONGS AND PIPE SPINNERS CONDUCT PRE-JOB SAFETY MEETING -DISCUSS OPERATING PIPE SPINNERS WITH CREW -PLAN TO PULL 5 STANDS USING RIG TONGS AND PIPE SPINNERS.AFTER 5 STANDS,STOP JOB AND ASSESS IF PROCEDURE NEEDS ADJUSTING. 03:00-04:30 1.50 EVAL P WEXIT POH FROM 1,112 TO 90' -RACK BACK DRILLPIPE, HEAVYWEIGHT PIPE,AND COLLARS IN DERRICK 04:30-07:30 3.00 EVAL P WEXIT LAY DOWN BHA FROM 90'TO SURFACE. -BIT LOOKED NEW 07:30-11:30 4.00 EVAL N DPRB WEXIT PICK UP 13-3/8"HALLIBURTON RTTS TEST PACKER PER HALLIBURTON REP. -LENGTH OF RTTS AND HANDLING PUPS:22' RIH TO 3,780' -WASH DOWN LAST STAND; 120 GPM @ 210 PSI -PU WT: 130K SO WT 108K 11:30-13:30 2.00 EVAL N DPRB WEXIT CIRCULATE AND CONDITION MUD -252 GPM @ 200 PSI INITIAL PRESSURE -PRESSURE DROPPED TO 150 PSI AT END OF CIRCULATION -MUD WEIGHT 8.7 PPG INITIAL;9.1 PPG FINAL AT END OF CIRCULATION 13:30- 15:30 2.00 EVAL N DPRB WEXIT SET RTTS AT 3,777'(CENTER OF ELEMENT) AND TEST 13-3/8"CASING TO 3,500 PSI -GOOD TEST RELEASE RTTS 15:30-18:30 3.00 EVAL N DPRB WEXIT POOH, RACKING BACK DRILLPIPE 18:30-19:00 0.50 EVAL N DPRB WEXIT LAY DOWN RTTS. 19:00-22:30 3.50 DRILL N DPRB WEXIT MU BHA#5,UPLOAD MWD,CONTINUE TO MU BHA TO 548' 'SHALLOW TEST MWD -726 GPM @ 1090 PSI Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 12 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/25/2010 22:30-00:00 1.50 DRILL N DPRB WEXIT RIH FROM 548'TO 2,440' 1/26/2010 00:00-00:30 0.50 DRILL P WEXIT LUBRICATE RIG.INSPECT TOP DRIVE AND DRAW WORKS. 00:30-02:00 1.50 DRILL N DFAL WEXIT RIH FROM 2,440'TO 3,780' WASH DOWN LAST STAND AND TAG CEMENT @ 3,811' MD -PU-140K,S0-120K, ROT-130RPM -1,450 PSI @ 650 GPM TORQUE=4-8 K @ 50 RPM 02:00-04:30 2.50 DRILL P WEXIT SHAKER SCREENS BLINDED OFF.WASH DOWN TO 3,811'. PICK UP TO 3,755'MD.CONDITION MUD SYSTEM -275 GPM @ 350 PSI ROTATING AND RECIPROCATING PIPE,40 RPM AND 60' STROKES Ac DRILL CEMENT FROM 3,811 TO 3,915' -15K WOB l\ -5-8K FT-LBS TORQUE @ 60-70 RPM -650 GPM © 1560 PSI 04:30-05:30 1.00 DRILL P INT1 ESTABLISH TOOLFACE AND BEGIN SLIDE TO KICKOFF FROM CEMENT PLUG -SLIDE FROM 3,915'TO 3,949'MD -TOOL FACE 113 ROHS -650 GPM @ 1,415 PSI -7K WOB 05:30-06:30 1.00 DRILL P INT1 STAND BACK 1 STAND,CIRCULATED CBU © 650 GPM 1,340 PSI ROTATE AND RECIPRICATE © 30 RPM 06:30-08:00 1.50 DRILL P INT1 RIG UP AND PERFORM LOT © 3,854;MD -MUD WEIGHT=9.2 PPG, MAX PSI=620 -LEAK OFF © 480 PSI(EMW=11.8 PPG) - -13-3/8"SHOE DEPTH=3,911'MD,3,487'TVD RIG DOWN TEST EQUIPMENT 08:00-08:30 0.50 DRILL P INT1 ESTABLISH PWD BASELINE 08:30-12:00 3.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 3,949'TO 4,233'MD. NO LOSSES DURING DRILLING. -PU-155K,SO-121K,RTW-137K, 13 WOB -725 GPM, 1750 PSI ON,725 PSI OFF -80 RPM,8K TQ ON,7K TQ OFF -MW-9.2 PPG,CALC ECD=9.66,ACTUAL ECD=9.52 PPGE -ART-1.5 HRS,AST-0.69 HRS,ADT-2.19 HRS. 12:00- 17:00 5.00 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 4,233'TO 4,800'MD. NO LOSSES DURING DRILLING. -PU-155K,SO-121K, RTW- 137K, 13K WOB -725 GPM, 1750 PSI ON,725 PSI OFF -80 RPM,8K TQ ON,7K TQ OFF -MW-9.2 PPG,CALC ECD=9.66,ACTUAL ECD=9.86 PPGE 17:00-18:00 1.00 DRILL P INT1 CIRCULATED CBU TO REDUCE THE ECD'S FROM 9.85 TO 9.67 © 725 GPM 18:00-00:00 6.00 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 4,800'TO 5,272'MD. NO LOSSES DURING DRILLING. Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 13 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/26/2010 18:00-00:00 6.00 DRILL P INT1 -PU-175K,SO-135K, RTW-152K, 13-15K WOB -795 GPM,2,440 PSI ON,2,190 PSI OFF -80 RPM,9-10K TO ON,9-10K TQ OFF -MW-9.3 PPG,CALC ECD 1 9.67,ACTUAL ECD=9.76 PPGE -ART-4.30 HRS,AST-1.87 HRS,ADT-6.17 HRS. 1/27/2010 00:00- 12:00 12.00 DRILL P INT1 DIRECTIONALLY DRJCL AHEAD FROM 5,272'TO 6,230'MD. NO LOSSES TO FORMATION DURING DRILLING. -PU-195K,SO-137K, RTW-160K, 15-35K WOB -800 GPM,2,550 PSI ON,2,270 PSI OFF -80 RPM, 11-14K TO ON,9K TQ OFF -MW-9.2 PPG,CALC ECD=9.67,ACTUAL ECD=9.87 PPGE -ART-4.91 HRS,AST-2.04 HRS,ADT-6.95 HRS. -AVERAGE BACKROUND GAS =150 12:00-00:00 12.00 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 6,230'TO 7,015'MD. NO LOSSES TO FORMATION DURING DRILLING. -PU-227K,SO-145K, RTW- 174K,25K WOB -795 GPM,2,550 PSI ON,2,400 PSI OFF -80 RPM, 13-15K TQ ON, 14-18K TO OFF -MW-9.3 PPG,CALC ECD=9.70,ACTUAL ECD=9.69 PPGE -ART-4.37 HRS,AST-2.0 HRS,ADT-6.37 HRS. -AVERAGE BACKROUND GAS =150,MAX=940 @ 6,816' MD 1/28/2010 00:00-10:30 10.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 6,230'TO 7,551'MD. NO LOSSES TO FORMATION DURING DRILLING. -PU-240K,SO-145K,RTW-180K,35K WOB -800 GPM,2,630 PSI ON,2,420 PSI OFF -80 RPM, 15K TQ ON, 13K TO OFF -MW-9.2 PPG -ART-5.58 HRS,AST-1.30 HRS,ADT-6.88 HRS. 10:30-14:00 3.50 DRILL P INT1 CIRCULATE 3X BOTTOMS UP -800 GPM(2,150 PSI) -80 RPM BACKREAM FROM 7,551'TO 7,250'MD WHILE STANDING BACK 14:00-'14:15 0.25 DRILL P INT1 FLOW CHECK FOR 15 MINUTES.STATIC 14:15-15:00 0.75 DRILL P INT1 POOH ON ELEVATORS TO 6,300' 15:00-15:15 0.25 DRILL P INT1 FLOW CHECK FOR 15 MINUTES.STATIC 15:15-17:30 2.25 DRILL P INT1 POOH TO 3,855'MD(60'INSIDE THE 13-3/8"SHOE) 17:30-18:00 0.50 DRILL P INT1 FLOW CHECK FOR 15 MINUTES.STATIC 18:00-20:30 2.50 DRILL P INT1 POOH TO BHA 20:30-21:30 1.00 DRILL P INT1 FLOW CHECK FOR 15 MINUTES.STATIC STAND BACK THE HWDP AND FLEX COLLARS 21:30-00:00 2.50 DRILL P INT1 LAY DOWN THE BHA 1/29/2010 00:00-00:30 0.50 DRILL P INT1 CONTINUE TO LAY DOWN BHA BIT 1/4"UNDER GAUGE MOTOR STABILIZER 1/16"UNDER GAUGE GHOST REAMER FULL GAUGE 00:30-01:00 0.50 DRILL P INT1 CLEAN AND CLEAR THE RIG FLOOR 01:00-03:15 2.25 DRILL P INT1 MAKE UP THE RSS BHA -SECURITY 12-1/4"PDC BIT Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 14 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/29/2010 01:00-03:15 2.25 DRILL P INT1 -GEOPILOT 7600 RSS -NM FLEX DC -SMART STABILIZER -GR/RES/PWD 03:15-03:30 0.25 DRILL P INT1 ATTEMPT TO DOWNLINK MWD TOOL. BATTERY FAILURE 03:30-06:30 3.00 DRILL N SFAL INT1 TROUBLESHOOT AND SWAP FOR NEW BATTERY 06:30-07:30 1.00 DRILL P INT1 CONTINUE TO MAKE UP THE BHA -XO -BALL CATCHER -CIRC SUB -XO -STAB -FLEX DRILL COLLARS -HEAVY WEIGHT DRILL PIPE -JARS 07:30-08:30 1.00 DRILL P INT1 PRESSURE TEST GEO SKID TO 2,500 PSI.NO LEAKS. SHALLOW HOLE TEST THE MWD. TEST DOWNLINK TO GEO SKID. 08:30-12:00 3.50 DRILL P INT1 PICK UP 3 JOINTS OF 5"DRILL PIPE FROM PIPE SHED. RUN IN HOLE WITH DRILL PIPE FROM 650'TO 3,866'MD USING TONGS AND SPINNER HAWKS 12:00-14:00 2.00 DRILL P INT1 CUT&SLIP DRILL LINE.SERVICE TOP DRIVE. 14:00-23:00 9.00 DRILL N WAIT INT1 WAIT ON WEATHER THAW#1 CHARGE PUMP LINE 23:00-00:00 1.00 DRILL P INT1 PJSM BLOW DOWN THE TOP DRIVE,FLOW CHECK RUN IN HOLE WITH 5"DP FROM 3,866'TO 4,527'MD -USING SPINNER HAWKS AND RIG TONGS 1/30/2010 00:00-08:30 8.50 DRILL P INT1 WASH AND REAM IN HOLE IN HOLE FROM 4,527'TO 7,546' MD. -500 GPM, 1,150 PSI,50 RPM 08:30-10:00 1.50 DRILL P INT1 CIRCULATE CASING BOTTOMS UP. -800 GPM,2,600 PSI, 120 RPM 10:00-10:30 0.50 DRILL P INT1 ESTABLISH ECD BASELINE FOR MUD OF 9.60 PPGE 10:30-12:00 1.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 7,551'TO 7,638'MD NO LOSSES TO FORMATION DURING DRILLING. -PU-225K,SO-140K, RTW-180K, 10-12 WOB -800 GPM,2,710 PSI ON,2,690 PSI OFF -120 RPM, 19K TQ ON, 15K TQ OFF -STRING STALLING OUT WITH 10K WOB -MW-9.5 PPG,CALC ECD=9.60,ACTUAL ECD=9.83 PPGE -ART-1.09 HRS,ADT-1.09 HRS. -AVERAGE BACKROUND GAS =115,MAX=203 12:00-00:00 12.00 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 7,638'TO 8,138'MD NO LOSSES TO FORMATION DURING DRILLING. -PU-255K,SO-150K, RTW-188K,5-12K WOB -808 GPM,2,610 PSI ON,2,650 PSI OFF -160 RPM, 15-20K TQ ON, 19K TQ OFF -STRING STALLING OUT WITH 8-10K WOB -AVG ROP=55.5 FT/HR -MW-9.4 PPG,CALC ECD=9.50,ACTUAL ECD=9.57 Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 15 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/30/2010 12:00-00:00 12.00 DRILL P INT1 PPGE -ART-8.99 HRS, ADT-8.99 HRS. -AVERAGE BACKROUND GAS =110, MAX=204 @ 7,853' MD 1/31/2010 00:00-03:30 3.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 8,138'TO 8,241'MD -NO LOSSES TO FORMATION DURING DRILLING. ROP'S FELL FROM 100 FT/HR TO 40 FT/HR -TOP DRIVE STALLING OUT WITH 7-10K WOB -PUMPED NUT PLUG SWEEP WITH INCREASE IN ROP AS SWEEP PASSED GHOST REAMER -PUMPED SECOND SWEEP WITH NO ROP INCREASE -PUMPED THIRD SWEEP WITH NO ROP INCREASE -PUMPED FOURTH SWEEP+LUBE WITH NO ROP INCREASE -ATTEMPTED TO CHANGE PARAMETERS(RPM'S,FLOW RATES,WOB)WITH NO IMPROVEMENT IN ROP ATTEMPTED TO PULL OFF BOTTOM,REAM HOLE,AND EASE BACK TO DRILLING WITH NO IMPROVEMENT IN ROP -PU-250K,SO-155K,RTW-190K, 10K WOB -800 GPM,2,700 PSI ON,2,610 PSI OFF -160 RPM,20K TQ ON, 17K TQ OFF -MW-9.4 PPG,CALC ECD=9.50,ACTUAL ECD=9.55 PPGE -AVERAGE BACKROUND GAS =85,MAX=113 03:30-05:00 1.50 DRILL P INT1 CIRCULATE BOTTOMS UP BLOW DOWN TOP DRIVE 05:00-10:30 5.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 8,241'TO 8,652'MD -NO LOSSES TO FORMATION DURING DRILLING. -INCREASED TORQUE LIMITATIOR FROM 22K TO 25K ON TOP DRIVE. -ROP INCREASED TO 200 FT/HR -PU-255K,SO-155K, RTW-195K, 14-25 WOB -800 GPM,2,700 PSI ON,2,620 PSI OFF -160 RPM,20-25K TQ ON, 19K TQ OFF -MW-9.4 PPG,CALC ECD=9.50,ACTUAL ECD=9.57 PPGE -ART-7.08 HRS,ADT-7.08 HRS. -AVERAGE BACKROUND GAS =458, MAX=5,884 10:30-12:00 1.50 DRILL P INT1 CIRCULATE WHILE ROTATING AND RECIPROCATING AT 800 GPM AND 160 RPM -GAS INCREASED TO 5,884 UNITS -MAX GAS CUT MUD=8.6 PPG -CIRCULATING PRESSURE=2,630 PSI -MUD WEIGHT IN=9.5 PPG, MUD WEIGHT OUT=9.5 PPG 12:00-15:00 3.00 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 8,652'TO 8,855'MD -NO LOSSES TO FORMATION DURING DRILLING. -PU-255K,SO-160K, RTW-197K,20-22 WOB -800 GPM,2,760 PSI ON,2,760 PSI OFF - 160 RPM,20-25K TQ ON, 19K TQ OFF Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 16 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 1/31/2010 12:00-15:00 3.00 DRILL P INT1 -MW-9.50 PPG,CALC ECD=9.67,ACTUAL ECD=9.88 PPGE -AVERAGE BACKROUND GAS =1,129,MAX=4,312 15:00-16:30 1.50 DRILL P INT1 ROTATE AND RECIPROCATE WHILE BRINGING MUD FROM 9.5 TO 9.7 PPG -160 RPM -780 GPM, PUMP PRESSURE=2,650 PSI 16:30-00:00 7.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 8,855'TO 9,272'MD -NO LOSSES TO FORMATION DURING DRILLING. -PU-275K,SO-158K, RTW-205K, 15-22 WOB -785 GPM,2,830 PSI ON 2,820 PSI OFF -160 RPM,25K TQ ON,24K TQ OFF -MW-9.85 PPG,CALC ECD=10.05,ACTUAL ECD=10.13 PPGE -ART-7.06 HRS,ADT-7.06 HRS. -AVERAGE BACKROUND GAS =1,287,MAX=3,778 2/1/2010 00:00-06:00 6.00 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 9,272'TO 9,650'MD -NO LOSSES TO FORMATION DURING DRILLING. -PU-280K,SO-163K, RTW-207K, 17-20 WOB -785 GPM,2,830 PSI ON 2,830 PSI OFF -160 RPM,25K TQ ON,24K TQ OFF -MW-9.90 PPG,CALC ECD=10.01,ACTUAL ECD=10.16 PPGE -AVERAGE BACKROUND GAS=592,MAX=639 -AT 9,524'MD BEGAN BLEEDING IN SPIKE FLUID WHILE DRILLING AHEAD 06:00- 12:00 6.00 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 9,650'TO 9,823'MD -NO LOSSES TO FORMATION DURING DRILLING. -PU-287K,SO-170K, RTW-215K,20 WOB -750 GPM,2,930 PSI ON 2,890 PSI OFF -160 RPM,25K TQ ON,23K TO OFF -MW- 10.20 PPG,CALC ECD=10.35,ACTUAL ECD=10.54 PPGE -ART-8.54 HRS,ADT-8.54 HRS. -AVERAGE BACKROUND GAS =1,224,MAX=3,311 -KNOCKED OFF HIGH LINE POWER @ 10:40 DUE TO IN-FIELD DISRUPTION -SWITCHED TO RIG POWER 12:00-22:30 10.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 9,823'TO BOTTOM AT 10,180'MD _ -GEOLOGIST PICKED DEPTH -NO LOSSES TO FORMATION DURING DRILLING. -PU-283K,SO-183K, RTW-219K, 15 WOB -600 GPM, 1,990 PSI ON 1,990 PSI OFF -100 RPM,25K TQ ON,25K TQ OFF -MW-10.20 PPG,CALC ECD=10.36,ACTUAL ECD=10.47 PPGE -ART-8.47 HRS,ADT-8.47 HRS. -AVERAGE BACKROUND GAS =964,MAX=3,460 -ON HIGH LINE POWER @ 19:30 22:30-00:00 1.50 DRILL P INT1 BEGIN CIRCULATING 2 BOTTOMS UP WHILE ROTATING AND RECIPROCATING -MW IN=10.1,MW OUT=10.1+ Printed: 2/18/2010 4:55:50 PM • BP EXPLORATION Page 17 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/1/2010 22:30-00:00 1.50 DRILL P INT1 -800 GPM,3,300 PSI ON THE UP STROKE -600 GPM,2,100 PSI ON THE DOWN STROKE -150 RPM -AVERAGE BACKROUND GAS =1,567,MAX=2,832 2/2/2010 00:00-01:30 1.50 DRILL P INT1 CIRCULATE TWO TIMES BOTTOMS UP WHILE ROTATING AND RECIPROCATING FROM 10,180'TO 9,997'MD -800 GPM,3,250 PSI -150 RPM -MW IN=10.1,MW OUT=10.1+ -SHALE COMING OVER SHAKERS CLEANED UP ON SECOND BOTTOMS UP -PUMP PRESSURES STABLE AT 3,250 PSI -AVERAGE BACKROUND GAS=705,MAX=1,022 01:30-02:00 0.50 DRILL P INT1 PUMPED OUT OF HOLE FROM 9,997'TO 9,902'MD -400 GPM,910 PSI -PU-290K,SO-185K -MW IN=10.1,MW OUT=10.1 -AVERAGE BACKROUND GAS=321,MAX=345 02:00-05:00 3.00 DRILL P INT1 PULL OUT OF HOLE ON ELEVATORS FROM 9,902'TO 7,263'MD -PU-235K,SO-165K -NO HOLE PROBLEMS MONITOR HOLE -STATIC 05:00-07:30 2.50 DRILL P INT1 RUN IN HOLE FROM 7,263'TO 10,180'MD -WASH DOWN LAST STAND -PUW-290K,SOW-170K, ROT-220K -600 GPM,2,020 PSI 07:30- 11:30 4.00 DRILL P INT1 CIRCULATE THREE TIMES BOTTOMS UP WHILE ROTATING AND RECIPROCATING FROM 10,180'TO 9,900'MD -STANDING BACK 1 STAND EVERY BOTTOMS UP -800 GPM,3,350 PSI -150 RPM -MW IN=10.1,MW OUT=10.1+ 11:30-00:00 12.50 DRILL N WAIT INT1 WAIT ON WEATHER-PHASE 3 CONDITIONS CIRCULATE THREE TIMES BOTTOMS UP WHILE ROTATING AND RECIPROCATING -530 GPM, 1,610 PSI -50 RPM 2/3/2010 00:00-06:30 6.50 DRILL N WAIT INT1 WAIT ON WEATHER-PHASE 3 CONDITIONS CIRCULATE 3 TIMES BOTTOMS UP WHILE ROTATING AND RECIPROCATING -530 GPM, 1,610 PSI -50 RPM 06:30-09:30 3.00 DRILL N WAIT INT1 WAIT ON WEATHER-PHASE 2 CONDITIONS -REMOVE SNOW FROM PAD,PREPPING TO GO BACK TO WORK CIRCULATE 2 TIMES BOTTOMS UP WHILE RECIPROCATING -530 GPM, 1,610 PSI Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 18 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/3/2010 09:30- 10:00 0.50 DRILL P INT1 RUN IN HOLE FROM 9,990'TO 10,180'MD -WASH DOWN LAST STAND -PUW-280K,SOW-180K, ROT-220K -600 GPM,2,020 PSI 10:00-13:30 3.50 DRILL P INT1 CIRCULATE 2 TIMES BOTTOMS UP WHILE ROTATING AND RECIPROCATING FROM 10,180'TO 9,997'MD -STANDING BACK 1 STAND EVERY BOTTOMS UP -800 GPM,3,350 PSI -150 RPM -MW IN=10.1,MW OUT=10.1+ 13:30-21:30 8.00 DRILL P INT1 PUMP DRY JOB BLOW DOWN THE TOP DRIVE MONITOR WELL -STATIC PULL OUT OF HOLE FROM 9,997'TO 3,866'MD @ 70 FT/HR MONITOR WELL -STATIC CONTINUE TO PULL OUT OF HOLE FROM 3,866'TO 555' MD @ 70 FT/HR LAY DOWN GHOST REAMER 21:30-00:00 2.50 DRILL P INT1 LAY DOWN BHA -2 JOINTS HWDP -JARS -3 NON MAG DRILL COLLARS -STABILIZER -CIRC SUB DOWNLOAD MWD LAY DOWN BHA -MWD -GEO PILOT&BIT -BIT GRADE 33CTAXIBTTD 2/4/2010 00:00-00:30 0.50 DRILL P INT1 CONTINUE TO LAY DOWN GEO-PILOT AND BIT 00:30-01:30 1.00 DRILL P INT1 CLEAN AND CLEAR RIG FLOOR LAY DOWN GEO SKID 01:30-02:00 0.50 CASE P INT1 PULL WEAR RING 02:00-02:30 0.50 CASE P INT1 INSTALL TEST PLUG 02:30-04:00 1.50 CASE P INT1 CHANGE 4-1/2"X 7"VBR TO 9-5/8"CASING RAM$, 04:00-05:00 1.00 CASE P INT1 RIG UP TEST EQUIPMENT TEST RAMS TO 250 PSI LOW,4,000 PSI HIGH FOR 5 MINUTES EACH CHARTED. -TEST PASSED RIG DOWN TEST EQUIPMENT 05:00-08:00 3.00 CASE P INT1 RIG UP AND PREPARE TO RUN 9-5/8",47#,L-80, HYDRIL 563 CASING WITH TORQUE TURN 08:00-12:00 4.00 CASE P INT1 PRE JOB SAFETY MEETING. MAKE UP SHOE TRACK CHECK FLOATS PICK UP AND MAKE UP PUP JOINTS. RUN 9-5/8",47#,L-80, HYDRIL 563 CASING TO 172'MD 12:00-21:00 9.00 CASE P INT1 PRE JOB SAFETY MEETING. RUN 9-5/8",47#,L-80, HYDRIL 563 CASING FROM 172'TO 3,900'MD -RUN SPEED=4 MINUTES PER JOINT SLIPS TO SLIPS Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 19 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/4/2010 12:00-21:00 9.00 CASE P INT1 -TORQUE TURN EACH CONNECTION TO 15,800 FT-LBS. -FILLED EVERY JOINT USING THE FRANKS TOOL AND CIRCULATE EVERY 20TH JOINT AT 3 BPM WITH 230 PSI WHILE IN CASED HOLE. -TAKING PICK UP AND SLACK OFF WEIGHTS EVERY 10 JOINTS -MW IN=10.1,MW OUT=10.1+ -LOST 18 BBLS FROM 172'MD TO 3,900'MD.(TOTAL 18 BLLS) 21:00-22:30 1.50 CASE P INT1 CIRCULATE 1 BOTTOMS UP AT 6 BPM WITH 410 PSI BY STAGING PUMPS UP AS FOLLOWS: -PUW-203K,SOW- 174K -3 BPM WITH 230 PSI FOR 15 MINUTES -4.5 BPM WITH 290 PSI FOR 15 MINUTES -6 BPM WITH 410 PSI -FULL RETURNS THROUGHOUT ENTIRE CIRCULATION AT 13-3/8"SURFACE CASING SHOE. -MW IN=10.1, MW OUT=10.1 -NO FLUID LOSS NOTED. 22:30-00:00 1.50 CASE P INT1 CONTINUE TO RUN 9-5/8",47#,L-80, HYDRIL 563 CASING FROM 3,900'TO 4,694'MD -PUW-236K,SOW-192K -RUN SPEED=4 MINUTES PER JOINT SLIPS TO SLIPS -TORQUE TURN EACH CONNECTION TO 15,800 FT-LBS. -FILLED EVERY JOINT USING THE FRANKS TOOL AND CIRCULATE EVERY 10TH JOINT AT 3 BPM STAGING UP TO 5 BPM WITH 250/360 PSI WHILE IN OPEN HOLE. -TAKING PICK UP AND SLACK OFF WEIGHTS EVERY 10 JOINTS -MW IN=10.1,MW OUT=10.1 -LOST 12 BBLS IN OPEN HOLE FROM 3,900'MD TO 4,694' MD.(TOTAL 30 BLLS) 2/5/2010 00:00-02:00 2.00 CASE P INT1 CONTINUE TO RUN 9-5/8",47#, L-80, HYDRIL 563 CASING FROM 4,694'TO 5,413'MD -PUW-270K,SOW-206K -RUN SPEED=6 MINUTES PER JOINT SLIPS TO SLIPS -TORQUE TURN EACH CONNECTION TO 15,800 FT-LBS. -FILLED EVERY JOINT USING THE FRANKS TOOL AND CIRCULATE EVERY 10TH JOINT AT 3 BPM STAGING UP TO 5 BPM WITH 320/450 PSI WHILE IN OPEN HOLE. -TAKING PICK UP AND SLACK OFF WEIGHTS EVERY 10 JOINTS -MW IN=10.1+,MW OUT=10.2+ -LOST 2 BBLS IN OPEN HOLE FROM 4,694'MD TO 5,413' MD. (TOTAL 32 BLLS) 02:00-03:45 1.75 CASE P INT1 CONTINUE TO RUN 9-5/8",47#,L-80, HYDRIL 563 CASING FROM 5,413'TO 6,545'MD -PUW-305K,SOW-213K -RUN SPEED=6 MINUTES PER JOINT SLIPS TO SLIPS -TORQUE TURN EACH CONNECTION TO 15,800 FT-LBS. -FILLED EVERY JOINT USING THE FRANKS TOOL AND CIRCULATE EVERY 10TH JOINT AT 3 BPM STAGING UP Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 20 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/5/2010 02:00-03:45 1.75 CASE P INT1 TO 5 BPM WITH 410/510 PSI WHILE IN OPEN HOLE. -TAKING PICK UP AND SLACK OFF WEIGHTS EVERY 10 JOINTS -MW IN=10.3, MW OUT=10.4 -LOST 3 BBLS IN OPEN HOLE FROM 5,413'MD TO 6,545' MD. (TOTAL 35 BBLS) 03:45-05:00 1.25 CASE P INT1 NOTICED GRADUAL REDUCTION FROM DOWN WEIGHT, DEVIATION FROM DRAG TREND PLOT(BROOMSTICK PLOT),AND INCREASED MW OUT. CIRCULATE 2 BOTTOMS UP WHLE RECIPRICATING AT 7 BPM WITH 580 PSI BY STAGING PUMPS UP AS FOLLOWS: -3 BPM WITH 410 PSI -5 BPM WITH 490 PSI -6 BPM WITH 540 PSI -39'RECIPRICATIONS -MW IN=10.1+,MW OUT=10.4 AT THE BEGINNING OF CIRCULATING -MW IN=10.1+,MW OUT=10.2 AT THE END OF CIRCULATING -NO LOSSES DURING CIRCULATION -RETURNS OF FINE SAND,SHALE AND COAL SEEN ACROSS SHAKERS 05:30-12:00 6.50 CASE P INT1 CONTINUE TO RUN 9-5/8",47#,L-80, HYDRIL 563 CASING FROM 6,545'TO 9696'MD -TORQUE TURN EACH CONNECTION TO 15,800 FT-LBS. -TAKING PICK UP AND SLACK OFF WEIGHTS EVERY 10 JOINTS UNTIL COULD NOT PICK UP ANYMORE -FILLED EVERY JOINT USING THE FRANKS TOOL AND CIRCULATE EVERY 10TH JOINT AT 3.5 BPM STAGING UP TO 5.5 BPM WITH340/520 PSI WHILE IN OPEN HOLE. -WASH DOWN 9,617'-9,696'WITH 3.5 BPM STAGING UP TO 5.5 BPM WITH 340/520 PSI -MW IN=10.1+,MW OUT=10.2 12:00-15:00 3.00 CASE P INT1 CONTINUE TO WASH DOWN 9-5/8",47#, L-80, HYDRIL 563 CASING FROM 9,696'TO 9,933'MD AT 3.5 BPM STAGING UP TO 5.5 BPM WITH 290/420 PSI TO GET BOTTOMS UP AT THE TOP OF THE HRZ -TORQUE TURN EACH CONNECTION TO 15,800 FT-LBS -RUN IN THE HOLE FROM 9,933'-10130'FILLING EVERY JOINT -MAKE UP THE HANGER AND LANDING JOINT AND CIRCULATE DOWN THE LAST JOINT @ 5.5 BPM WITH 490 PSI INITIAL CIRCULATING PRESSURE -LAND THE HANGER @ 10,162'WITH A FINAL SLACK OFF WEIGHT OF 255K -MW IN=10.1+,MW OUT=10.2 15:00-17:00 2.00 CEMT P INT1 CIRCULATE AND CONDITION THE MUD FOR THE CEMENT JOB AT 5.5 BPM WITH 490 PSI -TOTAL MUD LOST DURING THE CASING RUN=48 BBLS. 17:00- 18:00 1.00 CEMT P INT1 REMOVE THE FRANKS TOOL, BLOW DOWN THE TOP Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 21 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/5/2010 17:00-18:00 1.00 CEMT P INT1 DRIVE. -INSTALL THE XO,CEMENT HEAD, LOW TORQUE VALVE, AND CEMENT LINE. 18:00-19:00 1.00 CEMT P INT1 CONTINUE TO CIRCULATE AND CONDITION THE MUD FOR THE CEMENT JOB STAGING UP TO 7 BPM WITH 370 PSI. -MW IN=10.1,MW OUT=10.2 19:00-22:30 3.50 CEMT P INT1 CEMENT 9-5/8"INTERMEDIATE CASING WITH NO RECIPROCATION AS FOLLOWS: 19:33 START BATCH MIXING MUD PUSH II 19:34 PUMP 5 BBL 12.5 PPG MUD PUSH II TEST LINES TO 3,500 PSI-GOOD 19:45 PUMP 35 BBL 12.5 PPG MUD PUSH II AT 5 BPM WITH 174 PSI 20:04 START BATCH MIXING TAIL CEMENT 20:01 DROP BOTTOM PLUG; POSITIVE INDICATION THAT PLUG LEFT HEAD. START PUMPING 15.8 PPG TAIL CEMENT AWAY AT 5 BPM -PUMP 115 BBLS OF 15.8 PPG CLASS G CEMENT_ WITH LATEX 20:44 DROP TOP PLUG; KICK OUT WITH 10 BBL H2O; POSITIVE INDICATION THAT PLUG LEFT HEAD. -DISPLACE WITH SCHLUMBERGER PUMPS 20:48 BEGIN DISPLACING CEMENT WITH MUD. -DISPLACE WITH RIG PUMPS, 10.1 PPG LSND. -INCREASE PUMP RATE TO CATCH UP WITH CEMENT FROM 7 BBUMIN TO 10 BBUMIN 21:44 SLOW PUMP RATE TO 7 BPM WITH 2,000 STROKES LEFT 22:14 SLOW PUMP RATE TO 3 BPM WITH 150 STROKES LEFT 22:20 PLUG BUMP AT 7,294 STROKES(737 BBL DISPLACED). -FINAL PUMP PRESSURE AT BUMP 1,250 PSI AND HELD FOR 15 MINUTES. FLUSH CEMENT LINE AND BLOW DOWN TO CEMENTERS. CEMENT IN PLACE AT 22:19 HRS. CHECK FLOATS-HOLDING. -FULL RETURNS THROUGHOUT JOB. CEMENT JOB VOLUME: 115 BBLS 15.8 PPG CLASS G TAIL PUMPED;551 SACKS AT 1.17 CUFT/SX 22:30-00:00 1.50 CEMT P INT1 RIG DOWN AND FLUSH CEMENT HEAD. CLEAN AND CLEAR RIG FLOOR. RIG DOWN SCAFFOLDING. BACK OUT THE LANDING JOINT. 2/6/2010 00:00-02:00 2.00 WHSUR P INT1 LAY DOWN LONG BAILS,INSTALL SHORT BAILS REMOVE CASING EQUIPMENT FROM RIG FLOOR 02:00-04:00 2.00 WHSUR P INT1 PICK UP SINGLE JOINT OF DRILL PIPE MAKE UP PACKOFF RUNNING TOOL TO THE 9-5/8" Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 22 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/6/2010 02:00-04:00 2.00 WHSUR P INT1 PACKOFF RUN AND SET PACKOFF TEST TO 5,000 PSI FOR 30 MINUTES -GOOD TEST 04:00-05:00 1.00 BOPSUR P INT1 PRE-JOB SAFETY MEETING CHANGE OUT THE TOP RAMS FROM 9-5/8"CASING RAMS TO 4-1/2"X 7"VBR'S 05:00-06:00 1.00 BOPSUR P INT1 REMOVE FRANKS TOOL,SLB CROSS OVERS,AND PACK-OFF RUNNING TOOL 06:00-07:00 1.00 BOPSUR P PROD1 CHANGE OUT FLANGE ON CHOKE LINE 07:00-07:30 0.50 BOPSUR P PROD1 PRE-JOB SAFETY MEETING FILL STACK RIG UP TEST EQUIPMENT TO TEST BOPE 07:30-14:00 6.50 BOPSUF P PROD1 TEST THE ANNULAR WITH 5"TEST JT.TO 250 PSI LOW AND 2,500 PSI HIGH FOR 5 MINUTES EACH. -GOOD TEST. TEST THE CHOKE MANIFOLD AND IBOP TO 250 PSI LOW AND 4,000 PSI HIGH FOR 5 MINUTES EACH. -GOOD TESTS. TEST THE LOWER 3-1/2"X 6"VBR AND UPPER 4-1/2"X 7" VBR TO 250 PSI LOW AND 4,000 PSI HIGH WITH THE 5", AND 7"TEST JOINTS FOR 5 MINUTES EACH. -GOOD TESTS. TEST THE BLIND RAMS TO 250 PSI LOW AND 4,000 PSI HIGH FOR 5 MINUTES. -GOOD TEST. -TESTS WITNESSED BY BP WSL DICK MASKELL AND DUNCAN FERGUSON AND DOYON TOOLPUSHER NICK • MARMON. -WITNESS OF THE TEST WAIVED BY AOGCC REP.JOHN CRISP. 14:00- 14:30 0.50 BOPSUF P PROD1 INSTALL WEAR RING 14:30- 15:00 0.50 BOPSUP P PROD1 BLOW DOWN CHOKE AND KILL LINE MOBILIZE BHA TO RIG FLOOR 15:00-18:30 3.50 DRILL P PROD1 PRE-JOB SAFETY MEETING ON BHA MAKE UP BHA -NEW 8.5"SMITH GF15 INSERT BIT -7"SPERRY DRILL LOBE 7/8 WITH A.93'BEND 18:30-19:00 0.50 DRILL P PROD1 RUN IN HOLE WITH BHA FROM 480'TO 952'MD 19:00-21:00 2.00 DRILL P PROD1 PRE-JOB SAFETY MEETING CUT AND SLIP DRILL LINE SERVICE AND INSPECT TOP DRIVE AND BLOCKS 21:00-22:00 1.00 DRILL P PROD1 RUN IN HOLE WITH BHA FROM 952'TO 3,219'MD 22:00-00:00 2.00 DRILL P PROD1 PRE-JOB SAFETY MEETING ON STRIPPING DRILL STRIPPING DRILL WITH LUSCHE'S CREW 2/7/2010 00:00-01:30 1.50 DRILL P PROD1 PRE-JOB SAFETY MEETING STRIP IN HOLE DRILL WITH BEATTY'S CREW STAND BACK 2 STANDS, LAY DOWN DART VALVE&TIW VALVE 01:30-04:30 3.00 DRILL P PROD1 RUN IN HOLE WITH DRILL PIPE FROM 3,219'TO 9,821'MD USING TONGS AND SPINNER HAWKS Printed: 2/18/2010 4:55:50 PM • S BP EXPLORATION Page 23 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/7/2010 01:30-04:30 3.00 DRILL P PROD1 -FILLING DRILL PIPE EVERY 20 STANDS 04:30-05:30 1.00 CASE P PROD1 AT 9,821'STOPPED AND PERFORMED CHARTED CASING PRESSURE TEST TO 4,000 PSI FOR 30 MINUTES. -GOOD TEST 05:30-06:00 0.50 DRILL P PROD1 CONTINUE IN THE HOLE FROM 9,821'TO 10,081'MD. TAG UP ON FLOAT PLUGS AT 10,081'MD -PU-265K,SO-160K, RTW-205K,25K WOB -80 RPM, 15K TQ OFF 06:00-07:30 1.50 DRILL P PROD1 DRILL OUT FLOAT EQUIPMENT AND CEMENT FROM 10,081'TO 10,152'MD -PU-265K,SO-160K, RTW-205K,5-15K WOB -550 GPM -80 RPM, 15K TQ ON 07:30-09:30 2.00 DRILL P PROD1 PRE-JOB SAFETY MEETING DISPLACE WELL WITH 8.8 PPG FLO PRO SYSTEM -ROTATE AND RECIPROCATE -336 GPM @ 1,440 PSI -120 RPM, 18-25K TORQUE 09:30-10:00 0.50 DRILL P PROD1 CLEAN SURFACE EQUIPMENT 10:00-11:30 1.50 DRILL P PROD1 DRILL OUT SHOE TRACK AND 20'OF NEW FORMATION FROM 10,152'TO 10,200'MD. -WOB 10-15K 11:30- 12:00 0.50 DRILL P PROD1 RIG UP TEST EQUIPMENT PURGE KILL LINE 12:00-13:00 1.00 DRILL P PROD1 PERFORM FIT TO 9.5 PPG EMW OBTAIN SLOW PUMP RATES BLOW DOWN KILL AND CEMENT LINE RIG DOWN TEST EQUIPMENT 13:00-21:00 8.00 DRILL P PROD1 RUN IN HOLE WITH 5"DRILL PIPE FROM 10,104'TO 10,200'MD DIRECTIONALLY DRILL FROM 10,200'TO TD AT 10,623' MD. -NO LOSSES TO FORMATION DURING DRILLING. -PU-262K,SO-185K, RTW-216K,25K WOB -550 GPM, 1,740 PSI ON, 1,590 PSI OFF -100 RPM, 16K TQ ON, 18K TQ OFF -MW-8.95 PPG -ART-7.27 HRS,AST-0.00 HRS,ADT-7.27 HRS. -AVERAGE BACKROUND GAS =1,909, MAX=5,832 -MUD CUT FROM 8.8 TO 8.4 PPG WITH MAX GAS SIMOPS-FREEZE PROTECT THE OA -102 BBLS OF 10.1 PPG MUD, 130 BBLS OF DEAD CRUDE -800 PSI MAX PREESURE 21:00-22:30 1.50 DRILL P PROD1 OBTAIN SLOW PUMP RATES CIRCULATE 1 BOTTOMS UP -550 GPM, 1,560 PSI -100 RPM 22:30-23:00 0.50 DRILL P PROD1 FLOW CHECK PUMP OUT OF HOLE FROM 10,623'TO 10,104'MD -PUW-250K -550 GPM, 1,540 PSI 23:00-00:00 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP AT THE SHOE WHILE Printed: 2/18/2010 4:55:50 PM ......__ _.._.... 9 BP EXPLORATION Page 24 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/7/2010 23:00-00:00 1.00 DRILL P PROD1 RECIPROCATING FULL STAND -PUW-250K -550 GPM, 1,540 PSI 2/8/2010 00:00-00:30 0.50 DRILL P PROD1 INSPECT AND SERVICE TOP DRIVE,BLOCKS AND DRAW WORKS 00:30-01:00 0.50 DRILL P PROD1 TRIP IN HOLE FORM 10,104'TO 10,623'MD 01:00-02:30 1.50 DRILL P PROD1 CIRCULATE BOTTOMS UP WHILE RECIPROCATING -550 GPM, 1,650 PSI FLOW CHECK 02:30-03:30 1.00 DRILL P PROD1 PUMP OUT OF HOLE FROM 10,623'TO 10,104'MD -PUW-250K -550 GPM, 1,540 PSI 03:30-04:00 0.50 DRILL P PROD1 FLOW CHECK BLOW DOWN THE TOP DRIVE 04:00-04:30 0.50 DRILL P PROD1 MUD FOAMING UP IN TRIP TANK CIRCULATE DEFOAMER INTO THE MUD SYSTEM FLOW CHECK 04:30-10:30 6.00 DRILL P PROD1 PULL OUT OF HOLE FROM 10,104'MD TO 428'MD -FLOW CHECK EVERY 20 STANDS -MW IN=8.8, MW OUT=8.9 10:30-14:00 3.50 DRILL P PROD1 DOWN LOAD MWD LAY DOWN BHA -BIT GRADING 2-2-BT-M-E-1-NO-TD 14:00-15:30 1.50 CASE P PROD1 PRE-JOB SAFETY MEETING ON BEAVER SLIDE OPERATIONS CLEAR AND CLEAN RIG FLOOR -REMOVE ALL TOOLS NOT NEEDED FOR UPCOMING OPERATIONS 15:30-16:15 0.75 CASE P RUNPRD PRE-JOB SAFETY MEETING ON RUNNING 7"26#LINER RIGGED UP FOR LINER RUN 16:15-16:30 0.25 CASE N HMAN RUNPRD INADVERTENTLY RIGGED UP 7-5/8"CASING ELEVATORS INSTEAD OF 7"CASING ELEVATORS ATTEMPTED TO PICK UP 7"LINER JOINT#1 WITH 7-5/8 ELEVATORS JOINT#1 (7"LINER AND FLOAT SHOE)SLIPPED OUT OF ELEVATORS WHEN 15'ABOVE THE PIPE SKATE(PIN END STILL IN SKATE WHEN LINER SLIPPED),THE JOINT SLID DOWN THE SKATE INTO THE PIPE SHED -SEE COMMENTS 16:30-20:30 4.00 CASE N HMAN RUNPRD STOP OPERATIONS FOR SAFETY INVESTIGATION ORDERED NEW BUTTRESS LINER JOINT FOR SHOE TRACK AND FLOAT SHOE 20:30-23:00 2.50 CASE P RUNPRD PRE-JOB SAFETY MEETING ON RUNNING 7"26#,VAM TOP HC LINER MAKE UP FLOAT SHOE, FLOAT COLLAR,AND INSERT LANDING COLLAR JOINT RUN 15 JOINTS OF CASING TO 617'MD -FILLED LINER EVERY 5 JOINTS 23:00-00:00 1.00 CASE N MISC RUNPRD ATTEMPT TO INSERT BAKER WIPER PLUG -WIPER PLUG CAUGHT UP ON ID OF 7"VAM TOP HC COLLAR. -CORRECT PART WAS USED FOR LINER PER SPEC BEVELED EDGE OF RUBBER IN SHOP Printed: 2/18/2010 4:55:50 PM S BP EXPLORATION Page 25 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/9/2010 00:00-00:30 0.50 CASE N MISC RUNPRD CONTINUE TO BEVEL EDGE OF RUBBER IN SHOP 00:30-01:00 0.50 CASE P RUNPRD INSTALL LINER WIPER PLUG TO RUNNING TOOL -WIPER PLUG RAN SMOOTHLY INTO LINER MAKE UP HANGER AND PACKER 01:00-02:00 1.00 CASE P RUNPRD FILL THE TIE BACK RECEPTACLE WITH PAL MIX WAIT 1/2 HOUR FOR SET UP PICK UP 1 STAND OF 5"DRILL PIPE PUMP 1.5 LINER VOLUMES -PUW 67K,SOW 70K -189 GPM, 115 PSI -26%RETURN FLOW 02:00-08:00 6.00 CASE P RUNPRD RUN IN HOLE WITH LINER ON 5"DRILL PIPE FROM 708' TO 10,162'MD -7",26#,L-80,VAM TOP HC LINER -FILL EVERY 10 STANDS 08:00-09:30 1.50 CASE P RUNPRD CIRCULATE BOTTOMS UP AT 9-5/8"SHOE -294 GPM,450 PSI BLOW DOWN TOP DRIVE 09:30-10:00 0.50 CASE P RUNPRD RIH WITH LINER ON 5"DRILL PIPE FROM 10,162'TO 10,567 MD 10:00- 10:30 0.50 CASE P RUNPRD PICK UP TWO JOINTS OF DRILL PIPE FROM PIPE SHED. MAKE UP CEMENT HEAD AND BREAK CIRCULATION. WORK DOWN TO 10,623'. PU 2'. -PUW 250K,SOW 185K 10:30-13:30 3.00 CASE P RUNPRD CIRCULATE BOTTOMS UP;STAGING UP PUMPS -6 BPM,520 PSI -PUW 235K,SOW 185K RIG UP SCHLUMBERGER CEMENTERS BEGIN BATCH MIXING CEMENT 13:30-15:00 1.50 CASE P RUNPRD CEMENT 7"PRODUCTION LINER WITH RECIPROCATION AS FOLLOWS: RECIPROCATE PIPE 20'-25'STROKES TRHOUGHOUT CEMENT JOB. 12:48 START BATCH MIXING 12.5 PPG MUD PUSH II 12:53 START BATCH MIXING 15.8 PPG CEMENT 13:18 PUMP 25 BBL 12.5 PPG MUD PUSH II AT 5 BPM,400 PSI TEST LINES TO 4,500 PSI-GOOD 13:33 PUMP 32 BBL 15.8 PPG TAIL CEMENT AWAY AT.5 BPM -15.8 PPG CLASS G WITH LATEX 13:43 STOP PUMPING CEMENT SWAP VALVES ON TOP DRIVE FLUSH CEMENT LINES BLOW DOWN TOP DRIVE AND KELLY HOSE REMOVE CEMENTING LINE FROM TOP DRIVE AND INSTALL PLUG 13:53 DROP DART BEGIN DISPLACEMENT WITH RIG PUMPS DISPLACE WITH 8.9 PPG FLO-PRO MUD INCREASE PUMP RATE TO CATCH UP WITH CEMENT FROM 6 BPM TO 12 BPM Printed: 2/18/2010 4:55:50 PM BP EXPLORATION Page 26 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/9/2010 13:30-15:00 1.50 CASE P RUNPRD 14:07 SLOW PUMP RATE TO 7 BPM WITH 800 STROKES LEFT 14:17 SLOW PUMP RATE TO 4 BPM FOR DART TO LATCH LINER WIPER PLUG 14:20 SLOW PUMP RATE TO 3 BPM WITH 100 STROKES LEFT 14:23 PLUG BUMP AT 1,812 STROKES(183 BBL DISPLACED) BUMPED PLUG WITH 3,000 PSI PRESSURE PRESSURE UP TO SET LINER HANGER RELEASE RUNNING TOOL WITH 4,000 PSI BLEED OFF PRESSURE AND CHECK FLOATS-FLOATS HOLDING FULL RETURNS THROUGHOUT JOB, CEMENT IN PLACE AT 14:23 CEMENT JOB VOLUME; 32 BBLS 15.8 PPG CLASS G TAIL; 154 SACKS AT 1.17 CUFT/SK 15:00-16:30 1.50 CASE P RUNPRD CIRCULATE OUT CEMENT -436 GPM,660 PSI -RECOVERED ALL MUD PUSH AND 10-15 BBLS CEMENT CONTAMINATED MUD. 16:30- 17:00 0.50 CASE P RUNPRD RIG UP AND TEST LINER TOP PACKER TO 2,000 PSI FOR 10 MINUTES-GOOD TEST RIG DOWN TEST EQUIPMENT 17:00-19:30 2.50 CASE P RUNPRD DISPLACE WELL WITH HIGH VIS SWEEP,FOLLOWED BY 8.5 PPG SEAWATER. 19:30-00:00 4.50 CASE P RUNPRD POH WITH LINER RUNNING TOOL,LAYING DOWN DRILLPIPE FROM 9,980'TO 6,500'MD. 2/10/2010 00:00-04:30 4.50 CASE P RUNPRD POOH WITH LINER RUNNING TOOL,LDDP FROM 6,500'TO 1,880'MD. 04:30-05:00 0.50 CASE P RUNPRD RIH WITH LAST 8 STANDS OF DRILLPIPE IN DERRICK FROM 1,880'TO 2,624'MD. 05:00-07:30 2.50 CASE P RUNPRD POOH, LDDP FROM 2,624'TO SURFACE. 07:30-09:30 2.00 CASE P RUNPRD LAY DOWN LINER RUNNING TOOL. CLEAN AND CELAR RIG FLOOR 09:30-11:00 1.50 EVAL P OTHCMP MOBILIZE SCHLUMBERGER WIRELINE EQUIPMENT TO RIG FLOOR. RIG UP SHEAVES. PICK UP TOOLS AND SURFACE TEST USIT. 11:00-21:30 10.50 EVAL P OTHCMP RIH WITH USIT TO TOP OF LINER. LOG UP FROM 9,970'TO 7,400'ELM TO CONFIRM CEMENT TOP AND QUALITY. TOCAT8.118'EL& POOH AND LD USIT PU GAUGE RING AND JUNK BASKET AND RIH TO TOP LINER.TAG LINER AT 9,989'ELM. -GAUGE RING OD:8.54" -CASING DRIFTED GOOD -JUNK BASKET RETURNED EMPTY 21:30-22:00 0.50 EVAL P OTHCMP RIG DOWN SCHLUMBERGER WIRELINE Printed: 2/18/2010 4:55:50 PM � BP EXPLORATION Page 27 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/10/2010 22:00-23:00 1.00 RUNCOMP RUNCMP CLOSE BLINDS AND PRESSURE TEST WELL TO 4,000 PSI FOR 30 MINUTES -GOOD TEST 23:00-00:00 1.00 RUNCOMP RUNCMP CLEAN AND CLEAR RIG FLOOR. MOBILIZE TUBING HANGER AND CROSSOVER TO RIG FLOOR. PULL WEAR RING. MAKE UP HANGER TO CROSSOVER ON 1 JOINT 5" DRILLPIPE RUN HANGER AND LAND IN TUBING SPOOL. MARK DRILLPIPE AT RIG FLOOR. PULL HANGER AND LD HANGER,CROSSOVER,AND LANDING JOINT 2/11/2010 00:00-03:00 3.00 RUNCOMP RUNCMP MOBILIZE TUBING RUNNING EQUIPMENT TO RIG FLOOR. WARM UP CASING POWER TONGS. 03:00-03:30 0.50 RIGU P RUNCMP PJSM ON RUNNING COMPLETION. 03:30-04:00 0.50 RUNCOMP RUNCMP RIH WITH 7"26"L-80 TC-II TAILPIPE -BAKER LOK EACH CONNECTION -TORQUE TURN EVERY CONNECTION -OPTIMUM TORQUE 8,800 FT-LBS TAILPIPE CONSISTS OF: -20'MULESHOE JOINT -7"HES'RN'NIPPLE -10'PUP JOINT -10'PUP JOINT -9-5/8"X 7"BAKER S3 PACKER -10'PUP JOINT -10'PUP JOINT -7"HES'R'NIPPLE -10'PUP JOINT -7-5/8"VAM TOP HC BOX X 7"TC-II PIN CROSSOVER SWAP 7"ELEVATORS TO 7-5/8"ELEVATORS 04:00-19:00 15.00 RUNCOMP RUNCMP RIH WITH 7-5/8",29.7#,L-80, INTERNALLY PLASTIC COATED,VAM TOP HC TUBING -TORQUE TURN EVERY CONNECTION -USING JET LUBE SEAL GUARD ON ALL CONNECTIONS -OPTIMUM TORQUE 14,450 FT-LBS 19:00-20:30 1.50 RUNCOMP RUNCMP PICK UP SPACE-OUT PUPS AND RIH. -19.90',7.82',2.58' PICK UP FINAL JOINT AND RIH PICK UP EXTRA JOINT AND PUP AND RIH TO TAG TIEBACK RECEPTACLE -TAG 41'IN POH AND SWAP 2.58'PUP WITH 4.57'PUP MAKE UP FINAL JOINT -SPACE OUT PUTS MULESHOE 5'INSIDE TIEBACK RECEPTACLE. -244 TOTAL JOINTS -TOP OF 7"LINER AT 9,989' -MULESHOE AT 9,984' -PUW 310K SOW 215K 20:30-21:00 0.50 RUNCOMP RUNCMP MAKE UP TUBING HANGER AND LANDING JOINT TO TUBING Printed: 2/18/2010 4:55:50 PM 0 BP EXPLORATION Page 28 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/11/2010 20:30-21:00 0.50 RUNCOMP RUNCMP RIH AND LAND HANGER RUN IN LOCK DOWN SCREWS LAY DOWN LANDING JOINT AND CROSSOVER 21:00-21:30 0.50 RUNCOMP RUNCMP MAKE UP TWC TO T-BAR AND RIH SET TWC IN HANGER RIG UP TO TEST TWC 21:30-22:00 0.50 RUNCOMP RUNCMP TEST TWC FROM ABOVE TO 4,000 PSI FOR 10 MIN -GOOD TEST 22:00-22:30 0.50 RUNCOMP RUNCMP CLEAR RIG FLOOR DRAIN BOP STACK 22:30-00:00 1.50 BOPSUF P RUNCMP ND BOP STACK AND RACK BACK ON TO STUMP. 2/12/2010 00:00-05:00 5.00 WHSUR P RUNCMP NIPPLE UP ADAPTER FLANGE AND TREE. TEST ADAPTER FLANGE AND HANGER VOID TO 5,000 PSI FOR 30 MIN -GOOD TEST TEST TREE TO 5,000 PSI -GOOD TEST 05:00-06:00 1.00 WHSUR P RUNCMP RU DSM LUBRICATOR TEST LUBRICATOR TO 500 PSI PULL TWC RD DSM LUBRICATOR 06:00-06:30 0.50 RUNCOMP RUNCMP RIG UP WELLHEAD TO REVERSE CIRCULATE -PUMP DOWN ANNULUS VALVE -TAKE RETURNS OUT THE WING VALVE RIG UP CH2M HILL AND LRHOS FOR REVERSE CIRCULATING COMPLETION FLUIDS 06:30-10:00 3.50 RUNCOMP RUNCMP REVERSE CIRCULATE 351 BBLS CLEAN 2%KCL FLUID, 127 BBLS 2%KCL WITH CORROSION INHIBITOR DOWN IA. -3 BPM 10:00-12:30 2.50 RUNCOMP RUNCMP BLOW DOWN LINES AND SPOT LITTLE RED HOT OIL SERVICE TEST LINES TO 3,000 PSI PUMP 144 BBLS 80 DEGF DIESEL DOWN IA -2.0 BPM 750 PSI INITIAL -1.6 BPM 950 PSI FINAL 12:30- 15:00 2.50 RUNCOMP RUNCMP RIG DOWN LITTLE RED HOT OIL SERVICE LINE UP AND U-TUBE DIESEL FREEZE PROTECT INTO TUBING WHILE WAITING FOR DIESEL TO U-TUBE,HOLD SAFETY MEETING WITH SMITH AND BEATTY CREWS -DISCUSSED RECENT NEAR MISS INCIDENTS WITHIN ADW AND RECENT GPB INCIDENTS 15:00-18:30 3.50 RUNCOMP RUNCMP .RIG UP TO SET AND TEST PACKER_ DROP BALL AND ROD PRESSURE UP ON TUBING AND SET PACKER INCREASE PRESSURE TO 4,000 PSI AND TEST TUBING FOR 30 MIN -GOOD TEST BLEED PRESSURE OFF OF TUBING PRESSURE UP IA TO 4,000 PSI AND TEST FOR 30 MIN -GOOD TEST Printed: 2/18/2010 4:55:50 PM S BP EXPLORATION Page 29 of 29 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: 2/12/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/12/2010 Rig Name: DOYON 14 Rig Number: 14 Date From -To Hours Task Code NPT Phase Description of Operations 2/12/2010 15:00-18:30 3.50 RUNCOMP RUNCMP BLEED PRESSURE OFF OF IA -PRESSURES ON TUBING AND IA 0/0 AOGCC REP CHUCK SCHEVE WAIVED WITNESS OF IA TEST. 18:30-19:00 0.50 WHSUR P RUNCMP DRY ROD BPV IN HANGER PROFILE. 19:00-21:00 2.00 WHSUR P RUNCMP CLEAN AND CLEAR RIG FLOOR INSTALL ALL FLANGES AND GAUGES SECURE TREE RIG RELEASED:21:00 ON 2/12/2010 Printed: 2/18/2010 4:55:50 PM AGI-01 A, Well History (Post Rig Sidetrack) Date Summary 2/25/2010 WELL SHUT IN ON ARRIVAL. PULLED BALL& ROD FROM 9943' SLM. PULLED RHC PLUG BODY FROM RN NIPPLE @ 9953' SLM/9965' MD. DRIFT W/10'x 3-3/8" DMY GUN& 1-3/4" S. BAILER TO 10459' SLM(recovered soft cement). MADE 2 RUNS W/10'x 3.00" P. BAILER TO 10477' SLM (recovered -6-1/2 gal soft cement). RAN 10'x 3.50" P. BAILER TO 10481' SLM(recovered -3 GAL soft cement). 2/26/2010 MADE 5 RUNS W/10'x 3.50" P. BAILER TO 10489'SLM/10519' MD (recovered -17 gal soft cement). TAG TD AT 10,519'CORRECTED MD WITH 3.50" BAILER. WELL LEFT SHUT IN. 2/26/2010 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/0=500/0/0 PSI. RIG UP E-LINE. 2/27/2010 RUN JEWELRY LOG FROM 10506'-9900'. BHP=3715 PSI WITH WHP=300 PSI, BHT= 113°F. PERFORATE 10465'- 10496'WITH 3-3/8" PJ HSD 6SPF 60 DEG PHASING GUNS. 2/28/2010 PERFORATE 10350'- 10430'WITH 3-3/8" PJ HSD 6SPF 60 DEG PHASING GUNS. 3/1/2010 PERFORATE 10220'- 10350'WITH 3-3/8" PJ HSD 6SPF 60 DEG PHASING GUNS. FINAL T/I/O= 0/0/0 PSI. VALVES LEFT AS FOUND,TREE CAP PRESSURE TESTED TO 3000 PSI. TREE CAP PRESSURE BLED OFF POST TEST. JOB COMPLETE. 3/2/2010 T/I/O=680/Vac/230. Temp=SI. TBG FL(pre injectivity test). GI. 2" integral installed on OA. TBG FL @ 1176' (55 bbls). 3/3/2010 T/I/0= 1200/0/300 Injectivity Test(Post SDTRK) Pumped 5 bbls neat,200 bbls 1%kcl, 2 bbls neat and 120 bbls 140°F diesel down the tubing. Established an injectivity rate at 4.7 bpm CO 1400 psi for 100 bbls. Turn well over to SSL. Final W HP's=300/0/300 Slickline has control of well at departure. 3/3/2010 LRS PUMPED 5 BBLS METH,200 BBLS 1 %KCL AND 120 BBLS. DIESEL AND ESTABLISHED AN INJECTION RATE OF 4.7 BPM AT 1400 PSI. SET 7"A-1 INJECTION VALVE DB-6.00(S/N BVS-261)- MODIFIED LOCK HOUSING W/SET SCREWS AND 3.50 ORIFICE WITH MODIFIED FLAPPER HOUSING AT 1991'SLM. PERFORM PASSING CLOSURE TEST. WELL LEFT S/I. Page 1 of 1 a North America - ALASKA - BP Prudhoe Bay (various) AGI AGI-01 AGI-01A Design: AGI-01A Survey Report - Geographic 11 February, 2010 0 Survey Report-Geographic Company: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P Project Prudhoe Bay(various),GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site AGI,TR-12-14 Site Position: Northing: 5,973,288.42 ft Latitude: 70°19'55.268 N From: Map Easting: 685,006.87 ft Longitude: 148°29'57.054 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.41 ° Well AGI-01 API No. 500292230700 Well Position +N/-S 0.00 ft Northing: 5,979,223.82 ft Latitude: 70°20'52.673 N +E/-W 0.00 ft Easting: 688,901.48 ft Longitude: 148°27'58.998 W Position Uncertainty 0.00 ft Wellhead Elevation: 13.40 ft Ground Level: 13.40 ft Wellbore AGI-01A API No 500292230701 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°) (nT) BGGM2009 1/1/2010 22.49 80.99 57,690 I Design AGI-01A Audit Notes: 20100209 Setup definitive survey.Deleted prototype plan and set principal plan to prototype.Awaiting liner set depth then will load casings and ger Version: 1.0 Phase: ACTUAL Tie On Depth: 3,886.40 Vertical Section: Depth From(TVD) +N1-S +E/-W Direction (ft) (ft) (ft► 1°) 34.30 0.00 0.00 93.74 1 Survey Program Date: 2/11/2010 From To • (ft) (ft) Survey(Wellbore) Tool Name Description 48.80 3,886.40 2:Schlumberger GCT multishot(AGI-01) GCT-MS Schlumberger GCT multishot 3,915.00 7,495.56 MWD+IFR+MS Run 200(AGI-01A) MWD+IFR+MS MWD+IFR+Multi Station 7,515.32 10,151.67 MWD+IFR+MS Run 300(AGI-01A) MWD+IFR+MS MWD+IFR+Multi Station 10,228.78 10,560.76 MWD+IFR+MS Run 400(AGI-01A) MWD+IFR+MS MWD+IFR+Multi Station 2/11/2010 10:45:59AM Page 2 COMPASS 2003.16 Build 71 8 Survey Report-Geographic Company: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project Prudhoe Bay(various) ND Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A©47.70ft(D-14) Well: AGI-01 North Reference: True Welibore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +Nl-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 34.30 0.00 0.00 34.30 0.00 0.00 5,979,223.82 688,901.48 70°20'52.673 N 148°27'58.998 W 48.80 0.20 294.30 48.80 0.01 -0.02 5,979,223.83 688,901.46 70°20'52.673 N 148°27'58.998 W 52.20 0.20 288.50 52.20 0.01 -0.03 5,979,223.83 688,901.45 70°20'52.673 N 148°27'58.999 W 63.00 0.20 277.10 63.00 0.02 -0.07 5,979,223.84 688,901.41 70°20'52.673 N 148°27'59.000 W 80.30 0.20 258.30 80.30 0.02 -0.13 5,979,223.84 688,901.35 70°20'52.673 N 148°27'59.002 W 98.50 0.20 238.50 98.50 0.00 -0.19 5,979,223.81 688,901.29 70°20'52.673 N 148°27'59.003 W 116.80 0.20 211.10 116.80 -0.05 -0.23 5,979,223.77 688,901.25 70°20'52.672 N 148°27'59.005 W 134.90 0.20 185.60 134.90 -0.10 -0.25 5,979,223.71 688,901.23 70°20'52.672 N 148°27'59.005 W 153.20 0.20 160.60 153.20 -0.17 -0.24 5,979,223.65 688,901.24 70°20'52.671 N 148°27'59.005 W 171.40 0.20 138.00 171.40 -0.22 -0.21 5,979,223.59 688,901.27 70°20'52.671 N 148°27'59.004 W 189.80 0.20 115.60 189.80 -0.26 -0.16 5,979,223.56 688,901.32 70°20'52.670 N 148°27'59.002 W 208.10 0.30 97.00 208.10 -0.28 -0.09 5,979,223.54 688,901.40 70°20'52.670 N 148°27'59.000 W 226.50 0.30 84.30 226.50 -0.28 0.01 5,979,223.54 688,901.50 70°20'52.670 N 148°27'58.997 W 244.90 0.30 72.80 244.90 -0.26 0.10 5,979,223.56 688,901.59 70°20'52.670 N 148°27'58.995 W 263.40 0.30 63.50 263.40 -0.22 0.19 5,979,223.60 688,901.68 70°20'52.671 N 148°27'58.992 W 281.70 0.30 52.10 281.70 -0.17 0.27 5,979,223.65 688,901.76 70°20'52.671 N 148°27'58.990 W 300.10 0.30 45.60 300.10 -0.11 0.35 5,979,223.72 688,901.83 70°20'52.672 N 148°27'58.988 W 318.40 0.30 40.40 318.40 -0.04 0.41 5,979,223.79 688,901.89 70°20'52.672 N 148°27'58.986 W 336.70 0.30 32.20 336.70 0.04 0.47 5,979,223.87 688,901.95 70°20'52.673 N 148°27'58.984 W 355.00 0.30 22.90 355.00 0.12 0.51 5,979,223.95 688,901.99 70°20'52.674 N 148°27'58.983 W 373.30 0.30 10.30 373.30 0.21 0.54 5,979,224.05 688,902.01 70°20'52.675 N 148°27'58.982 W 391.70 0.30 353.30 391.70 0.31 0.54 5,979,224.14 688,902.02 70°20'52.676 N 148°27'58.982 W 410.20 0.40 328.50 410.20 0.41 0.50 5,979,224.24 688,901.97 70°20'52.677 N 148°27'58.983 W 428.60 0.30 316.80 428.60 0.50 0.44 5,979,224.33 688,901.90 70°20'52.678 N 148°27'58.985 W 447.00 0.30 301.70 447.00 0.56 0.36 5,979,224.39 688,901.83 70°20'52.678 N 148°27'58.987 W 465.40 0.30 287.70 465.40 0.60 0.28 5,979,224.43 688,901.74 70°20'52.679 N 148°27'58.990 W 483.80 0.30 280.30 483.80 0.63 0.18 5,979,224.45 688,901.65 70°20'52.679 N 148°27'58.992 W 502.00 0.30 275.70 501.99 0.64 0.09 5,979,224.46 688,901.55 70°20'52.679 N 148°27'58.995 W 520.40 0.30 272.40 520.39 0.65 -0.01 5,979,224.46 688,901.46 70°20'52.679 N 148°27'58.998 W 538.60 0.30 270.70 538.59 0.65 -0.10 5,979,224.46 688,901.36 70°20'52.679 N 148°27'59.001 W 556.90 0.30 269.90 556.89 0.65 -0.20 5,979,224.46 688,901.27 70°20'52.679 N 148°27'59.004 W 575.00 0.20 268.60 574.99 0.65 -0.28 5,979,224.46 688,901.19 70°20'52.679 N 148°27'59.006 W'. 592.90 0.10 336.90 592.89 0.66 -0.31 5,979,224.47 688,901.15 70°20'52.679 N 148°27'59.007 W 610.90 0.20 17.00 610.89 0.71 -0.31 5,979,224.52 688,901.15 70°20'52.680 N 148°27'59.007 W 628.70 0.30 8.70 628.69 0.78 -0.30 5,979,224.59 688,901.17 70°20'52.680 N 148°27'59.006 W 646.50 0.40 356.70 646.49 0.89 -0.29 5,979,224.70 688,901.17 70°20'52.681 N 148°27'59.006 W 664.40 0.40 342.80 664.39 1.01 -0.31 5,979,224.82 688,901.14 70°20'52.683 N 148°27'59.007 W 682.50 0.50 328.40 682.49 1.14 -0.37 5,979,224.95 688,901.08 70°20'52.684 N 148°27'59.009 W 700.40 0.50 322.20 700.39 1.27 -0.46 5,979,225.08 688,900.99 70°20'52.685 N 148°27'59.011 W', 718.40 0.50 317.70 718.39 1.39 -0.56 5,979,225.19 688,900.88 70°20'52.686 N 148°27'59.014 W'. 736.30 0.60 306.30 736.29 1.50 -0.69 5,979,225.30 688,900.75 70°20'52.687 N 148°27'59.018 W 754.20 0.60 278.20 754.19 1.57 -0.86 5,979,225.37 688,900.58 70°20'52.688 N 148°27'59.023 W 772.10 0.60 269.30 772.09 1.58 -1.05 5,979,225.37 688,900.39 70°20'52.688 N 148°27'59.028 W 790.00 0.60 266.00 789.99 1.57 -1.23 5,979,225.36 688,900.21 70°20'52.688 N 148°27'59.034 W 808.00 0.60 263.30 807.99 1.56 -1.42 5,979,225.34 688,900.02 70°20'52.688 N 148°27'59.039 W 825.90 0.50 262.60 825.89 1.54 -1.59 5,979,225.31 688,899.85 70°20'52.688 N 148°27'59.044 W 843.80 0.50 262.70 843.78 1.52 -1.75 5,979,225.29 688,899.70 70°20'52.688 N 148°27'59.049 W 861.90 0.40 270.40 861.88 1.51 -1.89 5,979,225.28 688,899.55 70°20'52.688 N 148°27'59.053 W 879.90 0.60 309.30 879.88 1.57 -2.02 5,979,225.33 688,899.42 70°20'52.688 N 148°27'59.057 W 897.80 0.50 316.20 897.78 1.68 -2.15 5,979,225.45 688,899.29 70°20'52.689 N 148°27'59.061 W 915.80 0.30 327.40 915.78 1.78 -2.23 5,979,225.54 688,899.21 70°20'52.690 N 148°27'59.063 W 933.80 0.30 326.30 933.78 1.86 -2.28 5,979,225.62 688,899.15 70°20'52.691 N 148°27'59.064 W 951.80 0.20 312.70 951.78 1.92 -2.33 5,979,225.68 688,899.10 70°20'52.692 N 148°27'59.066 W 969.70 0.30 198.10 969.68 1.89 -2.37 5,979,225.65 688,899.06 70°20'52.691 N 148°27'59.067 W 987.80 0.50 151.30 987.78 1.78 -2.35 5,979,225.54 688,899.09 70°20'52.690 N 148°27'59.066 W 2/11/2010 10:45:59AM Page 3 COMPASS 2003.16 Build 71 • I Survey Report-Geographic Company: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A©47.70ft(D-14) Site: AGI MD Reference: AGI-01A©47.70ft(D-14) Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +El-W Northing Easting (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1,005.80 0.80 134.10 1,005.78 1.62 -2.22 5,979,225.39 688,899.22 70°20'52.689 N 148°27'59.063 W 1,023.80 1.10 122.80 1,023.78 1.44 -1.98 5,979,225.21 688,899.46 70°20'52.687 N 148°27'59.056 W 1,041.90 1.40 117.80 1,041.87 1.25 -1.64 5,979,225.02 688,899.81 70°20'52.685 N 148°27'59.046 W 1,060.00 1.70 115.40 1,059.97 1.03 -1.20 5,979,224.82 688,900.25 70°20'52.683 N 148°27'59.033 W 1,077.80 1.90 114.10 1,077.76 0.79 -0.69 5,979,224.60 688,900.77 70°20'52.681 N 148°27'59.018 W 1,095.60 2.20 113.00 1,095.55 0.54 -0.11 5,979,224.36 688,901.36 70°20'52.678 N 148°27 59.001 W 1,113.50 2.40 111.40 1,113.43 0.27 0.55 5,979,224.10 688,902.03 70°20'52.675 N 148°27'58.982 W 1,131.20 2.60 110.70 1,131.12 -0.01 1.27 5,979,223.84 688,902.75 70°20'52.673 N 148°27'58.960 W 1,149.20 2.70 109.20 1,149.10 -0.29 2.06 5,979,223.58 688,903.54 70°20'52.670 N 148°27'58.938 W 1,167.00 2.90 108.10 1,166.87 -0.57 2.88 5,979,223.32 688,904.37 70°20'52.667 N 148°27'58.914 W 1,185.00 3.30 107.10 1,184.85 -0.86 3.81 5,979,223.05 688,905.31 70°20'52.664 N 148°27'58.886 W 1,202.80 3.60 106.50 1,202.62 -1.17 4.83 5,979,222.77 688,906.34 70°20'52.661 N 148°27'58.856 W 1,220.70 4.00 106.50 1,220.48 -1.51 5.97 5,979,222.46 688,907.49 70°20'52.658 N 148°27'58.823 W 1,238.70 4.30 106.10 1,238.43 -1.88 7.22 5,979,222.13 688,908.75 70°20'52.654 N 148°27'58.787 W 1,256.60 4.70 105.90 1,256.27 -2.26 8.57 5,979,221.77 688,910.11 70°20'52.650 N 148°27'58.747 W 1,274.60 4.90 105.30 1,274.21 -2.67 10.02 5,979,221.41 688,911.57 70°20'52.646 N 148°27'58.705 W 1,292.50 5.20 105.60 1,292.04 -3.09 11.54 5,979,221.02 688,913.10 70°20'52.642 N 148°27'58.660 W ' 1,310.50 5.40 105.80 1,309.96 -3.54 13.14 5,979,220.61 688,914.71 70°20'52.638 N 148°27'58.614 W 1,328.40 5.60 105.60 1,327.78 -4.00 14.79 5,979,220.19 688,916.37 70°20'52.633 N 148°27'58.565 W 1,348.80 5.70 105.50 1,348.08 -4.54 16.73 5,979,219.70 688,918.32 70°20'52.628 N 148°27'58.509 W 1,366.80 5.90 105.30 1,365.99 -5.02 18.48 5,979,219.26 688,920.08 70°20'52.623 N 148°27'58.458 W 1,384.70 6.10 104.90 1,383.79 -5.51 20.29 5,979,218.82 688,921.90 70°20'52.619 N 148°27'58.405 W 1,402.50 6.20 105.00 1,401.49 -6.00 22.13 5,979,218.38 688,923.75 70°20'52.614 N 148°27'58.351 W 1,420.10 6.40 104.70 1,418.98 -6.50 24.00 5,979,217.93 688,925.63 70°20'52.609 N 148°27'58.296 W 1,437.80 6.40 104.80 1,436.57 -7.00 25.91 5,979,217.48 688,927.55 70°20'52.604 N 148°27'58.241 W I 1,455.50 6.60 104.60 1,454.16 -7.51 27.84 5,979,217.02 688,929.50 70°20'52.599 N 148°27'58.184 W 1,473.20 6.70 104.40 1,471.74 -8.02 29.83 5,979,216.55 688,931.50 70°20'52.594 N 148°27'58.126 W 1,490.90 6.70 104.70 1,489.32 -8.54 31.83 5,979,216.09 688,933.51 70°20'52.589 N 148°27'58.068 W 1,508.50 6.80 104.90 1,506.80 -9.07 33.83 5,979,215.61 688,935.52 70°20'52.584 N 148°27'58.009 W 1,526.20 6.90 105.00 1,524.37 -9.61 35.87 5,979,215.11 688,937.58 70°20'52.578 N 148°27'57.950 W 1,543.70 7.00 105.30 1,541.74 -10.17 37.91 5,979,214.61 688,939.63 70°20'52.573 N 148°27'57.890 W 1,561.30 7.30 105.60 1,559.21 -10.75 40.02 5,979,214.08 688,941.76 70°20'52.567 N 148°27'57.828 W 1,579.00 7.60 105.90 1,576.76 -11.37 42.23 5,979,213.52 688,943.98 70°20'52.561 N 148°27'57.764 W 1,596.60 8.00 105.90 1,594.19 -12.03 44.53 5,979,212.92 688,946.30 70°20'52.554 N 148°27'57.697 W 1,614.20 8.70 106.00 1,611.61 -12.73 46.99 5,979,212.28 688,948.77 70°20'52.548 N 148°27'57.625 W 1,631.70 9.20 106.00 1,628.89 -13.48 49.60 5,979,211.59 688,951.40 70°20'52.540 N 148°27'57.548 W 1,649.30 9.80 105.90 1,646.25 -14.28 52.40 5,979,210.87 688,954.22 70°20'52.532 N 148°27'57.467 W 1,667.00 10.20 106.00 1,663.68 -15.12 55.35 5,979,210.10 688,957.19 70°20'52.524 N 148°27'57.380 W 1,684.60 10.50 106.20 1,681.00 -16.00 58.39 5,979,209.30 688,960.25 70°20'52.515 N 148°27'57.292 W 1,702.50 10.70 106.50 1,698.59 -16.93 61.55 5,979,208.45 688,963.43 70°20'52.506 N 148°27'57.199 W 1,720.00 11.00 107.00 1,715.78 -17.88 64.70 5,979,207.58 688,966.61 70°20'52.497 N 148°27'57.107 W 1,737.60 11.20 107.30 1,733.05 -18.88 67.94 5,979,206.66 688,969.87 70°20'52.487 N 148°27'57.012 W 1,755.20 11.30 107.60 1,750.31 -19.91 71.22 5,979,205.72 688,973.17 70°20'52.477 N 148°27'56.917 W 1,772.60 11.40 107.70 1,767.37 -20.94 74.48 5,979,204.76 688,976.46 70°20'52.467 N 148°27'56.821 W 1,790.40 11.60 107.70 1,784.81 -22.02 77.86 5,979,203.77 688,979.87 70°20'52.456 N 148°27'56.723 W 1,807.80 11.90 107.10 1,801.85 -23.08 81.24 5,979,202.79 688,983.27 70°20'52.446 N 148°27'56.624 W 1,825.30 12.20 106.70 1,818.96 -24.14 84.74 5,979,201.82 688,986.79 70°20'52.435 N 148°27'56.522 W 1,842.80 12.70 105.80 1,836.05 -25.20 88.36 5,979,200.86 688,990.44 70°20'52.425 N 148°27'56.416 W 1,860.30 13.20 104.90 1,853.11 -26.24 92.14 5,979,199.92 688,994.25 70°20'52.415 N 148°27'56.305 W , 1,877.90 13.90 103.50 1,870.22 -27.25 96.14 5,979,199.01 688,998.27 70°20'52.405 N 148°27'56.188 W 1,895.40 15.00 101.30 1,887.16 -28.18 100.40 5,979,198.18 689,002.56 70°20'52.396 N 148°27'56.064 W 1,918.80 16.40 98.70 1,909.69 -29.27 106.64 5,979,197.24 689,008.82 70°20'52.385 N 148°27'55.882 W 1,951.10 18.10 96.20 1,940.54 -30.51 116.14 5,979,196.25 689,018.34 70°20'52.373 N 148°27 55.604 W 1,990.10 19.30 95.00 1,977.48 -31.72 128.58 5,979,195.35 689,030.81 70°20'52.361 N 148°27'55.241 W 2,030.10 19.80 95.40 2,015.17 -32.94 141.91 5,979,194.47 689,044.17 70°20'52.349 N 148°27'54.851 W 2/11/2010 10:45:59AM Page 4 COMPASS 2003.16 Build 71 8 Survey Report-Geographic Company: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A©47.70ft(D-14) Well: AGI-01 North Reference: True Welibore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-5 +E/-W Northing Easting (ft) 11 (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2,071.00 20.80 96.10 2,053.53 -34.36 156.03 5,979,193.41 689,058.31 70°20'52.335 N 148°27'54.438 W 2,111.80 23.00 96.60 2,091.38 -36.05 171.15 5,979,192.10 689,073.47 70°20'52.318 N 148°27'53.997 W 2,152.50 25.00 96.00 2,128.56 -37.86 187.60 5,979,190.70 689,089.97 70°20'52.300 N 148°27'53.516 W 2,183.10 26.20 94.90 2,156.16 -39.11 200.76 5,979,189.78 689,103.15 70°20'52.288 N 148°27'53.131 W 2,202.40 27.30 93.50 2,173.39 -39.75 209.43 5,979,189.37 689,111.83 70°20'52.282 N 148°27'52.878 W 2,221.80 28.20 91.80 2,190.56 -40.16 218.45 5,979,189.18 689,120.86 70°20'52.278 N 148°27'52.614 W 2,240.90 29.10 89.90 2,207.32 -40.30 227.61 5,979,189.28 689,130.02 70°20'52.276 N 148°27'52.347 W 2,260.10 29.80 88.00 2,224.04 -40.12 237.04 5,979,189.69 689,139.44 70°20'52.278 N 148°27'52.071 W 2,279.10 30.40 86.30 2,240.48 -39.65 246.56 5,979,190.40 689,148.95 70°20'52.283 N 148°27'51.793 W 2,298.10 30.70 85.10 2,256.84 -38.92 256.19 5,979,191.37 689,158.55 70°20'52.290 N 148°27'51.512 W 2,317.10 31.00 84.60 2,273.16 -38.05 265.89 5,979,192.49 689,168.23 70°20'52.298 N 148°27 51.228 W 2,336.20 31.10 84.30 2,289.52 -37.09 275.70 5,979,193.69 689,178.01 70°20'52.308 N 148°27'50.942 W 2,355.40 31.10 84.30 2,305.96 -36.11 285.57 5,979,194.92 689,187.85 70°20'52.318 N 148°27 50.653 W 2,355.70 31.10 84.30 2,306.22 -36.09 285.72 5,979,194.94 689,188.00 70°20'52.318 N 148°27 50.649 W 2,357.50 31.20 84.40 2,307.76 -36.00 286.65 5,979,195.06 689,188.93 70°20'52.319 N 148°27 50.622 W 2,367.60 31.20 84.70 2,316.40 -35.50 291.86 5,979,195.68 689,194.12 70°20'52.323 N 148°27'50.469 W 2,383.30 31.10 84.80 2,329.83 -34.76 299.94 5,979,196.63 689,202.19 70°20'52.331 N 148°27'50.233 W 2,400.60 31.00 85.20 2,344.65 -33.98 308.83 5,979,197.63 689,211.05 70°20'52.338 N 148°27'49.973 W 2,419.20 31.00 85.50 2,360.60 -33.21 318.38 5,979,198.65 689,220.58 70°20'52.346 N 148°27 49.694 W 2,439.40 31.00 86.00 2,377.91 -32.44 328.75 5,979,199.68 689,230.93 70°20'52.354 N 148°27'49.391 W 2,460.80 31.00 86.50 2,396.25 -31.72 339.75 5,979,200.68 689,241.90 70°20'52.361 N 148°27'49.070 W 2,483.10 31.10 87.20 2,415.36 -31.08 351.24 5,979,201.60 689,253.37 70°20'52.367 N 148°27'48.734 W 2,506.10 31.40 88.40 2,435.02 -30.63 363.16 5,979,202.36 689,265.27 70°20'52.371 N 148°27'48.386 W 2,529.00 31.60 90.00 2,454.55 -30.46 375.12 5,979,202.83 689,277.23 70°20'52.373 N 148°27'48.036 W 2,551.60 31.80 91.40 2,473.78 -30.60 387.00 5,979,202.98 689,289.10 70°20'52.372 N 148°27'47.689 W 2,577.80 32.40 92.30 2,495.97 -31.06 400.91 5,979,202.88 689,303.02 70°20'52.367 N 148°27'47.283 W 2,606.20 33.60 92.60 2,519.79 -31.72 416.37 5,979,202.61 689,318.49 70°20'52.361 N 148°27'46.831 W 2,634.60 35.20 92.00 2,543.22 -32.36 432.40 5,979,202.37 689,334.53 70°20'52.354 N 148°27 46.363 W 2,663.00 35.90 91.60 2,566.33 -32.88 448.90 5,979,202.27 689,351.04 70°20'52.349 N 148°27 45.880 W 2,691.50 36.10 91.70 2,589.39 -33.36 465.65 5,979,202.21 689,367.79 70°20'52.344 N 148°27'45.391 W, 2,720.00 36.40 91.80 2,612.37 -33.87 482.49 5,979,202.12 689,384.64 70°20'52.339 N 148°27'44.899 W 2,748.50 36.60 92.10 2,635.28 -34.45 499.43 5,979,201.97 689,401.59 70°20'52.334 N 148°27'44.404 W 2,776.80 37.10 92.30 2,657.93 -35.10 516.39 5,979,201.75 689,418.56 70°20'52.327 N 148°27 43.908 W 2,805.30 37.70 92.40 2,680.57 -35.81 533.69 5,979,201.47 689,435.87 70°20'52.320 N 148°27 43.403 W 2,834.40 38.30 92.20 2,703.50 -36.53 551.59 5,979,201.20 689,453.78 70°20'52.313 N 148°27'42.880 W 2,864.20 38.60 92.20 2,726.83 -37.24 570.11 5,979,200.96 689,472.31 70°20'52.306 N 148°27'42.339 W 2,893.80 38.60 92.30 2,749.97 -37.97 588.56 5,979,200.70 689,490.77 70°20'52.299 N 148°27'41.799 W 2,923.30 38.70 92.40 2,773.01 -38.72 606.97 5,979,200.41 689,509.19 70°20'52.292 N 148°27'41.261 W 2,952.80 39.10 92.40 2,795.96 -39.50 625.48 5,979,200.10 689,527.72 70°20'52.284 N 148°27'40.721 W 2,982.70 39.70 92.50 2,819.07 -40.31 644.44 5,979,199.77 689,546.69 70°20'52.276 N 148°27'40.167 W 3,012.20 40.30 92.50 2,841.67 -41.14 663.38 5,979,199.42 689,565.65 70°20'52.268 N 148°27'39.613 W 3,041.50 40.70 92.80 2,863.95 -42.02 682.39 5,979,199.02 689,584.67 70°20'52.259 N 148°27'39.058 W 3,070.60 41.00 93.00 2,885.96 -42.98 701.40 5,979,198.53 689,603.70 70°20'52.250 N 148°27'38.502 W 3,099.70 41.30 93.20 2,907.87 -44.02 720.52 5,979,197.98 689,622.84 70°20'52.239 N 148°27'37.943 W 3,128.90 41.60 93.20 2,929.76 -45.10 739.82 5,979,197.39 689,642.16 70°20'52.229 N 148°27'37.379 W 3,158.10 41.90 93.20 2,951.54 -46.18 759.23 5,979,196.79 689,661.59 70°20'52.218 N 148°27'36.812 W 3,187.10 42.50 93.20 2,973.03 -47.27 778.68 5,979,196.20 689,681.06 70°20'52.207 N 148°27'36.244 W 3,215.90 43.30 93.40 2,994.12 -48.40 798.25 5,979,195.56 689,700.65 70°20'52.196 N 148°27'35.672 W 3,244.90 43.90 93.70 3,015.12 -49.64 818.21 5,979,194.83 689,720.64 70°20'52.184 N 148°27'35.089 W 3,273.70 44.30 94.10 3,035.81 -51.00 838.21 5,979,193.97 689,740.66 70°20'52.171 N 148°27'34.504 W 3,302.70 44.40 94.70 3,056.54 -52.55 858.42 5,979,192.92 689,760.90 70°20'52.155 N 148°27'33.914 W 3,332.00 44.60 94.90 3,077.44 -54.27 878.89 5,979,191.72 689,781.40 70°20'52.138 N 148°27 33.316 W 3,361.00 45.00 94.70 3,098.02 -55.98 899.25 5,979,190.52 689,801.80 70°20'52.122 N 148°27'32.721 W 3,390.00 45.50 93.80 3,118.44 -57.51 919.79 5,979,189.52 689,822.37 70°20'52.107 N 148°27'32.121 W 3,419.00 45.80 92.50 3,138.71 -58.65 940.49 5,979,188.90 689,843.10 70°20'52.095 N 148°27'31.516 W 2/11/2010 10:45:59AM Page 5 COMPASS 2003.16 Build 71 f 8 Survey Report-Geographic Company: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A©47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) P) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3,448.00 45.90 91.00 3,158.91 -59.28 961.29 5,979,188.79 689,863.90 70°20'52.089 N 148°27'30.908 W 3,476.90 46.00 89.50 3,179.00 -59.37 982.06 5,979,189.22 689,884.67 70°20'52.088 N 148°27'30.301 W 3,506.00 46.00 88.90 3,199.22 -59.08 1,002.99 5,979,190.04 689,905.58 70°20'52.091 N 148°27'29.689 W 3,535.20 45.90 88.60 3,219.52 -58.62 1,023.97 5,979,191.03 689,926.54 70°20'52.095 N 148°27'29.076 W 3,564.30 45.60 88.60 3,239.83 -58.11 1,044.81 5,979,192.06 689,947.36 70°20'52.100 N 148°27 28.467 W 3,593.60 45.20 88.90 3,260.40 -57.66 1,065.67 5,979,193.04 689,968.20 70°20'52.105 N 148°27'27.858 W 3,622.90 44.90 89.20 3,281.10 -57.31 1,086.40 5,979,193.91 689,988.92 70°20'52.108 N 148°27'27.252 W 3,652.20 44.90 89.50 3,301.85 -57.08 1,107.08 5,979,194.67 690,009.58 70°20'52.111 N 148°27'26.648 W 3,681.60 44.90 89.60 3,322.68 -56.92 1,127.83 5,979,195.35 690,030.32 70°20'52.112 N 148°27'26.041 W' 3,711.20 44.80 89.60 3,343.66 -56.77 1,148.71 5,979,196.02 690,051.19 70°20'52.114 N 148°27'25.431 W 3,740.70 44.30 89.30 3,364.69 -56.57 1,169.40 5,979,196.74 690,071.87 70°20'52.115 N 148°27'24.827 W 3,770.20 44.00 89.00 3,385.85 -56.27 1,189.95 5,979,197.57 690,092.40 70°20'52.118 N 148°27'24.226 W 3,799.90 44.10 89.00 3,407.20 -55.91 1,210.60 5,979,198.45 690,113.03 70°20'52.122 N 148°27'23.623 W 3,829.10 44.10 89.00 3,428.17 -55.55 1,230.91 5,979,199.31 690,133.33 70°20'52.125 N 148°27'23.029 W 3,858.00 44.20 89.10 3,448.90 -55.22 1,251.04 5,979,200.15 690,153.44 70°20'52.129 N 148°27'22.441 W 3,886.40 44.10 89.20 3,469.28 -54.93 1,270.82 5,979,200.95 690,173.21 70°20'52.131 N 148°27'21.863 W 3,915.00 44.01 89.57 3,489.84 -54.71 1,290.71 5,979,201.66 690,193.08 70°20'52.134 N 148°27'21.282 W 4,003.46 42.30 92.32 3,554.37 -55.69 1,351.19 5,979,202.21 690,253.56 70°20'52.124 N 148°27'19.515 W 4,097.85 43.14 95.25 3,623.72 -59.92 1,415.07 5,979,199.58 690,317.53 70°20'52.082 N 148°27'17.648 W 4,193.15 43.18 98.13 3,693.25 -67.52 1,479.80 5,979,193.62 690,382.42 70°20'52.007 N 148°27'15.757 W 4,287.11 44.39 100.90 3,761.09 -78.28 1,543.90 5,979,184.48 690,446.77 70°20'51.901 N 148°27'13.883 W 4,382.09 46.18 97.63 3,827.92 -89.11 1,610.50 5,979,175.33 690,513.62 70°20'51.795 N 148°27'11.937 W 4,477.77 45.59 95.37 3,894.53 -96.90 1,678.74 5,979,169.27 690,582.03 70°20'51.718 N 148°27'9.943 W 4,572.65 46.37 92.46 3,960.46 -101.54 1,746.80 5,979,166.34 690,650.18 70°20'51.672 N 148°27'7.955 W 4,667.39 46.01 91.64 4,026.05 -103.99 1,815.12 5,979,165.62 690,718.54 70°20'51.648 N 148°27'5.958 W 4,760.48 45.62 92.88 4,090.93 -106.62 1,881.82 5,979,164.67 690,785.28 70°20'51.622 N 148°27'4.009 W 4,854.89 45.23 92.65 4,157.19 -109.86 1,948.99 5,979,163.12 690,852.51 70°20'51.590 N 148°27'2.047 W 4,948.39 44.77 94.08 4,223.31 -113.74 2,014.99 5,979,160.91 690,918.58 70°20'51.551 N 148°27'0.118 W 5,042.64 46.07 94.91 4,289.46 -119.01 2,081.91 5,979,157.33 690,985.61 70°20'51.499 N 148°26'58.163 W 5,136.60 45.47 93.99 4,355.01 -124.23 2,149.03 5,979,153.80 691,052.84 70°20'51.448 N 148°26'56.201 W 5,233.02 46.08 96.61 4,422.26 -130.62 2,217.82 5,979,149.15 691,121.76 70°20'51.385 N 148°26'54.191 W 5,326.33 46.60 94.91 4,486.68 -137.39 2,284.98 5,979,144.07 691,189.06 70°20'51.318 N 148°26'52.229 W 5,420.99 46.50 94.12 4,551.78 -142.80 2,353.49 5,979,140.39 691,257.68 70°20'51.265 N 148°26'50.227 W 5,514.75 46.31 94.44 4,616.44 -147.87 2,421.20 5,979,137.03 691,325.50 70°20'51.215 N 148°26'48.249 W 5,609.09 45.31 95.18 4,682.19 -153.54 2,488.61 5,979,133.06 691,393.02 70°20'51.159 N 148°26'46.279 W 5,702.51 46.66 94.69 4,747.11 -159.32 2,555.54 5,979,128.98 691,460.07 70°20'51.102 N 148°26'44.323 W 5,797.02 47.65 95.26 4,811.37 -165.33 2,624.57 5,979,124.71 691,529.23 70°20'51.042 N 148°26'42.306 W 5,892.82 47.87 94.20 4,875.78 -171.17 2,695.25 5,979,120.64 691,600.03 70°20'50.984 N 148°26'40.241 W 5,987.70 46.33 93.00 4,940.36 -175.55 2,764.61 5,979,118.02 691,669.48 70°20'50.941 N 148°26'38.214 W', 6,081.63 45.74 91.34 5,005.57 -178.11 2,832.17 5,979,117.16 691,737.07 70°20'50.916 N 148°26'36.240 W', 6,176.52 47.07 91.65 5,071.00 -179.91 2,900.86 5,979,117.10 691,805.79 70°20'50.898 N 148°26'34.233 W 6,269.31 47.17 93.30 5,134.14 -182.84 2,968.79 5,979,115.87 691,873.76 70°20'50.869 N 148°26'32.248 W 6,363.82 46.72 91.48 5,198.67 -185.73 3,037.78 5,979,114.73 691,942.80 70°20'50.840 N 148°26'30.232 W 6,458.71 46.43 93.95 5,263.90 -188.99 3,106.61 5,979,113.20 692,011.68 70°20'50.808 N 148°26'28.221 W 6,551.89 46.01 95.13 5,328.37 -194.31 3,173.68 5,979,109.57 692,078.86 70°20'50.755 N 148°26'26.261 W 6,646.42 47.27 94.93 5,393.28 -200.33 3,242.14 5,979,105.28 692,147.44 70°20'50.696 N 148°26'24.261 W 6,741.03 46.11 96.00 5,458.17 -206.88 3,310.67 5,979,100.46 692,216.11 70°20'50.631 N 148°26'22.259 W 6,835.14 45.81 95.00 5,523.59 -213.37 3,378.00 5,979,095.67 692,283.59 70°20'50.567 N 148°26'20.291 W 6,929.54 44.01 95.92 5,590.45 -219.70 3,444.34 5,979,091.01 692,350.06 70°20'50.504 N 148°26'18.353 W 7,023.08 43.89 95.89 5,657.79 -226.38 3,508.92 5,979,085.96 692,414.78 70°20'50.438 N 148°26'16.466 W 7,118.97 44.31 96.47 5,726.65 -233.57 3,575.26 5,979,080.45 692,481.28 70°20'50.367 N 148°26'14.527 W 7,213.35 46.16 96.45 5,793.11 -241.11 3,641.84 5,979,074.60 692,548.03 70°20'50.293 N 148°26'12.582 W 7,307.00 47.38 94.69 5,857.26 -247.72 3,709.75 5,979,069.70 692,616.07 70°20'50.227 N 148°26'10.598 W 7,401.77 47.08 93.43 5,921.61 -252.64 3,779.14 5,979,066.52 692,685.56 70°20'50.179 N 148°26'8.570 W 7,495.56 46.40 94.28 5,985.89 -257.23 3,847.29 5,979,063.65 692,753.80 70°20'50.133 N 148°26'6.579 W 2/11/2010 10:45:59AM Page 6 COMPASS 2003.16 Build 71 • I Survey Report-Geographic Company: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) ND Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P ICI Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +EI-W Northing Easting (ft) 1°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 7,515.32 46.44 94.28 5,999.51 -258.30 3,861.56 5,979,062.94 692,768.10 70°20'50.123 N 148°26'6.162 W 7,609.39 45.64 93.90 6,064.81 -263.13 3,929.10 5,979,059.82 692,835.73 70°20'50.075 N 148°26'4.189 W 7,703.21 45.75 94.17 6,130.34 -267.86 3,996.08 5,979,056.78 692,902.80 70°20'50.028 N 148°26'2.232 W 7,798.51 45.99 93.67 6,196.70 -272.53 4,064.32 5,979,053.83 692,971.14 70°20'49.982 N 148°26'0.238 W 7,893.14 46.23 93.14 6,262.30 -276.58 4,132.40 5,979,051.50 693,039.29 70°20'49.941 N 148°25'58.248 W 7,987.98 46.29 92.19 6,327.87 -279.77 4,200.84 5,979,050.04 693,107.79 70°20'49.910 N 148°25'56.249 W 8,081.89 46.00 92.52 6,392.94 -282.55 4,268.50 5,979,048.96 693,175.49 70°20'49.882 N 148°25'54.272 W 8,178.39 45.64 93.02 6,460.19 -285.89 4,337.63 5,979,047.36 693,244.67 70°20'49.849 N 148°25'52.252 W 8,271.45 46.05 94.23 6,525.02 -290.12 4,404.26 5,979,044.82 693,311.39 70°20'49.807 N 148°25'50.305 W'. 8,365.64 45.38 94.34 6,590.78 -295.16 4,471.49 5,979,041.48 693,378.73 70°20'49.757 N 148°25'48.340 W 8,459.53 46.27 95.38 6,656.21 -300.86 4,538.59 5,979,037.46 693,445.94 70°20'49.700 N 148°25'46.380 W 8,553.69 45.66 95.66 6,721.66 -307.38 4,605.97 5,979,032.65 693,513.46 70°20'49.636 N 148°25'44.411 W 8,647.37 45.78 94.69 6,787.07 -313.42 4,672.76 5,979,028.29 693,580.38 70°20'49.576 N 148°25'42.460 W 8,741.96 45.89 92.80 6,852.97 -317.85 4,740.46 5,979,025.57 693,648.17 70°20'49.532 N 148°25'40.481 W 8,835.24 43.88 92.53 6,919.06 -320.92 4,806.22 5,979,024.16 693,713.97 70°20'49.501 N 148°25'38.560 W 8,928.83 41.80 94.60 6,987.69 -324.85 4,869.72 5,979,021.83 693,777.55 70°20'49.462 N 148°25'36.705 W 9,023.83 40.53 95.07 7,059.20 -330.12 4,932.03 5,979,018.13 693,839.97 70°20'49.410 N 148°25'34.884 W 9,119.31 38.26 95.61 7,132.98 -335.75 4,992.36 5,979,014.02 693,900.42 70°20'49.354 N 148°25'33.121 W ' 9,211.22 35.91 95.31 7,206.30 -341.03 5,047.52 5,979,010.14 693,955.70 70°20'49.302 N 148°25'31.510 W 9,306.09 33.51 95.88 7,284.28 -346.29 5,101.28 5,979,006.24 694,009.57 70°20'49.250 N 148°25'29.939 W 9,401.31 31.22 93.56 7,364.71 -350.51 5,152.07 5,979,003.29 694,060.44 70°20'49.208 N 148°25'28.455 W 9,496.21 29.02 92.91 7,446.79 -353.21 5,199.61 5,979,001.80 694,108.03 70°20'49.181 N 148°25'27.066 W 9,589.10 26.34 93.48 7,529.04 -355.60 5,242.69 5,979,000.49 694,151.16 70°20'49.157 N 148°25'25.807 W 9,683.46 23.82 93.20 7,614.50 -357.94 5,282.62 5,978,999.16 694,191.13 70°20'49.134 N 148°25'24.641 W', 9,778.34 21.91 93.68 7,701.92 -360.14 5,319.42 5,978,997.88 694,227.97 70°20'49.112 N 148°25'23.565 W' 9,870.78 19.94 94.56 7,788.26 -362.50 5,352.34 5,978,996.35 694,260.94 70°20'49.089 N 148°25'22.603 W 9,966.36 19.91 94.50 7,878.12 -365.08 5,384.81 5,978,994.60 694,293.47 70°20'49.063 N 148°25'21.655 W 10,060.49 19.88 94.24 7,966.63 -367.52 5,416.75 5,978,992.97 694,325.45 70°20'49.039 N 148°25'20.721 W 10,151.67 20.03 96.48 8,052.33 -370.43 5,447.73 5,978,990.84 694,356.49 70°20'49.010 N 148°25'19.816 W 10,228.78 20.24 96.73 8,124.73 -373.48 5,474.10 5,978,988.45 694,382.93 70°20'48.980 N 148°25'19.046 W 10,322.50 19.90 97.18 8,212.76 -377.37 5,506.02 5,978,985.36 694,414.94 70°20'48.941 N 148°25'18.113 W 10,417.04 19.43 95.65 8,301.79 -380.93 5,537.63 5,978,982.60 694,446.63 70°20'48.906 N 148°25'17.190 W 10,512.23 18.65 95.72 8,391.77 -384.01 5,568.54 5,978,980.31 694,477.59 70°20'48.876 N 148°25'16.287 W 10,560.76 18.27 95.72 8,437.80 -385.54 5,583.83 5,978,979.16 694,492.92 70°20'48.861 N 148°25'15.840 W 10,623.00 18.27 95.72 8,496.90 -387.48 5,603.24 5,978,977.71 694,512.37 70°20'48.841 N 148°25 15.273 W 2/11/2010 10:45:59AM Page 7 COMPASS 2003.16 Build 71 • I • Survey Report-Geographic Company: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (1 (1 (ft) (ft) (ft) (fT) (ft) Latitude Longitude AGI-01A Target 0.00 0.00 8,507.70 -385.44 5,612.92 5,978,980.00 694,522.00 70°20'48.861 N 148°25 14.990 W -actual welipath misses target center by 14.65ft at 10623.00ft MD(8496.90 TVD,-387.48 N,5603.24 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 10,621.00 8,495.00 7" 7.000 8.500 10,162.00 8,062.04 9 5/8" 9.625 12.250 Checked By: Approved By: Date: 2/11/2010 10:45:59AM Page 8 COMPASS 2003.16 Build 71 f WE_LHEAD= F C JMD DRAF sAFE101,NOTES: ACTUATOR= BAKER C AG 1-01 A KB. ELEV = 49' BF. ELEV = i - - - KOP= 1851' X Max Angle= 48°@ 5893' —I 2205' Il7-5/8"X 7"XO, ID=6.276" I Datum MD= 2216' I-{7"CAMCO DB-6 NIP, ID=6.00" Datum TV D= 13-3/8"CSG,68#,K-55 XO TO NT-80 -1 122' 2227 H 7"X 7-5/8"XO, ID=6.276" I 13-3/8"CSG,68#, NT-80, ID=12.415" -1 3911' I-----I , Minimum ID = 5.770" @ 9965' 7" HES RN NIPPLE 9912' -17-5/8"X 7"XO, ID=6.276" I 7-5/8"IPC TBG,29.7#, L-80 VA TOP, —I 9912' .0459 bpf, ID=6.875" I 9924' I-1 7"HES R NIP, ID=5.963" I 9945' IH9-5/8"X 7"BKR S-3 PKR, ID=6.000" I VA- * 9965' H 7"HES RN NIP,ID=5.770" I 9980' -9-5/8"X 7"BKR HRD ZXP LTP w/BKR HMC LNR HGR,ID=6.276" 0 0 9986' H 7"MULE SHOE, ID=6.276" I 7"IPC TBG,26#, L-80 TCII, .0383 bpf, ID=6.276" JH 9986' Ilito 9-5/8"CSG,47#, L-80 HYD 563, ID=8.681" 10162' PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON 02/08/10 ANGLE AT TOP PERF: 20°@ 10220' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10220- 10430 0 03/01/10 3-3/8" 6 10465- 10496 0 '03/01/10 PBTD -) 10536' I ∎i4:441k 7"LNR,26#,L-80 VAM TOP HC, -I 10621' .0383 bpf, ID=6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/29/92 AUDI 2 ORIGINAL COMPLETION WELL: AGI-01A 02/12/10 D14 SIDETRACK(AGI-01A) PERMIT No:'2091640 02/14/10 TLH DRLG HO CORRECTIONS API No: 50-029-22307-01-00 03/17/10 JED/SV PERFS(03/01/10) SEC 36,T12N, R14E, 1583'FSL&2390'FEL 03/23/10 ?/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 10 * • 2 :CHANICAL INTEGRITY REPORT - ?UD DATT • : 3-1- 245/6 OPER & FIELD t zc. 4. RIG R FL E.5: . •_ 3/0-44° WELL NUMBER AI- 01 A WELL DATA TD : .2E).. TVD.; :BTD : MD T•FD 6/54 'Casing : 0+_....• Shoe :_:./.,Q= .2213) 06 ZTD ; Dv: -+ .17D 7`` _.1a€t : 7 Q! D Shoe : 1 DGZ hip 1•y9S TvD ; TOP : ,9°Ido MD 7�'�1/ �77D Tubing _71 Packer °j9YS2s 7r5,,TVD ; Set et Tole Size and ; Perfs - to . ISCP.ANlCAL IIITEGICITY - ?ART` 11 z-1 Z-'C• Aanui.us Fr.ese Test: _P 11066 s 15 min ; 30 min ✓ Comments : ` 30 n•t.... . sS' a1. rj)_ ale a►. z4 C l ?) MECHANICAL INTEGRITY -- PART #2 Cement Volumes r Amt. Liner 3Z. B8L S. Cs g _ - ; DV Cnt vol to cover per!s i.t.;� ..-0 . Theoretical TOC L.. 'her Co / C 4.1 Td e+. �� " -7? T C = moo 4 s,,,,f) '4.1 L.4...5-(r:- Cement Bond Loge or No) 451! ; In AOGCC File •LIDS CBL Evaluation, zone above perfs 4,/57/T o eoue�r_ 7 rhf�f'h2. . & Ca s''' - 7 Nnr �c)) }. çProdu .tion Log: Type NA ; Evaluation C SO-So C 3 q. • contusion : . p in 11 :......... M - L.t.� �, ( De- m > Zi o �L s. k le...-....„ ... '.e !So(..4._ d,L(2:-.e,„. Page 1 of 2 Schwartz, Guy L (DOA) From: Rose, John G (ASRC) [John.G.Rose @bp.com] Sent: Wednesday, May 05, 2010 10:09 AM To: Schwartz, Guy L(DOA) Cc: Tirpack, Robert B; Egbejimba, Uchenna J; Roach, Frank Subject: FW: AGI-01A USIT log ( PTD 209-164) Guy, As discussed today (5/5/10), please note the following comments in regards to your questions below: 1. There was no USIT log run on the 7" injection liner on this well as the cement job on this liner was not designed to provide"containment/isolation" to prevent gas migration to upper zones. However, a USIT log was run in the 9-5/8" casing from the top of the 7" liner lap at -9970' MD to 7400' MD on 2/10/10 which did indeed show"sufficient" cement for"containment/isolation" for the planned gas injection to the Sadlerochit. Other issues to note: a. The 9-5/8" casing string on this well was set just above (-10') the TSAD on this well. b. The initial design for this well and as are some of our existing gas cap injectors, this well was to have an un- cemented "slotted" 7" liner as precise zonal isolation within the Sadlerochit was not a critical design factor for this well. 2. The e-line perforation work on this well was done post-rig from 2/27/10 thru 2/29/10. 3. The pre-injection MIT-IA was done on this well on 3/8/10 (PASS to 2300 psi) and was witnessed by Chuck Sheave. 4. This well was put on gas injection on 3/4/10. If you have any question or concerns, please advise. -jr John G.Rose BPX-Staff Engineer Office 907/564-5271 Cell 907/748-5223 FAX 907/564-4040 Home 907/243-8813 From: Roach, Frank Sent:Tuesday, May 04, 2010 9:05 PM To: Rose, John G (ASRC) Subject: FW: AGI-01A USIT log ( PTD 209-164) John, Take a look at Guy's e-mail below. I missed this here. Regards, -Frank Roach 5/5/2010 Page 2 of 2 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, May 04, 2010 10:51 AM To: Roach, Frank Subject: FW: AGI-01A USIT log ( PTD 209-164) Frank, Just noticed on 407 the well has been perforated... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Tuesday, May 04, 2010 10:22 AM To: 'Roach, Frank' Subject: AGI-01A USIT log ( PTD 209-164) Frank, In looking at the 407 report and USIT log for AGI-01A I noticed that the 7" liner was not logged with the USIT. Did I miss something?? Deviation is not an issue and the 7" liner was set and cemented when the USIT was run. Also what is the current status of the well. Has it been perforated? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 5/5/2010 bp Date: 04-01-2010 0 Transmittal Number: 93138 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Joe Lastufka at (907)564-4091 Delivery Contents SW Name Contractor Description 03-37 HAL END OF WELL REPORT AGI-01A HAL END OF WELL REPORT Please Sign and Return one copy of this transmittal. RECEIVED Thank You, Joe Lastufka APP 0 2 NIP Petrotechnical Data Center ConocoPhillips Sandy Lemke Exxon File Room DNR Corazon Manaois AOGCC Christine Mahnken u7e_ aoc,i -/61/ ,`35- ( O o9 — /3i9 /95-63 17)-41tit/'— Petrotechnical Data Center LR2-1 900 E.Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,March 10,2010 TO: Jim Regg P.I.Supervisor �e C 4-111,-,I SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)[NC AGI-01 A FROM: Chuck Scheve PRUDHOE BAY UNIT AGI-01A Petroleum Inspector Src: Inspector Reviewed By: Supry NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT AGI-01A API Well Number: 50-029-22307-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS100308154925 Permit Number: 209-164-0 Inspection Date: 3/8/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGI-OlA Type Inj. j G ''TVD 7858 , IA 30 2300 2270 2270 P.T.D 2091640-/type I est SPT Test psi 1965 OA 1 240 280 240 240 Interval TAI- P/F P '- Tubing 3300 3300 3300 3300 Notes: Packer depth provided by operator. II Wednesday,March 10,2010 Page I of 1 E E ° o ° U d c c '5 0 m 0 m to � 4 m2 > O' a� N C Q= er m °a N r y C , Q _ •C T . m O L N R J V N d Y U � r 0 N y C C ( m Y rn An cr.)▪ Q Q (� Q e - (5 m Q 5. R O E O C O O r T 0 O ( G O O 0 U N < N a Z 0 J N m O O O O O O 0 0 0 0 0 0 0 0' 0 O p .-.- r N r' N O O O O.-1- 0 N C) O O O O O 0 0 O O O O O O O O O O O .- \4 f. 4... ' Pei il ii mii , I . A !I 0 ♦ ♦o .. � j ♦ a O. 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I J a 'T Q N Q 3 WELL LOG TRANSMITTAL To: State of Alaska February 24, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Data: AGI-01A AK-MW-0007054180 AGI-01A 2" x 5" MD GAMMA/RESISTIVITY Logs: 1 Color Log 50-029-22307-01 2" x 5" TVD GAMMA/RESISTIVITY Logs: 1 Color Log 50-029-22307-01 Digital Log Images &LWDG-formatted LIS Data w/verification listing; 1 CD Rom 50-029-22307-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 009--f& Office: 907-273-3536 Fax: 907-273-3535 / 6)&09 Bryan.Burinda@halliburton.com • , 7() Date: ,;, Signed: % / / Page 1 of 2 Schwartz, Guy L (DOA) From: Rose, John G (ASRC) [John.G.Rose @bp.com] Sent: Monday, February 08, 2010 4:09 PM To: Schwartz, Guy L(DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: BOP Test on AGI-01A(PTD2D9-1.64) Guy, To let you know how this worked out, we finished running and cementing the 9-5/8" intermediate casing 10,162' MD at 24:00 hours on 02/05/2010 and began our planned BOP test at 07:00 on 02/06/2010. If you have any question or concerns, please advise. Thanks -jr John G.Rose BPX-Staff Engineer Office 907/564-5271 Cell 907/748-5223 FAX 907/564-4040 Home 907/243-8813 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, February 03, 2010 4:37 PM To: Rose, John G (ASRC) Subject: RE: BOP Test on AGI-01A(PTD 209-164) John, Thanks for the update. I concur with your assessment and agree you should continue operations now without the full BOP test to allow getting the casing in the ground as soon as possible. Keep me posted on progress and we can adjust BOP timing based on what happens next. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Rose, John G (ASRC) [mailto:John.G.Rose @bp.com] Sent: Wednesday, February 03, 2010 4:33 PM To: Schwartz, Guy L (DOA) Cc: Hobbs, Greg S (ANC); NSU, ADW Drig Rig 14 Subject: BOP Test on AGI-01A(PTD 209-164) Guy, As discussed, please note the following operational details as they relate to the BOP testing requirements for the AGI-01A rotary sidetrack currently being drilled by Doyon-14: 1. Last BOP test date - 01/22/10 (NOTE: This test was done 8 days early so that we would have a full 2 week window to drill, case and cement the 2/8/2010 Page 2 of 2 12-1/4" hole from our sidetrack point at 3911' MD (just below the existing 13-3/8"casing) down to the base HRZ casing point at 10,180' MD which is the current TD of the well.) 2. Next BOP test date - 02/05/10 3. Operations Summary a. Kicked-off cement plug at 3911'MD on 1/26. b. TD the interval at 10,180' MD on 2/01. c. As of 16:00 hours on 2/03, tripping out of the hole with the 12-1/4"drilling assembly at 6300' MD. 4. Plan Forward a. Continue TOH with 12-1/4" BHA. b. LD BHA. c. Change rams to 9-5/8"and test. d. Run 9-5/8"casing to 10,180' MD. e. Cement casing with 1500'of 15.8 ppg G. The plan forward work as detailed above should take us to-17:00 hrs on 2/05 which should allow us to begin our 2 week BOP test before midnight on 2/05 as required. The purpose of this e-mail is to advise if any delays are encountered, the ability to initiate the BOP before the 24:00 hour deadline on 2/05 may be challenged with the only option to run a full BOP test prior to PU the casing, however, that would add an extra 6-8 hours with our hole open when we need to get in cased-off. If you have any questions or concerns, please advise and thanks for your consideration. -jr John G.Rose BPX-Staff Engineer Office 907/564-5271 Cell 907/748-5223 FAX 907/564-4040 Home 907,243-8813 2/8/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, February 03, 2010 4:37 PM To: 'Rose, John G (ASRC)' Subject: RE: BOP Test on AGI-01A pror2ositlity John, Thanks for the update. I concur with your assessment and agree you should continue operations now without the full BOP test to allow getting the casing in the ground as soon as possible. Keep me posted on progress and we can adjust BOP timing based on what happens next. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Rose,John G (ASRC) [mailto:John.G.Rose @bp.com] Sent: Wednesday, February 03, 2010 4:33 PM To: Schwartz, Guy L(DOA) Cc: Hobbs, Greg S (ANC); NSU, ADW DrIg Rig 14 Subject: BOP Test on AGI-01A(PTD 209-164) Guy, As discussed, please note the following operational details as they relate to the BOP testing requirements for the AGI-01A rotary sidetrack currently being drilled by Doyon-14: 1. Last BOP test date - 01/22/10 (NOTE: This test was done 8 days early so that we would have a full 2 week window to drill, case and cement the 12-1/4" hole from our sidetrack point at 3911' MD(just below the existing 13-3/8"casing)down to the base HRZ casing point at 10,180' MD which is the current TD of the well.) 2. Next BOP test date - 02/05/10 3. Operations Summary a. Kicked-off cement plug at 3911' MD on 1/26. b. TD the interval at 10,180' MD on 2/01. c. As of 16:00 hours on 2/03, tripping out of the hole with the 12-1/4" drilling assembly at 6300' MD. 4. Plan Forward a. Continue TOH with 12-1/4" BHA. b. LD BHA. c. Change rams to 9-5/8" and test. d. Run 9-5/8"casing to 10,180' MD. e. Cement casing with 1500'of 15.8 ppg G. The plan forward work as detailed above should take us to-17:00 hrs on 2/05 which should allow us to begin our 2 week BOP test before midnight on 2/05 as required. The purpose of this e-mail is to advise if any delays are encountered, the ability to initiate the BOP before the 24:00 hour deadline on 2/05 may be challenged with the only option to run a full BOP test prior to PU the casing, however, that would add an extra 6-8 hours with our hole open when we need to get in cased-off. If you have any questions or concerns, please advise and thanks for your consideration. -jr 2/3/2010 1/1/4 Page 2 of 2 John C.Rose BPX-Staff Engineer Office 907/564-5271 Cell 907/748-5223 FAX 907/564-4040 Home 907/243-8813 2/3/2010 AGI-01A(PTD 209-164)upde-q Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, January 08, 2010 10:12 AM To: 'Roach, Frank' Cc: 'greg.hobbs @bp.com' Subject: RE: AGI-01A(PTD 209-164) updates Frank, I concur with the changes below. Your BOP plan meets AAC 25.035 requirements as stated. As I understand from our conversation the well will be perforated with e-line after the rig moves. I assume you will have a TIW valve on 4.5" DP ready to go when you running the 7 5/8"tubing. The Blind rams are also in compliance with regulations. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Roach, Frank [mailto:Frank.Roach @bp.com] Sent: Thursday, January 07, 2010 5:00 PM To: Schwartz, Guy L(DOA) Cc: Hobbs, Greg S (ANC) Subject: AGI-01A(PTD 209-164) updates Mr Schwartz, Per our phone conversation this afternoon, a change in scope to AGI-01A sidetrack(PTD#: 209-164) has occurred and I wanted to fill you in on the changes that have been made. The 7"slotted liner will be changed to a 7" solid and cemented liner. The plan is to have 4-1/2"x 7"VBR in the BOP stack. These rams will be tested with a 7"test joint prior to running the liner. Perforating the 7" liner will be performed after the rig has left the well. Thus, we will be running completion in an unperforated well. The 7" liner and 9-5/8"casing will be tested to 4,000 psi prior to running tubing. As such, we will not be changing our upper rams to 7-5/8"fixed to run completion. Also, as a point of clarification, the original PTD request showed the rig would arrive with blind/shear rams in the BOP stack. The rig will arrive with blind rams which still keeps us in compliance with 20 AAC 25.035. If you have any questions, comments, or concerns, please give me a call (564-4373 office, 854-2321 mobile). Regards, -Frank Roach 1/8/2010 pro a©� -/(e. `-( Mud Program Intermediate Mud Properties: LSND 12-%" hole section Depth Interval Density(ppg) PV YP API FL HTHP FL MBT PH KOP-THRZ 9.2 10- 18 18-28 <6 N/C <18 9- 10 THRZ-12-W 10.1 12-22 18-28 4-6 <10.0 <20 9- 10 TD Production Mud Properties: FLOPRO SF Reservoir Drill-in Fluid I 8-W hole section Depth Interval Density(ppg) PV YP LSVR API Fl pH MBT 12-%"TD- 8.5-9.0 6-12 22-28 >20,000 6.0-8.0 9.0-9.5 <3 8-W'TD Logging Program 12-%" Intermediate: Sample Catchers-as required by Geology Drilling: Dir/GR/Res w/PWD Open Hole: None Cased Hole: CCL f/13-%"contingency whipstock set 8-%" Production: Sample Catchers-as required by Geology Drilling: Drilling BHA-Dir/GR Open Hole: None Cased Hole: None Cement Program Casing Size: 98"47#, L-80 Intermediate Casing Basis: Lead: NONE Tail: 1,500'of 9-%"x 12-W open hole with 30% excess, plus 80' shoe track. Total Cement Spacer 30 bbls of Viscosified Spacer weighted to 10.4 ppg (Mud Push II) Volume: Lead None Tail 114.6 bbls, 552.3 sxs 15.8 lb/gal Class G+ adds- 1.17 cuft/sk Temp BHST= 130° F, BHCT TBD by Schlumberger Casing Size: 7"/Jel Production Liner Basis: Lead: NONE Tail: 8-'/2'x 7"open hole volume(418' + plus 40%excess)+ 80'of 7"shoe track+ 150' of 9-%"x 7"annulus+200'of 9-%"x 5"annulus. Total Cement Spacer 25 bbls of Viscosified Spacer weighted to 12.5 ppg (Mud Push II) Volume: Lead None Tail 29.9 bbls, 144 sxs, 15.8 lb/gal Class G +adds- 1.17 cuft/sk Temp BHST- 133° F, BHCT TBD by Schlumberger n 1.419 1.419 Ce ,✓L 1 7(00' / Ii /finer (sold W I'(( 6e pef4 fu-S� 9 f° 0. rc 7 ri 5' it: U'j Li LPL LL L I 0 .--- LLASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 ( FAX (907) 276 -7542 Mr. Greg Hobbs Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, AGI -01A BP Exploration (Alaska) Inc. Permit No: 209 -164 Surface Location: 1583' FSL, 2390' FEL, SEC. 36, T12N, R14E, UM Bottomhole Location: 1195' FSL, 3222' FWL, SEC.31, T12N, R15E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to re -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) 659 -3607 (pager). Sincerely, �7 Daniel T. Seamount, Jr. Chair DATED this 4 - day of December, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMII0ION Fr: r F " PERMIT TO DRILL 20 AAC 25.005 1 8 2009 1 a. Type of work: lb. Proposed Well Class: ❑ Development Oil ❑ Service - Wini ❑ Single Zone 1 c. Specify if well i ro o , ,, i ssinn ❑ Drill ®Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ' a Coalb@r!'C 9 8 - s ❑ Re -Entry ❑ Exploratory ® Service - WAG ❑ Service - Disp f4; ' '` :Vele Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 AGI -01A 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 10636' TVD 8507' Prudhoe Bay Field / Prudhoe 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028301 & 034628 1583' FSL, 2390' FEL, SEC. 36, T12N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1208' FSL, 3072' FWL, SEC. 31, T12N, R15E, UM January 1, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1195' FSL, 3222' FWL, SEC. 31, T12N, R15E, UM 2560 11,500' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: —47.3' feet 15. Distance to Nearest Well Open Surface: x- 688901 y- 5979224 Zone- ASP4 GL Elevation above MSL: 13.4' feet to Same Pool: 300' 16. Deviated Wells: Kickoff Depth: 3915 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 46 degrees Downhole: 3339 Surface: 2527 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 12-1/4" 9 -5/8" 47# L -80 Hydril 563 10216' Surface Surface 10216' 8113' 379 sx Class 'G' 8-1/2" 7" 26# L -80 BTC -M 569' 10066 7972' 10635' 8507' lo„een're Slone I14 sk. (/ass G . /4- /4- 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10850' 8571' 10117' 10770' 850 None Casing Length Size Cement Volume MD TVD Conductor / Structural 75' 30" 11 vds Arcticset 75' 75' Surface 3871' 13 - 3/8" 1500 sx Permafrost 'E'. 400 sx Class 'G' 3911' 3487' Intermediate 10222' 9 -5/8" 375 sx Class 'G' 10260' 8082' Production Liner 709' 7" 170 sx Class 'G' 10141' - 10850' 7986' - 8571' Perforation Depth MD (ft): Below Plug: 10301' - 10763' Perforation Depth TVD (ft): 8115' - 8497' 20. Attachments: ❑ Property Plat ❑ BOP Sketch Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is . e and correct. Contact Frank Roach, 564 -4373 Printed Name Gre. .. Title Engineering Team Leader i / Prepared By Name/Number. Signature Phone 564 -4191 Date /2 / �/ / � '`h9 Terrie Hubble, 564 -4628 s Commission Use Only Permit To Drill API Number: Permi( P� Dot See cover letter for Number: e . 209/6 41 50- 029 - 22307 -01 -00 / 7 P / other re qu i rements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbe metha e, gas hydrates, or gas contained shales: ler Other: ���© ps` " 5� Samples Req'd: ❑ yes lid No Mud Log Req'd: ❑ yes QrNo ' - 2560 P si, A 11 _L4.. (c 5 (am.. +) H Measures: Yes ❑ No Directional Survey Req'd: Yes ❑ No C lv-e"A �k 1 1_,e_ . £ I (r re. �pc,c.Z'''GX Cf (! U 0 APPROVED BY THE COMMISSION Z. 7 Date COMMISSIONER 2 Form 1 01 e 07/ 009 , T,his permit�ispvalic�,fo 24 months from date of approval (20 AAC 25.005(g)) Submit In D licate i 'ti /z. td 07 ( 44 To: AOGCC, Chairperson • Alaska Oil & Gas Conservation Commission From: Frank Roach - ODE Date: December 17, 2009 bp Re: PBU AGI -01A Permit to Drill Approval is requested for the drilling of the AGI -01A Ivishak gas injector sidetrack. For the planned drilling of this well, a 12 - /a" intermediate hole will be drilled from a KOP below the 13-%" casing shoe at -3911' MD to below BHRZ at -10,216' MD where 9-%", 47.0# intermediate casing will run and cemented to -9,216' MD. An 8 - production hole will then be drilled to the final well TD at -10,635' MD where a 7 ", 26 #, slotted production liner will be run. The planned completion for this well will be a 7 -% ", 29.7 #, internally plastic coated, premium threaded tubing string with a permanent production packer and 7" tailpipe that will be stung in to the 7" slotted liner top. This well is currently scheduled for Doyon 14 beginning -01/01/10. Please refer to the additional data within this request for specific well details and do not hesitate to call if additional information is required. Frank Roach - ODE Office - 564 -4373 Cell - 244 -1674 AGI -01A Sidetrack Page 1 AA-01A Planned Well Summ ary v Well AGI -01A T ype Sidetrack Objective ve Ivishak tit API Number: 50- 029 - 22307 -9X Current Status Shut -In Estimated Start Date: 1- Jan -2010 Time to Complete: 29.7 Days Surface Northing Easting Offsets TRS Location 5,979,224 688,901 1583' FSL / 2390' FEL 12N, 14E, 36 Northing Easting TVDss Offsets TRS TSAD 5,978,989 694,372 -8066 1209' FSL / 1806' FEL 12N, 15E, 31 Bottom Northing Easting TVDss Offsets TRS Location 5,978,980 694,522 -8460 1195' FSL / 1656' FEL 12N, 15E, 31 • Planned KOP: 3915'MD / ' TVDss Planned TD: 10,636'MD / 8,460' TVDss Rig: Doyon 14 1 GL: 13.4' RTE: 47.3' Directional - Halliburton (Sperry) WP01 KOP: 1 3915' MD Maximum Hole Angle: -46 in the 12 -1/4" intermediate section -20 in the 8 -1/2" production section Close Approach Wells: 2 close approach issues with AGI -01 (plugged and abandoned). Minor risked. Survey Program: Standard MWD +IIFR +MS Nearest Property Line: 11,500' to Northern IPA Boundary Nearest Well within Pool: 300' to AGI -01 (plugged and abandoned) AGI -01A Sidetrack Page 2 • • Current Well Information Well Name: AGI -01 API Number: 50- 029 - 22307 -00 PTD: 1921240 Well Type: Gas Injector Current Status: Shut in BHP: 3,617 psi ( 8,800' TVDss (7.9 ppg) BHT: 137° F @ 8,800' TVDss Mechanical Condition: Tubing: See current schematic for detail. Tubing of interest is 7 ", 26 #, L -80, IPC, NSCC to 10,041' (pre -rig tubing cut at -7,150' MD.) TD / PBTD: 10,129' MD / P &A to -10,007' MD during pre -rig P &A work Max Dogleg (to P &A): 6.9 °/100' @ 1,920' MD Max Angle (to P &A): 46° @ 3,478' MD Wellhead Equipment: FMC New Standard Big Bore Starting Head: 13-%" 5000 psi with 2- / outlet valve Tbg. Spool: 13-%" 5000 psi x 13-%" 5000 psi Tbg. Hanger: 12" x 7" NSCC w/7" NSCC (box) lifting threads Csg. Hanger: 9 -%" landed on hanger Tbg. Head Adapter: 13 -%" 5K x 7 - 5K Tree: FMC 7" bore x 7 - flange w/7" tree cap BPV Profile: Cameron 7" Type J Completion Equipment: SSSV Landing Nipple: 7" Camco BaI -O SVLN SSSV nipple Control line: 2 - .25" Stainless Gas Lift Mandrels: None Control line bands /clamps: 46 control line protectors Casing Equipment: Surface Casing: 13-%", 72 #, L -80 to 3911' MD 13 -3/8" Cement: cement to surface Intermediate Casing: 9 -% ", 47 #, L -80 to 10,260' MD 9 -5/8" Cement: Pumped 75 bbls of Class G cmt (-1345' of gauge hole = TOC at 8,915' MD) Tubing Fluids: seawater w /2000' diesel cap (confirm during pre -rig prep) IA Fluids seawater w /2000' diesel cap (confirm during pre -rig prep) OA Freeze Protection 13-%" x 9-%" pumped 175 bbls of mud down annulus to confirm open shoe - 90 bbls diesel (1,500') Perforations: P &A'ed w /cement tested to 2500 psi (TOC tag during pre -rig prep) Pre -Rig MIT Data: MIT -OA CMIT -TxIA PPPOT -T PPPOT -IC AGI -01A Sidetrack Page 3 Formation Markers AS01 A (Based on SOR) • Commercial Hydrocarbon Est. Formation Tops Uncertainty Bearing Est. Pore Press. Formation (TVDss) (feet) (Yes /No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells SV5 -3175 SV4 -3444 SV3 -3844 SV2 -4012 SV1 -4430 UG4 -4892 UG3 -5218 UG1 -5667 WS2 -6294 WS1 -6445 CM3 -6574 CM2 -7031 CM1 -7475 THRZ -7854 BHRZ -8051 LCU/TSAD -8066 Yes TCGL -8124 - Yes 3400 psi BCGL -8185 Yes TZ1B -8390 20 Yes BSAD -8460 20 No Casing/Tubing Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MDJTVD MD/TVD O.D. 12 -'/4" 9 -%" 47# L -80 Hydril 6,870 4,760 10,216' Surface 10,216' / 563 8,113' , 10066'/ 10,635' / 8 -1" 7" 26# L -80 BTC -M 7,240 5,410 569' 7, 8,507 10,066' / Tubing 7-%" 29.7# IPC vaHC op 6,890 4,790 10,066' surface 7,972' AGI -01A Sidetrack Page 4 Mud Program Intermediate Mud Properties: LSND 1 12 -1/4" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH KOP — THRZ 9.2 10-18 18 -28 < 6 N/C <18 9 — 10 THRZ — 12 -' /a" 10.1 12 — 22 18 - 28 4 — 6 <10.0 <20 9 — 10 TD Production Mud Properties: FLOPRO SF Reservoir Drill -in Fluid 1 8 -1/2" hole section Depth Interval Density (ppg) PV YP LSVR API Fl pH MBT 12 -1/4" TD — 8.5 — 9.0 6 -12 22 -28 >20,000 6.0 -8.0 9.0 -9.5 < 3 8 -'/2" TD Logging Program 12 -3/4" Intermediate: Sample Catchers — as required by Geology Drilling: Dir /GR/Res w /PWD Open Hole: None Cased Hole: CCL f/13- contingency whipstock set 8 -'/2" Production: Sample Catchers — as required by Geology Drilling: Drilling BHA — Dir /GR Open Hole: None Cased Hole: None Cement Program Casing Size: 9 -%" 47 #, L -80 Intermediate Casing Basis: Lead: NONE Tail: 1,000' of 9 -%" x 12 -1/4" open hole with 30% excess, plus 80' shoe track. Total Cement Spacer 30 bbls of Viscosified Spacer weighted to 10.4 ppg (Mud Push 11) Volume: Lead None Tail 78.4 bbls, 379 sxs 15.8 lb/gal Class G + adds —1.16 cuft/sk Temp BHST ~- 130° F, BHCT TBD by Schlumberger Casing Size: 7" Slotted Production Liner `\ b � w' Basis: Lead: NONE i _ ma t Tail: NONE v ,, o.}— ,„'' 1 ` Total Cement S° Volume: Spacer None ' Cep Lead None Tail None Temp SUPERCEDED AGI -01A Sidetrack Page 5 Well Control • Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind /shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. BOP regular test frequency for AGI -01A will be 14 days during drilling phase and 7 days during decompletion work. Intermediate Interval Maximum anticipated BHP 2518 psi @ 5270' TVDss — UG1 (9.2 ppg EMW) Maximum surface pressure 1992 psi (.10 psi /ft gas gradient to surface) Planned BOP test pressure Rams test to 4,000 psi /250 psi. Annular test to 3,500 psi /250 psi 13 - Casing Test 3500 psi surface pressure FIT to 11.9 ppg after drilling 20' from mid - window to satisfy ECD Integrity Test — 8 -1/2" hole management concerns, however, a minimum 11.3 ppg FIT provides 159.8 bbls kick tolerance w/10.1 ppg mud in the hole. 9- Casing The VBR's will be changed to 9 -%" rams to accommodate the 9-%" e / casing. Production Interval Maximum anticipated BHP 3339 psi @ 8124' TVDss — TSAD (7.9 ppg EMW) Maximum surface pressure 2527 psi (.10 psi /ft gas gradient to surface) Planned BOP test pressure Rams test to 4,000 psi /250 psi. Annular test to 3,500 psi /250 psi 9 - /e" casing / 7" Liner Test 4000 psi surface pressure Integrity Test — 6 -' /8" hole FIT to 9.5 ppg after drilling 20' of new hole to satisfy ECD management concerns, however, 8.5 ppg mud in the hole will provide an "infinite" kick tolerance. 7" SLOTTED liner The VBR's will NOT be changed to 7" fixed rams. Instead, a crossover sub (7" BTC -M to DP thread) will be made up to a joint of 5" drillpipe and D a TIW valve (valve in the open position and the valve key easily o 1 accessable) will be made up on top of the drillpipe. This assembly will beyt' placed in the mousehole, ready to be deployed. If the well starts to flow, 1 the assembly will be made up to the liner and RIH to where the drillpipe is across the BOP stack. The rams and /or annular will be closed on the drillpipe and then the TIW valve will be closed. Planned completion fluids 8.5 ppg Seawater / 6.8 ppg Diesel Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class 11 wastes to DS -04 for injection. Haul Class I waste to DS -04 and /or Pad 3 for disposal / Contact the GPB Environmental Advisors (659 -5893) f /guidance. Fault Prognosis • There are no planned fault crossings in this wellplan. AGI -01A Sidetrack Page 6 AGI - 01 A Operations Summary Pre -rig prep work: W 1 Function tubing and casing LDS. Repair /replace as required. Perform PPPOT -IC to 3,500psi and PPPOT -T to 5,000psi. S 2 Pull PXN prong and plug body from XN nipple at 10,117'. -- S 3 Run a static bottomhole pressure and temperature survey for determining MW needed for • sidetrack operations and BHST for cement testing. C' 4 P &A existing perforations through coil and 5 - cement retainer with 32.1 bbl (Obbl excess), 15.8ppg G cement: Liner Size 26.0# 7" (.03830 bpf) from 10,141' to 10,770' MD Casing size (Lnr top to WLEG) 47.0# 9-%" (.07320 bpf) from 10,129' to 10,141' MD Tubing size (WLEG to retainer) 17.0# 5 -'/2" (.02320 bpf) from 10,082' to 10,129' MD Annular size (WLEG to packer) 47.0# 9-%"x5- (.04380 bpf) from 10,129' to 10,049' MD Bottom of plug 10,850' MD Top of retainer 10,082' MD Total Footage to retainer 688' ( -29.6 bbls), Cement on top of retainer 75' ( -2.5 bbls) • Top Pert 10,301' MD Bottom Perf 10,763' MD SBHP and SBHT to be determined by static survey from step 3. S 5 WOC. Drift to TOC. F 6 CMIT -T to 2,500 psi for 30 min. Notify State inspector for witness. Pressure test is required for competent barrier for rig operations. If test fails, contact ODE. Freeze" Protect as necessary. E/F 7 Punch tubing above 5 -'/2" x 7" crossover at -10,020' MD (bottom of first full joint of 7" tubing) and circulate tubing and IA to clean 9.8 ppg brine. 'Power Jet cut 7" tubing at -7,150' MD (try to get cut -2' below a coupling to help with standoff from the intermediate casing). Establish circulation from the T to the IA. F 8 Attempt CMIT TxIA to 500 psi and establish LLR (LLR 11 gpm @ 500 psi on 8/24/09). MIT - OA to 2,000 psi. If combo doesn't track LLR from 8/24, contact ODE. D 9 Bleed casing and annulus pressures to zero. ✓ 10 Set a BPV. Remove well house and flow line. Level pad as necessary. Proposed Drilling Rig Operations: 1. MI /RU. 2. CMIT -TxIA rolling to 500 psi and MIT -OA to 2,000 psi to confirm barriers (10 minute tests - expect MIT -OA to pass). 3. Pull BPV w /tested lubricator and circulate out diesel freeze protection and displace the well to seawater. 4. Set and test TWC to 500 psi rolling test from below and 4,000 psi from above for 10 minutes. 5. Nipple down tree. Nipple up and test BOPE to 4,000psi. Pull TWC w /tested lubricator. 6. R/U & pull 7" tubing from the cut depth at 7,150' MD. 7. Test lower set of rams if required. 8. PU drill -pipe and make bit and scraper run to the top of the tubing stub. 9. RU E -line and RIH w /USIT log to confirm no cement behind pipe at desired cut depth. 10. RIH w /CIBP and CCL and set the CIBP at -4,100' MD and test well to 4,000 psi for 10 minutes. 11. RIH and cut 9 -%" casing -75' below surface casing shoe (cut at -3,985' MD) and circulate through cut. If unable to circulate, cut casing just inside surface casing and establish circulation. 12. Spear hanger and pull casing to floor. 13. RIH w/ open -ended drillpipe and set 17# kickoff plug on top of CIBP. Bring plug -300' inside 13-%" surface casing. WOC until desired compressive strength reached. Pressure test to 3,500 psi. 9 (End Work Under Sundry Approval #xxx -xxx / Begin Work Under PTD #xxx -xxx) "Iw r r° AGI -01 A Sidetrack Page 7 14. M/U 12 -1/4" Dir /GR/Res //D assembly. RIH, control drill to kick "of plug and 20' of new hole beyond cement. Circulate wellbore clean 15. Pull up into casing and conduct LOT. 16. Run back to bottom and drill the 12 -1/4" intermediate section to the TD target per directional plan. 17. Circulate, short trip and POOH to run the 9 -%" intermediate casing (manage drill -pipe as required). 18. Run and cement a 9 -% ", 47.0 #, L -80, Hydril 563 intermediate casing. TOC 1,000' above casing shoe. 19. After cement has reached a minimum 500 psi compressive strength, test the 9 -%" casing to 4,000psi for 30 minutes and record the test. Lod, �- 20. M/U 8 -1/2" drilling assembly w /Dir /GR + insert bit to drill -out the shoe track, displace to the well to the planned drill -in fluid, drill 20' of new hole and run FIT. 21. Drill ahead per the directional plan to TD. 22. Circulate, short trip, spot liner running pill. POOH to run the production liner. 23. Run and set 7 ", 26 #, BTC -M, slotted production liner. * *NOTE: Due to running 7" slotted pipe, rams will not be changed to 7" casing rams. There will be a joint of 5" drilipipe with a DP to 7" BTC- I<- M crossover on bottom and TIW valve on top (TIW valve in open position with valve key ready to use). In the event the BOP stack would need to be used, the crossover joint would be made up to the liner, run in hole to where the drilipipe joint is across the BOP stack, and the pipe rams closed on that joint of drilipipe. ��1 24. POOH L/D all drill pipe. . 5"" 'z -z io i 25. R/U and run 7 -% ", 29.7 #, L -80, VamTop HC, IPC completion tubing. 6 - �� .�, 26. Land the tubing RILDS. 27. Reverse the well to clean seawater to include inhibited seawater to the production packer depth per the plan. Chase corrosion inhibited fluid with diesel freeze protect. 28. Drop ball & rod. Set packer and individually test the tubing and annulus to 4,000psi 30 minutes and record each test. * *Notify state inspector 24 hrs before test for opportunity to witness ** 29. Set a TWC and test to 1,000 psi from above. 30. Nipple down the BOPE. Nipple up the tree and test to 5,000psi with diesel (new adapter flange required). 31. Pull TWC w /lubricator. 32. RU slickline and retrieve ball & rod. 33. Freeze protect tubing with diesel. 34. Install BPV and secure the well. 35. RDMO. Post -Rig Operations: (S -Riser Modification will be Required) 1. MI / RU slick line. 2. Pull the ball and rod / RHC plug from landing nipple below the production packer. 3. Install injection safety valve. 4. Install well house and instrumentation. AGI -01A Sidetrack Page 8 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under - pressured at 7.9 ppg EMW. This pressure is estimated based on offset well pressures and should be confirmed from the pre -rig bottom hole pressure survey. II. Lost Circulation/Breathing A. For the 12 - /a" intermediate hole, the lost circulation /breathing potential should be minimized due to the relative low mud weight which will be used to drill this interval of the well (10.1 ppg f /top HRZ). However, given the potential for a "weak" zone within the Colville to be present below the KOP, lost circulation /breathing problems must be considered a possibility. B. As for the production interval of the well, lost circulation in the Ivishak formation is usually fault related and as there are no planned faults through this interval of the well, the lost circulation potential while drilling this interval of the well has been rated "low". Please refer to the MI mud program for details as they relate to dealing with lost circulation problems while drilling this interval of the well. III. Kick Tolerance/Integrity Testing Test Point Test Depth Test type EMW (lb/gal) 13 -%" window 20 -ft minimum from the 9-%" window LOT 11.3 ppg min f /KT 11.9 ppg max f /ECD Mgt 9 -%" shoe 20 -ft minimum from the 7" shoe FIT Infinite w/ 8.5ppg mud 9.5 ppg max f /ECD Mgt IV. Stuck Pipe A. For the 12 - /a" intermediate interval of the well, insufficient/poor hole cleaning support resulting in stuck pipe will be of primary concern. B. For the 8 -' /2" production interval of the well, both differential sticking and sticking as associated with insufficient/poor hole cleaning should be of primary concern. VI. Hydrogen Sulfide A. AGI is not designated as an H2S site since samples are not taken on the pad, however Standard Operating Procedures for H2S precautions should be followed at all times. VII. Faults A. There are no visible fault crossings associated with this wellplan /directional plan. VIII. Anti - Collision Issues • Close approach wells: AGI -01 fails major risk scan in two areas along the planned new wellpath. AGI -01 does pass a minor risk scan since the well will be plugged and abandoned before the rig moves in for the sidetrack CONSULT THE DS -AGI DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION AGI -01A Sidetrack Page 9 bp CASING DETAILS WELL DETAILS: AGI -01 TVD MD Name Size Ground Level: 13.40 HALLIBURTON 8113.70 10216.45 95/8" 9.625 +N / -S +E / -W Northing Easting Latittude Longitude Slot 10799.40 7" 7.000 0.00 0.00 5979223.98 688901.77 70° 20' 52.674 N148° 27' 58.989 W 01 j . y Sperry Drilling Services SURVEY PROGRAM ANTI - COLLISION SETTINGS COMPANY DETAILS: North America -ALASKA-BP Date 2009- 12- 15T00:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.00 NORTH AMERICA Depth Range From: 3887.10 To 10635.74 ALASKA To Depth From Depth Survey/Plan /Plan Tool Results Limited By: Centre Distance: 1260.14 Calculation Method: Minimum Curvature P P Y Reference: Plan: AGI- 01A wp02 (AGI -01 /Plan AGI -01A Error System: ISCWSA 48.80 3887.10 2 : Schlumberger GCT multishot (AGI -01) GCT -MS Scan Method: Tray. Cylinder North 3887.10 10635.74 AGI- 01Awp02 (Plan AGI-01A) MWD +IFR +MS Error Surface: Elliptical Conic Warning Method: Rules Based 0 i 330 , �-� - 1_ --- ---�_ � 30 0 ,\' , \ -- -1- - - - -L � �1 GG GI -01 /AGI -01 i' \ V - -. _ 21 1 - - 330 - 1 - -1 1 -- ia71 .... / - - - \ \ From Colour To M) v ' i ' 1 _ ` /�` • , > �' .. ., \ v ,yam r" ` ( \i \ \� \. , y 300 � �'I / � _� 1 \ • \ \, r \ \ - ., - /.„. , , \ , \ \ ,.., .< \ \ : / /j : ,, / l i; r , / , v / , - ; . < \ \ \ \ \ \-< - 7 l l / ' , l / i\ \ \ 1 1 1 1 1 1 1 I • I , / y / / , ,- v ;- v t t t 270 Al ma ,,,,,, I . 1 , -7 , , • • v ' A A v y - 1 1 1 1 ! ! I JJ'�f�/ I ! ! / / / , r1 - 1 1 \ \ ' , / / / L / ''A. "I1;' I 1 ! / ! I 1 / 1 / / / • \ \ \ \ \ t \ 1 1 1 1 1 1 - I 1 \ \ \ \ \ _ - / , I ! • �Q�� I I I I 1 1 I v t v v \ �'v i OQ I I I I I / / 1 AGI -01 /AGI -01 a'\ \ \ A • • • , / / /7.4,4. L . IN �i I I I I I I I I I 1 / i \ \ , �\ • • • • • T �\ ' , / / / 4 , / 270 ►�IY�i 90 h - /` / �e t + Q� � � �l h { 1 1 I 1 I I l \ 1 \ 1\ I ! I I I I I � I I 240 \ \ , \ > \ \ f - .. , _ - - ; _, '\ / / 120 i f � / < ` / I / a . -- ' ( I 'r ♦ , '1 A 1 \ \ \ \ \ \ \ \ \ \ \ \ ' i / / (/ / I / I / I ! I I I ! '� \ I \ _ f - - T _ .. - '(- i\ i 1 ' { ' I \ \ \ \ \ \ \ \ \ \)\ \ \ \ \ , ', ,' /' /` /' Al , / / / l /! I ! . r \ � , - 1 - - - T -- < -�' 4 ` �-\ \ \\ \ '\ \ ,' ,_- _, �, //, / /, ..../ �I / 210 r - - - r 150 • �'�� \ \ \\ a \\ •\',`,',,. 1rr ,t ,'' / // /`,; , / / ,/ 180 \ \ ♦ \\\\\,', - - ' ' ' ' / / / 240 • • • \ n / , / 120 "•\•\\,;•,,, ` T„ -- __ - ' ,.< ' , /, A T 4 , i ? .� /. '<' /' � ti - , -c }� s) - , - 1 . 7 _ T \' SECTION DETAILS 210 /� , 7 - _ _ 1 - 150 Sec MD Inc Azi ND +N / -S +E / -W DLeg TFace VSec Target 1 3887.10 44.10 89.20 3469.78 -54.92 1271.31 0.00 0.00 1272.08 r I , - 2 3909.70 44.02 89.51 3486.03 -54.74 1287.02 1.02 110.47 1287.75 3 4229.70 44.59 100.94 3715.39 -75.15 1508.85 2.50 90.00 1510.46 180 4 4431.40 45.96 94.11 3857.40 -93.80 1650.78 2.50 -76.68 1653.32 5 8797.07 45.96 94.11 6892.10 - 318.76 4781.13 0.00 0.00 4791.73 6 9835.74 20.00 95.00 7755.95 - 361.74 5340.06 2.50 179.31 5352.29 7 10635.74 20.00 95.00 8507.70 - 385.59 5612.63 0.00 0.00 5625.86 AGI -01A Target Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [100 ft/in] Project: Prudhoe Bay (various) REFERENCE INFORMATION Site: AM H ALLIBURTON Co- ordinate (N /E) Reference: Well AGI -01, True North Well: AGI -01 Vertical (TVD) Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) M easured Depth Reference: D -14 RKB 13.4 +34,3KB @ 47.7ft (D -14) Welibore: Plan AGI-OIA Sperry Drilling Services . Calculation Method: Minimum Curvature Plan: AGI -01A wp02 WELL DETAILS: AGI -01 Ground Level: 13.4 +W -S +E/ -W Northing Easting Latittude Longitude Slot SECTION DETAILS 0.0 0.0 5979223.82 688901.48 70° 20 52.673 N148° 27' 58.998 W Sec MD Inc Azi ND +W -S +E/ -W DLeg TFace VSec Target SURVEY PROGRAM 1 3887.1 44.10 89.20 3469.8 -54.9 1271.3 0.00 0.00 1272.1 COMPANY DETAILS: BP - Alaska 2 3909.7 44.02 89.51 3486.0 -54.7 1287.0 1.02 110.47 1287.7 NORTH AMERICA Date: 2009- 12- 15T00:00:00 Validated: Yes Version: 3 4229.7 44.59 100.94 3715.4 -75.1 1508.9 2.50 90.00 1510.5 ALASKA Depth From Depth To Survey /Plan Tool 4 4431.5 45.97 94.11 3857.5 -93.8 1650.9 2.50 -76.66 1653.4 48.8 3887.1 2 : Schlumberger GCT multishot (AGI -01) GCT -MS 5 8797.2 45.97 94.11 6892.0 -318.6 4781.3 0.00 0.00 4791.9 Calculation Method: Minimum Curvature 3887.1 10635.9 AG-01A -01A) MWD +IFR +MS 6 9835.9 20.00 95.00 7755.9 -361.6 5340.3 2.50 179.30 5352.6 Error System: ISCWSA 7 10635.9 20.00 95.00 8507.7 -385.4 5612.9 0.00 0.00 5626.1 AGI -01A T1 Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 1920- CASING DETAILS • WELLBORE TARGET DETAILS (MAP CO- ORDINATES) ND MD Name Size Name TVD +N/ -S +E/ -W Northing Easting Shape 3486.0 3909.7 13 3/8" 13 -3/8 1680- 8113.7 10216.7 9 5/8" 9 -5/8 AGI -01A T1 8507.7 - 385.4 5612.9 5978980.00 694522.00 Circle (Radius: 100.1) 8507.7 10635.9 7" 7 1440 - 1200 - - 3887.1 MD, Tie -on Survey 960 I Total Depth : 10635.9' MD, 8507.7' TVD 1 KOP, Start Dir 2.5° /100' : 3909.7' MD, 3486TVD F. I • - / I I O 720- 1 / ' o -_ / End Dir : 4431.5' MD, 3857.5' TVD End Dir : 9835.9' MD, 7755.9' TVD \ I \ 1 480 I / Start Dir 2.5° /100' : 8797.2' MD, 6892TVD \\ i I / / '' I / / ' 7 1 2ao- 0 - ■ / ' I r n - 0 0 \ M O 1 I M / 0 O 7 I I 0- / 1/ / o 0 0 O \ I i : o o o \ \O o I AGI -01 /AGI -01 - I - _ • O I / 0 y., / 240 - 1 ` / 13 3/8" \ r -480- .. /"'' - 95% cont.. 9 5/8" 7,, AGI - 01A TI - -720- 1 I 1 -960- AGI -01 /AGI -01A wp02 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I l I i I I i I i Ii I I I I I I I I I T I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 720 960 1200 1440 1680 1920 2160 2400 2640 2880 3120 3360 3600 3840 4080 4320 4560 4800 5040 5280 5520 5760 6000 6240 West( -) /East( +) (600 ft/in) Project: Prudhoe Bay (various) REFERENCE INFORMATION SURVEY PROGRAM Site: AGI Co-ordinate (N /E) Reference: Well AGI -01, True North Date: 2009- 12- 15T00:00:00 Validated: Yes Version: Well: AG! -01 Vertical (TVD) Reference: D -14 RKB 13.4 +34.3KB @ 47.Th (D -14; We!lbore: Plan AGI -01A Measured Depth Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14 Depth FromDepth To Survey /Plan Tool . Plan: AG! -01A Wp02 Calculation Method: Minimum Curvature 48.8 3887.1 2 : Schlumberger GCT multishot (AGI -01) GCT -MS 3887.1 10635.9 AGI- 01Awp02 (Ran AGI -01A) MMVD +IFR +MS • HALLIBURTON WELL DETAILS: AGI -01 Grcurid Level: 13.4 Sperry Drilling Services +N / -S +E/ -W Northing Easting Latittude Longitude Slot 3000- 0.0 0.0 5979223.82 688901.48 70° 20' 52.673 N 148° 27' 58.998 W _ 3887.1 MD, Tie -on Survey WELLBORE TARGET DETAILS (MAP CO-ORDINATES) 3500- - - KOP, Start Dir 2.5 °/100' : 3909.7' MD, 3486'TVD Name TVD +N / -S +E/-W Northing Easting Shape ' ' AGI -01A T1 8507.7 -385.4 5612.9 5978980.00 694522.00 Circle (Radius: 100.0) 13 3 /8" ,' End Dir : 4431.5' MD, 3857.5' TVD SV4 4000- SECTION DETAJLS SV3 Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target - SV2 1 3887.1 44.10 89.20 3469.8 -549 1271.3 0.00 0.00 1272.1 4500- 2 3909.7 44.02 89.51 3486.0 -547 1287.0 1.02 110.47 1287.7 - 3 4229.7 44.59 100.94 3715.4 -75.1 1508.9 2.50 90.00 1510.5 SV1 \ 4 4431.5 45.97 94.11 3857.5 -93.8 1650.9 2.50 -76.66 1653.4 5 8797.2 45.97 94.11 6892.0 -318.6 4781.3 0.00 0.00 4791.9 6 9835.9 20.00 95.00 7755.9 -361.6 5340.3 2.50 179.30 5352.6 5000- _ - - - \ 7 10635.9 20.00 95.00 8507.7 -385.4 5612.9 0.00 0.00 5626.1 AGI -01A T1 UG4 C - UG3 CASING DETAILS o 5500- - TVD MD Name Size o 3486.0 3909.7 13 3/8" 13-3/8 �- = U G 1 - - - DDI =5.87 ERE) = .66 8113.7 10216.7 9 5/8" 9 -5/8 >_ a 8507.7 10635.9 7" 7 • 6000 - C) _ -0 FORMATION TOP DETAILS a WS2- - - - - - Start Dir 2.5 °/100' : 8797.2' MD, 6892'TVD TVDPath MDPath Formation • 6500- 3222.7 3539.8 SV5 - , - -. 3491.7 3917.6 SV4 - - 3891.7 4480.7 SV3 - W S 1 - - ' 4059.7 4722.4 SV2 - 4477.7 5323.8 SV1 7000- CM3 4939.7 5988.5 5265.7 6457.5 CM2 - End Dir : 9835.9' MD, 7755.9' TVD 5714.7 7103.4 U 6341.7 8005.4 WS2 CM1 _ _ - 6492.7 8222.7 WS1 7500- 6621.7 8408.3 CM3 THRZ Total Depth : 10635.9' MD, 8507.7' TVD 7078.7 9051.7 CM2 - _ ■ 7522.7 9582.1 CM1 BHRZ - - , ' 7901.7 9991.0 THRZ 8098.7 10200.7 BHRZ 8000- LCU /TSAD_ _ _ _ _ _. 8113.7 10216.7 LCU/TSAD 8171.7 10278.4 TCGL 9 5/8 "" " - 8232.7 10343.3 BCGL 1 - 8437.7 10561.4 TZ1B 8500- TCGL Vii' AGI -01 /AGI -01 8507.7 10635.9 BSAD BCGL -', ' COMPANY DETAILS: BP - Alaska - TZ1B T . BSAD . AGI -01 /AGI -01A wp02 NORTH AMERICA � 9000- 7 AGI -01A T1 ALASKA i i i I I i i i I I I I i i I I I I I I I I I I I I i I I I I I I I I I calculation Method: Minimum Curvature 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 Error System: ISCWSA Scan Method: Tray. Cylinder North Vertical Section at 93.94° (1000 Win) Error Surface: Elliptical Conic Warning Method: Rules Based • Halliburton Company HALL1BURTO Standard Proposal Report Database: ..Sperry EDM Prod .161 Local Co- ordinate Reference: Well AGI -01 Company: BP - Alaska TVD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Project: Prudhoe Bay (various) MD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Site: AGI North Reference: True Well: AGI -01 Survey Calculation Method: Minimum Curvature Welibore: Plan AGI -01A Design: AGI -01A wp02 Project Prudhoe Bay (various) Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site AGI, TR -12 -14 Site Position: Northing: 5,973,288.42ft Latitude: 70° 19' 55.268 N From: Map Easting: 685,006.87ft Longitude: 148° 29' 57.054 W Position Uncertainty: 0.0 ft Slot Radius: 0" Grid Convergence: 1.41 ° Well AGI -01, AGI -01 Well Position +NI -S 0.0 ft Northing: 5,979,223.82 ft Latitude: 70° 20' 52.673 N +E / -W 0.0 ft Easting: 688,901.48 ft Longitude: 148° 27' 58.998 W Position Uncertainty 0.0 ft Wellhead Elevation: 0.0 ft Ground Level: 13.4ft Welibore Plan AGI -01A Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) ( °) (nT) BGGM2008 10/6/2009 22.63 80.97 57,736 Design AGI -01A wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 3,887.1 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) r) 34.7 0.0 0.0 93.94 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/ -W Rate Rate Rate Tool Face (ft) ( °) ( °) (ft) ft (ft) (ft) 0100ft) ( 1100ft) ( °1100ft) ( °) 3,887.1 44.10 89.20 3,469.8 3,422.1 -54.9 1,271.3 0.00 0.00 0.00 0.00 3,909.7 44.02 89.51 3,486.0 3,438.3 -54.7 1,287.0 1.02 -0.35 1.37 110.47 4,229.7 44.59 100.94 3,715.4 3,667.7 -75.1 1,508.9 2.50 0.18 3.57 90.00 4,431.5 45.97 94.11 3,857.5 3,809.8 -93.8 1,650.9 2.50 0.68 -3.39 -76.66 8,797.2 45.97 94.11 6,892.0 6,844.3 -318.6 4,781.3 0.00 0.00 0.00 0.00 9,835.9 20.00 95.00 7,755.9 7,708.2 -361.6 5,340.3 2.50 -2.50 0.09 179.30 10,635.9 20.00 95.00 8,507.7 8,460.0 -385.4 5,612.9 0.00 0.00 0.00 0.00 12/15/2009 3:38:53PM Page 2 COMPASS 2003.16 Build 71 HALLI8URTOS • Halliburton Report Company Database: ..Sperry EDM Prod .161 Local Co- ordinate Reference: Well AGI -01 Company: BP - Alaska TVD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Project: Prudhoe Bay (various) MD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Site: AGI North Reference: True Well: AGI -01 Survey Calculation Method: Minimum Curvature Wellbore: Plan AGI -01A Design: AGI- 01Awp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/ -W Northing Easting DLS Vert Section (ft) (°) ( °) (ft) ft (ft) (ft) (ft) (ft) 52.30 100.0 0.20 236.32 100.0 52.3 0.0 -0.2 5,979,223.81 688,901.29 0.00 -0.19 200.0 0.25 103.42 200.0 152.3 -0.3 -0.1 5,979,223.55 688,901.36 0.41 -0.10 300.0 0.30 45.64 300.0 252.3 -0.1 0.3 5,979,223.72 688,901.83 0.27 0.35 400.0 0.34 340.39 400.0 352.3 0.4 0.5 5,979,224.19 688,902.00 0.34 0.51 500.0 0.30 276.21 500.0 452.3 0.6 0.1 5,979,224.46 688,901.56 0.34 0.06 600.0 0.13 359.70 600.0 552.3 0.7 -0.3 5,979,224.49 688,901.15 0.31 -0.36 700.0 0.50 322.34 700.0 652.3 1.3 -0.5 5,979,225.07 688,900.99 0.40 -0.55 800.0 0.60 264.50 800.0 752.3 1.6 -1.3 5,979,225.35 688,900.10 0.54 -1.44 900.0 0.47 317.06 900.0 852.3 1.7 -2.2 5,979,225.46 688,899.27 0.49 -2.27 1,000.0 0.70 138.02 1,000.0 952.3 1.7 -2.3 5,979,225.44 688,899.17 1.17 -2.38 1,100.0 2.25 112.58 1,099.9 1,052.2 0.5 0.0 5,979,224.29 688,901.52 1.65 0.01 1,200.0 3.55 106.59 1,199.8 1,152.1 -1.1 4.7 5,979,222.81 688,906.17 1.34 4.73 1,300.0 5.28 105.69 1,299.5 1,251.8 -3.3 12.2 5,979,220.86 688,913.76 1.73 12.40 1,400.0 6.19 104.99 1,399.0 1,351.3 -5.9 21.9 5,979,218.44 688,923.49 0.91 22.23 1,500.0 6.75 104.80 1,498.4 1,450.7 -8.8 32.9 5,979,215.84 688,934.55 0.57 33.39 1,600.0 8.14 105.92 1,597.6 1,549.9 -12.2 45.0 5,979,212.80 688,946.76 1.39 45.72 1,700.0 10.67 106.46 1,696.1 1,648.4 -16.8 61.1 5,979,208.57 688,962.99 2.54 62.11 1,800.0 11.77 107.37 1,794.2 1,746.5 -22.6 79.7 5,979,203.23 688,981.73 1.11 81.08 1,900.0 15.27 100.75 1,891.6 1,843.9 -28.4 101.6 5,979,197.98 689,003.74 3.83 103.30 2,000.0 19.42 95.10 1,986.8 1,939.1 -32.0 131.8 5,979,195.14 689,034.09 4.48 133.74 2,100.0 22.36 96.47 2,080.5 2,032.8 -35.5 166.6 5,979,192.50 689,068.94 2.98 168.68 2,200.0 27.16 93.67 2,171.3 2,123.6 -39.7 208.3 5,979,189.41 689,110.73 4.94 210.57 2,300.0 30.73 85.05 2,258.5 2,210.8 -38.8 257.2 5,979,191.48 689,159.52 5.48 259.22 2,400.0 31.00 85.19 2,344.1 2,296.4 -34.0 308.5 5,979,197.60 689,210.75 0.28 310.13 2,500.0 31.32 88.08 2,429.8 2,382.1 -30.7 360.0 5,979,202.18 689,262.11 1.53 361.25 2,600.0 33.34 92.54 2,514.6 2,466.9 -31.6 413.0 5,979,202.68 689,315.07 3.12 414.14 2,700.0 36.19 91.73 2,596.2 2,548.5 -33.5 470.7 5,979,202.19 689,372.80 2.89 471.85 2,800.0 37.59 92.38 2,676.4 2,628.7 -35.7 530.5 5,979,201.52 689,432.63 1.45 531.65 2,900.0 38.62 92.32 2,754.8 2,707.1 -38.1 592.4 5,979,200.64 689,494.64 1.03 593.64 3,000.0 40.05 92.50 2,832.3 2,784.6 -40.8 655.5 5,979,199.56 689,557.78 1.44 656.77 3,100.0 41.30 93.20 2,908.1 2,860.4 -44.0 720.7 5,979,197.97 689,623.04 1.33 722.04 3,200.0 42.86 93.29 2,982.5 2,934.8 -47.8 787.4 5,979,195.92 689,689.80 1.56 788.83 3,300.0 44.39 94.64 3,054.6 3,006.9 -52.4 856.5 5,979,193.03 689,759.02 1.79 858.12 3,400.0 45.60 93.35 3,125.4 3,077.7 -58.0 926.9 5,979,189.25 689,829.50 1.52 928.70 3,500.0 46.00 89.02 3,195.0 3,147.3 -59.2 998.7 5,979,189.85 689,901.27 3.13 1,000.38 3,539.8 45.85 88.60 3,222.7 3,175.0 -58.5 1,027.3 5,979,191.19 689,929.82 0.85 1,028.85 SV5 3,600.0 45.13 88.97 3,264.9 3,217.2 -57.6 1,070.2 5,979,193.24 689,972.73 1.27 1,071.63 3,700.0 44.84 89.60 3,335.7 3,288.0 -56.8 1,140.8 5,979,195.77 690,043.30 0.54 1,142.02 3,800.0 44.10 89.00 3,407.3 3,359.6 -55.9 1,210.7 5,979,198.45 690,113.10 0.85 1,211.65 3,887.1 44.10 89.20 3,469.8 3,422.1 -54.9 1,271.3 5,979,200.96 690,173.69 0.16 1,272.08 3887.1 MD, Tie -on Survey 3,900.0 44.05 89.38 3,479.1 3,431.4 -54.8 1,280.3 5,979,201.30 690,182.66 1.02 1,281.02 3,909.7 44.02 89.51 3,486.0 3,438.3 -54.7 1,287.0 5,979,201.54 690,189.40 1.02 1,287.74 KOP, Start Dir 2.5 °1100' : 3909.7' MD, 34861 -13 3/8" 12/15/2009 3:38:53PM Page 3 COMPASS 2003.16 Build 71 HALLIBURTO Halliburton Company sal Database: ..Sperry EDM Prod .161 Local Co- ordinate Reference: Well AGI -01 Company: BP - Alaska TVD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Project: Prudhoe Bay (various) MD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Site: AGI North Reference: True Well: AGI -01 Survey Calculation Method: Minimum Curvature Wellbore: Plan AGI -01A Design: AGI- 01Awp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N! -S +E/-W Northing Easting DLS Vert Section (ft) ( °) ( °1 (ft) ft (ft) (ft) (ft) (ft) 3,444.00 3,917.6 44.02 89.79 3,491.7 3,444.0 -54.7 1,292.5 5,979,201.71 690,194.88 2.50 1,293.21 SV4 4,000.0 44.07 92.76 3,550.9 3,503.2 -56.0 1,349.8 5,979,201.88 690,252.15 2.50 1,350.43 4,100.0 44.22 96.34 3,622.7 3,575.0 -61.5 1,419.2 5,979,198.10 690,321.67 2.50 1,420.05 4,200.0 44.49 99.89 3,694.2 3,646.5 -71.4 1,488.4 5,979,189.98 690,391.08 2.50 1,489.75 4,229.7 44.59 100.94 3,715.4 3,667.7 -75.1 1,508.9 5,979,186.73 690,411.66 2.50 1,510.45 4,300.0 45.03 98.53 3,765.3 3,717.6 -83.5 1,557.7 5,979,179.59 690,460.68 2.50 1,559.74 4,400.0 45.72 95.15 3,835.5 3,787.8 -92.0 1,628.3 5,979,172.91 690,531.51 2.50 1,630.80 4,431.5 45.97 94.11 3,857.5 3,809.8 -93.8 1,650.9 5,979,171.66 690,554.07 2.50 1,653.39 End Dir : 4431.5' MD, 3857.5' TVD 4,480.7 45.97 94.11 3,891.7 3,844.0 -96.3 1,686.2 5,979,170.01 690,589.44 0.00 1,688.80 SV3 4,500.0 45.97 94.11 3,905.1 3,857.4 -97.3 1,700.0 5,979,169.37 690,603.26 0.00 1,702.64 4,600.0 45.97 94.11 3,974.6 3,926.9 -102.5 1,771.7 5,979,166.03 690,675.07 0.00 1,774.53 4,700.0 45.97 94.11 4,044.1 3,996.4 -107.6 1,843.4 5,979,162.69 690,746.88 0.00 1,846.42 4,722.4 45.97 94.11 4,059.7 4,012.0 -108.8 1,859.5 5,979,161.94 690,763.00 0.00 1,862.56 SV2 4,800.0 45.97 94.11 4,113.6 4,065.9 -112.8 1,915.1 5,979,159.35 690,818.69 0.00 1,918.31 4,900.0 45.97 94.11 4,183.1 4,135.4 -117.9 1,986.8 5,979,156.01 690,890.50 0.00 1,990.21 5,000.0 45.97 94.11 4,252.6 4,204.9 -123.1 2,058.5 5,979,152.67 690,962.31 0.00 2,062.10 5,100.0 45.97 94.11 4,322.1 4,274.4 -128.2 2,130.2 5,979,149.33 691,034.12 0.00 2,133.99 5,200.0 45.97 94.11 4,391.6 4,343.9 -133.4 2,201.9 5,979,145.99 691,105.93 0.00 2,205.88 5,300.0 45.97 94.11 4,461.2 4,413.5 -138.5 2,273.6 5,979,142.65 691,177.74 0.00 2,277.77 5,323.8 45.97 94.11 4,477.7 4,430.0 -139.8 2,290.7 5,979,141.85 691,194.83 0.00 2,294.88 SV1 5,400.0 45.97 94.11 4,530.7 4,483.0 -143.7 2,345.3 5,979,139.31 691,249.55 0.00 2,349.66 5,500.0 45.97 94.11 4,600.2 4,552.5 -148.8 2,417.0 5,979,135.97 691,321.36 0.00 2,421.55 5,600.0 45.97 94.11 4,669.7 4,622.0 -154.0 2,488.7 5,979,132.63 691,393.17 0.00 2,493.45 5,700.0 45.97 94.11 4,739.2 4,691.5 -159.1 2,560.5 5,979,129.29 691,464.98 0.00 2,565.34 5,800.0 45.97 94.11 4,808.7 4,761.0 -164.3 2,632.2 5,979,125.95 691,536.79 0.00 2,637.23 5,900.0 45.97 94.11 4,878.2 4,830.5 -169.4 2,703.9 5,979,122.61 691,608.60 0.00 2,709.12 5,988.5 45.97 94.11 4,939.7 4,892.0 -174.0 2,767.3 5,979,119.65 691,672.12 0.00 2,772.71 UG4 6,000.0 45.97 94.11 4,947.7 4,900.0 -174.6 2,775.6 5,979,119.26 691,680.41 0.00 2,781.01 6,100.0 45.97 94.11 5,017.2 4,969.5 -179.7 2,847.3 5,979,115.92 691,752.22 0.00 2,852.90 6,200.0 45.97 94.11 5,086.7 5,039.0 -184.9 2,919.0 5,979,112.58 691,824.03 0.00 2,924.80 6,300.0 45.97 94.11 5,156.3 5,108.6 -190.0 2,990.7 5,979,109.24 691,895.84 0.00 2,996.69 6,400.0 45.97 94.11 5,225.8 5,178.1 -195.2 3,062.4 5,979,105.90 691,967.65 0.00 3,068.58 6,457.5 45.97 94.11 5,265.7 5,218.0 -198.1 3,103.6 5,979,103.98 692,008.91 0.00 3,109.88 UG3 6,500.0 45.97 94.11 5,295.3 5,247.6 -200.3 3,134.1 5,979,102.56 692,039.46 0.00 3,140.47 6,600.0 45.97 94.11 5,364.8 5,317.1 -205.5 3,205.8 5,979,099.22 692,111.27 0.00 3,212.36 6,700.0 45.97 94.11 5,434.3 5,386.6 -210.6 3,277.5 5,979,095.88 692,183.08 0.00 3,284.25 6,800.0 45.97 94.11 5,503.8 5,456.1 -215.8 3,349.2 5,979,092.54 692,254.89 0.00 3,356.14 6,900.0 45.97 94.11 5,573.3 5,525.6 -220.9 3,420.9 5,979,089.20 692,326.70 0.00 3,428.04 12/15/2009 3:38:53PM Page 4 COMPASS 2003.16 Build 71 HALLIBURTA • Halliburton opo sal Database: ..Sperry EDM Prod .161 Local Co-ordinate Reference: Well AGI -01 Company: BP - Alaska TVD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Project: Prudhoe Bay (various) MD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Site AGI North Reference: True Well: AGI -01 Survey Calculation Method: Minimum Curvature Wellbore: Plan AGI -01A Design: AGI -01A wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing Easting DLS Vert Section (ft) ( ( °) (ft) ft (ft) (ft) (ft) (ft) 5,595.12 7,000.0 45.97 94.11 5,642.8 5,595.1 -226.1 3,492.6 5,979,085.86 692,398.51 0.00 3,499.93 7,100.0 45.97 94.11 5,712.3 5,664.6 -231.2 3,564.4 5,979,082.52 692,470.32 0.00 3,571.82 7,103.4 45.97 94.11 5,714.7 5,667.0 -231.4 3,566.8 5,979,082.41 692,472.77 0.00 3,574.27 UG1 7,200.0 45.97 94.11 5,781.8 5,734.1 -236.4 3,636.1 5,979,079.18 692,542.13 0.00 3,643.71 7,300.0 45.97 94.11 5,851.3 5,803.6 -241.5 3,707.8 5,979,075.84 692,613.94 0.00 3,715.60 7,400.0 45.97 94.11 5,920.9 5,873.2 -246.7 3,779.5 5,979,072.50 692,685.75 0.00 3,787.49 7,500.0 45.97 94.11 5,990.4 5,942.7 -251.8 3,851.2 5,979,069.16 692,757.56 0.00 3,859.38 7,600.0 45.97 94.11 6,059.9 6,012.2 -257.0 3,922.9 5,979,065.82 692,829.37 0.00 3,931.28 7,700.0 45.97 94.11 6,129.4 6,081.7 -262.1 3,994.6 5,979,062.48 692,901.18 0.00 4,003.17 7,800.0 45.97 94.11 6,198.9 6,151.2 -267.3 4,066.3 5,979,059.14 692,972.99 0.00 4,075.06 7,900.0 45.97 94.11 6,268.4 6,220.7 -272.4 4,138.0 5,979,055.80 693,044.80 0.00 4,146.95 8,000.0 45.97 94.11 6,337.9 6,290.2 -277.6 4,209.7 5,979,052.46 693,116.61 0.00 4,218.84 8,005.4 45.97 94.11 6,341.7 6,294.0 -277.9 4,213.6 5,979,052.28 693,120.52 0.00 4,222.76 WS2 8,100.0 45.97 94.11 6,407.4 6,359.7 -282.7 4,281.4 5,979,049.12 693,188.42 0.00 4,290.73 8,200.0 45.97 94.11 6,476.9 6,429.2 -287.9 4,353.1 5,979,045.78 693,260.23 0.00 4,362.62 8,222.7 45.97 94.11 6,492.7 6,445.0 -289.0 4,369.4 5,979,045.02 693,276.51 0.00 4,378.93 WS1 8,300.0 45.97 94.11 6,546.4 6,498.7 -293.0 4,424.8 5,979,042.44 693,332.04 0.00 4,434.52 8,400.0 45.97 94.11 6,616.0 6,568.3 -298.2 4,496.5 5,979,039.10 693,403.85 0.00 4,506.41 8,408.3 45.97 94.11 6,621.7 6,574.0 -298.6 4,502.5 5,979,038.82 693,409.78 0.00 4,512.35 CM3 8,500.0 45.97 94.11 6,685.5 6,637.8 -303.3 4,568.3 5,979,035.76 693,475.66 0.00 4,578.30 8,600.0 45.97 94.11 6,755.0 6,707.3 -308.5 4,640.0 5,979,032.42 693,547.47 0.00 4,650.19 8,700.0 45.97 94.11 6,824.5 6,776.8 -313.6 4,711.7 5,979,029.08 693,619.28 0.00 4,722.08 8,797.2 45.97 94.11 6,892.0 6,844.3 -318.6 4,781.4 5,979,025.83 693,689.07 0.00 4,791.96 Start Dir 2.5 °1100' : 8797.2' MD, 6892'TVD 8,800.0 45.89 94.11 6,894.0 6,846.3 -318.8 4,783.4 5,979,025.73 693,691.08 2.52 4,793.97 8,900.0 43.39 94.15 6,965.1 6,917.4 -323.8 4,853.5 5,979,022.44 693,761.27 2.50 4,864.24 9,000.0 40.89 94.20 7,039.3 6,991.6 -328.7 4,920.4 5,979,019.24 693,828.28 2.50 4,931.33 9,051.7 39.60 94.23 7,078.7 7,031.0 -331.2 4,953.7 5,979,017.63 693,861.62 2.50 4,964.71 CM2 9,100.0 38.40 94.26 7,116.3 7,068.6 -333.4 4,984.0 5,979,016.15 693,892.00 2.50 4,995.13 9,200.0 35.90 94.32 7,196.0 7,148.3 -337.9 5,044.2 5,979,013.15 693,952.30 2.50 5,055.51 9,300.0 33.40 94.38 7,278.2 7,230.5 -342.2 5,100.9 5,979,010.27 694,009.07 2.50 5,112.35 9,400.0 30.90 94.46 7,362.9 7,315.2 -346.3 5,153.9 5,979,007.51 694,062.20 2.50 5,165.55 9,500.0 28.40 94.55 7,449.8 7,402.1 -350.2 5,203.2 5,979,004.87 694,111.59 2.50 5,215.01 9,582.1 26.34 94.64 7,522.7 7,475.0 -353.2 5,240.9 5,979,002.80 694,149.27 2.50 5,252.75 CM1 9,600.0 25.90 94.66 7,538.8 7,491.1 -353.9 5,248.7 5,979,002.36 694,157.14 2.50 5,260.63 9,700.0 23.40 94.78 7,629.7 7,582.0 -357.3 5,290.3 5,978,999.98 694,198.77 2.50 5,302.33 9,800.0 20.90 94.94 7,722.3 7,674.6 -360.5 5,327.8 5,978,997.74 694,236.40 2.50 5,340.02 9,835.9 20.00 95.00 7,755.9 7,708.2 -361.6 5,340.3 5,978,996.97 694,248.91 2.50 5,352.56 End Dir : 9835.9' MD, 7755.W TVD 12/15/2009 3:38:53PM Page 5 COMPASS 2003.16 Build 71 • Halliburton Company HALLIBURTO Standard Proposal Report Database: ..Sperry EDM Prod .161 Local Co- ordinate Reference: Well AGI -01 Company: BP - Alaska TVD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Project: Prudhoe Bay (various) MD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Site: AGI North Reference: True Well: AGI -01 Survey Calculation Method: Minimum Curvature Welibore: Plan AGI -01A Design: AGI-01A wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/ -W Northing Easting DLS Vert Section (ft) ( ( (ft) ft (ft) (ft) (ft) (ft) 7,768.45 9,900.0 20.00 95.00 7,816.1 7,768.4 -363.5 5,362.2 5,978,995.61 694,270.79 0.00 5,374.48 9,991.0 20.00 95.00 7,901.7 7,854.0 -366.2 5,393.2 5,978,993.68 694,301.87 0.00 5,405.61 THRZ 10,000.0 20.00 95.00 7,910.1 7,862.4 -366.5 5,396.2 5,978,993.49 694,304.93 0.00 5,408.67 10,100.0 20.00 95.00 8,004.1 7,956.4 -369.5 5,430.3 5,978,991.37 694,339.06 0.00 5,442.87 10,200.0 20.00 95.00 8,098.1 8,050.4 -372.4 5,464.4 5,978,989.25 694,373.20 0.00 5,477.07 10,200.7 20.00 95.00 8,098.7 8,051.0 -372.5 5,464.6 5,978,989.23 694,373.43 0.00 5,477.30 BHRZ 10,216.7 20.00 95.00 8,113.7 8,066.0 -372.9 5,470.1 5,978,988.89 694,378.88 0.00 5,482.76 LCUITSAD - 95/8" 10,278.4 20.00 95.00 8,171.7 8,124.0 -374.8 5,491.1 5,978,987.58 694,399.95 0.00 5,503.87 TCGL 10,300.0 20.00 95.00 8,192.0 8,144.3 -375.4 5,498.5 5,978,987.13 694,407.33 0.00 5,511.26 10,343.3 20.00 95.00 8,232.7 8,185.0 -376.7 5,513.2 5,978,986.21 694,422.11 0.00 5,526.07 BCGL 10,400.0 20.00 95.00 8,286.0 8,238.3 -378.4 5,532.5 5,978,985.00 694,441.46 0.00 5,545.46 10,500.0 20.00 95.00 8,380.0 8,332.3 -381.4 5,566.6 5,978,982.88 694,475.60 0.00 5,579.66 10,561.4 20.00 95.00 8,437.7 8,390.0 -383.2 5,587.5 5,978,981.58 694,496.57 0.00 5,600.67 TZ1B 10,600.0 20.00 95.00 8,473.9 8,426.2 -384.4 5,600.7 5,978,980.76 694,509.73 0.00 5,613.85 10,635.9 20.00 95.00 8,507.7 8,460.0 -385.4 5,612.9 5,978,980.00 694,521.99 0.00 5,626.13 Total Depth : 10635.9' MD, 8507.T TVD - 7" - AGI -01A T1 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N / -S +E/ -W Northing Easting - Shape ( ( (ft) (ft) (ft) (ft) (ft) AGI -01A T1 0.00 0.00 8,507.7 -385.4 5,612.9 5,978,980.00 694,522.00 - plan hits target center - Circle (radius 100.0) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ( ") ( ") 10,216.7 8,113.7 95/8" 9 -5/8 12 -1/4 10,635.9 8,507.7 7" 7 8 -1/2 3,909.7 3,486.0 13 3/8" 13 -3/8 17 -1/2 12/15/2009 3:38:53PM Page 6 COMPASS 2003.16 Build 71 • Halliburton Company HALLIBURTO Standard Proposal Report Database: ..Sperry EDM Prod .161 Local Co- ordinate Reference: Well AGI - 01 Company: BP - Alaska TVD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Project: Prudhoe Bay (various) MD Reference: D -14 RKB 13.4 +34.3KB @ 47.7ft (D -14) Site: AGI North Reference: True Well: AGI - 01 Survey Calculation Method: Minimum Curvature Wellbore: Plan AGI - 01A Design: AGI - 01A wp02 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name . Lithology ( °) (1 9,051.7 7,078.7 CM2 7,103.4 5,714.7 UG1 3,917.6 3,491.7 SV4 8,005.4 6,341.7 WS2 6,457.5 5,265.7 UG3 10,635.9 8,507.7 BSAD 10,561.4 8,437.7 TZ1B 4,480.7 3,891.7 SV3 10,200.7 8,098.7 BHRZ 10,216.7 8,113.7 LCU/TSAD I 9,991.0 7,901.7 THRZ 8,222.7 6,492.7 WS1 5,988.5 4,939.7 UG4 5,323.8 4,477.7 SV1 9,582.1 7,522.7 CM1 3,539.8 3,222.7 SV5 0.00 8,408.3 6,621.7 CM3 10,278.4 8,171.7 TCGL 10,343.3 8,232.7 BCGL 4,722.4 4,059.7 SV2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N /-S +E / -W (ft) (ft) (ft) (ft) Comment 3,887.1 3,469.8 -54.9 1,271.3 3887.1 MD, Tie-on Survey 3,909.7 3,486.0 -54.7 1,287.0 KOP, Start Dir 2.5 °/100' : 3909.7' MD, 3486'TVD 4,431.5 3,857.5 -93.8 1,650.9 End Dir : 4431.5' MD, 3857.5' TVD 8,797.2 6,892.0 -318.6 4,781.4 Start Dir 2.5 °/100' : 8797.2' MD, 6892'TVD 9,835.9 7,755.9 -361.6 5,340.3 End Dir : 9835.9' MD, 7755.9' TVD 10,635.9 8,507.7 -385.4 5,612.9 Total Depth : 10635.9' MD, 8507.7' TVD I 12/15/2009 3:38:53PM Page 7 COMPASS 2003.16 Build 71 TREE _ . WELLHEAD = CIW AG 1-0 1 NOTES: LINER NOT CEMENTED. ACTUATOR = BAKER C G IS IPC W ITH NSCC THREAD 1 KB. ELEV = 49' BF. ELEV = KOP = 1851' Max Angle = 46 @ 3478' Datum MD = 11204' I 2178' I_17" CAMCO BAL -O SSSV NIP, ID = 5.937 "I Datum TVD = 8800' SS 1 13 -3/8" CSG, 68 #, K -55, ID = 12.415" H 122' 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3911' 7" TBG, 26 #, NT -80 -IPC NSCC, — 10041' I I 10041' . 1-17" I 7" X 5 -1/2" XO, ID = 4.892" I .0383 bpf, ID = 6.276" 10046' I- ANCHOR 1 z Z. I 10049' I-19 -5/8" X 5 -1/2" BAKER FB -1 PKR I 10096' 1_15-1/2" PARKER SWS NIP, ID = 4.562"1 Minimum ID = 4.455" @ 10117' 5 -1/2" OTIS XN NIPPLE 10117' 1_15 -1/2" OTIS XN NIP, ID= 4.455" I 10117' H5 -1/2" PXN PLUG (08/23/09)' 5 -1/2" TBG, 17 #, L -80 -IPC NSCC, - 10129' I / . I 10129' H5-1/2" WLEG, ID = 4.892"1 .0232 bpf, ID = 4.892" 10127' H ELMD TT LOGGED 05/20/93 I 'TOP OF 7" L NR I-J 10141' 1 ii 1 9 -5/8" CSG, 47 #, NT -80, ID = 8.681" I 10260' PERFORATION SUMMARY ' REF LOG: BHCS ON 11/29/92 ANGLE AT TOP PERF: 36 @ 10301' 1 Note: Refer to Roduction DB for historical perf data ' SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 10301 - 10315 C IP 5/20/93 1 3 -3/8" 6 10329 - 10529 C ' 5/20/93 3 -3/8" 6 10540 - 10550 C ' 5/20/93 1 3 -3/8" 6 10598 - 10648 C ' 5/20/93 3 -3/8" 6 10665 - 10695 C ' 5/20/93 ' 3 -3/8" 6 10703 - 10733 C r 5/20/93 3 -3/8" 6 10743 - 10763 C ' 5/20/93 ' PBTD H 10770' 1 1 7" LNR, 26 #, NT -80, .0383 bpf, ID = 6.276" H 10850' I J DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/29/92 ORIGINAL COMPLETION 10/01/09 BSEJPJC SET PXN PLUG (08/23/09) WELL: AGI-01 01/29/01 SIS-LG REVISION 10/02/09 GBP/SV WHL CORRECTION PERMIT No: 1921240 05/21/01 RN/KAK CORRECTIONS API No: 50- 029 - 22307 -00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36, T12N, R14E, 1294.15' & FEL 4091.85' FNL 03/26/03 JP/KAK CSG DEPTH CORRECTION 05/12/03 JRC/KK CSG DEPTH CORRECTION BP Exploration (Alaska) WELLHEAD = CIW 'G' -0 S NOTES: LINER NOT CEMENTED. ACTUATOR = BAKER C Pre-Rig G IS IPC WITH NSCC THREAD KB. ELEV = 49' BF. ELEV = 1 KOP = 1851' Max Angle = 46 © 3478' Datum MD = 11204' 2178' 1_17" CAMCO BAL -O SSSV NIP, ID = 5.937"1 Datum TVD = 8800' SS O 13 -3/8" CSG, 68 #, K -55, ID = 12.415" H 122' 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3911' 1-- -7150' H I TUBING CUT I 7" TBG, 26 #, NT -80 -IPC NSCC, 10041' 10041' 1-17" X 5 -1/2" XO, ID = 4.892" I .0383 bpf, ID = 6.276" I H 10007' 10046' I -IANCHOR I C, 0 10049' I9 -5/8" X 5 -1/2" BAKER FB -1 PKR I . - 10082' H 5-1/2" CMT RETAINER I I 10096' I- I5 -1/2" PARKER SWS NIP, ID = 4.562" I Minimum ID = 4.455" @ 10117' 5-1/2" OTIS XN NIPPLE 1 I 10117' I_I5 -1/2" OTIS XN NIP, ID = 4.455" I 5 -1/2" TBG, 17 #, L -80 -IPC NSCC, -1 10129' I \ 10129' I- I5 -1/2" WLEG, ID = 4.892" I .0232 bpf, ID = 4.892" I 10127' IH ELMD TT LOGGED 05/20/93 I ITOP OF7 "LNRIH 10141' i 9 -5/8" CSG, 47 #, NT -80, ID = 8.681" I 10260' PERFORATION SUMMARY REF LOG: BHCS ON 11/29/92 I ANGLE AT TOP PERF: 36 @ 10301' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE ' 3 -3/8" 6 10301 - 10315 . 5/20/93 3 -3/8" 6 10329 - 10529 S x 5/20/93 ' 3 -3/8" 6 10540 - 10550 S ' 5/20/93 3 -3/8" 6 10598 - 10648 S ' 5/20/93 I 3 -3/8" 6 10665 - 10695 S 5/20/93 3 -3/8" 6 10703 - 10733 S ' 5/20/93 ' 3 -3/8" 6 10743 - 10763 S ' 5/20/93 PBTD H 10770' V " 'f •" • 1 � . 17" LNR, 26 #, NT -80, .0383 bpf, ID = 6.276" H 10850' '�•'• • � • � A ■ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/29/92 ORIGINAL COMPLETION 10/01/09 BSE/PJC SET PXN PLUG (08/23/09) WELL: AGI-01 01/29/01 SIS -LG REVISION 10/02/09 GBP /SV WHL CORRECTION PERMIT No: 1921240 05/21/01 RN/KAK CORRECTIONS AR No: 50- 029 - 22307 -00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36, T12N, R14E, 1294.15' & FEL 4091.85' FNL 03/26/03 JP /KAK CSG DEPTH CORRECTION 05/12/03 JRC /KK CSG DEPTH CORRECTION BP Exploration (Alaska) TREE _ • AG I -01 A WELLHEAD = CIW S „, NOTES: SLOTTED LINER. ACTUATOR= BAKERC KB. ELEV = 49' PROPOSED ALL IBGISIPC WITH Vam Top HC / TCII THREAD BF. ELEV = KOP = 1851' Max Angle = 46 @ 3478' Datum MD = 11204' Datum ND = 8800' SS L 2080' H 7 -5/8” X 7" XO, ID = 6.276" I 13-3/8" CSG, 68 #, H 122' O I 2100' I _17" CAMCO A -1 NJ VALVE, ID = X.XXX" I K -55, ID = 12.415" 2117 —17"X7 -5r8' X) C=6276' 13 -3/8" CSG, 68 #, H 3911' 1— I 3911' I- Openhole Sidetrack L -80, ID = 12.415" Cement kickoff plug 44 or 9987' H 7 -5/8" X 7" XO, ID = 6.276" I ' 10007' I-17" HES R NIP, ID = 5.963" I 7 -5/8" TBG, 29.7 #, L- 80 -IPC yam Top HC, —I 9987' . .0459 bpf, ID = 6.875" ,a 10027' I _19 -5/8" x 7" BAKER S -3 PKR, ID = 6.000' I I I 10052' W 7" HES RN NIP, ID = 5.770" I Minimum ID = 5.770" @ 10052' 10066' -I 7" WLEG, ID = 6.276" I 7" HES RN NIPPLE I t la I 10066' I 9 -5/8" x 7" BAKER ZXP LTP w / 17" TBG, 26 #, L- 80 -IPC TCII, .0383 bpf, ID = 6.276" I-J 10066' I FLEXLOCK LNR HGR, ID = 6.350' 19-5/8" CSG, 47 #, L -80, Hydril 563, .0732 bpf, ID 8.681" IH 10216' I PERFORATION SUMMARY REF LOG: BHCS ON 11/29/92 ANGLE ATTOPPERF: 36 @ 10301' \ Note: Refer to Production DB for historical perf data \ SIZE SPF INTERVAL Opn /Sqz DATE \ 7" SLTD SLOT \ \ \ \ ( 7" SOLID LNR, 26 #, L -80, BTC-M, .0383 bpf, ID = 6.276" H 10266' \ \ \ 1 7" SLTD LNR, 26 #, L -80, BTC-M, .0383 bpf, ID = 6.276" I 10635' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/29/92 ORIGINAL COMPLETION 10/01/09 BSE/PJC SET PXN PLUG (08/23/09) WELL: AGI-01 01/29/01 SIS -LG REVISION 10/02/09 GBP /SV WHL CORRECTION PERMIT No: 1921240 05/21/01 RN/KAK CORRECTIONS API No: 50- 029 - 22307 -00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36, T12N, R14E, 1294.15' & FEL 4091.85' FNL 03/26/03 JP /KAK CSG DEPTH CORRECTION 05/12/03 JRC /KK CSG DEPTH CORRECTION BP Exploration (Alaska) AGI -01A PTD discussion Page 1 of 3 4 • Schwartz, Guy L (DOA) From: Roach, Frank [Frank.Roach @bp.com] rb 201-/ 6 Y Sent: Monday, December 28, 2009 11:50 AM l To: Schwartz, Guy L (DOA) Cc: Hobbs, Greg S (ANC) Subject: AGI -01A PTD discussion Mr. Schwartz, Per our telephone discussion a few minutes ago, below are the clarification points that were discussed: - We will run a cement evaluation log on the 9 -5/8" casing, prior to drilling the production hole to demonstrate isolation to the injection interval. - Prior to running the completion, VBR's will be changed out to 7 -5/8" fixed rams and tested to 250 psi low / 4,000 psi high. Operations summary now looks as shown below (changes are in bold and red): Proposed Drilling Rig Operations: 1. MI /RU. 2. CMIT -TxIA rolling to 500 psi and MIT -OA to 2,000 psi to confirm barriers (10 minute tests - expect MIT -OA to pass). 3. Pull BPV w /tested lubricator and circulate out diesel freeze protection and displace the well to seawater. 4. Set and test TVVC to 500 psi rolling test from below and 4,000 psi from above for 10 minutes. 5. Nipple down tree. Nipple up and test BOPE to 4,000psi. Pull TWC w /tested lubricator. 6. R/U & pull 7" tubing from the cut depth at 7,150' MD. 7. Test lower set of rams if required. 8. PU drill -pipe and make bit and scraper run to the top of the tubing stub. 9. RU E -line and RIH w /USIT log to confirm no cement behind pipe at desired cut depth. 10. RIH w /CIBP and CCL and set the CIBP at -4,100' MD and test well to 4,000 psi for 10 minutes. 11. RIH and cut 9-%" casing -75' below surface casing shoe (cut at -3,985' MD) and circulate through cut. If unable to circulate, cut casing just inside surface casing and establish circulation. 12. Spear hanger and pull casing to floor. 13. RIH w/ open -ended drilipipe and set 17# kickoff plug on top of CIBP. Bring plug -300' inside 13-%" surface casing. WOC until desired compressive strength reached. Pressure test to 3,500 psi. (End Work Under Sundry Approval #309 -148 / Begin Work Under PTD #xxx -xxx) 14. M/U 12-%" Dir /GR /Res /PWD assembly. RIH, control drill to kick off of plug and 20' of new hole beyond cement. Circulate wellbore clean 12/28/2009 sAGI -01A PTD discussion • • Page 2 of 3 15. Pull up into casing and conduct LOT. 16. Run back to bottom and drill the 12 - %" intermediate section to the TD target per directional plan. 17. Circulate, short trip and POOH to run the 9-%" intermediate casing (manage drill -pipe as required). 18. Run and cement a 9-%", 47.0 #, L -80, Hydril 563 intermediate casing. TOC 1,000' above casing shoe. 19. After cement has reached a minimum 500 psi compressive strength, test the 9-%" casing to 4,000psi for 30 minutes and record the test. 20. RU E -line and RIH w/ USIT log to confirm isolation and cement quality of casing cement job. 21. M/U 8-Y2" drilling assembly w /Dir /GR + insert bit to drill -out the shoe track, displace to the well to the planned drill -in fluid, drill 20' of new hole and run FIT. 22. Drill ahead per the directional plan to TD. 23. Circulate, short trip, spot liner running pill. POOH to run the production liner. 24. Run and set 7 ", 26 #, BTC -M, slotted production liner. * *NOTE: Due to running 7" slotted pipe, rams will not be changed to 7" casing rams. There will be a joint of 5" drillpipe with a DP to 7" BTC -M crossover on bottom and TIW valve on top (TIW valve in open position with valve key ready to use). In the event the BOP stack would need to be used, the crossover joint would be made up to the liner, run in hole to where the drillpipe joint is across the BOP stack, and the pipe rams closed on that joint of drillpipe. 25. POOH L/D all drill pipe. 26. Change upper rams to 7-%" fixed rams and test to 250 psi low / 4,000 psi high. 27. R/U and run 7-%", 29.7 #, L -80, VamTop HC, IPC completion tubing. 28. Land the tubing RILDS. 29. Reverse the well to clean seawater to include inhibited seawater to the production packer depth per the plan. Chase corrosion inhibited fluid with diesel freeze protect. 30. Drop ball & rod. Set packer and individually test the tubing and annulus to 4,000psi 30 minutes and record each test. * *Notify state inspector 24 hrs before test for opportunity to witness ** 31. Seta TWC and test to 1,000 psi from above. 32. Nipple down the BOPE. Nipple up the tree and test to 5,000psi with diesel (new adapter flange required). 33. Pull TWC w /lubricator. 34. RU slickline and retrieve ball & rod. 35. Freeze protect tubing with diesel. 36. Install BPV and secure the well. 12/28/2009 AGI -01A PTD discussion • • Page 3 of 3 37. RDMO. Any questions /comments /concerns, don't hesitate to call or reply. Regards, -Frank Roach 12/28/2009 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 • AEO 2 6000000 i AEO 1 5950000 - AGI -01A 5900000 • 40 CFR 147.102 (b)(3) 5850000 400000 500000 600000 700000 800000 Alaska Department of Natura sources Land Administration System Page 1 of/ t Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 34628 Printable Case File Summary See Township, Range, Section and Acreage? New Search CO) Yes 0 No LAS Menu 1 Case Abstract !Case Detail 1 Land Abstract File: ADL 34628 ga r Search for Status Plat Updates As of 12/21/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 03/16/1967 Total Acres: 2459.000 Date Initiated: 12/23/1966 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 012N Range: 015E Section: 29 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 015E Section: 30 Section Acres: 588 Meridian: U Township: 012N Range: 015E Section: 31 Section Acres: 591 Meridian: U Township: 012N Range: 015E Section: 32 Section Acres: 640 Legal Description 12 -23 -1966 * * * SALE NOTICE LEGAL DESCRIPTION * * * C18 -7 T. 12N., R. 15E., U.M. SECTION 29: ALL 640 ACRES SECTION 30: ALL 588 ACRES SECTION 31: ALL 591 ACRES SECTION 32: ALL 640 ACRES http://dnr.alaska.gov/projects/las/Case Summary.cfrn?FileType=ADL&FileNumber=346... 12/21/2009 Alaska Department of Naturasources Land Administration System. Page 1 of, Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28301 Printable Case File Summary See Township, Range, Section and Acreage? New Search a Yes 0 No LAS Menu Case Abstract I Case Detail I Land Abstract File: ADL 28301 \lak Search for Status Plat Updates As of 12/21/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 012N Range: 014E Section: 25 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 014E Section: 26 Section Acres: 640 Meridian: U Township: 012N Range: 014E Section: 35 Section Acres: 640 Meridian: U Township: 012N Range: 014E Section: 36 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -122 012N- 014E -UM 25,26,35,36 2560.00 04 -01 -1977 * ** UNITIZED & GAS CAP PA LEGAL * ** TRACT 28 T 12 N., R. 14 E., U.M. http: / /dnr.alaska.gov /projects /las /Case Summary.cfin ?FileType= ADL &FileNumber=283... 12/21/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME //- 0/4 PTD# 9 /Ea41 Development ✓ Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: f � ,!/.D,4/€ ,J.4y POOL: 0/4 Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 A. ,, " . , Well Name: f PRUDHOE BAY UNIT AGI -01A Program SER Well bore seg ❑ PTD#: 2091640 Company BP EXPLORATION (ALASKA)INC - _ Initial Class /Type SER / PEND GeoArea 890 _ Unit 11650 On /Off Shore On - Annular Disposal ❑ Administration 1 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 14 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes �� 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 4 / 4C /a /a�,/ 9 15 All wells within 1/4 mile area of review identified (For service well only) tar-414.1.1A. 16 Pre - produced injector: duration of pre- production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA - - 118 Conductor string provided NA Conductor set in AGI-01 Engineering 119 Surface casing protects all known USDWs NA Surface casing set in AGI -01 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in AGI -01 21 CMT vol adequate to tie -in long string to surf csg NA Production casing to be cemented 1000' 22 CMT will cover all known productive horizons No Oh slotted liner completion in Ivishak 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 309 -418 (P &A sundry) 26 Adequate wellbore separation proposed Yes Proximity analysis performed. No issues. 127 If diverter required, does it meet regulations NA Wellhead already in place. BOP stack installed. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 3339 psi (7.9 PPG EMW) will drill with 8.5 -9.0 mud. GLS 12/28/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2527 psi will test BOP to 4000 psi • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on pad. Rig has alarms and sensors. 34 Mechanical condition of wells within AOR verified (For service well only) Yes Replacement wellbore for AGI -01... no AOR issues. New BHL is 300' away from original well. 35 Permit can be issued w/o hydrogen sulfide measures No AGI is not a H2S site, and measurments are not available, but H2S measures will be SOP. Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 12/21/2009 1 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: CCo /2 a - Commissioner Date Well History File APPENDIX Inforniation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. e f Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 19 15:40: 13 2010 Reel Header Service name LISTPE Date 10/02/19 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 10/02/19 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Field MWD/MAD LOGS WELL NAME: AGI-01A API NUMBER: 500292230701 OPERATOR: BP Exploration Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 19-FEB-10 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: -MW-0007054180 -MW-0007054180 -MW-0007054180 LOGGING ENGINEER: B. SCHULZE B. SCHULZE B. SCHULZE OPERATOR WITNESS: R. BORDES R. BORDES R. BORDES MWD RUN 4 JOB NUMBER: -MW-0007054180 LOGGING ENGINEER: B. SCHULZE OPERATOR WITNESS: R. BORDES SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 14E FNL: FSL: 1583 FEL: 2390 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 46.97 GROUND LEVEL: 13.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS 0061)—«4-1 /9e--// r , BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3911.0 2ND STRING 9. 625 8.500 10162.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. THIS WELLBORE WAS EFFECTED BY DRILLING OFF OF A CEMENT PLUG IN THE AGI-01 WELL. THE KICK-OFF POINT WAS 3915'MD/3489'TVD. 4 . MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND DRILLSTRING DYNAMICS SENSOR (DDSr) . MWD RUNS 1,2 ALSO INCLUDED AT-BIT INCLINATION (ABI) . MWD RUNS 2-4 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR-P4) . MWD RUN 3 ALSO INCLUDED GEOPILOT ROTARY-STEERABLE BHA (GP) AND AT-BIT GAMMA (ABGT) . ABGT DATA WERE APPENDED TO THE BOTTOM OF MWD RUN 3 FROM 10144 .5'MD-10175'MD. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 19 FEBRUARY 2010, QUOTING AUTHORIZATION FROM DOUG STONER (BP) . THIS UNSHIFTED MWD LOG IS THE PDCL FOR AGI-01A. 6. MWD RUNS 1-4 REPRESENT WELL AGI-01A WITH API# 50-029-22307-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10623'MD/8496'TVD. SROP = RATE OF PENETRATION WHILE DRILLING SGRC = DUAL GAMMA RAY COMBINED SEXP = EWR PHASE-4 9" 2 MHZ PHASE SHIFT RESISTIVITY SESP = EWR PHASE-4 15" 2 MHZ PHASE SHIFT RESISTIVITY SEMP = EWR PHASE-4 27" 2 MHZ PHASE SHIFT RESISTIVITY SEDP = EWR PHASE-4 39" 1 MHZ PHASE SHIFT RESISTIVITY SFXE = FORMATION EXPOSURE TIME EWR-PHASE-4 ABGT = AT-BIT GAMMA RAY ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 r Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3448.0 10586.5 ROP 3480.0 10623.0 FET 3890.0 10578.5 RPS 3890.0 10578.5 RPM 3890.0 10578.5 RPD 3890.0 10578.5 RPX 3890.0 10578.5 GR 7823.0 10175.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE _ MWD 1 3448.0 3811.0 MWD 2 3811.0 7551.0 MWD 3 7551.0 10180.0 MWD 4 10180.0 10623.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 ,1 GR MWD API 4 1 68 4 2 RPD MWD API 4 1 68 8 3 RPM MWD OHMM 4 1 68 12 4 I RPS MWD OHMM 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 FET MWD HR 4 1 68 24 7 GR MWD API 4 1 68 28 8 ROP MWD FPH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3448 10623 7035.5 14351 3448 10623 GR MWD API 24.73 454 .57 117 .094 4705 7823 10175 RPD MWD API 0.43 2000 43.1403 13378 3890 10578.5 RPM MWD OHMM 0. 16 2000 27.2571 13378 3890 10578.5 RPS MWD OHMM 0.29 2000 14 .0742 13378 3890 10578.5 RPX MWD OHMM 0. 36 1649. 18 5.20917 13378 3890 10578.5 FET MWD HR 0.24 135.48 2.19459 13378 3890 10578.5 GR MWD API 18.26 454 .57 78.5348 14278 3448 10586.5 ROP MWD FPH 1.27 408.73 125.576 14287 3480 10623 First Reading For Entire File 3448 Last Reading For Entire File 10623 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3448.0 3763.5 SROP 3480.0 3811.0 LOG HEADER DATA DATE LOGGED: 25-JAN-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 3811.0 TOP LOG INTERVAL (FT) : 3480.0 BOTTOM LOG INTERVAL (FT) : 3811.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 46.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11415397 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 3911.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.30 MUD VISCOSITY (S) : 62.0 MUD PH: 9.5 MUD CHLORIDES (PPM) : 2800 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : . 980 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .810 86.0 MUD FILTRATE AT MT: . 650 70.0 MUD CAKE AT MT: 1.250 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 ROP MWD010 FPH 4 1 68 8 3 First Last Name_Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3448 3811 3629.5 727 3448 3811 GR MWD010 API 24.39 57. 65 40.1097 632 3448 3763.5 ROP MWD010 FPH 4.14 207.4 56.42 663 3480 3811 First Reading For Entire File 3448 Last Reading For Entire File 3811 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF • File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3764.0 7503.5 SROP 3811.5 7551.0 SFXE 3890.0 7496.5 SEXP 3890.0 7496.5 SESP 3890.0 7496.5 SEMP 3890.0 7496.5 SEDP 3890.0 7496.5 LOG HEADER DATA DATE LOGGED: 28-JAN-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7551.0 TOP LOG INTERVAL (FT) : 3811.0 BOTTOM LOG INTERVAL (FT) : 7551.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 42.3 MAXIMUM ANGLE: 47. 9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11415397 -_EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 3911.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.30 MUD VISCOSITY (S) : 45.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 1400 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.200 70.0 MUD AT MAX CIRCULATING TERMPERATURE: . 990 86.0 MUD FILTRATE AT MT: .800 70.0 MUD CAKE AT MT: 1.700 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: • HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3764 7551 5657.5 7575 3764 7551 RPD MWD020 OHMM 0. 43 1769.27 3.07693 7214 3890 7496.5 RPM MWD020 OHMM 0. 16 20.21 2.57595 7214 3890 7496.5 RPS MWD020 OHMM 0.29 16.79 2.51203 7214 3890 7496.5 RPX MWD020 OHMM 0.7 14. 67 2.38367 7214 3890 7496.5 FET MWD020 HR 0.24 4. 42 0.817743 7214 3890 7496.5 GR MWD020 API 18.26 120.3 62.0066 7480 3764 7503.5 ROP MWD020 FPH 1.71 408.73 164 .537 7480 3811.5 7551 First Reading For Entire File 3764 Last.Reading For Entire File 7551 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 , Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE . START DEPTH STOP DEPTH SFXE 7497.0 10136.0 SESP 7497.0 10136.0 SEXP 7497.0 10136.0 SEDP 7497.0 10136.0 SEMP 7497.0 10136.0 SGRC 7504 .0 10175.0 SROP 7551.5 10180.0 ABGT 7823.0 10175.0 LOG HEADER DATA DATE LOGGED: 01-FEB-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 10180.0 TOP LOG INTERVAL (FT) : 7551.0 BOTTOM LOG INTERVAL (FT) : 10180.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 19. 9 MAXIMUM ANGLE: 46.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 76751 EWR4 ELECTROMAG. RESIS. 4 77613 ABGT At-Bit Dual GR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 __ DRILLER'S CASING DEPTH (FT) : 3911.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.80 MUD VISCOSITY (S) : 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 1200 FLUID LOSS (C3) : 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.860 80.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.780 133.0 MUD FILTRATE AT MT: 2.000 75.0 MUD CAKE AT MT: 3.220 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 RPD MWD030 OHMM 4 1 68 8 3 RPM MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPX MWD030 OHMM 4 1 68 20 6 FET MWD030 HR 4 1 68 24 7 GR MWD030 API 4 1 68 28 8 ROP MWD030 FPH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7497 10180 8838 .5 5367 7497 10180 GR MWD030 API 24 .73 454 .57 117.094 4705 7823 10175 RPD MWD030 OHMM 0.87 25. 92 5.23992 5279 7497 10136 RPM MWD030 OHMM 0.84 24 .37 4.8579 5279 7497 10136 RPS MWD030 OHMM 0. 86 24.41 4.78607 5279 7497 10136 RPX MWD030 OHMM 0.76 19.29 4.35443 5279 7497 10136 FET MWD030 HR 0.32 49.35 2.03225 5279 7497 10136 GR MWD030 API 27. 69 454.57 106. 959 5343 7504 10175 ROP MWD030 FPH 1.27 233. 6 81.3027 5258 7551.5 10180 First Reading For Entire File 7497 Last Reading For Entire File 10180 File...Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO ,;;, Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEMP 10136.5 10578.5 SESP 10136.5 10578.5 SEDP 10136.5 10578.5 SFXE 10136.5 10578.5 SEXP 10136.5 10578.5 SGRC 10175.5 10586.5 SROP 10180.5 10623.0 $ LOG HEADER DATA DATE LOGGED: 07-FEB-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 10623.0 TOP LOG INTERVAL (FT) : 10180.0 BOTTOM LOG INTERVAL (FT) : 10623.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 18.3 MAXIMUM ANGLE: 20.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 275518 EWR4 ELECTROMAG. RESIS. 4 11179702 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.500 DRILLER'S CASING DEPTH (FT) : 10162.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 8.80 __MUD VISCOSITY (S) : 42.0 MUD PH: 9.8 MUD CHLORIDES (PPM) : 41000 FLUID LOSS (C3) : 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : . 140 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 140.8 MUD FILTRATE AT MT: .100 71.0 MUD CAKE AT MT: .120 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 -First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10136.5 10623 10379.8 974 10136.5 10623 RPD MWD040 OHMM 1.03 2000 595.789 885 10136.5 10578.5 RPM MWD040 OHMM 0.36 2000 362.055 885 10136.5 10578.5 RPS MWD040 OHMM 0.42 2000 163.725 885 10136.5 10578.5 RPX MWD040 OHMM 0.36 1649. 18 33.3394 885 10136.5 10578.5 FET MWD040 HR 0.3 135.48 14 .3862 885 10136.5 10578.5 GR MWD040 API 22. 49 441.09 73.7325 823 10175.5 10586.5 ROP MWD040 FPH 2. 91 312. 1 111. 137 886 10180.5 10623 First Reading For Entire File 10136.5 Last Reading For Entire File 10623 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF Tape Trailer Service name LISTPE Date 10/02/19 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. 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Report#: 4 HALLIBURTON Well: AGI-01A Date: 1/26/2010-04:00 Area: Prudhoe Bay 04:00 Depth 3872' Location: North Slope, AK Progress 24 hrs: 61' of cmt Sperry Drilling Services Rig: Doyon 14 Rig Activity: drill cmt Job No.: AK-AM 0007054180 Report For: Bordes/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $20,310.56 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) SPP (psi) Gas (units) 5 6 Flow In (spm) Gallons/stroke 4.3180 Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I 3872' 9.30 9.30 45 4.0 11 22 7.0 10.20 2,000 4.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 200 Hughes MXL-1X 12.25 1.071 0.00 3911' 0' 0' Lithoiogy (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 3911' to 3872' 6 5 4968 BG to to to to to to to to Gas Type abreviations: BG- Background Gas; GP- Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Lubricate rig and inspect top drive. Run into the hole with 12.25" BHA washing down last stand.Tag cement at 3811'. Drill cement to 3872'. Logging Engineers: Tom Mansfield/Dan Sherwood * 10000 units= 100% Gas In Air I I I I Customer: BP Exploration, Inc. Report#: 5 HALLIBURTON Well: AGI-01A Date: 1/27/2010-04:00 Area: Prudhoe Bay 04:00 Depth 5565' Location: North Slope, AK Progress 24 hrs: 1654' Sperry Drilling Services Rig: Doyon 14 Rig Activity: Drilling Job No.: AK-AM 0007054180 Report For: 3ordes/Kobuk/Mask1e Daily Charges $1,994.00 Total Charges: $22,304.56 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 113.0 122.0 316.0 5382' _ Flow In (gpm) 813 SPP (psi) 2500 Gas (units) 75 75 133 5339' Flow In (spm) 190 Gallons/stroke 4.3180 Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 7300' 9.25 9.30 44 16.3 11 22 6.0 9.20 2,000 5.0 BHA Run # I Bit Type Size TFA Hours Depth in_/out Footage WOB RPM Condition 200 Hughes MXL-1X 12.25 1.071 10.80 3911' 1654' 0' Lithoiogy (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 3911' to 5565' 133 75 131926 BG to to to to to to to to Gas Type abreviations: BG - Background Gas; GP-Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drilled ahead from 3911'Casing shoe to 5565'. Logging Engineers: Tom Mansfield/Dan Sherwood * 10000 units= 100% Gas In Air I I I I - Customer: BP Exploration, Inc. Report#: 6 Well: AGI-01A Date: 1/28/2010 04:00 Area: Prudhoe Bay 04:00 Depth 7265' Location: North Slope, AK Progress 24 hrs: 3454' Sperry Drilling Services Rig: Doyon 14 Rig Activity: Drilling Job No.: AK-AM 0007054180 Report For: D. Maskil, asdf Daily Charges $1,994.00 Total Charges: $24,301.56 ROP & Gas: Current Avg 24 hr Max Max @ it Current Pump & Flow Data: R.O.P. (ft/hr) 112.0 141.0 489.0 7065' Flow In (gpm) 813 SPP (psi) 2500 Gas (units) 93 162 940 6816' Flow In (spm) 190 Gallons/stroke 4.3180 Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I 7300' 9.25 9.30 27 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 200 Hughes MXL-1X 12.25 1.071 24.50 3911' 3454' 0' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 3811' to 5000' 141 112 12163 BG 5000' to 6000' 215 120 20206 BG 6000' to 6800' 265 140 26103 BG 6800' to 6832' 940 420 93896 61 3 GP 6832' to 7230' 275 180 27216 BG to to to to Gas Type abreviations: BG - Background Gas; GP- Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... i ' 24 hr Recap: Drilled ahead from 5309', 00:01 on 1/27/10 to 7265'at 04:00, 12/28/2010. One gas peak of 940 units from 6816'. No connection gases observed. Logging Engineers: Tom Mansfield/Dan Sherwood * 10000 units = 100% Gas In Air I I I Customer: BP Exploration, Inc. Report#: 7 HALLIBURTON Well: AGI-01A Date: 1/29/2010-04:00 Area: Prudhoe Bay 04:00 Depth 7551' Location: North Slope, AK Progress 24 hrs: 286' Sperry Drilling Services Rig: Doyon 14 Rig Activity: Tripping Job No.: AK-AM 0007054180 Report For: Bordes/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $26,295.56 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 111.0 489.0 7538' Flow In (gpm) na SPP (psi) na Gas (units) 0 85 203 7402' Flow In (spm) na Gallons/stroke 4.3180 • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I cyo 7300' 9.25 9.30 47 12.5 10 26 5.5 9.40 1,200 4.5 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 200 Hughes MXL-1X 12.25 1.071 28.36 3911' 7551' 3640' 22 79 1-WT-A-E-4-ER-BHA 300 Sec FMF3643Z LG 12.25 0.902 7551' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) _ - Gas Breakdown Gas(units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 7230' to 7393' 128 72 12603 tr BG 7393' to 7426' 200 158 19819 tr GP 7426' to 7551' 126 71 12431 tr BG to to to to to to Gas Type abreviations: BG- Background Gas; GP- Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drilled ahead to 7551' MD experiencing high torque while drilling. Circ out 3X before back reaming to 7440'and CBU 3X more for hole cleaning. Continued backreaming to 7250'. Checked for flow and pulled out of the hole to 6300'. Pumped dry job and pulled out to 13 3/8"shoe. Checked for flow again and POOH to BHA. L/D BHA and cleared rig floor. Logging Engineers: Tom Mansfield/Dan Sherwood * 10000 units = 100% Gas In Air I I I I f Customer: BP Exploration, Inc. Report#: 8 I HALLIBUR 1�r UN Well: AGI-01A Date: 1/30/2010-04:00 Area: Prudhoe Bay 04:00 Depth 7551' Location: North Slope, AK Progress 24 hrs: 0' Sperry Drilling Services Rig: Doyon 14 Rig Activity: Tripping In w/BHA 3 I Job No.: AK-AM 0007054180 Report For: Bordes/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $28,289.56 IROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) 519 SPP (psi) 1225 Gas (units) 102 85 116 3:47 a.m. Flow In (spm) 123 Gallons/stroke 4.3180 IMud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I I7552' 9.30 9.30 56 12.5 10 23 5.2 9.30 1,200 5.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition I 200 Hughes MXL-1X 12.25 1.071 28.36 3911' 7551' 3640' 22 79 1-WT-A-E-4-ER-BHA 300 Sec FMF3643Z LG 12.25 0.902 7551' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) Gas Breakdown I Depth Gas(units) Chromatograph (ppm) Maximum Average Cl C2 C3 C4 Tot C5 Tot Type 4600' to 6124' 116 85 11386 to I to to to I to to to I to Gas Type abreviations: BG- Background Gas; GP- Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... I24 hr Recap: Continue to lay down BHA. Clean and clear the rig floor. Make up Geopilot and MWD. Upload MWD, battery problem problem(low voltage). L/D and change out MWD. Make up ball catcher, circ sub, HWDP and jars,shallow test MWD. Pick up 5" I DP and RIH to 3866'. Slip and Cut Drilling line. WOW. RIH 3866'-4527'on tongs and spinner-hawks. Begin washing/reaming tight hole from 4600'. Logging Engineers: Tom Mansfield/Dan Sherwood * 10000 units = 100% Gas In Air I I I I I Customer: BP Exploration, Inc. Report#: 9 Hi LLlbuN l,uN Well: AGI-01A Date: 1/31/2010-04:00 Area: Prudhoe Bay 04:00 Depth 8241' Location: North Slope, AK Progress 24 hrs: 690' Sperry Drilling Services Rig: Doyon 14 Rig Activity: Circ Out to POOH Job No.: AK-AM 0007054180 _ Report For: Bordes/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $30,283.56 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na 52.0 252.0 7888' Flow In (gpm) 825 SPP (psi) 2625 Gas (units) 86 85 219 8235' Flow In (spm) 190 Gallons/stroke 4.3180 • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 8159' 9.40 9.40 46 16.3 9 18 4.8 9.00 1,200 5.5 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 Sec FMF3643Z LG 12.25 0.902 13.25 7551' 8241' 690' 5-10 120-165 Lithoiogy (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 7551' to 8010' 203 115 20216 BG 8010' to 8073' 79 51 7802 BG 8073' to 8090' 112 92 10676 6 2 GP 8090' to 8210' 62 48 3763 2 1 BG 8210' to 8241' 219 135 21911 35 4 GP to to to to Gas Type abreviations: BG- Background Gas; GP- Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F-- - Formation...; E--- Early... 24 hr Recap: Continue to RIH from 4527'-4600'.Wash and ream 4600'-7546'. 500 gpm, 50 rpm. Circulate bottoms up, 800 gpm, 120 rpm w/mud running over shakers. Established MWD ECD baseline. Drill ahead 7551'to report depth of 8241'. Circ bottoms up to POOH. Logging Engineers: Tom Mansfield/Dan Sherwood * 10000 units = 100% Gas In Air 1 I Customer: BP Exploration, Inc. Report#: 10 1ALLIBURTON Well: AGI-01A Date: 2/01/2010-03:00 Area: Prudhoe Bay 04:00 Depth 9429' Location: North Slope, AK Progress 24 hrs: 1188' Sperry Drilling Services Rig: Doyon 14 Rig Activity: Drilling Ahead Job No.: AK-AM 0007054180 Report For: Bordes/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $32,277.56 ROP & Gas: Current Avg 24 hr Max Max @ ft _ Current Pump & Flow Data: R.O.P. (ft/hr) 81.0 102.6 270.4 8383' Flow In (gpm) 805 SPP (psi) 2950 Gas (units) 680 1240 5884 8555' Flow In (spm) 187 Gallons/stroke 4.3180 • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I 9157' 9.70 9.80 48 15.0 11 28 5.0 9.40 1,200 7.5 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 Sec FMF3643Z LG 12.25 0.902 26.60 7551' 1873' 5-10 120-165 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) , Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 8241' to 8355' 357 253 34189 40 3 BG 8355' to 8460' 185 138 17738 138 18 6 BG 8460' to 8595' 5884 2228 276976 20311 8523' 3727' 1404 GP 8595' to 8742' 1780 1185 111354 8545 3790' 1821' 814 BG 8742' to 8780' 4312 3717 232722 20070 8541' 3821' 1624 GP 8780' to 9035' 3778 2133 229535 19860 8909' 4268' 1936 BG 9035' to 9390' 1907 855 101161 8870 4604' 2635' 1392 BG to to Hourly Gas max gas avg gas max gas avg gas max gas avg gas max gas avg gas 4a.m. 113' 62' 10a.m. 462' 218' 4 p.m. 3460' 1865' 10p.m. 1569' 965' 5a.m. 217' 180' 11a.m. 5884' 2317' 5 p.m. 1534' 789' 11p.m. 1430' 1035' 6a.m. 28' 10' 12a.m. 1175' 941' 6 p.m. 1500' 708' 12p.m. 862' 679' 7a.m. 357' 227' 1 p.m. 1055' 866' 7 p.m. 3509' 1852' 1 a.m. 799' 557' 8a.m. 207' 136' 2 p.m. 931' 729' 8 p.m. 3778' 1907' 2 a.m. 618' 495' 9a.m. 184' 119' 3 p.m. 4312' 1980' 9 p.m. 2833' 1866' 3 a.m. 685' 405' Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drilled to 8241'. Circulated to POOH due to high torque. Did not POOH. Set Rotary Torque limit up to 22K. Drilled 8241'to 8652'with 5884 gas units from 8555', gas cut mud from 9.5 to 8.6 ppg. Increased torque limit to 25K. Increased mud weight to 9.7 ppg. Drilling ahead. Logging Engineers: Tom Mansfield/Dan Sherwood * 10000 units = 100% Gas In Air I I Customer: BP Exploration, Inc. Report#: 11 rIALLIBURTOI ' Well: AGI-01A Date: 2/02/2010-03:00 Area: Prudhoe Bay 04:00 Depth 10180' Location: North Slope, AK Progress 24 hrs: 751' Sperry Drilling Services Rig: Doyon 14 Rig Activity: Drilling Ahead Job No.: AK-AM 0007054180 Report For: Bordes/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $34,271.56 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 81.0 102.6 270.4 8383' Flow In (gpm) 820 SPP (psi) 3000 Gas (units) 17 1240 3360 10119' Flow In (spm) 187 Gallons/stroke 4.3180 • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) _ cP (Ib/100ft2) ml/30min mg/I % 9157' 10.10 10.20 48 15.0 11 26 5.0 9.00 1,100 9.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 Sec FMF3643Z LG 12.25 0.902 35.00 7551' 10180' 2629' 5-10 120-165 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average Cl C2 C3 C4 Tot C5 Tot Type 9340' to 9436' 793 736 3576 2368 685 414 102 BG 9436' to 9525' 1032 1024 4212 3098 516 321 83 BG 9525' to 9619' 890 866 2075 1444 518' 241' 111 GP 9619' to 9713' 1324 1296 3567 2134 774' 443' 166 BG 9713' to 9808' 3345 3235 8176 4514 1207' 880' 316 GP 9808' to 9902' 1390 1331 3165 2786 943' 420' 178 BG 9902' to 9997' 790 683 1734 1432 615' 360' 105 BG 9997' to 10091' 858 831 3845 2891 945' 170' 181 BG 10091' to 10180' 3360 3319 5713 4612 1243 870 256 GP Hourly Gas max gas avg gas max gas avg gas max gas avg gas max gas avg gas 4a.m. 637' 623' 10a.m. 2343' 2311' 4 p.m. 3460' 1865' 10p.m. 1569' 965' 5a.m. 639' 611' 11a.m. 3311' 2317' 5 p.m. 897' 876' 11p.m. 2832' 2716' 6a.m. 581' 541' 12a.m. 1512' 1478' 6 p.m. 843' 841' 12p.m. 1022' 1021' 7a.m. 843' 821' 1 p.m. 908' 902' 7 p.m. 429' 428' 1 a.m. 400' 389' 8a.m. 311' 300' 2 p.m. 434' 412' 8 p.m. 758' 754' 2 a.m. 321' 301' 9a.m. 1211' 1054' 3 p.m. 661' 653' 9 p.m. 1430' 1428' 3 a.m. 12' 10' Gas Type abreviations: BG - Background Gas; GP- Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T---Trip...; F-- - Formation...; E--- Early... 24 hr Recap: Drilling ahead drilled to 9.500 and weighted up mud from 9.7 to 10.1 Drilled to 10,180 and POOH at report time. Max gas 3,360 units at 10119 MD with back ground gas 3268 units. Logging Engineers: Dan Sherwood/Steven Jenkins * 10000 units = 100% Gas In Air I I Customer: BP Exploration, Inc. Report#: 12 HALLIBURTON Well: AGI-01A Date: 2/03/2010-03:00 Area: Prudhoe Bay 04:00 Depth 10180' Location: North Slope,AK Progress 24 hrs: N/A Sperry Drilling Services Rig: Doyon 14 Rig Activity: Circ and Recip Job No.: AK-AM 0007054180 Report For: Bordes/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $38,259.56 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) 531 SPP (psi) 1659 Gas (units) 0 227 765 11:45 Flow In (spm) 128 Gallons/stroke 4.3180 Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 10.20 10.20 47 15.0 11 25 3.8 9.20 1,100 10.0 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 Sec FMF3643Z LG 12.25 0.902 3.35 7551' 10180' 2629' 5-10 120-165 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) _ Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to to to to to to to to *Trip Gas Levels cannot be obtained to to fluid level in the possum belly IHourly Gas max gas avg gas max gas avg gas max gas avg gas max gas avg gas 4a.m. 85 84 10a.m. 76 63 4 p.m. 0 0 10p.m. 0 0 1 5a.m. 85 83 11a.m. 765 761 5 p.m. 0 0 11p.m. 0 0 6a.m. 85 83 12a.m. 134 131 6 p.m. 0 0 12p.m. 0 0 7a.m. 85 83 1 p.m. 242 240 7 p.m. 0 0 1 a.m. 0 0 1 8a.m. 79 75 2 p.m. 20 15 8 p.m. 0 0 2 a.m. 0 0 9a.m. 78 74 3 p.m. 15 10 9 p.m. 0 0 3 a.m. 0 Gas Type abreviations: BG- Background Gas; GP- Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: washed down the stand , at 800 gpm shut pumps down to montior well , pumped slug POOH , layed down BHA In prepartion Logging Engineers: Dan Sherwood/Steven Jenkins * 10000 units = 100% Gas In Air I I Customer: BP Exploration, Inc. Report#: 13 HALLIBURTON Well: AGI-01A Date: 2/06/2010-03:00 Area: Prudhoe Bay 04:00 Depth 10180' Location: North Slope, AK Progress 24 hrs: N/A Sperry Drilling Services Rig: Doyon 14 Rig Activity: Running casing Job No.: AK-AM 0007054180 Report For: Bordes/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $42,247.56 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) _ Flow In (gpm) 531 SPP (psi) 1659 Gas (units) 0 0 0 _ 0:00 Flow In (spm) 128 Gallons/stroke 4.3180 Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % 10.10 10.10 62 15.0 10 23 3.8 8.80 1,100 10.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 Sec FMF3643Z LG 12.25 0.902 3.35 7551' 10180' 2629' 5-10 120-165 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to to to to to to to to *Trip Gas Levels cannot be obtained to to fluid level in the possum belly Hourly Gas max gas avg gas max gas avg gas max gas avg gas max gas avg gas 4a.m. 0 0 10a.m. 0 0 4 p.m. 0 0 10p.m. 0 0 5a.m. 0 0 11a.m. 0 0 5 p.m. 0 0 11p.m. 0 0 6a.m. 0 0 12a.m. 0 0 6 p.m. 0 0 12p.m. 0 0 7a.m. 0 0 1 p.m. 0 0 7 p.m. 0 0 1 a.m. 0 0 8a.m. 0 0 2 p.m. 0 0 8 p.m. 0 0 2 a.m. 0 0 9a.m. 0 0 3 p.m. 0 0 9 p.m. 0 0 3 a.m. 0 0 Gas Type abreviations: BG- Background Gas; GP- Gas Peak; CG -Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F-- - Formation...; E--- Early... 24 hr Recap: Cont to Monitor flow and gas while circulating running casing, set plug at report time . Logging Engineers: Dan Sherwood/Steven Jenkins * 10000 units= 100% Gas In Air I 1 Customer: BP Exploration, Inc. Report#: 14 HALLIBURTOI Well: AGI-01A Date: 2/06/2010-03:00 Area: Prudhoe Bay 04:00 Depth 10180' Location: North Slope, AK Progress 24 hrs: N/A Sperry Drilling Services Rig: Doyon 14 Rig Activity: Tripping in Job No.: AK-AM 0007054180 Report For: Fregeuson/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $44,241.56 i . ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) 531 SPP (psi) 1659 Gas (units) 0 0 0 0:00 Flow In (spm) 128 Gallons/stroke 4.3180 Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 10.10 10.10 58 2.5 3 21 3.8 8.80 40,000 3.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 300 Sec FMF3643Z LG 12.25 0.902 3.35 7551' 10180' 2629' 5-10 120-165 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl _ Tuff (current) Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to to to to to to to to *Trip Gas Levels cannot be obtained to to fluid level in the possum belly Hourly Gas max gas avg gas max gas avg gas max gas avg gas max gas avg gas 4a.m. 0 0 10a.m. 0 0 4 p.m. 0 0 10p.m. 0 0 5a.m. 0 0 11a.m. 0 0 5 p.m. 0 0 11p.m. 0 0 6a.m. 0 0 12a.m. 0 0 6 p.m. 0 0 12p.m. 0 0 7a.m. 0 0 1 p.m. 0 0 7 p.m. 0 0 1 a.m. 0 0 8a.m. 0 0 2 p.m. 0 0 8 p.m. 0 0 2 a.m. 0 0 9a.m. 0 0 3 p.m. 0 0 9 p.m. 0 0 3 a.m. 0 0 Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: to 3,219'MD performed stippping drill ,tripping in at report time. Logging Engineers: Steven Jenkins/Mark Lindloff * 10000 units = 100% Gas In Air I Customer: BP Exploration, Inc. Report#: 15 HALLIBURTON Well: AGI-01A Date: 2/06/2010-03:00 Area: Prudhoe Bay 04:00 Depth 10623' Location: North Slope, AK Progress 24 hrs: N/A Sperry Drilling Services Rig: Doyon 14 Rig Activity: Drilled to TD Job No.: AK-AM 0007054180 Report For: Fregeuson/Kobuk/Maskle Daily Charges $1,994.00 Total Charges: $46,235.56 ROP & Gas: Current Avg 24 hr Max Max @ it Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 67.0 _ 341.0 10414' Flow In (gpm) 555 SPP (psi) 1659 Gas (units) 12 1120 6023 10525 Flow In (spm) 128 Gallons/stroke 4.3180 Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 8.90 8.90 48 2.5 3 21 3,8 8.80 40,000 3.0 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 Sec FMF3643Z LG .259.65 0.902 10.65 10180' 10620' 440' 5-10 120-165 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 10180' to 10290' 3375 3245 3955 1501 511 211 67 10290' to 10387' 2211 2210 3838 1331 311 210 65 10387' to 10477' 1537 1324 2389 1987 147' 98' 31 10477' to 10573' 6032 5736 6713 2987 1089' 489' 96 10573' to 10623' 4321 1543 1245 768 432' 211' 56 to to 8 to *Trip Gas Levels cannot be obtained to to fluid level in the possum belly Hourly Gas max gas max gas avg gas max gas avg gas max gas avg gas 4a.m. 8 4 10a.m. 318 315 4 p.m. 3276 3271 10p.m. 6023 5768 5a.m. 7 3 11a.m. 360 345 5 p.m. 1654 1632 11p.m. 1290 1145 6a.m. 4 2 12a.m. 2311 2112 6 p.m. 1043 1023 12p.m. 87 78 7a.m. 0 0 1 p.m. 40 31 7 p.m. 1054 1032 1 a.m. 45 41 8a.m. 0 0 2 p.m. 2010 1971 8 p.m. 674 651 2 a.m. 65 65 9a.m. 2451 2411 3 p.m. 5832 5671 9 p.m. 1923 1897 3 a.m. 0 0 Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG- Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: to 3,219'MD performed stippping drill , tripping in at report time. Logging Engineers: Steven Jenkins/Mark Lindloff * 10000 units= 100% Gas In Air I I N Y I o o c N m • d d m o, co O• m `-' I 0 T. _o m at a Z Q r� a'- a a z Q w o 0 o m m m O W H D H Q Q y z- 4 4 4 U w d w w 0 d < < a Co Z i i i I a 2 t7 x E o v o 0 N W O Ln O r r co CO J I LL a x 0 cD 0 0 U a ddC 0 coo 0o C N ` N N N O co to K o O m CL E 8 w coo m a q w T a ?j N I a to a W a O o m ' O U aO O N E N LO a > 0 0-i O O • ~ m Zly J }a Q m c0 sr CNI (0 W a W Q O a LL o 0 0 0 co F V 7 0 M 00 M• d CO O co N V r 1 O) as N M O a ,0 co O M N LL Q 7 u� CO N C O M � 0 CO C I 1 o 0 CO CI d 0 M N N N N I CE 1 Ce 'Q O Q c,a a , 1 T V Lil y N M m Ce X X m u_ m m J0) 01 0 0 tIc M N M W m N CO •O N M I I I o Y N N 10 L L co I N M >N >, C m N N Q < N ca @ > .N = 2 (� m L L m = L L L C C U o_J < < am < < < < o o) 3 O) m m m a) 3 C o) m, m e C C)W te I oomio ` o � 0 � Maa x $ 0 0 0 0 0 0 0 0 0 0 0 0 0 N m N 0 0 0 N O UO UD UD UO UD UD UO _ o M , V M N N N N N N N I 16 p. 0000000000000 M o 6666666666666 O N ',50000000000000 (�) 0 Z Z Y )p M E N 0 4, t A n 0 C.) 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M M N M V n N N N N N N 0) {� r C R 1 MI r •Y a O 0i 0i 0i Oi Oi O 0 0 0 0 O UD () 'y 'p J 3 ' Cr)0! L t O m N N O N M O O O O O M G) r+ 0 M n U) )O 47 O n co co co co co CV •N U 00 ate.. J �/ m . 0 CO N- N CO 0M) 0 0 0 0 0 0 0 (n - ') _ Q C. �� Q '+ t0 M i V _ Y C C C C C C L L L L L L 9 00 ? lL ll IL L� lL ll LL 0 c0 n UD N O N M C A c0 I� N N N N M M I I 1 I North America - ALASKA - BP fPrudhoe Bay (various) AGI ' AGI-01 AGI-01A ' Design: AGI-01A I Survey Report - Geographic 11 February, 2010 I I I Survey Report-Geographic ICompany: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P IProject Prudhoe Bay(various),GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point IMap Zone: Alaska Zone 04 Using geodetic scale factor Site AGI,TR-12-14 Site Position: Northing: 5,973,288.42ft Latitude: 70°19'55.268 N From: Map Easting: 685,006.87ft Longitude: 148°29'57.054 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.41 ° IWell AGI-01 API No. 500292230700 Well Position +N/-S 0.00 ft Northing: 5,979,223.82 ft Latitude: 70°20'52.673 N +E/-W 0.00 ft Easting: 688,901.48 ft Longitude: 148°27'58.998 W IPosition Uncertainty 0.00 ft Wellhead Elevation: 13.40 ft Ground Level: 13.40 ft Wellbore AGI-01A API No 500292230701 III Magnetics Model Name Sample Date Declination Dip Angle Field Strength O (°) (nT) BGGM2009 1/1/2010 22.49 80.99 57,690 I Design AGI-01A Audit Notes: 20100209 Setup definitive survey.Deleted prototype plan and set principal plan to prototype.Awaiting liner set depth then will load casings and ger IVersion: 1.0 Phase: ACTUAL Tie On Depth: 3,886.40 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) 34.30 0.00 0.00 93.74 Survey Program Date: 2/11/2010 I From To (ft) (ft) Survey(Wellbore) Tool Name Description 48.80 3,886.40 2:Schlumberger GCT multishot(AGI-01) GCT-MS Schlumberger GCT multishot I 3,915.00 7,495.56 MWD+IFR+MS Run 200(AGI-01A) MWD+IFR+MS MWD+IFR+Multi Station 7,515.32 10,151.67 MWD+IFR+MS Run 300(AGI-01A) MWD+IFR+MS MIND+IFR+Multi Station 10,228.78 10,560.76 MWD+IFR+MS Run 400(AGI-01A) MWD+IFR+MS MWD+IFR+Multi Station 1 I I I 2/11/2010 10:45:59AM Page 2 COMPASS 2003.16 Build 71 Survey Report-Geographic ICompany: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P ISurvey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-5 +E/-W Northing Easting I (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 34.30 0.00 0.00 34.30 0.00 0.00 5,979,223.82 688,901.48 70°20'52.673 N 148°27'58.998 W 48.80 0.20 294.30 48.80 0.01 -0.02 5,979,223.83 688,901.46 70°20'52.673 N 148°27'58.998 W 52.20 0.20 288.50 52.20 0.01 -0.03 5,979,223.83 688,901.45 70°20'52.673 N 148°27'58.999 W 63.00 0.20 277.10 63.00 0.02 -0.07 5,979,223.84 688,901.41 700 20'52.673 N 148°27'59.000 W 80.30 0.20 258.30 80.30 0.02 0.13 5,979,223.84 688,901.35 70°20'52.673 N 148°27'59.002 W 98.50 0.20 238.50 98.50 0.00 -0.19 5,979,223.81 688,901.29 70°20'52.673 N 148°27'59.003 W 116.80 0.20 211.10 116.80 -0.05 -0.23 5,979,223.77 688,901.25 70°20'52.672 N 148°27'59.005 W 134.90 0.20 185.60 134.90 -0.10 -0.25 5,979,223.71 688,901.23 70°20'52.672 N 148°27'59.005 W 153.20 0.20 160.60 153.20 0.17 0.24 5,979,223.65 688,901.24 70°20'52.671 N 148°27'59.005 W 171.40 0.20 138.00 171.40 -0.22 -0.21 5,979,223.59 688,901.27 70°20'52.671 N 148°27'59.004 W 189.80 0.20 115.60 189.80 -0.26 -0.16 5,979,223.56 688,901.32 70°20'52.670 N 148°27'59.002 W 208.10 0.30 97.00 208.10 -0.28 -0.09 5,979,223.54 688,901.40 70°20'52.670 N 148°27'59.000 W 226.50 0.30 84.30 226.50 0.28 0.01 5,979,223.54 688,901.50 70°20'52.670 N 148°27'58.997 W 244.90 0.30 72.80 244.90 -0.26 0.10 5,979,223.56 688,901.59 70°20'52.670 N 148°27'58.995 W 263.40 0.30 63.50 263.40 -0.22 0.19 5,979,223.60 688,901.68 70°20'52.671 N 148°27'58.992 W I 281.70 300.10 0.30 52.10 281.70 -0.17 0.27 5,979,223.65 688,901.76 70°20'52.671 N 148°27'58.990 W 0.30 45.60 300.10 -0.11 0.35 5,979,223.72 688,901.83 70°20'52.672 N 148°27'58.988 W 318.40 0.30 40.40 318.40 -0.04 0.41 5,979,223.79 688,901.89 70°20'52.672 N 148°27'58.986 W 336.70 0.30 32.20 336.70 0.04 0.47 5,979,223.87 688,901.95 70°20'52.673 N 148°27'58.984 W I 355.00 0.30 22.90 355.00 0.12 0.51 5,979,223.95 688,901.99 70°20'52.674 N 148°27'58.983 W 373.30 0.30 10.30 373.30 0.21 0.54 5,979,224.05 688,902.01 70°20'52.675 N 148°27'58.982 W 391.70 0.30 353.30 391.70 0.31 0.54 5,979,224.14 688,902.02 70°20'52.676 N 148°27'58.982 W 410.20 0.40 328.50 410.20 0.41 0.50 5,979,224.24 688,901.97 70°20'52.677 N 148°27'58.983 W 428.60 0.30 316.80 428.60 0.50 0.44 5,979,224.33 688,901.90 70°20'52.678 N 148°27'58.985 W 447.00 0.30 301.70 447.00 0.56 0.36 5,979,224.39 688,901.83 70°20'52.678 N 148°27'58.987 W 465.40 0.30 287.70 465.40 0.60 0.28 5,979,224.43 688,901.74 70°20'52.679 N 148°27'58.990 W 483.80 0.30 280.30 483.80 0.63 0.18 5,979,224.45 688,901.65 70°20'52.679 N 148°27'58.992 W 502.00 0.30 275.70 501.99 0.64 0.09 5,979,224.46 688,901.55 70°20'52.679 N 148°27'58.995 W 520.40 0.30 272.40 520.39 0.65 -0.01 5,979,224.46 688,901.46 70°20'52.679 N 148°27'58.998 W 538.60 0.30 270.70 538.59 0.65 -0.10 5,979,224.46 688,901.36 70°20'52.679 N 148°27'59.001 W 556.90 0.30 269.90 556.89 0.65 -0.20 5,979,224.46 688,901.27 70°20'52.679 N 148°27'59.004 W 575.00 0.20 268.60 574.99 0.65 -0.28 5,979,224.46 688,901.19 70°20'52.679 N 148°27'59.006 W 592.90 0.10 336.90 592.89 0.66 -0.31 5,979,224.47 688,901.15 70°20'52.679 N 148°27'59.007 W 610.90 0.20 17.00 610.89 0.71 0.31 5,979,224.52 688,901.15 70°20'52.680 N 148°27'59.007 W 628.70 0.30 8.70 628.69 0.78 -0.30 5,979,224.59 688,901.17 70°20'52.680 N 148°27'59.006 W 646.50 0.40 356.70 646.49 0.89 -0.29 5,979,224.70 688,901.17 70°20'52.681 N 148°27'59.006 W 664.40 0.40 342.80 664.39 1.01 -0.31 5,979,224.82 688,901.14 70°20'52.683 N 148°27'59.007 W 682.50 0.50 328.40 682.49 1.14 0.37 5,979,224.95 688,901.08 70°20'52.684 N 148°27'59.009 W 700.40 0.50 322.20 700.39 1.27 -0.46 5,979,225.08 688,900.99 70°20'52.685 N 148°27'59.011 W 718.40 0.50 317.70 718.39 1.39 -0.56 5,979,225.19 688,900.88 70°20'52.686 N 148°27'59.014 W 736.30 0.60 306.30 736.29 1.50 -0.69 5,979,225.30 688,900.75 70°20'52.687 N 148°27'59.018 W 754.20 0.60 278.20 754.19 1.57 0.86 5,979,225.37 688,900.58 70°20'52.688 N 148°27'59.023 W 772.10 0.60 269.30 772.09 1.58 -1.05 5,979,225.37 688,900.39 70°20'52.688 N 148°27'59.028 W 790.00 0.60 266.00 789.99 1.57 -1.23 5,979,225.36 688,900.21 70°20'52.688 N 148°27'59.034 W 808.00 0.60 263.30 807.99 1.56 -1.42 5,979,225.34 688,900.02 70°20'52.688 N 148°27'59.039 W 825.90 0.50 262.60 825.89 1.54 -1.59 5,979,225.31 688,899.85 70°20'52.688 N 148°27'59.044 W 843.80 0.50 262.70 843.78 1.52 -1.75 5,979,225.29 688,899.70 70°20'52.688 N 148°27'59.049 W 861.90 0.40 270.40 861.88 1.51 -1.89 5,979,225.28 688,899.55 70°20'52.688 N 148°27'59.053 W 879.90 0.60 309.30 879.88 1.57 -2.02 5,979,225.33 688,899.42 70°20'52.688 N 148°27'59.057 W 897.80 0.50 316.20 897.78 1.68 -2.15 5,979,225.45 688,899.29 70°20'52.689 N 148°27'59.061 W 915.80 0.30 327.40 915.78 1.78 -2.23 5,979,225.54 688,899.21 70°20'52.690 N 148°27'59.063 W 933.80 0.30 326.30 933.78 1.86 -2.28 5,979,225.62 688,899.15 70°20'52.691 N 148°27'59.064 W I 951.80 0.20 312.70 951.78 1.92 -2.33 5,979,225.68 688,899.10 70°20'52.692 N 148°27'59.066 W 969.70 0.30 198.10 969.68 1.89 -2.37 5,979,225.65 688,899.06 70°20'52.691 N 148°27'59.067 W 987.80 0.50 151.30 987.78 1.78 -2.35 5,979,225.54 688,899.09 70°20'52.690 N 148°27'59.066 W 2/11!2010 10:45:59AM Page 3 COMPASS 2003.16 Build 71 Survey Report-Geographic Company: North America-ALASKA-BP Local Coordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(0-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P ISurvey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1,005.80 0.80 134.10 1,005.78 1.62 -2.22 5,979,225.39 688,899.22 70°20'52.689 N 148°27'59.063 W 1,023.80 1.10 122.80 1,023.78 1.44 -1.98 5,979,225.21 688,899.46 70°20'52.687 N 148°27'59.056 W 1,041.90 1.40 117.80 1,041.87 1.25 -1.64 5,979,225.02 688,899.81 70°20'52.685 N 148°27'59.046 W I 1,060.00 1.70 115.40 1,059.97 1.03 -1.20 5,979,224.82 688,900.25 70°20'52.683 N 148°27'59.033 W 1,077.80 1.90 114.10 1,077.76 0.79 0.69 5,979,224.60 688,900.77 70°20'52.681 N 148°27'59.018 W 1,095.60 2.20 113.00 1,095.55 0.54 -0.11 5,979,224.36 688,901.36 70°20'52.678 N 148°27'59.001 W 1,113.50 2.40 111.40 1,113.43 0.27 0.55 5,979,224.10 688,902.03 70°20'52.675 N 148°27'58.982 W 1,131.20 2.60 110.70 1,131.12 -0.01 1.27 5,979,223.84 688,902.75 70°20'52.673 N 148°27'58.960 W 1,149.20 2.70 109.20 1,149.10 0.29 2.06 5,979,223.58 688,903.54 70°20'52.670 N 148°27'58.938 W 1,167.00 2.90 108.10 1,166.87 -0.57 2.88 5,979,223.32 688,904.37 70°20'52.667 N 148°27'58.914 W 1,185.00 3.30 107.10 1,184.85 -0.86 3.81 5,979,223.05 688,905.31 70°20'52.664 N 148°27'58.886 W I 1,202.80 3.60 106.50 1,202.62 -1.17 4.83 5,979,222.77 688,906.34 70°20'52.661 N 148°27'58.856 W 1,220.70 4.00 106.50 1,220.48 -1.51 5.97 5,979,222.46 688,907.49 70°20'52.658 N 148°27'58.823 W 1,238.70 4.30 106.10 1,238.43 -1.88 7.22 5,979,222.13 688,908.75 70°20'52.654 N 148°27'58.787 W 1,256.60 4.70 105.90 1,256.27 -2.26 8.57 5,979,221.77 688,910.11 70°20'52.650 N 148°27'58.747 W 1,274.60 4.90 105.30 1,274.21 -2.67 10.02 5,979,221.41 688,911.57 70°20'52.646 N 148°27'58.705 W 1,292.50 5.20 105.60 1,292.04 3.09 11.54 5,979,221.02 688,913.10 70°20'52.642 N 148°27'58.660 W 1,310.50 5.40 105.80 1,309.96 -3.54 13.14 5,979,220.61 688,914.71 70°20'52.638 N 148°27'58.614 W 1,328.40 5.60 105.60 1,327.78 -4.00 14.79 5,979,220.19 688,916.37 70°20'52.633 N 148°27'58.565 W I 1,348.80 5.70 105.50 1,348.08 -4.54 16.73 5,979,219.70 688,918.32 70°20'52.628 N 148°27'58.509 W 1,366.80 5.90 105.30 1,365.99 -5.02 18.48 5,979,219.26 688,920.08 70°20'52.623 N 148°27'58.458 W 1,384.70 6.10 104.90 1,383.79 -5.51 20.29 5,979,218.82 688,921.90 70°20'52.619 N 148°27'58.405 W 1,402.50 6.20 105.00 1,401.49 -6.00 22.13 5,979,218.38 688,923.75 70°20'52.614 N 148°27'58.351 W 1,420.10 6.40 104.70 1,418.98 -6.50 24.00 5,979,217.93 688,925.63 70°20'52.609 N 148°27'58.296 W 1,437.80 6.40 104.80 1,436.57 -7.00 25.91 5,979,217.48 688,927.55 70°20'52.604 N 148°27'58.241 W 1,455.50 6.60 104.60 1,454.16 -7.51 27.84 5,979,217.02 688,929.50 70°20'52.599 N 148°27'58.184 W 1,473.20 6.70 104.40 1,471.74 -8.02 29.83 5,979,216.55 688,931.50 70°20'52.594 N 148°27'58.126 W 1,490.90 6.70 104.70 1,489.32 -8.54 31.83 5,979,216.09 688,933.51 70°20'52.589 N 148°27'58.068 W 1,508.50 6.80 104.90 1,506.80 -9.07 33.83 5,979,215.61 688,935.52 70°20'52.584 N 148°27'58.009 W 1,526.20 6.90 105.00 1,524.37 -9.61 35.87 5,979,215.11 688,937.58 70°20'52.578 N 148°27'57.950 W 1,543.70 7.00 105.30 1,541.74 -10.17 37.91 5,979,214.61 688,939.63 70°20'52.573 N 148°27'57.890 W 1,561.30 7.30 105.60 1,559.21 -10.75 40.02 5,979,214.08 688,941.76 70°20'52.567 N 148°27'57.828 W ' 1,579.00 7.60 105.90 1,576.76 -11.37 42.23 5,979,213.52 688,943.98 70°20'52.561 N 148°27'57.764 W 1,596.60 8.00 105.90 1,594.19 12.03 44.53 5,979,212.92 688,946.30 70°20'52.554 N 148°27'57.697 W 1,614.20 8.70 106.00 1,611.61 -12.73 46.99 5,979,212.28 688,948.77 70°20'52.548 N 148°27'57.625 W 1,631.70 9.20 106.00 1,628.89 -13.48 49.60 5,979,211.59 688,951.40 70°20'52.540 N 148°27'57.548 W 1,649.30 9.80 105.90 1,646.25 -14.28 52.40 5,979,210.87 688,954.22 70°20'52.532 N 148°27'57.467 W 1,667.00 10.20 106.00 1,663.68 15.12 55.35 5,979,210.10 688,957.19 70°20'52.524 N 148°27'57.380 W 1,684.60 10.50 106.20 1,681.00 -16.00 58.39 5,979,209.30 688,960.25 70°20'52.515 N 148°27'57.292 W 1,702.50 10.70 106.50 1,698.59 -16.93 61.55 5,979,208.45 688,963.43 70°20'52.506 N 148°27'57.199 W 1,720.00 11.00 107.00 1,715.78 -17.88 64.70 5,979,207.58 688,966.61 70°20'52.497 N 148°27'57.107 W 1,737.60 11.20 107.30 1,733.05 18.88 67.94 5,979,206.66 688,969.87 70°20'52.487 N 148°27'57.012 W 1,755.20 11.30 107.60 1,750.31 -19.91 71.22 5,979,205.72 688,973.17 70°20'52.477 N 148°27'56.917 W 1,772.60 11.40 107.70 1,767.37 -20.94 74.48 5,979,204.76 688,976.46 70°20'52.467 N 148°27'56.821 W I 1,790.40 11.60 107.70 1,784.81 -22.02 77.86 5,979,203.77 688,979.87 70°20'52.456 N 148°27'56.723 W 1,807.80 11.90 107.10 1,801.85 -23.08 81.24 5,979,202.79 688,983.27 70°20'52.446 N 148°27'56.624 W 1,825.30 12.20 106.70 1,818.96 -24.14 84.74 5,979,201.82 688,986.79 70°20'52.435 N 148°27'56.522 W 1,842.80 12.70 105.80 1,836.05 -25.20 88.36 5,979,200.86 688,990.44 70°20'52.425 N 148°27'56.416 W I 1,860.30 13.20 104.90 1,853.11 -26.24 92.14 5,979,199.92 688,994.25 70°20'52.415 N 148°27'56.305 W 1,877.90 13.90 103.50 1,870.22 -27.25 96.14 5,979,199.01 688,998.27 70°20'52.405 N 148°27'56.188 W 1,895.40 15.00 101.30 1,887.16 -28.18 100.40 5,979,198.18 689,002.56 70°20'52.396 N 148°27'56.064 W 1,918.80 16.40 98.70 1,909.69 -29.27 106.64 5,979,197.24 689,008.82 70°20'52.385 N 148°27'55.882 W I 1,951.10 18.10 96.20 1,940.54 -30.51 116.14 5,979,196.25 689,018.34 70°20'52.373 N 148°27'55.604 W 1,990.10 19.30 95.00 1,977.48 -31.72 128.58 5,979,195.35 689,030.81 70°20'52.361 N 148°27'55.241 W 2,030.10 19.80 95.40 2,015.17 -32.94 141.91 5,979,194.47 689,044.17 70°20'52.349 N 148°27'54.851 W 1 2/11/2010 10:45:59AM Page 4 COMPASS 2003.16 Build 71 IISurvey Report-Geographic ICompany: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) 1 Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P ISurvey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting I (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2,071.00 20.80 96.10 2,053.53 -34.36 156.03 5,979,193.41 689,058.31 70°20'52.335 N 148°27'54.438 W 2,111.80 23.00 96.60 2,091.38 -36.05 171.15 5,979,192.10 689,073.47 70°20'52.318 N 148°27'53.997 W 2,152.50 25.00 96.00 2,128.56 -37.86 187.60 5,979,190.70 689,089.97 70°20'52.300 N 148°27'53.516 W 2,183.10 26.20 94.90 2,156.16 -39.11 200.76 5,979,189.78 689,103.15 70°20'52.288 N 148°27'53.131 W 2,202.40 27.30 93.50 2,173.39 39.75 209.43 5,979,189.37 689,111.83 70°20'52.282 N 148°27'52.878 W 2,221.80 28.20 91.80 2,190.56 -40.16 218.45 5,979,189.18 689,120.86 70°20'52.278 N 148°27'52.614 W 2,240.90 29.10 89.90 2,207.32 -40.30 227.61 5,979,189.28 689,130.02 70°20'52.276 N 148°27'52.347 W 2,260.10 29.80 88.00 2,224.04 -40.12 237.04 5,979,189.69 689,139.44 70°20'52.278 N 148°27'52.071 W 2,279.10 30.40 86.30 2,240.48 39.65 246.56 5,979,190.40 689,148.95 70°20'52.283 N 148°27'51.793 W 2,298.10 30.70 85.10 2,256.84 -38.92 256.19 5,979,191.37 689,158.55 70°20'52.290 N 148°27'51.512 W 2,317.10 31.00 84.60 2,273.16 -38.05 265.89 5,979,192.49 689,168.23 70°20'52.298 N 148°27'51.228 W I 2,336.20 2,355.40 31.10 84.30 2,289.52 84.30 2,305.96 -37.09 275.70 5,979,193.69 689,178.01 70°20'52.308 N 148°27'50.942 W 31.10 -36.11 285.57 5,979,194.92 689,187.85 70°20'52.318 N 148°27'50.653 W 2,355.70 31.10 84.30 2,306.22 -36.09 285.72 5,979,194.94 689,188.00 70°20'52.318 N 148°27'50.649 W 2,357.50 31.20 84.40 2,307.76 -36.00 286.65 5,979,195.06 689,188.93 70°20'52.319 N 148°27'50.622 W I 2,367.60 2,383.30 31.20 84.70 2,316.40 84.80 2,329.83 35.50 291.86 5,979,195.68 689,194.12 70°20'52.323 N 148°27'50.469 W 31.10 -34.76 299.94 5,979,196.63 689,202.19 70°20'52.331 N 148°27'50.233 W 2,400.60 31.00 85.20 2,344.65 -33.98 308.83 5,979,197.63 689,211.05 70°20'52.338 N 148°27'49.973 W 2,419.20 31.00 85.50 2,360.60 -33.21 318.38 5,979,198.65 689,220.58 70°20'52.346 N 148°27'49.694 W I 2,439.40 31.00 86.00 2,377.91 -32.44 328.75 5,979,199.68 689,230.93 70°20'52.354 N 148°27'49.391 W 2,460.80 31.00 86.50 2,396.25 -31.72 339.75 5,979,200.68 689,241.90 70°20'52.361 N 148°27'49.070 W 2,483.10 31.10 87.20 2,415.36 -31.08 351.24 5,979,201.60 689,253.37 70°20'52.367 N 148°27'48.734 W 2,506.10 31.40 88.40 2,435.02 -30.63 363.16 5,979,202.36 689,265.27 70°20'52.371 N 148°27'48.386 W 2,529.00 31.60 90.00 2,454.55 -30.46 375.12 5,979,202.83 689,277.23 70°20'52.373 N 148°27'48.036 W 2,551.60 31.80 91.40 2,473.78 -30.60 387.00 5,979,202.98 689,289.10 70°20'52.372 N 148°27'47.689 W 2,577.80 32.40 92.30 2,495.97 -31.06 400.91 5,979,202.88 689,303.02 70°20'52.367 N 148°27'47.283 W 2,606.20 33.60 92.60 2,519.79 -31.72 416.37 5,979,202.61 689,318.49 70°20'52.361 N 148°27'46.831 W 2,634.60 35.20 92.00 2,543.22 -32.36 432.40 5,979,202.37 689,334.53 70°20'52.354 N 148°27'46.363 W 2,663.00 35.90 91.60 2,566.33 -32.88 448.90 5,979,202.27 689,351.04 70°20'52.349 N 148°27'45.880 W 2,691.50 36.10 91.70 2,589.39 -33.36 465.65 5,979,202.21 689,367.79 70°20'52.344 N 148°27'45.391 W 2,720.00 36.40 91.80 2,612.37 -33.87 482.49 5,979,202.12 689,384.64 70°20'52.339 N 148°27'44.899 W 2,748.50 36.60 92.10 2,635.28 -34.45 499.43 5,979,201.97 689,401.59 70°20'52.334 N 148°27'44.404 W 2,776.80 37.10 92.30 2,657.93 -35.10 516.39 5,979,201.75 689,418.56 70°20'52.327 N 148°27'43.908 W 2,805.30 37.70 92.40 2,680.57 35.81 533.69 5,979,201.47 689,435.87 70°20'52.320 N 148°27'43.403 W 2,834.40 38.30 92.20 2,703.50 -36.53 551.59 5,979,201.20 689,453.78 70°20'52.313 N 148°27'42.880 W 2,864.20 38.60 92.20 2,726.83 -37.24 570.11 5,979,200.96 689,472.31 70°20'52.306 N 148°27'42.339 W I 2,893.80 38.60 92.30 2,749.97 -37.97 588.56 5,979,200.70 689,490.77 70°20'52.299 N 148°27'41.799 W 2,923.30 38.70 92.40 2,773.01 38.72 606.97 5,979,200.41 689,509.19 70°20'52.292 N 148°27'41.261 W 2,952.80 39.10 92.40 2,795.96 -39.50 625.48 5,979,200.10 689,527.72 70°20'52.284 N 148°27'40.721 W 2,982.70 39.70 92.50 2,819.07 -40.31 644.44 5,979,199.77 689,546.69 70°20'52.276 N 148°27'40.167 W 3,012.20 40.30 92.50 2,841.67 -41.14 663.38 5,979,199.42 689,565.65 70°20'52.268 N 148°27'39.613 W 3,041.50 40.70 92.80 2,863.95 42.02 682.39 5,979,199.02 689,584.67 70°20'52.259 N 148°27'39.058 W 3,070.60 41.00 93.00 2,885.96 -42.98 701.40 5,979,198.53 689,603.70 70°20'52.250 N 148°27'38.502 W 3,099.70 41.30 93.20 2,907.87 -44.02 720.52 5,979,197.98 689,622.84 70°20'52.239 N 148°27'37.943 W I 3,128.90 41.60 93.20 2,929.76 -45.10 739.82 5,979,197.39 689,642.16 70°20'52.229 N 148°27'37.379 W 3,158.10 41.90 93.20 2,951.54 -46.18 759.23 5,979,196.79 689,661.59 70°20'52.218 N 148°27'36.812 W 3,187.10 42.50 93.20 2,973.03 -47.27 778.68 5,979,196.20 689,681.06 70°20'52.207 N 148°27'36.244 W 3,215.90 43.30 93.40 2,994.12 -48.40 798.25 5,979,195.56 689,700.65 70°20'52.196 N 148°27'35.672 W 3,244.90 43.90 93.70 3,015.12 -49.64 818.21 5,979,194.83 689,720.64 70°20'52.184 N 148°27'35.089 W 3,273.70 44.30 94.10 3,035.81 -51.00 838.21 5,979,193.97 689,740.66 70°20'52.171 N 148°27'34.504 W 3,302.70 44.40 94.70 3,056.54 -52.55 858.42 5,979,192.92 689,760.90 70°20'52.155 N 148°27'33.914 W 3,332.00 44.60 94.90 3,077.44 -54.27 878.89 5,979,191.72 689,781.40 70°20'52.138 N 148°27'33.316 W 3,361.00 45.00 94.70 3,098.02 -55.98 899.25 5,979,190.52 689,801.80 70°20'52.122 N 148°27'32.721 W 3,390.00 45.50 93.80 3,118.44 -57.51 919.79 5,979,189.52 689,822.37 70°20'52.107 N 148°27'32.121 W 3,419.00 45.80 92.50 3,138.71 -58.65 940.49 5,979,188.90 689,843.10 70°20'52.095 N 148°27'31.516 W 2/11/1010 10:45:59AM Page 5 COMPASS 2003.16 Build 71 1 Survey Report-Geographic ICompany: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) IWell: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P iSurvey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) C) C) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3,448.00 45.90 91.00 3,158.91 -59.28 961.29 5,979,188.79 689,863.90 70°20'52.089 N 148°27'30.908 W 3,476.90 46.00 89.50 3,179.00 -59.37 982.06 5,979,189.22 689,884.67 70°20'52.088 N 148°27'30.301 W 3,506.00 46.00 88.90 3,199.22 -59.08 1,002.99 5,979,190.04 689,905.58 70°20'52.091 N 148°27'29.689 W 3,535.20 45.90 88.60 3,219.52 -58.62 1,023.97 5,979,191.03 689,926.54 70°20'52.095 N 148°27'29.076 W 3,564.30 45.60 88.60 3,239.83 58.11 1,044.81 5,979,192.06 689,947.36 70°20'52.100 N 148°27'28.467 W 3,593.60 45.20 88.90 3,260.40 -57.66 1,065.67 5,979,193.04 689,968.20 70°20'52.105 N 148°27'27.858 W 3,622.90 44.90 89.20 3,281.10 -57.31 1,086.40 5,979,193.91 689,988.92 70°20'52.108 N 148°27'27.252 W I 3,652.20 44.90 89.50 3,301.85 -57.08 1,107.08 5,979,194.67 690,009.58 70°20'52.111 N 148°27'26.648 W 3,681.60 44.90 89.60 3,322.68 56.92 1,127.83 5,979,195.35 690,030.32 70°20'52.112 N 148°27'26.041 W 3,711.20 44.80 89.60 3,343.66 -56.77 1,148.71 5,979,196.02 690,051.19 70°20'52.114 N 148°27'25.431 W 3,740.70 44.30 89.30 3,364.69 -56.57 1,169.40 5,979,196.74 690,071.87 70°20'52.115 N 148°27'24.827 W 1 3,770.20 3,799.90 44.00 89.00 3,385.85 -56.27 1,189.95 5,979,197.57 690,092.40 70°20'52.118 N 148°27'24.226 W 44.10 89.00 3,407.20 -55.91 1,210.60 5,979,198.45 690,113.03 70°20'52.122 N 148°27'23.623 W 3,829.10 44.10 89.00 3,428.17 -55.55 1,230.91 5,979,199.31 690,133.33 70°20'52.125 N 148°27'23.029 W 3,858.00 44.20 89.10 3,448.90 -55.22 1,251.04 5,979,200.15 690,153.44 70°20'52.129 N 148°27'22.441 W I 3,886.40 3,915.00 44.10 89.20 3,469.28 -54.93 1,270.82 5,979,200.95 690,173.21 70°20'52.131 N 148°27'21.863 W 44.01 89.57 3,489.84 -54.71 1,290.71 5,979,201.66 690,193.08 70°20'52.134 N 148°27'21.282 W 4,003.46 42.30 92.32 3,554.37 -55.69 1,351.19 5,979,202.21 690,253.56 70°20'52.124 N 148°27'19.515 W 4,097.85 43.14 95.25 3,623.72 -59.92 1,415.07 5,979,199.58 690,317.53 70°20'52.082 N 148°27'17.648 W 4,193.15 43.18 98.13 3,693.25 -67.52 1,479.80 5,979,193.62 690,382.42 70°20'52.007 N 148°27'15.757 W 4,287.11 44.39 100.90 3,761.09 -78.28 1,543.90 5,979,184.48 690,446.77 70°20'51.901 N 148°27'13.883 W 4,382.09 46.18 97.63 3,827.92 -89.11 1,610.50 5,979,175.33 690,513.62 70°20'51.795 N 148°27'11.937 W 4,477.77 45.59 95.37 3,894.53 -96.90 1,678.74 5,979,169.27 690,582.03 70°20'51.718 N 148°27'9.943 W I 4,572.65 46.37 92.46 3,960.46 -101.54 1,746.80 5,979,166.34 690,650.18 70°20'51.672 N 148°27'7.955 W 4,667.39 46.01 91.64 4,026.05 -103.99 1,815.12 5,979,165.62 690,718.54 70°20'51.648 N 148°27'5.958 W 4,760.48 45.62 92.88 4,090.93 -106.62 1,881.82 5,979,164.67 690,785.28 70°20'51.622 N 148°27'4.009 W I 4,854.89 45.23 92.65 4,157.19 -109.86 1,948.99 5,979,163.12 690,852.51 70°20'51.590 N 148°27'2.047 W 4,948.39 44.77 94.08 4,223.31 -113.74 2,014.99 5,979,160.91 690,918.58 70°20'51.551 N 148°27'0.118 W 5,042.64 46.07 94.91 4,289.46 -119.01 2,081.91 5,979,157.33 690,985.61 70°20'51.499 N 148°26'58.163 W 5,136.60 45.47 93.99 4,355.01 -124.23 2,149.03 5,979,153.80 691,052.84 70°20'51.448 N 148°26'56.201 W 5,233.02 46.08 96.61 4,422.26 -130.62 2,217.82 5,979,149.15 691,121.76 70°20'51.385 N 148°26'54.191 W 5,326.33 46.60 94.91 4,486.68 -137.39 2,284.98 5,979,144.07 691,189.06 70°20'51.318 N 148°26'52.229 W 5,420.99 46.50 94.12 4,551.78 -142.80 2,353.49 5,979,140.39 691,257.68 70°20'51.265 N 148°26'50.227 W 5,514.75 46.31 94.44 4,616.44 147.87 2,421.20 5,979,137.03 691,325.50 70°20'51.215 N 148°26'48.249 W 5,609.09 45.31 95.18 4,682.19 -153.54 2,488.61 5,979,133.06 691,393.02 70°20'51.159 N 148°26'46.279 W I 5,702.51 46.66 94.69 4,747.11 -159.32 2,555.54 5,979,128.98 691,460.07 70°20'51.102 N 148°26'44.323 W 5,797.02 47.65 95.26 4,811.37 -165.33 2,624.57 5,979,124.71 691,529.23 70°20'51.042 N 148°26'42.306 W 5,892.82 47.87 94.20 4,875.78 171.17 2,695.25 5,979,120.64 691,600.03 70°20'50.984 N 148°26'40.241 W 5,987.70 46.33 93.00 4,940.36 -175.55 2,764.61 5,979,118.02 691,669.48 70°20'50.941 N 148°26'38.214 W 6,081.63 45.74 91.34 5,005.57 -178.11 2,832.17 5,979,117.16 691,737.07 70°20'50.916 N 148°26'36.240 W 6,176.52 47.07 91.65 5,071.00 -179.91 2,900.86 5,979,117.10 691,805.79 70°20'50.898 N 148°26'34.233 W 6,269.31 47.17 93.30 5,134.14 182.84 2,968.79 5,979,115.87 691,873.76 70°20'50.869 N 148°26'32.248 W 6,363.82 46.72 91.48 5,198.67 -185.73 3,037.78 5,979,114.73 691,942.80 70°20'50.840 N 148°26'30.232 W 6,458.71 46.43 93.95 5,263.90 -188.99 3,106.61 5,979,113.20 692,011.68 70°20'50.808 N 148°26'28.221 W I 6,551.89 46.01 95.13 5,328.37 -194.31 3,173.68 5,979,109.57 692,078.86 70°20'50.755 N 148°26'26.261 W 6,646.42 47.27 94.93 5,393.28 -200.33 3,242.14 5,979,105.28 692,147.44 70°20'50.696 N 148°26'24.261 W 6,741.03 46.11 96.00 5,458.17 -206.88 3,310.67 5,979,100.46 692,216.11 70°20'50.631 N 148°26'22.259 W 6,835.14 45.81 95.00 5,523.59 -213.37 3,378.00 5,979,095.67 692,283.59 70°20'50.567 N 148°26'20.291 W , 6,929.54 44.01 95.92 5,590.45 -219.70 3,444.34 5,979,091.01 692,350.06 70°20'50.504 N 148°26'18.353 W 7,023.08 43.89 95.89 5,657.79 -226.38 3,508.92 5,979,085.96 692,414.78 70°20'50.438 N 148°26'16.466 W 7,118.97 44.31 96.47 5,726.65 -233.57 3,575.26 5,979,080.45 692,481.28 70°20'50.367 N 148°26'14.527 W 7,213.35 46.16 96.45 5,793.11 -241.11 3,641.84 5,979,074.60 692,548.03 70°20'50.293 N 148°26'12.582 W I 7,307.00 47.38 94.69 5,857.26 -247.72 3,709.75 5,979,069.70 692,616.07 70°20'50.227 N 148°26'10.598 W 7,401.77 47.08 93.43 5,921.61 -252.64 3,779.14 5,979,066.52 692,685.56 70°20'50.179 N 148°26'8.570 W 7,495.56 46.40 94.28 5,985.89 -257.23 3,847.29 5,979,063.65 692,753.80 70°20'50.133 N 148°26'6.579 W 1 2/11/2010 10:45:59AM Page 6 COMPASS 2003.16 Build 71 Survey Report-Geographic ICompany: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) I Well: AGI-01 North Reference: True Wel lbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P ISurvey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 7,515.32 46.44 94.28 5,999.51 -258.30 3,861.56 5,979,062.94 692,768.10 70°20'50.123 N 148°26'6.162 W 7,609.39 45.64 93.90 6,064.81 -263.13 3,929.10 5,979,059.82 692,835.73 70°20'50.075 N 148°26'4.189 W 7,703.21 45.75 94.17 6,130.34 -267.86 3,996.08 5,979,056.78 692,902.80 70°20'50.028 N 148°26'2.232 W I 7,798.51 45.99 93.67 6,196.70 -272.53 4,064.32 5,979,053.83 692,971.14 70°20'49.982 N 148°26'0.238 W 7,893.14 46.23 93.14 6,262.30 -276.58 4,132.40 5,979,051.50 693,039.29 70°20'49.941 N 148°25'58.248 W 7,987.98 46.29 92.19 6,327.87 -279.77 4,200.84 5,979,050.04 693,107.79 70°20'49.910 N 148°25'56.249 W 8,081.89 46.00 92.52 6,392.94 -282.55 4,268.50 5,979,048.96 693,175.49 70°20'49.882 N 148°25'54.272 W I 8,178.39 45.64 93.02 6,460.19 -285.89 4,337.63 5,979,047.36 693,244.67 70°20'49.849 N 148°25'52.252 W 8,271.45 46.05 94.23 6,525.02 290.12 4,404.26 5,979,044.82 693,311.39 70°20'49.807 N 148°25'50.305 W 8,365.64 45.38 94.34 6,590.78 -295.16 4,471.49 5,979,041.48 693,378.73 70°20'49.757 N 148°25'48.340 W 8,459.53 46.27 95.38 6,656.21 -300.86 4,538.59 5,979,037.46 693,445.94 70°20'49.700 N 148°25'46.380 W I 8,553.69 45.66 95.66 6,721.66 -307.38 4,605.97 5,979,032.65 693,513.46 70°20'49.636 N 148°25'44.411 W 8,647.37 45.78 94.69 6,787.07 313.42 4,672.76 5,979,028.29 693,580.38 70°20'49.576 N 148°25'42.460 W 8,741.96 45.89 92.80 6,852.97 -317.85 4,740.46 5,979,025.57 693,648.17 70°20'49.532 N 148°25'40.481 W 8,835.24 43.88 92.53 6,919.06 -320.92 4,806.22 5,979,024.16 693,713.97 70°20'49.501 N 148°25'38.560 W I 8,928.83 41.80 94.60 6,987.69 -324.85 4,869.72 5,979,021.83 693,777.55 70°20'49.462 N 148°25'36.705 W 9,023.83 40.53 95.07 7,059.20 330.12 4,932.03 5,979,018.13 693,839.97 70°20'49.410 N 148°25'34.884 W 9,119.31 38.26 95.61 7,132.98 -335.75 4,992.36 5,979,014.02 693,900.42 70°20'49.354 N 148°25'33.121 W 9,211.22 35.91 95.31 7,206.30 -341.03 5,047.52 5,979,010.14 693,955.70 70°20'49.302 N 148°25'31.510 W I 9,306.09 33.51 95.88 7,284.28 -346.29 5,101.28 5,979,006.24 694,009.57 70°20'49.250 N 148°25'29.939 W 9,401.31 31.22 93.56 7,364.71 -350.51 5,152.07 5,979,003.29 694,060.44 70°20'49.208 N 148°25'28.455 W 9,496.21 29.02 92.91 7,446.79 -353.21 5,199.61 5,979,001.80 694,108.03 70°20'49.181 N 148°25'27.066 W 9,589.10 26.34 93.48 7,529.04 -355.60 5,242.69 5,979,000.49 694,151.16 70°20'49.157 N 148°25'25.807 W I 9,683.46 23.82 93.20 7,614.50 -357.94 5,282.62 5,978,999.16 694,191.13 70°20'49.134 N 148°25'24.641 W 9,778.34 21.91 93.68 7,701.92 360.14 5,319.42 5,978,997.88 694,227.97 70°20'49.112 N 148°25'23.565 W 9,870.78 19.94 94.56 7,788.26 -362.50 5,352.34 5,978,996.35 694,260.94 70°20'49.089 N 148°25'22.603 W 9,966.36 19.91 94.50 7,878.12 -365.08 5,384.81 5,978,994.60 694,293.47 70°20'49.063 N 148°25'21.655 W I 10,060.49 19.88 94.24 7,966.63 -367.52 5,416.75 5,978,992.97 694,325.45 70°20'49.039 N 148°25'20.721 W 10,151.67 20.03 96.48 8,052.33 -370.43 5,447.73 5,978,990.84 694,356.49 70°20'49.010 N 148°25'19.816 W 10,228.78 20.24 96.73 8,124.73 -373.48 5,474.10 5,978,988.45 694,382.93 70°20'48.980 N 148°25'19.046 W 10,322.50 19.90 97.18 8,212.76 -377.37 5,506.02 5,978,985.36 694,414.94 70°20'48.941 N 148°25'18.113 W 10,417.04 19.43 95.65 8,301.79 -380.93 5,537.63 5,978,982.60 694,446.63 70°20'48.906 N 148°25'17.190 W I 10,512.23 18.65 95.72 8,391.77 -384.01 5,568.54 5,978,980.31 694,477.59 70°20'48.876 N 148°25'16.287 W 10,560.76 18.27 95.72 8,437.80 385.54 5,583.83 5,978,979.16 694,492.92 70°20'48.861 N 148°25'15.840 W 10,623.00 18.27 95.72 8,496.90 -387.48 5,603.24 5,978,977.71 694,512.37 70°20'48.841 N 148°25'15.273 W I I I I I 2/11/2010 10:45:59AM Page 7 COMPASS 2003.16 Build 71 ISurvey Report-Geographic ICompany: North America-ALASKA-BP Local Co-ordinate Reference: Well AGI-01 Project: Prudhoe Bay(various) TVD Reference: AGI-01A @ 47.70ft(D-14) Site: AGI MD Reference: AGI-01A @ 47.70ft(D-14) 1 Well: AGI-01 North Reference: True Wellbore: AGI-01A Survey Calculation Method: Minimum Curvature Design: AGI-01A Database: EDM.16-Anc Prod-WH24P ITargets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting I -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude AGI-01A Target 0.00 0.00 8,507.70 -385.44 5,612.92 5,978,980.00 694,522.00 70°20'48.861 N 148°25'14.990 W -actual wellpath misses target center by 14.65ft at 10623.00ft MD(8496.90 TVD,-387.48 N,5603.24 E) II -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole I Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 10,621.00 8,495.00 7" 7.000 8.500 I10,162.00 8,062.04 95/8" 9.625 12.250 Checked By: Approved By: Date: I I I I I I I I I I 1 2/11/2010 10:45:59AM Page 8 COMPASS 2003.16 Build 71 I HALLIBURTDN I ;perry Drilling BP Exploration (Alaska ) Inc. AGI-01A I 1000 I ! I 1 - I 1 1 I . ■■_ . I 2000 — f RIH tag EZSV pump _D II out cement test cement plug POOH failed — - I � I r 1 -1- I r ...... 3000 I TD 12.5 In ermediate 41: i.._ I UNIMI11111111 ' ■r� PII Ea III _. I 4000 . I III III , 5000 — - .c I. .■■ . I 6000 L _ _. ta Ia) 1 2 Run/Cement 1 7000 _9 5/8"Surface _ Csg @'MO I i I 8000 , r I —Start 6 1/8"Produ:tion 9000 . . 1 / . . I 10000 TD AGI01A I 10623'MD 02-07-2010 I11000 1 I 1 ' 0 10 20 30 40 50 60 I Rig Days
