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Home My WebLink About208-1917. 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 05-27B Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-191 50-029-21979-02-00 13498 Surface Intermediate Liner Liner Liner 9055 3668 9494 1963 1096 3095 13228 13-3/8" 9-5/8" 7" 4-1/2" 2-3/8" 9035 32 - 3700 31 - 9525 9191 - 11154 10477 - 11573 10172 - 13267 32 - 3615 31 - 8501 8281 - 9060 8919 - 9046 8813 - 9033 10170 2670 4760 7020 7500 11780 None 4930 6870 8160 8430 11200 10814 - 13125 4-1/2" 12.6# x 3-1/2" 9.3# 13cr, L80 29 - 10496 9019 - 9041 Conductor 80 20" 32 - 112 32 - 112 1490 470 4-1/2" HES TNT Perm , 9332, 8376 No SSSV 9332 8376 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (9070 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 0028326, 0028329 29 - 8925 107 124 963 0 489 1372 1945 1945 324 316 325-509 13b. Pools active after work:PRUDHOE OIL 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 4:12 pm, Sep 25, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.09.24 14:16:36 - 08'00' Bo York (1248) RBDMS JSB 092925 J.Lau 11/5/25 ACTIVITYDATE SUMMARY 9/10/2025 LRS #1 1.5" 0.134WT HT-110 Objective: Drfit/Log Ext Adperf MIRU on Ds5-27, NU BOP's . MU PCE, MU & Test1.69" MHA. DHD Bleed IA to adjacent well. MU HES Logging tools. Trouble shoot sinking stabilizer/outriggers. 9/11/2025 T/I/O = SSV/1890/20. Temp = SI. Bleed IA to CLP (assist Coil). ALP = 1900 psi SI @ CV. Bled IAP to production of 05-24 from 1890 psi to 450 psi in 5.5 hrs. No monitor. Final WHP's = SSV/450/20. SV, WV, SSV = C. MV = O. IA, OA = OTG. 06:15 9/11/2025 LRS #1 1.5" 0.134WT HT-110 Objective: Drift/Log Ext Adperf Issue with Outriggers sinking into soft gravel on pad. Rig down to place rig mats & rig up again. Function Test BOPs. MU HES GR/CCL Logging BHA. PT Body 250/4100 psi. L/K well with 135 bbls of 1% KCl. Wel on a vac. Establish continous hole fill. RIH. Log from 11,100', Coil Flag at 10,600', Top of log at 9,200' POOH. Confirm good log data. Send correlation to OE. Spot Crane & Gun Trailer. *H2S/LEL monitors bump tested. PT safety joint. Well Control Drill with Day/Night Crew. ***Job In Progress*** 9/12/2025 LRS #1 1.5" 0.134WT HT-110 Objective: Drift/Log Ext Adperf PJSM for Ext add perf. Deploy 9, 1.56" Triton Guns, 6spf, 60deg phase. RIH. Perf interval 10,814-10,998'. POOH. At Surface, perform good No-Flow test. Pop off, Confirmed Shots Fired. Ball recovered. Undeploy (9), 1.56" Triton Guns. BD YJOS MHA. RDMO *H2S/LEL monitors bump tested. PT safety joint. Well Control Drill with Night Crew. Tagged up on the Brass. Well Control Drill with Day Crew. ***Job Complete*** Daily Report of Well Operations PBU 05-27B 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 05-27B Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-191 50-029-21979-02-00 341J ADL 0028326, 0028329 13498 Surface Intermediate Liner Liner Liner 9055 3668 9494 1963 1096 3095 13228 13-3/8" 9-5/8" 7" 4-1/2" 2-3/8" 9035 32 - 3700 31 - 9525 9191 - 11154 10477 - 11573 10172 - 13267 2500 32 - 3615 31 - 8501 8281 - 9060 8919 - 9046 8813 - 9033 10170 2670 4760 7020 7500 11780 None 4930 6870 8160 8430 11200 11495 - 13125 4-1/2" 12.6# x 3-1/2" 9.3# 13cr, L80 29 - 104969046 - 9041 Conductor 80 20" 32 - 112 32 - 112 1490 470 4-1/2" HES TNT Perm Packer No SSSV Installed 9332, 8376 Date: Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 9/8/2025 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 8:33 am, Aug 25, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.08.25 08:11:26 - 08'00' Bo York (1248) 325-509 JJL 8/25/25 10-404 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment DSR-8/26/25SFD 8/28/2025JLC 8/28/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.28 16:37:16 -08'00'08/28/25 RBDMS JSB 082925 Extended Add Perfs 05-27B PTD:208-191 Well Name:05-27B API Number:50-029-21979-02 Current Status:Operable - Producer Rig:CTU Estimated Start Date:9/8/25 Estimated Duration:2days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd:Check status Regulatory Contact:Carrie Janowski (907) 564-5179 First Call Engineer:David Bjork (907) 564-4672 (907) 440-0331 Current Bottom Hole Pressure:3,380 psi @ 8,800’ TVD 7.4 PPGE (offset producer 05-30) Max. Anticipated Surface Pressure:2,500psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:350 psi (Taken on 8/19/24) Min ID:1.81” @ 10,171’ MD Max Angle:96 Deg @ 11,849’ MD, 70 Deg at 10,337’ MD Brief Well Summary: 05-27B was sidetracked in March ‘09. The well is a gravity drainage Z1A lateral. Unswept Z1A remains unperforated. We would like to perforate the remaining footage in the heel. Objective:Perforate remaining unswept Z1A interval Procedure Coiled Tubing 1. MU drift BHA with GR/CCL in 1.69” carrier, drift to 11,100ft. Note: 1.81” ID at 10,171ft (liner top seal assembly). 2. Correlate with attached log information. a. Correct flag and send to OE for confirmation. Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead 1.2x wellbore volume ~150 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 113 bbls b. 4-1/2” tubing – 2,991’ X .0152 bpf = 45.5 bbls c. 3-1/2” tubing 2,991’ – 10,166’ X .0087bpf=62.4 bbls d. 2-3/8” liner 10,166’ – 11,495’ (top perf)’ X .00387bpf=5.1 bbls 3. At surface, prepare for deployment of TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Extended Add Perfs 05-27B PTD:208-191 Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 5.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. e.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 6.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 1.56”Millennium guns or similar (1.76” swell in liquid) Perf Interval (tie-in depths)Total Gun Length Weight of Gun (lbs) Run #1 10,814’ - 10,998’184’~736 lbs (4 ppf) 7. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE Schematic x Standing Orders x Equipment Layoutdiagram x Sundry Change Form Extended Add Perfs 05-27B PTD:208-191 Current Wellbore Schematic Extended Add Perfs 05-27B PTD:208-191 Proposed Wellbore Schematic 10,814’ - 10,998’ New Perforations Extended Add Perfs 05-27B PTD:208-191 Tie-in Log Extended Add Perfs 05-27B PTD:208-191 BOP Schematic Extended Add Perfs 05-27B PTD:208-191 Extended Add Perfs 05-27B PTD:208-191 Extended Add Perfs 05-27B PTD:208-191 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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: Extended Perforating Conductor Surface Intermediate Liner Liner 470 2370 4760 7020 11780 Structural 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: 13b. Pools active after work: 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 RBDMS JSB 033023 DSR-3/30/23 Perforate Sundry Number WCB 11-27-2023 Extended Perforating Adperf depths are correctly shown on the new WBS, below. -WCB 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 05-27B Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-191 50-029-21979-02-00 ADL 0028329 , 0028326 13267 Conductor Surface Intermediate Production Liner 9033 80 3667 9494 1963 3101 13228 20" 13-3/8" 9-5/8" 7" 2-3/8" 9035 32 - 112 33 - 3700 31 - 9525 9191 - 11154 10166 - 13267 2365 32 - 112 33 - 3615 31 - 8501 8281 - 9060 8811 - 9033 10170 470 2370 4760 7020 11780 none 1490 5380 6870 8160 11200 12010 - 13125 4-1/2" 12.6# x 3-1/2" 9.3# 13-CR x L-80 29 - 104969052 - 9041 Structural 4-1/2" HES TNT No SSSV 9332 8376 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3/15/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov / By Samantha Carlisle at 12:34 pm, Feb 22, 2023 323-115 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.22 10:44:42 -09'00' MGR23FEB23 9,055' DSR-2/22/23 CO 341J SFD SFD SFD 3/1/2023 2365 10-404 13,498' JLC 3/3/2023 3/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.03 09:19:35 -09'00' RBDMS JSB 030323 Well: 05-27B PTD:208-191 API:50-029-21979-02-00 Well Name:05-27B API Number:50-029-21979-02-00 Current Status:Online, Operable Rig:Service Coil Estimated Start Date:03/15/23 Estimated Duration:2days Regulatory Contact:Carrie Janowski 564-5179 First Call Engineer:David Bjork (907) 564-4672 (O)(907) 440-0331 (M) Second Call Engineer:Eric Dickerman (907) 564-4061 (O)(307) 250-4013 (M) Current Bottom Hole Pressure: 3,245 psi @ 8,800’ TVD 7.1 PPGE | SBHPS offsets 09/2021 Maximum Expected BHP:3,350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP) Max. Anticipated Surface Pressure:2,365psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1,650psi (Taken on 01/19/2023) Min ID:2.377” 3-1/2” x 2-7/8” XO @ 10,205’ MD Max Angle:93 Deg @ 10,840’ Tie In Log:SLB Mem CCL/GR/TNF/TNN (18 Sept 2010) Brief Well Summary: 05-27B is a horizontal Z1A gravity drainage producer coil sidetracked in 2009, located south of the grabben. Historically a low-rate producer but managed to stay online with a low GOR. Objectives: The objective of this procedure is to shoot Extended Adperf (two runs; 390’ and 40’ of guns) to increase the fluid rate. Procedure: Coiled Tubing Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead ~150 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 115 bbls b. 4-1/2” Tubing - 2991’ X .0152bpf = 46 bbls c. 3-1/2” Tubing – 7175’ X 0.0087 = 62 bbl d. 2-3/8” Liner – 1844’ X .0039bpf = 7 bbls 3. MU and RIH with logging tools 1.69 motor and 1-3/4” junk mill. Clean out to 13,125ft. 4. Flag pipe as appropriate per WSS for adperf/CBP runs. 5. POOH and freeze protect tubing as needed. Well: 05-27B PTD:208-191 API:50-029-21979-02-00 6. Confirm good log data. 7. At surface, prepare for deployment of TCP guns. 8. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 10.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule *HES 1-9/16” Millennium guns were used to estimate for this job and calculate gun weights. Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 12,840’-12,880’ 40’ 40’ 144lbs (3.62ppf) Run #2 11,495’-11,878’ 383’ 383’ 1411 (3.62ppf) 11. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 14. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 15. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 16. RDMO CTU. 17. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Mini Log 7. Tie In Log/Perf Sheet 8. Sundry Change Form Well: 05-27B PTD:208-191 API:50-029-21979-02-00 Current Wellbore Schematic Well: 05-27B PTD:208-191 API:50-029-21979-02-00 Proposed Wellbore Schematic Well: 05-27B PTD:208-191 API:50-029-21979-02-00 Coiled Tubing BOPs Well: 05-27B PTD:208-191 API:50-029-21979-02-00 Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: 05-27B PTD:208-191 API:50-029-21979-02-00 Equipment Layout Diagram Well: 05-27B PTD:208-191 API:50-029-21979-02-00 Tie In: Well: 05-27B PTD:208-191 API:50-029-21979-02-00 TOP OF PERF SECTION Well: 05-27B PTD:208-191 API:50-029-21979-02-00 BASE OF PERF SECTION Well: 05-27B PTD:208-191 API:50-029-21979-02-00 TOP OF PERF INTVL 2 BASE OF PERF INTVL 2 Well: 05-27B PTD:208-191 API:50-029-21979-02-00 Mini Log Well: 05-27B PTD:208-191 API:50-029-21979-02-00 x Most recent Well Test – 2/13/2023 – 75bopd, 412wpd, 0.3mmscfd By Anne Prysunka at 9:51 am, Sep 02, 2022 5HJJ-DPHV%2*& )URP$ODVND16$65:HOO6LWH0DQDJHUV$ODVND16$65:HOO6LWH0DQDJHUV#KLOFRUSFRP! 6HQW7KXUVGD\$XJXVW$0 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F$ODVND16$65:HOO6LWH0DQDJHUV 6XEMHFW%23WHVW3%8%WHVWUHSRUWDQGFKDUW $WWDFKPHQWV+LOFRUS$65[OV[%23(WHVW&KDUW%SGI &DWHJRULHV%OXH&DWHJRU\ dŚŝƐŝƐƚŚĞKWƚĞƐƚƌĞƉŽƌƚǁŝƚŚƚŚĞƚĞƐƚĐŚĂƌƚĨŽƌWhϬϱͲϮϳ͘^ŽƌƌǇǁĞĨŽƌŐŽƚƚŽƐĞŶĚƚŚĞĐŚĂƌƚǁŝƚŚƚŚĞƌĞƉŽƚŽŶƚŚĞ ůĂƐƚĞŵĂŝů dŚĂŶŬǇŽƵ ^Z^D͛Ɛ ,ŝůĐŽƌƉ^D͗ϵϬϳͲϲϴϱͲϭϮϲϲ ,ŝůĐŽƌƉůĂƐŬĂ͕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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:ASR 1 DATE: 8/9/22 Rig Rep.: Rig Phone: 685-1266 Operator: Op. Phone:685-1266 Rep.: E-Mail Well Name: PTD #22081910 Sundry #322-171 Operation: Drilling: Workover: x Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/2500 Valves:250/3000 MASP:2365 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16"P Inside Reel valves 0NA HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3075 P CHOKE MANIFOLD:Pressure After Closure (psi)1775 P Quantity Test Result 200 psi Attained (sec)18 P No. Valves 16 P Full Pressure Attained (sec)60 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4X 2187 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:5.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/7/2022 22:00 Waived By Test Start Date/Time:8/9/2022 3:00 (date) (time)Witness Test Finish Date/Time:8/9/2022 8:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Lou Laubenstein Hilcorp Tested with both 3.5" and 4.5" test joints . Annular closing time = 24 sec C. Pace / C. Greub Hilcorp Alaska A. Haberthur/ C. Huntington PBU 05-27B Test Pressure (psi): skaNS-ASR-Well Site Managers@hilcorp.c Form 10-424 (Revised 02/2022) 2022-0809_BOP_Hilcorp_ASR1_PBU_05-27B +LOFRUS1RUWK6ORSH 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ Annular closing time = 24 sec +LOFRUS1RUWK6ORSHK CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:David Bjork (david.bjork@hilcorp.com) Cc:DOA AOGCC Prudhoe Bay Subject:20220705 0843 APPROVAL to utilize ASR and 11" BOPE Stack PBU 05-27B RWO PTD 208-191 sundry 322-171 Date:Tuesday, July 5, 2022 9:24:55 AM Attachments:BOP Schematic Hilcorp ASR.pdf Sundry_322-171_042022.pdf David, Hilcorp is approved to utilize ASR and 11” BOPE stack. As described in the approved sundry, the BOPE stack will include: 1. Annular 2. 2-7/8” X 5” VBRs 3. Blind 4. Flow cross Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: David Bjork <David.Bjork@hilcorp.com> Sent: Thursday, June 30, 2022 10:28 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 05-27 RWO PTD 208-191 sundry 322-171 Mel, I would like to revise the sundry 322-171. We would like to perform this RWO with the Hilcorp ASR instead of the Thunderbird#1. The BOP stack will change to an 11”. The test pressures, VBR sizes, test joints and operational detail will not change. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~(~g - ~ ~ ~ Well History File Identifier Organizing (done) R CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: o,.o.,,, iuuiuiuaiuiii DI TAL DATA Diskettes, No. ^ Other, No/Type: NOTES: BY: Maria Date: Project Proofing BY: Maria Date: I Scanning Preparation _~_ x 30 = , BY: Maria Date: (~l` ~ ~ Production Scanning Stage 1 BY: Stage 7 BY: ae,~~~~ea iiiuiiinuiiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: / ^ Other:: `~ /s/ IIIII'IIIIIIfl IIIII I h + ~ =TOTAL PAGES (Count does not include cover sheet) (~ /s/ IIIIIIIIIIIIIIIIIII Page Count from Scanned File: _ ~L~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: ~ ~a,.,, ~~ ~s~ ~ 1 If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: ~siu n ^i n n~ n i i ni Scanning is complete at this point unless rescanning is required. Rescanned III IIIIIIIIIII II III BY: Maria Date: ~s~ Comments about this file: Quality Checked II I II IIII III II I) III 10/6/2005 Well History File Cover Page.doc 12/30/10 Scherier NO. 5672 Alaska Data & Consulting Services Company: State of Alaska 2525 Sambetl Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838/1 Attn: Christine Shartzer ATTN: Beth (1 333 West 7th Ave, Suite 100 / i ^ 6 Anchorage, AK 99501 1 � Job 4 Log Description Date BL Color CD E BL65 -00011 MEM DDL 12/18/10 1 1 3B AY1M -00056 PROD PROFILE a,„ —/ - 11/27/10 1 i e,i, 1 11 -12 BCZ2 -00033 1�. i :t.�yu - L•7DL '_T4 1 01 -25 BG4H -00022 INJECTION PROFILE 4 .W.AFP-IME I !� �2. 1 04 -24 AY1M -00058 PROD PROFILE PROFILE , iiaL iirammammignimt ._ 1 P2 -16 B -00077 keaMZ _ i V 1 A-41 BCZ2 -00030 LDL / • -- , 11 /26/10 1 04-08 BCRJ- 000566 INJECTION PR a FILE - -t' — 12/06/10 1 ► Weil 1 01 -24A BBSK -00043 ri,`a14∎4 .L'8J :lel3IUr .hirafir 4Y 1 04-10 AVIH -00051 rl 6144orco811:4.4948 ai erla rcu r mr —'y4 1 • 15 -26B BD88 -00080 MEM PROD PROFILE /S 7 — ignliammignEmirmAiri, 1 2. 28810 -19 BCRJ -00055 PROD PROFILE _ e — • a, - 11/30/10 1 tef.�' 11 1 07 -23B AY1M-00056 SCMT — 11/28/10 , 4 - 4 1 1 a 02 -21A BBSK -00042 SCMT /SL — 0-I 11/23/10 ! 1 1 02 -22B BL65 -00006 SCMT t n — 3 12/11/10 ,94, ; , 1 1 18 -128 BBUO -00029 SCMT 6 (,�p 08130/10 a 1 1 P2 -16 B5JN -00077 USIT l S 1 J PI 11/28/10 1 1 05 -27B BAUJ -00049 MCNL -)-O , — 1 09/18/10 16-06B BBSK -00037 RST _ • , - ♦ 11/15/10 V . , *,f"/ 1 8088 -00050 RST __ L} if 0 09/20/10 1 k 1 E -34L1 -34L1 B088 -00050 MCNL _ [] — J T Jj 09/28/10 1 1 W -219 8WV-00012 CH EDIT PDC -GR USIT — • 11122/10 a -, _ J 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Sanibel! Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 III DATA SUBMITTAL COMPLIANCE REPORT 4/612010 Permit to Drill 2081910 Well Name/No. PRUDHOE BAY UNIT 05-27B Operator BP EXPLORATION (ALASKIy INC API No. 50-029-21979-02-00 MD 13498 TVD 9055 Completion Date 3/10/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION .-- Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX, CCL, Memory PS (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data. Digital Dataset Log Log Run Interval OH / T e Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log Cement Evaluation 5 Col 10110 13088 Case 4%6/2009 Mem CBL, Mem PSP, GR, CCL, Pres, Temp, VDL 8- Mar-2009 ED C Pds 17777 "Cement Evaluation 10110 13088 Case 4/6/2009 Mem CBL, Mem PSP, GR, ~ CCL, Pres, Temp, VDL 8- Mar-2009 t LIS Verification 11300 13498 Open 4/22/2009 LIS Veri, GR, ROP, RAD, ~, RAS, RPD, RPS C Lis 17891 ~uction/Resistivity 11300 13498 Open 4/22/2009 LIS Veri, GR, ROP, RAO, RAS, RPD, RPS i Log Induction/Resistivity 25 Col 11573 13498 Open 4/22/2009 MD MPR, GR 25-Feb-2009 og Induction/Resistivity 5 Col 11573 13498 Open 4/22/2009 TVD MPR, GR 25-Feb- / ~~ 2009 25 Col 11573 13498 Open 4/22/2009 MD GR 25-Feb-2009 Rpt LIS Verification 11300 13206 Open 5/26/2009 LIS Veri, GR, ROP, RAD, jj RAS, RPD, RPS D C Lis 18071 rlnduction/Resistivity 11300 13206 Open 5/26/2009 PB 1 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Cof 11573 13207 Open 5/26/2009 P B 1 MD MPR, GR g Induction/Resistivity 5 Col 11573 13207 Open 5/26/2009 P B 1 TVD MPR, GR o Gamma Ray 25 Col 11573 13207 Open 5/26/2009 P B 1 MD GR og See Notes 5 Col 11300 13498 Open 5/26/2009 Depth Shift Monitor Plot DATA SUBMITTAL COMPLIANCE REPORT 4/612010 Permit to Drill 2081910 Well Name/No. PRUDHOE BAY UNIT 05-27B Operator BP EXPLORATION (ALASt(A) INC API No. 50-029-21979-02-00 MD 13498 TVD 9055 Completion Date 3/10/2009 Completion Status 1-OIL Current Status 1-OIL UIC N D D Asc Directional Survey 33 13498 Open 4/16/2009 pt Directional Survey 33 13498 Open 4/16/2009 ED D Asc Directional Survey 33 13206 Open 4/16/2009 PB 1 Rpt Directional Survey 33 13206 Open 4/16/2009 PB 1 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION N Well Cored? Y ~ Daily History Received? d? "'Y7N- Chi R i s ~ N Formation To ve ps ece p Analysis Y7'N' Received? Comments: Compliance Reviewed By: T Date: ~ ~ ~~ • si.® BAKER M V6NE5 Baker Atlas PRINT DISTRIBUTION LIST FIELD PRUDHOE BAY UNIT DATE 5/21/2009 COMPANY BY >iXYLUKA'1'lUN (ALASKA) INC WELL NAME OS-27BPB 1 CUUN'fY NUR'I'H SLUPE BURUUGH STATE ALASKA THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2466344 Copies of Copies Digital Copies of Copies Digital Ea~Log of Film Da[a Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE. AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv~ BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: e F; ~ ' MAY 2 ~ 209 ~~~ qid ~ has Cans. C;o~Imis~il~ ~m Page 1 of 1 • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7t" Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: OS-27BPB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2466344 Sent by: Catrina Guidry Date: OS/21/0~ I' „ Received by: Date: MAY 2 2009 Alaska iii Gas ns. ~~nnaissian PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ~fURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~~ "~u°wss Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907)267-6612 FAX: (907) 267-6623 ~~ ~/~ ~~sv~~ INTEQ IN'I'E L®g ata T'ras~nittal ~'®rrn To: State of Alaska -A®GCC 333 W. 7rn Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: OS-27B ..e~. _.~.~ ____-___ _~-- _ _ _ - ` Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary ` 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) '' 1 color print - MPR/Directional Measured Depth Log (to follow) C p t',~ LAC Job#: 2466344 6~`~~~ Y Sent by: Catrina Guidry Date: 04/22/09 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~~ ,p j ~'~ ~ ' '~ 7260 Homer Drive 1 / ~~~ Anchorage, Alaska 99518 ~ ~~~ ~ Direct: (907) 267-6612 t(~I'rEQ FAX: (907) 267-6623 BAKER NV6NE5 Saker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKAI'LUN (ALASKA) 1NC CUUN'fY WELL NAME OS-27B STATE FIELD PRUDHOE BAY UNIT DATE NUK'1'H SLUYl:; BUKUUGH ALASKA 4/22!2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2466344 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DN7t -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: f~ ~ ~~~ Page 1 of f ~~E ~~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: April 15, 2009 Please find enclosed directional survey data for the following wells: K-06B J-OSC E-34L1 J-OSCL1 OS-27BPB1 07-02B OS-27B 07-20B 07-29D Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: Q ,State of Alaska AOGCC DATE: 2 C~ ~ Cc: State of Alaska, AOGCC ~~ ~ --1Q ~ STATE OF ALASKA ALASKA~IL AND GAS CONSERVATION COM SSION .,.`~O~ED.~/ APR 0 7 ZOC~9 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~I~s~~ iii ~ Gas Gong. C~~rmission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class. ttC OfBQE ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband~. ,~/ 3/12009 .erg ' 12. Permit to Drill Number 208-191 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/18/2009 ~ 13. API Number 50-029-21979-02-00 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 2/25/2009 f 14. Well Name and Number: PBU 05-278 2144' FSL, 1207' FWL, SEC. 32, T11 N, R15E, UM Top of Productive Horizon: 1463' FNL, 4724' FWL, SEC. 05, T10N, R15E, UM 8. KB (ft above MSL): 67' Ground (ft MSL): 34.54' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1135' FNL, 3839' FWL, SEC. 05, T10N, R15E, UM 9. Plug Back Depth (MD+TVD) 13228' 9035' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 698296 y- 5948338 Zone- ASP4 10. Total Depth (MD+TVD) 13498' 9055' 16. Property Designation: ADL 028326 & 028329 TPI: x- 701919 y- 5944826 Zone- ASP4 5945131 Zone- ASP4 701025 T t l D th 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: : x- y- ep o a D 18. Directional Survey ®Yes ^ No ubmit I r nic and rin inform ion er 0 2 .050 19. Water depth, if offshore N/A ft MSL ): 20. Thickness of Permafrost (TV 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): /~'V~~/J ~ MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX, CCL, Memory PSP GR /CCL /Press /Temp / CBL / VDL ~9s?19~Tj/D 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT:. WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 0" 1.5# H-4 rfa 110' Surf 11 30" 2850 # P lese - / " 2# - / - rf 7 1 7- - /8" 47# S rf 95 urf 501' 12-1 /4" 7 x Cla s 'G' 7" 2 -8 9 1' 111 28 ' 0' 8-1/ " 5 x I 'G' 4-1 /" 1 1 - 1 77' 1 in -3/ " 4.6# - 0 1 166' 1 7' 8811' 903 ' - /4" 163 sx Class 'G' 33.6 Bbls, 1.16 Yield 23. Open to production or inject ion? ®Yes ^ No 24. TueINC RecoRD If Yes, list each i nterval open d N b i Si SIZE DEPTH SET MD PACKER SET MD er): ze an um on (MD+TVD of Top & Bottom; Perforat 6 SPF 56" Gun Diameter 1 4-1/2", 12.6# x 3-1/2" 9.2# L-80 10496' 10477' , . MD TVD MD TVD 12010' - 12350' 9052' - 9038' ' ' ' ' 2rj, ACID, FRACTURE, CEMENT'SOUEEZE, ETC. - 9042 12430 - 12820 9038 13030' - 13125' 9042' - 9041' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with McOH 26. PRODUCTION TEST Date First Production: April 1, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 4/5/2009 HOUfS Tested: 5 PRODUCTION FOR TEST PERIOD OIL-BBL: g6 GAS-MCF: 967 WATER-BBL: 276 CHOKE SIZE: 80 GAS-OIL RATIO: 11231 Flow Tubing Press. 345 Casing Press: 1100 CALCULATED 24-HOUR RATE• OIL-BBL: 413 GAS-MCf: 4641 WATER-BBL: 1327 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. It ~/ ~ ri None iii~i/l~~~illl S --~- Form 10-407 Revised 02/2007 CONTINUED Orr REVERSE SIDE ~/~~0~ ~~,~ , A~'R ~ S 2009 G 2$. GEOLO(~aIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested . Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. From Parent Wellbore Zone 1A 11130' 9060' None Formation at Total Depth (Name): Zone 1A 13498' 9055' 30. List of Attachments: Summary of Daily Drilling Reports, Post Rig Summary, Well Schematic Diagram and Surveys. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sond Stewm Title Drilling Technologist Date - PBU 05-27B 208-191 Prepared By Name/Number. Sondra Stewman, 564-4750 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Sean MCLeughlin, 564-4387 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. IreM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (mutiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only = 7 4-1/16" CNV __® WELLHEAD = CM/ ACTUATOR = AXELSON _ KB. ELEV = _ _ 67' BF. ELEV = KOP = 2561' Max Angle = 96°@11849' Datum MD - 10321' Datum TVD = 8800' SS ID = 12.347" 4-1/2" TBG, 12.6#, L-80 BTGM, 3020' .0152 bpf, ID = 3.958" 13-3(8" CSG, 72#, L-80 BTC, ID = 12.347" 3700' 9-5/8" X 7" BKR HY FLO LNR HGR, ID = ? ~ 9191' 9-5/8" CSG, 47#, L-80 BTGM, ID = 8.681" 9525' Minimtam IQ = 1.81'" a~ 10171' 2.39" KB LTP SEAL ASSY 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" ~ 10467' 4-1/2" LNR, 13.5#, L-80 FL4S, 10651' .0149 bpf, ID = 3.92" 4-1/2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" 10899' 05-27B ' ~i i 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 11154' ~ . ;~ j l ' i ~~ 4-1/2" BOT GEN II WHIPSTOCK (02/16/09) 11573' ~~,~ l ~~, RA TAG 11578' ;~~ ~ ~~~~~i'~'~',~ ~'~,„''~' .~ ~ ~ 4-1/2" AVA TRSV SSSV NIP, ID = 3.813" 3020' -~ 4-1 /2" X 3-1 /2" XO, id = 2.992" C;AS 1 IFT MANDRELS S NOTES: W ELF ANC~E > 7t}° @ 10476''`** 2-3/ CHRQME LNR *** ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3120 3096 21 MGFMHO DOME RK 16 03/24/09 2 5949 5592 29 MGFMHO SO RK 20 03/24/09 3 7250 6734 28 MGFMHO DMY RK 0 01/01/00 4 7823 7238 31 MGFMHO DMY RK 0 10/30/96 5 8147 7501 40 MGFMHO DMY RK 0 01/01/00 6 8530 7789 43 MGFMHO DMY RK 0 01/01/00 7 8915 8076 40 MGFMHO DMY RK 0 05/28/08 l.Y1tMIl;HL NWIVVKCLJ ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 9147 8250 44 KBUG-LT DOME BK-2 16 11/13/89 9632' 3-1/2" OTIS X NIP, ID = 2.813"' 10166' 3-1/2°' BTT KP LTP, ID = 1.870" 10172' BTT DEPLOY SLV {2.250" BORE}, ID = 1.875" 10467' -~4-1/2" TNV POLISHED RISER 10477' 7" TNV SS PKR, ID = ? 10479' TMJ MILLOUT EXTENSION w / XO / SO, ID = ? 10496' 7" X 3-112" TMI OVERSHOT SEAL ASSY W/1" EXT (10.75') 10920' 7" ECP (34') MiLLOUT WINDOW (05-276) 11574' - 11578' 1729' 2-3f8°' MARKER JOINT PBTD I-1 13228' ~,--- .~_~~_.. ~ - t 2-3/8" LNR, 4.7#, L-80/13CR STL, .0039 bpf, ID = 1.995°' 13267' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/16/84 PKR176 ORIGINAL COMPLETION 10/30/89 AUDI4 RWO 11!20196 NOR 1 CTD SIDETRACK (05-27A) 03111(09 PJC DRLG DRAFT CORRECTIONS 03/27/09 JLJ/PJC GLV C/O (03124/09) PRUDHOE BAY UNIT WELL: 05-27B PERM[T No: 208191 API No: 50-029-21979-02 SEC 32, T11 N, R15E, 2144' FSL & 1207' FWL BP Exploration (Alaska) PERFORATION SUMMARY 7 r ~ BP EXPLORATION Page 1 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ' Task Code ~ _ NPT Phase Description of Operations _ __ _. 12/13/2009 ~ 00:00 - 12:00 ~ 12.00 ~ MOB ~ N ~ WAIT PRE 12:00 - 23:00 ~ 11.00 MOB P ~ ~ PRE 23:00 - 00:00 1.00 MOB N WAIT PRE 2/14/2009 00:00 - 05:00 5.00 MOB N WAIT PRE 05:00 - 05:20 0.33 MOB P PRE 05:20 - 06:30 1.17 MOB P PRE 06:30 - 06:45 0.25 MOB P PRE 06:45 - 09:30 2.75 MOB P PRA 09:30 - 09:45 0.25 MOB P PRE 09:45 - 14:00 4.25 MOB P PRE 14:00 - 14:15 0.25 MOB P PRE 14:15 - 18:00 3.75 MOB P PRE 18:00 - 18:30 0.50 MOB P PRE 18:30 - 20:00 1.50 MOB P PRE 20:00 - 20:15 0.25 MOB P PRE 20:15 - 21:00 0.75 MOB P PRE 21:00 - 00:00 3.00 MOB P PRE 2/15/2009 00:00 - 02:00 2.00 MOB P PRE 02:00 - 08:00 6.00 BOPSU P PRE 08:00 - 08:15 0.25 MOB P PRE 08:15 - 08:30 0.25 MOB P PRE 08:30 - 12:15 ~ 3.75 ~ MOB ~ P ~ ~ PRE 12:15 - 12:30 0.25 MOB P PRE 12:30 - 14:30 2.00 MOB P PRE Waiting on Doyon 14 rig move on spine road to move Nordic 1. Waiting on E pad for the wind to go down, gusting to 25 mph, unable to lower wind walls and derrick. Wind limit is 20 MPH. Nordic crew is replacing #2 fluid end while waiting. SAFETY MEETING. Held safety meeting with Security, tool service, Nordic and BP. Review rig move plan and hazard and procedures. Move rig on K pad road, to West Dock road, to Pad 10 to lay down derrick before getting on DS 05 access road. Arrive at Pad 10, wait for wind to subside so derrick can be lowered. Continue waiting at Pad 10 for the wind to lessen so derrick can be lowered. SAFETY MEETING. Wind has eased enough to lay windwalls over. PJSM to discuss hazards and mitigations. Hook up bridal lines to forklift, prep for pulling walls over. SAFETY MEETING. Crew change and PJSM for lowering windwalls. Lower windwalls. SAFETY MEETING. PJSM for lowering derrick. Lower derrick and move Rig to DS-05. Set down rig. SAFETY MEETING. PJSM for raising derrick and windwalls. Rasie derrick, raise windwalls. SAFETY MEETING. Crew change and PJSM for setting derrick tilt cylinders into position. Hook up tugger to derrick cylinders, pull them onto supports. Unhook bridal lines. Attach long slings to block, pick up stack and secure for travel. SAFETY MEETING. PJSM for moving rig over well. Jack up rig, move it over well and set down. Acce t ri at 21:00. N/U BOPs. Install catch basin around CT riser. Continue installing catch basin around CT riser. Clean up rig floor, grease tree valves, prep for BOP test. Test BOPs. Test witness waived by AOGCC official Chuck Sheive. Test 2" Combi Pipe/Slip, 2-3/8" Pipe/Slip, 2" Pipe/Slip, Blind Shears, Kill line Valves and TIW valves. Replace test joints back onto rack. Prep rig floor to pick up injector. SAFETY MEETING. Review procedure, hazards and mitigation for installing pipe straitener and guide arch on injecter and picking injecter out of pipe bay. M/U pipe straitener on injecter head. Pick injecter head from pipe bay. Secure hose bundle. Install guide arch on top of pipe straightener. Line up guide arch. SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil to injecter head. Install internal grapple and pull test. Pull coil to injecter. Stab ~ ~ BP EXPLORATION Page 2 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11 /2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ' Task Code NPT .Phase Description of Operations 2/15/2009 12:30 - 14:30 2.00 MOB P PRE coil. Cut off grapple. 14:30 - 17:30 3.00 MOB P PRE Fill coil. Pump reverse circ slack management. Cut off 330' 17:30 - 18:30 18:30 - 19:15 19:15 - 19:30 1.00 0.75 0.25 CLEAN CLEAN CLEAN P P P WEXIT WEXIT WEXIT coil to reach E-Line. Cut off 30 more ft coil to find clean area for CTC. M/U Kendal CTC and pull test. M/U BHI UOC and test E-Line. Crew change, then pull BPV equipment up to rig floor. SAFETY MEETING. PJSM for pulling BPV. Trapped pressure and overhead loads were discussed. 19:30 - 20:20 0.83 CLEAN P WEXIT Move Tioga heater away from Tiger Tank. Pull BPV. No pressure underneath. 20:20 - 20:45 0.42 CLEAN P WEXIT Load out BPV equipment. 20:45 - 21:00 0.25 CLEAN P WEXIT SAFETY MEETING. PJSM for moving Farr tongs to stabbing box. 21:00 - 21:50 0.83 CLEAN P WEXIT Move Farr tongs to stabbing box until liner running time. Move elevators onto rack. Clear rig floor. 21:50 - 22:30 0.67 CLEAN P WEXIT Pick up injector. Install pull test plate and pull test CT connector to 35K, good. Pressure test CT connector and inner reel valve to 200 / 3500 psi,. good. 22:30 - 23:50 1.33 CLEAN P WEXIT Install BHI cable head with check valves. Pressure test to 3,500 psi, good. 23:50 - 00:00 0.17 CLEAN P WEXIT M/U CT riser, bullhead biozan at 2.5 bpm, 2900 psi CT pressure, 0 psi WHP. 2/16/2009 00:00 - 01:00 1.00 CLEAN P WEXIT Continue bullheadin biozan. 30 bbls away, 2.54 bpm ~ 33 psi WHP. 60 bbls away, 2.54 bpm @ 19 psi WHP. 90 bbls away, 2.52 bpm @ 0 psi WHP. 120 bbls away, 2.52 bpm C~ 0 psi WHP. 150 bbls away, 2.55 bpm @ 0 psi WHP. At 165 bbls away, shut down pump. 01:00 - 01:15 0.25 CLEAN P WEXIT SAFETY MEETING. PJSM for pick up BHA #1. 01:15 - 02:00 0.75 CLEAN P WEXIT Break off CT riser, stand back injector. P/U BHA #1 - 2.74" arabolic speed mill and string mill, 2-1/8" BOT motor, Full 2-3/8" CoilTrak minus the HOT. Test BHA at surface. 02:00 - 04:45 2.75 CLEAN P WEXIT RIH. Stop at 730 ft, change out 2 bearing pins on injector chains. Continue RIH. 04:45 - 05:25 0.67 CLEAN P WEXIT Log GR down from 10,880 ft. Correct -11 ft. 05:25 - 05:55 0.50 CLEAN P WEXIT Go to 1.63 bpm C~ 2200 psi with no returns. Wt check at 11,130 ft is 30K. IH to 1,650 ft at 1.75 / 0 bpm C~ 2440 psi. Nothing seen at previous trouble spot of 11,172 ft. 05:55 - 06:30 0.58 CLEAN P WEXIT Back ream up to 11450' and ream down to 11610' clean. Back ream up to 11,100'. Pull back to 11,000 for dry pass past 11,172 ft. RIH no pump. RIH clean to 11270'. No indication of trouble spot. 06:30 - 09:45 3.25 CLEAN P WEXIT POH with milling BHA. Pump 1.0 bpm, no returns. Had over pull at SSSV and determined that SSSV was TRSV. Printed: 3/23/2009 11:15:02 AM r ~ BP EXPLORATION Page 3 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11 /2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To ,Hours Task Code NPT Phase Description of Operations ,2/16/2009 06:30 - 09:45 ~ 3.25 CLEAN P WEXIT Held TRSV open with 4500 psi and POH. 09:45 - 10:00 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and 10:00 - 12:00 I 2.001 WHIP I P 12:00-15:00 ~ 3.OO~WHIP ~P 15:00 - 15:30 0.50 WHIP P 15:30 - 16:00 0.50 WHIP P 16:00-18:40 ~ 2.67~WHIP ~P 18:40 - 18:55 0.25 WHIP P 18:55 - 19:10 0.25 WHIP P 19:10 - 19:20 0.17 WHIP P 19:20 - 20:30 1.17 WHIP P 20:30 - 22:45 ~ 2.25 W H I P P 22:45 - 22:55 0.17 WHIP P 22:55 - 23:10 0.25 WHIP P 23:10 - 23:45 0.58 WHIP P 23:45 - 00:00 0.25 WHIP P 12/17/2009 ~ 00:00 - 01:30 ~ 1.50 ~ WHIP ~ P mitigation for UO mills /motor and M/U BTT whipstock and Coiltrak BHA. WEXIT Lay out 2.74" mills and motor. UO Coiltrak. M/U BOT Gen II Whipstock and setting tools to CoilTrak tools. Enter and check TF offset. Check Coiltrak tools at surface. BHA OAL = 71.45'. WEXIT RIH with BOT whipstock BHA #2 with CoilTrak tools. Open EDC, set pump kickout at 800 psi. Circ at 0.2 bpm while RIH at 80 fpm. WEXIT Log GR tie-in at 10910'. -8' correction. WEXIT RIH clean to setting depth. Position to of BOT Gen II Whipstock at 11,570' with a 160ROHS TF. Close EDC. Press up and set whipstock. Stack 1 K down, Whipstock is set. WEXIT POH while pumping 1.0 bpm. ' Flow check at 1900'. No flow. Bullhead 80 bbl Biozan, 2.0 bpm with 550 psi WHP. WEXIT Shut down pump, monitor well. WHP bleeds off slowly. Crack open choke to check returns, well is dead. WEXIT POOH, pump 1 bpm through CT. WEXIT SAFETY MEETING. PJSM for UD BHA #2 and P/U BHA #3. Well control and crew positions were discussed. WEXIT Tag stripper and UD whipstock setting tool. Tool has functioned normally. Remove check valves from UOC. Pick u BHA #3 - Bi hole Nozzle, 1 jt 2-1/16" CSH, LOC, UOC. BHA OAL = 34.5 ft. WEXIT RIH BHA #3. Ta whi stock at 11 589 ft twice correct de th to 11 573 ft." WEXIT Pull back to 10,880 ft and shut in well, Circ min rate. WEXIT SAFETY MEETING. PJSM for pumping cement squeeze. High pressure and high wind conditions were discussed. WEXIT "Hook up water lines to rig, prep for cmt job. WEXIT Ready for cement. CT is at 10,880 ft. Isolate reel from rig pump. SLB pump 5 bbls fresh water ahead, then PT lines to 4,800 psi. Start cement down CT, zero In MM on density change. WEXIT CT is at 10,880 ft. Start cement down CT, zero In MM on density change. Bring rate to 1.5 bpm / 2900 psi CT / 0 psi WHP. In MM CT psi WHP 10 3700 0 20 3400 0 30 3250 120 35 3200 170 Go to 1.0 bpm 40 1100 200 Cmt at nozzle 50 900 220 60 450 256 67 430 260 Go to 0.6 bpm BP EXPLORATION Page 4 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11 /2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ~ Task Code ~~ NPT I, Phase Description of Operations _ _~ - 2/17/2009 00:00-01:30 1.50 WHIP P WEXIT 70 460 0 Open choke, start lay in 1.0 bpm 1:1, 01:30-02:30 1.OOWHIP P (WEXIT 02:30 - 03:30 1.001 WHIP P WEXIT 03:30 - 06:30 3.00 WHIP C WEXIT 06:30 - 08:00 1.50 WHIP C WEXIT 08:00-12:00 4.OOWHIP N (CEMT (WEXIT ~~ ~ ~ ~/ 12:00 - 14:00 14:00 - 16:00 2.00 WHIP N 2.00 WHIP N 16:00 - 17:20 1.33 WHIP P 17:20 - 20:20 3.00 WHIP P 20:20 - 00:00 I 3.671 STWHIPI P CEMT WEXIT CEMT WEXIT WEXIT WEXIT WEXIT lose WHP for a moment. Shut in choke, get it back. 80 1690 520 Picking up 60 ft/min 85 1900 700 Last cmt out nozzle at 10,000 ft, pull to safety. 89.5 965 520 WHP Pressure slowly bleeding off Park at safety depth 9470 ft and soueeze with well shut in WHP slowly bleeding off. In MM WHP 01:40 91.5 200 Squeeze 2 bbls, no WHP increase 02:00 94.0 103 Squeeze 2.5 bbls, No WHP increase. 02:20 97.0 90 Push away remaining cmt past whipstock, run down to whipstock and circulate. Pull back to 9,000 ft, wait for 2nd batch of cement. Fluid loss will be increased to 80-120 cc/30/min for 2nd batch. Park at 9,000 ft, wait for 2nd batch of cement. Shut in well, circulate periodically. Open up well and circ. 1.7 bpm, 1.2 bpm returns, 29% losses. RIH and tag whipstock to confirm no bridge above whipstock. Circ just above whipstock, 1.93 bpm / 1.45 bpm returns, 25% losses. Call SWS and change cement volume to 25 bbl from 50 bbl due to good returns. Pilot test on cement done at 0830 hrs. Load out for cement job and perform thickening time test on next cement. Circ 0.5 bpm, 0.2 bpm returns. 18 bph fluid loss. Circ 1.8 bpm, 1.35 bpm. returns. No cement ever seen to surface. Tag whipstock pinch point at 11562' and correct depth to 11,573'. Add 9'.- Circ. while waiting for SWS Cementers for second cement job. 0.4 bpm, 0.1 returns. Second cement batch has poor rheology based on lab tests. ,Testing another cement blend will take 6+ hrs, decision is made not to um a second cement'ob and ick u window mill. POOH. PU milling BHA. RIH. Log GR down from 11,385 ft. Correct +4 ft. RIH and tag whipstock at 11,573 ft at min rate.- Start time millin , 1 ft/hr. 20:30 - 11572.5 ft 1.54 / 1.21 bpm ~ 3480 psi DWOB = OK 21:00 - 11572.9 ft 1.54 / 1.25 bpm C~3 3550 psi DWOB = 0.45K 22:00 - 11573.8 ft 1.53 / 1.31 bpm @ 3520 psi DWOB = 0.90K 23:00 - 11574.9 ft 1.54 / 1.35 bpm @ 3630 psi DWOB = 1.78K 00:00 - 11576.0 ft 1.54 / 1.37 bpm @ 3710 psi DWOB = Printed: 3/23/2009 11:15:02 AM ~ ~ ~ BP EXPLORATION Page 5 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT ~I Phase Description of Operations 2/17/2009 20:20 - 00:00 3.67 STWHIP P WEXIT 2.39K 2 18 2009 00:00 - 02:55 2.92 STWHIP P WEXIT Continue time milling window. 00:00 - 11576.0 ft 1.54 /.1.37 bpm ~ 3710 psi DWOB = 2.39K 01:00 - 11576.8 ft 1.54 / 0.98 bpm C~ 3580 psi DWOB = 1.68K ~ ~ ~ ~ ~ ~ 02:00 - 11577.6 ft 1.47 / 1.17 bpm @ 3220 psi DWOB = 0.45K 1 Stall here, likely window exit. Mill rathole at 7 ft/hr from 11,578 ft. 1.48 / 1.11 bpm ~ 3190 psi DWOB = 0.50 K. Mill to 11,586 ft. 02:55 - 04:15 1.33 STWHIP P WEXIT Pick back up to top of window for first pass. Start new mud down the CT. Perform 3 up/down passes, no motor work seen. 04:15 - 0:10 2.92 STWHIP P WEXIT Dry run through window has slight weight bobble at 11,577 ft, ream window area again up and down. 1.55 / 1.35 bpm ~ 3300 psi. 07'10- 08:20 1.17 STWHIP P WEXIT Second dry run through window is still a bit ragged, make a couple more up/down passes. 1.77 / 1.51 bpm C~ 3650 psi. 08:20 - 10:50 2.50 STWHIP P WEXIT Third d ass is clean, POOH. 10:50 - 12:23 1.55 DRILL P PROD1 Tag up, PJSM, LD milling BHA #4, PU Build BHA#5 - 2.74"x3" HCC Bicenter - 2.7 deg AKO MiXP mtr -HOT - DGS - DPS 12:23 - 12:35 0.20 DRILL P PROD1 Surface Test 12:35 - 15:30 2.92 DRILL P PROD1 RIH w/ BHA#5. Pass 11,170 ft with HS toolface. 15:30 - 17:00 1.50 DRILL P PROD1 Log GR down from 11,320 ft. No correction. 17:00 - 21:20 4.33 DRILL P PROD1 Start to set down weight at 11,580 ft. Run through a bit faster at 150R, set down at 11,579 ft then pop through. Drill build section from 11,584 ft. Start with 150R TF to get inc down to 84 deg, then start turning. 1.65 / 1.31 bpm C~ 3160 psi. Initial ROP is 40-60 ft/hr. DWOB 0-1 K. 21:20 - 21:40 0.33 DRILL P PROD1 Wiper trip from 11,750 ft to window. Clean pass up and down. 21:40 - 00:00 2.33 DRILL P PRODi Drill from 11,750 ft. Maintain 8987.5 ft TVD while completing long RH turn. Some weight stacking past 11,780 ft. 1.51 / 1.35 bpm Q 2800 psi FS. ROP is 40-70 ft/hr with DWOB = 1-3 Klbs. Bleed off IA and OA to zero. Drill to 11,874 ft. 2/19/2009 00:00 - 00:30 0.50 DRILL P PROD1 Continue drilling to 11,900 ft. 00:30 - 01:00 0.50 DRILL P PROD1 Wiper trip from 11,900 ft to window. Clean pass up and down. 01:00 - 02:30 1.50 DRILL P PROD1 Drill from 11,900 ft. Continue RH turn holding 8987 ft TVD. 1.53 / 1.42 bpm C~ 3000-3700 psi. Some wt stacking in shale stringers. Drill to end of build at 11 950 ft 02:30 - 04:20 1.83 DRILL P PROD1 POOH. Stop at 9,940 ft to change a chain bearing. 04:20 - 04:30 0.17 DRILL P PROD1 SAFETY MEETING. PJSM for UD BHA. Hazards and mitigations were discussed. 04:30 - 06:30 2.00 DRILL P PROD1 UD BHA #5. Assemble BHA #6 on catwalk and test. 06:30 - 06:45 0.25 DRILL P PROD1 SAFETY MEETING. Shift change and PJSM for picking up BHA. Printed: 3/23/2009 11:15:02 AM BP EXPLORATION Page 6 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALIS TA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: _ ~ Date From - To Hours ', Task Code NPT , Phase Description of Operations 2/19/2009 06:45 - 07:10 0.42 DRILL P PROD1 Pick u lateral drillin BHA #6. HYC SRR bicenter, 1.0 deg AKO extreme, 2-3/8" CoilTrak with Res. 07:10 - 10:30 3.33 DRILL P PROD1 RIH. Tag bottom then MAD pass back to window. 10:30 - 14:25 3.92 DRILL P PROD1 Drill from 11 950 ft. 1.51 / 1.42 bpm ~ 2700-3000 psi. ROP increases to 90 ft/min past 12,020 ft. Drill to 12,100 ft. 14:25 - 15:10 0.75 DRILL P PROD1 Wiper trip from 12,100 ft to window. Pickup is slightly ragged off bottom, many small overpulls. Pull into casing and secure CT clamp inside reel. 15:10 - 16:55 1.75 DRILL P PROD1 Drill from 12,100 ft. Maintain 8,983 ft TVD for now. 1.63 / 1.49 bpm ~ 3000 psi FS, 3100 - 3400 psi while drilling. ROP is 80 - 100 ft/hr initially with 1-2 Klbs DWOB. Move up to 8,980 ft TVD after 12,110 ft. Drill to 12,250 ft. 16:55 - 17:40 0.75 DRILL P PROD1 Wiper trip from 12,250 ft to window. 17:40 - 20:50 3.17 DRILL P PROD1 Orill from 12,250 ft. Stacking wt and overpulls past 12,290 ft. Hold 8982 ft TVD for now. 1.62 / 1.54 bpm C~3 3500 psi on bottom. Frequent wt stacking in shales. Stacking wt at 12,330 ft hard to pass this area. Drill to 12,400 ft. 20:50 - 23:30 2.67 DRILL P PROD1 Wiper trip and tie-in. Wiper trip up through slotted liner back to 10,880. 5K overpull with motor work pulling past 11,172 ft. Tie-in log from 11,590 ft down. Correct +4 ft. Continue wiper to bottom. 23:30 - 00:00 0.50 DRILL P PROD1 Drill from 12,400 ft at 1.51 / 1.42 bpm C~ 2900-3400 psi. Initial ROP is 100 ft/hr with 1-2 Klbs DWOB. Stacking wt after 12,440. Drill to 12,442 ft. 2/20/2008 00:00 - 02:00 2.00 DRILL P PROD1 Continue drilling from 12,442 ft. Stacking wt often, start new mud downhole at 12,530 ft. Drill to 12,551 ft. 02:00 - 03:00 1.00 DRILL P PROD1 Wiper trip from 12,550 ft to window. Clean pass up and down. 03:00 - 04:45 1.75 DRILL P PROD1 Drill from 12,550 ft. Hold 8,983 ft TVD for now. New mud is all the way around. 1.60 / 1.52 bpm C~ 2700-3100 psi. Initial ROP is 100-120 fUhr with 1-3 Klbs DWOB. Drill to 12,674 ft. 04:45 - 05:45 1.00 DRILL P PROD1 Wiper trip from 12,674 ft to window. Early wiper trip due to poor weight transfer and weight stacking. 05:45 - 06:45 1.00 DRILL P PROD1 Drill from 12,674 ft to 12,704 ft. 1.47 / 1.40 bpm C~ 2600 - 3200 psi. 06:45 - 09:00 2.25 DRILL P PROD1 Weight transfer is poor, POOH for agitator. Also, orienter has failed. 09:00 - 09:15 0.25 DRILL P PROD1 SAFETY MEETING. PJSM for BHA change. 09:15 - 09:30 0.25 DRILL P PROD1 Lay down BHA #6. Bit has one chipped cutter, will re-run. 09:30 - 10:00 0.50 BOPSU P PROD1 Function test BOPs. 10:00 - 11:00 1.00 DRILL P PROD1 P/U BHA #7 -HYC bicenter Bit, 2-3/8" Xtreme, Agitator, Floats, 2-3/8" CoilTrak with Res. BHA OAL = 75.91 ft. M/U CT riser, test tool. rrirneo: sizsrzuua II:ID:VL HM 1 ~ BP EXPLORATION Page 7 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: I Date From - To ~ Hours Task ! Code ~ NPT ~ Phase. Description of Operations 2/20/2009 11:00 - 14:05 3.08 DRILL P PROD1 RIH. Stack wt at 11,170 ft with HS toolface, go to 90L to get 14:05 - 16:30 2.42 DRILL P PRODi 16:30 - 18:30 2.00 DRILL P PROD1 18:30 - 20:12 1.701 DRILL P l PROD1 20:12 - 21:34 1.37 DRILL P PROD1 21:34 - 22:43 1.15 DRILL P PROD1 22:43 - 23:59 ~ 1.27 ~ DRILL ~ P ~ PROD1 23:59 - 00:00 0.02 DRILL P PROD1 2/21/2009 00:00 - 00:29 0.48 DRILL P PROD1 00:29 - 01:21 0.87 DRILL N STUC PROD1 01:21 - 01:59 0.63 DRILL N STUC PROD1 01:59 - 02:09 0.17 DRILL N STUC PROD1 02:09 - 02:11 0.03 DRILL P PROD1 02:11 - 03:06 0.92 DRILL P PROD1 03:06 - 03:24 03:24 - 04:12 04:12 - 04:20 0.30 DRILL P PROD1 0.80 DRILL P PROD1 0.13 DRILL P PROD1 04:20 - 06:00 06:00 - 06:45 06:45 - 10:00 1.671 DRILL I N I STUC I PROD1 0.75 DRILL N STUC PROD1 3.25 DRILL N STUC PROD1 through. Tie-in depth, correct +2 ft. RIH to bottom. Drill from 12,704 ft to 12,850 ft. 1.54 / 1.45 bpm C~3 3200 psi FS, 3300-3600 psi while drilling. Winer trlD from 12.850 ft through slotted liner section to 10,800 ft. Stack out in window twice, then pop through. Back on bottom drilling PVT=321 bbls 3250psi FS, 3300 to 4000psi while drilling In/Out 1.61/1.55 IAP= 278psi & OAP= 229psi Wiper trip from 13,000' to 10,880' through slotted liner Drilled from 12,850 to 13,000' - AVG ROP= 88' fph RIH from 10,880' In/Out 1.53/1.55 PVT= 299 bbls Tagged down twice at bottom of window but popped through Back on bottom drilling PVT= 304 bbls 3250psi FS 3300 to 4000psi while drilling In/Out Rates 1.51/1.41 IAP= 244psi OAP= 228psi Continue drilling 13,113' Continue drilling from 13,113' Short trip to 10,880', PU and we are differentually stuck. Shut down pump and let everything stabilize, loriented BHA to see if it's free and it is. Pulled 63k a few times after 15 min and still stuck' Call for crude and continue pumping for 1 circulation and shut down. Called x3313 and they don't have a truck with dead crude and said it would be awhile to get one. Called Fullbore and we are getting one of their trucks from F-Pad to assist us. Completed 1 circulation, shut pump down and wait 15-20 min LRS on location with dead crude and called for PJSM. PU CT and pulled free (~ 31 k, released LRS back to Fullbore Continue short trip to 10,880' PVT= 287 bbls In/Out Rates 1.51/1.28 PUWT 27k RIH from 10,880' PVT= 276 bbls In/Out Rates 1.35/1.40 RIHWT 9.1 k Tagged at bottom of window again Tie in, correct depth +14' and continue RIH. Stacked out at 13,113' twice with no motor work or WOB Back on bottom drilling PVT= 280 bbls / ROP= 130 fph / WOB= 2.09k In/Out Rates 1.54/1.49 /IAP= 281 psi OAP=234psi Motor work started falling off, PU and we got Diff stuck again. Shut down pump and let well stabilize. Pump every 15 min to keep CT warm and call for crude, new mud. Cycle pipe several times -7k / 63K, no go. Wait for crude. Crude arrives. First vapor test is 1.8 psi, too high to pump. Second test is 1.3 psi, third is 1.7 psi. Release crude truck, call for another load. Another load available at F pad. Printed: 3/2 3/2009 11:15:02 i BP EXPLORATION Page 8 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/21/2009 10:00 - 11:20 1.33 DRILL N STUC PROD1 Second load arrives, tests out at 1.4 psi good to pump. Start crude down coil. Packing leak on Pump #1, switch to Pump #2. About 3 gal crude release from packing leak. Material release was called in to x5700. Pumn 50 bbls crude Dill f10 bbls out bitl then shut down for 2/22/2009 11:20 -13:30 2.171 DRILL N STUC (PROD1 13:30 - 15:30 ~ 2.00 ~ DRILL ~ P 15:30 - 15:55 0.42 DRILL P 15:55 - 17:30 1.58 DRILL P 17:30 - 19:56 19:56 - 20:01 20:01 - 20:21 20:21 - 21:02 21:02 - 21:25 21:25 - 21:31 21:31 - 21:53 21:53 - 00:00 00:00 - 00:19 00:19 - 00:32 00:32 - 01:02 01:02 - 01:26 2.431 DRILL I C 0.08 DRILL C 0.33 DRILL C 0.68 DRILL C 0.38 DRILL C 0.10 DRILL C 0.37 DRILL C 2.12 DRILL C 0.32 DRILL C 0.22 DRILL C 0.50 DRILL. C 0.40 DRILL C 01:26 - 03:27 I 2.021 DRILL I C 03:27 - 03:28 0.02 DRILL C 03:28 - 04:33 1.08 DRILL C 04:33 - 05:00 0.45 DRILL C 05:00 - 05:30 0.50 DRILL C 05:30 - 07:45 I 2.251 DRILL I C 07:45 - 08:00 I 0.251 DRILL I C Use choke to keep ECD > 9.2 while crude is coming up. Pull through window and cleanout slotted liner back to 10,400 ft. PROD1 Shut down at 10,400 ft and flow check well, well is dead. Run back to top of whipstock and tie-in depth. Correct +7 ft. RIH to bottom. PROD1 Tag bottom, start new mud downhole. PROD1 Drill from 13,160 ft. Hold 96 deg until we find good sand. New mud is just out the bit. 1.51 / 1.39 bpm ~ 3000 psi FS, 3100 - 3400 psi while drilling. ECD = 9.98 ppg. Initial ROP is 70 ft/hr, then start stacking wt. PROD1 Decision from town to POOH to PU side track BHA and side track at 12,100' PROD1 Stop to close EDC PRODi OOH check for flow, PU injector & LD Motor, Agitator & Resis tools PROD1 BHA OOH, MU side track BHA PROD1 PU Side Track BHA PROD1 PU injector and MU to BHA PROD1 PU injector to put checks in the UOC since we dropped the agitator PROD1 Stabbed on, test MWD, open EDC and RIH PROD1 Continue RIH PROD1 Tie in IAP=61 psi OAP= 99psi PROD1 Correct depth -2' PROD1 Tag bottom a few times to knock off brass cap. Had a couple of good stalls and stacked 4' higher on the last 2 tags. PUH to 12,100' to start OHST PROD1 Start cutting troug 170' LF up to 12100' PVT= 333 bbls IAP= 125psi AOP= 110psi PROD1 3 up passed at 30 fph completed. RIH to 12,120' and set the brake for 10 min PROD1 Start milling sidetrack at .1 fpm PROD1 Increase ROP to 12 fph PROD1 No drop in inclination RIH to bottom and try to knock brass cap off again PROD1 Tag bottom 7 times with no motor work. WOB sensor shows we were getting -2k down. Didn't get sidetracked and we are not seeing any motor work, POOH to check motor & bit. PROD1 SAFETY MEETING. PJSM for VD BHA. Crew positions and Printetl: 3/23/2009 11:15:02 AM BP EXPLORATION Operations Summary Report Page 9 of 25 ~ Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~ I Code's NPT Phase Description of Operations __ 2/22/2009 07:45 - 08:00 0.25 DRILL C PROD1 hand traps were discussed. 08:00 - 08:40 0.67 DRILL C PROD1 Tag stripper and UD BHA. Bit has 2 broken and 1 chi ed cutter, all on the outside. 08:40 - 10:30 1.83 DRILL C PROD1 Pressure test CT connector, good. Pressure test BHI CoilTrak on the Catwalk, tests OK. 10:30 - 13:00 2.50 DRILL X WAIT PROD1 Fill well with 1.5 bbls. Wait for AI billet to arrive from BTT. Plan is to set a billet at 12,140 ft. 12:15 -Fill well with 1 bbls. 13:00 - 14:00 1.00 DRILL C PROD1 KO billet arrives, assemble on catwalk. Smooth off area around setting rod hole. 14:00 - 14:30 0.50 DRILL C PROD1 Pick up BHA #8 - KO billet, Setting Tool, 2-3/8" CoilTrak. 14:30 - 17:10 2.67 DRILL C PROD1 RIH. Slow down passing 11,172 ft, nothing seen. Log GR down from 11,595 ft. Correct -5 ft. 17:10 - 17:35 0.42 DRILL C PROD1 RIH to setting depth. Go to 12,151 ft To Billet = 12,140 ft ,pick up to string wt and move TF to 30L. Close EDC. Pressure up CT to 3500 psi to shear off and leave billet in Billet set with top (~ 12,140 ft ~ 30L. 17:35 - 19:20 1.75 DRILL C PROD1 POOH. 19:20 - 19:30 0.17 DRILL C PROD1 PJSM to LD OH Billet BHA 19:30 - 19:50 0.33 DRILL C PROD1 LD BHA 19:50 - 20:30 0.67 DRILL C PROD1 Add Res Tool to MWD & test 20:30 - 20:45 0.25 DRILL C PRODi PU Sidetrack BHA and MU to 1.1 `motor with bicenter bit 20:45 - 20:55 0.17 DRILL C PROD1 PU Injector and MU to BHA 20:55 - 21:10 0.25 DRILL C PROD1 Stabbed on, test MWD 21:10 - 23:15 2.08 DRILL C PROD1 .RIH 23:15 - 23:35 0.33 DRILL C PROD1 Close EDC & Tie In 23:35 - 23:45 0.17 DRILL C PROD1 Correct depth -5', RIH to tag billet 23:45 - 23:59 0.23 DRILL C PROD1 Tag billet on depth, PU and start motor and RIH to 12,139' and make our way until we see motor work then time mill the 1st foot at lfph 23:59 - 00:00 0.02 DRILL C PROD1 12,139.6' seeing motor work, start time milling 2/23/2009 00:00 - 00:55 0.92 DRILL C PROD1 Continue time milling off Alum Billet 12,140' 30? LOHS FS= 2420psi In/Out Rates 1.5/1.4 IAP= 84psi OAP= 45psi 00:55 - 01:30 0.58 DRILL C PROD1 Stall 12,140.5' FS= 2420psi DP 50 to 110psi W06= 1.2k down to .41 k 01:30 - 02:00 0.50 DRILL C PROD1 Start milling at 2 fph FS= 2420psi WOB= .39k to .31 k 02:00 - 02:05 0.08 DRILL C PROD1 Creep in hole FS= 2622psi In/Out 1.6/1.5 WOB= .3k 02:05 - 02:10 0.08 DRILL C PROD1 Not seeing much WOB or DP 02:10 - 02:30 0.33 DRILL C PROD1 Drilling ahead building angle rnrnea: ~izsizvva ii:io.~cHm BP EXPLORATION Page 10 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To ', Hours Task ,Code NPT I Phase Description of Operations 2/23/2009 02:10 - 02:30 0.33 DRILL C PROD1 In/Out 1.6/1.5 W06= .95k to .79k 02:30 - 04:30 2.00 DRILL C PROD1 Res Tool shows TOB at 12,140' Near Bit shows we are 2 deg higher ininclination at 94.36 deg 04:30 - 06:00 1.50 DRILL C PROD1 Drilled to 12,300' 06:00 - 07:50 1.831 DRILL C 07:50 - 10:00 2.17 DRILL C 10:00 - 11:30 1.50 DRILL C 11:30 - 14:10 I 2.671 DRILL I C 14:10 - 15:50 ~ 1.67 ~ DRILL ~ C 15:50 - 17:50 2.00 DRILL C 17:50 - 18:30 0.67 DRILL C 18:30 - 21:30 ~ 3.00 ~ DRILL ~ C 21:30 - 23:45 ~ 2.25 ~ DRILL C 23:45 - 00:00 0.251 DRILL C 12/24/2009 ~ 00:00 - 00:15 ~ 0.25 ~ DRILL ~ C ROP=80 fph WOB= 1.7k In/Out= 1.63/1.49 IAP= 302psi OAP= 217psi Short trip to 10,880' Drop pump rate to zero going across billet: PROD1 Drill from 12,300 ft. Hold 90 deg inc for now. 1.73 / 1.60 bpm ~ 2800-3200 psi. ROP is 80-100 ft/hr with 1-3 Klbs DWOB. Occasional wt stacking. PROD1 Wiper trip from 12,450 ft to 10,880 ft. Drop pump to zero going past billet. PROD1 Drill from 12,450 ft. Continue holding 90 deg, start LH turn. 1.75 / 1.63 bpm Q 3000-3500 psi. Drill to 12,600 ft. PROD1 Wiper trip from 12,600 ft to 10,450 ft + tie-in log. Log GR down from 11,595 ft. Correct +4 ft. RIH to bottom. PROD1 Drill from 12,600 ft. Hold 89-90 deg inc for now to match formation dip. 1.73 / 1.62 bpm @ 2900 - 3600 psi. DWOB = 2-3 Klbs with -2K CT wt. Initial ROP is 120-150 ft/hr. Stacking wt occasionally. Drill to 12,750 ft. PROD1 Wiper trip from 12,750 ft to 10,800 ft. Clean pass up and down. PROD1 Back on bottom drilling, continue holding 90 deg turning to the right ROP= 100 - 150 fph W06= 1.5 - 2.5k In/Out Rates= 1.7/1.6 PROD1 Stacking WT and gettimg sticky picking up off bottom. 12,818' getting WT back and ROP increasing 12,865' stacking WT, reduce rate to 1.5 Bleed down IA & OA /IAP= 489psi OAP= 424psi EDC= 10.37 PROD1 Short tip to 10,800' PVT= 236 In/Out Rates= 1.57/1.51 IAP= 216psi OAP= 89psi 11,170' 4k over pull and motor work Tagged bottom of window, orient to 120' R and made it through PROD1 Tag bottom continue drilling FS= 2700psi C~ 1.5 ROP= 35-70 fph W06= 1.47k to 1.96k EDC= 10.23 PVT= 215 bbls In/Out Rates= 1.51/1.38 IAP= 203psi OAP= 94psi PROD1 Tag bottom continue drilling rnmeo: aizaizuuy i is io:~c r{m i BP EXPLORATION .Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Event Name: REENTER+COMPLETE Start: 2/5/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: i Page 11 of 25 ~ Spud Date: 10/5/1989 End: 3/11 /2009 Date From - To Hours ~ Task ~ Code NPT ' Phase' ~ Description of Operations 2/24/2009 00:00 - 00:15 0.25 DRILL C PROD1 FS= 2700psi @ 1.5 ROP= 35-70 fph WOB= 1.47k to 1.96k 00:15 - 01:20 1.08 DRILL C 01:20 - 01:55 0.58 DRILL C 01:55 - 03:05 1.17 DRILL C 03:05 - 06:00 2.921 DRILL C 06:00 - 06:15 0.25 DRILL C 06:15 - 06:45 0.50 DRILL C 06:45 - 07:30 0.75 DRILL C 07:30 - 09:45 2.25 DRILL C 09:45 - 10:00 0.25 DRILL C 10:00 - 11:00 1.00 DRILL C 11:00 - 13:50 2.83 DRILL C 13:50 - 16:00 2.17 DRILL C 16:00 - 17:00 1.00 DRILL C 17:00 - 18:30 1.50 DRILL P 18:30 - 21:00 2.50 DRILL P 21:00 - 22:00 1.00 DRILL P 22:00 - 00:00 2.00 DRILL P 12/25/2009 100:00 - 01:45 1.751 DRILL P 01:45 - 02:05 0.33 DRILL P 02:05 - 02:50 0.75 DRILL P 02:50 - 04:00 1.17 DRILL P 04:00 - 06:45 I 2.751 DRILL I P EDC= 10.23 PVT= 215 bbls Iri/Out Rates= 1.51/1.38 IAP= 203psi OAP= 94psi PROD1 Stacking WT and irratic ROP, start new mud down CT. PROD1 Drilling hard shale PROD1 Mud swap complete, drilling ahead dropping to 88 deg and holding FS= 2355psi ~ 1.5 ROP= 60-105 fph WOB= 1.41 k to 2.13k EDC= 9.78 PVT= 127 bbls In/Out Rates= 1.51/1.45 IAP= 85psi OAP= 20psi PROD1 Good WT transfer but after tag it stops moving, POOH for a itator PVT= 344 bbls IAP= 85psi OAP= 20psi PROD1 SAFETY MEETING. PJSM for change out BHA. PROD1 VD BHA #9. Bit has 1-2 with some worn cutters. PROD1 P/U BHA #10. HYC SRX Bit with 1.1 deg AKO, 2-3/8" CoilTrak with Res and Agitator. PROD1 RIH. Surface test agitator 1.7 bpm, good. PROD1 Log tie-in -6' correction. PROD1 Tag shale at 12960. Ta TD PROD1 Directionally drill 1.6/1.44 bpm C~ 3360, FS=3050, .wob 1.3, ecd 9.93, to 13150'. PROD1 Wiper to 10880' PROD1 Directionally drill 1.63/1.46 bpm ~ 3460, FS=3050, .wob 1.3, ecd 10.07, to .13200 PROD1 Directionally drill 1.63/1.46 bpm ~ 3310, FS=3050, .wob 1.7, ecd 10.03, to 13,282'. Difficulty sliding. Wiper trip. PROD1 Wiper to 10880'. PROD1 Drill from 13,282' at 1.62/1.46 bpm ~ 3950 psi, 3200 psi FS, 2.Ok# DHWOB, 11-250 fph ROP, -2.3k to -6.2k# CT Wt, IA = 146 psi, OA = 70 psi, PVT = 293 bbl, NBI = 88 deg Drill to 13,370'. Well has 800' of perforatable sand. Plan forward is to turn own and dive to find HOT. PROD1 Drill from 13,370' at 1.61/1.46 bpm ~ 3400 psi, 3200 psi FS. Slight differential sticking on bottom with occasional 10k-20k# overpulls. 1.6k-1.9k# DHWOB, 10-150 fph ROP, -6k CT Wt, IA = 192, OA = 9Q, PVT = 278,.. NBI = 88 to 81 deg ' Drill to 13,451'. PROD1 Wiper to 10,880'. Set down several times at 11,170' at 90L. Worked past at 130L. PROD1 Log Tie-in. +13' correction. PROD1 Continue wiper to TD. PROD1 Drill from 13451' ~ 1.54/1.30 C~ 3700 psi , 3300 psi FS Frequent stacking with clean pick ups. Drill to 13500'. PROD1 Slow wiper at 19 fpm while circulate bottoms up sample looking for HOT. HOT found in sample. TD called at 13,500'.' Continue final wiper at 27 fpm. have to orient thru 11166 and at rrintea: ai~oi~wa i is io:vc rm i BP EXPLORATION Page 12 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations ~ _ - _ _ 2/25/2009 04:00 - 06:45 2.75 DRILL P PROD1 window 11572. 06:45 - 07:00 0.25 DRILL P PROD1 Log tie-in +3 correction. 07:00 - 07:50 0.83 DRILL P PROD1 RIH see motor work 12900 thru 13050 ,Tag at 13498. 07:50 - 11:00 3.17 DRILL P PROD1 POH la in liner runnin ill. EOP flag 9600' 11:00 - 11:40 0.67 DRILL P PROD1 LD bha bit 3-2. 11:40 - 12:45 1.08 CASE P RUNPRD MU 1 joint PH-6. Pump slack from CT3-4 bpm. Recover 255'. 12:45 - 18:00 5.25 CASE P RUNPRD MU liner 50 its 2-3/8 13 CR. 18:00 - 18:20 0.33 CASE P RUNPRD Crew change. SAFETY MEETING, re: PU Liner. 18:20 - 20:25 2.08 CASE P RUNPRD PU remainin 49 ' ELBRT, and 6 jts of CSH. Stab onto well 20:25 - 21:40 1.25 CASE P RUNPRD Circulate at surface filling liner. 21:40 - 00:00 2.33 CASE P RUNPRD Run Liner: Indexing guide shoe, float collar, 1 jnt 2-3/8" 4.7 ppf STL 13CR LNR, float collar, 1 pup jnt 2-3/8" STL 13CR, 48 jnts 2-3/8" 4.7 pnf STL 13CR LNR, 2 pup jnts 2-3/8" STL 13CR, 50 jnts 2-3/8" 4.7 ppf STL 13 CR LNR, 1 pup jnt 2-3/8" STL 13CR, SELBRT, 3/4" Disconnect, 6 jnts 2-1/16" CSH, Baker quick connnect, & CTC. OAL = 3285.88' Run liner at 85 fpm in cased hole, pumping minimum rate. Wt Check Above Window = 29k# Run liner at 50-60 fpm in open hole, pumping minimum rate. Work liner through shales starting at 12,830'. 9600' EOP Flag seen at 9583' EOP (-17' correction) Work to 12,900'. 2/26/2009 00:00 - 03:00 3.00 CASE P RUNPRD Work liner from 12,900' through shales. Stop at 13020', 13285' and circulate at 0.3 bpm until full returns are seen. Work liner to 13,285' 03:00 - 04:00 1.00 CASE P RUNPRD Close choke keeping -300 psi back pressure on the well. Open choke bleeding off pressure and continue working the liner. Circulate with -7k# CT Wt at 0.3 bpm in / 0.3 bpm out. Unable to work past 13,279'. 04:00 - 07:30 3.50 CASE P RUNPRD Circulate with -4k# CTWt at 1.4 bpm / 1.2 bpm ~ 2500 psi. Work Iiner.Circulate 1.98/1.81 bpm @ 3360 psi. 07:30 - 08:30 1.00 CASE P RUNPRD PU to 44 K to acquire ball drop position. Launch 5/8 steel ball in mud with 1500 psi. Hear ball go over the top.54 bbl away. Surge pipe 08:30 - 09:50 1.33 CASE P RUNPRD Surge pump, rock coil. Surge pump.two volums + pumped. Pump Pill after 110% No results. 09:50 - 10:34 0.73 CASE P RUNPRD Launch second ball 5/8 AI in Pill. Pressure to 1630 psi and launch ball. Ball rolling. Lost prime after 1 bbl resume pumping 1.9 bpm 3440 psi. Heard ball rolling 12.7 bbl into displacement. PU SO. Pin hole CT in injector. 10:34 - 13:00 2.43 CASE N SFAL RUNPRD Discuss options with town and gather information and proce ures to we repair pin o e. 13:00 - 13:15 0.25 CASE N SFAL RUNPRD PJSM for weld repair of pin hole. 13:15 - 14:15 1.00 CASE N SFAL RUNPRD Circulate locate pin hole. Flag pin hole. Locat pin hol at bottom of chains. 2.5K down. Set upper combi. Increase koomey pressure to 2800 psi. Manuel lock BOP.Open HCR. Strip off lubricator. Install slips an og co ar. WT -.9K. Dial up chain tension. Untra sound test after adjacent to weld .152 - .156 OK. Weld pin hole. Strip back onto lubricator. Attempt to circulate t en see psi spike. rrincea: arzaizuva iisi°:~cHrvi i ~ BP EXPLORATION Page 13 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/26/2009 14:15 - 15:08 0.88 CASE P RUNPRD Circulate .72/.57 bpm C~? 2010 psi. 15:08 - 18:00 2.87 CASE P RUNPRD PU 44K not released.Circulate 10 bbl KCL and 10 bbl Hi Vis bio pill.. YP = 50 Cir 1.05-.95 bpm pressure initiall at 2100 psi rising to 2600 psi.Circulate 56 bbls. NO Go .Launch 5/8 phenolic ball with 5 bbl pill ahead and 5 behind. Launch with 500 psi. Circulate 1.73/1.57 bpm ~ 3580 psi. After 33 bbl reduce rate to 1.2/1.08 bpm @ 3000 psi. After 51 bbls no ball on seat. PU 40K. Not released. 18:00 - 18:50 0.83 CASE N DFAL RUNPRD Shutdown on t e pumps. Shift change, detailed handover with night crew, discuss options with town. 18:50 - 22:20 3.50 CASE N DFAL RUNPRD Starting circulating KCL. Initally pump 1.2 bpm in / 0.3 bpm out. PU to 38k, liner is not released. Gradually returns increased to 1.2 bpm in / 1.1 bpm out. Pump at 4 bpm, 4500 psi for 1 minutes, PU 38k, liner not released. Wait for delivery of additional KCL before pumping more due to losses. 22:20 - 22:30 0.17 CASE N DFAL RUNPRD Pump 40 bbl at 3.65 bpm / 1.82 bpm ~ 4200 psi. PU 38k, liner not released. 22:30 - 22:50 0.33 CASE N DFAL RUNPRD SAFETY MEETING discussing procedure, hazards, & mitigations to pump high viscosity pill and maximize differential across the SELBRT. 22:50 - 00:00 1.17 CASE N DFAL RUNPRD Batch u 15 bbl frac el ill. PT cement lines to 6000 psi. 2/27/2009 ~ 00:00 - 01:00 ~ 1.00 CASE ~ N ~ DFAL ~ RUNPRD Pump 15 bbl of frac gel pill to SELBRT to shift SELBRT Vol Q P Pump Frac Gel Pill 3 3 3400 i0 3 3800 15 3 3950 Switch to KCL - --- 25 3 4400 3Q 3 4550 35 3 4650 40 3 44600 Pill. at SELBRT, increase pump rate 45 3.2 5700 50 3.2 5800 55 3 5700 60 3 5700 Shutdown pumps, shut-in cementers and blowdown cement line- RD cementers 01:00 - 04:00 3.00 CASE N DFAL RUNPRD Next attem t is to ull the liner to surface. Order and wait on crude oil. 04:00 - 07:00 3.00 CASE N DFAL RUNPRD Test crude. Pump 50 bbl crude. Let Soak. Pull to 35k# on the liner. Coil pin holed below the goose neck and is weeping crude. Stack weight on liner moving pin hole to between injector Nnntea: siz~izuua nao:uz,vrn s + BP EXPLORATION Page 14 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date ,From - To Hours Task Code NPT Phase Description of Operations _ _ -- _ 2/27/2009 ~ 04:00 - 07:00 ~ 3.00 CASE N DFAL RUNPRD Circulate crude out of the well. Holding 120 psi in choke 07:00 - 07:15 0.25 CASE N DFAL RUNPRD Safety meeting for Stripping off injector and weld repair. 07:15 - 09:30 2.25 CASE N DFAL RUNPRD Clean floor. Conduct conference calls on path forward. 09:30 - 10:15 0.75 CASE N DFAL RUNPRD Stri off and reweld in hole. Strip back onto well. 10:15 - 13:00 2.75 CASE N DFAL RUNPRD Stab back onto well circulate at .53/.4 bpm ~ 300 psi. Wait on pump truck and frac gel. 13:00 - 13:15 0.25 CASE N DFAL RUNPRD PJSM for pumping hi vis pills. 13:15 - 14:55 1.67 CASE N DFAL RUNPRD Prime pump PT lined s to 6000 psi. Mix 13 bbl 4#/bbl Flo vis L pill. Pump 13 bbls pill and displace with 39 bbl KCL 2 bpm Q 3660 psi, Shut down. 14:55 - 17:00 2.08 CASE N DFAL RUNPRD Total in vol 52.2 bbls. Wait 20 min. 15:15 Break circulation with 3717 psi .75 bbls Total in vol 52.95 bbls Wait 20 min 15:40 Break circulation with 3870 psi .75 bbls Total in vol 53.7 bbls Wait 20 min 16:00 Break circulation with 3900 psi 1.0 bbls Total in vol 54.7 bbls Wait 20 min 16:20 Break circulation with 3800 psi 1.16bbls Total in vol 55.8 bbls Wait 20 min 16:40 Break circulation with 4150 psi 1.45bbls Total in vol 57.25 bbls Wait 20 min 17:00 Break circulation with 2900 psi 1.25bbls Total in vol 58.5 bbls Wait 20 min 17:00 - 18:15 1.25 CASE N DFAL RUNPRD Circulate pill to surface. 18:15 - 18:35 0.33 CASE N DFAL RUNPRD SAFETY MEETING discussing procedure, hazards, and mitigations o pump 13 bbl 55# HEC frac pill to create delta pressure across SELBRTto shift tool & release from liner. 18:35 - 21:45 3.17 CASE N DFAL RUNPRD Batch up 13 bbl of 55# Frac gel Warm up mes, ypass ree ouse micromotion PT cement lines to 6000 psi Pump 16 bbl pill followed by 32 bbl KCL (8 bbFof Frac Gel belowrSEI;BF~T), Down on pumps 19:55, ;„, - , Total Vol = 48`bbl, Wait 15 min. ~' `"'"""- 20:10 Break circulation with 4400 psi, 1.6 bbl. Tot Vol = 49.6 bbl 20:18 Break circ w/ 4900 psi, 1.1 bbl, Tot Vol = 50.7 bbl 20:29 Break circ w/ 5200 psi, 1.2 bbl, Tot Vol = 51.9 bbl 20:39 Break circ wf 5300-psi, 1.3 bbl, Tot Vol = 53.2 bbl 20:50 Break circ w/ 5800 psi, 1.5 bbl, Tot Vol = 54.7 bbl 21:00 Break circ w/ 5800 psi, 1.3 bbl, Tot Vol = 56.0 bbl 21:12 Break circ w/ 5800 psi, 1.3 bbl, Tot Vol = 57.3 bbl 21:24 Break circ w/ 5000 psi, 1.1 bbl, Tot Vol = 58.4 bbl Blow down cement lines 21:45 - 23:00 1.25 CASE N DFAL RUNPRD Circulate out Frac Gel. R/D Cementers. 23:00 - 00:00 1.00 CASE N DFAL RUNPRD Wait on crude. 2/28/2009. 00:00 - 01:15 1.25 CASE N DFAL RUNPRD Test Crude. Pump 50 bbl crude at 1.40 bpm in / 1.10 bpm out Pump 10 bbl McOH Pump 5 bbl KCL This positions McOH on the outer wraps of the reel, over the gooseneck, & 900' into the well for freeze protection. Crude is in the remainder of the CT, in the OH annulus, and 440' in the Printed: 3/23/2009 11:15:02 AM ~ ~ BP EXPLORATION Page 15 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALIS TA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ~I Task ~I Code NPT Phase ', Description of Operations 2/28/2009 00:00 - 01:15 01:15 - 04:45 1.25 3.50 CASE CASE N N DFAL DFAL RUNPRD RUNPRD annulus of the 4.5 slotted liner. Let crude soak for 2.5 hrs. Pump 2 bbl. Soak for 10 min. Pump 4 bbl. Soak for 15 min. Pull to 64k#k CT Wt. Liner is not released. Keep 58k# CT wt and cycle the pumps. 04:45 - 06:00 1.25 CASE N DFAL RUNPRD Circulate out crude keeping 58k# CT Wt. 06:00 - 10:00 4.00 CASE N DFAL RUNPRD Wait on E line spooler. Prep floor for hot tap and tubing cuttin .With CT set in compression with -5K. Combies Set with 2800 psi and manuel locks set. PJSM for strippin off Iubricator.Strip off lubricator. 10:00 - 10:15 0.25 CASE N DFAL RUNPRD PJSM for Hot tap 10:15 - 11:00 0.75 CASE N DFAL RUNPRD Hot Tap CT. 11:00 - 13:30 2.50 CASE N DFAL RUNPRD RU Eline. Cut coil tubin and Cut Ewire. Pull 180' of wire with tugger. RU to E line unit and spool wire Recover E wire. Pull last 300' from well by hand to eliminate potential for the tail to whip around. Boot in good condition. No birds nests. No Balls recovered. 13:30 - 14:40 1.17 CASE N DFAL RUNPRD Install inverted kendal connector. Kendal shorter than the . 14:40 - 16:30 1.83 CASE N DFAL RUNPRD Circulate to see if one of the three lost balls finds a ball seat. 1 bpm C~ 938 psi. Pump 30 bbls surface to SEBLRT liner running tool. No Go. decided to pump 4th 5/8" ball Stl .Per Baker four is the max that the ball catcher can hold. Circulate 1.3 bpm @880 psi. Pump 30 bbl. No shear. Drop 3/4" disconnect ball. Displace at .5/.28 bpm with 120 psi. Ball on seat 11.4 bbls. surge well to 4800 psi 16:30 - 17:30 1.00 CASE N DFAL RUNPRD Cut 156 ' of CT. While waiting on pump truck. 17:30 - 18:30 1.00 CASE N DFAL RUNPRD Wait on machine shop to turn down spoolable connector, it was sized for a tapered string. Crew change. 18:30 - 22:30 4.00 CASE N DFAL RUNPRD RU cementers PJSM then MU BD Kendal spoolable connector to CT in injector (connector has 27k# pull rating). PJSM re: stabbing connector, PT'ing cementers, and pumping to disconnect from liner. Stab BD Kendal connector into CT stump in the slips and MU connector. PT cementers to 6000 psi. Line up to pump down the coil. Pressure up to 5500 psi, bleed off. PU to 18k# CT Wt. Pressure up to 5800 psi, bleed off. PU to 30k# CT Wt. Getting ppear to be partial y s eared in the disconnect. Switch to rig pumps and cycle pressure and work pipe to release. Unable to release. 22:30 - 00:00 1.50 CASE N DFAL RUNPRD Circulate 0.35 bpm in / 0.24 bpm out C~3 2260 w/ 29k# CT Wt while we regroup w/ Baker and town team on a plan forward. Call out eline unit to chemical cut Baker is brainstormin fishing tans, and SLB is retrieving tools to hot tap. 3/1/2009 00:00 - 10:00 10.00 CASE N DFAL RUNPRD Wait on E-Line unit. 10:00 - 10:30 0.50 CASE N WAIT RUNPRD Wait on weather field activities shutting down anticipating Phase 3. SLB will not leave Deadhorse. 10:30 - 00:00 13.50 CASE N WAIT RUNPRD Phase 3 Weather called. 3/2/2009 00:00 - 07:00 7.00 CASE N WAIT RUNPRD GPB is in Level 2 on all main roads and Level 3 on access Printetl: 3/23/2009 11:15:02 Ann ~ ~ BP EXPLORATION Page 16 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/1.1/2009 Rig Name: NORDIC 1 Rig Number: Date From - To ' Hours Task Code NPT Phase Description of Operations 3/2/2009 00:00 - 07:00 7.00 CASE N WAIT RUNPRD roads and pads. 07:00 - 08:00 1.00 CASE N DFAL RUNPRD PJSM for stripping off lubricator and Hot tapping. Spot Wireline unit. 08:00 - 09:00 1.00 CASE N DFAL. RUNPRD Strip up off lubricator and Hot tap CT. 09:00 - 09:30 0.50 CASE N DFAL RUNPRD PJSM for RU of E line with chemica cutter. 09:30 - 13:00 3.50 CASE N DFAL RUNPRD UP 6' lubricator MU Lubricator XO 7" to 5.5" Otis and grease pack off. RU sheeves .NOTE Cutter is 1.375" ID of Baker. Disconnect is 1.375". Bead weld three Tack welds on nose of cutter and confirm NO GO. MU tool string and arm chemical cutter. Stiffness of 1.3/8 Chemical cutter 18.5' raised concern of not being able to pull the Cutter out of hole (pulling out of weak point) decided to add spacer to bottom 13:00 - 16:45 3.75 CASE N DFAL RUNPRD Wait on fabrication of spacer. RU and pu additional tension into CT 19K per recommendation PE E line supervisor. 16:45 - 17:10 0.42 CASE N DFAL RUNPRD PJSM for PU Chemical cutter. 17:10 - 21:00 3.83 CASE N DFAL RUNPRD PU Chemical cutter. Arm cutter,Strip into lubricator. cutter F'UUN to SUrtaCe. 21:00 - 21:15 0.25 CASE N DFAL RUNPRD PJSM to UD Chemical cutter. '. , 21:15 - 22:30 1.25 CASE N DFAL RUNPRD Pull Chemical cutter. R/D eline lubrica#4r and equigrrtentx~,~' 22:30 - 00:00 1.50 CASE N DFAL RUNPRD Chemical cutter did not function properly. Severing head was' `; blown off and left downhole and 2/3 of the chemical holes do 13/3/2009 ~ 00:00 - 00:45 ~ 0.75 ~ CASE ~ N 00:45 - 01:00 0.25 CASE N i 01:00 - 01:45 0.75 CASE N 01:45 - 01:55 0.17 CASE N 01:55 - 05:00 3.08 CASE N 05:00 - 07:00 ~ 2.00 ~ CASE ~ N 07:00 - 14:00 7.00 CASE N 14:00 - 18:00 4.00 CASE N not show an increased diameter from chemical flow. It appears ghat only 1/3 of the CT was cut. Discuss options w/ the PE shop & town team. DFAL RUNPRD Discuss options w/ town team. SLB E-line is driving to Kuparuk to find another chemical cutter. DFAL RUNPRD PJSM to install kendal connector on CT stump and PU CT stump w/ blocks. DFAL RUNPRD Install Kendal Connector on CT stump PU on CT slum w/ blocks to 31 k# Pipe is free, PU 7' to ensure pipe totally free, _ Secure CT in slips DFAL RUNPRD PJSM to cut off kendal connector & install spoolable connector. DFAL RUNPRD Cut kendal connector then MU spoolable connector to CT stump. Stab injector. Spool coil onto reel POH 70-100 fpm, 0.63 bpm ~ 2 40 psi DFAL RUNPRD Unstab injector and POH last 200' slowly. Move injector to ciruclation hole. LD 6 joint 2-1/16 CHS and High load disconnect. Recovered 5/8" Stl ball, 5/8 phenaulic ball and 3/4" • stl disconnec a. o e a as s was aunc a rom e riq floor after cutting coil and removing the E line from the coil _ tubin .. ~..• : DFAL RUNPRD Test ROPE. Send test report to AOGCC. Witness waived by John Crisp. DFAL RUNPRD Blow down Reel with N2 and bleed down. Pull coil stub to reel and secure coil end on reel Printetl: 3232009 11:1 S:UL AM .. ~ BP EXPLORATION Page 17 of 25 Operations Summary Report Legal Well Common W Event Name Contractor Rig Name: Date I, Name: 0 ell Name: 0 : R Name: N N From - To 5-27 5-27 EENTE ORDIC ORDIC Hours R+COM CALIST 1 Task ' PLET A Code' E NPT i Start Rig R Rig N Phase ', Spud Date: 10/5/1989 : 2/5/2009 End: 3/11/2009 elease: 3/11/2009 umber: Description of Operations 3/3/2009 18:00 - 18:15 0.25 CASE N DFAL RUNPRD SAFETY MEETING, re: reel swap 18:15 - 23:00 4.75 CASE N DFAL RUNPRD Lower 2" reel. PU reel w/ 2" tapered string RU reel hardline. 23:00 - 23:10 0.17 CASE N DFAL RUNPRD SAFETY MEETING, re: pulling coil across 23:10 - 00:00 0.83 CASE N DFAL RUNPRD Pull coil across 3/4/2009 00:00 - 02:00 2.00 CASE N DFAL RUNPRD PU Fishin tools to ri floor MU Baker connector Pull Test & pressure test connector Fill Coil and pressure test bulkhead. 02:00 - 02:30 0.50 BOPSU N DFAL RUNPRD Test and chart the inner reel. Wire bulkhead is leaking. 02:30 - 05:00 2.50 CASE N DFAL RUNPRD Tighten and regrease the bulkhead packing--still leaking. Bring out parts from SLB shop. Change out packing. PT to 1000 & started leaking. 05:00 - 06:00 1.00 CASE N DFAL RUNPRD Wait on new packing material to be made. 06:00 - 08:30 2.50 CASE N DFAL RUNPRD Make up bulkhead 7/32" E-Line packing and press test with 4600 psi. OK. 08:30 - 08:45 0.25 CASE N DFAL RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U BHA and pump slack out of coil. 08:45 - 09:15 0.50 CASE N DFAL RUNPRD M/U XO and 1 jt CSH. 09:15 - 10:00 0.75 CASE N DFAL RUNPRD Circ at 3.2 bpm at 4200 psi. Circ 2 times, heard E-Line moving for 3 minutes. Cut off 302' of 7/32" E-Line. 10:00 - 11:15 1.25 CASE N DFAL RUNPRD Insert 1/2" Steel ball. Launch ball with 500 psi and circ at 2.1 bpm. Heard ball in coil Slow rate to 1.5 bpm at 30 bbls. Pump 45 bbls. Recover 1/2" ball Circ 5 bbl high density pill. Got returns at 40.0 bbls. Very close to calculated coil volume. 11:15 - 11:30 0.25 FISH N DFAL RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U BTT fishing BHA. 11:30 - 12:20 0.83 FISH N DFAL RUNPRD M/U BTT fishin BHA #1 with Stinger, GS spear, jars, 4 jts CSH. 12:20 - 14:15 1.92 FISH N DFAL RUNPRD RIH with fishing BHA #1 while circ at 0.4 bpm at 500 psi. Up Wt at 10100' = 33K. 14:15 - 14:40 0.42 FISH N DFAL RUNPRD Up wt C~ 10,100' = 33k# Set down C~ 10,177 - no pumps PU clean - no pumps ,, .,,.: Stack wei ht a ain - 5k# PU to 37k# (5k over). Appear to have the fish. Stack weight again to 5k# „ - . ~,~ ,: Pressure up to 3800 psi & hold for 4 min Bleed off pressure through Baker choke to 0 psi 14:40 - 15:15 0.58 FISH. N DFAL, RUNPRf~; Pick up to 40k# -not free ' ~ Stack 10k# down Close Baker choke Pressure up to 4000 psi, hold for 4 min, then bleed off slowly. PU to 45k#. Depth ~ 45k# = 10,167.5' Pump 5 bbl to warm coil ~ .7 pm, 1400 psi Stack 10k#, close Baker choke. Circulate at 0.3 bpm, Bleed press. PU to 50k# ~ 10,165'. Pull slow at 52-55K for 5'. Moving coil. C~ 10.155' popped free rnniea: aieaicuva i is io.~c nm ~ ~ BP EXPLORATION Page 18 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date .From - To Hours I Task Code NPT Phase Description of Operations 3/4/2009 14:40 - 15:15 0.58 FISH N DFAL RUNPRD Drag 5' ~ 52-55k PU C~ 32k up wt -- up to 10,132'. 15:15 - 15:30 0.25 FISH N DFAL RUNPRD Stack 10k# ~ 10,175' -- 5' high PU 30k - 32k# Stack weight again - 10k# Pick up ~ 32.5k - no pump 15:30 - 18:15 2.75 FISH N DFAL RUNPRD POOH C~ 60 fpm, circulating across the top 18:15 - 18:30 0.25 FISH N DFAL RUNPRD SAFETY MEETING, re: L/D fishing BHA 18:30 - 19:15 0.75 FISH N DFAL RUNPRD VD BTT fishing BHA #1 9:15 - 22:45 .50 ISH N FAL UNPRD No fish. Stin er is bent O-rings on bottom of stinger are missing, rupture disc is burst, and the GS collet is in good shape with no rounded corners. The coil took 12 bbls to fill before circulating in the bung hole. Discuss options with town team and BTT. We have good indication that the SELBRT is free and most likely we released ', from the fish due to fluid falling out of the coil. Decided to fish with wireline GR spear with a jar down release finned with annealed steel Wait on tool to be located, pinned properly, and delivered. 22:45 - 23:30 0.75 FISH N DFAL RUNPRD PU BTT Fishing BHA #2 23:30 - 00:00 0.50 FISH N DFAL RUNPRD RIH BTT Fishin BHA#2 with GR s a w/jar down release, jars, 2 drill collars, and 4 jnts CSH. 3/5/2009 00:00 - 01:15 1.25 FISH N DFAL RUNPRD RIH w/ BTT GR Spear Fishing BHA #2 to 10,100'. 01:15 - 01:30 0.25 FISH N DFAL RUNPRD Up Wt = 33k RIH 15 fpm, Down Wt = 19.8K# Slow to 6 fpm C~3 10,156'. Set down 900# at 10,171' PU Wt = 33k# RIH, set down 1500# at 10172.7' PU Wt = 33k# RIH, set down 2000# at 10,172.1'. PU Wt = 33k# 01:30 - 02:45 1.25 FISH N DFAL RUNPRD POOH to surtace. 02:45 - 03:00 0.25 FISH N DFAL RUNPRD SAFETY MEETING, re: UD Fishing BHA & PU next BHA. 03:00 - 04:00 1.00 FISH N DFAL RUNPRD L/D BTT Fishing BHA #2. Recovered SELBRT with bottom seals missin . Six, 2.25" Chevron seals missing, 4 down, 2 up normal setup Aluminum & Steel ball recovered. 04:00 - 06:30 2.50 CEMT N DFAL RUNPRD Wait on LBRT stinger to be redressed at Baker shop for next run. 06:30 - 07:30 1.00 CEMT N DFAL RUNPRD Circ 3/4" steel ball, pump 42 bbl, recover 3/4" ball. 07:30 - 07:45 0.25 CEMT N DFAL RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U Seal Assy BHA. 07:45 - 08:10 0.42 CEMT N DFAL RUNPRD M/U BTT seal assembly BHA. 08:10 - 10:25 2.25 CEMT N DFAL RUNPRD RIH with BTT 2.24" Seal assembly, circ at 0.2 bpm, 150 psi. Up wt at 10100' = 33K Circ 20 bbl of 2# Biozan to bottom. RIH slow with 0.1 bpm, 220 psi. First pump press inc at 10,172.5'. seals inside PBR. stop pump. Open Baker choke. RIH to 10,179.6' and start to stack wt. Stack 10K at 10,183.5'. Close Baker choke. rnnteo: ai~ai~~~a i is i o:vc r.rvi • • BP EXPLORATION Page 19 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 3/5/2009 10:25 - 11:00 0.58 CEMT N DFAL RUNPRD Press up to 2400 psi and shear LWP at 39.5 bbls displ. Displ LWP at 0.8 bpm at 1500 psi, 0.7 bpm returns. Bump LWP at 54.0 bbl displ, 2.74 bbl late. Press up to 2500 psi and press fell off to 500 psi in 1 mina Press up to 2500 psi again and press fell off to 200 psi in 1 min. Seals in PBR were OK before shearing LWP. 11:00 - 12:30 1.50 CEMT N DFAL RUNPRD POH with seal assembly BHA. Circ 1.0 bpm, 650 psi, 0.3 bpm returns. 12:30 - 12:45 0.25 CEMT N DFAL RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for UO BHA and M/U milling BHA. 12:45 - 16:00 3.25 CEMT N DFAL RUNPRD UO seal assembl BHA #14. Recovered all tools. M/U millin BHA #15 with new 1.875" HCC Diamond parabolic mill, 1-11/16" motor, circ sub, hyd disc, XO and 104 jts of 1" CSH. Pick up CSH in singles due to Derrick down rig move. M/U Hyd Disc, Check valves, 2 jts CSH, Quick conn and CTC. BHA OAL = 3,291.78'. 16:00 - 17:30 1.50 CEMT P RUNPRD RIH with 1.875" milling BHA at 90 fpm. Circ at 0.3 bpm, 500 psi Ta de to ment sleeve rofile at 10,184'. 17:30 - 19:00 1.50 CEMT P RUNPRD Mill deployment sleeve profile with 1.875" parabolic mill. 0.9 bpm, 2500 psi. Stalled fi times total. Ream up and down 3 times. 19:00 - 20:15 1.25 CEMT P RUNPRD Cleanout to PBTD. Ta PB 20:15 - 22:00 1.75 CEMT P RUNPRD POH to surface. 22:00 - 22:15 0.25 CEMT P RUNPRD SAFETY MEETING, re: UD Cleanout BHA 22:15 - 00:00 1.75 CEMT P RUNPRD UD Cleanout BHA and standback 52 stands of 1" CSH. 3/6/2009 00:00 - 00:30 0.50 CEMT P RUNPRD Finish UD CSH. 00:30 - 02:00 1.50 EVAL P LOW ER1 PU Logging tools to rig floor. MU Lo in BHA with CR/CCL tool, 2 jnts of 2-1/16" CHS, 4 jnts of 1" CSH, and MHA. 02:00 - 03:45 1.75 EVAL P LOWERI RIH w/ GR/CCL Logging BHA, OAL = 206.3' 03:45 - 04:45 1.00 EVAL P LOWERI Log down from 9,600' to 10,300' C~ 30 fpm Log up from 10,300' to 9,600' @ 30 fpm. 04:45 - 06:30 1.75 EVAL P LOWERI POOH. Lay out logging tools. Download Memory logging data. Tied-in to CBL of 11/04/1989. uncorrected CT depth. Shoe is at 13,267. PBTD is at 13,227. 06:30 - 06:45 0.25 CEMT N DFAL RUNPRD SAFETY MEETING. Review procedure;,hazards and mitigation for M/U perf BHA with CSH. 06:45 - 09:45 3.00 CEMT N DFAL RUNPRD M/U liner punch BHA #17 with 10' SWS 1.56" perf gun, firing head, hyd disc, xo and 52 stds of_1".CSH. M/U Hyd disc, BPV, 2 jts 2-1/16" CSH, quick connect and CTC. BHA OAL = 3297.2'. 09:45 - 11:45 2.00 CEMT N DFAL RUNPRD RIH with liner punch BHA #17. Circ at 0.3 bpm; 230 psi. Tag PBTD at 13228'. Correct depth to 13,227. pick up 2'. 11:45 - 12:20 0.58 CEMT N DFAL RUNPRD Insert 1/2" AL ball, launch ball OK, heard ball in reel. Displ at 1.2 bpm, 3800 psi, 1.1 bpm returns. Printed: 3/23/2009 11:15:02 AM BP EXPLORATION Page 20 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/6/2009 11:45 - 12:20 0.58 CEMT N DFAL RUNPRD Slow pump at 25 bbls. 0.7 bpm, 1200 psi. Ball on seat at 39.0 bbl. firing head sheared at 3600 psi. 12:20 - 13:45 1.42 CEMT N DFAL RUNPRD POH with fired pert gun. 13:45 - 14:00 0.25 CEMT N DFAL RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for standing back 1"CSH and UO BHA. 14:00 - 15:45 1.75 CEMT N DFAL RUNPRD UO 2 jts 2-1/16" CSH and MHA. Stand back 52 stds of 1"CSH workstring. UO SWS fired 10' pert gun. All shots fired. PERFORATED INTERVAL IN 2-3/8" LINER = 13,220-13,22 6 spf• 15:45 - 16:15 0.50 CEMT P RUNPRD M/U Seal Ass BHA #18 for cementin liner. 2.24" seals on stinger, No-Go, Hyd Disc, 2 jts, 2-1/16" CSH, BTT quick connect and CTC. BHA OAL = 74.44' 16:15 - 18:00 1.75 CEMT P RUNPRD RIH with seal assembly cementing BHA #18. circ at 0.4 bpm, 220 psi. RIH to 10,100'. up wt = 31 K. Park seal assembly at 10170'. circ 0.1 bpm at 44 psi. 8:00 - 19:45 .75 EMT P UNPRD 10 175'. Stack 10K on NO-GO at 10,184'.. Circ 0.1 bpm at 95 psi. Circ. 0.5 bpm at 570 psi. 0.4 bpm returns, 13 bbls. Circ. 0.7 bpm at 970 psi. 0.6 bpm returns, 10 bbls. Circ. 0.9 bpm at 1310 psi, 0.7 bpm returns, 10 bbls Circ. 1.1 bpm at 1860 psi, 0.9 bpm returns, 15 bbls Circ. 1.3 bpm at 2200 psi, 1.0 bpm returns, 15 bbls Maximum circ rate with slick KCL water is 1.3 b m, losses at 30% Circ at 1.1 bpm at 1970 psi, 0.9 bpm returns, 100 bbls total. 19:45 - 20:00 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping 35 bbl Cement job with SWS. 20:00 - 21:00 1.00 CEMT P RUNPRD Batch mix 39 bbl, 12.5 PPG cement. Circ well at 1.1 bpm, 1900 psi, 0.9 bpm returns. 140 bbls. Cement at 12.5 PPG wt at 2100 hrs. 170 bbls KCL circulated. 21:00 - 22:30 1.50 CEMT P RUNPRD Circ. 5 bbl KCL water to warm cement line and pumps. ;~ Press test cement line to 6000 psi. OK. Bleed off press. Open up to coil. Stage 35 bbl, 12.5 ppg, G CMT. 1.1 bpm, .9 bpm returns, 2200 psi. In densiometer reads 12.45 bbg. SWS indicates 12.45 ppg. 10 bbl CMT, .9 bpm, 2250 psi, 0.8 bpm returns. - ~ 20 bbl CMT, 1.1 bpm, 3050 psi, 0.9 bpm returns 30 bbl CMT, 1.1 bpm, 3050 psi, 0.9 bpm returns, ~~ ~~ ~ 35 bbl CMT, 1.1 bpm, 3000 psi, 0.9 bpm returns. Stop pump,at 33.6 bbl. Lost prime with cement pump early. Isolate coil. Pump Biozan to cementers. Stage 1.5 bbl high vis Biozan, 3# Biozan Stage 12.4 bbl, 12.5 ppg, Formate Brine. 12.5 ppg measured at densiometer. Printed: 3/23/2009 11:15:02 AM BP EXPLORATION Page 21 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From. - To Hours ' Task Code NPT Phase Description of Operations 3/6/2009 21:00 - 22:30 1.50 CEMT P RUNPRD 6 bbl Brine, 1.1 bpm, 2600 psi, .7 bpm returns 10 bbl Brine, 1.0 bpm, 1600 psi, 0.9 bpm returns. 12.4 bbl Brine, 1.0 bpm, 1450 psi, 0.9 bpm returns. Stage Biozan displacement. 2 bbl Bio, cement at shoe, returns went to zero. 0.5 bpm, 2200 psi, 0 returns. 4.7 bbl Bio displ, locked up, 0.0 bpm, 4500 psi, Swap to SWS Cement pump. Displace with Biozan. pump up to 5800 psi, press broke, pump 0.2 bpm at 5900 psi. pump 0.3 bbl. Bleed down press. Press up again to 6000 psi. No pump rate. Bleed down press. Press up again to 6000 psi, No pump rate. liner is locked uo tight. 2.5 bbl cement outside liner before lock 22:30 - 23:00 0.50 CEMT P RUNPRD Bleed down press. Pick up and sting out of top of deployment sleeve. 2-3/8" Liner full of cement, 12 bbls. 2.5 bbl cement to 20.5 bbl cement inside coil. Close choke and bullhead cement down backside of 2-3/8" 20 bbl displ, 1.5 bpm. 3000 psi, .1200 psi siwhp, 25 bbl displ, 1.5 bpm, 2800 psi, 1280 psi siwhp. Coil fully displaced at 26 bbl displ plus 14 bbl Brine. Pump 2 bbl extra. Over displace coil volume by 2 bbl. 28 bbl displ. Stop pump. Monitor SIWHP. Lost 500 psi in 2 min. SIWHP = 650 psi after 5 min. Open choke slowly, bleed off whp. 23:00 - 00:00 1.00 CEMT P RUNPRD RIH while circ .9 bpm, to top of deployment sleeve at 10174': Circ. at 2.5 bpm, 3600 psi, 1.7 bpm returns. POH at 110 fpm, circ 2.8 bpm, 3250 psi, 3/7/2009 00:00 - 00:45 0.75 CEMT P RUNPRD POOH. 00:45 - 00:55 0.17 CEMT P RUNPRD SAFETY MEETING, re: BHA change. 00:55 - 01:30 0.58 CEMT P RUNPRD L/D Seal Assembly BHA #18 01:30 - 04:00 2.50 CEMT N CEMT RUNPRD eanout #19 wit 0 stands of 1 "CSH and 2 jnts of 2-1/16" CSH. 04:00 - 05:15 1.25 CEMT N CEMT RUNPRD RIH Cleanout BHA #19 05:15 - 07:30 2.25 CEMT N CEMT RUNPRD Wash/Drill cement at 0.93 bpm in / 0.83 bpm out C~? 2660 psi, 6 fpm, Out MM = 40 bbl Drill 0.91/0.83 C~ 3760 psi, 10 fpm. Drill 0.91/0.86 ~ 3600 psi, 12 fpm to 10,500'. Drill 1.11/0.90 Q 3700 psi, 17 fpm to 10,700'. PU 75'. CT Up ~` W1 ~ 28k# ~^ ~ 1 Dril~ement 1.00/0.95 C~ 3600 psi. Pump Biozan sweeps. 30'-100' wipers every 100'. CT Up Wt = 28k#. Drill cement to 10950'. 07:30 - 09:30 2.00 CEMT N CEMT RUNPRD Drill cement at 12 fpm. 1.0 bpm, 4300 psi, 0.9 bpm returns. Drilled to 11,170'. Drill cement at 8 fpm to 11350'. 5 stalls so far. Drill 50', wiper Printed: 3/23/2009 11:15:02 AM t , r BP EXPLORATION Page 22 of 25 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: 'From - To 05-27 05-27 REENT NORDIC NORDIC Hours ER+CO CALIS 1 Task MPLET TA Code E ' NPT Star Rig Rig ' Phase Spud Date: 10/5/1989 t: 2/5/2009 End: 3/11/2009 Release: 3/11/2009 Number: Description of Operations 3/7/2009 07:30 - 09:30 2.00 CEMT N CEMT RUNPRD at 50 fpm. Drill cmt at 7 fpm, 1.0 bpm, 4000 psi, 0.9 bpm returns. 10 stalls so far. Drilled to 11,600'. 100' clean wiper. 09:30 - 10:45 1.25 CEMT N CEMT RUNPRD Drill cement 6 fpm, 1.0 bpm, 4000 psi, 0.9 bpm returns. Drilled to 11700'. 12 hrs on cement, UCA = 300 psi. 100' clean wiper. 13 stalls total. Drill cement 5 fpm, 1.0 bpm, 3900 psi, .9 bpm returns. Staking wt. Drilled to 11900'. 10:45 - 11:50 1.08 CEMT N CEMT RUNPRD Wiper trip to 10,000' to clean hole. 1.0 bpm, 40 fpm up. RIH at 100 fpm. Clean hole. UCA sample at 500 psi. 11:50 - 13:30 1.67 CEMT N CEMT RUNPRD Drill cement 3 fpm., 1.0 bpm, 3900 psi, 0.9 returns. Drilled to 12100'. 15 stalls total. Drilled cement 3 fpm to 12,225'. 13:30 - 14:00 0.50 CEMT N CEMT RUNPRD Drill cement 3 fpm, 1.0 bpm, 3800 psi, 0.9 returns Stacking wt. Not sliding. Drilled to 12250'. 14:00 - 14:30 0.50 CEMT N CEMT RUNPRD Wiper trip to 11500' while adding friction reducer to fluid. RIH clean. 14:30 - 17:30 3.00 CEMT N CEMT RUNPRD Drill cement 3 fpm, 1.0 bpm, 3800 psi, 0.9 returns Drilled to 12400'. Wiper. Drill cement 3 fpm, 0.9 bpm, 3700 psi, 0.8 returns Drilled to 12,650'. Wiper. 17:30 - 19:00 1.50 CEMT N CEMT RUNPRD Wiper trip to 10,000' to ensure a clean hole and liner top. RIH clean to bottom. 19:00 - 21:15 2.25 CEMT N CEMT RUNPRD Difficulty getting started drilling. Hydraulic force pushing us off bottom. ,- Drill cement 1-2 fpm, 0.61 bpm in / 0.50 bpm out, 3000 psi Drill to 12,780'. 21:15 - 23:15 2.00 CEMT N CEMT RUNPRD Wiper to 10,000'. POH C~ 50-60 fpm, 0.9 - 1.0 bpm, RIH 100 fpm, 0.7 bpm. Difficulty sliding from 12,650' to TD. Add friction reducer to fluid. 23:15 - 00:00 0.75 CEMT N CEMT RUNPRD Drill cement 1-2 fpm, 0.60 / 0.5 bpm,,2850 psi. Drill to 12,800'. 3/8/2009 00:00 - 00:55 0.92 CEMT N CEMT RUNPRD Drill from 12,800' at 0.~6 bpm in / 0.65 bpm out C~ 3300 psi, 1-2 fpm Drill to 12,900'. 00:55 - 01:45 0.83 CEMT N CEMT RUNPRD Wiper to 12,000', 1.0 bpm, 35 fpm. Wiper to TD at 0.10 - 0.80 bpm, 45 fpm. 01:45 - 03:50 2.08 CEMT N CEMT RUNPRD Drill from 12,900' at 0.72 / 0.60 bpm C~ 3500 psi, 1-3 fpm Drill to 13,050'. DAYLIGHT SAVINGS TIME IN,EFFECT (LOST 1 HR) 03:50 - 04:45 0.92 CEMT N CEMT RUNPRD Wiper to 12,000', 0.9 bpm, 40?~i. Wiper to TD at 0.10 - 0.85 bpm, 50-65 fpm. 04:45 - 06:00 1.25 CEMT N CEMT RUNPRD Drill from 13,050', 0.70 / 0.59 bpm, 1-2 fpm. Total of 21 stalls on mud motor. Stalls at 13,081', 13,118' 06:00 - 08:00 2.00 CEMT N CEMT RUNPRD Drilled cement to 13130'. Unable to drill fiurther due to slind - Circ 35 bbl pill withyclean Bio7an and 1 % friction reducer. Still unable to get back to bottom. 08:00 - 10:15 2.25 CEMT N CEMT RUNPRD Wiper trip up to 10000' while empty one rig pit, add, new Biozan rnntea: sizsizoas tt:ts:uzann BP EXPLORATION Page 23 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: I ' I Date From - To Hours Task ; Code ' NPT ' Phase Description of Operations 3/8/2009 08:00 - 10:15 2.25 CEMT N CEMT RUNPRD and add 1 % friction reducer. RIH while circ new Biozan to bit. RIH to 13080'. unable to get deeper. 10:15 - 12:00 1.75 CEMT N CEMT RUNPRD POH while circ new Biozan in 2-3/8" liner. circ 0.7 bpm, 3000 psi. 12:00 - 12:15 0.25 CEMT N CEMT RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH. 12:15 - 15:00 2.75 CEMT N CEMT RUNPRD Stand back 50 stds of 1"CSH. UO milling BHA. 15:00 - 15:30 0.50 CEMT N CEMT RUNPRD Jet stack with swizzle stick. 15:30 - 15:45 0.25 BOPSU P RUNPRD Function test BOPE. Weekl function test. 15:45 - 16:00 0.25 CEMT N CEMT RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS MCBUGR/CCL logging BHA. 16:00 - 18:15 2.25 EVAL N CEMT RUNPRD M/U SWS Memo CBUGR/CCL, XO, circ sub, Hyd Disc, XO, 50 stds of 1 "CSH 18:15 - 19:30 1.25 EVAL N CEMT RUNPRD RIH w/ Logging Assembly 19:30 - 23:10 3.67 EVAL N CEMT RUNPRD Lo down at 0 fpm from 10,100' to 13.100' Log up at 30 fpm from 13,100 to 10,100'. 23:10 - 00:00 0.83 EVAL N CEMT RUNPRD POOH 3/9/2009 00:00 - 00:20 0.33 EVAL N CEMT RUNPRD POOH 00:20 - 00:30 0.17 EVAL N CEMT RUNPRD SAFETY MEETING, re: UD BHA and S/B CSH 00:30 - 03:00 2.50 EVAL N CEMT RUNPRD Standback 50 stands of CSH. UD SWS Memory CBUGR/CCL BHA. 03:00 - 07:00 4.00 EVAL N CEMT RUNPRD Wait on SWS to download tool data and generate logs. Email logs to Town. 07:00 - 08:30 1.50 EVAL P RUNPRD Perform injectivity test. Close choke, pump 0.5 bpm up to 1400 psi. Stop pump, ISIWHP = 1400 psi 4 min, 1000 psi 7 min, 800 psi 10 min, 750 psi 15 min, 700 psi 20 min, 660 psi 35 min, 550 psi Press does leak off, but ve low injectivity rate. A liner to acker will be re wired. 08:30 - 08:45 0.25 PERFO P LOWERi Prep rig floor to run SWS 1.56" pert guns. 08:45 - 09:00 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for running SWS 1.56" pert guns and 1" CSH workstring. 09:00 - 12:00 3.00 PERFO P LOWERI Run SWS 1.56',' PJ perf gun BHA #21, loaded at 6 spf, 825' of perfs. 1124' total, M/U hyd disc„ 59 jts CSH and a 7.9' pup, 2.68" No-Go to land on, Hyd Disc, BPV, 2 jts 2-1/16 CSH, quick connect and CTC. BHA OAL = 3025.18'. NO-GO to bottom pert = 2955.52' Top liner is at 10172'. Bottom shot de th on no- o = 13,127 12:00 - 14:00 2.00 PERFO P LOWERI RIH with pert BHA # 21. Tag No-Go on top of liner at 10,172'. Bottom shot depth = 13,125.5', Correct depth = 13,127.5', add 2 ft to CTD. 14:00 - 15:20 1.33 PERFO P LOWERI Insert 1/2" AL ball, press up to 1000 psi, open reel valve and Printed: 3/23/2009 11:15:02 AM BP EXPLORATION Page 24 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: 3/11/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/11/2009 Rig Name: NORDIC 1 Rig Number: Date From - To I Hours Task Code NPT Phase Description of Operations 3/9/2009 14:00 - 15:20 1.33 PERFOB P LOWERI launch ball. Position bottom pert charge at 13,127'. Displace AL ball at 1.1 bpm, 3000 psi. Heard ball in reel. Slow pump at 28 bbls to 0.5 bpm. Ball on seat at 39.5 bbls. Firing head sheared at 4400 psi. Fired guns on depth with bottom shot at 13,125'. 15:20 - 18:30 3.17 PERFO P LOWERI wit ire pe guns. Circ 0..8 bpm, 1800 psi. Flow check at top of liner. No flow. POH. Flow check at surface. 18:30 - 18:40 0.17 PERFO P LOWERi SAFETYMEETING, re: UD Perf BHA 18:40 - 20:30 1.83 PERFO P LOWERI UD 2 jts 2-1/16" CSH UD 59 jts of 1 "CSH 20:30 - 20:40 0.17 PERFO P LOWERI SAFETY MEETING, re: UD Perf Guns 20:40 - 23:30 2.83 PERFO P LOWERI UD 54 1.56" fired guns & blanks s ots ire , 1.5 spf, 1606PJ Charges PERFORATION INTERVALS 12,010' - 12,350'' 12,430' - 12,820'- 13,030' - 13,125'- TOTAL PERFORATED INTERVAL = 825' 23:30 - 00:00 0.50 PERFO P LOWERI Clean rig floor. Off load pert guns from pipeshed. 3/10/2009 00:00 - 00:30 0.50 PERFO P LOWERI Clean pipeshed and prep for running LTP. 00:30 - 00:50 0.33 CASE P RUNPRD PU Baker tools and LTP to rig floor. 00:50 - 01:00 0.17 CASE P RUNPRD SAFETY MEETING, re: PU Liner Top Packer BHA 01:00 - 02:00 1.00 CASE P RUNPRD PU LTP, 2 jts 2-1/16" CSH, and XOs. 02:00 - 04:20 2.33 CASE P RUNPRD RIH 3.5" HYD KB Liner Top Packer pumping minimum rate 50 - 70 fpm. 04:20 - 06:30 2.17 CASE P RUNPRD Weight Check at 10,100' = 28k# RIH at 40 fpm, pumping 0.10 bpm (Pump trips set to 1400 psi) Sting into seals at 10,176'. No go at 10182'. PU to 10,158'. Seals out not seen. Increase pumps to 0.2 bpm. RIH. Stin into seals at 10,174'. No go at 10,182'. PU to 10,159'. Seals out not seen. Pump down the backside & take returns up the coil. SIWHP = 900 psi. Circ P = 48 psi. RIH. Sting into seal at & no go at 10,182'. Pressure up back side to 1400psi. PU. Unsting from seals at 10,170' Launch 5/8" Aluminum ball with 1000 psi. Ball is rolling. RIH. No go at 10,181.6'. PU to 10,179.9 (Seals at 10,175.5'). Ball on seat at 32.6 bbl (38.5 bbl calculated). Pressure up to 2500. Set off 10k#. Bleed coil pressure. Pressure Test backside to 2000 si. Good test. Press u on LTP to 3700 psi and release from:. p. 06:30 - 08:30 2.00 CASE P _ RUNPRD POH with LTP running tools. =- ;. ~ cw 1.7 ~tpm~3100 psi. Printed: 3/23/2009 11:15:02 AM A • • BP EXPLORATION Page 25 of 25 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To j Hours Task Code I NPT 13/10/2009 08:30 - 09:00 0.50 CASE P 09:00 - 09:15 0.25 RIGD P 09:15 - 11:45 2.50 RIGD P 11:45 - 12:30 0.75 RIGD P 12:30 - 16:00 3.50 WHSUR P 16:00 - 18:00 2.00 WHSUR P 18:00 - 18:45 0.75 RIGD P 18:45 - 19:00 0.25 RIGD P 19:00 - 19:25 0.42 RIGD P 19:25 - 20:30 1.08 RIGD P 20:30 - 21:40 1.171 RIGD P 21:40 - 21:55 0.25 RIGD P 21:55 - 23:45 1.83 RIGD P 23:45 - 00:00 I 0.251 RIGD I P 3/11/2009 00:00 - 02:00 2.00 RIGD P 02:00 - 02:30 0.50 RIGD P 02:30 - 06:00 3.50 RIGD P 06:00 - 09:00 3.00 RIGD P Spud Date: 10/5/1989 Start: 2/5/2009 End: 3/11/2009 Rig Release: 3/11/2009 Rig Number: Phase Description of Operations RUNPRD Lay out running tools. 'POST SAFETY MEETING. Review procedure, hazards and mitigation for RIH with CSH workstring and layout string in singles for DD rig move. POST RIH with 22 stds 1"CSH. Lay out in singles. POST M/U nozzle BHA to frz protect tubing. BHA OAL = 9.5'. POST RIH to 9600' and circ well to KCL water. POH to 2000' and freeze protect tubing to surface with MEOH. POST Set BPV. Well is dead. POST Start fresh water down ,followed by inhibitor then McOH. POST SAFETY MEEING. PJSM for pumping N2. Hazards and crew positions were discussed. POST Circulate inhibitor then McOH down CT. POST Purge reel with 1,800 scfm N2 for 15 min. Allow pressure to bleed off. POST Break off CT riser and stand back injector. Cycle tree valves and grease. Vac fluid out of stack then fill with McOH, shut in master and swab. ;,ic°"~x....- POST SAFETY MEETING. PJSM for installing internal grapple and -~ ~ pulling CT across. Review procedures, hazards and mitigation. POST Cut off CT connector and install internal grapple. Pull test grapple, then pull CT back onto reel and secure it. Unhook grapple, pull cable back to rig floor. POST SAFTY MEETING. PJSM for removing gooseneck and setting injector in stabbing box. POST Remove gooseneck and set injector in stabbing box. POST Remove pipe straightener, secure on rig floor. POST Open.. lower--,BOP doors and inspect, find cement there. Open remaining doors and clean out cement. "` POST Pick BOP, N/Utree cap and press test with 3500 psi. RELEASED RIG AT 0900 HRS, 03/11/2009. TOTAL OF 24 DAYS AND 12 HOURS F OM RIG ACCEPT TOAIG RELEASE. Waiting on weather to lower wind walls and derrick. Wind limit is 20 MPH. Present wind at 20-30 MPH. All further DIMS information will be on well DS 09-33A. Printed: 3/23/2009 11:15:02 AM ,. , 05-27B Post Rig Summary Date Summar~r 03/22/09 Pull 4 1 /1 fi CIW H BPV. 1-2' ext used tagged C 88". No problems. Post CTD 03/23/09 T/I/O = 0+/0/0. Temp=Sl. TBG & IA FL for Slickline. TBG FL C~ 1200', IA near surface. Slickline has control of well. 03/24/09 T/I/0=0/20,/20 Temp= SI Assist Slickline, Load Tbg (Post CTD) Pumped 3 bbls meth spear followed with 22 bbls of 120'F crude to load Tbg for Slickline. FWHP's= 200/20/20. SET 3 1/2" WHIDDON GATHER SUB ON L~TP C~ 10164' SLM, 10166' MD PULLED 1.5" DGLV'S FROM STA #2 C~ 5936' SLM, (5949' MD), STA #1 C~ 3095' SLM (3120') SET 1.5" DOME VLV IN STA #1, SET S/O IN STA #2 PULLED 3 1/2" WHIDDON C-SUB FROM 10164' SLM 03/27/09 ASRC Test Unit #1 complete rig up, well POP. Increase A/L and production choke to initiate stable flow "'job in progress`* .. 03/28/09 ASRC Test Unit #1 flowback well, slightly increase A/L rate to 1.0 mm (approx rate). Achive full open choke, Stabilize and start 12 hour test 03/29/09 ASRC Test Unit #1 complete first 12 hour test, ASRC Test Unit #1 complete second 12 hour test continue flow. 03/30/09 ASRC Test Unit #1, running back to back well tests 03/31/09 ASRC Test Unit #1, running back to back well tests Page 1 of 1 ~~~~I BAKER INTEL Norith America -ALASKA - BP Prudhoe Bay PB DS 05 05-27 -Slot 27 05-276 50-029-21979-02 Survey: MWD Survey Report -Geographic 26 February, 2009 by ~.c~'C~~ w,~r S 1NTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB DS 05 welt. 05-27 Wellbore: 05-276 Design: 05-276 Survey Report -Geographic bP Local Co-ordinate Refer®nce: Well 05-27 -Slot 27 ND Ref®r®nce: Mean Sea Level MD Reference: 52:27 10/5/1989 00:00 @ 67.OOft (generic drillinc North Referent®: True Survey Calculation Mothod: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (F~cact 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 PB DS 05 TR-11-15 - _ -- -- ', Site Position: Northing: 5,947,204.70ft Latitude: 70° 15' 35.696 N From: Map Easting: 697,428.91ft Longitude: 148° 24' 14.424 W Position Uncertainty: O.OOft Slot Radius: 0" Grid Convergence: 1.50 ° ----- -- --- Well 05-27 -Slot 27, 05-27 - - ---- Well Position +N/S 0.00 ft Northing: 5,948,338.62ft Latitude: 70° 15' 46.621 N +E/-W 0.00 ft Easting: 698,296.20 ft Longitude: 148° 23' 48.327 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Welibore 05-276 - - -- Magnetics Model Nam® Sample Date Declination (°) BGGM2007 2/23/2009 22.93 ----- Design -- 05-27B ~ - _ Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (ND) +N/-S (ft) Ift) -34.00 0.00 Survey Program Date 2/26/2009 ~ From To (ft) (ft) Survey (VYelibore) Tool Name 200.00 11,566.20 1 : MWD- Standard (05-27) MWD 11,572.60 12,131.58 MWD (05-276P61) MWD 12,140.00 13,498.00 MWD (05-276) MWD Dip Angle Ffeld Strength (°) (nT) 80.94 57,699 ~ Tie On Depth: 12,131.58 +E/-W Direction (ft) (°) 0.00 141.12 _ ____ - _ Description MWD -Standard MWD -Standard MWD -Standard 226!2009 9:39:45AM Page 2 COMPASS 2003.16 Build 70 ~~~ Survey Report - Geographic bP f,NTEQ Company: North Americ a -ALASKA - BP Local Co-ordinate Ref®rence: Well 05-27 -Slot 27 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 05 MD R®ference: 52:27 1 0/5/1989 00:00 @ 67. OOft (generic drillinc Wetl: 05-27 North Reference: True Wellbore: 05-276 Survey Calculation Method: Minimum Curvature Design: 05-276 Database: EDM .16 - Anc Prod - WH24P -- ___ urvey _ -- - -- - --- -- - -- I Measured TVD Below Map Map Depth Inclination Azimuth System +N/-S +E/-W Northing Easting lft) (°) {°) (ft) (ftl (~) {ft) (ft) Latitude Longttude 12,131.58 90.77 300.05 8,982.03 -4,139.49 3,550.26 5,944,294.29 701,954.05 70° 15' 5.901 N 148° 22' 5.070 W TIP 12,140.00 91.19 301.10 8,981.88 -4,135.21 3,543.02 5,944,298.38 701,946.69 70° 15' 5.943 N 148° 22' 5.280 W KOP 12,170.88 93.94 297.07 8,980.50 -4,120.21 3,516.06 5,944,312.65 701,919.35 70° 15'6.091 N 148° 22' 6.064 W 12,200.18 92.83 291.16 8,978.77 -4,108.27 3,489.38 5,944,323.89 701,892.37 70° 15' 6.208 N 148° 22' 6.840 W 12,230.72 93.72 286.08 8,977.02 -4,098.54 3,460.50 5,944,332.86 701,863.24 70° 15' 6.304 N 148° 22' 7.680 W 12,260.60 94.88 284.91 8,974.78 -4,090.58 3,431.78 5,944,340.06 701,834.33 70° 15' 6.382 N 148° 22' 8.515 W 12,289.16 92.92 289.75 8,972.84 -4,082.09 3,404.59 5,944,347.83 701,806.92 70° 15' 6.466 N 148° 22' 9.306 W 12,330.74 91.38 294.90 8,971.28 -4,066.31 3,366.17 5,944,362.59 701,768.10 70° 15' 6.621 N 148° 22' 10.423 W 12,359.52 91.54 300.26 8,970.55 -4,053.00 3,340.68 5,944,375.22 701,742.27 70° 15' 6.752 N 148° 22' 11.164 W 12,388.46 89.54 305.04 8,970.27 -4,037.39 3,316.32 5,944,390.18 701,717.51 70° 15' 6.906 N 148° 22' 11.872 W 12,413.30 88.34 309.39 8,970.73 -4,022.37 3,296.55 5,944,404.67 701,697.35 70° 15' 7.054 N 148° 22' 12.447 W 12,443.56 88.22 315.13 8,971.64 -4,002.04 3,274.17 5,944,424.41 701,674.45 70° 15' 7.254 N 148° 22' 13.098 W 12,480.62 89.82 311.28 8,972.27 -3,976.68 3,247.17 5,944,449.05 701,646.79 70° 15' 7.503 N 148° 22' 13.883 W 12,507.62 90.55 307.74 8,972.19 -3,959.50 3,226.34 5,944,465.67 701,625.52 70° 15' 7.672 N 148° 22' 14.489 W 12,539.45 90.71 303.80 8,971.84 -3,940.90 3,200.52 5,944,483.58 701,599.22 70° 15' 7.855 N 148° 22' 15.239 W 12,578.05 90.34 298.93 8,971.48 -3,920.82 3,167.57 5,944,502.79 701,565.75 70° 15' 8.053 N 148° 22' 16.197 W 12,606.70 89.66 295.38 8,971.48 -3,907.75 3,142.09 5,944,515.19 701,539.93 70° 15' 8.182 N 148° 22' 16.938 W 12,637.22 88.71 291.31 8,971.92 -3,895.66 3,114.07 5,944,526.54 701,511.61 70° 15' 8.301 N 148° 22' 17.753 W 12,663.71 89.36 287.97 8,972.36 -3,886.75 3,089.13 5,944,534.78 701,486.45 70° 15' 8.388 N 148° 22' 18.478 W 12,690.59 89.54 285.15 8,972.62 -3,879.09 3,063.37 5,944,541.75 701,460.49 70° 15' 8.464 N 148° 22' 19.228 W 12,713.41 88.86 281.67 8,972.94 -3,873.80 3,041.18 5,944,546.46 701,438.17 70° 15' 8.516 N 148° 22' 19.873 W 12,744.31 89.20 278.46 8,973.46 -3,868.41 3,010.76 5,944,551.05 701,407.63 70° 15' 8.569 N 148° 22' 20.758 W 12,776.33 88.80 282.62 8,974.02 -3,862.55 2,979.30 5,944,556.08 701,376.02 70° 15' 8.627 N 148° 22' 21.673 W 12,806.12 89.54 287.88 8,974.46 -3,854.72 2,950.57 5,944,563.15 701,347.09 70° 15' 8.704 N 148° 22' 22.508 W 12,836.17 90.09 293.71 8,974.55 -3,844.05 2,922.49 5,944,573.07 701,318.74 70° 15' 8.809 N 148° 22' 23.325 W 12,866.85 92.24 298.95 8,973.93 -3,830.46 2,895.01 5,944,585.94 701,290.92 70° 15' 8.943 N 148° 22' 24.124 W 12,900.93 90.18 304.57 8,973.21 -3,812.53 2,866.05 5,944,603.10 701,261.50 70° 15' 9.119 N 148° 22' 24.966 W 12,929.61 90.12 309.85 8,973.13 -3,795.19 2,843.22 5,944,619.83 701,238.22 70° 15' 9.290 N 148° 22' 25.630 W 12,958.17 87.60 314.52 8,973.70 -3,776.02 2,822.07 5,944,638.43 701,216.57 70° 15' 9.479 N 148° 22' 26.245 W 12,989.37 87.54 318.23 8,975.02 -3,753.46 2,800.56 5,944,660.42 701,194.48 70° 15' 9.700 N 148° 22' 26.870 W 13,015.49 90.09 325.45 8,975.57 -3,732.94 2,784.44 5,944,680.50 701,177.83 70° 15' 9.902 N 148° 22' 27.339 W 13,044.01 91.11 328.93 8,975.27 -3,708.98 2,768.99 5,944,704.05 701,161.75 70° 15' 10.138 N 148° 22' 27.788 W 13,078.15 90.59 331.56 8,974.76 -3,679.35 2,752.05 5,944,733.22 701,144.04 70° 15' 10.430 N 148° 22' 28.280 W 13,104.83 90.15 334.94 8,974.59 -3,655.53 2,740.04 5,944,756.72 701,131.41 70° 15' 10.664 N 148° 22' 28.629 W 13,133.91 95.63 339.32 8,973.12 -3,628.78 2,728.76 5,944,783.15 701,119.43 70° 15' 10.927 N 148° 22' 28.957 W 13,163.13 91.21 341.81 8,971.38 -3,601.29 2,719.06 5,944,810.38 701,109.01 70° 15' 11.197 N 148° 22' 29.239 W 13,194.99 93.00 346.68 8,970.21 -3,570.65 2,710.42 5,944,840.78 701,099.56 70° 15' 11.499 N 148° 22' 29.490 W 13,224.71 94.58 351.65 8,968.24 -3,541.54 2,704.84 5,944,869.73 701,093.22 70° 15' 11.785 N 148° 22' 29.652 W 13,264.77 90.49 356.14 8,966.47 -3,501.76 2,700.59 5,944,909.38 701,087.92 70° 15' 12.176 N 148° 22' 29.775 W 13,296.31 89.45 352.72 8,966.49 -3,470.38 2,697.53 5,944,940.67 701,084.04 70° 15' 12.485 N 148° 22' 29.864 W 13,326.87 90.25 349.22 8,966.57 -3,440.20 2,692.74 5,944,970.71 701,078.45 70° 15' 12.782 N 148° 22' 30.003 W 13,361.09 87.14 345.69 8,967.35 -3,406.82 2,685.31 5,945,003.89 701,070.14 70° 15' 13.110 N 148° 22' 30.219 W 13,401.13 81.60 344.17 8,971.27 -3,368.35 2,674.95 5,945,042.06 701,058.78 70° 15' 13.488 N 148° 22' 30.520 W 13,432.43 80.65 343.04 8,976.10 -3,338.69 2,666.23 5,945,071.49 701,049.28 70° 15' 13.780 N 148° 22' 30.773 W 13,454.91 79.18 338.72 8,980.04 -3,317.78 2,658.98 5,945,092.19 701,041.48 70° 15' 13.986 N 148° 22' 30.984 W 13,498.00 79.18 338.72 8,988.13 -3,278.34 2,643.62 5,945,131.21 701,025.09 70° 15' 14.374 N 148° 22' 31.430 W TD - 3 3/8" 22f~2009 9:39:45AM Page 3 COMPASS 2003.16 Build 70 • • ~~~ E~°+uaitles Survey Report -Geographic bP 1NTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 05-27 -Slot 27 Project; Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 05 MD Reference: 52:27 10/5/1989 00:00 @ 67.OOft (generic drillinc We1L• 05-27 North Reference: True Wetlbore: 05-276 Survey Calculation Method: Minimum Curvature Design: 05-276 Database: EDM .16 - Anc Prod - WH24P r Casing Points Measured Vertical Depth Depth (ft) lft) Name 13,498.00 8,988.13 2 3/8" Survey Annotations Measured Vertical Local Coordinates Depth Depth +N/~ +E/_yy (ft) (ft) (ft) (ft} Commerrt 12,131.58 8,982.03 -4,139.49 3,550.26 TIP 12,140.00 8,981.88 -4,135.21 3,543.02 KOP 13,498.00 8,988.13 -3,278.34 2,643.62 TD Checked By: Approved By: Date: Casing Hole Diameter Diameter (~~) (~~) 2-3/8 3 - _- -- ?126/2009 9:39:45AM Page 4 COMPASS 2003.16 Build 70 ` • • ^~~r BAKER EI~I~I~S INTEQ North America -ALASKA - BP Prudhoe Bay PB DS 05 05-27 -Slot 27 05-27B P B 1 50-029-21979-70 Design: 05-27BPB1 Survey Report -Geographic 25 February, 2009 by C~ ~.. ~s INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB DS 05 Well: 05-27 Wellbore: 05-276P61 Design: 05-276PB1 ~~ BP Exploration (Alaska) Inc. Survey Report -Geographic by Local Co-ordinate Reference: Well 05-27 -Slot 27 TVD Reference: Mean Sea Level MD Reference: 52:27 10/5/1989 00:00 @ 67.OOft (generic drillinc North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P roject Prudhoe Bay, North Slope, UNITED STATES lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor ___ - - SRe PB DS 05, TR-11-15 Site Position: From: Map Position Uncertainty: 0.00 ft Well 05-27 -Slot 27, 05-27 Well Position +N/-S 0.00 ft +E/-W 0.00 ft Position Uncertainty 0.00 ft Wellbore 05-276P61 Magnetics Model Nam® ~ BGGM2007 Northing: 5,947,204.70ft Latitude: 70° 15' 35.696 N Fasting: 697,428.91ft Longitude: 148° 24' 14.424 W Slot Radius: 0" Grid Convergence: 1.50 ° --- I Northing: 5,948,338.62 ft Latitude: 70° 15' 46.621 N Fasting: 698,296.20 ft Longitude: 148° 23'48.327 W Wellhead Elevation: ft Ground Level: O.OOft Sample Date Declination (°) 2/20/2009 22.93 Design 05-276P61 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/-S i (ft) (ft) -34.00 0.00 Survey Program Date 2/23/2009 From To {ft) (ft) Survey (Wellbore) Tool Name 200.00 11,566.20 1 : MWD -Standard (05-27) MWD 11,572.60 13,132.49 MWD(05-27BPB1) MWD Dip Angle Fie{d Strength {°) (nT) 80.94 57,699 Tie On Depth: 11,566.20 +E/-W Direction (ft) {°) 0.00 142.86 J Description MWD -Standard MWD -Standard 2/15/2009 11:24:27AM Page 2 COMPASS 2003.16 Build 70 • ~R ~ BP Exploration (Alaska) Inc. Iles Survey Report -Geographic bP ' 1NTEQ Company: North America -ALA SKA - BP Local Co-ordinate Referent®: Well 05-27 -Slot 27 Pro)ect: Prudhoe Bay ND Refer®nce: Mean Sea Level Site: PB DS 05 MD Reference: 52:27 10/5/1989 00:00 67.OOft @ (generic drillin< WeIL• 05-27 North Reference: True Wellbon3: 05-276P61 Survey Calculation Method: Minimum Curvature Design: 05-276PB1 --- Database: -- -- EDM .16 - Anc Prod - WH24P 'Survey ---- Measur®d TVD Below Map Map Depth Inclination Azimuth System +NIS +E!-W Northing E asting ~ (~) (°) (°) (ft) (fq (ft) (ft) (ft) Latitude Longitude 11,566.20 90.07 135.56 TIP 11,572.60 90.02 135.50 KOP 11,598.19 83.85 144.00 11,631.77 84.04 155.50 11,663.18 87.45 166.50 11,693.22 86.34 177.08 11,729.60 86.28 192.80 11,760.84 89.14 205.08 11,788.38 91.20 213.95 11,817.58 88.10 222.04 11,848.88 95.75 232.78 11,878.46 94.94 244.68 11,918.04 90.92 259.42 11,950.50 87.45 273.97 11,980.38 91.44 278.72 12,011.72 94.18 284.08 12,041.24 92.58 288.61 12,072.20 90.58 292.45 12,102.18 89.36 296.93 12,131.58 90.77 300.05 12,161.30 92.24 303.74 12,193.68 90.58 307.93 12,222.86 90.43 311.08 12,253.12 92.06 315.62 12,284.84 89.23 311.65 12,314.82 88.89 309.63 12,346.48 88.65 307.59 12,376.66 86.43 303.66 12,410.04 88.22 301.38 12,442.24 89.79 295.98 12,473.20 89.91 293.10 12,504.07 91.38 292.43 12,534.10 91.53 289.80 12,564.57 90.67 287.16 12,594.42 92.58 290.24 12,625.56 91.44 295.17 12,655.97 90.03 298.64 12,685.42 89.51 301.93 12,717.07 90.71 304.81 12,753.76 89.75 310.02 12,781.25 88.03 313.72 12,819.71 88.03 315.54 12,850.27 88.31 322.95 12,878.99 89.20 319.56 12,910.53 93.81 317.89 12,944.57 89.29 315.08 12,975.73 84.44 310.03 13,007.27 85.67 306.82 13,039.75 88.71 305.00 13,071.17 93.00 304.66 13,102.31 91.87 302.04 13,132.49 95.05 297.79 8,978.68 -3,919.76 3,831.36 5,944,521.33 702,229.24 70° 15' 8.060 N 148° 21' 56.891 W 8,978.68 -3,924.33 3,835.84 8,980.05 -3,943.80 3,$52.33 8,983.60 -3,972.60 3,869.13 8,985.94 -4,002.17 3,879.30 8,987.57 -4,031.81 3,883.58 8,989.93 -4,067.87 3,880.46 8,991.18 -4,097.33 3,870.35 8,991.10 -4,121.27 3,856.79 8,991.28 -4,144.26 3,838.84 8,990.22 -4,165.39 3,815.86 8,987.46 -4,180.65 3,790.73 8,985.42 -4,192.79 3,753.24 8,985.89 -4,194.66 3,720.93 8,986.18 -4,191.35 3,691.25 8,984.64 -4,185.17 3,660.58 8,982.90 -4,176.88 3,632.31 8,982.05 -4,166.03 3,603.33 8,982.06 -4,153.51 3,576.10 8,982.03 -4,139.49 3,550.26 8,981.25 -4,123.79 3,525.04 8,980.45 -4,104.85 3,498.81 8,980.19 -4,086.29 3,476.30 8,979.53 -4,065.53 3,454.31 8,979.18 -4,043.65 3,431.36 8,979.67 -4,024.12 3,408.61 8,980.35 -4,004.37 3,383.88 8,981.64 -3,986.81 3,359.38 8,983.20 -3,968.89 3,331.26 8,983.76 -3,953.45 3,303.03 8,983.84 -3,940.59 3,274.87 8,983.50 -3,928.64 3,246.41 8,982.73 -3,917.83 3,218.40 8,982.15 -3,908.18 3,189.51 8,981.30 -3,898.61 3,161.26 8,980.21 -3,886.60 3,132.56 8,979.82 -3,872.84 3,105.44 8,979.94 -3,858.00 3,080.02 8,979.88 -3,840.59 3,053.59 8,979.73 -3,818.30 3,024.46 8,980.26 -3,799.96 3,004.00 8,981.58 -3,772.96 2,976.64 8,982.56 -3,749.84 2,956.72 8,983.18 -3,727.45 2,938.75 8,982.36 -3,703.76 2,917.96 8,981.44 -3,679.09 2,894.54 8,983.14 -3,658.06 2,871.63 8,985.86 -3,638.54 2,847.02 8,987.45 -3,619.51 2,820.75 8,986.98 -3,601.57 2,794.97 8,985.66 -3,584.47 2,768.98 8,983.84 -3.569.45 2.742.88 5,944,516.88 702,233.84 5,944,497.85 702,250.84 5,944,469.51 702,268.39 5,944,440.22 702,279.34 5,944,410.70 702,284.39 5,944,374.57 702,282.23 5,944,344.85 702,272.89 5,944,320.57 702,259.98 5,944,297.11 702,242.63 5,944,275.39 702,220.22 5,944,259.48 702,195.51 5,944,246.36 702,158.34 5,944,243.64 702,126.10 5,944,246.16 702,096.34 5,944,251.53 702,065.52 5,944,259.07 702,037.04 5,944,269.16 702,007.79 5,944,280.95 701,980.24 5,944,294.29 701,954.05 5,944, 309.31 701, 928.43 5,944,327.56 701,901.70 5,944,345.52 701,878.71 5,944,365.69 701,856.18 5,944,386.96 701,832.66 5,944,405.88 701,809.41 5,944,424.97 701,784.17 5,944,441.87 701,759.22 5,944,459.05 701,730.64 5,944,473.74 701,702.01 5,944,485.86 701,673.53 5,944,497.05 701,644.76 5,944,507.12 701,616.48 5,944,516.01 701,587.35 5,944,524.82 701,558.85 5,944,536.07 701,529.85 5,944,549.11 701,502.39 5,944,563.28 701,476.58 5,944,579.99 701,449.70 5,944,601.50 701,420.00 5,944,619.29 701,399.06 5,944,645.56 701,371.01 5,944,668.15 701,350.48 5,944,690.06 701,331.93 5,944,713.19 701,310.52 5,944,737.23 701,286.46 5,944,757.65 701,263.01 5,944,776.52 701,237.89 5,944,794.84 701,211.13 5,944,812.09 701,184.89 5,944,828.51 701,158.46 5,944,842.83 701,131.97 70° 15' 8.016 N 148° 21' 56.761 W 70° 15' 7.824 N 148° 21' 56.281 W 70° 15' 7.541 N 148° 21' 55.793 W 70° 15' 7.250 N 148° 21' 55.498 W 70° 15' 6.958 N 148° 21' 55.374 W 70° 15' 6.604 N 148° 21' 55.465 W 70° 15' 6.314 N 148° 21' 55.760 W 70° 15' 6.078 N 148° 21' 56.154 W 70° 15' 5.852 N 148° 21' 56.677 W 70° 15' 5.645 N 148° 21' 57.345 W 70° 15' 5.495 N 148° 21' 58.076 W 70° 15' 5.376 N 148° 21' 59.167 W 70° 15' 5.357 N 148° 22' 0.107 W 70° 15' 5.390 N 148° 22' 0.970 W 70° 15' 5.451 N 148° 22' 1.862 W 70° 15' 5.533 N 148° 22' 2.684 W 70° 15' 5.640 N 148° 22' 3.527 W 70° 15' 5.763 N 148° 22' 4.318 W 70° 15' 5.901 N 148° 22' 5.070 W 70° 15' 6.055 N 148° 22' 5.803 W 70° 15' 6.242 N 148° 22' 6.566 W 70° 15' 6.424 N 148° 22' 7.220 W 70° 15' 6.629 N 148° 22' 7.860 W 70° 15' 6.844 N 148° 22' 8.527 W 70° 15' 7.036 N 148° 22' 9.188 W 70° 15' 7.230 N 148° 22' 9.907 W 70° 15' 7.403 N 148° 22' 10.620 W 70° 15' 7.580 N 148° 22' 11.437 W 70° 15' 7.732 N 148° 22' 12.258 W 70° 15' 7.858 N 148° 22' 13.077 W 70° 15' 7.976 N 148° 22' 13.905 W 70° 15' 8.082 N 148° 22' 14.719 W', 70° 15' 8.177 N 148° 22' 15.559 W 70° 15' 8.272 N 148° 22' 16.381 W 70° 15' 8.390 N 148° 22' 17.215 W 70° 15' 8.525 N 148° 22' 18.004 W 70° 15' 8.671 N 148° 22' 18.743 W 70° 15' 8.843 N 148° 22' 19.512 W 70° 15' 9.062 N 148° 22' 20.359 W 70° 15' 9.242 N 148° 22' 20.954 W 70° 15' 9.508 N 148° 22' 21.749 W 70° 15' 9.736 N 148° 22' 22.328 W 70° 15' 9.956 N 148° 22' 22.851 W 70° 15' 10.189 N 148° 22' 23.455 W 70° 15' 10.432 N 148° 22' 24.136 W 70° 15' 10.638 N 148° 22' 24.802 W 70° 15' 10.831 N 148° 22' 25.518 W 70° 15' 11.018 N 148° 22' 26.282 W 70° 15' 11.194 N 148° 22' 27.031 W 70° 15' 11.363 N 148° 22' 27.787 W 70° 15' 11.510 N 148° 22' 28.546 W ?l25/2009 11:24:27AM Page 3 COMPASS 2003.16 Build 70 ~i~~ ~s 1NTEQ BP Exploration (Alaska) Inc. Survey Report -Geographic bP Company: North America -ALASKA - BP Local Co-ordinate Ref®rence: Well 05-27 -Slot 27 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 05 MD Reference: 52:27 10/5/1989 00:00 @ 67.OOft (generic drillinc Well: 05-27 North Reference: True Wellbore: 05-276P61 Survey Calculation Method: Minimum Curvature Design: 05-276PB1 Database: EDM .16 - Anc Prod - WH24P urvey -- ----- --- _- ____-- - ---_ _ ,---~ Measured TVD Below Map Map Depth Inclination Azimuth System +N/S +E/-W Northing Easting {ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 13,206.00 95.05 297.79 8,977.37 -3,535.31 2,678.10 5,944,875.25 701,066.32 70° 15' 11.846 N 148° 22' 30.430 W TD -Projected TD ~ Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/_W Northing Easting -Shape (°) (°) (ft) (ft) lft) (ft) {ft) 05-276 New Target 1 0.00 0.00 8,990.00 -4,215.99 3,595.22 5,944,219.00 702,001.00 - actual wellpath misses target center by 50.02ft at 1 2062.06ft Mb (8982.21 TVD, -4169.80 N, 3612.75 E) - Point 05-276 Target 2 0.00 0.00 8,970.00 -3,348.21 2,477.62 5,945,057.00 700,861.00 - actual wellpath misses target center by 274.32ft at 13206.OOft MD (8977.37 TVD, -3535.31 N , 2678.10 E) - Point 05-276 Fault 1 0.00 0.00 0.00 -4,354.65 3,200.41 5,944,070.00 701,610.00 - actual wellpath misses target center by 8987.53ft at 12284.84ft MD (8979.1 8 TVD, -4043.65 N, 3431.36 E) - Polygon Point 1 0.00 -4,354.65 3,200.41 5,944,070.00 701,610.00 Point 2 0.00 -4,760.20 3,594.89 5,943,675.00 702,015.00 05-278 Fault 3 0.00 0.00 0.00 -3,611.42 2,329.63 5,944,790.00 700,720.00 - actual wellpath misses target center by 8984.45ft at 13206.OOft MD (8977.37 TVD, -3535.31 N, 2678.10 E) - Polygon Point 1 0.00 -3,611.42 2,329.63 5,944,790.00 700,720.00 Point 2 0.00 -3,385.83 2,310.56 5,945,015.00 700,695.00 Point 3 0.00 -2,893.86 2,243.49 5,945,505.00 700,615.00 Point 4 0.00 -3,385.83 2,310.56 5,945,015.00 700,695.00 05-278 Polygon 0.00 0.00 0.00 -4,126.98 4,241.82 5,944,325.00 702,645.00 - actual wellpath misses target center by 8990.14ft at 11572.60ft MD (8978.68 TVD, -3924.33 N, 3835.84 E) - Polygon Point 1 0.00 -4,126.98 4,241.82 5,944,325.00 702,645.00 Point 2 0.00 -4,517.38 3,681.32 5,943,920.00 702,095.00 Point 3 0.00 -3,575.12 2,470.64 5,944,830.00 700,860.00 Point 4 0.00 -3,113.54 2,417.78 5,945,290.00 700,795.00 Point 5 0.00 -3,598.16 3,155.31 5,944,825.00 701,545.00 Latitude Longitude 70° 15' 5.148 N 148° 22' 3.763 W 70° 15' 13.687 N 148° 22' 36.259 W 70° 15' 3.786 N 148° 22' 15.248 W 70° 15' 11.099 N 148° 22' 40.566 W 70° 15' 6.020 N 148° 21' 44.956 W II Design Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 11,566.20 8,978.68 -3,919.76 3,831.36 TIP 11,572.60 8,978.68 -3,924.33 3,835.84 KOP 13,206.00 8,977.37 -3,535.31 2,678.10 TD 13,206.00 8,977.37 -3,535.31 2,678.10 Projected TD Checked By: Approved By: Date: • 2/25/2009 11:24:27AM Page 4 COMPASS 2003.16 Build 70 03/25/09 N0.515Q. Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 40o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WPII .Inh S 1 nn flnc .n*inn n~~e n~ n..~-.. rn MPC-03 AXBD-00015 MEM PRODUCTION PROFILE 03/13/09 1 1 05-276 BOOR-00002 MEM CBL 03/08/09 1 1 L2-24 AWL9-00025 PRODUCTION PROFILE 03/22/09 1 1 Y-05B AWJB-00011 MCNL j 11/09/08 1 1 D-12 12113022 RST U - ( 12/04/08 1 1 LGI-04 12103707 RST /'~ 12/25/08 1 1 r~o~aac raa.nwvw~cvuc rsc~,clr 1 ar .7llarvlrvla ArvU tiC 1 UF{rvlrvl7i Vrvt GVYr rAGrl 1 V: BP Exploration (Alaska) Inc. ~-y ~ ~ _3 fly r -~ rY',* Petrotechnical Data Center LR2-1 `' ~~ '~ ° ~ )~ 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~'~ 4~ °,j ;~~.I(r1 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: t~!'~~ ~. ~~Q~~ o [~ Gi 1~~~,~~~iU1 i ,.a..~,~~.~, C~„5L"j RQO C l~~c~o~T 333 W 7th AVENUE, SUITE 100 ii ii a~`~~....aaalll~~.iiiili -7 1` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 JOhri McMullen FAx (so7) 27sa5az Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-27B BP Exploration Alaska Inc. Permit No: 208-191 Surface Location: 2144' FSL, 1207' FWL, SEC. 32, T11N, R15E, UM Bottomhole Location: 1214' FNL, 3694' FWL, SEC. 05, T10N, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05. and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) .659-3607 (pager). Sincerely, Cathy . Foerster Commissioner DATED this ,~ day of December, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA 0+ ~~ ALAS~JIL AND GAS CONSERVATION COMMON s '. -,,,, { PERMIT TO DRILL ~~-~ ~`' 20 AAC 25.005 ~Q~- /,~•/d 08 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 05-27B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13540' TVD 8984'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2144' FSL 1207' FWL SEC 32 T11N R15E UM 7. Property Designation: ADL 028326 & 028329 Pool , , . , , , Top of Productive Horizon: 407' FNL, 3721' FWL, SEC. 05, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: May 1, 2009 Total Depth: 1214' FNL, 3694' FWL, SEC. 05, T10N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 3,250' 4b. Location of Well (State Base Plane Coordinates): Surface: x-698296 y-5948338 Zone-ASP4 10. KB Elevation (Height above GL): 67' feet 15. Distance to Nearest well within Pool: 605' 16. Deviated Wells: Kickoff Depth: 11600 feet Maximum Hole An le: 93 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3188 Surface: 2308 18. in Pr r m: ifi i n To - ettin h - B m uan i f ment c.f. r k Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data -/" 4.7# 13 r8 T 4' 104 27's 1 4' 4' 1 x I ' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 13600' Total Depth TVD (ft): Plugs (measured): None Effective Depth MD (ft): 13600' Effective Depth TVD (ft): 9045' Junk (measured): None .:Casing Length Size Cement Volume MD TVD Conductor /Structural 1 ' Surface 37 1 - / " x C III I 70 ' 3 15' Intermediate / " 37 sx Cla 'G' 501' Pr Liner 1 3' 7" x las 1 1' - 111 8280' - 9060' Lin r 1 2' 4-1/2" m m ~ ed Slo i t 0477' - 1 4 8 19' - 9 30' Perforation Depth MD (ft): Slotted: 10899' -13599' Perforation Depth TVD (ft): 9038' - 9045' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that th foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name Jo It n Title Engineering Team Leader Prepared By Name/Number Si nature Phone 564-4711 Date /L ~ Terrie Hubble, 564-4628 ~ Commssi .Use Onl Permit T rill N m r ai?Op/ / API Number: °~ ~ 50 21979-02-00 Permit Approval See cover letter for I • l7g o h r i m n Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~~ ®~iti 'C"~~"~•~~S'~'"' Samples Req'd: ^ es ~No Mud Log Req'd: ,^/Yes ~No ~$®O ~~; ~,~~~ Vic- ~1~--. HZS Measures: ~7 Yes ^ No Directional Survey Req'd: LyJ Yes ^ No Other. t•J APPROVED BY THE COMMISSION Date z .~~p . ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate • • by To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin, CTD Engineer Date: December 3, 2008 Re: Prudhoe Bay OS-27B Permit to Drill Request The sidetrack, OS-27B, is scheduled to be drilled by a CTD rig around May 1, 2009. The plan calls for a slimhole lateral with asolid/cemented liner. Pre-Rig Work: (scheduled to begin February 1, 2009) 1. S Caliper tubing as deep as possible (60 deg at 9800'). 2. S Dummy GLV's 3. O MIT-IA 4. C Dummy whipstock drift (2.7" x 15') to 11650'. Circulate well to KCl at maximum rate. Report any losses in AWGRS. 5. C Set 2-3/8" CIBP in solid liner ~ 12400' 3 ®~_ 6. O AC-LDS; AC-PPPOT- T ~~ 7. O PT MV, SV, WV 8. O Bleed gas lift and production flowlines down to zero and blind flange 9. O Remove wellhouse, level pad Rig Work: (scheduled to begin on May 1, 2009) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Mi112.8" window at 11600' and 10' of rathole. Swap th 3. Drill Build: 3" OH, 400' (40 deg/100 planned) 4. Drill Lateral: 3" OH, 1540' (12 deg/100 planned) 5. Run 2-3/8" solid chrome liner leaving TOL at 10400' 6. Pump primary cement leaving TOC at 11400', 40 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL/GR/CCL log 8. Test liner lap to 2000 psi. `_ 9. Perforate liner per asset instructions (~ 1000') ~ t"\ \ 5 10. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. ~~~ ~ Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2 3/8", 4.7# ,Chrome, STL connection Solid liner - 10400' to 13540' • A minimum of 40 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 10400 ft (TOL). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 92 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 3250 ft to the East • Distance to nearest well within pool - 605 ft to OS-03C Anticollision Summary • OS-03: 344' ctr-ctr, Status: P&A'd • 11-03: 1133' ctr-ctr, Status: P&A'd Logging • MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • The maximum recorded H2S level on DS OS is 27 ppm on OS-OSB (11/01/90) • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 3,188 psi at 8,800'ss (7.0 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2308 psi. Sean McLaughlin CTD Drilling Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE= " 4-1/16"CNV WELLHEAD = CNV ACTUATOR = AXELSON 20 CONDUCTOR 110' KB. ELEV = 67' 91.5#, H-40, BF. ELEV = KOP = 2561' ~ - 19.124" Max Angle = 95° @ 12511' 13-3/8" CSG, 105' Datum MD = 10321' 72#, K-55 BTC, Datum ND = 8800' SS ID = 12.347" 4-1/2" TBG, 12.6#, L-80 BTGM, 3020' .0152 bpf, ID = 3.958" 13-3/8" CSG, 72#, L-80 BTC, ~ = 12.347" 3700' Minimum ID =1.995" @ 12327' 3-1/2" G SUB 9-5/8" X 7" BKR HYFLO LNR HGR, ID = ? 9191' ~ 9-5/8" CSG, 47#, L-80 BTGM, ID = 8.681" ~ ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3120 3096 21 MGFMHO DMY RK 16 09113/08 2 5949 5592 29 MGFMHO DMY RK 20 09/13/08 3 7250 6734 28 MGFMHO DMY RK 0 01/01/00 4 7823 7238 31 MGFMHO DMY RK 0 10/30/96 5 8147 7501 40 MGFMHO DMY RK 0 01/01/00 6 8530 7789 43 MGFMHO DMY RK 0 01/01100 7 8915 8076 40 MGFMHO DMY RK 0 05/28!08 C~1EMK:AL MANUKtLS ST MD ND DEV NPE VLV LATCH PORT DATE 8 9147 8250 44 KBUG-LT DOME BK-2 16 11/13/89 9632' 3-1/2" OTIS X NIP, ID = 2.813" 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 10485' 10467' 4-1/2" TNV POLISHED RISER 10477' 7" TIW SS PKR ID = ? 10479' TNV MILLOUT EXTENSION w / XO / SO, ID = ? 4-1/2" LNR, 13.5#, L-80 FL4S, 10651' 10496' 7" X 3-1/2" TMI OVERSHOT SEAL .0149 bpf, m = 3.92" ASSY W/1" EXT (10.75') 4-1/2" LNR, 11.6#, L-80 FL4S, .0155 bpf., ID = 4.0" 10899' 10920' 7" ECP (34') ~ ~ ' ~ 7" LNR 29#, L-80 BTC, .0371 bpf, ID = 6.184" 11154' , ' ~ ~ TOP OF 2-3/8" LNR-CT 12327' 1 ~ ~ ~ 4-1/2" SLTD LNR 11.6#, L-80 FL4S, 12364' ' .0155 bpf, ID = 4.00" I I ~ ~ 4-1/2" LNR, 11.G#, L-99 FL4S, .9155 kpf, It = 4.9" i-j 12409' PERFORATION SUMMARY REF LOG: MWD/EWR/CNO ON 10/31/89 ANGLE AT TOP PERF: 86° @ 12903' Note: Refer to Production DB for historical pert data SIZE SPF WTERVAL Opn/Sgz DATE 4-1/2" SLTD 10899 - 12364 S 11/05/89 2-3/8" SLTD 12903 - 13599 O 11/20/96 12327' I-I3-1/2" G SUB, ID = 1.995" ? H ESTIMATED TOP OF CEMENT i MILLOUT WINDOW OS-27A ' ( ) 2-3/8" LNR, 4.6#, L-80 FL4S, 12903' \ .0039 bpf, ID = 1.995" 2-3/8" DRILLED LNR, 4.6#, L-80 FL4S, 13599' .0038 bpf, ID = 1.995" 2-3/8" LNR CT, 4.6#, L-80 FL4S, .0039 bpf, ID = 1.995" 13600' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/16/84 PKR 176 ORIGINAL COMPLETION 06/02!08 ?/ PJC DRAWING CORRECTIONS 10/30/89 AUDI 4 RWO 09/10/08 KDGSV GLV GO (05128/08) 11/20/96 NOR 1 CTD SIDETRACK (05-27A 09/21/08 CJWSV GLV GO (09/13/08) 08/18/03 CMO/TLP PERF ANGLE CORRECTION 05/30/06 DTM WELLHEAD CORRECTION 05/29/08 PJG KDC GLV GO (05/19/08) PRUDHOE BAY UNfT WELL: 05-27A PERMfT No: 1961030 API No: 50-029-21979-01 SEC 32, T11 N, R15E, 2144' FSL & 1207' FWL BP Exploration (Alaska) 0 ~ -~ s~~ S NOTES: OIL BASED MUD - 70° @ 10337' ~4-1/2" AVA TRSV SSSV NIP, ID = 3.813" ~ 3020'J--i4-1/2" X 3-1/2" XO GAS LIFT MANDRELS TREE= "4-1/16" CIW WEILHF.AD = CNV ACTUATOR = AXEISON KB. E1EV = -_ --_.r _._..- _ _...~- B_F. E1E_V___=_ KOP = ~^ 67' -•__._.._...-._. 2561' Max Angle =95° @ 12511' Datum MD = Datum TV D = 10321' 8800' SS • 20 CONDUCTOR, 110' 91.5#, H-40, ID = 19.124" 13-3/8" CSG, 105' 72#, K-55 BTC, ID = 12.347" 4-1/2" TBG, 12.6#, L-80 BTG~ 3020' .0152 bpf, ID = 3.958" 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 3700' Minimum ID =1.995" @ 12327' 3-1 /2" G SUB 9-5/8" X 7" BKR HYFLO LNR HGR, ID~ 9191' ~ 9-5/8" CSG, 47#, L-80 BTGM, ID = 8.681" ~ 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" O 5 ~2 7 B S~Y NOTES: OIL BASED MUD - 70° @ 10337' Proposed CTD Sidetrack 4-1/2" AVA TRSV SSSV NIP, ID = 3.813" GAS LIFT MANDRELS 4-1/2" LNR, 13.5#, L-80 FL4S, 10651' .0149 bpf, ID = 3.92" 4-1/2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" 10899' 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 11154' PERFORATION SUMMARY REF LOG: MWD/EWR/CNO ON 10/31/89 ANGLE AT TOP PERF: 86" @ 12903' Note: Refer to Production DB for Historical perf data SIZE SPF INTERVAL Upn/Sqz DATE 4-1/2" SLTD 10899 - 12364 S 11/05/89 2-3/8" SLTD 12903 - 13599 O 11 /20/96 TOP OF 2-3/8" LNR-CT 12327' 4-1/2" SLTD LNR, 11.6#, L-80 FL4S, 12364' .0155 bpf, ID = 4.00" ~ 4-1/2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" H 12409' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3120 3096 21 MGFMHO DMY RK 16 09/13/08 2 5949 5592 29 MGFMHO DMY RK 20 09/13/08 3 7250 6734 28 MGFMHO DMY RK 0 01/01/00 4 7823 7238 31 MGFMHO DMY RK 0 10/30/96 5 8147 7501 40 MGFMHO DMY RK 0 01/01/00 6 8530 7789 43 MGFMHO DMY RK 0 01/01/00 7 8915 8076 40 MGFMHO DMY RK 0 05/28/08 CHEMICAL MANDRELS 9632' ~ 3-1 /2" OTIS X NIP, ID = 2.813" 10400' 3-1/2" KB Liner Top Packer 10467' 4-1/2" TNV POLISHED RISER 10477' 7" TNV SS PKR, ID = ? 10479' TNV MILLOUT E~CTE7VSION w / XO / SO, ID = ? 10496' 7" X 3-1/2" TIW OVERSHOT SEAL ASSY W/1" EXT(10.75') 17" ECP (34') 11600' Mill Window off Mechanical Whipstock 90° inc ., 30R trayface .. -,..,_ B .uw. _A_, _.. _. ' 2-3/8" 13Cr80 Liner, Cemented & Perf'd 13540' \ 12400' 2-3/8" CIPB ESTIMATED TOP OF CEMENT 2-3/8" LNR-CT, 4.6#, L-80 FL4S, .0039 bpf, ID = 1.995" 13600' ` ` ` ~A DATE REV BY COMMENTS DATE REV BY COMMENTS 08/16/84 PKR 176 ORIGINAL COM PLE•TION 06/02/08 ?/ PJC DRAWING CORRECTIONS 10130/89 AUDI 4 RWO 09/10/08 KDGSV GLV GO (05/28/08) 11/20/96 NOR 1 CTD SIDETRACK (05-27A) 09/21/08 CJNISV GLV GO (09/13/08) 08/18/03 CMO/TLP PFRF ANGLE CORRE=CTION 11/05/08 MSE PROPOSED CTD SIDETRACK 05/30/06 DTM WELLHEAD CORRECTION 05/29/08 PJC/ KDC GLV GO (05/19/08) PRUDHOE BAY UNIT WELL: 05-27B PFJZMfT No: API No: 50-029-21979-02' SEC 32, T11 N, R15E, 2144' FSL & 1207' FWL BP Exploration (Alaska) BP Alaska by Baker Hughes INTEQ Planning Report INTEQ Company: BP AmoCO Date: 12/2/2008 Time: 16:30:53 Page: t Field: Prudhoe Bay Co-ordinate(NE)Reference: Well: OS-27, True North Site: PB DS 05 Vertical (TVD) Reference: 52 :27 10/5/1989 00:00 67.0 WeII: 05-27 Section(VS)Reference: Well (O.OON,O.OOE,325.OOAzi) Wellpath: Plan 4, 05-276 .. - Survey Calculation Method: Minimum Curvature _ _ - . - - Db: Sybase _ J ~ Field: Prudhoe Ba e - i ~ North Slop I I UNITED STATES , ', Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Sri PB DS OS ~, TR-11-i5 ~ UNITED STATES :North Sl ope Site Position: Northing: 5947204.70 ft Latitude: 70 15 35.696 N From: Map Fasting: 697428.91 ft Longitude: 148 24 14.424 W ~ Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg I Well: 05-27 Slot Name: 27 05-27 ' Well Position: +N/-S 1110.85 ft Northing: 5948338. 62 ft Latitude: 70 15 46.621 N I +E/-W 896.77 ft Fasting : 698296. 20 ft Longitude: 148 23 48.327 W I Position Uncertainty: 0.00 ft _ ~ --- Wellpath: Plan 4, 05-27B Drilled From: 05-27 500292197902 Tie-on Depth: 11 566.20 ft Current Datum: 52:27 10/5/1989 00:00 Height 67. 00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/12/2008 Declination: 23.08 deg Field Strength: 57693 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 325 00 33.00 0.00 . 0.00 Plan: Plan #4 Date Composed: 11 /12/2008 change WS TF Version: 9 Principal: Yes Tied-to: From: Definitive Path Targets "'Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S- +Ef-W 'Northiug Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft _ _ - OS-276 Polygon 67.00 -4126.99 4241.82 5944325.00 702645.00 70 15 6.020 N 148 21 44.956 W it -Polygon 1 67.00 -4126.99 4241.82 5944325.00 702645.00 70 15 6.020 N 148 21 44.956 W -Polygon 2 67.00 -4517.38 3681.32 5943920.00 702095.00 70 15 2.184 N 148 22 1.263 W -Polygon 3 67.00 -3575.12 2470.65 5944830.00 700860.00 70 15 11.456 N 148 22 36.464 W -Polygon 4 67.00 -3113.54 2417.78 5945290.00 700795.00 70 15 15.995 N 148 22 37.998 W i -Polygon 5 67.00 -3598.16 3155.31 5944825.00 701545.00 70 15 11.226 N 148 22 16.550 W 05-276 Faultl 67.00 -4354.65 3200.41 5944070.00 701610.00 70 15 3.786 N 148 22 15.248 W -Polygon 1 67.00 -4354.65 3200.41 5944070.00 701610.00 70 15 3.786 N 148 22 15.248 W ', -Polygon 2 67.00 -4760.20 3594.89 5943675.00 702015.00 70 14 59.796 N 148 22 3.780 W OS-27B Fault 2 67.00 -4415.27 2463.52 5943990.00 700875.00 70 15 3.193 N 148 22 36.680 W -Polygon 1 67.00 -4415.27 2463.52 5943990.00 700875.00 70 15 3.193 N 148 22 36.680 W ' -Polygon 2 67.00 -3882.01 2537.59 5944525.00 700935.00 70 15 8.437 N 148 22 34.520 W , OS-27B Fault3 67.00 -3611.42 2329.63 5944790.00 700720.00 70 15 11.099 N 148 22 40.566 W -Polygon 1 67.00 -3611.42 2329.63 5944790.00 700720.00 70 15 11.099 N 148 22 40.566 W -Polygon 2 67.00 -3385.83 2310.57 5945015.00 700695.00 70 15 13.318 N 148 22 41.119 W -Polygon 3 67.00 -2893.86 2243.49 5945505.00 700615.00 70 15 18.156 N 148 22 43.066 W -Polygon 4 67.00 -3385.83 2310.57 5945015.00 700695.00 70 15 13.318 N 148 22 41.119 W 05-276 Target 2 9037.00 -3348.21 2477.62 5945057.00 700861.00 70 15 13.687 N 148 22 36.259 W OS-27B New Targetl 9057.00 -4215.99 3595.22 5944219.00 702001.00 70 15 5.148 N 148 22 3.763 W BP Alaska ~ by Baker Hughes INTEQ Planning Report BA1°a INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 05 ~, Well: 05-27 I,. Wellpath: Plan 4, 05-276 Annotation NID TVD '~ ft ft __ 111566.20 - 9045.68 _ _ - - TIP 11600 00 9045.72 KOP . 11620.00 9045.51 End of 9 Deg/100' DLS i 11640.00 9044.79 4 11740.00 9040.39 5 11840.00 9039.94 6 11920.00 9044.33 End of 40 Deg/100' DLS 12128.04 9052.54 8 12428.00 9052.15 9 112628.00 9051.93 10 112948.00 9051.62 11 13258.00 9051.39 12 13540.00 9051.22 TD Date: 1272/2008 Time: 16:30:53 Page: 2 Co-ardinate(NE),Reference: Well: 05-27, True North Vertical (TVD) Reference: 52:27 10/5/1989 00:00 67.0 Section (VS) Reference: Well (O.OON,O.OOE,325.OOAzi) Survey CalculatiorrMethod: Minimum Curvature Db: Sybase _ _ __ - .. i -- Plan Section Information __ __ MD Inc1 Azim TVD +N/-S +E/-W DLS Build Turn 'CFO 'Carget ft deg deg ft ft ft deg/100it deg/t00ft deg/100ft .deg 11566.20 90.07 135.56 9045.68 -3919.76 3831.36 0.00 0.00 0.00 0.00 ii 11600.00 89.81 135.24 9045.72 -3943.83 3855.09 1.22 -0.77 -0.95 230.91 i 11620.00 91.37 136.14 9045.51 -3958.14 3869.06 9.00 7.79 4.50 30.00 !11640.00 92.74 144.03 9044.79 -3973.46 3881.87 40.00 6.86 39.43 80.00 11740.00 92.10 184.06 9040.39 -4067.57 3908.78 40.00 -0.64 40.03 90.00 11840.00 88.40 223.90 9039.94 -4157.09 3868.96 40.00 -3.70 39.84 95.00 111920.00 85.47 255.81 9044.33 -4196.72 3800.79 40.00 -3.67 39.89 96.00 ', 12128.04 90.08 280.37 9052.54 -4203.52 3594.67 12.00 2.22 11.81 80.00 12428.00 90.06 316.37 9052.15 -4063.32 3335.05 12.00 -0.01 12.00 90.00 12628.00 90.06 292.37 9051.93 -3951.25 3171.17 12.00 0.00 -12.00 270.00 12948.00 90.05 330.77 9051.62 -3742.88 2936.20 12.00 0.00 12.00 90.00 13258.00 90.04 293.57 9051.39 -3538.42 2710.45 12.00 0.00 -12.00 270.00 113540.00 90.03 327.41 9051.22 -3357.97 2499.07 12.00 0.00 12.00 90.00 Survey NID Licl Azim SS TVD N/S F/VV MapN MapE DLS VS TFO 'Foo - ft _- -deg deg __ _ -ft _ _ ft ft ft _ ft deg/100ft ft _ deg- 11566.20 90.07 135.56 8978.68 3919.76 3831.36 5944521.33 702229.24 0.00 5408.46 0.00 MWD ~ 11575.00 90.00 135.48 8978.68 -3926.04 3837.52 5944515.21 702235.57 1.22 -5417.14 230.91 MWD'; 11600.00 89.81 135.24 8978.72 -3943.83 3855.09 5944497.89 702253.60 1.22 -5441.79 230.91 MWD' 11620.00 91.37 136.14 8978.51 -3958.14 3869.06 5944483.96 702267.94 9.00 -5461.52 30.00 MWD 'I 11625.00 91.72 138.11 8978.38 -3961.80 3872.46 5944480.39 702271.44 40.00 -5466.47 80.00 MWD 11640.00 92.74 144.03 8977.79 -3973.46 3881.87 5944468.98 702281.15 40.00 -5481.42 80.05 MWD' 11650.00 92.73 148.03 8977.32 -3981.74 3887.46 5944460.85 702286.95 40.00 -5491.40 90.00 MWD ~ 11675.00 92.66 158.04 8976.14 -4003.97 3898.76 5944438.93 702298.84 40.00 -5516.10 90.19 MWD, 11700.00 92.50 168.05 8975.01 -4027.83 3906.04 5944415.27 702306.74 40.00 -5539.81 90.66 MWD' 11725.00 92.27 178.06 8973.96 -4052.59 3909.05 5944390.60 702310.40 40.00 -5561.83 91.12 MWD 11740.00 92.10 184.06 8973.39 -4067.57 3908.78 5944375.62 702310.52 40.00 -5573.94 91.53 MWD; ~ 11750.00 91.75 188.05 8973.06 -4077.51 3907.72 5944365.66 702309.73 40.00 -5581.48 95.00 MWD i 11775.00 90.83 198.01 8972.49 -4101.83 3902.10 5944341.20 702304.75 40.00 -5598.17 95.13 MWD 11800.00 89.89 207.96 8972.34 -4124.81 3892.35 5944317.97 702295.61 40.00 -5611.41 95.36 MWD ~ 11825.00 88.95 217.92 8972.59 -4145.77 3878.77 5944296.66 702282.59 40.00 -5620.78 95.42 MWD',,, 11840.00 88.40 223.90 8972.94 -4157.09 3868.96 5944285.08 702273.07 40.00 -5624.43 95.32 MW D 11850.00 87.99 227.88 8973.25 -4164.05 3861.78 5944277.94 702266.09 40.00 -5626.02 96.00 MWD 11875.00 87.00 237.84 8974.35 -4179.11 3841.90 5944262.36 702246.61 40.00 -5626.95 95.87 MWD'I 11900.00 86.10 247.81 8975.86 -4190.50 3819.73 5944250.40 702224.75 40.00 -5623.56 95.44 MWD ~ 11920.00 85.47 255.81 8977.33 -4196.72 3800.79 5944243.68 702205.98 40.00 -5617.79 94.84 MW D . 11925.00 85.57 256.40 8977.72 -4197.91 3795.95 5944242.36 702201.18 12.00 -5616.00 80.00 MWD ~ 11950.00 86.10 259.36 8979.54 -4203.15 3771.58 5944236.48 702176.95 12.00 -5606.30 79.95 MW D ~, 11975.00 86.64 262.32 8981.12 -4207.12 3746.95 5944231.87 702152.43 12.00 -5595.43 79.74 MWD !12000.00 87.19 265.28 8982.47 -4209.81 3722.13 5944228.52 702127.70 12.00 -5583.41 79.55 MWD ~' BP Alaska ~ ~~ by Baker Hughes INTEQ Planning Report ~TEQ Company: BP Amoco Date: 12(2(2008 Time: 16:30:53 Page: 3 Field: Pru dhoe Bay Co-ordi nate(NE) Reference: Well: 05-27, True North Site: PB DS 05 Vertical (TVD) Reference: 52:27 10/5/1989 00:00 67.0 'i Well: 05-27 Section (VS)~Reference: Well (O. OON,O.OOE,325.OOAzi) Wellpath: Pla n 4, 05-276 Survey Calculation Method: Minimu m Curvatu re D b: Sybase Survey ' MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TEO Tool ft deg deg ft ff, ft ft ft deg/100ft ft deg 12025.00 87.74 268.23 8983.58 -4211.23 3697.20 5944226.45 702102.82 12.00 5570.26 79.39 I 12050.00 88.30 271.17 8984.44 -4211.36 3672.22 5944225.66 702077.85 12.00 5556.04 79.26 MWD I' 12075.00 88.87 274.12 8985.05 -4210.20 3647.26 5944226.15 702052.86 12.00 -5540.78 79.16 MWD 12100.00 89.44 277.07 8985.42 -4207.77 3622.38 5944227.94 702027.93 12.00 -5524.51 79.09 MWD 12125.00 90.01 280.01 8985.54 -4204.06 3597.66 5944231.00 702003.13 12.00 -5507.29 79.04 MWD 12128.04 90.08 280.37 8985.54 -4203.52 3594.67 5944231.45 702000.12 12.00 -5505.13 79.03 MWD' 12150.00 90.08 283.01 8985.51 -4199.07 3573.17 5944235.33 701978.51 12.00 -5489.16 90.00 MW D 12175.00 90.08 286.01 8985.48 -4192.81 3548.97 5944240.96 701954.16 12.00 -5470.15 90.00 MWD 12200.00 90.08 289.01 8985.44 -4185.29 3525.13 5944247.84 701930.13 12.00 -5450.32 90.01 MWDI 12225.00 90.08 292.01 8985.41 -4176.53 3501.71 5944255.98 701906.49 12.00 -5429.72 90.01 I MW D 12250.00 90.08 295.01 8985.37 -4166.56 3478.79 5944265.34 701883.32 12.00 -5408.40 90.02 MWD, 12275.00 90.08 298.01 8985.34 -4155.41 3456.42 5944275.91 701860.66 12.00 -5386.43 90.02 MWD ~ 12300.00 90.07 301.01 8985.31 -4143.09 3434.67 5944287.64 701838.59 12.00 -5363.87 90.02 MWD. i 12325.00 90.07 304.01 8985.27 -4129.66 3413.59 5944300.51 701817.17 12.00 -5340.77 90.03 MWD 12350.00 90.07 307.01 8985.24 -4115.14 3393.24 5944314.49 701796.44 12.00 -5317.21 90.03 MWD 12375.00 90.07 310.01 8985.21 -4099.58 3373.68 5944329.53 701776.48 12.00 -5293.24 90.04 MWD 12400.00 90.07 313.01 8985.18 -4083.01 3354.96 5944345.60 701757,33 12.00 -5268.93 90.04 MWD~i 12425.00 90.07 316.01 8985.15 -4065.49 3337.13 5944362.64 701739.05 12.00 -5244.35 90.04 MWD j 12428.00 90.06 316.37 8985.15 -4063.32 3335.05 5944364.76 701736.91 12.00 -5241.38 90.05 MWD i 12450.00 90.06 313.73 8985.12 -4047.76 3319.51 5944379.90 701720.97 12.00 -5219.72 270.00 MWD 12475.00 90.06 310.73 8985.10 -4030.96 3301.00 5944396.21 701702.03 12.00 -5195.34 270.00 MWD 00 12500 90.06 307.73 8985.07 -4015.15 3281.64 5944411.50 701682.25 12.00 -5171.29 269.99 MWD, ' . 12525.00 90.06 304:73 8985.04 -4000.38 3261.47 5944425.74 701661.71 12.00 -5147.62 269.99 MWD ' 12550.00 90.06 301.73 8985.01 -3986.68 3240.56 5944438.88 701640.45 12.00 -5124.41 269.99 MWD 12575.00 90.06 298.73 8984.99 -3974.10 3218.96 5944450.89 701618.52 12.00 -5101.71 269.98 MW D 12600.00 i 90.06 295.73 8984.96 -3962.66 3196.74 5944461.74 701596.00 12.00 -5079.59 269.98 MWD' ~ 12625.00 90.06 292.73 8984.93 -3952.40 3173.94 5944471.39 701572.95 12.00 -5058.11 269.98 MW D 12628.00 90.06 292.37 8984.93 -3951.25 3171.17 5944472.47 701570.14 12.00 -5055.58 269.97 MWD 12650.00 90.06 295.01 8984.91 -3942.41 3151.02 5944480.77 701549.78 12.00 -5036.79 90.00 MWDII 12675.00 90.06 298.01 8984.88 -3931.26 3128.65 5944491.33 701527.12 12.00 -5014.82 90.00 MWD 12700.00 90.06 301.01 8984.86 -3918.95 3106.90 5944503.07 701505.05 12.00 -4992.26 90.01 MWD I 12725.00 90.06 304.01 8984.83 -3905.51 3085.82 5944515.94 701483.63 12.00 -4969.16 90.01 MWD I ' 12750.00 90.06 307.01 8984.80 -3890.99 3065.47 5944529.92 701462.90 12.00 -4945.60 90.01 MW D 12775.00 90.06 310.01 8984.78 -3875.43 3045.91 5944544.96 701442.94 12.00 -4921.63 90.01 MW D , 12800.00 90.06 313.01 8984.76 -3858.87 3027.19 5944561.02 701423.79 12.00 -4897.32 90.02 MWD' I 12825.00 90.05 316.01 8984.73 -3841.34 3009.36 5944578.07 701405.51 12.00 -4872.74 90.02 MWD 12850.00 90.05 319.01 8984.71 -3822.91 2992.48 5944596.05 701388.15 12.00 -4847.96 90.02 MWD 12875.00 90.05 322.01 8984.69 -3803.62 2976.58 5944614.91 701371.75 12.00 -4823.04 90.03 MWD i 12900.00 90.05 325.01 8984.66 -3783.52 2961.71 5944634.61 701356.36 12.00 -4798.05 90.03 MWD 00 12925 90 05 328.01 8984.64 -3762.68 2947.92 5944655.08 701342.02 12.00 -4773.06 90.03 MWD . 12948.00 . 90.05 330.77 8984.62 -3742.88 2936.20 5944674.56 701329.79 12.00 -4750.13 90.03 MWD'i 12950.00 90.05 330.53 8984.62 -3741.14 2935.22 5944676.28 701328.77 12.00 -4748.14 270.00 MW D 12975 00 90.05 327.53 8984.60 -3719.71 2922.36 5944697.36 701315.34 12.00 -4723.21 270.00 MWD! . 13000.00 90.05 324.53 8984.58 -3698.98 2908.39 5944717.72 701300.83 12.00 -4698.21 270.00 MWD I 13025.00 90.05 321.53 8984.56 -3679.01 2893.36 5944737.28 701285.28 12.00 -4673.23 269.99 MWD 13050.00 90.05 318.53 8984.54 -3659.85 2877.30 5944756.01 701268.72 12.00 -4648.33 269.99 MWD, ' 13075.00 90.04 315.53 8984.52 -3641.56 2860.26 5944773.84 701251.21 12.00 -4623.57 269.99 MWD 13100.00 90.04 312.53 8984.50 -3624.19 2842.29 5944790.73 701232.78 12.00 -4599.03 269.99 MWD 13125.00 90.04 309.53 8984.48 -3607.78 2823.43 5944806.64 701213.50 12.00 -4574.77 269.99 MWD' 13150.00 90.04 306.53 8984.46 -3592.38 2803.74 5944821.51 701193.41 12.00 -4550.87 269.98 MWD 13175.00 90.04 303.53 8984.45 -3578.03 2783.27 5944835.32 701172.57 12.00 -4527.37 269.98 MWD, II 13200.00 90.04 300.53 8984.43 -3564.78 2762.08 5944848.01 701151.04 12.00 -4504.36 269.98 MWDII ri.~ by ~ BP Alaska ~~ Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 12/2/2008 Time: 16:30:53 Page: 4 ' i Field: Prudhoe Bay Ca-ordinate(NE) Reference: Well: 05-27, True North Site: PB DS 05 Vertical (TVD)Reference: 52:27 10/5/1989 00:00 67. 0 Well: 05 -27 Section{VS)Ret'erence: WeIF(O .OON,O.OOE,325.OOA zi) Wellpath: Plan 4, 05-276 Survey Calculation Method: Minimu m Curvatu re Db: Sybase Survey - -- NID Incl Azim SS TVD N/S -- - E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 13225.00 90.04 297.53 8984.41 -3552.65 2740.22 5944859.56 701128.87 12.00 -4481.88 269.98 MWD; 13250.00 90.04 294.53 8984.40 -3541.68 2717.76 5944869.93 701106.13 12.00 -4460.02 269.97 MWD' 13258.00 90.04 293.57 8984.39 -3538.42 2710.45 5944873.00 701098.74 12.00 -4453.15 269.97 MWD 13275.00 90.04 295.61 8984.38 -3531.35 2694.99 5944879.66 701083.11 12.00 -4438.50 90.00 MW D 13300.00 90.04 298.61 8984.36 -3519.96 2672.74 5944890.46 701060.56 12.00 -4416.40 90.00 MWD ~ 13325.00 90.04 301.61 8984.35 -3507.42 2651.12 5944902.42 701038.62 12.00 -4393.73 90.00 MWD': 13350.00 90.04 304.61 8984.33 -3493.77 2630.18 5944915.52 701017.33 12.00 -4370.53 90.01 MWD' 13375.00 90.04 307.61 8984.32 -3479.04 2609.98 5944929.71 700996.75 12.00 -4346.88 90.01 MW D 13400.00 90.04 310.61 8984.30 -3463.27 2590.58 5944944.96 700976.95 12.00 -4322.84 90.01 MWD 13425.00 90.03 313.61 8984.28 -3446.51 2572.04 5944961.23 700957.97 12.00 -4298.47 90.01 MWD ~ 13450 00 90 03 316 61 8984.27 -3428.80 2554.40 5944978.47 700939.86 12.00 -4273.85 90.01 MWD . 13475.00 . 90.03 . 319.61 8984.25 -3410.19 2537.70 5944996.63 700922.69 12.00 -4249.03 90.01 MWD ~ 13500.00 90.03 322.61 8984.24 -3390.74 2522.01 5945015.66 700906.49 12.00 -4224.09 90.02 MW D 13525.00 90.03 325.61 8984.23 -3370.49 2507.35 5945035.52 700891.31 12.00 -4199.10 90.02 MWD 13540.00 90.03 327.41 8984.22 -3357.97 2499.07 5945047.81 700882.70 12.00 -4184.10 90.02 2 3/8"' BP Alaska NELIrAaTY DETYI! a00]!31l13N] r.,.n~ w.lr.a: sn P. on YD: I~aN.30 03 Nb ~ a.i. D~ ume : ST 10~a~1N! 00;00 !].00N O DSO i p~ 2 F LEGEND ~ ..a~osn ~~~~~ .mgmn OS271DS27) ,a OS27 (OS27A)) Nan 4.Oi27B ibsnab xaw - !.~ Nan., ~~. {1-) mw ro eau,. ; ..,imams ea u~..rsaw, uoaei gpm~rooi Cd ``a0/1'++~-/-^+10 En:YolmkfieNawiQWNO.n • BP Alaska wpunrx oayuu aaaii °~xTo iv»ox i.... wawa: oax7 is e. ro: 11aaa.xa alb a.1. p.mm: ~.t 9x : n +Omuu ao:ap n.0an V. M/a ~1lH ~EFN imm iY0 ]x6.00' 0.00 0.00 ]x.00 REFERENCE INFORMATION Coordinate (N/E) Reference. Well Centre'. OS27, True North VerOcal (TVD) Reference. 52:27 101611969 00:00 67.00 Section (VppSl fteterence Slot-27 (O.OON,O.OOE) Meawr Cal ulatroneMethod. MnimumOGUrv9ature0.00 87.00 LEGEND ~~~. 01-22 (01-22) 01-22A (01-22A) OS03 (OSO3) BAKER HUa N~s OS03 (OSO3A) ' OS03 OSO3B , ( ) oso3 (oso3c> INTE i osos (osos) OS09A (OS09A) OS21 (OS21) ' OS27 (OS27) OS27 (OS27A) i __. _ - 11-03 (11-03) ~, __ t 11-03A (11-03A) ~i Plan 4, OS27B Plan #4 i T %an: %an N41os27/Plan 4 .OS276) ' M atlmMna to Trw ~~ Cretlad By: BP Data: 11/312006 Mapnri NOM: 3x.00' ChOCketl'. Date'. bP MeyrwOC Fki10 Strar~pa 5768xnT OiV F^da 8ap3~li Conuulr0oim:aon I Data 11113/1009 Mo0el: Oppm1007 311 HMCnaalaw~ ~~ ,~,; ~,.~„o ,al w~ w,r.~ae„~r~~~tE~ aw n X4 1Me> M~fa.M aN14 w qW as tx 1xMa.0a NOx xT.N aw0al.a„3 • West(-~/East(+) [200ftlin] \1'El.l. UI~IAII S ~- Nanw ~N-R ~L-W Nwlllu~g Laawg IawUJc LWgiluJc 81W US-27 IIIU.tlS tlY4.]7 iYJXJ3tl G3 4`Ix2'n~N ]U'15'G, 421N IJ8'23'48.327W 27 IYi lax ItlU I~4 IG$ Istl ISU IJ3 13s J 2x 12U 113 33 XS n5 S? bU G8 ]5 W IUs _ ..113 12U 12x 135 - Iw i....."-I5R Ilr lei ~._In IBU Itlx 195 ~~~ \N I'I-t'UL1.181()\ 8k:fl INtiB IUMP.\N1' U!1'.\IL+' LuvrV~~la(i~m AIcNuJMU InlcivW. 5U W BY nnwcu IxVlh Rengc Frnn IIi462U Io 13SOU UU Alewuum Rurgc: ISSU ]U Referuwe. Ylnn Ylul XJ l'al.Wauun M.NuU. Mwunum t:urvalue LrtYr JSeI<m Ixt'W'X:\ S.mr AIaWUO Jrar l')IJWer NaN trtur Xurla.e. FIIiIwi.W ~ ('acing W anwgMM~vl RUI.a Beata 8r/R\'EY PRCRiR.\AI UeyN km IAPN I'o Rurv.~,Y'Ylan I ISG4.2U I?5J9 W YlawwJ. Yla x~J \ Y W'k:lf P.YflI UBI W~ luol YImiJ US37B AIW'U 1utI3Y119]A13 YueW W'ellpelX u5.27 I ie YU AIU 11544.2U Rig Rul INNUn NwGc 1 53 3] 114519tl9 W WI 4]UW - _ \'.Xecliw/ Dnyn (kigur XYr4ng Aogla -N~=s ~t-W' Yrvm ll'U 323. 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J5 $1 I / / / / J I J, ~ \ G0 CI / ~ ~ ~ . p ^a, I'rav,:IXng 151wJcr Ai.000N (IFU~ {!.I I Idcgl va t;crtre w lailrc JcPUaIiW l ISIi/nl LEGEND OI-22 (O1-22), Major Risk 01-22A (01-22A), Major Risk -- OS-03 (OS-03), Major Risk ' OS-03 (OS-03A), Major Risk OS-03 (OS-03B), Major Risk - OS-03 (OS-03C), Major Risk OS-09A (OS-09A ), Ma)or Risk OS-21 (OS-21), Major Risk -' OS-21A (OS-21A), Major Risk - OS 27 (05-27), Major Risk OS-27 (OS-27A), Major Risk I I-03 (I I-03), Major Risk I I-03A (I 1-03A), Major Risk -- Plan 4, OS-27B Plan #4 by - ~ - ~-- SFC'I'IUN Uk:'I'AILB S¢ MU Uw Au TVU -N S .E/-W DL<g 7Faa VSec 1 11546.2U ')U.U] 13156 2 IIGUI!W 8981 1352) NW548 -391 Y.7G WJ$]Z -J9J3 N3 3tlS1.36 3855119 UW UUU -5408 J4 122 21091 ->JJI ]Y J IIG20W Y137 136.14 YtWS iI -3YSR.IJ 3tlGY IW 9W 3llW -514152 9 IIGJUW 1271 IJ4 U3 WJJ ]9 -3Y]3 Jti 3tlX1 N7 JU.W tN.W -51X1 J2 5 11 ]JUW 9210 ItlJ.W G II WUIXI RB JU ?2190 W4039 JW75J 90399J -Jli]nY IWX]g 1116896 IU.W YI.W 90.W -5>].3 )J YS IMI -SG2J J3 '/ IIY2U UU XS J7 255.X1 YINJ.ll -01`)U.72 38W ]9 JU.W 9GW -541]7') 8 1312N W ')U U8 2X0.)] W52 54 -02U3 i2 )59J.G7 12 UU w W -55U5 13 9 12J2xW YO OG 31[.5] 9U52.13 -4W3.?2 333505 12.W SYI.W -52413R IU 1242tl.W YU UL 2Y23] 9051')3 -3')5125 31]11] 12.W -']I1.W -SUii Stl ~ 11 129JRW YU 9i 330.]7 905142 -3]J2 Ntl 293/+20 12.W WW -J]SU 13 12 132SNW `)U OJ 293.57 13 135JOW vU U3 32'l.JI W5139 -3558 J2 W5122 -1.35]9] 2]1005 24YY 0] 12.W 12.W 27U.lNl -JJ5115 W.UU -JIIrl.IU C P;'~a ~ BP Alaska by ~`}•+`~ Anticollision Report rr..r B Nua~s INTEQ Company: BP Amoco Date: 12/3/2008 Time: 09:38:16 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 05 Co-ordinat e(NE) Reference: Well: 05 -27, True North Reference Well: 05-27 Vertical (T VD) Reference: 52:27 10/5/1989 00: 00 67.0 Reference Wellpath: Plan 4, 05-27B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'Ri~eeells in this~ehiLpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 11566.20 to 13540.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1550.70 ft Error Surface: Ellip se + Casing ~', Survey Program for Definitive Wellpath Date: 11/12/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft ~I 200.00 11566.20 1 : MWD -Standard (200.00-125 MWD MWD - Standard ~!i 11566.20 13540.00 Planned: Plan #4 V9 MWD MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ft- in in L 13540.00 9051.22 2.375 3.000 2 3/8" i Summary <----------- Offset Wellpath ------------> Site Well Wellpath Reference MD Offset Ctr-Ctr MD Distance No-Go Area Allowable Deviation Warning ft ft ft ft ft PB DS 01 01-22 01-22 V4 12825.00 10588.00 1477.78 320.89 1156.89 Pass: Major Risk PB DS 01 01-22A 01-22A V3 12832.24 10605.00 1327.35 323.75 1003.61 Pass: Major Risk PB DS 05 05-03 05-03 V6 13189.18 10825.00 344.22 957.31 -613.09 FAIL: Major Risk PB DS 05 05-03 05-03A V1 13207.37 11025.00 1044.19 639.25 404.94 Pass: Major Risk PB DS 05 05-03 05-036 V2 Out of range PB DS 05 05-03 05-03C V5 13142.97 11550.00 566.39 473.74 92.65 Pass: Major Risk PB DS 05 05-09A 05-09A V1 Out of range PB DS 05 05-21 05-21 V1 Out of range PB DS 05 05-21A 05-21A V3 Out of range j PB DS 05 05-27 05-27 V1 11649.35 11650.00 4.26 479.73 -475.48 FAIL: Major Risk !; PB DS 05 05-27 05-27A V1 11649.35 11650.00 4.26 479.76 -475.51 FAIL: Major Risk PB DS 11 11-03 11-03 V1 11760.00 12961.00 1132.88 1765.82 -632.94 FAIL: Major Risk PB DS 11 11-03A 11-03A V1 11640.00 12389.00 1246.05 626.77 619.27 Pass: Major Risk ~ Site: PB DS 0 1 Well: 01-22 Rule Ass igned: Major Risk Wellpath: 01-22 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref' Offset TFO+AZI TFO=HS Casing/HSDistaoce Area Deviation R'arning ' ft ft ft ft ft ft deg. ` deg in ft ft ft 12825.00 9051.73 10400.00 9013.36 78.05 10.07 227.43 271.42 1550.61 318.79 1231.82 Pass 12825.00 9051.73 10425.00 9035.86 78.05 10.10 226.60 270.59 1539.59 319.25 1220.35 Pass ~ 12825.00 9051.73 10450.00 9058.39 78.05 10.14 225.76 269.75 1528.98 319.66 1209.32 Pass ! 12825.00 9051.73 10475.00 9080.96 78.05 10.17 224.90 268.90 1518.77 320.01 1198.76 Pass ~ 12825.00 9051.73 10500.00 9103.56 78.05 10.20 224.04 268.03 1508.99 320.31 1188.68 Pass i~ 12825.00 9051.73 10525.00 9126.21 78.05 10.23 223.16 267.15 1499.65 320.55 1179.09 Pass 12825.00 9051.73 10550.00 9148.87 78.05 10.26 222.27 266.26 1490.69 320.73 1169.95 Pass 12825.00 9051.73 10575.00 9171.52 78.05 10.29 221.37 265.36 1482.10 320.85 1161.25 Pass 12825.00 9051.73 10588.00 9183.31 78.05 10.31 220.90 264.89 1477.78 320.89 1156.89 Pass Site: PB DS 0 1 Well: 01-22A Rule Ass igned: Major Risk Wellpath: 01-22A V3 Inter-Site Error: 0.00 ft Reference Offset .Semi-Major Axis . Ctr-Ctr No-Co Allowable MD TVIIr MD TVD Ref Offset TFO+AZL'TFO-HS Casng/IiSDistance Area Deviation Warning ft ft ft ft 'ft ft deg deg in ft ft ft ~, 12814.46 9051.74 10350.00 8935.64 77.99 9.55 229.08 274.34 1533.12 320.26 1212.86 Pass 12815.18 9051.74 10375.00 8948.49 77.99 9.56 228.75 273.92 1511.03 320.60 1190.44 Pass i 12816.42 9051.74 10400.00 8961.23 78.00 9.58 228.46 273.48 1489.36 320.94 1168.42 Pass 12825.00 9051.73 10425.00 8973.93 78.05 9.65 229.04 273.04 1468.42 321.74 1146.68 Pass ! 12825.00 9051.73 10450.00 8987.01 78.05 9.66 228.57 272.56 1448.39 321.97 1126.42 Pass ~~~ ~~,~~~ s by :~~; BP Alaska Anticollision Report ~L~ >~~ Company: BP Amoco Date: 12/3!2008 Time: 49:38:16 Page: 2 Field: Prudhoe Bay Reference Site: PB DS 05 Co-ordinate(NE) Reference: Well: 05-27, True North Reference Weil: 05-27 Vert~al (TVD) Reference: 52:27 1 0!5/1989 00:06 67.0 Reference Wellpath: Plan 4, 05-276 Db: Orade Site: PB DS 01 Well• 01-22A Rule Assigned: Major Ris k Wellpath: 01-22A V3 Inter-Site Error: 0.00 ft Refe rence Off set Semi-M ajor Axis Ctr-Ctr No-Go Albwable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSDistaace Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 12825.00 9051.73 10475.00 9000.64 78.05 9.67 228.06 272.05 1429.23 322.20 1107.04 Pass 12825.00 9051.73 10500.00 9014.68 78.05 9.68 227.51 271.51 1409.95 322.43 1087.51 Pass 1 12825.00 9051.73 10525.00 9028.67 78.05 9.69 226.96 270.95 1390.18 322.79 1067.39 Pass '112825.00 9051.73 10550.00 9042.62 78.05 9.71 226.39 270.38 1370.38 323.00 1047.37 Pass 12825.00 9051.73 10575.00 9056.57 78.05 9.72 225.80 269.79 1350.75 323.19 1027.55 Pass 12831.88 9051.73 10600.00 9070.52 78.03 9.80 226.02 269.19 1331.23 323.70 1007.53 Pass 12832.24 9051.72 10605.00 9073.31 78.03 9.81 225.94 269.07 1327.35 323.75 1003.61 Pass Site: PB DS 05 Well• 05-03 Rule Assigned: Major Ris k Wellpath: 05-03 V6 Inter-Site Error: 0.00 ft Reference Off set Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSDistance Area Deviatwn Warning ft ft ft ft ft ft deg deg in ft ft ft ~, 13455.44 9051.27 10575.00 8941.03 74.65 242.77 31.53 74.27 406.54 950.53 -543.99 FAIL 13364.30 9051.32 10600.00 8959.63 73.44 237.97 23.07 76.75 400.04 942.76 -542.72 FAIL 13279.93 9051.38 10625.00 8978.23 70.02 225.88 15.43 79.23 391.34 905.08 -513.74 FAIL 13251.92 9051.39 10650.00 8996.82 69.20 223.63 16.07 81.77 381.48 902.41 -520.93 FAIL 113243.34 9051.40 10675.00 9015.40 69.75 226.48 19.78 84.46 372.53 917.47 -544.94 FAIL 13234.64 9051.41 10700.00 9033.98 70.30 229.29 23.63 87.26 364.66 930.71 -566.05 FAIL 13225.80 9051.41 10725.00 9052.56 70.85 232.08 27.62 90.18 357.98 941.81 -583.83 FAIL '~ 13216.83 9051.42 10750.00 9071.14 71.36 234.82 31.71 93.21 352.54 950.21 -597.67 FAIL 13207.74 9051.42 10775.00 9089.72 71.87 237.52 35.91 96.31 348.42 955.77 -607.35 FAIL j ~ 13198.52 9051.43 10800.00 9108.30 72.37 240.17 40.18 99.47 345.63 958.22 -612.59 FAIL 113189.18 9051.44 10825.00 9126.88 72.82 242.76 44.49 102.66 344.22 957.31 -613.09 FAIL 113179.73 9051.44 10850.00 9145.46 73.28 245.30 48.81 105.85 344.18 953.17 -608.99 FAIL ~~ 13170.56 9051.45 10874.00 9163.29 73.69 247.66 52.95 108.89 345.43 946.15 -600.72 FAIL Site: PB DS 05 Well: 05-03 Rule Assigned: Major Risk Wellpath: 05-03A V 1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ret Offset TFO+AZI TF0.HS Casiug/HSi)i+tanee Area Deviation Warning ', ft ft ft ft ft ft deg deg in ft ft ft r 13207.37 9051.42 11025.00 9024.83 71.89 130.27 28.18 88.54 1044.19 639.25 404.94 Pass '~, 13200.00 9051.43 11050.00 9024.77 72.30 131.09 29.07 88.54 1047.90 642.96 404.94 Pass 13191.92 9051.43 11075.00 9024.93 72.69 131.95 30.05 88.56 1052.06 646.71 405.35 Pass 13184.26 9051.44 11100.00 9025.34 73.06 132.73 31.00 88.58 1056.64 650.18 406.46 Pass i 13175.00 9051.45 11125.00 9026.05 73.51 133.61 32.16 88.63 1061.47 654.19 407.29 Pass ~, 13169.06 9051.45 11150.00 9027.05 73.75 134.18 32.93 88.69 1066.56 656.64 409.92 Pass 13161.57 9051.46 11175.00 9028.23 74.06 134.85 33.90 88.76 1072.44 659.59 412.85 Pass 13150.00 9051.46 11200.00 9029.53 74.54 135.76 35.36 88.84 1078.69 663.79 414.90 Pass 13150.00 9051.46 11225.00 9030.86 74.54 135.85 35.44 88.91 1084.31 664.07 420.24 Pass ~ 13139.27 9051.47 11250.00 9031.97 74.90 136.64 36.79 88.97 1090.05 667.52 422.53 Pass 13131.90 9051.48 11275.00 9033.00 75.14 137.17 37.73 89.03 1096.06 669.86 426.20 Pass ', '.13125.00 9051.48 11300.00 9034.05 75.37 137.64 38.62 89.09 1102.47 671.98 430.49 Pass 1 13117.34 9051.49 11325.00 9035.15 75.57 138.12 39.60 89.16 1109.18 674.02 435.16 Pass ~ ' 13110.12 9051.49 11350.00 9036.20 75.76 138.54 40.53 89.21 1116.00 675.86 440.14 Pass 13100.00 9051.50 11375.00 9036.92 76.02 139.05 41.78 89.26 1123.00 678.17 444.83 Pass ', 13100.00 9051.50 11400.00 9037.32 76.02 139.14 41.81 89.28 - 1130.10 678.44 451.66 Pass - ~'F~M BP Alaska Anticollision Report rrtr B ~G~IES 11NTEQ Company: - BP Amoco Date: 12/3/2008 Time: 09:38:16 ~ Page: 3 Field: Prudhoe Bay Reference Site: PB DS 05 Co-ordinate(NE) Refereuce: Well: 05-27, True North Reference Well: 05-27 Vertical{TVD) Reference: 52:27 10!5/1989 00: 00 67.0 Reference Welipath: Plan 4, 05-278 Db: Orade Site: PB DS 05 Well: 05-03 Rule Assigned: Major Risk Welipath: 05-03C V5 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casins/HSUistance Area Deviation Warning ft ft ft ft ft ft deg deg. in ft ft ft 13231.51 9051.41 11350.00 9037.87 70.49 66.23 25.45 88.71 599.57 443.04 156.53 Pass 13220.98 9051.41 11375.00 9036.82 71.13 67.06 26.60 88.59 591.60 447.40 144.20 Pass 13210.45 9051.42 11400.00 9035.02 71.72 67.86 27.66 88.39 583.28 451.52 131.76 Pass 13200.00 9051.43 11425.00 9033.22 72.30 68.62 28.72 88.19 576.60 455.52 121.07 Pass 13188.51 9051.44 11450.00 9032.45 72.86 69.42 30.00 88.10 571.40 459.56 111.84 Pass 13177.23 9051.44 11475.00 9032.46 73.40 70.16 31.34 88.08 567.64 463.45 104.18 Pass 13165.84 9051.45 11500.00 9032.83 73.89 70.88 32.74 88.11 565.42 467.07 98.34 Pass ~, 13154.39 9051.46 11525.00 9033.08 74.36 71.57 34.14 88.14 564.91 470.55 94.36 Pass 13142.97 9051.47 11550.00 9033.27 74.77 72.21 35.53 88.16 566.39 473.74 92.65 Pass ~ 13131.66 9051.48 11575.00 9033.55 75.15 72.81 36.92 88.20 569.83 476.69 93.14 Pass 13120.56 9051.49 11600.00 9033.88 75.49 73.36 38.31 88.25 575.17 479.38 95.79 Pass 13109.75 9051.49 11625.00 9033.63 75.77 73.87 39.60 88.24 582.49 481.72 100.77 Pass 13100.00 9051.50 11650.00 9032.64 76.02 74.30 40.70 88.17 591.39 483.76 107.63 Pass 13089.26 9051.51 11675.00 9030.93 76.21 74.71 41.86 88.04 602.13 485.56 116.57 Pass 13079.86 9051.52 11700.00 9028.94 76.38 75.06 42.84 87.90 615.00 487.07 127.93 Pass 13070.95 9051.52 11725.00 9027.63 76.51 75.36 43.84 87.82 629.27 488.35 140.92 Pass 13062.02 9051.53 11750.00 9027.44 76.60 75.64 44.94 87.85 643.10 489.46 153.64 Pass ' 13053.52 9051.54 11775.00 9028.10 76.68 75.88 46.06 87.96 657.95 490.47 167.47 Pass 13045.56 9051.54 11800.00 9029.00 76.73 76.08 47.14 88.08 674.07 491.26 182.81 Pass j 13038.14 9051.55 11825.00 9029.81 76.75 76.25 48.15 88.20 691.34 491.85 199.49 Pass i 13031.26 1 9051.56 11850.00 9030.47 76.76 76.39 49.07 88.30 709.64 492.35 217.30 Pass 13025.00 9051.56 11875.00 9030.60 76.78 76.51 49.88 88.35 729.01 492.75 236.26 Pass 13019.29 9051.57 11900.00 9029.21 76.75 76.60 50.50 88.29 749.40 492.93 256.48 Pass ~ Site: PB DS 05 Well: 05-27 Rule Assigned: Major Risk Welipath: 05-27 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aaic Ctr-Ctr No-C,o Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistaece Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 'i 13241.23 9051.40 10300.00 8859.82 69.88 59.19 7.02 71.44 602.02 400.05 201.97 Pass 13231.00 9051.41 10325.00 8868.55 70.53 60.00 8.84 72.03 592.77 405.49 187.28 Pass 13220.60 9051.41 10350.00 8877.16 71.15 60.79 10.70 72.64 584.12 410.87 173.26 Pass 13210.05 9051.42 10375.00 8885.61 71.74 61.57 12.59 73.27 576.06 416.12 159.95 Pass 13200.00 9051.43 10400.00 8893.89 72.30 62.30 14.44 73.91 568.59 421.17 147.42 Pass 13188.55 9051.44 10425.00 8902.00 72.85 63.06 16.47 74.57 561.72 426.28 135.45 Pass I ', 13177.62 9051.44 10450.00 8910.03 73.38 63.77 18.46 75.25 555.39 431.15 124.24 I Pass ', 13166.61 9051.45 10475.00 8918.07 73.85 64.44 20.49 75.95 549.52 435.78 113.74 Pass 13155.54 9051.46 10500.00 8926.11 74.31 65.09 22.54 76.68 544.13 440.28 103.85 Pass 113144.40 9051.47 10525.00 8934.17 74.72 65.71 24.63 77.44 539.21 444.55 94.66 Pass 13133.21 9051.48 10550.00 8942.23 75.10 66.28 26.75 78.21 534.67 448.56 86.11 Pass ~I 13121.97 9051.49 10575.00 8950.29 75.45 66.82 28.89 79.00 530.44 452.36 78.08 Pass i~ 13110.70 9051.49 10600.00 8958.36 75.74 67.33 31.05 79.81 526.52 455.83 70.69 Pass 13100.00 9051.50 10625.00 8966.41 76.02 67.80 33.16 80.64 522.97 459.09 63.87 Pass ', 13087.99 9051.51 10650.00 8974.25 76.23 68.26 35.42 81.46 520.01 462.04 57.98 Pass ~' 13075.00 9051.52 10675.00 8981.84 76.47 68.67 37.79 82.27 517.72 464.82 52.89 Pass ii 13065.01 9051.53 10700.00 8989.20 76.57 69.04 39.79 83.06 516.08 466.99 49.08 Pass ', 13053.45 9051.54 10725.00 8996.30 76.69 69.39 41.96 83.84 515.10 469.03 46.07 Pass 13041.84 9051.55 10750.00 9003.12 76.74 69.70 44.11 84.60 514.79 470.67 44.12 Pass 13030.22 9051.56 10775.00 9009.67 76.77 69.96 46.24 85.34 515.15 472.02 43.13 Pass ~! 13018.58 9051.57 10800.00 9015.93 76.74 70.19 48.34 86.04 516.16 473.01 43.16 Pass ~, 13006.96 9051.58 10825.00 9021.90 76.68 70.38 50.41 86.72 517.87 473.67 44.20 Pass • ~,~~~ BP Alaska Anticollision Report r~.r >«t~tT>~Q ' Company: BP Amoco Date: 12/3/2008 Time: 09:38:16 Page: 4 Fiehi: Prudhoe Bay ~i ' Reference Site: PB DS 05 Co-ordinate(NE) Reference: Weih 05-27, True North Reference Well: 05-27 Vertical (TVD) Reference: 52:27 1 0/5/1989 00: 00 67.0 Reference VVelipath: Plan 4, 05-27 6 Dh: tirade Site: PB DS 05 Well: 05-27 Rule Assigned: Major Risk Wellpath: 05-27 V1 Inter-Site Error: 0.00 ft ', Refe rence Offs et Semi-M ajor Aais Ctr-Ctr No-Go Allowable ', MD TVD MD TVD Re[ Offset TFO+AZI TFO-HS Casing/flSDistance Area. Deviation Warniag ft ft ft ft ft ft deg deg in ft ft ft 12995.36 9051.59 10850.00 9027.58 76.58 70.53 52.44 87.36 520.34 474.03 46.31 Pass 12983.80 9051.59 10875.00 9032.97 76.42 70.63 54.43 87.96 523.56 474.04 49.53 Pass 12972.31 9051.60 10900.00 9038.05 76.25 70.70 56.38 88.53 527.53 473.80 53.73 Pass ' 12960.89 9051.61 10925.00 9042.73 76.01 70.72 58.26 89.04 532.22 473.19 59.03 Pass ' 12611.48 9051.95 10950.00 9046.85 72.62 67.98 23.80 89.45 527.23 454.77 72.46 Pass ', ~, 12600.00 9051.96 10975.00 9050.40 73.46 68.95 25.56 89.83 517.90 460.25 57.65 Pass ' 12589.34 9051.97 11000.00 9053.39 74.17 69.85 27.17 90.16 509.14 465.08 44.06 Pass ' 12577.91 9051.98 11025.00 9055.82 74,92 70.76 28.82 90.44 501.04 470.07 30.96 Pass 12566.25 9051.99 11050.00 9057.70 75.62 71.65 30.44 90.66 493.63 474.82 18.81 Pass ~ ', 12554.38 9052.01 11075.00 9059.03 76.31 72.51 32.03 90.83 486.95 479.46 7.50 Pass 111575.00 9045.68 11575.00 9045.68 82.59 82.41 135.48 0.00 0.00 321.21 -321.21 FAIL ~, 11600.00 9045.72 11600.00 9045.72 82.88 82.78 135.24 0.00 0.00 322.48 -322.48 FAIL ', 11624.97 9045.38 11625.00 9045.85 83.01 83.11 356.96 218.86 0.60 349.79 -349.19 FAIL ' 11649.35 9044.35 11650.00 9046.06 81.62 81.83 34.02 246.25 4.26 479.73 X75.48 FAIL ' 11671.93 9043.28 11675.00 9046.34 78.23 78.60 51.95 255.14 11.94 484.79 X72.85 FAIL 11691.86 9042.37 11700.00 9046.60 73.70 74.19 64.28 259.49 23.23 466.13 X42.90 FAIL '~ 11708.85 9041.63 11725.00 9046.84 68.77 69.34 73.60 262.01 37.49 440.25 -402.76 FAIL 111723.06 9041.04 11750.00 4 9047.0 2 63.9 64 59 80 91 263.62 54.06 413.10 -359.04 FAIL i ~' 11734.89 9040.58 11775.00 9047.18 59.46 60.18 86.78 264.76 72.37 387.41 -315.03 FAIL ' 11744.86 9040.22 11800.00 9047.16 55.42 56.19 91.66 265.67 91.87 363.96 -272.09 FAIL ' 11753.32 9039.96 11825.00 9046.97 51.81 52.61 95.79 266.42 112.28 342.96 -230.68 FAIL '. , ' 11760.54 9039.77 11850.00 9046.61 48.63 49.44 99.31 267.06 133.39 324.27 -190.88 FAIL 11766.75 I 9039.63 11875.00 9046.11 45.79 46.64 102.33 267.61 155.07 307.60 -152.53 FAIL ~! 11772.13 9039.54 11900.00 9045.49 43.31 44.16 104.94 268.07 177.20 292.86 -115.66 FAIL 11776.83 9039.47 11925.00 9044.75 41.10 41.97 107.22 268.48 199.70 279.73 -80.03 FAIL ' 11780.97 9039.42 11950.00 9043.89 39.15 40.02 109.23 268.85 222.50 268.07 -45.57 FAIL j 11784.63 9039.38 11975.00 9043.02 37.41 38.30 110.99 269.15 245.55 257.60 -12.05 FAIL ', 11787.88 9039.36 12000.00 9042.15 35.87 36.76 112.54 269.40 268.83 248.25 20.58 Pass ~~ 11790.79 9039.35 12025.00 9041.30 34.48 35.38 113.91 269.62 292.29 239.85 52.44 Pass 11793.41 9039.34 12050.00 9040.47 33.25 34.15 115.13 269.79 315.91 232.25 83.66 Pass 11795.76 9039.33 12075.00 9039.73 32.14 33.05 116.21 269.93 339.67 225.39 114.28 Pass ' 11797.89 9039.33 12100.00 9039.11 31.14 32.07 117.16 270.04 363.57 219.20 144.37 Pass 11800.00 9039.34 12125.00 9038.60 30.15 31.10 118.07 270.11 387.58 213.02 174.56 Pass 11801.57 9039.34 12150.00 9038.18 29.45 30.40 118.75 270.16 411.68 208.49 203.18 Pass 11803.19 9039.35 12175.00 9037.80 28.73 29.68 119.44 270.20 435.84 203.78 232.06 Pass 11804.70 9039.35 12200.00 9037.44 28.06 29.03 120.07 270.24 460.06 199.41 260.65 Pass ' 11806.11 9039.36 12225.00 9037.12 27.44 28.42 120.66 270.27 484.32 195.34 288.99 Pass i '~ 11807.41 9039.37 12250.00 9036.75 26.86 27.88 121.21 270.30 508.64 191.57 317.07 Pass t 111810.00 9039.39 12275.00 9036.21 25.71 26.75 122.28 270.34 533.01 183.91 349.10 Pass II 111810.00 9039.39 12300.00 9035.49 25.71 26.83 122.34 270.40 557.42 184.16 373.26 Pass ' 11810.00 9039.39 12325.00 9034.60 25.71 26.90 122.42 270.47 581.89 184.42 397.47 Pass 11810.00 9039.39 12350.00 9033.51 25.71 26.98 122.51 270.56 606.40 184,68 421.71 Pass 11812.59 9039.41 12375.00 9032.19 24.73 25.89 123.63 270.66 630.92 177.21 453.71 Pass 11813.40 9039.42 12400.00 9030.65 24.42 25.61 124.07 270.77 655.49 175.05 480.44 Pass ', '.11814.15 9039.43 12425.00 9028.88 24.14 25.36 124.49 270.89 680.08 173.07 507.01 Pass ', '.11814.84 9039.44 12450.00 9026.98 23.88 25.14 124.89 271.01 704.71 171.27 533.45 Pass ', ' 11815.46 9039.45 12475.00 9024.94 23.65 24.95 125.26 271.14 729.38 169.65 559.73 Pass ', 11816.03 9039.45 12500.00 9022.79 23.43 24.78 125.61 271.27 754.08 168.19 585.88 Pass ' ' 11816.55 9039.46 12525.00 9020.54 23.24 24.64 125.95 271.39 778.80 169.00 609.80 Pass 11817.05 9039.47 12550.00 9018.27 23.05 24.51 126.26 271.51 803.53 171.93 631.60 Pass ' 11820.00 9039.51 12575.00 9016.01 21.94 23.57 127.54 271.61 828.31 167.67 660.64 Pass ~~ ~l~i~ y~ '~ b~ ~p~7;en - BP Alaska Anticollision Report atr s ~~~ iNTEQ Company: BP Amoco Date: 12/3/2008 Time: 09:38:16 Page: 5 Field: Prudhoe Bay Reference Site: PB DS 05 Co-ordinate(NE) Reference: Well: 05-27, True North Reference Well: 05-27 Vertical (TVD) Reference: 52:27 10/5/1989 00: 00 67.0 Reference Wellpath: Plan 4, 05-27 6 Db: Orade I Site: PB DS 05 Well: 05-27 Rule Assigned: Major Ris k Wellpath: 05-27 V1 Inter-Site Error: 0.00 ft Refe rence Offs et Semi-M ajorAaic Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+A2;I TFO-HS Casing/HSO!istance Area Deviation Warning ft ft ft ft ft ft deg deg. in ft ft ft '~ 11820.00 9039.51 12598.00 9013.92 21.94 23.62 127.64 271.71 851.09 171.70 679.39 Pass Site: PB DS 05 Well: 05-27 Rule Assigned: Major Ris k Wellpath: 05-27A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/IISDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13241.23 9051.40 10300.00 8859.82 69.88 59.42 7.02 71.44 602.02 400.69 201.33 Pass I, 13231.00 9051.41 10325.00 8868.55 70.53 60.22 8.84 72.03 592.77 406.14 186.62 Pass 13220.60 I 9051.41 10350.00 8877.16 71.15 61.02 10.70 72.64 584.12 411.53 172.59 Pass , 13210 05 9051 42 10375 00 8885.61 71.74 61.80 12.59 73.27 576.06 416.79 159.27 Pass . 13200.00 . 9051.43 . 10400.00 8893.89 72.30 62.54 14.44 73.91 568.59 421.86 146.74 Pass 13188.55 9051.44 10425.00 8902.00 72.85 63.30 16.47 74.57 561.72 426.97 134.75 Pass 13177.62 9051.44 10450.00 8910.03 73.38 64.01 18.46 75.25 555.39 431.85 123.54 Pass 13166.61 9051.45 10475.00 8918.07 73.85 64.69 20.49 75.95 549.52 436.49 113.04 Pass ~, 13155.54 9051.46 10500.00 8926.11 74.31 65.34 22.54 76.68 544.13 440.99 103.14 Pass ~, 13144.40 9051.47 10525.00 8934.17 74.72 65.95 24.63 77.44 539.21 445.27 93.95 Pass !, 13133.21 9051.48 10550.00 8942.23 75.10 66.52 26.75 78.21 534.67 449.27 85.40 Pass 13121.97 9051.49 10575.00 8950.29 75.45 67.07 28.89 79.00 530.44 453.07 77.37 Pass 13110.70 9051.49 10600.00 8958.36 75.74 67.57 31.05 79.81 526.52 456.54 69.99 Pass 13100.00 9051.50 10625.00 8966.41 76.02 68.04 33.16 80.64 522.97 459.80 63.17 Pass ~! 13087.99 9051.51 10650.00 8974.25 76.23 68.50 35.42 81.46 520.01 462.74 57.27 Pass ~ 13075.00 9051.52 10675.00 8981.84 76.47 68.91 37.79 82.27 517.72 465.53 52.19 Pass 13065.01 9051.53 10700.00 8989.20 76.57 69.28 39.79 83.06 516.08 467.69 48.38 Pass 13053.45 9051.54 10725.00 8996.30 76.69 69.62 41.96 83.84 515.10 469.73 45.37 Pass ~~ 13041.84 9051.55 10750.00 9003.12 76.74 69.93 44.11 84.60 514.79 471.37 43.42 Pass 13030.22 9051.56 10775.00 9009.67 76.77 70.20 46.24 85.34 515.15 472.72 42.42 Pass 13018.58 9051.57 10800.00 9015.93 76.74 70.43 48.34 86.04 516.16 473.71 42.45 Pass 13006.96 9051.58 10825.00 9021.90 76.68 70.61 50.41 86.72 517.87 474.37 43.49 Pass 12995.36 9051,59 10850.00 9027.58 76.58 70.76 52.44 87.36 520.34 474.73 45.60 Pass ', 12983.80 9051.59 10875.00 9032.97 76.42 70.87 54.43 87.96 523.56 474.74 48.82 Pass 12972.31 9051.60 10900.00 9038.05 76.25 70.93 56.38 88.53 527.53 474.50 53.03 Pass 12960.89 9051.61 10925.00 9042.73 76.01 70.95 58.26 89.04 532.22 473.89 58.33 Pass 12611.48 9051.95 10950.00 9046.85 72.62 68.21 23.80 89.45 527.23 455.45 71.78 Pass 12600.00 9051.96 10975.00 9050.40 73.46 69.18 25.56 89.83 517.90 460.95 56.95 Pass ', 12589.34 9051.97 11000.00 9053.39 74.17 70.09 27.17 90.16 509.14 465.79 43.35 Pass ~' 12577.91 9051.98 11025.00 9055.82 74.92 71.00 28.82 90.44 501.04 470.79 30.25 Pass 12566.25 9051.99 11050.00 9057.70 75.62 71.89 30.44 90.66 493.63 475.55 18.09 Pass I 12554.38 9052.01 11075.00 9059.03 76.31 72.75 32.03 90.83 486.95 480.19 6.76 Pass I .11575.00 9045.68 11575.00 9045.68 82.59 82.62 135.48 0.00 0.00 320.90 -320.90 FAIL 11600.00 9045.72 11600.00 9045.72 82.88 82.99 135.24 0.00 0.00 322.14 -322.14 FAIL i 11624.97 9045.38 11625.00 9045.85 83.01 83.31 356.96 218.86 0.60 349.84 -349.24 FAIL 'i 11649.35 9044.35 11650.00 9046.06 81.62 82.03 34.02 246.25 4.26 479.76 -475.51 FAIL 11671.93 9043.28 11675.00 9046.34 78.23 78.78 51.95 255.14 11.94 484.83 X72.89 FAIL 11691.86 9042.37 11700.00 9046.60 73.70 74.36 64.28 259.49 23.23 466.13 X42.90 FAIL 11708.85 9041.63 11725.00 9046.84 68.77 69.50 73.60 262.01 37.49 440.25 -402.76 FAIL 11723.06 9041.04 11750.00 9047.04 63.92 64.72 80.91 263.62 54.06 413.09 -359.02 FAIL ~ 11734.89 9040.58 11775.00 9047.18 59.46 60.31 86.78 264.76 72.37 387.39 -315.01 FAIL ~, 11744.86 9040.22 11800.00 9047.16 55.42 56.30 91.66 265.67 91.87 363.94 -272.07 FAIL 11753.32 9039.96 11825.00 9046.97 51.81 52.72 95.79 266.42 112.28 342.93 -230.65 FAIL 11760.54 9039.77 11850.00 9046.61 48.63 49.54 99.31 267.06 133.39 324.25 -190.85 FAIL ~J ;,.,fro •,a#.}y~ BP Alaska Anticollision Report U ~!~ iNTEQ Company: BP Amoco Date: 12/3!2008 Time: 09:38:16 Page: 6 Field: Prudhoe Bay l 'Reference Site: PB DS 05 Co-ordinate(NE) Reference: i Well: 05-27, True North. i Reference Well: 05-27 V ertical (TVD) Reference: 52 ; 27 1 0/5/1989 00: 00 67.0 I Reference Wellpatb: Plan 4, 05-27 6 Db: Orade J B Site: PB DS 05 Well: 05-27 Rule Assigned: Major Risk Wellpath: 05-27A V1 Inter-Site Error: 0.00 ft ~ Reference Offset Semi-MajorAzis Ctr-Ctr No-Go Allowable ~ MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 111766.75 9039.63 11875.00 9046.11 45.79 46.73 102.33 267.61 155.07 307.57 -152.50 FAIL ~, I 11772.13 9039.54 11900.00 9045.49 43.31 44.24 104.94 268.07 177.20 292.82 -115.62 FAIL 11776.83 9039.47 11925.00 9044.75 41.10 42.05 107.22 268.48 199.70 279.69 -80.00 FAIL ', !, 11780.97 9039.42 11950.00 9043.89 39.15 40.10 109.23 268.85 222.50 268.03 -45.53 FAIL 11784.63 9039.38 11975.00 9043.02 37.41 38.36 110.99 269.15 245.55 257.56 -12.01 FAIL 11787.88 9039.36 12000.00 9042.15 35.87 36.82 112.54 269.40 268.83 248.21 20.62 Pass 11790.79 9039.35 12025.00 9041.30 34.48 35.44 113.91 269.62 292.29 239.81 52.48 Pass 11793.41 9039.34 12050.00 9040.47 33.25 34.21 115.13 269.79 315.91 232.20 83.71 Pass ', 11795.76 9039.33 12075.00 9039.73 32.14 33.10 116.21 269.93 339.67 225.35 114.32 Pass 'i ~ 11797.89 9039.33 12100.00 9039.11 31.14 32.12 117.16 270.04 363.57 219.17 144.40 Pass ~ i 11800.00 9039.34 12125.00 9038.60 30.15 31.14 118.07 270.11 387.58 213.01 174.57 ~ Pass I~ 11801.57 9039.34 12150.00 9038.18 29.45 30.44 118.75 270.16 411.68 208.49 203.19 Pass !, 11803.19 9039.35 12175.00 9037.80 28.73 29.72 119.44 270.20 435.84 203.80 232.04 Pass ', 11804.70 9039.35 12200.00 9037.44 28.06 29.06 120.07 270.24 460.06 199.45 260.61 Pass 11806.11 9039.36 12225.00 9037.12 27.44 28.45 120.66 270.27 484.32 195.40 288.93 Pass 11807.41 9039.37 12250.00 9036.75 26.86 27.91 121.21 270.30 508.64 191.65 316.99 Pass ', 11810.00 9039.39 12275.00 9036.21 25.71 26.78 122.28 270.34 533.01 184.00 349.01 Pass 11810.00 9039.39 12300.00 9035.49 25.71 26.85 122.34 270.40 557.42 184.25 373.17 Pass 111810.00 9039.39 12325.00 9034.60 25.71 26.93 122.42 270.47 581.89 184.51 397.38 Pass 11810.00 9039.39 12350.00 9033.51 25.71 27.00 122.51 270.56 606.40 184.77 421.62 Pass ~ 11812.59 9039.41 12375.00 9032.19 24.73 25.91 123.63 270.66 630.92 177.30 453.63 Pass I 11813.40 9039.42 12400.00 9030.65 24.42 25.63 124.07 270.77 655.49 175.13 480.36 Pass 11814.15 9039.43 12425.00 9028.88 24.14 25.38 124.49 270.89 680.08 173.15 506.93 Pass ', 11814.84 9039.44 12450.00 9026.98 23.88 25.16 124.89 271.01 704.71 171.35 533.37 Pass 11815.46 1 9039.45 12475.00 9024.94 23.65 24.96 125.26 271.14 729.38 169.72 559.66 Pass 11816.03 ~ 9039.45 12500.00 9022.79 23.43 24.80 125.61 271.27 754.08 168.27 585.81 Pass ~ , 11816.55 9039.46 12525.00 9020.54 23.24 24.64 125.95 271.39 778.80 166.93 611.87 Pass !, 11817.05 9039.47 12550.00 9018.27 23.05 24.49 126.26 271.51 803.53 165.66 637.88 Pass 11820.00 9039.51 12575.00 9016.01 21.94 23.50 127.54 271.61 828.31 157.16 671.15 Pass 11820.00 9039.51 12600.00 9013.74 21.94 23.53 127.64 271.72 853.07 157.32 695.75 Pass ~~, 111820.00 9039.51 12625.00 9011.58 21.94 23.54 127.74 271.81 877.96 157.43 720.54 Pass I~ ~, 11820.00 9039.51 12650.00 9009.99 21.94 23.54 127.79 271.86 902.89 157.49 745.40 Pass ', 111820.00 9039.51 12675.00 9008.48 21.94 23.54 127.83 271.91 927.86 157.54 770.32 Pass ~, 11820.00 9039.51 12700.00 9007.41 21.94 23.54 127.85 271.92 952.86 157.56 795.30 Pass '.11820.00 9039.51 12725.00 9007.15 21.94 23.54 127.81 271.89 977.85 157.53 820.32 Pass 11820.00 9039.51 12750.00 9007.89 21.94 23.53 127.72 271.80 1002.80 157.44 845.35 Pass 11820.00 9039.51 12775.00 9009.60 21.94 23.53 127.58 271.66 1027.62 157.29 870.33 Pass ' ~ 11820.00 9039.51 12800.00 9011.72 21.94 23.51 127.43 271.50 1052.31 157.11 895.20 Pass 11820.00 9039.51 12825.00 9013.91 21.94 23.50 127.27 271.35 1076.84 156.90 919.94 Pass ~, 11820.00 9039.51 12850.00 9015.75 21.94 23.48 127.14 271.22 1101.24 156.69 944.56 Pass ~, 11816.38 9039.46 12875.00 9017.60 23.30 24.75 125.60 271.11 1125.49 167.29 958.20 Pass 11815.70 9039.45 12900.00 9019.28 23.56 25.00 125.22 271.01 1149.64 169.16 980.48 Pass 11814.97 9039.44 12925.00 9020.71 23.83 25.27 124.84 270.91 1173.66 171.18 1002.48 Pass 11814.19 9039.43 12950.00 9021.86 24.13 25.57 124.45 270.84 1197.55 173.36 1024.20 Pass '.11810.00 9039.39 12975.00 9022.78 25.71 27.48 122.74 270.79 1221.33 186.16 1035.17 Pass ', 11810.00 9039.39 13000.00 9023.67 25.71 27.43 122.68 270.73 1244.85 185.95 1058.91 Pass 11810.00 9039.39 13025.00 9024.46 25.71 27.38 122.62 270.68 1268.16 185.73 1082.43 Pass 11810.00 9039.39 13050.00 9025.29 25.71 27.33 122.57 270.63 1291.28 185.49 1105.79 Pass ', 11810.00 9039.39 13075.00 9026.37 25.71 27.27 122.51 270.57 1314.19 185.24 1128.95 Pass ', .11810.00 9039.39 13100.00 9027.94 25.71 27.21 122.43 270.49 1336.74 184.96 1151.78 Pass '~ .11810.00 9039.39 13125.00 9029.87 25.71 27.15 122.34 270.39 1359.10 184.66 1174.44 Pass • BP Alaska Anticollision Report ~.r B N~GNES INTEQ Company: BP Amoco Date: 12/3/2008 Time: 09:38:16 Page: 7 Field: Pnidhoe Bay Reference Site: PB DS 05 Co-ordinate(NE) Reference: WeN: 05-27, True North i Reference Well: 05-27 V ertical(TVD) Reference: 52:27 1 0/5/1989 00: 00 67.0 Reference Wellpath: Plan 4, 05-278 Db: Orate Site: PB DS 05 Well: 05-27 Rule Assigned: Major Risk Wellpath: 05-27A V1 Inter-Site Error: 0.00 ft Refe rence Off set Semi-M ajor Aais Ctr-Ctr No-Go Atlowab~ MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSOistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11810.00 9039.39 13150.00 9031.85 25.71 27.09 122.24 270.30 1381.22 184.35 1196.87 Pass '..11805.33 9039.36 13175.00 9033.80 27.79 29.42 120.31 270.23 1402.94 199.17 1203.77 Pass 11804.15 9039.35 13200.00 9036.16 28.31 29.99 119.74 270.13 1424.28 202.69 1221.59 Pass I, 11800.00 9039.34 13225.00 9038.81 30.15 32.23 117.99 270.02 1445.30 215.96 1229.34 Pass j 11800.00 9039.34 13250.00 9041.17 30.15 32.14 117.89 269.93 1465.90 215.61 1250.29 Pass I~, 11800.00 9039.34 13275.00 9042.99 30.15 32.05 117.82 269.86 1486.02 215.25 1270.78 Pass I~~ 11800.00 9039.34 13300.00 9044.29 30.15 31.95 117.77 269.81 1505.68 214.88 1290.79 Pass ~ 'i 11800.00 9039.34 13325.00 9045.07 30.15 3L85 117.74 269.78 1525.08 214.53 1310.55 Pass I 11796.26 9039.33 13350.00 9045.48 31.91 33.91 116.24 269.77 1544.01 226.61 1317.40 Pass Site: PB DS 1 1 Well: 11-03 Rule Assigned: Major Risk Wellpath: 11-03 V1 Inter-Site Error: 0.00 ft Reference Off set Semi-Major Axis Ctr-Ctr No-Go Aibwable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistaace Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11690.00 9042.45 12050.00 8653.88 74.21 306.60 88.61 284.56 1543.761127.29 416.47 Pass I 111690.00 9042.45 12075.00 8667.80 74.21 308.04 88.22 284.17 1526.781133.65 393.12 Pass ~ 111694.16 9042.27 12100.00 8681.53 73.07 319.80 89.55 283.83 1510.071167.03 343.04 Pass ', 11695.54 9042.21 12125.00 8695.12 72.70 324.77 89.72 283.45 1493.691182.70 311.00 Pass ', 11700.00 9042.01 12150.00 8708.61 71.48 337.15 91.17 283.12 1477.571217.72 259.85 Pass 11700.00 9042.01 12175.00 8722.02 71.48 338.80 90.74 282.69 1461.61 1224.79 236.82 Pass 11700.00 9042.01 12200.00 8735.32 71.48 340.45 90.31 282.26 1445.91 1231.84 214.07 Pass 11700.00 9042.01 12225.00 8748.51 71.48 342.21 89.88 281.83 1430.47 1239.16 191.31 Pass ~ 11700.00 9042.01 12250.00 8761.51 71.48 343.98 89.44 281.39 1415.34 1246.49 168.85 Pass !I 11704.50 9041.81 12275.00 8774.32 70.10 356.49 90.87 281.02 1400.441281.60 118.84 Pass ~' 11706.12 ~ 9041.74 12300.00 8786.94 69.60 362.11 91.11 280.60 1385.88 1298.85 87.03 Pass I11710.00 9041.58 12325.00 8799.37 68.42 373.01 92.28 280.22 1371.601329.74 41.86 Pass 'I 11710.00 9041.58 12350.00 8811.59 68.42 375.04 91.83 279.77 1357.461337.75 19.71 Pass ' 111710.00 9041.58 12375.00 8823.59 68.42 377.08 91.38 279.32 1343.531345.70 -2.17 FAIL 11710.00 9041.58 12400.00 8835.37 68.42 379.11 90.93 278.88 1329.821353.58 -23.76 FAIL i ~, 11714.77 9041.38 12425.00 8846.99 66.81 392.05 92.46 278.50 1316.301389.21 -72.90 FAIL ~ 111720.00 9041.17 12450.00 8858.53 65.04 405.67 94.18 278.13 1303.261426.39 -123.12 FAIL ~ ', '.11720.00 9041.17 12475.00 8870.00 65.04 407.94 93.71 277.66 1290.551434.89 -144.34 FAIL '.11720.00 9041,17 12500.00 8881.40 65.04 410.20 93.24 277.18 1278.291443.34 -165.06 FAIL ~', '.11720.00 9041.17 12525.00 8892.72 65.04 412.56 92.75 276.70 1266.451452.02 -185.56 FAIL ' 11724.33 9040.99 12550.00 8903.94 63.46 424.13 94.07 276.27 1254.961483.47 -228.52 FAIL ', 11726.36 9040.91 12575.00 8915.06 62.72 430.73 94.41 275.81 1243.871502.50 -258.64 FAIL 11730.00 9040.77 12600.00 8926.08 61.38 440.49 95.43 275.37 1233.181529.19 -296.01 FAIL ', 11730.00 9040.77 12625.00 8937.04 61.38 443.01 94.92 274.86 1222.901538.09 -315.19 FAIL '..11730.00 9040.77 12650.00 8948.00 61.38 445.55 94.40 274.34 1213.131546.95 -333.82 FAIL 11734.81 9040.59 12675.00 8958.96 59.49 457.44 95.87 273.89 1203.801578.12 -374.33 FAIL 11740.00 9040.39 12700.00 8969.92 57.45 469.58 97.49 273.43 1195.021609.50 X14.48 FAIL 11740.00 9040.39 12725.00 8980.87 57.45 472.23 96.95 272.89 1186.691618.38 X31.69 FAIL ' 11740.00 9040.39 12750.00 8991.80 57.45 474.88 96.40 272.34 1178.90 1627.15 -448.25 FAIL 11743.76 9040.26 12775.00 9002.70 55.88 484.12 97.40 271.84 1171.61 1650.93 -479.32 FAIL '.11746.08 9040.18 12800.00 9013.58 54.91 490.70 97.79 271.31 1164.851668.35 -503.50 FAIL '~ 11750.00 9040.06 12825.00 9024.44 53.27 499.76 98.84 270.79 1158.60 1691.03 -532.43 FAIL ', 11750.00 9040.06 12850.00 9035.30 53.27 502.50 98.27 270.23 1152.81 1699.48 -546.67 FAIL ' 11750.00 9040.06 12875.00 9046.16 53.27 505.24 97.70 269.65 1147.53 1707.76 -560.23 FAIL 11755.62 9039.90 12900.00 9057.02 50.80 516.50 99.42 269.14 1142.65 1734.02 -591.37 FAIL • Lk~s, BP Alaska ~~ `°~~_' Anticollision Report ~~~ >I~vTEQ Company: BP Amoco Date: 12/3/2008. Time: 09:38:16 Page: 8 FieM: Prudhoe Bay ' Reference Site: PB DS 05 Co-ordinate(NE) Reference: Well: 05-27, True Notth Reference Well: 05-27 V ertical (TVD) Reference: 52:27 1 0/5/1989 00: 00 67.0 Reference Wellpath: Plan 4, 05-27 8 ~-~ grade Site: PB DS 11 Well: 11-03 Rule Assigned: Major Risk Wellpath: 11-03 V1 Inter-Site Error: 0.00 ft ', Reference Otf set Semi-MajorAaie Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSDistaace Area Deviation Warning ~ ft ft ft ft ft ft deg deg in ft ft ft j 11760.00 9039.78 12925.00 9067.88 48.88 525.40 100.64 268.61 1138.301754.58 -616.28 FAIL 111760.00 9039.78 12950.00 9078.74 48.88 528.18 100.06 268.03 1134.421762.43 -628.01 FAIL 11760.00 9039.78 12961.00 9083.52 48.88 529.41 99.80 267.77 1132.881765.82 -632.94 FAIL Site: PB DS 11 Well: 11-03A Rule Assigned: Major Risk Wellpath: 11-03A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Atbwable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/FL9)istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11644.57 9044.58 11975.00 8825.08 82.04 127.04 64.06 278.20 1539.79 641.90 897.90 Pass ~, 11644.49 9044.58 12000.00 8843.31 82.05 126.85 63.44 277.62 1520.35 642.76 877.59 Pass 11644.42 9044.58 12025.00 8861.57 82.06 126.67 62.81 277.01 1501.09 643.61 857.48 Pass 11644.34 9044.59 12050.00 8879.89 82.06 126.50 62.15 276.39 1482.05 644.45 837.60 Pass 11644.27 9044.59 12075.00 8898.22 82.07 126.33 61.48 275.75 1463.21 645.26 817.96 Pass ~i !~ 11644.19 9044.59 12100.00 8916.57 82.08 126.16 60.80 275.09 1444.58 646.02 798.56 Pass 11644.12 9044.60 12125.00 8934.93 82.08 125.98 60.09 274.42 1426.15 646.72 779.42 Pass ', 11644.04 9044.60 12150.00 8953.30 82.09 125.81 59.37 273.72 1407.93 647.38 760.55 Pass ', 11643.97 9044.60 12175.00 8971.67 82.10 125.64 58.63 273.01 1389.93 648.00 741.94 Pass 11643.90 9044.61 12200.00 8990.05 82.10 125.48 57.87 272.28 1372.15 648.56 723.59 Pass 1 1111643.84 9044.61 12225.00 9008.42 82.11 125.33 57.10 271.53 1354.59 649.08 705.52 Pass ~ 11643.77 9044.61 12250.00 9026.81 82.11 125.18 56.30 270.76 1337.29 649.52 687.78 Pass , ' 11643.70 9044.62 12275.00 9045.22 82.12 125.02 55.48 269.97 1320.26 649.86 670.40 Pass 11643.64 9044.62 12300.00 9063.63 82.13 124.86 54.65 269.16 1303.48 650.09 653.39 Pass ' 11643.56 9044.62 12325.00 9082.03 82.13 124.70 53.79 268.33 1286.97 650.21 636.77 Pass 1 11643.49 9044.63 12350.00 9100.44 82.14 124.54 52.91 267.48 1270.74 650.20 620.55 Pass '.11640.00 9044.79 12375.00 9118.85 82.45 116.37 50.57 266.54 1254.85 626.61 628.23 Pass 11640.00 9044.79 12389.00 9129.16 82.45 116.37 50.07 266.04 1246.05 626.77 619.27 Pass • rements are i N ~_ ~ 05-27B of bag BAG bttm of bag middle of blind/shear Blind/Shears TOTs of pipes/slip 2" combi ram/slips ~ ~ Mud Cross I I Mud Cross of flow cross pipe/slip 2 3/$" pipe/slip TOTs 2" pipe/slips Val Flow Tee Alaska Department of Natural Resources Land Administration System Page 1 of~ C • See Township, Range, Section and Acreage? Yes ~' No New Search I AS ~tle~r~a.~ I Case Abstract ~ Case Detail I l_ar-cl Abstract Isle: AllL 28329 ''°' ~ Search for Status Plat ll,r~clates ~~ ~~f I ~%10%2(108 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 21900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tyre: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS Tile Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2501.000 Dute Initiated: 05/28/1965 Office of Primary Responsibility: DOG D1V OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtl~~e: NS NORTH SLOPE Last Transaction: AA-NRB ASSTGNMF,NT APPROVED 1Il~rirfian. U Township: OION Pmts 11~ ri~llcm: U Totit lr.thi/~. 0 I ON llc'f'1L/[[lll: U 7011'll~/1(/7: O I ~1\ _11C'1'lC~ILlil: U 701111`/lll~_ ~ I ()ill Ra~a;~~': 015E Section: 0~ Range: 015E S'~~~~lu~rr. U6 Range: O1 ~i~: ~~-c'~h,ll.~ U Range: Ol SF S~~'~'tinn: I)R Legal Description (l~-?<Y-1)6~ ~~~°*,SALSA'OTIC'ELF_CIALDF'SC1ZlPTIOr~''`>,:~ C1-/-1>I TIU;V-XI~L'-Ci_11~,6.?,SZ~OLl10 C=3- Last updated on 12/10/2008. Section~lc~res: 640 Search Sectionllcre~: (i09 S!'~'liurr Acres: 612 1Sc'~untt 4cres: 640 http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=283... 12/10/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~` G • .., -~ ~ -~sr ~ .- ~,_ar i .r:,;, ~;~ Faa~s f~ecar~l~r`s Search State Cabins ~1~tu~ 3~t~E+~s Alaska DNR Case Summary File Type: ADL _ File Number: ___ 28326 ~- printable Case File_Summary See Township, Range, Section and Acreage? Yes ~' NO New Search t A8 Menu I Case Abstract I Case Detail I Land Abstract ,. File: ADL 2g32(i '``~~'`~' Search for Status Plat Updates Cz~sto~ner: 000]07377 BP E~PLOIATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tvpe: 784. OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUIJD Status Date: 09/14/1965 Total Acres: 2491.000 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 ASS IGNMENT APPROVED tleridian: U Township: 011 }z~n~,~~~.~ OISE 'Section: 2~~ SE:ctionAcres: (~-lU ~ Search. Plats Met°idian: I ~ 7ulrrttl~i~~: 0] IN Xangc~.~ 0l>L S'ec°tiuir: (1 _ti~-c'/iu~r ~(rf~~~~~: 60=~ 'l~c'i'1[ilU/l: I_I iUH~il.~'~11~7: O~ I ~ ~~U71,~rC.~ O I JI', ~e'C!I(~!!: > I ~C~'//U/7 :~C/'['1": O~)~ Jlc~r•iciiurr.~ l'~ 7~r~iti~~r~~{ri~~: 01 IN R~ul~~~~.~ (11>I=: ,ti~r~~lic~n: >? Sc°c~iuf~:Jcr~~s.~ G=AO Lc~;al Description 0~ -28-196 * * *SALE NOTICE LEGAL DESCRIPTlON* C'1-1-1~6 TIIN-RISE-UM29,30,31,3? 291.00 U- 3- 7 ~1°}/ Last updated on 12/10/2008. http://dnr.alaska. goy/projects/las/Case_Summary. cfm?FileType=ADL&FileNumber=283 ... 12/ 10/2008 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME PBL~ 0,5 ~ ~~ PTD# a?0~~9/ / Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~C'~ ~©~ ~ POOL: ~~~E ~Gcr,: ~~ 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 throu h tar et 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 (Companv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 / 11 /2008 'WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 05-278 Program DEV Well bore seg ^ PTD#:2081910 Company BP EXPLORATION (ALASKA) tNC Initial Classlfype DEV I PEND GeoArea 890 Unit 11650 On10ff Shore On Annular Disposal ^ Administration 1 Pe[mitfeeattached-- -- --- -- --- ---- - -- -- - ----- NA----- --- --- -- ---- - ----- ---- -- -- - ----- 2 Lease number appropriate----- ------- - -- --- ---- - Yes- --- -- - -- ----- ---- ----- - - -- ----- ---- 3 Uniquewell_nameandnumber---- ---- - - -- -- - ----- Yes- - -- -- -- - --- --- --- -- - -- --- 4 Welllgcatedin-a-defined-pal--- ---- -- - ----- ---- -- Yes- - -- -- -- -- -- - - ------ --- ----- -- - -- 5 INeIIlgcatedDroperdistanceftomdrillingunit_boundary-------------- ----------Yes---.-- ----------------------------------------------------------- ------ 6 Welllgcatedproperdistancefromgiherwells---- -- - ----- - --- Yes---- -------- -- ----- ------ --- -- - ----- ----- 7 Sufficient acreageayailableindnllingunb______________________ __________Yes______ _2569acre&.______--__.__-__- ------------------------------------------- 8 If deviated, isWellbgreplat-included_______-________________ __________ No______ _Be0.uestedwellpathdiagtam_12119101j._______________-___-_--__--___._-_______ 9 OperakorgnlyaffectedRarfY--- -- ----- --- - --- ----- -Yes --- ------------------------------ - -- - -- ----- - ---- - 10 Ops[atorhas-app[opriakebondinfgrge---------------------_ --------_-Yes------ -BlankeiBgnd#619416~•-------------------------------------.--------------- 11 Pe[mikcanbeissuedwithoutggnservatiengrder------------------ ----------Yes---.-- ----------------.----------------------------------- --------- ---- Appr Date 12 PetmitcaDl~issuedwithqutadminigtrafive_app[oYal--------------- ---------Yes----.- ----------------.---------------------------------------- ---- 13 Canpermit_beaRRrgvedbefgrQl4-daYvlait--- ----- --- -- - -- Yes- -- ----- --- --- - ------ -- ---- - - -- ------ ACS 1211012008 14 WelllgcatedwAhinareaandsfraiaauthgrizedbylnjegti9nOrder#(pu110#in- c9mments)_(Fqr-NA_______ ________________________________________--____---___-_____-__.___-__ 15 AllwelJswithinll4_mileafea_olreyiewidentified(Forservicewellgnly)_____ __________ NA_______ ____--____._________________________-------------------------------- 16 Pre~producedirtjeCtgr;~uratignofprepro~ugtignlessthan3mgnths_(Fgr_seNiceWellgnly)-- NA------- ------------------------------------------------------------------- 17 Nonconven, gas confgrrns tq AS31,05:03Q(j.1.A),(1.2.A•D) - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string_prgvided - - - - - - - - - - - - - - - - - - - - - - - - NA - - - - - Cgnductgrset-in DS 05-27 (189-1Q5a.- - - - - - - - - - - - - - - - - - - - - - Engineerln9 19 Su[face_casingprgtecisaltkngwn U$DWS--------------------- -----_--- NA-___-__ _Ngaquifers,AIQ4B,_Con~usion5.______________-___---------------__--- 20 CMT-voladequate_tgci[culate_on_cgnductq[&surf-csg____--__-___ ____-_____NA___.___ _Surfarecasingsetin DS 05.27__________________________________________________ 21 CMT-val adequafe_tq tie-in Igng siring to serf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ .Intermediate casing and_prgduction liner set Jn-O$ Q@-27. _ - _ _ _ _ - _ _ . _ _ _ _ - - _ _ _ _ _ - - _ _ _ _ _ _ _ _ _ 22 CMT_vrilJcoverallkngwn_prgductivehgri~qns-- -- ----- ----- -Yes - -- --- -- -- - - --- - -- -- ----- -- --- --- - ---- 23 Casing designs adequate forC,TB_&permafrost-_________-__-- ___-_._--Yes----- -------------------------------------------------------------------- 24 Adequate tankage_gr reserve pft _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ Rig equipped with steel pits. No-reserve pit planned._ AN waste_to approved disposal well(s), _ _ _ _ _ _ _ _ _ - _ _ 25 If-a-re-drill,has-a10_-403fgrabandgnmentheen aRRroved----------- ----------Yes----- --308,444-------------------------------------------------------------- 26 Adequate wellbore separatignproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Proximity analysis performed, Nearest segment is PttA pgrtion of DS 05.27A and paths diverge._ _ _ _ _ _ _ _ 27 Ifdiverter_raquifed,dgesJtmeetregulatigns--------------------- ---------NA----- --BQPStack_urill already-be inplaee,------------------------------------------- 28 Dulling fluid program schematic & equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - Maximum expected fo[matign pressure 7,0-EMW.- MW planned 6.5 pp9• _ _ _ _ - _ _ _ - - - _ _ _ _ _ _ _ _ _ _ Appr Date TEM 12!1512008 29 BOPES,_dotheymeetregulatign----------- -- --- -- -- ---Yes--- -- - -- - -- ------ ---- -- -- - ------- 30 BOPI=-press rating appropriate; leaf to-(put psig in cgmments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - _ _ _ _ _ MASP calculated at 230J3psi, 35Q0_psi_SOP testplanned. _ - - . _ - - _ _ _ _ _ - _ _ - - _ _ - _ _ _ - _ _ _ - _ _ 31 Chgke_manJfgldcgmpliesv~lAPI_RP-43 (May $4)-- -- -- -- - - --- Yes----- ------- ---- -- ---- -------- -- - -- -- ------ . 32 Wgrkwihoccurwithoutoperationshutdown_____-___-____--__- ______--.Yes----- --------------------------------------------------------------------- 33 Is presence.gf H?S gas Rrobable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ _ _ H2$ is reported_at DS 05.- Mud should preclude H2S_gn_rig: R~-has sensgrs and alarms._ _ - _ _ - . _ _ _ - _ _ _ _ 34 _Mechanical-condition ofwflllswithinAQRyerified(Forservicewellgnly~---- ---------- NA------ -----.--------------------------_------------------------------------ 35 Pe[mitcan be issued wlo trydrogen-sulfide measu[es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ No_ _ - _ _ Max level H2$ qn DS 45 is 27ppm_v(e1105-058 (1111!90)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 36 Data_plesented qn potential overpressure zgnes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -------------------------------------------------------------- Appr Date 37 Seismic.anarysisgfshalbwgas_zones- ---- ----- - -- -- -- --- -~- - --- -- -- -- ------ ----- --- - ------ ------ ACS 1211012008 38 SeabedcondJtionsurvey.(ifgff-shore)-- ---- ------ -- -- - - -- NA -- - -- -- -- ------- - --- - --- ----- ------- 39 Contactnamelphoneforlvsekry-prggressrepods_(exploratgrygnly]_____ __-______Yes_____ __$ean_McLaughlin_-_554-4387___________________-____-__--________--__._______ Geologic Commissioner Engineering Public Date: Commissioner: Date issioner Date . ~~~°~~ ~z~~ lo~.lZ•o~ Well- History File APPENDIX Information of detailed nature that is not i~J 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. ~ ~ **** REEL HEADER **** MWD 09/04/21 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/02/25 2466344 O1 2.375" CTK *** LIS COMMENT RECORD *** ~!!!!!!!!!!!~!!!!!! Remark File Version 1.000 !!!!!!!!!~~!!!!!!~! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 11300.0000: Starting Depth STOP.FT 13498.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration. (Alaska), Inc. WELL. WELL: 05-27B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 15' 46.621"N 148 deg 23' 48.327"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 25 Feb 2009 API API NUMBER: 500292197902 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 32 TOWN.N T11N RANG. R15E PDAT. MSL EPD .F 0 LMF DF FAPD.F 67 DMF DF EKB .F 0 . EDF .F 67 EGL .F 0 CASE.F N/A OSl DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) A11 depths are Measured Depths (MD) unless otherwise noted. ~b~r-l9 l !'~-~S~ l • • (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting. Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and depth shifting has been waived by Priya Maraj with BP Exploration (Alaska), Inc. The MWD data is the Primary Depth Control (PDC) log for well 05-27B. (8) The sidetrack was drilled from 05-27 through a milled window in a 4 1/2 inch liner. Top of window 11574 ft.MD (8978.7 ft.TVDSS) Bottom of window 11578 ft.MD (8979.7 ft.TVDSS) (9) Tied to 05-27 at 11566 feet MD (8978.7 feet TVDSS). (10) No logging data was acquired on INTEQ runs 1 through 3. (11) Open hole side track from 05-27BPB1 at 12140 ft MD (8981.9 ft TVDSS). (12) INTEQ runs 7 through 9 occured while drilling 05-27BPB1 and are not presented. (13) The interval from 13458 ft to 13498 ft MD (8980.6 ft to 8988.1 ft TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) (OHMM) (OHMM) (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 78 records... 10 bytes 132 bytes *** LIS COMMENT RECORD *** ~~!!!!~!!!!!!!~!!!! Remark File Version 1.000 The data presented here is final and depth shifting had been waived by Priya Maraj with BP Exploration (Alaska), Inc. the MWD data is the Primary Depth Control (PDC) log for well 05-27B. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 123 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 11300.000000 Tape File End Depth = 13498.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 136 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !~~~~~~~~~!~!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes C~ Logging direction is down (value= 2.55) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 245 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 11300.000000 Tape File End Depth = 13497.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 258 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/02/25 2466344 01 **** REEL TRAILER **** MWD 09/04/21 BHI 01 • Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes C~ Tape Subfile 1 is type: LIS • • Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 11300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11300.5000 102.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11400.0000 118.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11500.0000 110.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11600.0000 63.6000 86.2000 16.7190 17.4400 19.1280 20.4800 11700.0000 85.9000 64.3000 11.7310 11.4750 12.3660 11.5710 11800.0000 102.9000 32.2000 10.5150 10.3760 11.8810 11.9430 11900.0000 144.9000 84.2000 12.3970 13.8990 16.7830 18.1820 12000.0000 126.2000 32.2000 10.9130 12.9720 15.6510 16.8190 12100.0000 57.2000 123.8000 11.7750 13.0720 13.5700 12.7400 12200.0000 65.0000 86.4000 11.6460 14.7950 15.8350 15.6440 12300.0000 42.1000 78.6000 13.0540 16.1570 17.1090 17.5140 12400.0000 87.4000 110.9000 16.7580 22.5680 24.6390 24.1700 12500.0000 53.1000 141.3000 15.0650 18.7190 20.5810 21.1630 12600.0000 42.1000 105.2000 11.8080 13.3760 15.7740 15.9550 12700.0000 40.8000 131.8000 14.7340 20.8990 27.0510 29.1580 12800.0000 48.5000 119.3000 14.1080 16.9260 21.0870 23.1610 12900.0000 133.4000 63.7000 14.8080 17.4070 22.9230 26.0940 13000.0000 146.0000 58.7000 16.7580 20.5970 26.4880 29.0010 13100.0000 57.7000 86.7000 13.5390 15.9210 19.4770 20.7020 13200.0000 102.9000 44.0000 18.7610 28.1720 • 30.8990 31.1650 13300.0000 38.7000 132.8000 25.8090 24.9290 13400.0000 46.3000 80.3000 20.5260 20.1480 13498.0000 0.0000 0.0000 0.0000 0.0000 Tape File Start Depth = 11300.000000 Tape File End Depth = 13498.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • 18.2700 17.3720 0.0000 25.7040 19.6000 0.0000 • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 11300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11300.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11400.0000 118.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11500.0000 110.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11600.0000 63.6000 86.2000 16.7190 17.4400 19.1280 20.4800 11700.0000 85.9000 64.3000 11.7310 11.4750 12.3660 11.5710 11800.0000 102.9000 32.2000 10.5150 10.3760 11.8810 11.9430 11900.0000 144.9000 84.2000 12.3970 13.8990 16.7830 18.1820 12000.0000 126.2000 32.2000 10.9130 12.9720 15.6510 16.8190 12100.0000 57.2000 123.8000 11.7750 13.0720 13.5700 12.7400 12200.0000 65.0000 86.4000 11.6460 14.7950 15.8350 15.6440 12300.0000 42.1000 78.6000 13.0540 16.1570 17.1090 17.5140 12400.0000 87.4000 110.9000 16.7580 22.5680 24.6390 24.1700 12500.0000 53.1000 141.3000 15.0650 18.7190 20.5810 21.1630 12600.0000 42.1000 105.2000 11.8080 13.3760 15.7740 15.9550 12700.0000 40.8000 131.8000 14.7340 20.8990 27.0510 29.1580 12800.0000 48.5000 119.3000 14.1080 16.9260 21.0870 23.1610 12900.0000 133.4000 63.7000 14.8080 17.4070 22.9230 26.0940 13000.0000 146.0000 58.7000 16.7580 20.5970 26.4880 29.0010 131.00.0000 57.7000 86.7000 13.5390 15.9210 19.4770 20.7020 13200.0000 102.9000 44.0000 18.7610 28.1720 s 30.8990 31.1650 13300.0000 38.7000 132.8000 25.8090 24.9290 13400.0000 46.3000 80.3000 20.5260 20.1480 13497.7500 -999.2500 39.6000 -999.2500 -999.2500 Tape File Start Depth = 11300.000000 Tape File End Depth = 13497.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • 18.2700 17.3720 -999.2500 25.7040 19.6000 -999.2500 -...~ Tape Subfile 4 is type: LIS i **** REEL HEADER **** MWD 09/05/20 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/02/21 2466344 01 2.375" CTK *** LIS COMMENT RECORD *** ~!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!~!~! Extract File: ldwg.las Version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 11300.0000: Starting Depth STOP.FT 13206.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 05-27BPB1 FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 15' 46.621"N 148 deg 23' 48.327"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 21 Feb 2009 API API NUMBER: 500292197970 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 32 TOWN.N T11N RANG. R15E PDAT. MSL EPD .F 0 LMF DF FAPD.F 67 DMF DF EKB .F 0 EDF .F 67 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) A11 Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log from well 05-27B above the Kick Off Point (KOP) of 12140 feet MD; carrying the final shift from the KOP to the bottom logged interval per Priya Maraj with BP Exploration (Alaska), Inc. (8) No logging data was acquired on INTEQ runs 1 through 3. (9) The sidetrack was drilled from 05-27 through a milled window in a 4 1/2 inch liner. Top of window 11573 ft.MD (8978.7 ft.TVDSS) Bottom of window 11578 ft.MD (8979.7 ft.TVDSS) (10) Tied to 05-27 at 11566 feet MD (8978.7 feet TVDSS). (11) The interval from 13167 feet to 13207 feet MD (8979.7 feet to 8972.2 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) (OHMM) (OHMM) (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected TVDSS -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 11303.5, 11303.3, ! -0.176758 11305.1, 11304.9, ! -0.175781 11307.5, 11307.9, ! 0.352539 11310.9, 11310.9, ! 0 11312.3, 11311.9, ! -0.352539 11313.2, 11313.4, ! 0.175781 11316.9, 11316.9, ! 0 11318.5, 11318.6, ! 0.175781 11320.6, 11320.6, ! 0 11322.2, 11321.6, ! -0.52832 11323.4, 11323.2, ! -0.176758 11328.2, 11328.2, ! 0 11332.1, 11331.9, ! -0.176758 11337.5, 11337.5, ! 0 11342.3, 11342.5, ! 0.175781 11344.6, 11344.6, ! 0 11349, 1 1348.6, ! -0.352539 11361.2, 11361.2, ! 0 11368.4, 11368.2, ! -0.176758 11373.3, 11373.3, ! 0 11386.6, 11386.9, ! 0.352539 11392.2, 11392, ! -0.175781 11395.4, 11395.6, ! 0.176758 11401, 1 1401.4, ! 0.353516 11409.8, 11410.2, ! 0.353516 11418.1, 11418.1, ! 0 11420.6, 11420.4, ! -0.176758 11427.6, 11427.4, ! -0.176758 11429.4, 11429.6, ! 0.176758 11434.9, 11434.7, ! -0.176758 11440.2, 11440.2, ! 0 11442.1, 11441.8, ! -0.352539 11446.9, 11446.9, ! 0 11448.1, 11447.9, ! -0.175781 11450, 11449.9, ! -0.176758 11457.4, 11457.3, ! -0.175781 11459, 11459, ! 0 11466.5, 11466.5, ! 0 11469.7, 11469.7, ! 0 11472.9, 11472.9, ! 0 11475.7, 11475.5, ! -0.175781 11479.6, 11479.6, ! 0 11481.9, 11481.9, ! 0 11491, 11490.8, ! -0.175781 11494.2, 11493.8, ! -0.352539 11499.1, 11499.1, ! 0 11502.1, 11501.9, ! -0.175781 11509.3, 11509.3, ! 0 11512.5, 11512.5, ! 0 11519.6, 11519.6, ! 0 11523.6, 11523.6, ! 0 11527.5, 11527.3, ! -0.175781 11530.5, 11530.3, ! -0.176758 11534.9, 11534.9, ! 0 11547, 11547.4, ! 0.352539 11552.9, 11552.9, ! 0 11557.8, 11557.8, ! 0 11564.2, 11564, ! -0.176758 11566.6, 11566.6, ! 0 11570.3, 11570.1, ! -0.176758 11576, 11576, ! 0 11578.4, 11578.4, ! 0 11581, 11580.5, ! -0.52832 11584.9, 11584.7, ! -0.176758 11588, 11588.2, ! 0.176758 11597.3, 11597.2, ! -0.176758 11606.2, 11606.2, ! 0 11618.3, 11618.3, ! 0 11630.5, 11630.1, ! -0.353516 11633.9, 11634, ! 0.176758 11644, 11644, ! 0 11656.6, 11656.6, ! 0 11664.3, 11664.3, ! 0 11668.7, 11668.6, ! -0.176758 11674, 11674.2, ! 0.175781 11685.6, 11685.6, ! 0 11687.9, 11688.1, ! 0.175781 11692.2, 11692.2, ! 0 11720.1, 11719.9, ! -0.175781 11745.1, 11745, ! -0.175781 11753.8, 11753.6, ! -0.176758 11758, 11758.2, ! 0.176758 11782.4, 11782.4, ! 0 11786.3, 11786.1, ! -0.175781 11796.1, 11796, ! -0.176758 11803.3, 11803, ! -0.352539 11809.2, 11809.2, ! 0 11815, 1 1815.2, ! 0.175781 11820.1, 11819.9, ! -0.175781 11825.2, 11825, ! -0.176758 11829.3, 11829.1, ! -0.175781 11836, 1 1836, ! 0 11853.8, 11853.6, ! -0.176758 11857.9, 11857.9, ! 0 11862.6, 11862.3, ! -0.352539 11867.7, 11867.6, ! -0.175781 11883.3, 11883.3, ! 0 11894.3, 11894.5, ! 0.176758 11901.2, 11901.2, ! 0 11908, 11 908.2, ! 0.176758 11913.5, 11913.7, ! 0.175781 11929.5, 11929.3, ! -0.175781 11933.7, 11933.7, ! 0 11936, 11 935.9, ! -0.175781 11939.6, 11939.6, ! 0 11946.1, 11946.1, ! 0 11952.1, 11951.9, ! -0.176758 11956.1, 11956.1, ! 0 11965.5, 11965.3, ! -0.175781 11968.3, 11968.5, ! 0.176758 11976.2, 11976.2, ! 0 11980.2, 11980.2, ! 0 11991.6, 11991.1, ! -0.52832 11996.4, 11996.7, ! 0.352539 12001.5, 12001.2, ! -0.352539 12007.5, 12007.5, ! 0 12020.2, 12020, ! -0.175781 12044, 12044, ! 0 12064.5, 12065.2, ! 0.705078 12083.3, 12083.7, ! 0.352539 12091.8, 12091.9, ! 0.176758 12113.6, 12113.4, ! -0.175781 12119.4, 12119.3, ! -0.176758 12126.6, 12128.2, ! 1.58789 12134.3, 12134.7, ! 0.352539 12140.2, 12139.1, ! -1.05859 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 203 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from well 05-27B above the Kick Off Point (KOP) of 12140 feet MD; carrying the final shift from the KOP to the bottom logged interval per Priya Maraj with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-ty pe is: 1 FRAME SPACE = 0. 500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 106 Tape File Start Depth = 11300.000000 Tape File End Depth = 13206.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 119 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!~!~!~!~~~~~!!~!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE _ ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD x.250 * F Code Samples Units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 212 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 11299.750000 Tape File End Depth = 13207.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 225 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/02/21 2466344 Ol **** REEL TRAILER **** MWD 09/05/20 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS • • Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 11300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11300.5000 102.9728 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11400.0000 115.8108 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11500.0000 110.2665 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11600.0000 68.1078 86.1725 16.6229 17.3924 19.1073 20.4333 11700.0000 89.1634 60.2687 11.7482 11.5280 12.3505 11.5560 11800.0000 105.6552 43.4139 10.5218 10.3657 11.8579 11.8934 11900.0000 140.5574 74.3924 12.3929 13.9101 16.7830 18.1869 12000.0000 128.7047 32.0601 10.9099 12.9798 15.6510 16.8355 12100.0000 58.7926 123.2192 11.7746 13.0716 13.5700 12.7421 12200.0000 61.1982 88.4189 11.6695 13.4388 13.5700 12.7682 12300.0000 128.4385 145.0402 11.9110 12.4909 14.3180 14.7450 12400.0000 76.1574 241.8617 11.4143 13.0657 14.4750 14.9180 12500.0000 74.5260 26.6484 11.0660 11.3510 13.1500 13.7670 12600.0000 65.7018 114.4793 11.6608 13.7779 15.6510 16.7778 12700.0000 151.6846 155.4428 14.9895 18.4011 20.1474 20.3639 12800.0000 91.2397 53.8799 12.9529 13.8896 15.9987 16.6180 12900.0000 81.4289 158.4822 10.5039 11.0149 12.7649 13.1700 13000.0000 70.8420 104.4303 12.1025 13.7674 14.4770 14.0870 13100.0000 79.1994 152.4951 12.4900 12.8254 13.0376 12.4964 13200.0000 -999.2500 98.1650 -999.2500 -999.2500 -999.2500 13206.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 11300.000000 Tape File End Depth = 13206.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • -999.2500 -999.2500 • • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 11299.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11400.0000 111.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11500.0000 110.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11600.0000 67.6000 86.2000 16.7190 17.4400 19.1280 20.4800 11700.0000 89.5000 58.9000 11.7310 11.4750 12.3660 11.5710 11800.0000 104.2000 32.2000 10.5150 10.3760 11.8810 11.9430 11900.0000 140.5000 74.5000 12.3970 13.8990 16.7830 18.1820 12000.0000 129.6000 32.2000 10.9130 12.9720 15.6510 16.8190 12100.0000 58.8000 123.8000 11.7750 13.0720 13.5700 12.7400 12200.0000 63.5000 84.1000 11.6440 13.3800 13.5700 12.7400 12300.0000 129.7000 55.3000 12.0490 12.6060 14.4750 15.0940 12400.0000 82.8000 97.8000 11.4310 12.9520 14.3180 14.7450 12500.0000 82.1000 65.1000 11.0280 11.3510 13.1500 13.6130 12600.0000 63.7000 112.1000 11.5620 13.6440 15.5730 16.7280 12700.0000 143.0000 172.5000 16.7800 19.9610 20.5240 21.2580 12800.0000 91.7000 54.7000 12.9090 13.7250 16.0170 16.6180 12900.0000 74.8000 161.3000 10.4480 11.1110 12.7510 13.0250 13000.0000 70.7000 119.6000 11.8680 14.0650 14.4770 14.0870 13100.0000 82.6000 137.4000 12.2060 12.0680 12.7020 12.1540 13200.0000 -999.2500 124.1000 -999.2500 -999.2500 • • -999.2500 -999.2500 13207.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 11299.750000 Tape File End Depth = 13207.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet n LJ n Tape Subfile 4 is type: LIS