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Home My WebLink About208-1487. 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 18-06B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-148 50-029-20797-02-00 10945 Surface Intermediate Liner Liner Liner 8683 2484 8288 353 681 2431 10906 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" 3-3/16" x 2-7/8" 8682 33 - 2517 32 - 8320 8022 - 8375 7932 - 8613 8511 - 10942 33 - 2517 32 - 8121 7823 - 8409 7733 - 8408 8310 - 8682 8508, 10892, Unknown, 10895 2670 4760 7020 7500 10530 None 5380 6870 8160 8430 10160 8360 - 10900 4-1/2" 12.6# L-80 29 - 7935 8161 - 8681 Conductor 80 20" 34 - 114 34 - 114 1490 470 4-1/2" Baker S3 Packer 7880 7681 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028321, 0028307 29 - 7736 N/A N/A 266 251 3620 6242 3934 6508 1550 1000 242 232 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 7880, 7681 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 12:41 pm, Jul 24, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.07.24 12:22:23 - 08'00' Bo York (1248) DSR-7/24/25 RBDMS JSB 073125 JJL 8/12/25 ACTIVITY DATE SUMMARY 6/29/2025 ***WELL S/I ON ARRIVAL*** (DRIFT / PERFORATE) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH. DRIFT w/ 2-7/8" X 10' DUMMY GUN TO 8498'. PERFORATING 8360' - 8361' w/ 2-7/8" GEO RAZOR, 6 SPF, 60 DEGREE PHASE GUN. LOG CORRELATED TO SLB RST LOG DATED 29-AUG-2011. ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 18-06B 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 18-06B Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-148 50-029-20797-02-00 10945 Surface Intermediate Production Liner Liner 8683 2484 8288 353 681 2431 10906 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" 3-3/16" x 2-7/8" 8682 33 - 2517 32 - 8320 8022 - 8375 7932 - 8613 8511 - 10942 33 - 2517 32 - 8121 7823 - 8409 7733 - 8408 8310 - 8682 10892 , unknown , 10895 2670 4760 7020 7500 10530 none 5380 6870 8160 8430 10160 8994 - 10900 4-1/2" 12.6# L-80 29 - 7935 8675 - 8681 Conductor 80 20" 34 - 114 34 - 114 1490 470 4-1/2" Baker SABL-3 , 7880 , 7681 No SSSV 7880 7681 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028321 , 0028307 29 - 7736 222 271 3714 3621 2963 4046 0 0 332 242 323-579 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 9:38 am, Dec 28, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.12.28 07:13:49 - 09'00' Bo York (1248) RBDMS JSB 122823 WCB 5-10-2024 DSR-1/26/24 ACTIVITYDATE SUMMARY 11/29/2023 SLB CTU #9 - 1.75" CT - .156" WT Job Scope = Depth Control Log, 3'x Extended Add Perf Runs Start Travel back to 18-06B @ 0430. Complete weekly BOP test. MU NS MHA and HES memory gamma/CCL tool and 2.25" drift nozzle. RIH. ***Job Continued on 11/30/23*** 11/30/2023 SLB CTU #9 - 1.75" CT - .156" WT Job Scope = Depth Control Log, 3'x Extended Add Perf Runs ***Job continued from 11/29/23*** RIH with drift/memory logging tool and 2.25" nozzle. Opened up to 0 psi, pumped 17 bbls of 60/40 meth with no WHP change. Drift to 10300 ctmd clean. Log up to 9500 clmd and paint blue coil flag. Log up to 9200 ctmd. POOH. OE Agrees with +10' Correction. PT Safety Joint. 342/3530 psi. Load well with 210 bbls KCL @ 4 bpm. RIH with 1st Set of Perf Guns, 2" HES MaxF, 60 deg Phase, 6 SPF, 378' Loaded. Shoot Holes at 9584' - 9962'. POOH, maintain hole fill. AT surface rig gun #1 down and Deploy gun #2 ***Job Continued 12/1/23*** 12/1/2023 SLB CTU #9 - 1.75" CT - .156" WT Job Scope = Depth Control Log, 3'x Extended Add Perf Runs ***Job continued from 11/30/23*** RIH with 2nd Set of Perf Guns, 2" HES MaxF, 60 deg Phase, 6 SPF, 282' Loaded. Shoot Holes at 9190' - 9472'. POOH, maintain hole fill. PU and RIH with 3rd set of Perf Guns, 2" MaxF, 60 deg Phase, 6 SPF, 107' Loaded. Shoot Holes at 8995' - 9102'. POOH, maintain hole fill. LD Guns, All balls recovered. RI with FP JSN 2.42". Swap well over to Diesel from 8000' CTMD for underbalance. 107 bbls diesel pumped. POOH. Rig down. ***Job Continued 12/2/23*** 12/2/2023 LRS Well Testing Unit #1, Begin WSR on 12/2/23 @ 0700 HRS, Unit Move, Post Extended Adperf Well Pop. RU, PT, IL Well 18-06, OL Well 18-23. Continue WSR on 12/03/23. 12/2/2023 SLB CTU #9 - 1.75" CT - .156" WT Job Scope = Depth Control Log, 3'x Extended Add Perf Runs ***Job continued from 12/1/23*** RDMO. ***Job Complete*** 12/3/2023 LRS Welltesting Unit #1. Continue WSR from 12/02/23. Standby for Post Adperf Well Pop on 18-06, IL Well 18-06, OL Well 18-23. STBY for DSO to backflow 18-06. Continue WSR on 12/04/23. 12/4/2023 LRS Welltesting Unit #1. Continue WSR from 12/03/23. Post Adperf Well Pop on 18- 06. IL Well 18-06, OL Well 18-23. Continue Drawdown and Flow to tanks. Job Complete. Daily Report of Well Operations PBU 18-06B Shoot Holes at 9584' - 9962'. POOH, Shoot Holes at 8995' - 9102'. POOH Shoot Holes at 9190' - 9472'. POOH 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 18-06B Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-148 50-029-20797-02-00 ADL 0028321 10945 Surface Intermediate Production Liner Liner 8683 2484 8288 353 681 2431 10906 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" 3-3/16" x 2-7/8" 8682 33 - 2517 32 - 8320 8022 - 8375 7932 - 8613 8511 - 10942 2470 33 - 2517 32 - 8121 7823 - 8409 7733 - 8408 8310 - 8682 10892 , unknown , 10895 2670 4760 7020 7500 10530 none 5380 6870 8160 8430 10160 10060 - 10900 4-1/2" 12.6# L-80 29 - 79358679 - 8681 Conductor 80 20" 34 - 114 34 - 114 1490 470 4-1/2" Baker SABL-3 No SSSV 7880 7681 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 11-1-2023 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 12:16 pm, Oct 23, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.10.20 19:28:39 - 08'00' Bo York (1248) 323-579 Perforate CO 341J SFD SFD 10/23/2023 DSR-10/24/23 , ADL0028307 SFD 10-404 MGR01NOV23&': Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.11.01 15:09:32 -08'00'11/01/23 RBDMS JSB 110223 Ext Perf Procedure 18-06B PTD:208 148 Well Name:18-06B extended add perf API Number:50-029-20797-02-00 Current Status:Offline Uncompetitive Rig:CTU Estimated Start Date:11/1/2023 Estimated Duration:1day Regulatory Contact:Carrie Janowski Permit to Drill Number:208-148 First Call Engineer:David Bjork (907) 440-0331 (c) Second Call Engineer: AFE Number:Cost / IOR Current Bottom Hole Pressure:3,350 psi @ 8,800’ TVD 7.4 PPGE (offset producer 18-14C) Max. Anticipated Surface Pressure:2,470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 2150psi (Taken on 1/25/2020 DHD) Min ID:2.36” liner top @ 8,508’ MD Max Angle:93 Deg @ 9,933’ Reference Log: LeeGR/CCL SLB 18-Nov 2014 Brief Well Summary: 1998 sidetrack in fair shape. Uncompetitive and dies off. A plug set in 2014 before GCWI arrived was milled out in August of 2022. Production did not increase. Objective: The objective of this procedure is to add Z1A perforations (107ft) and reperf additional Z1A (282ft and 378ft) that was squeezed in 2013. The perforating will be conducted in 3 runs. Procedure: Coiled Tubing x Notes: 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 Note: The well will be killed and monitored before making up the initial perfs guns. 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. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. 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. 3. Bullhead 200 bbls of KWF, 8.4 ppg 1% KCl or 8.5 ppg down the tubing to the formation. (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 = 145.4 bbls b. 4-1/2” Tubing - 8,508’ x .0152bpf = 130 bbls c. 3-1/2” Liner - 84’ x .0087bpf = 0.7 bbls d. 3-3/16” Liner – 766’ x 0.0076bfp=5.8bbls e. 2-7/8” Liner – 1,542’ x 0.0058bfp= 8.9bbls 4. MU and RIH with drift BHA to resemble 2” dmy gun. Run past 9,962’ctmd and POOH. MU and RIH with logging tools and log OOH. 5. POOH and confirm good data. Ext Perf Procedure 18-06B PTD:208 148 6. Freeze protect tubing as needed. 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 continuous hole fill taking returns to tank until lubricator connection is reestablished. 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 gunsandblanksperschedule below. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 18-06B Addperf Schedule *HES 2” (5.58ppf) maxforce guns were used to estimate for this job. 2.193” gun swell 11. MU lubricator and RIH withperf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. POOH. 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 dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. RBIH to 8,000ft and swap the wellbore to diesel ~ 120bbls. 16. RDMO CTU. 17. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic Perf Interval Perf Length Gun Length Weight of Gun (lbs) 9,584’-9,962’ 9,190’ – 9,472’ 8,995’ – 9,102’ 378’ 282’ 107’ 378’ 282’ 107’ 2,110lbs 1,573lbs 598lbs Assure overbalance. - mgr Ext Perf Procedure 18-06B PTD:208 148 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Mini Log 7. Tie In Log/Perf Sheet 8. Sundry Change Form Ext Perf Procedure 18-06B PTD:208 148 Current Wellbore Schematic Ext Perf Procedure 18-06B PTD:208 148 Proposed Schematic Ext Perf Procedure 18-06B PTD:208 148 Coiled Tubing BOPs Ext Perf Procedure 18-06B PTD:208 148 Standing Orders for Open Hole Well Control during Perf Gun Deployment Ext Perf Procedure 18-06B PTD:208 148 Equipment Layout Diagram Ext Perf Procedure 18-06B PTD:208 148 18-06B Mini Log Ext Perf Procedure 18-06B PTD:208 148 18-06B Tie-In Log Ext Perf Procedure 18-06B PTD:208 148 Ext Perf Procedure 18-06B PTD:208 148 Ext Perf Procedure 18-06B PTD:208 148 Ext Perf Procedure 18-06B PTD:208 148 Ext Perf Procedure 18-06B PTD:208 148 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 HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date By Anne Prysunka at 1:33 pm, Aug 12, 2022 • ® 20 81 48 BA ER 2 9 1 6 8 UGHES PRINT DISTRIBUTION LIST a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 WELL NAME 18-06B 900 E. Benson Blvd. Anchorage,Alaska 99508 or AKGDMINTERNAL@bp.com FIELD PRUDHOE BAY UNIT to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska --- LOG DATE March 22,2018 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(@.bhge.com TODAYS DATE April 25,2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF NKIN I S #OF COPIES #OF COPIES #OF COPIES J U U U v U 1 BP North Slope. 0 1 1 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aides Attn:Benda Glassmaker&Peggy O'Neil 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99501 3 ExxonMobil,Alaska 0 0 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 333 W.7th Ave,Suite 100 �_�/n . , . 44(n /ce Anchorage,Alaska 99501 !� L MOP 5 DNR-Division of Oil&Gas *** 0 0 1 0 Attn:Garret Brown 550 West 7th Avenue,Suite 1100 RECEIVED Anchorage,Alaska 99501 I•*Stamp"confidential"on all material deliver to DNR r MOP 6 2018 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,1R2-1 900 E.Benson Blvd. AOGCC Anchorage,Alaska 99508 Attn:Gerardo Cedillo f TOTALS FOR THIS PAGE: 0 2 5 0 0 Ima a Pro'ect Well History File Cove~age 9 J XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~ - ~~ ~ Well History File Identifier Organizing (done) RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES „~.„a uiuiuiuiiuiii DI TAL DATA Diskettes, No, ~' ^ Other, No/Type: „o~~~d~ iuumuiiuuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ~ /s/ I I Pro'ect Proofin III II~III IIIII II III 1 g gY: Maria Date: ~ /s/ Scanning Preparation __,~, x 30 = ~ + ~ ~ =TOTAL PAGES ~~ (Count does not include cover sheet) BY: Maria Date:. ~/ /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: a S ~~ /s/ 1 " ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO Y BY: Maria Date: /s/ nnin is com lete at this Dint unless rescanning is required. 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U = G O 0000000000000000000: r rrrrrrrrrrrrrrrrrrrr WW 0000000000000000000g W W W W W W W W W W W W W W W W W W W W 0 00000000000000000 000 0000000000000w a000000 V' . . .. . JJJJJ J J J . . . . . .. Z 2 o> ronao►ao ' � r C4 :::2 0t; .- 1 - . N a 0002C09010002oa00000 0 O 0, 999'x94$9 =q= Y 'r91. g9999 m a, nr O 33Z(D 7?Z0Z0 -iv�)Omx0 'a7 w m aammaao0E0E0000000 <mm o cj O 0 m J e? ce 0 C 0 • Z N 0 W Y N COMA = N U Z O ` a CO na ✓ - NVNVNvaNN_ Q N ' QQ MQQR DI !ms N COt m 'C c E ,ma, W IDE m AM Y U' O r N X Y V 0 .0 = z 222 a W O W eal W O Q NQQ -.1t amo_ rn • • STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 0 SET Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ CIBP Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 10000' 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 208-1480 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API N tuber: ~ Anchorage, AK 99519-6612 50-029-20797-02-00 8. Property Designation (Lease Number) : ~ ~y~ 9. Weil Name and Number: ADLO-028321 ~ ~ (~ ~~~/('~ ~PBU 18-O6B 10, Field/Pool(s): ~, PRUDH OE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10945 feet Plugs (measured) 10000' 7/19/10 feet true vertical 8682.84 feet Junk (measured) None feet Effective Depth measured 10906 feet Packer (measured) 7880 7932 8492 true vertical 8681.56 feet (true vertical) 7681 7733 8292 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 91.5# H-40 SURFACE - 79 SURFACE - 79 1490 470 Surtace 2517 13-3/8" 72# L-80 SURFACE - 2517 SURFACE - 2517 4930 2670 Intermediate 8320 9-5/8" 47# L-80/S095 SURFACE - 8320 SURFACE - 8121 8150 5080 Production 353 7" 29# L-80 8022 - 8375 7823 - 8176 8160 7020 Liner 681 4-1/2" 12.6# L-80 7932 - 8613 7733 -8409 8430 7500 Liner 2431 3-1 /2"/3-3-16"/2-7/8" 8511 - 10942 8311 - 8683 ~ 4 ~ ~ s , a ~ ~ 9.2#/6.2#/6.16# L-80 ~t.~~~~„ >~'a~ ~+ ', _ . ~_ Perforation depth: Measured depth: SEE ATTACHED - _ _ - True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# LL-80 O - 7935 0 - 7736 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X4-1/2" BKR S-3 PKR 7880 7681 9-5/8"X7" BKR ZXP LNR PKR 7932 7733 4-1/2" BKR KB PKR 8492 8292 12. Stimulation or cement squeeze summary: ~~~ Intervals treated (measured): Treatment descriptions including volumes used and final pressure: fission 13. Representative Daily Average Producti n to Oii-Bbl Gas-Mcf Water-Bbl Casin Tubing pressure Prior to well operation: 751 39073 0 1244 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 7/27/2010 Form 18-06B 208-148 PERF ATTOr_HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18-06B 10/29/08 PER 9,190. 9,480. 8,680.61 8,681.01 18-066 10/29/08 PER 9,570. 9,940. 8,681.3 8,679.4 18-06B 10/29/08 PER 10,060. 10,280. 8,679.37 8,681.09 18-06B 10/29/08 PER 10,420. 10,900. 8,681.3 8,681.36 18-06B 7/19/10 BPS 10,000. 10,060. 8,678.72 8,679.37 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE u • • • 18-06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/16/2010CTU 8 1.75" CT: Job Scope: Set CIBP. «<InterAct is publishing»> Move from A pad to DS 18. Rig up on DS 18-06. RIH w/ SLB GR/CCL logging tools. Unable to !get past liner top packer @ 8511' POOH straighten coil still unable to get past liner ;top packer. POOH fora 1.75" nozzle and knuckle joint. «<Job in progress»> 7/17/2010; CTU 8 1.75" CT: Job Scope: Log & Set CIBP. Continue WSR from?/16/10 «<InterAct is publishing»> Unable to get past liner top packer at 8511' P/U knuckle joint and smaller nozzle. Still unable to get past liner top packer .Called baker for fishing BHA to pull liner top packer. Cvt 150' of coil for pipe management. I RIH with BOT fishing assembly which includes oil jar and 4" GS hydraulic release spear. Set down and retreive fish. At surface The bottom two seal on the KB packer looked like they were stung in but the third seal was swollen appears not to `be stung in all the way. make up SLB GR/CCI. Unable to get into liner RIH w / ``,veturijunk basket. «<Job in progress»> 7/18/2010; CTU 8 1.75" CT: Job Scope: Log & Set CIBP. Continue WSR from?/17/10 w.. «<InterAct is publishing»> Still unable to get into liner top. RIH w / 3.13" venturi ;junk basket. Venturi came back clean. RIH w/ BOT motor and 2.30" diamond ;parabolic mill. Mill from 8499 to 8501.4. Pass through milled area 4x with no issues. ;Dry drift down to 10,200'. Make up GR/CCI log from 10200'to 9200' flag pipe @ 10030'.Good DATA from log. RIH w Halliburton 2.18" CIBP «<Job in progress»> ~~ 7/19/2010 CTU 8 1.75" CT: Job Scope: Set CIBP.~Continue WSR from?/18/10 «<InterAct is ;publishing»> RIH w / Halliburton 2.18" CIBP. Set CIBP @ 10000' PUH set back ;down on plug 2 k down to confirm it set. Freeze pro ect well w / 38 bbls of 60/40 Methanol.«<Job is complete»> FLUIDS PUMPED BBLS 220 1 % KCL 38 60/40 METH 258 Total TREE = CMI WELLHEAD CNU ,ACTUATOR BAKER C KB. ELEV = 53.38' BF. ELEV = ~ NA KOP = 3000' Max Angle = 93° @ 9933' 'Datum MD = N/A Datum TV D = 8800' SS SAFETY N :WELL ANGLE > 70° @ 8950'. 1 ~ ~ ~ ~ BEL W WHI STOCKAWELLBORES NOT SHOWN 2222' 4-1/2" CAMCO BAL-O SVLN , ID = 3.812" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2517' Minimum ID = 2.37" @ 9358' 3-3116" X 2-718" XO 4-112" TBG, 12.6#, L-80 IBT, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-60, ID = 8.681" 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: LWD BHI ON 10/25/2008 ANGLE AT TOP PERF: 88° @ 9190' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9190 - 9480 O 10/29/08 2" 6 9570 - 9940 O 10(29/0$ 2" 6 10060 - 10280 O 10/29/08 2" 6 10420 - 10900 O 10/29/08 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2971 2969 10 CA-MMG DOME RK 16 11/07/08 2 5320 5199 20 GA-MMG SO RK 20 11/07/08 3 7092 6895 6 CA-MMG DMY RK 0 11!23!05 4 7731 7532 3 CA-MMG DMY RK 0 11/23/05 i9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 7932' -~ 9-5/8" X 7" BKR ZXP LNR PKR, ID = 6.313" 7935' - 4-112" WLEG, O = 3.958" 7946' 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.187" 7952' 7" X 4-1/2" XO, ~ = 3.958" 8022' 9-5/8" X 7" BKR LNR HGR ~~ 7" MILLOUT WINDOW (18-06A) 8375' - 8400' I 4-1/2" MILLOUT WINDOW {18-O6B) 8613' - 8622' 492' SLM 4-1/2" BKR KB PKR, ID = 2.35" (12/11/08) 8492' 4-1/2" HES X NIP, ID = 3.813" 8511' 3.70" BTT DEPLOYMENT SLV w /4" G~ PROFILE, ID = 3.00" I 7935' I 3-1/2" X 3-3/16" XO, ID = 2.786" 3-112" LNR, 9.2#, L-80 STL, .0087 bpf, ID = 2.995" ~ 8592' 4-112" WHIPSTOCK 8612' __ ~ 4-1i2" LNR,12.6#, L-80, .0152 bpf , ID = 3.958" 8612' 9: RA TAG 8622' 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" 9358' PBTD ,,,,,,,,,,,,,,10906',,,,,,,,,,, 2-718" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 10942' DATE REV BY COMMENTS DATE 09!13!82 ORIGINAL COMPLETION 10/07/85 RWO 01/10/98 SIDETRACKCOMPLETION 10/29!08 NORDIC 1 CTD SIDETRACK (18-O6B) 11!04/09 MR/JMO DRLG DRAFT CORRECTIONS 11/05!09 NS/JMD SET KB PKR (12111/08) 3-3/16" X 2-718" XO, ID = 2.370" I 7~~1~0 PRUDHOE BAY UNIT WELL 18-06B PERMIT No: "r2081480 API No: 50-029-20797-02-00 SEC 24, T11 N, R14E, 835' FNL & 251' FEL BP 6cploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 2/23/2010 Permit to Drill 2081480 Well Name/No. PRUDHOE BAY UNIT 18-O6B Operator BP EXPLORATION (ALASF(ly INC API No. 50-029-20797-02-00 MD 10945 TVD 8683 Completion Date 10/29/2008 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 DIR / GR / RES, GR / CL / CNL Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / ryp~_ mea~rrmt D~umner Name _ _ scale meaia No Start Stop cH Received Comments D D Asc ~ Directional Survey 8598 10945 Open 11/10/2008 I pt Directional Survey 8598 10945 Open 11/10/2008 t; .l~ C Lis 17376~utron 8005 10907 Case 12/31/2008 LIS Veri, GR, CNT ~g Neutron 5 Blu 8000 10892 Case 12/31/2008 MCNL, Lee LTTN, GR, CCL 28-Oct-2008 pt LIS Verification 9291 10940 Open 1/20/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS ~~ C Lis 17485vlnduction/Resistivity 9291 10940 Open 1/20/2009 LIS Veri, GR, ROP, RAD, ~ RAS, RPD, RPS ~ ~LOg Induction/Resistivity 25 Col 8613 10945 Open 1/20/2009 MD MPR, GR 25-Oct-2008 jog Induction/Resistivity 25 Col 8613 10945 Open 1/20/2009 TVD MPR, GR 25-Oct-2008 - og Gamma Ray 25 Col 8613 10945 Open 1/20/2009 MD GR 25-Oct-2008 g See Notes 5 Col 8380 10939 Open 1/20/2009 Depth Shift Monitor Plot Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/23/2010 Permit to Drill 2081480 Well Name/No. PRUDHOE BAY UNIT 18-066 Operator BP EXPLORATION (ALASI(A) INC API No. 50-029-20797-02-00 MD 10945 TVD 8683 ADDITIONAL INFORM TION Well Cored? A Y - N / Chips Received?ti .~N-.. Analysis 4`fl~ Received? Comments: Completion Date 10/29/2008 Completion Status 1-OIL Current Status 1-OIL UIC N Daily History Received? ~°/ N Formation Tops u~ N Compliance Reviewed By: Date: C~ • ^; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURN~fiG OR FAXING YOUR COPY FAX; ~90i) 267-5623 Sent by: Terri Tuminello Date: 01/16/09 2 Received by: "~ Date: - - % '~' '~ '~ti..--.-- ;. Ilo1TEQ L®g Data Transmittal F®rm To: State of Alaska -A®GCC 333 W. 7~" Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 18-06B 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) I LAC Job#: 2254652 `® BAICLR aauRUec Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 i _:; ~~ - BAKER • N~JlLMES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH WELL NAME 18-06B STATE ALASKA FIELD PRUDHOE BAY UNTI' THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO # 2254652 Copies of Copies Digital Copia of Copies Digital Each Log of Film Data Each Log ofFihn Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DNISION OF OII, & 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: ~ j 4. DATE 1/16/2009 Page 1 of 1 12/18/08 • Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wpll -Inh it N0.5011 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 11-34 12071901 USIT /~ _ 10/17/08 VVIVI 1 vv 1 V-219 12103700 USIT .. 11/21/08 1 1 D-12 12113022 INJECTION PROFILE 12/05/08 1 1 R-11A 12096929 USIT 12/07/08 1 1 01-34 12116292 CORRELATION/GR LOG CO ~- ! ' =}- ~ a 12/06/08 1 1 F-19 AWJI-00011 MEM LDL ~ _ 1?J08/OS 1 1 18-29B AWJI-00010 MEM LDL .. (P ~ b 12/05/08 1 1 09-41 12017504 PRODUCTION PROFILE f 4l --~ 12/04/08 1 1 18-14B 12005233 MCNL -- 09/21/08 1 1 18-066 12083417 MCNL -~ 10/28/08 1 1 18-14C 12066551 MCNL 10/06/08 1 1 05-10C 11649990 MCNL 10/04/08 1 1 V-219 12103700 CH EDIT (USIT) 11/21/08 1 L - ~ ~ ~ P °- 5 VVl T -t ~ - ~- PI FAAC Af`Il~IA1A/1 Cnn_c oe ro,er cv c„n. u.,i. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth Received by: ~ ~ ~~ii' BAKER I~WGNES ~ ~~':~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: November 07, 2008 Please find enclosed directional survey data for the following wells: 06-23C 07-30B 18-14C 18-24B 18-06B ./ 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: ~ ,State of Alaska AOGCC DATE: \ ~ ~ ~,, ~r~8 Cc: State of Alaska, AOGCC a~~-I~g I .r u STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION `` °- WELL COMPLETION OR RECOMPLETION REPORT AND LfJG ~~~Q~ 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/29/2008- 12. Permit to Drill Number 208-148 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/22/2008 13. API Number 50-029-20797-02-00 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 10/25/2008- 14. Well Name and Number: PBU 18-066~ 835' FNL, 251' FEL, SEC. 24, T11N, R14E, UM Top of Productive Horizon: 1329' FNL, 1506' FEL, SEC. 24, T11 N, R14E, UM 8. KB (ft above MSL): 53.38' ~ Ground (ft MSL): 16.22' 15. Field /Pool(s): - Prudhoe Bay Field / Prudhoe Bay Total Depth: 840' FNL, 354' FWL, SEC. 19, T11 N, R15E, UM 9. Plug Back Depth (MD+TVD) 10906' 8682' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 691506 y- 5961027 Zone- ASP4 10. Total Depth (MD+TVD) 10945' 8683' 16. Property D signation: Q~ ADL 028321 ~ TPI: x- 690264 y_ 5960501 Zone- ASP4 5961037 Zone- ASP4 692111 l D th T t 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y- : x- o a ep 18. Directional Survey ®Yes ^ No mit I r ni n rin info i n er 2 .0 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 C 25.071): MWD DIR / GR / RES, GR / CCL / CNL t./%^/ p ~ ~,( ®?. d ~MD ~OpSTj/ 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. H-4 urf 7' rf 7' 1 Pol / - '~ -/" 47# L-80 / S0095 S 8 rf 1 1' 1 -1/4" x I PF'C' " 9# L- 2' 81 -1/ " 7 x I ss' ' " 77 4 " 1 , ~~rr~X~-~~s°xzare° s.2#~s.zM~s.1s# L-8 8 1 1 11' 8 -1/ " x l 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i P TVD f T & B tt nterval open mb r): Si d N rf ti SIZE DEPTH SET MD PACKER SET MD ze an u e om; ora on (MD+ op o e o f 2" Gun Diameter 6 s 4-1/2", 12.6#, L-80 7935' 7880' , p MD TVD MD TVD 9190' -9480' 8681' - 8681' ' 8681' 8679' ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - - 9940 9570 10060' - 10280' 8679' - 8681' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10420' -10900' 8681' -8681' 2000' Freeze Protected w/ McOH 26. PRODUCTION TEST Date First Production: November 21, 2008 Method of Operation (Flowing, Gas Lift, etc.): Flowin Date Of Test: 11/25/2008 HOUrS Tested: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 2,590 GAS-MCF: 13,033 WATER-BBL: 6 CHOKE SIZE: 90 GAS-OIL RATIO: 22,072 Flow Tubing Press. 2,189 Casing Press: 1,350 CALCULATED 24-HOUR RATE OIL-BBL: 7,771 GAS-MCF: 39,099 WATER-BBL: 19 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core s) Acquired? ^Yes ®No Sidewall Core s A wired? ^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. .,~._ u T None ~; f .~ . ~~~~, ~ ~ 2aoa z~ ~_.~ Form 10-407 Revised 02/2007 (..ONTINUED UN KEVERSE'tDE a~~ ~ . ..= ~ ~ ~ d.,~ ~ ~ r` r i... r~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MA S ENCOUNTERED): 29. FORMATION TESTS NAME MD 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. 23S6 /Zone 26 8700' 8492' None 22TS 8726' 8516' 21TS /Zone 2A 8774' 8558' Zone 1 B 8861' 8621' TDF /Zone 1A 8914' 8650' Formation at Total Depth (Name): TDF /Zone 1 A 8914' 8650' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoi g is true and correct to the best of my knowledge. ltl ~~~ Signed Terrie Hubble Title Drilling Technologist Date PBU 18-066 208-148 Prepared By Name/Number. Ter-'ie Hubble, 564-4628 Well Number Permit No. / A royal No. o~niny Engineer: Mel Rixse, 564-5620 INSTRUCTIONS GeNewv.: 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. Irene 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 TVD 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 (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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 • BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/20/2008 00:00 - 03:00 03:00 - 06:00 06:00 - 06:30 06:30 - 12:00 3.00 MOB P PRE 3.00 MOB N WAIT PRE 0.50 MOB P PRE 5.50 BOPSU P PRE 12:00 - 19:15 7.251 BOPSUp P I PRE 19:15 - 19:30 0.25 BOPSU P PRE 19:30 - 21:00 1.50 RIGU P PRE 21:00 - 21:30 0.50 BOPSU P PRE 21:30 - 23:00 1.50 BOPSU P PRE 23:00 - 00:00 1.00 BOPSU P PRE 10/21/2008 00:00 - 01:30 1.50 BOPSU P PRE 01:30 - 02:30 1.00 FISH C WEXIT 02:30 - 03:15 0.75 FISH P WEXIT 03:15 - 04:00 0.75 FISH C WEXIT 04:00 - 04:15 0.25 FISH C WEXIT 04:15 - 05:00 0.75 FISH C WEXIT 05:00 - 06:00 1.00 FISH P WEXIT 06:00 - 06:45 0.75 FISH C WEXIT 06:45 - 08:30 1.75 FISH ~ C ~ ~ W EXIT 08:30 - 09:15 0.751 FISH C WEXIT 09:15 - 10:15 I 1.00 I FISH I C I I W EXIT 10:15 - 10:45 0.50 FISH C WEXIT 10:45 - 11:15 0.50 FISH C WEXIT 11:15 - 12:15 1.00 FISH C WEXIT 12:15 - 12:30 0.25 FISH ~ C 12:30-17:00 ~ 4.50~FISH ~C WEXIT WEXIT Move rig to 18-06 Wait, Change out swab leaky swab valve, test, setup work platform Move over well 18-06 & set down Accept Rig at 06:30 Hrs on 10/20/2008 PJSM on BOP testing proceedures, ND tree cap, NU BOP, Dress off flange studs for tree cap, removed one 2' spool in riser PJSM on BOP testing proceedures, performed koomey draw do test, Pressure test BOP as per BP and AOGCC policies and regs, AOGCC representative Lou Grimaldi waived witnessing test. PJSM for pulling BPV Test lubricator Pull BPV RD and load out tools. well ~~ on a vac PJSM fo PU injector and pulling coil across. Adjust gooseneck rollers, RU injector and PU. Install grapple and pull test, pull coil across PU pack off assembly Change out wire rope injector sling Install CTC, pull test to 35K Fill hole w/ 39 bbl Pump a-Iline slack out of coil ~ 2.9 bpm PJSM for PU fishing assembly Start PU fishina assam Test inner reel valve and chart PJSM with change out crew on handling and PU Fishing BHA #1, Finish PU fishing assembly *RIH to 3446', crude and gas in returns ,shut down pumps, shut in choke, SI pressure 150 psi, pressured up down CT to 2000 psi and holding, bled off pressure to 100psi, swapping well over to 2ppb, 2 percent KCL milling fluid *RIH to 4367' w/ 1.4bpm, 1500psi, holding back pressure of 150psi, Dn Wt 15k, tagg^ ed up with set down weight of 15k, pump pressure increased to 2000psi, PU, latched with UP Wt of 41 k *Circ at 1.7bpm, 1790psi, holding 150psi back pressure, pumped a total of 91 bbls with crude and gas in returns back to tiger tank, well swapped over to 2ppb, 2 percent KCL milling fluid *Shut in well on choke, monitor, Opsi *Pressure test wellbore to 2091 psi for 30 minutes, IA 0 psi, OA 23 psi *Circ 92 bbls, taking returns to tiger tank, in /out rates 2.38/2.62 bpm, 2725psi, maintaining 150 - 200 psi back .pressure, MW in 8.37ppg, MW out varied from 7.65 - 8.25 - 6.75ppg, returns showed mud contaminated with crude and gas, slowed rate down to 1.01 in / 1.18 out bpm, MW in 8.34 ppg, MW out 7.59ppg, well stable I of 50k, 57k, 3 x at 63k without pumps, with pumps at .63 / .63 bpm, 864 psi, PU 2 x at 63k, ulled free with strai ht ull did n t *POH with up drag at 45k at 4367', pumping at .65 bpm, Printetl: 71/25/YUUS n:uzsa nm • • d i~ BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date from - To Hours Task Code NPT Phase Description of Operations 10/21/2008 12:30 - 17:00 4.50 FISH C WEXIT 1100psi, returns mixed with crude and gas, gas cut mud at 7.9ppg, up drag decreased POH to BHA, monitor well, POH LD BHA and fish, Recovered 100% of fish "SLB computer was updated (changed out) during the rig move on 10/20/08 and both encoders were left in the on position. Only one encoder was registering values, but the computer averaged the values of both encoders, since both were on. This caused the computer display to only count 1' for every 2' of travel. The manual counter was zeroed before we started out the hole. This showed that we actually POH from aoorox 8600'. Note: Asterik represents incorrect depths, correct de the should be a ro 17:00 - 18:30 1.50 STWHIP C WEXIT Reverse circ for slack management 18:30 - 18:45 0.25 STWHIP C WEXIT SAFETY MEETING. PJSM for cutting CT. Overhead loads and pinch points, hand traps discussed. 18:45 - 19:30 0.75 STWHIP C WEXIT Break injector off well. Rig up hydraulic CT cutter. Cut 360 ft of CT to find cable. 19:30 - 20:40 1.17 STWHIP P WEXIT Install CT connector. Pull test to 40 Klbs, good. Re-check set screws on CTC. 20:40 - 22:00 1.33 STWHIP P WEXIT Install BHI cable head. Move CT over circ hole and circulate remaining water out. 22:00 - 23:00 1.00 STWHIP N HMAN WEXIT Thaw out 1502 line to flowback tank. 23:00 - 23:15 0.25 STWHIP P WEXIT SAFETY MEETING. PJSM for picking up BHA. Discussed procedures and crew assignments. 23:15 - 00:00 0.75 STWHIP P WEXIT Pressure test CT connector and BHI cable head, good. Put CT in circ hole and pump slack forward while picking up BHA. Pressure test line to flowback tank. 10/22/2008 00:00 - 01:20 1.33 STWHIP P WEXIT P/U BH - + String Reamer, 2-7/8" BOT Xtreme, 2 jts PH6, 3" CoilTrack with DGS. 01:20 - 03:45 2.42 STWHIP P WEXIT RIH BHA #2. ~ ~ Log GR down from 8,450 ft. Correct +16 ft. Q ~ ~ Continue RIH. 0 03:45 - 04:00 0.25 STWHIP P WEXIT Tag at 8,615 ft at minimum rate. Pick up is 32 Klbs, o to 2.5 b m. 04:00 - 06:30 2.50 STWHIP WEXIT Mill from 8,612.6 ft at 2.50 / 2.50 bpm ~ 2,270 psi. DWOB is -0.47 Klbs with CT wt = 18.1 Klbs. 05:00 - 8,613.7 ft. 2.50 bpm ~ 2,410 psi. DWOB = 0.53 Klbs, CT wt = 17 Klbs. p~/ 06:00 - 8,614.6 ft. 2.52 bpm C~ 2,530 psi. DWOB = 2.46 Klbs, ~ ~lP CT wt = 14.9 Klbs. 06:30 - 07:00 0.50 STWHIP P WEXIT Mill from 8,615.2' - 8615.4' at 2.55/ 2.52 bpm at 2,550 psi, DWOB 2.87K, PVT 324bb1s 07:00 - 08:00 1.00 STWHIP P WEXIT Mill from 8,615.4' - 8616.1', 2.53/ 2.52 bpm at 2,590 psi, DWOB 3.04K, ECD 9.21ppg, PVT 324bb1s 08:00 - 09:00 1.00 STWHIP P WEXIT Mill from 8,616.1' - 8617', 2.53/ 2.53 bpm at 2,681 psi, DWOB 3.94K, ECD 9.22ppg, PVT 324bb1s 09:00 - 10:00 1.00 STWHIP P WEXIT Mill from 8,617' - 8618.2', 2.53/ 2.53 bpm at 2,575 psi, DWOB 2.77K, ECD 9.22ppg, PVT 323bb1s 10:00 - 11:00 1.00 STWHIP P WEXIT Mill from 8,618' - 8619.7', 2.53/ 2.53 bpm at 2,681 psi, DWOB 2.37K, ECD 9.21 ppg, PVT 323bb1s 11:00 - 12:00 1.00 STWHIP P WEXIT Mill from 8619.7' - 8620.4', 2.50 / 2.51 bpm at 2,550 psi, Printetl: 11/252UU8 11:UL::i25 Ann BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/22/2008 11:00 - 12:00 1.00f STWHIP P WEXIT DWOB 2.76K, ECD 9.22ppg, PVT 323bb1s 12:00 - 13:00 1.00 I STWHIP P WEXIT Mill from 8620.4' - 8621.4, 2.52/ 2.52 bpm at 2,563 psi, DWOB 13:00-14:00 ~ 1.OO~STWHIP~P 14:00 - 15:00 I 1.001 STWHIPI P 15:00 - 16:00 I 1.001 STWHIPI P 16:00 - 16:50 0.831 STWHIPI P 16:50 - 18:15 1.42 (STWHIPI P 18:15 - 18:30 0.251 STWHIPI P 18:30 - 19:30 1.001 STWHIPI P 19:30 - 20:40 I 1.171 DRILL I P 20:40 - 23:30 I 2.831 DRILL I P 23:30 - 00:00 0.501 DRILL P 10/23/2008 00:00 - 04:30 ~ 4.50 ~ DRILL ~ P 04:30 - 04:40 0.17 DRILL P 04:40 - 06:30 1.83 DRILL P 06:30 - 08:15 1.75 DRILL P 08:15 - 08:45 0.50 DRILL P 08:45 - 11:30 2.75 DRILL P 11:30 - 11:50 I 0.331 DRILL I P 3.12K, ECD 9.21 ppg, PVT 323bb1s WEXIT Mill from 8621.4 - 8622.8, 2.53/ 2.53 bpm at 2,654 psi, DWOB 2.71 K, ECD 9.22ppg, PVT 323bb1s, Window from 8613.5' to 8622.6', uncorrected WEXIT Drilling new hole from 8622.8 - 8626', 2.52/ 2.53 bpm at 2,629 psi, DWOB 2.93K, ECD 9.22ppg, PVT 322bb1s WEXIT Drilling new hole from 8626' - 8630', 2.39/ 2.39 bpm at 3200 psi, DWOB 4.6K, ECD 9.3ppg, Swapping well over to recondition Flo-Pro System WEXIT Drilling new hole from 8630' - 8634', 2.39/ 2.39 bpm at 3200 psi, DWOB 4.6K, ECD 9.3ppg, Swapping well over to recondition Flo-Pro System, Up Wt 31.1 k, Dn Wt 14.4k, worked thru window several times with pumps, also did a dry drift of window to btm with no problems, finished displacing well to Flo-Pro mud WEXIT POH to Milling BHA 2, 2.3 bpm, 2666psi, Paint flag at 8484', EOP at 8364', Up Wt 31.1 k WEXIT SAFETY MEETING. PJSM for change out BHA. Discussed well control, overhead loads and lifting. WEXIT Tag stripper. L/D BHA #2. Mill is 3.79" no-go, mill and string reamer show normal wear. PROD1 - 3.75 x 4.25 HYC SRX bi-center bit, 2-7/8" Xtreme motor with 2.4 e AKO 3" CoilTrak with Res. BHA OAL = 79.02 ft. PROD1 RIH BHA #3. Log down from 8,400 ft. Correct +16.5 ft. Log down to TD, tag at 8,633 ft. Pick up and close EDC, up wt is 32 Klbs. PROD1 Drill from 8,633 ft 2.47 / 2.43 bpm. FS = 3,150 psi. PVT = 316 bbls. Drill with 150E toolface, initial ROP is 30 - 60 ft/hr with 0-1 Klbs DWOB and CT wt = 14.4 Klbs. Drill to 8,647 ft. PROD1 Continue drilling from 8,647 ft. ROP is 20-50 ft/hr. PVT = 312 bbls. Maintain 120E TF to complete turn. Formation is 20% chert. Past 8,720 ft ROP slows to 10-30 ft/hr. TF is 45L, start to build angle. PVT = 309 bbls. Drill to 8,750 ft. PROD1 Wiper trip from 8,750 ft to window. Clean pass up and down. PROD1 Drill from 8,750 - 8820 ft. TF = 40-60L. ROP is 30-90 ff/hr. PROD1 Drill to 8900', TF 58L, 2.51/2.45 bpm, 3376 psi, DW06.64K, ECD 9.91 ppg, ROP 40-60 fph, PVT 308 bbls, IA 0 psi, OA 23 psi PROD1 Wiper trip from 8,900' to window. Clean pass up and down. PROD1 Drill to 9030', TF 51-71 L, 2.55/2.48 bpm, 3100-3400 psi, FS 2875 psi, DWOB 1 - 3K, ECD 9.92ppg, ROP 60-70 fph, PVT 305 bbls, IA 0 psi, OA 23 psi PRODi Drill to 9042' TF 90L, 2.50/2.48 bpm, 3300 psi, DWOB 1 - 3K, ECD 9.98ppg, ROP 60-30 fph, PVT 303 bbls, IA 0 psi, OA 23 Printed: 7 7/25/20013 11:0L::itl AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 18-06 Page 4 of 12 ~ Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ' Task Code NPT Phase Description of Operations 10/23/2008 11:30 - 11:50 0.33 DRILL P PROD1 psi, motor stalled out, PU off btm, shutting down pumps, slacked back down to 9035' taking weight with pump, PU with no upward movement 11:50 - 13:40 1.83 DRILL P PRODi ~ Attempt to pull free several times with Dn wt -4k and Up wt 80k, stacking wt with and without pumps, slack off to neutral position, circ hole clean, shut down pumps, relaxed hole, PU to 80k, pulled free 13:40 - 16:00 2.33 DRILL P PROD1 POH to BHA 3 16:00 - 16:25 0.42 DRILL P PROD1 POH with BHA 3, Set back Injector, Slowdown BHA, Pull BHA OOH, Service LOC, MU rebuilt HCC 4.125 BC bit, Change motor settin to 1.2de on BHA 4 16:25 - 18:50 2.42 DRILL P PRODi • RIH with lateral BHA 4. Log GR down from 8,630 ft. Correct +11 ft. 18:50 - 19:05 0.25 DRILL P PRODi Pick up to 8,400 ft to log CCL down, to confirm location of 4-1/2" X nipple. X nipple is found at 8,492 ft (shown at 8,482' on schematic.) 19:05 - 21:05 2.00 DRILL P PROD1 RIH to find bottom. Tag bottom at 9,042 ft. Up wt is 35 Klbs. Drill from 9,042 ft, start mud swap. Initial ROP is 100 - 140 ft/hr. Hold 90L TF to finish turn to left. Pickup at 9,135 ft is 45 Klbs. Drill to 9,200 ft. 21:05 - 21:50 0.75 DRILL P PROD1 Wiper trip from 9,200 ft to window. Up wt is 34 Klbs. Clean pass up and down. 21:50 - 23:15 1.42 DRILL P PROD1 Drill from 9,200 ft, new mud throughout system. 2.50 / 2.48 bpm ~ 2,900 psi FS. ROP 80-120 ft/hr. TF is 80L until 9,300 ft to complete left turn and stay in polygon. Maintain TVD < 8,628 ft to stay out of Kavik. PVT = 334 bbls, ECD = 9.75. Density is 8.53/8.51 ppg. Occasional weight stacking. Drill to 9,350 ft. 23:15 - 00:00 0.75 DRILL P PRODi Wiper trip from 9,350 ft to window. Up wt is 42 Klbs off bottom. Clean pass up and down. 10/24/2008 00:00 - 01:20 1.33 DRILL P PROD1 Drill from 9,350 to 9,500 ft. ROP is 80-120 ft/hr. 2.52 / 2.49 bpm ~ 3000 - 3400 psi. Density is 8.55 / 8.68 ppg with ECD = 9.87 PPg• Holdin around 8 628 ft TVD. 01:20 - 02:40 1.33 DRILL P PROD1 Wiper trip and tie-in log. No correction. Resume wiper trip to bottom. Clean pass up and down. 02:40 - 04:00 1.33 DRILL P PROD1 Drill from 9,500 ft. Start RH turn with 90R toolface, keep TVD around 8,628 just above Kavik shale. ROP is 100 - 130 ft/hr. Some weight stacking and differential sticking off bottom. Drill to 9,650 ft. 04:00 - 05:10 1.17 DRILL P PROD1 Wiper trip from 9,650 ft to window. CT wt off bottom is 40 Klbs. Clean pass up and down. 05:10 - 06:15 1.08 DRILL P PROD1 Drill to 9800 ft at 100-120 ft/hr. 2.51 / 2.48 bpm ~ 3000-3400 psi. PVT = 327 bbls. 06:15 - 06:50 0.58 DRILL P PROD1 Wiper trip from 9,800' to window, Up wt 33.5 K, hole clean 06:50 - 07:25 0.58 DRILL P PROD1 RIH to Btm, Dn wt 15.5k, 2.51 / 2.61 bpm, 2750 psi, 38 fpm, hole clean 07:25 - 08:55 1.50 DRILL P PROD1 Drill to 9950', TF 83 L, 2.51/2.51 bpm, 3050 psi, FS 2700 psi, j DWOB 2.35K, ECD 9.88ppg, ROP 115 - 160 fph, PVT 318 bbls, IA 0 psi, OA 23 psi Pflnt2tl: 1125/LUUB 11:U'L:Jif AM BP EXPLORATION Page 5 of 12 Operations. Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/24/2008 08:55 - 09:45 0.83 DRILL P PROD1 Wiper trip from 9,950' to window, Up wt 34K, hole clean 09:45 - 10:00 0.25 DRILL P PROD1 10:00 - 10:35 0.58 DRILL P PROD1 10:35 - 12:00 1.42 DRILL P PROD1 12:00 - 12:50 0.83 DRILL P PROD1 12:50 - 13:40 0.83 DRILL P PRODi 13:40 - 14:50 1.17 DRILL P PROD1 14:50 - 16:00 1.17 DRILL P PROD1 16:00 - 16:35 0.58 DRILL P PROD1 16:35 - 18:25 1.83 DRILL P PROD1 18:25 - 20:40 ~ 2.25 ~ DRILL ~ P 20:40 - 21:40 I 1.001 DRILL I P 21:40 - 23:40 2.00 DRILL ~ P 23:40 - 00:00 I 0.331 DRILL I P PROD1 PROD1 PROD1 PRODi 10/25/2008 00:00 - 00:15 0.25 DRILL P PROD1 00:15 - 00:50 0.58 DRILL N SFAL PROD1 00:50 - 01:15 ~ 0.42 ~ DRILL ~ N ~ SFAL ~ PROD1 01:15 - 01:45 0.50 DRILL N SFAL PROD1 01:45 - 02:10 0.42 DRILL P PROD1 02:10 - 04:10 2.001 DRILL P 04:10 - 05:10 I 1.001 DRILL I P PROD1 PROD1 Tie-in pass from 8650' to 8660', + 1.5' correction RIH to Btm, Dn wt 15.5k, 2.64 / 2.72 bpm, 2988 psi, 28 fpm, hole clean Drill to 10100', TF 100 L, 2.51/2.31 bpm, 3100 psi, FS 2750 psi, DWOB 2.34K, ECD 10.1 ppg, ROP 115 - 150 fph, PVT 306 bbls, IA 43 psi, OA 23 psi Wiper trip from 10100' to window, Up wt 34.5K, hole clean RIH to Btm, Dn wt 15.5k, 2.73 / 2.86 bpm, 3040 psi, 31fpm, hole clean Drill to 10250', TF 100 -90 L, 2.68 / 2.63 bpm, 3390 psi, FS 2850 psi, DWOB 2.29K, ECD 10.Oppg, ROP 131 fph, PVT 294 bbls, IA 93 psi, OA 23 psi Wiper trip from 10250' to window, Up wt 36.8K, hole clean RIH to Btm, Dn wt 15.5 - 12.5k, 2.65 / 2.91 bpm, 2940 psi, 46 fpm, hole clean Drill to 10400', TF 95 - 141 L, 2.50 / 2.50 bpm, 3475 psi, DWOB 2-4K, ECD 10.14ppg, ROP 100 - 150 tph, PVT 286 bbls, IA 166 psi, OA 23 psi, swapping well over to new Flo-Pro mud, stacking wt and stalling motor occasionally Wiper trip to window, and tie-in log. Correct +2.5 ft. Continue wiper trip to bottom. Drill from 10,400 ft. 2.54 / 2.50 bpm C~ 2800-3300 psi. Hold around 8,628 ft TVD. ECD is 9.69 ppg 8.50 / 8.48 ppg. Weight stacking and differential effects. 50 Klbs pickup at 10,450 ft. Drill to 10,550 ft. Wiper trip from 10,550 ft to window. Up wt off bottom is 50 Klbs. Clean pass up and down. Drill from 10,550 ft at 120 - 160 Whr. 2.65 / 2.59 bpm ~ 2800-3400 psi. Continue holding 8,629 ft TVD as per Geo. Frequent wt stacking. ECD = 9.82 ppg. Continue drilling from 10,595 to 10,632 ft. Leak on reel 1502 line. Reduce pump rate and pull into casing. PJSM then change out failed O-ring on 1502 connection. Pressure test connection, good. Resume circulation. Stay in casing and circulate, vacuum up mud in reel sump. Total of 10 gal Flo-Pro released, all captured in reel sump containment on rig. Incident reported to x5700. ..Run back in to bottom. 'Drill from 10,632 ft at 120-150 fUhr. 2.64 / 2.61 bpm ~ 2900-3400 psi. PVT = 310 bbls, ECD = 9.85 ppg. Continue holding around 8,629 ft TVD. Drill to 10,700 ft. Wiper trip from 10,700 ft to window. Up wt is 45 Klbs off bottom. Weight fluctuations around 10,000 ft, up and down. Small shale stringer here. Drill from 10,700 ft. 2.62 / 2.62 bpm C~3 2900-3700 psi. ROP Printed: 11/252008 11:02:38 AM BP EXPLORATION Page 6 of 12 ', Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/25/2008 04:10 - 05:10 1.00 DRILL P PROD1 150-180 fUhr. PVT = 297 bbls, ECD = 9.95 ppg. Maintain around 8,628 ft TVD. Drill to 10,850 ft ~ 05:10 - 06:20 1.17 DRILL P PROD1 Wiper trip to 8650', hole clean 06:20 - 06:25 0.08 DRILL P PROD1 Tie-in log from 8650' - 8659', +4.5 correction 06:25 - 07:35 1.17 DRILL P PROD1 RIH to Btm, 2.57/2.61 bpm, 2975 psi, Dn Wt 15k, ECD 9.84 ppg, IA 155 psi, OA 23 psi, hole clean 07:35 - 08:35 1.00 DRILL P PROD1 Drill to TD at 10945', TF 100 - 80 R, 2.58 / 2.56 bpm, 3450 psi, -~ FS 2930 psi, DWOB 1 K, ECD 9.97 ppg, ROP 110 fph, PVT 284 bbls, IA 178 psi, OA 23 psi 08:35 - 10:20 1.75 DRILL P PROD1 Wiper trip to 8650', hole clean 10:20 - 10:25 0.08 DRILL P PROD1 Tie-in log from 8650' - 8659', +1.5 correction 10:25 - 11:40 1.25 DRILL P PROD1 RIH to Btm, 2.33/2.48 bpm, 2750 psi, Dn Wt 15.9k, ECD 9.86 ppg, IA 155 psi, OA 23 psi, hole Clean, DUmDlna liner riinninn 11:40 - 14:05 2.42 DRILL P PRODi POH to Drlg BHA 4, spotted liner running pill across openhole, flagged pipe at 8479', EOP at 8400', second flag at 6179', EOP at 6100', PU injector, breakout LOC, Std back injector, Blowdown BHA 4 14:05 - 14:35 0.50 DRILL P PROD1 POH LD BHA 4, LD coilTrak, bit and motor 14:35 - 15:45 1.17 CASE P RUNPRD Breakout UOC, boot eline, M/U 1 joint of 2 3/8" PH6, X-O, CTC, Stab Injector, circ 4.5 to 4.75 bpm / 3380 - 3615 psi with Flo-Pro mud, Pump out ,cut off 332' of eline 15:45 - 17:30 1.75 CASE P RUNPRD MU Baker CTC, X-O, found flat spot on coil tbg above CTC, cut off CTC, cut 10' of CT, re-install CTC, X-O, Lockable Swivel, X-O, boot eline, pressure test CTC to 3500psi, LD X-O and swivel, Std back Injector 17:30 - 17:55 0.42 CASE P RUNPRD RU floor and handling tools for 2 7/8" liner, offload Baker equipment to rig floor, Ru and position catwalk 17:55 - 18:20 0.42 CASE P RUNPRD MU Liner BHA 5 18:20 - 19:00 0.67 CASE P RUNPRD Tour change, PJSM with new crew. 19:00 - 00:00 5.00 CASE P RUNPRD Run liner as per program: 2-7/8" Unique biased edge guide Shoe. BTT Float Collar, 2-7/8" STL 2-7/8", 6.16#, L-80, STL Liner without turbo BTT Float Collar, 2-7/8" STL BOT landing collar 49 jts 2-7/8", 6.16#, L-80, STL Liner with turbos BTT XO, 3-3 16" x 2-7/8" STL 24 its 3-3/16". 6.2#, L-80, TCII Liner with turbos 3-1/2", 9.2#, L-80, STL 10' Pup Jt BTT Deployment Sleeve, with 4" GS profile BOT SELRT BOT HLDC, 3/4" ball 6 jts 2-3/8" PH6 tbg BOT Locking swivel BOT CT connector BHA OAL = 2,635.11 ft. Fill liner with water after 2-7/8" and after 3-1/2" is made up. NOTE: Had to lay down 1 jt of 3-3/16 due to bad box, and 1 jt Printed: 11/25/2008 11:02:38 AM • BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date !From - To ~I Hours Task ~ Code NPT ' Phase Description of Operations 10/25/2008 19:00 - 00:00 5.00 CASE P RUNPRD of PH6 due to excessive scale. 10/26/2008 00:00 - 02:00 2.00 CASE P RUNPRD Continue M/U liner + running tools. M/U CT riser, circ fresh water out of liner. 02:00 - 03:50 1.83 CASE P RUNPRD RIH with liner. Wt check outside of window is 40 Klbs. Pass through window and RIH to bottom. Watch flag go by, +16 ft correction, consistent with previous runs. Ta bottom at 10 941 tt firm to . Establish good circulation, 1.11 / 1.11 bpm ~ 1830 psi. 2.03 / 2.01 bpm ~ 2,610 psi. Go to min rate, pick up wt is 41 Klbs. Slack back to same spot for ball drop. 03:50 - 04:15 0.42 CASE P RUNPRD Position reel and drop 5/8" steel ball. Launch ball with 1,500 psi, chase with hi-vis pill at 2.48 / 2.42 bpm ~ 3160 psi. Slow pump at 40 bbls to watch ball land. Ball lands at 40.2 bbls, about 15 bbls early, seat shears at 4,500 psi. 04:15 - 06:00 1.75 CASE P RUNPRD Pick up to get wt back, wt breaks back at 38 Klbs. Set 10 Klbs back down on it. Swap well over to 2% double slick KCI. 06:00 - 07:15 1.25 CASE P RUNPRD Fill pit 3 with clean KCI and mix 80 bbls Geo-vis. Circ at 1.46bpm, 531 psi 07:15 - 08:00 0.75 CEMT P RUNPRD Crew Change, PJSM reviewing procedures, hazards and mitigations for pumping cement job with SWS cementers and related personnel., Circ at 1.46 / 1.36bpm, 531 psi 08:00 - 08:30 0.50 CEMT P RUNPRD Batch mix 35bbls of CI G latex cement with gas block, Cement at wt at 0810 hrs. Press test cement line with 6500 psi, Circ at 1.46 / 1.36bpm, 531 psi, approx 7 percent fluid loss 08:30 - 09:50 1.33 CEMT P RUNPRD Pump 2 bbls thru cement lines, pressure test to 6500 psi, Pump cement job as follows. IA Opsi, OA 23psi, PVT 291 bbls Pump 31 bbl, 15.8 ppg, G Latex cement with gas bloc 10 bbl Cmt, 2.0 / 1.90 bpm, 1700 psi, 5.0% fluid loss 20 bbl Cmt, 2.0 / 1.90 bpm, 2275 psi, 30 bbl Cmt, 1.98 / 1.89 bpm, 2475 psi, 4.5% fluid loss. 31.0 bbl Cmt, stop pump. Clean cement line with GeoVis and air. Pump 2ppb GeoVis displacement. Zero in /out totalizers on displacement. Coil and PH6 ca aci = 56 bbls sto dis I at 54 bbl. 10 bbl displ, 2.19 / 2.12 bpm, 1600 psi, 20 bbl displ, 2.19 / 2.13 bpm, 950 psi 25 bbl displ, 2.23 / 2.19 bpm, 725 psi, cement going into liner 30 bbl displ, 2.20/ 2.10 bpm, 886 psi 40 bbl displ, 2.18 / 2.08 bpm, 1340 psi 40.6 bbl displ, cement at shoe, zero out totalizer 50 bbl displ, 2.18 / 2.09 bpm, 1930 psi. 54 bbl displ, 2.23 / 2.16 bpm, 2084 psi, stop pump Pick up 13' above breakover depth of 10933' to 10920' Nnntea: i vzoizuue i i:ur~a Hnn BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code NPT Spud Date: 8/17/1982 Start: 10/16/2008 End: 10/30/2008 Rig Release: 10/30/2008 Rig Number: N1 Phase Description of Operations 10/26/2008 108:30 - 09:50 I 1.331 CEMT I P RUNPRD exhaust 2 bbls cmt followed by 3 bbls of GeoVis at 3.26 bpm, 2250psi, Stop pump, Open Baker choke RIH and stack 15K at same depth, Close Baker choke 09:50 - 11:30 1.67 CEMT P RUNPRD 11:30 - 12:30 1.00 CEMT P RUNPRD 12:30 - 13:00 0.50 EVAL P LOWERi 13:00 - 13:15 0.25 EVAL P LOWERi 13:15 - 16:00 2.75 EVAL P LOWERI 16:00 - 17:15 1.25 EVAL P LOWERI 17:15 - 17:35 0.33 EVAL P LOWERI 17:35 - 19:00 1.42 EVAL P LOWERI 19:00 - 20:00 1.00 EVAL P LOWERI 20:00 - 20:40 0.67 EVAL P LOWERI 20:40 - 22:30 1.83 EVAL P LOWERI 22:30 - 22:40 0.17 EVAL P LOW ERi 22:40 - 23:20 0.67 EVAL P LOWERi 15.5 bbl 5 bbls, 2.67 / 2.57 bpm, 2827 psi 10 bbls, 2.71 / 2.58 bpm, 3250 psi 15.5 bbls, 1.32 / 1.24 bpm, 2168 psi, bumped plug, hold 3150 psi on LWP, 5 minutes Bleed off press and check floats, Floats held Press up 500 psi, sting out, Circ at top of liner 2 bbls at 1.5 bpm. Good cement lob, 5% fluid loss at end of cement job CIP at 09:40 hours on 10/26/08 POH to BHA 5, Circ .59 / .14 bpm, 1095 psi, Std Bk injector POH, LD 6 Jts of 2 3/8" PH6 tbg and SELRT, Offload rig with Baker tools Program SLB memory tools with carrier, RU handling tools, bring up tools, source to rig floor PJSM reviewing procedure, hazards and mitigation for M/U mill motor and SWS Memory CNL/GR loooino tools.. M/U Memory logging / Cleanout BHA 6 with 2.30" diamond mill, motor, 2 jts 1-1/4" CSH, SWS Carrier, Circ sub, Hyd disc, 78 jts 1-1/4" CSH, Hyd Disc, 2 jts PH6, locking swivel with PAC connections, X-O and Baker CTC. BHA OAL = 2586', Stab Injector RIH with BHA 6 cleanout and memory logging BHA to 7946', Up wt 25k, Dn wt 10.8k Washing down f/ 7946' - 7952', stacking weight, 1.6 bpm, 2120 psi, contaminated cement in returns, MW in 8.38ppg, MW out 9.9ppg Note - 9 5/8" x 7" ZXP Packer at 7935' 9 5/8" x 7" Baker liner Hanger at 7946' 7 x 4.5" X-O at 7952' POH to change out BHA, pump rate at 1.56 bpm, 1660psi, cement in returns, weighting 9.64 - 10.03 ppg. Circ until returns clean up. Tag stripper. Circ until returns clean up. Mix more citric in cuttings box to reduce dirty vac pH. Load BOT tools to rig floor for next milling run. PJSM for pulling CSH. Break off injector and set it on legs. Break off CT riser. Drop 1/2" ball to circ sub, open at 3,500 psi. Stand back 39 stds of 1-1/4" CSH. SAFETY MEETING. PJSM for pulling logging tools. Radioactive hazards and crew positions were discussed. Pull logging tools. Load out tools for download. Recover 1/2" ball from circ sub. Punted: 11/252008 11:02:J8 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code NPT ',10/26/2008 22:40 - 23:20 0.67 EVAL P 23:20 - 00:00 0.67 EVAL P 10/27/2008 00:00 - 00:30 0.50 EVAL P 00:30 - 00:50 0.33 EVAL N 00:50 - 02:30 I 1.671 EVAL I P 02:30 - 03:20 0.831 BOPSUf~P 03:20 - 03:30 0.17 EVAL P 03:30 - 04:00 0.50 EVAL N 04:00 - 05:50 I 1.831 EVAL ( N 05:50 - 08:00 I 2.171 CEMT I N 08:00 - 08:15 0.25 CEMT N 08:15 - 08:35 0.33 CEMT N 08:35 - 10:00 1.42 ~ CEMT ~ N 10:00 - 12:00 2.00 CEMT N 12:00 - 12:20 0.33 CEMT N 12:20 - 13:20 1.00 CEMT P 13:20 - 16:00 2.67 CEMT P Start: 10/16/2008 Rig Release: 10/30/2008 Rig Number: N1 Page 9 of 12 ~ Spud Date: 8/17/1982 End: 10/30/2008 Phase Description of Operations LOW ER1 After download, depth correction is -56 ft. LOW ERi Cut off CT connector and install new one for milling. Pull test to 35 Klbs, PT to 3,500 psi, good. LOWERI Pull test CT connector to 35 Klbs, PT to 3,500 psi, good. DPRB LOWERI Piece of debris is seen in the CT riser, just below the annular. Pull CT riser off above the annular to investigate. Remove several pieces of annular rubber. Replace CT riser section. LOWERI M/U swizzle stick to jet stack. Jet stack 2 passes, up and down. Break off CT riser, open lower BOP doors to check for cement. LOWERI Function test BOPs. LOWERI SAFETY MEETING. PJSM for picking up BHA. Lifting, crew positions were discussed. DPRB LOWERI P/U BHA #7 - 3.80" Diamond speed mill, 2-7/8" Xtreme, 5/8" circ sub, 3/4" Disconnect, DBPV, 2 jts PH6, CT connector. BHA OAL = 77.67 ft. DPRB LOWERI RIH BHA #7 to 7948', motor stalled Start to see weight bobbles at 7,200 ft, go to 2.5 bpm here. DPRB RUNPRD Drill soft cement from 7948' -_8000', washing to 8146', 2.70 / 2.70 bpm, 1824 psi, FS 1631 psi, WOB 3 - 4.5k, ROP 200fph, Dn Wt 15k, IA 0 psi, OA 23 psi, litely contaminated cement returns, MW out 8.45ppg DPRB RUNPRD W iper trip to 7900', 2.69 bpm, 1718 psi, Up wt 32.5k off btm DPRB RUNPRD RIH to 8146', 2.67 bpm, 1714 psi, Dn wt 12.2k at 7900', Dn wt 14.6k at 8140', cement contaminated returns, MW out 8.5 - 8.7PP9 DPRB RUNPRD Washing from 8146' - 8501',TOL, to ed several times, motor stalled each time, 2.70 / 2.70 bpm, 1875 psi, FS 1850 psi, WOB .Ok, ROP 525fph, Dn Wt 13.2k, IA 0 psi, OA 23 psi, litely contaminated cement returns, MW out 8.45 - 9.5ppg, sweeping hole with 20 bbl GeoVis pills, cement contaminated return on btms up, MW out at 10.1 ppg, cleaned up to 8.31 ppg DPRB RUNPRD POH to BHA 7, 2.82 bpm, 1736 psi, MW out 8.31 ppg DPRB RUNPRD POH, pull back inject, LD 3.80" cleanout assy RUNPRD MU swizzle stick, stab injector, wash thru stack, slowly, POH, pull back injector, LD swizzle stick, cap off lubricator RUNPRD Break circ thru kill line, closed choke, pressure test liner lap to 2029 psi high, Pressure bled down to 1721 psi ih 15 minutes, c ecked surface lines, found leak in possum belly from choke line, released pressure to 0 psi, test surface lines to 2000 psi, ok Second retest liner lap to 2007 psi, lost 205 psi in first 15 minutes, lost 117 psi in the second half of 30 mins Third retest liner lap a third time to 2087 psi, lost 139 psi in first 15 minutes, lost 97 psi in second half of 30 mins Liner Lap Tests First Second Third SI 2029 2007 2087 5 mins 1875 1915 2018 Nrintea: t v[bi~uua t t:ucssS Hnn BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 i Date ;From - To Hours Task ,Code NPT Phase ~ Description of Operations 10/27/2008 13:20 - 16:00 2.67 CEMT P RUNPRD 10 mins 1783 1849 1978 15 mins 1729 1802 1943 20 mins leak 1758 1912 25 mins 1718 1875 30 mins 1685 1846 16:00 - 16:30 0.50 EVAL N DPRB LOWERI RU handling equipment, PU tools to rig floor 16:30 - 16:45 0.25 EVAL N DPRB LOWERI PJSM reviewing procedure, hazards and mitigation for M/U mill, motor and SWS Memory CNL/GR logging tools. 16:45 - 20:00 3.25 EVAL N DPRB LOW ERi M/U Memory logging / Cleanout BHA 8 with 2.30" diamond mill, motor, 2 jts 1-1/4" CSH, SWS Carrier, Circ sub, Hyd disc, 78 jts 1-1/4" CSH, Hyd Disc, 2 jts PH6, locking swivel with PAC connections, X-O and Baker CTC. BHA OAL = 2587', Stab Injector. 20:00 - 21:10 1.17 EVAL N DPRB LOWERI RIH BHA #8. 21:10 - 00:00 2.83 EVAL N DPRB LOWERI Tag at 8,507 ft and stall. Pick up and mill through it at 20-60 fUhr with 200 psi motor work. 21:25 -Stall at 8,515.8 ft and very slow progress, likely the Aluminum profile. Mill at 1.46 / 1.42 bpm ~ 1,570 psi Free Spin. Continue milling down to 8,516.5 ft. 10/28/2008 00:00 - 01:00 1.00 EVAL P LOWERI Continue milling aluminum insert. 00:25 -Break through at 8,516.9 ft, total of 3 hrs spent milling the profile. Run up and down through it twice, clean passes, then pull up to 8,000 ft to start logging. 01:00 - 03:30 2.50 EVAL N DPRB LOWERI Log down from 8,000 ft at 30 fUmin. Ta at 10,901 ft, 2 times, PBTD un orrected. Start pert pill down CT, pick up and flag CT at 10,788 ft (8,200 ft EOP, orange). 03:30 - 05:10 1.67 EVAL N DPRB LOWERI La in erf ill from TD. Log up at 60 ft/min. POOH after 8,000 ft. 05:10 - 05:20 0.17 EVAL N DPRB LOWERI SAFETY MEETING. PJSM for standing back CSH. Crew positions and overhead loads were discussed. 05:20 - 06:00 0.67 EVAL N DPRB LOWERI Break off CT riser and stand back. Stand back 1-1/4" CSH 06:00 - 09:00 3.00 EVAL N DPRB LOW ERi PJSM for standing back CSH, crew positions, overhead loads and handling precautions for radio active sources were discussed, POH, Stand back 1-1/4" CSH, LD MCNL tools, recovered source, mill and motor 09:00 - 11:00 2.00 EVAL N DPRB LOWERI M/U swizzle stick, jet stack up and down, break out injector, closed master and swab valves, suck out stack, open lower BOP doors to check for cement, no cement found, volu^^e test stack to 3500 psi, ok 11:00 - 15:00 4.00 EVAL N DFAL LOWERI Offload MCNL tools and source on rig floor, PJSM reviewing procedure, hazards and mitigation for source and SWS Memory CNL/GR logging tools. NO DATA. M/U Memory to in BHA 9 with Nozzle - 5/8" hole, SWS Carrier, Circ sub, Hyd disc, 80 jts 1-1/4" CSH, Hyd Disc, 2 jts PH6, locking swivel with PAC connections, X-O and Baker CTC. BHA OAL = 2575', Stab Injector. 15:00 - 16:00 1.00 EVAL N DFAL LOWERI RIH to 8000'. 16:00 - 17:40 1.67 EVAL N DFAL LOWERi Log down at 30 fUmin. ,45 bpmC~ 190 psi.Tag TD at 10900.1. Nnrnea: i vzs~zuuu i i:ucso Nm • BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ' Task Code NPT Phase Description of Operations 10/28/2008 17:40 - 19:30 1.83 EVAL N DFAL LOWERi Log up at 60 ft /min. Lay inl5bbl pert pill. POOH after 8,000 ft. 19:30 - 19:45 0.25 EVAL N DFAL LOWERI Tag stripper. PJSM for standing back CSH. Crew positions, well control were discussed. 19:45 - 21:15 1.50 EVAL N DFAL LOWERI Open circ sub with 1/2" ball. Stand back 1-1/4" CSH. 21:15 - 21:30 0.25 EVAL N DFAL LOWERI SAFETY MEETING. PJSM for pulling logging source. Handling precautions were discussed. 21:30 - 22:00 0.50 EVAL P LOWERI Load out logging tools, download data. Load pert gun running equipment to rig floor. After downloadin to sand correctin de th +6 ft PBTD was found at 10,905.6 ft (10,908.8 ft on Liner tally). 2" Log faxed to Anc. 22:00 - 22:15 0.25 PERFO P LOWERi SAFETY MEETING. PJSM for running pert guns. Crew positions and handling guns was discussed. 22:15 - 00:00 1.75 PERFO P LOWERi Run pert gun BHA: Bottom Nose, SWS Perforating Guns, SWS Firing Head, BTT HYD DISC, 5/8" BALL SEAT, XO, 28 JTS OF 1-1/4" CSH, avg/ jt 30.99', X-OVER, BOT HYDRAULIC DISCONNECT, 3/4"BALL, BOT Dual BPV's, X-O, 2-3/8 PH-6 Tubing, BOT X-O, Lockable swivel, X-O, BOT SLIP TYPE CTC BHA OAL = 2,673.63 ft 10/29/2008 00:00 - 03:00 3.00 PERFO P LOWERI Continue M/U perf assembly. 03:00 - 05:00 2.00 PERFO P LOWERi RIH with BHA #9. Tag at 10,901 ft, correct to PBTD of 10,905.6 ft. Pick up to find a ball drop spot. 05:00 - 05:55 0.92 PERFO P LOWERI Drop 1/2" steel ball, launch with 1,500 psi. Chase ball with new Flo-Pro, 5 bbls ahead and 10 bbls behind. After 30 bbls slow pump to 0.6 bpm to watch ball land on seat. Ball lands at 50.6 bbls, pressure up and start to move CT uphole. Fire guns on the fly at 3,500 psi at 10,900 ft. Good shot indication from acoustic sensor and fluid losses. Perf intervals 9190-9480' 9570-9940 10060-10280 10420-10900 05:55 - 07:45 1.83 PERFO P LOWERI POOH holding 200-300 psi back pressure while inside liner. Flo ckeck at 8468'. OK. Continue to POH. 07:45 - 09:30 1.75 PERFO P LOWERI Standback CSH tubing 09:30 - 09:45 0.25 PERFO P LOW ERi PJSM for LD spent guns 09:45 - 14:30 4.75 PERFO P LOWERI LD spent guns. 14:30 - 15:00 0.50 PERFO P LOWERI Clear floor and PU nozzle. 15:00 - 16:30 1.50 WHSUR P POST RIH to 2000'. FP with 50/50 MEOH. POH. 16:30 - 16:45 0.25 WHSUR P POST LD nozzle. Stand back injector. 16:45 - 17:30 0.75 WHSUR P POST Set BPV. 17:30 - 19:00 1.50 RIGD P POST Cut and slip drilling line. Unhang blocks. 19:00 - 21:00 2.00 RIGD P POST M/U CT riser to stack. Prep to purge reel. rnntea: iirzoreuuo 11:VY:3if HM BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: 18-06 Common Well Name: 18-06 Spud Date: 8/17/1982 Event Name: REENTER+COMPLETE Start: 10/16/2008 End: 10/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/30/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT_ -Phase Description of Operations 10/29/2008 19:00 - 21:00 2.00 RIGD P POST Pump 40 bbls fresh water ahead then 5 bbls McOH. Purge reel with 1,700 scfm for 15 min. Allow pressure to bleed off. 21:00 - 22:00 1.00 RIGD P POST Break off CT riser, stand back injector. Remove catch basin from around CT riser, prep to N/D BOPs. 22:00 - 00:00 2.00 RIGD P POST N/D BOPs, install tree cap and PT to 3,500 psi, good. Secure tree for travel. Ri released 00:00, final re ort for this well. All further information on G-02B DIMS report. Printed: 11/252008 11:UL:Jtf ann m b ~ BP Alaska ~~~~~° Baker Hughes INTEQ Survey Report BAK Rr 11UGNES a~~ Cumpan}: BP Amoco Field: Prudhoe Bay Site: PB DS 18 Well: 18-06 W'cllpath: 18-06B Date: 10/27/2008 Time: 11:27:52 Pabe: 1 Co-ordinate(NE) Reference: Well: 18-06, True North Vertical ("l'VD) Reference: 18-06A 53.4 Section (VS) Kcference: Well (O.OON,O.OOE,90.53Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Map Zone: Coordinate System: Alaska, Zone 4 Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.46 deg Well: 18-06 Slot Name: 06 18-06 Well Position: +N/-S 1815.28 ft Northing: 5961026.94 ft Latitude: 70 17 53.106 N +E/-W -31.23 ft Easting : 691505.96 ft Longitude: 148 26 56.465 W Position Uncertainty: 0.00 ft Wellpath: 18-06B 500292079702 Drilled From: Tie-on Depth: 18-06A 8598.96 ft Current Datum: 18-06A Height 53.38 ft Above System Datum: Mean Sea Level Magnetic Data: 8/12/2008 Field Strength: 57688 nT Declination: Mag Dip Angle: 23.21 deg 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.38 0.00 0.00 90.53 Survey Program for Definitive Wellpath Date: 8/12/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 107.38 8307.38 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 8388.00 8598.96 Survey #1 MWD-standard (8388.0 MWD MWD -Standard 8613.00 10945.00 MWD (8613.00-10945.00) MWD MWD -Standard Annotation .~1D TVD ft ft 8598.96 8395.53 TIP 8613.00 8408.73 KOP 10945.00 8682.83 TD Survey: MWD Company: Baker Hughes INTEQ Tool: MWD;MWD -Standard Start Date: 10/23/2008 Engineer: Tied-to: From: Definitive Path BAKER ~~f.~~ b ~ BP Alaska • N~lG ES ~~~~~~ Baker Hughes INTEQ Survey Report INTEQ - __ _ _ _ _ - Company: BP Amoco Date: 10/27/2008 Timr. 11:27:52 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-06, True North Site: PB DS 18 Vertical (TVD) Reference: 18-06A 53.4 Well: 18-06 Section (VS) Reference: Well (O.OON,O.OOE,90.53Azi) VVcllpalh: 18-06B .Survey Calculation Method: Minimum Curvature Db: Oracle Surs~cv ~ --- D1D Incl Azim TVD Sys TVD NIS E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft ~~ - _- -. - 8598.96 19.27 241.49 8395.53 8342.15 -356.33 -1293.51 5960637.78 690222.03 -1290.19 0.00 MWD 8613.00 20.66 242.74 8408.73 8355.35 -358.57 -1297.75 5960635.44 690217.85 -1294.40 10.36 MWD 8633.03 17.82 233.16 8427.64 8374.26 -362.03 -1303.34 5960631.84 690212.34 -1299.97 21.16 MWD 8661.63 16.25 217.67 8455.00 8401.62 -367.82 -1309.29 5960625.89 690206.54 -1305.87 16.73 MWD 8690.93 18.66 201.28 8482.96 8429.58 -375.44 -1313.50 5960618.17 690202.53 -1310.01 18.61 MWD 8720.15 22.03 183.85 8510.38 8457.00 -385.28 -1315.57 5960608.29 690200.71 -1311.98 23.61 MWD 8751.87 29.37 172.45 8538.96 8485.58 -398.95 -1314.95 5960594.63 690201.69 -1311.23 27.80 MWD 8782.29 35.89 162.53 8564.59 8511.21 -414.88 -1311.28 5960578.80 690205.75 -1307.42 27.66 MWD 8812.53 41.86 155.17 8588.13 8534.75 -432.52 -1304.38 5960561.35 690213.11 -1300.35 24.93 MWD 8841.81 47.56 146.59 8608.95 8555.57 -450.43 -1294.31 5960543.70 690223.63 -1290.12 28.32 MWD 8877.31 55.01 138.90 8631.16 8577.78 -472.38 -1277.50 5960522.19 690240.99 -1273.11 26.92 MWD 8907.35 61.32 132.92 8647.01 8593.63 -490.65 -1259.73 5960504.37 690259.22 -1255.17 26.95 MWD 8936.91 68.39 125.86 8659.57 8606.19 -507.57 -1239.05 5960487.99 690280.32 -1234.34 32.22 MWD 8966.93 75.10 120.61 8668.98 8615.60 -523.16 -1215.21 5960473.01 690304.55 -1210.36 27.84 MWD 8997.75 82.74 114.92 8674.90 8621.52 -537.22 -1188.47 5960459.64 690331.64 -1183.49 30.70 MWD 9027.81 88.65 107.62 8677.16 8623.78 -548.07 -1160.57 5960449.50 690359.81 -1155.49 31.18 MWD 9058.11 89.51 103.22 8677.64 8624.26 -556.12 -1131.37 5960442.20 690389.20 -1126.22 14.79 MWD 9089.19 90.18 100.68 8677.73 8624.35 -562.56 -1100.96 5960436.54 690419.76 -1095.76 8.45 MWD 9120.35 89.42 97.12 8677.84 8624.46 -567.38 -1070.18 5960432.51 690450.65 -1064.94 11.68 MWD 9150.89 87.02 93.05 8678.79 8625.41 -570.08 -1039.79 5960430.58 690481.10 -1034.52 15.46 MWD 9183.06 87.54 90.02 8680.31 8626.93 -570.94 -1007.67 5960430.53 690513.23 -1002.39 9.55 MWD 9213.94 88.65 88.14 8681.34 8627.96 -570.45 -976.81 5960431.82 690544.06 -971.54 7.07 MWD 9243.88 89.66 85.54 8681.78 8628.40 -568.80 -946.92 5960434.23 690573.90 -941.67 9.32 MWD 9273.62 88.50 82.21 8682.26 8628.88 -565.63 -917.36 5960438.15 690603.36 -912.14 11.86 MWD 9303.50 89.63 80.49 8682.75 8629.37 -561.13 -887.83 5960443.40 690632.77 -882.64 6.89 MWD 9335.40 90.89 78.05 8682.60 8629.22 -555.19 -856.49 5960450.13 690663.95 -851.36 8.61 MWD 9368.56 89.54 74.14 8682.48 8629.10 -547.23 -824.31 5960458.91 690695.91 -819.25 12.47 MWD 9398.46 90.34 72.06 8682.51 8629.13 -538.54 -795.70 5960468.33 690724.29 -790.73 7.45 MWD 9431.98 91.20 69.72 8682.06 8628.68 -527.56 -764.03 5960480.11 690755.67 -759.16 7.44 MWD 9462.50 91.35 67.45 8681.38 8628.00 -516.42 -735.63 5960491.97 690783.77 -730.86 7.45 MWD 9494.66 90.98 64.65 8680.72 8627.34 -503.37 -706.25 5960505.76 690812.81 -701.60 8.78 MWD 9526.48 88.77 65.19 8680.79 8627.41 -489.89 -677.43 5960519.98 690841.28 -672.91 7.15 MWD 9556.44 89.75 70.31 8681.18 8627.80 -478.55 -649.71 5960532.02 690868.69 -645.30 17.40 MWD 9586.94 88.83 72.43 8681.56 8628.18 -468.80 -620.81 5960542.49 690897.33 -616.49 7.58 MWD 9617.08 89.33 75.98 8682.04 8628.66 -460.60 -591.82 5960551.43 690926.11 -587.57 11.89 MWD 9646.80 89.26 79.89 8682.41 8629.03 -454.39 -562.77 5960558.38 690954.99 -558.57 13.16 MWD 9675.86 89.54 83.18 8682.71 8629.33 -450.12 -534.03 5960563.39 690983.61 -529.88 11.36 MWD 9709.84 89.14 86.82 8683.11 8629.73 -447.15 -500.19 5960567.21 691017.36 -496.06 10.78 MWD 9739.46 89.45 90.34 8683.47 8630.09 -446.42 -470.58 5960568.70 691046.94 -466.47 11.93 MWD 9770.77 89.82 93.55 8683.67 8630.29 -447.48 -439.29 5960568.43 691078.24 -435.17 10.32 MWD 9800.64 90.37 96.37 8683.62 8630.24 -450.07 -409.54 5960566.61 691108.05 -405.39 9.62 MWD 9834.15 91.13 94.12 8683.18 8629.80 -453.13 -376.17 5960564.40 691141.48 -372.00 7.09 MWD 9865.85 91.66 92.03 8682.41 8629.03 -454.83 -344.53 5960563.50 691173.15 -340.35 6.80 MWD 9896.73 92.37 90.20 8681.32 8627.94 -455.43 -313.68 5960563.69 691204.01 -309.49 6.35 MWD 9932.51 92.77 88.10 8679.72 8626.34 -454.90 -277.94 5960565.13 691239.72 -273.76 5.97 MWD 9966.21 90.55 86.02 8678.74 8625.36 -453.17 -244.30 5960567.71 691273.30 -240.14 9.03 MWD 9996.95 89.66 84.18 8678.69 8625.31 -450.55 -213.68 5960571.12 691303.85 -209.54 6.65 MWD 10028.63 89.42 81.37 8678.94 8625.56 -446.56 -182.25 5960575.90 691335.16 -178.15 8.90 MWD 10057.47 89.08 79.25 8679.32 8625.94 -441.71 -153.83 5960581.48 691363.45 -149.77 7.44 MWD 10088.61 89.05 76.20 8679.83 8626.45 -435.09 -123.41 5960588.87 691393.69 -119.41 9.79 MWD 10119.51 87.91 75.60 8680.65 8627.27 -427.56 -93.45 5960597.16 691423.44 -89.52 4.17 MWD 10156.95 89.57 73.86 8681.47 8628.09 -417.71 -57.34 5960607.93 691459.29 -53.51 6.42 MWD 10188.53 89.72 70.99 8681.67 8628.29 -408.17 -27.24 5960618.23 691489.13 -23.50 9.10 MWD BAKER BP Alaska ~ '~~ ,,, ~}} HUGHES ~~'~~~~~~ Baker Hughes INTEQ Survey Report iNTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 18 Well: 18-06 VI'ellpath: 18-06B ~ Date: 10/27/2008 "limn. 11:27:52 Page: Co-ordinate(NE) Reference: Well: 18-06, True North Vertical (TVD) Reference: 18-06A 53.4 Section (VS) Reference: Well (O.OON,O.OOE,90.53Azi) Survey Calculation Method: Minimum Curvature Db: 3 '~i racle Survey, MD Incl Azim 'I'VU Sys TVD N/S E/W MapN MapE VS DLS Tool l ft deg deg ft ft ft ft ft -- ft ft deg/100ft - 10219.13 90.22 68.26 8681.68 8628.30 -397 .52 1.44 5960629.61 691517.53 5.09 9.07 MWD 10250.41 90.80 66.95 8681.40 8628.02 -385 .60 30.36 5960642.26 691546.14 33.90 4.58 MWD 10282.39 90.43 65.66 8681.06 8627.68 -372 .75 59.64 5960655.85 691575.08 63.06 4.20 MWD 10315.99 89.51 63.10 8681.08 8627.70 -358 .23 89.94 5960671.14 691604.99 93.22 8.10 MWD 10349.19 89.54 60.80 8681.35 8627.97 -342 .61 119.23 5960687.49 691633.88 122.37 6.93 MWD 10380.80 90.12 58.57 8681.45 8628.07 -326 .66 146.52 5960704.14 691660.75 149.51 7.29 MWD 10416.37 90.34 56.09 8681.30 8627.92 -307 .46 176.46 5960724.09 691690.19 179.27 7.00 MWD 10447.21 89.48 54.40 8681.35 8627.97 -289 .88 201.80 5960742.31 691715.07 204.45 6.15 MWD 10476.87 88.96 52.63 8681.76 8628.38 -272 .25 225.64 5960760.54 691738.45 228.13 6.22 MWD 10505.23 89.26 51.09 8682.20 8628.82 -254 .74 247.94 5960778.62 691760.30 250.27 5.53 MWD 10536.39 89.79 48.97 8682.45 8629.07 -234 .72 271.82 5960799.23 691783.66 273.96 7.01 MWD 10566.59 88.89 46.53 8682.80 8629.42 -214 .42 294.17 5960820.10 691805.49 296.13 8.61 MWD 10597.60 88.40 45.39 8683.54 8630.16 -192 .87 316.46 5960842.21 691827.21 318.21 4.00 MWD 10629.22 88.74 42.77 8684.32 8630.94 -170 .16 338.44 5960865.46 691848.61 339.99 8.35 MWD 10662.02 89.02 45.40 8684.97 8631.59 -146 .61 361.26 5960889.59 691870.82 362.59 8.06 MWD 10692.68 92.12 50.39 8684.66 8631.28 -126 .06 383.99 5960910.71 691893.02 385.13 19.16 MWD 10723.08 92.61 53.80 8683.41 8630.03 -107 .40 407.96 5960929.97 691916.50 408.92 11.32 MWD 10755.66 92.06 56.64 8682.08 8628.70 -88 .84 434.69 5960949.21 691942.75 435.49 8.87 MWD 10785.58 90.52 58.09 8681.40 8628.02 -72 .71 459.88 5960965.98 691967.52 460.53 7.07 MWD 10819.37 91.07 60.92 8680.94 8627.56 -55 .56 488.99 5960983.86 691996.18 489.48 8.53 MWD 10852.71 90.09 64.42 8680.60 8627.22 -40 .26 518.60 5960999.91 692025.39 518.95 10.90 MWD 10883.31 88.77 67.16 8680.90 8627.52 -27 .71 546.51 5961013.16 692052.96 546.74 9.94 MWD 10901.03 88.12 69.22 8681.38 8628.00 -21 .13 562.95 5961020.16 692069.24 563.12 12.19 MWD 10945.00 88.12 69.22 8682.83 8629.45 -5 .54 604.04 5961036.79 692109.91 604.06 0.00 MWD JELLHEAD= McEVOY CTUA TOR = ~ BAKER C - - B. ELEV = 53.38' F. ELEV = NA OP = 3000' lax Angle = 92 ~ 10693' alum MD = N/A alum TVD = 8800' SS DRLG DRAFT 2222• H41/2"CAMCABAL-OSVLN,ID=3.812" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2517' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2971 2969 10 CA-MMG DOME RK 16 11 /07/( ~ 2 5320 5199 0 CA-MMG SO RK 20 11 /07/( ~ 3 7092 6895 6 CA MMG DMY RK 0 11/23/( - 4 7731 7532 3 CA-MMG DMY RK 0 11/23/( Minimum ID = 2.37" @ 9358' 3-3/16" x 2-7/8" XO ID = 3 875' 7880' 9-5/8" X 41 /2" BKR SA BL-3 PKR . , 7913' 41/2" HES X NIP, ID = 3.813" 7932' 9-5/8" X 7" BKR ZXP LNR PKR, ID = 6.313" " " ' TBG, 12.6#, L-80, .0152 bpf, ID = 3.958 1 /2 7934 7935' 41 /2" TT WLEG 7946' 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.187" 7952' T' X 41/2" XO, ID = 3.958" 8022' 9-5/8" X 7" BKR LNR HGR 9-518" CSG, 47#, L-80, ID = 8.681" 8320' 7" LNR, 29#, L-80, ID = 6.184" $$54' 4 1 /2" whipstock 8612' PERFORATION SUMMARY REF LOG: LWD BHI ON 10/25/2008 A NGLE A T TOP PERF: 88 ~ 9190' Note: Refer to Production DB for historical perf data S¢E SPF INTERVAL Opn/Sqz DATE 2.0" 6 9190-9480 Open 10/29!08 2.0" 7 9570-9940 Open 10/29!08 2.0" 8 10060-10280 Open 10/29/08 2.0" 9 10420-10900 Open 10/29/08 41 /2" LNR, 12.6#, L-80, .0152 bpf , ID = 3.958" ~--~ 11934' 8492' -i 4112" HES X NIP, ID = 3.813" 41 /2" N~-LOUT VIANDOW 8614' - 8623' (18-O6B ) 8511' TOP 3-1 /2" x 3-3/16" x 2-718" LINER 8592' 3-1/2" x 3-3/16" XO, ID = 2.786" 9358' 3-3/t 6" x 2-7/8" XO, ID = 2.37" PBTD 10906' 8655' c1BP 2-7/8" LNR, 6.16#, L-80. ID = 2.440" 10942' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09113/82 ORIGINAL COMPLETION WELL: 18-068 1oro7/as Rwo PERr~r ~~ 01!10!98 SIDETRACK COMPLETION API No: 50-029-20797-02 10/29/08 Nordic 1 CTD SIDETRACK (18-066) SEC 24, T11 N, R14E, 4646.32' FEL & 1953.09' F 11/10/08 JCMISV GLV GO (11/07/08) RP Frnlnratinn fAlacltal 1 ~ -0 ~ ~ SATES: W ELL ANGLE > 70° ~ 8950' 8~ > 90° BOPE Sketch for 18-06B Perto Drill Maunder, Thomas E (DQA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 15, 2008 10:20 AM To: 'Rixse, Mel G' Subject: RE: BOPE Sketch for 18-06B Permit to Drill ~cs-_ 1~ Mel, Nothing further is needed. twill place a copy of this message in the well file. Tom Maunder, PE AOGCC Page 1 of 1 From: Rixse, Mel G [mailto:Mel,Rixse@bp.com] Sent: Tuesday, October 14, 2008 4:39 PM To: Maunder, Thomas E (DOA) Subject: BOPE Sketch for 18-06B Permit to Drill Tom, I attached the smaller BOPS sketch for 2" CTD on the Permit to Drill request for well 18- 066. I would like to correct that proposed BOPE to the following: BOPs from top down will include: Annular, TOT double gate (Blind/Shears, 2-3/8" pipe/slips), mud cross, TOT double gate (2-3/8" x 3-1/2 VBR's, pipe/slips, 2-3/8" pipe/slips), and XO to top of swab valve. Attached is the corrected BOP sketch. Please let me know if you approve of this change and if I need to do anything additional. Nordic 1 is expected to move to DS18-066 on Thursday, October 16th. Sincerely, Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 -Office (907)223-3605 -Cell «BOP Stack Sketch for 18-066.pdf» 10/15/2008 • are ^L' W ~_ ~ 18-06B BAG Dowell Blind/Shears TOTs of pipes 2 318" combi ram/slips Mud Cross I I Mud Cross cross of blind/shears variable bore pipe 3 1/2"-2 718" TOTs 2 3/8" combi ram/slips Swab Val Flow Tee C~ ALASSA OIL A1~TD GA.S CO1~T5ERQATIOlQ CO1~II-IIS51O1~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 r SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-06B BP Exploration Alaska Inc. Permit No: 208-148 Surface Location: 835' FNL, 251' FEL, SEC. 24, T11N, R14E, UM Bottomhole Location: 697' FNL, 277' FWL, SEC. 19, T11N, 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 iri 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). Si erel Daniel T. Seamount, Jr. Chair DATED this ~? day of October, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' STATE OF ALASKA /D->-D~ µ ALASKA AND GAS CONSERVATION COMMISSI~ ~ I,(7` ~ PERMIT TO DRILL 20 AAC 25.005 w~ ~~,~~~ 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. S ecify 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 18-068 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-6612 6. Proposed Depth: MD 10945' TVD 8625'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028307 ~ 028321 Pool FNL, 251 FEL, SEC. 24, T11 N, R14E, UM 835 Top of Productive Horizon: 1237' FNL 1676' FEL SEC. 24 T11N R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2008 , , , , Total Depth: 697' FNL, 277' FWL, SEC. 19, T11N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,700' 4b. Location of Well (State Base Plane Coordinates): Surface: x-691506 y-5961027 Zone-ASP4 10. KB Elevation (Hei ht above GL): 53.38' feet 15. Distance to Nearest Well Within Pool: 182' 16. Deviated Wells: Kickoff Depth: 8630 feet Maximum Hole A le: 90 d Tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3290 Surface: 2410 Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data ~-~n"X~~e' 8.81#/6.2# STL/TCIt ' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11934' Total Depth TVD (ft): Plugs (measured): 7' 10700' Effective Depth MD (ft): 11846' Effective Depth TVD (ft): 8697' Junk (measured): None asin Len th Size ement Volume MD TVD Conductor /Structural ' Surface Intermediate Liner - , Perforation Depth MD (ft): Above Plug: 9100' -10100' Perforation Depth TVD (ft): 8686' -8689' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot. ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal A royal: Commission Representative: Date: 22. I hereby certify that t e foregoing is true and correct. Printed Name Jo 5NA t e Si natur Contact Mel Rixse, 564-5620 Title En ineerin Team Leader ~ er MamelNurt~er Phone 564-4711 Date Q 23 4 p Term Hubble, 56414628 C Permit To Drill o?D '/~~ API Number: 50-029-20797-02-00 Permit Ap royal ~ t • O See cover letter for Conditions of Approval If box is checked, well may not be used to explore for, test, or produce coalbed met1hane, gas hydrates, or gas contained shales: Samples Req'd: Yes U No Mud Log Req'd: ^ Yes ~No HrS Measures: ~ Yes ^ No Directional Survey Req'd: (Yes ^ No Other: '~~.~ PS ~~~~ ~5~ Its Date APPROVED BY T COM~SM.SIIONER Fonn 10-401 Revised 12/2005 suomit m uupucate a f ~ ~t • DS18 - 06B - Coiled Tubing~illing To: Tom Maunder Petroleum Engineer ~p Alaska Oil & Gas Conservation Commission IJ From: Mel Rixse CTD Engineer Date: September 18, 2008 Re: 18-066 Application for Permit to Drill Request CTD Drill and Completel8-06B program: Saud in November 1.2008 Pre-Rig Work: 1. O PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi 2. O MIT-OA DONE 05-Apri12008 3. O MIT-IA. DONE 13-July-2008 4. S Drift to 8700'MD for Baker 4-1/2"" monobore whipstock. 5. S Set CIBP C 8660' MD 6. O MIT -Tubing to 1000 psi 7. E Set Baker 4-1/2" Monobore Whipstock (TOWS 8630' MD) 8. O Function test LDS. 9. O Set BPV 10. O Bleed production flow lines and GL lines down to zero and blind flange 11. O Remove wellhouse, level pad, drill mouse hole. Rig Sidetrack Operations: (Scheduled to begin on December 1, 2008) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. Mill 3.80" window at 8630'. Drill build/turn section with 4.25" bicenter bit, and land well. Drill lateral section to 10,945' MD w/ resistivity log. Run 3-1 /2"x 3-3/16"x 2-7/8" solid liner w/cementralizers to TD. Place liner top at 8580' MD. Cement liner from TD to TOL (8580'MD) with 15.8ppb cement. Clean out liner/Run MCNUGR/CCL log. Test liner lap to 2000 psi. Perforate per geologist. Set liner top packer (if fails liner lap test) Freeze protect well to 2500' with diesel. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU test separator, flow test well. September 15, 2008 DS18 - 066 - Coiled Tubing~illing 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: 4-1/8" Casing Program: • 3-1/2", 8.81#, L-80, STL connection solid liner - 8580'MD - 8610' MD w/ liner top packer. • 3-3/16", 6.2#, L-80, STL TC-II connection solid liner - 8610'MD - 9370' MD. • 2-7/8", 4.7# , L-80, STL connection Solid liner - 9370'MD - 10,945' MD. • A minimum of 18.5 bbls 15.8 ppg cement will be used for liner cementing. (TOC 8580'MD) 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 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line - 24,700' Anticollision Summary • L2-13 - 182' ctr-ctr, Status: Producing • 18-23 - 740' ctr-ctr, Status: Producing • 18-31 - 1161' ctr-ctr, Status: Shut-in, Plug set in production tubing. Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCUCNL log will be run. Hazards • The maximum recorded H2S level on DS 18 is 20 ppm on 18-18B(06-28-2008). Drill Site 18 is not an H2S pad. • Lost circulation risk is low. No fault crossings are expected. Reservoir Pressure • Res. press. is estimated to be 3,290 psi at 8,800'ss (7.2 ppg EMW). Maximu dace pressure with gas (0.10 psi/ft) to surface is 2410 psi. Mel Rixse CTD Engineer September 15, 2008 DS18 - 06B - Coiled Tubing~illing = cw LHEAD= IueEVOY C'NATOR = BAKER C KB. B.H/= 53.38' BF. aEV = NA KOP= Mix Ask _ _ Datum AiD = Dsh+m ND = _ 3000 i8_®.9154' WA 880D' S5 113.3/8' CSG 72i. L-8D. D = 12.347' I Minimum ID = 3.812" ~ ~' 4-1t2" CAMCO BAL-0 SVLN II 4.112' ~ 9.518' CSO, 47#, L-BQ ID = 8.891' I 7' LNR 29i L-80. D = 8.184' PBiFORATK74 SUMIMRY REF LOOc LlND SPStRY SUN CN 01109A8 AN6LEATTOPP&tF. 88 ®9100' Note: Refer to Ro~etion DBfar hietarieel peA dste ~ZE SPF MEINAL OpNSot DATE 2718' 4 9100-9360 O 11/27100 2718' 4 9450 -9670 O 11/27100 2718' 4 9600 -10100 O 1126A0 23M' 4 10790 -10845 C 01n 7188 23/4• a 11005-11120 c o1n7/88 23N' 4 11230-11610 C 01n7/!b 2314' 4 11620- 11855 C 01n7188 23M' 4 11690- 11710 C 01n7198 2314' 4 11730-11790 C 01n7188 2314' 4 11800-11820 C 01n7188 (3AS LR MAIIDRELS ST e4D TVD Dam/ TYPE V LV LATdi PDttT DATE 2971 2~8 1o t~ MwD Dear Rlc o o7n ~ 2 5320 s199 a ~alwwc3 oMr RK o o7n3roa 3 7082 8885 8 CA•MNG DAIY RK 0 11/13ro5 4 7731 7532 3 CA-A/ND DMY RK 0 11!23105 9~518'X4iR'BKRSAM.-3PKRD=3.875" ~I 4t/1'HESXNP. D=3.813' 45/8"X7' BKR ZXP LNR PKR D = 8.313' I 41x2' TTYYLBCi X519' X 7' BKR HMC LNR HciR ID = 8.187" 7' X 41lY XO, D = 3.958' 8.518'X7' BKR LNR HOR 7• II~LLaurllNUOO~w I 8375' -8400' (OFF tMiPSTOCK ) i 8182' 4112' HES X N~ ID = 3.815' 139' 1-1 4-1R" AIEAS JT (ZB) 10159' 4112' MJ1S JT (28 ) 1070Q' 2-11Y 03P (04lOB/04) 11175' 4112' YYRD CBP CIM, 01/20102 ~ PaTO H „gas' r 4112' LNR 12.89. L-iM..0152 bef . ID = 3.856' DATE REi/ BY CDNMBITS DATE 08113!62 OItlOMML C04NR.ETION t01D719i R1MO otno199 atDErteACtc coMn~enat --- 07A770S KJB/JMD PiAL®WRDP(051Dd0~ om9a9 Rr.11AD aLV oro (07n3109) PRUO~IOE BAY UNR IA1aL: 18.06A P8iA1R No:'197247D ARNo: SO.029~~787-Ot 711 N, R14E 4848.32' FEL 81963.09' Brr Eeptontten (Atssk:l ~s-osA s sAr~TYNOT~: wsu. Aflcxe> 70• ~ e99o' a > 90° ~ 9265'. MLAS JT DAMAGED RROM MILl.91G ~2~ 41R'G#M008AL-OSVLN. D=3.812' September 15, 2008 DS18 - 066 - Coiled Tubin~illing cNv (:I LIA IVK= tlA KtltG KB. ELEV = 53.38' BF. ELEV = NA KOP = 3000' Max Ar19k = )6 !4 9454' 1 ~ -~ 6 B $AFE7Y NOTES: W ElL ANGLE> 70° ~ 89$0' a > 90° Proposed CTD Sidetrack ~9285~' MLASJT~AMAGEDFRDMMILLING CAMCO BAL-O SV LN , ID = 3.812" GAS I IFT MANDRELS Minimum ID = 3.812" ~ 2222' 4-1/2" CAMCO BAL-O SVLN ID = 3.958" 8890' 412' F£SXNP, ID=3.813" P6iFORATION SIduNAARY REF LOG: LWD SPERRY SUN ON 01/09/98 ANGLE AT TOP FERF: 88 ~ 9100' Note: Refer to Production DB for historical pert data S¢E SPF INTBiVAL OpNSgz DOTE 2-7/8" 4 9100 -9360 O 11/27/00 2-7/B" 4 9450 -9670 O 11/27/00 2-7/8" 4 9800 - 10100 O 11 /26100 2-3/a" 4 10790- 10845 C 01/17/98 2-3/a" 4 11005 - 11120 C 01 /17/98 2-3/a' 4 11230 - 11610 C 01 /17/98 2-314" 4 11820 - 11656 C 01 /17/98 2-3/a' 4 11690 - 11710 C 01/17/98 214" 4 11730 - 11790 G 01 /17/98 z-3/a' a 11600 - 11820 c ov17/sfi ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2971 2969 10 CA-MMG DMY RK 0 07/13/08 2 5320 5199 0 CA-MMG DMY RK 0 07/13/08 3 7092 6895 6 CA-MMG OAAY RK 0 11/23/05 4 7731 7532 3 CA-MMG DRAY RK 0 11/23/05 7880' i--i 9-518' X 4-1/2' BKR SABL-3 PKR, ID = 3.875" ~ 7913' 41 /2' HES X NIP, ID = 3.813" 7932' 9-5/8" X 7' BKR ZXP LNR PKR, ID = 8.313' 7936' 4-112" TT WLEG 794$' 9-5/8" X 7" BKR HMC LNR HGR, ID = 8.187' 7962' 7' X 4-1 /2" XO, ID = 3.958" 8022' 9-5/8" X 7" BKR LNR HGR T' MA.LOUTVIANOOW 8375' - 8400' (OFF WHIPSTOCK ) $482' 4-1/2' HES X NIP, D= 3.813' 8540' BOT KB Packer $580' TOP 3-117' x 3-3116" x 2-718" LINER 9200' 3-3116" x 2-716" XOV ER DOTE REV BY COMMENTS DATE 08/13/82 ORIGINAL COMPLETION 10/07/85 RWO 01/10198 SIDETRACK COMPLETION 07/07/08 KJB/JMD PULLED WRDP (05/08/08) 07/18/08 R/JMD GLV CJO (07!13/08) 08/21/08 MSE PROPOSED CTD ST ~cTM,olrxvo2 ~ ~pf , 10 = 3.958' H 11934' PRUDHOE BAY UNR WELL: 18-068 PERMR No: API No: 50-029-20797-02 T11 N, R14E, 4848.32' FEL 8 1953 BP Exploration (Alaska) September 15, 2008 by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P BAKER ' ~s I[NTEQ Company: BP Amoco Date: 9/9!2008 Time: 09:59:45 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-06, True North '~~ Site: PB DS 18 Vertical (TVD) Reference: 18-06A 53.4 Well: 18-06 Section (VS) Reference: Well (O.OON,O.OOE,70.OOAzi) Wellpath: Plan 2, 18-066 --- Survey Calculation Method: Minimum Curvature llb: Sybase - Field: Prudhoe Bay __ _ _ - -- North Slope UNITED STATES Map System:US State Plane Coordinate System 192 7 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 18 TR-11-14 UNITED STATES :North S lope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.46 deg Well: 18-06 Slot Name: 06 18-06 Well Position: +N/-S 1815.28 ft Northing: 5961026.94 ft Latitude: 70 17 53.106 N +E/-W -31.23 ft Easting : 691505.96 ft Longitude: 148 26 56.465 W Position Uncertainty: 0.00 ft Wellpath: Plan 2, 18-066 Drilled From: 18-06A Tie-on Depth: 8598.96 ft Current Datum: 18-O6A Height 53.38 ft Above System Datum: Mean Sea Level Magnetic Data: 8/12/2008 Declination: 23.21 deg Field Strength: 57688 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.38 0.00 0.00 70.00 Plan: Plan#2 Date Composed: 8/12/2008 Copy Mel's Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets _._ _ Map Map <---- Latitude ----> _ <--- Longitude --->~ ~ Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Die ft - ft _ft ft ft 18-066 Polygon 53.38 -341.78 -1463.23 5960648.00 690052.00 70 17 49.743 N 148 27 39.117 W -Polygon 1 53.38 -341.78 -1463.23 5960648.00 690052.00 70 17 49.743 N 148 27 39.117 W -Polygon 2 53.38 -367.64 -880.67 5960637.00 690635.00 70 17 49.489 N 148 27 22.135 W -Polygon 3 53.38 -152.40 -101.88 5960872.00 691408.00 70 17 51.607 N 148 26 59.435 W -Polygon 4 53.38 244.41 539.47 5961285.00 692039.00 70 17 55.509 N 148 26 40.739 W -Polygon 5 53.38 59.17 859.87 5961108.00 692364.00 70 17 53.687 N 148 26 31.399 W -Polygon 6 53.38 -476.48 131.95 5960554.00 691650.00 70 17 48.419 N 148 26 52.619 W -Polygon 7 53.38 -823.91 -1269.44 5960171.00 690258.00 70 17 45.001 N 148 27 33.465 W 18-06B Target 1 8678.38 -573.82 -915.94 5960430.00 690605.00 70 17 47.462 N 148 27 23.163 W 18-06B Target 2 8678.38 -257.95 -42.55 5960768.00 691470.00 70 17 50.569 N 148 26 57.705 W 18-066 Target 3 8678.38 136.26 543.72 5961177.00 692046.00 70 17 54.445 N 148 26 40.615 W Annotation MD TVD. _. _ ft ft 8598.96 8395.53 TIP 8630.00 8424.54 KOP 8650.00 8443.16 End of 9 deg / 100 ft DLS 8660.00 8452.60 4 8670.00 8462.18 5 8700.00 8491.18 6 8715.00 8505.66 7 8730.00 8520.05 8 by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P BAICgt~R ' INTEQ Company: BP Amoco __ - Date: 9/9/2008 Time: 09:59:45 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-06, True North Site: PB DS 18 Vertical (TVD) Reference: 18-06A 53.4 Well: 1 8-06 Sectiou (VS) Reference: Well (O.OON,O.OOE,70.OOAzi) Wellpath: Plan 2, 18-06 -- 6 --- Survey Calculation Method: Minim um Curvature Db: Sybase - J Annotation MD TVD ft ft 8755.00 8543.42 9 8855.00 8621.59 10 8950.00 8659.46 11 9020.00 8669.41 End of 30 deg / 100 ft DLS 9270.00 8683.26 13 9520.00 8682.05 14 9595.00 8681.72 15 9995.00 8680.18 16 10495.00 8678.98 17 10945.00 8678.41 TD Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turu TFO Target ft deg deg ft -- __ ft ft deg/100ft deg/100ft deg/100ft deg 8598.96 19.27 241.49 8395.53 -356.33 -1293.51 - 0.00 0.00 0.00 0.00 - 8630.00 22.35 244.05 8424.54 -361.36 -1303.32 10.34 9.92 8.25 17.65 8650.00 20.55 244.05 8443.16 -364.56 -1309.90 9.00 -9.00 0.00 1 80.00 8660.00 17.76 240.69 8452.60 -366.07 -1312.80 30.00 -27.91 -33.64 200.00 8670.00 15.58 233.49 8462.18 -367.62 -1315.21 30.00 -21.82 -71.97 220.00 8700.00 15.03 198.96 8491.18 -373.71 -1319.72 30.00 -1.81 -115.08 -110.00 8715.00 15.30 181.73 8505.66 -377.53 -1320.42 30.00 1.76 -114.89 -95.00 8730.00 17.66 168.18 8520.05 -381.73 -1320.01 30.00 15.78 -90.35 -65.00 8755.00 23.88 156.22 8543.42 -390.09 -1317.19 30.00 24.88 -47.84 -40.00 8855.00 52.19 138.93 8621.59 -439.53 -1282.27 30.00 28.30 -17.29 -28.00 8950.00 80.35 134.11 8659.46 -501.70 -1222.77 30.00 29.65 -5.07 -10.00 9020.00 83.49 113.13 8669.41 -539.81 -1165.37 30.00 4.48 -29.97 -83.00 9270.00 90.29 83.85 8683.26 -576.05 -921.28 12.00 2.72 -11.71 -78.00 9520.00 90.25 53.85 8682.05 -486.89 -690.77 12.00 -0.02 -12.00 -90.00 9595.00 90.25 44.85 8681.72 -438.09 -633.93 12.00 0.00 -12.00 -90.00 9995.00 90.17 92.85 8680.18 -297.97 -271.68 12.00 -0.02 12.00 90.00 10495.00 90.08 32.85 8678.98 -80.12 153.19 12.00 -0.02 -12.00 -90.00 10945.00 90.05 86.85 8678.41 137.61 528.08 12.00 -0.01 12.00 90.00 Survey -- MD Intl Azim SS TVD N/S E/W MapN°' MapE - DLS VS - - TFO _ Too ft deg -~- deg ft - ft ft ft ft deg/100ft ft deg 8598.96 19.27 241.49 8342.15 -356.33 -1293.51 5960637.78 690222.03 0.00 -1337.37 0.00 MWD 8600.00 19.37 241.59 8343.13 -356.49 -1293.81 5960637.61 690221.73 10.34 -1337.71 17.65 MWD 8625.00 21.85 243.68 8366.53 -360.53 -1301.63 5960633.38 690214.02 10.34 -1346.44 17.56 MWD 8630.00 22.35 244.05 8371.16 -361.36 -1303.32 5960632.51 690212.35 10.34 -1348.31 15.60 MWD 8650.00 20.55 244.05 8389.78 -364.56 -1309.90 5960629.14 690205.86 9.00 -1355.58 180.00 MWD 8660.00 17.76 240.69 8399.22 -366.07 -1312.80 5960627.55 690202.99 30.00 -1358.84 200.00 MWD 8670.00 15.58 233.49 8408.80 -367.62 -1315.21 5960625.95 690200.62 30.00 -1361.63 220.00 MWD 8675.00 15.13 228.08 8413.62 -368.45 -1316.24 5960625.08 690199.62 30.00 -1362.88 250.00 MWD 8700.00 15.03 198.96 8437.80 -373.71 -1319.72 5960619.74 690196.27 30.00 -1367.95 255.22 MWD 8715.00 15.30 181.73 8452.28 -377.53 -1320.42 5960615.91 690195.67 30.00 -1369.91 265.00 MWD 8725.00 16.78 172.27 8461.90 -380.28 -1320.26 5960613.16 690195.90 30.00 -1370.70 295.00 MWD 8730.00 17.66 168.18 8466.67 -381.73 -1320.01 5960611.71 690196.19 30.00 -1370.96 304.09 MWD 8750.00 22.58 158.10 8485.45 -388.27 -1317.95 5960605.23 690198.41 30.00 -1371.27 320.00 MWD 8755.00 23.88 156.22 8490.04 -390.09 -1317.19 5960603.43 690199.22 30.00 -1371.17 329.47 MWD 8775.00 29.31 150.46 8507.92 -398.06 -1313.14 5960595.57 690203.47 30.00 -1370.09 332.00 MWD 8800.00 36.33 145.56 8528.92 -409.51 -1305.92 5960584.31 690210.97 30.00 -1367.23 337.15 MWD 8825.00 43.49 142.07 8548.09 -422.42 -1296.43 5960571.64 690220.79 30.00 -1362.72 341.28 MWD 8850.00 50.73 139.40 8565.10 -436.57 -1284.83 5960557.79 690232.75 30.00 -1356.66 343.97 MWD 8855.00 52.19 138.93 8568.21 -439.53 -1282.27 5960554.90 690235.38 30.00 -1355.27 345.79 MWD 8875.00 58.10 137.71 8579.64 -451.78 -1271.36 5960542.94 690246.60 30.00 -1349.21 350.00 MWD 8900.00 65.51 136.38 8591.44 -467.89 -1256.35 5960527.22 690262.02 30.00 -1340.61 350.70 MWD 8925.00 72.93 135.20 8600.31 -484.62 -1240.06 5960510.90 690278.73 30.00 -1331.03 351.33 MWD by ~' BP Alaska ~- Baker Hughes INTEQ Planning Report B ~R ' ~wr~es INTEQ Company: BP Amoco Date: 9/9/2008 Time: 09:59:45 Page: 3 Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: 18-06, True North Site: PB DS 18 Vertical (TVD) Reference: 18-06A 53.4 Well: 18 -06 Section (VS) Reference: Well (O .OON,O.OOE,70.OOAzi) Wellpath: Plan 2, 18-06B Survey Calculation Method: Minimu m Curvature Db: Syb ase Survey MD -- Incl ___ Azim SS TVD N!S E/W MapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg 8950.00 80.35 134.11 8606.08 -501.70 -1222.77 5960494.27 690296.45 30.00 -1320.62 351.75 MWD 8975.00 81.35 126.58 8610.06 -517.67 -1203.97 5960478.79 690315.65 30.00 -1308.41 277.00 MWD 9000.00 82.49 119.09 8613.58 -531.08 -1183.19 5960465.91 690336.76 30.00 -1293.47 278.20 MWD 9020.00 83.49 113.13 8616.03 -539.81 -1165.37 5960457.64 690354.79 30.00 -1279.72 279.25 MWD 9025.00 83.61 112.54 8616.59 -541.74 -1160.79 5960455.83 690359.42 12.00 -1276.07 282.00 MWD 9050.00 84.25 109.59 8619.23 -550.68 -1137.60 5960447.48 690382.83 12.00 -1257.33 282.07 MWD 9075.00 84.90 106.65 8621.59 -558.42 -1113.95 5960440.35 690406.67 12.00 -1237.76 282.38 MWD 9100.00 85.56 103.72 8623.67 -564.94 -1089.91 5960434.44 690430.87 12.00 -1217.40 282.66 MWD 9125.00 86.24 100.79 8625.46 -570.23 -1065.54 5960429.77 690455.36 12.00 -1196.31 282.90 MWD 9150.00 86.92 97.86 8626.95 -574.27 -1040.92 5960426.36 690480.08 12.00 -1174.56 283.11 MWD 9175.00 87.62 94.94 8628.14 -577.06 -1016.10 5960424.21 690504.95 12.00 -1152.19 283.28 MWD 9200.00 88.32 92.02 8629.03 -578.57 -991.17 5960423.33 690529.92 12.00 -1129.28 283.42 MWD 9225.00 89.02 89.10 8629.61 -578.82 -966.18 5960423.72 690554.90 12.00 -1105.88 283.53 MWD 9250.00 89.73 86.19 8629.89 -577.79 -941.20 5960425.39 690579.84 12.00 -1082.06 283.60 MWD 9270.00 90.29 83.85 8629.88 -576.05 -921.28 5960427.63 690599.71 12.00 -1062.74 283.63 MWD 9275.00 90.29 83.25 8629.86 -575.49 -916.31 5960428.32 690604.67 12.00 -1057.88 270.00 MWD 9300.00 90.29 80.25 8629.73 -571.91 -891.58 5960432.53 690629.30 12.00 -1033.41 270.00 MWD 9325.00 90.29 77.25 8629.60 -567.03 -867.06 5960438.03 690653.69 12.00 -1008.70 269.98 MWD 9350.00 90.29 74.25 8629.48 -560.88 -842.83 5960444.80 690677.75 12.00 -983.83 269.97 MWD 9375.00 90.28 71.25 8629.35 -553.47 -818.96 5960452.81 690701.42 12.00 -958.87 269.95 MWD 9400.00 90.28 68.25 8629.23 -544.82 -795.50 5960462.06 690724.65 12.00 -933.87 269.94 MWD 9425.00 90.28 65.25 8629.11 -534.95 -772.54 5960472.51 690747.35 12.00 -908.91 269.92 MWD 9450.00 90.27 62.25 8628.99 -523.90 -750.12 5960484.13 690769.48 12.00 -884.06 269.91 MWD 9475.00 90.26 59.25 8628.87 -511.68 -728.31 5960496.89 690790.97 12.00 -859.39 269.89 MWD 9500.00 90.26 56.25 8628.76 -498.35 -707.17 5960510.76 690811.77 12.00 -834.96 269.88 MWD 9520.00 90.25 53.85 8628.67 -486.89 -690.77 5960522.63 690827.86 12.00 -815.64 269.87 MWD 9525.00 90.25 53.25 8628.65 -483.92 -686.75 5960525.70 690831.81 12.00 -810.85 270.00 MWD 9550.00 90.25 50.25 8628.54 -468.45 -667.12 5960541.67 690851.03 12.00 -787.11 270.00 MWD 9575.00 90.25 47.25 8628.43 -451.97 -648.33 5960558.62 690869.40 12.00 -763.81 269.98 MWD 9595.00 90.25 44.85 8628.34 -438.09 -633.93 5960572.86 690883.44 12.00 -745.53 269.97 MWD 9600.00 90.25 45.45 8628.32 -434.56 -630.38 5960576.48 690886.90 12.00 -740.99 90.00 MWD 9625.00 90.25 48.45 8628.21 -417.50 -612.11 5960594.00 690904.72 12.00 -717.99 90.00 MWD 9650.00 90.25 51.45 8628.10 -401.42 -592.98 5960610.57 690923.44 12.00 -694.51 90.02 MWD 9675.00 90.25 54.45 8627.99 -386.36 -573.03 5960626.13 690943.00 12.00 -670.61 90.03 MWD 9700.00 90.24 57.45 8627.89 -372.36 -552.32 5960640.65 690963.35 12.00 -646.36 90.04 MWD 9725.00 90.24 60.45 8627.78 -359.47 -530.90 5960654.08 690984.43 12.00 -621.83 90.05 MWD 9750.00 90.24 63.45 8627.68 -347.72 -508.84 5960666.39 691006.18 12.00 -597.08 90.07 MWD 9775.00 90.23 66.45 8627.58 -337.13 -486.19 5960677.55 691028.55 12.00 -572.18 90.08 MWD 9800.00 90.23 69.45 8627.48 -327.75 -463.02 5960687.51 691051.47 12.00 -547.20 90.09 MWD 9825.00 90.22 72.45 8627.38 -319.59 -439.39 5960696.27 691074.88 12.00 -522.20 90.10 MWD 9850.00 90.21 75.45 8627.28 -312.68 -415.37 5960703.79 691098.72 12.00 -497.27 90.12 MWD 9875.00 90.21 78.45 8627.19 -307.04 -391.02 5960710.05 691122.92 12.00 -472.45 90.13 MWD 9900.00 90.20 81.45 8627.10 -302.68 -366.41 5960715.04 691147.41 12.00 -447.83 90.14 MWD 9925.00 90.19 84.45 8627.02 -299.61 -341.60 5960718.74 691172.13 12.00 -423.47 90.15 MWD 9950.00 90.18 87.45 8626.94 -297.85 -316.66 5960721.13 691197.01 12.00 -399.44 90.16 MWD 9975.00 90.17 90.45 8626.86 -297.39 -291.67 5960722.23 691221.98 12.00 -375.79 90.17 MWD 9995.00 90.17 92.85 8626.80 -297.97 -271.68 5960722.16 691241.98 12.00 -357.21 90.18 MWD 10000.00 90.17 92.25 8626.78 -298.19 -266.69 5960722.06 691246.98 12.00 -352.59 270.00 MWD 10025.00 90.17 89.25 8626.71 -298.52 -241.69 5960722.37 691271.97 12.00 -329.21 270.00 MWD 10050.00 90.17 86.25 8626.64 -297.54 -216.71 5960723.99 691296.91 12.00 -305.41 269.99 MWD 10075.00 90.16 83.25 8626.57 -295.25 -191.82 5960726.91 691321.74 12.00 -281.24 269.98 MWD 10100.00 90.16 80.25 8626.50 -291.67 -167.08 5960731.12 691346.38 12.00 -256.76 269.97 MWD 10125.00 90.16 77.25 8626.42 -286.79 -142.57 5960736.62 691370.76 12.00 -232.06 269.96 MWD by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P INTEQ Company: BP Amoco Date: 9/9/2008 Time: 09:59:45 Page: 4 !, Field: Pr udhoe Bay Co-ordinate(NE) Reference: Well: 18-06, True North Site: PB DS 18 Vertical (TVD) Reference: 18-06A 53.4 'i Well: 18-06 Section (VS) Reference: Well (O .OON,O.OOE,70.OOAz i) Wellpath: Plan 2, 18-068 ~-- -- Survey Calculation Method: Minimu m Curvature Db: Sybase Survey - ~ MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS - 'fF0 --- -- Too ft deg deg ft ft ft ft ft degft00ft ft deg 10150.00 90.16 74.25 8626.36 -280.64 -118.34 5960743.39 691394.82 12.00 -207.19 269.96 MWD 10175.00 90.15 71.25 8626.29 -273.23 -94.46 5960751.40 691418.50 12.00 -182.22 269.95 MWD 10200.00 90.15 68.25 8626.22 -264.58 -71.01 5960760.65 691441.72 12.00 -157.22 269.94 MWD 10225.00 90.15 65.25 8626.15 -254.71 -48.04 5960771.10 691464.43 12.00 -132.26 269.93 MWD 10250.00 90.14 62.25 8626.09 -243.66 -25.62 5960782.72 691486.56 12.00 -107.41 269.92 MWD 10275.00 90.14 59.25 8626.03 -231.45 -3.81 5960795.48 691508.05 12.00 -82.74 269.92 MWD 10300.00 90.13 56.25 8625.97 -218.11 17.33 5960809.35 691528.84 12.00 -58.31 269.91 MWD 10325.00 90.13 53.25 8625.91 -203.68 37.74 5960824.29 691548.88 12.00 -34.20 269.90 MWD 10350.00 90.12 50.25 8625.86 -188.21 57.37 5960840.26 691568.11 12.00 -10.46 269.89 MWD 10375.00 90.12 47.25 8625.81 -171.73 76.17 5960857.22 691586.48 12.00 12.84 269.89 MWD 10400.00 90.11 44.25 8625.76 -154.29 94.08 5960875.11 691603.93 12.00 35.63 269.88 MWD 10425.00 90.10 41.25 8625.71 -135.93 111.04 5960893.89 691620.43 12.00 57.86 269.87 MWD 10450.00 90.10 38.25 8625.67 -116.71 127.03 5960913.51 691635.92 12.00 79.45 269.87 MWD 10475.00 90.09 35.25 8625.63 -96.69 141.99 5960933.91 691650.36 12.00 100.36 269.86 MWD 10495.00 90.08 32.85 8625.60 -80.12 153.19 5960950.76 691661.13 12.00 116.55 269.86 MWD 10500.00 90.08 33.45 8625.59 -75.93 155.92 5960955.01 691663.76 12.00 120.55 90.00 MWD 10525.00 90.08 36.45 8625.55 -55.44 170.24 5960975.86 691677.55 12.00 141.01 90.00 MWD 10550.00 90.08 39.45 8625.52 -35.73 185.61 5960995.95 691692.42 12.00 162.20 90.01 MWD 10575.00 90.08 42.45 8625.48 -16.85 202.00 5961015.24 691708.31 12.00 184.05 90.01 MWD 10600.00 90.08 45.45 8625.44 1.14 219.35 5961033.67 691725.20 12.00 206.51 90.01 MWD 10625.00 90.08 48.45 8625.41 18.21 237.62 5961051.19 691743.02 12.00 229.51 90.02 MWD 10650.00 90.08 51.45 8625.37 34.29 256.75 5961067.76 691761.74 12.00 253.00 90.02 MWD 10675.00 90.08 54.45 8625.34 49.35 276.70 5961083.32 691781.30 12.00 276.89 90.03 MWD 10700.00 90.08 57.45 8625.31 63.34 297.42 5961097.84 691801.65 12.00 301.14 90.03 MWD 10725.00 90.07 60.45 8625.27 76.24 318.83 5961111.27 691822.73 12.00 325.68 90.03 MWD 10750.00 90.07 63.45 8625.24 87.99 340.89 5961123.58 691844.48 12.00 350.43 90.04 MWD 10775.00 90.07 66.45 8625.21 98.57 363.54 5961134.74 691866.85 12.00 375.33 90.04 MWD 10800.00 90.07 69.45 8625.18 107.96 386.71 5961144.71 691889.77 12.00 400.31 90.05 MWD 10825.00 90.06 72.45 8625.15 116.11 410.34 5961153.46 691913.18 12.00 425.30 90.05 MWD 10850.00 90.06 75.45 8625.13 123.02 434.36 5961160.98 691937.02 12.00 450.24 90.05 MWD 10875.00 90.06 78.45 8625.10 128.67 458.71 5961167.24 691961.22 12.00 475.06 90.06 MWD 10900.00 90.06 81.45 8625.07 133.03 483.33 5961172.23 691985.71 12.00 499.68 90.06 MWD 10925.00 90.05 84.45 8625.05 136.09 508.14 5961175.93 692010.44 12.00 524.04 90.06 MWD 10945.00 90.05 86.85 8625.03 137.61 528.08 5961177.95 692030.33 12.00 543.29 90.07 3.5 BP Alaska ~~a LEGEND ,6-Dfih6-~~ ,6 D6 n6-o6n~ Ptan 2 18-060 ~u„o.,..xo~~ iwm wm z~ zi~ wrae ~ 'I" '~ ~: - _ BAKER _ . Plang2 Oxx : . WELLPATN DETMU Pl : ,eo6e /- lNJG1~ ~ ~ si ~~ s~i 8 ~ 1 OOmcrOO.O an , Par ,.~.. i,a en aD: 9!99.96 1NTEQ ~ ~,~ ~ ~ a~, _ ~a~~, 9W. Dawa tE-0YY S].]Wt 9 V.fac' Orq~ oEl-W fre~wiTVD 9rrya IYY iO.9O 0.99 D.r ]1.19 F r ~)e NO ' ( M ~ 1 rrT- -` ((', t I h( ~ -1-- i +r _ i T y r 1- I' I I' t i T i l l i 1 ~ ~ ~-'~- ~ L 1~~t ~~-1-i~r~ h 1-'i ~j_ T , t ~1 ~ r t r I { -t t ~ ~ ~ ~ ~I ~ ~ ~ Y +~ r 1 -~T r.... to osa 533e Meawre 0 R %p. 1 . ~_. . . .r '~"1' . l I t~~ ' ll * ... l I 1 _ "" Ce can u Met atl M•,:v Curva:re r - 1 I rl h..,~ i 4 + a-+ +. ~ -~ tT - ~~ ~ -1 . - ~ .~t 1 I .mr9...a... .. .. .. - ,.. .W. .... W, ,.- ,W- *-. r _ -.-1 i` iF 7 , '~'~ r~ h ~r -} +1 - - ~ ~ F + ~ - I -- -.' i~ I t =H ;~ . }~ . ~ $ ~~,,,.D S: _ _ _ i ~ Y ~ s~ii ru wane r Haas, iM ~ i - T ~ { ~_1 - } ~ 1 , '~ , _ i - __. .. *0 I I _ .. h t ~' {4 l _i I _ near nr lav area aW.n a aar w raa afr~wi I -T - -_-______...... -. -.__ ii a Y is aW W a ~ir w,~ ~ ~ i n. f ° ' r~ _ n ii _ r t r L { - _ -.-1 1 - h~ I ~ i 1 I 1 h~ 1 { ~.._ 1 ~ - - ' .: .. , _. _ ~ . a. o r rnn ~9 °~ wa a°'aa 99aar +fEr rear ia°ia 9~i9 iioaa:a9 ::: gar ...a. ralr 1~ a aaaa an.n ~ ~ } I ,., -_. :_ t 1' aNN9...,9~a ~ ~~~ ,r9 aP M~,,.,~, „, ,~ eaohsO• .~E.a~~ ,~ vw o ~ ~ 0 waa.s~raoDas usB a~s C 300 ~ t ~~• F--1 1=`='+ - - ' ~s eszsm ix.zs sel.zz Pom = A ~ 1 _, ~_ .. we ~ta9n as t ~ t' 1 -'}~ p { O _ ~ 0 i - s ~ ~ ~ I i 1 r i {• ~- a ~ M OO~ I ~ i r I _ tt ~ I I f I B ~ ,t j Ir F r 1 ±1 _ I r I azm ~,t{ t ~ 1 r' { 1 ~ t ~ { -- 1 1 , ~~ i aoo- I - 1 ~ F !i 7 I -..~ II .I } I ~ ' ~ t >~ ~i ~11 r I ~ . i - - - ~ .'.. fwo ~ Y i' • .... ~ F. -,. r } } ~ 4 -- t t 1 1 i )_t I i.r ~ ."_- ~ -Y ~ - ~.. . _ I . t .. ... En.. „aa9 _ - - _. , ; ,~ ~. ~~ ~ ;gy s . 1 [ 9 I r-' ~ r --r ~ ~ ~ ' , m mo ma ,~ ,,m , m ,m~ am ~ ~ ~tl ~ .tltl ~ w9.el-Vea:ry.~ [~oowin] ~~ ,m a ,m =m >m .m m~ ~m .m am mo ~e r 1 y l a irk I , 9 ~}~ t~_ ~ I F a / ~ ii 4r i i I t I r ~'~ ''~{ T }• TT ~ . C'- . f I .{ iF i._ fI I: _'~ . f ~` r t I T. ~f. i I ~ . j ~,' . , IFI 11 .. .__. ~, +~ +~ Ii I ~'1 T I { FIY-~t~~ ~ rFl l'I~f ~r~j~ I y~ 1 j ~ 4~~~ ++~ - i+ { 1 ' ' }~ r .'~ ~'f t I ~~ -I. O l I I { .T~ _t . Y e5aa ll ~ .. ~ ' ~ t ~ ~ ~ \ O 0 _"-`- ~'~^~r a O ~ ~ . ~ I n i ~ . l leer °r au~ N>' - I :. -.. ~.. ys~ tsaa feaw f l I I.. T1 r 1 1 1 { i,"YI L ~ ~. ~. . I ~ t 11 ~. 1 ~ f f f - -.. Tr ~ i ~ t T~ I,. I y 1 ~I ~ i I I -f . l ~ ( -~ Y {- ~y 1 I F i t ~ h h Y- l ~~ + ft r ( l i ~ ~ t ~ ~I Y + T s _ _ ersO-. ,69a 1sAS _ It- 4 "; ' - ~ 1 ! 1 1- .. { t 1 4 f _...! r L t _ -~ 1~. _ ~ - T ~ r }. _T_} t ~- I t f. -.. ~ f r i r T l ~.. ! _h f lrr-~~ T - {{ t t ._1-. ~ T f_ .-~ tt i, I t 1 ~ j ~~ . t a ~ -r 1~ L~ { 1-,i _fi 7 t 1 . t 1 r . II . ebuO I ( • _ { t { ~ - - + ~ - r ~ ~ i t + + { - - [ ~ I I ~ 11 ' ' + i I r L 1 { f f - . I 1 __... r _ t -- tr I } ._:.. t I. ~ --.. : Ir 7I + f f I T ~ h t I ~ ~ r t- . I l 1 ~ ~ T ~ ~ T tt + ~T r ~ L ~ 1 ~ ~+ ~ Y ~ t~ .- _ l ,~ .- r Y ~. . , 1 L 7 f 1 ..1~ _~ i t 1 . , } .. 1 ; ~ - _ L + t - ~ t ` ~ ~t, ~ _ ~ ~' +k y • ~ + + ~~ ~';- ;~ ~~= L~ .r ~ ~ $; r ~T ~ it r ~ } ~r 1 , _ i _ _ ~ I , ~ • I ~ i _ ~~ 1 1 h ~ j I . , 1 ( I - ~ , ~ r I t 1 ; l j~ T , ~ T t i t '- t I f r h '' } ~ +I~ ~ r$ r r + ~ ~ ~ t s ;' ~ i E +~ fi ~ la l f t 4- { { t~ ++ } ~l t ~ { i t t?~ ++ -1 $, i }I k 1 , ~ { ~ 1 _ ~ a ~ ~ .. _ ~tl . ; -r„~ ~-, r, j , , , ~ tTTTT i .. , , j-:; , ,- rTn .iaaO .ilm .imO ~zw -+zm -++m -nm r-rte-.~ r,Trj +mo +am l .- +r,--Tr~T uO sm n ~T-~.T o I I ~ , r am zm • '} i ~ i { t~ ~,T, TT ~+~+ - T;-,~;- zao ~o eoO ~~ VeRical Seetion at 70.00' [SOWin] zlO zm + r•, }-Tr r}T -r m +m ss a ~ I . ~~ ; r ~ ,1, r ~ : . r , rj r ~ , ~ . m +m im zm zm mo laO ~ : j , r aaa rao s + ~ 7 m es , O sm i iECEND 12~131L2.13) BP Alaska - `~'~"`~""' ~~~'~ ,6~1;~~) 6AKER 1B-18118181 HUGHES by weuvgTY OETU~J 1019 ,B,BgI 1B-18 ~10 ieA Bt) Plnn 3, BBJ)OY 18.18118-188) 18-IB 10188PBtl ,8.231,x23) NTEQ Pn Tr on YO. 66696 10r3AI B23A) ,a~24118 z4) W~: YeA1c3 10.2011a2CA11 YN.ONU 160fiq 0].OON 18.2011 B-2ML1) nnyy rrqq n~yy iB 241IB-2agL2) V. ~npY ~WJ ~FJW from TVO 18.241PIan 1. 18248) 102] IB-2]) 70.00' 0.00 0.00 Ol.eO 18.2J 1B 2JA~ ---- a-2] 02]8 - 18.2]~t B-2]C) -~ 18.2] 102]D REFERENCE INFORMATION -- tes] tas]DPBt) 1831 1031) Co-ordinate (HIE) Reterence: Well Centre: 78-06, True North teal te3tq) Vertical (TVD) Reference: 18-O6A 53.38 Bat (1BatP81) Fan 2, t008B Section (VS) Reference: Slot - O6 (O.OON,O.OOE) - Planp2 Measured Depth Reference'. 18~06A 53.38 Calculation Method Minimum Curvature s... YP ... .u Tvo • .rus f .u.r o,.a rs... v~ T..~.1 T Plan: Planp2118-Ofi/Plan 2, 18-0681 M Created By: BP Date: 9A/2008 giimulhs to True North Maena~Naaanh: z3. z,° checked: Dace: Rrgle 8095° II SpMUad~p4 fih9gm100] (;~ri~,:ut Iola rnaiiwi~M90]I~~3~O1 x5]0 -maA. till.michaelwi@mlagrun • West(-)/East(+) [100ft1in] W4:LL U!'I:AILJ +~l-S +LI-W ..\arlhing Lading Lalilu0e I.ungilaae Slul Itl 15.15 -J1.21 5961026.91 6915U5.96 ]0°I )'Sl.l Uh\ li8°26'S6.J65W U6 13 S} 0 38 45 98 -105 135 --165 -173 ANTI-COLLISION SETTINGS I~IMrnnv ueraas SURVIiV pROGINM I3P nnry1iO Ucplh 4m Ueplh To Surveylplan Interpolatiun MeihodMD Interval: 50.00 1.1 ,.I, M...°°w„c~,,,.,,~„ Depth Range Frum: 8598.96 70: 10945.00 cwsA x59x va Ix945.W plnnncJ: rlanX2 v4 Maximum Range: 1290.76 Reference Plan: Plantt2 .~: Il~ii~pi2.,i,~r,.ynFn / a a' ~6 ISn ISU \ \ ~ .3~~ ~'~~L2 ~}Pl ,..rN ' a ° 165 . ~ /~ 4~ iss lio 143 i b6 i3~ !/~ b 1 ZS uo g , ~ ~ I i$~ 3 lU U / - 921 N3 7> / ~ ~~ 46 \ ~ \ ~ ~ 6U 5> 45 ,8 rY 69J N P W ~ ^: wl n r (T 3c ~~ ' I`•~ ~, c ~~ ~ b ~ ~ ~G /~ I D - , ~i I ^.f .5 ~~ ~ , ', S: (~ fiS ,S / p6_ : - ~~ ` ~ ~. 4 9U 105 - 1 13 !~ 6 111 / I ~?; 115 111 'sn o0 ISR /i 6 21'. IFS ivn 2-)3P1L2"13A) so ISR X66 IS-11~ 195 ~ / Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre [o Centre Separation [l5ft/in] W 4:LLYA i'il Ut1rAl1.S Tool Pla° S, IB-U6B ~ MWU Yarenl Wrllpulh: ILLUbA 'rho pU MU: XJ9tl.9h IUg: VorakE xer. Uaw~o: IKWA sJ.Jan V.Sectinn Origin Origin xlarling Angle +Y/-S *FJ-W kYOm fVU ]U.W° U.W U.OU l]]X LEGEND - L2-13A (L2-13A), Major Risk - L2-13 (L2-13), Major Risk I8-06 (18-06), Major Risk 18-06 (18-06A), Major Risk lR-IR (18-IS), Major Risk IS-IS (IS-I8A), Major Risk IS-18(18-ISAPBIj, Major Risk --- IS-IS (18-188), Major Risk 18-IR (18-188P81), Major Risk 18-23 (18-23). Major Risk 18-23A (18-23AI. Major Risk 18 24 (18 24AL2), Major Risk IS 24 (Plan 1, lf{-24B), Majur Risk - 18-27 (I8-27), Major Rlsk 18-27 (18-27A), Major Rlsk IS-27 (18-278), Major Rlsk - 18-27 (I8-27C). Major Risk - 18-27 (I8-27D), Major Risk - 18-27 (18-27DP81), Major Risk - 18-31(18-31), Major Risk - 18-31 (I8-31A), Major Risk - IS-31(18-31P81), Major Risk Plan 2, 18-068 - Plan#2 by • n~ secrloN ucrnus iNTE(~ S< MU Aei .N r.w' - g 41 a9 tl59 35.51 3M1U 12151 u E 2. 3 1W59.W 2.55 3 3.3~ 3 -13 3d I I 331aY tl+.d9 -135tl.tla JM11M1? 1521 -I3b163 153 -IS?9.4? 30.W -13M19v1 14d.1d 56?? -l XX -13?unl .131 ~.IY 511.W -1311 Ir _ 3N3.UY 5319 IJtlYI II 95LLW d hall -014.51 -1?tlE.3) 3LLW _ -Snl 1u -1?2'?.)l .13?U.63 tl3 W I S3.tl5 - tl15 M1< tl4d?.US I2W - isz b.55 ~ Itl IWaiW 9LLU5 BAXS tl6)a 61 11161 528LX 12W WW 5<]._9 DS18 - 06B - Coiled Tubin~illing L N~~_ 1..1. dowel) 2" combi aiae/slips Cf055 Mud Cross 2 318" combi aiaelslip 2" combi wipe/slips Swab Valve Flow Tee BAG Mud Cross September 15, 2008 Alaska Department of Natural Resources Land Administration System Page 1 of~' - r,..r: F~~as ~~=Wca~cer's Search State Calains ~+'~L1 ~ 34.15 Alaska DIVR base Summar- File Type: ADL ? File Number: ~ _ ?8321,,, _ ~ Printable C.a. se File_Summ.. ary See Township, Range, Section and Acreage? New Search i fi Yes ~'° No ---. _~_.. _ ._ _ _._._a LpS i`=l~ns~ ~ Case Abstract !Case !]etail ~ Lanni Abstract ~, I-Ilc~: AUL 28321 `'"'` Sc~~~rct~ for Status flat Updates \~ nl II) ail 'O(lti Custonlel~: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL AZ°[`N: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Ty~~e: ~ OIL & GAS LEASE COMP DNK linit.~ 780 OIL AND GAS File Locution: DOG DIV O1L AND GAS Case Status: 35 ISSUED Status Dute: 09/14/1965 Total Acres: 2480.000 Date Initiated : 05/28/1965 Office of PI•imcarv Responsibility: DOG DIV OIL AND GAS I ust Trclnsactian Date: 12/04/2006 Case Subtype : t~S NORTH SLOPF_, Lust Transaction: AA-NRB ASSIGNMENT APPROVED Iti'IeI•idrerrr: l 7~nvrzship: 0"1 IN Kuuge: O15E' Section: 17 Scc~Irr»r :1c°rrs: 6~1~1 Search Fiats tller'ILllan: U ~ulfY/1~IIp: O1I~ Kange: ~1I~I' ti~c'Cllon: 1c~ .1~~c"llC!YI 'It_'rL'~': ~~)~) ALk~ri~lr~nL~ li 7inrn~hii~: 011~~ ,Range: UI~I; Section: 19 S<~~~nun.l<~r<~~_ i;OI ~lI ~ri~Jiun.~ [ I /~)1r2~hr~~: ll I 1 \ Range: l1 I SE 5~~~~~iu~L~ 20 Section Acrc•~.~ f~-1O Legal Description D~-2~~-196 * ** SALE NOTICE LEGAL DESCRIPTION CI-l-1~1 TILti; RISE. U1jII", IBS, 1y, 2024<40.00 Last updated on 10/0112008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28321 &... 10/1/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~2'~ .,,-. -_ .,a ......;r; ._~~ ;as ~~~order's ~w~.r;;b; State Cabins ~~u ~1 5 . Alaska DR Case summary LPG ea~i~ ~ Case Abstract ~ Case Detail ~ Land Abstract ~. Pile: ~DL 23307 ~ ~ search for Status Plat Upda~es ~~ ~~ I~ l (J `O I '2008 Cztsto~TreY: 000107377 131' EXPLORATION (ALASKA) INC PO E30X 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tyke: ~';~_~~ O[L & GAS LEASE COMP DNR Unit: 7~0 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Stu~trs Date: 09/14/1965 7otul Acres: 2560.000 Date Initiated: 05/28/1965 C)ffice ofPrirnar°yResponsibility: DOG DIV OIL AND GAS Lust Tf~ansuction Duce: 12/04/2006 Case Subtti~~e: ~ NORTH SLOPE Last Trcxnsactio~z: AA-NRB ASSIGNMENT APPROVED Ltef•k~'iara: U Township: O1 I N l~'~u~~~~: 014E Secti<»r: 13 Sc~c~~r~ur :acres: 640 Search. ~i~ts Me~'idi~nt ~ L' Tvyt~n~/ti/~: fl l I N I~~rntrc~.~ 014E S~~c/ru~r.~ l ~- Sac /iot2l~c~'es': 640 A1et~idiu~t: I_` To~a~~r~Iti~>.~ ill IN I~rn~~rc.~ 014E Seetian: 23 SE~c~/iurl:4cr•es: 640 llrrrc/iuu: U Totiin.~~6~ii~~ Ol IN Ran~r_ (ll-l}~; Section: 24 ~'~~~~riun Acres: (i-11) Legal Description 0~-?8-196? *SALE NOIICI LEGAL DESCRIPTION* CI-~-128 IIN 1-{E U~LI13,1=1,23,2 260.00 U- 3- 7 Last updated on 10/01/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28307&... 10/1 /2008 TRANSMITTAL LETTER CIiECKLIST WELL NAME ~~~ ~~ ~6,/~ / Developmeint~ Service Eacptoratory Stratigraphic Test Non-Conventional Weil FIELD: f .~~4.~1oE ~.4y POOL: __ ~.c'.~D.~D~' ~~Y ~~" ~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS ~yrlgT (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. . AP[ No. SO- 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 cumber (50- - _~ from records, data and togs 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 contingept 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 frst caught and 10' sample intervals throe h tar et canes. Non-Conventional Well please note the following special condition of this permit: production or production testing of coal bed me~lrane is not allowed for (name of well) until after (Comnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Comoanv Name) must contact the Commission to obtain advance approval of such water well testing ro Rev: 1/112008 WELL PERMIT CHECKLIST Field ~ Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT 18-068 Program DEV Well bore sag ^ PTD#:2081480 Company BP EXPLORATION~LASKA^NC Initial ClasslType DEV 1 PEND GeoArea 890 Unit 11650 On1Off Shore On Annular Disposal ^ Administration 1 Pe[mitisa attached- - - - - - - - - - - - - - - - - - - - RA- - - - - - - - - - - - - - - - - - - - - - - - - 2 _Leasens,mberappropnate. ---- - - --- - - ---- - --- Yes- -- - -- -- - - - ------ - - -- - --- - - --- -- - 3 UnigAeWelinameandnumber- - -- --- ---- - --- - Yes- ------- ----- - -- - ----- ----- - - ----- -- 4 Welllocakedina-defined-P94t. --- ---- -- -- - --- _ Yes- ----- -- - - ------ ----- --- - ----- - 5 )NaillQCatedPropardistancefromdriJlingunitboundary----------------------- -Yes- ----.---------------------------------------------------------- --- B Wall locatedP[opardistanCef[omotberwells------------------------- -Yes- ------------------------------------------------------------ -- ---- 7 Sufficient acreage-available in_drilling unit- - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 If deviated, iswellborePiaiincJuded_--~----- ----- - -- - ------ -Yes - --- -- - -- -- - - ----- ---- - -- -- ------ 9 Operator onlya#fectedpargr--- ------- ---- - -- ------ -Yes- ---- -- -- - ----- - ------- ----- - ---- ----- - - - 10 Operatolbas_appropriate_bondinfgrce------------------------------ -Yes- ------@IanketBand#6194193..----------------------------------------------- 11 Pe[mitoanbaissuedwltboutconsanrati9nordar--------------------------- -Yes- ------------------------------------------------------------------------ Appr Date 12 PermitcanJ~elssuedwithoutadminist[ativa_approval------------------------ -Yes. ---------.------------------------------------------------------- -- - 13 CanpermitJ~eaPR~vedbefore15-dayv~ait--------------------------- -Yes- ----------------------------------------------------------------- - - ACS 101112008 14 _INeIUQCatedwithinareaand_strataa~ih4rlzQdkylnlscti9nOrde[#(putlQ#in_commen~)-(For_ NA-- ------------------------------------------------------------,---------- 15 AJlw~ilawithin114_miles~ea_ofrevi~videniifisd(Forservicewailonly)------------- --NA-- ------------------------------------------------------------------------- 16 Pre•producedinjactor, duration ofpre,productiontessthan3months(forservicewallonly)_ _NA- ---------------_------_---_---_----------.----------------------------- 17 NonGOnven,®asconformsioAS31.05.034(j.t.A)~(b2.A•O)----- --- --- .... - - ~ - ---- ----- --- -- -- ------ ----- ----~--- -- -- -- ---- fngineering 18 Conductorstrigg.Provided------------------------------------ -NA_- ____--COnductorsetinDS1Q•06 (1132.122)..-------------------.--------.--------.-.---- 19 Su_rfacecasiggprotectsalLknpwntl$DWS------------------------------ --NA-- ----.Noaquifars,-A1O46,-Conclusion-5.---------------------------------------------- 20 CMT-voladeg4ale t9citcutateonc9nduct9r$surf_cBg----------------------- --KA_ ------Surface casing set in RS 18•Q6.-__-_---_---_-_____._------_-___---_.-._---_- 21 CMT-voladequatetctie•U.kingstringtoss~rfcsg-------------------------- - NA-- ---.--Producti4n_casingsetin-DS 18-06:------------------------.---------.----------- 22 CMT_wiiJCOVeralllcnownproductivahorizons----------------------------- -Yes- ------------.-------------------,---------------.-..------------------- 23 CasingdesgnsadequateforC,LS&permafrost - - --- - -- --- -Yes --- -- - --- ----- - - ------- --- - -- -- -- - -- 24 Adequate tankage-or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - - - . -Rig equipped with gtaei pits. No-reserve p1S Planned.- All waste_t9 aPP-roved disposal well(s). - - - . - - - - - - - - - 25 If-are-drill,hasal0.403Sorahandonment keen aPPmved-------------------- -Yes- -.---308,342-..----------------------------------------------------------- 26 Adaquate_ate114ora separationpropcsed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ - - - _ Proximity analysis performed, Nearestsegment is P&A podion of OS.18-06A and paths diverge._ - _ _ _ _ _ _ - 27 If-diverterrequiled,daesitmeetre9ulations-___-.___._---_-___--_---_._ . NA_- _--___BOPStackwillalready-be(rlplace.--_--__-_---_-_-_----_--------------------- Appr Date 28 Driping fluid_ program schematic & equip list adequate- -- - - - - - - - - - - - - - - - - - - - - - -Yes . _ - - - _ _ Maximum expected fomlation pressure 7,2_ CMW._ NIW planned 8.6 ppg. - - - _ _ _ _ - _ . - - _ - - _ _ _ - _ - - - _ TEM 10!112008 29 BOPEs,dotheymeetregulaticn ----- - --- - -- - --- - -Yes --- --- - ---- -- - --- - - ---- -- - ----- --- 30 BOPS-press rating appropriate; lest to-(put prig in-cAmmenis)- - - - - - - - - - - - - - - - - - Yes - _ - - - - MASP calculated at 2419psi, 3500_psi_BOP testplanned, _ _ _ _ _ - - - - - - - - - _ - - - - - - _ - - - - . 31 Choke_manif4ldco_mpiieswlAPl_RP•53(May54) -- -- -- - --- - - - -Y~ --- -- - ---- - -- - -- ------ -- - ------ - -- --- --- 32 Workvvilloccurwithout-operationshutdown----------------------------- -Yes- .------------------------------------------------------------------ -- 33 IS presence of 1125 gas probable - - - - - - - - - - - - - - - - - - - - _ - - - - - - _ _ - - - _ _ No- _ - - _ _ - - MinotH2S-is reported at OS 1$. _Mud-should preclude H2S on rg.-Rig has sensors and alarms. - - - - _ .. - _ - - 34 -MechanicaLc9nditionofv,~ilswHhinAQRverifled(F9rservieeweU9nly)------------ -NA-- -----------------------.---------------------------------------------- Geology 35 Pe[miicanbeissuedwlohydrogen-suifidemeasures-_-------------------- ---No_- __--MaxlevelH2$on-DS 18=24ppm_onweJ118.1@B(6I28IOQ),__-_------_-----------------_-. 36 Aata_presanted onpofaniial9verpressurezones- - - - - - - - - - -~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 37 Seismic analysis ofshallpwgaszones_______--------------_------_ _.~- -------------------------------------------------- - ------------------ ACS 10!112006 38 Seabed condition5urvey_(ifQff-shore)_______---_-----------------_- --NA- --_----.---.-------- 39 ContaCtnamelphonefolweek~y_prayressrepcrJs[eKplotatoryon~t)-------------- --Yes -------MBIRixser564-562Q•----------------------------------------------------- Geologic Engineering ' Date Date Date: Commissioner: Com is Commissioner: ~o -3-oA J Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. tapescan.txt **** REEL HEADER *~~° MWD 09/01/13 BHI O1 LIS Customer Format Tape **** TAPE HEADER *~~~ MWD 08/10/25 2254652 O1 3.0" 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 8381.0000: starting Depth STOP.FT 10940.0000: Ending Depth STEP.FT 0.5000: Level spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 18-06B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 53.106"N 148 deg 26' 56.465"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 25 Oct 2008 API API NUMBER: 500292079702 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 24 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 53.36 DMF DF EKB .F 0 EDF .F 53.36 EGL .F 0 Page 1 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 tapescan.txt CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVD55) 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 lob 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 provided by Schlumberger GR CNL dated 28 Oct 2008 from well per Doug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was 4.5 inch liner. Top of window Bottom of window (9) Tied to 18-06A at (10) The interval from feet TvDSS) was not logged drilled from 18-06A through a milled window in a 8613 ft.MD (8355.4 ft.TVD55) 8622 ft.MD (8363.8 ft.TVD55) 8598.96 feet MD (8342.15 feet TVDSS). 10905 feet to 10945 feet MD (8628.1 feet to 8629.4 due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROPJ4VG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 8384.1, 8383.07, ! -1.03613 8391.57, 8389.91, ! -1.6582 8395.5, 8394.26, ! -1.24316 8398.61, 8398.61, ! 0 8402.14, 8401.93, ! -0.207031 8403.59, 8403.8, ! 0.207031 8407.73, 8407.94, ! 0.207031 8409.39, 8409.6, ! 0.208008 8412.92, 8413.75, ! 0.829102 8421.42, 8421, ! -0.414062 8424.32, 8424.53, ! 0.207031 8431.57, 8431.57, ! 0 8434.68, 8434.68, ! 0 8438.62, 8439.04, ! 0.414062 8442.56, 8441.94, ! -0.62207 8444.88, 8444.47, ! -0.414062 8450.69, 8451.1, ! 0.415039 8455.25, 8455.04, ! -0.207031 8460.84, 8461.26, ! 0.415039 8483.65, 8484.27, ! 0.62207 8492.15, 8492.35, ! 0.208008 8496.71, 8497.12, ! 0.415039 8499.4, 8499.82, ! 0.414062 8505.41, 8505.21, ! -0.208008 8512.5, 8512.29, ! -0.207031 Page 2 Borehole Corrected (oHMM) 8516.86, 8517.27, 8527.43, 8528.67, 8530.54, 8531.16, 8532.82, 8533.85, 8538, 8538, ! 8539.45, 8539.45, 8594.11, 8594.53, 8620.02, 8620.44, 8621.47, 8622.1, 8622.92, 8623.96, 8629.29, 8630.53, 8637.37, 8637.78, 8.651.26, 8652.29, 8697.69, 8699.14, 8700.59, 8701.42, 8703.08, 8704.33, 8709.08, 8711.36, 8711.98, 8713.43, 8718.2, 8718.82, 8723.59, 8724.42, 8726.49, 8727.32, 8728.36, 8728.77, 8746.81, 8746.81, 8750.95, 8751.37, 8759.87, 8760.49, 8770.44, 8771.47, 8772.72, 8773.75, 8775.21, 8776.45, 8781.31, 8781.1, 8784.42, 8784.42, 8794.16, 8795.4, 8798.31, 8798.72, 8804.73, 8806.18, 8813.85, 8814.27, 8818, 8819.45, 8826.91, 8828.78, 8829.82, 8831.27, 8832.1, 8833.34, 8837.69, 8839.14, 8840.59, 8841.63, 8843.29, 8843.91, 8867.58, 8868.82, 8870.68, 8872.14, 8880.84, 8882.09, 8888.3, 8888.51, 8895.97, 8896.39, 8917.73, 8918.56, 8925.2, 8926.44, 8933.69, 8934.11, 8941.15, 8942.19, 8945.71, 8945.92, 8951.1, 8950.27, 8956.49, 8957.11, 8974.62, 8974.62, 8989.23, 8989.44, 9016.49, 9017.11, 9046.49, 9047.11, 9179.43, 9178.4, 9244.32, 9243.49, 9262.39, 9262.39, 9384.57, 9383.33, 9961.31, 9961.51, 10023.5. 10024.2. tapescan.txt 0.415039 1.24414 0.62207 1.03613 ! 0 ! 0.414062 ! 0.414062 ! 0.62207 ! 1.03711 ! 1.24414 ! 0.414062 ! 1.03613 ! 1.4502 ! 0.829102 ! 1.24316 ! 2.28027 ! 1.45117 ! 0.62207 ! 0.829102 ! 0.829102 ! 0.415039 ! 0 ! 0.414062 ! 0.62207 ! 1.03613 ! 1.03613 ! 1.24414 ! -0.207031 ! 0 ! 1.24316 ! 0.415039 ! 1.45117 ! 0.415039 1.45117 ! 1.86621 ! 1.45117 ! 1.24414 ! 1.4502 ! 1.03711 ! 0.62207 ! 1.24414 ! 1.45117 ! 1.24316 ! 0.208008 ! 0.415039 ! 0.830078 ! 1.24414 ! 0.415039 ! 1.03613 ! 0.207031 ! -0.829102 ! 0.62207 ! 0 ! 0.208008 ! 0.62207 ! 0.62207 ! -1.03613 ! -0.829102 ! 0 ! -1.24316 ! 0.207031 ! 0.62207 Page 3 10031, 10030.2, 10034.3, 10032.8, 10037.6, 10036.5, 10044, 10043.6, 10046.1, 10045, 10051.4, 10050.1, 10056.7, 10053.6, 10061.7, 10059.4, 10067.5, 10065.2, 10074.2, 10072.9, 10096.9, 10095.2, 10113.7, 10113.1, 10211, 10212.7, 10221.1, 10220.7, 10233.6, 10234, 10237.3, 10238.1, 10241, 10241.7, 10246.4, 10247.1, 10254.1, 10254.1, 10264.7, 10264.1, 10272.2, 10272.2, 10274.7, 10274.7, 10281.3, 10282.3, 10286.3, 10287.1, 10288.8, 10288.8, 10292.1, 10291.7, 10300, 10302.5, 10307, 10308.8, 10310.1, 10311.9, 10336.4, 10335.6, 10394.1, 10394.3, 10398.6, 10398.2, 10400.7, 10400.7, 10412.5, 10412.3, 10492.5, 10491, 10503, 10504.4, 10545.3, 10544.3, 10553.6, 10551.9, 10562.3, 10559.2, 10678.2, 10671, 10682.6, 10675.3, 10702.1, 10693.2, 10714.9, 10709.5, 10736.3, 10730.9, 10742.9, 10738.7, 10802.7, 10799.5, 10811.2, 10807, 10856.4, 10852.7, 10863.4, 10859.1, 10871.5, 10866.1, EOZ END ! BASE CURVE: GROH, Tape Subfile: 1 Minimum record length: Maximum record length: *~~ FILE HEADER ~°°~ MWD .001 tapescan.txt -0.829102 -1.45117 -1.03613 -0.415039 -1.03613 -1.24414 -3.10938 -2.28027 -2.28027 -1.24414 -1.6582 -0.621094 1.65918 -0.415039 0.415039 0.829102 0.62207 0.62207 0 -0.62207 0 0 1.03613 0.829102 0 -0.414062 2.48828 1.86621 1.86621 -0.829102 0.207031 -0.415039 0 -0.208008 -1.45117 1.45117 -1.03613 -1.6582 -3.10938 -7.25586 -7.25586 -8.91406 -5.38965 -5.38965 -4.14648 -3.10938 -4.14551 -3.73145 -4.35352 -5.38965 OFFSET CURVE: GRAX 213 records... 10 bytes 132 bytes Page 4 tapescan.txt 1024 *** LIS COMMENT RECORD ~** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by schlumberger GR CNL dated 28 oct 2008 per Doug stoner with BP Exploration (Alaska), Inc. FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Log~in9 direction is down (value= 255) Optical Lod 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 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code Samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 143 Tape File Start De th = 8381.000000 Tape File End Depth = 10939.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet *~** FILE TRAILER **** Tape Subfile: 2 156 records... Minimum record length: 54 bytes Page 5 Maximum record length: **** FILE HEADER **** MWD .001 1024 tapescan.txt 4124 bytes ~~ *** 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 Lod 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 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD 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: 285 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 8381.750000 Tape File End Depth = 10945.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 298 records... Minimum record length: 54 bytes Page 6 • tapescan.txt Maximum record length: 4124 bytes **** TAPE TRAILER **~* MWD 08/10/25 2254652 O1 °~~ REEL TRAILER ~°°~ MWD 09/01/13 BHI O1 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape subfile 1 is type: LIs 0 Tape subfile 2 is type: LIs DEPTH GR ROP RAD RAs RPD RPS 8381.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8381.5000 36.9651 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8400.0000 275.9266 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8500.0000 39.4932 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8600.0000 19.4042 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8700.0000 44.0721 16.9862 43.4351 2000.0000 115.0540 91.6212 8800.0000 35.2387 77.1629 42.5268 2000.0000 272.7625 225.5241 8900.0000 41.0430 27.1000 44.2415 2000.0000 723.3511 532.8613 Page 7 • • tapescan.txt 9000.0000 64.9995 53.2733 41.3264 2000.0000 648.5472 470.2906 9100.0000 73.3379 119.8798 41.8246 2000.0000 605.2789 552.5472 9200.0000 64.9718 109.6981 45.5155 2000.0000 605.2789 485.3350 9300.0000 60.6628 116.5400 42.5975 2000.0000 483.0704 428.0520 9400.0000 70.0000 119.0218 40.8340 2000.0000 566.8928 485.3350 9500.0000 82.4908 108.2039 41.3762 2000.0000 595.5372 485.3350 9600.0000 58.5150 113.3392 40.4159 2000.0000 583.7987 490.3466 9700.0000 66.1045 146.0715 42.6026 2000.0000 548.0559 478.1136 9800.0000 66.5765 121.3793 39.4224 2000.0000 551.3419 497.4211 9900.0000 78.6718 155.4530 45.8116 2000.0000 602.8765 468.0789 10000.0000 74.7057 122.5526 40.0623 2000.0000 305.3856 300.0233 10100.0000 60.3757 137.5728 41.2537 2000.0000 592.1366 510.2878 10200.0000 35.3814 131.9677 42.6591 2000.0000 719.6218 650.2532 10300.0000 83.5694 140.4901 43.2966 2000.0000 554.2483 383.2983 10400.0000 105.1082 126.8008 41.6926 2000.0000 528.7573 438.6470 10500.0000 65.1226 159.9959 40.0575 2000.0000 479.6190 402.9188 10600.0000 58.3887 173.2926 40.1003 2000.0000 436.2366 366.7228 10700.0000 72.7830 182.7170 39.5292 2000.0000 422.3965 375.3889 10800.0000 59.5713 192.1891 39.9749 2000.0000 410.2980 362.2963 10900.0000 -999.2500 113.9406 40.3831 2000.0000 420.1150 334.9270 10939.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Page 8 • tapescan.txt Tape File Start Depth = 8381.000000 Tape File End Depth = 10939.500000 Tape File bevel spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RPD RPS 8381.7500 -999.2500 -999.2500 -999.2500 -999.2500 8382.0000 -999.2500 -999.2500 -999.2500 -999.2500 8400.0000 286.0000 -999.2500 -999.2500 -999.2500 8500.0000 35.9000 -999.2500 -999.2500 -999.2500 8600.0000 18.9000 -999.2500 -999.2500 -999.2500 8700.0000 106.5000 17.0000 91.2720 70.4730 8800.0000 35.9000 85.2000 311.7870 261.3610 8900.0000 42.6000 27.1000 826.6140 580.3579 9000.0000 63.9000 53.2000 676.9089 467.0480 9100.0000 73.4000 119.8000 605.2789 559.0880 9200.0000 61.3000 98.8000 605.2789 485.3350 9300.0000 60.2000 116.0000 508.6880 428.0520 9400.0000 68.9000 120.3000 508.6880 526.8259 9500.0000 83.1000 87.6000 605.2789 485.3350 9600.0000 60.2000 114.8000 560.7059 515.9910 9700.0000 68.0000 142.1000 532.6780 480.5670 9800.0000 66.9000 136.3000 551.3419 490.6070 • RAD -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 46.4860 43.7410 42.8850 41.7310 41.9210 44.9460 41.9210 40.3860 43.0740 40.0770 41.8480 39.4370 RAS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 Page 9 • tapescan.txt 9900.0000 78.7000 155.5000 605.2319 465.7440 10000.0000 72.4000 122.0000 305.2170 289.9100 10100.0000 54.5000 139.8000 687.5050 495.4690 10200.0000 32.9000 132.7000 748.0220 653.7910 10300.0000 96.4000 143.6000 424.1530 335.8300 10400.0000 103.9000 123.4000 525.2130 438.6470 10500.0000 67.9000 159.1000 479.6190 404.3630 10600.0000 59.0000 173.1000 424.1530 380.7730 10700.0000 68.4000 172.3000 429.0190 372.6230 10800.0000 61.2000 181.6000 410.2980 357.7100 10900.0000 63.6000 115.6000 395.4790 337.2790 10945.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8381.750000 Tape File End Depth = 10945.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet Tape Subfile 4 is type: LIS • 45.7670 39.2220 42.8010 41.7800 43.1090 41.6230 40.2770 40.7950 38.4990 39.2160 39.2850 -999.2500 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 6064.5400 -999.2500 Page 10