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HomeMy WebLinkAbout208-144Ima a Pro~ct 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. ~Q g - ~ ~ ~~. - Well History File Identifier Organizing (done) R CAN C r Items: reyscale Items: ^ Poor Quality Originals: ^ Other: DIG AL DATA Diskettes, No. ' ^ Other, No/Type: NOTES: QY Project Proofing gY; Maria Scanning Preparation gY; Maria Date: Date: x30= Date: ~ c Production Scanning III ~ R.,~a~~e~~ IIIIIIIIIIIIIIIIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: -°°~ mP ,iuiuuiiiimiu v~P D + ~ J =TOTAL PAGES ~ D S (Count does not include cover sheet) ~/~/~ /~~ /s/ r r ~ Stage 1 Page Count from Scanned Fite: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: `~ /Q ~s~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s~ lete at this Dint unless rescanning is required. II I II'I II III II I I I~ Scanning is comp p Rescanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Quality Checked III II'lll III III III Comments about this file: IDS 10/6/2005 WeII History File Cover Page.doc ii STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMI�N SEP 0 6 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon [J Repair Well LI Plug Perforations L[ Perforate [J Other L[ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Welij 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Na me: BP Exploration (Alaska), Inc Development ISI Exploratory ❑ 208 -144 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23398 -00 -00 7. Property Designation (Lease Number): bm 8. Well Name and Number: z. ADL0028330 a 0)11 9 1 ' a PBU 12 -37 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 9 ` 10. Field /Pool(s): ■, ,, To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10450 feet Plugs measured None feet true vertical 9184 feet Junk measured None feet Effective Depth measured 10362 feet Packer measured 9501 feet true vertical 9124.76 feet true vertical 8535.92 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" X 34" 215.5# A53 26 - 106 26 - 106 0 0 Surface 3727 9 -5/8" 40# L -80 25 - 3752 25 - 3524.88 5750 3090 Intermediate None None None None None None Production 9750 7" 26# L -80 24 - 9774 24 - 8722.31 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9780 - 9805 feet 9909 - 9929 feet 9931 - 9949 feet 9965 - 9979 feet 10029 - 10036 feet 10052 - 10062 feet 10068 - 10073 feet 10136 - 10150 feet 10136 - 10150 feet True Vertical depth 8726.41 - 8743.52 feet 8814.71 - 8828.42 feet 8829.8 - 8842.15 feet 8853.13 - 8862.75 feet 8897.12 - 8901.93 feet 8912.94 - 8919.82 feet 8923.95 - 8927.39 feet 8970.62 - 8980.2 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 24 - 9619 24 - 8616.45 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Packer 9501 8535.92 Packer None None None g SSSV 12. Stimulation or cement squeeze summary: SHED °Pa 01 20 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 399 1911 6960 1826 241 Subsequent to operation: 401 1850 7105 1813 241 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 12 Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature i/ K �-/jA7 Phone 564 -4424 Date 9/6/2012 ' D M 1 0 f Vt-r 019/)/ Alai SEP 2012 v- ORIGINAL Submit Original Only Form 10-404 Revised 10/2010 y Casing / Tubing Attachment ADL0028330 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" X 34" 215.5# A53 26 - 106 26 - 106 LINER 710 4 -1/2" 12.6# 13Cr80 9608 - 10318 8609.02 - 9094.83 8430 7500 LINER 129 4 -1/2" 12.6# L -80 10318 - 10447 9094.83 - 9182.81 8430 7500 PRODUCTION 9750 7" 26# L -80 24 - 9774 24 - 8722.31 7240 5410 SURFACE 3727 9 -5/8" 40# L -80 25 - 3752 25 - 3524.88 5750 3090 TUBING 9595 4 -1/2" 12.6# 13Cr80 24 - 9619 24 - 8616.45 8430 7500 • • Daily Report of Well Operations ADL0028330 ACTIVITYDATE I SUMMARY Ty •n ' •, _. y , pre -a: pe DRIFT TBG W/ 3.70" CENT, 20' OF 3 -3/8" DMY GUN, 2 -1/2" S. BAILER & TAG HARD BTM AT 10,163' SLM (no sample recovered) 7/1/2012 ** *WELL SHUT -IN ON DEPARTURE * ** ** *WELL SHUT IN ON ARRIVAL * * *(ELINE ADPERF -S) INITIAL T /I /O = 1930/1840/0 RAN 10' 2 -7/8" PJOMEGA 6 SPF 60 DEG. EH: 0.34 "; PEN: 36 ". TIE -IN LOG IS SLB JEWELRY LOG DATED 2- JAN -2009. CCL STOP DEPTH = 9915.5' + 3.5' TO TOP SHOT PERFORATED FROM 9919 -9929' - _- 7/2/2012 ** *JOB CONTINUED ON 3 JULY 2012 * ** ** *JOB CONTINUED FROM 2 -JULY 2012 * ** (ELINI_ ADPERF) 2ND PERF RUN = 10' x 2 -7/8" PJOMEGA GUN - PERFED INTERVAL 9909 - 9919 WELL LEFT SHUT IN ON DEPARTURE - NOTIFIED PAD OP OF WELL STATUS FINAL T /I /O = 1820/1800/0 7/3/2012 ** *JOB COMPLETED * ** • • TAM= v CW • WELLHEAD = FMC • r S�Y NOTES: ** *CHROME TBC� LNR & ACTUATOR = BAKER C 1 2 _3 7 NI ES * ** KB. ELEV = 68.1 BF. ELEV = 41.88 - - KOP = —. — -- 2 - 66 Max Angle = 48° 0 9070' , ' 2176' — j4 -12' HES X NIP, ID = 3.813" Datum MD = 99 Datum TVD = — 8800' SS 120" CONDUCTOR, 215.5#, A -53, ID = ? H 106' 19 -518" CSG, 40 #, L -80 BTC-M, ID = 8.835" --I 3755' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3325" @ 9607' 5 3831 3595 27 KGB -2 DOME BK 16 03/29/09 4 5619 5217 25 KGB-2 DOME BK 16 03/29/09 4 -1/2 �� HES XN NIPPLE 3 6736 6219 26 KGB-2 SO BK 28 03/29/09 2 7811 7197 25 KGB -2 DMY BK 0 11/09/08 1 9392 8460 47 KGB-2 DMY BK 0 11/09/08 7" CSG, 26 #, L -80 TCII XO TO L-80 BTC-M —j 5259' 1---: I I I 9470' —14-1/2" HES X NIP, ID = 3.813" z X 9501' —{7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" ' 9534' H4-1/2" HES X NIP, ID = 3.813" I I I 9607' 1-14-1/2" HES XN NIP, ID = 3.725" 1 9610' — T' X5" I-RD BKR ZXP LTPw /BKR N. ;lL FLEXLOCK LNR HGR, ID = 4.40" _ 4 -1/2" TBG, 12.6#, 13CR -80 VAM TOP, H 9619' \ 3 9619' — {41/2 WLEG, ID= 3.958' 1 0152 bpf, ID = 3.958" 1 9614' H ELIM T( LOGGED 01 /02/09 I 7" CSG, 26 #, L-80 BTGM, ID = 6.276" --1 9776' 1' • 9644' —15" X 4 -1/2" XO, ID = 3.950" I PERFORATION SUINIVIARY REF LOG: SLB MAO 11/07/08 I ANGLE AT TOP PERF: 47° 0 9780' Note: Refer to Production OB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE I 3 __§... • I n , j•a 2 -7 : 6 • r• - . • • 0 07/03/12 3- • "' - 9949 • 01 it •. I 3 -3/8" 6 9965 - 9979 0 01/03/09 3 -3/8" 6 10029 - 10036 0 01/03/09 I 3 -3/8" 6 10052 - 10062 0 01/03/09 3 -3/8" 6 10068 - 10073 0 01/03/09 3 -3/8" 6 10136 - 10150 O 01/02/09 I 3 -3/8" 6 10162 - 10171 0 01/02/09 FBTD H 10362' 1 - 4-1/2" LNR 12.6#, 13CR 80 VAM TOP, H 10449' . .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMtMEIYTS PRUDHOE BAY UNIT 11/10/08 N7ES ORIGINAL COMPLETION 02/09/11 MB/JMD REMVD SSSV SAFETY NOTE WELL: DS 12 -37 12/06/08 DTR/PJC GLV C/O (11/23/08) 05/10/12 GRC/JMD DRAWING CORRECTIONS (05/09/1 PERMT No: '208144 01/13/09 JKD/SV INITIAL PERFS (01/04/09) 07/09/12 JCMVJMD ADPERF (07/03/12) API No: 50- 029 - 23398 -00 06/01/09 MBM/fLH GLV C/O (03/29/09) SEC 18, T1 ON, R15E, 828'FSL & 737' FEL 08/25/09 TP/JMD DRLG DRAFT CORRECTIONS 12/20 /10 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 3/2412010 Permit to Drill 2081440 Well Name/No. PRUDHOE BAY UNIT 12-37 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-23398-00-00 MD 10450 TVD 9185 Completion Date 1/4/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surv Yes ~, DATA INFORMATION Types Electric or Other Logs Run: Gyro, MWD, DIR/GR/RES/PWD, NEU, DEN Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / ly IYleOlrrmi 17un11JC1 name ~~a~c n~cwu IYV Jaa1L JwN vn r~ca.crvcaa vvnnncnw Pr ssure 2 Blu 9600 10250 Case 1/16/2009 SBHPS, Pres, Temp, GR, CCL 4-Jan-2009 C Pds 17478 Pressure 9600 10250 Case 1/16/2009 SBHPS, Pres, Temp, GR, CCL 4-Jan-2009 ED C Lis 17519 •~(nduction/Resistivity 100 10499 Open 1!28/2009 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, RAM, DRHO i og Induction/Resistivity 25 Blu 100 10410 Open 1/28/2009 MD Vision Service 7-Nov- i 2009 og Induction/Resistivity 25 Blu 100 10410 Open 1/28/2009 TVD Vision Service 7-Nov- 2009 og Production 5 Blu 9640 10171 Case 6/11/2009 PPL w/ Deft & Ghost, GR, CCL, Pres, Temp, Spin, I- ,~ Gradio 21-Apr-2009 (QED C Pds 18169 Production 9640 10171 Case 6/11/2009 PPL w/ Deft & Ghost, GR, CCL, Pres, Temp, Spin, ! Gradio 21-Apr-2009 D D Asc Directional Survey 0 10450 Open 11/12/2008 pt Directional Survey 0 10450 Open 11/12/2008 Well Cores/Samples Infiormation: Sample Interval Set Name Start Stop Sent Received Number Comments ~ DATA SUBMITTAL COMPLIANCE REPORT 3/24/2010 Permit to Drill 2081440 Well Name/No. PRUDHOE BAY UNIT 12-37 Operator BP EXPLORATION (ALASKI~ INC MD 10450 TVD 9185 Completion Date 1/4/2009 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? ~#~ Analysis Received? Comments: API No. 50-029-23398-00-00 UIC N Daily History Received? ~ N Formation Tops t~ Compliance Reviewed By: _ _ - Date: ~ L(~ •I 06/08!09 ~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK ` 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE ~ 05/15/09 1 1 06-08A AViH-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 A-44 AWLS-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05/17/09 1 1 H-29A AYOO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK - , 05/06/09 1 1 15-456 ANHY-00010 PRODUCTION PROFILE '~-- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ ~ 05/08/09 1 1 M-19B AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A B1JJ-00018 MEM CNUSTP ~ 05/18/09 1 1 X-30A B2WY-00005 MEM PROD PROFILE C 05/10/09 1 1 12-23 AYKP-00021 USIT L - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE - 05!19/09 1 1 Z-146 AZCM-00022 PROD PROFILE/JEWELRY LOG ~ ~- 05/20/09 1 1 L1-21 62NJ-00006 PRODUCTION PROFILE 05/24/09 1 1 A-31A AZCM-00023 USIT =~ - Q {o G 05/22/09 1 1 H-19B' 62WY-00004 MEM PROD PROFILE t- 05/07/09 1 1 G-16 AYKP-00022 SCMT / / 05/09/09 1 1 M-19B AY3J-00024 SCMT - 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE _ C/G/ / 04/21/09 1 1 11-04A AYOO-00028 USIT JG~L~ _ 05/21/09 1 1 18-30 BiJJ-00015 MEM PROD PROFILE /C/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ - l 05/11/09 1 1 3-37/L-35 AWL9-00035 PROD/INJECTION PROFILE 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL ~ _ l~dl5 04/26/09 1 1 PLtASt A(:KNUWLtU(9t Fitl.tlY1 CfT JIlaIV11VU HIVU rill UrS1V11VU VIYC VVr'T CH~.n ~ V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, March 09, 2009 11:54 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU 12-37 / PTD # 208-144 Hi Art, Please reference the following well: Well Name: PBU 12-37 Permit #: 208-144 API #: 50-029-23398-00-00 Top Perf MD: 9780' Bottom Perf MD: 10171' This well began Production on March 5, 2009 Method of Operations is: Flowing Date of Test: 03/07/09 Hours Tested: 6 24-Hour Rate /Oil-Bbl:. 915 24-Hour Rate /Gas-Mcf: 4,661 24-Hour Rate /Water-Bbl: 5,817 Test Rate /Oil-Bbl: 229 Test Rate /Gas-Mcf: 1,165 Test Rate /Water-Bbl: 1,454 Choke Size: 83 Gas-Oil Ration: 5,868 Flow Tubing Pressure: 257 Casing Pressure: 1,500 - Oil Gravity-API: Unavailable 3/9/2009 ,\C~ ^ ~\~ ~, 3X~ a~~ STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~, 2 2009 WELL COMPLETION OR RECOMPLETION REPORT AND L 5lacka fli! ~ ~8a COti3, C®t1'tltll$$i®R 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 2oaAC 25.105 2oAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. W ~ ®~eve~lo pni'ent ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband 1/4/2009 ~ 12. Permit to Drill Number 208-144 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/25/2008 ~ 13. API Number 50-029-23398-00-00 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 11/7/2008 14. Well Name and Number: PBU 12-37 829' FSL, 738' FEL, SEC. 18, T10N, R15E, UM Top of Productive Horizon: 4778' FSL, 1211' FEL, SEC. 18, T10N, R15E,UM 8. KB (ft above MSL): 68.10' Ground (ft MSL): 39.1' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Tota Depth: ~I q~~~ 5270 FSL, 12 2' FEL, SEC. 18, T10N, R15E, UM 9. Plug Back Depth (MD+TVD) 10362' 9125' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 696862 y- 5931140 Zone- ASP4 10. Total Depth (MD+TVD) 10450' 9185' ~ 16. Property Designation: ADL 028330 TPI: x- 696271 y- 5935077 Zone- ASP4 5935568 Zone- ASP4 696246 l D th T t 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: : x- y- o a ep 18. Directional Survey ®Yes ^ No mi el r i n rint inf i n r 20 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 AAC 25.071): Gyro, MWD, DIR/GR/RES/PWD, NEU, DEN 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 1 1 rf 1 8' 4" s Ar i A rx. ,~ ~ ~ ~~ T x r i 7" 2 L- 7 ' 7 - 4" 31 Li 1 ' -1 1 1 1 I ' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i P nterval open Si d N b rf i SIZE DEPTH .SET MD PACKER SET MD er): ze an um orat on (MD+TVD of Top & Bottom; e 6 spf 3-3/8" Gun Diameter 4-1/2", 12.6#, 13Cr80 9619' 9501' , MD TVD MD TVD 9760' - 9805' 8726' - 8744' ' ' ' ' 25. Ac10, FRACTURE, CEMENT SQUEEZE, ETC.. -9949 8830 - 8842 9931 9965' - 9979' 8853' - 6663' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10029' 10036' 8897' - 8902' ' ' ' ' Freeze Protect w/ 75 Bbls of Diesel - 10062 8913 - 8920 10052 10068' - 10073' 8924' - 8927' 10136' -10150' 8971' - 8980' 10162' - 10171' 8988' - 8995' 26, PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-FIOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITr-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. None ~ ~ r'h:~? ~ t~0~ - -d ~~ ,_ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No PemlaftOSt Top If yes, list intervals and formations tested, briefly summarizing test 1922' results. Attach separate sheets to this form, if needed, and submit Permaftost Base detailed test information per 20 AAC 25.071. Sag River 9775' 8723' None Shublik A 9811' 8748' Shublik B 9839' 8767' Shublik C 9862' 8783' Top Sadlerochit / 46P 9917' 8820' 45N 9930' 8829' 45P 9943' 8838' 44p 9987' 8868' 43N 10014' 8887' 43P 10030' 8898' 42p 10069' 8925' 41 P 10096' 8943' 31 p 10161' 8988' 27P 10252' 9050' OWC 10323' 9098' 26p 10350' 9117' 25N 10388' 9142' 25P 10406' 9155' Formation at Total Depth (Name): 25P 10406' 9155' 30. List of Attachments: Summary of Daily Drilling Reports, Post Rig Well Work Summary, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~~ D ~~(~ ~ ate itle Drilling Technologist Signed Terrie Hubble PBU 12-37 208-144 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Travis Peltier, 564-4511 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (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 gp Page 1 of 1 Leak-Off Test Summary Legal Name: 12-37 Common Name: 12-37 Test Date I Test Type ~~Test Depth (TMD~Test Depth (TVD) AMW Surtace Pressure Leak Off Pressure (BHP) EMW 10/27/2008 FIT (ft) (ft) (ppg) (psi) (psi) (ppg) 10/31/2008 FIT 3,785.0 (ft) 3,536.0 (ft) 9.20 (ppg) 606 (psi) 2,296 (psi) 12.50 (ppg) 11/7/2008 FIT 9,800.0 (ft) 8,740.0 (ft) 8.40 (ppg) 955 (psi) 4,769 (psi) 10.50 (ppg) Printed: 11/25/2008 11:04:40 AM a r gP Page 1 of 15 Operations Summary Report Legal Well Name: 12-37 Common Well Name: 1 2-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code' NPT Ph ase ~ Description of Operations 10/21/2008 12:00 - 18:30 6.50 MOB P PRE Move Camp, truck shop, welding shop, and pit module from Z-Pad to DS 12. Spot camp and shops on DS 12. 18:30 - 00:00 5.50 MOB P PRE Move sub from Z-Pad to DS 12, currently between W-Pad and S-Pad on spine road. 10/22/2008 00:00 - 14:00 14.00 MOB P PRE Continue to move sub from Z-Pad to DS 12 14:00 - 17:00 3.00 RIGU P PRE Set Herculite, Move rig over well 12-37, hang riser and set diverter in cellar. 17:00 - 20:00 3.00 RIGU P PRE Raise Derrick and set pits 20:00 - 22:00 2.00 RIGU P PRE -Rig down bridal lines. 22:00 - 00:00 2.00 RIGU P ( PRE 10/23/2008 100:00 - 09:00 9.00 RIGU P PRE 09:00 - 10:00 1.00 RIGU P PRE 10:00 - 11:30 1.50 RIGU P PRE 11:30 - 12:00 0.50 RIGU P PRE 12:00 - 14:00 2.00 RIGU P PRE 14:00 - 16:30 2.50 RIGU P PRE 16:30 - 22:30 6.00 RIGU P PRE 22:30 - 00:00 ~ 1.50 ~ BOPSUf~ P ~ ~ PRE ~ 10/24/2008 ~ 00:00 - 04:00 ~ 4.00 ~ RIGU ~ P ~ ~ PRE 04:00 - 12:00 8.00 I DRILL ~ N ~ WAIT ~ SURF -Rig up floor, cattle shoot, and electrical and service lines in interconnect Accept rig at 22:00 hours -Nipple up diverter system and diverter lines -Change pump liners from 5" to 5.5" -Pre Spud meeting with Rig Crew Continue to nipple up Diverter and diverter line -Nipple up riser -Strap 4" Drill pipe -Take on spud mud Test Diverter system, knife valve fully open after 15 seconds, bag fully closed after 33 seconds. Pick up 54 joints of 4" drill pipe and stand back in the derrick. -Received instructions not to proceed with spuding well until well 12-18 is secured. Test Diverter system, knife valve not opening before annular shuts. Test witnessed by Jeff Jones AOGCC representative. -Troubleshoot knife valve. , Troubleshoot gauges on remote BOP control panel, troubleshoot knife valve. -Pre spud meeting with crew Pick up 45 joints of 4" drill pipe and stand back in the derrick, pick up 21 joints 4" HWDP and stand back in derrick -Continue to troubleshoot knife valve. -Run hydraulic lines from Accumulator to new gauges on remote BOP panel on the rig floor. Continue to work on securing Well 12-18. -Test diverter system, knife valve opens after 27 seconds, bag fully shuts a er secon s. -New gauge manifold rigged up in doghouse above remote panel. Test Diverter s stem, Accumulator, PVT, return flow, and as detectors. Test witnessed by Jeff Jones AOGCC representative, Joey LeBlanc WSL, and Lenward Toussant NTP. Build BHA while waiting on well 12-18 to be secured -Pick up jars and rack back jar stand. -Pickup collar stand and stand back in derrick -Pick up Motor, MWD, ARC, and orient toolface. -Torque bit on the bottom and rack back waiting for okay to spud. Waiting on okay to drill ahead. -Service topdrive, drawworks, and rig -Load, strap, and drift 9 5/8" 40# casing. (special drift 8.75") rnncea: i vzoizuun i i:uw:ao r+m gP Page 2 of 15 Operations Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Hours I Task Code NPT Phase Description of Operations 10/24/2008 ~ 12:00 - 00:00 ~ 12.00 ~ DRILL ~ N ~ WAIT ~ SURF 10/25/2008 100:00 - 03:00 3.00 DRILL N ~ WAIT ~ SURF 03:00 - 06:30 ~ 3.50 ~ DRILL ~ P ~ ~ SURF 06:30 - 09:30 3.00 ~ DRILL P SURF 09:30 - 11:00 1.50 DRILL P SURF 11:00 - 00:00 13.00 DRILL P SURF 110/26/2008 ~ 00:00 - 13:30 ~ 13.50 ~ DRILL ~ P ~ ~ SURF 13:30 - 15:00 ~ 1.50 ~ DRILL ~ P ~ ~ SURF 15:00 - 18:00 ~ 3.00 ~ DRILL ~ P ~ ~ SURF Waiting on okay to drill ahead. -Continue to work on 9 5/8" casing -Clean and paint rig. Waiting on well 12-18 to be secured. -Continue to work on 9 5/8" casing -Clean and paint rig. -Pre spud meeting with rig crew Well 12-18 secured, master valve shut, okay to spud well 12-37. -Mobilize remainder of Spud mud from mud plant. -Gyrodata in route to rig -Fill hole with mud and check for leaks -Pressure test surface system Drill from 108' to 268' MD. t Run Gyro every stand. -10K WOB -450 GPM at 615 psi on, 505 psi off -50 RPM at 2K TO on, 0.5 K TO off -PU 40K, SO 40K, ROT 40K Pull out of hole to pickup collar stand and jar stand. -Run back in hole to 268'. Directional Drill from 268'to 1,003' MD, slide as needed for 2/100 build section. -Run Gyro every stand to 516'. rip down ayro -Wipe 30' on each connection. -10-30K WOB -550 GPM at 1,640 psi on, 1,470 psi off -60 RPM at 4K TO on, 1 K TO off -PU 65K, SO 60K, ROT 60K -Adding H2O at 30-40 bbls/hr, MW 9.1 RT=3.16 , ST=6.85, DT=10.01 Directional Drill from 1,003'to 1,863' MD, slide as needed for 2/100 build section. -Wipe 30' on each connection. -20-30K WOB -545 GPM at 1,860 psi on, 1,780 psi off -60 RPM at 4.OK TO on, 2.OK TO off -PU 82K, SO 64K, ROT 68K -Adding H2O at 85-100 bbls/hr, MW 9.0, running centrifuge and Mud cleaner. -Trouble sliding from 1,330' to 1,380', hanging up off bottom. Backream one stand, still having problems sliding to bottom. Circulate bottoms up for wi er tri ,excessive sand across shakers. Circulate and reciprocate from 1,863'to 1,765'. ac ream to prevent localized washout while circulating bottoms up from 1,765'to 1,577'. -554 GPM at 1,765 psi -65 RPM at 3K TO, 74K RWT -Mud weight in = 9.0 ppg, out = 9.0 ppg. Monitor well, well static. Trip out of the hole from 1,577' to 1,099' working tight spots at 1,286', 1,133', 1,099'. Backream out of the hole from 1,099' to 817'. Pull out of the hole from 817' to 728'. rrirnea: i vzoi~wo i i:vw:va Nm BP Operations Summary Report Page 3 of 15 ~ Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours I Task Code NPT Phase Description of Operations -_ _ - 10/26/2008 15:00 - 18:00 3.00 DRILL P SURF -450 GPM at 1,150 psi 18:00 - 00:00 6.00 I DRILL P 10/27/2008 100:00 - 17:30 17.501 DRILL P 17:30 - 18:30 1.001 DRILL P 18:30 - 20:30 2.00 DRILL P 20:30 - 22:00 1.501 DRILL P 22:00 - 00:00 I 2.001 DRILL I P 10/28/2008 100:00 - 02:30 2.501 DRILL P 02:30 - 04:30 I 2.001 DRILL I P 04:30 - 10:00 I 5.501 DRILL I P -40 RPM at 3.8K TO -Run in hole on elevators from 728'to 1,596'. Encountered tight hole at 1,596', ream down from 1,596' to 1,863' -120 GPM at 350 psi -45 RPM at 3K TO SURF Directional Drill from 1,863'to 2,245'. -Wipe 30' on each connection -15-25K WOB -602 GPM at 2611 psi on, 2,477 psi off -60 RPM at 5K TO on, 3K TO off -PU 85K , SO 65K, RWT 76K -On bottoms up from wiper trio extreme amounts of sand and ~ wood from la de th of 1 -Adding water 80-110 bph, mud weight = 9.1 ppg. SURF Drill tangent from 2,245' to 3,765' TD, -Wipe 30' on each connection -10-20K WOB -600 GPM at 3,209 psi on, 3,107 psi off -60 RPM at 5K TO on, 5K TO off -PUW 125K ,SOW 82K, RotWT 97K -Total sliding = 21.9 hrs, Total rotating = 14.7 hrs -Total drilling = 36.6 hrs, Total jars hrs = 49.8 hrs -Adding water 50 bph, mud weight = 9.3 ppg -PJSM with incoming crew at noon SURF Circulate bottoms up while reciprocating string 90'. -Pumps at 650 gpm, 3170 psi -Rotate 80 rpm, 5k torque, Rot Wt 97k -Monitor well -static SURF Short trip to 1,977' md. -Tight area from 2,137'to 2,038 -Work through area with 30k over, no pumps SURF Continue short trip to 1,768' md. -Pump out from 1,977' to 1,863' at 374 gpm, 1036 psi -Rotate at 40 rpm -Wipe from 1,863' to 1,768' and with no pump or rotation SURF RIH from 1,768'to 1,974' -Stack 40k at 1,974', ream and wash to work down to 2,004' and -Pump at 187 gpm, 278 psi and rotate at 30 rpm -PJSM with incoming crew SURF RIH from 2,004' to 3,765' TD. -Ream, wash down from 2,004' to 2,240' and -Pumps at 180 gpm, 450 psi; rotate at 40 rpm -Able to run to 3,765' with no problems, no fill SURF Circulate bottom's up. -Pumps at 620 gpm, 3150 psi; rotate at 80 rpm -Rot WT 90k, torque 5.5k Wlbs -String in 290 bbls cold mud to cool down spud mud SURF POH from TD to 907' md. -Work pipe with 25k overpull at 2,585' and -Backream and pump out from 2,585' to 1,750' -Pumps at 450 gpm, 1850 psi; rotate at 40 rpm rnntea: i vcoiwva 1 I IV4:4J f11V1 BP Operations Summary Report Legal Well Name: 12-37 Page 4 of 15 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date i From - To ~ Hours Task Code NPT Phase Description of Operations 10/28/2008 ~ 10:00 - 14:00 ~ 4.00 ~ DRILL ~ P ~ ~ SURF Stand back HWDP and 6 3/4" DCs 14:00 - 16:00 I 2.00 I CASE I P 16:00 - 18:00 ~ 2.00 ~ CASE ~ P 18:00 - 19:00 1.00 CASE P 19:00 - 00:00 I 5.001 CASE I P 10/29/2008 100:00 - 04:15 4.251 CASE ~ P 04:15 - 06:15 I 2.00 I CASE I P 06:15 - 12:00 5.75 CASE I P 12:00 - 00:00 12.00 ~ CASE ~ P -Encountered 25k overpull, swab and surge from 907' to 218'; backream and pump out -Pumps at 485 gpm, 860 psi; rotate at 50 rpm -Torque at 1 k fUlbs -Lay Down 12 1/4" BHA -Damage on upper stabilizer shoulders -Bit rating: 5-7-WT-A-E-3/8-SD-TD -Clear and clean floor of 12 1/4" BHA and tools -PJSM with incoming crew SURF PJSM on rigging up, running 9 5/8" casing. -Rig up Power Tongs, Slips, Elevators and Frank's fill-up tool -Make Dummy run with Landing joint and Hanger Mandrel SURF Run 9 5/8", 40 #, L-80 BTC Casing. -Special drift casing to 8.75" -Bakerlock all connections below joint 3 -Check floats -okay -RIH to 634' and -Bow Spring Centralizer on jts 1 and 2, across collars on jts 3-17 -Avg Torque on BTC connection 7500 fUlbs -Fill on each joint -PUW 57k, SOW 50k SURF Wash down jt 18 from 634' to 687' -Centralizer on joint -Pumps at 170 gpm, 134 psi SURF Work casin at 687' to et ast obstacle -Full returns• shakers show small amounts of wood and gravel -Pumps at 210 gpm, 237 psi -PUW 58k, SOW 50k SURF RIH from 687' to 987' with 9 5/8" casing string -Work casing past obstacles with 1' reciprocation and various pump rates (3 to 8 bpm) -Initial tight spot at 687' repeatedly required work with each joints collar / centralizer working past it -Full returns; shakers show small amounts of wood and gravel -PUW 58k, SOW 50k -Centralizers on joints 1-25 per well program SURF RIH from 987'to 1,850' -RIH without pumps -Slight bobbles on weight indicator show some resistance but still RIH within drag restrictions SURF RIH from 1,850' to 2,265' -No problems pulling up -Unable to o down without washin and full strin wei ht -250 GPM at 450 psi -PUW 125K, SOW 75K 'SURF RIH from 2,265 to 3,562'. -Minimal cuttings coming across the shakers -188 GPM at 466 psi -PUW 170K, SOW 90K rnnieo: i vzaizuua I I:V4:4D MNI I~ gp Page 5 of 15 Operations Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To I Hours Task ~ Code ; NPT Phase Description of Operations 10/30/2008 00:00 - 01:30 1.50 CASE P SURF RIH from 3 562' to TD. -188 GPM at 466 psi -PUW 170k, SOW 90k 01:30 - 03:00 1.50 CASE P SURF Circ & Condition mud -Circulate surface to surface to condition mud -Establish initial circulation rates for 1 bpm through 6 bpm -250 GPM bpm at 380 psi 03:00 - 04:30 1.50 CASE P SURF Rig up cement head and cement lines -Circulate mud to condition well and mud properties for cementing -Verify new circulation rates for 1 bpm through 6 bpm ` -PJSM with crew, SLB, CH2mHill, Tourpusher, WSL on cement job 04:30 - 10:30 6.00 CEMT P SURF Cement 9 5/8" casin -Pump 10 bbls of Mud Push II -Test lines to 3500 psi -Pump 60 bbls 10.0 ppg Mud Push II Spacer (red dye at last 20 bbls) -Drop bottom plug; positive indication plug dropped -Pump 754 bbls of 10.7 ppg DeepCRETE lead slurry per SLB cemen in ro ram -Pump 48 bbls of 15.8 ppg Class "G" tail slurry per SLB program -Pump all slurries at avg of 5 bpm -Drop top plug: positive indication plug dropped -Pump out cement and top plug with 10 bbl water -Switch to rig pumps and displace cement with 269 bbls mud -Slow pumps to 3 bpm 10 bbls before expected plug bump -Bump plug with 750 psi, increase to 1250 and hold for 2 min -Bleed off pressure to 0 psi and check floats; floats holding -Pressure up to 3500 psi for casing test: slow leak off over 5 min period -bleed off and abort test -No cement returns to surface - 93 total bbls lost to formation while circulating in preparation for the cement 'ob, cementin o erations and cement displacement. 10:30 - 12:00 1.50 CEMT P SURF RD test equipment and casing running equipment -Contacted Chuck Scheve of AOGCC to inform him of no cement returns to surface -Flush cement /mud from all lines, riser and 20" diverter -LD landing joint -Clear and clean rig floor -PJSM with incoming crew 12:00 - 14:30 2.50 DIVRTR P SURF ND diverter and lines -Change out bails on top drive -Wash equipment 14:30 - 16:30 2.00 REMCM P SURF RIH with 1.25" H dril i e for Top Job -RIH to 364' from ground level 16:30 - 20:00 3.50 REMCM P SURF PJSM on Top Job cementing procedure -RU cementing equipment -Pressure Test lines to 2500 -Pump 213 bbls of 10.7 qqq cement rnmea: i vz~zuue I I:V4:4J HM BP Operations Summary Report Legal Well Name: 12-37 Page 6 of 15 ~ Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase i Description of Operations 10/30/2008 16:30 - 20:00 3.50 REMCM P SURF -Positive cement returns to surface 20:00 - 21:30 I 1.50 21:30 - 00:00 2.501 BOPSUp P 110/31/2008 100:00 - 02:00 2.00 BOPSUF{P 02:00 - 06:00 4.001 BOPSUR P 06:00 - 07:00 I 1.001 BOPSUR P 07:00 - 10:30 3.50 DRILL P 10:30 - 13:30 3.00 DRILL P 13:30 - 15:00 1.50 DRILL P 15:00 - 17:30 2.50 DRILL P 17:30 - 19:00 1.50 EVAL P 19:00 - 20:00 1.00 DRILL P 20:00 - 21:00 I 1.001 DRILL I P -Top Job cementing operations witnessed by AOGCC rep Chuck Scheve SURF RD cementing equipment -Blow down lines; wash all equipment -LD Hydril pipe -Clear and clean floor of handling equipment INT1 Install Generation 5 wellhead equipment and test -Remove diverter equipment from cellar -NU BOP -PJSM with incoming crew INT1 Complete NU BOP -Install riser -Obtain RKB measurements -Service top drive INT1 RU BOP test equipment and test BOP -PJSM with Rig Crew on testing BOP -Test BOP to 250 Low and 35 psi High with 4" test joint -Witness of test waived by AOGCC rep Jeff Jones -Test witnessed by WSL Rob O'Neal, Tourpusher Biff Perry #1 Top pipe rams (3 1/2"x6") with 4" test joint, Choke Valves 1,2,3,16, Dart, HCR Kill valve, Lower IBOP #2 Choke Valves 4,5,6, Manual Kill valve, Manual IBOP #3 Choke Valves 7,8 & 9, TIW #4 Super Choke and Manual Choke to 250 psi low, 3500 high #5 Choke Valves 10, 11 and 15 #6 Choke Valve 14 #7 HCR Choke #8 Manual Choke, Annular #9 Bottom pipe rams (2 7/8"x5") with 4" test joint #10 Blind Rams, Choke Valves 12 & 13 No Failures, Good Test INT1 RD test equipment -Clear and clean rig floor -Install wear ring INTi PU 4" DP one-by-one to 3,541' and -PUW 85k, SOW 65k INT1 POH with 4" DP standing back in derrick INT1 PU 8 3/4" BHA -8 3/4" bit, 1.5 deg motor, stabilizer, 3-6 1/2" DCs, jars, 23 jts HWDP, ghost reamer INTi RIH with 8 3/4" BHA -Pick up 4" DP one-by-one and RIH to 3,587' and INTi Pressure test 9 5/8" casin -RU test equipment -Pressure casin u to 3500 si for 30 min n -Pressure bled 20 psi first 15 min, 0 si second 30 min -RD test equipment INT1 PJSM on slip and cut drilling line -Slip and cut 87' drilling line -Inspect drawworks, service crown INTi Drill up plugs, cement in shoe -Wash down and tag plugs on death at 3,673' rnmea: i uzoizuvu i i:uv:va r+rvi gP Page 7 of 15 Operations Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To ,Hours Task ~ Code i NPT Phase ~I Description of Operations - --- 10/31/2008 20:00 - 21:00 1.00 DRILL P INTi -Drill up plugs and cement to 3,750' and -PUW 115k, SOW 77k, ROT Wt 95k -Pumps at 500 gpm, 2166 psi -Rotate at 40 rpm, 5k ft/Ibs torque 21:00 - 22:00 1.00 DRILL P INT1 Displace to LSND drilling mud -Pump 50 bbl water followed by 50 bbl Hi-Vis spacer -Displace system with 256 bbls 9.2 ppg LSND -SPRs: -Pump 1: 2 bpm=120 psi, 3 bpm=170 psi -Pump 2: 2 bpm=120 psi, 3 bpm=180 psi 22:00 - 22:30 0.50 DRILL P INT1 Drill out rest of shoe and new hole to 3,785' and -Pumps at 525 gpm, 1290 psi off, 1450 psi on -Rotate at 40 rpm, 4k torque off, 4.5 torque on 22:30 - 23:00 0.50 DRILL P INT1 Circulate bottoms up -Pumps at 550 gpm, 1410 psi -Establish clean ECD's for MWD -Baseline of 9.58 ppg 23:00 - 00:00 1.00 EVAL P INTi Pull up into shoe RU test equipment for FIT -Perform FIT for 12.5 EMW to 610 si -MW in at 9.2 ppg -RD test equipment -PJSM with incoming crew 11/1/2008 00:00 - 09:00 9.00 DRILL P INT1 Drill ahead in 8 3/4" hole to 5,051' and -80 rpm, 550 gpm, 2040 psi on, 1810 psi off -7k torque on, 5k torque off -PUW 132k, SOW 98k, ROT Wt 108k, WOB 15k -Cal ECD 9.53, Act ECD 10.38, MW in and out 9.2 ppg -Jar hrs 55.6, Bit hrs 5.69 -AST .72 hrs, ART 4.68 hrs, ADT 5.40 hrs 09:00 - 17:30 8.50 DRILL N RREP INTi Unable to rotate Top Drive -Troubleshoot problems with Top Drive -Replace Top Drive blower motor -Circulate 50 gpm and slowly reciprocate pipe while replacing blower motor -PUW 130k, SOW 98k 17:30 - 00:00 6.50 DRILL P INT1 Drill ahead in 8 3/4" hole from 5,051' to 5,882' and -80 rpm, 550 gpm, 2365 psi on, 2150 psi off -8k torque on, 6k torque off -PUW 145k, SOW 105k, ROT Wt 120k, WOB 15k -Cal ECD 9.21, Act ECD 10.12, MW in and out 9.2 ppg -Jar hrs 59.89, Bit hrs 10.06 -Total sliding 1.72 hrs, Total rotating 7.96 hrs, Total drilling 9.68 hrs -PJSM with incoming crew 11/2/2008 00:00 - 12:00 12.00 DRILL P INT1 Drill ahead in 8 3/4" hole from 6,570' to 7,350' and -80 rpm, 550 gpm, 2790 psi on, 2510 psi off -9k torque on, 7k torque off -PUW 165k, SOW 128k, ROT Wt 138k, WOB 15k -Cal ECD 9.65, Act ECD 10.42, MW in and out 9.25 ppg -AST 2.05 hrs, ART 6.33 hrs, ADT 8.38 hrs -PJSM with incoming crew -Crew conducted weekly safety meeting 12:00 - 00:00 12.00 DRILL P INT1 Drill ahead in 8 3/4" hole from 7,350' to 8,217' and rnncea: i ucoic~~o i ~.w.wo ..m ,! BP Operations Summary Report Legal Well Name: 12-37 Page 8 of 15 ~ Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 ,Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code I NPT Phase Description of Operations ~ -- - -- 111 /2/2008 12:00 - 00:00 12.00 DRILL P INTi -80 rpm, 550 gpm, 3040 psi on, 2830 psi off l i 1/3/2008 100:00 - 08:30 I 8.501 DRILL ~ P 08:30 - 09:00 0.50 DRILL P 09:00 - 15:00 6.00 DRILL P 15:00 - 16:00 I 1.001 DRILL I P 16:00 - 19:00 3.001 DRILL ~ P 19:00 - 21:00 2.00 DRILL P 21:00 - 00:00 3.00 DRILL P 111/4/2008 100:00 - 01:30 I 1.50 ~ DRILL ~ P 01:30 - 02:00 ~ 0.50 i DRILL ~ P 02:00 - 12:00 I 10.001 DRILL I P -7.5k torque on, 5.5k torque off -PUW 173k, SOW 140k, ROT Wt 150k, WOB 15k -Cal ECD 9.74, Act ECD 10.06, MW in and out 9.3 ppg -AST 4.51 hrs, ART 4.23 hrs, ADT 8.74 hrs -For last 24 hour period: Total sliding 6.56 hrs, Total rotating 10.56 hrs, Total drilling 17.12 hrs Note: One additional hour due to Daylight Savings Time INTi Drill ahead in 8 3/4" hole from 8,217' to 8,610' md. -80 rpm, 550 gpm, 2960 psi on, 2750 psi off -7.5k torque on, 5k torque off -PUW 183k, SOW 145k, ROT Wt 153k, WOB 15k -Cal ECD 9.70, Act ECD 9.94, MW in and out 9.25 ppg -AST 5.40 hrs, ART .93 hrs, ADT 6.33 hrs INT1 Circulate bottoms up prior to POH -550 gpm, 2850 psi, 80 rpm INT1 POH 8,610' to 907' and -Monitor hole before POH -Static -During trip out, wiped tight spots at: 6,815', 6,592', 6,359-6,168', 4,543-4,448', 3,969-3,874' -Monitor well at shoe - 1/2 bph loss rate INT1 Lay down BHA -Monitor well - 1 b h loss rat -Clear and clean rig floor -Download MWD info INT1 Change out motor from 1.50 deg to 1.83 deg (new motor) -Change out battery in ARC tool -Service Top Drive -Adjust brakes on drawworks -Tighten bolts on rotary motor INTi PU rebuilt PDC bit -PU rest of BHA, RIH to 907' and INTi RIH from 907' to 3,874' and -Conduct shallow hole test on MWD equipment -Continue to RIH to 6,647' and INT1 RIH from 6647' to 8610' -Ream down to tie in logs from 8463' to 8610' - Pumps: 420 gpm at 2440 psi - PUW 180k, SOW 133k, ROT Wt 150k, 30 rpm st 6k/ft-Ibs INT1 Circulate and condition hole bottoms up. Mud runnin off the s a ers, s age up pumps to tilling rate: - Initial: 430 gpm at 2400 psi - Final: 550 gpm at 3400 psi INT1 Drill ahead 8 3/4" hole from 8610' to 9130' and -Pumps: 535 gpm at 3725 psi (3505 psi off bottom) - 60 rpm at 9k/ft-Ibs torque (6.6k/ft-Ibs torque off bottom) - PUW 184k, SOW 145k, ROT Wt 155k, WOB 15k - Begin adding spike fluid to bring mud weight up to 10.8 ppg at 8700' - Mud weight in/out 10.8 ppg - Cal ECD 11.26, Act ECD 11.57 while drilling, rrincea: i vzoizvva i i:vv.yo Hiw ~ • BP Operations Summary Report Legal Well Name: 12-37 Page 9 of 15 ~ Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Hours ', Task Code NPT Phase Description of Operations 11/4/2008 112:00 - 19:00 I 7.001 DRILL I P 19:00 - 20:30 ~ 1.50 ~ DRILL ~ P 20:30 - 22:00 1.501 DRILL P 22:00 - 23:30 1.501 DRILL ~ P 23:30 - 00:00 0.501 DRILL P 11/5/2008 100:00 - 01:00 1.001 DRILL ~ P 01:00 - 02:45 I 1.751 DRILL I P 02:45 - 03:00 I 0.251 DRILL ~ P 03:00 - 04:15 1.251 DRILL ~ P 04:15 - 05:00 0.75 DRILL P 05:00 - 06:00 1.00 DRILL P 06:00 - 07:00 I 1.001 DRILL I P INT1 Drill ahead 8 3/4" hole from 9130' to 9716' and -Pumps 500 gpm at 3800 psi (3530 psi off bottom) - 60 rpm at 9k/ft-Ibs torque (6.6k/ft-Ibs torque off bottom) - PUW 190k, SOW 142k, ROT Wt 160k, WOB 15k - Cal ECD 11.23, Act ECD 11.63 - Mud weight in/out at 9716': 10.8 ppg INTi Circulate bottoms up to aquire geological sample: -Pumps 500 gpm at 3545 psi - 80 rpm at 6.5k/ft-Ibs - Samples not indicative of top of Sag river formation INT1 Drill from 9716' to 9726' and and circulate bottoms up for geological sample: - Pumps 500 gpm at 3590 psi - 80 rpm at 6.5k/ft-Ibs torque - Samples not indicative of top of Sag river formation INT1 Drill from 9726' to 9736' and and circulate bottoms up for geological sample: - Pumps 500 gpm at 3495 psi - 80 rpm at 6.6k/ft-Ibs torque - Samples not indicative of top of Sag river formation INT1 Drill from 9736' to 9756' and and circulate bottoms up for geological sample: - Pumps 500 gpm at 3505 psi - 80 rpm at 6.5k/ft-Ibs torque - PUW 192k, SOW 142k, ROT Wt 160k - AST 4.02 hrs, ART 8.55 hrs, ADT 12.57 hrs - Bit time 12.58 hrs, Jars 96.48 INT1 Circulate bottoms up to aquire geological sample: -Pumps 500 gpm at 3500 psi - 80 rpm at 6.5k/ft-Ibs - Samples not indicative of top of Sag river formation INT1 Drill from 9756' to 9777' and and circulate bottoms up for geological sample: - Pumps 500 gpm at 3495 psi - PUW 192k, SOW 142k, ROT Wt 160k - 80 rpm at 9k/ft-Ibs torque - Samples contain glauconite and sandstone indicative of top of Sag river formation. Drill additional three feet to TD. INT1 Drill from 9777' to TD at 9780' md, -Pumps: 500 gpm at 3755 psi - PUW 192k, SOW 142k, ROT Wt 160k, - 80 rpm at 9k/ft-Ibs torque INT1 POH for wiper trip from 9780' to 8744' and -PUW 195k, SOW 152k Consistant overpulls of 20k to 25k during wiper trip. INTi RIH from 8744' to 9704' md. Wash down from 9704' to TD at 9780', no fill seen on bottom. INT1 Circulate bottoms up with 35bb1 hi-vis sweep, rotation and reciprocation: - Pumps: 500 gpm at 3600 psi. - 80 rpm at Sk/ft-Ibs torque - PUW 192k SOW 142k, ROT Wt 160k INT1 POH from 9780' to 9078' and monitor well -static. Pump dry rnnce¢ i iicoicuuo i i.av.~o rave ~ r gp Page 10 of 15 Operations Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date :From - To Hours ~ Task Code NPT Phase Description of Operations -- --- 11/5/2008 06:00 - 07:00 1.00 DRILL P INT1 job and blow down top drive. 07:00 - 11:00 4.00 DRILL P INTi 11:00 - 13:00 2.00 DRILL P INTi 13:00 - 13:30 0.50 CASE P INT1 13:30 - 14:30 1.00 CASE P INTi 14:30 - 15:00 0.50 CASE P INT1 15:00 - 15:30 0.50 CASE P INT1 15:30 - 17:00 1.50 CASE P INTi 17:00 - 22:00 5.00 CASE P INTi 22:00 - 23:00 I 1.001 CASE I P I I INT1 23:00 - 00:00 1.001 CASE P INTi 11/6/2008 00:00 - 00:30 0.50 CASE P INT1 00:30 - 08:00 7.50 CASE P INT1 08:00 - 09:00 1.00 CASE P INT1 09:00 - 10:00 1.00 CASE P INT1 10:00 - 10:15 0.25 CASE P INT1 Continue POH from 9078' to 900'. 15k maximum over pulls, hole appears to be in good condition. Rack back 7 stands of HW DP and lay down 8 3/4" drilling BHA. 8.75" Hycalog bit graded at 1-1-BT-X-I-WT-TD. Clear rig floor. Pull wear ring, install test plug and 7" test joint. Change top pipe rams from 3.5" x 6" variable to 7" pipe rams.. and rig up test equipment. Low /high pressure test 7" rams. Good tests at 250 psi and 3500 psi Rig down test equipment. PJSM and dummy run with 7" mandrel hanger. Rig up 7" casing handling equipment and casing power tongs. Make up shoe track and baker-loc the first three joints. Confirm floats are holding. Continue running in the hole with 7" L-80_ BTC-M casing to 3729' at one joint per minute, filling the pipe every joint. - Average make-up torque of 7600 ft-Ibs - PUW 112k, SOW 98k Break circulation with 1.5 casing volumes. Stage up pumps: Initial: 3 bpm at 360 psi Final: 6 bpm at 482 psi Continue RIH from 3729' to 4517' at one joint per minute, filling the pipe every joint and circulating down every ten joints for five minutes. - PUW 126k, SOW 105k Make-up 7" BTC-M x TCI I crossover, 1 ea 2' space out pup. Rig up Torque turn equipment for TCII casing. Continue running in hole ~ 1 minute per joint with 7" 26# L-80 TC-II casing from 4,517' to 9,038' (Above top HRZ). Fill each joint and break circulation every 10 joints for 5 minutes Take PU/SO every 10 joints. Torque Turn casing to optimum make-up torque of 10,100 Wlbs. Used JetLube Seal Guard thread lubricant. 114 joints of TC-II casing run so far. PU - 252k, SO - 160k ~ 9,038'. Pushing away at -1 bbl per hour during running - No losses while circulating. Circulate 1.2 bottoms up C~ 5 bpm, 810 psi. Shut down and monitor well -static Continue running in hole C~ 1 minutes per joint with 7" 26# L-80 TC-II casing from 9,038' to 9,748'. Fill each joint but no circulating in the HRZ or Kingak. Torque Turn casing to make-up torque of 10,100 ft/Ibs. Used JetLube Seal Guard pipe lubricant. 132 total joints of TC-II casing run. Pick up 7" hanger, landing joint and land casing on depth ~ 9,777', Up wt 195k Dn Wt 155k. HES Float Shoe -Bottom C~? 9,777' 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Float Collar - Top ~ 9,693' 114 Jts 7", 26#, L-80 BTC-Mod (#3-116) 7", 26#,L-80 TC-II x BTC-Mod Crossover Pup. iea 7", 26#, TC-II 2ft Space out pup Printed: 11/25/2008 11:04:45 AM ~ ~ gp Page 11 of 15 Operations Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase ii Description of Operations 11/6/2008 10:00 - 10:15 0.25 CASE P INT1 132 Jts 7", 26#, TC-II (#117-248) 7" 26# L-80 TC-II Pup Jt. FMC Hanger Total of 112 - 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers and 2 stop collars: 1 centralizer on Jts 1 & 3 w/ locked w/ set screws 10' from shoe. BTC-M jts 21-116, XO jt, & TC-II jts 117-128 have one free floating on entire joint. 10:15 - 10:30 0.25 CEMT P INTi Rig down Frank's tool. Make up cementing head. 10:30 - 12:30 2.00 CEMT P INT1 Break circulation. Stage pumps up from 1 bpm to 5 bpm, FCP - 660 psi. Condition mud for cementing. Held cementing PJSM while circulating. Did not reciprocate casing. 12:30 - 14:00 1.50 CEMT P INTi Switch to Dowell. Pump 10 bbls MudPush II viscosified spacer. Pressure test lines to 4,000 psi - OK. Pump additional 41 bbls 11.5 ppg of MudPush II ~ 5 bpm, 550 psi. Drop bottom plug. Mix & pump 145 bbls 12 ppg LiteCrete ~ 5 bpm ICP - 600 psi, FCP - 320 psi followed by 40.6 bbls of Class "G" 15.8 ppg cement C~ 4 bpm avg, ICP - 200, FCP - 100 psi. Drop top plug and wash up on top of plug w/ 10 bbls H2O. Swap to rig pumps. 14:00 - 15:30 1.50 CEMT P INT1 Switch to rig and displace cement with 360.7 bbls of 10.8 ppg mud. 1st 197 bbls ~ 6 bpm, 270 psi ICP, 375 psi FCP. Reduce rate to 4 bpm ~ 197 bbls away - 330 psi ICP, 980 psi FCP. Reduce rate to 3 bpm ~ 256 bbls away - 960 psi ICP, 1640 psi FCP. Reduce rate to 2 bpm ~ 312 bbls away - 1520 psi ICP, 1820 psi FCP. Reduce rate to 1 bpm ~ 347 bbls away - 1610 psi ICP, 1661 psi FCP. Bumped plug at 6,275 strokes - 94.6% efficiency. CIP ~ 15:29 hr. Pressure up to 2150 psi for 2 minutes - no bleedoff. Full returns during all of 15:30 - 16:00 0.50 CASE P INTi Bring pressure up to 3 460 psi and pressure test 7" casing for 30 minutes. Pressure held steady at 3,540 psi throughout entire test. 16:00 - 17:00 1.00 CEMT P INT1 Bleed off pressure, check for flowback - No flow. Back out landing joint. Lay down all casing and cementing equipment. 17:00 - 18:00 1.00 WHSUR P INT1 Install 7" Packoff and run in lock down screws. Torque to 450 ft-Ibs. Test to 5000 psi for 15 min., Good Test. 18:00 - 18:30 0.50 WHSUR P INTi Drain BOP stack. RU lines for OA injection. Inject 5 bbls 10.8 ppg LSND down OA ~ 18 spm. 18:30 - 19:30 1.00 BOPSU P INT1 Chan e U er Pi a Rams to 3 1/2 x 6 v i ~ & prepare to test w/ 4" test joint. 19:30 - 20:00 0.50 BOPSU P INTi Test upper pipe rams w/ 4" test joint to 250 psi low & 3,500 psi high *Note: Sim Ops - OA injection: Inject 10.9 ppg LSND mud total ~ 0.5 bpm every 30 minutes to maintain injection channel. 20:00 - 21:00 1.00 BOPSU P INT1 RD testing equipment. Install wear ring. 21:00 - 23:00 2.00 DRILL P PROD1 PJSM. PU 6-1/8" drilling BHA #4 w/MX-R18DX, 7/8 3 stage Motor 1.5ABH w/float, NM Stab, NM Flex Lead DC, Impulse MWD, ADN4, Sea NM Flex DC, Hyd Jars, HWDP. 23:00 - 00:00 1.00 DRILL P PROD1 RIH on 4" drill pipe from 844' to 940'. Shallow tested MWD at Printetl: 11/'L5/2UUt5 11:U4:4b AM ~ i g P Page 12 of 15 Operations Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase II Description of Operations 11/6/2008 23:00 - 00:00 1.00 DRILL P PROD1 940' - 240 gpm, 1350 psi. Continue RIH to 1,200' md. 11/7/2008 00:00 - 03:30 3.50 DRILL P PROD1 RIH on 4" drill pipe from 1,200'to 9,444'. 03:30 - 05:00 1.50 DRILL P PROD1 Cut and Slip 125' of drilling line. Service top drive and crown, 05:00 - 05:30 0.50 DRILL P 05:30 - 06:00 0.50 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 08:30 I 1.501 DRILL I P 08:30 - 09:00 I 0.501 DRILL I P 09:00 - 10:00 1.00 DRILL P 10:00 - 10:30 0.50 DRILL P 10:30 - 12:00 1.50 DRILL P 12:00 - 20:00 I 8.001 DRILL I P 20:00 - 00:00 I 4.001 DRILL I P 11/8/2008 100:00 - 02:00 I 2.001 DRILL I P inspect drawworks. *Note: Sim Ops - OA injection: In'ect 106 bbls 10.9 LSND mud total ~ 6 b m to flush annulus After UCA i i rp?cSiv_e stren th RU Little Red Hot Oil & In'ect 60 bbls dead crude for freeze roteci to 2,060' md. PROD1 PJSM. Perform well kill drill. All hands on Pettit crew given chance to operate choke while in cased hole. PROD1 Continue RIH from 9,440' and to 9,690' md. Tag cement stringers at 9685' and tag plugback at 9690' PROD1 Drill shoe track from 9690' to 9770': - Pumps: 230 gpm at 2360 psi - PUW 205k, SOW 117k, ROT Wt 145k - 40 rpm at 10.Ok/ft-Ibs torque - Mud weight in/out: 10.8 ppg PROD1 Displace well from 10.8 LSND to 8.4 ppg FloPro SL with a 50 bbls fresh water spacer. - Initial /Final circulating pressures at 250 gpm: 2249 psi / 1625 psi - Mud weight in/out: 8.4 ppg PROD1 Drill out the remainder of the shoe track plus 20' of new hole. -Pumps: 250 gpm at 1680 psi (1530 psi off bottom) - PUW 205k, SOW 117k, ROT Wt 145k, WOB 12k - 80 rpm at 7.Ok/ft-Ibs torque (6.Ok/ft-Ibs off bottom) - Mud weight in/out: 8.4 ppg PROD1 Circulate bottoms up, rotate and reciprocate. - Pumps: 250 gpm at 1590 psi PROD1 Rig up test equipment and perform FIT to 10.5 ppg EMW with 955 psi surface pressure. Rig down test equipment. PROD1 Drill from 9800'to 9836'. - Pumps: 250 gpm at 1715 psi (1520 psi off bottom) - PUW 182k, SOW 125k, ROT Wt 145k - 80 rpm at 7.Ok/ft-Ibs torque (5.5k/ft-Ibs off bottom) - Mud weight in/out: 8.4 ppg PROD1 Drill from 9836' to TD at 10450'!` -Pumps: 250 gpm at 1920 psi (1665 psi off bottom) - PUW 200k, SOW 150k, ROT Wt 160k - 80 rpm at 7.Ok/ft-Ibs torque (6.Ok/ft-Ibs off bottom) - ADT 7.12hrs, ART 7.12hrs, AST 0.00 hrs, Bit 7.12 hrs - Mud weight in/out: 8.4 ppg PROD1 MAD pass to re-evaluate Ivishak production interval at 200fUhr from TD at 10450' and to 10017'. - Pumps 250 gpm at 1675 psi - PUW 195k, SOW 150k, ROT Wt 160k - 60 rpm at 6.Ok/ft-Ibs torque PROD1 Continued MAD pass evaluation of the Ivishak production interval at 200fUhr from 10017' to 9723' - Pumps 250 gpm at 1675 psi - PUW 195k, SOW 150k, ROT Wt 160k Printed: 11/25/2008 11:04:45 AM gp Page 13 of 15 ~ Operations Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date ;From - To Hours Task ~ Code NPT .Phase Description of Operations 11/8/2008 00:00 - 02:00 2.00 DRILL P PROD1 - 60 rpm at 6.Ok/ft-Ibs torque 02:00 - 03:00 1.00 DRILL P PROD1 Complete MAD pass. Circulate bottoms up -Pumps 250 gpm at 1600 psi - PUW 185k, SOW 150k 03:00 - 06:30 3.50 DRILL P PRODi POH from 9723' to 844' 06:30 - 09:00 2.50 DRILL P PROD1 Lay down 21 jts of HWDP 09:00 - 09:30 0.50 DRILL P PROD1 Lay down 6 1/8" drilling BHA#4 Bit Grade: 1-3-BT-G-E-1-LT-TD 09:30 - 14:30 5.00 DRILL N SFAL PROD1 Troubleshoot BOP ram door 14:30 - 15:30 1.00 CASE P RUNPRD Test top pipe rams with 4.5" test joint to 250 psi and 3500 psi, good tests. Rig down test equipment. 15:30 - 16:30 1.00 CASE P RUNPRD Rig up casing handling equipment and torque turn 16:30 - 19:00 2.50 CASE P RUNPRD Make up shoe track w/Bakerlok. RIH and verify floats. Continue RIH w/ 19 joints of 4.5" 12.6# L-80 Vam-too liner at 1 jt. per minute to 846 md. Filled each jt and topped off w/ top drive off every 10 joints. Make up connections to optimum torque of 4400 ft-Ibs. - Two centralizers and one stop ring on all but joint 16 -PUW 37k, SOW 37k 19:00 - 19:30 0.50 CASE P RUNPRD Establish circulation slowly while monitoring for losses - Circulate 1 1/2 DP and liner volume at 210 gpm, 130 psi - Stop circulation, monitor well -Static - 3 bbls lost during circulation 19:30 - 00:00 4.50 CASE P RUNPRD RIH with 4.5" liner on 4" drill pipe from 846' to 9573' and - PUW 160k, SOW 135k Total losses to the formation for the day of 22bbls 11/9/2008 00:00 - 01:00 1.00 CEMT P RUNPRD RIH from 9573' to 9777' md. Circulate 1.5 liner and drill pipe volumes staging up the pumps from 1 bpm at 620 psi to 5 bpm at 715 psi. 01:00 - 02:00 1.00 CEMT P RUNPRD RIH from 9777' to 10,450'. Make up cement head and tag TD_ 02:00 - 03:00 1.00 CEMT P RUNPRD Circulate three open hole volumes and reciprocate while Schulmberger cementers rig up. Staged up the pumps from 1 bpm at 620 psi to 5 bpm at 863 psi. 03:00 - 04:00 1.00 CEMT P RUNPRD PJSM. Pump 10 bbls Mudpush to floor and downhole w/Schlumberger pumps. Shut in and pressure test lines to 4000 psi. Pump a total of 20.0 bbls 12.0 ppg Mudpush down hole. At 0320 hrs start to pump 25.0 bbls 15.8 ppQ class G tail w/ GasBlok slur at 5 bpm. ICP - 622 psi, FCP - 261 psi. Shut down. Clear lines of cement by pumping mud through topdrive to bleeder. Drop drill pipe wiper dart, witness positive indication of plug drop. Total displacement = 106.8 bbls. Pump 8.4 ppg FloPro ~ 5 bpm. Slow to 3 bpm at 86 bbls away & see drill pipe wiper dart catch liner wiper olua C~ 87 bbls away, shear off at 2000 psi. Maintain 3 bpm until plug bump. See lu s bum landin collar as ex ected - 1700 strokes, 2500 psi. Saw good lifting pressure throughout displacement. No measureable losses durin dis lacement. Cement in place at 0356 hrs. At plug bump bring pressure up to 2600 psi ancL hold f/3 mins to set liner han er sli s. 04:00 - 05:00 1.00 CEMT P RUNPRD Slack off to 75k to verify liner hanger slips. Hanger holding. Printed: 11/25/2008 11:04:45 AM • gp Page 14 of 15 Operations. Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date !From - To Hours ~ Task Code'i NPT i Phase Description of Operations 11/9/2008 04:00 - 05:00 1.00 CEMT P RUNPRD PU to 140k, pressure to 3,500 psi and hold. PU to expose rotating dog sub and slack off 75k -Good indication of set -felt strong jolt on rig floor. Rotate at 15 rpm. Slack off while rotating to confirm set of ZXP packer. Saw no further indication. Bleed off pressure to zero and check floats for bleedoff back to surface. Floats holding. Pressure up to 1000 psi. PU until PBR packoff cleared liner top extension sleeve and pressure dropped off. Circulate out cement above liner top with 30 bbls 8.4 ppg FloPro. PU 36' to clear liner top w/stinger and put NOGO mark on drill pipe. Circulate and reciprocate at 450 gpm, 1835 psi. Mudpush and 9 bbls of cement seen at s rfa e. 05:00 - 06:00 1.00 CASE P RUNPRD Rig down and lay down cement head and 1 single. Displace well to 8.5 ppg seawater. 06:00 - 14:00 8.00 CASE P RUNPRD POH from 9571' to surface laying down drill pipe to the shed. Baker running tool returned to surface with dog sub sheared. 14:00 - 14:30 0.50 CASE P RUNPRD Close blind rams and test 7" casing and 4.5" Liner to 3500 p~. for 30 min. Lost 30 psi in 1st 15 min and 0 psi in second 15 min. Rig down test equipment. 14:30 - 16:30 2.00 BUNCO RUNCMP Pull wear ring, rig up to run completion and make a dummy run with the tubing hanger. 16:30 - 00:00 7.50 BUNCO RUNCMP Make up tail pipe assembly to packer assembly and Baker-loc all joints below the packer. RIH to 6302' and w/ 4.5" 12.6# 13Cr80 Vam Top com letion. Torque Turn set to 4,440 ft./Ibs optimum torque 11/10/2008 00:00 - 04:00 4.00 BUNCO RUNCMP RIH with 4.5" 12.6# 13Cr80 Vam Top completion from 6302'to 9571' md. Torque Turn set to 4,440 ft./Ibs optimum torque 04:00 - 05:00 1.00 BUNCO RUNCMP RIH with WLEG -Pick up and repeat tag up sequence to ensure entry into tie-back sleeve -Space out with 9.82' and 19.79' pup joints placed one full jt below hanger -Total 221 jts run 4 1/2" 12.6# 13CR Vam Top completion string 05:00 - 05:30 0.50 BUNCO RUNCMP Land tubing hanger with 110k and run in lockdown screws 05:30 - 08:00 2.50 BUNCO RUNCMP Reverse circulate corrosion inhibitor -Reverse circulate 176 bbls clean seawater into annulus -Follow with 71 bbls corrosion inhibited seawater into annulus -Displace with 75 bbl clean seawater (to position inhibited water between packer and GLM with shear valve) at 3 bpm, 260 psi 08:00 - 10:00 2.00 BUNCO RUNCMP Drop ball and rod to set packer and test tubing for 30 min at 3500 si - ood test. Slowly bleed tubing pressure to 1500 psi and pressure up the inner annulus to 3500 psi for 30 min - good test. Bleed annular pressure to 0 psi then tubing pressure to 0 psi. Pressure annulus to 3000 psi to shear DCK valve in GLM #5 -Valve sheared at 3300 psi Confirmed shear by pumping 2 bbls through both annulus and tubing 10:00 - 10:30 0.50 BUNCO RUNCMP Install TWC and ressure from below to 1000 si for 5 mins - good test. Blow down choke and kill lines. 10:30 - 12:00 1.50 BUNCO RUNCMP Nipple down BOP stack Printed: 11/25/2008 11:04:45 AM gP Page 15 of 15 Operations Summary Report Legal Well Name: 12-37 Common Well Name: 12-37 Spud Date: 10/25/2008 Event Name: DRILL+COMPLETE Start: 10/21/2008 End: 11/10/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/10/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To !Hours Task Code NPT Phase ~ Description of Operations 11/10/2008 12:00 - 14:00 2.00 BUNCO RUNCMP Nipple up tree and tubing head adaptor 14:00 - 14:30 0.50 BUNCO RUNCMP Pressure test tree, adaptor flange and pack-offs to 5000 psi - good tests. 14:30 - 15:30 1.00 BUNCO RUNCMP Ri u Valve crew lubricator and ull TWC 15:30 - 18:00 2.50 BUNCO RUNCMP Rig up Little Red Services and pump 75 bbls diesel to freeze protect inner annulus. Allow well to u-tube into balance. 18:00 - 19:00 1.00 BUNCO RUNCMP Rig up valve crew lubricator and install BPV. Pressure test frc below to 1000 psi.. Secure well and release rig at 1900 hrs. Prepare to move to H-38 Pflnt2tl: 11/25/LUUt3 11:U4:4S HM M 4. ~~~- = l Report Date: 8-Nov-08 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - EOA Structure /Slot: DS-12 / 12-37 Well: 12-37 Borehole: 12-37 UWVAPI#: 500292339800 Survey Name /Date: 12.37 /November 8, 2008 Tort /AHD / DDI I ERD ratio: 122.000° / 4546.77 ft / 5.800 / 0.495 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVLong: N 70.21608164, W 148.41197563 Location Grid NIE Y/X: N 5931140.330 ftUS, E 696861.770 ftUS Grid Convergence Angle: +1.49433645° Grid Scale Factor: 0.99994403 rtepvri Survey /DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 353.760° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 68.10 ft relative to MSL Sea Bed /Ground Level Elevation: 39.10 ft relative to MSL Magnetic Declination: 23.084° Total Field Strength: 57691.261 nT Magnetic Dip: 80.888° Declination Date: October 28, 2008 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North -> True North: +23.084° u Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft tt ft ft ft de lm ft ftUS ftUS AI ~!\~fi C/10i CA \A/iAO Ai i(1~GC7 RTE 0.UU U.UU U.VU -b25.1u U.VV V. UU U.VV U.UU v.uu v.vv v.vv o~allvv. ao va~ov i.,i Iv iv.c ~vw ~v+ .. 1+a+.+~ 1ai ...+.+ GYD GC SS 89.00 0.17 174.98 20.90 89.00 -0. 13 0.13 0.13 -0.13 0.01 0.19 5931140. 20 696861.78 N 70.21608128 W 148.41197554 189.00 0.51 119:10 120.90 189.00 -0. 54 0.69 0.65 -0.50 0.41 0.44 5931139. 85 696862.20 N 70.21608028 W 148.41197229 277.00 1.77 92.78 208.88 276.98 -0. 98 2.42 2.24 -0.75 2.11 1.51 5931139. 63 696863.90 N 70.21607958 W 148.41195859 370.00 2.57 89.63 301.81 369.91 -1. 42 5.94 5.69 -0.81 5.63 0.87 5931139. 67 696867.42 N 70.21607943 W 148.41193020 467.00 4.09 86.86 398.65 466.75 -1. 83 11.57 11.28 -0.60 11.26 1.58 5931140. 02 696873.04 N 70.21607998 W 148.41188480 MWD+IFR+MS 516.95 4.69 82.33 448.45 516.55 -1. 87 15.39 15.07 -0.23 15.06 1.39 5931140. 49 696876.83 N 70.21608099 W 148.41185413 570.79 5.52 77.43 502.07 570.17 -1. 53 20.18 19.78 0.62 19.77 1.74 5931141. 47 696881.52 N 70.21608334 W 148.41181616 630.82 6.50 71.70 561.77 629.87 -0. 50 26.46 25.92 2.32 25.82 1.91 5931143. 32 696887.52 N 70.21608797 W 148.41176741 660.64 7.18 69.97 591.38 659.48 0. 29 30.01 29.38 3.49 29.17 2.38 5931144. 58 696890.84 N 70.21609116 W 148.41174036 721.10 7.49 63.71 651.35 719.45 2. 55 37.72 36.84 6.53 36.25 1.42 5931147 .80 696897.84 N 70.21609946 W 148.411 750.41 7.95 59.09 680.39 748.49 4. 05 41.66 40.59 8.41 39.71 2.63 5931149 .78 696901.24 6 N 70.21610462 W 148.4116 840.18 8.64 48.39 769.23 837.33 10. 54 54.57 52.59 16.08 50.07 1.88 5931157 .71 696911.40 N 70.21612557 W 148.41157 936.59 9.52 33.58 864.44 932.54 20 .86 69.70 65.92 27.53 59.90 2.58 5931169 .41 696920.93 N 70.21615685 W 148.41149253 1029.61 10.83 25.16 956.00 1024.10 34 .23 86.11 79.74 41.85 67.87 2.13 5931183 .94 696928.52 N 70.21619598 W 148.41142824 1121.63 12.95 15.52 1046.05 1114.15 51 .19 105.02 95.27 59.62 74.31 3.15 5931201 .86 696934.49 N 70.21624450 W 148.41137634 1217.44 13.89 8.91 1139.25 1207.35 72 .26 127.24 113.35 81.32 78.96 1.88 5931223 .68 696938.58 N 70.21630381 W 148.41133880 1317.37 13.92 5.39 1236.25 1304.35 95 .61 151.24 133.30 105.14 81.95 0.85 5931247 .57 696940.94 N 70.21636887 W 148.41131471 1415.40 14.94 0.47 1331.19 1399.29 119 .71 175.66 153.92 129.52 83.16 1.63 5931271 .96 696941.52 N 70.21643547 W 148.41130494 1511.85 16.44 357.67 1424.05 1492.15 145 .68 201.74 176.20 155.59 82.71 1.74 5931298 .01 696940.39 N 70.21650670 W 148.41130859 1603.54 17.89 357.54 1511.65 1579.75 172 .68 228.80 200.01 182.62 81.57 1.58 5931325 .01 696938.55 N 70.21658055 W 148.41131771 1700.38 19.24 355.46 1603.45 1671.55 203 .47 259.62 227.78 213.39 79.67 1.55 5931355 .71 696935.85 N 70.21666461 W 148.41133305 1797.38 20.74 353.42 1694.61 1762.71 236 .62 292.78 257.97 246.39 76.44 1.71 5931388 .61 696931.75 N 70.21675476 W 148.41135912 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 12-37\12-37\12-37\12-37 Generated 1 /26/2009 3:56 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft tt ft ft de 100tt n cc ftUS Cnh1 A77 ~i ftUS C[1C[]7C A4 AI ~!1 ~J1C4Afl7~] \A/ i A4 Ai i'~O!\A1 7 t5`J3.4/ LI.Lq SJ3.04 (/84.31 IOJL.41 L/I.VV JL/.LL Loa.oJ cVV.vv ic.:/v - - - 1988.68 23.19 351.77 1872.45 1940.55 307.06 363.22 323.54 316.32 67.96 2.16 5931458.29 696921.46 N 70.21694580 W 148. 41142748 2083.61 25.20 348.42 1959.04 2027.14 345.86 402.12 359.87 354.62 61.23 2.56 5931496.40 696913.73 N 70.21705044 W 148. 41148178 2179.68 26.80 347.27 2045.38 2113.48 387.75 444.23 399.23 395.78 52.35 1.75 5931537.32 696903.78 N 70.21716290 W 148. 41155339 2275.93 27.23 345.36 2131.13 2199.23 431.09 487.95 440.26 438.25 42.00 1.01 5931579.51 696892.33 N 70.21727893 W 148. 41163684 2371.31 27.97 344.91 2215.66 2283.76 474.78 532.13 481.94 480.96 30.67 0.81 5931621.90 696879.88 N 70.21739561 W 148. 41172829 2466.72 28.03 343.08 2299.90 2368.00 518.92 576.92 524.34 524.02 18.32 0.90 5931664.61 696866.41 N 70.21751322 W 148. 41182789 2562.11 26.59 342.38 2384.66 2452.76 561.88 620.69 565.83 565.81 5.33 1.55 5931706.05 696852.34 N 70.21762739 W 148. 41193264 2658.20 26.22 343.40 2470.72 2538.82 603.84 663.42 606.69 606.65 -7.24 0.61 5931746.55 696838.71 N 70.21773896 W 148. 41203405 2754.01 26.41 345.09 2556.61 2624.71 645.72 705.89 647.79 647.52 -18.77 0.81 5931787.10 696826.12 N 70.21785063 W 148. 41212705 2850 01 24.83 345.36 2643.16 2711.26 686.77 747.40 688.28 687.66 -29.36 1.65 5931826.95 696814.49 N 70.21796028 W 148. 41221245 . 2945.61 24.66 346.54 2729.99 2798.09 726.42 787.41 727.52 726.47 -39.08 0.55 5931865.50 696803.76 N 70.21806632 W 148. 4122 3041.10 24.74 347.28 2816.74 2884.84 766.03 827.32 766.85 765.34 -48.11 0.33 5931904.11 696793.72 N 70.21817250 W 148. 41236371 3136.36 25.13 347.47 2903.12 2971.22 805.95 867.48 806.54 804.53 -56.89 0.42 5931943.05 696783.92 N 70.21827956 W 148. 41243451 3232.27 26.20 347.86 2989.57 3057.67 847.25 909.02 847.66 845.11 -65.76 1.13 5931983.39 696774.00 N 70.21839043 W 148. 41250606 3327.11 26.74 347.44 3074.46 3142.56 889.28 951.29 889.55 886.40 -74.81 0.60 5932024.43 696763.88 N 70.21850324 W 148. 41257901 3421.72 25.42 346.63 3159.44 3227.54 930.59 992.88 930.74 926.93 -84.13 1.45 5932064.70 696753.50 N 70.21861397 W 148. 41265422 3517.02 25.77 347.59 3245.39 3313.49 971.48 1034.05 971.56 967.07 -93.31 0.57 5932104.58 696743.28 N 70.21872361 W 148. 41272829 3612.67 25.40 347.67 3331.66 3399.76 1012.55 1075.36 1012.58 1007.41 -102.16 0.39 5932144.68 696733.38 N 70.21883384 W 148. 41279967 3698.89 26.30 347.60 3409.25 3477.35 1049.93 1112.95 1049.94 1044.13 -110.21 1.04 5932181.18 696724.38 N 70.21893416 W 148. 41286461 9-5/8" ~ 3755'md 3809.49 27.10 347.48 3508.06 3576.16 1099.33 1162.64 1099.33 1092.66 -120.93 0.72 5932229.40 696712.39 N 70.21906672 W 148 .41295111 3906.54 27.04 346.35 3594.48 3662.58 1143.18 1206.81 1143.20 1135.68 -130.93 0.53 5932272.14 696701.28 N 70.21918424 W 148 .41303176 4004.45 26.91 346.29 3681.73 3749.83 1187.22 1251.22 1187.28 1178.83 -141.43 0.14 5932315.00 696689.65 N 70.21930213 W 148 .41311649 4097.76 27.26 344.96 3764.81 3832.91 1229.27 1293.70 1229.41 1219.98 -151.98 0.75 5932355.86 696678.03 N 70.21941455 W 148 .41320159 4192.88 25.74 345.53 3849.94 3918.04 1271.24 1336.14 1271.48 1261.02 -162.80 1.62 5932396.60 696666.15 N 70.21952667 W 148 .41328883 4288.74 24.65 347.89 3936.68 4004.78 1311.73 1376.95 1312.07 1300.72 -172.19 1.55 5932436.04 696655.73 N 70.21963514 W 148 .41336463 4386.97 25.66 347.90 4025.59 4093.69 1353.27 1418.70 1353.70 1341.55 -180.95 1.03 5932476.63 696645.91 N 70.21974667 W 148 .41343527 4482.55 24.38 348.88 4112.20 4180.30 1393.51 1459.12 1394.03 1381.14 -189.09 1.41 5932515.99 696636.74 N 70.21985484 W 148 .41350096 4578.29 24.39 348.25 4199.40 4267.50 1432.88 1498.65 1433.48 1419.88 -196.93 0.27 5932554.51 696627.89 N 70.21996068 W 148 .41356+ 4673.58 24.40 347.66 4286.18 4354.28 1472.03 1538.01 1472.73 1458.37 -205.14 0.26 5932592.77 696618.68 N 70.22006583 W 148 .41363 4769.66 23.71 347.00 4373.92 4442.02 1510.95 1577.17 1511.77 1496.58 -213.73 0.77 5932630.74 696609.10 N 70.22017022 W 148 .41369972 4865.28 24.00 348.44 4461.37 4529.47 1549.40 1615.84 1550.34 1534.37 -221.95 0.68 5932668.30 696599.90 N 70.22027344 W 148 .41376604 4961.02 24.45 349.71 4548.68 4616.78 1588.55 1655.12 1589.58 1572.94 -229.39 0.72 5932706.66 696591.45 N 70.22037881 W 148 .41382608 5055.24 24.28 349.81 4634.51 4702.61 1627.33 1693.99 1628.43 1611.19 -236.30 0.19 5932744.72 696583.55 N 70.22048331 W 148 .41388183 5151.58 24.26 349.19 4722.33 4790.43 1666.82 1733.59 1668.00 1650.12 -243.52 0.27 5932783.45 696575.32 N 70.22058968 W 148 .41394005 5246.74 23.98 348.65 4809.18 4877.28 1705.57 1772.48 1706.84 1688.29 -250.99 0.37 5932821.40 696566.85 N 70.22069394 W 148 .41400034 5342.37 23.88 348.82 4896.59 4964.69 1744.21 1811.27 1745.59 1726.33 -258.57 0.13 5932859.23 696558.29 N 70.22079787 W 148 .41406148 5438.06 23.88 349.78 4984.09 5052.19 1782.82 1850.00 1784.29 1764.39 -265.76 0.41 5932897.09 696550.11. N 70.22090185 W 148 .41411951 5533.85 23.85 351.52 5071.69 5139.79 1821.52 1888.76 1823.04 1802.63 -272.06 0.74 5932935.15 696542.81 N 70.22100631 W 148 .41417031 5627.64 24.64 355.23 5157.22 5225.32 1860.01 1927.26 1861.52 1840.87 -276.48 1.83 5932973.26 696537.40 N 70.22111078 W 148 .41420599 5724.40 24.73 355.06 5245.13 5313.23 1900.41 1967.67 1901.84 1881.13 -279.90 0.12 5933013.42 696532.93 N 70.22122078 W 148 .41423359 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 12-37\12-3712-3T12-37 Generated 1/26/2009 3:56 PM Page 2 of 4 Comments Measured Inclination Azimuth SulS-Sea TVD ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS 513LU.UI 1b.y5 J5b.:32i b3:i1.54 SJyy.234 1y41.:i"G "LUUt3.by ly4L.b23 lyLl.yl -L23:3..31 1.625 byJ:3Ub4.Uy bybbGC.4b IV /U.LLI.SJC 125 VV 1425. 414Lb1U`J 5916.22 25.66 354. 47 5418.16 5486.26 1983.19 2050.47 1984.49 1963.63 -287. 01 0.51 5933095. 69 696523.67 N 70.22144615 W 148. 41429098 6011.80 27.00 353. 28 5503.82 5571.92 2025.58 2092.86 2026.85 2005.77 -291. 54 1.51 5933137. 70 696518.04 N 70.22156129 W 148. 41432756 6107.30 26.95 352. 07 5588.93 5657.03 2068.89 2136.18 2070.16 2048.74 -297. 07 0.58 5933180. 51 696511.40 N 70.22167867 W 148. 41437213 6203.02 27.46 351. 41 5674.06 5742.16 2112.62 2179.94 2113.92 2092.04 -303. 35 0.62 5933223. 63 696503.98 N 70.22179697 W 148. 41442287 6298.73 26.73 351. 82 5759.27 5827.37 2156.18 2223.53 2157.51 2135.17 -309. 71 0.79 5933266. 57 696496.50 N 70.22191479 W 148. 41447419 6393.96 26.59 349. 04 5844.38 5912.48 2198.83 2266.25 2200.22 2177.29 -316. 81 1.32 5933308. 50 696488.31 N 70.22202987 W 148. 41453147 6490.12 26.63 347. 64 5930.35 5998.45 2241.71 2309.32 2243.22 2219.47 -325. 52 0.65 5933350. 43 696478.51 N 70.22214510 W 148. 41460171 6585.31 25.70 348. 34 6015.79 6083.89 2283.47 2351.30 2285.11 2260.53 -334. 26 1.03 5933391. 24 696468.70 N 70.22225726 W 148 .41467222 6681.73 25.69 347. 74 6102.67 6170.77 2325.06 2393.10 2326.83 2301.43 -342. 92 0.27 5933431. 90 696458.97 N 70.22236899 W 148 .41474213 6776.93 25.56 347. 54 6188.51 6256.61 2366.00 2434.27 2367.91 2341.64 -351. 73 0.16 5933471. 87 696449.12 N 70.22247886 W 148 .41481324 8 6872.55 25.08 345. 89 6274.94 6343.04 2406.58 2475.16 2408.66 2381.44 -361. 12 0.89 5933511 .41 696438.69 N 70.22258758 W 148 .4148 6967.61 25.36 345. 36 6360.94 6429.04 2446.68 2515.67 2448.97 2420.68 -371. 18 0.38 5933550 .36 696427.62 N 70.22269477 W 148 .41497017 7063.46 25.50 348. 88 6447.51 6515.61 2487.54 2556.82 2490.00 2460.78 -380. 35 1.58 5933590 .22 696417.41 N 70.22280434 W 148 .41504415 7159.14 25.50 348. 81 6533.87 6601.97 2528.58 2598.01 2531.16 2501.20 -388. 32 0.03 5933630 .40 696408.39 N 70.22291475 W 148 .41510846 7254.72 24.83 348. 02 6620.38 6688.48 2569.05 2638.65 2571.76 2541.01 -396. 47 0.78 5933669 .99 696399.19 N 70.22302352 W 148 .41517429 7349.65 23.99 349. 81 6706.82 6774.92 2608.14 2677.88 2610.95 2579.50 -404. 03 1.18 5933708 .27 696390.64 N 70.22312868 W 148 .41523523 7445.75 23.80 352. 47 6794.69 6862.79 2647.01 2716.80 2649.87 2617.96 -410. 02 1.14 5933746 .55 696383.64 N 70.22323373 W 148 .41528364 7540.30 23.13 352. 24 6881.42 6949.52 2684.65 2754.45 2687.51 2655.27 -415. 03 .0.72 5933783 .72 696377.66 N 70.22333567 W 148 .41532405 7637.64 24.10 353. 24 6970.61 7038.71 2723.63 2793.44 2726.49 2693.95 -419. 95 1.08 5933822 .26 696371.74 N 70.22344134 W 148 .41536377 7732.41 23.42 351. 77 7057.35 7125.45 2761.81 2831.62 2764.66 2731.80 -424. 93 0.95 5933859 .97 696365.78 N 70.22354475 W 148 .41540392 7828.25 24.74 351. 80 7144.84 7212.94 2800.89 2870.72 2803.76 2770.51 -430. 51 1.38 5933898 .51 696359.18 N 70.22365048 W 148 .41544901 7923.39 24.46 352. 00 7231.35 7299.45 2840.47 2910.33 2843.36 2809.72 -436. 09 0.31 5933937 .56 696352.58 N 70.22375760 W 148 .41549405 8017.99 25.60 352. 50 7317.06 7385.16 2880.48 2950.35 2883.37 2849.37 -441. 49 1.23 5933977 .06 696346.16 N 70.22386595 W 148 .41553759 8114.22 25.92 351. 16 7403.73 7471.83 2922.28 2992.17 2925.19 2890.77 -447. 43 0.69 5934018 .28 696339.13 N 70.22397903 W 148 .41558558 8210.42 25.50 351. 64 7490.41 7558.51 2963.97 3033.91 2966.92 2932.03 -453. 67 0.49 5934059 .36 696331.82 N 70.22409176 W 148 .41563596 8306.11 25.47 352. 09 7576.79 7644.89 3005.12 3075.08 3008.09 2972.79 -459. 50 0.20 5934099 .96 696324.93 N 70.22420311 W 148 .41568298 8401.32 27.16 352. 86 7662.13 7730.23 3047.32 3117.28 3050.29 3014.63 -465. 02 1.81 5934141 .64 696318.32 N 70.22431742 W 148 .41572753 8497.19 29.31 352 .87 7746.58 7814.68 3092.66 3162.64 3095.62 3059.63 -470. 65 2.24 5934186 .47 696311.52 N 70.22444036 W 148 .4157 8548.76 31.38 354 .48 7791.09 7859.19 3118.71 3188.69 3121.65 3085.53 -473. 51 4.31 5934212 .28 696307.99 N 70.22451110 W 148 7 .41579 8591.79 32.55 353 .93 7827.59 7895.69 3141.49 3211.47 3144.40 3108.19 -475. 81 2.80 5934234 .88 696305.10 N 70.22457301 W 148 .41581466 8687.96 39.87 358 .06 7905.15 7973.25 3198.19 3268.22 3200.94 3164.81 -479. 60 8.02 5934291 .37 696299.84 N 70.22472769 W 148 .41584523 8783.77 42.97 359 .75 7976.99 8045.09 3261.30 3331.60 3263.78 3228.17 -480. 78 3.44 5934354 .68 696297.00 N 70.22490079 W 148 .41585480 8879.48 46.03 359 .96 8045.24 8113.34 3328.00 3398.68 3330.16 3295.25 -480. 95 3.20 5934421 .72 696295.09 N 70.22508404 W 148 .41585618 8974.46 47.47 0 .04 8110.32 8178.42 3396.77 3467.85 3398.63 3364.43 -480. 95 1.52 5934490 .87 696293.28 N 70.22527303 W 148 .41585621 9069.93 48.25 0 .28 8174.37 8242.47 3467.12 3538.64 3468.69 3435.22 -480. 75 0.84 5934561 .64 696291.63 N 70.22546643 W 148 .41585464 9165.56 47.85 358 .62 8238.30 8306.40 3537.88 3609.77 3539.23 3506.33 -481. 43 1.36 5934632 .71 696289.10 N 70.22566071 W 148 .41586016 9261.46 47.34 359 .66 8302.98 8371.08 3608.38 3680.58 3609.53 3577.13 -482. 49 0.96 5934703 .46 696286.19 N 70.22585414 W 148 .41586879 9356.11 46.82 359 .28 8367.43 8435.53 3677.35 3749.89 3678.31 3646.44 -483. 13 0.62 5934772 .72 696283.74 N 70.22604349 W 148 .41587399 9452.40 45.95 358 .07 8433.85 8501.95 3746.80 3819.60 3747.62 3716.13 -484. 74 1.28 5934842 .34 696280.32 N 70.22623388 W 148 .41588699 9516.17 45.17 358 .94 8478.50 8546.60 3792.18 3865.13 3792.90 3761.65 -485. 93 1.56 5934887 .81 696277.94 N 70.22635822 W 148 .41589662 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 12-37\12-37\12-37\12-37 Generated 1/26/2009 3:56 PM Page 3 of 4 T Comments Measured D h Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Lon itude ept Section Departure g ft de de ft ft ft ft ft ft ft de OOft ftUS ftUS 9546.84 47.52 359. 34 8499. 67 8567.77 3814.27 3887.32 3814.95 3783.83 -486.26 7.72 5934909 .98 9579.50 47.64 358. 33 8521. 70 8589.80 3838.28 3911.43 3838.92 3807.94 -486.75 2.31 5934934 .06 9627.01 47.48 359. 81 8553. 77 8621.87 3873.19 3946.49 3873.77 3842.99 -487.32 2.32 5934969 .09 9665.49 47.05 359. 79 8579. 88 8647.98 3901.30 3974.75 3901.82 3871.26 -487.42 1.12 5934997 .34 9674.71 47.07 359. 35 8586. 16 8654.26 3908.01 3981.50 3908.52 3878.01 -487.47 3.50 5935004 .08 7" Cr$ 9777'md 9720.83 46.55 359. 63 8617. 72 8685.82 3941.47 4015.13 3941.92 3911.63 -487.77 1.21 5935037 .68 MWD+IFR:AK 9777.21 46.81 359. 45 8656. 41 8724.51 3982.28 4056.15 3982.67 3952.65 -488.10 0.52 5935078 .68 9873.17 46.82 359. 02 8722. 08 8790.18 4051.93 4126.11 4052.23 4022.61 -489.03 0.33 5935148 .59 9968.90 46.61 359. 17 8787. 71 8855.81 4121.32 4195.80 4121.54 4092.29 -490.13 0.25 5935218 .21 10063.49 46.52 358. 34 8852. 75 8920.85 4189.74 4264.49 4189.90 4160.96 -491.63 0.64 5935286 .81 10160.08 46.88 359.40 8918.99 8987.09 4259.76 4334.78 4259.86 4231.24 -493.01 0.88 5935357.03 10255.56 47.00 357.97 8984.18 9052.28 4329.26 4404.54 4329.32 4300.98 -494.61 1.10 5935426.70 10351.20 47.15 357.75 9049.32 9117.42 4399.11 4474.57 4399.15 4370.96 -497.23 0.23 5935496.58 10402.36 46.88 356.81 9084.20 9152.30 4436.46 4512.00 4436.49 4408.34 -499.00 1.44 5935533.91 10450.00 46.88 356.81 9116.76 9184.86 4471.19 4546.77 4471.21 4443.06 -500.94 0.00 5935568.56 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD +IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) MWD +IFR [Alaska] -- (In-field referenced MWD in Alaska. Model takes account of increased violence of magnetic field disturbances in Alaska. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) iftUS) Easting (X) iftUSl Surface : 828 FSL 738 FEL S18 T10N Ri 5E UM 5931140.33 696861.77 BHL : 5271 FSL 1223 FEL S18 T10N R15E UM 5935568.56 696245.17 696277.03 N 70.22641883 W 148.41589930 696275.91 N 70.22648468 W 148.41590327 696274.43 N 70.22658045 W 148.41590789 696273.60 N 70.22665767 W 148.41590870 696273.37 N 70.22667610 W 148.41590911 696272.19 N 70.22676796 W 148.41591154 696270.79 N 70.22688002 W 148.41591422 696268.03 N 70.22707115 W 148.41592180 696265.12 N 70.22726151 W 148.41593072 696261.84 N 70.22744911 W 148.41594279 696258.62 N 70.22764111 W 148.41595 696255.20 N 70.22783164 W 148.41596 696250.76 N 70.22802283 W 148.41598810 696248.01 N 70.22812495 W 148.41600244 696245.17 N 70.22821980 W 148.41601808 CJ SurveyEditor Ver SP 2.1 Bld( doc40x_100) 12-37\1 2-3711 2-37\12-37 Generated 1/26/2009 3:56 PM Page 4 of 4 ~. • 12-37, Well History (Post Rig) Date Summary 11/23/2008 WELL S/I ON ARRIVAL. PULL B&R FROM RHC-M PLUG BODY C~ 9596' SLM. PULL 1" (BK) DGLV FROM STA # 4, PULLED 1" (BEK) DCK FROM STA #5. SET 1" (BK LGLV (1500# TRO, 16/64" PORTS) IN STA#5 C~3 3820' SLM. SET 1" (BK) S/O (20/64" PORTS) IN STA#4 C«~ 5619' SLM. PULL RHC-M PLUG BODY FROM XN NIPPLE ~ 9600' SLM. DRIFT TUBING W/ 2-7/8" DMY GUN, S.BAILER, TAG STICKY BTM C~ 10,304' SLM (+7' CORK TO XN= 10,311' MD) S.BAILER EMPTY. WELL S/I ON DEPARTURE, DSO NOTIFIED OF ALL CONDITIONS. 1/2/2009 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 100/150/0. DRIFT 4.5" TUBING WITH 3 3/8" X 10' DUMMY GUN. RUN GR/CCL JEWELERY LOG. JEWELRY LOG TIED INTO REFERENCE LOG: SLB MD OPEN HOLE LWD LOG DATED 07 NOV 08. JEWELRY LOG AND DRIFT MADE IN THE SAME RUN. PERFORATE RUN 1: 10162' - 10171' RUN 2: 10136' - 10150'. PERFORATE WITH 3 3/8" HSD PJ 3406 6 SPF 60 DEG PHASING GUNS. PERFORATION DEPTHS CORRELATED TO TIE IN LOG: SWS JEWELRY LOG DATED 02 JAN 09. REFERENCE LOG DEPTHS =TIE IN LOG DEPTHS. NO DEPTH OFFSET BETWEEN LOGS. 1/3/2009 PERFORATE INTERVALS: RUN 3: 10068' - 10073', RUN 4: 10052' - 10062', RUN 5: 10029' - 10036', RUN 6: 9965' - 9979', RUN 7: 9931' - 9949', WITH 3 3/8" HSD PJ 3406 6 SPF 60 DEG PHASING GUNS. PERFORATION DEPTHS CORRELATED TO TIE IN LOG: SWS JEWELRY LOG DATED 02 JAN 09. REFERENCE LOG DEPTHS =TIE IN LOG DEPTHS. NO DEPTH OFFSET BETWEEN LOGS. 1/4/2009 PERFORATE RUN 8: 9780' - 9805' WITH 3 3/8" HSD PJ 3406 6 SPF 60 DEG PHASING GUNS. ' PERFORATION DEPTHS CORRELATED TO TIE IN LOG: SWS JEWELRY LOG DATED 02 JAN 09. REFERENCE LOG DEPTHS =TIE IN LOG DEPTHS. NO DEPTH OFFSET BETWEEN LOGS. POOH WITH FINAL GUN RUN, AND RIH FOR STATIC BHP SURVEY. STATION LOG DEPTHS: 9987' (8800' TVD), 9841' (8700' TVD), 9695' (8600' TVD). POOH WITH SBHPS, RIG DOWN. WELL LEFT SHUT-IN ON DEPARTURE. FINAL T/I/O = 0/0/0 JOB COMPLETE. Page 1 of 1 /V L.LLr3LH V = .7CG JS.rI.ViV ~ <8 ELEV = 26 22 3F ELE~6=~y~ 4188 <4P ~ 250 ,Aax Angle = ~48'~ @9070' ?alum MD = 9987' ~ ~~pF~ Tatum TVD = 8800' 20" CONDUCTOR, 215.5#, A-53, ID = -'80' 9-5/8" CSG, 40 #/ft, L-80, BTC, ID = 8.835" ~--{ 3755' Minimum ID = 3.7'25" @ 9,607" 4-1~2" HE~ XN NIPPLE 7" CSG, 26 #/ft, L-80, TCII, ID = 6.276" 5259' JHrC I T IVV I CJ: l+l-iKVIVIC I VCSIIVl7 6t LIIVCK >® 2176' 4-1/2" HES X NIPPLE, ID = 3.813" f;a~ t IFT M#Nf1R1_S ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3831 3595. 27 KGB 2 DOME BK 1f 11t23l0 4 5619 5217 25 KGB 2 SO BK 20 11123!0 3 6736 6219 25 KGB 2 DMY BK t3 191C191Q Z 7814 7197 25 KGB-2 DMY BK 0 11/t19lCI 1 9392 846C} 47 KGB-2 DMY BK 0 11JQ910 9470' ~-i4-1/2" HES X NIPPLE, ID = 3.813" ~7" x 4-1/2" BKR S-3 PKR, ID = 3.875" ~ 9534' x--14-112" HES X NIPPLE, ID = 3.813" 4-1/2" TBG, 12.6 #/ft, 13CR, I~ 9618' VAM TOP, ID = 3.958" 7" CSG, 26 #/ft, L-80, BTC-M, ID = 6.276" ~ 9777' PERFORAl10N SUMMARY REF LOG: SLB MWD 11/07/08 ANGLE AT TOP PERF: 47° @ 9780' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9780 - 9805 O 01/04/09 3-3/8" 6 9931 - 9949 O 01/03/09 3-3/8" 6 9965 - 9979 O 01/03/09 3-3/8" 6 10029 - 10036 O 01/03/09 3-3/8" 6 '10052 - 10062 O 01/03/09 3-3/8" 6 10068 - 10073 O 01/03!09 3-3/8" 6 10136 - 10150 O 01/02/09 3-318" 6 10162 - 10171 O 01!02/09 PBTD 10362' 1/2" TBG, 12.6 #/ft, 13CR, I 10449' 4M TOP, ID = 3.958" 9607' -14-1/2" HES XN NIPPLE, ID = 3.725" 9610' 7" x 5" BKR ZXP LT PKR w/PBR, ID = 4.40" 9620' 4-1/2" WLEG, ID = 3.958" 9632' 7" x 5" BKR FLEX LOCK LNR HGR, ID = 4.44" PRUt3HO BAY UNIT WELL-: >;as i2~7 PERMiT Nn: 208-144 APl Na: 50-023398-00 SEC 18. T10N, R15E, 828 FSL, 737 FE1. BP Exploration (Atasicaj ~ i SCHLUMBERGER Survey report °b 1 Client ...................: Field ..................... Well ...................... API number ...............: Engineer .................. COUNTY :................... STATE :.................... ----- Survey calculation m Method for positions.....: Method for DLS...........: BPXA Prudhoe Bay 12-37 50-029-23398-00 E. Galotta US AK ethods------------ Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Drillers Depth GL above permanent.......: 39.1 ft KB above permanent.......: N/A ft DF above permanent.......: 68.1 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 353.76 degrees [(c)2008 IDEAL ID13_OC_13] 8-Nov-2008 13:01:14 Page 1 of 5 Spud date ................: 25-Oct-08 Last survey date.........: 08-Nov-08 Total accepted surveys...: 120 MD of first survey.......: 0.00 ft MD of last survey........: 10450.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2008 Magnetic date ............: 23-Oct-2008 Magnetic field strength..: 57691.99 GAMA Magnetic dec (+E/W-).....: 23.09 degrees Magnetic dip .............: 80.89 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.67 meal 57692.00 GAMA 80.89 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.09 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.09 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=5chlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • SCHLU MBERGER Survey Rep ort 8-Nov-2008 13:01:14 Page 2 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP_ GYD SS 2 89.00 0.17 174.98 89.00 89.00 -0.13 -0.13 0.01 0.13 174.98 0.19 BP_ GYD SS 3 189.00 0.51 119.10 100.00 189.00 -0.54 -0.50 0.41 0.65 140.18 0.44 BP_ GYD SS 4 277.00 1.77 92.78 88.00 276.98 -0.98 -0.75 2.11 2.24 109.59 1.51 BP_ GYD SS 5 370.00 2.57 89.63 93.00 369.91 -1.42 -0.81 5.63 5.69 98.17 0.87 BP_ GYD SS 6 467 00 4 09 86.86 97.00 466.75 -1.83 -0.60 11.26 11.28 93.07 1.58 BP GYD SS 7 . 516.95 . 4.69 82.33 49.95 516.55 -1.87 -0.23 15.06 15.07 90.89 1.39 _ BP_ MWD+IFR+MS • 8 570.79 5.52 77.43 53.84 570.17 -1.53 0.62 19.77 19.78 88.20 1.74 BP_ MWD+IFR+MS 9 630.82 6.50 71.70 60.03 629.87 -0.50 2.32 25.82 25.92 84.87 1.91 BP_ MWD+IFR+MS 10 660.64 7.18 69.97 29.82 659.48 0.29 3.49 29.17 29.38 83.18 2.38 BP_ MWD+IFR+MS 11 721.10 7.49 63.71 60.46 719.45 2.55 6.53 36.25 36.84 79.80 1.42 BP_ MWD+IFR+MS 12 750.41 7.95 59.09 29.31 748.49 4.05 8.41 39.71 40.59 78.04 2.63 BP_ MWD+IFR+MS 13 840.18 8.64 48.39 89.77 837.33 10.54 16.08 50.07 52.59 72.20 1.88 BP_ MWD+IFR+MS 14 936.59 9.52 33.58 96.41 932.54 20.86 27.53 59.90 65.92 65.31 2.58 BP_ MWD+IFR+MS 15 1029.61 10.83 25.16 93.02 1024.10 34.23 41.85 67.87 79.74 58.34 2.13 BP_ MWD+IFR+MS 16 1121.63 12.95 15.52 92.02 1114.15 51.19 59.62 74.31 95.27 51.26 3.15 BP_ MWD+IFR+MS 17 1217.44 13.89 8.91 95.81 1207.35 72.26 81.32 78.96 113.35 44.16 1.88 BP_ MWD+IFR+MS 18 1317.37 13.92 5.39 99.93 1304.35 95.61 105.14 81.95 133.30 37.93 0.85 BP_ MWD+IFR+MS 19 1415.40 14.94 0.47 98.03 1399.29 119.71 129.52 83.16 153.92 32.70 1.63 BP_ MWD+IFR+MS 20 1511.85 16.44 357.67 96.45 1492.15 145.68 155.59 82.71 176.20 27.99 1.74 BP_ MWD+IFR+MS 21 1603.54 17.89 357.54 91.69 1579.75 172.68 182.62 81.57 200.01 24.07 1.58 BP_ MWD+IFR+MS • 22 1700.38 19.24 355.46 96.84 1671.55 203.47 213.39 79.67 227.78 20.47 1.55 BP_ MWD+IFR+MS 23 1797.38 20.74 353.42 97.00 1762.71 236.62 246.39 76.44 257.97 17.24 1.71 BP_ MWD+IFR+M5 24 1893.47 21.26 353.64 96.09 1852.41 271.06 280.60 72.56 289.83 14.50 0.55 BP_ MWD+IFR+MS 25 1988.68 23.19 351.77 95.21 1940.55 307.06 316.32 67.96 323.54 12.13 2.16 BP_ MWD+IFR+MS 26 2083.61 25.20 348.42 94.93 2027.14 345.86 354.62 61.23 359.87 9.80 2.56 BP_ MWD+IFR+MS 27 2179.68 26.80 347.27 96.07 2113.48 387.75 395.78 52.35 399.23 7.53 1.75 BP _MWD+IFR+MS 28 2275.93 27.23 345.36 96.25 2199.23 431.09 438.25 42.00 440.26 5.47 1.01 BP_ MWD+IFR+MS 29 2371.31 27.97 344.91 95.38 2283.76 474.78 480.96 30.67 481.94 3.65 0.81 BP_ MWD+IFR+MS 30 2466.72 28.03 343.08 95.41 2368.00 518.92 524.02 18.32 524.34 2.00 0.90 BP_ MWD+IFR+MS [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 8-Nov-2008 13:01:14 Page 3 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2562.11 26.59 342.38 95.39 2452.76 561.88 565.81 5.33 565.83 0.54 1.55 BP _MWD+IFR+MS 32 2658.20 26.22 343.40 96.09 2538.82 603.84 606.65 -7.24 606.69 359.32 0.61 BP _MWD+IFR+MS 33 2754.01 26.41 345.09 95.81 2624.71 645.72 647.52 -18.77 647.79 358.34 0.81 BP _MWD+IFR+MS 34 2850.01 24.83 345.36 96.00 2711.26 686.77 687.66 -29.36 688.28 357.56 1.65 BP _MWD+IFR+MS 35 2945.61 24.66 346.54 95.60 2798.09 726.42 726.47 -39.08 727.52 356.92 0.55 BP _MWD+IFR+MS 36 3041.10 24.74 347.28 95.49 2884.84 766.03 765.34 -48.11 766.85 356.40 0.33 BP _MWD+IFR+MS 37 3136.36 25.13 347.47 95.26 2971.22 805.95 804.53 -56.89 806.54 355.96 0.42 BP _MWD+IFR+MS • 38 3232.27 26.20 347.86 95.91 3057.67 847.25 845.11 -65.76 847.66 355.55 1.13 BP _MWD+IFR+MS 39 3327.11 26.74 347.44 94.84 3142.56 889.28 886.40 -74.81 889.55 355.18 0.60 BP _MWD+IFR+MS 40 3421.72 25.42 346.63 94.61 3227.54 930.59 926.93 -84.13 930.74 354.81 1.45 BP _MWD+IFR+MS 41 3517.02 25.77 347.59 95.30 3313.49 971.48 967.07 -93.31 971.56 354.49 0.57 BP _MWD+IFR+MS 42 3612.67 25.40 347.67 95.65 3399.76 1012.55 1007.41 -102.16 1012.58 354.21 0.39 BP _MWD+IFR+MS 43 3698.89 26.30 347.60 86.22 3477.35 1049.93 1044.13 -110.21 1049.94 353.97 1.04 BP _MWD+IFR+MS 44 3809.49 27.10 347.48 110.60 3576.16 1099.33 1092.66 -120.93 1099.33 353.68 0.72 BP _MWD+IFR+MS 45 3906.54 27.04 346.35 97.05 3662.58 1143.18 1135.68 -130.93 1143.20 353.42 0.53 BP _MWD+IFR+MS 46 4004.45 26.91 346.29 97.91 3749.83 1187.22 1178.83 -141.43 1187.28 353.16 0.14 BP _MWD+IFR+MS 47 4097.76 27.26 344.96 93.31 3832.91 1229.27 1219.98 -151.98 1229.41 352.90 0.75 BP _MWD+IFR+MS 48 4192.88 25.74 345.53 95.12 3918.03 1271.24 1261.02 -162.80 1271.48 352.64 1.62 BP _MWD+IFR+MS 49 4288.74 24.65 347.89 95.86 4004.78 1311.73 1300.72 -172.19 1312.07 352.46 1.55 BP _MWD+IFR+MS 50 4386.97 25.66 347.90 98.23 4093.69 1353.27 1341.55 -180.95 1353.70 352.32 1.03 BP _MWD+IFR+MS 51 4482.55 24.38 348.88 95.58 4180.30 1393.51 1381.14 -189.09 1394.03 352.20 1.41 BP _MWD+IFR+MS • 52 4578.29 24.39 348.25 95.74 4267.50 1432.88 1419.88 -196.93 1433.48 352.10 0.27 BP _MWD+IFR+MS 53 4673.58 24.40 347.66 95.29 4354.28 1472.03 1458.37 -205.14 1472.73 351.99 0.26 BP _MWD+IFR+MS 54 4769.66 23.71 347.00 96.08 4442.02 1510.95 1496.58 -213.73 1511.77 351.87 0.77 BP _MWD+IFR+MS 55 4865.28 24.00 348.44 95.62 4529.47 1549.40 1534.37 -221.95 1550.34 351.77 0.68 BP _MWD+IFR+MS 56 4961.02 24.45 349.71 95.74 4616.78 1588.55 1572.94 -229.39 1589.58 351.70 0.72 BP _MWD+IFR+MS 57 5055.24 24.28 349.81 94.22 4702.61 1627.33 1611.19 -236.30 1628.43 351.66 0.19 BP _MWD+IFR+MS 58 5151.58 24.26 349.19 96.34 4790.43 1666.82 1650.13 -243.52 1668.00 351.61 0.27 BP _MWD+IFR+MS 59 5246.74 23.98 348.65 95.16 4877.28 1705.57 1688.29 -250.99 1706.84 351.54 0.37 BP _MWD+IFR+MS 60 5342.37 23.88 348.82 95.63 4964.69 1744.21 1726.33 -258.57 1745.59 351.48 0.13 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 8-Nov-2008 13:01:14 Page 4 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5438.06 23.88 349.78 95.69 5052.19 1782.82 1764.39 -265.76 1784.29 351.43 0.41 BP _MWD+IFR+MS 62 5533.85 23.85 351.52 95.79 5139.79 1821.52 1802.63 -272.06 1823.04 351.42 0.74 BP _MWD+IFR+MS 63 5627.64 24.64 355.23 93.79 5225.32 1860.01 1840.87 -276.48 1861.52 351.46 1.83 BP _MWD+IFR+MS 64 5724.40 24.73 355.06 96.76 5313.23 1900.41 1881.13 -279.90 1901.84 351.54 0.12 BP _MWD+IFR+MS 65 5820.01 25.95 355.38 95.61 5399.64 1941.32 1921.91 -283.31 1942.68 351.61 1.28 BP _MWD+IFR+MS 66 5916.22 25.66 354.47 96.21 5486.26 1983.19 1963.63 -287.01 1984.49 351.68 0.51 BP MWD+IFR+MS 67 6011.80 27.00 353.28 95.58 5571.92 2025.58 2005.77 -291.54 2026.85 351.73 1.51 BP _ _MWD+IFR+MS • 68 6107.30 26.95 352.07 95.50 5657.03 2068.89 2048.74 -297.07 2070.16 351.75 0.58 BP _MWD+IFR+MS 69 6203.02 27.46 351.41 95.72 5742.16 2112.62 2092.04 -303.35 2113.92 351.75 0.62 BP _MWD+IFR+MS 70 6298.73 26.73 351.82 95.71 5827.37 2156.18 2135.17 -309.71 2157.51 351.75 0.79 BP _MWD+IFR+M5 71 6393.96 26.59 349.04 95.23 5912.48 2198.83 2177.29 -316.81 2200.22 351.72 1.32 BP _MWD+IFR+MS 72 6490.12 26.63 347.64 96.16 5998.45 2241.71 2219.47 -325.52 2243.22 351.66 0.65 BP _MWD+IFR+MS 73 6585.31 25.70 348.34 95.19 6083.89 2283.47 2260.53 -334.26 2285.11 351.59 1.03 BP _MWD+IFR+MS 74 6681.73 25.69 347.74 96.42 6170.77 2325.06 2301.43 -342.92 2326.83 351.53 0.27 BP _MWD+IFR+MS 75 6776.93 25.56 347.54 95.20 6256.61 2366.00 2341.64 -351.73 2367.91 351.46 0.16 BP _MWD+IFR+MS 76 6872.55 25.08 345.89 95.62 6343.04 2406.58 2381.44 -361.12 2408.66 351.38 0.89 BP _MWD+IFR+MS 77 6967.61 25.36 345.36 95.06 6429.04 2446.68 2420.68 -371.18 2448.97 351.28 0.38 BP _MWD+IFR+MS 78 7063.46 25.50 348.88 95.85 6515.61 2487.55 2460.78 -380.35 2490.00 351.21 1.58 BP _MWD+IFR+MS 79 7159.14 25.50 348.81 95.68 6601.97 2528.58 2501.20 -388.32 2531.16 351.18 0.03 BP _MWD+IFR+MS 80 7254.72 24.83 348.02 95.58 6688.48 2569.05 2541.01 -396.47 2571.76 351.13 0.78 BP _MWD+IFR+MS 81 7349.65 23.99 349.81 94.93 6774.92 2608.14 2579.50 -404.03 2610.95 351.10 1.18 BP _MWD+IFR+MS • 82 7445.75 23.80 352.47 96.10 6862.79 2647.01 2617.96 -410.02 2649.87 351.10 1.14 BP _MWD+IFR+MS 83 7540.30 23.13 352.24 94.55 6949.52 2684.65 2655.27 -415.03 2687.51 351.12 0.72 BP _MWD+IFR+MS 84 7637.64 24.10 353.24 97.34 7038.71 2723.64 2693.95 -419.95 2726.49 351.14 1.08 BP _MWD+IFR+MS 85 7732.41 23.42 351.77 94.77 7125.45 2761.81 2731.80 -424.93 2764.66 351.16 0.95 BP _MWD+IFR+MS 86 7828.25 24.74 351.80 95.84 7212.94 2800.89 2770.51 -430.51 2803.76 351.17 1.38 BP _MWD+IFR+MS 87 7923.39 24.46 352.00 95.14 7299.45 2840.47 2809.72 -436.09 2843.36 351.18 0.31 BP _MWD+IFR+MS 88 8017.99 25.60 352.50 94.60 7385.16 2880.48 2849.37 -441.49 2883.37 351.19 1.23 BP _MWD+IFR+MS 89 8114.22 25.92 351.16 96.23 7471.83 2922.28 2890.77 -447.43 2925.19 351.20 0.69 BP _MWD+IFR+M5 90 8210.42 25.50 351.64 96.20 7558.51 2963.97 2932.03 -453.67 2966.92 351.20 0.49 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_13] SCHLUNIBERGER Survey Report 8-Nov-2008 13:01:14 Page 5 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8306.11 25.47 352.09 95.69 7644.89 3005.12 2972.79 -459.50 3008.09 351.21 0.20 BP_ MWD+IFR+MS 92 8401.32 27.16 352.86 95.21 7730.23 3047.32 3014.63 -465.02 3050.29 351.23 1.81 BP_ MWD+IFR+MS 93 8497.19 29.31 352.87 95.87 7814.68 3092.66 3059.63 -470.65 3095.62 351.25 2.24 BP_ MWD+IFR+MS 94 8548.76 31.38 354.48 51.57 7859.19 3118.71 3085.53 -473.51 3121.65 351.28 4.31 BP_ MWD+IFR+MS 95 8591.79 32.55 353.93 43.03 7895.69 3141.49 3108.19 -475.81 3144.40 351.30 2.80 BP_ MWD+IFR+MS 96 8687.96 39.87 358.06 96.17 7973.25 3198.19 3164.81 -479.60 3200.94 351.38 8.02 BP MWD+IFR+MS 97 8783.77 42.97 359.75 95.81 8045.08 3261.30 3228.17 -480.78 3263.78 351.53 3.44 _ BP_ MWD+IFR+MS 98 8879.48 46.03 359.96 95.71 8113.34 3328.00 3295.25 -480.95 3330.16 351.70 3.20 BP_ MWD+IFR+MS 99 8974.46 47.47 0.04 94.98 8178.42 3396.77 3364.42 -480.95 3398.63 351.86 1.52 BP_ MWD+IFR+MS 100 9069.93 48.25 0.28 95.47 8242.47 3467.12 3435.22 -480.75 3468.69 352.03 0.84 BP_ MWD+IFR+MS 101 9165.56 47.85 358.62 95.63 8306.40 3537.88 3506.33 -481.43 3539.23 352.18 1.36 BP_ MWD+IFR+MS 102 9261.46 47.34 359.66 95.90 8371.08 3608.38 3577.13 -482.49 3609.53 352.32 0.96 BP_ MWD+IFR+MS 103 9356.11 46.82 359.28 94.65 8435.53 3677.35 3646.44 -483.13 3678.31 352.45 0.62 BP_ MWD+IFR+MS 104 9452.40 45.95 358.07 96.29 8501.95 3746.80 3716.13 -484.74 3747.61 352.57 1.28 BP_ MWD+IFR+MS 105 9516.17 45.17 358.94 63.77 8546.60 3792.18 3761.65 -485.93 3792.90 352.64 1.56 BP_ MWD+IFR+MS 106 9546.84 47.52 359.34 30.67 8567.77 3814.27 3783.83 -486.26 3814.95 352.68 7.72 BP_ MWD+IFR+MS 107 9579.50 47.64 358.33 32.66 8589.80 3838.28 3807.94 -486.75 3838.92 352.72 2.31 BP_ MWD+IFR+MS 108 9627.01 47.48 359.81 47.51 8621.87 3873.19 3842.99 -487.32 3873.77 352.77 2.32 BP_ MWD+IFR+MS 109 9665.49 47.05 359.79 38.48 8647.98 3901.30 3871.26 -487.42 3901.82 352.82 1.12 BP_ MWD+IFR+M5 110 9674.71 47.07 359.35 9.22 8654.26 3908.01 3878.01 -487.47 3908.52 352.84 3.50 BP_ MWD+IFR+MS 111 9720.83 46.55 359.63 46.12 8685.83 3941.47 3911.63 -487.77 3941.92 352.89 1.21 BP_ MWD+IFR+MS 112 9777.21 46.81 359.45 56.38 8724.51 3982.28 3952.65 -488.10 3982.67 352.96 0.52 BP_ INC+TREND 113 9873.17 46.82 359.02 95.96 8790.18 4051.93 4022.61 -489.03 4052.23 353.07 0.33 BP_ MWD+IFR:AK 114 9968.90 46.61 359.17 95.73 8855.81 4121.32 4092.29 -490.13 4121.53 353.17 0.25 BP_ MWD+IFR:AK 115 10063.49 46.52 358.34 94.59 8920.85 4189.74 4160.96 -491.63 4189.90 353.26 0.64 BP_ MWD+IFR:AK 116 10160.08 46.88 359.41 96.59 8987.09 4259.75 4231.24 -493.01 4259.86 353.35 0.88 BP_ MWD+IFR:AK 117 10255.56 47.00 357.97 95.48 9052.28 4329.25 4300.98 -494.61 4329.32 353.44 1.10 BP_ MWD+IFR:AK 118 10351.20 47.15 357.75 95.64 9117.42 4399.11 4370.96 -497.23 4399.15 353.51 0.23 BP_ MWD+IFR:AK 119 10402.36 46.88 356.81 51.16 9152.30 4436.46 4408.34 -499.00 4436.49 353.54 1.44 BP_ MWD+IFR:AK 120 10450.00 46.88 356.81 47.64 9184.86 4471.19 4443.06 -500.94 4471.21 353.57 0.00 Projected_TD [(c)2008 IDEAL ID13_OC_13] 01 /23/09 ~ch~berger Alaska Data & Consulting Services a(" 2525 Gambell Street, Suite 400 ` Anchorage, AK 99503-2838 ~\a ATTN: Beth ~J -` a~~,t.D~ ~ ,Q QG Wnll \ ~ I..M u N0.5047 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 H-35 11970840 PRODUCTION PROFILE 08/12/08 1~ yV'V~ 1 -11 12111927 IBP & CROSS-FLOW STP ~ j 11/24/08 1 1 MPS-41 11966291 SCMT - ~'ol 11/24/08 1 1 K-05C AWJB-00016 MEM PROD PROFILE V _ ~. 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE 0 -~ 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~''-" 12!30/08 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 - b 01/10/09 1 1 01-29 AP3O-00011 USIT 'f~ - ~ ~ 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP .-- L{ 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESSlfEMP' - ~ 01/06/09 1 1 R-24 AY3J-00004 USIT 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILElWFL .r f4'~ 01/08/09 1 1 07-0 A AYOO-00009 USIT - L 01/22!09 1 1 N-12 12014053 RST - 09/30/08 1 1 E-326 AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) i )S.tr°~ 06/15/07 1 B-27A 11999059 RST ®Q~ ~ ~S' _ 11107!08 1 1 12-37 40018138 OHM D/LWD EDIT _~L ~~-' 11/07/08 2 1 N-18A 08AKA0037 OH MWD/LWD EDIT ~~~ -- 12/24/08 2 1 H-38 08AKA0031 OH MWD/LWD EDIT G 12/07/08 2 1 ~L 5- ~ ~~~ of CACC llf-Vw~n\w11 Cnnr n BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street. Suite 400 900 E. Benson Blvd. ~ ~.~ Anchorage, AK 9ra-~ ~8` ~~ - ~ , ~ ` Anchorage, Alaska 99508 t t( r ATTN: Beth ~~ Date Delivered: Received by: ~ nr ma . A'7.1 ~ ~.- -* a 1 nifk~R^~S4C.1S1 ~" ) ~, C~ 01 /13/09 ~~~1~11~~~~5~ N0.5040 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oii & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WP_II .Inh @ 1 nn f)ncrrinfinn r1.~fe GI I~..~... ran 12-37 AZCM-00003 SBHP SURVEY ~~ - i.. L ~ - ~ 01/04/09 1 1 H-38 12057673 USIT ~ ~~, - ':_ ~, _~) 12/10/08 1 1 W-218 11968975 USIT _ ~~ - ~~ L '- L/~- (G 12/11/08 1 1 Z-09A 08AKA0020 OH MWD/LWD EDIT __ '~~ -~~-// ~ _ /_ ~ ~ 10/16/08 2 1 YLCNAC Hl.g1VVVVLtUUC 11t1a1Y I CST JIli1V11Vta HIVU IStI UFSNINta VIVt GVYY tAGrt 1 U: BP Exploration (Alaska) Ina - Petrotechnical Data Center LR2-1 `°' _. _ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40Q Anchorage, AK 99593-?~ 38~ ATTN: Beth ~, /I Received by: ~ ! ~_...---~--`"'~ a • • Schlumber er 9 Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc Dispatched To: Christine Mahnken Well No DS 12-37 Date Dispatched: 12-Nov-OS Installation/Rig Nabors 7ES Dispatched By: Paul Wyman LWD Log Delivery V2.1, 03-06-06 Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 pwyman C~?slb.com Fax:907-561-8317 ~~~1~~~ • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc Dispatched To: Geology Well No DS 12-37 Date Dispatched: 12-Nov-08 Installation/Rig Nabors 7ES Dispatched By: Paul Wyman LOG Run No. Scale Original Film No Of Prints 1 CD w/ No of Tapes Perform Letter 1 Surveys 1 Field Prints LWD 1 set 1 CD Drilling Mechanics ( TRP & DRL) 2" MWD 1 Set Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 pwvman @slb.com Fax:907-561-8317 LWD Log Delivery V2.1, 03-06-06 Schlumberger Private Sundry 308-358: 12-37 P&A ~ • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, November 02, 2008 9:19 AM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); NSU, ADW Drlg Rig 7 ES; Roach, Frank Subject: RE: Sundry 308-358: 12-37 P&A Travis, Thanks for the information Tom Maunder, PE AOGCC 2 ~~-~~~ Nothing further is needed. Page 1 of 1 From: Peltier, Travis M [mailto:Travis.PeRier@bp.com] Sent: Sat 11/1/2008 12:03 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); NSU, ADW Drlg Rig 7 ES; Roach, Frank Subject: Sundry 308-358: 12-37 P&A Tom, Thanks, 1 have received the approved Sundry and PTD for both 12-37 and 12-37. The Sundry asks for the plug length /volume to be provided before proceeding. The current planned length is to bring the plug 150' into the 7" shoe at 9622' MD. The cement slurry volume required for this will be ~ 39 bbls. Please let me know if you have any questions about this. -Travis Peltier BPXA Drilling Engineer (907)632-2284 11/3/2008 PTD# 208-144: 12-37 FIT vs ~ • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, October 31, 2008 9:35 AM To: 'Peltier, Travis M' Cc: NSU, ADW Drlg Rig 7 ES; Greg Hobbs (BP) Subject: RE: PTD# 208-144: 12-37 FIT vs LOT Travis, 1 acknowledge our call. The important thing is that the level of integrity you desire is demonstrated. As discussed, the LOT and FIT are often used interchangeably although in practice one test does not result in pumping fluid into the exposed formation (FIT) while the other does (LOT). Regardless of what test is actually accomplished, it is important that in the operations report that LOT be used if fluid is pumped into the formation and FIT be used when the formation is not pumped into. Call or message with any questions. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peitier@bp.com] Sent: Friday, October 31, 2008 9:30 AM To: Maunder, Thomas E {DOA) Cc: NSU, ADW Drlg Rig 7 ES Subject: PTD# 208-144: 12-37 FIT vs LOT Tom, As per our phone conversation, the 12-37 PTD lists that our planned operation for the 8-3/4" formation test is a LOT (step 9, pg. 8). The intended plan is an FIT, with a minimum of 11.7 ppg (pg. 8 Sec. 3 & pg. 6). Do you have any issues with us running an FIT rather than a LOT? Thanks, and please let me know if you have any questions. -Travis Peltier BPXA Drilling Engineer (907)564-4511 10/31/2008 12-37 Surface Cement Job ~ ~ Page 1 of 1 Maunder, Thomas E (DQA) From: Peltier, Travis M [Travis.Peltier@bp.com] Sent: Friday, October 31, 2008 9:24 AM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 7 ES Subject: 12-37 Surface Cement Job Tom, Closing the loop on our surface cement job, after we failed to get cement to surface, we performed a top job with 1.25" hydril pipe. We RIH with the pipe 364' from GL and pumped 213 bbls of 10.7 ppg cement before getting positive returns to surface. AOGCC Rep Chuck Scheve witnessed the operation. -Travis Peltier BPXA Drilling Engineer (907)564-4511 10/31 /2008 ~ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ~~z`~ ~~7la~ DATE: October 30, 2008 P.I. Supervisor FROM: Chuck Scheve, SUBJECT: Casing Cement Top Job Petroleum Inspector PBU 12-37 PTD#208-144 Thursday, October 30, 2008; I traveled to the DS 12-37 well in the Prudhoe Bay Field and witnessed the cement Top Job on the Surface casing in this well. During the primary cement job on this well partial lost circulation was encountered (93 bbl lost to hole) with no cement returns noted at surface. 11/4" tubing was run in the hole outside the surface casing to a depth of 364' below ground level were the pipe tagged up solid. From this depth 213 bbl of arctic set light cement (10.7 Ib per gal.) was pumped and full weight cement returns were observed at surface. SUMMARY: I witnessed the placement of a cement Top Job on the Surface casing in the PBU12-37 well. r ALASS-A ®IL AMID GAS CO1~T5ERQATIOl1T C011~II5SIOI~T Greg Hobbs Engineering Team Leader BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 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 12-37 Sundry Number: 308-358 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~i~~ Cathy P. Foerster Commissioner DATED this ~ day of October, 2008 Encl. ( • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL' 20 AAC 25.280 Contingency Plan to Sidetrack (12-37A) '}~ .Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ ARer Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: BP Fx location (Alaska) Inc. 4. Current Well Class: ®Development ^ Exploratory 5. Permit To Drill Number ~~ ~t-~~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 ^ Service ^ Stratigraphic 6. API Number: 50- ®'~~ - ~'' ~ ls- ~ C~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? ^ Yes ®No 8. Well Name and Number: PBU 12-37 9. Property Designation: ADL 028330, ADL 028329 10. KB Elevation (ft): Planned 68.5' 11. Field /Pool(s): Prudhoe Bay Field / Prudhoe Ba Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Planned: 10463' Total Depth TVD (ft): 9199' Effective Depth MD (ft): Planned: 10313' Effective Depth TVD (ft): 9090' Plugs (measured): None Junk (measured): None 1 -1/4" Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Planned: 4-1/2", 12.6# Tubing Grade: 13Cr80 Tubing MD (ft): 9624' Packers and SSSV Type: Planned: 7"x4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): Planned: 9514' 13. Attachments: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed O rations Pro ram 14. Well Class after proposed work: ^ Exploratory ®Development ^ Service 15. Estimated Date for Commencin O rations: October 21, 2008 16. Well Status after proposed work: ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: Commission Re resentative: ^ WAG ^ GINJ ^ WINJ ^ WDSPL 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Travis PeRier, 564-4511 Printed Name Gre obbs ~ Title Engineering Team Leader ~ r~r~,rroer: Signature Phone 564-4191 Date l ~ a Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: v~ ~ i ~ ~ ~-~ ~ 3C~ .`9~C~ S~CC~~`~ ~5 ~ ~ C~ ~G'MC~,~~ 1~''~s~c rG~~~c "C i~ Subsequent Form Required: ~~~ APPROVED BY 6? roved B COMMISSIONER THE COMMISSION Date ~Z ~ ~ v Form 10-403 Revised~6/2006 ~fiIGINAL i ~~i?t Submit In Duplicate 12-37 Well Abandonment Well Type: Producer Current Status: This well is a 6-1/8" open hole into the Ivishak formation. Request: Abandon Scope of Work: Lay in cement from 6-1/8" TD to 7" casing shoe to abandon Ivishak reservoir and prepare to sidetrack into the Sag River formation for 12-37A. MASP: 2422 psi Estimated Start Date: October 21, 2008 Proposed Procedure: 1. Continuing from the 12-37 PTD step #20. ,.~~,~ ~~ ~~ `5 ~-'~''~-'~~ ~~',d G- ~ ~~I~~ 2. POOH, UD BHA. PU cement plug BHA. • 3. RIH and lay in cement plug. Circulate out excess cement at 7" shoe. POOH and LD cementing BHA. 4. RIH with Sag sidetrack BHA. Kick-off into Sag. 5. Continue from step #5 in the 12-37A PTD. Drilling Engineer: Travis Peltier (907)564-4511 Production Engineer: Katrina Cooper (907)564-4212 Geologist: Daniel Schafer (907)564-5098 ATTACH: Current Schematic Proposed Schematic • KB. ELEV = 59 BF. F1E1(~ 30.5 KOP = Nkix Angle = Datum MD = Datum TVD = 8800 r ~.J Propo~d TREE = CNV 41 /18 5M WELLHEAD = FMC Gen 5 CSG HEAD = 11 " SM WY T' MANDREL HANGER 8 PACKOFF TBG SPOOL = 11" X 11" SM TBG HANGER = 11 " X 41/2" ADP FLANGE= 11"X41/16" '80' 20', 215.51e, A-53, Insulated Conductor -2200' HES 4-1/2'X' Landing Nipple; ID= 3.813" 3,682' 9-5/8", 40 #/ft, L-80, BTC, ID = 8.835" Proposed TOC GAS LIFT MANDRELS (4-1/2" x 1" KBMG) Minimum ID = 3.725" ~ 4-112" HES XN NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 DCK 2 S/O 3 DMY DMY 2 DMY DeAY 1 DMY DMY 1,484' HES 4-1/2" X NIPPLE; I.D. 3.813" - 2", 12.6#/ft, 13 Chrome, VamTop, ID = 3.958" PERFORATION SUMMARY (TBD) REF LOG: (TBD) ANGLE AT TOP PERF: TBD ~ TBD' MD Note: Refer to PhoduStion DB for historiSal pert data Ivishak ~~~~, Plugback 1,514' BAKER PKR 7° X 4-1/2' S-3, ID = 3.88", xx' TBS I, 544' HES 4-1 /2" X NIPPLE; ID ~ 3.813" I, 574' HES 4-1 /2" XN NIPPLE; ID = 3.725' 1,824, 7" x 4-1 /2" Baker Flex-Loc Liner Hanger (ID =2.992") w/ ZXP Liner Top Pkr w/ 10' TBS (ID = 5.25") 9774, 7", 26 #/ft, L-80, BTC-M (f/9,774'to 5000' MD) & TC-II (f/5000' to Surd, ID = 6.276" 3, 002' 4-1 /2" P B TD 3,162' 4-1/2", 12.611, 13CR-80, VamTOP, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT TMP INITtAI WELL: OS 12-37 PERMIT No: API No: BP Ekploration (Alaska) Completion 12-37A ELEV = Proposed Completion D S 12-37 Proposed TOC 4482' TRff = CMJ 4-1 /16 5M WELLHEAD = FMC Gen 5 CSG HEAD= 11" 5M W/ 7" MANDREL HANGER & PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER= 11" X 4-1/2" ADP FLANGE= 11" X 4-1/16" -80' 20". 215.5#, A-53, Insulated Conductor -2200' HES 4-1/2 'X' Landin Nip le; ID = 3.813" 3,682' 9-5/8", 40 #/ft, L-80, BTC, ID = 8.835" ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 DCK-2 S/O 3 DMY DMY 2 DMY DMY 1 DMY DMY 10,463' 6-1/8" Openhole TD PRUDHOE BAY UNR WELL: DS 12-37 PERMR No: API No: BP Exploration (Alaska) 12-37A PTD ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 23, 2008 1:39 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC}; Smith, Phil G (ASRC); Tirpack, Robert B; DOA AOGCC Prudhoe Bay; Foerster, Catherine P (DOA) Subject: RE: 12-37A PTD and DS 12-37 (208-144) Travis, Thanks for the revised information for 12-37A. I will place it in the permit package. There appears to be issue that has come up on 12-37 that I wish to advise you of. You may already be aware of this. Inspector Jeff Jones was just at the rig for the diverter inspection. Some non-compliance issues were noted. These include: 1. Inoperative hydraulic pressure gauges on the remote BOP panel. 2. It appears that the operation of the knife valve and diverter are not sequenced properly since the diverter is closed prior to the knife valve being fully opened. The inoperative gauges on the remote pane! is an item that was observed during a BOP inspection about 3 weeks ago and the Inspector was informed at that time that repairs would be accomplished following the completion of that well. Apparently that repair work was not accomplished. Inspector Jones informed the BP WSL that operations on DS 12-37 may not proceed until the repairs are made and proper operation/function witnessed by an Inspector. The Commission reserves the right to pursue an enforcement action regarding these matters. Call or message with any questions. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Thursday, October 23, 2008 1:06 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Tirpack, Robert B Subject: 12-37A PTD Tom, Thanks for the phone call. As per your request, here is the updated 12-37A PTD pages that reflect that we have NO AC issues in this 6-1/8" wellbore as well as the Anadrill Directional Plan. Thanks again, and I will keep you informed of 01-18's status as well. -Travis Peltier GPB Rotary Drilling (907)564-4511 «12-37 (P6} report.pdf» «12-37_P6_export_file.txt» «12-37A PTD October 22_08 update.doc» 2/6/2009 Maunder, Thomas E (DOA) Page 1 of 4 From: Peltier, Travis M [Travis.Peltier@bp.com] Sent: Wednesday, October 08, 2008 8:43 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Tom, Thank you for find this. Yes, H is a missed edit. It should read DS 12. It will read incorrectly as H-pad as well on the 12-37A PTD. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 08, 2008 8:29 AM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Travis, I am completing my review of the 12-37 - Ivishak penetration. On the Drilling Hazards sheet regarding H2S, it say "H Pad" although the wells listed are on DA 12. Was the "H" a missed edit? Thanks, Tom Maunder, PE 'AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Monday, October 06, 2008 4:15 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Hubble, Terrie L; Smith, Chasity R (DOA) Subject: RE: DS 12-37 Tom, FYI, they should be there tomorrow. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 06, 2008 3:13 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Hubble, Terrie L; Smith, Chasity R (DOA) Subject: RE: DS 12-37 Travis, et al, t have checked around over here and so far as I can determine, we have not received the new information. Our receptionist was anticipating receiving new information, but she hasn't seen anything. It is probably appropriate to resend the document. Thanks, 10/8/2008 Page 2 of 4 Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis,Peltier@bp.com] Sent: Monday, October Ofi, 2008 2:17 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC) Subject: RE: DS 12-37 Tam, I saw that the signed PTD's and Sundry went out to you on October 2 for 12-37 and 12-37A. I was wondering when I would know of any reviews or approvals since our planned spud is in about 12 - 15 days. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, September 25, 2008 5:18 AM To: Peltier, Travis M; Hobbs, Greg S (ANC) Cc: Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA) Subject: RE: DS 12-37 Travis, That is correct. The key document is the Ivishak hole PTD. #2 I'd say is the Sag horizontal. The sundry can wait a little until you have the specifics. As long as everyone knows the process, then there shouldn't be any bumps in the road. Call or message with any questions. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Wednesday, September 24, 2008 4:17 PM To: Maunder, Thomas E (DOA); Hobbs, Greg S (ANC) Cc: Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA) Subject: RE: DS 12-37 Tom, Thanks for the clarification. Just to summarize what I am reading, I will need to do the following things: 1) Send in a new PTD for 12-37, detailing the Ivishak hole 2) Send in a Sundry to plug and abandon this hole (50% chance according to the reservoir engineer) 3) Send in a PTD for 12-37A, detailing the Sag horizontal. Outcome: If we end up completing the Ivishak, the P&A Sundry and 12-37A PTD will eventually expire. If we end up P&A'ing 12-37, then we have all of the paperwork in place to procede with drilling the Sag river formation. Thanks, and let me know if I have things stated correctly. If so, I will get new PTD's and Sundry out to you ASAP -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, September 24, 2008 2:08 PM 10/8/2008 • Page 3 of 4 To: Peltier, Travis M; Hobbs, Greg S (ANC) Cc: Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA) Subject: RE: DS 12-37 Travis and Greg, I have spoken with my colleague Steve over here regarding the intent for this well. The application presently in house is permitted for a Sag BHL with an Ivishak pilot hole, not a well with a completed Ivishak BHL. If there is the possibility that the well will be completed as an Ivishak well, then that is the permit the well should be spudded with. 1f the Ivishak BHL is not productive, then the Sag BHL would be drilled as 12-37A. Anyway, what that gets us to is that it will be necessary to submit a new PTD for the Ivishak BHL. We will treat that application as a replacement for the package presently in house. If you expect the Ivishak BHL to likely be plugged, then you should submit another application for the Sag BHL 12-37A. A sundry would be needed for the plugging, however don't believe there will be any issues with that. Sorry about the paperwork hassle, however it can get problematic when the permitted BHL winds up not getting drilled and the completed BHL is in a deeper formation. Call or message with any questions. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Wednesday, September 24, 2008 9:02 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Tom, 1 would expect our spud date to be around the 21st of October. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, September 24, 2008 8:41 AM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Travis, Thanks for updating the numbers. I wondered about the 8-1/2" versus 8-3/4" hole sizes, but as you pointed out 8- 1/2" was throughout the document. I will still have to speak with Steve Davies on the pilot hole keeper/versus plug back. When is spud planned? Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Wednesday, September 24, 2008 8:33 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Tom, Thanks for catching this, and Im sorry I made a large error. The intermediate hole size should be 8-3/4" rather than 8-1/2". Checking the volumes, they are all correct for 8-3/4". What is incorrect are all of the places where I state 8-1/2" in the Permit to Drill rather than 8-314". I have changed them all in the attached document. The lead section in the 8-3/4" is LiteCrete, with a 2.45 cu. ft. / sk. The correct number of sks for the lead is 369 and 10/8/2008 Page 4 of 4 should be stated that way on page 5. Unless it is misstated somewhere else, the number is correct. The tail volume for the surface section includes a 6 bbl volume for the shoe tract section. This adds another 30 sks to the 188 sks required for the open hole for a total of 218 sks. In regards to the pilot hole, should I submit another PTD to you before we drill that section or should I just keep you updated on our progress? t know not a lot of wells like this are drilled, but there do seem to be a few that pop-up every year. Thanks again for the help and catching my errors. -Travis Peltier (907)564-4511 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, September 19, 2008 2:18 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC) Subject: DS 12-37 Travis, I am reviewing the permit application for this well. Would you please check the 7" cement calculations? You state that the tail should cover 1000' with 40% XS. I calculate the necessary volume (for 8.5" x 7") to be 31.6 bbls rather than the 40.5 bbls you have planned. For the lead, I calculate the necessary length as 9774-1000-800- 3683 = 4291'. The gage volume calculates to be 96.9 bbls. Adding 40% XS gives 135.6 bbls which requires 310 sx as opposed to the 196 sx planned. I believe the liner calculation is OK, but I also did a quick calculation of the surface tail and I would calculate the necessary sx fora 500' column with 40% XS (for 12.25" x 9.625") as 188 sx. Also, I need to look into how this well may evolve. If the pilot hole proves to be "a keeper", the a new permit may be necessary. I need to speak with Steve Davies next week. The permit as written is appropriate if the pilot hole is plugged back and the horizontal section drilled. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 10/8/2008 • ,t a ~, i ~ ~ € ~. n ~ ~ ~,~ ALASSA OIL AP1TD GAS C01~5ERQATIOI~T COl-'IIrIISSI01~ Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PAL/N, 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 12-37 BP Exploration Alaska Inc. Permit No: 208-144 Surface Location: 829' FSL, 738' FEL, SEC. 18, T10N, R15E, UM Bottomhole Location: I' FSL, 1208' FEL, SEC. 07, T10N, R15E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 Chapter 25 of the Alaska Administrative Code unless the 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. WYien providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of October, 2008 and Title 20, Commission cc: Department of Flsh & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' /~~~ STATE OF ALASKA ,.ASKA~L AND GAS CONSERVATION COMMISSI~ ~~ PERMIT TO DRILL 20 AAC 25.005 ftovb~d: 09/30/08, h-ishak BHL 1 a. Type of work ® Drill ^Redrill ^ Re-Entry 1 b. CurreAt Well Class ^ Exaloratorv ~ ^ Service ^ Stratigraphic Test ®Development Oil Development Gas Multiple Zone Single Zone 1 c. ~fy if well is proposed for. Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP location (Alaska) Inc. 5. Bond: ®Blanket Single Well Bond No. 6194193 11. Well Name and Number: PBU 12-37 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-6612 6. Proposed Depth: MD 10463' TVD 9199' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028330, ADL 028329 Pool FEL, SEC. 18, T10N, R15E, UM 829 FSL, 738 Top of Productive Horizon: UM 1208' FEL 18 T10N R15E 5162' FSL SEC 8. Land Use Permit: 13. Approximate Spud Date: October 21, 2008 , , , , . , Total Depth: 1' FSL, 1208' FEL, SEC. 07, T10N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,530' 4b. Location of Well (State Base Plane Coordinates): Surface: x-696862 -5931140 Zone-ASP4 10. KB Elevation Planned Hei ht above GL : feet 15. Distance to Nearest Well Wdhin Pool: ~0' 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole A le: 47 d Tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3262 Surface: 2462 Hole Casin Wei ht Grade Cou lin Len MD TVD MD TVD includin sta a data ,~ , ,~ 1 g, PRESENT WELL CONDITION SUMMARY (To be competed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): in Len ize ement Volume MD nductor /Structural Surface Intermediate Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Ap oval: Commission Re resentative: Date: 22. I hereby certify that the foregoing is true and correct. Contakx Traver Peltier, 564451 t Printed Name Gr Ho Title Enginaelring Team Leader ra'eparea ey Nart~INimber Si nature Phone 564-4191 Date !~! L O Terris Hubble, 5644628 Permit To Drill ~TO~/ API Number: Permit A proval so- ,~39~0000 See cover letter for Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: ~./ ~~~i (L('~t,~p~ ~` ~ 1Q©Q, ~~e~-~~~~Samples Req'd: ^ yes ld No Mud Log Req'd: ,^./Yes l!s No ~~ ~~` ~~`~ ~ ~ ~ i~ 'T HZS Measures: ®'Yes ^ No Directional Survey Req'd: In Yes ^ No Other: ~ ~~ ~3 ~ ~ ©~ ~~5 ~~S `U-~~~ O Date APPROVED BY THCE C~OM~i~R Form 10-401 Revised 12/2005 ~ aukxmt m vupncak~ ~ ' ~ ~~~ ~ L ~, x ~.w~ To: Alaska Oil & Gas Conservation Commission From: Travis Peltier, ODE Date: September 25, 2008 Re: 12-37 Grassroots well Permit to Drill The 12-37 well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location around October 21, 2008. 12-37 is a new, ultra-slim hole design well completing the Ivishak reservoir. The 12-1/4" hole will be drilled to the topmost, competent shale of the SV3 where the 9-5/8" surface casing will be run and cemented. An 8-3/4" hole will then be drilled to the top of the Sag River Formation, with 7" casing top set with cement. The planned production hole then is drilled into the Ivishak ZZ to a TD of 10,463'MD. In the event this well is wet, we will plug back this pilot hole to the 7" shoe, and drill a Sag lateral to a TD of 13,152' MD. The details of this sidetrack can be found in the Permit to Drill for 12-37A. In either case, a solid 4-1/2" production liner will be run and cemented in place. The Ivishak reservoir (e.g. Z2) will be completed if it turns out to be economically attractive. Should the Ivishak reservoir be completed, the Sag target will be preserved as a future CTD candidate. • Please note the following Well Summary as detailed on the next few pages: • 12-37 Permit to Drill Application Page 1 i ~- Planned Well Summary Well 12-37 Well Grassroots Target Ivishak T e Producer Ob'ective formation API Number: TBD Current Status 12-37 will be a new well. Estimated Start Date: 21-Oct-2008 Time to Com lete: 30.6 Da s Surface Northin Eastin Offsets TRS Location 5,931,140 696,863 829' FSL / 738' FEL 10N, 15E, 18 Production Northin Eastin TVDss Offsets TRS Tar et 5,935,460 696,262 -9,019 5162' FSL / 1208' FEL 10N, 15E, 18 Bottom Northin Eastin TVDss Offsets TRS Location 5,935,579 696,259 -9,130 1' FSL / 1208' FEL 10N, 15E, 7 • Planned KOP: Surface Planned TD: 10,463'MD / 9,130' TVDss Ri Nabors 2ES BFE: 41' RTE: 68.5' UlreCilOllal -Sperry 12-3 KOP: Surface 7_pb1_wp5 Maximum Hole Angle: --25° in the 12-1/4" surface section (C~ 1,915' MD to TD) ~47° in the 8-3/4" intermediate section (@ 8,916' MD to TD) -47° in the 6-1/8" roduction section to TD. Close A roach Wells: 01-18 in the 8-3/4" section. Surve Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro ert Line: 18,530' to the PBU property line to the South Nearest Well within Pool: 13-21 is the closest well at 900' ctr-ctr distance. Contacts Name Phone # E-mail Drilling Engineer Travis Peltier 564-4511 travis.peltier@bp.com Geologist Daniel Schafer 564-5098 daniel.schafer@bp.com Pad Engineer Trina Cooper 564-4212 Katrina.Coo~er@bp.com • 12-37 Permit to Drill Application Page 2 ,Formation Markers 12-37 (Based on SOR) • • • Formation /Zone (TVDss) MD TVD Thick MD Thick An le NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re aired from surface to TD for all new wells NOTE: All formation to s are Based on 12-37_w 4 Formation SSTVD MD TVD Thick MD Thick An le Surface 69 0 2749 2885 0.0 SV4 -2680 2885 630 698 24.2 SV3 -3310 3583 200 221 24.4 SV2 -3510 3804 405 448 24.2 SV 1 -3915 4252 695 768 24.4 UG4 -4610 5020 90 100 24.4 UG3 -4700 5120 730 807 24.2 UGl -5430 5927 575 636 24.2 WS2 -6005 6563 265 294 24.2 WS1 -6270 6857 205 226 24.4 CM3 -6475 7083 520 576 24.4 CM2 -6995 7659 917 1035 24.2 CM1 -7912 8694 244 341 39.1 THRZ -8156 9035 188 275 47.0 BHRZ -8344 9310 86 126 47.0 TKNG -8430 9436 31 46 47.0 TJB -8461 9482 75 110 47.0 TJA -8536 9592 119 174 47.2 TSGR -8655 9766 5 8 47.0 7" Lnr Set Point -8660 9774 19 27 47.0 ~~ TSHU ~ ~ -8679 `" 9~0! - 20 ~ -30 47.0 ~ ~. TSHB -8699 9~;1 14 20 - -, 47.0 TSHC -8713 9~3ti I 44 65 47.0 TSAD (46P) -8757 9916 27 39 46.9 45N _8784' 9955. _ 13 20_ 47.t? 45P -8797 9975 25 36 -17.0 44N _8822 1001.1 3 4 ., ' a7.0 44P -8825 10015 29 43 47.0 43N -8854 10058 ' 3 4 . 47.2 43P -8857 10062 35 52 47.2 42N -8892 10114 4 6 472: 42P -8896 10120 24 35 47.2 41N -8920 10155. 4 6 47A 41P -8924 10161 29 42 47.0 31 N -8953 10203 5 8 47.0 . 31P -8958 10211 61 89 47.0 27P -9019 10300 70 103 47.0 26N -9089 10403 3 4 47.0 26P -9092 10407 12 18 47.0 -25N -9104 10425 6 9 47.0 25P -9110 10434 14 20 47.0 24N -9I24 10454 - 6 9 48A TD in 24N -9130 10463 48.0 12-37 Permit to Drill Application Page 3 .~ • Casina/Tubina Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 42" 20" 215.5 A-53 W LD 108 G L 108/108 insulated 12-'/4" 9-5/8" 40# L-80 BTC-M 5,750 3,090 3,683' GL 3,683' / 3,469 8-3/4" 7" 26# L-80 TC-II 7,240 5,410 5,000' GL 5,000' / 4,660 8-3/4" 7" 26# L-80 BTC-M 7,240 5,410 4,774' 5,000' / 4,660 9,774' / 8,729 6-1/8" 4 ~/z" 12.6# 13Cr- 80 VAM Top 10,160 10,530 839' 9 624' / 8,626' 10,463' / 9,199 Tubing 4'/2" 12.6# 13Cr- 80 Vam Top 10,160 10,530 9,573' GL 9.624' / 8,626 Mud Proaram 12-'/0" Surface Hole Mud Pro erties Spud -Freshwater Mud Interval Densit PV YP PH Funn Vis FL 0-1950' (-BPRF) 8.8-9.2 30-55 50 - 870 9.0 - 9.5 400-600 NC - 8 (Initial) 300+ Final 1950'-3682' (SV3) 9.2-9.5 30-55 45 - 60 9.0 - 9.5 250 (Initial) < 6.0 225 Final 8-3/4" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 3,682'-9,035' THRZ 8.8-9.4 12-18 18-24 9-10 <6 < 15 9,035'-9,774' TSAG 11.1 12-22 18-28 9-10 HTHP < 10 < 18 6-'/e" Production Hole Mud Pro erties FloPro-SF Interval Densit PV YP PH API Filtrate MBT 9,774'-10,463' Final Well TD 8.4-8.6 6-12 22-28 9.0-9.5 6-8 <3 Logging Program 12-'/a" Hole Section: Surface Gyro until MWD surveys are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-3/4" Hole Section: MWD /LWD: DIR/GR/RES/PWD real time O en Hole: None Cased Hole: None required 6-'/8" Hole Section: Sample as required by well site Geolo ist MWD /LWD: DIR/GR/RES/NEU/DEN O en Hole: None Cased Hole: None 12-37 Permit to Drill Application Page 4 • • Cement Program Casin Size: 9-5/8" 40#, L-80 Surface Casin Basis: Lead: Open Hole (OH) volume + 250% excess in permafrost and 40% below permafrost. TOC at surface. Tail: OH vo lume + 40% excess + 80' shoe tract. TOC 500' above Casin shoe. Total Cement Volume: Spacer 70 bbls of MudPush weighted to 10.0 ppg Lead 461 bbls 701 sks , 10.7 Dee Crete- 3.69 cuft/sk Tail 45.1 bbls, 253 cuft, 218 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Tem BHST = 80 °F, BHCT = 72 °F Casin Size: 7" 26#, L-80 Intermediate Casin Basis: Lead: OH volume + 40% excess from to of tail to 800' below surface shoe. Tail: OH vo lume + 40% excess + 80' shoe tract. Tail TOC 1,000' above 7" shoe. Total Cement Volume• Spacer 25 bbl of MUDPUSH Spacer weighted to 11.5-Ib/gal Lead 161 bbl 369 sks 12.0 LiteCRETE - 2.45 cuft/sk Tail 40.5 bbls, 227 cuft, 196 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Tem BHST = 200°F, BHCT = 140 °F Casin Size 4.5" 12.6#, 13CR-80 Production Liner Basis: Lead: None Tail: 689' of open hole with 40% excess, 80' shoe tract, 150' 4-'/z" x 6-1/8" liner lap, and 200' of 7' x 4" DP excess. Tail TOC: 9,424' MD 0200' above Liner Top) Total Cement Volume: Spacer 20 bbls of Mudpush II Weighted to 12 ppg Lead None Tail 24.8 bbls, 139 cuft, 120 sks 15.8 Ib/ al Class G + adds -1.17 cuft/sk Tem BHST = 203°F, BHCT = 137 °F Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface, 12-12A to the north and 12-11 to the south are nearest wells. Each are 60' from the planned spud location. Close Approach Shut-in Wells: One well will be shut-in in order to drill 12-37. This is 01-18 for the intermediate hole, with the closest approach of 126' at 8,968' MD. Hydrogen Sulfide DS 12 is designated as an H2S site. Recent H2S data from the pad is as follows: Date of WPII Name H2S Level Reading ~1l #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) 12-37 Permit to Drill Application 12-11 NA 12-12A 20 m 3/8/2008 1-30 NA 1-10 NA 12-03 300 10/7/2003 11-1'L :iUU b/L//GNUS DS 12 is a H2S site Page 5 • • Faults The 12-37 wellpath is not expected to intersect any mapped faults. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for 12-37 will be 14 days during drilling phase. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3262 si C«~ 8800' TVDss 7.2 EMW Maximum surface ressure 2382 si .10 si/ft as radient to surface 83 bbls over 11.7 ppg FIT assuming 9.0 ppg reservoir, 4" drillpipe, and 11.1 Kick tolerance mud Rams test to 3,500 psi/250 psi. Planned BOP test pressure Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface ressure Inte rit Test - 8-3/4" hole 11.7 FIT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3262 si @ 8800' TVDss 7.2 EMW Maximum surface ressure 2462 si .10 si/ft as radient to surface Kick tolerance Infinite with a 8.8 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin "Liner Test 3500 si surface ressure Inte ri Test - 6-1/8" hole 8.8 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Variance ReAUests: To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. While the flow paddle is removed from the flow line, PVT alarms will be used and the pit levels accurately monitored for any pit gain. Also, a visual check will be made during connections by looking down the riser to ensure the well is not flowing. After returned debris that could plug the flow line diminishes the flow paddle will be reinstalled. Disposal • No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II injection. Haul all Class I waste to Pad 3 for disposal. 12-37 Permit to Drill Application hauled to grind and wastes to DS-04 for Page 6 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control • A. The Ivishak in this fault block is expected to be under-pressured at 7.2 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. I1. Lost Circulation/Breathing A. The 12-37 is not expected to intersect any mapped faults. B. There have been no significant lost circulation events in the area. The loss events that have occurred usually are less than 100 bbls in total volume, with 01-30 being the largest volume lost of 100 barrels. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for both the intermediate and production sections is 83.7 barrels and infinite, respectively, with planned mud weights. The FIT will prove up adequate formation strength for expected ECD's. B. Integrity Testing Test Point Test Depth Test t e EMW (lb/gal) 9 5/8" shoe 20-ft minimum from the 9 5/8" shoe FIT 11.7 minimum 7" shoe 20-ft minimum from the 7" shoe FIT 8.8 minimum IV. Stuck Pipe A. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required • to avoid stuck pipe. VI. Hydrogen Sulfide A. I- is designated as an H2S site; H2S levels of potentially lethal concentrations have been recorded ~S `.~ on tphis pad. The maximum recorded on this pad is 300 ppm, both at 12-03 and 12-22 in 2003 and 2005, res ectivel . 'per`-~~.`'°~~ ~`'® ~~ VII. Faults A. Little faulting is expected along the planned trajectory. See Section II on lost circulation for more details. VIII. Anti-Collision Issues B. Due to close approach concerns, one well will be shut-in in order to drill 12-37. This is 01-18 in the intermediate hole, with the closest approach of 126' at 8,968' MD. CONSULT THE DS-12 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION • 12-37 Permit to Drill Application Page 7 r i Operations Summary Current Condition and history: / 12-37 will be a new well. Pre-Riq Operations: 1. Install 20" conductor casing. 2. Weld an FMC landing ring on the conductor. 3. If necessary, level the pad and prepare location for rig move. Riq Operations: 1. MI/RU. 2. Nipple up the diverter spool and riser. P/U sufficient length of 4" drill pipe and stand back in the derrick. 3. M/U a 12-'/a" drilling assembly with Dir/GR. Spud and directionally drill surface hole to the base of the permafrost. Gyro data will be required until clean surveys can be taken. Circulate and condition hole. Short trip to the top of the heavy weight drillpipe and/or pull out of hole for a new bit if necessary. 4. RIH and drill the remainder of the surface hole to the planned surface hole TD in a shale member of the SV3 sand at 3682' MD. POOH and UD BHA. 5. Run, and cement the 9-5/e", 40# casing back to surface. A TAM port collar may be run as a contingency if hole conditions indicate a problematic primary cement job. With plug on cement job bumped, test the 9 5/1' casing to 3500 psi for 30 minutes and record the test. (NOTE: Efforts to ensure the final TOC is within 3' of surface will be required.) 6. N/D the riser spool and N/U the FMC casing head and tubing spool. 7. N/U the BOPE and test to 3,500 psi. 8. MU 6-3/a" MWD/LWD drilling assembly and RIH picking-up 4" drill pipe as required to drill the 8-3/4" hole. 9. Drill out cement, float equipment, and the shoe. Displace the well as required with new ~9.5 ppg LSND drilling fluid. Drill approximately 20' new formation and perform the planed LOT. 10. Drill ahead, according to directional proposal, to 100' above the HRZ. 11. Increase mud weight to 10.8 ppg per the Kingak polar plot. 12. Drill according to directional plan to intermediate hole TD at 9,774' MD, approximately 5' and below the top of the Sag. Circulate bottoms up as necessary for sample collection to properly identify shale/siltstone cap. 13. Condition hole as necessary to run the 7" casing and POOH. 14. RlU, run, and cement the 7", 26#, L-80 intermediate casing (TC-II & BTC-M connections). After bumping the plug on the cement job, pressure test the 7" casing to 3,500 psi for 30 minutes. Record the test. (NOTE: To eliminate space-out problems and to insure the casing shoe is into the top of the Sag, the casing will be hung on emergency slips. Also, the planned TOC will be 800' below the surface casing shoe.) 15. After allowing tail slurry to develop ~50 psi compressive strength split the stack and install the casing slips and pack-off and cut of the excess casing per FMC representative. 16. NU the BOP stack and test the "breaks" to 3500 psi. 17. Freeze-protect the 9 5/a" x 7" annulus, once the tail cement has reached 500 psi compressive strength. Confirm that the OA is open. Ensure that the mud/diesel/brine in the OA is overbalanced to formation at the 9 5/8" shoe (~8.5 ppg). 18. M/U a 6-'/8" MWD/LWD drilling assembly. P/U additional 4" drill pipe as required to TD the well and RIH to top of the float collar and re-test the casing to 3500 psi f/10 minutes. 19. Displace the well to 8.5 ppg Flo-Pro SF fluid. 20. Drill out shoe and 20' of new formation and perform the planned FIT. Drill ahead, per directional proposal and rig site geologist, to well TD at approximately 10,463' MD. 21. Condition the hole as required in preparation of running and cementing the 4-'/z" production liner. If necessary, spot liner running pill on bottom. POOH, UD excess 4" drill pipe, and UD BHA. 22. R/U and run the 4'/z", 12.6#, 13Cr-80, VamTOP liner. CBU at 7" shoe and TD as necessary. Cement • the liner per Dowell program. Release from the liner and set the packer. Circulate excess cement to surface. 12-37 Permit to Drill Application Page 8 • • • ,~ 23. Displace the well to seawater above the liner top. POOH and inspect and UD liner running tools. 24. After cement reaches a minimum 1000 psi compressive strength, R/U and pressure test the casing x liner string to 3,500psi for 30 minutes and record the test. 21. R/U and perforate well on drillpipe. 22. R/U and run a 4-'/z", 12.6#, 13Cr-80, Vam Top completion w/ GLM's. Space and land the tubing with the tubing tail inserted into the liner tie back sleeve. RILDS. 23. Reverse circulate filtered seawater and corrosion inhibitor into the tubing x casing annulus. 24. Drop ball/rod and set liner top hanger/packer. 25. Individually test the tubing and annulus to 3,500 psi for 30 minutes and record each test. 26. Shear DCR valve. 27. Install TWC and test. 28. N/D the BOPE. 29. N/U the adapter flange and tree. Test tree and adapter to 5,000 psi with diesel. 30. RU DSM. Pull TWC. 31. R/U circulating lines and test. Freeze-protect the tubing and annulus to 2,000' TVD and allow the diesel to U-tube to equilibrium. 32. Install a BPV and VR plugs in the annulus valves. 33. Secure, rig down and move off. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install gas lift valves. 3. Install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 11 /15/2008 Estimated Spud Date: 12/01/2008 12-37 Permit to Drill Application Page 9 KB. ELEV = 59 BF. ELEV `= 30.5 KOP = Max Angle = Datum MD = Datum ND = 8800 ~. TREE _ -~ CNV 41 /16 5M WELLHEAD = FMC Gen 5 CSGHEAD= 11"SMWIT'MANDREL HANGER 8 PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER = 11 " X 41/2" ADPFLANGE= 11"X41/16" -80' 20', 215.51, A-53, Insulated Conductor -2200' HES 4-1/2'X! Landing Nipple; ID= 3.813" 3,682' 9-5/8", 40 #/ft, L-80, BTC, ID = 8.835" Proposed TOC 4482' GAS LIFT MANDRELS (41/2" x 1" KBMG) Minimum ID = 3.725" ~ 9,574' 4-112" HES XN NIPPLE ST MD ND DEV TYPE VLV LATCH PORT DATE 4 DCK 2 S/O 3 DMY DMY 2 DMY DMY 1 DMY DMY 9,484' HES 4-1/2" X NIPPLE: I.D. 3.813° 9,514' BAKER PKR 7" X 4-112' S-3, ID = 3.88', xx' TBS 9,544' HES 4-112" X NIPPLE; ID = 3.813" 4-1/2", 12.6#/11, 13 Chrome, 9,824' VamTop, ID = 3.958" PERFORATION SUMMARY { i B;~'; ~ REF LOG: {T9©} , ~;x ANGLEAT TOP PERF: 787 a~ TBS ',- Note: Refer to ProduStion DB for historiSal oerf data 9,574' HES 4-112" XN NIPPLE; ID = 3.725' 9,624' 7" x 4-1 /2" Baker Flex-Loc Liner Hanger (ID =2.992") w/ ZXP Liner Top Pkr w/ 10' TBS (ID = 5.25") 9774' 7", 26 #/ft, L-80, BTC-M (f/9,774'to 5000' MD) & TC-II (f/5000' to Surf), ID = 6.276" 10,313' 4-1/2" PBTD 10,463' 41/2", 12.6#, 13CR-80, VamTOP, ID = 3.958" DATE REV BY COMMENTS []ATE REV BY COMMENTS PRUDHOE BAY UNIT TMP INITIAL WELL: DS 12-37 PERMIT No: API No: 81P 6cploration (Alaska) Propo d Com pletion ~ D~ 12-37 MPANY DETAILS REFERENCE INFORMATION BP Amuco Co-ordinate (N/E) Reference: Well Centre: 12-37 Plan, True North fit[] Vertical (TVD) Roti~rencc: 41'GL+28.59.5 69.00 ~~IINN~~ Iculation Mcihod: Minimum Curvature Section (VS) Reference: Slot - (1100N,0.00E) Errur System: ISCWSA Measured Depih Reference: 41'GL+28.5=69.5 G9.00 Scan Mcihud: Trav Cylinder Nunh Calculation Method: Minimum Curvature Error Surface: Elliptical+Casing CASING DETAILS No. TVD MD Name Size I 3469.00 2 8729.00 368227 9 5/8" 9773.98 7" 9.625 7.00(1 _ 3 9199A0 10463.13 4 I/2" 4.500 HALLIBURTON Sperry Drilling Servic®a r - i, - FORMATION TOP DETAILS - i - - - No. TVDPath MDPath Formation 1 2784.00 2924.53 SV3 2 3579.00 3803.95 SV2 ;_ , 3 3984.00 4251.96 SVI i 4 4634.00 4970.98 UG4 - - - _:_ _ I - 5 4839.00 5197.75 UG3 ~ ~ 6 5539.00 5972.08 UG I 10 7 8 6074.00 6563.89 W52 6339.00 6857.03 WSI ~ _ ' I ' _,- 9 6544.00 7083.80 CM3 10 7064.00 7659.02 CM2 II 7981.00 8694.34 CM1 ~ --. 12 8225.00 9034.98 THRZ I 13 8413.00 9310.64 BHRZ ~ ' ~, 14 8499.00 9436.74 TKNG - . i IS 8530.00 9482.19 TJB ~ ~ 16 8605.00 9592.16 TJA i 17 8724.00 9766.65 TSGR IS 8748.00 9801.84 TSHU ! 19 8768.00 9831.17 TSHB -_ _i 20 8782.00 9851.70 TSHC 21 8826.00 9916.21 TSAD (46P) 22 8853.00 9955.80 45N 23 8866.00 9974.86 45P 24 8891.00 10011.52 44N 25 8894.00 10015.92 44P 26 8923.00 10058.44 43N - - - 27 8926.00 10062.84 43P ! ~ 28 8961.00 10114.16 42N ~ 29 8965.00 10120.02 42P I ~ ~ i 30 8989.00 10155.22 41N _ _ ,_ 31 8993.00 10161.08 41P ~ ~ 32 9022.00 10203.60 3IN I ' _ ~ 33 9027.00 10210.93 31 P I ~ ~ 34 9088.00 10300.38 27P I 35 9158.00 10403.02 26N ~ _ _ 36 9161.00 10407.42 26P i I . ~ 37 38 9173.00 10425.01 25N 9179.00 10433 SI 25P . ! 39 9193.00 10454.34 24N I_ _ - ~ TARGET DETAILS Name TVD +N/-S +E/-W Northing Fasting Shape 12-99 TSAG 8724.00 3944.34 -488.02 5935070.16 696272.66 Circle (Radius: 200) 12-37 Fault I 8769.00 2585.38 -346929 5933634.00 693328.00 Polygon 12-37 Fault 2 8769.00 3629.09 -5167.75 5934633.00 6916(13.00 Polygon 12-37 TSAD rev I 8826.00 4053.72 -488.02 5935179.50 696269.80 Circle (Radius: 200) SURVEY PROGRAM Depth To Survey/Plan Tiwl Plan : 12-37Pb1 Wp 5.0(12-37PIan/ 12-37PBI Plan) 80Q00 Planned: 12-37P61 Wp 5.0 V 14 CB-GYRO-SS Crcatcd By: Sperry Drilling Data 5/30/2008 10463.13 Planned: l2-37P61 Wp S.ll V14 MWD+IFR+MS WEL L DETAILS Name +N/-S +E/-W Nonhing Fasting Latitude Longitude Slut 12-37PIan -1481.41 -1142.76 5931140.11 696863.34 A 70°12'SZ891N 148°24'43A(7W N/A Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VScc Target 1 28.00 0.00 OAO 28.00 Q00 0.00 0.00 0.00 0.00 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 3 583.33 5.00 90.00 582.91 0.00 14.54 L50 90A0 -1.58 4 1914.62 25.31 349.78 187L03 285.21 22.18 2.00 -IIO.IS 28L10 5 8355.05 25.31 349.78 7693.22 2994.91 -466.46 OAO Q00 3027.90 6 8916 21 47.00 0.00 8144.00 3322.37 -488A2 4.00 19.87 3355.76 7 9916.21 47.00 0.00 8826.00 4053.72 -488.02 0.00 0.00 4083.76 12-37 TSAD rev 1 8 1(1463.13 47.00 0.(10 9199.00 4453.71 -488.02 0.00 0.00 4480.37 i ~I i. 1 1 1 1 t L. } _ i ~_r - _{-_ . 9 1 2" "PoGrl Depth : 0463.13' MD, S ~. ~ 12-37Pb1 Wp 5 0 2000 4000 6000 Vertical Section at 353.75° [2000ft/in] I I~~'-' r i 1000(1 1PANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BP Amoco -ordinate (N/E) Reference: Well Centre: 12-37 Plaq Truc Nonh Dapih Fm Depth To Survey/Plan Tool Plan: 12-37P6I Wp 5.0 (12-37 Plan/ 12-37P01 Plan) Vertical (TVD) Reference: 41'GL+28.5=69.5 69.00 Calculation Method: Minimum Curvature Section (VS) Reference: Slot - (U.OON,O.OOE) 28.00 ROQUO Planned: 12-37P6I Wp 5.0 V 14 C&GYR0.SS Created By: Sperry Drilling Date: 5/30/2008 Error Systan: ISCWSA casurcd Dcpfh Reference: 41'GL+28.5=69.5 69.00 80000 10463.13 Planned: l2-37PbIW 5.0 V14 MWD+IFR+MS Scan Method: Trev Cylinder North Calculation Method: Minimum Curvature WELL DETAILS Ertor Surface: Elliptical+Casing Warning Method: Rules Based Nance +N/-S +E/- W Nonhing Easting Latitude Longitude Slot H w ~~'~~~~Q~^ , V 12-37 Plan -148L41 -1142. 76 5931140.11 696863.34 70°12'57.891N 148°24'43.067W N/A ~ TARGET DETAILS $p6f'~`~/ ~r~~~~hg B~f V~C 9 B - - - ~ ~ I . - f ~ - {-- -~.r Name TVD +N/-S +E/-W Northing Easting Shape 4893 - - ~ ~ - - - ~ 1 J ~ _ ~,. Total Dc h :104 ~ ~-~ 12-99 TSAG 63.13' MD, 9199' D '. 12.37 Fault 1 8724A0 8769.00 3944.34 -488.02 5935070.16 696272.66 2585.38 -3469.29 5933634.00 693328.00 Circle (Radius: 200) Polygon 12-37Pb1 Wp 5. 12-37 Fault 2 8769A0 3629A9 -5167.75 5934633.00 691603.00 Polygon ~' - 12-37 TSAD rev 1 8826.00 4053.72 -488.02 5935179.80 696269.80 Circle (Radius: 200) __}-~~_ 12-37P6I Plao r ~ 12 -37 TSAD rev I - 3915 ~ , ~,~, ,-~ .. .. . - -. ~ - - Start Dir "/100' :8355.05' MD, 769 .22'TVD _ _ 8 V 2936 12-37 Faul 1 ' -- --- 75 0 _ _ . ^ I 70 0 - ~ + ~ ~ ~ ~ - ~ ~ T ~ - - ~ - -- -_ FORMATION TOP DETAILS ~l 65 0 i - ~ '~ ~ '~ ~ ~ No. TVDPa[h MDPa[h Fomtation ): I-r t _(. _ - , . I 2784A0 2924.53 SV3 : 2 3579.00 3803.95 SV3 ._ 55 0 ,- ... l i ~' _ :... 3 3984A0 4251.96 SVI ~. - ~ ~ I ' 4 4634.00 4970.98 UG4 ~ ~ •~ ~ ~ ~ ~ ~ _ 5 4839.00 5197.75 UG3 I ' ~ ~ - 50 0 ~ 6 5539.00 5972.08 UGI ' - ~ +... _.' ~ - - ~ I ~ - -~ ~ ~ _- 1-~ - 7 6074.0(1 6563.89 WS2 ~ ~ 8 6339.00 6857.03 WSl ~ _ - 45 0 I i 9 6544.00 7083.80 CM3 - -' ~ -. I, 10 7064A0 7659.02 CM2 ~ . - , __.. 40 0 ~, Il 7981.00 8694.34 CMI 95/8".- 12 8225.00 9034.98 THRZ ~, 13 8413.00 9310.64 BHRZ 3 14 8499.00 9436.74 TKNG - ~ ~ ~ - ~ ~ ~ ~ l5 8530.00 9482.19 T1B ~ '. 0 j~~ l6 8605.00 9592.16 TJA - End Di ~' MD, 1871.03' : 1914.6_ VD - 3 ~ - - - - - - - 17 8724.00 9766.65 TSGR i 18 8748.00 9801.84 TSHU TIII 25 ~ _ ~ 0 '~ 19 8768.00 983 L l7 TSHB i ~ ~ " ' ' ~ --- ' ~~- - - ~ ' ~ - - ~- 20 8782A0 9851.70 TSHC - " -' ~ ~ ~ ~ Start MD; 5 it 2 /100 ; 583:33 2.91 TVD - - 21 8826A0 9916.21 TSAD (46P) ~ ~ ~ 2 0 CASING DETAILS 22 8853.00 9955.80 45N ~ ~ - ~ - ~ - ~ ' ~ ~ - ~ art Dir 1.5"/100' : 250' M 250'TVD - --~~~~~- - - - - - ~ --- ~- 23 8866.00 9974.86 45P 24 889L00 10(111.52 44N , ~ ~ No. TVD MD Name Sizc 1 25 8894.00 10015.92 44P > 0 I 3469.00 3682.27 9 5/8" 9.625 26 8923.00 10058.44 43N ~ 2 8729.00 9773.98 7" 7.000 27 8926.00 10062.84 43P ~ -,7 ~ 3 9199.00 10463.13 4 1/2" 4.800 28 8961.00 10114.16 42N I I ' - ~ 29 8965 00 10120 02 42P I ~ SECTION DETAILS 30 8989 Oll 10155 22 41N - i ~ - I 31 8993A0 10161.08 41P I ` ' ~ `z ` Scc MD Inc Azi TVD +N/-S +E/-W DLcg TFacc VSvc Target 32 9022.00 10203.60 3lN . - .:.- -. , :L -. 33 9027.00 10210.93 31P I 28.00 0.00 o.UO 28.00 0.00 O.UO O.UO o.UO 0.00 00 10300 38 27p 34 9088 2 250.W O.W O.UO 250.00 0.00 0.00 000 0.00 O.W . . 02 26N 35 9158A0 10403 3 S%3.33 5.00 90.00 5%2.91 U.UU 14.54 LSU 90.00 -L58 . 36 9161 AO 10407.42 26P 4 1914.62 25.31 349.7% 1%71.03 285.21 22.1% 2.00 -110.15 2%L10 7% 7693.22 2994.91 -466.46 OAU 0.00 3027.90 05 25 31 349 5 8355 37 9173.00 10425.01 25N -3 915 -2 936 -1 957 -9 79 . . . 6 8916.21 47.W 0.00 8144.110 3322.37 -488.02 4.OU 19.87 3355.76 38 9179.00 10433.81 25P 7 9916.21 47.00 0.W 8826.00 4053.72 -4%8.02 0.00 0.00 4082.76 12-377SAD rev I 39 9193.00 10454.34 24N Wcsl(-)/East(+ 8 10463.13 47.00 0.00 9199A0 4453.71 -488A2 OAO 0.00 4380.37 '~ Sperry-Sun ~' BP Planning Report • • • Company:. BP Amoco Date: .:5/30/2008 Timer 12:21:43 Page:. 1 Field: Prudhoe Bay Co-ordinate(NE) References W eIL 12-37 Plan, True North Site: PB DS 12 Vertical (TVl)) Reference: 41'GL+28.5=69:5 69.0 Well: 12-37 Plan Section (VS) Reference: Well (O.OON,O;OOE,353.75Azi) Wellpath: 12-37PB1 Plan Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 12-37Pb1 Wp 5.0 Date Composed: 5/1/2008 Version: 14 Principal: Yes Tied-to: From Well Ref. Point Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 12 TR-10-15 UNITED STATES :North S lope Site Position: Northing: 5932650.90 ft Latitude: 70 13 12.462 N From: Map Easting: 697966.79 ft Longitude: 148 24 9.888 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 12-37 Plan Slot Name: Well Position: +N/-S -1481.41 ft Northing: 5931140.11 ft Latitude: 70 12 57.891 N +E/-W -1142.76 ft Easting : 696863.34 ft Longitude: 148 24 43.067 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in irr 3682.27 3469.00 9.625 12.250 9 5/8" 9773.98 8729.00 7.000 8.500 7" 10463.13 9199.00 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle .Dip Direction ft ft deg deg 2924.53 2784.00 SV3 0.00 0.00 3803.95 3579.00 SV2 0.00 0.00 4251.96 3984.00 SV1 0.00 0.00 4970.98 4634.00 UG4 0.00 0.00 5197.75 4839.00 UG3 0.00 0.00 5972.08 5539.00 UG1 0.00 0.00 6563.89 6074.00 WS2 0.00 0.00 6857.03 6339.00 WS1 0.00 0.00 7083.80 6544.00 CM3 0.00 0.00 7659.02 7064.00 CM2 0.00 0.00 8694.34 7981.00 CM1 0.00 0.00 9034.98 8225.00 THRZ 0.00 0.00 9310.64 8413.00 BHRZ 0.00 0.00 9436.74 8499.00 TKNG 0.00 0.00 9482.19 8530.00 TJB 0.00 0.00 9592.16 8605.00 TJA 0.00 0.00 9766.65 8724.00 TSGR 0.00 0.00 9801.84 8748.00 TSHU 0.00 0.00 9831.17 8768.00 TSHB 0.00 0.00 9851.70 8782.00 TSHC 0.00 0.00 9916.21 8826.00 TSAD (46P) 0.00 0.00 9955.80 8853.00 45N 0.00 0.00 9974.86 8866.00 45P 0.00 0.00 10011.52 8891.00 44N 0.00 0.00 10015.92 8894.00 44P 0.00 0.00 10058.44 8923.00 43N 0.00 0.00 10062.84 8926.00 43P 0.00 0.00 10114.16 8961.00 42N 0.00 0.00 10120.02 8965.00 42P 0.00 0.00 10155.22 8989.00 41 N 0.00 0.00 10161.08 8993.00 41 P 0.00 0.00 Sperry-Sun ~' BP Planning Report • t Company: BP Amoco Date:. 5/30/2008 Time: 12:21:43 Page:. 2' Field: Prtadhce Bay Co-ordinate(NE) Reference:: Well: 12-37 Plan, True North Site: PB DS 12 Vertical (TVD) Reference: 41'GL+28.5=69.5 69.0 Well: 12-37 Plan Section (VS) Reference: Well (t). OON,O:OOE,353. 75Azi) Wellpath: 12-37P61 Plan Survey Calculation Method: M inimum Curvature ' Db: OraGe Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 10203.60 9022.00 31 N 0.00 0.00 10210.93 9027.00 31 P 0.00 0.00 10300.38 9088.00 27P 0.00 0.00 10403.02 9158.00 26N 0.00 0.00 10407.42 9161.00 26P 0.00 0.00 10425.01 9173.00 25N 0.00 0.00 10433.81 9179.00 25P 0.00 0.00 10454.34 9193.00 24N 0.00 0.00 Targets Map Map ~-- Latitude ----> <- Longitude -> Name Description TVD +N/-S +E/-W Northing: Fasting` Deg Min Sec Deg Miq Sec _ Dip. Dir. ft ft ft ft ft 12-99 TSAG 8724.00 3944.34 -488.02 5935070.16 696272.66 70 13 36.684 N 148 24 57.243 W -Circle (Radius: 200) -Plan hit target 12-37 Fault 1 8769.00 2585.38 -3469.29 5933634.00 693328.00 70 13 23.311 N 148 26 23.830 W -Polygon 1 8769.00 2585.38 -3469.29 5933634.00 693328.00 70 13 23.311 N 148 26 23.830 W -Polygon 2 8769.00 2549.98 -2878.98 5933614.00 693919.00 70 13 22.965 N 148 26 6.684 W -Polygon 3 8769.00 2696.13 -2383.98 5933773.00 694410.00 70 13 24.404 N 148 25 52.309 W -Polygon 4 8769.00 2728.25 -1237.68 5933835.00 695555.00 70 13 24.723 N 148 25 19.015 W -Polygon 5 8769.00 2790.86 -684.83 5933912.00 696106.00 70 13 25.339 N 148 25 2.958 W -Polygon 6 8769.00 2576.00 -80.19 5933713.00 696716.00 70 13 23.226 N 148 24 45.396 W -Polygon 7 8769.00 2417.53 510.91 5933570.00 697311.00 70 13 21.668 N 148 24 28.228 W -Polygon 8 8769.00 2476.27 1058.66 5933643.00 697857.00 70 13 22.245 N 148 24 12.319 W -Polygon 9 8769.00 2361.78 1650.90 5933544.00 698452.00 70 13 21.118 N 148 23 55.119 W -Polygon 10 8769.00 2187.05 2251.59 5933385.01 699057.00 70 13 19.398 N 148 23 37.675 W -Polygon 11 8769.00 2066.85 2832.68 5933280.01 699641.00 70 13 18.214 N 148 23 20.799 W -Polygon 12 8769.00 2091.20 3394.54 5933319.01 700202.00 70 13 18.451 N 148 23 4.481 W -Polygon 13 8769.00 1981.00 3975.90 5933224.01 700786.00 70 13 17.364 N 148 22 47.599 W -Polygon 14 8769.00 2091.20 3394.54 5933319.01 700202.00 70 13 18.451 N 148 23 4.481 W -Polygon 15 8769.00 2066.85 2832.68 5933280.01 699641.00 70 13 18.214 N 148 23 20.799 W -Polygon 16 8769.00 2187.02 2251.59 5933384.98 699057.00 70 13 19.397 N 148 23 37.675 W -Polygon 17 8769.00 2361.78 1650.90 5933544.00 698452.00 70 13 21.118 N 148 23 55.119 W -Polygon 18 8769.00 2476.27 1058.66 5933643.00 697857.00 70 13 22.245 N 148 24 12.319 W -Polygon 19 8769.00 2417.53 510.91 5933570.00 697311.00 70 13 21.668 N 148 24 28.228 W -Polygon 20 8769.00 2576.00 -80.19 5933713.00 696716.00 70 13 23.226 N 148 24 45.396 W -Polygon 21 8769.00 2790.86 -684.83 5933912.00 696106.00 70 13 25.339 N 148 25 2.958 W -Polygon 22 8769.00 2728.25 -1237.68 5933835.00 695555.00 70 13 24.723 N 148 25 19.015 W -Polygon 23 8769.00 2696.13 -2383.98 5933773.00 694410.00 70 13 24.404 N 148 25 52.309 W -Polygon 24 8769.00 2549.98 -2878.98 5933614.00 693919.00 70 13 22.965 N 148 26 6.684 W -Plan out by 3296.70 at 8769.00 3992.59 -488.02 5935118.40 696271.39 70 13 37.158 N 148 24 57.244 W 12-37 Fault 2 8769.00 3629.09 -5167.75 5934633.00 691603.00 70 13 33.566 N 148 27 13.181 W -Polygon 1 8769.00 3629.09 -5167.75 5934633.00 691603.00 70 13 33.566 N 148 27 13.181 W -Polygon 2 8769.00 3206.85 -4436.47 5934230.00 692345.00 70 13 29.418 N 148 26 51.932 W -Polygon 3 8769.00 3228.09 -3371.49 5934279.00 693409.00 70 13 29.632 N 148 26 20.998 W -Polygon 4 8769.00 3321.82 -3052.92 5934381.00 693725.00 70 13 30.555 N 148 26 11.745 W -Polygon 5 8769.00 3395.81 -2514.78 5934469.00 694261.00 70 13 31.285 N 148 25 56.115 W -Polygon 6 8769.00 3381.90 -1942.92 5934470.00 694833.00 70 13 31.150 N 148 25 39.503 W -Polygon 7 8769.00 3427.51 -1390.51 5934530.00 695384.00 70 13 31.600 N 148 25 23.458 W -Polygon 8 8769.00 3617.13 -874.36 5934733.00 695895.00 70 13 33.465 N 148 25 8.465 W -Polygon 9 8769.00 3730.85 -325.18 5934861.00 696441.00 70 13 34.584 N 148 24 52.513 W -Polygon 10 8769.00 3764.65 219.92 5934909.00 696985.00 70 13 34.917 N 148 24 36.678 W -Polygon 11 8769.00 3667.43 840.63 5934828.01 697608.00 70 13 33.960 N 148 24 18.648 W -Polygon 12 8769.00 3605.25 1383.23 5934780.01 698152.00 70 13 33.348 N 148 24 2.887 W -Polygon 13 8769.00 3528.53 1678.34 5934711.01 698449.00 70 13 32.593 N 148 23 54.315 W -Polygon 14 8769.00 3567.45 1950.46 5934757.01 698720.00 70 13 32.975 N 148 23 46.410 W -Polygon 15 8769.00 3563.50 2523.59 5934768.01 699293.00 70 13 32.934 N 148 23 29.762 W -Polygon 16 8769.00 3404.92 3118.69 5934625.01 699892.00 70 13 31.372 N 148 23 12.477 W -Polygon 17 8769.00 3290.56 3705.94 5934526.01 700482.00 70 13 30.245 N 148 22 55.421 W -Polygon 18 8769.00 3404.92 3118.69 5934625.01 699892.00 70 13 31.372 N 148 23 12.477 W -Polygon 19 8769.00 3563.50 2523.59 5934768.01 699293.00 70 13 32.934 N 148 23 29.762 W -Polygon 20 8769.00 3567.45 1950.46 5934757.01 698720.00 70 13 32.975 N 148 23 46.410 W Sperry-Sun BP Planning Report • Company: BP Amoco Date: 5/30/2008. Time:. 12;21:43 Page:.: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: W ell: 12-37 Plan, True North Site: PB DS 12 Vertical (TVD) Reference: 41 'GL+28.5=69.5 69.0 Well: 12-37 Plan Section (VS) Reference: W ell (O.OON,O.OOE,353.75Azi) Wellpath 12-37P61 Plan Survey Calculation Method: Mi nimum Curvature Db: Oracle Targets Map Map <-- Latitude --> <- Longitude ---> Name.. Description TVD +N/-5 +E/-W Northing Easting I)eg Min Sec Deg Mine Sec Dip. Dir. ft ft ft ft ft' -Polygon 21 8769.00 3528.53 1678.34 5934711.01 698449.00 70 13 32.593 N 148 23 54.315 W -Polygon 22 8769.00 3605.25 1383.23 5934780.01 698152.00 70 13 33.348 N 148 24 2.887 W -Polygon 23 8769.00 3667.43 840.63 5934828.01 697608.00 70 13 33.960 N 148 24 18.648 W -Polygon 24 8769.00 3764.65 219.92 5934909.00 696985.00 70 13 34.917 N 148 24 36.678 W -Polygon 25 8769.00 3730.85 -325.18 5934861.00 696441.00 70 13 34.584 N 148 24 52.513 W -Polygon 26 8769.00 3617.13 -874.36 5934733.00 695895.00 70 13 33.465 N 148 25 8.465 W -Polygon 27 8769.00 3427.51 -1390.51 5934530.00 695384.00 70 13 31.600 N 148 25 23.458 W -Polygon 28 8769.00 3381.90 -1942.92 5934470.00 694833.00 70 13 31.150 N 148. 25 39.503 W -Polygon 29 8769.00 3395.81 -2514.78 5934469.00 694261.00 70 13 31.285 N 148 25 56.115 W -Polygon 30 8769.00 3321.82 -3052.92 5934381.00 693725.00 70 13 30.555 N 148 26 11.745 W -Polygon 31 8769.00 3228.09 -3371.49 5934279.00 693409.00 70 13 29.632 N 148 26 20.998 W -Polygon 32 8769.00 3206.85 -4436.47 5934230.00 692345.00 70 13 29.418 N 148 26 51.932 W -Plan out by 4693. 82 at 8769.00 3992.59 -488.02 5935118.40 696271.39 70 13 37.158 N 148 24 57.244 W 12-37 TSAD rev 1 8826.00 4053.72 -488.02 5935179.50 696269.80 70 13 37.760 N 148 24 57.244 W -Circle (Radius: 200) -Plan hit target Plan Section Information MD Incl. Azim TVD +N/-S +E/-W DLS Build Turn. TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.00 583.33 5.00 90.00 582.91 0.00 14.54 1.50 1.50 0.00 90.00 1914.62 25.31 349.78 1871.03 285.21 22.18 2.00 1.53 -7.53 -110.15 8355.05 25.31 349.78 7693.22 2994.91 X66.46 0.00 0.00 0.00 0.00 8916.21 47.00 0.00 8144.00 3322.37 X88.02 4.00 3.87 1.82 19.87 9916.21 47.00 0.00 8826.00 4053.72 X88.02 0.00 0.00 0.00 0.00 12-37 TSAD rev 1 10463.13 47.00 0.00 9199.00 4453.71 -488.02 0.00 0.00 0.00 0.00 Survey MD IncP Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft = ft ft 28.00 0.00 0.00 28.00 -41.00 0.00 0.00 0.00 0.00 5931140.11 696863.34 CB-GYRO 100.00 0.00 0.00 100.00 31.00 0.00 0.00 0.00 0.00 5931140.11 696863.34 CB-GYRO 200.00 0.00 0.00 200.00 131.00 0.00 0.00 0.00 0.00 5931140.11 696863.34 CB-GYRO 250.00 0.00 0.00 250.00 181.00 0.00 0.00 0.00 0.00 5931140.11 696863.34 Start Dir 1. 300.00 0.75 90.00 300.00 231.00 -0.04 0.00 0.33 1.50 5931140.12 696863.67 CB-GYRO 400.00 2.25 90.00 399.96 330.96 -0.32 0.00 2.94 1.50 5931140.19 696866.28 CB-GYRO 500.00 3.75 90.00 499.82 430.82 -0.89 0.00 8.18 1.50 5931140.32 696871.52 CB-GYRO 583.33 5.00 90.00 582.91 513.91 -1.58 0.00 14.54 1.50 5931140.49 696877.87 Start Dir 2° 1 600.00 4.90 86.33 599.52 530.52 -1.69 0.05 15.97 2.00 5931140.57 696879.30 CB-GYRO 700.00 4.73 62.40 699.17 630.17 -0.39 2.23 23.89 2.00 5931142.96 696887.16 CB-GYRO 800.00 5.37 40.68 798.79 729.79 4.31 7.69 30.59 2.00 5931148.59 696893.72 MWD+IFR 900.00 6.57 25.22 898.25 829.25 12.39 16.41 36.08 2.00 5931157.46 696898.98 MWD+IFR 1000.00 8.10 15.02 997.44 928.44 23.83 28.40 40.34 2.00 5931169.55 696902.93 MWD+IFR 1100.00 9.80 8.17 1096.22 1027.22 38.64 43.62 43.38 2.00 5931184.84 696905.56 MWD+IFR 1200.00 11.59 3.38 1194.48 1125.48 56.78 62.07 45.18 2.00 5931203.33 696906.88 MWD+IFR 1300.00 13.44 359.87 1292.10 1223.10 78.24 83.72 45.75 2.00 5931224.99 696906.89 MWD+IFR 1400.00 15.33 357.21 1388.97 1319.97 102.99 108.54 45.08 2.00 5931249.78 696905.57 MWD+IFR 1500.00 17.24 355.12 1484.95 1415.95 131.00 136.51 43.17 2.00 5931277.69 696902.94 MWD+IFR 1600.00 19.17 353.44 1579.94 1510.94 162.23 167.59 40.04 2.00 5931308.68 696898.99 MWD+IFR 1700.00 21.11 352.06 1673.82 1604.82 196.65 201.74 35.67 2.00 5931342.70 696893.74 MWD+IFR 1800.00 23.06 350.90 1766.48 1697.48 234.22 238.92 30.09 2.00 5931379.72 696887.18 MWD+IFR 1900.00 25.02 349.91 1857.80 1788.80 274.89 279.09 23.28 2.00 5931419.70 696879.33 MWD+IFR 1914.62 25.31 349.78 1871.03 1802.03 281.10 285.21 22.18 2.00 5931425.78 696878.08 End Dir : 1 2000.00 25.31 349.78 1948.22 1879.22 317.51 321.13 15.71 0.00 5931461.52 696870.67 MWD+IFR 2100.00 25.31 349.78 2038.62 1969.62 360.16 363.21 8.12 0.00 5931503.38 696861.98 MWD+IFR lent Sperry-Sun BP Planning Report • • • Company:. BP Amoco Date: 5/30/2008 Time: . 12;21:43 Page: 4 Field: Prudhoe Bay Co-ordinate(N E) Reference: Well: 12-37 Plan, True.North Site: PB DS 12 Vertical (TVD}Reference: 41'GL+28.5=69.5 69 .0 Well: 12-37 Plan Section (VS) Reference: Well (O,OON,O.OOE,353.75Azi} Wellpath: 12-37P61 Plan Survey Calculation Method: Minimum' Curvature Dbc Oracle Survey MD Incl Azim TVD Sys 1'VD VS N/S E/W I)LS MapN MapE TooUCo ft deg deg ft ft ft ft ft' deg/100ft ft ft 2200.00 25.31 349.78 2129.02 2060.02 402.81 405.28 0.53 0.00 5931545.24 696853.30 MWD+IFR 2300.00 25.31 349.78 2219.42 2150.42 445.46 447.35 -7.05 0.00 5931587.10 696844.62 MWD+IFR 2400.00 25.31 349.78 2309.82 2240.82 488.11 489.43 -14.64 0.00 5931628.96 696835.94 MWD+IFR 2500.00 25.31 349.78 2400.22 2331.22 530.76 531.50 -22.23 0.00 5931670.82 696827.26 MWD+IFR 2600.00 25.31 349.78 2490.62 2421.62 573.41 573.57 -29.82 0.00 5931712.68 696818.58 MWD+IFR 2700.00 25.31 349.78 2581.02 2512.02 616.06 615.65 -37.40 0.00 5931754.54 696809.90 MWD+IFR 2800.00 25.31 349.78 2671.42 2602.42 658.71 657.72 -44.99 0.00 5931796.40 696801.22 MWD+IFR 2900.00 25.31 349.78 2761.82 2692.82 701.36 699.79 -52.58 0.00 5931838.25 696792.53 MWD+IFR 2924.53 25.31 349.78 2784.00 2715.00 711.82 710.11 -54.44 0.00 5931848.52 696790.40 SV3 3000.00 25.31 349.78 2852.22 2783.22 744.00 741.87 -60.16 0.00 5931880.11 696783.85 MWD+IFR 3100.00 25.31 349.78 2942.62 2873.62 786.65 783.94 -67.75 0.00 5931921.97 696775.17 MWD+IFR 3200.00 25.31 349.78 3033.02 2964.02 829.30 826.01 -75.34 0.00 5931963.83 696766.49 MWD+IFR 3300.00 25.31 349.78 3123.42 3054.42 871.95 868.09 -82.93 0.00 5932005.69 696757.81 MWD+IFR 3400.00 25.31 349.78 3213.82 3144.82 914.60 910.16 -90.51 0.00 5932047.55 696749.13 MWD+IFR 3500.00 25.31 349.78 3304.22 3235.22 957.25 952.23 -98.10 0.00 5932089.41 696740.45 MWD+IFR 3600.00 25.31 349.78 3394.62 3325.62 999.90 994.31 -105.69 0.00 5932131.27 696731.77 MWD+IFR 3682.27 25.31 349.78 3469.00 3400.00 1034.99 1028.92 -111.93 0.00 5932165.70 696724.62 9 5/8" 3700.00 25.31 349.78 3485.03 3416.03 1042.55 1036.38 -113.27 0.00 5932173.12 696723.08 MWD+IFR 3800.00 25.31 349.78 3575.43 3506.43 1085.20 1078.45 -120.86 0.00 5932214.98 696714.40 MWD+IFR 3803.95 25.31 349.78 3579.00 3510.00 1086.89 1080.12 -121.16 0.00 5932216.64 696714.06 SV2 3900.00 25.31 349.78 3665.83 3596.83 1127.85 1120.53 -128.45 0.00 5932256.84 696705.72 MWD+IFR 4000.00 25.31 349.78 3756.23 3687.23 1170.50 1162.60 -136.04 0.00 5932298.70 696697.04 MWD+IFR 4100.00 25.31 349.78 3846.63 3777.63 1213.15 1204.67 -143.62 0.00 5932340.56 696688.36 MWD+IFR 4200.00 25.31 349.78 3937.03 3868.03 1255.80 1246.75 -151.21 0.00 5932382.42 696679.68 MWD+IFR 4251.96 25.31 349.78 3984.00 3915.00 1277.96 1268.61 -155.15 0.00 5932404.17 696675.17 SV1 4300.00 25.31 349.78 4027.43 3958.43 1298.45 1288.82 -158.80 0.00 5932424.28 696671.00 MWD+IFR 4400.00 25.31 349.78 4117.83 4048.83 1341.10 1330.89 -166.38 0.00 5932466.14 696662.32 MWD+IFR 4500.00 25.31 349.78 4208.23 4139.23 1383.75 1372.97 -173.97 0.00 5932507.99 696653.63 MWD+IFR 4600.00 25.31 349.78 4298.63 4229.63 1426.40 1415.04 -181.56 0.00 5932549.85 696644.95 MWD+IFR 4700.00 25.31 349.78 4389.03 4320.03 1469.04 1457.11 -189.15 0.00 5932591.71 696636.27 MWD+IFR 4800.00 25.31 349.78 4479.43 4410.43 1511.69 1499.19 -196.73 0.00 5932633.57 696627.59 MWD+IFR 4900.00 25.31 349.78 4569.83 4500.83 1554.34 1541.26 -204.32 0.00 5932675.43 696618.91 MWD+IFR 4970.98 25.31 349.78 4634.00 4565.00 1584.62 1571.12 -209.71 0.00 5932705.14 696612.75 UG4 5000.00 25.31 349.78 4660.23 4591.23 1596.99 1583.33 -211.91 0.00 5932717.29 696610.23 MWD+IFR 5100.00 25.31 349.78 4750.63 4681.63 1639.64 1625.41 -219.49 0.00 5932759.15 696601.55 MWD+IFR 5197.75 25.31 349.78 4839.00 4770.00 1681.33 1666.53 -226.91 0.00 5932800.06 696593.06 UG3 5200.00 25.31 349.78 4841.03 4772.03 1682.29 1667.48 -227.08 0.00 5932801.01 696592.87 MWD+IFR 5300.00 25.31 349.78 4931.44 4862.44 1724.94 1709.55 -234.67 0.00 5932842.87 696584.18 MWD+IFR 5400.00 25.31 349.78 5021.84 4952.84 1767.59 1751.63 -242.26 0.00 5932884.72 696575.50 MWD+IFR 5500.00 25.31 349.78 5112.24 5043.24 1810.24 1793.70 -249.84 0.00 5932926.58 696566.82 MWD+IFR 5600.00 25.31 349.78 5202.64 5133.64 1852.89 1835.77 -257.43 0.00 5932968.44 696558.14 MWD+IFR 5700.00 25.31 349.78 5293.04 5224.04 1895.54 1877.85 -265.02 0.00 5933010.30 696549.46 MWD+IFR 5800.00 25.31 349.78 5383.44 5314.44 1938.19 1919.92 -272.60 0.00 5933052.16 696540.78 MWD+IFR 5900.00 25.31 349.78 5473.84 5404.84 1980.84 1961.99 -280.19 0.00 5933094.02 696532.10 MWD+IFR 5972.08 25.31 349.78 5539.00 5470.00 2011.58 1992.32 -285.66 0.00 5933124.19 696525.84 UG1 6000.00 25.31 349.78 5564.24 5495.24 2023.49 2004.07 -287.78 0.00 5933135.88 696523.42 MWD+IFR 6100.00 25.31 349.78 5654.64 5585.64 2066.14 2046.14 -295.37 0.00 5933177.74 696514.73 MWD+IFR 6200.00 25.31 349.78 5745.04 5676.04 2108.79 2088.21 -302.95 0.00 5933219.59 696506.05 MWD+IFR 6300.00 25.31 349.78 5835.44 5766.44 2151.44 2130.29 -310.54 0.00 5933261.45 696497.37 MWD+IFR 6400.00 25.31 349.78 5925.84 5856.84 2194.08 2172.36 -318.13 0.00 5933303.31 696488.69 MWD+IFR 6500.00 25.31 349.78 6016.24 5947.24 2236.73 2214.43 -325.71 0.00 5933345.17 696480.01 MWD+IFR 6563.89 25.31 349.78 6074.00 6005.00 2263.98 2241.31 -330.56 0.00 5933371.91 696474.46 WS2 rent 7S 1S 1S 7S 7S 1S 7S 7S 1S 7S 7S AS ~S QS 4S ~S Sperry-Sun BP Planning Report • • Company:. BP Amoco Date: 5/30/2008 Timer 12:21:43 Pager 5 Field: Prudhoe Bay Co-ordinate(NE)Reference: Well: 12-37 Plan, True North :Site: PB DS 12 Vertical ('I'VD) Reference: 41'GL+28.5=69.5 69 .0 Well: 12-37 Plan Section (VS) Reference: Well (O.OON,O.OOE,353.75Azi) Wellpath: 12-37P61 Plan Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ff deg/100ft ft ft 6600.00 25.31 349.78 6106.64 6037.64 2279.38 2256.51 -333.30 0.00 5933387.03 696471.33 MWD+IFR 6700.00 25.31 349.78 6197.04 6128.04 2322.03 2298.58 -340.89 0.00 5933428.89 696462.65 MWD+IFR 6800.00 25.31 349.78 6287.44 6218.44 2364.68 2340.65 -348.48 0.00 5933470.75 696453.96 MWD+IFR. 6857.03 25.31 349.78 6339.00 6270.00 2389.01 2364.65 -352.80 0.00 5933494.62 696449.01 WS1 6900.00 25.31 349.78 6377.85 6308.85 2407.33 2382.73 -356.06 0.00 5933512.61 696445.28 MWD+IFR 7000.00 25.31 349.78 6468.25 6399.25 2449.98 2424.80 -363.65 0.00 5933554.47 696436.60 MWD+IFR 7083.80 25.31 349.78 6544.00 6475.00 2485.72 2460.06 -370.01 0.00 5933589.54 696429.33 CM3 7100.00 25.31 349.78 6558.65 6489.65 2492.63 2466.87 -371.24 0.00 5933596.32 696427.92 MWD+IFR 7200.00 25.31 349.78 6649.05 6580.05 2535.28 2508.95 -378.82 0.00 5933638.18 696419.24 MWD+IFR 7300.00 25.31 349.78 6739.45 6670.45 2577.93 2551.02 -386.41 0.00 5933680.04 696410.56 MWD+IFR 7400.00 25.31 349.78 6829.85 6760.85 2620.58 2593.09 -394.00 0.00 5933721.90 696401.88 MWD+IFR. 7500.00 25.31 349.78 6920.25 6851.25 2663.23 2635.17 -401.59 0.00 5933763.76 696393.20 MWD+IFR 7600.00 25.31 349.78 7010.65 6941.65 2705.88 2677.24 -409.17 0.00 5933805.62 696384.51 MWD+IFR 7659.02 25.31 349.78 7064.00 6995.00 2731.05 2702.07 -413.65 0.00 5933830.32 696379.39 CM2 7700.00 25.31 349.78 7101.05 7032.05 2748.53 2719.31 -416.76 0.00 5933847.48 696375.83 MWD+IFR 7800.00 25.31 349.78 7191.45 7122.45 2791.18 2761.39 -424.35 0.00 5933889.34 696367.15 MWD+IFR 7900.00 25.31 349.78 7281.85 7212.85 2833.83 2803.46 -431.93 0.00 5933931.19 696358.47 MWD+IFR 8000.00 25.31 349.78 7372.25 7303.25 2876.48 2845.53 -439.52 0.00 5933973.05 696349.79 MWD+IFR 8100.00 25.31 349.78 7462.65 7393.65 2919.12 2887.61 -447.11 0.00 5934014.91 696341.11 MWD+IFR 8200.00 25.31 349.78 7553.05 7484.05 2961.77 2929.68 -454.69 0.00 5934056.77 696332.43 MWD+IFR 8300.00 25.31 349.78 7643.45 7574.45 3004.42 2971.75 -462.28 0.00 5934098.63 696323.75 MWD+IFR 8355.05 25.31 349.78 7693.22 7624.22 3027.90 2994.91 -466.46 0.00 5934121.67 696318.97 Start Dir 4° 1 8400.00 27.01 351.12 7733.56 7664.56 3047.68 3014.45 -469.74 4.00 5934141.12 696315.18 MWD+IFR 8500.00 30.82 353.62 7821.08 7752.08 3096.00 3062.37 -476.09 4.00 5934188.85 696307.58 MWD+IFR 8600.00 34.67 355.61 7905.18 7836.18 3150.08 3116.21 -481.12 4.00 5934242.54 696301.15 MWD+IFR 8694.34 38.33 357.17 7981.00 7912.00 3206.12 3172.21 -484.62 4.00 5934298.43 696296.19 CM1 8700.00 38.55 357.25 7985.43 7916.43 3209.63 3175.73 -484.79 4.00 5934301.94 696295.93 MWD+IFR 8800.00 42.45 358.63 8061.46 7992.46 3274.39 3240.62 -487.09 4.00 5934366.74 696291.94 MWD+IFR 8900.00 46.36 359.82 8132.88 8063.88 3344.03 3310.57 -488.00 4.00 5934436.64 696289.20 MWD+IFR 8916.21 47.00 0.00 8144.00 8075.00 3355.76 3322.37 -488.02 4.00 5934448.43 696288.87 End Dir 9000.00 47.00 0.00 8201.15 8132.15 3416.67 3383.65 -488.02 0.00 5934509.69 696287.27 MWD+IFR 9034.98 47.00 0.00 8225.00 8156.00 3442.10 3409.23 -488.02 0.00 5934535.26 696286.61 THRZ 9100.00 47.00 0.00 8269.34 8200.34 3489.37 3456.78 -488.02 0.00 5934582.79 696285.37 MWD+IFR 9200.00 47.00 0.00 8337.54 8268.54 3562.07 3529.92 -488.02 0.00 5934655.90 696283.46 MWD+IFR 9300.00 47.00 0.00 8405.74 8336.74 3634.77 3603.05 -488.02 0.00 5934729.01 696281.55 MWD+IFR 9310.64 47.00 0.00 8413.00 8344.00 3642.50 3610.83 -488.02 0.00 5934736.79 696281.35 BHRZ 9400.00 47.00 0.00 8473.94 8404.94 3707.47 3676.19 -488.02 0.00 5934802.11 696279.65 MWD+IFR 9436.74 47.00 0.00 8499.00 8430.00 3734.18 3703.06 -488.02 0.00 5934828.97 696278.94 TKNG 9482.19 47.00 0.00 8530.00 8461.00 3767.23 3736.30 -488.02 0.00 5934862.20 696278.08 TJB 9500.00 47.00 0.00 8542.14 8473.14 3780.17 3749.32 -488.02 0.00 5934875.22 696277.74 MWD+IFR 9592.16 47.00 0.00 8605.00 8536.00 3847.17 3816.73 -488.02 0.00 5934942.60 696275.98 TJA 9600.00 47.00 0.00 8610.34 8541.34 3852.87 3822.46 -488.02 0.00 5934948.33 696275.83 MWD+IFR 9700.00 47.00 0.00 8678.54 8609.54 3925.57 3895.59 -488.02 0.00 5935021.43 696273.92 MWD+IFR 9766.65 47.00 0.00 8724.00 8655.00 3974.03 3944.34 -488.02 0.00 5935070.16 696272.65 12-99 TSA 9773.98 47.00 0.00 8729.00 8660.00 3979.36 3949.70 -488.02 0.00 5935075.52 696272.51 7" 9800.00 47.00 0.00 8746.74 8677.74 3998.27 3968.73 -488.02 0.00 5935094.54 696272.02 MWD+IFR 9801.84 47.00 0.00 8748.00 8679.00 3999.61 3970.08 -488.02 0.00 5935095.89 696271.98 TSHU 9831.17 47.00 0.00 8768.00 8699.00 4020.93 3991.52 -488.02 0.00 5935117.33 696271.42 TSHB 9832.63 47.00 0.00 8769.00 8700.00 4022.00 3992.59 -488.02 0.00 5935118.40 696271.39 12-37 Faul 9851.70 47.00 0.00 8782.00 8713.00 4035.85 4006.54 -488.02 0.00 5935132.33 696271.03 TSHC 9900.00 47.00 0.00 8814.94 8745.94 4070.97 4041.86 -488.02 0.00 5935167.65 696270.11 MWD+IFR 9916.21 47.00 0.00 8826.00 8757.00 4082.76 4053.72 -488.02 0.00 5935179.50 696269.80 12-37 TSA 9955.80 47.00 0.00 8853.00 8784.00 4111.54 4082.67 -488.02 0.00 5935208.44 696269.04 45N lent S S S S S S S S S S S S S S S S S S S S S S S S 6 S S S S S IS IS ev Sperry-Sun BP Planning Report • • Company: BP Amoco Date: 5/30/2008 Time: ' 12:21:43 Page: 6 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL:12-37 Plan, True North Site: PB DS 12 Vertical (TVD) Reference: 41'GL+28.5=69.5 69 .0. Well: 12-37 Plan Section (VS) Reference: Well (O:OON,O .OOE,353.75Azi) Wellpath: 12-37P61 Plan Survey Calcula tion Method: Minimum Curvature Db: ` Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 9974.86 47. 00 0.00 8866. 00 8797. 00 4125.40 4096.61 -488.02 0.00 5935222. 38 696268.68 45P 10000.00 47. 00 0.00 8883. 14 8814. 14 4143. 67 4115.00 -488.02 0.00 5935240. 75 696268.20 MWD+IFR 10011.52 47. 00 0.00 8891. 00 8822. 00 4152. 05 4123.42 -488.02 0.00 5935249. 17 696267.98 44N 10015.92 47. 00 0.00 8894. 00 8825. 00 4155. 25 4126.64 -488.02 0.00 5935252. 39 696267.90 44P 10058.44 47. 00 0.00 8923. 00 8854. 00 4186. 16 4157.74 -488.02 0.00 5935283. 48 696267.09 43N 10062.84 47. 00 0.00 8926. 00 8857. 00 4189. 36 4160.96 -488.02 0.00 5935286. 69 696267.00 43P 10100.00 47. 00 0.00 8951. 34 8882. 34 4216. 37 4188.13 -488.02 0.00 5935313. 86 696266.29 MWD+IFR 10114.16 47. 00 0.00 8961. 00 8892. 00 4226. 67 4198.49 -488.02 0.00 5935324. 21 696266.02 42N 10120.02 47. 00 0.00 8965. 00 8896. 00 4230. 93 4202.78 -488.02 0.00 5935328. 50 696265.91 42P 10155.22 47 .00 0.00 8989. 00 8920. 00 4256. 51 4228.52 -488.02 0.00 5935354. 22 696265.24 41 N 10161.08 47 .00 0.00 8993. 00 8924. 00 4260. 78 4232.81 -488.02 0.00 5935358. 51 696265.13 41 P 10200.00 47 .00 0.00 9019. 54 8950. 54 4289. 07 4261.27 -488.02 0.00 5935386. 97 696264.39 MWD+IFR 10203.60 47 .00 0.00 9022. 00 8953. 00 4291. 69 4263.90 -488.02 0.00 5935389. 60 696264.32 31 N 10210.93 47 .00 0.00 9027. 00 8958. 00 4297. 02 4269.27 -488.02 0.00 5935394. 96 696264.18 31 P 10300.00 47 .00 0.00 9087. 74 9018. 74 4361. 77 4334.40 -488.02 0.00 5935460. 07 696262.48 MWD+IFR 10300.38 47 .00 0.00 9088. 00 9019. 00 4362. 05 4334.68 -488.02 0.00 5935460. 35 696262.47 27P 10400.00 47 .00 0.00 9155. 94 9086. 94 4434. 47 4407.54 -488.02 0.00 5935533. 18 696260.57 MWD+IFR 10403.02 47 .00 0.00 9158. 00 9089. 00 4436. 67 4409.75 -488.02 0.00 5935535. 38 696260.52 26N 10407.42 47 .00 0.00 9161. 00 9092. 00 4439. 86 4412.96 -488.02 0.00 5935538. 60 696260.43 26P 10425.01 47 .00 0.00 9173. 00 9104. 00 4452. 66 4425.83 -488.02 0.00 5935551. 46 696260.10 25N 10433.81 47 .00 0.00 9179. 00 9110. 00 4459. 05 4432.27 -488.02 0.00 5935557. 89 696259.93 25P 10454.34 47 .00 0.00 9193. 00 9124. 00 4473. 98 4447.28 -488.02 0.00 5935572. 90 696259.54 24N 10463.12 47 .00 0.00 9198. 99 9129. 99 4480. 36 4453.70 -488.02 0.00 5935579. 32 696259.37 4 1 /2" 10463.13 47 .00 0.00 9199. 00 9130. 00 4480. 37 4453.71 -488.02 0.00 5935579. 33 696259.37 MWD+IFR lent WELL DETAILS ANTI-COLLISION SLTTIt\~ COhll'ANY DETAILS SURVEY PR~GRAM- Name -S F./-W Northing F.asling Lalimde LongiNJc SIW nl'Amoco Depih Fm Dupth To Survey/Plan 7onl Inicrpolatiun Method:MU Interval: 25.00 1?-371'Inn -1481.41 -114?.76 SY31140.11 696861,74 7l1'I'_'57.891N 148°'_4'4.i f167W NIA OCpih Range From: 2N.00 To' 10463.13 Cal~vlatinn Mclhurl: Mhlinnlnl Cwvamre 28,W RIN)[XI PlanneJ: 12-17P61 Wp 50 V14 ('n-GYRO-SS Maximum Range: 1243.51 Reference: Plan: 12-37P61 Wp S.U Ercor Syslenr lSCWSq RIXUw m46111 Planned: e-37Pn1 WP59V14 MWD IFkMS Scan MethnJ: Tra, Cylinder Nol1h Fnur Swtacc: F.Iliiniwl Casing blaming McrhnJ: Rulca nail 16O ~OIOUT To MD I?-37P61 Plan 250 Rlp 150 - SOO Rcf. DaNnr: 41'GL-28.5-69.5 69.OUfi - 7SO V.Scctiun (Mpn (higin Starting Angle ~NI-S ~F./-W Frum TVU - IOOO - 1250 75175° U.W O.W 28.W 125 1 SOO - 1750 - 2000 - 2250 - 2SOO LEGEND 100 - 27SO IX UI M (I~?W ~I I% -- 3000 ( - - w 4 UL1%t01.1%A Plant. Mnjur Risk 3250 - I'~IN (I?-0YI. Malor Ri+k - ^.Id n'--IO1. hta~nr Risk ___- 3500 Ri,k iliA~I i ii~M" ;°k~ = i + ,, - 37SO ~ 1211 (Plan 12-IIAI. Mnjur Risk 75 __`_ QOOO ~ I?-I?(I_'-I?I, MJru Risk I ^_-0 l I?-I?A I. Mnjur Risk - 8000 M1I i~ - 8250 I_-Ii (I.-I IA MaIu K sk 12-0112-^nLM jar Rixk - 8500 1^_-I1 (L'-I3n Pl1I I. Mnjur Rlsk - c-u (u-Burn>4 Ma}or Risk _ o 87SO i? ?U (I? '_U I. hiajol'Risk ' ' ' 3 l Ri k SO ~ 1 _- _U (I _- UA 1, h ajur s 1^ -' I (I?' I6 hl irrc RSk 9000 _ _ _ 13 3] Pl (I 37 Pl NOF RRORS nt 9250 - an . a . . - ea7PDl clan - 9500 - r_a7rnl wp s o 9750 25 10000 0 2 75 100 125 150 160 Removed. ;an for Plans le @ No Errors TVU -NI~S -F./-W DLeg TFaa VSec Targcl 110 O.W ?8_110 Oll I1 W 25n.W W YU.W 5%'_.YI 31 349.78 1 %71.03 31 349.78 76Y3.]? 1X1 O.W 8144.W W 0.011 N826.W W O.W YIYY IX) O.fU U. W U.011 '_R5.'_I 7444.YI 13?'.17 4US1.7^_ 4451.71 O.W O.W OW O.W 0.00 O.W (IW O.W 1454 1.50 YU.W -I SS '_'_.18 ?.011 -110.15 2N I.IU -466.46 O.W O.W 30'_7911 -4R%-11' 4.W 19.87 3355.76 -48811 O.W 0 W 0U%2.76 1?-37 TSAD rev I -4%%.112 nW O.W 4480.37 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOft/in] Sperry-Sun Anticollision Report • • Company:.: BP Amoco Date: 5/30/2008 Time: 12:24:03 Paget 1 Field: ..Prudhoe Bay . Reference Site: PB DS 12 Co-ordinate(NE) Reference: WeIL• 12-37 Plan, True North Reference Well: 1 2-3T Plan Vertical (TVD) Reference: 41'GL+28.5=69:5 69A Reference Wellpath: 1 2-37PB1 Plan Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are TIretd~~m~ls in this tRtdlCipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 28.00 to 10463.13 ft Scan Method: Trav Cylinder North Maximum Radius: 1243.51 ft Erro r Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/1/2008 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft 28.00 800.00 Planned : 12-37Pb1 Wp 5.0 V14 CB-GYRO-SS Camera based gyro single shots 800.00 10463.13 Planned : 12-37Pb1 Wp 5.0 V14 MWD+IFR+MS MWD +IFR + M ulti Station Casing Points MD TVD Diameter '. Hole Size Name ft ft in in 3682.27 3469.00 9.625 12.250 9 5/8" 9773.98 8729.00 7.000 8.500 7" 10463.13 9199.00 4.500 6.125 4 1 /2" Summary <----=------ Offset. Wellpath --------> Reference Offset Ctr-Ctr No-Go Allowable :Site Well Wellpatk MD MD Distance Area Deviation .:.Warning ft ft ft ft ft PB DS 01 01-13 01-13 V2 Out of range PB DS 01 01-18 01-18 V9 8967.53 10675.00 126.30 0.00 126.30 Pass: Minor 1/200 PB DS 01 01-18 01-18A Plan VO Pla n: 1 Out of range PB DS 12 12-09 12-09 V1 644.43 650.00 180.01 18.98 161.03 Pass: Major Risk PB DS 12 12-10 12-10 V1 572.47 575.00 60.97 12.56 48.41 Pass: Major Risk PB DS 12 12-10A 12-10A V3 572.47 575.00 60.97 12.56 48.41 Pass: Major Risk PB DS 12 12-11 12-11 V1 1152.14 1150.00 50.55 20.70 29.85 Pass: Major Risk PB DS 12 12-11 Plan 12-11A V1 Plan: P 1153.62 1150.00 50.56 20.67 29.90 Pass: Major Risk PB DS 12 12-12 12-12 V3 1672.26 1650.00 50.40 37.00 13.40 Pass: Major Risk PB DS 12 12-12 12-12A V6 1672.41 1650.00 50.40 37.00 .13.40 Pass: Major Risk PB DS 12 12-13 12-13 V7 1970.12 1925.00 43.29 30.82 12.47 Pass: Major Risk PB DS 12 12-13 12-13A V6 1973.63 1925.00 43.50 30.86 12.64 Pass: Major Risk PB DS 12 12-13 12-13B V6 1966.95 1925.00 43.16 30.78 12.38 Pass: Major Risk PB DS 12 12-13 12-136PB1 V5 1966.95 1925.00 43.16 30.78 12.38 Pass: Major Risk PB DS 12 12-13 12-136P62 V10 1966.95 1925.00 43.16 30.78 12.38 Pass: Major Risk PB DS 12 12-20 12-20 V7 313.57 325.00 247.61 5.86 241.75 Pass: Major Risk PB DS 12 12-20 12-20A V17 321.19 325.00 247.74 6.11 241.63 Pass: Major Risk PB DS 12 12-21 12-21 V1 10202.92 10050.00 894.05 645.99 248.06 Pass: Major Risk PB DS 12 12-37 Plan 12-37 Plan VO Plan : 12 8850.00 8850.00 0.87 3.75 -2.88 FAIL: NOERRORS Site: PB DS 01 Well: 01-18 Rule Assigned: Minor 1/200 Wellpath: 01-18 V9 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8972.02 8182.07 9450.00 7332.52 21.78 276.19 18.22 18.22 4.500 1228.70 44.87 1183.84 Pass 8971.62 8181.79 9475.00 7350.08 21.77 277.35 18.34 18.34 4.500 1203.83 45.24 1158.59 Pass 8971.24 8181.53 9500.00 7367.65 21.77 278.52 18.46 18.46 4.500 1178.95 45.62 1133.34 Pass .8970.88 8181.29 9525.00 7385.25 21.77 279.68 18.58 18.58 4.500 1154.08 46.00 1108.08 Pass 8970.56 8181.06 9550.00 7402.86 21.77 280.84 18.71 18.71 4.500 1129.22 46.40 1082.82 Pass 8970.26 8180.86 9575.00 7420.50 21.77 281.99 18.85 18.85 4.500 1104.37 46.81 1057.55 Pass 8969.98 8180.67 9600.00 7438.15 21.77 283.15 18.99 18.99 4.500 1079.52 47.23 1032.29 Pass 8969.73 8180.50 9625.00 7455.82 21.77 284.31 19.14 19.14 4.500 1054.68 47.66 1007.02 Pass 8969.49 8180.34 9650.00 7473.50 21.77 285.47 19.30 19.30 4.500 1029.84 48.10 981.75 Pass 8969.26 8180.18 9675.00 7491.17 21.76 286.63 19.47 19.47 4.500 1005.02 48.54 956.48 Pass 8969.02 8180.01 9700.00 7508.85 21.76 287.79 19.64 19.64 4.500 980.20 48.98 931.22 Pass 8968.78 8179.85 9725.00 7526.53 21.76 288.95 19.82 19.82 4.500 955.40 49.43 905.97 Pass 8968.56 8179.70 9750.00 7544.22 21.76 290.11 20.02 20.02 4.500 930.60 49.88 880.72 Pass STATE OF ALASKA ~ EC's ALASKA~iIL AND GAS CONSERVATION COMMISSION ~ ~ ~,~ ~ ~~~g PERMIT TO DRILL • 20 AAC 25.005 .",,~ ~}{ ~ s, ~d~;~~. ~~~^r'iwl~~ic~r~ 1 a. Type of work ® Drill ^ Redri ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. S pecify ' ~ osed for: ^ Coal Methane ^ Gas Hydrates ^ Sh Gas 2. Operator Name: BP Exploration (Alaska) In 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. ell Name and Number: PBU 12-37 3. Address: P.O. Box 196612, Anchorage, ska 99519-6612 6. Proposed Depth: MD 13152 TVD 8634 .Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental ion): Surface: 4452' FNL 4342' FWL T10 1 SEC 18 E 7. Property Designation: ADL 028330, ADL 028329 Pool , , . , , 5 , lag P~anrred> Top of Productive Horizon: 3416' FNL, 4228' FWL, SEC. 18, T10N, R1 ,UM 8. Land Use Permit: 13. Approximate Spud Date: November 10, 2008 Total Depth: 3198' FNL, 642' FWL, SEC. 08, T10N, R15E, 9. Acres in Property: 2560 14. Distance to Nearest Property: 18530 4b. Location of Well (State Base Plane Coordinates). Surface: x-696863 y-5931140 Zone-A 4 10. KB Elevation Plan d (Height above GL): ~ feet 15. Distance to Nearest Well Within Pool: 910' 16. Deviated Wells: Kickoff Depth: 28 fee Maximum Hole An le: 105 d re 17. Maximum Anticipate Pressures in psig (see 20 AAC 25.035) Downhole: 3262 Surfacer 2462 1 in i io n T in D m f Cem n c.f. r adc Hole Casin Wei ht Grade Cou lin Le h MD TVD MD TVD includin sta a data 42" 2" 1 WL 1 urf 1 1 Ar i A 1 -1/4" 1" 4 L- T -M rf rf 6 34 7 1 De r 1 x l " 7" T -I I " -1 7" -8 T -M 4774' 4 774' 7 9' 1/ " 4-1 1 1 r- m 7' 7 1 1 2' 86 4 x 1 ' 19. PRESE NT WELL CONDITION SUMMARY (To be eted for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effectiv ep MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Len Size ment Vol: a MD TVD Conductor /Structural - Surface Intermediate Liner :e..~ .~ __ __.-.~. Perforation Depth MD (ft): Perforation Depth TVD (ft): 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 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fo, goi ,is true and corre Printed Name Gre b Si nature Contact T is Peltier 564-4511 Title Engineering Team Leader Pr red ey Name/Number. Phone S'. - ~! ~ / Date `' ? -+ Sondra wman 564-4750 ` Commission U e Onl Permit To Drill r• O~ /~~ API Number: 50 Od .~7339~'~0o Permit Approval See cover lette r r r it Conditions of Approval: If box is checked, well may not used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ es ~No Mud Log Req'd: ^ Yes o HZS Measures: ~es ^ No Directional Survey Req'd: Yes ^ No Other: APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate i ~ i V ~ ~ To: Alaska Oil & Gas Con rvation Commission From: Travis Peltier, ODE Date: September 2, 2008 Re: 12-37 Grassroots well Pe 't to Drill The 12-37 well is scheduled to be dril by Nabors Rig 7ES which is currently scheduled to move onto the location around Nov 10, 2008. 12- is a new, ultra-slim hole design well completing the Sag with an Ivishak pilot hole. The 12-1/4" hole 1 be drilled to the topmost, competent shale of the SV3 where the 9-5/8" surface casing will be run and c ented. An 8-1/2" hole will then be drilled to the top of the Sag River Formation, with 7" casing top set ith cement. The planned pilot hole then is drilled into the Ivishak Z2 to a TD of 10,463'MD. We wil lug back this pilot hole to the 7" shoe, and drill a Sag lateral to a TD of 13,152' MD. A solid 4-1/2" oduction liner will be run and cemented in place. The Ivishak reservoir (e.g. Z2) will be completed Ivishak reservoir be completed, the Sag target will turns out to be economically attractive. Should the as a future CTD candidate. Please note the following Well Summary as detailed next few pages: 12-37 Permit to Drill Application Page Planned Well Summar • Well 12-37 Well Grassroots T et Sag T e Producer O ective River API Number: TBD Current Status 12-37 will be a new well. Estimated Start Date: 10-Nov- 08 Time to Comple 30.6 Days Surface Northin Eastin Offsets TRS Location 5,931,140 696,863 4452' FNL / 4342' L 10N, 15E, 18 Northin Eastin TVDs Off is TRS Target s,932,173 696,723 -3,416 3416' FNL 4228' FWL 10N, 15E, 18 Locations 6,933,219 696,506 -5,676 364' FN / 4038' FWL 10N, 15E, 18 5,934,242 696,301 -7,836 36' FN / 3859' FWL 10N, 15E, 18 5,935,075 696,272 -s,6ss 0 3' F / 3851' FWL 10N, 15E, 18 5,935,280 696,248 -s,741 02 ' F L / 3833' FWL 10N, 15E, 18 5,935,555 696,200 -8,649 002 NL / 3792' FWL 10N, 15E, 18 5,936,636 697,132 -8,626 4244 NL / 4751' FWL 10N, 15E, 7 /\ Bottom Northin Eastin TVDss ffsets TRS Location 5,937,707 698,047 -8,565 31 ' FN 642' FWL 10N, 15E, 8 Planned KOP: Surface Ri Nabors 2ES BFE: 41' nned TD: 1~3,152'MD / TVDss l RTE: 168.5' LJIf@CIIOfIaI -Sperry 12-3 7_pb1_wp5 and 2-37_wp5 KOP~ Surface Maximum Hole Angle: ~25° in the 12- /4" surface section (C«3 1,915' MD to T ~47° in the 8- 2" intermediate section (C«~ 8,916' MD to D) ~47° in the 6 /8" production section to TD for the Ivishak lugback 105° in the -1/8" sa horizontal section C«3 10,048' MD. Close A roach Wells: 01-18 in th 8-1/2" section. 12-21 and 01-13 in the 6-1/8" s tion. Surve Pro ram: MWD Sta and + IFR /Cassandra / MS Nearest Pro ert Line: 18,530' t the PBU property line to the South Nearest Well within Pool: 01-30 is a closest well at 910' ctr-ctr distance. Contacts Drilling Engineer Geologist Pad Engineer Name Travis Peltier Daniel Schafer Trina Cooper Phone # E-mail 564-4511 travis.pe] 564-5098 daniel.sc 564-4212 Katrina.( 12-37 Permit to Drill Application Page 2 'Formation Markers 12$7 (Bad on SOR) Form ~on /Zone (TVDss) TVD Thick MD Thick An le NOTE: All formation tops are quired from 1000' above proposed KOP to TD for sid acks NOTE: All formation to s are re `fired from surface to TD for all new wells NOTE: All formation to s aze Based on -37 w 4 Formati SSTVD MD TVD Thick MD Thick An e Surface 69 0 2749 2885 0.0 SV4 -2680 2885 630 698 24.2 SV3 -3310 3583 200 221 24.4 SV2 -3510 3804 405 448 24.2 SV1 -391 4252 695 768 24.4 UG4 -46 5020 90 100 24.4 UG3 -4 0 5120 730 807 24.2 UGl - 30 5927 575 636 24.2 WS2 005 6563 265 294 24.2 WS1 6270 6857 205. 226 24.4 CM3 -6475 7083 520 576 24.4 CM2 -6995 7659 917 1035 24.2 CM 1 -7912 8694 244 341 39.1 THRZ -8156 9035 188 275 47.0 BHRZ -8344 9310 86 126 47.0 TKNG -8430 9436 31 46 47.0 TJB -8461 9482 75 110 47.0 TJA -8536 9592 119 174 47.2 TSGR -8655 9766 5 8 47.0 7" Lnr Set Point -8660 9774 19 27 47.0 TSHU -8679 9801 20 30 47.0 TSHB 8699 9831 14 Z0 47.0 TSHC - 713 9851 44 65 47.0 TSAD (46P) -8 7 9916 27 39 46.9 45N -87 9955 13 20 47.0 45P -8797 9975 25 36 47.0 44N -8822 10011 3 4 47.0 44P -8825 10015 29 43 47.0 43N -8854 10058 3 4 ~ 47.2 43P -8857 10062 35 52 47.2 42N -8892 0114 4 6 47.2 42P -8896 1 120 24 35 47.2 41 N -8920 10 5 4 6 47.0 41P -8924 101 29 42 47.0 37N -8953 10203 5 8 47.0 31P -8958 10211 61 89 47.0 27P -9019 10300 70 103 47.0 26N -9089 10403 3 4 47.0 26P -9092 10407 12 18 47.0 25N -9104 10425 6 9 47.0 25P -9110 10434 20 47.0 24N -9124 10454 6 9 48.0 TD in 24N -9130 10463 48.0 12-37 Permit to Drill Application Page 3 Casina/Tubina Protra~ .~ Hole Csg / W ` Grade Conn Burst Collapse Le th Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 42" 20" 215.5 -53 WLD 108 GL 108/108 insulated 12-'/4" 9-5/8" 40# L 0 BTC-M 5,750 3,090 3,683' GL 3,683' / 3,469 8-'/2" 7" 26# L-8 TC-II 7,240 5,410 5,000' GL 5,000' / 4,660 8-'/z" 7" 26# L-80 BTC-M 7 240 410 5 4 774' 5,000' / 9,774' / , , , 4,660 8,729 6-1 /8" 4 ~/z" 12.6# 13Cr- AM Top 160 10, 10,5 3,579' 9,573' / ' 13,152' / 80 8,592 8,634 Tubing 4'h" 12.6# 13Cr- 80 V Top 10,160 10, 0 9,573' GL 9,573' / 8,592 Mud Proaram 12-'/a" Surface Hole Mud Pro erties ud -Freshwater Mud Interval Densit V Y PH Funn Vis FL 0-1950' (~BPRF) 8.8-9.2 30- 50 - 70 9.0 - 9.5 400-600 NC - 8 (Initial) 300+ Final 1950'-3682' (SV3) 9.2-9.5 30-55 4 - 60 9.0 - 9.5 250 (Initial) < 6.0 225 Final d 8-1/2" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 3,682'-9,035' THRZ 8.8-9.4 12-18 18-24 9-10 <6 < 15 9,035'-9,774' TSAG 11.1 12-22 8-28 9-10 HTHP < 10 < 18 6-'/e" Production Hole Mud Pro erties FloPro-SF Interval Densit PV Y PH API Filtrate MBT 9,774'-13,152' Final Well TD 8.4-8.6 6-12 22-2 9.0-9.5 6-8 <3 ~ ~ Lo in Pro ram 12-~/a" Hole Section: Surface Gyro until MWD s eys are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None a 8-1/2" Hole Section: MWD /LWD: DIR/GR/RES/PWD re time O en Hole: None Cased Hole: None required ~ s 6'/8" Hole Section: Sample as re uire well site Geologist MWD /LWD: DIR/GR/RES from op Sa to TD, NEU/DEN will be include or the plugback interval. O en Hole: None Cased Hole: None 12-37 Permit to Drill Application Page 4 Cement Proararn _ / Casin Size: 9-5/8" #, L-80 Surface Casin Basis: Lead: O n at surfac Hole (OH) volume + 250% excess in permafr t and 40% below permafrost. TOC Tail: OH v me + 40% excess + 80' shoe tract. TOC ~5 0' above Casin shoe. Total Cement Volume• Spacer -bbls of MudPush weighted to 10.0 ppg Lead 46 bbls 701 sks , 10.7 Dee Crete- .69 cuft/sk Tail 45. bls, 253 cuft, 218 sks 15.8 Ib/ al C ss G + adds - 1.16 cuft/sk Tem BHS - 80 °F, BHCT = 72 °F Casin Size: 7" 26#, L-80 Interm late Casin Basis: Lead: OH volume + 4 ° excess from to of tail to 00' below surface shoe. Tail: OH vo lume + 40°° xcess + 80' shoe tract. it TOC 1,000' above 7" shoe. Total Cement Volume• Spacer 25 bbl of M PUSH Spacer weight to 11.5-Ib/gal Lead 161 bbl 369 s 12.0 LiteCR E - 2.45 cuft/sk Tail 40.5 bbls, 227 ft, 196 sks 15.8 I / al Class G + adds - 1.16 cuft/sk Tem BHST = 200°F, CT = 140 °F Casin Size 4.5" 12.6#, 13CR-80 Productio Liner Basis: Lead: None Tail: 3378' of open hole with 40% a ess, 'shoe tract, 150' 4-'/z" x 6-1/8" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 9,424' MD (200' above Li p) Total Cement Volume• Spacer 20 bbls of Mudpush II Weig ed to 12 ppg Lead None Tail 87.9 bbls, 495 cuft, 423 s 1 Ib/ al Class G + adds -1.17 cuft/sk Tem BHST = 203°F, BHCT = 7 °F Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order o move onto the ell. At surface, 12-12A to the north and 12-11 to the south are nearest wells. Each are 60' om the planned s d location. Close Approach Shut-in Wells: Three wells will be shut-in in order to drill 12-37. 1-18 for the intermediate ole, with the closest approach of 126' at 8,968' MD. 01-13 and 12-21 in the production le with the approaches bei 763' and 860' at 11,323' and 9,882' MD, respectively. Hydrogen Sulfide DS 12 is designated as an H2S site. ecent H2S data from the pad i as follows: Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Faci~ Other Relevant H2S Data 12-37 Permit to Drill Application 12-11 NA 12-12A 20 m /2008 1-30 NA 1-10 NA 12-03 300 10/7/ 3 DS 12 is a H2S site ge 5 (H2S alarms from rigs, et~ Faults The 12-37 wellpath~not expected to intersect any mapped faults. Well Control Well control equipment nsisting of 5,000 psi working pressure pipe annular preventer will be i talled and are capable of handling the maxi Based upon calculations belo BOP equipment will be tested to 3,500 ps; BOP regular test frequency for Diverter, BOPE and drilling fluid Intermediate Interval will be 14 days during drilling schematics on file with the (2), blind/shear rams, and potential surface pressures. Maximum antici ated BHP 3262 i C~ 8800' TVDss 7.2 W) Maximum surface ressure 2382 .10 si/ft as radient to urface Kick tolerance 83 bbls er 11.7 ppg FIT assumi g 9.0 ppg reservoir, 4" drillpipe, and 11.1 mud Planned BOP test pressure Rams test 3,500 psi/250 psi. Annular test 2,500 si/250 s 9-5/8" Casin Test 3500 si surfa a ressure Inte rit Test - 8-1/2" hole 11.7 FIT of r drillin 20' f m middle of window Production Interval \ / Maximum antici ated BHP 3262 si C«~ 8800' T ss 7 EMW Maximum surface ressure 2462 si .10 si/ft a ra ient to surface Kick tolerance Infinite with a 8.8 F Planned BOP test pressure Rams test to 3,500 psi/2 psi. Annular test to 2,500 si si 9-5/8" Casin "Liner Test 3500 si surface ress e Inte rit Test - 6-1/8" hole 8.8 FIT after drillin 20' o new hole Planned com letion fluids 8.5 Seawater / 7. Di el • To avoid the risk of plugging the flow line with large r cks and wood en untered while drilling surface ~ hole, it is requested to drill without a flow paddle for a first portion of th surface hole. While the flow paddle is removed from the flow line, PVT alarms ill be used and the pit vels accurately monitored for any pit gain. Also, a visual check will be made dur g connections by looki down the riser to ensure the well is not flowing. After returned debris that coul plug the flow line diminis s the flow paddle will be reinstalled. • No annular injection in this well. • Cuttings Handling: Cuttings generate from drilling operations will be inject at DS-04. Any metal cuttings will b sent to the North Slope Borough. • Fluid Handling: Haul all drilling and mpletion fluids and other Class II injection. Haul all Class I waste to Pad for disposal. ed to grind and to DS-04 for 12-37 Permit to Drill Application ~ Page IIin~Hazards and Conting~fici POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Sag in this fau estimated based on Prudhoe production II. Lost Circulation/Breathii~ A. The 12-37 is not expecte B. There have been no sign usually are less than 100 k is expected to be under-pressured at 7.2 ppg 't well pressures. 3500 psi test pressure is in a casing tests. intersect any mapped faults. ~t lost circulation events in the area. i,;in total volume, with 01-30 being the This pressure is ice with the RP for > events that have occurred volume lost of 100 barrels. III. Kick Tolerance/Integrity Test g A. The Kick Tolerance for both the termediate and production sectio s is 83.7 barrels and infinite, respectively, with planned mud w ~ hts. The FIT will prove up ad uate formation strength for expected ECD's. B. Integrity Testing Test Point Test Depth Test t e EMW (Ib/gal) 9 5/s" shoe 20-ft minim from the 9- g" shoe FIT 11.7 minimum 7" shoe 20-ft minim from the "shoe FIT 8.8 minimum IV. Stuck Pipe A. Significant directional work will be required in th sticking tendency will be of concern. Watch for to avoid stuck pipe. tion hole section. Hole cleaning and differential tight hole and short trip /back ream as required VI. Hydrogen Sulfide A. H-PAD is designated as an H2S site; H2S level f po ntially lethal concentrations have been recorded on this pad. The maximum recorded on this pa is 300 m, both at 12-03 and 12-22 in 2003 and 2005, respectively. VII. Faults A. Little faulting is expected along the planned ajectory. See S tion II on lost circulation for more details. VIII. Anti-Collision Issues B. Due to close approach concerns, three w Its will be shut-in in orde to drill 12-37. 01-18 for the intermediate hole, with the closest appr ch of 126' at 8,968' MD. -13 and 12-21 in the production hole with the approaches being 763' a 860' at 11,323' and 9,882' ,respectively. CONSULT THE DS-12 DAT HEET AND THE WELL PLAN~OR ADDITIONAL INFORMATION 12-37 Permit to Drill Applicatior~ ~ Page 7 Operations Summary / 12-37 w _be a new well. Pre-Ri O era ns: 1. Install 20" con ctor casing. 2. Weld an FMC la ing ring on the conductor. 3. If necessary, leve a pad and prepare location for rig move. Rig Operations: 1. MI/RU. 2. Nipple up the diverter sp I and riser. P/U sufficient length of 4" rill pipe and stand back in the derrick. 3. M/U a 12-~/a" drilling assembl with Dir/GR. Spud and directionally rill surface hole to the base of the permafrost. Gyro data will be quired until clean surveys can be ken. Circulate and condition hole. Short trip to the top of the heavy eight drillpipe and/or pull out of ole for a new bit if necessary. 4. RIH and drill the remainder of the urface hole to the planned s rface hole TD in a shale member of the SV3 sand at -3682' MD. POO nd UD BHA. 5. Run, and cement the 9 5/8", 40# c ing back to surface. TAM port collar may be run as a contingency if hole conditions indicate .problematic primary cement job. With plug on cement job bumped, test the 9-5/a" casing to 3500 i for 30 minutes d record the test. (NOTE: Efforts to ensure the final TOC is within 3' of surfac ill be required.) 6. N/D the riser spool and N/U the FMC casin ead and tubs spool. 7. N/U the BOPS and test to 3,500 psi. 8. MU 6-3/a" MWD/LWD drilling assembly and R picking- 4" drill pipe as required to drill the 8-3/4" hole. 9. Drill out cement, float equipment, and the shoe. LSND drilling fluid. Drill approximately 20' new forrr 10. Drill ahead, according to directional proposal, to ~1( 11. Increase mud weight to 10.8 ppg per the Kingak pol 12. Drill according to directional plan to intermediate h the top of the Sag. Circulate bottoms up as n shale/siltstone cap. 13. Condition hole as necessary to run the 7" casing 14. R/U, run, and cement the 7", 26#, L-80 inter c bumping the plug on the cement job, pressure st the test. (NOTE: To eliminate space-out prob ms Sag, the casing will be hung on emergency. lips. surface casing shoe.) ice the well as required with new ~9.5 ppg and perform the planed LOT. we the HRZ. at 9,774' MD, approximately 5' and below l for sample collection to properly identify 1 POOH. sate casin TC-II & BTC-M connections). After the 7" casin to 3,500 psi for 30 minutes. Record and to insure a casing shoe is into the top of the Also, the pla ed TOC will be 800' below the 15. After allowing tail slurry to develop ~50 psi mpressive strength split a stack and install the casing slips and pack-off and cut of the excess ca ng per FMC representative. 16. NU the BOP stack and test the "breaks" t 500 psi. 17. Freeze-protect the 9-s/8" x 7" annulus, on the tail cement has reached 50 si compressive strength. Confirm that the OA is open. Ensure th the mud/diesel/brine in the OA is o rbalanced to formation at the 9-5/a" shoe (~8.5 ppg). 18. M/U a 6-%8" MWD/LWD drilling asse ly. P/U additional 4" drill pipe as requir to TD the well and RIH to top of the float collar and re-te the casing to 3500 psi f/10 minutes. 19. Displace the well to 8.5 ppg Flo-Pro fluid. 20. Drill out shoe and 20' of new for tion and perform the planned FIT. Drill ahea per directional proposal and rig site geologist, to II TD at approximately 10,463' MD. Option B: IF IVISHAK IS OIL SATU ATED 21. Condition the hole as required ' preparation of running and cementing the 4-'/2" products liner. If necessary, spot liner running p' on bottom. POOH, VD excess 4" drill pipe, and UD BHA. 12-37 Permit to Drill Applicat~n Page 8 22. R/U and run 4'/2", 12.b'1~, 13Cr-80, VamTOP liner. CBU at 7" shoed TD as n essary. Cement the liner per owell program. Release from the liner and set the packer. Circulat excess cement to surface. 23. Displace the Ito seawater above the liner top. POOH and inspect and VD lin running tools. 24. After cement re hes a minimum 1000 psi compressive strength, R/U and pre ure test the casing x liner string to 3,5 psi for 30 minutes and record the test. Option A: IF IVISHA WATER SATURATED 21. POOH, VD BHA. P cement plug BHA. 22. RIH and lay in cemen lug. Circulate out excess cement at 7" shoe. POOH nd LD cementing BHA. 23. RIH with Sag sidetrac HA. Kick-off into Sag. 24. POH when directional rk is complete. LD BHA. 25. PU horizontal BHA, RIH d drill to TD at 13,182' MD. 26. Condition the hole as req 'red in preparation of running and cementing he 4-~/z" production liner. If necessary, spot liner runni ,pill on bottom. POOH, VD excess 4" drill e, and VD BHA. 27. R/U and run the 4'/z", 12.6#, 13Cr-80, VamTop liner. CBU at 7" shoe d TD as necessary. Cement the liner per Dowell program. elease from the liner and set the pac r. Circulate excess cement to surface. 28. Displace the well to seawater a ve the liner top. POOH and inspec nd UD liner running tools. 29. After cement reaches a minimu 1000 psi compressive strength, U and pressure test the casing x liner string to 3,500psi for 30 minu sand record the test. Both Options 30. R/U and perforate well on drillpipe. 31. R/U and run a 4-~/2", 12.6#, 13Cr-80, Top completion w/ G M's. Space and land the tubing with the tubing tail inserted into the liner tie b k sleeve. RILDS. 32. Reverse circulate filtered seawater and c osion inhibitor into a tubing x casing annulus. 33. Drop ball/rod and set liner top hanger/pack 34. Individually test the tubing and annulus to 3, 0 psi for 30 mi tes and record each test. 35. Shear DCR valve. 36. Install TWC and test. 37. N/D the BOPE. 38. N/U the adapter flange and tree. Test tree and a 39. RU DSM. PuIITWC. 40. R/U circulating lines and test. Freeze-protect th diesel to U-tube to equilibrium. 41. Install a BPV and VR plugs in the annulus valves. 42. Secure, rig down and move off. ,000 psi with diesel. and annulus to 2,000' TVD and allow the Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC pl 2. Install gas lift valves. 3. Install the well house, instrumentation, and flow nipple below the production packer. Estimated Pre-rig Start Date: 11/15 Estimated Spud Date: 12/01 12-37 Permit to Drill Application / ~ Page 9 KB. ELEV ~= 59 BF. ELEV = 30.5 KOP = . ._.._.. Max Angle = Datum ND = Datum TVD = 8800 Propo d Com pletion 12-37 Proposed TOC 4482' 20", 215.5, A-53, HES 4-1/2'X' Lan ;onductor ID = 3.813" LIFT MANDRELS (4-117' x 1" KBMGI Minimum ID = 3.725" ~ 9,574' 4-1 XN NIPPLE 4-1/2", 12.6#/ft, 13 Chrome, 9,824' VamTop, ID = 3.958" ST MD D DEV TYPE VLV WTCH PORT OIATE 4 DCK 2 S/O 3 DMY DMY 2 DMY DMY 1 DMY DMY ~4-112" X NIPPLE; I.D. 3.813" KER PKR 7" X 4-1/2' S-3, ID = 3.88", xx' i 4-1 /2" X NIPPLE; ID = 3.813" 5 4-112" XN NIPPLE; ID = 3.725' x 4-1 /2° Baker Flex-Loc Liner Hanger P Liner Top Pkr w/ 10' TBS (ID = 5.25" ~g (f/5 0' to Surfl, ID = 6.276" 1 ~ ` ~ ' e! PERFORATION SUMMARY (TB[3) REF LOG: (?BD} ANGLEATTOPPERF: TBD a~ ;Bi7' MD Note: Refer to ProduStion DB for historiSal perf data 13,002' 4-1/2" PBTD 4'to DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT OSf30/08 TMP INITWL WELL: DS 12-37 No: A No: BP 6cplo ion (Alaska) TREE = CNV 41 /16 SM WELLHEAD = FMC Gen 5 CSG EAD = 11" 5M WI 7" MANDREL HANGER & PACKOFF SPOOL= 11"X11"5M G HANGER = 11" X 41/7' ADP FLANGE= 11"X41/15' COMPANY DETAILS BP Amocu IJ)) Iculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical i Casing CASING DETAILS No. TVD MD Namc Sizc 1 3469.00 3682.27 9 5/8" 9.625 2 8729.00 9773.98 7" 7.000 3 9199.00 10463.13 41/2" 4.500 HALLfBURTON Sperry Orflli~g 8ervicea, FORMATION TOP DETAILS , No. TVDPath MDPa[h Formations 1 2784.00 2924.53 SV3 2 3579.00 3803.95 SV2 3 84.00 4251.96 SVl _ 4 46 4970.98 UG4 5 4839.00 75 UG3 6 5539.00 5972. GI 7 6074.00 6563.89 8 6339.00 6857.03 W S I 9 6544.00 7083.80 CM3 10 7064.00 7659.02 CM2 ll 7981.00 8694.34 CMI 12 8225.00 9034.98 THRZ I3 8413.00 9310.64 BHRZ I4 8499.00 9436.74 TKNG I S 8530.00 9482.19 TJB _ - - 16 8605.00 9592.16 TJA 17 8724.00 9766.65 TSGR 18 8748.00 9801.84 TSHU _- 19 8768.00 9831.17 TSHB -- 20 8782.00 9851.70 TSHC 21 8826.00 9916? 1 TSAD (46P) 22 8853.00 9955.80 45N 23 8866.00 9974.86 45P ~ 24 8891.00 10011.52 44N 25 8894.00 10015.92 44P 26 8923.00 10058.44 43N 27 8926.00 10062.84 43P 28 8961.00 10114.16 42N 29 8965.00 10120.02 42P 30 8989.00 10155.22 41N ~~ , 31 8993.00 I O 161.08 41 P 32 9022.00 10203.60 31 N 33 9027.00 10210.93 3I P 34 9088.00 10300.38 27P 35 9158.00 10403.02 26N 36 9161.00 10407.42 26P I 37 9173.00 10425.01 25N ' 38 9179.00 10433.81 25P 39 9193.00 10454.34 24N REFERENCE INFORMATION Co-ordinate (N/E) Rekrcncc: Well Centre: 12-37 Plan, Tmc North Vertical (TVD) Reference: 41'GU 28.5=69.5 69.00 Section (VS)Reference: Slot- (QOON,ODOE) Measured Depth Rc(ercnce: 41'GL i 28.5=69.5 69.00 Calculation Method: Minimum Curvature _i I~[ ~!I.~~~1 Il 28.00 zso.oo 582.91 1871.03 7693.22 8144.00 8826.00 9199.00 0.00 ~.~~ 0.00 285.21 2994.91 3322.37 4053.72 4453.71 0.00 0.00 0.00 0.00 0.00 0.00 14.54 LSO 90.00 22.18 2.00 -11QI5 -466.46 0.00 0.00 -488.02 4.00 19.87 -488.02 0.00 O.OO -488.02 0.00 0.00 0.00 o.oo - l .58 281.10 3027.90 3355.76 4082.76 12-37 TSAD rev 1 4480.37 ~kl- SURVEY PROGRAM Fm DcplhTo Survey/Plan Tool Plan: 12-37Pb1 Wp S.U (12-37 Plan/12-37PB1 Plan) 800.00 Planned: 12-37Pb1 Wp 5.0 V I4 CB-GYRO-SS Crcaled By: Sperry Drilling Date: 5/30/2008 i 10463.13 Planned: l2-37Pbl Wp 5.0 V14 MWDtIFRi MS WELL DETAILS Name +N/-S i E/-W Northing Easting Latitude Longitude Slot 12-37 Plan -1481.41 -1142.76 5931140.11 696863.34 70°12'57.891N 148°24'43.067W N/A Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 28.00 0.00 OAO 2 250.00 0.00 0.00 3 583.33 5.00 90A0 4 1914.62 25.31 349.78 5 8355.05 25.31 349.78 6 8916.21 47A0 O.OU 7 9916.21 47.00 0.(10 8 10463.13 47.00 QOO TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape 12-99 TSAG 8724A0 3944.34 -488.02 5935070.16 696272.66 Circle (Radius: 200) 12-37 Fault I 8769.00 2585.38 -3469.29 5933634.00 693328.00 Polygon 12-37 Fault2 8769.00 3629.09 -5167.75 5934633.00 691603.00 Polygon 12-37 TSA(1tCV I 8826.00 4053.72 -488.02 5935179.50 696269.80 Circle (Radius: 200) 2000 4000 ion at 353.75° [2000fUin] 10000 1 COMPANY DETAILS BP Amoco Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trnv Cylinder North Error Sur(acc: Elliptical + Casing Warning Method: Rules Based HALLIBURTON Sperry Grilling Services REFERENCE INFORMATION SURVEY PROGRAM ordinate (N/E) Reference: Well Centre: 12-37 Plan, True North Depth Fm Depth To Survey/Plan Tool Plan: 12-37PbI Wp 5.0 (12-37 Plan/12-37P81 Plan) Vertical (TVD) Reference: 41'GL i 28-5=69.5 69.00 Section (VS) Reference: Slot - (O.OON,O.OOE) 28.00 800.00 Planned: 12-37PbI Wp 5.0 V14 CB-GYRO-SS Created By: Sperry Drilling Date: 5/30/2 W8 leasured Depth Reference: 41'GLi28.5=69.5 69.00 SW.00 10463.13 Planned: l2-37PbI W 5.0 V14 MWDi1FR+MS Calculation Method: Minimum Curvature WELL DETAILS Name i N/-S ~ E/- W Northing Easting Latitude Longitude Slot 12-37 Plan - -1481.41 -1142. 76 5931140.11 696863.34 70°12'S7. 891N 148°24'43.067W N/A ' ~ ~ ~~ I ~ - - ~~ ~ I ~ ~_ _ -- - I TARGET DETAILS - ` I I ~ ' I i Name TVD +N/-S +E/-W Northing Easing Shape I 12-99 TSAG 8724.00 3944.34 -488.02 5935070.16 696272.66 Circle (Radius: 200) _ Total De h :104 { - -- 63.13' MD, 9199' D 12-37 Fault I 8769.00 2585.38 -3469.29 5933634.00 693328.00 ygon 1 ._ -~ - ~ ~ - ]2-37PbI Wp 5.( \ 12-37 Fault 2 8769A0 3629.09 -5167.75 5934633.00 6916(13 olygon I - A 12-37 TSAD rev 1 8826.00 4053.72 -488.02 5935179.50 69 Circle (Radius: 200) 391 FORMATION TOP DETAILS I. _ No. TVDPath MDPath Formation ' I 2784.00 2924.53 SV3 2 3579.00 3803.95 SV2 ~ - 3 3984.00 4251.96 SVI ~ - 4 4634.00 4970.98 UG4 - 5 4839.00 5197.75 UG3 - 6 5539.00 5972.08 UG1 '. 7 6074.00 6563.89 WS2 8 6339.00 6857.03 WSI 9 6544.00 7083.80 CM3 10 7064.00 7659.02 CM2 11 7981.00 8694.34 CMl 12 8225.00 9034.98 THRZ 13 8413.00 9310.64 BHRZ - - - - 14 8499.00 9436.74 TKNG IS 8530.00 9482.19 TJB 16 8605.00 9592.16 ~ - - - 17 8724.00 9766.6 SGR I. I 18 8748.00 9 4 TSHU i - 19 8768.0 31.17 TSHB i i ~~. ~ 20 87 9851.70 TSHC 21 _6.00 9916.21 TSAD (46P) - 8853A0 9955.80 45N - -- - 23 8866.00 9974.86 45P 24 8891.0(1 1001 L52 44N 25 8894A0 10015.92 44P I_ 26 8923.00 10058.44 43N _ 27 8926.0(1 10062.84 43P 28 896L00 10114.16 42N 29 8965AO 10120.02 42P - 30 8989A0 10155.22 41N 31 8993.00 10161.08 41P ~. 32 9022.W 10203.6(1 31N 33 902200 10210.93 31P 34 9088.0(] 10300.38 27P 35 9158.00 10403.02 26N 36 916L00 10407.42 26P 37 9173.00 10425.01 25N -3915 38 9179.00 10433.81 25P 39 9193.(1]454.34 24N r1 t'11III I i, 30 End Di :1914.62' MD, 1871.03' VD ._ I -- I _ ~ I L ~ - - i I Start it 2°/100' ; 583.33' MD; 5 ~.91'TVD ~ - - ~ III - - I - i - _ 2 - rt Dir L5°/100' : 250' M 250'TVD ~ ~' - ~ i ~ i ' ~ - ~ CASING DETAILS ~ No. TVD MD Namc Sizc 4 (_ ; 5 0 i 1 3469.00 3682.27 9 5/8" 9.625 -1 - ~ I I ~ 2 8729.00 9773.98 7" 7.(100 - ~s ;_ -r - - ~ 3 9199.00 10463.13 4 1/2" 4.500 i _. -,,. _ SECTION DETAILS *'3 ! Sec MD _ ~ _ ~ ~ Inc Azi TVD tN/-S iE/-W DLeg TFace VSec Targe t ~~ I ~ ~ - - ~ I - - 28.00 0.00 0.00 28.00 0.00 0.00 0. W 0.00 0.00 2 250.00 0.00 OAO 250.00 0.00 0.00 0.00 0.00 0.00 3 583.33 5.00 90.W 582.91 O.W 14.54 1.50 90.00 -1.58 4 1914.62 25.31 349.78 1871.03 285.21 22.18 2.00 -110.15 281.10 -1957 -979 5 8355.05 25.31 349.78 7G93.22 2994.91 -466.46 O.OU 0.00 3027.90 6 8916.21 47.00 0.(10 8144.00 3322.37 -488.02 4-00 19.87 3355.76 7 9916.21 47.00 0.00 SH26.00 4053.72 -488.112 U.00 0.00 4082.76 12-37 TSAD rev I ~Wcs[(-)/East(+ 8 10463.13 47.00 0.00 9194110 4453.71 -488.02 0.00 0.00 44$~ '~ Sperry-Sun BP Planning Report • Company: BP Amoco Date: 5/30/2008 Time: 12:21:43 Page:. 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 12-37 PIa rue North Site: PB DS 12 Vertical (TVD) Reference: 41'GL+28.5=69 69.0 Well: 12-37 Plan Section (VS) Reference: Well (O.OON,O E,353.75Azi) Wellnath: 12-37PB1 Plan Survev Calculation Method: Minimum Cu tune Db: Oracle Plan: 12-37Pb1 Wp 5.0 Date Composed: 5/1/2008 Version: 14 Principal: Yes Tied-to: From Well .Point Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate Sys 1927 Map Zone: Alaska one 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well ntre Sys Datum: Mean Sea Level Geomagnetic Model: bgg 007 Site: PB DS t2 TR-10-15 UNITED STATES :North Slope Site Position: Northing: 5932650.90 ft Latitude: 70 12.462 N From: Map Easting: 697966.79 ft Longitude: 148 4 9.888 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 12-37 Plan Slot Name: Well Position: +N/-S -1481.41 ft Northing: 5931 0.11 ft Latitude: 0 12 57.891 N +E/-W -1142.76 ft Easting : 6968 .34 ft Longitude: 48 24 43.067 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 3682.27 3469.00 9.625 12.250 9 5/8" 9773.98 8729.00 7.000 8.500 7" . 10463.13 9199.00 4.500 6.125 41/2" Formations MD TVD Formations Lith gy Dip Angle Dip Direction ft ft deg deg 2924.53 2784.00 SV3 0.00 0.00 3803.95 3579.00 SV2 0.00 0.00 4251.96 3984.00 SV1 0.00 0.00 4970.98 4634.00 UG4 0.00 0.00 5197.75 4839.00 UG3 0.00 0.00 5972.08 5539.00 UG1 0.00 0.00 6563.89 6074.00 WS2 0.00 0.00 6857.03 6339.00 WS1 ~ 0.00 0.00 7083.80 6544.00 CM3 ~~ 0.00 0.00 7659.02 7064.00 CM2 ~. 0.00 0.00 8694 34 7981 00 CM1 ~ 0.00 0.00 . 9034.98 . 8225.00 THRZ \ 0.00 0.00 9310.64 8413.00 BHRZ 0.00 0.00 9436.74 8499.00 TKNG ~ 0.00 0.00 9482.19 8530.00 TJB ~ 0.00 0.00 9592.16 8605.00 TJA ~ 0.00 0.00 9766.65 8724.00 TSGR ~ 0.00 0.00 9801.84 8748.00 TSHU 0.00 0.00 9831.17 8768.00 TSHB 0.00 0.00 9851.70 8782.00 TSHC 0.00 0.00 9916.21 8826.00 TSAD (46P) 0.00 0.00 9955.80 8853.00 45N 0.00 0.00 9974.86 8866.00 45P 0.00 0.00 10011.52 8891.00 44N 0.00 0.00 10015.92 8894.00 44P 0.00 0.00 10058.44 8923.00 43N 0.00 0.00 10062.84 8926.00 43P 0.00 0.00 • 10114.16 10120.02 8961.00 8965.00. 42N 42P 0.00 0.00 0.00 0.00 10155.22 8989.00 41 N 0.00 0.00 10161.08 8993.00 41 P 0.00 0.00 ~ Sperry-Sun ~ BP Planning Report • Company: BP Amoco Date: 5/30/2008 Time: 12:21:43 e: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 12-37 Plan, True Nort Site: PB DS 12 Vertical (TVD) Reference: 41'GL+28.5=69.589.0 Well: 12-37 Plan Section (VS) Reference: Well (O. OON ,O.OOE,353.7 i) Wellpath: 12-37PBT Plan Survey Calculation Method:. M inimum Curvature Db: Oracle Formations MD TVD Formations Lithology Dip a Dip Direction ft ft . deg 10203.60 9022.00 31 N .00 0.00 10210.93 9027.00 31 P 0.00 0.00 10300.38 9088.00 27P 0.00 0.00 10403.02 9158.00 26N 0.00 0.00 10407.42 9161.00 26P 0.00 0.00 10425.01 9173.00 25N 0.00 0.00 10433.81 9179.00 25P 0.00 0.00 10454.34 9193.00 24N 0.00 0.00 Targets Map Map <-- Latitude --> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 12-99 TSAG 8724.00 3944.34 88.02 5935070.16 6962 .66 70 13 36.684 N 148 24 57.243 W -Circle (Radius: 200) -Plan hit target 12-37 Fault 1 8769.00 2585.38 -34 29 5933634.00 328.00 70 13 23.311 N 148 26 23.830 W -Polygon 1 8769.00 2585.38 -346 9 5933634.00 93328.00 70 13 23.311 N 148 26 23.830 W -Polygon 2 8769.00 2549.98 -2878. 5933614.00 693919.00 70 13 22.965 N 148 26 6.684 W -Polygon 3 8769.00 2696.13 -2383.9 5933773. 694410.00 70 13 24.404 N 148 25 52.309 W -Polygon 4 8769.00 2728.25 -1237.68 5933835 0 695555.00 70 13 24.723 N 148 25 19.015 W -Polygon 5 8769.00 2790.86 -684.83 59339 .00 696106.00 70 13 25.339 N 148 25 2.958 W -Polygon 6 8769.00 2576.00 -80.19 9337 3.00 696716.00 70 13 23.226 N 148 24 45.396 W -Polygon 7 8769.00 2417.53 510.91 3 70.00 697311.00 70 13 21.668 N 148 24 28.228 W -Polygon 8 8769.00 2476.27 1058.66 5 643.00 697857.00 70 13 22.245 N 148 24 12.319 W -Polygon 9 8769.00 2361.78 1650.90 544.00 698452.00 70 13 21.118 N 148 23 55.119 W -Polygon 10 8769.00 2187.05 2251.59 3 85.01 699057.00 70 13 19.398 N 148 23 37.675 W -Polygon 11 8769.00 2066.85 2832.68 5933 0.01 699641.00 70 13 18.214 N 148 23 20.799 W -Polygon 12 8769.00 2091.20 3394.54 59333 .01 700202.00 70 13 18.451 N 148 23 4.481 W -Polygon 13 8769.00 1981.00 3975.9 593322 01 700786.00 70 13 17.364 N 148 22 47.599 W -Polygon 14 8769.00 2091.20 3394 5933319.1 700202.00 70 13 18.451 N 148 23 4.481 W -Polygon 15 8769.00 2066.85 283 .68 5933280. 699641.00 70 13 18.214 N 148 23 20.799 W -Polygon 16 8769.00 2187.02 2 .59 5933384.9 699057.00 70 13 19.397 N 148 23 37.675 W -Polygon 17 8769.00 2361.78 50.90 5933544.00 98452.00 ~ 70 13 21.118 N 148 23 55.119 W -Polygon 18 8769.00 2476.27 058.66 5933643.00 7857.00 70 13 22.245 N 148 24 12.319 W -Polygon 19 8769.00 2417.53 510.91 5933570.00 6 311.00 70 13 21.668 N 148 24 28.228 W -Polygon 20 8769.00 2576.00 -80.19 5933713.00 69 16.00 70 13 23.226 N 148 24 45.396 W -Polygon 21 8769.00 2790.8 -684.83 5933912.00 696 6.00 70 13 25.339 N 148 25 2.958 W -Polygon 22 8769.00 2728 -1237.68 5933835.00 695 .00 70 13 24.723 N 148 25 19.015 W -Polygon 23 8769.00 269 .13 -2383.98 5933773.00 69441 00 70 13 24.404 N 148 25 52.309 W -Polygon 24 8769.00 2 .98 -2878.98 5933614.00 69391 0 70 13 22.965 N 148 26 6.684 W -Plan out by 3296.70 at 8769.00 2.59 -488.02 5935118.40 696271. 70 13 37.158 N 148 24 57.244 W 12-37 Fault 2 8769.00 629.09 -5167.75 5934633.00 691603.0 70 13 33.566 N 148 27 13.181 W -Polygon 1 8769.00 3629.09 -5167.75 5934633.00 691603.00 70 13 33.566 N 148 27 13.181 W -Polygon 2 8769.00 3206.85 -4436.47 5934230.00 692345.00 70 13 29.418 N 148 26 51.932 W -Polygon 3 8769.00 3228.09 -3371.49 5934279.00 693409.00 70 13 29.632 N 148 26 20.998 W -Polygon 4 8769. 3321.82 -3052.92 5934381.00 693725.00 0 13 30.555 N 148 26 11.745 W -Polygon 5 8769 0 3395.81 -2514.78 5934469.00 694261.00 13 31.285 N 148 25 56.115 W -Polygon 6 87 .00 3381.90 -1942.92 5934470.00 694833.00 7 13 31.150 N 148 25 39.503 W -Polygon 7 8 9.00 3427.51 -1390.51 5934530.00 695384.00 70 13 31.600 N 148 25 23.458 W -Polygon 8 69.00 3617.13 -874.36 5934733.00 695895.00 70 33.465 N 148 25 8.465 W -Polygon 9 769.00 3730.85 -325.18 5934861.00 696441.00 70 T 34.584 N 148 24 52.513 W -Polygon 10 8769.00 3764.65 219.92 5934909.00 696985.00 70 1 .917 N 148 24 36.678 W -Polygon 11 8769.00 3667.43 840.63 5934828.01 697608.00 70 13 3.960 N 148 24 18.648 W -Polygon 12 8769.00 3605.25 1383.23 5934780.01 698152.00 70 13 .348 N 148 24 2.887 W -Polygon 13 8769.00 3528.53 1678.34 5934711.01 698449.00 70 13 3 93 N 148 23 54.315 W -Polygon 14 8769.00 3567.45 1950.46 5934757.01 698720.00 70 13 32. 5 N 148 23 46.410 W -Polygon 15 8769.00 3563.50 2523.59 5934768.01 699293.00 70 13 32.9 N 148 23 29.762 W -Polygon 16 8769.00 3404.92 3118.69 5934625.01 699892.00 70 13 31.37 N 148 23 12.477 W -Polygon 17 8769.00 3290.56 3705.94 5934526.01 700482.00 70 13 30.245 148 22 55.421 W -Polygon 18 8769.00 3404.92 3118.69 5934625.01 699892.00 70 13 31.372 148 23 12.477 W -Polygon 19 8769.00 3563.50 2523.59 5934768.01 699293.00 70 13 32.934 N 148 23 29.762 W -Polygon 20 8769.00 3567.45 1950.46 5934757.01 698720.00 70 13 32.975 N 148 23 46.410 W / \ 1 ~ Sperry-Sun , BP Planning Report Company: BP Amoco Date: 5/30/2008 .Time: 12:21:43 Page: 3 • Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL• 12-37 Plan, Tru orth Site: PB DS 12 Vertical (TVD) Reference: 41'GL+28.5=69.589 Well: 12-37 Plan Section (VS) Reference: Well (O.OON,O.OOE, 3.75Azi) Wellpath: 12-37PB1 Plan Survey Calculation Method: Minimum Curvatu Db: Oracle Targets Map Map <- Lad --> <--- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg. Min ec Deg Min Sec Dip. Dr ft ft ft ft ft -Polygon 21 8769.00 3528.53 1678.34 5934711.01 698449.00 70 1 2.593 N 148 23 54.315 W -Polygon 22 769.00 3605.25 1383.23 5934780.01 698152.00 70 1 33.348 N 148 24 2.887 W -Polygon 23 69.00 3667.43 840.63 5934828.01 697608.00 70 33.960 N 148 24 18.648 W -Polygon 24 8 9.00 3764.65 219.92 5934909.00 696985.00 70 3 34.917 N 148 24 36.678 W -Polygon 25 8 .00 3730.85 -325.18 5934861.00 696441.00 7 13 34.584 N 148 24 52.513 W -Polygon 26 876 0 3617.13 -874.36 5934733.00 695895.00 13 33.465 N 148 25 8.465 W -Polygon 27 8769. 3427.51 -1390.51 5934530.00 695384.00 0 13 31.600 N 148 25 23.458 W -Polygon 28 8769. 3381.90 -1942.92 5934470.00 694833.00 70 13 31.150 N 148 25 39.503 W -Polygon 29 8769.0 3395.81 -2514.78 5934469.00 694261.00 70 13 31.285 N 148 25 56.115 W -Polygon 30 8769.00 3321.82 -3052.92 5934381.00 693725.00 70 13 30.555 N 148 26 11.745 W -Polygon 31 8769.00 3228.09 -3371.49 5934279.00 693409.0 70 13 29.632 N 148 26 20.998 W -Polygon 32 8769.00 206.85 -4436.47 5934230.00 692345. 70 13 29.418 N 148 26 51.932 W -Plan out by 4693.82 at 8769.00 92.59 -488.02 5935118.40 696271 9 70 13 37.158 N 148 24 57.244 W 12-37 TSAD rev 1 8826.00 4 3.72 -488.02 5935179.50 69626 .80 70 13 37.760 N 148 24 57.244 W -Circle (Radius: 200) -Plan hit target Plan Section Information MD Intl Azhu TVD +N/-S +E/-W DLS Buil Turn TFO Target ft deg deg ft ft ft deg/100ft de OOft deg/100ft deg 28.00 0.00 0.00 28.00 0.00 .00 0.00 .00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 0 0.00 .00 0.00 0.00 583.33 5.00 90.00 582.91 0.00 14. 1.50 1.50 0.00 90.00 1914.62 25.31 349.78 1871.03 285.21 22.1 2.00 1.53 -7.53 -110.15 8355.05 25.31 349.78 7693.22 2994.91 -466.46 0.00 0.00 0.00 0.00 8916.21 47.00 0.00 8144.00 3322.37 X88.02 4.00 3.87 1.82 19.87 9916.21 47.00 0.00 8826.00 4053.72 -488.02 0.0 0.00 0.00 0.00 12-37 TSAD rev 1 10463.13 47.00 0.00 9199.00 4453.71 -488.02 0. 0.00 0.00 0.00 Survey MD Inch Azim TVD Sys TVD VS N E/W DLS MapN MapE TooVCi ft deg deg ft ft ft ft deg/100ft ft ft 28.00 0.00 0.00 28.00 -41.00 0.00 0.00 0.00 0.00 5931140.11 696863.34 CB-GYRC 100.00 0.00 0.00 100.00 31.00 0.00 0.00 0.00 0.00 5931140.11 696863.34 CB-GYRC 200.00 0.00 0.00 200.00 131.00 0.00 0.00 0.00 0.00 5931140.11 696863.34 CB-GYRC 250.00 0.00 0.00 250.00 181.00 0.0 0.00 0.00 0.00 5931140.11 696863.34 Start Dir 1 300.00 0.75 90.00 300.00 231.00 -0. 0.00 0.33 1.50 5931140.12 696863.67 CB-GYRC 400.00 2.25 90.00 399.96 330.96 - .32 0.00 .94 1.50 5931140.19 696866.28 CB-GYRC 500.00 3.75 90.00 499.82 430.82 .89 0.00 8 1.50 5931140.32 696871.52 CB-GYRC 583.33 5.00 90.00 582.91 513.91 -1.58 0.00 14. 1.50 5931140.49 696877.87 Start Dir e 600.00 4.90 86.33 599.52 530.52 -1.69 0.05 15.9. 2.00 5931140.57 696879.30 CB-GYRC 700.00 4.73 62.40 699.17 630.17 -0.39 2.23 23.89 2.00 5931142.96. 696887.16 CB-GYRC 800.00 5.37 40.68 798.79 729.79 4.31 7.69 30.59 .00 5931148.59 696893.72 MWD+IFf 900.00 6.57 25.22 898.25 829.25. 12.39 16.41 36.08 00 5931157.46 696898.98 MWD+IFf 1000.00 8.10 15.02 997.44 928.4 23.83 28.40 40.34 2: 0 5931169.55 696902.93 MWD+IFf 1100.00 9.80 8.17 1096.22 1027. 38.64 43.62 43.38 2.0 5931184.84 696905.56 MWD+IFf 1200.00 11.59 3.38 1194.48 1125 8 56.78 62.07 45.18 2.00 5931203.33 696906.88 MWD+IFf 1300.00 13.44 359.87 1292.10 1 .10 78.24 83.72 45.75 2.00 5931224.99 696906.89 MWD+IFI 1400.00 15.33 357.21 1388.97 1 9.97 102.99 108.54 45.08 2.00 .931249.78 696905.57 MWD+IFI 1500.00 17.24 355.12 1484.95 15.95 131.00 136.51 43.17 2.00 31277.69 696902.94 MWD+IFI 1600.00 19.17 353.44 1579.94 510.94 162.23 167.59 40.04 2.00 5 1308.68 696898.99 MWD+IFI 1700.00 21.11 352.06 1673.82 1604.82 196.65 201.74 35.67 2.00 59 342.70 696893.74 MWD+IFI 1800.00 23.06 350.90 1766.48 1697.48 234.22 238.92 30.09 2.00 5931 9.72 696887.18 MWD+IFI 1900.00 25.02 349.91 1857.8 1788.80 274.89 279.09 23.28 2.00 59314 .70 696879.33 MWD+IFI • 1914.62 25.31 349.78 1871. 1802.03 281.10 285.21 22.18 2.00 593142 78 696878.08 End Dir 2000.00 25.31 349.78 194 2 1879:22 317.51 321.13 15.71 0.00 5931461. 696870.67 MWD+IFI 2100.00 25.31 349.78 20 .62 1969.62 360.16 363.21 8.12 0.00 5931503. 696861.98 MWD+IFI 4 ~ Sperry-Sun ~' BP Planning Report / • .7 • Company: BP Amoco Date: 5/30/2008 Time: 12:21:43 Page: 4 Field: Prudhoe Bay Co-ordinate(N E) Reference: Well: 12-37 Plan, T e North Site:: PB DS 12 Vertical (TVI)) Reference: 41'GL+28.5=69:5 .0 Well: 12-37 Plan Section (VS) Reference: Well (O.OON,0.00 ,353.75Azi) Wellpath: 12-37P61 Plan Survey Calculation Method: Minimum Curva a Db: Oracle Survey MD Incl Azim Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft degl100ft ft ft 2200.00 25.31 349.78 212 02 2060.02 402.81 405.28 0.53 0.00 5931 5.24 696853.30 MWD+IFR 2300.00 25.31 349.78 2219. 2150.42 445.46 447.35 -7.05 0.00 593 87.10 696844.62 MWD+IFR 2400.00 25.31 349.78 2309. 2240.82 488.11 489.43 -14.64 0.00 59 628.96 696835.94 MWD+IFR 2500.00 25.31 349.78 2400.2 2331.22 530.76 531.50 -22.23 0.00 5 1670.82 696827.26 MWD+IFR 2600.00 25.31 349.78 2490.62 2421.62 573.41 573.57 -29.82 0.00 1712.68 696818.58 MWD+IFR 2700.00 25.31 349.78 2581.02 512.02 616.06 615.65 -37.40 0.00 931754.54 696809.90 MWD+IFR 2800.00 25.31 349.78 2671.42 02.42 658.71 657.72 X4.99 0.00 5931796.40 696801.22 MWD+IFR 2900.00 25.31 349.78 2761.82 2 2.82 701.36 699.79 -52.58 0.00 5931838.25 696792.53 MWD+IFR 2924.53 25.31 349.78 2784.00 27 .00 711.82 710.11 -54.44 0.00 5931848.52 696790.40 SV3 3000.00 25.31 349.78 2852.22 278 2 744.00 741.87 -60.16 0.0 5931880.11 696783.85 MWD+IFR 3100.00 25.31 349.78 2942.62 2873.6 786.65 783.94 -67.75 0. 5931921.97 696775.17 MWD+IFR 3200.00 25.31 349.78 3033.02 2964.02 829.30 826.01 -75.34 0 0 5931963.83 696766.49 MWD+IFR 3300.00 25.31 349.78 3123.42 3054.42 871.95 868.09 -82.93 .00 5932005.69 696757.81 MWD+IFR 3400.00 25.31 349.78 3213.82 3144.82 914.60 910.16 -90.51 .00 5932047.55 696749.13 MWD+IFR 3500.00 25.31 349.78 3304.22 3235.22 57.25 952.23 -98.10 0.00 5932089.41 696740.45 MWD+IFR 3600.00 25.31 349.78 3394.62 3325.62 .90 994.31 -105.6 0.00 5932131.27 696731.77 MWD+IFR 3682.27 25.31 349.78 3469.00 3400.00 103 99 1028.92 -111.9 0.00 5932165.70 696724.62 9 5/8" 3700.00 25.31 349.78 3485.03 3416.03 1042.5 1036.38 -113. 0.00 5932173.12 696723.08 MWD+IFR 3800.00 25.31 349.78 3575.43 3506.43 1085. 1078.45 -12 6 0.00 5932214.98 696714.40 MWD+IFR 3803.95 25.31 349.78 3579.00 3510.00 1086.8 1080.12 -12 .16 0.00 5932216.64 696714.06 SV2 3900.00 25.31 349.78 3665.83 3596.83 1127.85 120.53 - 8.45 0.00 5932256.84 696705.72 MWD+IFR 4000.00 25.31 349.78 3756.23 3687.23 1170.50 62.60 36.04 0.00 5932298.70 696697.04 MWD+IFR 4100.00 25.31 349.78 3846.63 3777.63 1213.15 1 4.67 143.62 0.00 5932340.56 696688.36 MWD+IFR 4200.00 25.31 349.78 3937.03 3868.03 1255.80 12 .75 -151.21 0.00 5932382.42 696679.68 MWD+IFR 4251.96 25.31 349.78 3984.00 3915.00 1277.96 126 1 -155.15 0.00 5932404.17 696675.17 SV1 4300.00 25.31 349.78 4027.43 3958.43 1298.45 1288.8 -158.80 0.00 5932424.28 696671.00 MWD+IFR 4400.00 25.31 349.78 4117.83 4048.83 1341.10 1330.8 -166.38 0.00 5932466.14 696662.32 MWD+IFR 4500.00 25.31 349.78 4208.23 4139.23 1383.75 1372.9 -173.97 0.00 5932507.99 696653.63 MWD+IFR 4600.00 25.31 349.78 4298.63 4229.63 1426.40 1415. -181.56 0.00 5932549.85 696644.95 MWD+IFR 4700.00 25.31 349.78 4389.03 4320.03 1469.04 1457 1 189.15 0.00 5932591.71 696636.27 MWD+IFR 4800.00 25.31 349.78 4479.43 4410.43 1511.69 14 .19 - .73 0.00 5932633.57 696627.59 MWD+IFR 4900.00 25.31 349.78 4569.83 4500.83 1554.34 1 1.26 -2 32 0.00 5932675.43 696618.91 MWD+IFR 4970.98 25.31 349.78 4634.00 4565.00 1584.62 71.12 -20 1 0.00 5932705.14 696612.75 UG4 5000.00 25.31 349.78 4660.23 4591.23 1596.99 583.33 -211. 0.00 5932717.29 696610.23 MWD+IFR 5100.00 25.31 349.78 4750.63 4681.63 1639.64 625.41 -219.4 0.00 5932759.15 696601.55 MWD+IFR 5197.75 25.31 349.78 4839.00 4770.00 1681.33 1666.53 -226.91 .00 5932800.06 696593.06 UG3 5200.00 25.31 349.78 4841.03 4772.03 1682.2 1667.48 -227.08 00 5932801.01 696592.87 MWD+IFR 5300.00 25.31 349.78 4931.44 4862.44 1724. 1709.55 -234.67 0. 0 5932842.87 696584.18 MWD+IFR 5400.00 25.31 349.78 5021.84 4952.84 1767 9 1751.63 -242.26 0. 5932884.72 696575.50 MWD+IFR 5500.00 25.31 349.78 5112.24 5043.24 181 4 1793.70 -249.84 0.0 , 5932926.58 696566.82 MWD+IFR ~ 5600.00 25.31 349.78 5202.64 5133.64 18 .89 1835.77 -257.43 0.00 5932968.44 696558.14 MWD+IFR 5700.00 25.31 349.78 5293.04 5224.04 1 5.54 1877.85 -265.02 0.00 ` 933010.30 696549.46 MWD+IFR 5800.00 25.31 349.78 5383.44 5314.44 38.19 1919.92 -272.60 0.00 33052.16 696540.78 MWD+IFR 5900.00 25.31 349.78 5473.84 5404.84 980.84 1961.99 -280.19 0.00 5' 3094.02 696532.10 MWD+IFR 5972.08 25.31 349.78 5539.00 5470.00 2011.58 1992.32 -285.66 0.00 59 •124.19 696525.84 UG1 6000.00 25.31 349.78 5564.24 5495.24 2023.49 2004.07 -287.78 0.00 5933 .88 696523.42 MWD+IFR 6100.00 25.31 349.78 5654.64 5585.64 2066.14 2046.14 -295.37 0.00 59331 74 696514.73 MWD+IFR 6200.00 25.31 349.78 5745.04 5676.0 2108.79 2088.21 -302.95 0.00 5933219.9 696506.05 MWD+IFR 6300.00 25.31 349.78 5835.44 5766. 2151.44 2130.29 -310.54 0.00 5933261. 696497.37 MWD+IFR 6400.00 25.31 349.78 5925.84 5856. 2194.08 2172.36 -318.13 0.00 5933303.3 696488.69 MWD+IFR 6500.00 25.31 349.78 6016.24 594 .24 2236.73 2214.43 -325.71 0.00 5933345.17 696480.01 MWD+IFR 6563.89 25.31 349.78 6074.00 60 5.00 2263.98 2241.31 -330.56 0.00 5933371.91 696474.46 WS2 ent 5 5 5 5 5 5 S 5 S S S S S S S S S S S S S S S S S S S S S S IS IS IS IS IS IS ~ Sperry-Sun ` BP Planning Report • C7 • Company: BP Amoco Date: 5/30/2008 Time:. 12:21:43 Page: 5 Field: Prudhoe Bay Co-ordinate(N E) Reference: Well: 12-37 Plan, True North Site: PB DS 12 Vertical (TVD) Reference: 41' GL+28.5=69.5 69. 0 Well: 12-37 Plan Section (VS) Reference: Well (O.OON,O.OOE,353.75 i) Wellpath: 12-37P61 Plan Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN apE Tool/Co ft deg deg ft ft ft ft ft deg/100ft ft ft 6600.00 25.31 349.78 6106.64 6037.64 2279.38 2256.51 -333.30 0.00 5933387.03 696471.33 MWD+IFR 6700.00 25.31 349.78 6197.04 128.04 2322.03 2298.58 -340.89 0.00 5933428.89 696462.65 MWD+IFR 6800.00 25.31 349.78 6287.44 18.44 2364.68 2340.65 -348.48 0.00 5933470.7 696453.96 MWD+IFR 6857.03 25.31 349.78 6339.00 6 0.00 2389.01 2364.65 -352.80 0.00 593349 2 696449.01 WS1 6900.00 25.31 349.78 6377.85 63 .85 2407.33 2382.73 -356.06 0.00 59335 .61 696445.28 MWD+IFR 7000.00 25.31 349.78 6468.25 63 25 2449.98 2424.80 -363.65 0.00 5933 .47 696436.60 MWD+IFR 7083.80 25.31 349.78 6544.00 647 0 2485.72 2460.06 -370.01 0.00 593 89.54 696429.33 CM3 7100.00 25.31 349.78 6558.65 6489. 2492.63 2466.87 -371.24 0.00 59 596.32 696427.92 MWD+IFR 7200.00 25.31 349.78 6649.05 6580.0 2535.28 2508.95 -378.82 0.00 33638.18 696419.24 MWD+IFR 7300.00 25.31 349.78 6739.45 6670.45 2577.93 2551.02 -386.41 0.00 933680.04 696410.56 MWD+IFR 7400.00 25.31 349.78 6829.85 6760.85 2620.58 2593.09 -394.00 0.00 5933721.90 696401.88 MWD+IFR 7500.00 25.31 349.78 6920.25 6851.25 2663.23 2635.17 -401.59 0.00 5933763.76 696393.20 MWD+IFR 7600.00 25.31 349.78 7010.65 6941.65 2705.88 2677.24 -409.17 0.0 5933805.62 696384.51 MWD+IFR 7659.02 25.31 349.78 7064.00 6995.00 31.05 2702.07 -413.65 0 0 5933830.32 696379.39 CM2 7700.00 25.31 349.78 7101.05 7032.05 2 8.53 2719.31 -416.76 .00 5933847.48 696375.83 MWD+IFR 7800.00 25.31 349.78 7191.45 7122.45 2 1.18 2761.39 -424.35 .00 5933889.34 696367.15 MWD+IFR 7900.00 25.31 349.78 7281.85 7212.85 28 .83 2803.46 -431.93 0.00 5933931.19 696358.47 MWD+IFR 8000.00 25.31 349.78 7372.25 7303.25 287 48 2845.53 -439.5 0.00 5933973.05 696349.79 MWD+IFR 8100.00 25.31 349.78 7462.65 7393.65 2919. 2887.61 -447 1 0.00 5934014.91 696341.11 MWD+IFR 8200.00 25.31 349.78 7553.05 7484.05 2961. 2929.68 -4 9 0.00 5934056.77 696332.43 MWD+IFR 8300.00 25.31 349.78 7643.45 7574.45 3004.4 2971.75 -4 .28 0.00 5934098.63 696323.75 MWD+IFR 8355.05 25.31 349.78 7693.22 7624.22 3027.90 2994.91 6.46 0.00 5934121.67 696318.97 Start Dir 4° 1 8400.00 27.01 351.12 7733.56 7664.56 3047.68 3014.45 69.74 4.00 5934141.12 696315.18 MWD+IFR 8500.00 30.82 353.62 7821.08 7752.08 3096.00 062.37 -476.09 4.00 5934188.85 696307.58 MWD+IFR 8600.00 34.67 355.61 7905.18 7836.18 3150.08 116.21 -481.12 4.00 5934242.54 696301.15 MWD+IFR 8694.34 38.33 357.17 7981.00 7912.00 3206.12 3 72.21 -484.62 4.00 5934298.43 696296.19 CM1 8700.00 38.55 357.25 7985.43 7916.43 3209.63 31 5.7 -484.79 4.00 5934301.94 696295.93 MWD+IFR 8800.00 42.45 358.63 8061.46 7992.46 3274.39 32 -487.09 4.00 5934366.74 696291.94 MWD+IFR 8900.00 46.36 359.82 8132.88 8063.88 3344.03 33 7 -488.00 4.00 5934436.64 696289.20 MWD+IFR 8916.21 47.00 0.00 8144.00 8075.00 3355.76 2. -488.02 4.00 5934448.43 696288.87 End Dir 9000.00 47.00 0.00 8201.15 8132.15 3416.67 83.6 -488.02 0.00 5934509.69 696287.27 MWD+IFR 9034.98 47.00 0.00 8225.00 8156.00 3442.10 409.23 X88.02 0.00 5934535.26 696286.61 THRZ 9100.00 47.00 0.00 8269.34 8200.34 3489.37 3456.78 -488.02 0.00 5934582.79 696285.37 MWD+IFR 9200.00 47.00 0.00 8337.54 8268.54 3562. 3529.92 -488.02 0.00 5934655.90 696283.46 MWD+IFR 9300.00 47.00 0.00 8405.74 8336.74 3634 7 3603.05 -488.02 0.00 5934729.01 696281.55 MWD+IFR 9310.64 47.00 0.00 8413.00 8344.00 364 .50 3610.83 88.02 0.00 5934736.79 696281.35 BHRZ 9400.00 47.00 0.00 8473.94 8404.94 37 .47 3676.19 ` 88.02 0.00 5934802.11 696279.65 MWD+IFR 9436.74 47.00 0.00 8499.00 8430.00 3 4.18 3703.06 .8.02 0.00 5934828.97 696278.94 TKNG 9482.19 47.00 0.00 8530.00 8461.00 767.23 3736.30 -48 02 0.00 5934862.20 696278.08 TJ B 9500.00 47.00 0.00 8542.14 8473.14 3780.17 3749.32 -488 2 0.00 5934875.22. 696277.74 MWD+IFR 9592.16 47.00 0.00 8605.00 8536.00 3847.17 3816.73 X88. 0.00 5934942.60 696275.98 TJA 9600.00 47.00 0.00 8610.34 8541. 3852.87 3822.46 -488. 0.00 5934948.33 696275.83 MWD+IFR 9700.00 47.00 0.00 8678.54 8609. 3925.57 3895.59 -488.0 0.00 5935021.43 696273.92 MWD+IFR 9766.65 47.00 0.00 8724.00 86 .00 3974.03 3944.34 -488.02 0.00 5935070.16 696272.65 12-99 TSA 9773.98 47.00 0.00 8729.00 8 .00 3979.36 3949.70 -488.02 .00 5935075.52 696272.51 7" 9800.00 47.00 0.00 8746.74 7.74 3998.27 3968.73 -488.02 .00 5935094.54 696272.02 MWD+IFR 9801.84 47.00 0.00 8748.00 679.00 3999.61 3970.08 -488.02 0 5935095.89 696271.98 TSHU 9831.17 47.00 0.00 8768.00 8699.00 4020.93 3991.52 X88.02 0. 0 5935117.33 696271.42 TSHB 9832.63 47.00 0.00 8769.00 8700.00 4022.00 3992.59 -488.02 0.0 5935118.40 696271.39 12-37 Faul 9851.70 47.00 0.00 8782.0 8713.00 4035.85 4006.54 -488.02 0.00 5935132.33 696271.03 TSHC 9900.00 47.00 0.00 8814. 8745.94 4070.97 4041.86 -488.02 0.00 5935167.65 696270.11 MWD+IFR 9916.21 47.00 0.00 882 0 8757.00 4082.76 4053.72 -488.02 0.00 5935179.50 696269.80 12-37 TSA 9955.80 47.00 0.00 88 .00 8784.00 4111.54 4082.67 -488.02 0.00 5935208.44 696269.04 45N ent S 5 5 5 5 5 5 5 5 S S S S S S S S S S S S S S S 6 S S S S S S S S S IS ev ~ Sperry-Sun BP Planning Report / • • • Company: BP Amoco Date: 5/30/2008 Time: 12:21:43 Page: 6 Field: Prudhoe Bay Co-ordinate(N E) Reference: Well: 12-37 an, True North Site:. PB DS 12 Vertical (TVD) Reference: 41' GL+28. 9.5.69 .0 Well: 12-37 Plan Section (VS) Reference: Well (0.00 ,O.OOE,353.75Azi) Wellpath: 12-37P61 Plan Survey Calculation Method:. Minimum urvature Db: Oracle Survey MD Incl Azim Sys TVD VS N/S E/W DLS pN MapE TooUCo ft deg deg ft ft ft ft ft . deg/100ft ft ft 9974.86 47.00 0.00 8866.0 8797.00 4125.40 4096.61 X88.02 0.00 935222.38 696268.68 45P 10000.00 47.00 0.00 8883.14 8814.14 4143.67 4115.00 -488.02 0.00 5935240.75 696268.20 MWD+IFR 10011.52 47.00 0.00 8891.00 8822.00 4152.05 4123.42 -488.02 0.00 5935249.17 696267.98 44N 10015.92 47.00 0.00 8894.00 8825.00 4155.25 4126.64 -488.02 0.00 5935252.39 696267.90 44P 10058.44 47.00 0.00 8923.00 854.00 4186.16 4157.74 X88.02 0.0 5935283.48 696267.09 43N 10062.84 47.00 0.00 8926.00 8 7.00 4189.36 4160.96 X88.02 0. 5935286.69 696267.00 43P 10100.00 47.00 0.00 8951.34 88 .34 4216.37 4188.13 -488.02 0 5935313.86 696266.29 MWD+IFR 10114.16 47.00 0.00 8961.00 889 00 4226.67 4198.49 -488.02 .00 5935324.21 696266.02 42N 10120.02 47.00 0.00 8965.00 8896.0 4230.93 4202.78 X88.02 .00 5935328.50 696265.91 42P 10155.22 47.00 0.00 8989.00 8920. 4256.51 4228.52 X88.02 0.00 5935354.22 696265.24 41 N 10161.08 47.00 0.00 8993.00 8924.00 4260.78 4232.81 X88.02 0.00 5935358.51 696265.13 41 P 10200.00 47.00 0.00 9019.54 8950.54 4289.07 4261.27 -488.0 0.00 5935386.97 696264.39 MWD+IFR 10203.60 47.00 0.00 9022.00 8953.00 4291.69 4263.90 -488. 0.00 5935389.60 696264.32 31 N 10210.93 47.00 0.00 9027.00 8958.00 297.02 4269.27 X88 0.00 5935394.96 696264.18 31 P 10300.00 47.00 0.00 9087.74 9018.74 61.77 4334.40 -48 2 0.00 5935460.07 696262.48 MWD+IFR 10300.38 47.00 0.00 9088.00 9019.00 4 .05 4334.68 -4 .02 0.00 5935460.35 696262.47 27P 10400.00 47.00 0.00 9155.94 9086.94 44 47 4407.54 8.02 0.00 5935533.18 696260.57 MWD+IFR 10403.02 47.00 0.00 9158.00 9089.00 443 7 4409.75 88.02 0.00 5935535.38 696260.52 26N 10407.42 47.00 0.00 9161.00 9092.00 4439. 4412.96 88.02 0.00 5935538.60 696260.43 26P 10425.01 47.00 0.00 9173.00 9104.00 4452. 4425.83 -488.02 0.00 5935551.46 696260.10 25N 10433.81 47.00 0.00 9179.00 9110.00 4459.05 4432.27 -488.02 0.00 5935557.89 696259.93 25P 10454.34 47.00 0.00 9193.00 9124.00 4473.98 7.28 -488.02 0.00 5935572.90 696259.54 24N 10463.12 47.00 0.00 9198.99 9129.99 4480.36 53.7 -488.02 0.00 5935579.32 696259.37 4 1 /2" 10463.13 47.00 0.00 9199.00 9130.00 4480.37 3.7 -488.02 0.00 5935579.33 696259.37 MWD+IFR '` ''~ '. ~\ ~ ~ ~~ ent WELL UFTAILS ANTI-COLLISION SETTINGS COMPANY UFTAILS SURVEY PROGRAM Nmnc -N/-5 Pl-W Northing Eaamg Lnritude LongirtWC Slol BP Amato Ueplh Fm Depth To Survey/Plan Toul Inmrpolation Meth od:MD Interval: 25.00 ' ' I?-17 Plan -Ii81AI -I 132.76 5931140.11 196867.74 70°I2'S7.8YIN 148'24'41fM7W N/A Depth Range Fiom : 28.00 To: 10463.13 Calculation M.thal: Minimum Curvamn ' 18.W U-G} BIX).W Plenr~ed: l?-J7P61 Wp511 VIO C RO-SS , SA VI4 MWUIFRMS 37Pb W ' MaxlntUnl Range: 1243.$1 Re Perence: Plan: 12-37PbI Wp5.0 Fn'or Syztem: ISC WSA Scan Methai- Trev Cylinder Nunh 8/101X1 _- I p 10467.17 Planned: l Error Srnlice'. EUiplical ~ Ca.ing Wamuig Mcfi.xL Rulee Uaxd (12-3 WF.LLPATFI UFTAILS 160 Plan From Colour To MD I'_-17PR1 Plnn 28 250 ~g ' 150 '~ 2SO SOO GL 18.5-69.5 G9 tX1U Rel. Dartim 41 ~ SOO 7SO V.Hemion Uignn Origin Sorting / r 33 ~ "~ O Mgk ~N/-S ~r: -W Frum NU . ,r l~ - 750 1000 25 '~ r 1VV ~~ ,~ ~.1~ i ~ . \ ~~ ~ IOOO i2so 1500 1750 2000 12SO Isoo U50 2000 2250 . ~ I ~ ~ _ 2250 2500 00 `_ / ~` ' ~\ 2500 2750 ~ 01-13101 - o,.,X,ol. i ~ ~-~' / 2750 - 3000 01~'Bt"' - ~lyP~ ~ ~ 3000 3250 ~= t ~ ' 3250 3500 - _I I,;; 30 r " ~ 3500 37s0 ""1"'r ~5 3750 - 4000 - iii- I 4000 800 i i ~/ 9 0 ,19 .~ 800 _ i ' ~ , 0 8500 - hIJU2 L-13112 ~~ t~v G ~ ~ ~ ?~ 00 8750 - i~~n~i~ ~" \ / 9000 " ° 1 1" ' ~ \ \ \\ J7 Pla I " ` ~~~ ~ - ~ ' 92 0 9s 0 12 77P61 r ~ ~ . ~~ ~ 95 9750 )5 ~~ - j:.:. ~ ~ ~ ~ 975 --- 10000 0 270 ~.,. {!= > _'` ~, 90 753.75' 0.W UW '_B.O(I 5 00 21 1-18 Minor risked 1 /200 50 120 Pre Plans Removed. See AC Scan for Plans Parents Profile @ No Errors SECTION UFTAILS Sec MO Ls An NU -N/-5 .E-W ULeg TFace VSec Target 1 38-W U.IN) U1)0 18.W 0011 O.W 0.W O.W U.IXI 1511.W O.W U.W 2SO.W UW (IW U.W U.W O.W 1 S83.JJ S.W W.W 582.91 0.1X1 14.54 1.50 W.W -1.58 4 1911.6? 25.71 341.78 1871.07 285.21 '_'_.I8 ? W ~I10.15 '_A 1.10 5 8355DS 25.31 349.78 7697'? '_994.91 -066.46 (1W U.W 3U27.911 6 841E 21 47.011 O.W 8144.1X1 3722.1] -088.02 4.W 19.87 3355.76 7 1916 21 47. W O.OU 88'_6(X) 41157 71 -088.112 O W O.W 4081.76 12-37 TSAD rev l 8 10463.17 47W O.W Y19Y.W 445].71 -088.01 O.W nW 4480.37 25 50 60 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs i [SOft/in] Sperry-Sun Anticollision Report ~'- • C7 • Company: BP Amo Date:. 5/30/2008 Time: 12:24:03 Page: 1 Field: Prudhoe Reference Site: PB DS 12 Co-ordinate(NE) Reference: Well' 12- Plan, True North. Reference Well: 1 2-37 Plan Vertical (TVD) Reference: 4 1'GL+2 =69.5 69.0 Reference Welipath: 1 2-37PB1 Plan Db: OraGe GLOBAL SCAN APPLIED: All welipa within 200'+ 100/1000 of reference -There are Tllreld~wadls in this fit Cipal Plan i£ P LANNED PROGRAM Interpolation Method: MD terval: 25.00 ft Error Model: I W SA Ellipse Depth Range: 28.00 to 1046 13 ft Scan Method: rav Cylinder North Maximum Radius: 1243.51 ft Error Surface: Ilipse + Casing Survey Program for Definitive Welipath Date: 5/1/2008 Validated: No Version: 1 Planned From To Survey Toolcode Tool me ft ft 28.00 800.00 Planned: 12-37Pb1 Wp V14 CB-GYRO-SS Ca era based gyro single shots 800.00 10463.13 Planned: 12-37Pb1 Wp 5. V14 MWD+IFR+MS M D + IFR + Mu lti Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 3682.27 3469.00 9.625 12.250 9 5/8 9773.98 8729.00 7.000 8.500 7" 10463.13 9199.00 4.500 6.125 4 1 /2" Summary <---------- Offset Welipath --------> Reference set Ctr-Ctr No-Go Allowable Site Well Welipath MD MD Distance Area Deviation Warning' ft ft ft ft ft PB DS 01 01-13 01-13 V2 Out of range PB DS 01 01-18 01-18 V9 8 .53. 10675.00 126.30 0.00 126.30 Pass: Minor 1/200 PB DS 01 01-18 01-18A Plan VO Plan: 1 Out of range PB DS 12 12-09 12-09 V1 644. 650.00 180.01 18.98 161.03 Pass: Major Risk PB DS 12 12-10 12-10 V1 572 575.00 60.97 12.56 48.41 Pass: Major Risk PB DS 12 12-10A 12-10A V3 57 4 575.00 60.97 12.56 48.41 Pass: Major Risk PB DS 12 12-11 12-11 V1 11 .14 1150.00 50.55 20.70 29.85 Pass: Major Risk PB DS 12 12-11 Plan 12-11A V1 Plan: P 11 3.62 150.00 50.56 20.67 29.90 Pass: Major Risk PB DS 12 12-12 12-12 V3 1 2.26 50.00 50.40 37.00 13.40 Pass: Major Risk PB DS 12 12-12 12-12A V6 72.41 1 0.00 50.40 37.00 13.40 Pass: Major Risk PB DS 12 12-13 12-13 V7 970.12 19 00 43.29 30.82 12.47 Pass: Major Risk PB DS 12 12-13 12-13A V6 1973.63 192 0 43.50 30.86 12.64 Pass: Major Risk PB DS 12 12-13 12-136 V6 1966.95 1925. 43.16 30.78 12.38 Pass: Major Risk PB DS 12 12-13 12-136PB1 V5 1966.95 1925.0 43.16 30.78 12.38 Pass: Major Risk PB DS 12 12-13 12-13BPB2 V10 1966.95 1925.00 ~ ~ 43.16 30.78 12.38 Pass: Major Risk PB DS 12 12-20 12-20 V7 313.57 325.00 ` • 47.61 5.86 241.75 Pass: Major Risk PB DS 12 12-20 12-20A V17 321.19 325.00 7.74 6.11 241.63 Pass: Major Risk PB DS 12 12-21 12-21 V1 10202.92 10050.00 .05 645.99 248.06 Pass: Major Risk PB DS 12 12-37 Plan 12-37 Plan VO PI : 12 8850.00 8850.00 ` 87 3.75 -2.88 FAIL: NOERRORS Site: PB DS 01 Well: 01-18 `` Rule A~ ' gned: Minor 1/200 Welipath: 01-18 V9 Inter-Sit rror: 0.00 ft Reference Offset Semi-Ma" r Axis Ctr-Ctr Go Allowable MD TVD MD TVD Ref ffset TFO+AZI TFO-HS Casing/HSDistance Ar Deviation Warning ft ft ft ft ft ft deg deg in ft ft• ft 8972.02 8182.07 9450.00 7332.52 21.78' 276.19 18.22 18.22 4.500 1228.70 44.8 1183.84 Pass 8971.62 8181.79 9475.00 7350.08 21.7 277.35 18.34 18.34 4.500 1203.83 45.24 1158.59 Pass 8971.24 8181.53 9500.00 7367.65 21. 278.52 18.46 18.46 4.500 1178.95 45.62 133.34 Pass 8970.88 8181.29 9525.00 7385.25 2 7 279.68 18.58 18.58 4.500 1154.08 46.00 08.08 Pass 8970.56 8181.06 9550.00 7402.86 .77 280.84 18.71 18.71 4.500 1129.22 46.40 1 .82 Pass 8970.26 8180.86 9575.00 7420.50 1.77 281.99 18.85 18.85 4.500 1104.37 46.81 105 ,, 5 Pass 8969.98 8180.67 9600.00 7438.15 ~ 21.77 283.15 18.99 18.99 4.500 1079.52 47.23 1032. Pass 8969.73 8180.50 9625.00 7455.8 21.77 284.31 19.14 19.14 4.500 1054.68 47.66 1007.0 Pass 8969.49 8180.34 9650.00 7473. 21.77 285.47 19.30 19.30 4.500 1029.84 48.10 981.75 Pass 8969.26 8180.18 9675.00 7491., 21.76 286.63 19.47 19.47 4.500 1005.02 48.54 956.48 Pass 8969.02 8180.01 9700.00 75 .85 21.76 287.79 19.64 19.64 4.500 980.20 48.98 931.22 ss 8968.78 8179.85 9725.00 75 6.53 21.76 288.95 19.82 19.82 4.500 955.40 49.43 905.97 P s 8968.56 8179.70 9750.00 7 4.22 21.76 290.11 20.02 20.02 4.500 930.60 49.88 880.72 Pa ~\ COMPANY DETAILS BP Amoco by Iculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical i Casing CASING DETAILS No. TVD MD Name Size 1 8634.00 13151.82 4 I/2" 4.500 H A L L I B U R TO N perry Drilling 8ervic®~ . ~. ' {- I (- ~- _ ~- - - '~ ;- - ~ - - - - REFERENCE INFORMATION Co-ordinate (N/E) Reference: Wall Contre: 12-37 Plan, Truc North Vertical (TVD) Rcfamnce: 41'GLt 28.5=69.5 69.00 Section (VS)Rcference: Slot-(O.OON,0.00E) Measured Dcpih Reference: 41'GLi28.5=69.5 69.00 Calculation Method: Minimum Curvature ~ '_''__ ___ ' __ __ _ ~ __ ___ - - ~ ~ ~- - _ - -- - - -- - - - - _~ ~ -- - SURVEY PROGRAM epth Fm Depth To Survey/Plan Tool Plan: 12-37 WP 5.0 (12-37 Plan/12-37 Plan) ' 715.00 13151.82 Planned: l2-37 WP 5.0 V25 MWDiIFRi MS Crea[ed By: Sperry Drilling Date: S/30/2008 WELL DETAILS Name iN/-S i E/-W Northing Easting Latimdc Longitude Slot 12-37 Plan -1481.41 -1142.76 5931140.11 696863.34 70°12'S7.891N 148°24'43.067W N/A SECTION DETAILS Scc MD Inc Azi TVD +N/-S +E/-W DLcg TFace VSec Target I 9715.00 47.00 0.00 8688.77 3906.56 -488.02 0.00 0.00 3726.16 2 9735.00 49.40 0.00 8702.10 3921.47 -488.02 12.00 0.00 3740.76 3 9965.09 90.00 351.00 8780.41 4131.68 -506.85 18.00 346.32 3942.78 4 10(148.42 105.00 351.00 8769.57 4213.06 -519.73 18.00 0.00 401 5 10198.43 1O5A0 351 AO 8730.74 4356.16 -542.40 0.00 Q00 .35 5 10311.80 90.00 5.00 8715.91 4467.90 -546.06 18.00 136.0 4264.03 --.. 7 1054228 90.90 46.48 8714.02 467L00 -448.15 18AU 4482.78 _ 8 11729.61 9(1.90 46.48 8695.34 5488.53 412.69 O.OU 0.00 5458 03 9 11772 09 92.70 49.36 8694.00 5516.98 444.20 57.98 5492 28 12-37 D T1 10 12408.62 92.70 49.36 8664.00 5931.07 926.69 .00 0.00 5995 7U 12-37 ConIT2 rev l II 12698.15 9221 3L98 855L50 6149.62 1114 6.00 -91._ .. _ -- 12 13151.82 9221 3 L98 8634.00 5534.15 9 0.00 O.UU 6673.08 12-37 Cont T3 Rcv 2 i 7500 ~ _ i ~ - - I _ ~ ~ _' .. - -. ~ - I '~ - - - - _ - St t Dir 12"/100' :971 688.7TTVD - -- ~ ~ _ - - ~-- -- !~_ - Start -Dir 18"/100':9735' 2.1'TVD~ ~ ~ ~ - i + -- - ~ ~ -- ~~ ~ 800 I I I- _ .End Dir ; 10048.43 MD, 8769. __. .-. _. ' - ~ - i - ~ ~ - - StartDirl "/IW':IB198.42'M .74'TVD- - - ~ - - - - _ ' ; , - - C _ . . - End Dir :1054328' D. y' TVD , , - ' _- Start Dir 8°/100' : CI7 9.61' M D, 8695.34 'TVD °o ~~ ~ -_- ._ .... _. - - ~ End D rr : 11772.0 ' MD, 8 694' TVD - ' ' ' - . - - _ a I . I -- -1-_ ~ r , ~ ~ ~ i ~ ~ St art Dir 6"11 00' : 12 End 08 r MD, 8664 T .62 . 12698.15'MD, VD ~ 865L5' V D ~ ~ I ~ i -' ~ - i - - - - -' _ - Tot al Dcptl : I 3151.R2 ' MD, 863 4' j .. 850 .. - ~ I ~ _ I i _ ~ ~i II ~ ~, ' I ; ~ _ I ; - 12 -37 Co t T 3 Rcv 6 - - -- ' > __ - i - I - - _ 2.37 P tan 1 - ~ ' ` '' 12-3 7 Cont T2 r ev 1 -" O '. . ~D r'-- .11000 ' -_ '- - - ~ ~ - 12000 ° . aa: - ' +_ _ _ ,37 Co T 3 Rev 2 _' 000( ~ ..t'~21 1000 T get i - ,- -, _ ._ i 9000 -_ 12-37 Plat (IZ-37PB1 Plan) ~ -.~~ -_ i-r-. ~ C i 950 i ~ i +N/-S Name TVD 12-37 Cont T3 Rcv 1 8617.00 6534.15 12-37 Cunt T3 Rcv 2 8634.00 6534.15 12-37 ContT3 8639.00 6534.15 TARGET DETAILS +E/-W Northin Eastin Sha c g g P 1354.59 5937707A0 598047.00 Point 1354.59 5937707.00 698047.00 Point 1354.59 5937707.00 698047.00 Point ~ ~ - - ~ _ __ ~~ - - - - . __--. - - - _ _ - ' - _ ' __ ---. - - ~ i - '~, - - '~ .. _. - - - ~ ~ ~ ~ ~ - I- r~ ' -. :: 1 ~ - - - - I ~ /_ , ~ - { I ~~ - '~ - 12-37 ContT2 8644.00 593 L07 12-37 Cont T2 rev 1 8664.00 5931.07 12-37 D TI 8694.00 5516.98 I3-21 1(100' "fa rct 8713.00 4175.29 925.69 5937093AO 697635.00 Poin[ 926.69 5937093.00 697635.00 Point 444.20 5936666.49 697163.50 Point 354.68 5935323.00 697109.00 Circle (Radius: 1000) 5500 6000 Ver ~ ° Scetion at 11.71° [5008/in] 6500 7000 7500 8000 L J COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BP Amoco -ordinate (N/E) Reference: Well Centre: 12-37 Plan, True North Depth Fm Depth To Survey/Plan Tool Plan: 12-37 WP S. 0 (12-37 PIaNl2-37 Plan) , Vertical (TVD) Reference: 41'GL ~ 28.5=69.5 69.00 Calculation Mc[horl: Minimum Curvature Section (VS)Rcfcrcnce: Slut-(O.OON,O.OOE) 9715.00 13151.82 Planned: l2-37 WP 5.0 V25 MWD~I FRIMS Created ey: Sperry Drilling Date: S/30/2008 Error System: ISCWSA casurcd Depth Re(crcnce: 41'GL i 28.5=69.5 69.00 Scan MethoJ: Trav Cylinder North Calculation Mcihod: Minimum Curvature WELL DETAILS Error Surf~acc: Elliptical i Casing Warning Method: Rules Based _ _ , Name +N/- S i E/-W North ing Easting La titude Longitude Slot H w ~~'~~~~OR~ I I ~ ~ ~ ' ' t ~ 12-37 Plan - -1481.41 -1142.76 593114(1.11 696863.34 7U°12'SZ891N 148°24'43.067W N/A ~ ~ - - ~. T ARGET DETAILS S(]etT`~" ~/ Dr{{{{f1g BHPV{C9d ---- _ - - _. -_ -. , Name TVD +N/-S +E/-W Northing Easting Shape ' ~ ~- -_ _- _ ~ , ~ I 12-37 Con[T3 Rev l 8617.00 6534.15 1354.59 593770200 698047.00 Point 7165 ~ ~ 12-37 ContT3 Rcv ~ 2 8634.00 6534.15 1384.89 593770200 69804200 Point _ - - ~ _ - - __ _ __ _I _ ~ ' I ~ 37 C t T3 i 8639 00 6534 15 384 S9 5937707 00 698047 00 Point - --_---- ~' --- '- ' I ~ -- -~_ j 12-37 ContT2 8644.0(1 5931.07 926.69 5937093.00 697635.00 Point i - - - - - -- - ~ -- - _ I 12-37 CUnt T2 rev l 8664.00 5931.07 926.69 5937093A(1 697635.00 Point ! -- - -_ - ~ { i 12-37 D Tl ~ 8594.00 5516.98 444.20 5936666.49 697163.50 Poin - "- - - -- - - , -t- 12-21 1000' Target - 8713.00 4175.29 354.68 5935323.00 697109.00 (Radius: 1000) - " - i - I Tota( Dc the 1318 P 1 2' MD, 8634' TVD -- .. - - - 1Z-3 7 Plan 6514 - ~ - -1 _. -I-T' 1 12- 2-37 Coto T 37 WP 5.0 3 cv 1 . _ _ _ - I ' ,, r_ I - _ ' i i I I n 52-37DCont ir 2~r I?698 cv1~408 15' MD, 86 . ,86 1 64' D ----__ __ - -~ __ _- }-_ T--, - --_. -- 5863 ~.~ - _ - -- ! -r . .... .--__ _. --~ ii ~'~- .. I --._ ! I ' - ~ - .. .End Dir : 1 _. 9' D, 8694' T VD ' .-_. . .------ --_._ - . __ _ _I ,.., - ~I i s o ~ - Sta 100':11729.61'M ,$ 695.34'T VD _ '. ? .c -~ - ~i -- , _ -. ~ I~ ~ ~ ~ I ~ ~ _ i I ' ' 5211 ~ ~ ~ i ' i _ _. i - I i ` I . -"~ - `~ ~- i ~ ~ - ~ - ndDir :105 2.28' MD, 8714:02' TVD - ' _. ~ -'.-- ~ -- I ~~ ! - .. 456 . ~I -:_ _, .., : t2-37 Plan ( ' ° . ~ '12-3 PBI Plan) - .. ' ~ '~ ' ' -. ' - - - - - - ~. ~-- . - - - ~...~.- 1 i-. - Start Dir 18 / - ~... ~. I T D , :10198.42 MD, 873(L74 100 I ' ~ ~ CASING DE ,I I '' End Dir :10 ~ 048. 2' MD, 8769.5 7 TVD I ~ _ _ - - - _ _ _ 1 --{- rargct i 12-21 I )0' T - - - - No. TVD MD Name Size 9 i ~ - I ~ I 8634.00 13151.82 41/2" 4.500 '- I I SlartDirl - - ' 8°/LO :9735'MD,8702,1'TVp ~ 3908 i I ~ Start Dir 1 7TTV 8688 2°/10 ' :971 S MD ___ , , f _ __ _ , . SEC TION DETAILS -~ ~ - I - - Sec MD Inc Azi TVD +N/-S ~ E/-W DLeg TFace VSec Target ~ -_i ~ S - ~ ~ - ~ 1 9715.110 47.00 OAO 8688.77 3905.56 -488.02 0.00 O.OU 3726.16 ! ~ ~ I ~ 2 9735.00 49.40 0.00 8702.10 3921.47 -088,02 12.00 0.00 3740.76 ^` ' I, - i ~ : ~ ~ --~-~-~--I 3 9965.09 90.00 351.00 8780.41 4131b8 -506.85 18.00 346.32 3942.78 ~ I 4 10048.42 IUS.UO 3SL00 8759.57 4213.05 -519.73 18.00 O.UU 4019.84 _ 5 10198.42 IOS.00 351.00 8730.74 4356.16 -542.40 0.00 0.00 4155.36 - ~ 6 10311.80 90.00 5.110 8715.91 4467.90 -546.06 18.00 136.07 4254.03 - - - 7 10842.28 90.90 46.48 8714.(12 4671.00 -448.18 18.00 88.64 4482.78 8 11729.51 90.90 46.48 8595.34 5488.53 412.69 0.00 O.UO 5458.03 2606 -1954 -1303 -651 0 65 9 ]1772.09 92.70 49.36 8594.00 5515.98 444.20 8.00 57.98 5492.28 12-37DTI - 10 12408.[ 2 92.70 49.35 8564.00 5931.07 926.69 O.OU 0.00 5995.70 12-37 Cont T2 rev I Il 12698.!5 92.21 31.98 8651.511 5149.62 1114.48 6.00 -91.23 5247.8 ~ ~Vcsl(-)/Eas't(+ 12 13151.82 92.21 31.98 8634.00 6534.15 1354.59 0.00 O.OU 567-37 Cont T3 Rcv 2 Sperry-Sun BP Planning Report • Company: BP Amoco Date: 5/30/2008 Time: 12:51:26 Page: 1 Field:. Prudhoe Bay Co-ordinate(NE}Reference: Well: 12-37 Plan, True orth Site: PB DS 12 Vertical (TVD) Reference: 41'GL+28.5=69.5 69. Well: 12-37 Plan Section (VS) Reference: Well (O.OON,O.OOE,1 1Azi) Wellnath: 12-37 Plan Survev Calculation Method: Minimum Curvature Db: OraCle Plan: 12-37 WP 5.0 Date Composed: 5/5/2008 Version: 25 Principal: Yes Tied-to: From: Definitive P Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate Syst 1927 Map Zone: Alaska, Zon Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Cent Sys Datum: Mean Sea Level Geomagnetic Model: bggm200 Site: PB DS 12 TR-10-15 UNITED STATES :North Slope Site Position: Northing: 932650.90 ft Latitude: 70 13 2.462 N From: Map Easting: 97966.79 ft Longitude: 148 24 9.888 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 12-37 Plan Slot Name: Well Position: +N/-S -1481.41 ft Northing: 593114 11 ft Latitude: 7 12 57.891 N +E/-W -1142.76 ft Easting ; 696863. ft Longitude: 1 24 43.067 W Position Uncertainty: 0.00 ft Casing Points MD TVD ft ft Diameter Hole Size Name in in 13151.82 8634.00 4.500 6.125 41/2" Formations MD TVD Formations Targets Dip Angle Dip Direction Name Description Dip. Dir. TVD ft +N/-S ft +E/-W ft Ma Northi ft .Map Easting ft <--- Latitude -> Deg Min Sec <-- Longitude --> Deg Min Sec 12-37 Cont T3 Rev 1 8617.00 6534.15 1354. 5937707.00 98047.00 70 14 2.154 N 148 24 3.703 W 12-37 Cont T3 Rev 2 8634.00 6534.15 13 9 5937707.00 047.00 70 14 2.154 N 148 24 3.703 W 12-37 Cont T3 8639.00 6534.15 1 .59 5937707.00 698 7.00 70 14 2.154 N 148 24 3.703 W 12-37 Cont T2 8644.00 5931.07 926.69 5937093.00 69763 00 70 13 56.223 N 148 24 16.140 W 12-37 Cont T2 rev 1 8664.00 5931.07 926.69 5937093.00 697635. 70 13 56.223 N 148 24 16.140 W 12-37 D T1 8694.00 5516.9 444.20 5936666.49 697163.50 70 13 52.151 N 148 24 30.160 W 12-21 1000' Target 8713.00 4175 9 354.68 5935323.00 697109.00 0 13 38.955 N 148 24 32.763 W -Circle (Radius: 1000) Plan Section Information MD Incl Azim TVD ft deg deg ft 9715.00 47.00 0. 00 8688.77 9735.00 49.40 0. 00 8702.10 • 9965.09 10048.42 90.00 105.00 351. 351. 00 00 8780.41 8769.57 10198 42 105.00 351. 00 8730.74 . 10311.80 90.00 5. 00 8715.9 + /-S ft +E/-W ft DLS Build Turn deg/100ft deg/100ft deg/100ft Target d 906.56 -488.02 0.00 0.00 0.00 0.00 3921.47 X88.02 12.00 12.00 0.00 0.00 4131.68 -506.85 18.00 17.65 -3.91 346.32 4213.06 -519.73 18.00 18.00 0.00 0.00 4356.16 -542.40 0.00 0.00 0.00 0.00 4467.90 -546.06 18.00 -13.23 12.35 136.07 • • • Sperry-Sun ~ BP Planning Report Company: BP Amoco Date: 5/30/2008 Time: 12:51:26 Page: 2 Field: Prudhoe Bay Co-ordinate(NE ) Reference: Well: 12-37 Plan, T e North Site:. PB DS 12 Vertical (TVD) Reference: 41'GL+28.5=69.5 .0 Well: 12-37 Plan Section (VS) Reference: Well (O.OON,0.00 ,1 1.71Azi) Wellpath: 12-37 Plan Survey Calculation Method: .Minimum Curv n; Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TF Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft d 10542.28 90.90 46.48 8714.02 71.00 -448.15 18.00 0.39 18.00 .64 11729.61 90.90 46.48 8695.34 5 8.53 412.69 0.00 0.00 0.00 .00 11772.09 92.70 49.36 8694.00 55 .98 444.20 8.00 4.24 6.79 7.98 12-37 D T1 12408.62 92.70 49.36 8664.00 593 07 926.69 0.00 0.00 0.00 0.00 12-37 Cont T2 rev 1 12698.15 92.21 31.98 8651.50 6149. 1114.48 6.00 -0.17 -6.00 -91.23 13151.82 92.21 31.98 8634.00 6534. 1354.59 0.00 0.00 0.00 0.00 12-37 Cont T3 Rev 2 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DL MapN MapE TooUCo ft deg deg ft ft ft ft ft de 100ft ft ft 9715.00 47.00 0.00 8688.77 8619.77 3 6.16 3906.56 -488.02 .00 5935032.40 696273.64 Start Dir 1 9735.00 49.40 0.00 8702.10 8633.10 37 .76 3921.47 -488.02 12.00 5935047.30 696273.25 Start Dir 1 9752.28 52.43 359.07 8713.00 8644.00 375 87 3934.88 -488.1 18.00 5935060.71 696272.79 12-21100 9800.00 60.81 356.85 8739.23 8670.23 3792.3 3974.66 -489. 18.00 5935100.43 696270.30 MWD+IFR 9900.00 78.48 353.13 8773.89 8704.89 3881. 4067.66 -497 1 18.00 5935193.17 696259.55 MWD+IFR 9965.09 90.00 351.00 8780.41 8711.41 3942.78 4131.68 - .85 18.00 5935256.94 696248.95 MWD+IFR 10000.00 96.28 351.00 8778.50 8709.50 3975.37 4166.10 12.30 18.00 5935291.20 696242.61 MWD+IFR 10048.42 105.00 351.00 8769.57 8700.57 4019.84 213.06 19.73 18.00 5935337.94 696233.95 End Dir : 1 10100.00 105.00 351.00 8756.22 8687.22 4066.44 62.26 -527.53 0.00 5935386.93 696224.87 MWD+IFR 10198.42 105.00 351.00 8730.74 8661.74 4155.36 4 6.16 -542.40 0.00 5935480.40 696207.56 Start Dir 1 10200.00 104.80 351.20 8730.34 8661.34 4156.79 435 7 -542.64 18.00 5935481.90 696207.28 MWD+IFR 10300.00 . 91.58 3.58 8716.08 8647.08 4252.33 4456. -546.95 18.00 5935580.22 696200.41 MWD+IFR 10311.80 90.00 5.00 8715.91 8646.91 4264.03 4467 -546.06 18.00 5935592.00 696200.98 MWD+IFR 10400.00 90.37 20.87 8715.63 8646.63 4351.93 45 .5 -526.38 18.00 5935678.17 696218.42 MWD+IFR 10500.00 90.76 38.87 8714.63 8645.63 4446.55 4 .94 X76.79 18.00 5935765.78 696265.74 MWD+IFR 10542.28 90.90 46.48 8714.02 8645.02 4482.78 671.00 -448.15 18.00 5935797.57 696293.56 End Dir : 1 10600.00 90.90 46.48 8713.11 8644.11 4530.19 4710.74 06.31 0.00 5935838.39 696334.35 MWD+IFR 10700.00 90.90 46.48 8711.54 8642.54 4612.33 4779.60 33.80 0.00 5935909.11 696405.03 MWD+IFR 10800.00 90.90 46.48 8709.96 8640.96 4694.4 4848.45 - 1.30 0.00 5935979.83 696475.71 MWD+IFR 10900.00 90.90 46.48 8708.39 8639.39 4776. 4917.31 -1 .80 0.00 5936050.54 696546.39 MWD+IFR 11000.00 90.90 46.48 8706.82 8637.82 48 .74 4986.16 -116. 0.00 5936121.26 696617.07 MWD+IFR 11100.00 90.90 46.48 8705.24 8636.24 4 0.88 5055.01 -43. 0.00 5936191.98 696687.74 MWD+IFR 11200.00 90.90 46.48 8703.67 8634.67 23.02 5123.87 28.71 0.00 5936262.70 696758.42 MWD+IFR 11300.00 90.90 46.48 8702.10 8633.10 105.16 5192.72 101.21 0.00 5936333.41 696829.10 MWD+IFR 11400.00 90.90 46.48 8700.52 8631.52 5187.29 5261.58 173.72 0.00 5936404.13 696899.78 MWD+IFR 11500.00 90.90 46.48 8698.95 8629.95 5269.43 5330.43 246.22 0 5936474.85 696970.46 MWD+IFR 11600.00 90.90 46.48 8697.37 8628.3 5351.57 5399.28 318.72 0. 5936545.57 697041.14 MWD+IFR 11700.00 90.90 46.48 8695.80 8626. 5433.71 5468.14 391.22 0.0 5936616.29 697111.81 MWD+IFR 11729.61 90.90 46.48 8695.34 862 5458.03 5488.53 412.69 0.00 5936637.23 697132.74 Start Dir 8° 1 11772.09 92.70 49.36 8694.00 86 .00 5492.28 5516.98 444.20 8.00 5936666.49 697163.50 12-37 D T1 11800.00 92.70 49.36 8692.68 23.68 5514.36 5535.13 465.36 0.00 936685.19 697184.17 MWD+IFR 11900.00 92.70 49.36 8687.97 618.97 5593.44 5600.19 541.16 0.00 36752.19 697258.24 MWD+IFR 12000.00 92.70 49.36 8683.26 8614.26 5672.53 5665.24 616.96 0.00 5 6819.20 697332.32 MWD+IFR 12100.00 92.70 49.36 8678.55 8609.55 5751.62 5730.30 692.76 0.00 59 886.20 697406.39 MWD+IFR 12200.00 92.70 49.36 8673.8 8604.83 5830.71 5795.35 768.56 0.00 593 53.21 697480.46 MWD+IFR 12300.00 92.70 49.36 8669 8600.12 5909.79 5860.41 844.36 0.00 5937 0.22 697554.54 MWD+IFR 12400.00 92.70 49.36 866 .41 8595.41 5988.88 5925.46 920.16 0.00 59370 .22 697628.61 MWD+IFR 12408.62 92.70 49.36 86 .00 8595.00 5995.70 5931.07 926.69 0.00 593709 0 697635.00 12-37 Con 12500.00 92.57 43.88 9.79 8590.79 6070.53 5993.74 993.01 6.00 5937157. 697699.66 MWD+IFR 12600.00 92.40 37.87 55.45 8586.45 6157.73 6069.25 1058.36 6.00 5937234.5 697763.01 MWD+IFR 12698.15 92.21 31.98 8651.50 8582.50 6247.82 6149.62 1114.48 6.00 5937316.36 697817.02 End Dir : 1 12700.00 92.21 31.98 8651.43 8582.43 6249.56 6151.19 1115.46 0.00 5937317.95 697817.95 MWD+IFR 12800.00 92.21 31.9 8647.57 8578.57 6343.29 6235.95 1168.39 0.00 5937404.06 697868.65 MWD+IFR 12900.00 92.21 31. 8643.71 8574.71 6437.03 6320.71 1221.31 0.00 5937490.16 697919.34 MWD+IFR gent ar IS IS 1S 1S 1S 1S 1S 1S 7S 7S 4S 4S 2r AS 4S i9 ~S AS AS Sperry-Sun BP Planning Report ~- • ~ J .] Company: BP Amoco Date: 5/30/2008 Time: 12:51:26 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 12-37 Plah, Tru orth Site: PB DS 12 Vertical (TVD) Reference: 41'GL+28.5=69.5 69 Well: 12-37 Plan Section (VS) Reference: Well (O.OON,O.OOE, .71Azi) Weltpath: 12-37 Plan Survey Calculation Method: Minimum Curvatur Db: Oracle. Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE ToollCo ft deg deg ft ft ft ft ft deg/100ft ft ft 13000.00 92.21 31.98 8639.8 8570.86 6530.77 6405.47 1274.24 0.00 593757 .27 697970.03 MWD+IFR 13100.00 92.21 31.98 8636.00 8567.00 6624.51 6490.23 1327.16 0.00 5937 2.37 698020.73 MWD+IFR 13151.80 92.21 31.98 8634.00 565.00 6673.06 6534.13 1354.58 0.00 593 06.98 698046.99 Total Dep : 1 13151.82 92.21 31.98 8634.00 65.00 6673.08 6534.15 1354.59 0.00 59 707.00 698047.00 12-37 Con ent / \ WELL DETAILS Nvne 'N/-S ,E-W Nurahing Craving LeomOe l.ungittxle Slot I?-37 Plan -1481.41 -1142.76 SY31140.11 696863.34 7U'I2'S7.891N 148'?4'OJA67W N/A 60 50 3 25 5 0 COMPANY DETAILS SURVEY PROGRAM DP Amoco Dep[h Fm Ueplh To Sorvey/Plan Tuul ~~Iculaliun McOxd' Mmimwn Curvanue 9715.W 17151.8? PlanneJ: l?-37 wP S.U V25 MWD'IFR-MS F.rtur Sysrcm: ISC W SA Scan Methrd: Trav CylinOer Nonh rrtm snrlaa: nupr;ral caning Wamiog M~~h~vl: Rules Dnu~d From Colour To MD 0 250 zso soo 500 750 750 1000 1000 1250 1250 1500 ~ 1500 1750 '~ 1750 2000 ~ 2000 ~- 2250 2250 2500 2500 2750 2750 3000 3000 ---- 3250 3250 - - ~ 3500 3500 3750 3750 4000 \', 4000 800 8000 250 8500 00 8750 9000 0 0 9250 1 92 0 9500 1?-i7 Plan W'es I2-l7A Crmt n~lameJ W I?-17, I?-37reoameJ YDI raremweuparn: ea7PnlPlan Tie oo MU: 9715.W R ~ Damm: 41'GL-.28.5-6Y.5 6Y Wk V.Sccrion Origin Ongm S[amng Angle ~N/-S 'C:/-W From TVD 1171° O.W 0.1X1 ?81X1 LEGr:ND 01-I U (01-101. Major Rink 01 ~IS (Ill-III XIinur l/2U - UI-I%1111-181. Mina 01-18(111 -18A' nxir l/?1X1 01-30(01- a1ur lGyk III-i I-30n1. Mujrn Risk ~ _ 1?-I_'AI, Mjur Risk ?U (12 DUI. Major Risk 12-2 0 11 2-'_OAI. M jar Rink 12'_1 (I. 211. Minm l/1W ~^-°- 12-J7 Plen 112-37PB1 Plan). NOERAORS 12x7 rmn 1?-J7 WP 5.11 9750 10000 0 2 5 0 ANTI-COLLISION SETTINGS Inmrpolation Method:MD Interval: 25.00 Depth Range From: 9715.00 To: 13151.82 Maximum Range: 1512.38 Reference: Plan: 12-37 WP 5.0 75 240 9A~/ ~, 100 ~~\ 12-21 125 1-13 Minor risked 21 Plan 1-18 Minor risked 150 (will be removed upon approval ) 160 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to CI 120 Pre Plans Removed. See AC Scan for Plans Parents Profile @ No Errors SCCTION UETAILS ~~\anl Sec MD Inc Ni TVD N/-S E/-W Ulog TFace VSec Target jV 91 Y715.Iq 47.W OW %688.77 391W.56 -088.0? O.W O.W 3726.Ib 9735.W 49.40 nW 8702.10 79?1.47 -088.02 12.W O.W 3740.76 3 YY650Y YO IMI 3511p 8780.41 4111 G8 -50685 IgW 7461? 3942.78 4 1004802 IUS./Xl i51 W 8769.57 4211.06 -519.73 IRW U.W 41119.84 5 IOIY84'_ IOS.W JSLW 8730.74 4156.14 -54200 U.W O.W 4155.36 6 10311.80 90.W S.W 8715 HI 4467.Y0 -546 U6 18.W 136 U7 4'_64.W 7 111543 ~8 W.W 46.48 8714 U? 467100 348.15 1%Iq 88.64 448'_.78 8 11729.(rl YO.YU 46.48 8695.34 54%8.51 412.6Y 0.(MI O.W 5458.03 Y 1177204 42.7U 4976 86901X1 SSI6.Y% 444.20 8.W 57.98 549'_?8 I?37 UTI III I _'408.6'_ 9?.7U 49.16 8664.W 591107 926 G9 0 W 0. W 5995.70 1?-37 Cure T? rev I II I?6)8.15 Y2.21 ]1.98 8651-50 6149.6? 1114.48 6W -91.21 6247.82 12 1315 L8'_ 9'_?I 31-98 8634.W fi514-IS 1354.59 O.W OW 6673.08 12-37 Cum T3 RCV2 re Separation [SOft/in] • ~ Sperry-Sun . Anticollision Report • • • Company: BP Am Date: 6/2/2008 Time: 14:25:46 Page: 1 Field: Prudh y Reference Site: PB DS 1 Co-ordinate(NE) Reference: WeIL' 12-37 Plan, True N h Reference Well: 1 27 Plan Vertical (TVD) Reference: 41'GL+28.5=69.5.69.0 Reference Wellpath: 12-37 Plan Db: OraGe GLOBAL SCAN APPLIED: All well the within 200'+ 1 00/1000 ofreference -There are TIL~eYd~s~is in this fi2titlcipal Plan & NNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9715.00 to 13 1.82 ft Scan Method: Trav Cylinder N h Maximum Radius: 1512.38 ft Error Surface: Ellipse + Casi Survey Program for Definitive Wellpath Date: 5/5/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 28.00 9715.00 Planned : 12-37Pb1 Wp .0 V14 (0) CB-GYRO-SS Camera based gyro Ingle shots 9715.00 13151.82 Planned : 12-37 WP 5.0 5 MWD+IFR+MS MWD +IFR + M ul ' tation Casing Points MD TVD Diameter Hole Size Name ft ft in in 13151.82 8634.00 4.500 6.125 4 1 /2 Summary <----------- Offset Wellpath --- ----> Reference Offset Ctr-Ctr Go Allowable Site Well Wellpath MD MD Distance. rea Deviation Warning ft ft ft ft ft PB DS 01 01-10 01-10 V2 794.30 9225.00 814.68 627.13 187.55 Pass: Major Risk PB DS 01 01-13 01-13 V2 1 2.64 9950.00 763.0 876.55 -113.53 FAIL: Major Risk PB DS 01 01-18 01-18 V9 Out of range PB DS 01 01-18 01-18A Plan VO Plan: 1 1128 12 11303.72 103 0 6743.49 -6639.79 FAIL: Major Risk PB DS 01 01-30 01-30 V1 13095. 9350.00 88 .09 698.61 187.48 Pass: Major Risk PB DS 01 01-30 Plan 01-30a V3 Plan: 0 13093. 9275.00 9 .08 698.22 206.86 Pass: Major Risk PB DS 12 12-12 12-12A V6 10140.30 10075.00 7 2.17 602.49 139.68 Pass: Major Risk PB DS 12 12-20 12-20 V7 10225.00 0425.00 1 47.82 632.28 515.53 Pass: Major Risk PB DS 12 12-20 12-20A V17 9724.64 75.00 58.00 619.99 838.01 Pass: Major Risk PB DS 12 12-21 12-21 V1 9881.89 9 0.00 859.66 1043.80 -184.14 FAIL: Major Risk PB DS 12 12-37 Plan 12-37PB1 Plan V1 Plan: 9725.00 97 .00 0.10 0.44 -0.34 FAIL: NOERRORS Site: PB DS 01 Well: 01-10 Rule Assigned: Major Risk Wellpath: 01-10 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis tr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS sing/H tance Area Deviation Warning. ft ft ft ft ft ft deg deg n ft ft 13095.54 8636.17 8400.00 7868.50 134.84 56.43 76.53 44.55 1082. 436.49 645.81 Pass 13085.48 8636.56 8425.00 7891.60 134.83 56.67 77.49 45.51 1068.0 443.62 624.47 Pass 13075.49 8636.94 8450.00 7914.74 134.82 56.90 78.47 46.49 1054.15 450.83 603.32 Pass 13065.58 8637.33 8475.00 7937.91 134.82 57.13 79.48 47.5 1040.48 8.12 582.36 Pass 13055.74 8637.71 8500.00 7961.11 134.81 57.37 80.52 48. 1027.11 4 .48 561.63 Pass 13045.98 8638.08 8525.00 7984.35 134.80 57.60 81.58 4 0 1014.04 472. 541.15 Pass 13036.30 8638.46 8550.00 8007.62 134.80 57.83 82.67 .69 1001.29 480.3 520.93 Pass 13026.69 8638.83 8575.00 8030.91 134.79 58.07 83.79 1.81 988.88 487.86 501.01 Pass 13017.16 8639.19 8600.00 8054.24 134.78 58.30 84.94 2.96 976.81 495.39 481.43 Pass 13007.70 8639.56 8625.00 8077.60 134.77 58.53 86.12 54.14 965.11 502.92 62.19 Pass 12998.31 8639.92 8650.00 8100.99 134.77 58.74 87.33 55.35 953.77 510.37 44 40 Pass 12988.96 8640.28 8675.00 8124.41 134.76 58.95 88.5 56.58 942.77 517.78 424. Pass 12979.65 8640.64 8700.00 8147.84 134.76 59.16 89. 57.84 932.12 525.13 406.9 Pass 12970.39 8641.00 8725.00 8171.31 134.75 59.37 91 1 59.13 921.85 532.40 389.45 Pass 12961.17 8641.35 8750.00 8194.79 134.74 59.58 9 42 60.44 911.95 539.57 372.38 Pass 12951.99 8641.71 8775.00 8218.30 134.74 59.79 3.76 61.78 902.46 546.63 355.83 ss 12942.85 8642.06 8800.00 8241.84 134.73 60.00 5.13 63.15 893.38 553.55 339.83 P s 12933.76 8642.41 8825.00 8265.39 134.72 60.21 96.52 64.54 884.72 560.31 324.42 Pa 12924.71 8642.76 8850.00 8288.97 134.72 60.42 97.94 65.96 876.51 566.88 309.63 Pass 12915.71 8643.11 8875.00 8312.57 134.71 60.6 99.39 67.40 868.75 573.24 295.50 Pass 12906.75 8643.45 8900.00 8336.19 134.70 60 4 100.85 68.87 861.45 579.37 282.08 Pass Alaska Department of Natural sources Land Administration System ~ Page 1 of '~ .~ 7r.~~i ~~.=.erg,., ;~,~~,~ Pf~ts f~~c=~r~~r's Se~t~ch Sfate Cabins (~1~#tll~~!€~iFJE'C~S ~~ Alaska DNR Case Summary File T e• ADL File Number: 28329 ~-~+ Printable_Case File_Summary YP .~ __~_. ~ µ _._........_......._. _. _...; See Township, Range, Section and Acreage? Yes No __Y_. New Search LAS Mendr i Case Abstract ~ Case Detail i Land Abstract File: aDL 24329 ~`'~`'F~ Search for Status Plat Updates ~ti of (l~~!(1-~'~UQS Customer: 00010%377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 74 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Corse Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2501.000 Date Initiczted.~ 05/28!1965 Office of Prinrarv Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U "l oirnshr~~: U l ON Ra~r,,e~: 015E Section: 0~ .5'e~clinu .~1crc~s: fi=~0 Search Plats Meridian.' l' Tuirn~~hi/~: O1(1N haf~~re: 015E .S"ec~~ron: 06 .S'~~clru~t .~ic~r~e.~~: 60~) Meridian.' L' l ~~tirf~.ehr/~: 0 I UN l~~n~~rc~: 0151., <5'r~clron: 0 ~ .S~~~ctiun :-l cr~cs: (, l Nferidiar2: l ! l rnrnsh~j~.~ 01ON l~~m~~c~: O I ~ L: .~'~~riion: 08 S~c°clrnrr ; lcre~s: 6=~0 Legal 1)cscrihtiou OS-?8-196 * ~ *SALE NOTICE LEUAL DESCRIPTION* C7=1-1~9 TION-RISE-UMW, 6, 7,8 201.00 U- 3- 7 ~n taf Case Su mark Last updated on 09/04/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28329&... 9/4/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~' l .~- ~a~ :. ;::,c; _~~~~ ;~; ~ ~ ~ ;t_ ~'^rorcfiar`s SearciaState Cabins ~I~tue~ ~~11'~S Alaska DNR Cane Summary File Type ADL„„ File Number: 2s33or~? t~ printable Case File_Summary See Township, Range, Section and Acreage? ~' Yes ~"'~ No New Search l..AS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract _ ~,. /'[!e: AUL 28330 ''~'~' ~ Search for Status Plat Updates A c,l~ O~~~O-~; ~0(lti Custorl~~r: 000107377 BP EXPLORA~IlON (ALASKA) WC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~_ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2512.000 Date Initiated: OSI28/1965 Office of Primary Responsibility: DOG DN OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED 1.1~~rrdian: U %nn~nship.~ O~ON R~n~ge: Ol>I: .5'c'~~Irorr~ 17 Srclir~n:9c~r~s: 640 Search Plats alc~rrclian: l_i ~uirri.~Ftr/~: O ] (1N Pcrr~,~~c~: U f ~ L S'~~~~iun: I S S~ c~Ir~,ri .-l~~j~c.~~: 6 i ~ 1 /~~ri~li~rn: l ! 7~~icn.~lzi/>: Ol (IN /~u~t,~r<~.~ U f ?l ,~'c~c:iu~r.~ l ~) ,ti'~c~lrurt .ac~rc~~.~ 61 ll~~riclru».~ 11 7ini~nsfrr/~: 01(1\~ Ru~l,;c~: 011: ,C~>~I[t)rt: ~0 S'c~ctinr~,1c°r~~s: 6=10 Leal Detici-iption 0~ -2'-1965 * x `SALE NOTICE LEGAL DESCRIPTION* Cld-160 'L'ION-RISE-UM U.18.I9,20 212.00 U- 3- 7 Last updated on 09/04/2008. http://www.dnr. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=283 30&... 9/4/2008 TRANSMITTAL LETTER CHECK,I,IST WELL NAME f ,~~ f~ ~~ PTD# a?O~ ~~-~ /Developmeint~ _ Service _____ Ex lorato _ Non-Conventional Well p h' - S~b~pdic Test FIELD: ~.c°!/~,~D~ ~~y POOL: r~.~~/.l'~DE' l~A}~~'t _ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS ~yyAT (OPTIONS) ~~. FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing (If last two digits in well API numb are Permit No. _, AP[ No. SO-_ 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 acquired for the pilot h~i,- .~,~.~ (~' all records, data and logs be clearly differentiated in both well name ( PH) and API number (SO = ,.~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and p uce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. "" ` "` "'" All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu et zones. Non-Conventional please note the following special condition of this permit Well production or production testing of coal bed mejhane is not allowed for (name of win antic after (Comoanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity.lComnanv Name) must contact the Commission to obtain advance approval of such water welt testing DrO~faRl. rt<w: rig inane WELL PERMIT C HECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY 12-37 Program DEV Well bore sag PTD4: 2081440 Oo mpany BP EXPLORATION~ALASKA) ItdC__ Initial ClasslType DEV I PEND GeoArea 890 Unit 11650 On10ff Shore Q_n___ Annular Disposal Administration 1 Pe[mitfl~ attached - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate- - - - - - - - - - - - - _Yes _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 Un~uewell.nameandnumbe[--------------------------- -----Y~- - --- 4 Well located in a_definedpool- - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 5 WelUocatedProPerdistancef[omdrillingunit_boundary-_-_--_-_-_ ----- --Yes----- ----------------------~ -- ---- -- - -- - - -- -- - - -- 6 Weil located Proper distance from oilier wells- - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficieatacreegeayailablein-drilling~rnit____----__-_------- ---------Yes----- --2560 acres.----_--_-_-------------- -- -- - -- - ---- -- 8 If deviated, is utellbore Plat.included - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Ope[atoronlyaffectedPa~Y -- - -- -- - - - -- - -- -Yea- -- -- -- -- -- - -- -- -- ----- --- -- -- -- - -- ----- 10 Ope[atorbas_appropriatebond'lnforoe---------------------- -- ------Yes---.- --@IarlketSond#6154193•--.------------------------ - -- - - -- - --- 11 Pe[mitr~anb4issuedwithoutoonsentationorder------------------- ---------Yes----- ------------- ------- ------- - ----- --- ----- - - -- --------- Appr Date 12 Pe[mitoanbeissuedwithRUtadministrative_approval---------------- ---------Yes.---- ------------------- ------- - -- -- -- -- -- --- -- -- --- --- - -- 13 CanpertnitbeaPProvedbefore15~laywaft---------------------- ---Yes----- ---.----------- ------- -- ----- --- --- - - ~ -- - - -- ACS 1017!2008 14 Well located lvithin erQe and_sSrata author[zBd bY-Inle~ion 0[de[ # (pit l(}~ in.commenis)_(For_ _HA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - 15 AJlwelJs_ulithUl(4-milearea-of review tdentified(Fo[se_nncewell only)------ ----------NA----__ -- -- -- --------------- - -- ----------- --- -- -- - 16 PJe-produced injector, duratiRn of Pre-p[oduction less than 3 moatils- (Por service well only) - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 .tyanconven, gas_rAnformslo AS31,05.030([.1.A)~G,2.A-D} - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conduckorst[in9-provided---- -- -- -- - -- - -------- Yes. -- - - -- -- - - - --- - -- -- --- -- -- -- --- - ----- -- 19 SudacecesirlgRrotectsallknownUSDWs_______-------------- -------- N?------ -_NOaquifers,A104B,_Conclusion.5.___-__-----.------------------------ -- 20 CMT-vol adequafe_to circulate_on coaduct9r8, surf_csg - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 CMT-voi adequate_to tie-in long string to sl~rf ca9 - - - - - - - - - - NO - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT will cover-ahkoown-Productive horizons_.--------_._----.- ------.--Yes---- ---------------------- - - -- -- - -- - -- - - - --- - - 23 Casipg designs edequaie fo[ C~ T, B &_parmafcast - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - 24 Adequate tankage-or feserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Y~ - - - - - - -Rig equipped with steel pits, No reserve pit plarlned._ All waste-to approvEd disposal well(s). - - - - - - - - _ - - - - 25 a 10.403 for abandonment been approved . - - - - re-d[iil bes If a - - - - - NP'- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 , _ - Adequate weil4ore separation proposed- - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - _ - - _ .Proximity analysis perFotmed, Traveling cylinder path calculated, Gyros possible in surface-hole, - - _ _ - - _ - - - 27 If diverter-re4uired, does itmeet re9ulatiens - - - - - - - - - - - - - - -Yes - - - Yes - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Maximum expected formaiipn pressure 7,2-EMW. M!AI planned up to 11.1 ppg in 8,75" hole and 8,6_ppg in_zone. _ Appr Date 28 Dulling fluid program schematic & equip listadequate- - - - - - - - - - - - - - - - _ - - - _ - - - - - - - - - - TEM 1018!2008 29 30 BOPI=s,-do iheymeetregulatioa - - - - - - - - - - - - - - BOPE_press rating approp[iate; test to_{put psig irr c9mments)- - - - - - - - - - - - - - - -Yes - - - - - - - - - -Yes - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - _ MA$P calculated at 2462 psi, 3500_psi_BOP test_pianned, _ _ _ - - - - - - - - - - - - - _ - - _ - - - - _ - - 31 Choke_manifokl complies wIAPI_RP-53 (May 84}- - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work willoccu[withoutoperationshutdown---------------------- -----_--Yes----- -------------------- - -- -- -- ---- - - -- - -- -- --- 33 Is presence of H?$ gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ - . _ - _ H2$ is reported_at DS 12.-Mud should preclude H2$on_rig~ R~.Itas sensors and alarms.- - - - - - - _ - - - _ _ - _ 34 _Mechanical,condition of vrells wdhin AOR yenfied (FCrsernce well onh!} - - - - - - - - - - - - - - ~- - - - - - - - - - - - - - - - - - - - - - Geology 35 Permitean be issued wlo hydrogen sulfide meas~,res - - - - - - - - - - - - - - - - - - - - - - ~io_ - _ . _ - - -Pad-D$12 is a H2S pad; Max level H2S well 12.03=300ppm (1017103).- _ _ - - - - . - - - - - - . - - _ _ _ - _ - _ - 36 t)atapresented on potential overpressurezones- - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - _ - - Appr Date 37 Seismicanalysis of shailowgas zones- - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 101712008 38 Seakedconditionsurvey-(ifoff_-shore)----------------------- ------ -- ~---- - -- - - -- --- ----- -- -- - -- - -- - - -- -- 39 Contactnamelphoneforweekly_progressreports[exploratorycnly]------- ----------Yes_-_- _--TravisP@iterr5&4.4511.--__-._-------__-----_--------------------------- -- Geologic Commissioner. Engineering Public Date: Commissioner. Date m sinner Date Q ~Q~~~Qv