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Home My WebLink About207-130• • Image Project Well Hi~tor~ File Gover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~~ ~ Well History File Identifier Organizing (cone) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: „wo=,ed iiiumuuuiuu DIGI AL DATA Diskettes, No. ~. ^ Other, No/Type: a~~a~~e,a,a iiuuuiuiiiiiiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: r /s/ Y {' Project Proofing III II~I~I I~III II III BY: aria Date: Q /s/ Scanning Preparation ~ x 30 = J + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: + ~ ~ 1 ~ a lsl Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: aria Date: ~ / ~~ /s/ + ' 1 Stage 1 If NO in stage 1, page(s) discrepancies/were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II ~I I I) II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III'll II'I II P P 10/6/2005 Well History File Cover Page.doc • 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 May ' / 3 18, 2012 �. a y A,' ► c,101#1ELi AUG 1 7 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) A -Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A -03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A -04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 ----7 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 _ NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA _ 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 _ NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 £~ .~~ ne '~ ., f~ ,~~~ ,.~. ~~ ..~.w 4 ~`, .q .~~. ~ ~ ~ -. MICROFILMED 6/30/2010. DO NOT PLACE ANY NEW MATE RIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071300 Well Name/No. PRUDHOE BAY UNIT A-12A MD 10938 TVD 8911 REQUIRED INFORMATION Mud Log No Operator BP EXPLORATION (ALASKA) INC Completion Status 1-OIL Current Status 1-OIL Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX, Memory CNL, C Well Log Information; Log/ Electr Data Digital Dataset Type Med/Frmt Number Name __- ---- og Neutron Log Log Run Scale Media No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 25 Blu 8020 10772 Open 3/4/2008 MCNL, GR, CCL, CNL w/Carrier 17-Jan-2008 ~Q DDS ~ w/Carrier 17-Jan-2008 C••feti~.~ .,^ Graphics ,~D D Asc Directional Survey Rpt Directional Survey .ED C Las 16214~duction/Resistivity Rpt LIS Verification C Lis 17117~nduction/Resistivity Induction/Resistivity ~g Induction/Resistivity og Gamma Ray See Notes Well Cores/Samples Information: Completion Date 1/19/2008 API No. 50-029-20515-02-00 UIC N 8900 10938 Open 3/10/2008 8900 10938 Open 3/10/2008 8879 10937 Open 4/11/2008 ATR, RPM, GR, RAM, ROP, RPD 8870 10936 Open 11/13/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 8870 10936 Open 11/13/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 25 Col 8926 10936 Open 11/13/2008 MD MPR, GR 15-Jan-2008 25 Col 8926 10936 Open 11/13/2008 TVD MPR, GR 15-Jan-2008 25 Col 8926 10936 Open 11/13/2008 MD GR 15-Jan-2008 2 Col 8870 10936 Open 11/13/2008 Depth Shift Monitor Plot Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071300 Well Name/No. PRUDHOE BAY UNIT A-12A Operator BP EXPLORATION (ALASKA) INC MD 10938 TVD 8911 Completion Date 1/19/2008 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? ~/ N Chips Received? Y /~' Formation Tops ~ N Analysis Y / N Received? Comments: API No. 50-029-20515-02-00 UIC N Compliance Reviewed By: __ Date: o -~___ ~~~ • • s ~/-® BAKER HVGNES Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA'f1UN (ALASKA) 1NC CUUN'1'Y NUKI'H SLUYE BUKUUGH WELL NAME A-12A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 11/I 1/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1748055 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Ferson Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: /1 ao~~ ~3 Page 1 of 1 • • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: A-12A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) ao~ i3o ~~~i ~- LAC Job#: 1748055 Sent by: Catrina Guidry Date: 11/11/08 Received by: Date: - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (yU %/) lb 1-66L3 Baker Hughes INTEQ ~~'~ .~'; ~ 7260 Homer Drive ~~GI$S Anchorage, Alaska 99518 Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 -----~ Date 04-11-2008 Transmittal Number:92955 ~s° r ~~i-~'~A ~W~LL DATA TRANSMITTAL Enclosed are the l~~alcrials listeid' below. (BPXA FIELD LOG DATA) r you nave any questions, please contact llouglas llortch at the YllC; at 564-4y 13 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: C-35B c7C~ -(~q ~~ (0 2 (5~ Y-01 AP61 ~~_~~ ~! (o ~! (o Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~ ~ N S ~~ BAKER NUGNES INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Te1907-267-6600 Fax 907-267-6623 To Whom It May Concern: March 7, 2008 Please find enclosed directional survey data for the following wells: p-t~3 OS-13B 15-45BPB 1 15-45B 18-32B C-35B Enclosed for each well is: tea copies of directional survey reports lea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: U ` ,State of Alaska AOGCC DATE: (6 ~ ~ Cc: State of Alaska, AOGCC v~u?-130 02/28/08 ~~i~t~~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Woll .Inh ~! Inn rln ..tin n.,~.. 15-25A 12014000 LDL / -~jCa '~ 02/20/08 A-12A 11963077 MCNL sr 01/19108 1 GNI-04 12031448 TEMP SURVEY (REVISED) ~(j~- ~ (~ 01122108 1 1 P2-32 11968730 USIT - '- 3- 02/13/08 1 1 17-02 11996384 USIT /~Q - ~' 02/17/08 1 1 Y-07A 11962781 SCMT '}- j ~ " 'R 02/03/08 1 1 P2-58 12031456 USIT /~jQ - t/ 02/25/08 1 1 MPH-12 12005205 MEM INJ PROFILE ~ - j~ 1t ~ 02/15/08 1 1 4-14/R-34 11975755 USIT v2e ~ 02/25/08 1 1 S-126 11968731 JEWELRY/PERF/SBHP ~- ~ ~ 02/15/08 1 1 rLtASt HI:IINUVVLtUGt KtIaIY I tSY SIGNING ANU Kt 1 UKNING VNt GVPY EACH TV: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ' Anchorage, Alaska 99508 ~ ` '' Date Delivered: w~ /y i_s ~ ~ '; 13(~~2 :. ~ ,~-~r,.~ . NO. 4612 Company: State of Alaska C~ Alaska Oil & Gas Cons Comm Dp~~ C ~,. Attn: Christine Mahnken 333 West 7th Ave, Suite 100 , ~~ ~.~ ~ Anchorage, AK 99501 ~ Q~ Field: P.Bay,Aurora,GNI,Pt.Mac,MilnePt,Endicott S'p 0~~ ~0y3~ BL Color CID 2 °~ ~ ~7 Q~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth ~ Received by: Reviewed By: Safety Valve & Well Pressures Test Report P.1. Snpr~~P~ =z~zz"~`' Comrn pad; PsU_A InspDt: 2/11/2008 Inspected by Lou Grimaldi Interval InspNo svsLG080213083056 Belated lnsp: Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Chuck Wyatt Reason Miscellaneous Src: Inspector Well Data Pilots - -- - - ---- SSV SSSi --- -'--- ---__ _ ~ S{iutln Dt iY'el! T >>e --- -- J1 ~ Y{ell Pressures ~ Gus !.i t Waiter ~ Comneer~ts f 1 Well Permit Separ Set UP Test Pest Test Date SI OiI,WAG,GINJ, _ Inner Outer "Tubing _ _ _ _ Number Nwnber PSI PSI Trip Code Code Code GAS,CYCLE, S[ PSI PSl PSI Yes/No Yes/No -12A 2071300 120 160 125 I, P Y l I ~ 1-OIL ~ _ ~ - ~ 1910 i 2 ~ 260 I - ~, Yes ~ No - - ,_ - -- - J _ ~ • Comments Performance Wells Components Failures Failure Rate 1 2 0 ~~ • Thursday, February 14, 2008 ~~/ ~~~%~ " '4 ~ ALASKA OIL AND GASTCONS RVA~T'ION COMMISS O ~~~ ~~~~1~~~ ~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG F~EB 1 ~ ?Q~~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. vyti~ggas9ll 8~i - 20AAC 25.105 zoAAC zs.1,o ®DevelopmertAR~ ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Ab ~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/19/2008 ,(~ 207-130 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 1/10/2008 50-029-20515-02-00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 1116' FNL 920' FE 1/15/2008 ' PBU A-12A - , L, SEC. 35, T11 N, R13E, UM Top of Productive Horizon: 8. KB (ft above MSL): 77.4' ~ 15. Field /Pool(s): 4269' FNL, 2046' FEL, SEC. 26, T11 N, R13E, UM Ground (ft MSL): 47.27' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 1100' FSL, 2371' FEL, SEC. 26, T11 N, R13E, UM 10860 8882 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 654447 y- 5949331 Zone- ASP4 10938 8911 ADL 028286 " TPI: x- 653276 y- 5951434 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 652949 y- 5951517 Zone- ASP4 N/A 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071 MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX, Memory CNL, CCL, RESf,J/~/~~1~~~ : ~ , .~DM~ ~p7Y7?/~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING. DEPTH MD SETTING DEPTH TVD HALE AMOUNT WT. PER FT. GRADE TOP $OTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 113' Surface 113' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2677' Surface 2677' 17-1/2" 3720 cu ft Arcticset 9-5/8" 47# L-80 Surface 8804' Surface 8614' 12-1/4" 1210 cu ft'G' 130 cu ft Arcticset 7" 47# L-80 8311' 8166' 8730' 8-1/2" 396 cu ft Class'G' s-s~1s° x z-pie" 6.2# / 6.16# L-80 8252' 10938' 8113' 8911' 3-3l4" x 4-1 /8" 208 cu ft Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 SPF 4-1/2", 12.6#, 13Cr80 8399' 8144' MD TVD MD TVD 9500' - 9$70' 5846' - 5825' CEMENT SOVEEZE ETC 25.' ACID FRACTURE 9880' - 9960' 8825' - 8804' , , . , 9995 - 10050' 5795' - 5751' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10070' - 10110' 8776' - 8766' 8200' Freeze Protected with Diesel 10390' - 10550' 8763' - 8795' 10610' - 10730' 8806' - 8837' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): February 7, 2008 Gas Lift Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 2/7/2008 12 TEST PERIOD 1420 1104 863 45 679 Flow Tubing Casing Press: CALCULATeD OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 380 1800 24-HOUR RATE.• 2841 2209 1726 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. w~; ~*iOfE, i ~~ None ~ ._.."~ ~ ~ F~t~ ~ ~ ~ODB t~ `~. Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~~,1 '~ G. 8. GEOLpGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, fist intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Sag River 8898' 8701' None TSHU / TSHA 8925' 8726' TSHB 8959' 875T TSHC 8978' 8774' Top of Sadlerochit 9010' 8801' 45SB / Z26 Lower 9076' 8846' 45SB / Z2B Lower 9994' 8795' Top of Sadlerochit 10173' 8753' Top of Sadlerochit 10378' 8759' 45SB 10576' 8800' 42SB /Zone 4A 10908' 8899' Formation at Total Depth (Name): Ivishak zone 4A 10938 8911' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that reg 'ng is true and correct to the best of my knowledge. i ~/ Si d ~'' ~ ~ gne ( ( g Sondra tewman Title Drilling Technologist Date PBU A-12A 207-130 Prepared ey Name/IVumber. Sondra Stewman, 564-4750 Drilling Engineer: Greg Sarber, 564-4330 Well Number Permit No. / A royal No. INSTRUCTIONS GeNeRa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). treM 8: The Keily 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 TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only _- TREE _ . 4" CN~f UVELLHEFID= FMC ACTUATOR= OT1S KB ELEV = 77.43' __ BF. ELEV = 48.56' ____._ KOP = 8926' Max Angle = _w -_ 1 ~7 ~ 9712' ~.,.......M._ Daum MC3 = 9087' Datum TV'D= 8840' SS 13-3/$" CSG, 7211:, L-8d, [7 =12.347" ~~ ~'j`i?~' f~~Y6~ltaftCi t~ = 2.37" 9~` 2593' -~9-518" DV PFfR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3151 3151 1 MMG DOME RK 16 02/01 /08 4 4725 4725 1 MMG SO RK 20 02/01/08 3 6009 6003 14 MMG DMY RK 0 12/06/07 2 7083 7015 19 MMG DMY RK 0 12!06/07 1 7991 7876 22 MPv1G DMY RK 0 12/06/07 $113' 4-1/2" X-NIP ID=3.813" $"1q4' 9-5/8" x 4-1/2" BKR S-3 PKR, ID = 4.75" $°179' ~-~ 4-1/2" OTIS X NIP, ID = 3.813" I TOP OF T' LNR 4-112" TBG, 12.6#, 13Cr80, VamTop, .0152 bpf, ID = 3.958" 9-518" CSG, 47#, L-8d, ID = 8.681" PERFORATION St.~MA RY f~EF LQG; S MCNL tON {l '1t X08 ANGLE ATTC)PPERF`.1"""" ,"'". Note: Refer to Production DB for histoncai perf data SIZE SPF ' INTERVAL OPnlsgz DATE 2" 6 ~ _ ' 870. ,,1 2" s 99~~.; ~ a~ wa 01 r1 s101~ 2" fi 10070 - 1;~ 7 , 0 O 01!18108 2" 6 10390 - , r~:;} t~ O {}111 sl~s 2" 6 10610-?(J7:~w f? 01f1€3108 $252® -~TOPOF3-3?16" LNR; 1D=??? $272' 3-112" XN X NIP, ID = 2.75" 3-1I2 x 3-3I1-" <, $39$' 4-1 i2" TBG TAIL: ID = 3.958" wi 5.5" OD {Fluted) WLEG 8500' TOP OF CE(y1ENT , ~ ~ .., '~ •u` Q __ ___ _ .._,~ __ ~-- --- _ -?m----~-~ - ~.._ _ _ ___ _ ___ - -----il DATE REV BY COMMENTS DATE REV BY COMMENTS 41/04/80 ORtGINAi. CQtNPLETICIN d1 /26108 !TL!-l COE2RECTIONS 06!01!90 RfN(i 021091Q8 TELlPJC GLV Ct0 (02/01f01t} d5118C01 RPUKAK CORRECTIONS 14104102 BMJKAK WANERSAFETYNOTE 10117/42 DAVtKK F[SH kl1?1~i~t~ ?~FcC`rl<~1 yTD SlL~E(R6~CIt 1A-12A} PRUDHOI; 3AY UNIT WELL: ,` -'4 PERMffNct: ~ ' I Y,~~d SEC 35, T11 N; 813E BP Exploration {Alaska}. SA NOTES: WARNING: RADIO TRANSM ITTER IN WEATHER MONITORING SHACK MUST BETURNED OFF ,~, BEFORE ANY WELL WORK INVOLVING IXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR. ""*4-112" CHROMETBG**" 2089' 4-1/2" X-NIP ID=3.813" ., i BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ! Code ~ NPT Phase Description of Operations 1/4/2008 21:30 - 23:00 1.50 MOB P PRE Jack up rig and prepare to move off of DS 15-04B well. 23:00 - 23:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for moving rig. 23:15 - 23:45 0.50 MOB P PRE Move rig off of well and down back side of DS 15 and onto access road to front of DS 15. 23:45 - 00:00 0.25 MOB N RREP PRE 1/5/2008 00:00 - 04:00 4.00 MOB N RREP PRE 04:00 - 04:30 0.50 MOB P PRE 04:30 - 12:00 7.50 MOB N RREP PRE 12:00 - 12:50 0.83 MOB N RREP PRE 12:50 - 13:30 0.67 MOB P PRE 13:30 - 17:30 4.00 MOB N WAIT PRE 17:30 - 00:00 6.50 MOB P PRE 1/6/2008 00:00 - 01:45 1.75 MOB P PRE 01:45 - 02:00 0.25 MOB P PRE 02:00 - 02:30 I 0.501 MOB I P I I PRE 02:30 - 08:00 ~ 5.50 ~ BOPSUF{ P ~ ~ PRE 08:00 - 14:00 6.00 BOPSU P PRE 14:00 - 17:30 3.50 RIGU P PRE 17:30 - 18:15 0.75 BOPSU P PRE 18:15 - 19:15 1.00 RIGU P PRE 19:15 - 20:15 1.00 RIGU P PRE 20:15 - 20:30 0.25 BOPSU P PRE While moving the rig on the access road between the back drillsite and front drillsite of DS 15, at 23:45 hrs, on 01/04/2008, the front hydraulic drive gasket failed on the drillers side of the rig. A fine spray of hydraulic oil left a thin spray film on the road for about 100 yds, about 2 ft. wide. Driller shut down rig drive system as soon as the spill was seen. The rig crew put dykes under the dripping drive motor and cleaned up area around drive motor. The tourpusher called 5700 spill response and notified them of hydraulic oil spill on road. We estimated the spill volume at 30 gals. Access to back of drillsite is blocked by rig. Work on drive motor to move rig to front of DS 15 and clear access. Refer to remarks section of this report. Work on rig drive motor to allow movement of rig and clear DS 15 access road. Repair hydraulic drive motor on rig to move rig forward and clear DS 15 access road. Move rig to front part of DS 15, so access road is clear. Clean rig tire and rim. Remove hydraulic drive motor. Build and install temporary cover on gear box Plug hydraulic lines and PT. OK Warm up moving system to 100F. Restab drive bushing into reel. Move held up by 27E move. Wait on security. Move rig to A pad. -30F, 5 mph wind. Move rig to A pad. Position rig in front of well. -30F. SAFETY MEETING. Review procedure, hazards and mitigation for backing over well. Back rig over well and set rig down with no incidents. ACCEPT RIG AT 02:30 HRS, 01/06/08. N/U BOPE. Move in cuttings tank and continue with general rig up. Spot trailers and M/U hardline. Test BOP. Witnessin4 BOP test waived by An ,[` . representative John Crisp. Install packoff on lubricator. PU injector and stab onto packoff, PU injector and stripper. Thread tugger cable thru the packoff and reconnect to air tugger. RU & pull coil across. MU CTC. Fill CT. PT inner reel valve and bulkhead. Reverse circ at max rate for E-Line slack management. 5.0 bpm, 2000 psi. Cut off coil to find E-Line. Cut 20' coil. M/U CTC and pull test SAFETY MEETING. Review procedure, hazards and Printed: 1/24/2008 2:44:23 PM ,~ ~ , a ~ BP EXPLORATION Operations Summary Report Page 2 of 15 Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date I From - To 'Hours Task Code NPT Phase Description of Operations 1/6/2008 20:15 - 20:30 0.25 BOPSU P PRE mitigation for pulling BPV with lubricator. 20:30 - 00:00 3.50 BOPSU P PRE Rig up lubricator, press test with 1500 psi, try to pull BPV. No recovery, grease and ice on top of BPV. Jet top of BPV. Attempt to pull, no recovery. Bullhead 30 bbls water at 75F at 3 bpm. 1/7/2008 100:00 - 04:00 I 4.001 BOPSURN I DPRB I WEXIT 04:00 - 10:00 I 6.001 BOPSUR N I DPRB I WEXIT 10:00 - 11:30 I 1.501 BOPSURN I DPRB I WEXIT 11:30 - 12:55 1.42 CLEAN P WEXIT 12:55 - 13:15 0.33 CLEAN P WEXIT 13:15 - 13:40 0.42 CLEAN N DFAL WEXIT 13:40 - 16:10 2.50 CLEAN N DFAL WEXIT 16:10 - 19:00 2.83 CLEAN P WEXIT 19:00 - 20:30 1.50 CLEAN P WEXIT 20:30 - 22:00 1.50 CLEAN P WEXIT 22:00 - 00:00 2.00 CLEAN P WEXIT 1/8/2008 00:00 - 00:30 0.50 CLEAN P WEXIT 00:30 - 00:45 0.25 EVAL P WEXIT 00:45 - 02:00 1.25 EVAL P WEXIT 02:00 - 03:00 1.00 EVAL P WEXIT 03:00 - 03:40 0.67 EVAL P WEXIT 03:40 - 04:10 I 0.50 I EVAL I P I I W EXIT Replace BPV recovery threaded spear and try again. Made 3 attempts with no success, each time the bottom 1/2" of threads are worn off. The threads are not getting started. Bullhead 40 bbls thru BPV at 4 bpm to clear thread area. Well is dead. Try again to M/U threads and pull BPV. No luck. Change threaded spear and try again. Made up to BPV threads OK, but was not able to pull BPV. Check recovery tool. Put Tioga heater on tree. Bullhead 30 bbl thru BPV. Wait on day BPV crew. PU nozzel and wash BPV little returns injecting thru BPV. PJSM./Check threads with plug on "T" bar. OK. PU lubricator RIH and retrieve PBV, Valve had significant dehydrated gel packed around it, About one quart. Some of gel not fully hydrated. LD lubricator. MU BHI BHA#1 cleanout and logging run. RIH to 1200. Circulating at min rate. Short reported by MWD. POH Pop off well. Set back injector and test MWD. Wire pulled from anchor, were not pumping at high enough rate to move wire forward. Cut coil, install new CTC and rehead. PT to 4000 psi. RIH. Circulate at 3 bpm C~3 900 psi returns at 118 bbp. Continue to RIH at .6 bpm, no returns. Log down with GR for depth tie-in from 8880-9050 at 150 fph. Correct -4' CTD. Pump 0.4 bpm, no returns. Log down with CCL from 8100' to PBTD. Tag PBTD at 9273'. Pump 0.4 bpm, no returns. POH. pump 1.6 bpm while POH. No returns. Pump across the top to fill tubing with slick fluid for chrome tubing. Lay out BHI MWD logging BHA #1. SAFETY MEETING. Review procedure, hazards and mitigation for M/U BHA #2, BTT ball catcher BHA. M/U SWS E-Line Anchor and BTT ball cathcers BHA #2. Drifted SWS E-Line Anchor with 7/8" ball. BHA OAL = 5.85'. RIH with SWS anchor / BTT ball catchers BHA to 4015'. Circ 0.8 bpm with no returns. Insert 5/8" Phenolic ball and displace with 2% KCL water, double slick. Circ. at 2.5 bpm at 900 psi. Slow down to 1.5 bpm at 50 bbls. Ball on seat at 54.1 bbls. Coil volume was 58.4 bbls. Sheared at 1300 psi. Pins set for 2040 psi. Losing returns, so do not have a full column of fluid on backside of coil. Insert 3/4" Phenolic ball and displace with 2% KCL water, Printed: 1/24/2008 2:44:23 PM ~.~ ' BP EXPLORATION Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 1 /6/2008 Rig Release: 1/19/2008 Rig Number: Date ~ From - To ', Hours Task Code NPT Phase 1/8/2008 03:40 - 04:10 ~ 0.50 EVAL ~ P WEXIT 04:10 - 04:50 0.67 EVAL P WEXIT 04:50 - 05:00 0.17 EVAL P WEXIT 05:00 - 05:10 I 0.17 I EVAL I P I I W EXIT 05:10 - 06:00 I 0.831 EVAL I P I I W EXIT 06:00 - 06:30 0.50 EVAL P I I W EXIT 06:30 - 08:05 I 1.581 EVAL I P I I W EXIT 08:05 - 10:00 f 1.921 EVAL i P i I W EXIT 10:00 - 10:30 0.50 EVAL P WEXIT 10:30 - 11:45 1.25 EVAL P WEXIT 11:45 - 12:15 I 0.50 I EVAL I P I I W EXIT 12:15 - 13:00 0.75 EVAL P WEXIT 13:00 - 14:00 1.00 EVAL P WEXIT Page 3 of 15 ~ Spud Date: 10/14/1980 End: 1 /19/2008 Description of Operations double slick. Circ at 2.5 bpm at 900 psi. Slow down to 1.5 bpm at 45 bbls. Ball on seat at 54.0 bbls. Sheared at 2300 psi. Pins set for 2040 psi. Well almost full of fluid after pumping 110 bbls for 2 balls POH. Circ across the top at 1.5 bpm. Lay out BHA. Found the 5/8" Phenolic ball had broken in half. This could cause a problem during a liner job. Recommend that we use Aluminium balls to prevent this problem. SAFETY MEETING. Review procedure, hazards and mitigation for running liner and BTT SELRT M/U 2-7/8" bull nose guide shoe with no holes, pup jt, pre-drilled pup jt, 2 float shoes, pup jt, Landing cllr, 5 jts, 2-7/8" STL Liner, XO and 4 jts, 3-3/16" TCII Liner, XO and X Nipple Crew change. SAFETY MEETING. Review procedure, hazards and mitigation for running liner and BTT SELRT. MU 3-1/2" STL, 10' pup Jt, BTT Deployment Sleeve and BTT SELRT. Liner total length of liner = 313.82'. M/U XO, Hyd Disc, Locking swivel , SWS E-Line Anchor and CTC. Liner and running tools BHA = 325.1'. RIH with liner. Up wt 43K. Dwn wt 23K. Tag at 9276'. Top of liner = 8959.2', corrected depth. PJSM for liner release and cementing. Walked thru the sequence of events for the entire job with this new SELTR tool. Discussed job hazards in particulare, the extreme weather. -35F with slight breese. Position reel in ball drop position. Launch 5/8" AI ball with 500 psi. Circulate ball 2.6 bpm, C~ 44 bbl slow to 0.75 bpm. Bump total 68 bbls. Rock rate. Shut in and wait 10 min. Recommend pumping 1.0-1.5 bpm to move ball better. Pump 5 bbl 2# bio. AL Ball on seat at 88 bbls. sheared at 2100 psi. Correct press. Pick up with 41 K. Liner looks free. Stack 10K wt back down on liner. Batch mix 20 bbl cement. Press test cement line w/4000 psi. Stage 15.8 PPG, G Cement, 2.0 bpm, 800 psi, Pumped 17.4 bbls. Pump Biozan to cementers. Zero in/out totalizers on end of cement. Coil capacity = 58.5 bbls. Liner capacity = 1.84 bbls to landing collar. Total = 60.34 bbl. Displace Cement with 30 bbl, 2# Biozan, 2.7 bpm, 1600 psi. No returns. Stage KCL water. 2.7 bpm, 1600 psi, no returns. 40 bbl displ, 2.7 bpm, 1600 psi, no returns 42.9 bbl displ, cement at shoe. pump press is increasing as expected. 45 bbl displ, 2.7 bpm, 1920 psi. no returns. 50 bbl displ, 2.7 bpm, 2050 psi, starting to get returns. 55 bbl displ, 2.7 bpm, 2100 psi, 1.0 bpm returns. Printed: 1/24/2008 2:44:23 PM ' ,~ ' BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~, From - To Hours ' Task Code NPT -1- 1/8/2008 ~ 13:00 - 14:00 1.00 EVAL P 14:00 - 14:15 ~ 0.25 ~ EVAL ~ P 14:15 - 14:50 I 0.58 I EVAL I P 14:50 - 16:45 ~ 1.92 ~ EVAL ~ P 16:45 - 18:00 1.25 EVAL P 18:00 - 20:30 2.50 EVAL P 20:30 - 21:00 0.50 EVAL P 21:00 - 23:30 2.50 WHIP P 23:30 - 00:00 I 0.501 WHIP I P 1 /9/2008 100:00 - 00:30 I 0.50 I WHIP I P 00:30 - 02:30 ~ 2.00 W H I P ~ P 02:30 - 03:00 I 0.501 WHIP I P 03:00-03:15 I 0.251WHIP IP Spud Date: 10/14/1980 Start: 1 /6/2008 End: 1 /19/2008 Rig Release: 1/19/2008 Rig Number: Phase ~' Description of Operations WEXIT 56.5 bbls. Stop displacement. This leaves 2 bbls cement in coil. Pick up 11 ft to 9261'. Up wt with no pump was 39.5K. Stinger out of LW P and seals above deployment sleeve. Pump 7 bbls displacement, to displ 2 bbl cement and 5 bbl Biozan to backside of coil. 2.2 bpm, 1350 psi. No returns. Stop pump. RIH again. 28K dwn wt. Set down 10K at same depth so seals are in. Pump 1.6 bpm to bump plug. Pump 4.5 bbls. Did not bump plug. Liner came up hole with us when we pulled up. Very light liner. 2000 lbs. Pick up 20' and RIH to same depth and stack wt. Pump 4 bbls at 1.5 bpm. No bump plub. Pick up full speed while pumping. Pick up 30 ft. RIH with pumps on. Partial returns. RIH to PBTD, stack 10K. No increase in pump press. WEXIT Work pipe up and down to try and release from liner. Work pipe with and without pump. RIH to PBTD with BHA. WEXIT Bullhead KCL water down backside of coil to clear any cement from 7" liner and 4-1/2" tubing. Bullhead 5.0 bpm at 1400 psi. Backside volume = 97 bbls. Bullhead 150 bbls. WEXIT POH while pumping 1.0-2.0 bpm down backside with slick KCL water. WEXIT UO BHA. WEXIT R/U to pump slack management. Circ. across top of stack thru kill line to shaker to clean stack. Fill coil w/ rig water. Reverse circ thru coil at 4.50 bpm, 4500 psi. 3 times. Heard e-line move for a total of 2 min. Reverse circ 3 bbls air thru coil. WEXIT Cut coil to find E-Line. Cut 39' of coil. WEXIT M/U SLB Dipple CTC, Re-head eline. meg test eline okay. PT to 4000 psi. WEXIT M/U BOT 4-1/2" x 7" whipstock setting BHA #4. WS, #10 J-Hydraulic setting tool, BHI CoilTrak. Overail BHA length 81.33' WEXIT Continue M/U whipstock setting BHA #4. Stab injector. WEXIT Open EDC. RIH w/ whipstock BHA #4. RIH at 80 fpm, 0.4 bpm, no returns. At 6500', started getting nearly full returns. Returns were mostly diesel. WEXIT Log GR tie-in to PDC log from 8920'-8955'. -5.5' correction. Up wt 41 k. Dn wt 30K. PUH to 8,926' top of whipstock. Orient TF to 0 deg highside. WEXIT Top of Whipstock at 8,926'. Close EDC. Began pumping at 0.5 bpm. Bring up pump to 3000 psi, pressure dropped to 300 psi. Clear indication of release. Shut off pumps, RIH slow, set down 3K. P/U clean. Printed: 1/24/2008 2:44:23 PM r ~ ~' `OL BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ~ Hours Task ~ Code NPT ~ Phase Description of Operations 1/9/2008 03:15 - 05:10 1.92 WHIP P WEXIT POOH to surface, 100 fpm, 1.5 / 0.6 bpm 05:10 - 06:00 0.83 WHIP P WEXIT S/B injector. UD whipstock setting BHA #4. 06:00 - 06:20 0.33 WHIP P WEXIT M/U Cementing nozzle BHA #5. OAL = 14.55'. 06:20 - 08:00 1.67 ZONISO P WEXIT RIH with cementing BHA. circ at 0.7 bpm. 50% returns. Tag pinch point on whipstock at 8940' and correct depth to 8930'. -10' correction. 08:00 - 08:15 0.25 ZONISO P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for pumping cement job. 08:15 - 09:05 0.83 ZONISO P WEXIT Batch mix 20 bbl, 15.8 ppg, G Cement. circ at 1.8 bpm, 1.3 bpm returns, 620 psi. 09:05 - 10:00 0.92 ZONISO P WEXIT Stg 4 bbl water. Press test cement line to 4000 psi. Stg 20.3 bbl, 15.8 ppb, G Cement, 2.1 bpm, 1000-2200 psi. Stop pump. Pump Biozan to cementers to clean line. Slowdown Stage 30 bbl 2# Biozan to displace cement. 20 bbl displ, 2.0 bpm, 700 psi, 1.7 bpm returns. Stage 2% KCL water. 30 bbl displ, 2.0 bpm, 470 psi, Close choke 35 bbl displ, 2.0 bpm, 420 psi, 310 psi SIWHP, CMT at nozzle. 40 bbl displ, 2.0 bpm, 360 psi, 385 psi WIWHP, 5 bbl cmt out 45 bbl displ, 2.0 bpm, 1300 psi, 850 psi SIWHP, 10 bbl cmt out. Open choke and Lay in 10 bbl CMT,1.5 bpm, pull at 40 fpm, hold 300 psi WHP 50 bbl displ, 1.5 bpm, 930 psi, 420 psi choke press, 1 bpm returns. 58 bbl displ, 1.5 bpm, 1300 psi, 400 psi choke press, Bio to nozzle at 8650' Stop pump, Close choke and pull to safety at 8300'. 10:00 - 11:30 1.50 ZONISO P WEXIT Wait 15 min. Sqz 1 bbl, 50 psi WHP. wait 10 min. Sqz 1 bbl, 50 psi WHP, Wait 10 min. Sqz 1 bbl, 100 psi, Wait 10 min. Sqz 1 bbl, 100 psi, Wait 10 min. Sqz 1/2 bbl, 100 psi, Wait 10 min. Not getting a sqz, WHP bleeds off slow to zero May be leaking into Sag River perfs above whipstock. Sqz 1/2 bbl, 100 psi, Sqz 1/2 bbl, 100 psi. Cement is Sqz away to top of Sag River perfs and still bleeding off. Open choke and circ at 0.5 bpm. 11:30 - 11:50 0.33 ZONISO P WEXIT RIH while circ at 0.5 bpm. Full returns. RIH to 8920'. No cement. Circ at 1.5 bpm. 1.45 bpm returns.. 11:50 - 14:00 2.17 ZONISO P WEXIT POH. Circ. bottoms up. No cement to surface. 14:00 - 15:00 1.00 STWHIP P WEXIT M/U 3.80" Window milling BHA with 3.80" HCC Diamond Window mill, used string reamer, 2 Jts 2-3/8" PH6 and BHI Coiltrak tools. OAL = 112.67'. ~ 15:00 - 17:00 2.00 STWHIP P WEXIT RIH with Window milling BHA #6. ~~ Dry tag at 8928". Full returns with KCL water. Swap well to 2# Biozan. 17:00 - 20:00 3.00 STWHIP P WEXIT Mill cement down from 8927-8930' Mill 3.80" window thru 7", 29#, L-80 Liner. Start Milling at 8930' Printed: 1/24/2008 2:44:23 PM ~~ BP EXPLORATION Operations Summary Report Page 6 of 15 Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date II Frorn - To 'Hours Task j Code. NPT Phase Description of Operations 1/9/2008 17:00 - 20:00 3.00 STWHIP P WEXIT at 1 fph. Full returns. Multiple stalls trying to get window started. 20:00 - 22:00 2.00 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2800 psi, 1 fph. Milled to 8932.0'. 22:00 - 00:00 2.00 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2600 psi, 1 fph. Milled to 8933.9'. 1/10/2008 00:00 - 02:00 2.00 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2800 psi, 1 fph. Milled to 8936.0'. 02:00 - 04:10 2.17 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2800 psi, 1 fph. Exit 7" liner at 8937.7'. Window is 7.7' long. Mill to 8940.4' 04:10 - 04:30 0.33 STWHIP P WEXIT P/U and backream window. Ream down at 0.5 fpm. 04:30 - 04:45 0.25 STWHIP P WEXIT Mill formation to 8942' 04:45 - 05:00 0.25 STWHIP P WEXIT P/U and backream window. Ream down at 0.5 fpm. P/U and shut down pumps. Dry tag window -okay. 05:00 - 06:00 1.00 STWHIP P WEXIT Finish milling 10' of formation while swapping well to FloPro. 06:00 - 08:10 2.17 STWHIP P WEXIT POOH w/ window milling BHA #6. Full returns. 08:10 - 08:30 0.33 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for laying out milling BHA and M/U build BHA. Also held pre-spud well review meeting with crew. 08:30 - 09:00 0.50 STWHIP P WEXIT Lay out window milling BHA. 09:00 - 10:00 1.00 DRILL P PROD1 M/U Coiltrak Build BHA #7 with HCC BC bit #1, 3.2 deg Xtreme motor and BHI Coiltrak tools. OAL = 66. 10:00 - 11:45 1.75 DRILL P PROD1 RIH with Coiltrak Build BHA #7. Circ at 0.4 bpm, 950 psi. 11:45 - 12:15 0.50 DRILL P PROD1 Log GR tie-in. +5 ft TD. 12:15 - 16:30 4.25 DRILL P PROD1 Drill build section in Shublik. 2.6 bpm, 2900-3600 psi, 1-2K wob, Several stalls. Trouble keeping a HS toolface. Ream hole several times to try and get a highside TF. Drilled to 8961'. 16:30 - 18:00 1.50 DRILL P PROD1 Ream highside from 8945-8961. Ream up and down trying to keep highside, 3 times. 2.5 bpm, 2600 psi. Full returns. 18:00 - 19:15 1.25 DRILL P PROD1 PUH above window. Orient highside, ream hole down to bottom at 0.5 fpm. Tagged bottom and stalled. 19:15 - 20:30 1.25 DRILL P PROD1 Time drill from 8960' at 6-10 fph. Started getting 8% losses at 8962.5'. Drilled to 8965' 20:30 - 21:30 1.00 DRILL N SFAL PROD1 Hardline in reel started leaking. Pull up into casing and shut down pumps. Replace hammer union connection and clean up FloPro. 21:30 - 00:00 2.50 DRILL P PROD1 RIH to bottom. Back on bottom drilling Shublik. 2.6/2.6 bpm l~ 2900-3200 psi, TF 0, ROP 10 fph, WOB 1.5K, 22 deg incl, ECD 9.8. Hard drilling. Drilled to 8,971'. 1/11/2008 00:00 - 02:00 2.00 DRILL P PROD1 Drill build thru Shublik, 2.6/2.6 bpm @ 2900-3100 psi, TF 0, ROP 5 fph, WOB 2.5K, 22 deg incl, ECD 9.8. Hard drilling. 5-10% pyrite in samples. Multiple stalls. Trying to build inclination to drill away from original wellbore. Drilled to 8,976'. 02:00 - 04:15 2.25 DRILL P PROD1 POOH to check BHA 04:15 - 05:00 0.75 DRILL P PROD1 L/D drilling build BHA #7. Bit graded 5/8/0. 05:00 - 06:00 1.00 DRILL P PROD1 R/U for cutting coil. Cut 100' of coil for chrome management. 06:00 - 09:00 3.00 DRILL P PROD1 M/U SLB Dipple CTC, Re-head eline. Pull test and press test. M/U Build Coiltrak BHA #8 with Smith BC bit #2 and 3.2 deg Printed: 1/24/2008 2:44:23 PM • BP EXPLORATION Page 7 of 15 operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date ~ From - To ~ Hours Task Code NPT Phase Description of Operations 1/11/2008 06:00 - 09:00 3.00 DRILL P PROD1 Xtreme motor and Coiltrak tools. OAL = 66.09'. 09:00 - 10:30 1.50 DRILL P PROD1 RIH with Build BHA #8. Circ thru open EDC. 1.4 bpm, 1500 psi. 10:30 - 11:00 0.50 DRILL P PROD1 Log GRtie-in. +7' CTD. 11:00 - 13:30 2.50 DRILL P PROD1 RIH clean to bottom. Drill build section in Shublik. 2.6 bpm, 3000-3600 psi, 3-5K wob, 5R TF, 28 deg incl, 20 fph. Drilled to 9016'. 13:30 - 15:00 1.50 DRILL N DFAL PROD1 POH for failed DGS. 15:00 - 16:30 1.50 DRILL N DFAL PROD1 Change out DGS and Bit. Adjust motor to 2.9 deg bend. M/U Build Coiltrak BHA #9 with HYC BC Bit #3, 2.9 deg Xtreme motor and Coiltrak tools. OAL = 66.04' 16:30 - 18:30 2.00 DRILL N DFAL PROD1 RIH with Build BHA #9. Circ 1.4 bpm, 1500 psi. Stop at 8800'. Pull at 70 fpm, no pump, 40.OK up wt. RIH at 70 fpm, no pump, Dwn wt = 25.5K. 18:30 - 18:50 0.33 DRILL N DFAL PROD1 Tie-in to GR at 8890'. +1' correction. 18:50 - 19:00 0.17 DRILL N DFAL PROD1 RIH to bottom. Tag on depth. 19:00 - 21:00 2.00 DRILL P PROD1 Drill build thru Shublik, 2.5/2.5 bpm @ 2700-3100 psi, TF 0, ROP 25-35 fph, WOB 0.5K, 45 deg incl, ECD 9.7. Drilled to 9,064'. 21:00 - 00:00 3.00 DRILL P PROD1 Drill build section, 2.4/2.4 bpm ~ 2700-2900 psi, TF 15L, ROP 15-25 fph, WOB 0.5-1 K, 55 deg incl, ECD 9.7. Drilled to 9,113'. 1/12/2008 00:00 - 01:15 1.25 DRILL P WEXIT Drill build section, 2.4/2.4 bpm C~ 2650-2800 psi, TF 15L, ROP 15-25 fph, WOB 1 K, 68 deg incl, ECD 9.7. Drilled to 9,128'. 01:15 - 03:00 1.75 DRILL P PROD1 Drill build section, 2.25/2.25 bpm ~ 2500-3000 psi, TF 15L, ROP 25-35 fph, WOB 1.5K, 75 deg incl, ECD 9.8. Landed build at 9,165'. 03:00 - 05:30 2.50 DRILL P PROD1 POOH for lateral BHA. 05:30 - 06:30 1.00 DRILL P PROD1 S/B injector. UD drilling build BHA #9. Bit graded 1/1/i. 06:30 - 06:45 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U BHA. 06:45 - 07:30 0.75 DRILL P PROD1 M/U Lateral /RES BHA #10 with HCC BC Bit #4 and 1.4 deg Xtreme motor and Coiltrak BHA. OAL = 78.96'. 07:30 - 09:00 1.50 DRILL P PROD1 RIH with Build BHA #10. circ at 0.3 bpm and 960 psi. 09:00 - 09:20 0.33 DRILL P PROD1 LOG GR tie-in. +4.5". 09:20 - 10:00 0.67 DRILL P PROD1 Log MAD pass down with RES tool. Circ at 0.5 bpm, 1200 psi. 10:00 - 11:30 1.50 DRILL P PROD1 Drill Zone 4 lateral with RES tool. 2.6 bpm, 2950-3600 psi, 70L TF, 1-3K wob, 89 deg incl. Drilled to 9274'. 11:30 - 12:00 0.50 DRILL N SFAL PROD1 Pull up to window and check hardline. Pull to 7600'. Stop pump and secure reel. 12:00 - 15:00 3.00 DRILL N SFAL PROD1 Replace seal in 1502 E-Line hardline connection. Install E-Line to bulkhead. Test OK. 15:00 - 17:15 2.25 DRILL N SFAL PROD1 RIH at 10 fpm to thaw frozen coil, 100' between reel and injecter. Fluid out temp = 65 deg. Break circ after 2 hrs. 17:15 - 17:45 0.50 DRILL N SFAL PROD1 RIH to bottom. RIH clean thru window and to bottom. 17:45 - 20:00 2.25 DRILL P PROD1 Drill Zone 4 lateral with RES tool. 2.6/2.6 bpm, 2800-3600 psi, 90R TF, 1-3K wob, 89 deg incl., 60-90 fph, 9.8 ECD. Drilled to 9350' 20:00 - 20:30 0.50 DRILL P PROD1 Wiper trip to window. Printed: 1/24/2008 2:44:23 PM ~ ~ BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task 'Code'. NPT Phase Description of Operations 1/12/2008 20:30 - 22:00 1.50 DRILL P ~ ~ PROD1 Drill Z4 lateral, 2.5/2.5 bpm ~ 2800-3300 psi, TF 45R, ROP 22:00 - 22:45 0.75 DRILL P PROD1 22:45 - 00:00 1.25 DRILL P PROD1 1/13/2008 100:00 - 03:00 I 3.001 DRILL I P I I PROD1 03:00 - 04:30 1.501 DRILL P PROD1 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 05:15 0.25 DRILL P PROD1 05:15 - 05:40 0.42 DRILL P PROD1 05:40 - 06:00 0.33 DRILL P PROD1 06:00 - 08:00 2.001 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 11:00 2.50 DRILL P PROD1 11:00 - 12:10 I 1.171 DRILL I P I I PROD1 12:10 - 12:45 0.58 DRILL P PRODi 12:45 - 14:00 1.25 DRILL P PRODi 14:00 - 14:45 I 0.751 DRILL I P I I PROD1 14:45 - 15:00 0.25 DRILL P PROD1 15:00 - 15:15 0.25 DRILL P PROD1 15:15 - 15:45 0.50 DRILL P PROD1 15:45 - 17:00 1.25 DRILL P PROD1 17:00 - 17:50 I 0.831 DRILL I P I I PRODi 17:50 - 19:15 1.42 DRILL P PROD1 19:15 - 20:45 1.50 DRILL P PROD1 20:45 - 00:00 I 3.251 DRILL I P I I PROD1 60-110 fph, WOB 1 K, 87 deg incl, ECD 9.9. Stalling and stacking weight. Drilled to 9,433'. Wiper trip to window to see if drilling improves. Drill Z4 lateral, 2.6/2.6 bpm C~ 2900-3400 psi, TF 90R, ROP 30-60 fph, WOB 1.5K, 92 deg incl, ECD 9.9. Drilled to 9,474'. Drill Z4 lateral, 2.6/2.6 bpm C~ 3000-3300 psi, TF 120L, ROP 30-45 fph, WOB 1.5K, 92 deg incl, ECD 9.9. Drilled to 9,562'. Drill Z4 lateral, 2.6/2.6 bpm C~ 3000-3300 psi, TF 90L, ROP 30-45 fph, WOB 1.5-2K, 90 deg incl, ECD 9.9. Drilled to 9,600'. Wiper trip to window. Hole clean. Tie-in to GR at 8920'. +4' correction. RIH clean to btm. Very cold weather, -46F. Limit outside work. Drill Z4 lateral, 2.6/2.5 bpm C 3100-3400 psi, TF 90L, ROP 50 fph, WOB 2K, 90 deg incl, ECD 10.0. Drilled to 9617'. ~ Lost all returns at 9617' appears to be fault PVT = 305 bbls Drill past loss zone. 2.6 bpm, 3000-3300 psi, TF 90L, ROP 40-50 fph, WOB .8K, 91 deg incl, ECD 9.5. Gained 0.4 bpm returns at 9622'. Returns started fluctuating between 0.4-0.9 tam after 9626'. 1.0 bpm returns at 9640'. 1.5 bpm returns at 9677'. Drilled to 9681'. Wiper trip to window. Getting low on FloPro. Clean trip. FloPro on location. RIH clean to bottom. Circ new FloPro. Drill lateral, 2.5 bpm, 2600-3100 psi, 1.9 bpm returns, 10L TF, 97-106 deg incl, 60 fph, Drilled to 9796'. Drill lateral, 2.5 bpm, 2700-3200 psi, 2.0 bpm returns, 10L TF, 97-106 deg incl, 60 fph, Drilled to 9850'. Wiper trip to window. Clean hole. RIH clean to bottom. Drill lateral, 2.6 bpm, 2700-3200 psi, 2.4 bpm returns, 90L TF, 104 deg incl, 60 fph, Drilled to 9915'. Drill lateral, 2.5 bpm, 2700-3200 psi, 2.2 bpm returns, 90L TF, 106 deg incl, 90 fph, Drilled to 10,000'. Wiper trip to window. Clean hole. Log tie-in. Added 2' to CTD. RIH clean to bottom. Drill lateral, 2.5 bpm, 2700-3200 psi, 2.3 bpm returns, 100E TF, 104 deg incl, 90 fph, Drilled to 10,100'. Drill lateral, 2.5 bpm, 2700-3200 psi, 2.3 bpm returns, 100E TF, 104 deg incl, 90 fph, Drilled to 10,150' Wiper trip to window. Clean hole. Drill Z4 lateral, 2.5/2.3 bpm C~ 3000-3600 psi, TF 120L, ROP 50-90 fph, WOB 3-3.5K, 100 deg incl, ECD 9.9. Drilled to 10,212'. Drill lateral, 2.5/2.3 bpm @ 2800-3500 psi, TF 180R, ROP 10-30 fph, WOB 2-3K, 98 deg incl, ECD 9.9. Hard drilling, may have drilled into the base of the Shublik. Trying to drop inclination to get back into sand. Printed: 7/24/2008 2:44:23 PM ~ ~ BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task '; Code II NPT ~~ Phase Description of Operations 1/13/2008 20:45 - 00:00 3.25 DRILL P PROD1 Drilled to 10,237'. 1/14/2008 00:00 - 02:00 2.00 DRILL P PROD1 Drill lateral, 2.5/2.3 bpm ~ 2800-3300 psi, TF 180R, ROP 02:00 - 04:00 I 2.001 DRILL I P I I PROD1 04:00 - 06:10 I 2.171 DRILL I P I I PROD1 06:10 - 07:30 1.33 DRILL P PROD1 07:30 - 10:30 3.00 DRILL P PROD1 10:30 - 11:30 I 1.001 DRILL I P I I PROD1 11:30 - 12:30 1.00 DRILL P PROD1 12:30 - 12:50 0.33 DRILL P PROD1 12:50 - 13:30 .0.67 DRILL P PROD1 13:30 - 15:00 1.50 DRILL P PROD1 15:00 - 15:45 0.75 DRILL P PROD1 15:45 - 17:30 1.75 DRILL P PROD1 17:30 - 18:45 1.25 DRILL P PROD1 18:45 - 19:50 1.08 DRILL P PROD1 19:50 - 22:45 2.92 DRILL P PROD1 22:45 - 00:00 1.25 DRILL P PROD1 1/15/2008 100:00 - 01:30 1.501 DRILL P PROD1 01:30 - 03:15 1.75 DRILL P PROD1 03:15 - 03:30 0.25 DRILL P PROD1 03:30 - 04:30 1.00 DRILL P PROD1 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 06:30 0.501 DRILL P PROD1 10-20 fph, WOB 1-3K, 95 deg incl, ECD 9.9. Hard drilling, trying to drop inclination to get out of Shublik. Drilled to 10,256'. Drill lateral, 2.6/2.4 bpm C~ 3000-3400 psi, TF 180R, ROP 10 fph, WOB 1-3K, 92 deg incl, ECD 9.9. Slow drilling in Shublik, dropping inclination to get back into sand. Drilled to 10,275'. Drill lateral in Shublik, 2.7/2.5 bpm C~ 3000-3300 psi, TF 180R, ROP 15-25 fph, WOB 2-3K, 89 deg incl, ECD 9.9. Drilled to 10,300'. Wiper trip to window. Clean hole. Drill lateral in Shublik, 2.6/2.4 bpm @ 3000-3800 psi, TF 170 R, ROP 15-25 fph, WOB 2-3K, 76 deg incl, ECD 9.9. Drill lateral in Z4, 2.6/2.4 bpm ~ 3000-3800 psi, TF 90R, ROP 80 fph, WOB 2-3K, 74 deg incl, ECD 9.9. Drilled to 10450'. Wiper trip to window. Clean hole. Log GR tie-in. +4.5'. RIH clean to bottom. Drill lateral in Z4, 2.6/2.4 bpm ~ 3000-3800 psi, TF 60R, ROP 100 fph, WOB 2-3K, 80 deg incl, ECD 9.9. Drilled to 10,545'.• Drill lateral in Z4, 2.6/2.4 bpm C~? 3000-3800 psi, TF 60R, ROP 100 fph, WOB 2-3K, 80 deg incl, ECD 9.9. Drilled to 10587'. Wiper trip to window. Clean hole. RIH clean to bottom. Drill lateral in Z4, 2.6/2.4 bpm ~ 3000-3800 psi, TF 60R, ROP 100 fph, WOB 2-3K, 78 deg incl, ECD 9.9. Drilled to 10,655'. Drill lateral in Z4, 2.5/2.3 bpm @ 3000-3600 psi, TF 120L, ROP 70-100 fph, WOB 2-3K, 78 deg incl, ECD 10.0. Drilled to 10,750'. Wiper trip to window. RIH to bottom. Hole clean. Drill Z4 lateral, 2.6/2.4 bpm C~ 3100-3600 psi, TF 120L, ROP 80 fph, WOB 1.5-3K, 71 deg incl, ECD 10.1. Hole getting differentially sticky. Found some motor rubber over shakers. Drilled to 10,812'. Drill Z4 lateral, 2.6/2.5 bpm C~ 3200-3800 psi, TF 100L, ROP 60-80 fph, WOB 1.5-3K, 69 deg incl, ECD 10.2. Hole sticky. OWC came in at 10.755' MD. 8768' TVD. Drilled to 10,870'. W iper trip to window. Hole clean. Tie-in to GR. +5.5' correction. RIH clean to bottom. Drill Z4 lateral, 2.5/2.3 bpm C~3 3100-3600 psi, TF 115L, ROP 20-45 fph, WOB 2.5-4K, 68 deg incl, ECD 10.1. Drilled to 10,915'. Drilled Z4 lateral to TD at end of polygon at 10,938'. Printed: 1/24/2008 2:44:23 PM ~ ~ BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 1/15/2008 06:30 - 07:45 1.25 DRILL P PROD1 Wiper trip to window. Clean hole. 07:45 - 15:00 7.25 DRILL N WAIT PROD1 Pull to 8880', 50' above window. Open EDC. Circ. at 0.4 bpm, 0.2 bpm returns. WAIT ON WEATHER. WAIT ON LINER DELIVERY. _ UNABLE TO LOAD LINER AT STORES DUE TO COLD WEATHER. -44F. Wind changed direction and it warmed to -40F at 1500 hrs. 15:00 - 15:15 0.25 DRILL P PROD1 Log GR tie-in. On Depth. No correction. 15:15 - 16:30 1.25 DRILL P PROD1 RIH to bottom. Circ. new FloPro. RIH clean to bottom. Tag final corrected TD at 10,936'. 16:30 - 19:00 2.50 DRILL P PROD1 Log MAD pass to window. Lay in new FloPro liner pill while POH. Heat exterior pipe elevator motors with Tioga air heater to warm them up for loading liner onto rig. 19:00 - 21:00 2.00 DRILL P PROD1 POOH to surface. Flag coil at 8200' EOP and 6200' EOP. Liner arrived on location. Begin loading liner in pipeshed. Drift and strap liner. 21:00 - 00:00 3.00 DRILL N WAIT PROD1 Circ thru coil at 500' from surface thru open EDC. 1.63/1.54 bpm. FINISH LOADING 3-3/16" LINER IN PIPESHED. REMOVE THREAD PROTECTORS, DRIFT, AND STRAP. LOAD 2-7/8" LINER IN PIPESHED. LINER COULD NOT PREVIOUSLY BE LOADED IN PIPESHED DUE TO DELAY IN DELIVERY ASSOCIATED W/ COLD WEATHER. 1/16/2008 00:00 - 00:10 0.17 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for L/D drilling BHA. 00:10 - 00:45 0.58 DRILL P PROD1 PUH from 500' to surface. S/B injector. L/D lateral drilling BNA #10. Bit graded 1/2/i. 00:45 - 01:00 0.25 BOPSU P PRODi Funtion test BOPE -Okay. 01:00 - 02:15 1.25 DRILL N WAIT PRODi PREP 2-7/8" LINER IN PIPESHED. REMOVE THREAD PROTECTORS, DRIFT, AND STRAP. STORES WAS UNABLE TO DELIVER LINER AT AN EARLIER TIME DUE TO COLD WEATHER (BELOW -35 DEG F) 02:15 - 03:00 0.75 CASE P RUNPRD Prep for running liner. P/U BOT tools thru beaver slide. 03:00 - 03:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U liner. 03:15 - 06:00 2.75 CASE P RUNPRD M/U Indexing guide shoe, 1 jt 2-7/8" STL, Flt Cllr, Flt Cllr, 1 jt 2-7/8" STL, BTT Flapper check valve, BTT O-ring sub, 33 jts 2-7/8" STL, XO, 51 jts of 3-3/16" TCII liner, XO, 3-1/2" STL 10' pup jt, X Nipple, 3-1/2" STL 10' STL 10 pup jt. Filled liner at 35 jts in. 06:00 - 06:15 0.25 CASE P RUNPRD SAFETY MEETING. Crew change. Review procedure, hazards and mitigation for M/U liner with day crew. 06:15 - 10:00 3.75 CASE P RUNPRD M/U 50 jts of 3-3/16" TCII Liner. M/U XO, 3-1/2" pup jt, X Nipple, 3-1/2" pup jt, 3-1/2" pup jt and BTT Deployment Sleeve. Total length of liner = 2,686.78'. 10:00 - 13:30 3.50 CASE P RUNPRD M/U BTT 1 ", 20 ft Slick jt, XO, 1 jt CSH, 33 stds of 1-1/4" CSH, Printed: 1/24/2008 2:44:23 PM BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date ~I From - To Hours Task Code NPT Phase ' Description of Operations 1/16/2008 10:00 - 13:30 3.50 CASE P RUNPRD strapped and drifted each stand. Ave jt = 30.85'. 13:30 - 16:00 2.50 CASE P RUNPRD M/U 17 jts of 1-1/4" CSH in singles and 8' and 4' pups to space out. Fill annular area with water. Press test Slick jt and O-Ring sub, OK. M/U BTT Deployment sleeve and CTLRT. 16:00 - 17:10 1.17 CASE P RUNPRD M/U SWS E-Line Anchor. Press test CTC and Anchor. OK. M/U to BTT Swivel and CTLRT. BHA total length = 2,697.5'. 17:10 - 19:45 2.58 CASE P RUNPRD Circ. at surface at 0.25 bpm. Circ 6 bbls to ensure floats are clear. IH with 2-7/8" x 3-3/16" Liner inner strin and CTLRT. Circ at 0.2 bpm at 1400 psi. Correct depth at 6200' EOP flag to 8897.5'. -11.5' correction Up wt 45K, do wt 30K. Tag bottom at 10936' Up wt, 51 K, pumps at 0.2 bpm Losses still at 0.2 bpm. 19:45 - 00:00 4.25 CASE P RUNPRD Drop 5/8" steel ball w/ flo-pro, did not hear ball in coil. Pumped at 2 bpm at 3560 psi for 43 bbls. Got 2500 Ibs surface wt back while pumping at 2 bpm at 41 bbls away (possible release from liner). At 43 bbls away dropped rate to 0.5 bpm. Did not see ball land on seat at calculated coil volume of 57.8 bbls. Ramped pumps up and down between 0 and 1 bpm. Pumped 106.7 bbls w/ no indication of ball landing on seat. Drop 2nd 5/8" steel ball w/ flo-pro, launch w/ 1000 psi and confirm via hearing the ball. Pump ball at 2 bpm @ 3650 psi. Pump 40 bbls and drop rate to 0.6 bpm at 1600 psi. Pumped 64.4 bbls away. Begin ramping pumps up and down. P/U wt at 0.3 bpm, 42K Pumped 110 bbls away. w an ressure chan a to indicate ball landed on seat. 1/17/2008 00:00 - 03:30 3.50 CASE P RUNPRD Consult w/ town on plan Toward. Increase rate to 2.4 bpm at 4500 psi for 5 min. Brought rate down to 0.25 bpm. Up wt 35K. Surface weights indicate that CTLRT released from liner. Never saw pressure increase from ball landing on seat. Set back down & swap well to 2% double slick KCL ~ 2 bpm. 30 bbls KCL out shoe, up wt 35K Pumping at 2.0 bpm, 2500 psi. At 118 bbls of KCL away, pressured up to 4300 psi and dropped off. Indicated that ball landed on seat and sheared. Up wt, 36K 100 bbls KCL out shoe, up wt 36K Well swapped over to KCL, up wt 37K Losses have decreased to 3%, 2.39/2.34 bpm Haul used flo-pro to MI for reconditioning. RU cementers. 03:30 - 04:00 0.50 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for cementing liner with inner string. 04:00 - 06:00 2.00 CEMT P RUNPRD Stage 5 bbls rig water, PT cmt lines to 5000 psi. Stage 37 bbls 15.8 PPG, G Cement, 2.0 bpm, 3800 psi. Pump Biozan to cementers. Zero in/out totalizers on end of cement. Printed: 1/24/2008 2:44:23 PM ~ ~ BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date 'From - To Hours , Task Code NPT 1/17/2008 04:00 - 06:00 2.00 CEMT P 06:00 - 07:45 1.751 CEMT P 07:45 - 08:00 0.251 CEMT P 08:00 - 11:00 I 3.001 CEMT I P 11:00 - 12:00 I 1.001 CEMT I P 12:00 - 12:15 I 0.251 CEMT I P 12:15 - 16:00 3.75 EVAL P 16:00 - 17:40 1.671 EVAL P 17:40 - 19:10 I 1.50 I EVAL I P 19:10 - 20:45 1.58 EVAL N WAIT 20:45 - 21:30 0.75 EVAL P 21:30 - 22:45 1.25 EVAL P 22:45 - 23:00 0.25 EVAL P 23:00 - 00:00 I 1.00 I EVAL I P Spud Date: 10/14/1980 Start: 1 /6/2008 End: 1 /19/2008 Rig Release: 1/19/2008 Rig Number: Phase Description of Operations RUNPRD Coil capacity = 57.8 bbls. CSH capacity = 4.1 bbls. Total = 61.9 bbl. Displace Cement with 30 bbl, 2# Biozan Follow w/ KCL water. 20 bbl displ, 2.0 bpm, 2800 psi, 1.8 bpm returns 25.3 bbl displ, cement at shoe, zero out totalizer. pump press is increasing as expected. 30 bbl displ, 1.8 bpm, 3200 psi, 1.55 bpm returns 35 bbl displ, 1.8 bpm, 3600 psi, 1.55 bpm returns 40 bbl displ, 1.5 bpm, 2740 psi, 1.3 bpm returns 45 bbl displ, 1.5 bpm, 3200 psi. 1.3 bpm returns 50 bbl displ, 1.45 bpm, 3450 psi, 1.4 bpm returns. 55 bbl displ, 1.4 bpm, 3500 psi, 1.2 bpm returns. 58.5 bbl displ, 0.9 bpm, 1760 psi, 0.8 bpm returns 61.7 bbls. Stop displacement. This leaves 0.2 bbls cement in CSH. Out total = 33.4 bbls, Lost 3.6 bbls CMT to fault. Open choke to test floats. Floats held. Pick up 25 ft to 10906'. Up wt with no pump was 36K. Stinger out of o-ring sub and flapper check valve. Pump 5 bbls displacement, 0.5/0.4 bpm, to displ 0.2 bbl cement and 4.8 bbl Biozan to backside of coil. Pull CSH out of liner at 70 fpm, 0.6 bpm. RUNPRD POH clean thru liner. POH at 90 fpm while circ to replace CT voidage. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH. RUNPRD Lay out BTT liner running tools. Recovered both 5/8" balls on seat. Stand back 1-1/4" CSH. RUNPRD Rig maintenance, repaired leak in Koomey unit, welded on rig floor. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS MCNL/GR logging tools and RIH with CSH workstring. LOWERI M/U Mill and motor and MCNL/GR/CCL logging tools. M/U BTT MHA and RIH with 43 stds of CSH. M/U SWS MHA. BHA OAL = 2761'. SWS Cement UCA sample at 700 psi at 5 hours. LOWERI RIH with BHA #12 with mill, motor, 2 jts CSH, MCNL/GR/CCL and CSH. Circ at 0.3 bpm. LOWERI Log down from 8100' at 30 fpm with Memory CNL/GR/CCL. Circ. at 1.5 bpm. Got contaminated cement back to surface at 10.5 ppg. RIH thru top of liner clean. Tag bottom at 10,872'. LOWERi Wait on vac truck with 35 bbl liner pill. Circulate liner pill to bit. LOWERI Log up at 60 ft/min while laying in 20 bbl pert pill in liner. LOWERI POOH to surface. LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for laying down BHA and standing back CSH. LOWERI S/B injector. S/B 30 stands of 1-1/4" CSH in derrick, lay down the rest (28 joints). L/D logging/cleanout BHA #12. Printed: 1/24/2008 2:44:23 PM • • BP EXPLORATION Page 13 of ~ 5 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date !From - To ~ Hours I, Task Code NPT Phase Description of Operations 1/18/2008 00:00 - 03:00 3.00 EVAL P LOWERI Continue laying down CSH. Conduct safety meeting for pulling source out of tool. 03:00 - 04:00 1.00 EVAL P LOW ER1 Make up swizzle stick to jet BOP stack. Make 2 passes through the stack at 3 bpm. 04:00 - 04:35 0.58 EVAL P LOW ER1 Line up valves for liner lap test, slowly pressure up to 2,000 psi. 5 minutes - 1,780 psi, declining pressure increase it back to 2,000. 10 minutes - 1,263 psi 04:35 - 05:00 0.42 EVAL P LOW ER1 Pressure back up to 2,000 psi. 5 min - 1,436 psi 10 min - 1,296 psi 15 min - 1,212 psi 20 min-1143 psi Liner lap test failed. Bleed off pressure. 05:00 - 06:00 1.00 EVAL P LOW ER1 R/U to cut coil for chrome management. 06:00 - 06:30 0.50 EVAL P LOW ER1 Crew Change. SAFETY MEETING. Review procedure, hazards and mitigation for cutting 100' of coil. 06:30 - 07:15 0.75 PERFO P LOWERi Cut off 100' of coil with hyd cutter. 07:15 - 08:45 1.50 PERFO P LOWERI M/U SWS CTC and E-Line Anchor. Press test and pull test. 08:45 - 09:00 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for running 2" SWS pert guns. 09:00 - 11:40 2.67 PERFO P LOWERI Run 42, 2" SWS PJ perf guns and blanks, loaded 6 spf, as per program. 11:40 - 12:00 0.33 PERFO N WAIT LOWERI Wait on possible change in perforating. GEO decided to leave out one 40' set of perfs. 12:00 - 15:00 3.00 PERFO N MISC LOWERI POH with 18 guns. Change out 2 partial loaded guns and 1 fully loaded gun with 3 blank guns. RIH with 2" guns again as per modified program. 15:00 - 17:15 2.25 PERFO P LOWERI RIH with 30 stds of CSH. M/U BTT Hyd Disc and SWS NRJ. M/U injecter with E-Line Anchor and CTC. Perforating BHA #13, OAL = 2,801.77'. 17:15 - 19:30 2.25 PERFO P LOWERI RIH with 2" SWS perforating BHA #13. Circ at 0.5 bpm while running in. 19:30 - 19:50 0.33 PERFO P LOWERI Tag PBTD at 10,869 ft, correct to 10,860 ft. Pull up hole to 10,737.3 ft. Pump 7 bbls clean flo-pro ahead of ball. Drop 1/2" Aluminum ball. Launch with 1,000 psi. 19:50 - 20:10 0.33 PERFO P LOWERI Pump remaining flo-pro at 2,000 psi (1.8 bpm) to chase ball. Swap to KCI water to finish chasing ball. Pull up to 3 ft below firing depth. 20:10 - 20:50 0.67 PERFO P LOW ER1 At 40 bbls pumped (70% reel volume) slow pump rate to 0.8 bpm. At 63.3 bbls away no indication of ball seating. Stop pumping and wait for 2 minutes. Resume pump at 1.0 bpm. At 65.2 bbls away Circ pressure starts to increase, maintain 0.85 bpm. Start pulling up slowly to firing depth. At 3,000 psi pressure drops away, good shot indication on acoustic meter. Bottom shot position is 10,730 ft. Printed: 1/24/2008 2:44:23 PM • BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT ' Phase Description of Operations 1/18/2008 20:10 - 20:50 0.67 PERFO P LOWERI Up weight is 34 Klbs. 20:50 - 21:40 0.83 PERFO P LOWERI Pull up hole to 8,100 ft to flow check. 21:40 - 22:10 0.50 PERFO P LOWERI Flow check well at 8,100 ft. No sign of flow. 22:10 - 23:20 1.17 PERFO P LOWERI POOH to surface. 23:20 - 23:50 0.50 PERFO P LOWERI Flow Check -okay. 23:50 - 00:00 0.17 PERFO P LOWERI Safety Meeting -Review procedure, hazards and mitigation for laying down CSH. 1/19/2008 00:00 - 02:30 2.50 PERFO P LOWERI Lay down CSH in singles in pipe shed. 02:30 - 02:40 0.17 PERFO P LOWERI Safety Meeting -Discuss hazards and mitigations for laying down spent pert guns. 02:40 - 06:00 3.33 PERFO P LOWERI Break out firing head and lay down perforation guns. 1/2" Aluminum ball is recovered from firing head. All shots fired. 2", PJ, 6 SPF PERFORATED INTERVALS: 9,800 - 9,870' 9,880 - 9,960' 9,995 - 10,050' 10,070 - 10,110' 10,390 - 10,550' 10,610 - 10,730' TOTAL PERFS = 525'. 06:00 - 06:30 0.50 CASE P RUNPRD Crew change. SAFETY MEETING. Review procedure, hazards and mitigation for M/U BTT liner top packer BHA. 06:30 - 07:30 1.00 CASE P RUNPRD M/U BTT 4-1/2" KB Liner top Packer with 3.0" seal assembly and running tools. M/U 2 jts PH6 tubing, anchor and CTC. BHA OAL = 83.34'. 07:30 - 09:20 1.83 CASE P RUNPRD RIH with LT Packer BHA # 14. Circ at 0.2 bpm, RIH at 80 fph. Up wt at 8150' = 35K, Dwn wt = 25K. 09:20 - 10:20 1.00 CASE P RUNPRD RIH with LTP while pump 0.3 bpm. Seals went in at 8257'. Stop pump, open choke. RIH and stack 10K at 8263.5' Up depth 1 ft off landing = 8258.5'. Stack 10K at 8263.5'. Pump down backside of coiled tubing press test. Press up to 2040 psi. Chart Liner la ressure test for 30 min. Start press. = 2040 psi, 30 min end press = 1980 psi, lost 60 psi in 30 min. Ve ood test. Decided not to set liner top acker. 10:20 - 12:00 1.67 CASE P RUNPRD POH with BTT LTP BHA. circ at 0.6 bpm at 160 psi. POH at 80 fph. 12:00 - 12:50 0.83 CASE P RUNPRD Lay out BTT LT Packer BHA. M/U nozzle BHA. 12:50 - 14:50 2.00 WHSUR P POST RIH with nozzle BHA #15 to circ tubing to diesel. RIH to 8200'. 14:50 - 15:30 0.67 WHSUR P POST R/U Little Red and pump warm diesel at 2.0 bpm to nozzle. 15:30 - 18:00 2.50 WHSUR P POST POH while chasing diesel to surface. Stop at 3000', circ diesel to surface. Close choke and POH with no pump to further underbalance well. 18:00 - 18:30 0.50 WHSUR P POST Lay out nozzle BHA. Crew change. Printed: 1/24/2008 2:44:23 PM `~ '~ i $P EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: 1/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 1/19/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ' Task Code NPT Phase I Description of Operations 1/19/2008 18:30 - 18:45 0.25 WHSUR P POST Safety Meeting to discuss setting BPV. 18:45 - 19:30 0.75 WHSUR P POST Install BPV lubricator and pressure test to 600 psi, good test. 19:30 - 20:00 0.50 WHSUR P POST Set BPV then remove BPV lubricator and lay down. 20:00 - 20:20 0.33 WHSUR P POST MU injector to wellhead and prep to purge reel with N2. 20:20 - 20:40 0.33 WHSUR P POST Pump 5 bbls McOH ahead of N2. Conduct Safety Meeting for N2 purge of reel. 20:40 - 21:00 0.33 WHSUR P POST Pressure test N2 line to 4,000 psi then start N2 down coil at 1,500 scfm. 21:00 - 22:00 1.00 WHSUR P POST Shut down N2, bleed off pressure. 22:00 - 00:00 2.00 BOPSU P POST Finish pumping remaining fluid out to flowback tank. Nipple down and secure BOP stack. N/U tree cap and PT to 3500 psi. Weld guide rollers onto injector. RIG RELEASE 24:00 HRS ON 1/19/2008 TOTAL TIME FROM RIG ACCEPT TO RELEASE WAS 13 DAYS, 21.5 HRS. Prep to move rig to Pad 10. Printed: 1/24/2008 2:44:23 PM bP BP Alaska $ Baker Hughes INTEQ Survey Report T IN EQ Company: BP Amoco Date: 1/21!2008 Time: 08:44:56 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: A-12, True North Site: PB A Pad Vertical (TVD) Reference: 13:12 10/14/1980 00:00 77.4 Well: A-12 Wellpath: (~ ' (~, (3 Section (VS) Reference: Survey Calculation Method: Well (O.OON,O.OOE,326.73Azi) Minimum Curvature Db: Orade 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 A Pad TR-11-13 UNITED STATES :North Slope Site Positiou: Northing: 59461 31.57 ft Latitude: 70 15 35.209 N From: Map Easting: 653509.42 ft Longitude: 148 45 32.775 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.17 deg Well: A-12 Slot Name: 12 A-12 Well Position: +N/-S 3181.13 ft Northing: 5949332.25 ft Latitude: 70 16 6.495 N +E/-W 1003.29 ft Eastiug : 654447.58 ft Longitude: 148 45 3.571 W Position Uncertainty: 0.00 ft Wellpath: A-12A Drilled From: A-12 500292051501 Tie-on Depth: 8900.00 ft Current Datum: 13:12 10/14/1980 00:00 Height 77.40 ft Above System Datum: Mean Sea Level Magnetic Data: 5/5/2004 Declination: 25.22 deg Field Strength: 57585 nT Mag Dip Angle: 80.83 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.40 0.00 0.00 326.73 Survey Program for Definitive Wellpath Date: 5/5/2004 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 8900.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 8926.00 10938.00 MWD (8926.00.10938.00) MWD MWD -Standard Annotation MD TVD ft ft 8900.00 8702.36 TIP 8926.00 8726.55 KOP 10938.00 8910.79 TD Survey: MWD Start Date: 1/14/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey r MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 8900.00 21.68 351.30 8702.36 8624.96 924.22 -440.77 5950247.17 653987.98 1014.53 0.00 MWD 8926.00 21.40 351.23 8726.55 8649.15 933.66 -442.21 5950256.57 653986.34 1023.21 1.08 MWD 8949.63 21.47 352.77 8748.54 8671.14 942.21 -443.42 5950265.10 653984.96 1031.02 2.40 MWD 8978.45 27.20 354.03 8774.79 8697.39 954.00 -444.77 5950276.86 653983.37 1041.62 19.96 MWD 9015.62 39.31 355.12 8805.82 8728.42 974.26 -446.66 5950297.07 653981.06 1059.60 32.62 MWD 9046.64 48.52 355.79 8828.14 8750.74 995.68 -448.35 5950318.46 653978.93 1078.44 29.73 MWD 9078.26 58.37 358,91 8846.95 8769.55 1021.02 -449.48 5950343.76 653977.28 1100.24 32.14 MWD 9109.38 67.38 358.70 8861.13 8783.73 1048.69 -450.06 5950371.41 653976.14 1123.69 28.96 MWD 9136.58 75.46 359.75 8869.79 8792.39 1074.44 -450.40 5950397.15 653975.27 1145.41 29.93 MWD 9168.90 84.59 357.17 8875.38 8797.98 1106.23 -451.27 5950428.91 653973.75 1172.46 29.32 MWD 9200.14 86.49 353.18 8877.81 8800.41 1137.25 -453.89 5950459.87 653970.49 1199.83 14.11 MWD ~, V?- / 3 ~ • bP BP Alaska Baker Hughes INTEQ Survey Report uvTE Q Company: BP Amoco Date: 1/21!2008 Time: 08:44:56 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: A-12, True North Site: PB A Pad Vertical (TVD) Reference: 13:12 10/14/1980 00:00 77.4 Well: A-12 Section (VS) Reference: Well (O.OON,O.OOE,326.73Azi) W'ellpath: A-12A Survey Calculation Method: Minimum Curvature Db: Orade Survey MD ft Inc! deg Azim deg 1'VD ft Sys TVD ft N/S ft E/W ft 9230.14 88.68 350.81 8879.07 8801.67 1166.93 -458.06 9261.24 89.39 346.92 8879.60 8802.20 1197.44 -464.06 9289.82 88.83 344.62 8880.04 8802.64 1225.13 -471.09 9320.28 86.59 346.03 8881.26 8803.86 1254.57 -478.80 9355.28 87.02 350.82 8883.21 8805.81 1288.80 -485.81 9386.20 89.02 353.69 8884.28 8806.88 1319.41 -489.97 9419.49 91.11 358.65 8884.24 8806.84 1352.62 -492.19 9451.08 92.67 3.47 8883.20 8805.80 1384.17 -491.61 9479.87 93.10 5.79 8881.75 8804.35 1412.83 -489.29 9510.75 92.98 7.34 8880.11 8802.71 1443.46 -485.77 9538.75 91.90 4.63 8878.92 8801.52 1471.28 -482.85 9571.17 90.18 2.14 8878.33 8800.93 1503.64 -480.94 9600.11 90.77 355.85 8878.09 8800.69 1532.56 -481.44 9647.37 92.15 350.20 8876.89 8799.49 1579.43 -487.18 9679.65 97.07 351.66 8874.29 8796.89 1611.20 -492.25 9710.45 101.49 349.77 8869.33 8791.93 1641.19 -497.15 9741.81 105.07 346.88 8862.14 8784.74 1671.07 -503.32 9771.29 106.50 343.88 8854.13 8776.73 1698.52 -510.48 9801.63 105.97 338.64 8845.64 8768.24 1726.10 -519.83 9830.89 105.13 334.87 8837.80 8760.40 1751.99 -530.96 9862.53 105.20 331.18 8829.52 8752.12 1779.20 -544.81 9892.43 104.89 327.50 8821.75 8744.35 1804.03 -559.53 9926.75 105.53 322.94 8812.75 8735.35 1831.23 -578.41 9955.53 105.10 317.98 8805.14 8727.74 1852.63 -596.08 9988.38 105.14 314.10 8796.57 8719.17 1875.45 -618.09 10020.53 104.87 309.85 8788.24 8710.84 1896.21 -641.17 10051.96 104.77 305.29 8780.20 8702.80 1914.73 -665.24 10078.22 104.37 302.58 8773.59 8696.19 1928.92 X86.33 10112.46 103.04 298.26 8765.47 8688.07 1945.76 -715.01 10140.60 102.30 294.96 8759.30 8681.90 1958.05 -739.55 10169.72 100.87 290.49 8753.45 8676.05 1969.06 -765.86 10201.25 100.09 288.13 8747.71 8670.31 1979.31 -795.11 10230.67 96.51 287.11 8743.47 8666.07 1988.12 -822.86 10259.29 91.01 285.93 8741.59 8664.19 1996.24 -850.22 10293.11 85.15 284.72 8742.72 8665.32 2005.17 -882.81 10324.75 80.35 286.77 8746.72 8669.32 2013.68 -913.01 10354.31 74.84 286.48 8753.06 8675.66 2021.94 -940.66 10386.17 73.35 289.58 8761.80 8684.40 2031.42 -969.79 10414.33 75.61 292.91 8769.33 8691.93 2041.25 -995.07 10446.85 78.66 297.36 8776.58 8699.18 2054.72 -1023.76 10476.91 78.87 301.57 8782.44 8705.04 2069.22 -1049.43 10506.95 80.07 305.68 8787.93 8710.53 2085.57 -1074.01 10536.29 80.44 310.09 8792.90 8715.50 2103.32 -1096.83 10566.33 79.51 305.20 8798.13 8720.73 2121.39 -1120.24 10597.55 78.76 301.80 8804.02 8726.62 2138.31 -1145.80 10628.45 77.99 298.22 8810.24 8732.84 2153.44 -1172.01 10658.41 76.53 294.71 8816.85 8739.45 2166.47 -1198.16 10691.41 73.51 292.25 8825.38 8747.98 2179.17 -1227.39 10720.81 71.39 289.33 8834.25 8756.85 2189.12 -1253.59 10751.51 70.63 285.76 8844.24 8766.84 2197.87 -1281.26 10782.83 70.01 282.40 8854.79 8777.39 2205.05 -1309.86 10810.47 70.50 279.57 8864.13 8786.73 2210.00 -1335.40 10840.45 68.99 275.92 8874.51 8797.11 2213.80 -1363.26 MapN nlapE ft ft 5950489.45 653965.71 5950519.83 653959.08 5950547.37 653951.49 5950576.65 653943.18 5950610.72 653935.47 5950641.24 653930.68 5950674.39 653927.78 5950705.95 653927.71 5950734.64 653929.45 5950765.34 653932.34 5950793.21 653934.69 5950825.60 653935.94 5950854.50 653934.84 5950901.24 653928.14 5950932.89 653922.42 5950962.77 653916.90 5950992.52 653910.12 5951019.82 653902.40 5951047.19 653892.49 5951072.85 653880.83 5951099.77 653866.43 5951124.30 653851.20 5951151.09 653831.76 5951172.12 653813.66 5951194.49 653791.19 5951214.77 653767.69 5951232.79 653743.24 5951246.54 653721.87 5951262.79 653692.86 5951274.57 653668.07 5951285.04 653641.55 5951294.69 653612.09 5951302.93 653584.17 5951310.48 653556.64 5951318.74 653523.89 5951326.63 653493.52 5951334.32 653465.71 5951343.20 653436.39 5951352.51 653410.91 5951365.38 653381.96 5951379.35 653356.00 5951395.20 653331.09 5951412.48 653307.91 5951430.05 653284.14 5951446.44 653258.23 5951461.04 653231.73 5951473.52 653205.31 5951485.62 653175.83 5951495.03 653149.43 5951503.21 653121.59 5951509.80 653092.85 5951514.23 653067.22 5951517.45 653039.29 VS DLS Tool ft deg/104ft 1226.94 10.75 MWD 1255.73 12.71 MWD 1282.75 8.28 MWD 1311.59 8.69 MWD 1344.05 13.72 MWD 1371.93 11.31 MWD 1400.91 16.17 MWD 1426.97 16.03 MWD 1449.66 8.19 MWD 1473.34 5.03 MWD 1495.00 10.41 MWD 1521.00 9.33 MWD 1545.45 21.83 MWD 1587.79 12.30 MWD 1617.13 15.89 MWD 1644.89 15.58 MWD 1673.26 14.37 MWD 1700.14 11.02 MWD 1728.33 16.67 MWD 1756.08 12.74 MWD 1786.43 11.26 MWD 1815.27 11.93 MWD 1848.36 12.96 MWD 1875.94 16.69 MWD 1907.10 11.40 MWD 1937.12 12.80 MWD 1965.82 14.03 MWD 1989.24 10.10 MWD 2019.05 12.86 MWD 2042.80 11.74 MWD 2066.44 15.82 MWD 2091.06 7.76 MWD 2113.65 12.64 MWD 2135.45 19.65 MWD 2160.79 17.69 MWD 2184.47 16.48 MWD 2206.55 18.66 MWD 2230.46 10.46 MWD 2252.55 13.94 MWD 2279.55 16.31 MWD 2305.75 13.75 MWD 2332.91 14.03 MWD 2360.27 14.87 MWD 2388.22 16.33 MWD 2416.39 10.96 MWD 2443.42 11.62 MWD 2468.65 12.42 MWD 2495.31 11.64 MWD 2518.01 11.90 MWD 2540.50 11.27 MWD 2562.19 10.29 MWD 2580.35 9.80 MWD 2598.80 12.48 MWD • • by BP Alaska $ Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 1/21/2008 Time: 08:44:56 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeA: A-12, True North Site: PB A Pad Vertical (TVD) Reference: 13:12 10/14/1980 00:00 77.4 WeII: A-12 Section (VS) Reference: Well (O.OON,O.OOE,326.73Azi) Wellpath: A-12A Survey Caknlation Method: Minimum Curvature Db: Orade Survev MD Ind Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 10870.73 68.51 271.95 8885.49 8808.09 2215.73 -1391.41 5951518.81 653011.11 2615.87 12.32 MWD 10894.47 67.78 269.17 8894.33 8816.93 2215.95 -1413.44 5951518.58 652989.08 2628.13 11.29 MWD 10938.00 67.78 269.17 8910.79 8833.39 2215.37 -1453.73 5951517.16 652948.81 2649.75 0.00 MWD v ~ ~ d ~ SARAH PALIN, GOVERNOR ~~ OIL A1~TD GAS 333 W. 7th AVENUE, SUITE 100 C0111SERQA~`IOAT C011I1~'IISSIOlIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Sarber CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-12A BP Exploration Alaska, Inc. Permit No: 207-130 Surface Location: 1116' FNL, 920' FEL, SEC. 35, T11N, R13E, UM Bottomhole Location: 1073' FSL, 2373' FEL, SEC. 26, T11 N, R 13E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ~~ Dan T. Seamount Commissioner DATED this day of October, 2007 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASiC~IL AND GAS CONSERVATION COMMI~IN PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is propose~g}i~f6~ ^ Coalbed Methane ^ Gas Hydra es ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU A-12A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11000 TVD 8850ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1116' FNL 920' FEL SEC T11 N R13E UM 35 7. Property Designation: ADL 028286 Pool , , , , . , Top of Productive Horizon: 153' FNL, 1366' FEL, SEC. 35, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 15, 2007 Total Depth: 1073' FSL, 2373' FEL, SEC. 26, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,870' 4b. Location of Well (State Base Plane Coordinates): Surface: x-654447 y-5949331 Zone-ASP4 10. KB Elevation (Height above GL): 77.4' feet 15. Distance to Nearest Well Within Pool: 1,530' 16. Deviated Wells: Kickoff Depth: g8g6 feet Maximum Hole An le: 106 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3256 Surface: 2376 18. Gasin :Pr ram: S bo ns To - Setti De ' h - Bo lt m uant' f - ment c.f. or sa ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3314" x 4-118" 3-3/16" X z-~/a~~ 6.2# / 6.16# L-80 TCII / STL. 2675' 8325' 8101' 11000' 8850' 208 cu ft Class 'G' 19. PRESE NT WELL CONDITION SUMMARY (To tie completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9801 Total Depth TVD (ft): 9553 Plugs (measured): None Effective Depth MD (ft): 9757 Effective Depth TVD (ft): 9511 Junk (measured): 9757 (Approx.) asing Length; Size ement Volume MD D Conductor /Structural 113' 20" x 30" 8 cu ds Concrete 113' 113' Surface 2677' 13-3/8" 3720 cu ft Arctic Set 2677' 2677' Intermediate 8804' 9-5/8" 1210 cu ft Class'G' 130 cu ft AS 8804' 8614' Pr ion Liner 1489' 7" 396 cu ft Class'G' 8311' - 9800' 8166' - 9552' Perforation Depth MD (ft): 9012' - 9107' Perforation Depth TVD (ft): 8807' - 8896' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Greg Safier, 564-4330 Printed Name eg Sar er Title CT Drilling Engineer Mel Rixse, 564-5620 Prepared By Name/Number: Si nature " t ~"~~ Phone 564-4330 Date - ~ ~ ~ ~ Terrie Hubble, 564-4628 = Commi`sion Use nl Permit To Drill Number: ~ I~~~ API Number: 50-029-205151.:00 ~ Permit A proval See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or product coalbed meth~e, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes Ly No Mud Log Req'd: ~^/Yes ~ No Y HZS Measures: [Yes ^ No Directional Survey Req'd: lJ Yes ^ No Other: ~~ \ /Q ~ ~ APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005 ®~ ~ w (V` NA L ~~~~ r ~~~~~3 'j~< ~~ ~~os Cons. Commission S it In Duplicate ~f ~ ~ by BP Prudhoe Bay A-12A CTD Sidetrack September 24, 2007 CTD Sidetrack Summary Pre-Rig Work: 1. O Functions test LDS 2. O PPPOT-T, IC 3. S Pull SSSV. Fish HES Tubing patch at 7,203'. Recover reducing nipple at 8,342'. 4. S Drift for chemical cut in 4-1 /2" Tubing. 5. S Run Multifinger caliper from TTail to surface. 6. E Set HES fast drill plug in TTail between X and XN nipples at 8,326'. (Ref Tubing Tally) 7. E Chemical cut at 8,219', (Near top of pup joint above packer) 8. O CMIT T x IA to 3500 psi. MIT OA to 2000 psi. 9. O Load T and IA with seawater circ thru chem cut and FP T & IA to 2000' with diesel. 10. O Bleed T, IA, OA to zero. 11. O Set BPV 12. O Bleed production flow lines and GL lines down to zero and blind flange 13. O Remove wellhouse, level pad ~~~ T~~ Rig Workover Operations: (Scheduled to begin on November 1, 2007) 1. To be performed by a rig from the BP workover group. Rig Sidetrack Operations: (Scheduled to begin on November 15, 2007 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT Drilling BOPE and test. 3. RU Slickline. Retrieve ball and rod, RHC plug. Dummy off upper GLM. 4. RU Coil. RIH, drill up fast drill plug at 8,326', and open up XN nipple to 3.80". 5. Set whipstock with top at 8,896'. •--~-~ ~~ 6. Mill 3.80 window at 8,896'. t ~~ ~ V-'P~Cfi~' 7. Drill build/turn section with 3.75" x 4.125" bicenter bit, and land well. 8. Drill lateral section to 11,000'. 9. Run and cement a 2-7/8" x 3-3/16" L-80 liner string, abandoning perfs in parent wellbore. 10. Make a cleanout run with mill and motor and SWS GR-CNL logging tool. 11. Perforate well. 12. Circulate well to KWF brine. FP well to 2000' with diesel. 13. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design. 4. Rerun SSSV when running GLV's. Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.7 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.75"x4-1 /8" (bi-center bits used) Casing Program: fully cemented liner • 3-3/16", L-80 6.2# TCII 8,325' and - 9,800' and • 2-7/8", L-80 6.16# STL 9.800' and -11,000' and • A minimum of 37 bbls 15.8 ppg cement will be used for liner cementing. (Assuming TD @ 11,000', and planning on 40% excess in the open hole interval) • TOC planned at 8,400' Existing casino/tubing Information 13-3/8", L-80 72#, Burst 5380, collapse 2670 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 psi 7", L-80 29#, Burst 8160, collapse 7030 psi 4-1 /2", L-80 12.6#, Burst 8430, collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 105.11 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 21,870 ft. • Distance to nearest well within pool -1,530 ft. (A-13) Logging • MWD directional, Gamma Ray, Resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on A Pad is 400 ppm on well A-43. • The maximum recorded H2S level on X-30 was 60 ppm on 08/09/2005. • Lost circulation risk is average. Reservoir Pressure • The reservoir pressure on A-12 was measured at 3,256 psi at 8800'ss in June 2006. (7.11 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2376 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble ~ uvv SAFETY NINES: UUARNING: RA07D TRANSMT113i IN •1lh~AD= FMG WEATHER MONTORINO Sii4CK MUST BE Tl~t-~p OFF ;TUATOi?= OTtS ~~~ 2 MANY V11B.LVNDf~CR~N4X.VINGE7iR.OSN€5 ~' ~-~ - ~ 4~. CANSEi~t CONTAOT PADOPH314TOR"'T X IAX ELEV T 49.56' IP= *~AOOMM.OPERA7INQPRESSUf7FOFTHEi3- x Ar~t~ -- . 27 ~ 8200; 3X8" ANNULUS MUST NOT EXCEB! 2000 pSi tum 1a0= 9087' l10/04Jp2 WANER~"' TVtk 133" OSG, 721F, L-~, ~ =12.347' 2677' Minirrllum ID = 2.313" 8342' 2 718" REDUCED NlPPL 1988' 4112"' CAINGQ S38 V NIP, ID = 9.813" 2893' 8.5,8" Dv PKR FTl MD TVD ~/ TYpE VtV LATGti PART QATE a 3osa 3ooa 1 oTis RA 3 5754 5670 6 gT1S RA 2 7a38 7268 1B OTC RA s13s 7928 z4 DTI RA i T8G PATCH 7203' 72 t 7', 14 = 7MENTS (Q 7205' 7213' ENIICAL INJ. hk°+NDREI 17' PA RKER X NP, ®= 3.813• 8288' H9.518" x 4-12" BIQ2 S-3 PKR, 83=4.75" 41 r2° reG ~ 2 bAl, l 80, 0.0152 bpf, ID = 3,959" 8-518" CSD, 4711, l•80, ID = 8.881" 8804' PERFORATKSN SUMM4RY REF lOCit SWS BRCS ON 10(30/80 A NGLE AT TDP FERF: 21 ~ 8897' Note: Refer to Ftoductxx~ DB for historical oeA data SIZE SPF -~-INTfftVAI ~ OpnXSgz i]4TE 33X$" 4 8897-8924 S 08!18X97 33~ 4 9012.9020 O 09Y14X90 3-••3X8° 4 9027.8107 O 09114X80 3.1,x°' 4 9108-s132 S 08X30X90 37J8" a x137-x144 5 08130X90 3118" 4 9149-9182 S 08l3W90 8311' ~- -~4-112" OTtS X N'P, !D = 3.813" ~ 8342' -117' XN Ni'1!9' 2«718" ~ REOUGINO Nom, it? - 2 313" 8373' 4=117' TBO YA R, in = 3,958" 83g$' Ca.fuS}TTLOGGF3702/17~5 EIL [LATE REV BY COAANl3dTS ATE REV BY COMa6JTS 07X~74'8f1 ORfGNAL GOMPLETKNV 10117A2 D4V/KiS FISH _... 06101190 RWO D1r30VD1 SIS•MH CfMV1l9ZTIDT0 CANVAS 02117.;0'1 SIS•MD FINAL 05178'07 RNIICAi{ CORRECTIONS 70V04!OQ BMNCAK WANERSAFETY NOTE PRU~iDE 9AY UNIT WELL: A-72 i~RMR No: 1801170 API No: 50.029-20515.00 SEC 35. T11N, 873E ~ ~ploration (Alaska) -~D= ° ~ A-12 A SAFEl„f~i'FFS,NARNNG RADIOTRANSMfRFRN WFATFEF2 MONRORING SHACK MUST BE TURNED OFF lATOR= OTIS ' B~OREANV WELL WORKIN~/OIVrlGF7(PLOSNES ~fl/ = 77 43 CAN BF-GN CONTACT PAD OPBtATOR"'T X U- X LFY = 49 56' _ _ _ 5800' Angle = 27 ®8200' OA COMM. OPERATING PFfESSUFtE OF THE 13- 318" ANNULUS MUST NOT EXCEED 2000 PSI „I,a-,= ww,' tloroaro2wANER~... ov Minimum ID = 2.313" @ 834 2 718" REDUCED NIPPLE (retrieved) 4 3 2 1 8170' - 41/2" HES X Nipple, L-80, 3.813" ID 8200' - 7-5/8" x 4-1/2" Baker S3 Packer 8220' - 4-112" HES X Nipple, L-80, 3.813" ID 9-5/8" x 4-112" Unique Machine Overshot OF 7" L NR iTOPOF 3-3/76' LI 3 5" XN Nip 2 75" 4-t/2" TBG. 12.8/. L-80. 0 Ot52 bof. D • 3.95! PERFORATION SUMu14RY FIEF LOG. SWS BRCS ON 10/30/80 ANGLEAT TOP PERF 21 ~ 8897' Note Faafer tD RDductan OB for hntorcal Wert data SQE SPF INTCTZVAL Opn/Sgt DATE 3-3/8" d 8897-8924 isolated proDOaed 3-318" 4 9012-9020 isolated proposed 3-318" 4 9027-9107 ~obted proposed 3-118" 4 9108-9132 isa~ted proocsert 3 ' ~q" 4 ?' 1,''-9144 7" x 4-12" XN NP rotrevc 4.1 /2" THO TA t , O • 3 958 9800' 3-3118 z 2-7/8 X-ova -3/18' X 2.7/8" cmt'ed and parted 8896' Mechanical Whpstock r2~SPlJhER BLAt7ES E/L (10117/02) DOTE REV BV COfv1NENI5 LIATE REV (3V OOA+N/ENTS 0+ 04+80 ORIGINAL (z)r,.vi FfgN 10!17!02 [Y1V1KK FISH 06'C t 190 RWO 0? 30+01 SIS-MH CONVFJtT[O TO CANVAS - - 0227101 S5-MD FNAL - 05118/0t RfWKAK CORRECTIONS __. .. 10+04102 BfvYKAK WANERSAFFT7NOTE I 8325' I 9800' PRUDFiOE BAY UNT WElL A-12 F$~MT No 1801170 APf No 50-029-20515-00 SEC 35 711N R13E BP Exploration (Alaska) by BP Alaska Br Baker Hughes INTEQ Planning Report 1NTE Q Compaoyc t3P Amoco Date: 9/24/2007 Time: 09:22:00 PageE 1 Field:: Prudhoe Bay Co-ordinate(NE) Reference: Well: A-i2, True North Site: PB A Pad Vertical (TVD) Reference: 13 :1210/14/1980 00:0077.4 Well: A-12 Section (VS) Reference: Well (O.OON,O.OOE,330.OOAzi) Wellpath: Plar- 7, A-12A Survey Calculation Method: Minimum Curvature Db: ZNade 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 A Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5946131 .57 ft Latitude: 70 15 35.209 N From: Map Easting: 653509 .42 ft Longitude: 148 45 32.775 W Position Uncertainty: 0.00 ft North Reference: True Gronud Level: 0.00 ft Grid Convergence: 1.17 deg Well: A-12 Slot Name: 12 A-12 Well Position: +N/-S 3181.13 ft Northing: 5949332 .25 ft Latitude: 70 16 6.495 N +E/-W 1003.29 ft Fasting : 654447 .58 ft Longitude: 148 45 3.571 W Position Uncertainty: 0.00 ft Wellpath: Plan 7, A-12A Drilled From: A-12 500292051501 Tie-on Depth: 8800.00 ft Current Datum: 13:12 10/14/1980 00:00 Height 77 .40 ft Above System Datum: Mean Sea Level Magnetic Data: 5/5/2004 Declination: 25.22 deg Field Strength: 57585 nT Mag Dip Angle: 80.83 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.40 0.00 0.00 330.00 Plan: Plan #7 Date Composed: 5!5/2004 copy Greg's plan 7 text file Version: 17 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <--- Latitude. ---> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Eastiog Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft A-12A Fault 1 77.40 1588.78 -1003.27 5950900.00 653412.00 70 16 22.120 N 148 45 32.780 W -Polygon 1 77.40 1588.78 -1003.27 5950900.00 653412.00 70 16 22.120 N 148 45 32.780 W -Polygon 2 77.40 1479.75 -77.25 5950810.00 654340.00 70 16 21.048 N 148 45 5.820 W A-12A Fault 2 77.40 1554.57 -1286.06 5950860.00 653130.00 70 16 21.783 N 148 45 41.013 W -Polygon 1 77.40 1554.57 -1286.06 5950860.00 653130.00 70 16 21.783 N 148 45 41.013 W -Polygon 2 77.40 2121.70 -894.31 5951435.00 653510.00 70 16 27.361 N 148 45 29.610 W -Polygon 3 77.40 2511.34 -871.31 5951825.00 653525.00 70 16 31.193 N 148 45 28.941 W -Polygon 4 77.40 2121.70 -894.31 5951435.00 653510.00 70 16 27.361 N 148 45 29.610 W A-12A Polygon 77.40 1419.92 -573.62 5950740.00 653845.00 70 16 20.459 N 148 45 20.271 W -Polygon 1 77.40 1419.92 -573.62 5950740.00 653845.00 70 16 20.459 N 148 45 20.271 W -Polygon 2 77.40 1824.38 -785.38 5951140.00 653625.00 70 16 24.437 N 148 45 26.437 W -Polygon 3 77.40 1980.51 -1082.26 5951290.00 653325.00 70 16 25.972 N 148 45 35.081 W -Polygon 4 77.40 2019.03 -1496.59 5951320.00 652910.00 70 16 26.350 N 148 45 47.145 W -Polygon 5 77.40 2258.17 -1451.67 5951560.00 652950.00 70 16 28.703 N 148 45 45.839 W -Polygon 6 77.40 2216.35 -632.29 5951535.00 653770.00 70 16 28.292 N 148 45 21.981 W -Polygon 7 77.40 1877.80 -464.19 5951200.00 653945.00 70 16 24.963 N 148 45 17.086 W -Polygon 8 77.40 1385.20 -344.26 5950710.00 654075.00 70 16 20.118 N 148 45 13.593 W A-12A Target 3 8739.40 2060.33 -779.54 5951376.00 653626.00 70 16 26.758 N 148 45 26.268 W A-12A Target 4 8819.40 2165.35 -1120.48 5951474.00 653283.00 70 16 27.790 N 148 45 36.195 W A-12A Target 2 8879.40 1617.46 -499.54 5950939.00 653915.00 70 16 22.402 N 148 45 18.114 W A-12A Target 1 8881.40 1322.36 -547.61 5950643.00 653873.00 70 16 19.500 N 148 45 19.513 W b BP Alaska s~~r p Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 9/24/2007 Time:. 09:22:00 Page; 2 Field; Prudhoe Bay Co-ordinate(NE) Reference:.. • WeII: A-12, True North Site: PB A Pad Vertical (1'VI)) Reference: 13 ; 1 210/14/1980 00:00.77.4 We11E A-12 Section (VS) Reference: Well {O.OON,U.QOE,330.OOAzi) Wellpath: Platy 7, A-12A Snrvey Calcalatfoo Method::: Minimum Curvature Db: Orade Targets Map Map <---- Latitude ----> ~ Longitude --> ..Name Description TVD +N/ S +E/-W Northing Eastiag Deg- Min .Sec Deg Min. 'Sec Dip. Dir. ft 1t ft ft ft A-12A Target 5 8927.40 2188.22 -1455.10 5951490.00 652948.00 70 16 28.015 N 148 45 45.938 W Annotation MD TVD ft ft 8800.00 8609.86 TIP 8896.00 8698.65 KOP 8916.00 8717.11 End of 9 Deg/100' DLS 9048.77 8805.58 End of 3 5 Deg/100' DLS 9173.77 8847.58 5 9358.77 8881.34 6 9533.77 8882.96 7 9633.77 8881.63 8 9729.68 8868.63 9 9844.68 8838.74 10 10169.68 8751.74 11 10269.68 8739.40 12 10369.68 8747.77 13 10644.68 8819.35 14 10809.68 8872.35 15 11000.00 8927.29 TD Plan Section Information MD Ind Azim TVD +N/-S +E/-W DLS Build Turn. TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8800.00 22.98 352.21 8609.86 886.62 -435.33 0.00 0.00 0.00 0.00 8896.00 21.73 351.34 8698.65 922.76 -440.54 1.35 -1.30 -0.91 194.43 8916.00 23.53 351.34 8717.11 930.37 -441.70 9.00 9.00 0.00 0.00 9048.77 70.00 351.34 8805.58 1023.40 -455.87 35.00 35.00 0.00 0.00 9173.77 71.10 331.48 8847.58 1134.41 -493.28 15.00 0.88 -15.89 270.00 9358.77 88.05 353.91 8881.34 1306.60 -545.90 15.00 9.16 12.13 55.00 9533.77 90.90 20.01 8882.96 1478.79 -524.87 15.00 1.63 14.91 84.00 9633.77 90.61 5.01 8881.63 1576.13 -503.27 15.00 -0.29 -15.00 269.00 9729.68 105.00 5.01 8868.63 1670.54 -494.99 15.00 15.00 0.00 0.00 9844.68 104.90 347.15 8838.74 1780.88 -502.54 15.00 -0.08 -15.53 272.00 10169.68 104.21 296.68 8751.74 2019.27 -689.64 15.00 -0.21 -15.53 276.00 10269.68 90.00 291.85 8739.40 2059.87 -779.87 15.00 -14.22 -4.83 199.00 10369.68 80.42 303.45 8747.77 2105.92 -867.92 15.00 -9.58 11.60 130.00 10644.68 70.64 261.94 8819.35 2165.03 -1120.50 15.00 -3.55 -15.09 251.50 10809.68 72.48 287.98 8872.35 2178.61 -1274.81 15.00 1.11 15.78 90.00 11000.00 74.67 258.27 8927.29 2188.17 -1454.72 15.00 1.15 -15.61 270.00 Survey MD Ind Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 2677.00 0.92 157.23 2599.41 -20.65 18.48 5949311.98 654466.49 0.00 -27.13 0.00 13 3/8" 8800.00 22.98 352.21 8532.46 886.62 -435.33 5950209.69 653994.19 0.39 985.50 194.44 MWD 8804.00 22.93 352.18 8536.15 888.17 -435.54 5950211.23 653993.95 1.35 986.95 194.43 9 5/8" 8825.00 22.65 351.99 8555.51 896.23 -436.66 5950219.27 653992.66 1.35 994.48 194.46 MWD 8850.00 22.33 351.77 8578.61 905.69 -438.01 5950228.70 653991.12 1.35 1003.36 194.63 MWD 8875.00 22.00 351.54 8601.76 915.03 -439.38 5950238.00 653989.56 1.35 1012.12 194.83 MWD 8896.00 21.73 351.34 8621.25 922.76 -440.54 5950245.71 653988.24 1.35 1019.40 195.05 7" 8900.00 22.09 351.34 8624.96 924.24 -440.77 5950247.18 653987.98 9.00 1020.80 0.00 MWD 8916.00 23.53 351.34 8639.71 930.37 -441.70 5950253.29 653986.92 9.00 1026.57 0.00 MWD 8925.00 26.68 351.34 8647.86 934.14 -442.27 5950257.06 653986.27 35.00 1030.13 360.00 MWD 8941.26 32.37 351.34 8662.00 942.06 -443.48 5950264.95 653984.90 35.00 1037.59 0.00 A-12A 8950.00 35.43 351.34 8669.25 946.88 -444.21 5950269.75 653984.07 35.00 1042.13 360.00 MWD • b BP Alaska Br P Baker Hughes INTEQ Planning Report INTE Q Company:. BP Amoco Date: 9/24/2007 Time:: 09:22:00 Page. 3 Field:' Prudhoe Bay ' Co-ordinatelNE) Reference: Well: A-12, True North Site: PB A Pad Vertical (TVD) Reference: 13 ; 12 10/14/1980 00:00: 77.4 Wells A-1 2 Section (VS) Reference: Well (O.OON,O.OOE,330.OOAzi) Wellpatb: Plan 7, A-12A Survey Cakulatiou Method:. Minimum Curvature Db: Orade Survey Ma Igcl Azim SS TVD ' N/S ENV MapN MapE DLS VS TFO Tool ft deg. .deg ft ft ft ft ft deg/1OOft ft deg` 8975.00 44.18 351.34 8688.44 962.69 -446.62 5950285.50 653981.34 35.00 1057.02 0.00 MWD 9000.00 52.93 351.34 8704.97 981.19 -449.44 5950303.95 653978.14 35.00 1074.46 360.00 MWD 9025.00 61.68 351.34 8718.46 1001.97 -452.61 5950324.66 653974.55 35.00 1094.04 360.00 MWD 9048.77 70.00 351.34 8728.18 1023.40 -455.87 5950346.01 653970.85 35.00 1114.22 0.00 MWD 9050.00 70.00 351.14 8728.60 1024.54 -456.04 5950347.14 653970.65 15.00 1115.30 270.00 MWD 9075.00 70.05 347.15 8737.15 1047.61 -460.47 5950370.12 653965.75 15.00 1137.49 270.07 MWD 9089.25 70.12 344.88 8742.00 1060.60 -463.70 5950383.04 653962.25 15.00 1150.36 271.43 A-12A 9100.00 70.19 343.17 8745.65 1070.33 -466.49 5950392.71 653959.27 15.00 1160.17 272.20 MWD 9125.00 70.41 339.19 8754.08 1092.60 -474.08 5950414.82 653951.22 15.00 1183.26 272.79 MWD 9150.00 70.73 335.23 8762.40 1114.33 -483.21 5950436.35 653941.65 15.00 1206.64 274.13 MWD 9173.77 71.10 331.48 8770.18 1134.41 -493.28 5950456.21 653931.17 15.00 1229.06 275.45 MWD 9175.00 71.21 331.64 8770.57 1135.43 -493.83 5950457.23 653930.59 15.00 1230.23 55.00 MWD 9200.00 73.39 334.84 8778.18 1156.69 -504.55 5950478.26 653919.44 15.00 1254.00 54.95 MWD 9225.00 75.62 337.97 8784.86 1178.76 -514.19 5950500.13 653909.36 15.00 1277.94 53.97 MWD 9250.00 77.89 341.04 8790.59 1201.56 -522.71 5950522.74 653900.37 15.00 1301.93 53.14 MWD 9275.00 80.19 344.05 8795.34 1224.97 -530.06 5950545.99 653892.54 15.00 1325.88 52.43 MWD 9300.00 82.52 347.03 8799.10 1248.89 -536.23 5950569.79 653885.88 15.00 1349.69 51.86 MWD 9325.00 84.86 349.97 8801.85 1273.24 -541.18 5950594.03 653880.43 15.00 1373.25 51.41 MWD 9350.00 87.22 352.89 8803.58 1297.90 -544.90 5950618.60 653876.21 15.00 1396.46 51.09 MWD 9358.77 88.05 353.91 8803.94 1306.60 -545.90 5950627.28 653875.03 15.00 1404.50 50.89 MWD 9375.00 88.31 356.33 8804.45 1322.76 -547.28 5950643.41 653873.32 15.00 1419.19 84.00 MWD 9400.00 88.71 0.06 8805.10 1347.74 -548.07 5950668.36 653872.02 15.00 1441.21 83.92 MWD 9425.00 89.12 3.79 8805.58 1372.72 -547.23 5950693.35 653872.35 15.00 1462.42 83.83 MWD 9450.00 89.53 7.52 8805.87 1397.59 -544.76 5950718.27 653874.30 15.00 1482.73 83.76 MWD 9475.00 89.94 11.25 8805.99 1422.25 -540.69 5950743.00 653877.87 15.00 1502.05 83.71 MWD 9500.00 90.35 14.98 8805.93 1446.59 -535.02 5950767.46 653883.04 15.00 1520.29 83.69 MWD 9525.00 90.76 18.70 8805.68 1470.51 -527.78 5950791.52 653889.79 15.00 1537.39 83.70 MWD 9533.77 90.90 20.01 8805.56 1478.79 -524.87 5950799.85 653892.52 15.00 1543.10 83.74 MWD 9550.00 90.86 17.58 8805.31 1494.15 -519.64 5950815.32 653897.44 15.00 1553.79 269.00 MWD 9575.00 90.79 13.83 8804.95 1518.21 -512.88 5950839.51 653903.70 15.00 1571.25 268.96 MWD 9600.00 90.72 10.08 8804.62 1542.66 -507.70 5950864.06 653908.38 15.00 1589.83 268.91 MWD 9625.00 90.64 6.33 8804.32 1567.40 -504.13 5950888.86 653911.43 15.00 1609.47 268.86 MWD 9633.77 90.61 5.01 8804.23 1576.13 -503.27 5950897.61 653912.12 15.00 1616.60 268.81 MWD 9650.00 93.05 5.01 8803.71 1592.28 -501.85 5950913.79 653913.21 15.00 1629.88 360.00 MWD 9675.00 96.80 5.01 8801.56 1617.09 -499.67 5950938.63 653914.87 15.00 1650.28 0.00 MWD 9700.00 100.55 5.01 8797.79 1641.71 -497.51 5950963.29 653916.53 15.00 1670.52 0.00 MWD 9725.00 104.30 5.01 8792.42 1666.02 -495.38 5950987.64 653918.16 15.00 1690.51 360.00 MWD 9729.68 105.00 5.01 8791.23 1670.54 -494.99 5950992.16 653918.46 15.00 1694.22 0.00 MWD 9750.00 105.08 1.86 8785.96 1690.12 -493.81 5951011.76 653919.24 15.00 1710.59 272.00 MWD 9775.00 105.13 357.97 8779.44 1714.25 -493.85 5951035.88 653918.71 15.00 1731.51 271.18 MWD 9800.00 105.11 354.09 8772.92 1738.32 -495.51 5951059.92 653916.55 15.00 1753.19 270.17 MWD 9825.00 105.02 350.21 8766.42 1762.23 -498.81 5951083.75 653912.76 15.00 1775.54 269.16 MWD 9844.68 104.90 347.15 8761.34 1780.88 -502.54 5951102.31 653908.65 15.00 1793.56 268.15 MWD 9850.00 104.98 346.33 8759.97 1785.88 -503.72 5951107.29 653907.36 15.00 1798.47 276.00 MWD 9875.00 105.33 342.46 8753.43 1809.11 -510.21 5951130.38 653900.40 15.00 1821.84 275.79 MWD 9900.00 105.61 338.58 8746.76 1831.82 -518.24 5951152.92 653891.91 15.00 1845.53 274.78 MWD 9925.00 105.82 334.69 8739.98 1853.91 -527.78 5951174.81 653881.92 15.00 1869.42 273.74 MWD 9950.00 105.96 330.80 8733.14 1875.28 -538.79 5951195.95 653870.47 15.00 1893.44 272.69 MWD 9975.00 106.03 326.90 8726.25 1895.84 -551.22 5951216.25 653857.63 15.00 1917.46 271.62 MWD 10000.00 106.03 323.00 8719.34 1915.51 -565.01 5951235.63 653843.43 15.00 1941.39 270.55 MWD 10025.00 105.96 319.10 8712.45 1934.19 -580.12 5951254.00 653827.95 15.00 1965.12 269.47 MWD 10050.00 105.82 315.20 8705.60 1951.82 -596.47 5951271.28 653811.24 15.00 1988.56 268.39 MWD 10075.00 105.61 311.31 8698.83 1968.30 -613.99 5951287.40 653793.38 15.00 2011.60 267.32 MWD by BP Alaska s$ Baker Hughes INTEQ Planning Report >NTE Q "Company: BP Amoco Dater 9/24/2007 Time: 09:22:00 ' Page:.: 4 FieM: Pnadhoe Bay Go-ordioate(NE) Reference: WeII: A-12, True North Sites PB A Pad Vertical (TVD) Reterwce: 13:1 2 10/t4/1980 00:00 77.4 Well: A-1 2 Section (VS) Reterence•.' WeA (O.OON,O.OOE,330:OOAzi) Wellpath: Pla n 7, A-12A Survey Caiculatioa Method: , Minimum Curvature Db: Orate Survey MD Incl Azim SS TVD NB E/W MapN MapE DI.S VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10100.00 105.33 307.43 8692.15 1983.58 -632.62 5951302.29 653774.45 15.00 2034.14 266.27 MWD 10125.00 104.99 303.56 8685.61 1997.59 -652.26 5951315.89 653754.53 15.00 2056.09 265.24 MWD 10150.00 104.58 299.71 8679.23 2010.27 -672.83 5951328.14 653733.70 15.00 2077.36 264.22 MWD 10169.68 104.21 296.68 8674.34 2019.27 -689.64 5951336.80 653716.71 15.00 2093.56 263.24 MWD 10175.00 103.46 296.41 8673.07 2021.58 -694.25 5951339.01 653712.05 15.00 2097.87 199.00 MWD 10200.00 99.91 295.18 8668.00 2032.23 -716.29 5951349.21 653689.80 15.00 2118.11 198.94 MWD 10225.00 96.35 293.97 8664.47 2042.52 -738.80 5951359.03 653667.09 15.00 2138.27 198.69 MWD 10250.00 92.80 292.78 8662.47 2052.40 -761.67 5951368.45 653644.02 15.00 2158.27 198.52 MWD 10269.68 90.00 291.85 8662.00 2059.87 -779.87 5951375.54 653625.67 15.00 2173.84 198.42 MWD 10275.00 89.48 292.46 8662.02 2061.88 -784.79 5951377.44 653620.71 15.00 2178.04 130.00 MWD 10300.00 87.07 295.33 8662.77 2072.00 -807.64 5951387.09 653597.67 15.00 2198.22 130.00 MWD 10325.00 84.67 298.22 8664.57 2083.23 -829.89 5951397.86 653575.18 15.00 2219.08 129.91 M1IVD 10350.00 82.29 301.13 8667.41 2095.52 -851.47 5951409.71 653553.36 15.00 2240.51 129.70 MWD 10369.68 80.42 303.45 8670.37 2105.92 -867.92 5951419.76 653536.70 15.00 2257.74 129.37 MWD 10375.00 80.17 302.68 8671.27 2108.78 -872.31 5951422.53 653532.25 15.00 2262.41 251.50 MWD 10400.00 79.00 299.05 8675.79 2121.39 -893.41 5951434.71 653510.90 15.00 2283.88 251.63 MWD 10425.00 77.89 295.40 8680.80 2132.59 -915.19 5951445.47 653488.90 15.00 2304.48 252.29 MWD 10450.00 76.82 291.72 8686.27 2142.34 -937.54 5951454.75 653466.35 15.00 2324.10 253.02 MWD 10475.00 75.80 288.00 8692.19 2150.60 -960.38 5951462.53 653443.35 15.00 2342.66 253.82 MWD 10500.00 74.84 284.25 8698.53 2157.31 -983.61 5951468.77 653419.99 15.00 2360.09 254.70 MWD 10525.00 73.94 280.47 8705.26 2162.47 -1007.12 5951473.45 653396.38 15.00 2376.31 255.65 MWD 10550.00 73.11 276.66 8712.35 2166.04 -1030.82 5951476.53 653372.61 15.00 2391.26 256.67 MWD 10575.00 72.35 272.81 8719.77 2168.01 -1054.61 5951478.01 653348.79 15.00 2404.86 257.75 MWD 10600.00 71.67 268.94 8727.50 2168.38 -1078.38 5951477.89 653325.02 15.00 2417.06 258.90 MWD 10625.00 71.06 265.03 8735.49 2167.14 -1102.03 5951476.16 653301.40 15.00 2427.81 260.09 MWD 10644.68 70.64 261.94 8741.95 2165.03 -1120.50 5951473.68 653282.98 15.00 2435.22 261.34 MWD 10650.00 70.65 262.78 8743.71 2164.36 -1125.47 5951472.91 653278.02 15.00 2437.13 90.00 MWD 10675.00 70.71 266.76 8751.98 2162.21 -1148.96 5951470.28 653254.59 15.00 2447.01 89.72 MWD 10700.00 70.85 270.73 8760.22 2161.69 -1172.56 5951469.27 653231.01 15.00 2458.36 88.40 MWD 10725.00 71.09 274.68 8768.37 2162.81 -1196.16 5951469.90 653207.39 15.00 2471.13 87.10 MWD 10750.00 71.40 278.63 8776.41 2165.55 -1219.66 5951472.17 653183.83 15.00 2485.26 85.81 MWD 10775.00 71.80 282.56 8784.31 2169.91 -1242.98 5951476.05 653160.44 15.00 2500.69 84.54 MWD 10800.00 72.28 286.47 8792.02 2175.87 -1265.99 5951481.53 653137.31 15.00 2517.36 83.30 MWD 10809.68 72.48 287.98 8794.95 2178.61 -1274.81 5951484.09 653128.44 15.00 2524.13 82.09 MWD 10825.00 72.50 285.57 8799.56 2182.82 -1288.79 5951488.01 653114.37 15.00 2534.78 270.00 MWD 10850.00 72.58 281.64 8807.06 2188.43 -1311.97 5951493.14 653091.09 15.00 2551.22 270.72 MWD 10875.00 72.75 277.72 8814.51 2192.44 -1335.49 5951496.67 653067.50 15.00 2566.45 271.90 MWD 10900.00 72.99 273.80 8821.88 2194.84 -1359.25 5951498.58 653043.69 15.00 2580.41 273.07 MWD 10925.00 73.30 269.89 8829.13 2195.61 -1383.16 5951498.86 653019.77 15.00 2593.03 274.23 MWD 10950.00 73.69 266.00 8836.24 2194.75 -1407.11 5951497.51 652995.85 15.00 2604.26 275.36 MWD 10975.00 74.14 262.13 8843.17 2192.27 -1430.99 5951494.54 652972.02 15.00 2614.05 276.47 MWD 11000.00 74.67 258.28 8849.89 2188.17 -1454.72 5951489.95 652948.38 15.00 2622.37 277.54 2 7/8" • • E { i s n f aE i~~ g~ m~W ~~ ~ _< <~ -ss «d a ca ~c 8 ~ ~~$ Q = a~ ;~ - ~ a m ~e ~a I`~ ~ ~ ~ ~ ••w~s 8 0 by BP Alaska Anticollision Report ~.r ~t~s 1NTEQ Company: BP Amoco Date: 9!24@007 Time: 09:25:31. rage: 1 Fieht: Prudhoe Bay Reference Site: PB A Pad Co-ordieate(NE) Reference: Well' A-12, True North Reference Well: A-12 Vertical (TVD) Reference: 13:12 10M4/1980 00:00 77.4 Reference Wellpathc Plan 7, A-12A Db: OraGe GLOBAL SCAN APPLIED: All wellpaths within 200'+ I00/1000 of reference -There are 1~9BIiiBaeells iu this94eh19pal Plan 8 PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 8800.00 to 11000.00 ft Scan Method: Trav Cylinder North Maximum Radius: 2500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5!5/2004 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 100.00 8800.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 8800.00 11000.00 Planned: Plan #7 V17 MWD MWD -Standard Casing Points MD TVD Diameter Hale Size Name ft ft in in 2677.00 2676.81 13.375 17.500 13 318" 8804.00 8613.55 9.625 12.250 9 5/8" 8896.00 8698.65 7.000 8.500 7" 11000.00 8927.29 2.875 3.750 2 7/8" Summary -- Offset Wellpath - ---> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath ~ MD MD Distance Area Deviation Wamiog ft ft ft ft ft A-12,PIan 7, A-12A,PI 9900.00 9900.00 0.00 188.55 -188.55 FAIL: Major Risk PB A Pad A-11 A-11 V1 10955.42 8500.00 1434.50 157.85 1276.65 Pass: Major Risk PB A Pad A-12 A-12 V1 8900.00 8900.00 0.01 213.06 -213.05 FAIL: Major Risk PB A Pad A-13 A-13 V1 9950.00 9000.00 1480.93 401.48 1079.45 Pass: Major Risk PB A Pad A-29 A-29 Vi 10969.08 8800.00 1949.22 176.01 1773.21 Pass: Major Risk PB A Pad A-34 A-34 V2 Out of range PB A Pad A-43 A-43 V1 10900.00 9400.00 1401.44 146.08 1255.36 Pass: Major Risk Site: Well: Rule Assigned: Major Risk Wellpath: A-12,PIan 7, A-12A,P Ian #7 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/HSi)istance Area Deviatiou Warning ft ft ft ft ft ft deg deg in ft ft ft 8800.00 8609.86 8800.00 8609.86 45.30 0.00 352.21 0.00 12.250 0.00 169.72 -169.72 FAIL 8900.00 8702.36 8900.00 8702.36 46.25 0.28 351.34 0.00 3.750 0.00 172.32 -172.32 FAIL 9000.00 8782.37 9000.00 8782.37 45.32 1.14 351.34 0.00 3.750 0.00 172.47 -172.47 FAIL 9100.00 8823.05 9100.00 8823.05 46.14 2.40 343.17 0.00 3.750 0.00 176.64 -176.64 FAIL 9200.00 8855.58 9200.00 8855.58 46.66 3.79 334.84 0.00 3.750 0.00 178.85 -178.85 FAIL 9300.00 8876.50 9300.00 8876.50 45.79 5.25 347.03 0.00 3.750 0.00 177.14 -177.14 FAIL 9400.00 8882.50 9400.00 8882.50 42.62 6.46 0.06 0.00 3.750 0.00 168.43 -168.43 FAIL 9500.00 8883.33 9500.00 8883.33 36.42 7.10 14.98 0.00 3.750 0.00 150.52 -150.52 FAIL 9600.00 8882.02 9600.00 8882.02 39.04 8.50 10.08 0.00 3.750 0.00 159.13 -159.13 FAIL 9700.00 8875.19 9700.00 8875.19 41.73 9.99 5.01 0.00 3.750 0.00 167.99 -167.99 FAIL 9800.00 8850.32 9800.00 8850.32 45.56 11.41 354.09 0.00 3.750 0.00 180.09 -180.09 FAIL 9900.00 8824.16 9900.00 8824.16 48.01 12.30 338.58 0.00 3.750 0.00 188.55 -188.55 FAIL 10000.00 8796.74 10000.00 8796.74 47.28 12.49 323.00 0.00 3.750 0.00 188.11 -188.11 FAIL 10100.00 8769.55 10100.00 8769.55 43.43 11.92 307.43 0.00 3.750 0.00 178.46 -178.46 FAIL 10200.00 8745.40 10200.00 8745.40 38.03 11.05 295.18 0.00 3.750 0.00 162.42 -162.42 FAIL 10300.00 8740.17 10300.00 8740.17 38.22 12.50 295.33 0.00 3.750 0.00 162.55 -162.55 FAIL 10400.00 8753.19 10400.00 8753.19 41.06 15.03 299.05 0.00 3.750 0.00 172.86 -172.86 FAIL 10500.00 8775.93 10500.00 8775.93 34.08 13.74 284.25 0.00 3.750 0.00 155.10 -155.10 FAIL 10600.00 8804.90 10600.00 8804.90 26.32 12.06 268.94 0.00 3.750 0.00 135.83 -135.83 FAIL 10700.00 8837.62 10700.00 8837.62 28.27 13.81 270.73 0.00 3.750 0.00 142.48 -142.48 FAIL 10800.00 8869.42 10800.00 8869.42 37.70 18.58 286.47 0.00 3.750 0.00 168.43 -168.43 FAIL 10900.00 8899.28 10900.00 8899.28 30.86 17.18 273.80 0.00 3.750 0.00 150.39 -150.39 FAIL ~i by BP Alaska Anticollision Report ~.r ins INTEQ Company: BP Amoco Date: 9/24/2007 Time: 09125:31 Paget 2 Field: Prudhoe Bay Reference Site: PB A Pad Co-ordinate(NE) Reference: Well: A-12, True North Reference Wells A-12 Vertical(TVD) Reference: 13:12.1 0/14/1980 00:00 77.4 Reference Wellpath; Plan 7, A-12A Db: Oracle Site: Well: Rule Assigned: Major Risk Welipath: A-12,PIan 7, A-12A,PIan #7 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSDistance Area- Deviation Warning Site: PB A Pad Well: A-11 Rule Assigned: Major Risk Wellpath: A-11 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSiltistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10325.00 8741.97 7100.00 6383.32 39.94 89.79 283.90 345.68 2449.56 154.46 2295.10 Pass 10350.00 8744.81 7200.00 6463.84 41.59 94.62 286.58 345.45 2372.29 167.10 2205.19 Pass 10350.00 8744.81 7300.00 6545.06 41.59 97.37 286.64 345.50 2295.72 169.17 2126.55 Pass 10369.68 8747.77 7400.00 6627.12 42.83 101.64 288.62 345.18 2219.92 179.54 2040.38 Pass 10397.53 8752.72 7500.00 6709.83 41.21 101.62 285.32 345.91 2144.86 183.09 1961.77 Pass 10445.90 8762.74 7600.00 6792.87 38.04 98.35 279.91 347.59 2070.15 186.53 1883.62 Pass 10492.94 8774.10 7700.00 6875.90 34.61 93.77 275.07 349.75 1996.05 189.11 1806.94 Pass 10537.35 8786.12 7800.00 6958.87 31.18 88.33 270.91 352.31 1922.79 191.02 1731.77 Pass 10578.29 8798.17 7900.00 7041.86 27.98 82.49 267.48 355.18 1850.58 192.47 1658.10 Pass 10615.22 8809.73 8000.00 7125.10 25.22 76.72 264.81 358.25 1779.46 193.98 1585.49 Pass 10651.01 8821.44 8100.00 7208.69 23.73 73.59 263.91 0.96 1709.58 194.73 1514.85 Pass 10718.87 8843.78 8200.00 7292.59 30.09 91.07 272.66 358.94 1640.64 187.68 1452.95 Pass 10804.76 8870.86 8300.00 7376.57 38.12 110.78 283.12 355.90 1571.89 178.14 1393.75 Pass 10891.38 8896.75 8400.00 7460.35 31.63 96.20 275.93 0.78 1503.02 167.65 1335.37 Pass 10955.42 8915.16 8500.00 7544.18 25.64 81.11 270.69 5.53 1434.50 157.85 1276.65 Pass Site: PB A Pad Well: A-12 Rule Assigned: Major Risk Wellpath: A-12 V1 Inter-Site Error: 0.00 ft Reference Offset .Semi-Major Aais 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 8800.00 8609.86 8800.00 8609.86 45.30 45.30 352.21 0.00 9.625 0.00 211.85 -211.85 FAIL 8900.00 8702.36 8900.00 8702.36 46.25 47.16 351.34 0.00 7.000 0.01 213.06 -213.05 FAIL 8991.96 8777.37 9000.00 8795.63 45.41 48.07 171.62 180.28 7.000 23.81 101.12 -77.31 FAIL 9049.70 8805.90 9100.00 8889.41 44.90 49.27 171.49 180.30 7.000 88.87 84.17 4.70 Pass 9113.29 8827.54 9200.00 8983.46 46.32 52.27 162.89 181.83 7.000 165.70 79.00 86.70 Pass 9172.88 8847.29 9300.00 9077.78 46.57 53.79 153.41 181.80 7.000 243.77 74.79 168.97 Pass 9213.28 8859.24 9400.00 9172.30 46.65 55.59 154.80 178.29 7.000 324.91 76.01 248.90 Pass 9247.69 8867.50 9500.00 9266.95 46.49 57.11 157.42 176.66 7.000 409.58 77.52 332.06 Pass 9276.86 8873.06 9600.00 9361.84 46.16 58.43 160.28 176.01 7.000 497.00 78.36 418.64 Pass 9301.48 8876.69 9700.00 9456.98 45.76 59.60 163.07 175.86 586.61 78.74 507.88 Pass 9322.57 8879.03 9800.00 9552.15 45.32 60.72 165.67 175.98 677.75 78.96 598.79 Pass 9322.77 8879.05 9801.00 9553.10 45.32 60.73 165.69 175.98 678.67 78.96 599.71 Pass Site: PB A Pad Well: A-13 Rule Assigned: Major Risk Welipath: A-13 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/H9)istance Area: Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9975.00 8803.65 7300.00 6865.79 47.76 52.25 349.75 22.86 2188.41 196.79 1991.62 Pass 9975.00 8803.65 7400.00 6956.23 47.76 53.60 351.55 24.65 2114.56 207.13 1907.44 Pass 9975.00 8803.65 7500.00 7046.90 47.76 54.95 353.47 26.57 2042.73 218.02 1824.71 Pass 9975.00 8803.65 7600.00 7137.74 47.76 56.30 355.53 28.63 1973.48 229.49 1743.99 Pass 9975.00 8803.65 7700.00 7228,88 47.76 57.59 357.73 30.83 1906.98 241.45 1665.54 Pass by BP Alaska Anticollision Report ~.r ~~s INTEQ Company: BP Amoco Date: 9!24/2007 Time: 09:25:31 Page: 3 Field: Prudhoe Bay Reference Site: P B A Pad Co-ordinate(NE) Reference: WeIC A-12, True North Reference Well: A-12 Vertical (TVD) Reference: 13:12 1 0/1:4/1980 00:00.77.4 Reference Weilpath: Plan 7, A-12A Db: Orate Site: PB A Pad Well: A-13 Rule Assigned: Major Risk Weilpath: A-13 V1 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/HSUictance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9975.00 8803.65 7800.00 7320.33 47.76 58.84 0.09 33.19 1843.51 253.84 1589.67 Pass 9975.00 8803.65 7900.00 7412.04 47.76 60.06 2.62 35.72 1783.45 266.63 1516.82 Pass 9975.00 8803.65 8000.00 7504.06 47.76 61.23 5.31 38.41 1726.89 279.68 1447.21 Pass 9975.00 8803.65 8100.00 7596.42 47.76 62.36 8.17 41.27 1674.14 292.86 1381.29 Pass 9975.00 8803.65 8200.00 7688.82 47.76 63.48 11.21 44.32 1626.42 306.14 1320.27 Pass 9975.00 8803.65 8300.00 7780.87 47.76 64.60 14.45 47.55 1584.89 319.42 1265.47 Pass 9975.00 8803.65 8400.00 7872.47 47.76 65.72 17.87 50.98 1550.10 332.45 1217.65 Pass 9967.69 8805.66 8500.00 7963.74 47.85 68.08 22.91 54.87 1522.27 348.27 1173.99 Pass 9966.09 8806.10 8600.00 8055.22 47.86 69.42 26.92 58.64 1500.91 360.64 1140.27 Pass 9964.23 8806.62 8700.00 8147.14 47.89 70.75 31.07 62.49 1485.59 371.87 1113.71 Pass 9962.23 8807.17 8800.00 8239.19 47.91 72.10 35.31 66.42 1477.09 381.82 1095.28 Pass 9960.03 8807.77 8900.00 8331.39 47.93 73.44 39.61 70.38 1475.62 390.25 1085.37 Pass 9950.00 8810.54 9000.00 8423.85 48.05 76.16 45.45 74.65 1480.93 401.48 1079.45 Pass 9950.00 8810.54 9100.00 8516.57 48.05 77.03 49.25 78.45 1492.50 405.18 1087.33 Pass 9950.00 8810.54 9200.00 8609.28 48.05 77.89 52.97 82.18 1510.92 407.12 1103.80 Pass 9950.00 8810.54 9300.00 8702.19 48.05 78.73 56.60 85.80 1535.10 407.33 1127.77 Pass 9950.00 8810.54 9400.00 8795.68 48.05 79.53 60.11 89.32 1563.66 405.95 1157.71 Pass 9950.00 8810.54 9500.00 8889.50 48.05 80.34 63.51 92.71 1596.89 403.26 1193.63 Pass 9950.00 8810.54 9600.00 8983.57 48.05 81.16 66.77 95.97 1634.63 399.89 1234.75 Pass 9941.35 8812.91 9700.00 9077.87 48.07 83.79 71.60 99.46 1676.76 401.43 1275.33 Pass 9939.35 8813.46 9800.00 9172.21 48.08 85.09 74.96 102.50 1723.55 397.83 1325.73 Pass 9938.19 8813.78 9860.40 9229.18 48.08 85.89 76.90 104.26 1753.96 395.34 1358.62 Pass Site: PB A Pad Well: A-29 Rule Assigned: Major Risk Weilpath: A-29 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aai~ Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSUistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10605.89 8806.76 7900.00 6517.82 25.90 68.39 277.12 9.09 2444.14 215.27 2228.87 Pass 10618.96 8810.94 8000.00 6599.40 24.94 67.11 277.33 11.36 2382.80 218.89 2163.91 Pass 10631.09 8814.87 8100.00 6681.41 24.09 66.26 277.76 13.68 2323.31 222.63 2100.68 Pass 10864.78 8888.88 8200.00 6763.50 34.00 93.18 289.46 10.14 2261.79 175.75 2086.04 Pass 10890.34 8896.44 8300.00 6845.48 31.73 85.54 288.32 13.00 2202.49 175.05 2027.44 Pass 10911.91 8902.75 8400.00 6927.22 29.75 79.13 287.78 15.84 2145.94 174.76 1971.18 Pass 10930.07 8907.99 8500.00 7008.87 28.05 73.88 287.78 18.68 2092.21 174.77 1917.44 Pass 10945.32 8912.32 8600.00 7090.65 26.60 69.69 288.26 21.53 2041.26 174.99 1866.26 Pass 10958.17 8915.92 8700.00 7172.40 25.38 66.42 289.15 24.41 1993.62 175.46 1818.15 Pass 10969.08 8918.94 8800.00 7254.38 24.34 63.93 290.39 27.35 1949.22 176.01 1773.21 Pass Sife: PB A Pad Well: A-43 Rule Assigned: Major Risk Weilpath: A-43 V1 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/HSUistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft- ft 10325.00 8741.97 7100.00 6287.67 39.94 31.78 297.06 358.84 2469.33 74.08 2395.25 Pass 10350.00 8744.81 7200.00 6371.36 41.59 33.64 300.44 359.31 2390.39 77.73 2312.66 Pass 10350.00 8744.81 7300.00 6454.95 41.59 34.23 301.27 0.14 2312.85 76.75 2236.10 Pass 10369.68 8747.77 7400.00 6538.73 42.83 35.82 304.09 0.64 2236.72 78.99 2157.72 Pass 10381.64 8749.82 7500.00 6622.65 42.14 35.74 303.52 1.80 2162.03 79.09 2082.94 Pass 10400.00 8753.19 7600.00 6705.82 41.06 35.23 302.37 3.31 2089.89 79.72 2010.16 Pass by BP Alaska Anticollision Report ~.r s~~$ 1NTEQ Company: BP Amoco Date: 9/24/2007 Time: 09:25:31 Paget 4 Field: Prudhoe Bay Reference Site: PB A Pad Co-ordinate(NE) Reference: Well: A-12, True North Reference Well: A-12 Vertical (TVD) Reference: 13:12,10/14/1980 00:00 77.4 Reference Weilpat6: Plan 7, A-12A Db: Orade Site: PB A Pad Well: A-43 Rule Assigned: Major Risk Wellpath: A-43 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAaic Ctr-Ctr No-Go Allowable MD TVD MD TVD Ret Offset TFO+AZI TFO-HS Casing/IISflistaoee Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10425.00 8758.20 7700.00 6788.75 39.46 34.18 300.62 5.22 2019.89 81.09 1938.79 Pass 10439.24 8761.26 7800.00 6871.56 38.49 33.76 300.34 7.03 1952.01 81.52 1870.49 Pass 10457.41 8765.38 7900.00 6953.35 37.22 33.00 299.83 9.21 1887.81 82.43 1805.38 Pass 10475.00 8769.59 8000.00 7034.61 35.95 32.19 299.62 11.62 1826.99 83.45 1743.53 Pass 10491.34 8773.69 8100.00 7115.95 34.73 31.38 299.77 14.21 1769.03 84.58 1684.45 Pass 10507.02 8777.78 8200.00 7197.73 33.54 30.54 300.18 16.99 1713.81 85.84 1627.97 Pass 10525.00 8782.66 8300.00 7280.01 32.15 29.43 300.55 20.07 1661.58 87.46 1574.12 Pass 10536.05 8785.75 8400.00 7362.66 31.28 28.87 301.87 23.08 1612.81 88.88 1523.93 Pass 10550.00 8789.75 8500.00 7444.53 30.19 28.06 303.10 26.44 1569.77 90.75 1479.02 Pass 10562.53 8793.43 8600.00 7525.28 29.21 27.33 304.73 29.99 1533.41 92.77 1440.64 Pass 10575.00 8797.17 8700.00 7606.57 28.24 26.57 306.53 33.72 1501.55 94.95 1406.60 Pass 10586.03 8800.55 8800.00 7688.25 27.39 25.93 308.66 37.55 .1474.81 97.19 1377.62 Pass 10600.00 8804.90 8900.00 7769.67 26.32 25.03 310.62 41.68 1454.58 99.27 1355.32 Pass 10607.13 8807.15 9000.00 7850.76 25.80 24.74 313.42 45.59 1441.26 101.86 1339.40 Pass 10866.29 8889.32 9100.00 7933.43 33.87 32.28 324.41 45.33 1424.16 132.37 1291.79 Pass 10875.00 8891.91 9200.00 8017.64 33.11 31.69 326.94 49.23 1410.07 138.37 1271.70 Pass 10892.19 8896.99 9300.00 8101.68 31.56 30.09 328.64 53.62 1402.76 140.94 1261.82 Pass 10900.00 8899.28 9400.00 8186.07 30.86 29.54 331.41 57.61 1401.44 146.08 1255.36 Pass 10914.74 8903.57 9500.00 8271.08 29.48 28.10 333.46 61.96 1405.74 147.54 1258.19 Pass 10925.00 8906.53 9600.00 8356.30 28.53 27.16 335.98 66.09 1416.43 150.02 1266.42 Pass 10925.00 8906.53 9700.00 8440.31 28.53 27.36 339.72 69.82 1436.94 156.54 1280.39 Pass 10933.77 8909.04 9800.00 8522.19 27.70 26.24 342.52 74.00 1463.95 157.71 1306.24 Pass 10925.00 8906.53 9900.00 8599.93 28.53 27.13 347.18 77.28 1490.72 167.44 1323.27 Pass 10925.00 8906.53 10000.00 8667.16 28.53 26.76 350.55 80.65 1513.25 171.34 1341.91 Pass 10909.61 8902.08 10100.00 8719.94 29.96 28.29 355.15 82.86 1530.62 183.61 1347.01 Pass 10900.00 8899.28 10200.00 8770.40 30.86 29.12 358.99 85.19 1545.20 192.41 1352.79 Pass 10883.93 8894.56 10300.00 8822.08 32.31 30.77 3.54 87.22 1564.38 205.11 1359.27 Pass 10875.00 8891.91 10400.00 8874.58 33.11 31.54 7.24 89.52 1590.08 213.33 1376.75 Pass 10600.00 8804.90 10500.00 8928.41 26.32 25.32 3.98 95.04 1620.77 173.40 1447.37 Pass 10575.00 8797.17 10600.00 8983.60 28.24 27.50 9.30 96.49 1646.12 191.66 1454.46 Pass 10575.00 8797.17 10700.00 9041.36 28.24 27.32 11.92 99.11 1675.42 194.04 1481.39 Pass 10558.54 8792.25 10800.00 9100.97 29.52 28.84 16.24 100.89 1709.49 205.94 1503.55 Pass 10550.00 8789.75 10900.00 9162.77 30.19 29.62 19.66 103.00 1747.09 212.67 1534.43 Pass 10550.00 8789.75 10951.00 9195.07 30.19 29.58 20.90 104.24 1768.11 213.27 1554.84 Pass • i g ~ a ~ jo' o ^ I j I I~ f ~ r f I _~it }( t {r +-F ~ } - if -~{hIf j ~ 8 i ~ - ~ ~ I s ~ I -- t 1 ;il ~ ;: ~ ~ - ~ ~ ~ r - 4 F ~ kl., ~I+ ~ , ~ s i~ r ~~ ~ ~ I 1 U U : I I F ! ~ ~ ~ _. ~-`+ ~ a,: !~ ~~ @ a2 1,sa~ E g a~ ~ ~ i I~1 ~ Ii ~ } l it }[}~ i ~ } ~-jj ~ ~ '- ~ ~ j} I ~ 8 ~ 8 ~', R y$ ~ ~ ~. 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S.._. - i,-,-.~, r~,~~1~ ' --- ~ r~ '§ _""•.•"••------ ~ g ~ ~ ~ ~ ~ ~ ~ ~ ~ L~IAlOOL1 (+14iioN/l-1w~oS $ • i ~. a _~~ .;t !; ~~ - z~ a ~~ ~~ ~~ ~ .. a _ 9 5 5 9 2 g Qs~`~ s =3= a~~ .F af~a3 U _ z ~ ~.. z ?r=te O_ ':~ O ~z~ ~~~ ~gggEEggg Cod .~ Z 9 ~ ~ ~_ 3 i 3 3 ~~yyy~ A a~aaaa W ~OZ~~~~¢ ,~ ,~ .-~ -din a.~n 1 V Q QQQQQQ ~ ~NM1 O~Rrn p C N ~ ~ eC R Q Q Q Q Q Q L 1 Iii ' ~_ ~ _ i ~ ~ ' ~~ `~ ~- ,i ~ i i " ,~_ / /,, ~/ _ /, /% ,~_ ~ -~ _ ~; ~ ~ 3~,~ i ;WV ' ' ~ a8fr3 a 3AEa o 8~ = 77 m ~ SA3~3Fga2E=_s_33 a? ~ °-° - P 33 89G ~3..:...'.v:~: '_ -- - va; n =--=- _~ \ \~~ \~ ~ ,,,_ `~ ~ A~~ ~ ~~ ~ ~ \, ~ ~~ ~ `~ Q `~ ~~ '~, L''',~' ~ ~ I ~ ~~ ~~ ~ 1 ~ ~~ ~ ~~ / ~ I ~ \ ~ / [ { ~ / ~ ~ A ~. A ~~ ~ ~ / ~ ~ F / ~ i ~ ~ \, ,, ~ ~ ~ ~__ _ . , \ ,~ ~~ / ~- - ~~' .. iiiiiiiliTiiiiiiil~iiiii'iiiiiiiilii~ilfiliiTiiiiiiiiiii' Rig Floor to Top of Well A-12A 2.25 9.23 5.00 ~ 12.65 ~~- 13.56 ~.~- 21!tE-sooopsi. R-2~t Iud ~ r . . . 14.89 ~ R P•:1 Choh~ _iriN 16.10 ~~ - -~ L~~ricatcr IQ = 6.3?~ ~ •~; th s' Otis Unions ~~~ ? i 16" Annularx +COD psi ? vte- ca, cs~. RX-as Ef r ~ is ~'a -::~T .. , .._,~~, ? 1!16" a7," I'--:i RX-LE ? 1'16 ~Ci:: ~- ? t t 6~ X 3 t'd" Flange a A~ ac~ter Swab Valve SSV Master Valve 26.68 ~ 31.00 Lock Down Screws Ground Level Alaska Department of Natural Resources Land Administration System Page 1 of :v~'~s ~ ~..> .~ ~.i .:J.)ti i_r3f?C ~E....;l~.~. ~ t~i'_ll , ,~ «iz, i ~ ~@r`S .~@2(C~3 ~ut8t8 ~8k31f1$ ~t~t~~l ~~~ ~~ ~sr»n task DNR Case a ary File Type ADS File Number: _„_?82s6 >~ Printable Case File Summary See Township, Range, Section and Acreage? C` Yes r` No New Search LAS_Menu I Case Abstract I Case Detail I Land Abstract File: AllL 28286 ~'j~'I'__ Search far Status Plat Updates .A~ of 09%2~i2007 Customer: 000].07377 'BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV/ AUTH Status Dater 08/19/1965 Total Acres: 2560.000 -ate Initiated: 05/28/1965 Office of Primary Responsibility : DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: ~S NORTH SLOPE Last Transaction: AA-NRB ASSIGNME NT APPROVED 1~1c>ric~icar~: U T~nnnship: O1 1N IZan~r~~: O1 ,E Sc~~~tiofl: 2~ Sc~cli~m ~lcrcrs: 640 Search Plats a1~~ri~li~n1: U I'utirns~lrrp: 011N Runge.' 013E S~:c~i~n~: 26 S'ec~tiuf~r :lcre.c: 640 A1~ r-icliun: l_! Tuu~~t,chii~: O11N Rungtr.~ 013E Sectic~n.~ i 5 ~5'E ctiurr .1 crc.~~: 6~0 :~JL'l7C!lUn: ~.' Iutt'lLC{1[~>: O~1N R~ingt': O~ii~, ~~~eCtZOY7: 3fi .Sf'CI(r)n :~Cl'c',5~: ~i=~~) 0~-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* Cl ~-97 TI I N-R13E- UM 2~, 26, 35, 36 2560.00 E C1 C~ C?'~ C~ Se stl t1'1 It7 c'~11"~/ Last updated on 09/25/2007. http://www.dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28286&... 9/25/2007 • i TRANSMITTAL LETTER CHECKLIST WELL NAME ~~G~ ~/' ~~~ PTD# y~~ ~130Q v Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported ins a function of the original API number stated above. a PILOT HOLE In accordance with 20 AAC 25.OO~i(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for name of well) until after (Com~an~Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Compan~Neme) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 ^^ , , , o m , a N N N - ~ ~ ~ N p ~ ~ ~ ~ ~ ~ ~ . ~, i ~ 3 N c . C ~, O~ ° N ~, ~. O• ~ O~ ~~ N G W~ p) ~ ~ o o O i o. Q. 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M _ W ~ ~ Q N _ O ~ G ~ M ~ ~~ ~ N _ O ~ ~N N O ~ ~ ~ N ~ ~ i ~ Q ~ G. ~ '', = G ~ ~I ~ Q fn U ~ a ¢ a ¢ l W a -w- I ~ ¢Q i • 1Nel I H isiory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history rile. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • **** REEL HEADER **** MWD 08/11/06 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/01/15 174855 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 8870.0000: Starting Depth STOP.FT 10936.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: A-12A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 16' 6.495"N 148 deg 45' 3.571"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 15 Jan 2008 API API NUMBER: 500292051502 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 35 TOWN.N T11N RANG. R13E PDAT. MSL . EPD .F 0 LMF RF FAPD.F 77.4 DMF RF EKB .F 0 EDF .F 77.4 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ~ts"~---130 ~~11 ~-- (2) All depths are Bit Depths unless (3) All True Vertical Depths (TVDSS) (4) All Formation Evaluation data is (5) Baker Hughes INTEQ utilized Coil' Advantage otherwise noted. are Subsea corrected. realtime data. Prak downhole tools and the surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and ' Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CCNL dated 17 Jan 2008 per Doug Dortch with BP Exploration (Alaska), Inc. (8) Tied to A-12 at 8900 feet MD (8625 feet TVDSS). (9) The sidetrack was drilled from A-12 through a milled window in a 7 inch liner. Top of window 8930 ft.MD (8625 ft.TVDS5) Bottom of window 8938 ft.MD (8660 ft.TVDSS) (10) The interval from 10896 feet to 10936 feet MD (8818 feet to 8833 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m ohm.m ohm.m ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, TVD -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 8884.1, 8883.48, ! -0.62207 8886.38, 8885.55, ! -0.829102 8895.92, 8896.54, ! 0.62207 8897.58, 8897.78, ! 0.207031 8902.34, 8901.72, ! -0.62207 8909.19, 8907.94, ! -1.24414 8916.23, 8914.78, ! -1.45117 8921, 89 20.38, ! -0.62207 8924.53, 8923.9, ! -0.62207 8928.46, 8927.63, ! -0.829102 8933.02, 8931.99, ! -1.03613 8938.41, 8938.62, ! 0.208008 8943.39, 8943.6, ! 0.207031 8945.92, 8946.13, ! 0.207031 8951.31, 8950.27, ! -1.03711 8957.11, 8955.45, ! -1.6582 8958.56, 8958.15, ! -0.414062 8960.84, 8959.39, ! -1.45117 8967.06, 8965.61, ! -1.4502 8968.51, 8967.27, ! -1.24316 8973.9, 8972.87, ! -1.03613 8977.63, 8976.6, ! -1.03613 8979.92, 8979.09, ! -0.829102 8981.16, 8980.95, ! -0.207031 8982.61, 8982.61, ! 0 8989.6, 8989.39, ! -0.208008 8992.92, 8992.29, ! -0.62207 8995.82, 8995.4, ! -0.415039 8997.89, 8997.68, ! -0.208008 8999.96, 8999.76, 9003.7, 9003.07, 9005.35, 9004.73, 9008.67, 9009.09, 9018.41, 9018.41, 9023.39, 9023.18, 9025.67, 9025.05, 9031.68, 9031.27, 9035.25, 9035.04, 9037.53, 9037.32, 9040.43, 9040.22, 9046.44, 9046.03, 9050.38, 9049.76, 9053.07, 9053.07, 9069.29, 9069.08, 9078.82, 9078.82, 9082.97, 9082.97, 9107.22, 9107.01, 9113.23, 9112.4, 9129.39, 9129.81, 9197.73, 9197.53, 9202.92, 9201.67, 9206.03, 9206.23, 9225.1, 9224.48, 9226.76, 9226.55, 9243.59, 9244.62, 9246.7, 9247.53, 9255.2, 9255.4, 9270.95, 9272.61, 9363.22, 9366.13, 9365.3, 9367.99, 9370.27, 9372.14, 9380.84, 9382.71, 9396.18, 9397.63, 9403.23, 9404.48, 9411.73, 9413.39, 9415.67, 9416.71, 9424.17, 9427.07, 9464.73, 9467.22, 9513.23, 9514.06, 9603.75, 9602.71, 9605.61, 9604.37, 9611.42, 9609.14, 9614.53, 9612.04, 9618.46, 9615.98, 9622.2, 9619.29, 9647.37, 9646.33, 9657.73, 9655.66, 9681.37, 9680.54, 9687.38, 9685.3, 9691.32, 9689.04, 9694.63, 9692.15, 9699.19, 9697.54, 9704.58, 9701.89, 9708.31, 9706.44, 9712.45, 9710.59, 9718.46, 9717.01, 9738.77, 9736.91, 9740.01, 9738.36, 9742.09, 9739.81, 9746.44, 9743.12, 9766.91, 9765.87, 9773.75, 9772.09, 9780.17, 9776.44, 9791.31, 9789.86, 9803.33, 9801.67, 9818.61, 9818.41, -0.207031 -0.62207 -0.62207 0.414062 0 -0.207031 -0.62207 -0.415039 -0.207031 -0.207031 -0.208008 -0.415039 -0.62207 0 -0.207031 0 0 -0.208008 -0.830078 0.415039 -0.207031 -1.24414 0.207031 -0.62207 -0.207031 1.03613 0.829102 0.207031 1.6582 2.90234 2.69434 1.86621 1.86621 1.45117 1.24316 1.6582 1.03613 2.90234 2.48828 0.829102 -1.03613 -1.24414 -2.28027 -2.4873 -2.4873 -2.90234 -1.03711 -2.07227 -0.829102 -2.07324 -2.28027 -2.4873 -1.6582 -2.69531 -1.86523 -1.86523 -1.45117 -1.86621 -1.6582 -2.28027 -3.31738 -1.03613 -1.6582 -3.73047 -1.45117 -1.65918 -0.207031 9823.8, 9822.76, 9827.94, 9826.7, 9835.61, 9833.33, 9866.5, 9865.46, 9872.29, 9871.88, 9877.68, 9876.44, 9884.32, 9883.28, 9894.06, 9893.02, 9903.22, 9903.02, 9911.31, 9909.44, 9921.67, 9919.6, 9960.38, 9958.51, 9967.84, 9966.18, 9977.58, 9975.51, 9980.28, 9979.04, 9993.33, 9992.09, 10038.9, 10037.4, 10050.1, 10048, 10053.8, 10050.9, 10056.5, 10054, 10065.8, 10061.9, 10073.3, 10070.4, 10083.2, 10080.1, 10086.1, 10082.6, 10091.1, 10089.5, 10100.8, 10099, 10110.2, 10108.7, 10113.9, 10112.2, 10116.6, 10114.1, 10121, 10119.3, 10123.9, 10121.8, 10131.3, 10129.5, 10150.7, 10150.1, 10155, 10154.2, 10160, 10160.2, 10162.3, 10162.7, 10170.6, 10166.2, 10173.5, 10170.6, 10176.6, 10174.5, 10179.1, 10177.2, 10185.1, 10182.8, 10201.7, 10200.4, 10205.6, 10204.2, 10209.1, 10209.4, 10214.4, 10211.7, 10218.6, 10215.5, 10221.3, 10220, 10225.8, 10225.4, 10226.6, 10226.6, 10233.5, 10234.1, 10237.6, 10239.1, 10244.3, 10242.6, 10250.1, 10248.2, 10253.2, 10252.4, 10254.4, 10253.8, 10259.7, 10258.5, 10262.4, 10261.8, 10267, 10267.6, 10270.9, 10271.5, 10274.2, 10274.6, 10277.7, 10277.7, 10282.1, 10282.1, 10285.8, 10284.4, 10288.9, 10288.9, 10293.3, 10292.7, 10302, 10301, ! 10303.6, 10302.8, ! -1.03613 ! -1.24316 ! -2.28027 ! -1.03613 ! -0.414062 ! -1.24316 ! -1.03613 ! -1.03711 ! -0.207031 ! -1.86621 ! -2.07227 ! -1.86621 ! -1.65918 ! -2.07227 ! -1.24414 ! -1.24414 ! -1.45117 ! -2.07324 ! -2.90234 ! -2.48828 ! -3.93848 ! -2.90234 ! -3.10938 ! -3.52344 ! -1.6582 ! -1.86523 ! -1.4502 ! -1.6582 ! -2.4873 ! -1.65918 ! -2.07227 ! -1.86523 ! -0.62207 ! -0.829102 0.207031 ! 0.415039 ! -4.35352 ! -2.90234 ! -2.07324 ! -1.86523 ! -2.28027 ! -1.24414 ! -1.45117 ! 0.208008 ! -2.69531 ! -3.10938 ! -1.24414 ! -0.415039 I 0 ! 0.62207 ! 1.45117 ! -1.6582 ! -1.86621 ! -0.829102 ! -0.62207 ! -1.24414 ! -0.62207 ! 0.62207 ! 0.62207 ! 0.414062. ! p ! 0 ! -1.45117 ! 0 ! -0.62207 -1.03613 ! -0.829102 10305.1, 10305.9, ! 0.829102 10307.8, 10311.7, ! 3.93848 10310.7, 10313.6, ! 2.90234 10313.4, 10314.8, ! 1.45117 10329.2, 10330, ! 0.829102 10334.8, 10335.6, ! 0.830078 10341.6, 10343.5, ! 1.86621 10349.5, 10350.3, ! 0.829102 10367.7, 10368.6, ! 0.829102 10370.8, 10372.4, ! 1.6582 10373.3, 10374.5, ! 1.24414 10376.6, 10378.5, ! 1.86523 10388, 10389, ! 1.03711 10391.1, 10391.9, ! 0.829102 10419.5, 10416.8, ! -2.69531 10423.6, 10420.5, ! -3.10938 10426.1, 10422.6, ! -3.52344 10438.6, 10438.1, ! -0.414062 10459.3, 10457, ! -2.28027 10464.3, 10461.2, ! -3.10938 10512.3, 10507.9, ! -4.35352 10515.4, 10511.3, ! -4.14551 10528.7, 10523.5, ! -5.18262 10563.1, 10561.5, ! -1.6582 10577.8, 10573.5, ! -4.35352 10582, 10577.4, ! -4.56055 10584.7, 10580.3, ! -4.35254 10592.7, 10587.9, ! -4.76855 10601.4, 10597.9, ! -3.52344 10605.6, 10601.4, ! -4.14648 10611.1, 10605.5, ! -5.59766 10614.2, 10607.3, ! -6.84082 10653.8, 10650.6, ! -3.10938 10657.1, 10652.7, ! -4.35352 10662.5, 10658.9, ! -3.52441 10670.7, 10667.8, ! -2.90137 10674, 10671.9, ! -2.07324 10733.4, 10727.6, ! -5.80469 10736.5, 10732.8, ! -3.73145 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 276 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN A-12A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. ! • WN A-12A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** iiiiiiiiiiiiiiiiii! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumgerger GR CCNL dated 17 Jan 2008 per Doug Dortch with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 115 Tape File Start Depth = 8870.000000 Tape File End Depth = 10936.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 128 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN A-12A.xtf LCC 150 CN BP Exploration (Alaska) WN A-12A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!~!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: LIFO MNEM ----- CHAN DIMT ------------------ CNAM --- - ODEP GR GR - ------- GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 229 Tape File Start Depth = 8879.000000 Tape File End Depth = 10936.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 242 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/01/15 174855 01 **** REEL TRAILER **** MWD 08/11/06 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS ~ i Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8870.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8870.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8900.0000 134.8754 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9000.0000 143.0561 16.5835 2000.0000 94.0228 -999.2500 -999.2500 9100.0000 24.4918 16.1000 9.4522 8.8051 -999.2500 -999.2500 9200.0000 43.8797 75.7918 5.3537 5.1795 -999.2500 -999.2500 9300.0000 36.8052 40.0683 11.4339 12.6796 12.7970 15.3925 9400.0000 43.4811 112.8953 15.1160 14.0161 14.5600 16.1200 9500.0000 34.7177 44.1894 9.1944 7.8517 7.2477 7.3023 9600.0000 46.6453 122.9414 17.2920 13.1872 12.3231 12.3356 9700.0000 147.6951 40.8593 18.1231 19.9609 16.2239 16.7261 9800.0000 37.7644 93.7725 2000.0000 52.9219 37.1431 35.9171 9900.0000 30.1152 64.9762 2000.0000 273.1960 54.7080 46.9009 10000.0000 29.9144 143.9142 2000.0000 1027.2578 67.7887 60.5945 10100.0000 27.8093 121.9546 2000.0000 70.2721 51.1400 52.5745 10200.0000 245.1414 60.2701 24.5091 31.0216 26.7092 28.5851 10300.0000 164.6069 46.1564 2000.0000 2000.0000 2000.0000 357.6435 10400.0000 32.5085 107.7409 24.3912 38.7105 34.0670 42.5674 10500.0000 41.0109 133.7160 22.9452 17.9109 13.1670 11.6618 10600.0000 66.1681 75.7550 29.0608 26.7508 18.6970 17.2453 10700.0000 38.0726 121.9332 26.4033 26.6432 ~ ~ 23.2817 24.6445 10800.0000 33.4578 90.0195 10.1039 8.3538 8.1400 10900.0000 -999.2500 304.2818 12.6761 13.5807 17.0325 10936.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8870.000000 Tape File End Depth = 10936.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 9.4385 13.0788 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8879.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8879.2500 102.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8900.0000 103.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9000.0000 168.6000 17.0000 2179.3999 94.2620 38.9370 28.8770 9100.0000 24.7000 16.1000 9.4680 8.8060 7.8840 7.6900 9200.0000 50.9000 78.8000 5.3860 5.1760 4.8420 4.9610 9300.0000 39.8000 38.0000 11.8110 13.0600 13.2940 16.3120 9400.0000 69.6000 112.8000 13.7330 13.4920 14.3780 16.1200 9500.0000 33.6000 42.2000 8.9400 7.6380 7.0350 7.0160 9600.0000 46.6000 33.7000 16.9830 12.9950 12.1010 11.9590 9700.0000 138.0000 91.6000 19.8660 23.4500 20.0350 22.3360 9800.0000 39.1000 80.4000 2179.3999 50.2920 36.6640 35.4410 9900.0000 28.3000 83.4000 2179.3999 263.7590 54.3150 46.1930 10000.0000 30.5000 138.6000 2179.3999 440.6000 66.9580 59.0230 10100.0000 27.8000 112.7000 2179.3999 74.8410 52.2950 51.9270 10200.0000 254.1000 50.7000 23.5860 31.0140 27.1850 30.5820 10300.0000 174.3000 17.5000 2179.3999 6064.5400 1716.2100 311.4460 10400.0000 31.9000 107.2000 23.4020 38.1000 33.6870 41.9940 10500.0000 30.5000 109.1000 23.1010 17.5180 12.6770 11.0210 10600.0000 35.5000 67.4000 24.2930 20.8480 15.8040 14.2460 10700.0000 36.3000 91.8000 21.3400 18.5100 • 15.2790 14.5280 10800.0000 27.8000 90.8000 9.1200 6.7290 6.1910 10900.0000 -999.2500 39.7000 13.9160 12.5920 13.6310 10936.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8879.000000 Tape File End Depth = 10936.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 7.8200 13.2170 -999.2500 • Tape Subfile 4 is type: LIS