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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-07A PRUDHOE BAY UNIT NGI-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 NGI-07A 50-029-20210-01-00 206-126-0 G SPT 7909 2061260 1977 3375 3376 3375 3375 21 212 200 202 4YRTST P Adam Earl 6/20/2022 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-07A Inspection Date: Tubing OA Packer Depth 189 2208 2179 2179IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622085359 BBL Pumped:3.5 BBL Returned:3.5 Wednesday, July 20, 2022 Page 1 of 1 3URSHUW\'HVLJQDWLRQ /HDVH1XPEHU 2SHUDWLRQV 3HUIRUPHG 2SHUDWRU1DPH $GGUHVV :HOO&ODVV%HIRUH:RUN 3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU /RJV /LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$& )LHOG3RRO V $EDQGRQ 6XVSHQG 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV 5HHQWHU6XVS:HOO 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ &DVLQJ /HQJWK 6L]H 0' 79' %XUVW &ROODSVH 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)RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 2:16 pm, Dec 27, 2021 'LJLWDOO\VLJQHGE\%R<RUN '1 FQ %R<RUNF 86R +,OFRUS $ODVND//&RX $ODVND1RUWK 6ORSHHPDLO E\RUN#KLOFRUSFRP 'DWH %R<RUN 0*5'(& SVL '65 ; '/% JLC 1/4/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.04 14:47:15 -09'00' RBDMS HEW 1/5/2022 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗E'/ͲϬϳW/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϮϭϬͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐ/ŶũĞĐƚŽƌ >ĞŐ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶ ϭϱƚŚ͕ϮϬϮϮ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂů ZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞ ZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗ĂƌƌŝĞ :ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽ ƌŝůůEƵŵďĞƌ͗ϮϬϲͲϭϮϲ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϰϲϳϮ Ğůů͗ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůů ŶŐŝŶĞĞƌ͗ZLJĂŶdŚŽŵƉƐŽŶ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϱϮϴϬ Ğůů͗ϵϬϳͲϯϬϭͲϭϮϰϬ 'ĂƐ/ŶũĞĐƚŝŽŶZĂƚĞ͗ ΕϮϮϯ͕ϬϬϬ DƐĐĨͬĂLJ /ŶũĞĐƚŝŽŶWƌĞƐƐƵƌĞ͗ϯ͕ϰϬϯ ƉƐŝ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ; ƐƚŝŵĂƚĞͿ͗ϯϮϱϬ ƉƐŝ WƌŽŐƌĂŵKďũĞĐƚŝǀĞ;ƐͿ͗ E'/ͲϬϳ ŝƐĂŐĂƐ ĐĂƉ ŝŶũĞĐƚŝŽŶǁĞůůƚŚĂƚŚĂƐĚĞŵŽŶƐƚƌĂƚĞĚĂĚĞĐƌĞĂƐĞŝŶŝŶũĞĐƚŝǀŝƚLJ͘dŚĞǁĞůůŚĂƐŶŽƚďĞĞŶǁĂƚĞƌ ǁĂƐŚĞĚƐŝŶĐĞ 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(43/6 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. NGI-07A FROM: Brian Bixby PRUDHOE BAY UNIT NGI-07A i Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 317-12--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-07A API Well Number 50-029-20210-01-00 Inspector Name: Brian Bixby Permit Number: 206-126-0 Inspection Date: 6/3/2018 Insp Num: mitBDB180603144958 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well T - - T e In G --- - ---- NGI-07A VD 7909 ' Tubing I 3305 3304 - 3305 - 3291 YP J PTD 2061260 ' • Type Test SPT (Test psi 1977 , j IA 10 2500 - 2485 -! 2480 -H BBL Pumped: 3.5 `FBBL Returned: r 3 I OA 1 1 136 • 131 - 130 - - Interval 4YRTST IPF i P v Notes: SCANNED JUN 2 2 cU 16 Tuesday,June 05,2018 Page I of 1 • Image Project Wel! History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o~~ ~ - ~~ ~ Well History File Identifier Organizing done) ^ Two-sided III 111111 II III II III ^ Rescan Needed (~~ ~~~~~~ ~~ ~~ III ~~~ RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. f ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Q g /s/ Project Proofing III 111111 VIII II III BY: aria Date: ~ Qg /s/ Scanning Preparation _~ x 30 = ~ + J =TOTAL PAGES~Q~~ (Count does not include cover sheet) ,/t /~ BY: Maria Date: /s/ r 'Y_I[_ Production Scanning III (I'I!I VIII II III Stage 1 Page Count from Scanned File: -~E~-'~- (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: YES NO BY: Maria Date: ' / / ~ Q g /s/ 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 ~I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked (I~ ~~~~~~ ~~I ~~~~ III 10/6/2005 Well History File Cover Page.doc i • ;~ ~:,. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 1s N~~ DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061260 Well Name/No. PRUDHOE BAY UNIT NGI-07A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20210-01-00 MD 8671 TVD 8576 Completion Date 10/15/2006 Completion Status 1GINJ Current Status 1GINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No _ Directional Sunre Ye~ DATA INFORMATION Types Electric or Other Logs Run: MWD. DIR, GR, RES, PWD, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt I~fmber Name ED ~D Asc~ Directional Survey og Ceme t Evaluation ED C Las 15438 'See Notes Rpt ~ LIS Verification ~~~{ZCt ED C Lis 16479 In~~duction/Resistivity ED C Pds 16884vSee Notes Induction/Resistivity og Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop (data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH / CH Received Comments 2401 8671 Open 11/9/2006 5 Col 1 100 8025 Case 1/22/2007 USIT, GR, CCL 13-Oct- 2006 2424 8671 Open 9/17/2007 Field Data, LAS - GR, ROP w/EMF Graphics 2073 8665 Open 6/19/2008 LIS Veri, GR, RPS, RPM, RPX, ROP, FET 2073 8665 Open 6/19/2008 LIS Veri, GR, RPS, RPM, RPX, ROP, FET 0 0 9/16/2008 TVD and MD EWR logs in PDS graphics 25 Co! 2464 8671 Open 9/16/2008 MD ROP, DGR, EWR 12- Oct-2006 25 Col 2415 8526 Open 9/16/2008 TVD ROP, DGR, EWR 12- Oct-2006 Sample Set Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y1C,pD Daily History Received? Chips Received? y4-1+i~ Formation Tops / N Analysis Y(y/ Received? DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061260 Well Name/No. PRUDHOE BAY UNI7 NGI-07A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20210-01-00 MD 8671 ND 8576 Completion Date 10/15/2006 Completion Status 1GINJ Current Status 1GINJ UIC Y Comments: Compliance Reviewed By: Date: ~ ~ WELL LOG TRANSMITTAL To: State of Alaska August 21, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: NGI-07A AK-MW-4618256 NGI-07A• 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20210-0 l 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20210-01 Digital Log Images: 1 CD Rom 50-029-20210-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 - /1 '"lf 1 Date: ~ ` _ ~ - ~ ~' Signed: ~ ~ v 3 WELL L®G TRANSMITTAL To: State of Alaska June 10, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: NGI-07A AK-MW-4618256 1 LDWG formatted CD rom with verification listing. API#: 50-029-20210-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 ri Anchorage, Alaska 99508 _. ~~ ~~ _- _ , , ~ ~~ Date: _ . ` ~ '~ ~.._-______ Signed ~, /_ ,~J ~p Date 09-14-2007 Transmittal Number:92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have anv questions, please contact llou~las llortcn at the rli~ a[ ~o4-4y ! 3 u~C slivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 1106-06B ~ ~5 vab x'06-06BPB1 ~ a~-~~ ~ ~ c~a~ '13-31A-uTcaoS-/boo ,ct5~l2'~ 14-11 A `~ ao~ ~a6 Y ~b 14-11APB1 14-21A u=eao5 -~v~ ~ ~5 ~/3! 15-39A ao(o-o~~r ~ ~~a 16-066 aoc,-o ~ i '' ~ sy33 16-14Bao(o•o~3 "~5~,/3</ c-osB aos- ~~ ~ ~~s J-17C ~~ O~s2 ~ 45~-r3'3' NGI-07A ~'z~aoC.-iaL j°" ISolc3~l %'• ~ 'f Please tgn 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 ~±~~ ~ `~" _~ ~: m .~%l ~„ _ y ryrr~ ..~r. -- Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99~ 19-6612 ovzzi2oo~ SChlunlber~~er Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth z~ ao~ - ray Wall _Inh ~t 1 nn nncnrin4inn NO. 4112 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn; Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~to GI r..~... rn MPS-10A 11076475 CH EDIT SCMT (PDC-GR) 10/17/05 1 15-08CL1 10942196 CH EDIT JEWELRY (PDC-GR) 03/01/05 1 Z-12 11513657 RST 12/06/06 1 1 L3-11 11533392 RST 12/31/06 1 1 AGI-10A 11485869 USIT 11109/06 1 GNI-02A 11485873 USIT 11/15/06 1 GNI-02A 11485874 MDT 12/03/06 1 12-18 NIA USIT 11!17/06 1 NGI-07A 11212892 USIT 10/13!06 1 DS 12-14AL7 11540230 CORROSION & CBL 12/18/06 1 01-23 11549351 USIT 12/16/06 1 WGI-09 11486172 USIT 12/03/06 1 r LCMAC Fil+n1VVYYLCUl7C RCli Clr' 1 6T Al171V11V17 AIVU Kt 1 UKIVIN(i IJNt I+VY• tA(:hl 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & i~onsWtu/tj~+3gKVic~s 2525 Gambell Stileet~'b`mtek400~L,~., Anchorage, AK 99503-2638 ATTN: Beth r r rr~ ~~.~ ~a ~ ?a~r,~,, ,, Received by: STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMI ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~' 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAAC zs.,,o ® GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Ciass: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/15/2006 12. Permit to Drill Number 206-126 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/2/2006 13. API Number 50-029-20210-01-00 4a. Location of Well (Governmental Section}: Surface: ' ' 7. Date T.D. Reached 10/11/2006 14. Well Name and Number: PBU NGI-07A 216 FNL, 989 FWL, SEC. 12, T11N, R14E, UM Top of Productive Horizon: 509' FNL, 1507' FWL, SEC. 12, T11 N, R14E, UM 8. KB Elevation (ft): 48.85' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Tota! Depth: 513' FNL, 1509' FWL, SEC. 12, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 8671 + 8576 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 687182 y- 5972100 Zone- ASP4 10. Total Depth (MD+TVD) 8671 + 8576 Ft 16. Property Designation: ADL 028302 TPI: x- 687708 y- 5971820 Zone- ASP4 Total Depth: x- 687710 y- 5971816 Zone- ASP4 11. Depth where SSSV set 2136 MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD, DIR, GR, RES, PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH<TVD HOLE AMOUNT .SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 urface 81' Surface 81' 32" 240 sx Arctic Set A rox. 13-3/8" 72# MN-80 Surface 4' Surface 2424' 17-1/2" 4800 sx Permafrost II 9-5/ " 47# L-80 812 ' 0' 8031' 1 -1/4" 2 sx Lite r e 62 x I s'G' 7" 26# L-80 8045' 8670' 7950' 8575' 8-1/2" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD .PACKER SET MD 7" Slotted Liner 7-5/8" x 7", 29.7# x 26#, 8049' 8004' MD TVD MD TVD L-80 x TCII 8108' - 8669' 8013' - 8574' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 100 BBLS of Diesel 26. PRODUCTION TEST Date First Production: November 5, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK} 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". 4, ~ ~ ~ f~~ ~ ~,~ d~ul, Z~lzy.,.~ None ~ "` Lo~~; ~.... z yz y y~ I~r Form 10-407 Revised 12/2003 _ ~ ~ CONTINUED ON REVERSE SIDE ~ ~ ~~~~ _.....,..~ . .,•~. a..P G 28. ~ GEOLOGIC MARKERS 29. NATION TESTS Include and briefly summarize test results. List intervals tested, NaMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4938' 4843' None West Sak 2 6277' 6182' West Sak 1 6462' 6367' Colville Mudstone 6710' 6615' TH RZ 7922' 7827' BHRZ 8112' 801 T Top of Put River 8112' 8017' Bottom of Put River 8195' 8100' LCU 8195' 8100' Sag River 8195' 8100' Shublik 8240' 8145' Sadlerochit 8284' 8189' TCGL /Zone 3 A 8369' 8274' 22TS 8534' 8439' 21TS /Zone 2 A 8565' 8470' TZ1 B 8605' 8510' Base of Sadlerochit 8671' 8576' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. i Signed Sondr tewman ~ Title Technical Assistant Date (`' ~ - t~C(j PBU NGI-07A 206-126 Prepared i3y NameMumber.• Sondra Stewman, 564-4750 Well Number Drilling Engineer: Barbara Lasley, 564-5126 Permit No. / A royal No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Class cation of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 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). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 2T: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE _ 4NELLHEAD= ~ McEvoy/Gray ACTUATOR= Axelson KB. ELEV = 28.86' BF. ELEV = 17.05' KOP = 2455' Max Angle = 27at 3395' Datum MD = 8849' ss Datum TV D = 8800' ss NOTF~S: This is the field Nq NC07A FINAL osalwell** 2125` 7 5/8" x 7" XO 2136' 7" CAMCO DB SSSV NIP, ID = 6.0" TGII TO VAM TOP HC X-OVER 2147' 7" x 7 5/8" XO Baker WS for 72# csg, KOP in 13-3/8" 2446' 13 3/8" EZSV (--~ 2452' 9 5/8" Cut 1-`I 2424' 13-3(8" CSG, 72#, N-80, I©= 12.347" ( 2725' 9 5/8" FZSV 2972' Top of 7" 3025' Minimum ID = 5.770" @ 8028 7" HES RN NIPPLE TOP OF 7" LNR 7446' 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" 7736' PERFORATION SUMMARY REF LOG: BHCS 05/10/76 ANGLE AT TOP PERF: 8 @ 8032' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1" 18 8108'-8669' OPN 10/11/06 Lnr 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" ~ 8645' __ 7 5/8" TBG, 29.7#, L-80-IPC, VAM TOP HC, ID = 6.875", 0.04591 BBL/FT 7 5!8" x 7" 26# TGII TO VAM 7972, TOP HC XO I 7983' 7" R Nipple, ID = 5.963" 9 518" x 7" Baker S-3 Pkr, 7" 8004' 26# TGII, ID = 6.059" 8028' 7" RN Nipple, ID = 5.770" 7" HMC Liner hanger/ ZXP 8045' Packer w / 10' TBS (7.5" ID) 26# BTC 8049' 7" 26# TGII WLEG ~ $Y-----' TGII, ID = 8.681", 0.07321 BBL/FT DATE REV BY COMMENTS DATE REV BY COMMENTS 07115/76 Original Completion 04!08/83 Last Workover 03(17/06 KSBITLH Fish pulled (03/12/06) 03123!06 DFR/PJC IBP set at 7423 03/27!26 RPH/PJC Waiver safety note deleted 10115106 BMLfBR Sidetrack End of Well 8671' 7" 26# TD 8671' 7" 26# L-80 Perforated PBTD PRUDHOE BAY UNIT WELL: NGI-07A PERMIT No: 1760380 API No: 50-029-20210-01 SEC 12, T11 N, R14E, 4237.14' FEL & 272.21' FNL BP F~rploration (Alaska) BP EXPLORATION Operations Summary Report Page 1 of 19 Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours Task Code NPT ~ Phase ~ Description of Operations 9/21/2006 15:30 - 00:00 8.50 RIGU P PRE Rig released from 15-39A at 15:30 hrs. Blow down rig Rig down service line Separate rig modules 9/22/2006 100:00 - 17:00 I 17.00 I RIGU I P 17:00 - 23:00 I 6.001 RIGU I P 23:00 - 00:00 I 1.001 RIGU I P 9/23/2006 ~ 00:00 - 12:00 12.00 I RIGU P PRE Prepare to move from Drili Site 15 to NGI pad. Separate modules and install moving systems Clean up location, removing hecurlite and matting boards Transported Pipe shed, motor complex, pump module, pit module and sub base to NGI pad from DS 15 Install Emergency Descent device in derrick after pulling sub off DS15-39A PRE Set matting boards and Herculite for Sub Base, Spot Sub over well OpsionlA&OA PRE Set matting boards and Herculite for Pipe Shed, Spot Pipe Shed PRE PJSM, Set rig mats and lay herculite for pits and motor complex, set complexes in place. Set rig mats and set pump complex in place. Berm around alt complexes, Connect service lines, electrcal, water, steam, Connect to Rig power Rig up mud pump suction lines and pump line to rig floor -Finished installing Emergency descent device in derrick. Rig accepted at 12:00 hrs on 9/23/2006 12:00 - 15:00 3.00 WHSUR P DECOMP PJSM, Rig up Little Red pumping services, Test all lines and valves to 3000 psi, good test. 15:00 - 17:30 2.50 WHSUR P DECOMP PJSM, Test Tubing x 9 5/8 annulus (IA ) pumped 3.1 bbls to 2000 psi, bled off to 1600 psi in 6 minutes, continued to bleed off to 1525 psi after 17 minutes, bleed off tubing, 2.5 bbl. bled back Test 13 3/8 x 9 5/8 annulus - (OA) pumped 1.7 bbls to 2000 psi, charted for 30 min., bleed off to 1800 psi over the 30 minutes, bleed off OA, 1.7 bbl. bled back Held Pre-spud meeting with rig crew 17:30 - 19:00 1.50 WHSUR P DECOMP PJSM, Rig lubricator and pull BPV with Drill site maintenance 19:00 - 21:30 2.50 W HSUR P DECOMP Rig up test manifold in cellar to displace methanol/water freeze protect out of well 21:30 - 22:00 0.50 WHSUR P DECOMP PJSM, Test mud lines, choke lines and test manifold to 4000 psi for 5 min., Good Test 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM, Circulate 56 bbl of 9.8 ppg heated Brine down tubing to displace 60/40 MW from annulus. Circulate through choke and into cuttings tank C~ 3 BPM and 280 psi. Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Operations Summary Report Page 2 of 19 Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: ~ Date ;From - To Hours Task i Code NPT Phase Description of Operations 9/23/2006 22:00 - 00:00 2.00 WHSUR P DECOMP Shut down and pump down the annulus to displace the 81 bbl 60/40 MW from the tubing. Circ. @ 3 BPM and 200 psi Continue circulating until returns are Clean 9.8 ppg brine 190 bbfs total pumped around. Shut down and verify the well is dead and in balance 9/24/2006 00:00 - 01:30 1.50 WHSUR P DECOMP PJSM, Rig down lines from test manifold in cellar and blow down choke manifold 01:30 - 03:30 2.00 WHSUR P DECOMP PJSM, Rig up DSM lubricator and set BPV with Drill Site Maintenance -Tested below BPV to 1000 psi for 5 min., Good Test Rig down lubricator and lay out 03:30 - 05:30 2.00 WHSUR P DECOMP PJSM, Remove Christmas tree, Cameron tech.'s inspected hanger threads, adapter and tubing hanger. Plug SSV lines. 05:30 - 06:00 0.50 WHSUR P DECOMP PJSM, Nipple up BOP's 06:00 - 10:00 4.00 BOPSU N RREP DECOMP Change out wire rope on bridge cranes in cellar. Lines damged during spooling on to drum. 10:00 - 19:30 9.50 BOPSU P DECOMP Nipple up BOPE's, torque all bolts on adapter spool, connect choke hose, kill lines & hyd. lines. M/U bell nipple and attach to flowline, Set drip pan, install turnbuckles & center stack Energize stack and function test rams, good test 19:30 - 21:30 2.00 BOPSU P DECOMP PJSM, Change top set of pipe rams to 4 1/2 x 7" variables 21:30 - 00:00 2.50 BOPSU P DECOMP Test BOPE's -testing to 250 low & 4000 high, test annular to 3500 psi Test witness by BP WSL Dave Newlon, Nabors Toolpusher Rick Brumley, Witness of test waived by AOGCC rep. Lou Giamaldi #1 test- blind rams, HCR vavle to kill line and #1 8~ #2 valve on choke manifold, Set 7" test joint #2 test - Top Pipe Rams, inside manual kill valve, Choke manifold valves 3,4,5,6 9/25/2006 00:00 - 03:30 3.50 BOPSU P DECOMP Continue Testing BOPE's -test to 250 low & 4000 high Test witness by BP WSL Dave Newlon, Nabors Toolpusher Rick Brumley, Witness of test waived by AOGCC Rep. Lou Giamaldi #3 test Choke manifold valves 7,8,9 #4 test Choke manifold valves 10,11,12 #5 test Choke manifold valves 13,14,15 #6 test -HCR valve on choke line #7 test -Manual valve on choke line #8 test -annular to 250 psi low /3500 psi high #9 test -dart valve #10 test -Surface safety vavle #11 test -Lower IBOP #12 test -Upper IBOP Perform accumulator test, Supply 3000psi, manifold 1500 psi, annular 1200 psi Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 3 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From -To Hours I Task Code NPT Phase Description of Operations 9/25/2006 00:00 - 03:30 3.50 BOPSU P DECOMP Function 3000 to 1900psi 200 psi recovery 23 sec. /full recovery 1:20 8 nitrogen bottles - avg 2310 psi 03:30 - 04:30 1.00 BOPSU P 04:30 - 08:00 3.50 BOPSU P 08:00 - 09:00 1.00 PULL P 09:00 - 09:30 0.50 PULL P 09:30 - 10:00 0.50 PULL P 10:00 - 13:00 3.00 PULL P 13:00 - 22:00 I 9.001 PULL I P 22:00 - 23:30 I 1.50 23:30 - 00:00 0.50 9/26/2006 00:00 - 01:30 1.50 P P P All tests passed DECOMP Blow down choke manifold and clear floor from test equip. DECOMP Rig up Lubricator and pull TWC with Drill Site Maintenance DECOMP Rig up floor to Lay Down 7" Tubing PJSM Rig Crews and service Techs. on UD tubing and Hanger DECOMP Run spear into 7" Tubing Hanger, Pull hanger free ~ 210k PUW, free wt. = 125k DECOMP CBU, Monitor well ,PJSM on laying down 7" DECOMP Monitor well (static), Finish rigging up floor and control line spooler PJSM, with Day crew Termininate control line UD 7" tubing hanger and space out pup joint DECOMP UD 74 joints of IFJS 7" tubing and 1 cut off joint 23.90' Recover SSSV control line and 2 SS bands and 27 Otis type (rubber & pin style) clamps, missing 2 SS bands and 1 Rubber type clamp Total of 3024' of tubing recovered DECOMP Rig down tubing Handling Equip. off of floor for test. Drained stack and discovered a SSSV control line rubber clamp and 3 other pieces left in hole and stuck in the stack, Function Rams and drop junk down to top of 9 5/8" hanger. Pick up 1 joint of DP + 10' pup. Push clamps and all pieces into 9 5/8 csg below hanger. Plan is to push the clamps into the rat hole below the EZSV with the casing scaper run. DECOMP P/U 5" test jt & Rig up to test DECOMP Testing BOP rams with 5" test joint -test to 250 low & 4000 high Test witness by BP WSL Dave Newlon, Nabors Toolpusher Rick Brumley, Witness of test waived by AOGCC Rep. John Crisp Test lower pipe ram, passed Test upper pipe ram, passed Test annular, passed 01:30 - 04:00 2.50 BOPSU N SFAL DECOMP M/U wear bushing running tool and wear bushing, RIH (5' stick in), Set 4 LDS, attempted to back out of wear bushing. Unable to release from wear bushing, pull to floor, unable to back out of tool. Lay down running tool and wear bushing together 04:00 - 04:30 0.50 CLEAN P DECOMP Rig up rig tongs and pick up tools from outside 04:30 - 05:30 1.00 CLEAN P DECOMP Pre Job Safety Meeting for picking up BHA Retaliation Policy presentation 05:30 - 06:30 1.00 CLEAN P DECOMP M/U 9 5/8" casing scraper assembly and RIH, P/U HW DP 1 x 1 06:30 - 10:30 4.00 CLEAN P DECOMP RIH picking up singles out of Pipe shed. Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date sits/loos From - To I Hours I Task I Code I NPT ( Phase 10:30 - 12:30 12:30 - 13:00 13:00 - 15:00 15:00 - 15:30 15:30 - 17:00 17:00 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 21:00 21:00 - 22:00 22:00 - 00:00 9/27/2006 100:00- 02:00 02:00 - 03:30 03:30 - 04:30 04:30 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 09:30 09:30 - 11:30 11:30 - 12:00 12:00 - 13:00 Description of Operations 2.00 CLEAN P DECOMP Tag Stub at 3,025' by pipe tally Circulate Safe Surf sweep around MW 9.8 in and out 0.50 CLEAN P DECOMP Monitor Well, well static Pump Dry Job 2.00 CLEAN P DECOMP POH from 3,025' 0.50 CLEAN P DECOMP Lay down Bumper sub, jars, and casing scraper 1.50 WHSUR P DECOMP Set wear bushing in tubing spool, to short to lock down with lock down screws 0.50 CLEAN P DECOMP Service Top drive 0.50 WHSUR P DECOMP Set wear bushing, lock down correctly 0.50 CLEAN P DECOMP Rig up wireline to run gauge ring and junk basket 1.50 CLEAN P DECOMP RIH with junk basket run 1 Recovered assorted pieces of SSSV rubber clamps (1/2 5 gallon bucket of debris) Pre Job Safety Meeting and HACL on Leveling the derrick 1.00 CLEAN P DECOMP RIH with junk basket run 2 Basket was empty Level the Derrick 1.00 CLEAN P DECOMP Lay down Junk basket and pick up Gamma Ray and USIT 2.00 CLEAN P DECOMP RIH with USIT, Gamma Ray, Casing Collar Locator and log from 2,950' to surface 2.00 DHB P DECOMP RIH with EZSV on wireline Correlate depth with second FO and pup RIH to 2,975' bottom of EZSV, 5' above casing collar Set EZSV, 1100 Ibs tension before set, 700 Ibs tension after setting EZSV. Top of EZSV @ 2,972' Bottom of EZSV ~ 2,975' 1.50 DHB P DECOMP POH with wireline and lay down CCL and EZSV setting tool 1.00 CASE P DECOMP Pressure test casing to 3,500 psi, charted for 30 minutes witnessed by Joey LeBlanc WSTL, Rick Brumley NTP 1.50 BOPSU P DECOMP Change upper rams to 9 5/8" 2.00 BOPSU P DECOMP Pressure test Upper Rams low 250 psi, high 4,000 psi Test Witnessed by Chris Clemens WSTL and Keith Carter Driller 0.50 WHSUR P DECOMP Pull test plug and install wear ring 1.00 STCTPL P DECOMP MU multi string cutter BHA 2.00 STCTPL P DECOMP RIH to 2,440' Space out with pup and single 0.50 STCTPL P DECOMP Pump at low rate, 4.0 bbl/min C~? 630 psi slack off to find casing collar, tag ~ 2,472' Pick up to 2,455' with cutter RTW=110K, PUW=110K, SOW=110K Close Lower Annulus Cut 9 5/8" casing, 5.0 bbl/min ~ 1,078 psi, 45 RPMs ~ 5.0 Kft/Ibs WOB=4-5K Shut down rotary and slack off to verify cut Pick up, shut down pumps to close knives, slack off below cut 1.00 STCTPL P DECOMP Pre Job Safety meeting on Circulating Diesel Rig up head pin, TIW valve, and circulate to heat up annulus Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date From - To ~ Hours ~ Task ~ Code j NPT 9/27/2006 12:00 - 13:00 1.00 STCTPL P 13:00 - 13:30 0.50 STCTPL P 13:30 - 14:00 0.50 STCTPL P 14:00 - 18:30 4.50 STCTPL P 18:30 - 19:00 0.50 STCTPL P 19:00 - 22:30 3.50 STCTPL P 22:30 - 23:00 0.50 STCTPL P 23:00 - 00:00 1.00 STCTPL P 9/28/2006 100:00 - 01:00 01:00 - 02:30 02:30 - 03:00 03:00 - 04:00 1.00 CLEAN P 1.50 CLEAN P 0.50 STCTPL P 1.00 WHSUR P Phase DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 04:00 - 05:30 1.50 STCTPL P DECOMP 04:00 - 18:30 14.50 STCTPL P DECOMP 18:30 - 19:30 1.00 STCTPL P DECOMP 19:30 - 21:30 2.00 STCTPL P DECOMP 21:30 - 22:30 1.00 BOPSU P DECOMP 22:30 - 00:00 1.50 BOPSU P DECOMP 9/29/2006 00:00 - 01:30 1.50 BOPSU N SFAL DECOMP 01:30 - 03:00 1.50 CLEAN P DECOMP 03:00 - 05:00 2.00 BOPSU N SFAL DECOMP Description of Operations fluid Close annular preventer and open lower annulus valve to take returns to cuttings tank Pump seawater down drill pipe 1 bbl/min ~ 1,700 psi, returns to cuttings tank Shut down, open annular preventer and close annular valve Rig up and pressure test Little Red to 3,500 psi. Hot Diesel Time 44 bbls 14:00 Displace Drill Pipe Close annular preventer, open annular valve, and take returns to cuttings tank 46 bbls 14:30 Let Soak 30 min 25 bbls 15:12 Let soak 30 min 69 bbls 16:13 Let soak 30 min 180 bbls 17:51 Rig down Little Red With rig pumps displace drill string with brine, 45 bbls 4 bbls/min ~ 545 psi Estimate returns of 46 bbls of Artic Pack Close annulus valve rig down return line to cuttings tank and install pressure gauge monitor well, well static Pull out of hole and lay down cutting tool Pull wear bushing Load pipe shed and rig floor with all fishing tools for next run while waiting on sea water truck Pre Job Safety Meeting on circulating out diesel rig up second return line to cuttings tank to separate Artic Pack from Brine Circulate first 150 bbls of Artic Pack /Diesel mixture into back section of cuttings tank, 100 bbls had green tint 8 bbs/min ~ 545 psi Circulate 250 bbls of brine into front section of cuttings tank 5 bbls/min ~ 280 psi Pick up fishing assembly to spear 9 5/8" casing Spear 9 5/8" casing Pull packing and landing joint 190KIbs to break free, 155KIbs up weight Lay down 9 5/8" spear and rig up 9 5/8" casing equipment Pull and lay down Landing joint, 59 joints of 9 5/8" casing (13 of which had centralizers), 2 Pups on each side of FO, and cut Rig down 9 5/8" casing equipment Clean Artic Pack from Rig floor and drip pan Rig up and wash out BOP Close Blinds, drain stack, and change top rams to 5" Attempt to test upper rams, test plug leaking After stacking weight and pulling test plug to inspect and reseat, still could not get test plug to hold Called Cameron, mobilize new test plug Rig up and pick up 6 collars while waiting on test plug Run new test plug, still could not test Stacked 15KIbs on test plug, still could not test Pulled inspection port, "O"ring of test plug sitting in Flange Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NG--07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date I From - To I Hours I Task I Code I NPT 9/29/2006 03:00 - 05:00 2.00 BOPSU N 05:00 - 09:30 4.50 CLEAN P 09:30 - 10:30 1.001 BOPSUp P 10:30 - 11:00 0.50 WHSUR P 11:00 - 14:00 3.00 CLEAN P 14:00 - 14:30 0.50 CLEAN P 14:30 - 16:00 1.50 CLEAN P 16:00 - 17:00 1.00 CLEAN P 17:00 - 19:00 I 2.001 CLEAN I P 19:00 - 21:30 1 2.501 CLEAN I P 21:30 - 22:30 1.00 CLEAN P 22:30 - 00:00 1.50 CLEAN P 9/30/2006 00:00 - 00:30 0.50 CLEAN P 00:30 - 02:30 I 2.001 EVAL I P 02:30 - 03:00 0.50 EVAL P 03:00 - 05:30 2.50 DHB P 05:30 - 07:30 I 2.001 DHB I P 07:30 - 09:00 1.50 DHB P 09:00 - 10:00 1.00 DHB P 10;00 - 14:30 I 4.501 STWHIPI P SFAL Phase Description of Operations DECOMP Lay down test equipment DECOMP Pick up remainder of drill collars while chasing down equipment to test Rams Stand Collars back in Derrick DECOMP RIH with test plug Test 5" upper pipe Rams low - 250 psi, high - 4,000 psi Test Witnessed by Chris Clemens WSTL, Dave Hanson NTP DECOMP Install wear bushing DECOMP Make up BHA #4 DECOMP Rig Service/ Top Drive DECOMP Run collars and HWDP out of derrick, 1,234' DECOMP Circulate out Artic Pack Circulate Safe Surf O surface to surface 465 GPM ~ 750 psi PUW=120K, SOW=120K DECOMP RIH picking up singles 39 singles picked up 48 stands total in hole and derrick DECOMP Circulate out Artic Pack Circulate Safe Surf O surface to surface 420 GPM ~ 750 psi PUW=140K, SOW=140K, RWT=140K Torque=l.5K @ 60 RPMs Circulate second Safe Surf O sweep surface to surface 840 GPM ~ 2,400 psi DECOMP POH racking back 5" drill pipe DECOMP Rack back HWDP and Collars DECOMP Lay down Jars and bumper sub Lay down mills screwed together DECOMP PJSM, HACL for rigging up SWS Rig up Wireline RIH log casing collars from 2,955' to 2,200' POH Rig down SWS DECOMP Service rig and finish cleaning shaker room DECOMP PJSM for picking up EZSV Bring all tools to the rig floor Make dummy run thru stack and well head Pick up EZSV and run in hole DECOMP RIH with EZSV on drill pipe out of derrick Set top EZSV ~ 2,452', bottom on top of 9 5/8" stump Pick up to up weight 111 K Rotate 35 turns to the right Pick up 15K to 116K, Close bag, Pick up 15K to 135K, hold for 5 min, pick up to 160K and shear off. DECOMP POH with running tool DECOMP Pressure test casing to 3,500 psi, charted for 30 minutes 54 strokes pressured up to 3,500 psi Test witnessed by Chirs Clemens WSTL and Dave Hanson NTP Clean and clear rig floor during test WEXIT Pickup up Milling/Whipstock BHA Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 7 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours I - - Task j Code ~ NPT Phase Description of Operations 9/30/2006 14:30 - 15:30 1.001 STWHIP P WEXIT TIH to 2,413' on drill pipe out of derrick 15:30 - 16:30 1.00 STWHIP P WEXIT PJSM on rigging up Gyro 16:30 - 18:00 I 1.501 STWHIPI P 18:00 - 19:00 I 1.001 STWHIP P 19:00 - 00:00 I 5.001 STWHIPI P 10/1/2006 100:00 - 01:00 1.001 STWHIP~ P 01:00 - 01:30 I 0.501 STWHIPI P 01:30 - 02:30 1.001 STWHIP P 02:30 - 03:30 I 1.001 STWHIPI P 03:30 - 04:30 I 1.001 STWHIPI P 04:30 - 09:30 I 5.001 STWHIPI P 09:30 - 11:30 I 2.001 STWHIPI P Rig up Gryo WEXIT Orient whipstock to 111 deg Set whipstock ~ 2,452' Bottom anchor set at 18K weight on bit Pulled 20K over to check anchor Brass pin sheared at 45K weight on bit TOW=2,424', BOW=2,446' WEXIT Displace seawater with 9.1 LSND mud 800 GPM 829 psi, no rotation, reciprocating pipe 30 bbl Hi Vis spacer 9.1 ppg LSND mud WEXIT Mill Window from 2,424' to 2,452' 650 GPM C~ 470 psi Tourque off bottom 1.5KfUlbs, on bottom 5-6Kft/Ibs ~ 80 RPMs WOB=2-5KIbs PUW=140K, SOW=140K, RTW=140K WEXIT Mill Window from 2,452' to 2,464' 600 GPM @ 560 psi. Torque off bottom 1.5KfUlbs, on bottom 2KWIbs ~ 100 RPMs W0B=10-15KIbs PUW=140K, SOW=140K, RTW=140K Total of 800 Ibs of metal shavings were collected and weighted WEXIT Circulate Hi Vis Sweep with Super Sweep material surface to surface 840 GPM C~ 1,000 psi 1.8KWIbs of torque C~ 100 RPMs Tight spot when upper mill enters top of window MW = 9.2 ppg in, 9.2 ppg out WEXIT Continue to dress upper section of window PJSM on FIT Rig up for FIT Attempt to slide through but taking weight Dress upper section of window Slide through with no problem WEXIT Perform FIT Hole depth 2,464' Shoe depth 2,435' Shoe TVD 2,435' MW 9.2 PP9 Test Pressure 250 psi EMW = 11.1 pP9 Charted for 10 minutes Witnessed by Joey LeBlanc WSTL and Rick Brumley NTP WEXIT PJSM -Monitor well, well static POH to BHA Rack back HWDP WEXIT Lay down 18 - 6 1/2" drill collars Lay down subs, bumper sub, and mills Upper mill full gauge WEXIT Pull wear ring Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To i Hours Task ~ Code ~ NPT ~ Phase Description of Operations 10/1/2006 09:30 - 11:30 2.00 STWHIP P WEX1T function rams, pump thru kill line, blow thru choke, MU BOP flushing tool and flush metal cuttings out of ram gates. Install wear ring 11:30 - 16:00 4.50 DRILL P INT1 Pick up 81 joints of 5" drill pipe and run in hole Rack back 27 stands in derrick 16:00 - 17:00 1.00 DRILL P INT1 Clean Rig floor Pre job safety meeting for picking up BHA Bring tools up to the rig floor 17:00 - 19:30 2.50 DRILL P INT1 Build BHA to MWD tool Orient to Motor 19:30 - 20:30 1.00 DRILL P INT1 Upload to MW D tool 20:30 - 23:00 2.50 DRILL P INT1 Continue picking up BHA 23:00 - 00:00 1.00 DRILL P INT1 Pick up one joint of drill pipe and test MWD 720 GPM @ 1,430 psi Good shallow hole test PUW=82K, SOW=82K 10/2/2006 00:00 - 02:00 2.00 DRILL P INT1 RIH picking up drill pipe from shed Pick up 50 joints 02:00 - 04:00 2.00 DRILL P INT1 Rig up Gyro to Orient on top of window Circulate bottoms up while rigging up Gyro Obtain ECD baseline data MW=9.1, PV=11, YP=31, 700 GPM ~ 958 psi, CECD=9.2 (from model), AECD=9.17 Orient 115 degrees to slide through window 04:00 - 04:30 0.50 DRILL P INT1 Pick up Joint #51 and slide to top of window without pumps 04:30 - 06:00 1.50 DRILL P INT1 Pick up Stand 18 and slide through window, window slick Drill ahead from 2,464' to 2,523' in sliding mode Low flow to increase dogleg capability in SV sands 500 GPM ~ 900 psi off, 930 psi on, CECD=9.15, AECD=9.15, MW=9.1 WOB=2-5K, PUW=126K, SOW=124K No back ream across whipstock 06:00 - 07:00 1.00 DRILL P INT1 Gryo to verify tool face, scribe still good 07:00 - 08:30 1.50 DRILL P INT1 Drill ahead from 2,523' to 2,618', 75' slide and 20' rotate Low flow to increase dogleg capability in SV sands 500 GPM @ 890 psi off, 1,080 psi on WOB=2-5K, PUW=126K, SOW=124K, RWT=125K Torque 2K off, 5K on ~ 60 RPMs back ream 30' at drilling rate 08:30 - 09:30 1.00 DRILL P INT1 Gyro for Direction and tool face 2,513' 6.50 Inc 127.19 Azi 09:30 - 10:30 1.00 DRILL P INT1 Drill ahead from 2,618' to 2,714', Slide 30% 600 GPM ~ 1,200 psi off, 1,350 psi on W0B=10-15K, PUW=126K, SOW=124K, RWT=125K Torque 1.5K off, 2.9K on ~ 80 RPMs back ream 60' at drilling rate 10:30 - 11:00 0.50 DRILL P INTi Gyro for Directional Survey 2,609' 11.94 Inc 128.35 AZI 11:00 - 12:00 1.00 DRILL P INT1 Drill ahead from 2,714' to 2,808', Slide 30% 600 GPM @ 1,250 psi off, 1,350 psi on W06=10-20K, PUW=126K, SOW=124K, RWT=125K Torque 1.5K off, 2.2K on ~ 90 RPMs back ream full stand at drilling rate Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 9 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 27E Date From - To Hours ~ Task , Code ~ NPT 10/2/2006 11:00 - 12:00 1.00 DRILL ~ P 12:00 - 12:30 0.50 DRILL P 12:30 - 20:00 I 7.501 DRILL I P 20:00 - 00:00 I 4.001 DRILL I P 10/3/2006 ~ 00:00 - 03:30 3.501 DRILL P 03:30 - 06:00 I 2.501 DRILL I P 06:00 - 12:00 I 6.001 DRILL I P 12:00 - 18:00 I 6.001 DRILL I P Spud Date: 9/30/2006 Start: 9/23/2006 End: 10/15/2006 Rig Release: 10/15/2006 Rig Number: Phase ' Description of Operations INTi Noon update ADT=3.24, AST=2.57, ART=0.67 INT1 Gyro for Directional Survey 2,703' 12.97 Inc 127.11 AZI INT1 Good MWD survey; rig down Gyro while drilling stand down Drill ahead from 2,808' to 3,940', Slide 30-40% per stand 700 GPM @ 1,750 psi off, 2,100 psi on, CECD=9.6, AECD=9.7, MW=9.3 W0B=15-25K, PUW=149K, SOW=138K, RWT=143K Torque 1.5K off, 2.2K on ~ 90 RPMs back ream full stand at drilling rate pumped 2 - 25 bbl Hi Vis Sweeps 9.3 ppg 300+ Funnel Vis 3,000' 30% increase in cuttings, 3,500' 20% increase in cuttings INT1 .Drill ahead from 3,940' to 4,400', Slide 30% per stand 700 GPM C~? 1,800 psi off, 2,100 psi on, CECD=9.5, AECD=9.9, MW=9.3 WOB=10-25K, PUW=155K, SOW=145K, RWT=148K Torque 1.OK off, 3.7K on ~ 80 RPMs back ream full stand at drilling rate going up, 70% coming down pumped 25 bbl Hi Vis Sweeps 9.3 ppg 300+ Funnel Vis C~ 3,962' no increase in cuttings, 4,464' 25 bbl weighted Hi Vis sweep 11.8 ppg 300+ Vis with nutplug to identify when it came back, 20% increase in cuttings Midnight update ADT=6.77, AST=3.06, ART=3.71 INT1 Drill ahead from 4,400' to 4,700', Slide 40-50% per stand 700 GPM ~ 1,850 psi off, 2,200 psi on, CECD=9.5, AECD=9.9, MW=9.4 W0B=10-25K, PUW=166K, SOW=154K, RWT=162K Torque 2.7K off, 4.2K on ~ 80 RPMs back ream full stand at drilling rate going up, 70% coming down 4,464' 25 bbl weighted Hi Vis sweep 11.8 ppg 300+ Vis with nutplug to identify when it came back, 20% increase in cuttings, sweep returned very close to calculated surface to surface strokes. INTi Drill ahead from 4,700' to 4,890', Back to vertical, rotate ahead 700 GPM ~ 1,900 psi off, 2,150 psi on, CECD=9.5, AECD=9.9, MW=9.4 WOB=20-30K, PUW=170K, SOW=156K, RWT=165K Torque 2.7K off, 4.2K on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down INT1 Drill ahead from 4,890' to 5,400', Correction slides as need to stay vertical 700 GPM @ 1,960 psi off, 2,200 psi on, CECD=9.5, AECD=9.9, MW=9.4 W06=15-30K, PUW=180K, SOW=165K, RWT=168K Torque 2.7K off, 4.2K on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down Noon update ADT=6.94, AST=1.54, ART=5.40 INT1 Drill ahead from 5,400' to 5,856', Correction slides as need to stay vertical 700 GPM C~3 2,000 psi off, 2,300 psi on, CECD=9.6, AECD=9.9, MW=9.45 W06=5-30K, PUW=194K, SOW=175K, RWT=183K Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date I From - To Hours Task ! Code NPT Phase Description of Operations 10/3/2006 12:00 - 18:00 6.00 DRILL P INTi Torque 3.OK off 5.5K on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down 5,464' 25 bbl Hi Vis Weighted sweep 11.7 ppg 300+Vis surface to surface, cuttings increased by 15% 18:00 - 23:00 5.00 DRILL P INT1 Drill ahead from 5,886' to 6,308', Correction slides as need to stay vertical 700 GPM ~ 2,000 psi off, 2,320 psi on, CECD=9.5, AECD=9.9, MW=9.4 W06=5-30K, PUW=200K, SOW=185K, RWT=185K Torque 3.5K off, 7.OK on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down Midnight update ADT=9.04, AST=0.53, ART=8.51 23:00 - 00:00 1.00 DRILL P INT1 Circulate Hi Vis Weighted sweep 11.8 ppg 300+ Vis surface to surface, cuttings increased by 20% 700 GPM ~ 2,000 psi, 80 RPMs @ 3.5KfUlbs Shakers clean after sweep returned 10/4/2006 00:00 - 00:30 0.50 DRILL P INT1 Continue circulating till bottoms up times two CECD=9.51 AECD=9.60 Shakers clean MW = 9.3 ppg in, 9.3 ppg out 00:30 - 00:45 0.25 DRILL P INT1 Monitor well, well static 00:45 - 01:15 0.50 DRILL P INT1 POH from 6,308' to 5,930' without any problems No over pulls and taking proper fill Pump dry job and install stripping rubbers 01:15 - 02:00 0.75 DRILL P INT1 POH from 5,930' to 5,362' Pulling tight, 30-60K over and trying to swab, hole would wipe clean and over pulls would go away but never would take proper fill, 5 bbl gain with 5 stands 02:00 - 09:00 7.00 DRILL P INT1 POH from 5,362' to 3,555' Backreaming to prevent swabbing 700 GPM ~ 1,900 psi, 80 RPMS ~ 5-6KfUlbs normally, ratty torque in spots 6-12KfUlbs accompanied by an increase in stand pipe pressure typically 100-200 psi. Continue backreaming to the shoe. Hole unloading, 70% increase in cuttings. Slow down backreaming speed to keep ECD below 10.0 ppg. 09:00 - 09:30 0.50 DRILL P INTi Mad Pass from 2,535' to 2,416'. Data to be used to tie into the original well. Limit tripping speed to 300'/hr, trip through window was slick. 09:30 - 10:00 0.50 DRILL P INT1 Monitor well, static loss was 0.7 bbl, 1.4 bbls/hr. Repair flow paddle and Mix dry job 10:00 - 10:30 0.50 DRILL P INT1 Continue MAD passing from 2,416' to 2,230' Circulate bottoms up while MAD passing 700 GPM ~ 1,875 psi, ECD=9.75 ppg, MW = 9.3 ppg in, 9.3 ppg out 40 RPMs ~ 400 ft/Ibs of torque 35% increase in cuttings 10:30 - 12:30 2.00 DRILL P INT1 Monitor well, well static Pump dry job and install stripping rubber POH to BHA 12:30 - 13:30 1.00 DRILL P INT1 Change BHA Motor bearings were loose, picked up new motor with 1.15 ABH Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To i NGI-07 NGI-07 REENTE NABOB NABOB Hours R+COM S ALASK S 27E Task I PLET A DRI Code ~ E LLING NPT Start f Rig Rig Phase Spud Date: 9/30/2006 : 9/23/2006 End: 10/15/2006 Release: 10/15/2006 Number: Description of Operations 10/4/2006 13:30 - 14:30 .1.00 DRILL P INT1 _-- Download MWD data 14:30 - 15:00 0.50 DRILL P INT1 Rig Service -Lubricate rig and service top drive 15:00 - 17:30 2.50 DRILL P INT1 Make up new bit, picked up a HCM 5062 Changed MWD pulser to increase flow range from 700-800 GPM to 800-900 GPM Orient motor to MWD 17:30 - 18:30 1.00 DRILL P INT1 Up link to MWD tools 18:30 - 19:30 1.00 DRILL P INT1 RIH with BHA to the first stand of drill pipe, 1,100' 19:30 - 20:00 0.50 DRILL P INT1 Shallow hole test MWD, Good test 700 GPM @ 1,240 psi Pre-Job Safety Meeting for cut and slip drilling line 20:00 - 21:30 1.50 DRILL P INT1 Cut and slip drilling line, set crown-o-matic 21:30 - 22:00 0.50 DRILL P INT1 RIH to 2,140' 22:00 - 00:00 2.00 DRILL P INTi MAD Pass from 2,135' to 2,450' for gamma ray tie into original well bore Trip in at 300'/hr Trip through window was slick, did not need to orient 10/5/2006 00:00 - 02:00 2.00 DRILL P INT1 RIH from 2,450' to 5,490', hole slick, proper displacement, not pushing away any fluid PUW=165K, SOW=150K 02:00 - 03:30 1.50 DRILL P INT1 Tagged up at 5,490', took 30K to get through, pulled back and went through without any problems. RIH to 5,607', tagged up took 50K to get through, drag increased over all by 10-15K. RIH to 5,774', tagged up and could not get through with 50K. Kelly up and ream to bottom. Std 53 400 GPM ~ 900 psi, 40 RPMs @ 4KfUlbs Std 54 460 GPM Ca? 1,080 psi, 40 RPMS ~ 4Kff/Ibs, stalled motorC5,910' Std 55 500 GPM (~ 1,120 psi, ECD 9.72, 40 RPMs ~ 5Kft/Ibs stalled motor @ 5,954' Std 56 550 GPM @ 1,270 psi, ECD=9.71, 60 RPMS @ 5KfUlbs Std 57 600 GPM ~ 1,520 psi, ECD=9.69, 65 RPMs ~ 6KfVlbs Std 58 700 GPM ~ 1,880 psi, ECD=9.75, 70 RPMs C~ 6Kft/Ibs Bottoms up from start of reaming brought back a lot of coal and sand. 03:30 - 04:30 1.00 DRILL P INTi Circulate Hi Vis Sweep around 300+Vis with 5 sacks of nutplug Calculated Hole volume is 872 bbls, 8,650 strokes Sweep came back at 8,700 strokes with about 20% increase in cuttings 04:30 - 12:00 7.50 DRILL P INTi Drill ahead from 6,308' to 6,795', Correction slides as needed to stay vertical 870 GPM @ 2,910 psi off, 3,150 psi on, CECD=9.41, AECD=9.75, MW=9.3 W06=5-15K, PUW=230K, SOW=185K, RWT=200K Torque 8-10K off, 9-11 K on @ 100 RPMs back ream full stand at drilling rate going up, 70% coming down Noon update ADT=4.46, AST=1.00, ART=3.46 12:00 - 18:00 6.00 DRILL P INT1 Drill ahead from 6,795' to 7,257', Correction slides as needed to stay vertical 870 GPM ~ 2,970 psi off, 3,195 psi on, CECD=9.42, AECD=9.76, MW=9.3 Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Event Name: REENTER+COMPLETE Start: 9/23/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours Task '~ Code -- ___ _ - - --- ......_._--___._-- 10/5/2006 12:00 - 18:00 6.00 DRILL ~ P 18:00 - 00:00 10/6/2006 00:00 - 05:00 6.001 DRILL I P 5.001 DRILL I P 05:00 - 06:00 1.00 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 08:00 1.00 DRILL P 08:00 - 08:30 0.50 DRILL P 08:30 - 10:00 1.50 DRILL P 10:00 - 14:00 4.00 DRILL P NPT f Phase Page 12 of 19 Spud Date: 9/30/2006 End: 10/15/2006 Description of Operations INT1 W0B=8-10K, PUW=235K, SOW=190K, RWT=210K Torque 8-10K off, 10-12K on C~ 100 RPMs back ream full stand at drilling rate going up, 70% coming down 6,883' pumped 25 bbl Weighted sweep, 12.4 ppg - 52 Vis - 24 YP, 20% increase in cuttings INT1 Drill ahead from 7,257' to 7,700', Correction slides as needed to stay vertical 870 GPM C~3 3,050 psi off, 3,300 psi on, CECD=9.72, AECD=9.77, MW=9.6 W0B=8-15K, PUW=260K, SOW=195K, RWT=210K Torque 8-9K off, 11-13K on ~ 100 RPMs back ream full stand at drilling rate going up, 70% coming down 7,500' pumped 25 bbl Hi Vis sweep with 5 sacks of nutplug, 9.5 ppg - 300+ Vis, 10-15% increase in cuttings, Calculated strokes 10,275, started seeing nutplug at 10,300 strokes. Finished weighting up for HRZ at 7,450' Midnight update ADT=9.54, AST=2.07, ART=7.47 INT1 Drill ahead from 7,700' to 8,107', Correction slides as needed to stay vertical 870 GPM @ 3,050 psi off, 3,250 psi on, CECD=9.72, AECD=9.69, MW=9.6 W0B=8-10K, PUW=260K, SOW=200K, RWT=225K Torque 9-11K off, 11-15K on @ 100 RPMs back ream full stand at drilling rate going up, 70% coming down 7,820' noticed a 2% increase in Flow returns, stop and check for flow. Mud bubbling slightly in the bell nipple but not flowing. Sniffed possum belly. Check closely every connection, continue to have bubbling in the bell nipple but well not flowing. INT1 Circulate bottoms up to confirm drill gas 860 GPM f~ 2,900 psi, 990 bbls, 9,900 strokes After bottoms up gas still present, weight up mud INT1 Increase mud weight from 9.6 ppg to 9.8 ppg 250 GPM @ 325 psi, 50 RPM ~ 9.5K ft/Ibs, reciprocating pipe INT1 Circulate heavier mud around before continuing to drill. 9.8PP9-9PV-20YP 500 GPM C~ 1,100 psi, 50 RPMs ~ 9.0 KWlbs, reciprocating pipe INT1 Pickup a single and rotate to TD, 8,126' 870 GPM ~ 3,100 psi off, 3,300 psi on, CECD=9.88, AECD=9.96, MW=9.8 WOB=8-10K, PUW=260K, SOW=200K, RWT=225K Torque 10.5K off, 12.OK on C~ 90 RPMs Geologist picked TD Daily Update ADT=3.35 hrs, ART=3.49 hrs, AST=0.0 hrs INT1 Circulate up a sample which confirmed we TD'ed in the Put River 860 GPM ~ 3,000 psi, 70 RPMs C~3 10,5 Kff/Ibs Geologist estimates we drilled 6' into the Put River MW = 9.8 ppg in and out Monitor well, well static, no gas bubbling INT1 Wiper trip to 100' above section requiring reaming on the TIH with BHA7 Printed: 1D/25/2006 10:01:51 AM BP EXPLORATION Page 13 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 27E Date I From - To I Hours ! Task I Code I NPT 10/6/2006 10:00 - 14:00 I 4.00 t DRILL ~ P 14:00 - 16:30 I 2.501 DRILL I P 16:30 - 21:00 ~ 4.501 DRILL P 21:00 - 21:30 0.50 DRILL P 21:30 - 23:00 1.50 DRILL P 23:00 - 00:00 1.00 DRILL P 10/7/2006 100:00 - 02:00 I 2.00 DRILL P 03:00 - 06:00 3.00 BOPSUR P 06:00 - 10:30 4.501 CASE P 10:30 - 12:00 I 1.50 I CASE I P 12:00 - 17:30 I 5.501 CASE I P 17:30 - 18:30 1.00 CASE ~ P 18:30 - 00:00 I 5.501 CASE I P Spud Date: 9/30/2006 Start: 9/23/2006 End: 10/15/2006 I Rig Release: 10/15/2006 Rig Number: Phase Description of Operations INTi Hole was in great shape, no over pulls greater than 20K and hole took proper fill on the way out and proper displacement on the way in INT1 Circulate a 30 bbl sweep surface to surface + 1 bottoms up 12.5 ppg 120 Vis, 20% increase in cuttings returns and gas bubbles on bottoms up but gas bubbles dissipated after bottoms up 880 GPM ~ 3,110 psi, 10.8K ~ 100 RPMs, CECD=9.88, AECD=9.95 MW = 9.8 ppg in and out Monitor well, well static, no gas present INT1 Pull 2 stands checking for swabbing, hole taking proper fill Pump dry job, blow down top drive, and pull out of hole No over pulls on trip out and hole took proper fill Pick up and slack off weights every 500' on the way out INT1 Rack back 6 stands of HWDP plus Jar stand INT1 Lay down 8" drill collars INT1 Down Load MWD data Clean rig floor, service top drive, crown, blocks, drain motor INT1 Lay down MWD, LW D, Stab, Motor and Bit Bit graded 2-5-BT-N-X-1-ER-TD INT1 Clear/Clean Rig Floor /Clean Drip pan under rotary table INT1 Pre Job Safety Meeting for pulling wear bushing, changing out rams, and testing Rams Pull wear bushing Change upper rams to 9 5/8" Test upper rams and choke valve #16, record on chart Low test pressure 250 psi, High test pressure 4,000 psi Test witnessed by Joey LeBlanc WSTL and Dave Richards NTP Rig down test equipment INT1 Rig up to run 9 5/8" casing Pre Job Safety meeting on running 9 5/8" casing with casing crew INT1 RIH with Shoe joint, Joint #2, and Float collar Joint, 210' Baker lock both connections between joints Fill pipe and test floats, floats working INTi RIH from 210' to 2,374' record pick up and slack off weights every 15 joints 1 xi picking up 9 5/8" casing out of pipe shed Stop just above the shoe to circulate INT1 Circulate 1.5 bottoms up at shoe Rate Flow PSI 4 bbls/min 43% 185 psi 6 bbls/min 48% 270 psi Full returns while circulating INT1 RIH from 2,374' to 4,732', averaging running speed 2 min/joint 1 xi picking up 9 5/8" casing out of pipe shed record pick up and slack off weights every 15 joints First 10 Centralizers hanging up in the window, 40-60K Ibs to force centralizer out of window. Next 20 centralizers still hanging up but only requiring 15-20K to get pass window. Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: NGI-07 Common W ell Name: NGI-07 Spud Date: 9/30/2006 Event Nam e: REENTE R+COM PLET E Start : 9/23/2006 End: 10/15/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 10/15/2006 Rig Name: NABOB S 27E Rig Number: i Date From - To Hours Task Code ~ NPT Phase Description of Operations 10/7/2006 18:30 - 00:00 5.50 CASE P INT1 - Circulate 10 minutes on Joint 115, full returns while circulating Rate Flow PSI 4 bbls/min 46% 303 psi 4.5 bbls/min 46% 320 psi 5.8 bbls/min 47% 350 psi Calculated displacement for 115 joints=82 bbls, actual=84 RIH from 4,732' to 4,974', 120 joints in hole averaging running speed 2 min/joint 1x1 picking up 9 5/8" casing out of pipe shed record pick up and slack off weights every 15 joints 10/8/2006 00:00 - 02:00 2.00 CASE P INTi RIH from 4,974' to 6,157', 149 joints in hole averaging running speed 2 min/joint 1x1 picking up 9 5/8" casing out of pipe shed record pick up and slack off weights every 15 joints Return flow started increasing on each joint and displacement was off 02:00 - 03:30 1.50 CASE P INT1 Wash down from 6,157 to 6,280', 152 joints in hole Circulate 1,200 strokes per joint to get bottoms up after 3 joints Joint Rate Returns PSI 150 5 bbl/min 48% 390 psi 151 5 bbl/min 48-54% 270 psi 152 5 bbl/min 47-51% 240 psi Gas still present after bottoms up (return MW=9.4 ppg balanced scale, 9.8 ppg pressurized) but displacement right on, Calculated=107 bbls, Actual=106.14 bbls, monitor well, no flow, well static 03:30 - 09:30 6.00 CASE P INT1 RIH from 6,280' to 7,107', 172 joints in hole averaging running speed 2 min/joint 1 xi picking up 9 5/8" casing out of pipe shed record pick up and slack off weights every 15 joints Wash down joint 172, 5 bbls/min ~ 340 psi to correct displacement. RIH from 7,107' to 8,126', 196 joints in hole averaging running speed 2 min/joint 1x1 picking up 9 5/8" casing out of pipe shed, 20' pup between joint 194 and joint 195 record pick up and slack off weights every 15 joints Break circulation with Franks tool, 4bbls/min C~J 470 psi 09:30 - 10:30 1.00 CASE P INT1 Rig down Franks tool, rig up cement head 10:30 - 14:00 3.50 CASE P INT1 Stage pumps up, Circulate 2 bottoms up 3.0 BPM 330 psi 42% returns 4.0 BPM 380 psi 44% returns 5.0 BPM 465 psi 47% returns 7.0 BPM 645 psi 52% returns 8.0 BPM 670 psi 55% returns PUW=410K, SOW=310K Fuli returns with no losses while circulating. Held Prejob safety meeting for cementing 14:00 - 17:00 3.00 CEMT P INT1 Pressure test cement lines to 4,000 psi Pump 60.3 bbls at 5.6 bbl/min of MudPUSH II ~ 10.6 ppg Kick out bottom plug, positive indication bottom plug left Pump 208.7 bbls at 5.5 bbls/min of LiteCRETE Lead ~ 12.2 ppg (could not get 12.5 ppg due to additives) Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Operations Summary Report Page 15 of 19 Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABORS 27E Rig Number: i Date ;From - To Hours i Task ~ Code NPT Phase i Description of Operations 10/8/2006 14:00 - 17:00 3.00 CEMT P INT1 Pump 129.2 bbls at 5.6 bbls/min of Class G tail @ 15.8 ppg kick top plug out, not a good indication plug left cement head Switch over to rig and displace cement as per Schlumberger pumping schedule. 3,560 strokes to catch plug 5,860 strokes to bump the plug, bumped plug with 2,500 psi Held pressure for 5 minutes, release pressure, floats holding Reciprocated pipe through out cement job, Full returns throughout cement job, no losses to well. 17:00 - 23:00 6.00 CEMT P INTi Obtained verbal dispensation from the two barrier policy to set emergency slips. Monitor well for 6 hours injecting in annulus every 2 hours 19:00 hrs 55 strokes to break down at 680 psi, 2 bbls/min. Pumped 5 bbls after break down, injection pressure 600 psi Pump out the 9 5/8" to get ready for casing cut after setting emergency slips. 21:00 hrs 20 strokes to reach injection pressure at 500 psi, 1.5 bbls/min. Pumped 5 bbls after reaching injection pressure. Pre job meeting to discuss preparation work for splitting the stack. 23:00 - 00:00 1.00 WHSUR P INT1 Nipple down BOP to set emergency slips 10/9/2006 00:00 - 01:00 1.00 WHSUR P INT1 Nipple Down BOP Stack split at 01:00.. 01:00 - 02:00 1.00 WHSUR P INT1 Pull 360K to set emergency slips Problems getting slips to set adjust, hammer on slips, pull casing to one side Finally did get slips to set with 150KIbs 02:00 - 02:30 0.50 WHSUR N SFAL INT1 Measurement between slips and top of casing head is suppose to be 8 5/16" with a groove to accept packoff. Actual measurement is 7 1/4" with no groove for packoff. Called Vetco representative in Soldotna and waiting on him to review drawings and specs to tell us whether the slips will seal and maintain setting weight. We also need a reccomendation on what type of pack-off to use and to detemine what type of casing head we have. Records show Gen 2 but it may be a Gen 1. 02:30 - 03:30 1.00 WHSUR N SFAL INT1 Still unsure if slips provide a mechanical barrier. Nipple back up until we hear from Vetco Gray. 03:30 - 07:30 4.00 WHSUR N SFAL INT1 Waiting on word from Vetco Gray Clean pits to get ready for FloPro mud Monitor outer annulus valve 9 5/8" x 13 3/8" 07:30 - 10:00 2.50 WHSUR N SFAL INT1 Response from Mark Isam with Vetco Gray was that slips are good, will work in either Gen 1 or Gen 2. The casing head is a Gen 1 which will require some modifications to the pack-off. Sent the pack-off to get machined. Decided to go with a McEvoy tubing spool on top which will give have another pack-off for another secondary seal. For seals there will be the slips as a secondary, the Vetco Gray pack-off as the primary, and the McEvoy pack-off as a secondary. Continue cleaning pits to get ready for FloPro mud Rig down stabbing board, secure rig for high winds. Monitor outer annulus valve 9 5/8" x 13 3/8" Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Name: NGI-07 Common W ell Name: NGI-07 Spud Date: 9/30/2006 Event Nam e: REENTE R+COM PLET E Start : 9/23/2006 End: 10/15/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 10/15/2006 Rig Name: NABOB S 27E Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 10/9/2006 10:00 - 10:30 0.50 WHSUR N SFAL INT1 Rig up injection line to 9 5/8" x 13 3/8" annulas to inject 5 bbls Pre Job Safety Meeting for injecting 10:00 hrs 34 strokes to reach injection pressure at 600 psi, 1.5 bbls/min. Pumped 5 bbls at 590 psi after reaching injection pressure. Opened up tubing inner annulus valve 9 5/8", slips did seal, no leak while injecting mud. Rig down injection line and continued to monitor OA 10:30 - 11:00 0.50 WHSUR N SFAL INT1 Pre Job Safety Meeting prior to Nippling down stack 11:00 - 11:30 0.50 WHSUR N SFAL INTt Break stack between casing head and tubing spool, pick up 3'. Slack off pipe into slips as per Cameron represenetative 11:30 - 13:30 2.00 WHSUR P INT1 Toolbox meeting on cutting 9 5/8" casing Rig up and cut 9 5/8" casing Pull and lay down pups and cut joint (strap on cut jnt=36.28') 13:30 - 16:30 3.00 WHSUR P INT1 ND BOPS Remove casing spool 16:30 - 22:00 5.50 WHSUR P INT1 Install Vetco Gray pack-off Install new McEvoy tubing spool and pack-off Test to 3,700 psi for 30 minutes through test port Nipple up BOPS Make up bell nipple and attach to flowline, Set drip pan, install turnbuckles & center stack Change out casing bails and elevators Change shaker screens Load liner and DP into pipe shed 22:00 - 00:00 2.00 BOPSU P INT1 Change out top rams from 9 5/8" to 5" Energize stack and function test rams, good test Pick up test joint 10/10/2006 00:00 - 02:00 2.00 BOPSU P INTi Rig up to test BOP Rig up Little Red & pump 140 bbls.dead crude into 9 5/8" x 13 3/8" annulus to freeze protect to 2,200'. Pressure test lines to 3300 psi. Injected ~ 2 bbl/min / 1150 psi This was done in SIMOPS w/ BOP test. 02:00 - 06:30 4.50 BOPSU P INT1 Test BOPs, AOGCC waived witness as per John Spa-ding BOP test witnessed by Joey LeBlanc WSTL, Dave Richards NTP Low test pressure 250 psi, High test pressure 4,000 psi on rams, 3,500 psi on annular #1 Upper Well Control Valve, Top Pipe Rams, choke 1, 2, Kill HCR #2 Choke 3,4,5,6, Manual Kill, Lower Well Control Valve #3 Choke 7,8,9, TIW #4 Choke 10,11,12 #5 Choke 13,14,15, 16 #6 Choke HCR #7 Manual Choke #8 Lower Pipe Rams #9 Annuiar #10 IBOP Dart Valve #11 Blind Rams 06:30 - 08:00 1.50 BOPSU P INT1 Pull lets plug .Rig down test equip. and blew down ki-I line, choke line and choke manifold. Set Wear Bushing (9.125 ID, 13.375 OD, length 17 3/4") Printed: 10/25/2006 10:01:51 AM BP EXPLORATfON Page 17 of 19 Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Spud Date: 9/30/2006 Event Name: REENTER+COMPLETE Start: 9/23/2006 End: 10/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours Task Code' NPT Phase Description of Operations - - - -- ,. - - - - 10/10/2006 108:00 - 11:00 I 3.00 DRILL I P I PRODi PJSM - P/U BHA T / 795' 11:00 - 12:00 1.00 DRILL P 12:00 - 13:30 1.50 DRILL P 13:30 - 18:00 4.50 DRILL P 18:00 - 19:00 1.00 DRILL P 19:00 - 20:00 1.00 CEMT P 20:00 - 21:30 1.50 CEMT P 21:30 - 00:00 2.50 DRILL P 10/11/2006 00:00 - 01:00 1.00 DRILL P 01:00 - 02:00 1.00 DRILL P 02:00 - 02:30 0.50 DRILL P 02:30 - 03:00 0.50 DRILL P 03:00 - 03:30 0.50 DRILL P 03:30 - 06:00 2.50 DRILL P 06:00 - 17:00 I 11.001 DRILL I P 17:00 - 18:00 1.00 DRILL P 18:00 - 19:00 1.00 DRILL P 19:00 - 19:30 0.50 DRILL P 19:30 - 20:00 0.50 DRILL P 20:00 - 21:00 1.00 DRILL P 21:00 - 00:00 I 3.00 I DRILL I P 10/12/2006 00:00 - 02:30 2.50 DRILL P 02:30 - 04:00 1.50 DRILL P 04:00 - 05:30 1.50 DRILL P 05:30 - 07:00 I 1.501 CASE I P BIT, PDM, Float Sub, 8 1/4" Stabilizer, LWD/MWD, 3 x NM flex DC, Circ. Sub, 9 x HWDP, Jars, 11 x HWDP PRODi Perform Strippping drill with Morning Crew (Bryon Updike's crew) PRODi Perform Strippping drill with Night Crew (Abe Purugganan's crew) PROD1 RIH to 7,968' PROD1 Wash down to float collar @ 8044' PROD1 Test casing to 4000 psi for 30 min. Charted test, Good test PROD1 Drill hard cement, Float collar down to 8,121'. PROD1 Displace well to 8.6 Flo-Pro Mud as per plan PROD1 Clean possum belly, shakers & solids control equip. Obtain Slow Pump Rates. Check PVT and Flow sensors PROD1 Drill Float Shoe & 20' of new new hole to 8,146'. PROD1 Circulate Bottoms Up - 10 BPM ~ 1400 psi. PROD1 Perform FIT. 585 psi w/ 8.6 ppg mud ~ 8,031 TVD = 10.0 ppg: EMW PROD1 Obtain Base line ECD: 9.18 ppg ~ 630 GPM. PRODi Drill ahead from 8,148' to 8,280', 550 GPM ~ 1750psi., 10 to 15KW06 90 RPM w/ 7 to 8K/Ibs. Torque P/U Wt. = 250 K, S/O Wt. = 210 K, ROT Wt. = 230K PROD1 Drill ahead from 8,280'-8671 650 GPM @ 2250psi., 10 to 15 K WOB 10 0 RPM w/ 10 to 15K/Ibs. Torque P/U Wt. = 245 K, S/O Wt. = 210 K, ROT Wt. = 225K Avg. gas 190 units, Max 3032 unit from 8640' TD ~ 17:00 hrs PROD1 Pump weighted sweep (22 bbl, 150 vis, 10.2 ppg) S/S No significant increase in cuttings when sweep came back PROD1 Monitor well for 15 min. static POH to shoe, no overpulls PROD1 Service TDS, Crown and Drawworks Visual inspection of derrick for ice PROD1 RIH no issues, clean hole PROD1 Pump weighted sweep (24 bbl, 75 vis, 10.3 ppg) S/S Slight increase in cuttings when sweep came back Max gas on BU - 1635 units PROD1 Monitor well for 15 min., Static POH to shoe, no tight spots, flow check O.K. Pump dry job, Drop 2.375 drift w/100' wire tail Cont. POH PROD1 POH from 4200 to top of HWDP at 796'. PROD1 PJSM -Monitor well for 10 minutes, OK. UD HWDP and Jars PROD1 PJSM UD BHA (download MWD) Clear floor RUNPRD R/U to run 7" slotted liner Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Operations Summary Report Legal Well Name: NGI-07 Common Well Name: NGI-07 Event Name: REENTER+COMPLETE Start; 9/23/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/15/2006 Rig Name: NABOBS 27E Rig Number: Page 18 of 19 Spud Date: 9/30/2006 End: 10/15/2006 Date ! From - To Hours I Task ~ Code' NPT L Phase I Description of Operations 10/12/2006 07:00 - 09:30 2.50 CASE P RUNPRD Pick up 7" 26# L-80 BTC=M slotted liner, HMC hanger, and ZXP packer and running tool. RIH with one stand of DP. - PU = 65k; SO = 62k 09:30 - 10:00 0.50 CASE P RUNPRD Rig down casing equipment Toolbox meeting for RIH with drill pipe 10:00 - 15:00 5.00 CASE P RUNPRD RIH with 5" DP to the shoe at 8126' MD. 15:00 - 17:00 2.00 CASE P RUNPRD Circulate two bottoms up at the shoe at 7 bpm, 850 psi. - PU 220k; SO 198k - Gas to surface at 2500 stks. Bottoms up 4200 stks. 17:00 - 17:30 0.50 CASE P RUNPRD RIH to TD. Tag at 8671' MD. Set 10k down wt. - PU 235k; SO 205k 17:30 - 19:30 2.00 CASE P RUNPRD Drop ball. Pump down at 4 bpm, 430 psi. Ball on seat. Set the hanger - Pressure up to 2160 psi, set 50k down wt. Set the packer - Pressure up to 4000 psi Test packer to 3500 psi for 15 minutes. Release from liner with 15 turns. Pull setting tool out of Packer. 19:30 - 22:30 3.00 CASE P RUNPRD Displace well to 8.6 ppg brine at 5 bpm. Flow check the well for 30 minutes. Observed small flow. - Clean possum belly and under shakers. 22:30 - 00:00 1.50 CASE P RUNPRD Circulate well at 10 bpm while prepping to weight up. Began weight up with 8.8 ppg in and 8.7 ppg out. - Saw gas at surface at 3500 stks. Max gas reading of 3300 units. - After weight up, max gas reading was 200 units. 10/13/2006 00:00 - 01:30 1.50 CASE P RUNPRD Continue to circulate 8.8 ppg brine surface to surface. Monitor well 30 minutes. Well static. 01:30 - 02:00 0.50 CASE P RUNPRD Monitor hole. Set PVT/flow equipment. PJSM. 02:00 - 05:30 3.50 CASE P RUNPRD POOH, laying down singles from 8045 - 4700' MD. - Hole taking proper fill. 05:30 - 07:30 2.00 CASE P RUNPRD PJSM. Slip and cut 96' of drilling line. 07:30 - 09:30 2.00 CASE P RUNPRD PJSM. POOH, laying down drill pipe. 09:30 - 10:30 1.00 CASE N RREP RUNPRD Repair skate ejector. 10:30 - 14:00 3.50 CASE P RUNPRD POOH laying down drill pipe. Lay down setting tool. 14:00 - 15:00 1.00 EVAL P RUNPRD PJSM. Rig up wireline. - Monitor well 10 minutes prior to running in hole. 15:00 - 19:00 4.00 EVAL P RUNPRD RIH with USIT/GR/CCL for 9-5/8" cement evaluation. Log from 8025' to surface. POOH 19:00 - 19:30 0.50 EVAL P RUNPRD Rig down' wireline. 19:30 - 20:30 1.00 BOPSU P RUNPRD PJSM. Change out uppper pipe rams to 7-5/8". 20:30 - 22:00 1.50 BOPSU P RUNPRD PJSM. Pull wear ring. Set test plug. Test 7-5/8" rams to 250 psi low and 4000 psi high. 22:00 - 23:30 1.50 BUNCO RUNCMP PJSM. Rig up to run 7" and 7-5/8" tubing. Make up landing joint. 23:30 - 00:00 0.50 BUNCO RUNCMP Pick up WLEG and packer assemblies, baker lock same. 10/14/2006 00:00 - 14:30 14.50 BUNCO RUNCMP RIH with 7-5/8", 29.7# Vam Top HC tubing as per tally - Torque turn every joint - Displacement correct. - Tag at 11.5' in on joint #195. Set 10k down. 14:30 - 16:00 1.50 BUNCO RUNCMP PJSM for spaceout. Lay out joints #195, #194, and #193. Add pups 5.94' and 9.91'. PU jt #193. Printed: 10/25/2006 10:01:51 AM BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: NGI-07 Common W ell Name: NGI-07 Spud Date: 9/30/2006 Event Nam e: REENTE R+COM PLET E Start : 9/23/2006 End: 10/15/2006 Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 10/15/2006 Rig Name: . NABOB S 27E Rig Number: Date ~ From - To Hours ~Task i Code ~ NPT Phase i Description of Operations 10/14/2006 14:30 - 16:00 1.50 BUNCO RUNCMP Make up hanger and landing joint. 16:00 - 18:30 2.50 BUNCO RUNCMP Circulate surface to surface at 3 bpm at 170 psi. - Saw flow increase. Shut in well, 30 psi on casing. No gain. - Circulate through gas buster at 1 bpm at 80 psi, staged up to 3 bpm at 180 - 200 psi. Had 4 to 16 ppm gas at the possum belly. 18:30 - 19:30 1.00 BUNCO RUNCMP PJSM. Land tubing hanger. RILDS. 19:30 - 21:00 1.50 BUNCO RUNCMP Rig up to reverse circulate. Spot Little Red. PJSM. Pressure test lines and manifold to 4300 psi. 21:00 - 22:00 1.00 BUNCO RUNCMP -Reverse circulate 100 bbls of corrosion inhibited 8.8 ppg brine with rig pumps at 3 bpm at 500 psi through choke with blinds closed. - Reverse circulate 36 bbls of diesel with Little Red at 3 bpm at 150 psi. - Shut in annulus. 100 psi on the gauge. 22:00 - 00:00 2.00 BUNCO RUNCMP Drop the ball and rod. Shut the blind rams. Pressure up to 4000 psi to set the packer and test the tubing. - Blinds leaking. Bleed off the pressure. - Function blind rams open and closed. Pressure up again. - Blinds leaking at approximately 3850 psi. - Bleed pressure and open blinds. Rig up landing joint. Kelly up. Test tubing to 4000 psi for 30 minutes. - Chart test. - Test passed. 10/15/2006 00:00 - 02:00 2.00 BUNCO RUNCMP PJSM. Line up to test the 9-5/8 x 7-5/8" annulus. Top off annulus with diesel. Pressure up tubing to 2000 psi. Pressure up annulus to 4000 psi (tubing pressure increased to 2650 psi). Hold and chart pressure for 30 minutes. - Test passed. Bleed annulus to zero. Bleed tubing to zero. Verify zero pressure on tubing and annulus. 02:00 - 02:30 0.50 BUNCO RUNCMP Run TWC. Test to 1000 psi from above. 02:30 - 03:30 1.00 BOPSU P RUNCMP Blow down choke, lines & Top Drive. Suck out drip pan. 03:30 - 11:00 7.50 BOPSU P RUNCMP PJSM. Nipple down BOP stack. - Change top rams to 4-1/2" x 7" variables. - Pull Blind Shear rams - Pull choke line off BOP & secure - Set & secure BOP on stump 11:00 - 14:00 3.00 WHSUR P RUNCMP N/U adapter flange 14:00 - 15:00 1.00 WHSUR P RUNCMP Test adapter flange to 5000 psi. 15:00 - 16:30 1.50 WHSUR P RUNCMP Torque bolts on tree & test to 5000 psi. 16:30 - 17:30 1.00 WHSUR P RUNCMP Rig up DSM lubricator & pull TWC. 17:30 - 21:00 3.50 W HSUR P RUNCMP R/U SWS Slick Line w/ BOP & lubricator. Test to 1500 psi. RIH, latch onto ball /rod assy & POH. R/D SWS. 21:00 - 22:30 1.50 WHSUR P RUNCMP R/U LRS. Test lines to 3000 psi. Bullhead 100 BBIs diesel dwn tubing ~ 3 BPM & 1200 psi. R/D LRS. 22:30 - 23:30 1.00 WHSUR P RUNCMP Set DSM lubricator & set BPV. 23:30 - 00:00 0.50 WHSUR P RUNCMP Secure Well. Rig released ~ 23:59 HRS 10/15/2006. Printed: 10/25/2006 10:01:51 AM ~alliburton Company Survey Report Company: BP AMOCO ~ Date: 1 012 6/2 0 0 6 lime: 08.24:12 ~ Pagr. l Field: Prudhoe Bay (v2riousj Co -ordinate(\H:) Reference: Well: NGI-07, Tr ue North Site: NGI ~c rtical ilVl)) fte ferencc: NGI-07A_ 42.8 Well: NGI-07 Section (v51 Kcfcr ence: Well (O.OON,O.OOE119.72Azi) ~tclipath: NGI-07A Su rticy Calculation Method: Minimum Curvahire Db: Orade -_ __ Field: Prudhoe Bay (various) _. 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: bggm2006 Well: NGI-07 Slot Name: NGI-07 Well Position: +N/-S 1344.58 ft Northing: 5972099.94 ft Latitude: 70 19 43.052 N +E/-W 459.80 ft Easting : 687182.47 ft Longitude: 148 28 54.411 W Position Uncertainty: 0.00 ft Wellpath: NGI-07A Drilled From: NGI-07 500292250301 Tie-on Depth: 2401.85 ft Current Datum: NGI-07A: Height 48.85 ft Above System Datum: Mean Sea Level Magnetic Data: 9/29/2006 Declination: 24.33 deg Field Strength: 57661 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 31.80 0.00 0.00 119.72 Survey Program for Definitive Wellpath Date: 10/26/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 101.85 2401.85 1 : Camera based gyro multisho C B-GYRO-MS Camera based gyro multishot 2424.00 8615.94 NGI-07A II FR+MS+SAG (2424.00-8 MWD+IFR+MS MWD +IFR + Multi Sta tion Survey MU Intl brim TVD Sys TVD NIS EIW MapN D~tapF: Toot ft dey deg ft ft ft ft ft ft 31.80 0.00 0.00 31.80 -17.05 0.00 0.00 5972099.94 687182.47 TIE LINE 101.85 0.25 153.00 101.85 53.00 -0.14 0.07 5972099.81 687182.54 CB-GYRO-MS 201.85 0.25 135.00 201.85 153.00 -0.48 0.32 5972099.46 687182.80 CB-GYRO-MS 301.85 0.17 166.00 301.85 253.00 -0.78 0.51 5972099.17 687183.00 CB-GYRO-MS 401.85 0.50 232.00 401.85 353.00 -1.20 0.20 5972098.75 687182.70 CB-GYRO-MS 501.85 0.75 268.00 501.84 452.99 -1.49 -0.79 5972098.43 687181.71 CB-GYRO-MS 601.85 0.50 235.00 601.84 552.99 -1.76 -1.80 5972098.14 687180.71 CB-GYRO-MS 701.85 0.17 229.00 701.83 652.98 -2.11 -2.27 5972097.78 687180.25 CB-GYRO-MS 801.85 0.00 229.00 801.83 752.98 -2.21 -2.39 5972097.68 687180.14 CB-GYRO-MS 901.85 0.17 185.00 901.83 852.98 -2.35 -2.40 5972097.53 687180.13 CB-GYRO-MS 1001.85 0.08 329.00 1001.83 952.98 -2.44 -2.45 5972097.44 687180.08 CB-GYRO-MS 1101.85 0.50 23.00 1101.83 1052.98 -1.98 -2.31 5972097.90 687180.21 CB-GYRO-MS 1201.85 0.92 26.00 1201.82 1152.97 -0.86 -1.79 5972099.04 687180.70 CB-GYRO-MS 1301.85 0.75 45.00 1301.81 1252.96 0.33 -0.98 5972100.24 687181.49 CB-GYRO-MS 1401.85 0.00 0.00 1401.81 1352.96 0.79 -0.51 5972100.72 687181.94 CB-GYRO-MS 1501.85 0.50 92.00 1501.81 1452.96 0.78 -0.08 5972100.71 687182.37 CB-GYRO-MS 1601.85 0.50 79.00 1601.81 1552.96 0.84 0.79 5972100.80 687183.24 CB-GYRO-MS 1701.85 0.50 112.00 1701.80 1652.95 0.76 1.62 5972100.74 687184.07 CB-GYRO-MS 1801.85 0.75 124.00 1801.80 1752.95 0.23 2.57 5972100.24 687185.03 CB-GYRO-MS 1901.85 0.92 143.00 1901.79 1852.94 -0.77 3.59 5972099.26 687186.08 CB-GYRO-MS 2001.85 0.17 91.00 2001.78 1952.93 -1.42 4.22 5972098.63 687186.73 CB-GYRO-MS 2101.85 0.25 327.00 2101.78 2052.93 -1.24 4.25 5972098.81 687186.75 CB-GYRO-MS 2201.85 0.00 327.00 2201.78 2152.93 -1.05 4.14 5972098.99 687186.63 CB-GYRO-MS 2301.85 0.00 327.00 2301.78 2252.93 -1.05 4.14 5972098.99 687186.63 CB-GYRO-MS 2401.85 0.17 321.00 2401.78 2352.93 -0.94 4.04 5972099.10 687186.53 CB-GYRO-MS 2424.00 0.12 337.45 2423.93 2375.08 -0.89 4.01 5972099.15 687186.50 MWD+IFR+MS 2513.00 6.50 127.19 2512.74 2463.89 -3.85 7.99 5972096.29 687190.56 MWD+IFR+MS 2609.00 11.94 128.35 2607.47 2558.62 -13.31 20.12 5972087.14 687202.91 MWD+IFR+MS 2638.80 12.56 126.50 2636.59 2587.74 -17.15 25.14 5972083.43 687208.03 MWD+tFR+MS ' ~ ~alliburton Company Survey Report Company: BP Amow Uatc: 1 0/2612 0 06 ~limc: 08-24.12 Pagc: 2 Ficld: Pru dhoe Bay (various] Co-e~r dinate(NE) Rc(crencc Well: NGI-07, T rue North Site: NG I Vertical (TVD) Reference: NGI-07A: 48-8 ~tcll: NG I-07 Section (VS) Reference: Well (O.OON.O.O OE119.72Azi) ~1cllpath: NG I-07A Survey Calculati mi ~~~icthod: Minimum Curva ture bb: Oracle Surccc )1T) lucl ~ ~ ~ .~zim 1~~ D Sys TVD !V/S Ei~~ ~t.~pA - - ]tapE - - l~onl f[ deg deg ft ft ft ft ft ft 2733.04 13.12 122.20 2728.47 2679.62 -28.94 42.43 5972072.07 687225.61 MWD+IFR+MS 2830.43 14.06 118.59 2823.14 2774.29 -40.49 62.17 5972061.01 687245.63 MWD+IFR+MS 2924.06 15.62 116.53 2913.64 2864.79 -51.57 83.44 5972050.47 687267.16 MWD+IFR+MS 3020.09 17.80 112.35 3005.61 2956.76 -62.92 108.58 5972039.75 687292.58 MWD+IFR+MS 3112.58 20.99 112.29 3092.84 3043.99 -74.59 136.99 5972028.80 687321.27 MWD+IFR+MS 3205.65 23.70 115.04 3178.92 3130.07 -88.83 169.37 5972015.37 687353.99 MWD+IFR+MS 3298.29 26.88 118.73 3262.68 3213,83 -106.78 204.61 5971998.30 687389.67 MWD+IFR+MS 3394.68 27.16 119.86 3348.54 3299.69 -128.21 242.80 5971977.84 687428.38 MWD+IFR+MS 3489.62 24.79 118.47 3433.89 3385.04 -148.49 279.10 5971958.47 687465.17 MWD+IFR+MS 3581.70 22.85 116.02 3518.12 3469.27 -165.54 312.14 5971942.25 687498.62 MWD+IFR+MS 3677.33 21.10 118.70 3606.80 3557.95 -181.95 343.92 5971926.64 687530.80 MWD+IFR+MS 3772.72 19.17 120.47 3696.36 3647.51 -198.14 372.49 5971911.17 687559.76 MWD+IFR+MS 3866.22 16.93 120.79 3785.25 3736.40 -212.89 397.41 5971897.04 687585.05 MWD+IFR+MS 3959.63 14.54 123.01 3875.16 3826.31 -226.25 418.93 5971884.23 687606.89 MWD+IFR+MS 4056.60 12.93 122.26 3969.35 3920.50 -238.67 438.32 5971872.30 687626.58 MWD+IFR+MS 4148.90 11.86 118.96 4059.50 4010.65 -248.77 455.35 5971862.62 687643.86 MWD+IFR+MS 4244.93 10.56 115.59 4153.70 4104.85 -257.35 471.92 5971854.46 687660.64 MWD+IFR+MS 4336.55 9.83 120.55 4243.87 4195.02 -264.95 486.23 5971847.21 687675.13 MWD+IFR+MS 4429.02 8.02 129.62 4335.22 4286.37 -273.08 498.00 5971839.38 687687.09 MWD+IFR+MS 4526.72 4.91 132.68 4432.29 4383.44 -280.26 506.32 5971832.41 687695.60 MWD+IFR+MS 4621.80 1.05 135.65 4527.22 4478.37 -283.65 509.92 5971829.12 687699.28 MWD+IFR+MS 4717.38 0.60 181.62 4622.79 4573.94 -284.77 510.52 5971828.01 687699.91 MWD+IFR+MS 4811.47 0.61 202.96 4716.88 4668.03 -285.73 510.31 5971827.05 687699.72 MWD+IFR+MS 4907.53 0.84 209.39 4812.93 4764.08 -286.81 509.77 5971825.95 687699.20 MWD+IFR+MS 5001.72 0.60 207.33 4907.11 4858.26 -287.85 509.20 5971824.90 687698.67 MWD+IFR+MS 5100.47 0.61 206.12 5005.86 4957.01 -288.78 508.73 5971823.96 687698.22 MWD+IFR+MS 5195.67 0.46 356.74 5101.06 5052.21 -288.86 508.49 5971823.88 687697.98 MWD+IFR+MS 5289.90 1.08 3.93 5195.28 5146.43 -287.59 508.53 5971825.14 687697.98 MWD+IFR+MS 5386.80 1.21 11.47 5292.16 5243.31 -285.68 508.79 5971827.06 687698.20 MWD+IFR+MS 5481.80 1.55 12.06 5387.13 5338.28 -283.44 509.26 5971829.31 687698.61 MWD+IFR+MS 5573.20 1.87 18.33 5478.49 5429.64 -280.81 509.99 5971831.95 687699.28 MWD+IFR+MS 5666.86 1.85 25.88 5572.10 5523.25 -278.00 511.13 5971834.79 687700.35 MWD+IFR+MS 5763.80 1.47 52.78 5669.00 5620.15 -275.84 512.80 5971836.99 687701.96 MWD+IFR+MS 5857.92 0.95 106.56 5763.10 5714.25 -275.34 514.51 5971837.54 687703.66 MWD+IFR+MS 5949.68 0.95 121.29 5854.85 5806.00 -275.95 515.89 5971836.97 687705.05 MWD+IFR+MS 6047.41 1.20 .125.26 5952.56 5903.71 -276.96 517.42 5971835.99 687706.61 MWD+IFR+MS 6141.47 1.52 133.48 6046.60 5997.75 -278.39 519.13 5971834.61 687708.35 MWD+IFR+MS 6235.26 1.98 142.50 6140.34 6091.49 -280.53 521.02 5971832.52 687710.29 MWD+IFR+MS 6325.95 1.98 145.48 6230.98 6182.13 -283.06 522.86 5971830.03 687712.20 MWD+IFR+MS 6421.49 2.13 146.61 6326.46 6277.61 -285.90 524.77 5971827.24 687714.18 MWD+IFR+MS 6515.99 1.63 146.85 6420.91 6372.06 -288.49 526.47 5971824.69 687715.95 MWD+IFR+MS 6611.33 1.04 155.77 6516.22 6467.37 -290.42 527.57 5971822.79 687717.09 MWD+IFR+MS 6704.61 1.41 166.37 6609.48 6560.63 -292.31 528.19 5971820.92 687717.75 MWD+IFR+MS 6799.20 0.93 170.07 6704.05 6655.20 -294.19 528.59 5971819.04 687718.21 MWD+IFR+MS 6896.18 0.04 225.39 6801.02 6752.17 -294.99 528.71 5971818.25 687718.34 MWD+IFR+MS 6986.38 0.70 262.51 6891.22 6842.37 -295.09 528.14 5971818.14 687717.77 MWD+IFR+MS 7087.02 0.73 275.35 6991.85 6943.00 -295.11 526.89 5971818.09 687716.53 MWD+IFR+MS 7181.60 0.95 285.69 7086.42 7037.57 -294.84 525.54 5971818.32 687715.17 MWD+IFR+MS 7276.98 1.01 290.85 7181.79 7132.94 -294.33 523.99 5971818.80 687713.61 MWD+IFR+MS 7371.31 1.32 303.17 7276.10 7227.25 -293.44 522.30 5971819.64 687711.90 MWD+IFR+MS 7461.46 2.25 316.92 7366.21 7317.36 -291.57 520.22 5971821.45 687709.78 MWD+IFR+MS 7558.21 1.61 315.93 7462.90 7414.05 -289.21 517.98 5971823.76 687707.47 MWD+IFR+MS ` ~ ~alliburton Company Survey Report Company: BP Amoco Date: 1 012 6/2 0 0 6 Tinre: 178:24:12 Pa~c: 3 Field: Prudhoe Bay (various) Co-ordinate(VN~~ Ke~erencc: Well: NGI-07, True North Site: NGI Vertical (TVD) Reference: NGI-07A: 48.8 Well: NGI-07 Section (VS) Reference:. Well (O.OON,O.OOE,119.72Azi) Wellpath: Survey NGI-07A Survey Calculation Method: Minimum Curvature Db: Oracla MD ft 7653.55 7747.17 7842.59 7935.92 8032.04 8049.24 8124.36 8219.83 8312.26 8407.12 8498.62 8597.41 8615.94 8671.00 Incl Azim "1'VD deg deg -- ft - _- 0.08 346.24 7558.23 0.48 105.99 7651.85 0.55 117.46 7747.26 0.67 132.42 7840.59 0.88 143.38 7936.70 0.89 146.14 7953.90 1.12 247.55 8029.01 1.02 165.84 8124.47 0.83 170.72 8216.89 0.46 171.19 8311.74 0.43 156.62 8403.24 0.38 171.60 8502.02 0.55 180.43 8520.55 0.55 180.43 8575.61 Sys TVD ft 7509.38 7603.00 7698.41 7791.74 7887.85 7905.05 7980.16 8075.62 8168.04 8262.89 8354.39 8453.17 8471.70 8526.76 N/S ft -288.18 -288.23 -288.55 -289.12 -290.10 -290.31 -291.08 -292.26 -293.72 -294.77 -295.45 -296.11 -296.26 -296.79 E/W MapN ft ft 517.03 5971824.76 517.40 5971824.73 518.19 5971824.43 518.99 5971823.87 519.84 5971822.92 519.99 5971822.71 519.64 5971821.94 518.99 5971820.74 519.30 5971819.29 519.47 5971818.24 519.66 5971817.57 519.85 5971816.91 519.86 5971816.76 519.86 5971816.23 MapE fool ft 687706.50 MWD+IFR+MS 687706.86 MWD+IFR+MS 687707.66 MWD+IFR+MS 687708.48 MWD+IFR+MS 687709.36 MWD+IFR+MS 687709.51 MWD+IFR+MS 687709.18 MWD+IFR+MS 687708.56 MWD+IFR+MS 687708.90 MWD+IFR+MS 687709.10 MWD+IFR+MS 687709.31 MWD+IFR+MS 687709.52 MWD+IFR+MS 687709.53 MWD+IFR+MS 687709.54 PROJECTED BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: NGI-07 Common Name: NGI-07 Test Date ! Test Type j Test Depth (TMD) ~ Test Depth (ND) AMW Surface Pressure Leak Off Pressure (BHP) EMW 10/1/2006 FIT 2,435.0 (ft) 2,435.0 (ft) 9.20 (ppg) 250 (psi) 1,414 (psi) 11.18 (ppg) 10/11/2006 FIT 8,126.0 (ft) 8,031.0 (ft) 8.60 (ppg) 585 (psi) 4,173 (psi) 10.00 (ppg) Printed: 10/25/2006 10:01:44 AM i t 26-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well NGI-07A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 2,401.85' MD Window /Kickoff Survey: 2,424.00' MD (if applicable) Projected Survey: 8,671.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date `1 ~1'd v ~ ~ Signed Please call meat 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 02 D ~- ~~~ ~_ --; , ALASSA OIL A1~TD Gds co~sERV~~'IOH CornrIIsslo~ Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI-07A BP Exploration (Alaska) Inc. Permit No: 206-126 Surface Location: 216' FNL, 989' FWL, SEC. 12, T11N, R14E, UM Bottomhole Location: 501' FNL, 1510' FWL, SEC. 12, T11N, R14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this.? day of August, 2006 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. '~~~ STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 T RECEIVEDa?~~p~ AUG 2 8 2006 Alaska flil R r~~ f'r,..~ r., 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 isg ~,q,~$ d for: ^ Coalbed Metha'ril'~`'~1'~g Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number:$~z~~ PBU NGI-07A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 8717 TVD 8617 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 9' FW 4E UM ' 7. Property Designation: ADL 028302 Pool 216 FNL, 98 L, SEC. 12, T11N, R1 , Top of Productive Horizon: 501' FNL, 1510' FWL, SEC. 12, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud a e: October 06 Total Depth: 501' FNL, 1510' FWL, SEC. 12, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to N t Property: 21,900' 4b. Location of Well (State Base Plane Coordinates): Surface: x-687182 y-5972100 Zone-ASP4 10. KB Elevation (Height above GL): 47' feet 15. Distance to Nearest Well Within Pool: 1,350' 16. Deviated Wells: Kickoff Depth: 2450 feet Maximum Hole An le: 30 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA 25.035) Downhole: 3383 Surface: 5 18. Casin P ram: S ecifications To - Settin' De th -Bo ttom Quantit of C ent c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 12-1/4" 9-5/8" 47# L-80 TCII 8122' Surface Surface 8122' 8022' 474 sx LiteCrete 552 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-M 747' 7970' 7870' 8717' 8617' Uncemented Slotted Liner 19. PRESE NT WELL GOND(TION SUMMARY (To be completed focRedrill and Re-entry Operations) Total Depth MD (ft): 8645 Total Depth TVD (ft): 8644 Plugs (measured): 7423 Effective Depth MD (ft): 8640 Effective Depth TVD (ft): 8639 Junk (measured): None asing Length ize Cement Volume MD TVD Conductor /Structural g1' 20" 240 sx Arcticset 81' 81' Surface 2725' 13-3/8" 4800 sx Permafrost II 2725' 2725' Intermediate 7735' 9-5/8" 750 sx Class 'G' 275 sx Permafrost II 7735' 7734' Pr uc ion Liner 1194' 7" 250 sx Class'G' 7446' - 8640' 7445' - 8639' Perforation Depth MD (ft): 8032' - 8534' Perforation Depth TVD (ft): 8031' - 8533' 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 Barbara Lasley, 564-5126 Printed Name ~~ave Wesle , Title Senior Drilling Engineer z t[ o ~ 0 44 t~ Prepared By Name/Number: Si nature -"L~ G Phone 564-5153 Date 4 ~ ~~~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: c~ o ~'. API Number: 50-029-20210-01-00 Permit pro al See cover letter for Date: other re uirements Conditions of Approval: p If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ( £' S'~ P 0 ~~ t ~ 4000 P S Gr . Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No MZ-~- ~~~~ ~~~ ' `p ~ /-t~cN~ ~, HZS Measures: Yes ^ No D' ectional Survey Req'd: Yes No O~t'hler: Qu'vSkct~,.z~ fo Zo q-/f(,~5. d~~~l~~t!t ~~ a.~~ti-~-~`C ~ Sf G+ur.,e rS u,~~rocled APPROVED BY THE COMM-SSION Date 3 d~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate ORIGINHL • • To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Barbara M. Lasley, Drilling Engineer ~p Date: August 10, 2006 ~,J Re: NGI-07A Sidetrack Permit to Drill Approval is requested for the permit to drill for well NGI-07A. The NGI-07A sidetrack is currently scheduled for Nabors 27E beginning the second week of October, 2006. Well NGI-07 is an Ivishak gas cap injector currently shut-in due to a slow production casing leak and tubing x inner annulus r communication via an SSSV balance line. The well has been shut in and secured with an inflatable bridge plug set at 7,422' MD (3/22/06). NGI-07 was drilled and completed in July 1976 and started injection in June 1977. A RWO was done in April 1983; the 4 ~/z" tubing was replaced with 7" tubing and a 5'/2" tailpipe assembly. The RWO was followed in July with add perfs. NGI-07 was returned to full-time injection. Well Integrity (WI) issues first surfaced in August 1990 when a possible 9 5/8 casing leak was noted. The leak-off rate was small enough that the well would pass AOGCC test criteria. Tubing x inner annulus communication was identified in 1995-1997. Chronic TxIA communication through the SSSV nipple persisted and is the primary problem at this time. The plan to repair well NGI-07 includes the following. The existing 7" tubing string will be pulled to 3000' MD. The 9-5/8" casing will be cut and pulled to ~ 74' MD, above the full opening valve at 2491' MD. An EZSV and whipstock will be run to allow kickin the 13-3/8" casing at 2450' MD. The well will be drilled to the 12-1/4" TD at 8122' MD. A 9-5/8" production casing will be run and cemented to the window, and freeze protected to surface. The production zone will be drilled to 8717' MD and completed with 7" slotted liner. A 7-5/8" internally plastic coated tubing string will be run for gas injection. Planned Well Summary Well NGI-07A Well Injector Target Ivishak T e Sidetrack Ob'ective Estimated Start Date: 08-Oct-2006 Time to Com lete: 23.0 Da s Surface Northin Eastin Offsets TRS Location 5,972,101 687,182 215' FNL / 4291' FEL 11 N, 14E, 12 Target Northin Eastin TVDss Offsets TRS Location 5,971,828 687,710 -8,570 501' FNL / 3770' FEL 11 N, 14E, 12 Bottom Northin Eastin TVDss Offsets TRS Location 5,971,828 687,710 -8,570 501' FNL / 3770' FEL 11 N, 14E, 12 Planned KOP: 2450'MD / 2403'TVDss Planned TD: 8717' MD / 8570' TVDss Ri Nabors 27E API Number: 50-029-20210-01 RKB: 47' NGI-07A Permit to Drill Application Page 1 Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. NGI wells are at 120' spacing. Close Approach Shut-in Wells: None Weli Control i v 3 Well control equipment consisting of 5,000 psi working pressure pipe rams, blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: Well Interval: 12 ~/z" intermediate interval into TSAD Maximum antici ated BHP: 3,383 psi at 8,000' TVDss. Maximum surface ressure: 2,583 pSl (based oar BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: 59 bbls with 1 .0 p EMW LOT Planned BOPE test pressure: 250 psi low 4,00 psi high - 7 da test Workover o s / 14 da test c cle Drillin o s BOPE configuration for 9 S/e" int casin to to bottom . Annular preventer, 9-s/e"pipe rams, blind/shear rams, variable rams. Well Interval: 8'h" injection interval in Ivishak Zones 1, 2, 3 and 4 sands Maximum antici ated BHP: 3,383 psi at 8,530' TVDss. Maximum surface pressure: 2,530 pSl (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10 ~ p EMW FIT. Planned BOPE test ressure: 250 si low / ,00 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.6 seaw' 17.1 Diesel BOPE and drilling fluid system schematics are currently on file with the AOGCC. BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Area of Review Wells within 1/4 mi. of this injection well @ top reservoir Well Name Dist, Ft. Annulus Inte rit Comments NGI-07 500ft N/A NGI-13 1350ft Slow tubin x IA communication WGI-08 1550ft Recent RWO, no issues WGI-04 1950ft Recent RWO, no issues Hydrogen Sulfide NGI is not designated as an H2S site. #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) Well Name H2S Level t7~ o3P I-f $ oRl NGI-08 Gas in"ector - no sam les NGI-06 Gas in~ector - no sam les WGI-08 Gas in'ector - no sam les NGI-13 Gas in'ector - no sam les Gas in'ector - no sam les N/A -Gas Injector NGI-07A Permit to Drill Application Page 2 • Formation Markers NGI-O7A (Based on SOR) • Coniniercia! Est. Pore Est. Pore Est. Formation Tops Uncertainty Hydrocarbon Press. Press. rormanon (TVDss) (eet) (Yes/No) (Psi) ( EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells SV6 1600 0 BPRF ermafrost 1830 0 EOCU 2310 10 *** KO P ~ 2450' MD *** SV5 3065 10 SV4 3315 10 SV3 3770 10 SV2 3925 10 SVi 4325 10 UG4 4800 10 UG3 5045 15 UG1 5615 15 WS2 6140 15 WS1 6310 15 CM3 6555 15 CM2 7205 15 CM 1 7460 15 THRZ 7780 20 BHRZ /Top Put River 7980 20 LCU 8040 20 TSG R 8045 20 TSHA 8090 20 TSHB 8105 20 TSHC 8115 20 TSHD 8125 20 TSAD 8130 20 Yes 42SB 8165 20 Yes TCGL 8215 20 Yes BCGL 8275 20 Yes 23SB 8327 20 Yes Note: Thick Put River (sand/conglomerate) located between BHRZ & LCU Note: Put River in pressure communication with underlying Ivishak Note• LCU in parent truncated all the Kingak Fm. Planned sidetrack to ESE may encounter 0-10' of Kingak below LCU. Drilling risk of possible exposure in production interval is considered minor since the well is near vertical (limited and exposure) and the interval will drill fast (limited exposure time). 22TS 8380 20 Yes 21TS 8415 20 Yes TZ1 B 8460 20 Yes TDF 8500 20 Yes BSAD 8530 20 Yes 3383 psi NGI-07A Permit to Drill Application Page 3 • • TD Criteria: Intermediate Casing Point - TD 5-10' above BHRZ -- See following Decision Tree for more detail. Production - TD well 15' tvd (max) below BSAD or adequate rathole to complete lowest Z1 B sand. Faults No faults are anticipated to be crossed by the NGI-07A injector well. Several faults, however, are in the proximity of the proposed well. The three closest faults are as follows. The first fault is a NW-SE trending fault with 20-40 ft. of throw down to the SW. Fault #1 is located 650 ft. to the east of the target circle. The second fault is a NW- SE trending fault with 10-30 ft. of throw down to the SW. Fault #2 is located 225 ft. west of the target circle. The third fault is a SW-NE trending fault with throw of 10-20 ft. down to the NW. Fault #3 tips out just to the NE of the target circle, and its throw increases to the W to 20-40 ft. Fault #3 is located 500 ft. north of the target circle. In the vicinity of the proposed NGI-07A well, a number of wells experienced significant lost circulation (>100 bbls) including the parent well. The NGI-07 parent well took losses of 150 bbls in Zone 2 at 8295 ft. MD and 120 bbls in Zone 2 at 8336 ft. MD. Based on the seismic, it appears that the Zone 2 losses in NGI-07 could possibly be related to crossing Fault #2. Four other wells took losses above the Sag River-LCU. They were as follows: NGI- 05 with 400 bbls at 8431 ft. MD, NGI-04 with 300 bbls at 9980 ft. MD, NGI-01 with 400 bbls at 8540 ft. MD, and NGI-02 with 100 bbls at 8507 ft. MD. Two other wells in the area (L1-01 and L1-09) had significant losses, but those losses occurred below the BSAD. Overall, the depth conversion is well constrained, and the fit of the structure to the well picks is good. This combined with the moderate risk of lost circulation results in a low to moderate risk due to structure. Directional -Sperry P06 KOP: 2450' MD Maximum Hole An le: ~30° in the 12 1/a" intermediate section Close Approach Wells: All wells pass major risk close approach criteria. The closest well is NGI-04 at 75' ctr-ctr 16' allowable deviation at 4113' tanned MD. Surve Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro ert Line: 21900' to the PBU property line Nearest Well within Pool: NGI-13 is 1350' away from planned well NGI-07A at top of Ivishak Logging Program Hole Section Required Sensors /Service 12'h" intermediate: Real time MWD Dir/GR/RES/PWD 8'/i" roduction: Real time MWD Dir/GR/PWD O en Hole: None Cased Hole: USIT in Intermediate section Mud Program Hole Section / o eration: Drillin 12-'/a" interval, surf shoe - 7,900 (To HRZ) T e Densit Viscosit PV YP Chlorides API FL H LSND 9.1 - 9.3 45 - 60 15 - 22 25 - 30 <600 6.0 - 8.0 9.0 - 9.5 Hole Section / o eration: Drillin 12-'/a" interval, 7,900 (HRZ) - 8,122 (Int TD) T e Dens' Viscosit PV YP Chlorides API FL H LSND 9.6 45 - 60 18 - 25 25 - 35 <600 < 5.5 9.0 - 9.5 Hole Section / o eration: Drillin 8-'h" roduction interval to 8,717' TD) T e Densit Viscosit PV YP LSRV API FL H Flo-Pro SF 8.4 - 8.6 45 - 55 8 - 15 24 - 30 >20,000 7.0 - 9.0 9.0 - 9.5 NGI-07A Permit to Drill Application Page 4 • • Disposal Annular No annular injection in this well. In'ection: Cuttings Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at Handlin DS-04. Any metal cuttings should be sent to the North Slope Borough. Fluid All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for Handlin injection. All Class I wastes are to be hauled to Pad 3 for disposal. Casing/Tubing Program S ile Tb O.D. WUFt Grade Conn / B sst ~ ) Collspse ~P ) Length MD % VDrkb MD / TVDrkb 12'/a" 9 5/8" 47# L-80 TC-II 6,870 4,760 8,122' Surface 8,122' / 8,022' 8-'h" 7" 26# L-80 BTC-M Slotted Slotted 747' 7,970' / 7,870' 8,717' / 8,617' Tubing 7 5/8" 29.7# L-80 Vam Top HC 6,890 4,970 7,930' Surface 7,930' / 7,830' Tubing 7" 26# L-80 TC-II 7,240 5,410 40' 7,930' / 7,830' 7,970' / 7,870' Cement Program Casin Strin 9-5/8", 47#, L-80, TC-II Intermediate casin Slurry Design Basis: Tail slurry. 1,501' of 9 5/8" x 12-'/a" annulus with 30% excess, plus ~90' of 9 s/". 47#, shoe track. Tail TOC C~ 6,621 md. ° Lead Slurry: 2,621 of 9-/8 x 12-/a annulus with 30 /° excess. Lead TOC to 4,000' and to cretaceous. Pre-Flush: 20 bbls CW 100 S acer Fluid: 40.0 bbls MudPush II at 10.6 p Slur T e 12.5 Litecrete Mix method Batch Mix Lead Slurry: BHST /BHCT 50° F 180° F confirm with SLB rior to cementin Thickenin time 4 hrs 100 Bc Slur Volume 190 bbl / 1066 cf / 4 x Litecrete, 12.5 .2 `cf/sk Slur T e 15.8 Class `G' liner slur with `GASBLOK' additive Mix method Batch mix Tail Slurry: BHST /BHCT 170° F / 130° F Thickenin time 4 hrs , Slur Volume 114 bbls / 646 cf / 5 sx Class `G', 15.8 .17 cf/sk. ~~ NGI-07A Permit to Drill Application Page 5 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.70 ppg EMW. This pressure is estimated based on offset well pressures. B. The Put River is.in pressure communication with underlying Ivishak, monitor PWD for potential pressure increase. II. Lost Circulation/Faults A. No faults are anticipated to be crossed by the NGI-07A injector well. Several faults, however, are in the proximity of the proposed well. In the vicinity of the proposed NGI-07A well, a number of wells experienced significant lost circulation (>100 bbls) including the parent well. Overall, the depth conversion is well constrained, and the fit of the structure to the well picks is good. This combined with the moderate risk of lost circulation results in a low to moderate risk due to structure III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 59 bbls with 9.6 ppg mud, 11.0 ppg FIT, and an 8.9 ppg pore pressure at the Put River. This FIT should prove up adequate formation strength for expected ECD's. B. Recent sidetrack AGI-07A experienced gas cut mud in the reservoir, although reservoir pressure was predicted at 7.7 ppg. After weighting up to 9.0+ ppg the gas ceased, but minor static losses ensued and did not cease throughout the remainder of the well and completion. Gas-detection/mud logging equipment will be available to aid the mud weight decision process if gas cut mud occurs in this well. C. The Kick Tolerance for the production hole section is infinite with 8.6 ppg mud, 10.0 ppg FIT, and an 8.9 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. iv. Integrity Testing Test Paint.: Test Aepth Test type En1W (Ififal} 12 ~/a" window 20-ft min from the 12 ~/a" window LOT 11.0 min 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 min V. Stuck Pipe A. Stuck pipe not anticipated. B. There could be slight differential sticking issues within the reservoir, though risk is considered minimal with the short, vertical, slotted liner completion. VI. Hydrogen Sulfide A. NGI is not designated as an H2S site since samples are not taken on the pad, however Standard /' Operating Procedures for H2S precautions should be followed at all times. VIII. Anti-Collision Issues A. All wells pass major risk close approach criteria. The closest well is NGI-04 at 75' ctr-ctr (16' allowable deviation) at 4113' planned MD. NGI-07A Permit to Drill Application Page 6 • • NGI-07A Drill and Complete Procedure Summary Current Status: - Inflatable bridge plug at 7422' MD. - Slow production casing x formation communication.. - Tubing x inner annulus communication via an SSSV balance line. Pre-Riq Operations: 1. SLICKLINE: Pull IBP at 7422' MD. 2. WIRELINE: Run static pressure surrey to determine BHP for proper MW during drilling operations. 3. COIL TUBING: Plug and abandon the open perforations with ~46 bbls of 15.8 ppg cement, leaving the TOC just above the 7" x 5-1/2" crossover. Cement volume based on the following calculations: - 1194' of 7" liner (cap. = 0.0371 bbl/ft) = 44.3 bbls - 10' of 9-5/8" casing (cap. = 0.0732 bbls/ft) = 0.7 bbls - 41' of 5-1/2" tubing tail (cap. = 0.0232 bbl/ft) = 1.0 bbls 4. SLICKLINE/WIRELINE: Drift tubing to estimated TOC. Tag cement to verify TOC depth. 5. WIRELINE: Jet cut the tubing in the middle of the full length tubing joint at 3000' MD. 6. Circulate the well to seawater through the tubing cut until returns are clean. 7. Bleed casing and annulus pressures to zero. Freeze protect to 2,200' MD with diesel. 8. Function all tubing and casing lock down screws. Repair and replace as necessary. Test 9-6/8" packoff to 5,000 psi for 30 minutes. 9. Set a BPV. Remove well house and flow line. Level the pad as necessary. Riq Operations: 1. MIRU Nabors rig 27E. 2. Pull BPV. Circulate out freeze protection and displace the well to seawater. 3. Run and test TWC to 1000 psi 4. Nipple down tree. Nipple up and test BOPE to 4,OOOpsi high, 250 psi low. Pull TWC. a. Ensure one set of rams are equipped to close around 7" tubulars. 5. Unseat the hanger. Pull and lay down the 7" tubing from the cut at 3000' MD. 6. Change out 7" BOP rams to accommodate 9-5/8" casing. Test. 7. Rig up E-line. 8. Make up gauge ring /junk basket to drift 9-5/8" casing for EZSV. RIH and tag tubing stump at 3000' MD. POH. - 9. Make up USIT / CCL logging tools. RIH. Log from tubing stump to surface. POOH. ~ 10. Pick up 9-5/8" EZSV. RIH and set EZSV above tubing stump at 3000' MD. ~ 11. Rig down E-line. ~p 12. Make up casing cutter for 9-5/8" 47# casing. RIH to 2474' MD, picking up singles. ~` 13. Cut casing at 2474' MD. Establish circulation behind 9-5/8" casing. POOH. ~a 14. Spear casing. Circulate out Arctic Pack. -- 15. Pull and lay down 9-5/8" casing. ~ 16. Change rams back to variables. Test. ~ 17. PU 13-3/8" casing scraper and mill assembly. Cleanout to EZSV set depth. POOH. LD assy. 0 18. Make up 13-3/8" EZSV on drill pipe. RIH. Set EZSV at 2460' MD. POOH. 1 19. Test EZSV and 13-3/8" casing to 3500 psi for 30 minutes. Chart test. `n 20. Pick up and RIH with 13-3/8" Baker bottom-trip anchor whip stock assembly. Shear off. 21. Displace the well to 9.3 ppg milling fluid. (~ NGI-07A Permit to Drill Application Page 7 • • 22. Mill window, plus 20' beyond the middle of the window. Circulate well clean. 23. Pull up into casing and conduct an FIT/LOT, targeting minimum of 11.0 ppg EMW. POH. 24. Make up 12-1/4" drilling assembly with Dir/GR/Res. RIH. 25. Drill the 12-1/4" intermediate section with 9.3 ppg fluid to 7800' MD, just above the top HRZ. 26. Prior to penetrating the top HRZ, weight up drilling fluid to 9.6 ppg. ~ 27. Drill ahead to TD in the base HRZ at 8122' MD with 9.6 ppg drilling fluid. 28. Condition hole and circulate bottoms up. POOH, lay down 12-1/4" drilling assembly. 29. Change out upper BOP rams to accommodate 9-5/8" casing. Test. ~ 30. Run 9-5/8" 47# production casing. l 31. Cement production casing in one stage. 32. Change rams back to variables. Test. 33. Make up 8-1/2" drilling assembly with Dir/GR. 34. RIH to the landing collar. 35. Test to 4000 psi for 30 minutes, chart same. ~ 36. Drill out the 9-5/8" float equipment and cement to the shoe. 37. Displace the well to 8.6 ppg solids free Flo-Pro drilling fluid. 38. Drill out the shoe plus ~20' new formation. 39. Conduct FIT, targeting 10.0 ppg EMW. 40. Drill to TD at 8717' MD. 41. Circulate well bore clean, short trip to shoe., circulate. POH 42. Pick up 7" slotted production liner. 43. RIH to TD. Set the liner top hanger/packer. Release from the liner. POOH. 44. Change out. upper 130P rams to accommodate 9-5/8" lubricator, Test. 45. Run USIT log to confirm cement behind 9-5/8" casing.. Rig down E-line. ~° - 46: Change out upper BOP rams to accommodate 7-5/8" tubing. Test. 47. Make up and run 7-5/8" internally plastic coated (IPC) completion string. a. Each connection will be torque-turned and externally pressure tested to 4000 psi. NOTE: This is 84% of the connection collapse rating. 48. Reverse circulate corrosion inhibitor and diesel freeze protection. Ensure volume of diesel pumped is equivalent to the annular volume to 2200' MD. 49. Drop the ball and rod. Set the packer and immediately bring tubing pressure up to 4000 psi. Chart this test for 30 minutes. Bleed the tubing pressure to 2000 psi. Increase the annular pressure to 4000 psi. Chart this test for 30 minutes. Notify the AOGCC to witness tubing and annular pressure test. 50. Bleed the annulus pressure to zero. Bleed the tubing pressure to zero. 51. Set and test a TWC to 1000 psi. 52. Change rams back to variables. Nipple down the BOPE. 53. Nipple up and test the tree to 5000 psi. Lubricate out the TWC. ~ 54. Rig up slickline. Pull the ball and rod. Rig down slickline. 55. Bullhead diesel freeze protection fluid down the tubing, sufficient to freeze protect 2200' of 7-5/8" tubing. 56. Secure the well with a BPV. RDMO. Post-Rig Operations: 1. Set SSSV injection valve. 2. "S" Riser will require modifications to fit new tree. 3. Install well house and instrumentation. NGI-07A Permit to Drill Application Page 8 i_ ____ TREE = GRAY GEN 2 WELLHFAD= GRAY ACTUATOR = AXELSON KB. ELEV = 47' BF. ELEV = ? KOP = 2900' Max Angle = 2 @ 8200' Datum MD = 8849' SS Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" I 2725' Minimum ID = 4.455" @ 7424' OTIS XN NIPPLE 7" TBG, 29#, L-80, .0371 bpf, ID = 6.184" 7395' TOP OF 5 1/2" TBG 7395' 7399' ~9-5/8" X 5-1/2" BAKER FB-1 PKR 7423 ELMD 3" BAKER IBP (03/23/06) 7424' S-1/2" OTIS XN NIP, ID = 4.455" 5-1/2"-TBG, 17#, L-80, .0232 bpf,-ID=4.892" i-'I. 7436' TOP OF 7" LNR 7446' NGI-07 i 2139' ~ 7" OTIS RPB SSSV NIP, ID = 5.963" 7395' I~ 7" x 5-1/2" xo 7436' ~ 5-1/2" WLEG I 7428' ELM TT LOGGED 06/30/90 9-5/8" CSG, 47#, N-80, ID = 8.681" ~ 7736' PERFORATION SUMMARY REF LOG: BHCS ON 05/10/76 ANGLE AT TOP PERF: 2 @ 8032' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8032 - 8090 O 07/01/90 3-3/8" 4 8094 - 8138 O 07/01/90 3-3/8" 4 8176 - 8201 O 01/11/77 3-3/8" 4 8201 - 8220 O 07/23/83 3-3/8'° 4 8245 - 8260 O 07/01/90 3-3/8" 4 8288 - 8305 O 07/27/83 3-3/8" 4 8330 - 8342 O 07/01/90 3-3/8" 4 8350 - 8446 O 07/27/83 3-3/8" 4 8458 - 8464 O 07/01/90 3-3/8" 4 8464 - 8534 O 07/27/83 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" TD $645' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/15/76 ORIGINAL COMPLETION 04/08/83 LAST WORKOV ER 03/17/06 KSB/TLH FISH PULLED (03/12/06) 03/23/06 DFR/PJC IBP SET @ 7423' 03/27/06 RPH/PJC WAVER SFTY NOTE DELETED PRUDHOE BAY UNfT WELL: NGI-07 PERMfT No: x1760380 API No: 50-029-20210-00 SEC 12, T11N, R14E, 4237.14' FEL & 272.21' FNL BP Exploration (Alaska) TREE = Grav Gen II WELLHEAD= Gray ACTUATOR = Axelson KB. ELEV = BF. ELEV = KOP = 4T ~ 2900' Max-Angle = 2 @ 8200' Datum MD = Datum TV D = 8849' ss 8800' ss NOTES: This is the field Nq NGI - 7 A Proposed isposal well ** 2060' 7 5!8" x 7" XO 2100' 7' CAMCO DB SSSV NIP, ID = 6.0" TGII TO VAM TOP HC X-OVER 2140' 7" x 7 5/8" XO Baker WS for 72# csg, KOP in 13-3/8" 2450' 9 5/8" ¢SV I-I 2460' 9 5/8" Cut I~ 2474' 113-3/8" CSG, 72#, N-80, ID = 12.347" I~ 2725' of 7" I'-I 3000' Minimum ID = 5.770" @ 7965 7" HES 12N NIPPLE 7 5/8" TBG, 29.7#, L-80-IPC, VAM TOP HC, ID = 6.875", 0.04591 BBL/FT 7 5!8" x 7" 26# TGII TO VAM 7930' TOP HC XO 7940' 7" R Nipple, ID = 5.963" 9 5/8" x 7" Baker S-3 Pkr, 7" 7955' 26#TGII, ID = 6.059" 7965' 7" RN Nipple, ID = 5.770" 7970' I Packer w / 10' TBS (7.5" ID) 26# BTC 7972' 7" 26# TGII WLEG TOP OF 7" LNR 7446' 8122' I I TGII, ID = 8.681", 0.07321 BBL/FT 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" 7736' PERFORATION SUMMARY REF LOG: BHCS 05/10/76 ANGLE AT TOP PERF: 8 @ 8032' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 17" LNR, 29#, N-80, .0371 bpf, 1D = 6.184" I 8645' I 8677' 7" 26# L-80 Sbtted PBTD 8717' 7" 26# TD DATE REV BY COMMENTS DATE REV BY COMMENTS 07/15/76 Original Completion 04/08/83 Last Workover 03/17/06 KSB/TLH Fish pulled (03/12/06) 03/23!06 DFR/PJC IBP set at 7423 03/27/26 RPH/PJC Waiver safety note deleted PRUDHOE BAY UNfT WELL: NGI-07A PERMff No: 1760380 API No: 50-029-20210-01 SEC 12, T11 N, R14E, 4237.14' FEL & 272.21' FNL BP Exploration (Alaska) • coMPnNV DLrnIL6 Vu OP \muco Icula( M hml. M'nimum Curvature Ilrt rsyvfcm. IM WSA tir~an Meth;v3~. Troy C'vlindur Nonh Iirtor 6ud'acc. P.Iliptii~al+('asiny Waminy Mmhlvl: Rulc>0a+cd ~. I .. - 1 RI.1=L:RLN['I. INI~()RMATION SLRb'I~.Y PR<l(iRAM ( J' c r\ I R t l\ II ( :X(107 T Nonh cpfn Ia, IhTfn T.. Snn~c~ Pl.m Tirol Plan VGI-07A wp06lNG1 07. Plan VGI 07A) ~ IfT\D)Rt 11756'1')7M1INh. X14711 S 'm\ R 11 I I.IIIIN.1111 LI M.acunJ D I th R.f.rtn... v U] sx 117n nnlw 1] n0 1sh.110 x]Innn PlunncJ_N(i1-07,\wplln Vl4 MN'DH4'R+MS ('rcaled By Tmy lakahosky 0akat0(u,hp u~r9nle'. 612'?005 ('ulculnii;;n M1lef h~W- M1linimum ('urvumrc \\I:LL DfT:\I L6 Name +I.'ti +F'-k' Nunhing Ilu.tiny Latitude Lnn6itude 11uf i NIiIJI] 11.1.1-5N J5')NII 50'~OV').'13 !x]IM_'.37 111'1'1.i0:~N 11N". X'54.111\4 II] - ~'Q-~~- ---r-~- _ _ _ l-' tiF. (TIGV D. A U I - - Scc MD Inc Aii TVD N:-5 F, -l4' DLcy TFace 1'Scc Target ~ - ' ( ( i ' - ~ ~ - ~ I 235(10(1 11.1(1 1310 0(1 28 7% 17.0(1 _34Y 9i %i 3370 [19 II% 1. 10 0.00 .4? -II.Ba 4.01 1 (111 102 0(1 39 IIi 91 '11 17 x5 - I _~ . . t !X44 (11 111111 . . 11(1 1]39 ii 11 . . ~ - - . . (111 1611 (1(1 91 73 ifi ~21 f9 ' ~63 ~ _i . 3 671 fin6 11.1111 . II 11(1 %617.011 - _ . . - . . -?%3.56 i+1.(19 0.110 0.(111 i4.-7z if/.U9"FVD ~ ~ ~ ~ - TARGET' DFT:\ILS ' '- j -' ~ Name T\'D -V-S ~F..-\t' Yonhine Fasting tihape . I VGI-07A TI wpINr Sfi 17.11(1 -2ft3.50 5'109 5971%36.55 fi%7710.36 Point CASING DFT:VIS No. T\U MD Natnc Side 1 6032.(X1 RI'_I.fifi 95:8" 9.fi25 _ Sfi I7 (10 %716.66 7" 7 (100 a H I Vortical Section m l l x.64° I I I001t: inI HALLIBURTON FORAL\TION TOP DETAILS No. TVDPath MDPath Formation I 3112.(X1 ll2fi.116 SVS 3362.1X1 331X1.76 SV4 3 3617.1X1 ;%49.17 SV3 4 39711X1 30fi1.79 SV3 5 337'_ 110 33711.Sfi SV I 6 4%171X1 393fi 66 UG4 7 SIN)2.IN1 5191.66 UG3 % 566'_.UII $7fil.fifi UGI 9 61%71111 fi2%6.66 N'S3 ID 63571111 635fi 66 N'SI II 66021111 fi7111.6fi CM3 12 7252.1111 735 L66 C'M3 13 75117 (III 7606.66 ('MI 14 7%37.00 79]6.66 TIIRZ IS %1127.110 %I?6.66 BIIRZ I6 %11%7.1X1 61%6.66 LCU 17 60931X1 %I9Lfi6 TSGR I% R137.(NI %236.66 TSIIA 19 x15?1111 %35 L66 TSIIB 20 xlfi2.lA1 63fi1.66 TSIIC' 21 %172.11(1 627 L66 TSIID 22 %177.IIU %276.fi6 TSAD 23 %2121X1 %31 I.fi6 a2S6 24 626'_.1111 %3fi Lh6 TC'GL 25 %3'_2.00 64]L66 BC'GL 26 %374.011 6371.66 2358 27 6127.1111 %526.fi6 23T5 26 %x62.110 6561.66 21 T5 29 %507.011 %BIIfi.6fi TZ I B 30 6537.1111 6(v16.fi6 TDF 31 8577.11(1 N676.h6 BSAD • • t'(1hl P:\N\' DI~:T:\ILS RFFFRFN('h INF(1Rh1:\TIDN SI;RVI:Y PR(NiR:\hl 13P:\m;wa ;.;rrdiwlc lNl:l Refcrcnce. W¢II C'enlre: N(i1-117, True Nonh DePlh Fm Deplh Ta SuncyPlan Tuul PInn~N(i1-11]A xp11M1INr1-07'Plen N(dJl7,\I ' " \ D)Rcli-rem-c~ X~. 0]CX'197R Ixr.IN1l~.IXI cnicallT\ t'I.ul: t;: M1I hxl. hl- rumlun';uurc 5c.linn It Sl Rcfcr Sln 117113 N.0IXiI:I _35111X1 n7lh nn PlunncA~N(iI-117:\xplln\-1J MWD+IFR+hIx ('rcalcJ BvTruv lak M:kr liekalllr:r l+p. r8311c: n12~?Mln F;rur Sl:Irn1: ISC \l1:\ %Ica,.mN Dcprh Rclenme. X~U]5'X Iy,n INWXI J'INl X.an M1lclh;xl. Trav ('vllnder Nonh ('alcularion Melhrd: Mir;imum ('unalur. W I~1L DI~:T,\ILS Lmn surfs. c'. If llipucel «ca<ing R'amin_u hlctu;r~l. RuI.X BauJ ' . ~ _ ~\;m;c ~I: -x ~F ~l\ s:~nhing I~.u.ung Latitude Longitude xk:l SE(TIOV DETAILS - - n(iFn] li!!sn 959nn 59"_o44.y9 5X71X'_J7 •Ir14'93115±N 1!X^_X'SJ lI I\Y o7 S<c bID Inc Azi Tt'D V.-S -F..-W' DLcg TFaa• \'5cc Tarncl __ . T:1RCiF.T DF.T:\ILS I _'45(1.1111 (1.1(1 17.(10 2994.43 -U.%4 501 0.00 o.no 793 ' 3l 111 (10 3R.7fr 118.83 37)0.04 -111,41 ?11.(17 3.00 Ib3.1111 ?39.%5 ~ Vartle TVD V.-S F-tt' Vonhing Eosling Shape 3 !%99 f1? 0,00 0.00 9759.35 ?%9.55 521.(19 3,(1(1 I%(1.(111 59:1,77 ! X715.5h (1.(10 (1.00 %517(111 ~fr955 5?I.f14 11,(111 (1.011 593,73 - - - ~ V(i1-137i\TI a~p115 %517.(10 -351.011 511.3% 5471 R51.fr7 fi87703.17 Poinl V(il-(17/\ Poly X517.(111 3%7.x1 1954.?1 5973h?9.(1(1 5%x5?9.(1(1 Polygon V(I (17A Frul1 3 %fi 17.nU 55X 73 14(15 sfi 5471179.(1(1 5x4101110 Polvgon - - - - - ~ _- _ i - ~ I ~__ I VCI f17\Foultl %fi17.11(I h9?Rn IJ53_II Sy7_'7'y,nn hRxh?9,(1(1 Polygon I i V1r1117~T1 WpUfi xfi 17.00 3%9.111 _1114 <471%'S_++ fi%771 U.9h Polnl _ __... __-_. _ I i _._. _.. _ . 101 '. ,- _~ I I 1 I _ ~ - F()RA1.\TIt)V T()P DFTNLS I~ l 95 P/ Yf. .. - Vo. T\"DPalh AIDPaIh Formation - ~ }, tu Ir qr 5 ~ T __ ~ I t _ i _ ~ ~ ~ ~ ` + . 1'_(10 it 35llh 1 31 Sts t ~ L ~ ~ - - - I ;i51.uo 7lon_7X sva - i 3 i7 00 99 3 t r t { j ~' ~ - f f- - ~ - 38 . 817. S : 4 A97?(I(1 10h 1 74 $V2 I i - _ _ - _ - - _ _ - _ _ - . 5 517] D(1 997(1 55 SV - ~ _ _ _. _ _.. ._ . 5 !x17.011 9415.fifi U(i! I 7 5114?.11(1 5141.fifi UCi3 ~ - ~ _.. _ I x i5fi?.fill 57fil.fifi U(il - , . I _ _ - - 9 fi1fr7.00 fi3%h.fi5 WS3 (I - - I ~ ~. I i ~ I ~ ' - ~ - 10 hi 57.1111 h93 h.M1fi W51 _- 0 I ~ LL , ~ - - - - II 550 .110 fi701.fifi C'Mi ,5(111 ' - ~ , ' ;t 0t 1': 78 10 1 M D; 7) - 70 ~ 0~ 'T1 VD - - - 1 7 x_00 7151 hfi ('M3 1 1 ' ' fi5( ~ I ~ 13 7 0711 1 75 1555 C h 1I 14 7x 7 (10 743fi 55 TI IRZ 70(10 ' ~ ~ I - Is x0 7 00 %1' fi fih BI IRZ 73MR-A00 V(i l 7(VQ iI. . _ ~ ~ ~_ . . _ I5 8(1x7(10 RI%555 L('U _ i 17 809'_00 x191.55 TYCiR IX x177 00 x?75.55 TSIIA -Inl _ I4 X15'_1111 x351.fi5 TSIIB t - - ~ ~ ' :. ~ ~ ~ -. ... ' ~'.. ~ ' - - ~ - - - - 'n Xlfi'_(/(1 R'_fi1.55 TSIIC' 7 , _. - _ ~ ~ I -. _ -" - - _- - _ - _'I 517'_.00 %371 .fih TSIID ,. - - - - - - t i - - - - - - X 177 (10 x37fi.5fi TSAD ' ( S ' r a I - - i X _JI 1 Xil I.G I l3SB 1 s 5 Un X3fi1 55 TC GL -- - . . x3 3 no Xa31 h5 BccL ~ - ~ - _ _ . . h ni7311(1 %47_i_fi5 3iSB _ _ _ - _ -..- _ I _ _ - _ _ _ _ _ - --_- ~ x9 7110 %535.fifi ?3TS _ ~ ~ ` I _X %1fi'_.II(I xsfi l.hh ?ITS '111 - ._ - 3y X507110 %5115.fi5 TZIB 51 55 _ _ , .. 7Mg l Upth: X71 fifi MD, 8517 TVD in X517.11(1 % fi. TDF 31 8577 nn X575 fi5 BSAD ~ .. _ ~ - - t~ -i =A~ ~'~ i 5 ~ -I ~ fdD :dx14 2MD 4799 ia'Tt'D _ . i I Plnn~ia.n ; HALLIBIJRTON _ ~ I Grillin 8~rvic~s S ~rr ~ VGI 7A I ~ fi y g P _ 8 '~ l':\SIV(i DF is\ILS -ill( - . ._ _ _ I ~ Vo. TVD hID Snmc Slee _ __ _ ._ _.. - _- _ _ - _ - _ _ _ _ _ _ _ j ~ i - -.-._ 1 NI13'_.00 xI31.5fi 4i,%" 4,5?5 " _ - - ~ - -- - _ xfi 17.011 %71fib5 7 7.110(1 ~ _ _ __. _ _ _ - ~ I I T _ , I ~f I . ~ - n um 300 300 !un 5no Sun Tun xuo 4nn N'cXll-L Full 1 ~ (Nell inJ Sperry-Sun BP Planning Report Company: BP Amoco Date: 6/12/2006 Time: 14:09`.47 Page: 1 Field: Prudhoe Bay (various) Co-ordinate(NE) Reference: Well: NGI-07, True North Site: NGI Vertical (TVD) Reference:. 8:07 5/8/1:976 00:00 47.0. " Well: NGI-07 Section (VS) Reference: Well (O.OOtd,l).OOE,118.64Azi) Wellpath: Plan NGI-07A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: NGI-07A wp06 Date Composed: 5/24/2006 Version: 34 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay (various) 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: bggm2005 Site: NGI TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5970744.41 ft Latitude: 70 19 29.828 N From: Map Easting: 686756.30 ft Longitude: 148 29 7.834 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: NGI-07 Slot Name: 07 NGI-07 Well Position: +N/-S 1344.58 ft Northing: 5972099.94 ft Latitude: 70 19 43.052 N +E/-W 459.80 ft Easting : 687182.47 ft Longitude: 148 28 54.411 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 8121.66 8022.00 9.625 12.250 9 5/8" 8716.66 8617.00 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 SV6 0.00 0.00 0.00 BPRF 0.00 0.00 0.00 EOCU 0.00 0.00 3126.06 3112.00 SV5 0.00 0.00 3400.78 3362.00 SV4 0.00 0.00 3899.37 3817.00 SV3 0.00 0.00 4061.79 3972.00 SV2 0.00 0.00 4470.56 4372.00 SV1 0.00 0.00 4946.66 4847.00 UG4 0.00 0.00 5191.66 5092.00 UG3 0.00 0.00 5761.66 5662.00 UG1 0.00 0.00 6286.66 6187.00 WS2 0.00 0.00 6456.66 6357.00 WS1 0.00 0.00 6701.66 6602.00 CM3 0.00 0.00 7351.66 7252.00 CM2 0.00 0.00 7606.66 7507.00 CM1 0.00 0.00 7926.66 7827.00 THRZ 0.00 0.00 8126.66 8027.00 BHRZ 0.00 0.00 8186.66 8087.00 LCU 0.00 0.00 8191.66 8092.00 TSGR 0.00 0.00 8236.66 8137.00 TSHA 0.00 0.00 8251.66 8152.00 TSHB 0.00 0.00 8261.66 8162.00 TSHC 0.00 0.00 8271.66 8172.00 TSHD 0.00 0.00 8276.66 8177.00 TSAD 0.00 0.00 8311.66 8212.00 42S6 0.00 0.00 8361.66 8262.00 TCGL 0.00 0.00 8421.66 8322.00 BCGL 0.00 0.00 8473.66 8374.00 23S6 0.00 0.00 8526.66 8427.00 22TS 0.00 0.00 8561.66 8462.00 21TS 0.00 0.00 8606.66 8507.00 TZ1 B 0.00 0.00 • Sperry-Sun BP Planning Report Company: BP Amoco Date: 6/12/2006 Time: 14:09:47 Page: 2 Field: Prudhoe Bay (various) Co-ordinate(NE) Reference: Well: NGI-07, True North Site: NGI Vertical (TVD) Reference: 8: 07 5/8/1976 00:00 47.0 Well: NGI-07 S ection(VS)Reference: Well (O:OON;O.OOE,118.64Azi) Wellpath: Plan NGI-07A S urvey Calculation Method: Minimum Curvature Dbc Oracle Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 8646.66 8547.00 TDF 0.00 0.00 8676.66 8577.00 BSAD 0.00 0.00 Targets Map Map <--- Latitude ---> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easfing Deg Min Sec Deg Min See Dip. Dir. ft ft ft ft ft NGI-07A T1 wp05 8617 .00 -261.00 514. 38 5971851. 87 687703.17 70 19 40.485 N 148 28 39.395 W -Plan out by 24.50 at 8617 .00 -284.56 521. 09 5971828. 48 687710.47 70 19 40.253 N 148 28 39.199 W NGI-07A Poly 8617 .00 487.84 1459. 24 5972624. 00 688629.00 70 19 47.848 N 148 28 11.808 W -Polygon 1 8617 .00 93.53 222. 95 5972199. 00 687403.00 70 19 43.972 N 148 28 47.902 W -Polygon 2 8617 .00 - 1021.03 469. 23 5971091. 00 687677.00 70 19 33.010 N 148 28 40.714 W -Polygon 3 8617 .00 -720.12 1199. 01 5971410. 00 688399.00 70 19 35.969 N 148 28 19.411 W -Polygon 4 8617 .00 320.36 994. 89 5972445. 00 688169.00 70 19 46.202 N 148 28 25.365 W -Plan out by 121 5.21 at 8617 .00 -284.56 521. 09 5971828. 48 687710.47 70 19 40.253 N 148 28 39.199 W NGI-07A Fault 2 8617 .00 -668.73 1905. 56 5971479. 00 689104.00 70 19 36.473 N 148 27 58.786 W -Polygon 1 8617 .00 -668.73 1905. 56 5971479. 00 689104.00 70 19 36.473 N 148 27 58.786 W -Polygon 2 8617 .00 -836.34 1126. 08 5971292. 00 688329.00 70 19 34.826 N 148 28 21.540 W -Plan out by 1436.78 at 8617 .00 -284.56 521. 09 5971828. 48 687710.47 70 19 40.253 N 148 28 39.199 W NGI-07A Fault 1 8617 .00 642.80 1463. 11 5972779. 00 688629.00 70 19 49.372 N 148 28 11.694 W -Polygon 1 8617 .00 642.80 1463. 11 5972779. 00 688629.00 70 19 49.372 N 148 28 11.694 W -Polygon 2 8617 .00 578.30 1161. 39 5972707. 00 688329.00 70 19 48.739 N 148 28 20.503 W -Plan out by 1321.89 at 8617 .00 -284.56 521. 09 5971828. 48 687710.47 70 19 40.253 N 148 28 39.199 W NGI-07A T1 wp06 8617 .00 -284.50 521. 09 5971828. 55 687710.46 70 19 40.254 N 148 28 39.199 W -Plan hit target Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 2450.00 0.10 17.00 2449.93 -0.84 4.01 0.00 0.00 0.00 0.00 3410.00 28.78 118.83 3370.09 -113.91 211.07 3.00 2.99 10.61 102.00 4849.02 0.00 0.00 4749.35 -284.56 521.09 2.00 -2.00 -8.26 180.00 8716.66 0.00 0.00 8617.00 -284.56 521.09 0.00 0.00 0.00 0.00 Survey MD Incl tlzim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ft deg deg ft ft ft ft ft deg/t00ft ft ft 2450.00 0.10 17.00 2449.93 2402. 93 3.92 -0.84 4.01 0.00 5972099.20 687186 .50 Start Dir 3/ 2500.00 1.48 115.41 2499.92 2452. 92 4.56 -1.08 4.60 3.00 5972098.97 687187 .10 MWD+IFR 2600.00 4.48 117.81 2599.78 2552. 78 9.76 -3.46 9.23 3.00 5972096.71 687191 .78 MWD+IFR 2700.00 7.48 118.29 2699.22 2652. 22 20.18 -8.37 18.42 3.00 5972092.03 687201 .09 MWD+IFR 2800.00 10.48 118.50 2797.98 2750. 98 35.79 -15.79 32.15 3.00 5972084.95 687215 .00 MWD+IFR 2900.00 13.48 118.61 2895.79 2848. 79 56.54 -25.72 50.38 3.00 5972075.49 687233 .47 MWD+IFR 3000.00 16.48 118.69 2992.39 2945. 39 82.39 -38.11 73.06 3.00 5972063.67 687256 .45 MWD+IFR 3100.00 19.48 118.74 3087.49 3040. 49 113.25 -52.94 100.13 3.00 5972049.52 687283 .88 MWD+IFR 3126.06 20.26 118.75 3112.00 3065. 00 122.11 -57.20 107.90 3.00 5972045.45 687291 .75 SV5 3200.00 22.48 118.78 3180.85 3133. 85 149.05 -70.16 131.51 3.00 5972033.08 687315 .69 MWD+IFR 3300.00 25.48 118.80 3272.21 3225. 21 189.69 -89.74 167.13 3.00 5972014.41 687351 .77 MWD+IFR 3400.00 28.48 118.83 3361.31 3314. 31 235.05 -111.60 206.87 3.00 5971993.54 687392 .05 MWD+IFR 3400.78 28.50 118.83 3362.00 3315. 00 235.43 -111.78 207.20 3.00 5971993.37 687392 .38 SV4 3410.00 28.78 118.83 3370.09 3323. 09 239.85 -113.91 211.07 3.00 5971991.34 687396 .30 Start Dir 2/ 3500.00 26.98 118.83 3449.64 3402. 64 281.93 -134.21 247.94 2.00 5971971.97 687433 .67 MWD+IFR 3600.00 24.98 118.83 3539.53 3492. 53 325.73 -155.33 286.31 2.00 5971951.81 687472 .55 MWD+IFR 3700.00 22.98 118.83 3630.90 3583. 90 366.37 -174.93 321.92 2.00 5971933.11 687508 .63 MWD+IFR 3800.00 20.98 118.83 3723.62 3676. 62 403.80 -192.98 354.71 2.00 5971915.89 687541 .86 MWD+IFR 3899.37 18.99 118.83 3817.00 3770. 00 437.76 -209.35 384.46 2.00 5971900.26 687572 .01 SV3 3900.00 18.98 118.83 3817.60 3770. 60 437.97 -209.45 384.64 2.00 5971900.16 687572.19 MWD+IFR Went . ! • Sperry-Sun BP Planning Report Company: BP Amoco Date: 6/12/2006. Time: 14:09:47 Page: 3 Field: Prudhoe Bay (various). Co-ordinate(NE) Reference: Well: NGI-07, True North Site: NG I V ertical (TVD) Reference: 8: 07 5/8/1976 00:0047.0 Well: NG I-07 SecNoq (VS) Referenc e: Well (O.OON,O.OOE,118.64Azi) Wellpath: Plan NGl-07A Survey Calculation Method: Minimum Curvature Dhc Oracle Survey MD Incl Azim TVD Sys TVD VS N/S FJVV DLS MapN MapE TooVCo ft deg deg ft ft ft ft ft deg/10oft ft ft 4000.00 16.98 118.83 3912.71 3865.71 468.84 -224.34 411 .68 2.00 5971885.96 687599.59 MWD+IFR 4061.79 15.74 118.83 3972.00 3925.00 486.24 -232.73 426 .93 2.00 5971877.95 687615.05 SV2 4100.00 14.98 118.83 4008.84 3961.84 496.37 -237.61 435 .80 2.00 5971873.29 687624.03 MWD+IFR 4200.00 12.98 118.83 4105.87 4058.87 520.52 -249.26 456 .96 2.00 5971862.17 687645.48 MWD+IFR 4300.00 10.98 118.83 4203.69 4156.69 541.28 -259.27 475 .14 2.00 5971852.62 687663.91 MWD+IFR 4400.00 8.98 118.83 4302.17 4255.17 558.61 -267.63 490 .33 2.00 5971844.64 687679.29 MWD+IFR 4470.56 7.57 118.83 4372.00 4325.00 568.77 -272.53 499 .22 2.00 5971839.97 687688.31 SV1 4500.00 6.98 118.83 4401.20 4354.20 572.49 -274.32 502 .49 2:00 5971838.25 687691.61 MWD+IFR 4600.00 4.98 118.83 4500.65 4453.65 582.91 -279.35 511 .61 2.00 5971833.46 687700.86 MWD+IFR 4700.00 2.98 118.83 4600.40 4553.40 589.85 -282.69 517 .70 2.00 5971830.27 687707.03 MWD+IFR 4800.00 0.98 118.83 4700.34 4653.34 593.31 -284.36 520 .72 2.00 5971828.68 687710.09 MWD+IFR 4849.02 0.00 0.00 4749.35 4702.35 593.73 -284.56 521 .09 2.00 5971828.48 687710.47 End Dir 4900.00 0.00 0.00 4800.34 4753.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 4946.66 0.00 0.00 4847.00 4800.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 UG4 5000.00 0.00 0.00 4900.34 4853.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5100.00 0.00 0.00 5000.34 4953.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5191.66 0.00 0.00 5092.00 5045.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 UG3 5200.00 0.00 0.00 5100.34 5053.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5300.00 0.00 0.00 5200.34 5153.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5400.00 0.00 0.00 5300.34 5253.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5500.00 0.00 0.00 5400.34 5353.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5600.00 0.00 0.00 5500.34 5453.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5700.00 0.00 0.00 5600.34 5553.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5761.66 0.00 0.00 5662.00 5615.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 UG1 5800.00 0.00 0.00 5700.34 5653.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 5900.00 0.00 0.00 5800.34 5753.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6000.00 0.00 0.00 5900.34 5853.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6100.00 0.00 0.00 6000.34 5953.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6200.00 0.00 0.00 6100.34 6053.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6286.66 0.00 0.00 6187.00 6140.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 WS2 6300.00 0.00 0.00 6200.34 6153.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6400.00 0.00 0.00 6300.34 6253.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6456.66 0.00 0.00 6357.00 6310.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 WS1 6500.00 0.00 0.00 6400.34 6353.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6600.00 0.00 0.00 6500.34 6453.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6700.00 0.00 0.00 6600.34 6553.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6701.66 0.00 0.00 6602.00 6555.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 CM3 6800.00 0.00 0.00 6700.34 6653.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 6900.00 0.00 0.00 6800.34 6753.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7000.00 0.00 0.00 6900.34 6853.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7100.00 0.00 0.00 7000.34 6953.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7200.00 0.00 0.00 7100.34 7053.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7300.00 0.00 0.00 7200.34 7153.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7351.66 0.00 0.00 7252.00 7205.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 CM2 7400.00 0.00 0.00 7300.34 7253.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7500.00 0.00 0.00 7400.34 7353.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7600.00 0.00 0.00 7500.34 7453.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7606.66 0.00 0.00 7507.00 7460.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 CM1 7700.00 0.00 0.00 7600.34 7553.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7800.00 0.00 0.00 7700.34 7653.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7900.00 0.00 0.00 7800.34 7753.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR 7926.66 0.00 0.00 7827.00 7780.00 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 THRZ 8000.00 0.00 0.00 7900.34 7853.34 593.73 -284.56 521 .09 0.00 5971828.48 687710.47 MWD+IFR rent S S S S S S S S S 9 S S S S S S S S S S S S S S S S S S 5 S S S S IS IS IS IS S S IS IS IS Sperry-Sun BP Planning Report Company: BP Amoco Date: 6/12/2006 Time: 14:09:47 Page: 4 .Field: Prudhoe Bay (various) Co-ordinate(NE) Reference: . Well: NGf-07, True North Site: NGI Vertical (TVD) Reference: 8:07 5/8/197600:00 47.0 Well: NGI-07 Section (VS) Reference: Well (O.OON,O.OOE,118.64Azi) Wellpath: Plan NGI-07A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft 8100.00 8121.66 8126.66 8186.66 8191.66 8200.00 8236.66 8251.66 8261.66 8271.66 8276.66 8300.00 8311.66 8361.66 8400.00 8421.66 8473.66 8500.00 8526.66 8561.66 8600.00 8606.66 8646.66 8676.66 8700.00 8716.00 8716.66 Incl deg Azim .deg TVD ft Sys TVD ft VS ft N/S ft E/W ft DLS .deg/100ft MapN ft 0.00 0.00 8000.34 7953. 34 593.73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8022.00 7975. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8027.00 7980. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8087.00 8040. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8092.00 8045. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8100.34 8053. 34 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8137.00 8090. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8152.00 8105. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8162.00 8115. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8172.00 8125. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8177.00 8130. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8200.34 8153. 34 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8212.00 8165. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8262.00 8215. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8300.34 8253. 34 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8322.00 8275. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8374.00 8327. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 .0.00 8400.34 8353. 34 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8427.00 8380. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8462.00 8415. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8500.34 8453. 34 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8507.00 8460. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8547.00 8500. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8577.00 8530. 00 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8600.34 8553. 34 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8616.34 8569. 34 593 .73 -284.56 521. 09 0.00 5971828.48 0.00 0.00 8617.00 8570. 00 593 .73 -284.56 521. 09 0.00 5971828.48 MapE Tool/Coi ft 687710.47 MWD+IFR 687710.47 9 5/8" 687710.47 BHRZ 687710.47 LCU 687710.47 TSGR 687710.47 MWD+IFR 687710.47 TSHA 687710.47 TSHB 687710.47 TSHC 687710.47 TSHD 687710.47 TSAD 687710.47 MWD+IFR 687710.47 42S6 687710.47 TCGL 687710.47 MWD+IFR 687710.47 BCGL 687710.47 23S6 687710.47 MWD+IFR 687710.47 22TS 687710.47 21 TS 687710.47 MWD+IFR 687710.47 TZ1 B 687710.47 TDF 687710.47 BSAD 687710.47 MWD+IFR 687710.47 Total Deptl 687710.47 NGI-07A T • Terri Hubble.. BP Exploration AK inc. PO Box 19661.2 MB 7-5 Anchorage, AK 995T9 PAY TO THE ORDER OF ~ .rt "Mastercard Check" 89-6/1'252. 297 DATE $ I(~ . a First National Bank Alaska Anchorage, AK 99501 ~I ~~~ ~~~o,r MEMO ~:L2520006~~:99L4622?L556~~' 029? • • TRA>~SMITTE~~.. L.ET'T'ER ~~E~KLjST WELL NAME /~~~ ~~~~~ PTD# ~~' .. l~ ~~ Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS Vb'HAT ~ (OPTIONS) APPLIES I NIli LTI LATERAL (If [ast two digits in API number are between 60-69) TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing well I Permit No. , API No. 50- - _ Production should continue to be reported as a function of the original API number stated above. i PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- -) from records, data and logs ~ acquired for well i SPACING j The permit is approved subject to full compliance with 20 AAC ~ !EXCEPTION ~ ~ 25.055. Approval to perforate and produce % infect is contingent ~ i 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 I All dry ditch sample sets submitted to the Commission must be in I ~ SAMPLE ~ no greater than 30' sample intervals from below the permafrost or ~ .from where samples are first caught and 10' sample intervals through target zones. ~ Non-Conventional ~ Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed ~ for (name of well) until after (Com~anv Name) has designed and ~ tmplemented a water well testing program to provide baseline data on water quality and quantity. SCompany Name) must contact the Commission to obtain advance approval of such water well testing j Rev: 1 125/06 C:`jodyltransmittal checklist • - -- m I I N rn o m o- I N p I ~ (0 ~. >N O liI OI I ~ ~ ~ ~ ~ I m O i O i , :. ~I~ ~ it a ' o I ~ I ~, ¢' c r', ~ 0 C7 ~I I Z I Z',, ~', v. m C7 'i M W ~~. ao, 21 o d, v p o, a~ ~, ~ C7. ~ ~ ~> a, ~ ~ II a .a ~ o ', a w ~ ~ Z ; i c n; °' °o, N 3 I Z ~ O^ ~, L p ~~ O. C Q I j ~. ~ ~ ~ ~ ~ ~~ ~ : : ~ ~ ~O N N~ x~ ~ N ~ ~ m ¢. ~ ~ III O. o _ _ ~~ III'' ~ ~ ~, ~ ~ ~ ~ ~~ ~ ~ ~ ~ li ~ ~ ~ '~ a~, m. m. m. a~ m. a~ m, m a~ m m, m m m ¢, ¢ I Q Q ¢ ¢ o, a~, a~, o a~ ¢, a~ a~, a~, a~ m, o m, o: Q, ¢ ¢ ¢ ~ n } ~ r ~ ~ } } } ~ } ~ } } }. } Z, Z, Z Z Z, Z, Z, ~ 1•, >- } Z, >- >- >- >-, ~, Z ~, ' Z, Z, Z, Z Z T ~ ~' T U ~ o I II ~ ~~ ~ 3 - E. a~ ~ .z a~ ~ N : ~I O o. I _ ~ >; v ' v 3. m. ~~ co ' O a~ rv ~, ~ ~, a ~ '', c ~~ a m .~ ', ~ .~ m. a~ - o s, ~ ~ O - m > ~' ', W ', m v yr w Q' I ~ ° a~ ~ ~ o- I~ a N N O N. 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I ~ c. a ° Z' ° ~ ~ ~ $' °~' °~ m ~ `-°~ ~' =' o' a ¢ :? ~ ~ m a `°, ~ ai s s_' s `°' m v, i a. m: o m' °~; M m. .N t ~ o w o Q 3' o c O. ~~ 3. o ~ Z .Q ~ ~ ~ w ~ ~ .a .~ 3 3 ~ ~ ?~ .., o i v ~' ~~ ~ o' ~' ~' °v m ~' N' a a ~ can. o. 3 0 ~ ~ °, ao O o c. a, a ~' o a~ a ~ ~' o m ~~ o c o' o' ° °' Y; a6i; o o' ~' ~°' E' ~' ~ ~ ~ rn o I ~ a ~ N c, H v a `~' a' a`y a~ ~ n' ~ °: ~ ~~ Q c ~ ° n o' ~ ~ - a o ~ a~' -d m ~' rn o m :. ~' c' o' o a ~ ~ m E. f0 0 o rn m' ~' a w ui' ~ w ~' ~~ vUi I of o`. m m m ~°' ~ co o' m', aS >, .5 ~ 3 _ ~ N o N .o s a~ O, ;° ~, ~ .E. n Q. ~ N T N m. m. a~ 3. c. :o. ~ c ~' o, or a`~ c. ~ ~ ~ ~~ a ~ m o, ~ o o m. w >, '-', ~ ~ ~: ~ a a. a. o ._ c ~ ~ .O. -o a, ~, ar y ~~ m a> >, rn «, t a>, ~ N o ~ n c ~ ~. ~ a, ar ~ ~ a; a; ~ m ~ o .c c c ~ •3' 3, ~' ~ m m' c°.r ~ ~ _ ~ ~, ~ ~ •~ o ~ ~' ~ N' ~ ~ ~ ~ uX.t~ ~' ~ ;' ~ ~ cmi' ~ m: o `o v v ~ v ~ a >, o, _, a. ~- a ~: - ~ .c i u o~ o. c. ~, m o o. m v m. a uS 3 _ a. ~. (n d -- N ~ o 0 0 ~~ .~ m. m. ~~ ~~ a -° ~ a c°~' v' m ~? F H c 6 ~ a > ~ Wd d, Y. ~ ~ ' ~ ~ y, ~ ~o. J mj E ~ a ~ ~ ~ ~ a~ a~ a`~, c ~ 3 ~ c c 't 'v> a> ~ a~ 'v :- ~ o' o- m a~ m; 'a~. afOi o. Y T a~ o c ~ a a n a~ a~ m o, o, ~ ~', ~', ~ m a. a w - O. O, N U ~a~~:~~~~,wOOaav~¢'a,z, v,cnvvvv¢w¢ om,m,c5~-~;jap,cn,~,v. W d O ~ N M V M CO f~ ao O O ~ N M~~ CO I~ o O) O ~ N M~ uY CO f~ W~ r N N N N N N N N N N M ~ r N M V ~ CO I~ M O ~ r r ~-_ r r r ~. ~_ __- ___ _- --.__ __ __- - _- ____- M M M M U H o o 0 r O ~, y N II, +' N O C t6 N N ~ l6 N ~ p N '~~~ C7 ~ N ',. ~ N ~.. ~ ~ M ~~ •~ ~ III ~ N T J~ ,C ~ U II C Q¢ O GU 'S a Q ¢ ~ ' c Q ~ ' a°> ¢ ~ II w I O Y '' O M\ m ,v ', p (0 ~ II f0 p •O-' 1 ~ O c o N .N N .O c ~ rn c I WU II ui m p N U C O .~ N O y O U Well History Fite APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part ofi the history file. To improve the readability of the Well History file and to simplify finding infom~ation, 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. ngi-07a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 09 13:26:07 2008 Reel Header Service name .............LISTPE Date . ...................08/06/09 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/06/09 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Greater Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA r Scientific Technical Services Sci-entific Technical Services NGI-07A 500292021001 BP Exploration - Alaska Sperry Drilling Services 09-JUN-08 MWD RUN 1 MWD RUN 2 JOB NUMBER: MW0004618256 Mw0004618256 LOGGING ENGINEER: B. TRANI B. TRANI OPERATOR WITNESS: C. CLEMENS B. DECKER SURFACE LOCATION SECTION: 12 TOWNSHIP: 11N RANGE: 14E FNL: 216 FSL: FEL: FWL: 989 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 48.85 GROUND LEVEL: 16.65 WELL CASING RECORD Page 1 MWD RUN 3 Mw0004618256 B. TRANI B. DECKER ~~C- c~ C~(o- l2Cp ~/(o L(~-~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: ngi-07a.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 2424.0 8.500 9.625 8126.0 • 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS THE NGI-07 WELLBORE BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 2424'MD/2424'TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED WITHOUT MWD TOOLS. 4. MWD RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 1 AND 2 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). UPHOLE MAD SGRC TIE-IN DATA WERE MERGED WITH RUN 1 MWD DATA. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE BLOCK-SHIFTED 5.75' UP- HOLE, PER E-MAIL FROM DOUG DORTCH (SAIC/BP) DATED 6 JUNE 2008, AS AUTHORIZED BY DOUG STONER (BP). ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THIS SHIFTED MWD LOG BECOMES THE PDCL FOR NGI-07A. 6. MWD RUNS 1-3 REPRESENT WELL NGI-07A WITH API# 50-029-20210-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8671'MD/8576'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. Page 2 a ngi-07a.tapx File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPS RPM RPD RPX ROP FET 1 clipped curves; all bit runs merged. .5000 START DEPTH 2073.0 2408.0 2408.0 2408.0 2408.0 2458.5 2459.0 STOP DEPTH 8629.0 8068.5 8068.5 8068.5 8068.5 8665.5 8068.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT BASELINE DEPTH GR 2072.8 2078.5 8665.3 8671.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 2078.5 MwD 2 6309.0 MWD 3 8126.0 REMARKS: MERGED MAIN PASS. UNSHIFTED DEPTH --------- MERGE BASE 6309.0 8126.0 8671.0 Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset DEPT FT 4 1 68 0 RPD MWD OHMM 4 1 68 4 RPM MWD OHMM 4 1 68 8 RPS MWD OHMM 4 1 68 12 Page 3 channel 1 2 3 4 ~ ~ ngi-07a.tapx RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 2073 8665.5 5369.25 13186 2073 8665.5 RPD MWD OHMM 0.55 2000 5.11017 11322 2408 8068.5 RPM MWD OHMM 0.36 1674.29 3.00626 11322 2408 8068.5 RPS MWD OHMM 0.33 1717.63 2.9206 11322 2408 8068.5 RPX MWD OHMM 0.29 1917.45 2.6851 11322 2408 8068.5 FET MWD HOUR 0.12 30.59 0.88043 11220 2459 8068.5 GR MWD API 10.49 420.07 80.9697 13113 2073 8629 ROP MWD FT/H 0.45 537.1 175.655 12415 2458.5 8665.5 First Reading For Entire File..........2073 Last Reading For Entire File...........8665.5 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/09 Maximum Physical Record..65535 File Type ................L0 Next File Name.........,.STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2078.5 6267.0 RPD 2413.5 6259.5 RPx 2413.5 6259.5 RPS 2413.5 6259.5 RPM 2413.5 6259.5 ROP 2464.0 6309.0 ET 2464.5 6259.5 $ Page 4 ~ ~ ngi-07a.tapx LOG HEADER DATA DATE LOGGED: 03-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6309.0 TOP LOG INTERVAL (FT): 2464.0 BOTTOM LOG INTERVAL (FT): 6309.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .5 MAXIMUM ANGLE: 27,2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2424.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.35 MUD VISCOSITY (S): 54.0 MUD PH: 9,Q MUD CHLORIDES (PPM): 3500 FLUID LOSS (C3): 4.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .940 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .530 111.0 MUD FILTRATE AT MT: .380 60.0 MUD CAKE AT MT: 1.210 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 Page 5 ngi-07a.tapx RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MwD010 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MwD010 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 2078.5 6309 4193.75 8462 2078.5 6309 RPD MWDO10 OHMM 0.55 2000 5.62751 7693 2413.5 6259.5 RPM MwD010 OHMM 0.36 1674.29 2.67647 7693 2413.5 6259.5 RPS MWDO10 OHMM 0.33 1717.63 2.59272 7693 2413.5 6259.5 RPX MWDO10 OHMM 0.29 1917.45 2.46326 7693 2413.5 6259.5 FET MwD010 HOUR 0.12 2.02 0.554814 7591 2464.5 6259.5 GR MWDO10 API 10.49 120.69 65.1887 8378 2078.5 6267 ROP MWDO10 FT/H 2.4 537.1 219.079 7691 2464 6309 First Reading For Entire File..........2078 Last Reading For Entire File...........6309 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/09 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 6260.0 RPD 6260.0 RPM 6260.0 RPS 6260.0 FET 6260.0 STOP DEPTH 8074.0 8074.0 8074.0 8074.0 8074.0 Page 6 ngi-07a.tapx GR 6267.5 8082.0 ROP 6309.5 8126.0 LOG HEADER DATA DATE LOGGED: 06-oCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8126.0 TOP LOG INTERVAL (FT): 6309.0 BOTTOM LOG INTERVAL (FT): 8126.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: 2.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2424.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 3500 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .940 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .450 133.0 MUD FILTRATE AT MT: .800 60.0 MUD CAKE AT MT: 1.210 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Page 7 ngi-07a.tapx Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6260 8126 7193 3733 6260 8126 RPD MWD020 OHMM 0.83 13.06 4.01347 3629 6260 8074 RPM MWD020 OHMM 0.78 13.57 3.70536 3629 6260 8074 RPS MWD020 OHMM 0.74 16.67 3.61568 3629 6260 8074 RPX MWD020 OHMM 0.72 12.81 3.15538 3629 6260 8074 FET MWD020 HOUR 0.36 30.59 1.56154 3629 6260 8074 GR MWD020 API 32.65 305.59 122.57 3630 6267.5 8082 ROP MWD020 FT/H 4.46 310.85 113.971 3634 6309.5 8126 First Reading For Entire File..........6260 Last Reading For Entire File...........8126 File Trailer service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8082.5 8634.5 ROP 8126.5 8671.0 Page 8 • ngi-07a.tapx LOG HEADER DATA DATE LOGGED: 11-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8671.0 TOP LOG INTERVAL (FT): 8126.0 BOTTOM LOG INTERVAL (FT): 8671.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM ANGLE: 1.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 175785 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8126.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 50.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 3500 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .160 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .100 126.0 MUD FILTRATE AT MT: .170 70.0 MUD CAKE AT MT: .190 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 Page 9 • ngi-07a.tapx GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 Name Service Unit Min Max DEPT FT 8082.5 8671 GR MWD030 API 22.77 420.07 ROP MWD030 FT/H 0.45 229.14 First Reading For Entire File..........8082.5 Last Reading For Entire File...........8671 File Trailer Service name... .......STSLIB.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/09 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 First Last Mean Nsam Reading Reading 8376.75 1178 8082.5 8671 63.9591 1105 8082.5 8634.5 74.9107 1090 8126.5 8671 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/09 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Reel Trailer Service name .............LISTPE Date . ...................08/06/09 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical services Physical EOF Physical EOF End Of LIS File Page 10
