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Home My WebLink About202-209Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 W-32A 202209 500292197001 4 9/23/2023 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:202-209 6.50-029-21970-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13950 12500 8958 9195 12800 12500 8377 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20" 38 - 113 38 - 113 Surface 2661 13-3/8" 37 - 2698 37 - 2698 4930 2270 Intermediate 9619 9-5/8" 36 - 9655 36 - 8759 6870 4760 Production 288 5-1/2" 9377 - 9665 8528 - 8767 7740 6820 Perforation Depth: Measured depth: 10800 - 13770 feet True vertical depth:8947 - 8950 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L80 34 - 9264 34 - 8435 9195 8377Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S3 Packer Liner 4699 3-1/2" 9246 - 13945 8420 - 8932 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 28515173983367 5659619 1474 1074 324 297 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen Brian.Glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5277 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8931 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028263 PBU W-32A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 4:01 am, Jul 12, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.09 06:33:16 -08'00' Stan Golis (880) RBDMS HEW 7/14/2021MGR26JUIL2021 SFD 7/16/2021DSR-7/13/21 ACTIVITY DATE SUMMARY 6/26/2021 CTU #9 - 1.75" Coil x 0.156" wt Job Objective: Mill Obstruction and set CIBP for WSO MIRU CTU. Make up 2-1/8" Milling BHA with 2.30" diamond parabolic mill. Tag restriction at 10778' ctm uncorrected. Paint flag EOP =10766'. Mill out restriction. Dry drift to 12800' but had a slight bobble at 12542' ctm, Mill out restriction. Dry drift from 9950' to 12600'. Pooh. ***Continued on 06/27/21*** 6/27/2021 CTU #9 - 1.75" Coil x 0.156" wt Job Objective: Mill Obstruction and set CIBP for WSO Pooh with mill. Lower tools from the lubricator and the motor bit box and mill were left in hole. Make up 2.30" JSN drift BHA and RIH, pushing Mill/Bit Box fish to 12800'. POOH. Make up NS Extra-Range CIBP and RIH. Correct depth at flag. Set CIBP at 12500'. Breakdown tools, recover ball. No freeze protect pumped . RDMO ***Job Complete*** Daily Report of Well Operations PBU W-32A · ." ·':.'&cJ 1 '\ 3 ',.:;\ WELL LOG TRANSlVIITT AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: M-38A_PB1, N-01A, P-18 L1, S-18A, W-16A_PB1, W-32A PB1. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 '¡t. M-38A PBI: U..l.~ gOl-\3'd- l,-/t.../lO Digital Log Images: 50-029-22519-01,70 1 CD Rom scANNI:D rES 0 1 Z007 N-01A: g Cf-.I- t 13 Digital Log Images: 50-029-20079-01 P-18 L1: dOd. - 03C1 f*-IL/L/Ó?5' Digital Log Images: 50-029-22097-60 ti/4L1I1 1 CD Rom 1 CD Rom S-18A: 6)Od - 1{¿;3# 1L../L/Id. Digital Log Images: 50-029-21156-01 1 CD Rom W-16A_PB1: :;)03-/00 1:1: 1'-/4bC] Digital Log Images: 50-029-22045-01, 70 1 CD Rom W-32A_PB1: do8 -80'1 tt t4L!13 Digital Log Images: 50-029-21790-01, 70 1 CD Rom 1- . . WELL LOG TRANSMITTAL JD~- !1DLl To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 1?5119 RE: MWD Formation Evaluation Logs W-32A + PB1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 W-32A + PBI: LAS Data & Digital Log Images: 50-029-21970-01, 70 1 CD Rom '(l \.... '~OVh ~/DLP . . ·r····················,·····,······ ',' 4... . .. .. :1; 'd _. . ,- ,.. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 3 Fl---~ò~>- DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Jj; <.t J I 0 IV:';j MJ..\~ , Permit to Drill 2022090 Well Name/No. PRUDHOE BAY UNIT W-32A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21970-01-00 MD 13950 -' lVD 8931 ¡/' Completion Date 1/3/2003 C:--~' ' Completion Status 1-01l Current Status 1-01l UIC N ---- -----~------ ------ ---- -.--- REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes ------ -------------- ---------------- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, MGR, CCl (data taken from logs Portion of Master Well Data Maint) Well Log Information: log/ Electr ~ Data Digital Dataset log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments -- --------- ---------- Rpt LIS Verification 1 9654 13900 Open 5/13/2003 Rpt Directional Survey 9635 13025 Open 12/13/2002 PB1 ED 0 1170Í/(.IS Verification 9654 13900 Open 5/13/2003 Rpt Directional Survey 12370 13950 Open 12/13/2002 Rpt Directional Survey 9635 13025 Open 12/13/2002 PB1 MWD Rpt LIS Verification 9654 12980 Open 5/13/2003 PB1 ED C 1152Ì-- Gamma Ray 8992 13839 Open 2/14/2003 v'" : ED 0 11708 LIS Verification 9654 12980 Open 5/13/2003 PB1 Rpt Directional Survey 12370 13950 Open 12/13/2002 MWD ED Dt-- Directional Survey 12370 13950 Open 12/13/2002 MWD ~ ED o Cr-" Directional Survey 12370 13950 Open 12/13/2002 ED Dc-- Directional Survey 9635 13025 Open 12/13/2002 PB1 MWD ED 0 ~ Directional Survey 9635 13025 Open 12/13/2002 PB1 i ED C Lis 12545~uction/Resistivity 9650 13960 Open 7/9/2004 RES FET GR :ED C Lis 12546 Induction/Resistivity 9650 13033 Open 7/9/2004 PB 1 RES FET GR - -- --- -- -- c___________~~ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022090 Well Name/No. PRUDHOE BAY UNIT W-32A 'Operator BP EXPLORATION (ALASKA) INC MD 13950 TVD 8931 Completion Date 1/3/2003 Completion Status 1-01L ADDITIONAL INFORMATION Well Cored? Y 1® Chips Reœ:i\1êõ7 - ¥ / N-- Daily History Received? Formation Tops Analysis ___V / N Received? ---- ---------- - - ---- .-- - --- Comments: ----- ~ Compliance Reviewed By: _ API No. 50-029-21970-01-00 Current Status 1-01L WN WN Date: UIC N ---" g fV1u,,- ~ 1 '--'"' ) ...... ~."O2.- 20f WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 06, 2004 RE: MWD Fonnation Evaluation Logs: W-32A & W-32A PBI, AK-MW-22176 W-32A+PBl: Digital Log Images: 50-029-21970-01, 70 'tlCD Rom / 2 S-~b /'2-sL/~ ,-P/31- PLEASE ACKN'OWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: 7/c/o 4 ,}/ (J 0 I, /( I !L_~~~., ,f,Á/'vt) l II~ -".... V-I, Signed: ) ) aoa-dOC) / I -¡ og WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska May 07, 2003 RE:MWD Fonnation Evaluation Logs W-32A PBI, AK-MW-22 I 7600 1 LDWG forrnattedDisc with verification listing. API#: 50-029-21970-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun DriUing Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- T echnicalData Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed~~ (~ RECE\VED Mf\ '( "\ '3 ,00:) 0"" & Gai Con$. ~ þJ~a 1 M~e~&gß ,) \ / é9Cbì-ao¡ I /7 ()7 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska May 09, 2003 RE:MWDFormation Evaluation Logs W-32A, AK-MW -2217600 1 LDWG formatted Disc with verification listing. API#: 50-029-21970-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~/dJo~ RECEIVED MAY 13 2003 Alaaka Oii & Ga& Coos. CommiIIïDn An~~~ø STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well a;a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service {~¡~~"">'''''''r 2. Name of Operator r¿:ìA;i\,;::riŒ'1~, H: i!\.>i\'¡~'* 7. Permit Number ( i ~'1 t,·~ '! :...r Y!3ttf1œi W 202 209 302 357 BP Exploration Alaska) Inc. i I 3' ~ ~ \'1 ' .f~1·"1íJ - - 3. Address ¡ V"!,~8} _ I ¡:'W 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 t--~~~,.; ~::..,..;',~:::~:\':;:~,~::::~';~ 50-029-21970-01 4. Location of well at surface ' -"'''''''''') ".,..._".3 9. Unit or Lease Name 735' SNL, 1442' WEL';'SEC. 21, T11N, R12E, UM X = 611789, Y = 5959518 Prudhoe Bay Unit At top of productive interval 2601' NSL, 1969 WEL, SEC. 16, T11 N, R12E, UM X = 611205, Y = 5962845 10. Well Number At total depth 4474' NSL, 1711' WEL, SEC. 21, T11 N, R12E, UM X = 611521, Y = 5959444 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 88.06' ADL 028263-2 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/10/2002 . 11/26/2002 ' 113/2003 ,. 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13950 8931 FT 13911 8936 FT a;a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, MGR, CCL Classification of Service Well W-32A 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 13-3/8" 68# L-80 Su rface 2698' 17-1/2" 3840 cu ft Cold Set III & II 9-518" 47# L-80 Su rface 9655' 12-1/4" 2017 cu ft Class 'G' 5-112" 17# NT -80 9377' 9665' 8-1/2" 340 cu ft Class 'G' 3-1/2" 9.3# L-80 9246' 13945' 4-3/4" 505 cu ft Class 'G' 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2204' MD 1900' (Approx.) '77tc/-:..J,-x) Ýi'-/..5.í/ fflP i\?, î'-? ' ,VI> 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25. 2-112" Gun Diameter, 4 spf MD TVD 10800' - 11110' 8947' - 8925' 1118a-1131~ 8926'-891~ 11410'-11825' 8915'-8908' 11860' - 12140' 8911' - 8927' 12245' - 12450' 8935' - 8953' 2" Gun Diameter, 4 spf MD TVD 12900' - 13165' 8966' - 8970' 13220' - 13370' 8970' - 8970' 13540' - 13770' 8968' - 8950' SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 9264' PACKER SET (MD) 9195' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. Date First Production January 17, 2003 Date of Tes~urs Tested 1/24/2003 2 Flow Tubing Casing Pressure Press. 342 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD -0- CALCULATED OIL-BBL 24-HoUR RATE GAs-McF 13,500 GAs-McF WATER-BBL -0- WATER-BBL CHOKE SIZE 11° GAS-OIL RATIO 13 OIL GRAVITY-API (CORR) 24.8 28. CORE DATA :1" "?,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submif~or~ CbipS.' . No core samples were taken. i=orm 10-407 Rev. 07-01-80 / " \" PR"U~ QJ:'l v FFR I 9 20m Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sadlerochit I Zone 48 45P 44P 43P 42P 42P 9814' 9872' 9922' 9938' 10148' 10468' 8888' 8926' 8952' 8959' 9003' 9005' owe 10730' 8960' 43P 44P 45P 45P 10747' 1 0787' 10918' 12245' 8957' 8950' 8930' 8935' 31. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble /fO.AJl.i 0, ~ TtlIe Technical Assistant Date 0 d-. -/0 · D 3 W-32A 202-209 302-357 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No.1 Approval No. Drilling Engineer: Rob Tirpack, 564-4166 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). I-:-EM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: Common Name: Test Date 11/8/2002 FIT W-32 W-32 Test Type Test Depth (TMD) 9,677.0 (ft) TestDepth· (TV D) 8,777.0 (ft) AMW 8.40 (ppg) SurfacePl'essurê l.~ak qffPl'essure (ßHP) 593 (psi) 4,423 (psi) EMW 9.70 (ppg) ,.~' ._~ Printed: 12/6/2002 1:56:30 PM Legal Well Name: W-32 Common Well Name: W-32 Event Name: REENTER+COMPLETE Contractor Name: DOYON Rig Name: DOYON 14 From - To Höurs Task Code NPT 1 0/31/2002 15:00 - 16:00 1.00 MOB P 16:00 - 18:00 2.00 MOB P 18:00 - 19:00 1.00 MOB P 19:00 - 20:00 1.00 RIGU P 20:00 - 22:00 2.00 PULL P 22:00 - 00:00 2.00 PULL P 11/1/2002 00:00 - 02:00 2.00 PULL P Phase PRE PRE PRE PRE DECOMP Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 Description of Operations Held PJSM. Skidded Rig Floor. Held PJSM. Moved off of W 38L 1. Moved in Rig and Spotted over W 32L 1. Shimmed and Set Rig. Skidded Rig Floor into Position. Set Cuttings Tank, R I U Rig Floor. Took on Sea Water. R / U Manifold and Circulating Lines. Accepted Rig @ 2000 hrs 10/31/2002 DECOMP Held PJSM. Circulated Freeze Protect Diesel out of Wellbore. Pumped 40 bbls to Achieve Circulation. Pumped Down IA and Took Returns up Tubing. Overboarded 45 bbls of Diesel and Diesel cut Dirty Seawater, Rate 5 bpm, 600 psi. Pumped Down Tubing and Took Returns up lA, Overboarded 150 bbls of Diesel and Diesel cut Dirty Seawater, Rate 5 bpm, 600 psi. DECOMP Circulated 1 Complete Wellbore Volume. Pump Rate 7.5 bpm, 1,650 psi. Losses while Circulating 80 bph. No Gas on Bottoms Up. Pumped and Spotted 30 bbl Hi-Vis Pill at the Tubing Cut at 9,275'. Blew Down Lines, RID Circulating Manifold. Held PJSM. Ran and Set TWC Valve in Tubing Hanger Profile. Held PJSM. N I 0 Production Tree and Adapter Flange, Checked Tubing Hanger Threads, Checked XO Make Up in Hanger, OK. Held PJSM. N I U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Top Pipe Rams wi 2-7/8" x 5" Variable Rams, Blind Ram, Lower Pipe Rams wi 3-1/2" x 6" Variable Rams. DECOMP Held PJSM. R I U Equipment to Test BOPE. DECOMP Tested BOPE. Tested Upper Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 3,500 psi High I 250 psi Low. Tested Annular Preventer to 2,500 psi High I 250 psi Low. All Tests Held fl 5 Min. All Pressure Tests Held wi No Leaks or Pressure Loss. Witnessing of BOPE Test Waived by AOGCC Rep Jeff Jones. Held PJSM. RID BOPE Test Equipment. Held PJSM. R I U DSM Lubricator, Pulled TWC, Well on Vacuum. RID DSM. Filled the Hole, Took 65 bbls. Static Losses while Testing BOPE 5.5 bph. Held PJSM. R I U Cameo Spooling Equipment. R I U Equipment to Pull Tubing. M I U 1 Joint 5" DP and XO to 3-1/2" TDS Threads. RIH and Screwed into Tubing Hanger. Backed Out Lock Down Screws. Pulled on Tubing Hanger and String. Tubing and Hanger Pulled Free at 120,000#, String Weight 132,000#. Pulled Tubing Hanger to Rig Floor. Terminated Control Lines, Broke Out and LID Tubing Hanger. DECOMP Circulated Bottoms Up. Pump Rate 7 bpm, 875 psi. Losses while Circulating 12 bph. No Gas on Bottoms Up. Pumped and Spotted 30 bbl Hi-Vis Pill at 9,275'. DECOMP POOH, LID 65 Jts 3-1/2" 9.3# TDS Tubing, SSSV Assembly. Spooled Up Dual Encapsulated Control Line while POOH. Recovered 4 Stainless Steel Bands and 33 Rubber CL Clamps. 02:00 - 02:30 0.50 PULL P DECOMP 02:30 - 03:00 0.50 WHSUR P DECOMP 03:00 - 04:30 1.50 WHSUR P DECOMP 04:30 - 06:30 2.00 BOPSUR P DECOMP 06:30 - 07:30 07:30 - 12:00 1.00 BOPSURP 4.50 BOPSUR P 12:00 - 12:30 0.50 BOPSUR P DECOMP 12:30 - 13:30 1.00 WHSUR P DECOMP 13:30 - 14:00 0.50 PULL P DECOMP 14:00 - 14:30 0.50 PULL P DECOMP 14:30 - 16:00 1.50 PULL P 16:00 - 20:00 4.00 PULL P Printed: 12/6/2002 1:56:39 PM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 11/1/2002 11/2/2002 Code NPT Phase 16:00 - 20:00 4.00 PULL P DECOMP 100% Recovery of Clamps and Bands. 20:30 - 21 :30 1.00 PULL P DECOMP Rigged Down Camco Spooling Equipment and Cleared Rig Floor. 21 :30 - 00:00 2.50 PULL P DECOMP POOH, L / D 3-1/2" 9.3# TDS Tubing. L / D a Total of 200 Jts @ 0000 hrs. Losses 17 bph. 00:00 - 03:00 3.00 PULL P DECOMP Held PJSM. POOH, L / D 3-1/2" 9.3# TDS Tubing. Recovered: 288 jts of 3-1/2" Tubing, 6 GLM Assemblies, 1 SSSV Assembly, 2 x 10ft space out pups, Cut Off Joint of 3-1/2" Tubing - 3.51'. Losses 15 bph. 03:00 - 04:00 1.00 BOPSURP DECOMP Held PJSM. R / U Equipment to Test BOPE. Ran and Set Test Plug and Test Joint. Tested Lower Pipe Rams and Blind Rams to 3,500 psi High / 250 psi Low. All Tests Held f/ 5 Min. All Pressure Tests Held w/ No Leaks or Pressure Loss. Witnessing of BOPE Test Waived by Jeff Jones-AOGCC Rep. Pulled Test Plug, L / D Test Joint. Ran and Set Wear Bushing. Wear Bushing I.D. = 8.75". R / D Test Equipment. 04:00 - 04:30 0.50 PULL P DECOMP Held PJSM. R / U to Run Fishing BHA and 5" DP. Brought Fishing BHA Components up to Rig Floor. 04:30 - 05:30 1.00 PULL P DECOMP M / U Fishing BHA: 8-1/8" Guide Bowl and Overshot Extension w/3-1/2" Basket Grapple - Top Sub - XO Sub - Bumper Sub - 6-1/4" Oil Jars - 8 x 6-3/4" D.C. - 7 x 5" HWDP. BHA Length 486.05'. 05:30 - 07:00 1.50 PULL P DECOMP RIH w/ Overshot Fishing BHA on 5" DP from Derrick to 5,653'. 07:00 - 08:00 1.00 PULL P DECOMP Held PJSM. Cut and Slip Drilling Line. Serviced Top Drive. 08:00 - 11 :30 3.50 PULL P DECOMP RIH w/ Overshot Fishing BHA on 5" DP to 9,200. P / U DP Singles from Pipe Shed. 11 :30 - 12:00 0.50 PULL P DECOMP M / U Top Drive and Engaged Pump. Checked Parameters: String Weight Up 247,000#, String Weight Down 217,000#, String Weight Rotating 227,000#. Pump Rate 5 bpm, 150 psi. Washed Down to the Top of and Swallowed Fish, Pump Pressure Increased to 400 psi. Shut Down Pump and Fully Engaged Fish at 9,280'. Overpulled 15,000# and Rotated Drill String to the Right in Attempt to Release K Anchor. Drill String Rotated Freely w/ No Increase in Torque. Increased Overpull to 25,000# and Rotated Drill String w/ No Increase in Torque. SBR Rotating Freely on Slick Stick. Jarred on Fish and Sheared SBR Free from Slick Stick. 12:00 - 13:00 1.00 PULL P DECOMP Circulated Bottoms Up, Pump Rate 7.5 bpm, 300 psi. No Gas to Surface. Losses 4 bph. Pumped and Spotted 30 bbl Hi-Vis Pill at 9,270'. 13:00 - 16:30 3.50 PULL P DECOMP POOH w/ 5" DP. Losses while POOH 3 bph. 16:30 - 17:00 0.50 PULL P DECOMP POOH w/ Fishing BHA. 17:00 - 17:30 0.50 PULL P DECOMP Held PJSM. Broke Out and L / D Fish. Recovered: Cut Jt, X Nipple, Pup Jt, SBR Barrel, 30.5'. 17:30 - 18:30 1.00 PULL P DECOMP Held PJSM. M / U Fishing BHA: 8-1/8" Guide Bowl, Double Pin Bushing, Bowl and Overshot Extension w/ 3-1/2" Basket Grapple - Top Sub - XO Sub - Bumper Sub - 6-1/4" Oil Jars - 8 x 6-3/4" D.C. - Accelerator Jars - 7 x 5" HWDP. BHA Length 502.55'. 18:30 - 21 :00 2.50 PULL P DECOMP RIH w/ Fishing BHA on 5" DP to 9,215'. Losses while RIH 2 bph. 21 :00 - 21 :30 0.50 PULL P DECOMP M / U Top Drive and Engaged Pump. Checked Parameters: Printed: 12/6/2002 1 :56:39 PM ) BPE8><.AI...OR.hVflCl>N Oper'ätiol1sSÜ I11rnä ryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 FroITL-Tó Hours Task Code NPT Phase 11/2/2002 21 :00 - 21 :30 0.50 PULL P DECOMP String Weight Up 247,000#, String Weight Down 217,000#, String Weight Rotating 227,000#. Pump Rate 5 bpm, 150 psi, RPM 30, Torque 5,000 ft Ilbs. Washed Down to the Top of and Swallowed Fish, Pump Pressure Increased to 550 psi. Shut Down Pump and Fully Engaged Fish at 9,285'. Overpulled 25,000# and Rotated Drill String to the Right 8 turns, Torque Increase to 9,000 ft Ilbs and Dropped back to 5,000 ft Ilbs. K Anchor Released. 21 :30 - 22:30 1.00 PULL P DECOMP Circulated Bottoms Up, Pump Rate 8 bpm, 350 psi. No Gas to Surface. Losses 2 bph. Pumped and Spotted 30 bbl Hi-Vis Pill at 9,280'. 22:30 - 23:00 0.50 PULL P DECOMP POOH wI 5" DP to 8,350'. 23:00 - 00:00 1.00 PULL N RREP DECOMP Held PJSM. Rig Repair. Repair Drawworks Clutch. 11/3/2002 00:00 - 02:00 2.00 FISH N RREP DECOMP Held PJSM. Repaired Rig. Worked on Drawworks Clutch. 02:00 - 04:00 2.00 FISH P DECOMP POOH wI 5" DP to 500'. 04:00 - 04:30 0.50 FISH P DECOMP POOH wI Fishing BHA. 04:30 - 05:00 0.50 FISH P DECOMP Broke Out and LID Fish. Recovered: Slick Stick and K Anchor. 14.25' 05:00 - 05:30 0.50 FISH P DECOMP Cleared Rig Floor. Brought Milling Assembly to Rig Floor. 05:30 - 06:30 1.00 FISH P DECOMP Held PJSM. M I U Milling BHA: 2.75" Bullnose Mill- PRT w/4" Grapple - PRT Extension - 8.5" Packer Mill - Triple Conn Sub - 3 x Boot Baskets - Bit Sub - Bumper Sub - 6-1/4" Oil Jars - 8 x 6-3/4" D.C. - 7 X 5" HWDP. BHA Length 500.21'. 06:30 - 07:00 0.50 FISH P DECOMP RIH wI Milling BHA on 5" DP to 2,989'. 07:00 - 08:00 1.00 FISH P DECOMP Held PJSM. Slipped and Cut Drilling Line. Serviced Rig. 08:00 - 10:00 2.00 FISH P DECOMP RIH wI Milling BHA on 5" DP to 9,300'. Tagged Fish at 9,300'. 10:00-14:30 4.50 FISH P DECOMP M I U Top Drive, Established Parameters: Pump Rate 5 bpm, 530 psi, String Weight Up 245,000#, String Weight Down 220,000#, String Weight Rotating 235,000#. RPM 90, Torque 5,000 ft Ilbs. Milled 9-5/8" x 3-1/2" Packer from 9,300' to 9,303'. WOM 5,000# -10,000#, RPM 120, Torque Off Bottom 5,000 ft Ilbs, Torque On Bottom 7,000 - 11,000 ft Ilbs. Attempted to Push Packer Down Hole After Milling Slips. Packer did not Move. Set Down on Packer wI 20,000 to Ensure PRT Grapples Engaged. 14:30 -15:00 0.50 FISH P DECOMP Circulated Bottoms Up, Pump Rate 5 bpm, 470 psi. No Gas to Surface. Losses 2 -3 bph. 15:00 - 18:00 3.00 FISH P DECOMP POOH wI 5" DP from 9,303' to 500'. 18:00 - 19:30 1.50 FISH P DECOMP POOH wI Milling BHA. Broke out and LID Packer and Tailpipe. 100% Total Recovery. Length 65.37'. 19:30 - 20:30 1.00 FISH P DECOMP Broke Out and LID Packer Mil, Triple Conn Sub, Boot Baskets, Bit Sub, Bumper Sub and Oil Jars. Cleaned Out Boot Baskets, Recovered 5 Gallons of Metal Cuttings. 20:30 - 21 :00 0.50 FISH P DECOMP Cleared BHA Components from Rig Floor. 21 :00 - 22:00 1.00 FISH P DECOMP RIH wI 6-3/4" D.C. and 5" HWDP. Broke Out and LID Same. 22:00 - 23:00 1.00 FISH P DECOMP Held PJSM. Brought 2-7/8" Clean Out BHA Components to Rig Floor. R I U Handling Equipment f/2-7/8" Components. 23:00 - 00:00 1.00 FISH P DECOMP M I U Clean Out BHA. 11/4/2002 00:00 - 02:00 2.00 FISH P DECOMP Held PJSM. M I U Clean Out BHA: 4-3/4" Junk Mill - Bit Sub - 8 x 3-3/8" D. C. - Double Pin Sub - XO - 5-1/2" Casing Scraper- Bit Sub - 3-3/4" Bumper Sub - 3-3/4" Oil Jars - 4 x 3-3/8" D.C. - XO - 8 Jts 2-7/8" DP - XO - Double Pin Sub - 9-5/8" Casing Scraper - Bit Sub. BHA Length 642.08'. RID 2-7/8" Handling Printed: 12/6/2002 1 :56:39 PM ) ) BPE*~lliORt\TIØN O~E;)ratiol"ls·..··$l.Imrnary·...Rf!.F>Ðrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 HoUrs Task Code Descriptionof()peratiÖns DECaMP Equipment, R / U 5" Handling Equipment. DECaMP RIH w/ Clean Out BHA on 5" DP to 9,380'. Tagged up just Inside Top of Liner at 9,380' DECaMP M / U Top Drive and Engaged Pumps. Established Parameters: Pump Rate 5 bpm, 700 psi, RPM 40, Torque Off Bottom 3,000 ft /Ibs, String Weight Up 220,000#, String Weight Down 210,000#, String Weight Rotating 215,000#. Attempted to Wash Down without Rotating, Set Down w/ 15,000#, Could not Push Junk Down. Washed and Milled on Junk from 9,380' to 9,990'. WOM 5,000#, RPM 80, Torque On Bottom 5,000 ft / Ibs, Torque Limiter Set to Stall out at 5,500 ft / Ibs. Pump Rate 6 bpm, 840 psi. DECaMP POOH to 9,870', Drill String Hung Up on Junk in the Hole. M / U Top Drive and Pumped out of the Hole from 9,870' to 9,350'. DECaMP RIH to 9,740', Whipstock Packer Setting Depth. No Drag, Hole Clean. Pumped and Circulated around 30 bbl Hi-Vis Sweep. Pump Rate 7 bpm, 1,200 psi. Losses While Circulating 5 bph. Pumped and Spotted 30 bbl Hi-Vis Pill at 9,740' to Control Losses. Flow Checked Well, Fluid Level Dropped Very Slowly. Held PJSM. POOH w/ 5" DP to 8,480'. Held PJSM. Slipped and Cut Drilling Line. POOH w/ 5" DP to 1 ,790'. Held PJSM. M / U RTTS Packer w/ Storm Valve. Held PSJM. RIH w/ RTTS and Set at 50'. Backed out of Storm Valve and POOH w/ 5" DP. M / U Retrieving Tool and Pulled Wear Bushing. M / U Packoff Retrieving Tool to 5" DP, RIH and Latched onto Packoff. Ensured that OA was 0 psi, Backed Out Lock Down Screws. Pulled Packoff Out of Wellhead and through BOP Stack to Surface. M / U New Packoff onto Tool, Ran and Set Packoff in Wellhead and RILDS. Tested Packoff to 5,000 psi f/ 10 minutes, OK. DECaMP RIH w/ Packer Retrieving Tool and Stabbed into Storm Valve. Checked f/ Pressure under Packer, 0 psi. Released and Pulled RTTS Packer to Surface. Broke Out and L / D RTTS Packer. Ran and Set Wear Bushing. POOH wI 5" DP and Racked Back in Derrick. R / U Equipment fl 2-7/8" Clean Out Equipment. POOH, Broke Out and L / D Clean Out BHA. Held PJSM. Cleared Rig Floor, R / U 5" DP Equipment. M / U RTTS Packer. RIH w/ RTTS Test Packer on 5" DP to 9,370'. Held PJSM. Set RTTS at 9,370'. Closed Pipe Rams and Tested 9-5/8" Casing as Follows: Strokes Pmp'd Pressure 10 570 psi 20 1,000 psi 30 1 ,480 psi 40 1,990 psi 50 2,520 psi 55 2,800 psi 60 3,040 psi 65 3,330 psi 11/4/2002 2.00 FISH P 3.00 FISH P 00:00 - 02:00 02:00 - 05:00 05:00 - 16:30 11.50 FISH P 16:30-17:30 1.00 FISH P 17:30 - 19:00 1.50 FISH P 19:00 - 19:30 0.50 FISH P DECaMP 19:30 - 21 :00 1.50 FISH P DECaMP 21 :00 - 23:30 2.50 FISH P DECaMP 23:30 - 00:00 0.50 FISH P DECaMP 11/5/2002 00:00 - 00:30 0.50 WHSUR P DECaMP 00:30 - 01 :30 1.00 WHSUR P DECaMP 01 :30 - 02:30 1.00 WHSUR P 02:30 - 03:00 0.50 FISH P DECaMP 03:00 - 04:30 1.50 FISH P DECaMP 04:30 - 05:00 0.50 FISH P DECaMP 05:00 - 08:00 3.00 FISH P DECaMP 08:00 - 09:30 1.50 FISH P DECaMP Printed: 12/6/2002 1 :56:39 PM )- . " Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/5/2002 08:00 - 09:30 09:30 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 15:30 15:30 - 16:30 16:30 - 17:30 17:30 - 18:00 18:00 - 21 :00 ") Bp··EXPLORt\-rIC>N Q.peratiløn·~.··Summªrj··R~F>ørt W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Hours Task Code NPT Phase 1.50 FISH P DECOMP 3.50 FISH P 0.50 FISH P 0.50 CLEAN P 1.50 CLEAN P DECOMP DECOMP DECOMP DECOMP 1.00 CLEAN P DECOMP 1.00 CLEAN P DECOMP 0.50 CLEAN P 3.00 CLEAN P DECOMP DECOMP 21 :00 - 23:30 2.50 CLEAN P DECOMP 23:30 - 00:00 0.50 CLEAN P DECOMP 11/6/2002 00:00 - 00:30 0.50 CLEAN P DECOMP 00:30 - 01 :00 0.50 CLEAN P DECOMP 01 :00 - 02:30 1.50 CLEAN P DECOMP 02:30 - 04:00 04:00 - 04:30 04:30 - 08:00 08:00 - 09:30 1.50 CLEAN P DECOMP 0.50 CLEAN P DECOMP 3.50 CLEAN P 1.50 CLEAN P DECOMP DECOMP Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 [)éscri ptionof Op~ration$ 68 3,520 psi Held Pressure f/ 30 minutes, Pressure Held at 3,510 psi f/ 30 minutes. Bled Down Pressure, Opened Pipe Rams. Released RTTS Packer. POOH w/ 5" DP to Surface. Broke Out and L / D RTTS. Held PJSM. R / U Schlumberger E-Line Equipment. RIH w/ 4.75" Gauge Ring and Junk Basket on E-Line. Tagged Up at 9,560', Could not Work Gauge Ring Deeper. Gauge Ring Hung Up while Pulling Up, 500# Overpull to Clear. POOH w/ Gauge Ring and Junk Basket. No Recovery in Junk Basket. Broke Off 4.75" Gauge Ring, RIH w/ 2.75" Junk Basket to 9,760'. OK. POOH w/ Junk Basket, Recovered 1/2 Cup of Calcium Carbonate. M / U 4.75" Gauge Ring w/ Junk Basket and RIH on E-Line. Tagged up at 9,560'. Gauge Ring Hung Up while Pulling Up, 2,000# Overpull to Clear. Continued w/ Intermittent Drag f/ 15'. POOH w/ Gauge Ring and Junk Basket. Recovered 1/2 piece of Rubber in Junk Basket. R / D Schlumberger E-Line Equipment. Held PJSM. M / U Clean Out BHA: 4-3/4" Junk Mill - Bit Sub - 5-1/2" Casing Scraper - XO - 2 x Junk Baskets - XO - XO - 3-3/4" Bumper Sub - 3-3/4" Oil Jars - 12 x 3-3/8" D.C. - XO - XO - XO - 2 X 9-5/8" Junk Baskets - XO. BHA Length 402.06'. R / D 2-7/8" Handling Equipment, R / U 5" Handling Equipment. RIH w/ Clean Out BHA on 5" DP to 9,000'. Held PJSM. Slipped and Cut Drilling Line. Held PSJM. Finished Slipping and Cutting Drilling Line. RIH w/ Clean Out BHA on 5" DP to 9,655'. Tagged Up at 9,655'. M / U Top Drive and Engaged Pumps. Established Parameters: Pump Rate 5 bpm, 400 psi, RPM 20, Torque Off Bottom 2,000 ft / Ibs, String Weight Up 225,000#, String Weight Down 212,000#, String Weight Rotating 222,000#. Attempted to Wash Down without Rotating, Set Down w/ 10,000#, Washed and Milled from 9,655' to 9,765'. WOM 1,000#, RPM 50, Torque On Bottom 5,000 ft /Ibs, Torque Limiter Set to Stall out at 5,500 ft / Ibs. Staged Up Pump Rate from 8 bpm, 1,150 psi to 12 bpm, 2,650 psi. Slowed Pump Rate Down to 4 bpm, 300 psi and RIH to Tag top of 5-1/2" w/ 9-5/8" Junk Basket, Pressure Increased to 500 psi. 4-3/4" Mill Depth 9,764',5-1/2" Casing Scraper Depth 9,760', 9-5/8" Junk Basket Depth 9,370'. Pumped and Circulated Around 2 - 30 bbl Hi-Vis Barafiber Sweeps, 15 Minutes Apart. Pump Rate 14.5 bpm, 3,400 psi. No Losses. Circulated Back Very Small Amount of Calcium Carbonate. POOH w/ Clean Out BHA to Top of 5-1/2" Liner at 9,377'. RIH without Pumps or Rotation to 9,764'. Did not Encounter any Junk while RIH. POOH w/ 5" DP to 400' POOH w/ BHA, Stood 3-3/8" DC in Derrick, Broke Out and L / D Junk Baskets, Casing Scraper, Jars, Bumper Sub and Mill. Cleaned out Junk Baskets, Recovered 2 Cups of Calcium Printed: 12/6/2002 1:56:39 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BPE*PLORATION Op~ratiQRstiS!uR1mCl.ry . Repørt W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 11/6/2002 08:00 - 09:30 Date From-To Hours Task COde N PI Phase 1.50 CLEAN P DECOMP Carbonate from 9-5/8" Junk Baskets, No Recovery in 5-1/2" Junk Baskets. DECOMP Held PJSM. R / U Schlumberger Equipment. DECOMP RIH w/ 4.75" Gauge Ring and Junk Basket on E-Line. Tagged Up at 9,680', Could not Work Gauge Ring Deeper. Gauge Ring Hung Up while Pulling Up, 800# Overpull to Clear. POOH w/ Gauge Ring and Junk Basket. No Recovery in Junk Basket. R / 0 Schlumberger Equipment. Held PJSM. Moved Out Schlumberger Unit, Mobilized and Spotted Halliburton Slickline Unit. R / U Halliburton Slickline Equipment. RIH w/ 2' - 1-7/8" Stem w/ 4.75" Centrilizer on Slickline. Tagged Up Hard at 9,560'. Attempted to Work Swedge Deeper with No Success. POOH w/ 4.75" Swedge on Slickline. Changed Out from 4.75" Swedge to 4.70" Gauge Ring. RIH w/ 4.70" Gauge Ring on Slickline. Tagged Up at 9,655', Worked Gauge Ring Through to 9,703'. Tagged Up at 9,703', Worked Gauge Ring Through to 9,770. POOH to 9,500', RIH to 9,703', Tagged Up at 9,703', Worked Gauge Ring Through to 9,770'. POOH w/ 4.70" Gauge Ring on Slickline. DECOMP M / U Schlumberger's 4.75" Gauge Ring / Junk Basket onto Slickline. RIH w/4.75" Gauge Ring / Junk Basket to 9,703'. Tagged Up Solid at 9,703', Attempted to Work Through with No Success. Jarred w/ 500# Overpull to Free up at 9,703'. POOH w/ 4.75" Gauge Ring / Junk Basket. DECOMP R / 0 Halliburton Slickline Unit. DECOMP Held PJSM. M / U Clean Out BHA: 4-3/4" Reverse Basket - Bit Sub - 4-3/4" String Mill - Flex Joint - 4-3/4" String Mill - XO - 2 x Junk Baskets - XO - XO - 3-3/4" Bumper Sub - 3-3/4" Oil Jars - 12 x 3-3/8" D.C. - XO - XO - XO - 2 X 9-5/8" Junk Baskets - XO. BHA Length 413.09'. DECOMP RIH w/ Clean Out BHA on 5" DP to 9,380'. DECOMP M / U Top Drive and Engaged Pumps. Established Parameters: Pump Rate 10 bpm, 2,850 psi, RPM 80, Torque Off Bottom 3,000 ft / Ibs, String Weight Up 225,000#, String Weight Down 210,000#, String Weight Rotating 217,000#. Washed, Milled and Dressed Off 5-1/2" Liner from 9,380' to 9,773'. Worked the Mills Very Slowly through the Following Depths: 9,377' - 9,390' Top of 5-1/2" Liner, 9,530' - 9,580', 9,620' - 9,720', Took Weight at 9,660', Worked Mills from 9,620'- 9,690' 3 times, No Drag. DECOMP Pumped and Circulated Around 2 - 30 bbl Hi-Vis Barafiber Sweeps, 15 Minutes Apart. Pump Rate 11.5 bpm, 3,500 psi. No Losses. DECOMP POOH w/ Clean Out BHA to Top of 5-1/2" Liner at 9,370'. RIH without Pumps or Rotation to 9,773'. No Drag or Resistance while RIH. DECOMP POOH w/ 5" DP to 400'. 09:30 - 10:00 10:00 - 11 :30 0.50 CLEAN P 1.50 CLEAN P 11 :30 - 12:00 0.50 CLEAN P DECOMP 12:00 - 14:30 2.50 CLEAN P DECOMP 14:30 - 16:00 1.50 CLEAN P DECOMP 16:00 - 19:00 3.00 CLEAN P DECOMP 19:00 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 11/7/2002 00:00 - 02:30 02:30 - 05:30 05:30 - 08:00 08:00 - 08:30 08:30 - 10:30 10:30 - 12:00 2.00 CLEAN P 0.50 CLEAN P 2.50 CLEAN P 2.50 CLEAN P 3.00 CLEAN P 2.50 CLEAN P 0.50 CLEAN P 2.00 CLEAN P 1.50 CLEAN P DECOMP POOH w/ BHA, Stood 3-3/8" DC in Derrick, Broke Out and L / o Junk Baskets, Casing Scraper, Jars, Bumper Sub and Mill. Cleaned out Junk Baskets, No Recovery from Junk Baskets. Printed: 12/6/2002 1 :56:39 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 Date bodë NPT Dèscription.···()fOper~tiøns DECOMP Held PJSM. R I U Schlumberger Equipment. DECOMP RIH wI 4.75" Gauge Ring and Junk Basket on E-Line to 9,750'. Made CCL - GR Logging Pass from 9,750' to 9,300'. POOH, No Recovery in Junk Basket. Broke off and LID Junk Basket. PROD1 M I U Baker 5-1/2" F-1 Retainer Production Packer to E-Line Tool String. PROD1 Held PJSM. RIH wI Baker 5-1/2" F-1 Retainer Production Packer on E-Line to 9,750'. Pulled Up Hole and Correlated to CCL - GR Log. Set Baker 5-1/2" F-1 Retainer Production Packer at 9,692', E- Line Measurements. Waited 7 Minutes for Explosive Charge to Set Packer. Packer in Place at 1625 hrs. POOH wI CCL-GR on E-Line. PROD1 RID Schlumberger Equipment. RID Schlumberger Equipment. PROD1 Held PJSM. M I U Whipstock BHA: 5-1/2" Casing Whipstock- 4.315" Starting Mill- 4-3/4" Window Mill- XO - 3-1/8" Drill Collars - Float Sub - XO - MWD - Reversible Flow Sub - XO - Bumper Sub - 11 x 3-1/8" Drill Collars - XO - Xo - Circulating Sub. BHA Length 428.32'. M I U 1 Stand of 5" DP, M I U Top Drive, Tested MWD, 147 gpm, 500 psi, OK. RIH wI Whipstock BHA on 5" DP to 4,025'. Tripping Speed 1-1/2 - 2 Minutes I Stand. Held PJSM. RIH wI Whipstock BHA on 5" DP to 9,619'. Tripping Speed 1-1/2 - 2 Minutes I Stand. Oriented Whipstock at 5-1/2" Liner Top at 9,370'. M I U Top Drive, Engaged Pumps, Established Parameters: Pump Rate 150 gpm, 800 psi, String Weight Up 235,000#, String Weight Down 215,000#. Oriented Whipstock 75 deg Left and RIH very slowly to 9,671' Tool Face Moved to 90 deg Left. Put a Slight Turn in Drill String and Picked up to 9,630', to Work Turn Down into Whipstock. Started Down, Whipstock Hung up at 9,639'. Worked Whipstock Up and Down with 10,000# Drag. Continued Down the Hole wI Whipstock at 65- 70 deg Left Orientation. Whipstock oriented at 54 deg Left. Set Down wI 25,000# and Set Whipstock Anchor. Pulled Up to Confirm Anchor Set, Shear Bolt Connecting Mill to Whipstock Sheared as Anchor Set. Set Down and Pulled up to Confirm Whipstock is Set and Sheared. WEXIT Held PJSM wI Peak Drivers and Rig Crew. Displaced to 8.4 ppg QuickDril Mud. Pump Rate 160 gpm, 700 psi. Circulated Mud System 1 Full Circulation, 8.4 ppg - In, 8.4 ppg - Out. WEXIT Held PJSM. Closed Pipe Rams and Tested 9-5/8" x 5-1/2" Liner as Follows: Strokes Pmp'd Pressure 10 440 psi 20 920 psi 30 1 ,400 psi 40 1,880 psi 50 2,360 psi 60 2,840 psi 70 3,320 psi 75 3,340 psi From<-To HoUrs 11/7/2002 12:00 - 12:30 12:30 - 14:00 0.50 CLEAN P 1.50 CLEAN P 14:00 - 15:00 1.00 STWHIP P 15:00 - 17:00 2.00 STWHIP P 17:00 - 18:00 1.00 STWHIP P 18:00 - 21 :30 3.50 STWHIP P 21 :30 - 22:00 0.50 STWHIP P PROD1 22:00 - 00:00 2.00 STWHIP P PROD1 11/8/2002 00:00 - 04:00 4.00 STWHIP P WEXIT 04:00 - 06:30 2.50 STWHIP P WEXIT 06:30 - 09:30 3.00 STWHIP P 09:30 - 10:30 1.00 CASE P Printed: 12/6/2002 1 :56:39 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BPEX1PLORATION ºlp~rª~i<>ns·..·.Su·rnmC1rv¡.·.·Rep()rt W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 1118/2002 09:30 - 10:30 Date From-To Hours Task Code NPT Phase 10:30 - 15:00 15:00 - 20:00 20:00 - 20:30 20:30 - 23:00 23:00 - 23:30 1.00 CASE P 4.50 STWHIP P 5.00 STWHIP P 0.50 STWHIP P 2.50 STWHIP P 0.50 EVAL P WEXIT 78 3,500 psi Held Pressure fl 30 minutes, OK. Bled down Pressure, Opened Pipe Rams. WEXIT Milled Window from 9,665' to 9,677'. WOM 2,000# - 5,000#, RPM 60 - 100, Torque Off Bottom 2,000 ft Ilbs, Torque On Bottom 3,000 - 5,000 ft Ilbs, Pump Rate 160 gpm, 750 psi. WEXIT Milled Window and New Formation from 9,677' to 9,691'. WOM 8,000# - 10,000#, RPM 110, Torque Off Bottom 2,000 ft Ilbs, Torque On Bottom 3,000 - 5,000 ft Ilbs, Pump Rate 160 gpm, 750 psi. WEXIT Made Several Wiper Trip Passes Through Window, With and Without Pumps to Ensure Good Window Cut. 5-1/2" Window Top 9,665',5-1/2" Window Bttm 9,677' WEXIT Pumped and Circulated Around 50 bbl Hi-Vis Sweep. Pump Rate, 160 gpm, 900 psi, Dropped Ball and Opened Circulating Sub Once Sweep Reached the Top of the 5-1/2" Liner. Increased Pump Rate to 610 gpm, 860 psi. Circulated 2 x Bottoms Up Returns Over Shakers were Clean. Note: Recovered 40# of Metal Cuttings. WEXIT Held PJSM. Closed Pipe Rams and Performed FIT. Strokes Pmp'd Pressure 2 120 psi 4 240 psi 8 360 psi 10 460 psi 12 560 psi 13 593 psi MW 8.4 ppg, Window TVD 8,777', Pressure 593 psi = 9.7 ppg EMW. Held Pressure f/1 0 minutes, Pressure at 10 minutes 593 psi. Bled down Pressure, Opened Pipe Rams. Flow Checked Well, Well Static. Held PJSM. POOH wI 5" DP to 9,300'. Held PJSM. Slipped and Cut Drilling Line. POOH wI 5" DP to 400'. Calculated Fill 66.5 bbls, Actual Fill 68 bbls. FI9w Check Well Every 20 Stands, Well Static. POOH, Broke Out and LID Window Milling BHA. Held PJSM. M I U Stack Washer, Washed and Jetted BOP Stack. M I U Retrieving Tool, Pulled Wear Bushing. R I U Equipment to Test BOPE. Held PJSM. Tested BOPE. Tested Upper and Lower Rams, Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 3,500 psi High I 250 psi Low. Tested Annular Preventer to 2,500 psi High /250 psi Low. All Tests Held fl 5 Min. All Pressure Tests Held wI No Leaks or Pressure Loss. Witnessing of BOPE test Waived by AOGCC Rep Chuck Sheave. PROD1 RID BOPE Test Equipment. M I U Retrieving Tool, Ran and Set Wear Bushing. PROD1 Held PJSM. M I U BHA: 4-3/4" STC MBT285QYPX PDC Bit, Ser# JS9376, dressed w/6x1 0 jets, 3-5/8" SperryDrill Lobe 7/8 2.3 stg Motor wI 2.12 deg Bent Housing, Non-Mag Float Sub - Non-Mag XO - SuperSlim Tm Bm Gm MWD - Reverse Flow Sub - Non-Mag MWD Flex Sub - Non-Mag XO - 3 x Flex 23:30 - 00:00 0.50 STWHIP P WEXIT 11/9/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 05:00 4.00 STWHIP P WEXIT 05:00 - 06:30 1.50 STWHIP P WEXIT 06:30 - 07:30 1.00 BOPSURP PROD1 07:30 - 10:30 3.00 BOPSURP PROD1 10:30 - 11 :00 11 :00 - 14:00 0.50 BOPSUR P 3.00 DRILL P Printed: 12/6/2002 1:56:39 PM ') ) BPEXPLORAml<DN ()f.Jeré1ti()I1$.··SUl11l11ary. ..~ep()rt Legal Well Name: W-32 Common Well Name: W-32 Spud Date: 10/31/2002 Event Name: REENTER+COMPLETE Start: 10/31/2002 End: 11/29/2002 Contractor Name: DOYON Rig Release: 11/29/2002 Rig Name: DOYON 14 Rig Number: 14 Hours Task Code NPT Descriþtionöf Operations 11/9/2002 11 :00 - 14:00 3.00 DRILL P PROD1 Collars - HE Drilling Jars - Circulating Sub - XO Sub - 30 Jts 2-7/8" DP - XO - XO. Total BHA Length - 1,123.39'. Set Motor Bend and Oriented to MWD. 14:00 - 15:00 1.00 DRILL P PROD1 M I U Top Drive and Tested MWD Tools, 160 gpm, 780 psi. No Pulse. 15:00 - 16:00 1.00 DRILL P PROD1 RIH wI 4-3/4" Directional BHA on 5" DP to 2,000'. M I U Top Drive, Tested MWD, 160 gpm, 780 psi. No Pulse. Lowered Pressure in Pulsation Dampener from 500 psi to 200 psi. Tested MWD, 160 gpm, 780 psi, No Pulse. 16:00 - 17:00 1.00 DRILL N DFAL PROD1 POOH wI 5" DP. M I U Top Drive to BHA. Tested MWD, Pumped Hi-Vis Pill, 160 gpm, 780 psi, No Pulse. 17:00 - 21 :00 4.00 DRILL N DFAL PROD1 POOH to MWD, Changed out Pulsers. RIH wI MWD on 1 Stand of 2-7/8" DP. M I U Top Drive, Tested MWD 160 gpm, 780 psi, No Pulse. 21 :00 - 22:00 1.00 DRILL N DFAL PROD1 POOH, Broke Out and LID Mud Motor. M I U Top Drive wI XO Directly Above MWD. Tested MWD, 160 gpm, 310 psi. No Pulse. 22:00 - 23:00 1.00 DRILL N DFAL PROD1 Changed Out Pulsers in MWD. M I U Top Drive and Tested MWD wI 160 gpm, 310 psi, Very Weak Intermittent Pulse. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 POOH, Broke out and LID All MWD Tools and BHA. 11/10/2002 00:00 - 01 :30 1.50 DRILL N DFAL PROD1 Held PJSM. Changed out MWD Tools. M I U DM Directional Pulser I Probe and DM Superslim Bottom Sub. Downloaded Data to Probe. 01 :30 - 02:00 0.50 DRILL N DFAL PROD1 M I U Top Drive and Tested MWD. 160 gpm, 300 psi. Good Pulse and Read Out. 02:00 - 02:30 0.50 DRILL N DFAL PROD1 M I U Motor and PDC Bit and Oriented Tools. 02:30 - 03:00 0.50 DRILL N DFAL PROD1 RIH wI Directional BHA on 2-7/8" DP to 1,123'. M I U Top Drive and Tested MWD. 160 gpm, 780 psi. Good Pulse and Read Out. 03:00 - 03:30 0.50 DRILL N DFAL PROD1 Changed Out Handling Equipment to 5". RIH wI 4-3/4" Directional BHA on 5" DP to 1,700'. 03:30 - 06:30 3.00 DRILL P PROD1 RIH wI 4-3/4" Directional BHA on 5" DP to 9,600'. 06:30 - 07:00 0.50 DRILL P PROD1 M I U Top Drive and Engaged Pump. Pump Rate 160 gpm, 1,100 psi. Oriented Tools to 54 deg Left. Shut Down Pump and RIH to 9,691'. 07:00 - 00:00 17.00 DRILL P PROD1 Drilled 4-3/4" Directional Hole by Sliding from 9,691' to 10,150'. WOB 10,000# - 15,000#, Motor RPM 256, Pump Rate 160 gpm, SPP Off Bottom 1,450 psi, On Bottom 1,750 psi. String Weight Up 220,000#, String Weight Down 205,000#. Pumped 30 bbl Hi-Vis Sweeps every 200'. ART = 0.0 hrs, AST = 14.40 hrs. 11/11/2002 00:00 - 11 :30 11.50 DRILL P PROD1 Drilled 4-3/4" Directional Hole by Sliding from 10,150' to 10,473'. WOB 10,000# -15,000#, Motor RPM 256, Pump Rate 160 gpm, SPP Off Bottom 1,450 psi, On Bottom 1,750 psi. String Weight Up 229,000#, String Weight Down 205,000#. Pumped 30 bbl Hi-Vis Sweeps every 200'. 11 :30 - 12:30 1.00 DRILL P PROD1 Pumped 30 bbl Hi-Vis Sweep from Surface Back to 5-1/2" Liner Top at 9,377'. Pump Rate 160 gpm, 1,450 psi. Flow Checked Well, Well Static. 12:30 - 14:00 1.50 DRILL P PROD1 Held PJSM. POOH from 10,473' to 9,995' w/1 0,000# - 15,000# Drag. M I U Top Drive and Pumped Out of the Hole from 9,995' to 9,707', Pump Rate 170 gpm, 1,700 psi. POOH w/out Pumps from 9,707' to Window at 9,665' wI 5,000# - 7,000# Drag. Printed: 12/6/2002 1 :56:39 PM ') ') BPEX.PL@RÆXIIØN OJ>~FéltiC)[ls·...Sumrl'lªry.·.·~epC)1"1: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 Date From- To HOLlrs Task Code 11/11/2002 12:30 - 14:00 1.50 DRILL P Description of Operations PROD1 POOH to 9,400' and Positioned Circulating Sub at 5-1/2" Liner Top at 9,377', Dropped Circulating Sub Dart and Sheared Sub Open. PROD1 Circulated Hole Clean wI Circulating Sub Open. Pump Rate 600 gpm, 2,180 psi. Reciprocated Circulating Sub Across 5-1/2" Liner Top. Circulated back Abundant Fine Sand w/ Sweep and Bottoms Up. Circulated Until Returns Over Shaker were Clean, 150 bbls past Bottoms Up. Flow Checked Well, Well Static. POOH wI 5" DP to 1,123'. POOH wI Directional BHA. Racked 2-7/8" DP in Derrick. Broke Out and LID Jars and Motor. MWD Downloaded Data from Directional Probe. Changed Out Directional Probe and Turbine. M I U Gamma Ray-Resistivity Tool. Uploaded Data to MWD Tools. Held PJSM. M I U BHA: 4-3/4" GeoDmd MDT285QYPX PDC Bit, Ser# JS9292, dressed wI 6x1 0 jets, 3-5/8" SperryDrill Lobe 4/5 3.5 stg Motor wI 1.50 deg Bent Housing, Non-Mag Float Sub - SuperSlim GR Res - SuperSlim Tm Bm Gm HOC - Reverse Flow Sub - Non-Mag MWD Flex Sub - Non-Mag XO - 3 x Flex Collars - HE Drilling Jars - Circulating Sub - XO Sub. Set Motor Bend and Oriented to MWD. M I U Top Drive and Tested MWD Tools, 160 gpm, 1,050 psi. Good Pulse. Held PJSM. Finished M I U 4-3/4" Directional BHA wI 84 Jts 2-7/8" DP - XO - XO. Total BHA Length - 2,851.86'. RIH wI 4-3/4" Directional BHA on 5" DP to 9,360'. Held PJSM. Slipped and Cut Drilling Line. RIH wI 4-3/4" Directional BHA on 5" DP to 10,375'. M I U Top Drive and Oriented Tools at Top of Window. Strted taking weight @ 10190'. Wash to bottom @ 10473' 37 Spm @ 1600 Psi. Make MAD pass from 10473 to 9695'. Pull @ 150 ft/hr. P/U 210K, S/O 190K. TIH to 10321'. Tag up on tight hole. Wash from 10321 to bottom @ 10473'. Directionaly drill from 10473 to 10547'. Slid only. 38 Stks, 1459 Gpm, PP off 1550 Psi, PP on 1750 Psi, AST 2.63 Hrs. Hole losing mud. Circulate across top of hole & monitor static losses. Losing 90-110 Bph. POOH up into 5 1/2" liner @ 9640'. Monitor static losses. Build mud volume. Fluid losses 95 Bph to 110. Pump LCM down Hole. Mixing 3 Ppb OM Seal & 7 Ppb Barafiber. 30 Spm @ 1200 PSi. After 1 hr increased rate to 38 Spm @ 1550 Psi. Fluid loss went from 140 Bph to 48 Bph. When 20 bbls of LCM exited bit bit, pressure dropped from 1200 PSI @ 30 SPM to 950 Psi @ 31 SPM. (The pressure had spiked several times up to 1,300 ? just prior to the lose of the pulse. Losses for 1 hour in 5 minute increments: 21 :00 hrs. 214 bbls. in active 21 :05 204 bbls. in active 1330 strokes LCM is 14:00 - 15:00 1.00 DRILL P 15:00 - 18:30 3.50 DRILL P PROD1 18:30 - 20:30 2.00 DRILL P PROD1 20:30 - 21 :00 0.50 DRILL P PROD1 21 :00 - 22:00 1.00 DRILL P PROD1 22:00 - 22:30 0.50 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 11/12/2002 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 04:00 3.00 DRILL P PROD1 04:00 - 05:00 1.00 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 13:00 7.00 DRILL P PROD1 13:00 - 13:30 0.50 DRILL P PROD1 13:30 - 14:00 0.50 DRILL P PROD1 14:00 - 17:00 3.00 DRILL P PROD1 17:00 - 17:30 0.50 DRILL P PROD1 17:30 - 18:00 0.50 DRILL P PROD1 18:00 - 20:30 2.50 DRILL P PROD1 20:30 - 22:00 1.50 DRILL P PROD1 Printed: 12/6/2002 1 :56:39 PM ) ) ·BPEXPLORÃTI0N Ope~~tion$.SLlIrt>R'lary..R~pØrt exiting bit 21:10 189 bbls. in active 21: 15 178 bbls. in active 21 :20 169 bbls in active 21 :25 157 bbls in active 21 :30 153 bbls in active PROD1 Monitor static fluid loss, 36 Bph. Drop ball & open Circulating sub. After ball dropped & circulation restarted, MWD started to work again. Pump pressure increased to 1600 Psi. When ball hit & ports opened pressure dropped to 640 Psi @ 38 Spm. Con't to pump while mixing 50 bbl LCM pill. LCM pill as follows: 20 ppb fine Baraseal, 20 ppb med. Baraseal, 30 ppb Barafiber, 20 ppb OM Seal, 10 ppb fine Walnut. Fluid loss @ 2400 hrs 18 Bph static & 24 Bph while circulating. Total Fluid loss 600 bbls. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Date FrOrn-To HoUrs Task Code NPT Phase 11/12/2002 20:30 - 22:00 1.50 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P 11/13/2002 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 02:00 1.00 DRILL P PROD1 02:00 - 04:30 2.50 DRILL P PROD1 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 06:00 1.00 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 07:00 0.50 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 09:00 1.00 DRILL P PROD1 09:00 - 10:30 1.50 DRILL P PROD1 10:30 - 13:00 2.50 DRILL P PROD1 13:00 - 15:00 2.00 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 18:30 0.50 DRILL P PROD1 18:30 - 20:00 1.50 DRILL P PROD1 20:00 - 23:00 3.00 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 11/14/2002 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 03:00 2.50 DRILL P PROD1 03:00 - 04:30 1.50 DRILL P PROD1 04:30 - 00:00 19.50 DRILL P PROD1 Päg~110f17 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 D$scriptionof Operations Con't circulating, 38 Spm @ 520 Psi. losing 25 Bph. Finish mixing 50 bbl LCM pill. Pump pill, 40 Spm @ 1000 Psi. Losing 10 Bph. Monitor well, well static, no losses. POOH wi 5" DP to 2851'. Change out handling tools for 27/8" DP. POOH wi 2 7/8" DP to BHA. POOH wi BHA to surface. Check bit & motor, OK. Download MAD data. Inspect MWD pulsar. Found pulsar plugged wi Barafiber & LCM material. change out same. Upload MWD tool, Orient MWD & motor. Surface test equip. Equip tested good. RIH wi BHA on 2 7/8" DP to 2851'. Change out tools for 5" DP. Fill pipe & test MWD. Had no to weak pulse. Con't to RIH to 4250'. Test MWD, no to weak pulse. POOH to 2 7/8" DP. Change out handling tools for 27/8" DP. POOH wi 27/8" DP. Stand back BHA. Surface test MWD. 36 Spm @ 1020 Psi. Mwd not working, Flush wi Fresh water, No good. Plug into Tool & diagnose same. Change out pulsar in MWD. Plugged wi sand & LCM. Plug into MWD & test same, OK. Surface test MWD. 36 Spm @ 1120 Psi. RIH w/ BHA. RIH wi 2 7/8" DP. RIH wi 5" DP to 9260'. Filled & tested MWD every 15 stands. Cut & slip Drillig line. RIH wi 5" DP to 9665'. Circulate bottoms up. 38 Spm @ 1600 Psi. No losses to hole. Wash & ream from window @ 9670 to TD @ 10547'. Hole in good condition, had to work pipe from out under window only. No losses noted while washing to bottom. Directionaly drill from 10547 to 11141'. 38 Stks, 159 Gpm, Torq on 5K, Torq off 4.5K, PP on 1950 Psi, PP off 1700 Psi, Surface Rpm 50 rotating, Bit Rpm 254 Sliding, P/U 225K, S/O 185K, Rot 205K. AST 6.26 Hrs. ART 4.69 Hrs. Fluid losses for the day 465 Bbls. Losing 30 Bph average while drilling. Printed: 12/6/2002 1 :56:39 PM ) ') BPEXPL.OAAfION Openª~iløn$...·SIJ·ltlr)'Iª·ry·...·Rg·Þ()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 Hours Task Code N PT Phase 11/14/2002 04:30 - 00:00 19.50 DRILL P PROD1 Having some problems wi MWD due to Steel Seal additions, Cut Steel Seal & swept wi water @ 1830 Hrs & MWD functions fine. 11/15/2002 00:00 - 22:00 22.00 DRILL P PROD1 Directionaly drill from 11141 to 12140'. 38 Spm, 160 Gpm, PP on 1950 Psi, PP off 1700 Psi, Torq on 5.5K, Torq off 4.0K, WOB 5-8K, Bit Rpms 256, Pipe Rpms 50, P/U 233K, S/O 197K, Rot 215K. AST 5.37 Hrs, ART 6.62 Hrs. Average losses while drilling 70 BPH. Total Losses for the day 1509 Bbls. 22:00 - 23:00 1.00 DRILL P PROD1 Survey. Obtain SPRs. Monitor static losses 48 BPH. 23:00 - 00:00 1.00 DRILL P PROD1 Backream out of hole. from 12140 to 11000'. 30 RPMs, PP 1400 Psi. Hole in good shape. 11/16/2002 00:00 - 00:30 0.50 DRILL P PROD1 Backream out of hole to 10400'. 50 RPMs, 37 SPM @ 1400 PSI. 00:30 - 01 :30 1.00 DRILL P PROD1 Pump out of hole from 10400 to 9695'.37 SPM @ 1400 PSI. Losing 70 BPH while pumping out. 01 :30 - 02:00 0.50 DRILL P PROD1 RIH to 10700'. Hole in good condition. Losses were 48 BPH while tripping in. 02:00 - 03:00 1.00 DRILL P PROD1 Pump & spot 40 bbl, 30 ppb LCM pill wi 1400 Stks. 03:00 - 04:00 1.00 DRILL P PROD1 POOH to 9100'. Monitor well. Static losses 48 BPH. 04:00 - 05:00 1.00 DRILL P PROD1 Wash back in hole to to space out circulating sub @ 9377' (TOL). Losses 70 BPH while pumping @ 37 SPM. 05:00 - 06:00 1.00 DRILL P PROD1 Drop ball & open circulating sub. Circulate sweep surface to surface 600 Gpm @ 3100 Psi. Losing 60 BPH. Rotate & work circulating sub accross liner top to clean hole. static losses 50 BPH. 06:00 - 07:00 1.00 DRILL P PROD1 Pump & spot 60 bbl of 50 ppb LCM pill wi 1200 Stks. 07:00 - 07:30 0.50 DRILL P PROD1 Pull 10 stands to 8500'. 07:30 - 08:00 0.50 DRILL P PROD1 Circulate accross top of stack. Monitor losses, losses dropped to zero. 08:00 - 08:30 0.50 DRILL P PROD1 Circulate staging up pump to 550 GPM @ 2350 Psi. wi no losses. 08:30 - 10:00 1.50 DRILL P PROD1 POOH wi 5" DP to 2851'. 10:00 - 10:30 0.50 DRILL P PROD1 Change out handling tools for 2 7/8" DP. 10:30 - 11 :30 1.00 DRILL P PROD1 POOH wi 27/8" DP. 11 :30 - 13:00 1.50 DRILL P PROD1 POOH & LID BHA. Download MWD data. 13:00 - 13:30 0.50 DRILL P PROD1 Clean & clear floor of vendors tools. 13:30 - 14:00 0.50 BOPSUR P PROD1 Pull wear bushing & install test plug to test BOPE. 14:00 - 17:30 3.50 BOPSURP PROD1 R/U & test BOPE. Test rams, choke manifold, valves & lines to LP 250 Psi, HP 3500 Psi, Test annular, LP 250 Psi, HP 2500 Psi. . Test witnessed by John Crisp wi AOGCC. 17:30 - 18:30 1.00 BOPSUR P PROD1 Rid test equip. Pull test plug & install wear bushing. 18:30 - 23:00 4.50 DRILL P PROD1 PJSM. M/U BHA. Change out probe in MWD. Surface test MWd equip. 23:00 - 00:00 1.00 DRILL P PROD1 P/U additional 2 7/8" DP. RIH 1 x 1. 11/17/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Con't to P/U 57 jts 1x1 27/8" DP & RIH. 01 :00 - 02:00 1.00 DRILL P PROD1 RIH by stands w/2 7/8" DP to 4646'. 02:00 - 02:30 0.50 DRILL P PROD1 Change out handling tools for 5" DP. Test MWD for pulse. 02:30 - 04:00 1.50 DRILL P PROD1 RIH w/ 5" DP to 9626'. Fill every 15 stands & check for pulse in MWD. 04:00 - 05:00 1.00 DRILL P PROD1 Cut & slip drilling line. 05:00 - 07:00 2.00 DRILL P PROD1 Circulate bottoms up. 37 SPM @ 1390 Psi. No losses to hole. Printed: 12/6/2002 1:56:39 PM ') ) Legal Well Name: W-32 Common Well Name: W-32 Spud Date: 10/31/2002 Event Name: REENTER+COMPLETE Start: 10/31/2002 End: 11/29/2002 Contractor Name: DOYON Rig Release: 11/29/2002 Rig Name: DOYON 14 Rig Number: 14 Date Task Code NPT Phase [)espriptiOn..of()peratiöns 11/17/2002 05:00 - 07:00 2.00 DRILL P PROD1 Orient tool face 50 degrees left to go thru window. 07:00 - 08:00 1.00 DRILL P PROD1 Wash down to 10670'. 37 SPM @ 1400 PSi. Hit minor ledges @ 10135 & 10460'. No losses to hole noted. 08:00 - 09:00 1.00 DRILL P PROD1 Circulate & wash to bottom @ 12140'. 50 RPMs, Torq 4k, 37 SPM @ 1650 Psi. Started losing mud @ 20 BPH to hole. 09:00 - 00:00 15.00 DRILL P PROD1 Directionaly drill from 12140 to 12616'. 38 SPM, 160 GPM, PP on 2130 Psi, PP off 1780 Psi, Torq on 7K, Torq off 4.5K, WOB 7-10K, Bit RPMs 254, Pipe RPMs 50. P/U 222K, SIO 187K, ROT 207K. AST 2.45 Hrs, ART 5.52 Hrs. Losses were averaging 37 BPH for the last 7 Hrs. Total losses for the day were 439 bbls. 11/18/2002 00:00 - 12:00 12.00 DRILL P PROD1 Directionaly drill from 12616 to 12847'. Lost MWD pulse. 38 SPM, 160 GPM, PP on 2100 Psi, PP off 1800 Psi, Torq on 6.5K, Torq off 5K, WOB 7-10K, Bit RPMs 254, Pipe RPMs 50. P/U 225K, SIO 190K, ROT 210K. AST 2.25 Hrs, ART 5.72 Hrs. Losses average 33 BPH. 12:00 - 14:00 2.00 DRILL N DFAL PROD1 Flow check, Pump water slug. POH pumping & rotating from 12800 to 11700' attempting to make MWD respond. 14:00 - 14:30 0.50 DRILL N DFAL PROD1 Attempt to cycle MWD, no success. 14:30 - 16:00 1.50 DRILL N DFAL PROD1 Con't to POOH to 9580'. 16:00 - 17:30 1.50 DRILL N DFAL PROD1 Flow check. Break circulation. Drop dart & open circulating sub. Circulate bottoms up @ 500 GPM. Had large amount of cuttings @ bottoms up. 17:30 - 18:30 1.00 DRILL N DFAL PROD1 Spot 60 bbl LCM pill. 30ppb Barafiber & 20 ppb OM seal. 18:30 - 19:00 0.50 DRILL N DFAL PROD1 POOH 10 stands & pump dry job. 19:00 - 21 :00 2.00 DRILL N DFAL PROD1 Flow check. POOH wI 5" DP. Well appears static - no losses. 21 :00 - 23:00 2.00 DRILL N DFAL PROD1 Change out handling tools to 2 7/8". POOH w/2 7/8" DP. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 LID jars & stand back DCs. 11/19/2002 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 Finish down loading MWD data. change out motor & bit. 01 :00 - 02:30 1.50 DRILL N DFAL PROD1 Change out MWD equip. Upload MWD & orient same. 02:30 - 03:00 0.50 DRILL N DFAL PROD1 Surface test MWD & motor. 03:00 - 04:30 1.50 DRILL N DFAL PROD1 TIH wI 27/8" DP to 4647'. Break circulation & test MWD for pulse. 04:30 - 05:00 0.50 DRILL N DFAL PROD1 Change out handling tools for 5" DP. 05:00 - 06:30 1.50 DRILL N DFAL PROD1 TIH wI 5" DP to 9623'. No losses to hole. 06:30 - 07:00 0.50 DRILL N DFAL PROD1 Orient above whipstock & circulate 1000 strokes. 37 SPM @ 1450 Psi. 07:00 - 08:30 1.50 DRILL N DFAL PROD1 TIH & wash every 5th stand down, to 12400'. 37 SPM @ 1650 Psi. 08:30 - 09:30 1.00 DRILL N DFAL PROD1 Wash & ream last 4 stands to bottom @ 12847'. No losses to hole. 09:30 - 00:00 14.50 DRILL P PROD1 Directionaly drill from 12847 to 13010'. Hole was static until started drilling, losses increased to +/- 22 BPH. 38 SPM, 160 GPM, PP on 2300 Psi, PP off 1980 Psi, Torq on 7K, Torq off 5K, WOB 7-10K, Bit RPMs 254, Pipe RPMs 50. P/U 230K, SIO 195K, ROT 215K. AST 4.77 Hrs. ART 3.14 Hrs. 11/20/2002 00:00 - 08:00 8.00 DRILL P PROD1 Drill from 13010 to 13025'. Drilling very hard & slow. Pump lube cocktail & spotted glass beads in an attempt to slide drill, no go. 38 SPM, 160 GPM, PP on 2300 Psi, PP off 1980 Psi, Torq on 7K, Torq off 5K, WOB 7-10K, Bit RPMs 254, Pipe RPMs 50. P/U 230K, S/O 195K, ROT 215K. ART .5 Hrs, AST .5 Hrs. Printed: 12f6f2002 156:39 PM ) ) BPEXPl..OR1-\TION Opgrations. .SUfflrnå.r¡.·.·Repor1: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 Date Frorn-·To HOLlrs Task Code NPT Phase Description of Operations 11/20/2002 08:00 - 08:30 0.50 DRILL P PROD1 POOH to 11920'. 08:30 - 09:30 1.00 DRILL P PROD1 Wash & ream back down to 12400' 50 RPMs, Torq 4K, 36 SPM @ 1850 Psi. 09:30 - 10:30 1.00 DRILL P PROD1 Ream through low side of open hole to prepare for sidetracking operation. from 12365 to 12400'. 10:30 - 20:00 9.50 STKOH P PROD1 Begin sidetracking open hole. Time drill 5 FPH from 12406 to 12426'. Hole losses average 20 BPH. 37 SPM, 154 GPM, Bit RPMs 254, PP on 2200 PSI, WOB 5-8K. P/U 215K, S/O 190K, Rot 205K. 20:00 - 23:30 3.50 STKOH P PROD1 Con't to attempt drilling ahead by both rotation & sliding. Drilled 2' from 12426 to 12428'. WOB 6-15K, 37 SPM, 154 GPM, Torq 4-7K, motor 254 RPMs, Pipe 25 RPMs. Pumped a Lo-Vis sweep wI no results. Low dirrerential pressure (50#). Possible motor &/or bit failure. 23:30 - 00:00 0.50 STKOH N DFAL PROD1 POOH from 12428 to 11400'. 11/21/2002 00:00 - 01 :30 1.50 STKOH N DFAL PROD1 Con't to POOH wI 5" DP to 9600'. Hole in good condition. 01 :30 - 02:00 0.50 STKOH N DFAL PROD1 Drop dart & on Pump Out Sub. Break circulation. 500 GPM @ 3000 PSi. 02:00 - 02:30 0.50 STKOH N DFAL PROD1 Pump 60 bbl LCM pill made up of 17 ppb Liquid casing & 8 ppb OM Seal. Chase wI 1200 STKs. 02:30 - 03:00 0.50 STKOH N DFAL PROD1 POOH 10 stands & pump dry job. Hole static, no losses. 03:00 - 04:30 1.50 STKOH N DFAL PROD1 Con't to POOH wI 5" DP to 4647'. 04:30 - 05:00 0.50 STKOH N DFAL PROD1 Change out handling tools for 27/8" DP. 05:00 - 06:30 1.50 STKOH N DFAL PROD1 POOH w/2 7/8" DP. 06:30 - 07:30 1.00 STKOH N DFAL PROD1 POOH wI BHA. Down load MWD. Change out MWD pulsar. 07:30 - 08:00 0.50 STKOH N DFAL PROD1 M/U MWD & upload same. 08:00 - 08:30 0.50 STKOH N DFAL PROD1 LID bit & motor. Float sub flapper hinge washed out, causing flapper to go into MM. P/U new motor & re-run bit. 08:30 - 09:30 1.00 STKOH N DFAL PROD1 Orient motor & MWd. Trip in hole to 200'. Surface test equip. 09:30 - 10:30 1.00 STKOH N DFAL PROD1 Cut & slip 60' of drilling line. 10:30 - 12:00 1.50 STKOH N DFAL PROD1 RIH wI BHA & 2 7/8" DP. 12:00 - 12:30 0.50 STKOH N DFAL PROD1 Fil pipe. Test MWD. Lubricate rig. 12:30 - 13:00 0.50 STKOH N DFAL PROD1 Change out hnadling tools for 5" DP. 13:00 - 14:30 1.50 STKOH N DFAL PROD1 RIH wI 5" DP to 9626'. Fill pipe every 15 stands & test equip. 14:30 - 16:00 1.50 STKOH N DFAL PROD1 Circulate 1000 STKs. Check MWD. Orient tools 50 degrees left. change MWD Mode. 16:00 - 18:00 2.00 STKOH N DFAL PROD1 Con't to RIH in open hole section washing from 9900 to 10700'.. Rih to 12307'. Wash & ream from 12307 to 12428'. 18:00"' 00:00 6.00 STKOH P PROD1 Drill from 12428 to 12530'. Losses average 20 BPH. 38 SPM, 160 GPM, PP on 2050 Psi, PP off 1760 Psi, Torq on 5.5K, Torq off 4.5K, WOB 8-10K, Bit RPMs 254, Pipe RPMs 50. P/U 220K, S/O 190K, ROT 205K. AST 1.3 Hrs, ART. 72 Hrs. 11/22/2002 00:00 - 00:00 24.00 STKOH P PROD1 Directionaly drill from 12560 to 13025'. Losses average 20 BPH while drilling. 38 SPM, 160 GPM, PP on 2050 Psi, PP off 1850 Psi, Torq on 6K, Torq off 4K, WOB 8-1 OK Bit RPMs 254, Pipe RPMs 50. P/U 230K, S/O 195K, ROT 210K. AST 6.01 Hrs, ART 8.69 Hrs. 11/23/2002 00:00 - 00:00 24.00 STKOH P PROD1 Drill from 15025 to 13551'. Losses were running approx 30 BPH while drilling. Crossed fault @ 13424' @ lost returns. Lost approx 170 bbls of mud before getting returns back. Afterwards losses were running approx 36 BPH. Con't to drill ahead wI losses. 30 SPM, 160 GPM, PP on 2300 Psi, PP off 1980 Psi, Printed: 12/6/2002 1 :56:39 PM ) ) BR.·.··EXPl..<I>RAfrON O~êl"¡jfiØll$SUl'l1l'1'1ary.. ··Rßþørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 Date From".To Hours Task Code NPT Phase Descri ptiOhofOperations 11/23/2002 00:00 - 00:00 24.00 STKOH P PROD1 Torq on 6K, Torq off 4k, WOB 7-10K, Bit RPMs 254, Pipe RPMs 50. P/U 235K, S/O 192K, ROT 220K. AST 6.25 Hrs, ART 12.75 Hrs. 11/24/2002 00:00 - 02:00 2.00 STKOH P PROD1 Drill from 13551 to 13585'. Plugged drill string from the addition of beads. Worked pipe to establish circulation & clear BHA. No good. 38 SPM, 160 GPM, PP on 2300 Psi, PP off 1980 Psii, Torq on 4K, Torq off 6K. WOB 8-1 OK Bit RPMs 254, Pipe RPMs 50. P/U 230K, S/O 192K, ROT 220K. 02:00 - 05:30 3.50 STKOH P PROD1 POOH & work pipe. Established partial circulation & gradually increase to full circulation @ 12307'. Started to backream out of hole when circulation started. When full circulation was established, checked MWD tools, fuctioning fine. Con't POOH to 9332'. 05:30 - 06:30 1.00 BOPSURP PROD1 M/U storm packer on 5" DP & set @ 50'. P/U 75K, S/O 85K. 06:30 - 07:30 1.00 BOPSUR P PROD1 Pull wear bushing. M/U & install test plug. 07:30 - 10:30 3.00 BOPSURP PROD1 Pressure test BOPE as per AOGCC standards. Tested rams, choke manifold, valves & lines to LP 250#, HP 3500#. Tested annular to LP 250#, HP 2500#. Test witnessing waived by Jeff Jones wi AOGCC. 10:30 - 11 :00 0.50 BOPSURP PROD1 Pull test plug & installed wear bushing. RID test equip. 11 :00 - 11 :30 0.50 BOPSURP PROD1 Pull & LID storm pkr. Filled hole wi 38 bbls mud. 11:30-13:00 1.50 STKOH P PROD1 Cut & slip 60' of drilling line. Lubricate rig. 13:00 -16:00 3.00 STKOH P PROD1 RIH to 10000'. Wash down from 10000 to 10600'. Con't to RIH to 12860'. Wash & ream from 12860 to TD @ 13585'. Hole in good condition. 16:00 -17:00 1.00 STKOH N DFAL PROD1 Drill from 13585 to 13588'. Motor showing low torq, could not drill ahead. PP on 2600 Psi, PP off 2140 Psi. Before tool failure PP off was 1980 Psi. 17:00 - 19:30 2.50 STKOH N DFAL PROD1 Flow Check well. POOH from 13588 to 9626'. Hole in good condition. 19:30 - 22:15 2.75 STKOH N DFAL PROD1 Break circulation, drop dart & open pump out sub. Circulate sweep surface to surface. 500 GPM. Spot 40 bbl LCM pill. 10 ppb OM seal & 20 ppb Barafiber. 22:15-23:00 0.75 STKOH N DFAL PROD1 Flow check well. POOH 10 stands. Flow check well, Pump slug. 23:00 - 00:00 1.00 STKOH N DFAL PROD1 Con't POOH from 8600 to 2 7/8" DP. 11/25/2002 00:00 - 00:30 0.50 STKOH N DFAL PROD1 Change out handling tools for 27/8" DP. 00:30 - 02:30 2.00 STKOH N DFAL PROD1 POOH wi 27/8" DP & stand back in derrick. 02:30 - 07:00 4.50 STKOH N DFAL PROD1 POOH wi BHA. Change out probe in MWD tool. LID bit & motor. Motor appeared to have cracked shaft. P/U new bit & motor. Orient same. Pulse test MWD tool. 07:00 - 08:00 1.00 STKOH N DFAL PROD1 RIH wi 2 7/8" DP. Test MWD equip. 08:00 - 12:00 4.00 STKOH N DFAL PROD1 Change out handling tools for 5" DP.RIH to window. 12:00 - 13:30 1.50 STKOH N DFAL PROD1 Orient tools & con't to RIH to 12400' @ open hole kick off point. Low side bit & con't to RIH. Tagged up 13025'. Entered old wellbore. POOH to 12400'. 13:30 - 14:00 0.50 STKOH N DFAL PROD1 Orient & locate new wellbore. Work & ream hole thru kick off point by low siding bit. 14:00 - 15:30 1.50 STKOH N DFAL PROD1 RIH & ream from 13158 to 13588'. 15:30 - 00:00 8.50 STKOH P PROD1 Drill from 13588 to 13774'. Losses average 28 BPH. 38 SPM, 160 GPM, PP on 2030 Psi, PP off 1850 Psi, Torq on 6.5K, Torq off 4.5K,WOB 8-1 OK. Bit RPMs 130. Pipe RPMs 190. P/U Printed: 12/6/2002 1:56:39 PM ) ) BPEXPL.@!RATION Op(!ratiørl$..·.Sur11·tì1·aFt/..·Repol"t Legal Well Name: W-32 Common Well Name: W-32 Spud Date: 10/31/2002 Event Name: REENTER+COMPLETE Start: 10/31/2002 End: 11/29/2002 Contractor Name: DOYON Rig Release: 11/29/2002 Rig Name: DOYON 14 Rig Number: 14 From-To !-Iou rs Task Gode NPT Phäse Descriptiönof Operations 11/25/2002 15:30 - 00:00 8.50 STKOH P PROD1 240K. S/O 185K, ROT 215K. AST 3.25 Hrs. ART 3.25 Hrs. 11/26/2002 00:00 - 09:30 9.50 STKOH P PROD1 Drill from 13774 to TD @ 13950'. average losses 20 BPH. 38 SPM, 160 GPM, PP on 2300 Psi, PP off 2050 Psi, Torq on 7K, Torq off 5K, WOB 8-10K, Bit RPMs 135, Pipe RPMs 190. P/U 240K, S/O 195K, ROT 215K. AST 4.5 Hrs, ART 11.25 Hrs. 09:30 - 11 :30 2.00 STKOH P PROD1 Backream from 13950 to 12308'. 11 :30 - 14:00 2.50 STKOH P PROD1 Ream from 12308 to 13150'. RIH to faulted section @ 13416'. Work bit thru & ream hole. RIH to 13950'. 14:00 - 16:00 2.00 STKOH P PROD1 Circulate 3 open hole volumes & spot liner running pill thru entire open hole section. 16:00 - 18:00 2.00 STKOH P PROD1 Flow check well. POOH from 13950 to 9626'. Had tight spot @ 13416' (fault zone) 18:00 - 20:00 2.00 STKOH P PROD1 Flow check well. Drop dart open pump out sub. circulate sweep surface to surface @ 500 GPM. Pump slug. 20:00 - 22:00 2.00 STKOH P PROD1 POOH from 9626 to 2 7/8" DP. Pulled wet at start. 22:00 - 22:30 0.50 STKOH P PROD1 Flow check well. Change out handling tools for 5" DP. Pump 2nd slug (100 bbls). Hole static, no losses. 22:30 - 00:00 1.50 STKOH P PROD1 POOH & LID 1x1 27/8" DP. 11/27/2002 00:00 - 02:00 2.00 STKOH P PROD1 Con't to POOH & LID 1x1 27/8" DP. 02:00 - 04:00 2.00 STKOH P PROD1 LID DCs. Attempt to down load MWDdata, no good. LID MWD tools. Break out bit & LID motor. 04:00 - 05:00 1.00 STKOH P PROD1 Clear floor. LID all 2 7/8" DP handling tools. 05:00 - 06:00 1.00 CASE P COMP Held PJSM. R/U tools to run 3 1/2" liner. 06:00 - 10:30 4.50 CASE P COMP Run 3 1/2" liner. Ran 150 jts, 3 1/2" 9.3#, L-80, BTC-Mod tubing. Lost 30 bbls while running liner. 10:30 - 12:00 1.50 CASE P COMP M/U liner top packer. M/U cementing head & stand back same. Circulate liner volume. Lost 15 bbls while circulating. 12:00 - 15:30 3.50 CASE P COMP RIH wI liner on 5" DP to TOL @ 9330'. Fill pipe every 10 stands. 15:30 - 16:00 0.50 CASE P COMP Circulate & condition mud. Pumped 1 DP & liner volume. 16:00 - 18:00 2.00 CASE P COMP Con't to RIH wI liner into openhole sectiom. Tagged up to 13942'. Had to work thru tight spot @ 13461'. 18:00 - 20:00 2.00 CASE P COMP Circulate & condition hole prior to cementing. Lost returns while circulating, then regained partial returns. ( est 15%). Hold PJSM. R/U cementing equip & batch mix cement. 20:00 - 21 :30 1.50 CEMT P COMP Test lines to 3800 Psi. Cement liner as follows: .Pumped 15 bbls CWo Mixed & pumped 43 bbls of 10 ppg "mud push". Followed w/90 bbls (396 sxs) Blended "G" cement. Mixed @ 15.8 ppg. Yld 1.53 cuft/sx. APR 6 BPM. APP 700 Psi. Dropped top plug & kicked out wI 5 bbls @ 5 BPM. Switch to rig pump & displace @ 6.8 BPM wI 195 bbls of mud. Bumped plug to 3500 Psi, Floats held. PD @ 2140 Hrs, 11/27/2002. When starting to cement had slight returns after 12 bbls away, lost returns. Then after 36 bbls regained slight returns (est. 5%) Con't wI returns thru-out job & they increased to about 15%. Pressures did indicate lifting of cement column. 21 :30 - 22:00 0.50 CEMT P COMP Set liner hanger wI 15 turns. P/U out of dogs & circulate 50 bbls. Set down wt & set "lXP" Packer. 22:00 - 22:30 0.50 CEMT P COMP RID cementing lines. Stand back cementing head. R/U to circulate. 22:30 - 23:30 1.00 CLEAN P COMP Displace well to clean seawater @ 600 gpm. 23:30 - 00:00 0.50 RUNCOrvP COMP Double cut & slip 120' of drilling line. 11/28/2002 00:00 - 00:30 0.50 CEMT P COMP Finish cutting & slipping 120' of drilling line. Service top drive & Printed: 12/6/2002 1 :56:39 PM ) ) BPEX-PLORA1"I@N (Ðlpe..afiøFlS..·.5umI11a.P¡.·aepprt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 REENTER+COMPLETE DOYON DOYON 14 Date FrÖrn>- To Hours Task Code NET Phase 11/28/2002 00:00 - 00:30 0.50 CEMT P 00:30 - 01 :30 1.00 CEMT P 01 :30 - 09:00 7.50 CEMT P 09:00 - 09:30 0.50 CEMT P 09:30 - 10:30 1.00 RUNCOI\tP 10:30 - 00:00 13.50 RUNCOI\tP 00:00 - 01 :00 1.00 RUNCOI\tP 01 :00 - 02:30 1.50 RUNCOI\tP 02:30 - 03:30 1.00 RUNCOI\tP 03:30 - 06:30 3.00 RUNCOI\tP 06:30 - 08:00 1.50 RUNCOI\tP COMP COMP COMP COMP COMP COMP 11/29/2002 COMP COMP COMP COMP COMP 08:00 - 08:30 0.50 RUNCOI\tP COMP 08:30 - 09:30 1.00 BOPSURP COMP 09:30 - 10:30 1.00 WHSUR P COMP 10:30 - 12:00 1.50 WHSUR P COMP 12:00 - 13:30 1.50 WHSUR P COMP 13:30 - 15:00 1.50 WHSUR P COMP 15:00 - 17:00 2.00 WHSUR P COMP Start: 10/31/2002 Rig Release: 11/29/2002 Rig Number: 14 Spud Date: 10/31/2002 End: 11/29/2002 lubricate rig. Lay down cementing head. LID tubing tools. POOH & LID 5" DP. Pull wear bushing. Hold PJSM. R/U completion running tools. Run 41/2" 12.6#, L-80, Cr 13 Vam Ace completion string. Ran 265 jts of 287 jts. Finish RIH w/ 3 1/2" completion to top of 7" XO below liner hanger assy @ 9268 ft. Space out completion string 4 ft above 7" XO w/ WLEG @ 9264 ft. MU tbg hng land same. RILDS. RU & test circulating manifold. Circ & spot inhibited seawater in annlus. Set 9 5/8" 'S' 3 pkr, test 4 1/2" Vam Ace tbg to 3500 psi / 30 mins. Bleed off tbg pressure to 2000 psi. Test 4 1/2" x 9 5/8" ann Ius to 3500 psi / 30 mins. Bleed off tbg pressure and shear RP. Pump thru RP shear both ways @ 2.8 BPM - 290 psi. LD landing jt. Dry rod TWC. Test from below 2000 psi. ND bell nipple, flow line & BOPE. NU & test tree to 5000 psi / 10 mins RU DSM lubricator, pull TWC. RD DSM RU Hot Oil unit, test lines 3500 psi. Pump 137 bbls diesel down IA. Pump rate of 3 BPM @ max 700 psi. U tube well w/ diesel to balance point of 2000 ft in tbg & IA. RD Hot Oil unit. Dry rod BPV. Secure well head. Printed: 12/6/2002 1 :56:39 PM ) ') BP EXPLORATION Operations. Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION NORDIC CALISTA NORDIC 2 Start: 12/6/2002 Rig Release: 12/9/2002 Rig Number: 2 Spud Date: 10/31/2002 End: 12/9/2002 Date From - To Hours Task Code NPT Phase Description of Operations 12/6/2002 00:00 - 01 :00 1.00 BOPSUR P CaMP MIRU Nordic #2. Accept rig at 00:00 hrs 12-6-2002. Start NU BOPE. Same time installation of new 23/8" CT and reel. Spot Tiger Tank and rig camp. 01 :00 - 06:30 5.50 BOPSURP CaMP Test BOPE 250 psi low 13500 psi high. Witnessing wavied by AOGCC 06:30 - 07:00 0.50 RIGU P CaMP Crew change review Technical Limit Plan Foward. 07:00 - 08:00 1.00 RIGU P CaMP Continue BOP test 08:00 - 08:30 0.50 RIGU P CaMP Start rig maint. R&R Gooseneck Roller I Chg Pack-Off I Ck Accumulators 08:30 - 09:00 0.50 RIGU P CaMP PJSM to pull CT from reel to injector. 09:00 - 13:00 4.00 RIGU P CaMP Pull and stab CT. ( 4hrs. time deducted from daywork rate) 13:00 - 13:30 0.50 RIGU P CaMP PJSM to pull test 2 SLB CTC. Same time start putting 80 jts 1 1/4" CSH into pipe shed and SLM 13:30 - 16:45 3.25 RIGU P CaMP Results from SLB dimple CTC. #1 CTC slipped 1/8" at 97k. #2 CTC failed at 98k. (same time working with 1 1/4" CSH) 16:45 - 17:30 0.75 RIGU P CaMP Install Baker CTC. Pull test to 35K. 17:30 - 18:30 1.00 RIGU P CaMP Stab on well. Pump 1" steel ball through coil. 18:30 - 18:45 0.25 RIGU P CaMP Crew change TL 18:45-20:15 1.50 RIGU P CaMP Retrieve 1" ball. PT CTC and inner reel valve. 20:15-21:10 0.92 RIGU P CaMP Pull BPV. 21:10 - 00:00 2.83 RIGU P CaMP Start to plu BHA #1. (82 jts of the 1 1/4" CSH are singles) 12/7/2002 00:00 - 05:30 5.50 CLEAN P CaMP Continue plu BHA #1. 05:30 - 06:00 0.50 CLEAN P CaMP Stab-on injector. 06:00 - 06:30 0.50 CLEAN P CaMP Tech Limit meeting. Start RIH 06:30 - 07:30 1.00 CLEAN P CaMP RIH to 9140'. 07:30 - 08:00 0.50 CLEAN P CaMP Start logging CCLlgr. Tagged up at 9240', surprise!. Top of 3.5" liner. 08:00 - 08:15 0.25 CLEAN P CaMP Mill to 9244'. Pumping at 1.0 - 1.5 bpm. This BHA is not designed to drill a large amount of hard cement.Tagging this high has caused concern over the CCLlgr tool suviving the milling operations. This is also the last memory gr tool available on the slope. Two others were destroyed after using in similiar situations. No other choise but TOH. 08: 15 - 09:20 1.08 CLEAN P CaMP TOH to drop CCLlgr. 09:20 - 09:40 0.33 CLEAN P CaMP PJSM working CSH tubing 09:40 - 13:00 3.33 CLEAN P CaMP Stand back 1 1/4" hydril 13:00 - 13:30 0.50 CLEAN P CaMP LID Schlumberger CCLlgr tool. 13:30 - 17:40 4.17 CLEAN P CaMP TIH wI 1 1/4" hydril 17:40 - 18:15 0.58 CLEAN P CaMP P/U 2 jts hydril. Notice traveling blocks not falling properly with just one jt hanging. 18:15 - 19:00 0.75 CLEAN P CaMP Check and grease crown block and traveling block. Crew change out. 19:00 - 19:30 0.50 CLEAN P CaMP Tech Limit meeting. 19:30 - 20:00 0.50 CLEAN P CaMP P/U MHA and stab-on well. 20:00 - 21 :20 1.33 CLEAN P CaMP RIH with mill pumping at 0.9 bpm. Check wt at 9000' 28k. RIH tagged at 9244'. 21 :20 - 22:00 0.67 CLEAN N DFAL CaMP Start drilling cement. 1.45 bpm 2285 psi free-spin. Motor stalling soon after starting. P/U off bottom several times. Motor appears to have partially plugged off, can only pump at 0.7 bpm @ 3800 psi. 22:00 - 23:45 1.75 CLEAN N DFAL CaMP TOH to hydril. P/U injector and drop .625" ball. Restab inj. pump 7.9 bbls and open circ sub. Pump 10 min to possibly flush out anything.. Break off and stand back injector. Printed: 12/16/2002 10:38:34 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION NORDIC CALISTA NORDIC 2 Start: 12/6/2002 Rig Release: 12/9/2002 Rig Number: 2 Spud Date: 10/31/2002 End: 12/9/2002 Date From - To Hours Task Code NPT Phase Description of Operations 12/7/2002 23:45 - 00:00 0.25 CLEAN N DFAL COMP Stand back hydril tubing. 12/8/2002 00:00 - 00:45 0.75 CLEAN N DFAL COMP Continue to standback 1 1/4" hydril tubing 00:45 - 01 :45 1.00 CLEAN N RREP COMP One of the crown sheaves has returned to making noise. Appears to be locking up while raising the blocks. Re-grease again. Nope sheave is definitely locking up. Secure BHA. 64 stds of 1 1/4" hydril still in the well. Annulus is full. Cemented liner and no open perfs. 01:45 - 02:10 0.42 CLEAN N RREP COMP PJSM. Currently the blocks are strung with 8 lines. Plan is to re-string the blocks to 6 lines bypassing the locked sheave. Review procedures. Will regroup as needed to review "next step" items throughout the job. 02:10 -11:20 9.17 CLEAN N RREP COMP Secure traveling blocks remove bales, remove drawwork guards, remove weight indicators.. Unstring blocks. Wait on new drill line. Re-string blocks with 6 lines. 11 :20 - 13:20 2.00 CLEAN N DFAL COMP Continue TOH stand back hydril. Found TFA on paraboilic mill 90% plugged off from the outside with soft (magnetic) mallible steel. 13:20 - 14:25 1.08 CLEAN N DFAL COMP Stab back on well open-ended, close swab valve. Pump 10 bbls hi-vis pill and flush coil. Stab off well. 14:25 - 18:15 3.83 CLEAN N DFAL COMP PIU new motor. RIH wI 20 stds and a single of 1 1/4" hydril. 18:15-18:45 0.50 CLEAN N DFAL COMP Crew change. TL meeting review plan forward. 18:45 - 17:35 22.83 CLEAN N DFAL COMP Stab on injector. RIH (decided to RIH with reduced amount of 1 1/4" CSH to see if we can get through whatever is on top liner. Either cement and or junk.) 17:35 - 21 :00 3.42 CLEAN N DFAL COMP TIH. At 9230' pick wt. 35k dwn 21 k @ 1.6 bpm free-spin 1540 psi. RIH tag at 9236. 21 :00 - 23:30 2.50 CLEAN N COMP At 9240' CTD setdown and stalled. PIU start time milling at 9239.6' -.8 frequent stalls. 1800 psi @ 1.7 bpm. Continue time milling. Not much luck. Continued stalling. Last stall has resulted in high pressures while pumping <1 bpm. May have plugged the mill like before. Unable to discharge obstruction with high pressures. Talk to town team. Decision to move-off well. 23:30 - 00:00 0.50 CLEAN N COMP TOH 12/9/2002 00:00 - 00:45 0.75 CLEAN N DPRB COMP Continue TOH to the hydril tubing. 00:45 - 03:00 2.25 CLEAN N DPRB COMP Drop .625" ball and open circ sub. LID 24 jts 1 1/4" rental hydril. Standback remainder. LID motor. Same debris wedged into nozzle area of mill. 03:00 - 05:00 2.00 PERF N DPRB COMP PIU nozzle. RIH to 2000' and lay-in methanol 1 : 1 05:00 - 05:30 0.50 PERF N DPRB COMP Standback injector. Install BPV. Close Master and Swab valves. 05:30 - 10:30 5.00 DEMOB N DPRB COMP Clean mud tanks. Set BPV. Blow down BOP stack and nipple down. Tree cap installed and tested to 3500 psi. Rig Released at 10:30 hrs 12-9-200 Prep to move to M-09 Printed: 12/16/2002 10:38:34 AM ) ') BP EXPLORATION Operations Summary Report Page 1 öf 7. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION Start: 1/1/2003 Rig Release: Rig Number: Spud Date: 10/31/2002 End: 1/5/2003 Date From ~ Tö Hours Task Code NPT Phase Description of Operations 12/6/2002 00:00 - 01 :00 1.00 BOPSURP COMP MIRU Nordic #2. Accept rig at 00:00 hrs 12-6-2002. Start NU BOPE. Same time installation of new 2 3/8" CT and reel. Spot Tiger Tank and rig camp. 01 :00 - 06:30 5.50 BOPSURP COMP Test BOPE 250 psi low 13500 psi high. Witnessing wavied by AOGCC 06:30 - 07:00 0.50 RIGU P COMP Crew change review Technical Limit Plan Foward. 07:00 - 08:00 1.00 RIGU P COMP Continue BOP test 08:00 - 08:30 0.50 RIGU P COMP Start rig maint. R&R Gooseneck Roller I Chg Pack-Off I Ck Accumulators 08:30 - 09:00 0.50 RIGU P COMP PJSM to pull CT from reel to injector. 09:00 - 13:00 4.00 RIGU P COMP Pull and stab CT. ( 4hrs. time deducted from daywork rate) 13:00 - 13:30 0.50 RIGU P COMP PJSM to pull test 2 SLB CTC. Same time start putting 80 jts 1 1/4" CSH into pipe shed and SLM 13:30 - 16:45 3.25 RIGU P COMP Results from SLB dimple CTC. #1 CTC slipped 1/8" at 97k. #2 CTC failed at 98k. (same time working with 1 1/4" CSH) 16:45 - 17:30 0.75 RIGU P COMP Install Baker CTC. Pull test to 35K. 17:30 - 18:30 1.00 RIGU P COMP Stab on well. Pump 1" steel ball through coil. 18:30 - 18:45 0.25 RIGU P COMP Crew change TL 18:45-20:15 1.50 RIGU P COMP Retrieve 1" ball. PT CTC and inner reel valve. 20:15-21:10 0.92 RIGU P COMP Pull BPV. 21 : 1 0 - 00: 00 2.83 RIGU P COMP Start to plu BHA #1. (82 jts of the 1 1/4" CSH are singles) 12/7/2002 00:00 - 05:30 5.50 CLEAN P COMP Continue plu BHA #1. 05:30 - 06:00 0.50 CLEAN P COMP Stab-on injector. 06:00 - 06:30 0.50 CLEAN P COMP Tech Limit meeting. Start RIH 06:30 - 07:30 1.00 CLEAN P COMP RIH to 9140'. 07:30 - 08:00 0.50 CLEAN P COMP Start logging CCLlgr. Tagged up at 9240', surprise!. Top of 3.5" liner. 08:00 - 08:15 0.25 CLEAN P COMP Mill to 9244'. Pumping at 1.0 - 1.5 bpm. This BHA is not designed to drill a large amount of hard cement.Tagging this high has caused concern over the CCLlgr tool suviving the milling operations. This is also the last memory gr tool available on the slope. Two others were destroyed after using in similiar situations. No other choise but TOH. 08: 15 - 09:20 1.08 CLEAN P COMP TOH to drop CCLlgr. 09:20 - 09:40 0.33 CLEAN P COMP PJSM working CSH tubing 09:40 - 13:00 3.33 CLEAN P COMP Stand back 1 1/4" hydril 13:00 - 13:30 0.50 CLEAN P COMP LID Schlumberger CCLlgr tool. 13:30 - 17:40 4.17 CLEAN P COMP TIH wI 1 1/4" hydril 17:40 - 18:15 0.58 CLEAN P COMP P/U 2 jts hydril. Notice traveling blocks not falling properly with just one jt hanging. 18:15 -19:00 0.75 CLEAN P COMP Check and grease crown block and traveling block. Crew change out. 19:00 - 19:30 0.50 CLEAN P COMP Tech Limit meeting. 19:30 - 20:00 0.50 CLEAN P COMP P/U MHA and stab-on well. 20:00 - 21 :20 1.33 CLEAN P COMP RIH with mill pumping at 0.9 bpm. Check wt at 9000' 28k. RIH tagged at 9244'. 21 :20 - 22:00 0.67 CLEAN N DFAL COMP Start drilling cement. 1.45 bpm 2285 psi free-spin. Motor stalling soon after starting. P/U off bottom several times. Motor appears to have partially plugged off, can only pump at 0.7 bpm @ 3800 psi. 22:00 - 23:45 1.75 CLEAN N DFAL COMP TOH to hydril. P/U injector and drop .625" ball. Restab inj. pump 7.9 bbls and open circ sub. Pump 10 min to possibly flush out anything.. Break off and stand back injector. Printed: 1/6/2003 2:56:13 PM ) ) BP EXPLORATION Operations Summary Report Page 2 of 7 Legal Well Name: Common Well Name: Eve nt Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION Start: 1/1/2003 Rig Release: Rig Number: Spud Date: 10/31/2002 End: 1/5/2003 Date From - To Hours Task Code NPT Phase Description· of Operations 1217/2002 23:45 - 00:00 0.25 CLEAN N DFAL COMP Stand back hydril tubing. 12/8/2002 00:00 - 00:45 0.75 CLEAN N DFAL COMP Continue to stand back 1 1/4" hydril tubing 00:45 - 01 :45 1.00 CLEAN N RREP COMP One of the crown sheaves has returned to making noise. Appears to be locking up while raising the blocks. Re-grease again. Nope sheave is definitely locking up. Secure BHA. 64 stds of 1 1/4" hydril still in the well. Annulus is full. Cemented liner and no open perfs. 01:45 - 02:10 0.42 CLEAN N RREP COMP PJSM. Currently the blocks are strung with 8 lines. Plan is to re-string the blocks to 6 lines bypassing the locked sheave. Review procedures. Will regroup as needed to review "next step" items throughout the job. 02:10 - 11 :20 9.17 CLEAN N RREP COMP Secure traveling blocks remove bales, remove drawwork guards, remove weight indicators.. Unstring blocks. Wait on new drill line. Re-string blocks with 6 lines. 11 :20 - 13:20 2.00 CLEAN N DFAL COMP Continue TOH stand back hydril. Found TFA on paraboilic mill 90% plugged off from the outside with soft (magnetic) mallible steel. 13:20 -14:25 1.08 CLEAN N DFAL COMP Stab back on well open-ended, close swab valve. Pump 10 bbls hi-vis pill and flush coil. Stab off well. 14:25 - 18:15 3.83 CLEAN N DFAL COMP P/U new motor. RIH wi 20 stds and a single of 1 1/4" hydril. 18:15-18:45 0.50 CLEAN N DFAL COMP Crew change. TL meeting review plan forward. 18:45 - 17:35 22.83 CLEAN N DFAL COMP Stab on injector. RIH (decided to RIH with reduced amount of 1 1/4" CSH to see if we can get through whatever is on top liner. Either cement and or junk.) 17:35 - 21 :00 3.42 CLEAN N DFAL COMP TIH. At 9230' pick wt. 35k dwn 21 k @ 1.6 bpm free-spin 1540 psi. RIH tag at 9236. 21 :00 - 23:30 2.50 CLEAN N COMP At 9240' CTD setdown and stalled. P/U start time milling at 9239.6' -.8 frequent stalls. 1800 psi @ 1.7 bpm. Continue time milling. Not much luck. Continued stalling. Last stall has resulted in high pressures while pumping <1 bpm. May have plugged the mill like before. Unable to discharge obstruction with high pressures. Talk to town team. Decision to move-off well. 23:30 - 00:00 0.50 CLEAN N COMP TOH 12/9/2002 00:00 - 00:45 0.75 CLEAN N DPRB COMP Continue TOH to the hydril tubing. 00:45 - 03:00 2.25 CLEAN N DPRB COMP Drop .625" ball and open circ sub. LID 24 jts 1 1/4" rental hydril. Standback remainder. LID motor. Same debris wedged into nozzle area of mill. 03:00 - 05:00 2.00 PERF N DPRB COMP P/U nozzle. RIH to 2000' and lay-in methanol 1 :1 05:00 - 05:30 0.50 PERF N DPRB COMP Stand back injector. Install BPV. Close Master and Swab valves. 05:30 - 10:30 5.00 DEMOB N DPRB COMP Clean mud tanks. Set BPV. Blow down BOP stack and nipple down. Tree cap installed and tested to 3500 psi. Rig Released at 10:30 hrs 12-9-200 Prep to move to M-09 1/1/2003 00:00 - 01 :00 1.00 DEMOB P COMP General RD on V-03. CHk moving system 01 :00 - 01 :30 0.50 DEMOB P COMP Jack up rig, move off well to end of Pad 01 :30 - 01 :45 0.25 DEMOB P COMP Safety mtg re: rigmovelsupport personnel 01 :45 - 04:30 2.75 MOB P COMP Head down V Pad access road to W Pad 04:30 - 06:00 1.50 MOB P PRE Turn off Spine Road onto W Pad access road. Position in front of well. Safety mtg re: move over well 06:00 - 08:00 2.00 MOB P ,PRE Spot rig over well, begin nippling down tree cap. Accept rig at I Printed: 1/6/2003 2: 56: 13 PM ) ') BPEXPLORA TION Operations Summary Report Page 3 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION Start: 1/1/2003 Rig Release: Rig Number: Spud Date: 10/31/2002 End: 1/5/2003 Date From - To Hours Task Code NPT Phase Descri ptiOn . of· Operations 1/1/2003 06:00 - 08:00 2.00 MOB P PRE 06:30 hrs. NU BOPE 08:00 - 15:50 7.83 MOB N WAIT PRE Waiting on DSM berm crew to rig down cuttings box and dike on W pad and transport to V pad. Need to have in place prior to starting BOP test. Notified State of Alaska, AOGCC of extimated timing on start of BOP test. 15:50 - 21 :00 5.17 BOPSUB P COMP BOP pressure test. Witness waived by AOGCC, John Crisp. 21 :00 - 22:15 1.25 EVAL P COMP Check well for pressure-bleed off 20 psi air. Install transducers IA40,OAO Load extra CSH in pipeshed and strap. Work to thaw frozen harline to flowback tank 22:15 - 23:15 1.00 EVAL P COMP Cut off 17.5' CT. Install DS CTC. PT 35k 23: 15 - 00:00 0.75 EVAL P COMP Fill CT wi KCI wi biozan. Pump wiper dart. Hit at 58 bbls (bio). PT inner reel valve @ 3500 psi 1/2/2003 00:00 - 01 :30 1.50 EVAL N HMAN COMP Fin thaw hardline to flowback tank. FP wi MeOH WO SWS GR/CCL (one man, two jobs-Nordic 2 logging also) 01 :30 - 02: 15 0.75 EVAL P COMP MU 2.80" mill on 2.125" motor. MU SWS GR/CCL, MHA 02: 15 - 04:50 2.58 EVAL P COMP MU 55 stds CSH workstring. PU 40 CSH singles. Kick drill 04:50 - 05:50 1.00 EVAL P COMP RIH wi CT 0.5/480 taking returns to slop tank 05:50 - 06:45 0.92 EVAL N WAIT COMP Park at 9000', CBU. WO SWS engr to return to set up SWS counter. H2S alarm at 11 ppm (from seawater in wellbore), divert to flowback tank. Circ 0.6/690 06:45 - 09: 1 0 2.42 EVAL P COMP Log down from 9000' to TD at 13910' at 60 fpm. Pumping KCL down coil @ 0.5 bpm, taking returns to tiger tank. Set down at 13718'. PU clean @ 47 klbs. Repeat set down. Note pumping 0.5 bpm, below any significant motor horsepower production. PU, kick on pumps to 1.5 bpm. RIH slow. Made it thru obstruction. Suspect cement stringer. RIH milling occasionally stringers until tag up hard at 13845'. Can't mill thru it. This depth is 70' deeper than deepest perf depth. Contact town. Abort further clean out. 09:10 -10:50 1.67 EVAL P COMP Log up from 13845' at 60 fpm. Pumping at 0.8 bpm. Pulling at 80% to clean hole. Paint flags at 13741' (9000' EOP), 11741' (7000' EOP), 10741' (6000' EOP). All depths are CTM. Pulled clean in 3-1/2" liner. No overpulls or problems. 10:50 - 11 :00 0.17 EVAL P COMP Swap to flopro perf pill. Pump 5 bbls. Drop 5/8" ball to open circ sub. Chase with remainer of 25 bbls of pill. Follow gel with 2% KCL. 11:00 -12:00 1.00 EVAL P COMP RIH to lay in perf pill. Coil + CSH vol=65.5 bbls. Did not observe ball land on seat. 12:00 - 13:20 1.33 EVAL P COMP POH laying in mud at 0.6 bpm. 13:20 - 13:30 0.17 EVAL P COMP Check for ball. Did not find the ball in ball drop. Resume pumping at 1.8 bpm, 3800 psi. Do not hear ball rolling. 13:30 - 14:05 0.58 EVAL P COMP POH, continuing to pump at 1.8 bpm. Tag up at surface, after pumping another 65 bbls. Did not observe ball go on seat. Will check with BHA at surface. 14:05 - 14:20 0.25 EVAL P COMP Stand back injector. 14:20 - 14:35 0.25 EVAL P COMP Safety meeing re tripping pipe. Discuss hazards and mitigation; falling objects, working underloads, wet pipe, cold weather for derrick hand, missing circ ball. 14:35 - 15:30 0.92 EVAL P COMP Pull 1 stand. Pulled wet. Stop and drop a 2nd 5/8" ball. Pump on seat. Shear circ sub with 2200 psi (Expected 2800 psi). Good indication of shear. Printed: 1/6/2003 2:56:13 PM ) ) BP EXPLORATION Q,perations Summary Report Page 4 of? Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION Start: 1/1/2003 Rig Release: Rig Number: Spud Date: 10/31/2002 End: 1/5/2003 Date From - To Hours Task ·Code NPT Phase Description of Operations 1/2/2003 15:30 - 17:00 1.50 EVAL P COMP Stand back 1-1/4" CSH work string. 75 stds, 4700' of pipe. 17:00-17:10 0.17 EVAL P COMP Tool box talk with SWS memory hand about rigging down his logging tool. Note - No radioactive sources present. 17:10 -17:30 0.33 EVAL P COMP Lay down Baker MHA and SWS tools. Only one 5/8" ball found in the circ sub. Stil 1 missing circ sub in coil. No SWS data-tool quit after 2 hrs in hole 17:30 - 18:40 1.17 EVAL P COMP Rig up and pressure test liner lap for 30 minutes to 2500 psi surface pressure. Crew change. Lost 50 psi in 45 min. Bleed off press 18:40 - 19:40 1.00 EVAL P COMP Look for missing ball-nope. Then, pump wiper dart thru CT. Ball hit at 50 bbls. Dart hit at 58.0 bbls. Recover wiper and ball 19:40 - 20:00 0.33 EVAL N DFAL COMP MU SWS memory GR/CCL flowthru carrier/nozzle 20:00 - 21 :50 1.83 EVAL N DFAL COMP MU 75 stds CSH workstring 21 :50 - 22:40 0.83 EVAL N DFAL COMP RIH w/ GR/CCL tool on CT 22:40 - 00:00 1.33 EVAL N DFAL COMP Begin logging down at 60'/min from 9000'. Log down to tag at 13848.6' 1/3/2003 00:00 - 01 :30 1.50 EVAL N DFAL COMP Log up from 13848.6' at 60'/min 44.4k leaving fresh mud in liner. Paint flags at 11730' (7000' EOP) and 10730' (6000' EOP)-repainted over prior flags (on depth) 01:30-02:10 0.67 EVAL N DFAL COMP POOH w/ CT 02: 10 - 05:20 3.17 EVAL N DFAL COMP Standback 75 stds-wet before and after opening circ sub 05:20 - 05:50 0.50 EVAL N DFAL COMP LD GR/CCL-have data 05:50 - 06: 15 0.42 EVAL P COMP Crew change/safety mtg 06: 15 - 08:55 2.67 EVAL P COMP RIH w/ 20 stds CSH. POOH LDDP 08:55 - 09:20 0.42 EVAL P COMP Safety meeting prior to picking up perf guns. Attended by SWS perforators, rig Nordic and SWS hands, TP, Co Man. Discuss BHA - Remove Baker Circ Sub, kick safety, safety joint, crossovers needed for SWS guns, potential for lost returns after perforating, lifting, overhead loads, SWS perf SOP, hazards and mitigation. 09:20 - 09:35 0.25 PERF P COMP Make up safety joint. 09:35 -12:10 2.58 PERF P COMP Pick up perf gun string #1, consisting of gun strings 1A and 1 B. String 1A will perforate the following intervals with 2" guns at 4 SPF; 12,900'-13165' 13220'-13370' 13540'-13770' 12:10 -14:00 1.83 PERF P COMP String 1 B will perforate the following intervals with 2.5" guns at 4 spf; 11860'-12140' 12245'-12450' Make up 55 stands, 110 joints of Nordic 1-1/4" CSH work string. Make up upper BHA, stab on injector. RIH with perf guns 1A and 1 B on coil tubing. Stop at first flag. 10934.1' ELM (Found at 10934.7'). Stop at second flag. Found second flag on depth at 11934' ELM. Continue RIH saw bobbles on weight at last tag of 13846', but fell thru to top of landing collar at 13910'. Note - gun OD is 2", last run OD was 14:00 - 14:30 14:30 - 16:00 0.50 PERF P 1.50 PERF P COMP COMP Printed: 1/6/2003 2:56:13 PM ) ) BP EXPLORA TIQN Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION Start: 1/1/2003 Rig Release: Rig Number: Spud Date: 10/31/2002 End: 1/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1/3/2003 14:30 - 16:00 1.50 PERF P COMP larger and probably tagged up on cement stringer that was being milled. Will use ELM flags as reference, which were exactly on depth. 16:00 - 16:15 0.25 PERF P COMP Tool box talk discussing procedure for cycling pressure to fire HDF firing head. 16:15 - 16:25 0.17 PERF P COMP Position gun at firing depth. Cycle WHP to 2000 psi, hold 2 minutes to fire HDF firing head. Standby to monitor shot detection box. Confirmed fire of gun 1A, bottom 3 intervals, depths as per proceedure. 16:25 - 17:45 1.33 PERF P COMP Pull up hole. Clean at 51 klbs. Pull up to 12900' as per proceedure. Standby. Well is on screaming vac. Puming 1.5 bpm, no returns. Can't pump at higher rate thru firing head. Call town to discuss. After 30 minutes/45 bbls got some returns back. 1.5/0.5 pump pressure is 1800 psi. Pump high vis flow pro pill to attempt to slow it down some more. After 75 bbls away, 1.5 in, 0.7 out. 17:45 - 18:25 0.67 PERF P COMP Town confirms that it is ok to perf well despite the fluid losses. RIH to next perf depth. No problems or weight bobbles seen. Position at ball drop depth, 10' below shoot depth. Pump 5 bbls flopro hi vis pill. Drop 5/8" ball to fire guns. Confirm ball rolling. Pull up to firing depth. Chase with 10 more bbls of flo pro followed by KCL. Returns still 65%. Pumping 2.2/1.5. Ball on seat at 58.1 bbls away (Total coil + CSH vol=63.5 bbls). Good indication of fire at 3000 psi ctp. 18:25 - 19:35 1.17 PERF P COMP Shot intervals in gun 1 B. POH. Pumping at 1.5 bpm, 0 returns. Switch to pumping accross the top to keep the well full. 19:35 - 20:05 0.50 PERF P COMP Park at 4000', wo additional KCI water. Continue fill over top wI charge pump. Losing 52 bph static-cuss 'n discuss next perf run wI town and still want to shoot. . . 20:05 - 20:50 0.75 PERF P COMP Resume POH 28k. Filling pits wI 2% KCI. 20:50 - 21 :30 0.67 PERF P COMP OOH. Fin fill pits-PVT 335. Blow CT back wI air. RU to pull CSH Safety mtg re: CSH 21 :30 - 22:55 1.42 PERF P COMP Standback 55 stds CSH workstring 22:55 - 23:45 0.83 PERF P COMP PVT 273 RU to pull perf guns Safety mtg re: perf guns 23:45 - 00:00 0.25 PERF P COMP PVT 243 LD spent perf guns 1/4/2003 00:00 - 03:10 3.17 PERF P COMP PVT 238 LD spent perf guns, all shots fired 03:10 - 03:50 0.67 PERF P COMP PVT 138 Load out guns 03:50 - 04:05 0.25 PERF P COMP Safety mtg re: perf guns 04:05 - 06:00 1.92 PERF P COMP PVT 108 MU 49 2-1/2" SWS perf guns and blanks. Fill pits wI 2%KCI 06:00 - 06: 15 0.25 PERF P COMP PVT 340 Crew chglsafety mtg 06: 15 - 06:45 0.50 PERF P COMP Fin run perf guns for gun string #2. 06:45 - 07:40 0.92 I PERF P String #2 will perforate the foiling intervals with 2.5" guns at 4 spf. 10800'-11110' 11180'-11315' 11410'-11825' Run 30 stands 1-1/4" CS hydrill work string. Total BHA length = 2921.03'. COMP Printed: 1/6/2003 2:56:13 PM ) ) EXPLORATION Operations Summary· Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION Task Code NPT Phase 1/4/2003 07:40 - 08:05 08:05 - 09:35 0.42 PERF P 1.50 PERF P COMP COMP 09:35 - 10:20 0.75 PERF P COMP 10:20 - 11 :45 1.42 PERF P COMP 11 :45 - 12:00 0.25 PERF P COMP 12:00 - 12:15 0.25 PERF P COMP 12:15 -13:00 0.75 PERF P COMP 13:00 -17:15 4.25 PERF N WAIT COMP 17:15 -17:30 0.25 PERF N DFAL COMP 17:30 - 18:00 0.50 PERF N DFAL COMP 18:00 - 18:35 0.58 PERF N COMP 18:35 - 20:30 1.92 PERF N COMP 20:30 - 21:40 1.17 PERF N COMP 21 :40 - 22:10 0.50 PERF N COMP Start: 1/1/2003 Rig Release: Rig Number: Spud Date: 10/31/2002 End: 1/5/2003 Description of Operations Make up injector. RIH, Well continuing to take fluid. IAP=7 psi, OAP=145 psi. Found first flag at 8921.2', (Should be 8919', based on 6000' EOP, BHA length, and -2' Memory GR-CCL correction). Make -2.2' correction to get on depth with ELM log. Continue RIH. Check flag at 9919' (7000' EOP plus corrections), Found it right on depth. Continue RIH. RIH 30' past firing depth. Pull up to ball drop depth. Pump 5 bbls flopro mud. Drop 5/8" ball to fire perf guns. Pull up into firing depth. Chase with 10 additional bbls of mud, then KCL. Pumping at 2.3 bpm in, 1.4 bpm out. Losing 1 bpm, 60 bbls/hr. Ball on seat at 56.1 bbls away. (Coil + CSH vol=61.0 bbls). Got poor indication of fire at 1500 psi. Should have been 2500 psi over. Not a positive indication of guns firing. Tried pumping at 2.3 bpm, could pump easily. Ball seat in gun firing head may have shifted as normal, as we are able to pump. POOH, pumping accross the top. Pit vol at 8500=253 bbls. Pit vol at tag up = 165 bbls. Lost 41 bbls while POH in addition to pipe volume. Stand back injector. Continuing to circulate accross the top of the well to replace lost fluid. Well taking fluid at consistent rate to last perf run. About 30 bbls/hr. Safety meeting prior to trip out with CS hydril. Stand back CS hydril work string. (30 stands, 60 joints). Problem during tripping CSH out of hole. Found tool joint backed off in CSH string. Left fish in the hole. Fish consists of all perforating guns, 6 stands and a single (13 joints) of 1-1/4" CS hydril pipe. Perforating guns are probably not fired, but do have the firing ball on seat in the firing head. There is no indication of damage to pin of recovered bottom joint. Assume that the pipe has backed off, and we do not have a split box. Call for fishing tools from Baker fishing. Call for 50 joints of rental 1-1/4" CS hydril pipe. Wait on equipment. and personnel. Equipment and personnel on location. Hold safety meeting prior to picking up fishing tools. Discuss BHA, drift Baker rental pipe, fishing stratagy, need to check all connections when TIH, ball on seat in perf guns, well taking fluid, lifting, overhead loads, hazards and mitigation. Make up CSH work string. Pick up 12 singles of Baker rental 1-1/4" CSH. Well still taking fluid at 30 bbl/hr. Continuing to flow accross the top. Round tripping vac trucks with 2% KC:L Crew change and pre task safety meeting. MU 48 stds CSH RIH w/ fishing assy (1-1/4 CSH pin on BOT fishing motor) BHA #8 PVT 248 Found first flag at 9390.5', corr to 9389.6', repaint. 0.6/530 RIH 10300' 35.8k, 20.5k 0.6/550,0.7/670,1.0/1270 RIH looking forTOF 0.7/0.3/670 and tagged at 10366.5'. Screwed into CSH box on top of fish on first try. PUH w/4k extra string wt (39.4k). RIH w/ 3k wt loss. Postion guns on depth and pressure up. Ball seat sheared at 3700 psi. Well Printed: 1/6/2003 2: 56: 13 PM ) ') BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-32 W-32 COMPLETION Start: 1/1/2003 Rig Release: Rig Number: Spud Date: 10/31/2002 End: 1/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1/4/2003 21 :40 - 22:10 0.50 PERF N CaMP went on immediate vac 22:10 - 23:50 1.67 PERF N CaMP POOH slow the first 300' while sync CT rate with fill over the top rate. POOH losing 60 bph over CT displ. See definite wt loss as guns pulled out of 3-1/2" liner into 4-1/2" 23:50 - 00:00 0.17 PERF N CaMP At surface w/ CT and have extra wt. Blow back CT w/ air. Fill pits and resume fill over the top losing 60 bph. Phz 1 1/5/2003 00:00 - 02:00 2.00 PERF N DFAL CaMP Standback 48 stds CSH workstring (wet). Fin fill pits w/ 2% KCI while fill over the top losing 60 bph. LD 12 singles 02:00 - 02:15 0.25 PERF N CaMP LD fishing BHA. Fishing CSH pin was made up tite to box of fish without cross threading. Assume that on the prior perf run that the bigger (than normal) guns acted like a 'string shot' and loosened connection resulting in a back-off 02:15-02:45 0.50 PERF P CaMP LD single. Standback 6 stds CSH 02:45 - 03:00 0.25 PERF P CaMP Safety mtg re: perf guns 03:00 - 05:30 2.50 PERF P CaMP LD BOT MHA, load out tools. LD perf guns-all shots fired. Lost avg 60 bph after perforating second run 05:30 - 06:45 1.25 PERF P CaMP Load out perf guns and tools 06:45 - 07:30 0.75 RIGD P CaMP Well still on a significant vac. Swap to methanol. Bullhead/fill the well with methanol to FP. 07:30 - 08: 15 0.75 RIGD P CaMP Blow down reel with N2 for transportation to D pad. 08:15 - 09:30 1.25 RIGD P CaMP Clean pits, Nipple down BOP stack, NU tree cap. PT cap to 5000 psi. Cap pressure test completed at 09:30. RIG RELEASED AT 09:30 09:30 - 12:00 2.50 RIGD P CaMP Continue with rig down. Scope down derrick. Load up rental CSH pipe, send back to API yard for inspection. 12:00 - 12:15 0.25 RIGD P CaMP Safety meeting prior to moving rig off well. 12:15-13:00 0.75 MOB P PRE Move rig off of well W-32. Position rig for move to D-30. Standby for safety meeting prior to rig move. 13:00 - 13:45 0.75 MOB P PRE Safety mtg w/ support personnel 13:45 - 18:00 4.25 MOB P PRE Move off W Pad and head to D Pad 18:00 - 21 :30 3.50 MOB P PRE Cross Kuparuk River bridge/crew change 21 :30 - 00:00 2.50 MOB P PRE Off Spine onto G Pad access roads and head across G Pad Printed: 1/6/2003 2:56: 13 PM Well: Field: API: Permit: Date ) ) 10/31/02 11/10/02 11/29/02 Doyon 14 12/20/02 PULLED LOWER BALL AND ROD 50" LONG, MISSING UPPER 22" OF PRONG. ATTEMPTING TO CLEAN UP TTP TO PULL - RUN SEVERAL LIB'S 3.60" TO 2.50", JOB IN PROGRESS. W -32A Prudhoe Bay Unit 50-029-21970-01 202-209 Accept: Spud: Release: Rig: 12/21/02 PULL RHC PLUG. MILLED PIECE OF FISHING NECK IN PLUG. MISSING 17" OF 3/4" PRONG DRIFT WI 3.62" CENT WI 2.65" LIB TO 9253'. DRIFT 4 1/2" TUBING TO 3.5" TUBING STUCK. TAP UP. POOH. NO IMPRESSION ON LIB. RAN 4 1/2 SLlPSTOP CATCHER. PULLED TOP 2 STATIONS. STA 6...1 1/2 DGLV, RK. STA 5 1 1/2 RP SHEAR VLV, RK. SET STA 5. OGLV, RK, 5/16 DUAL CHECK ORIFICE. SET STA 6. LGLV, RK 1500 TRO - GENERIC. PULL CATCHER. DRIFT WI 2.76 SWAGE & SB TO SIT DOWN AND WORK PAST 9266',9321 TO 9801' SLM, TAP PULL BIND 500# OVER TO SUCK OUT OFF, SAMPLE OF FINE METAL SHAVINGSI ASPHAL. POST RIG WORK ., ) o¿1:9ao 9 10-Dec-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well W-32A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,370.21 ' MD Window / Kickoff Survey 12,400.00' MD (if applicable) Projected Survey: 13,950.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) t~. ~':;" (::~ E:, r\l t:' C' E(:~ 11:5 ~~.~. "';~. :~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA WPad W-32A ~' Job No. AKZZ22176, Surveyed: 26 November, 2002 Survey Report 9 December, 2002 Your Ref: API 500292197001 Surface Coordinates: 5959517.88 N. 611789.05 E (70017' 54.0882" N. 149005'40.8453" W) Grid Coordinate System: NAD27 Alaska State Planes. Zone 4 ~ Surface Coordinates relative to Project H Reference: 959517.88 N. 111789.05 E (Grid) Surface Coordinates relative to Structure Reference: 2295.58 N, 1908.00 E (True) Kelly Bushing: 88.06ft above Mean Sea Level Elevation relative to Project V Reference: 88.06ft Elevation relative to Structure Reference: 88.06ft 5pE!I'I'Y-5Uf1 DRILLING seRVices A Halliburton Company Survey Ref: svy11389 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A Your Ref: AP/S00292197001 Job No. AKZZ22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12370.21 86.340 168.030 8858.77 8946.83 1386.54 N 862.97 W 5960891.44 N 610905.55 E -1425.38 Tie On Point _ 12400.00 86.890 168.770 8860.53 8948.59 - 1357.41 N 856.99 W 5960862.40 N 610911.96 E 3.092 -1396.00 Window Point 12420.81 84.860 168.980 8862.02 8950.08 1337.05 N 852.99 W 5960842.10 N 610916.27 E 9.807 -1375.47 12439.58 84.270 168.740 8863.80 8951.86 1318.72 N 849.38 W 5960823.82 N 610920.15 E 3.391 -1356.99 12466.4 7 84.200 167.930 8866.50 8954.56 1292.51 N 843.97 W 5960797.70 N 610925.95 E 3.008 -1330.56 12493.73 85.310 166.860 8869.00 8957.06 1266.02 N 838.04 W 5960771.30 N 610932.27 E 5.644 -1303.82 ~ 12518.05 84.950 165.220 8871.06 8959.12 1242.51 N 832.20 W 5960747.88 N 610938.46 E 6.880 -1280.06 12532.24 83.970 163.600 8872.43 8960.49 1228.90 N 828.40 W 5960734.33 N 610942.46 E 13.297 -1266.29 12563.95 86.740 164.070 8875.00 8963.06 1198.55 N 819.60 W 5960704.11 N 610951.71 E 8.859 -1235.56 12596.37 89.350 162.920 8876.10 8964.16 1167.49 N 810.40 W 5960673.19 N 610961.37 E 8.796 -1204.10 12627.89 87.200 162.790 8877.05 8965.11 1137.38 N 801.11 W 5960643.23 N 610971.11 E 6.834 -1173.60 12659.87 88.580 162.040 8878.23 8966.29 1106.92 N 791.46 W 5960612.91 N 610981.21 E 4.911 -1142.72 12691.81 90.520 159.980 8878.48 8966.54 1076.72 N 781.06 W 5960582.87 N 610992.06 E 8.859 -1112.07 12724.76 91.080 158.790 8878.02 8966.08 1045.89 N 769.46 W 5960552.21 N 611004.11 E 3.991 -1080.72 12754.82 90.650 158.390 8877.57 8965.63 1017.90 N 758.49 W 5960524.39 N 611015.50E 1.954 -1052.26 12787.60 89.410 157.370 8877.55 8965.61 987.54 N 746.15 W 5960494.21 N 611028.29 E 4.898 -1021.35 12819.96 89.380 157.320 8877.89 8965.95 957.68 N 733.69 W 5960464.54 N 611041.20 E 0.180 -990.93 12849.79 88.770 156.1 00 8878.37 8966.43 930.28 N 721.89 W 5960437.32 N 611053.40 E 4.572 -963.02 12883.92 91.080 159.140 8878.42 8966.48 898.73 N 708.90 W 5960405.97 N 611066.86 E 11 . 186 -930.89 12915.67 91.320 158.020 8877.75 8965.81 869.18 N 697.31 W 5960376.59 N 611078.89 E 3.607 -900.83 12947.24 90.620 158.000 8877.22 8965.28 839.91 N 685.49 W 5960347.50 N 611091.14 E 2.218 -871.04 12980.78 90.120 157.760 8877.00 8965.06 808.84 N 672.86 W 5960316.62 N 611104.23 E 1.654 -839.42 13011.54 89.480 156.540 8877.11 8965.17 780.49 N 660.92 W 5960288.46 N 611116.60 E 4.479 -810.54 13044.04 87.470 156.170 8877.97 8966.03 750.73 N 647.89 W 5960258.90 N 611130.07 E 6.288 -780.21 ~' 13076.4 7 87.940 157.120 8879.27 8967.33 720.99 N 635.04 W 5960229.34 N 611143.35 E 3.266 -749.89 13108.24 87.820 156.780 8880.45 8968.51 691.77 N 622.61 W 5960200.32 N 611156.22 E 1.134 -720.13 13139.53 88.650 157.710 8881.41 8969.47 662.93 N 610.51 W 5960171.66 N 611168.74 E 3.983 -690.75 13172.21 89.850 157.360 8881.84 8969.90 632.73 N 598.03 W 5960141.65 N 611181.68 E 3.825 -660.01 13202.34 90.490 157.300 8881.75 8969.81 604.93 N 586.41 W 5960114.03 N 611193.70E 2.133 -631.69 13235.16 90.340 157.240 8881.51 8969.57 574.66 N 573.73 W 5960083.95 N 611206.83 E 0.492 -600.86 13267.64 89.720 156.870 8881.50 8969.56 544.75 N 561.07 W 5960054.23 N 611219.94 E 2.223 -570.39 13299.07 90.060 157.590 8881.56 8969.62 515.77 N 548.91 W 5960025.43 N 611232.53 E 2.533 -540.87 13330.50 89.510 157.030 8881.67 8969.73 486.78 N 536.78 W 5959996.62 N 611245.08 E 2.497 -511.34 13362.83 90.460 157.510 8881.68 8969.74 456.96 N 524.29 W 5959966.99 N 611258.02 E 3.292 -480.97 13393.78 91.450 156.450 8881.17 8969.23 428.48 N 512.19 W 5959938.69 N 611270.54 E 4.686 -451.96 9 December, 2002 - 13:58 Page 20f4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A Your Ref: APlS00292197001 Job No. AKZZ22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13425.72 89.450 152.150 8880.92 8968.98 399.70 N 498.34 W 5959910.13 N 611284.82 E 14.847 -422.57 13459.52 90.000 153.700 8881.08 8969.14 369.61 N 482.96 W 5959880.27 N 611300.64 E 4.866 -391.79 13490.76 90.460 154.130 8880.95 8969.01 341.55 N 469.22 W 5959852.42 N 611314.80 E 2.016 -363.12 13522.23 92.000 154.830 8880.28 8968.34 313.16N 455.67 W 5959824.23 N 611328.77 E 5.375 -334.12 13554.58 92.670 153.940 8878.96 8967.02 284.01 N 441.70 W 5959795.30 N 611343.18 E 3.442 -304.36 13586.81 93.110 153.840 8877.33 8965.39 255.11 N 427.53 W 5959766.61 N 611357.77 E 1 .400 -274.82 13617.42 94.500 151.990 8875.30 8963.36 227.92 N 413.62 W 5959739.62 N 611372.08 E 7.549 -247.01 13650.94 94.840 154.300 8872.57 8960.63 198.12 N 398.53 W 5959710.05 N 611387.61 E 6.943 -216.53 13682.79 95.110 154.440 8869.81 8957.87 169.51 N 384.81 W 5959681.65 N 611401.76 E 0.954 -187.32 13713.30 95.180 153.960 8867.08 8955.14 142.15 N 371.58 W 5959654.49 N 611415.39 E 1.584 -159.37 13747.07 94.960 155.090 8864.09 8952.15 111.78 N 357.12 W 5959624.34 N 611430.31 E 3.396 -128.36 13778.11 95.820 153.020 8861 .17 8949.23 84.00 N 343.60 W 5959596.76 N 611444.24 E 7.194 -99.97 13810.10 95.640 153.920 8857.98 8946.04 55.52 N 329.38 W 5959568.50 N 611458.88 E 2.855 -70.86 13841.88 95.550 153.970 8854.88 8942.94 27.1 0 N 315.49 W 5959540.29 N 611473.19 E 0.324 -41 .83 13874.55 96.330 154.610 8851.50 8939.56 2.17 S 301.39 W 5959511.23 N 611487.73 E 3.082 -11.92 13950.00 96.330 154.610 8843.18 8931.24 69.92 S 269.24 W 5959443.97 N 611520.88 E 0.000 57.25 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 177.320° (True). Magnetic Declination at Surface is 25.836°(04-Nov-02) -- Based upon Minimum Curvature type calculations, at a Measured Depth of 13950.00ft., The Bottom Hole Displacement is 278.17ft., in the Direction of 255.442° (True). 9 December, 2002 - 13:58 Page 3 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A Your Ref: API 500292197001 Job No. AKZZ22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12370.21 12400.00 13950.00 8946.83 8948.59 8931.24 1386.54 N 1357.41 N 69.92 S 862.97 W 856.99 W 269.24 W Tie On Point Window Point Projected Survey ~~ Survey tool program for W-32A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9635.83 0.00 9635.83 8743.07 13950.00 8743.07 AK-1 BP _HG - BP High Accuracy Gyro(W-32) 8931.24 AK-6 BP _IFR-AK(W-32A PB1) ~. 9 December, 2002 - 13:58 Page 4 0'4 DrillQuest 3.03.02.004 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well W-32A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,370.21' MD Window / Kickoff Survey 12,400.00 I MD (if applicable) Projected Survey: 13,950.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) aZ};; ~ ¿;o 9 10-Dec-02 RECEIV£D DEe 73 200 ß"aS/{;s Ü;f " 2 ~! & Gas Co . ~ Ancf1 tls. !.:o/1]m¡ . Of8ge ððio." Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA W Pad W-32A MWD ~/ Job No. AKMW22176, Surveyed: 28 November, 2002 Survey Report 9 December, 2002 Your Ref: API 500292197001 Surface Coordinates: 5959517.88 N, 611789.05 E (70017' 54.0882" N, 149005'40.8453" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959517.88 N, 111789.05 E (Grid) Surface Coordinates relative to Structure Reference: 2295.58 N, 1908.00 E (True) Kelly Bushing: 88.06ft above Mean Sea Level Elevation relative to Project V Reference: 88.06ft Elevation relative to Structure Reference: 88.06ft spe!r""......y-!5UI! DRILLING SERVices A Halliburton Company Survey Ref: svy11390 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A MWD Your Ref: API 500292197001 Job No. AKMW22176, Surveyed: 28 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12370.21 86.340 167.440 8858.76 8946.82 1397.03 N 877.65 W 5960901.71 N 610890.72 E -1436.54 Tie On Point 12400.00 86.890 168.770 8860.52 8948.58 1367.93 N 871.52 W 5960872.70 N 610897.28 E 4.824 -1407.19 Window Point 12420.81 84.860 169.640 8862.02 8950.08 1347.55 N 867.63 W 5960852.37 N 610901.47 E 10.609 -1386.64 12439.58 84.270 169.230 8863.79 8951.85 1329.18 N 864.21 W 5960834.06 N 610905.17 E 3.822 -1368.13 12466.4 7 84.200 168.390 8866.50 8954.56 1302.93 N 859.01 W 5960807.89 N 610910.75 E 3.119 -1341 .67 12493.73 85.310 170.460 8868.99 8957.05 1276.25 N 854.03 W 5960781.29 N 610916.13 E 8.588 -1314.79 -~--'" 12518.05 84.950 165.220 8871.05 8959.11 1252.57 N 848.93 W 5960757.69 N 610921.58 E 21.519 -1290.89 12532.24 83.970 166.790 8872.42 8960.48 1238.87 N 845.51 W 5960744.03 N 610925.20 E 12.999 -1277.04 12563.95 86.740 163.440 8874.99 8963.05 1208.33 N 837.40 W 5960713.62 N 610933.77 E 13.681 -1246.16 12596.37 89.350 162.870 8876.10 8964.16 1177.32 N 828.01 W 5960682.76 N 610943.62 E 8.240 -1214.75 12627.89 87.200 164.090 8877.05 8965.11 1147.12 N 819.05 W 5960652.69 N 610953.03 E 7.842 -1184.16 12659.87 88.580 161.570 8878.22 8966.28 1116.59 N 809.62 W 5960622.30 N 610962.91 E 8.979 -1153.22 12691.81 90.520 160.120 8878.48 8966.54 1086.42 N 799.14 W 5960592.29 N 610973.84 E 7.583 -1122.60 12724.76 91 .080 159.560 8878.02 8966.08 1055.49 N 787.78 W 5960561.54 N 610985.65 E 2.403 -1091.17 12754.82 90.650 158.900 8877.56 8965.62 1027.39 N 777.12 W 5960533.60 N 610996.73 E 2.620 -1062.60 12787.60 89.410 158.450 8877.54 8965.60 996.85 N 765.20 W 5960503.24 N 611009.10 E 4.024 -1031.54 12819.96 89.380 158.210 8877.89 8965.95 966.78 N 753.25 W 5960473.35 N 611021.50 E 0.747 -1000.94 12849.79 88.770 156.290 8878.37 8966.43 939.28 N 741.72 W 5960446.02 N 611033.44 E 6.753 -972.93 12883.92 91.080 157.300 8878.41 8966.4 7 907.91 N 728.27 W 5960414.86 N 611047.35 E 7.387 -940.97 12915.67 91.320 157.400 8877.75 8965.81 878.62 N 716.05 W 5960385.75 N 611060.01 E 0.819 -911.14 12947.24 90.620 158.510 8877.21 8965.27 849.36 N 704.20 W 5960356.67 N 611072.29 E 4.156 -881.36 12980.78 90.120 158.950 8877.00 8965.06 818.10 N 692.04 W 5960325.60 N 611084.92 E 1.986 -849.57 13011.54 89.480 158.680 8877.10 8965.16 789.42 N 680.92 W 5960297.09 N 611096.46 E 2.258 -820.40 13044.04 87.470 156.150 8877.97 8966.03 759.43 N 668.44 W 5960267.29 N 611109.38 E 9.940 -789.85 -.-.j 13076.4 7 87.940 157.630 8879.27 8967.33 729.63 N 655.73 W 5960237.68 N 611122.54 E 4.785 -759.49 13108.24 87.820 156.930 8880.44 8968.50 700.34 N 643.46 W 5960208.58 N 611135.24 E 2.234 -729.66 13139.53 88.650 158.380 8881.41 8969.47 671.42 N 631.57 W 5960179.83 N 611147.56 E 5.338 -700.21 13172.21 89.850 159.190 8881.83 8969.89 640.95 N 619.75 W 5960149.55 N 611159.83 E 4.430 -669.23 13202.34 90.490 164.900 8881.74 8969.80 612.30 N 610.47 W 5960121.04 N 611169.54 E 19.070 -640.18 13235.16 90.340 157.000 8881.51 8969.57 581.31 N 599.76 W 5960090.20 N 611180.71 E 24.074 -608. 72 13267.64 89.720 157.500 8881 .49 8969.55 551.35 N 587.20 W 5960060.44 N 611193.71 E 2.452 -578.21 13299.07 90.060 157.840 8881.55 8969.61 522.28 N 575.26 W 5960031.55 N 611206.08 E 1.530 -548.61 13330.50 89.510 157.230 8881.67 8969.73 493.24 N 563.25 W 5960002.69 N 611218.52 E 2.613 -519.03 13362.83 90.460 156.820 8881.68 8969.74 463.47 N 550.63 W 5959973.11 N 611231.59 E 3.200 -488.71 13393.78 91.450 155.820 8881.16 8969.22 435.13 N 538.20 W 5959944.96 N 611244.43 E 4.546 -459.82 9 December, 2002 - 14:03 Page 2 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A MWD Your Ref: AP/500292197001 Job No. AKMW22176, Surveyed: 28 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13425.72 89.450 152.310 8880.91 8968.97 406.42 N 524.24 W 5959916.46 N 611258.82 E 12.647 -430.48 13459.52 90.000 151.540 8881.07 8969.13 376.59 N 508.33 W 5959886.87 N 611275.17 E 2.800 -399.95 13490.76 90.460 153.650 8880.95 8969.01 348.86 N 493.95 W 5959859.36 N 611289.96 E 6.913 -371.58 13522.23 92.000 154.500 8880.27 8968.33 320.57 N 480.20 W 5959831.27 N 611304.14 E 5.589 -342.67 13554.58 92.670 153.980 8878.95 8967.01 291.46 N 466.15 W 5959802.37 N 611318.62 E 2.621 -312.93 13586.81 93.110 154.090 8877.33 8965.39 262.52 N 452.06 W 5959773.65 N 611333.14 E 1.407 -283.37 '-~J- 13617.42 94.500 151.600 8875.30 8963.36 235.34 N 438.12 W 5959746.68 N 611347.48 E 9.300 -255.57 13650.94 94.840 154.210 8872.57 8960.63 205.60 N 422.90 W 5959717.17 N 611363.13 E 7.827 -225.15 13682.79 95.110 154.510 8869.80 8957.86 177.00 N 409.17 W 5959688.77 N 611377.29 E 1.265 -195.94 13713.30 95.180 154.620 8867.07 8955.13 149.56 N 396.12 W 5959661.53 N 611390.75 E 0.426 -167.91 13747.07 94.960 155.780 8864.08 8952.14 119.02 N 382.01 W 5959631.21 N 611405.31 E 3.483 -136.75 13778.11 95.820 155.670 8861.17 8949.23 90.85 N 369.31 W 5959603.23 N 611418.43 E 2.793 -108.02 13810.10 95.640 155.030 8857.97 8946.03 61.92 N 356.03 W 5959574.50 N 611432.13 E 2.069 -78.50 13841.88 95.550 154.530 8854.88 8942.94 33.31 N 342.56 W 5959546.09 N 611446.04 E 1.591 -49.29 13874.55 96.330 155.760 8851.50 8939.56 3.82 N 328.90 W 5959516.81 N 611460.13 E 4.441 -19.20 13950.00 96.330 155.760 8843.18 8931.24 64.55 S 298.11 W 5959448.90 N 611491.93 E 0.000 50.55 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 177.320° (True). Magnetic Declination at Surface is 25.836°(04-Nov-02) - Based upon Minimum Curvature type calculations, at a Measured Depth of 13950.000., The Bottom Hole Displacement is 305.02ft., in the Direction of 257.781° (True). 9 December, 2002 - 14:03 Page 3 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU _WOA W Pad - W-32A MWD Your Ref: AP/SO0292197001 Job No. AKMW22176, Surveyed: 28 November, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12370.21 12400.00 13950.00 8946.82 8948.58 8931.24 1397.03 N 1367.93 N 64.55 S 877.65 W 871.52 W 298.11 W Tie On Point Window Point Projected Survey Survey tool program for W-32A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9635.85 0.00 9635.85 8743.08 13950.00 8743.08 AK-1 BP _HG - BP High Accuracy Gyro(W-32) 8931.24 MWD Magnetic(W-32A PB1 MWD) 9 December, 2002 - 14:03 Page 4 of4 Dri/lQuest 3.03.02.004 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) c9 Q:;) - dO Jì 1 0-Dec-02 Re: Distribution of Survey Data for Well W-32A PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,635.85' MD 9,665.00' MD 13,025.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ...1~,\tO ~:çCt;;..' f'1\"n DEe '\ ~ LIJ\;¡" . .. .,",r: ':JJ~\W\.\_n . ,- {;. vCi~ ,;;¡. . Ç¡.'" ".... ~~~.t~\I.~lI,.N ~cl\~aÇß Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA W Pad W-32A PB1 Job No. AKZZ22176, Surveyed: 26 November, 2002 Survey Report 9 December, 2002 Your Ref: API 500292197070 Surface Coordinates: 5959517.88 N, 611789.05 E (70017'54.0882" N, 149005'40.8453" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '-' Surface Coordinates relative to Project H Reference: 959517.88 N, 111789.05 E (Grid) Surface Coordinates relative to Structure Reference: 2295.58 N, 1908.00 E (True) Kelly Bushing: 88.06ft above Mean Sea Level Elevation relative to Project V Reference: 88.06ft Elevation relative to Structure Reference : 88.06ft spe...........y-sufl DRILLING SeRVices A Halliburton Company Survey Ref: svy11387 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A PB1 Your Ref: AP/500292191070 Job No. AKZZ22176 Surveyed: 26 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9635.85 33.770 8.671 8655.02 8743.08 3237.00 N 520.56 W 5962746.78 N 611220.40 E -3257.80 Tie On Point ,. 9665.00 33.990 9.530 8679.23 8767.29 - 3253.05 N 517.99 W 5962762.86 N 611222.73 E 1.808 -3273.71 Window Point 9692.74 33.000 3.080 8702.37 8790.43 3268.24 N 516.30 W 5962778.08 N 611224.19 E 13.313 -3288.81 9723.27 32.170 355.990 8728.10 8816.16 3284.66 N 516.42 W 5962794.50 N 611223.83 E 12.792 -3305.21 9760.17 36.900 341.300 8758.54 8846.60 3305.00 N 520.67 W 5962814.77 N 611219.28 E 25.878 -3325.73 9792.05 39.110 334.620 8783.67 8871.73 3323.16 N 528.05 W 5962832.82 N 611211.63 E 14.638 -3344.21 9820.93 44.470 328.320 8805.21 8893.27 3340.01 N 537.28 W 5962849.54 N 611202.15 E 23.557 -3361.48 9855.69 52.410 322.790 8828.26 8916.32 3361.39 N 552.03 W 5962870.69 N 611187.08 E 25.742 -3383.52 9886.76 58.170 317.700 8845.95 8934.01 3380.98 N 568.38 W 5962890.03 N 611170.44E 22.905 -3403.86 9916.28 60.470 310.490 8861.03 8949.09 3398.61 N 586.60 W 5962907.39 N 611151.95 E 22.398 -3422.32 9949.26 64.300 300.880 8876.34 8964.40 3415.59 N 610.32 W 5962924.02 N 611127.99 E 28.297 -3440.39 9982.31 70.560 294.380 8889.03 8977.09 3429.69 N 637.35 W 5962937.72 N 611100.76 E 26.230 -3455.74 10011.45 76.630 288.290 8897.26 8985.32 3439.83 N 663.37 W 5962947.47 N 611074.59 E 28.902 -3467.09 10046.63 82.970 284.120 8903.49 8991.55 3449.48 N 696.59 W 5962956.62 N 611041.22 E 21.464 -3478.27 10078.88 82.480 279.580 8907.58 8995.64 3456.04 N 727.89 W 5962962.72 N 611009.83 E 14.047 -3486.30 10107.25 83.720 272.500 8910.99 8999.05 3459.00 N 755.88 W 5962965.26 N 610981.80 E 25.157 -3490.56 10142.75 84.980 263.920 8914.49 9002.55 3457.90 N 791.16 W 5962963.63 N 610946.54 E 24.311 -3491.11 10171.38 86.550 258.020 8916.61 9004.67 3453.42 N 819.34 W 5962958.73 N 610918.43 E 21.270 -3487.95 10202.36 89.080 253.560 8917.79 9005.85 3445.82 N 849.34 W 5962950.69 N 610888.54 E 16.541 -3481.76 10237.30 87.020 247.100 8918.98 9007.04 3434.07 N 882.21 W 5962938.45 N 610855.86 E 19.395 -3471.57 10268.05 84.430 240.330 8921.27 9009.33 3420.51 N 909.68 W 5962924.48 N 610828.59 E 23.513 -3459.30 10297.83 83.960 232.150 8924.29 9012.35 3404.06 N 934.29 W 5962907.67 N 610804.22 E 27.372 -3444.02 10330.16 89.020 226.410 8926.27 9014.33 3383.02 N 958.73 W 5962886.27 N 610780.10 E 23.639 -3424.15 10362.97 90.740 216.470 8926.34 9014.40 3358.45 N 980.42 W 5962861.38 N 610758.78 E 30.745 -3400.62 -' 10393.43 94.160 209.110 8925.04 9013.10 3332.89 N 996.88 W 5962835.58 N 610742.70 E 26.621 -3375.86 10427.39 94.070 200.310 8922.59 9010.65 3302.15 N 1011.03W 5962804.63 N 610729.01 E 25.847 -3345.81 10444.81 97.100 196.820 8920.90 9008.96 3285.72 N 1016.55 W 5962788.12 N 610723.74 E 26.458 -3329.66 10476.29 101.560 190.720 8915.79 9003.85 3255.58 N 1023.95 W 5962757.87 N 610716.79 E 23.793 -3299.89 10513.64 102.590 185.680 8907.97 8996.03 3219.44 N 1029.16 W 5962721.66 N 610712.11 E 13.480 -3264.04 10547.29 100.310 183.460 8901.29 8989.35 3186.57 N 1031.78 W 5962688.75 N 610709.98 E 9.365 -3231.33 10575.18 96.680 183.350 8897.17 8985.23 3159.04 N 1033.42 W 5962661.20 N 610708.75 E 13.021 -3203.90 10607.81 98.240 184.440 8892.94 8981.00 3126.76 N 1035.62 W 5962628.89 N 610707.03 E 5.816 -3171.76 10639.95 99.610 182.920 8887.95 8976.01 3095.08 N 1037.66 W 5962597.18 N 610705.47 E 6.324 -3140.21 10670.92 100.420 184.530 8882.56 8970.62 3064.64 N 1039.64 W 5962566.72 N 610703.94 E 5.749 -3109.90 10703.68 100.220 184.610 8876.70 8964.76 3032.52 N 1042.21 W 5962534.56 N 610701.85 E 0.656 -3077.93 9 December, 2002 - 13:55 Page 2 af5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A PB1 Your Ref: APlS00292197070 Job No. AKZZ22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10734.27 101.240 184.570 8871.00 8959.06 3002.56 N 1044.61 W 5962504.57 N 610699.89 E 3.337 -3048.12 10775.22 100.350 183.670 8863.33 8951.39 2962.44 N 1047.50 W 5962464.41 N 610697.60 E 3.063 -3008.18 10815.88 98.210 182.790 8856.77 8944.83 2922.38 N 1049.76 W 5962424.32 N 610695.93 E 5.680 -2968.27 10862.59 98.930 180.640 8849.81 8937.87 2876.21 N 1051.14W 5962378.14 N 610695.24 E 4.805 -2922.22 10911.35 96.940 180.530 8843.08 8931.14 2827.92 N 1051.64 W 5962329.85 N 610695.46 E 4.087 -2874.00 10958.13 95.290 179.830 8838.10 8926.16 2781.41 N 1051.78W 5962283.34 N 610696.01 E 3.828 -2827.55 10991.79 92.960 180.170 8835.68 8923.74 2747.84 N 1051.78W 5962249.78 N 610696.51 E 6.995 -2794.02 11024.18 90.250 180.170 8834.77 8922.83 2715.47 N 1051.88 W 5962217.40 N 610696.89 E 8.367 -2761.68 11054.49 87.880 176.640 8835.27 8923.33 2685.18 N 1051.04 W 5962187.13 N 610698.19 E 14.026 -2731.39 11087.42 88.190 177.230 8836.39 8924.45 2652.32 N 1049.28 W 5962154.30 N 610700.44 E 2.023 -2698.48 11119.86 89.510 174.280 8837.05 8925.11 2619.98 N 1046.88 W 5962122.00 N 610703.32 E 9.961 -2666.06 11149.63 88.890 173.220 8837.46 8925.52 2590.39 N 1043.63 W 5962092.46 N 610707.00 E 4.125 -2636.35 11182.94 89.570 173.700 8837.91 8925.97 2557.30 N 1039.84 W 5962059.43 N 610711.28 E 2.499 -2603.12 11216.73 92.830 169.890 8837.20 8925.26 2523.87 N 1035.02 W 5962026.08 N 610716.60 E 14.837 -2569.51 11248.10 94.160 169.180 8835.29 8923.35 2493.08 N 1029.33 W 5961995.38 N 610722.74 E 4.804 -2538.48 11294.71 95.100 167.960 8831.53 8919.59 2447.55 N 1020.13 W 5961949.98 N 610732.63 E 3.298 -2492.57 11344.01 92.710 167.530 8828.17 8916.23 2399.49 N 1009.69 W 5961902.08 N 610743.78 E 4.925 -2444.07 11375.89 90.250 170.200 8827.35 8915.41 2368.22 N 1003.54 W 5961870.91 N 610750.40 E 11.385 -2412.55 11408.00 90.220 172.320 8827.21 8915.27 2336.49 N 998.66 W 5961839.26 N 610755.75 E 6.603 -2380.63 11439.77 89.910 169.950 8827.18 8915.24 2305.10 N 993.76 W 5961807.94 N 610761.11 E 7.523 -2349.04 11486.59 91.570 171.930 8826.57 8914.63 2258.87 N 986.39 W 5961761.83 N 610769.17 E 5.518 -2302.52 11535.52 94.71 0 172.190 8823.89 8911.95 2210.49 N 979.64 W 5961713.55 N 610776.63 E 6.439 -2253.88 11580.63 93.860 170.220 8820.52 8908.58 2166.04 N 972.76 W 5961669.21 N 610784.17 E 4.745 -2209.15 11632.02 92.040 173.760 8817.88 8905.94 2115.22 N 965.61 W 5961618.51 N 610792.08 E 7.737 -2158.06 11679.61 89.780 175.370 8817.12 8905.18 2067.86 N 961.11 W 5961571.22 N 610797.29 E 5.830 -2110.54 11728.42 90.120 176.470 8817.16 8905.22 2019.17 N 957.64 W 5961522.59 N 610801.48 E 2.359 -2061.74 11775.78 88.490 175.710 8817.74 8905.80 1971.93 N 954.41 W 5961475.40 N 610805.42 E 3.797 -2014.40 11823.91 85.960 175.270 8820.07 8908.13 1924.01 N 950.63 W 5961427.54 N 610809.91 E 5.335 -1966.35 11872.43 86.460 172.780 8823.28 8911.34 1875.86 N 945.59 W 5961379.47 N 610815.66 E 5.223 -1918.02 11919.40 88.000 172.920 8825.55 8913.61 1829.31 N 939.75 W 5961333.01 N 610822.19 E 3.292 -1871.25 11967.37 88.130 169.770 8827.17 8915.23 1781.92 N 932.53 W 5961285.74 N 610830.11 E 6.568 -1823.58 12015.24 85.490 171.640 8829.83 8917.89 1734.76 N 924.81 W 5961238.69 N 610838.53 E 6.755 -1776.10 12048.63 85.060 170.530 8832.58 8920.64 1701.89 N 919.66 W 5961205.90 N 610844.18E 3.555 -1743.03 12081 . 1 8 85.570 171.040 8835.24 8923.30 1669.86 N 914.46 W 5961173.96 N 610849.85 E 2.212 -1710.80 12110.47 86.930 170.430 8837.15 8925.21 1641.02N 909.76 W 5961145.19 N 610854.98 E 5.087 -1681.76 9 December, 2002 - 13:55 Page 3 0'5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A PB1 Your Ref: AP/500292197070 Job No. AKZZ22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 12148.74 86.610 170.270 8839.31 8927.37 1603.35 N 903.35 W 5961107.62 N 610861.95 E 0.935 -1643.84 12180.62 86.770 169.500 8841.15 8929.21 1572.02 N 897.76 W 5961076.37 N 610868.00 E 2.463 -1612.28 12212.23 84.220 170.500 8843.63 8931.69 1540.99 N 892.29 W 5961045.43 N 610873.93 E 8.662 -1581.02 12244.52 83.340 170.460 8847.13 8935.19 1509.33 N 886.98 W 5961013.85 N 610879.71 E 2.728 -1549.15 12274.85 84.060 170.660 8850.46 8938.52 1479.59 N 882.04 W 5960984.19 N 610885.10 E 2.463 -1519.22 12307.84 84.450 168.060 8853.76 8941 .82 1447.33 N 875.98 W 5960952.03 N 610891.64 E 7.930 -1486.71 ---- 12339.09 85.400 167.800 8856.53 8944.59 1416.90 N 869.47 W 5960921.69 N 610898.60 E 3.151 -1456.00 12370.21 86.340 168.030 8858.77 8946.83 1386.54 N 862.97 W 5960891.44 N 610905.55 E 3.109 -1425.38 12403.57 86.960 168.860 8860.72 8948.78 1353.92 N 856.30 W 5960858.91 N 610912.71 E 3.102 -1392.47 12434.95 87.720 168.730 8862.17 8950.23 1323.17 N 850.21 W 5960828.26 N 610919.25 E 2.457 -1361.48 12466.10 88.240 167.930 8863.27 8951.33 1292.68 N 843.91 W 5960797.87 N 610926.00 E 3.062 -1330.73 12499.27 88.370 166.940 8864.25 8952.31 1260.32 N 836.70 W 5960765.62 N 610933.70 E 3.009 -1298.06 12561.12 87.480 163.560 8866.49 8954.55 1200.56 N 820.96 W 5960706.10 N 610950.32 E 5.648 -1237.63 12594.05 89.780 163.430 8867.28 8955.34 1169.00 N 811.61 W 5960674.68 N 610960.14 E 6.996 -1205.67 12625.90 91.540 163.190 8866.91 8954.97 1138.49 N 802.47 W 5960644.31 N 610969.74 E 5.577 -1174.77 12658.02 92.800 162.630 8865.70 8953.76 1107.81 N 793.03 W 5960613.78 N 610979.62 E 4.292 -1143.68 12689.80 93.200 161.740 8864.04 8952.10 1077.60 N 783.32 W 5960583.71 N 610989.78 E 3.067 -1113.05 12722.02 92.400 160.880 8862.46 8950.52 1047.11 N 773.01 W 5960553.38 N 611000.55 E 3.643 -1082.11 12753.74 91.940 160.260 8861.26 8949.32 1017.22 N 762.47 W 5960523.65 N 611011.53 E 2.433 -1051.76 12785.33 92.580 160.470 8860.01 8948.07 987.49 N 751.86 W 5960494.08 N 611022.58 E 2.132 -1021.57 12817.48 92.800 160.140 8858.51 8946.57 957.26 N 741.04 W 5960464.01 N 611033.85 E 1.233 -990.86 12849.43 93.480 159.430 8856.76 8944.82 927.32 N 730.02 W 5960434.24 N 611045.32 E 3.075 -960.44 12882.81 92.560 158.860 8855.00 8943.06 896.17 N 718.15 W 5960403.27 N 611057.65 E 3.241 -928.77 12914.03 91.510 158.430 8853.89 8941.95 867.11 N 706.79 W 5960374.39 N 611069.44 E 3.634 -899.21 ~ 12945.00 91.110 158.450 8853.18 8941.24 838.32 N 695.41 W 5960345.76 N 611081.25 E 1.293 -869.92 12980.34 91.200 157.780 8852.47 8940.53 805.53 N 682.24 W 5960313.18 N 611094.90 E 1.913 -836.55 13025.00 91.200 157.780 8851.53 8939.59 764.20 N 665.35 W 5960272.10 N 611112.40 E 0.000 -794.47 Projected Survey 9 December, 2002 - 13:55 Page 4 of5 Dril/Quest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A PB1 Your Ref: AP/500292197070 Job No. AKZZ22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 177.320° (True). Magnetic Declination at Surface is 25.836°(04-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13025.00ft., The Bottom Hole Displacement is 1013.26ft., in the Direction of 318.955° (True). -' Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9635.85 9665.00 13025.00 8743.08 8767.29 8939.59 3237.00 N 3253.05 N 764.20 N 520.56 W 517.99 W 665.35 W Tie On Point Window Point Projected Survey Survey tool program for W-32A PB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) - 0.00 9635.83 0.00 8743.07 9635.83 13025.00 8743.07 AK-1 BP _HG - BP High Accuracy Gyro(W-32) 8939.59 AK-6 BP _IFR-AK(W-32A PB1) 9 December, 2002 - 13:55 Page 5 of5 DrillQuest 3.03.02.004 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~ Dë),~O 9 10-Dec-02 Re: Distribution of Survey Data for Well W-32A PB 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,635.85' MD 9,665.00' MD 13,025.00 I MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) i~;1t ~:~~. if~~ t':. ~ \l f;:" () DEC 13 2002 Alaslœ Ol'! ~ \.:ia5lA1íiS, \.;Qmmission .Mcboqge Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA WPad W-32A PB1 MWD '--..,.' Job No. AKMW22176, Surveyed: 26 November, 2002 Survey Report 9 December, 2002 Your Ref: APlS00292197070 Surface Coordinates: 5959517.88 N, 611789.05 E (700 17' 54.0882" N, 149005' 40.8453" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -, Surface Coordinates relative to Project H Reference: 959517.88 N, 111789.05 E (Grid) Surface Coordinates relative to Structure Reference: 2295.58 N, 1908.00 E (True) Kelly Bushing: 88.06ft above Mean Sea Level Elevation relative to Project V Reference: 88.06ft Elevation relative to Structure Reference: 88.06ft !5pE!r"r'Y-5UI! DRILLING seRVIc:es A Halliburton Company Survey Ref: svy11388 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A PS1 MWD Your Ref: API 500292197070 Job No. AKMW22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9635.85 33.770 8.671 8655.02 8743.08 3237.00 N 520.56 W 5962746.78 N 611220.40 E -3257.80 Tie On Point MWD Magnetic 9665.00 33.990 9.530 8679.23 8767.29 3253.05 N 517.99 W 5962762.86 N 611222.73 E 1.808 -3273.71 Window Point 9692.74 33.000 3.080 8702.37 8790.43 3268.24 N 516.30 W 5962778.08 N 611224.19 E 13.313 -3288.81 9723.27 32.170 355.990 8728.10 8816.16 3284.66 N 516.42 W 5962794.50 N 611223.83 E 12.792 -3305.21 9760.17 36.900 341.710 8758.54 8846.60 3305.02 N 520.59 W 5962814.79 N 611219.35 E 25.336 -3325.75 9792.05 39.110 335.310 8783.67 8871.73 3323.25 N 527.80 W 5962832.92 N 611211.88 E 14.165 -3344.30 9820.93 44.470 328.930 8805.20 8893.26 3340.21 N 536.83 W 5962849.74 N 611202.59 E 23.671 -3361.66 9855.69 52.410 323.380 8828.25 8916.31 3361.74 N 551.36 W 5962871.05 N 611187.74 E 25.762 -3383.84 9886.76 58.170 318.330 8845.95 8934.01 3381.50 N 567.50 W 5962890.57 N 611171.31 E 22.843 -3404.34 9916.28 60.470 310.860 8861.02 8949.08 3399.29 N 585.57 W 5962908.09 N 611152.98E 23.109 -3422.96 9949.26 64.300 302.680 8876.33 8964.39 3416.73 N 608.97 W 5962925.18 N 611129.32 E 24.84 7 -3441.47 9982.31 70.560 295.830 8889.02 8977.08 3431.59 N 635.58 W 5962939.64 N 611102.49 E 26.915 -3457.56 10011.45 76.630 289.020 8897.25 8985.31 3442.22 N 661.40 W 5962949.88 N 611076.52 E 30.592 -3469.38 10046.63 82.970 284.360 8903.48 8991.54 3452.14 N 694.55 W 5962959.31 N 611043.23 E 22.238 -3480.84 10078.88 82.480 280.680 8907.57 8995.63 3459.08 N 725.77 W 5962965.78 N 611011.90 E 11.420 -3489.23 10107.25 83.720 275.160 8910.98 8999.04 3462.95 N 753.65 W 5962969.24 N 610983.97 E 19.804 -3494.41 10142.75 84.980 266.540 8914.48 9002.54 3463.47 N 788.94 W 5962969.24 N 610948.67 E 24.422 -3496.58 10171.38 86.550 261.480 8916.60 9004.66 3460.49 N 817.33 W 5962965.84 N 610920.33 E 18.458 -3494.93 10202.36 89.080 255.710 8917.78 9005.84 3454.38 N 847.66 W 5962959.27 N 610890.10 E 20.323 -3490.23 10237.30 87.020 247.900 8918.97 9007.03 3443.48 N 880.81 W 5962947.88 N 610857.12 E 23.103 -3480.90 10268.05 84.430 241.400 8921.26 9009.32 3430.36 N 908.50 W 5962934.35 N 610829.62 E 22.698 -3469.09 10297.83 83.960 233.680 8924.28 9012.34 3414.48 N 933.48 W 5962918.10 N 610804.88 E 25.838 -3454.39 10330.16 89.020 227.600 8926.26 9014.32 3394.02 N 958.41 W 5962897.27 N 610780.26 E 24.435 -3435.12 _/ 10362.97 90.740 217.390 8926.33 9014.39 3369.86 N 980.54 W 5962872.79 N 610758.49 E 31.556 -3412.03 10393.43 94.160 209.390 8925.03 9013.09 3344.48 N 997.28 W 5962847.16 N 610742.13 E 28.538 -3387.45 10427.39 94.070 200.250 8922.58 9010.64 3313.77 N 1011.48 W 5962816.24 N 610728.39 E 26.846 -3357.44 10444.81 97.100 196.690 8920.89 9008.95 3297.33 N 1016.97 W 5962799.72 N 610723.14 E 26.761 -3341.28 10476.29 101.560 191.510 8915.78 9003.84 3267.22 N 1024.54 W 5962769.51 N 610716.02 E 21.546 -3311.56 10513.64 102.590 186.190 8907.96 8996.02 3231.15 N 1030.16 W 5962733.35 N 610710.94 E 14.198 -3275.78 10547.29 100.310 183.890 8901.28 8989.34 3198.30 N 1033.06 W 5962700.46 N 610708.53 E 9.528 -3243.11 9 December, 2002 - 14:01 Page 2 of 5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PSU_WOA W Pad - W-32A PS1 MWD Your Ref: API 500292197070 Job No. AKMW22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10575.18 96.680 183.670 8897.16 8985.22 3170.78 N 1034.88 W 5962672.92 N 610707.12 E 13.039 -3215.70 10607.81 9ß.240 184.760 8892.93 8980.99 3138.52 N 1037.25 W 5962640.62 N 610705.22 E 5.816 -3183.58 10639.95 99.610 183.340 8887.94 8976.00 3106.85 N 1039.50 W 5962608.92 N 610703.45 E 6.101 -3152.05 10670.92 100.420 185.130 8882.56 8970.62 3076.43 N 1041.75 W 5962578.48 N 610701.65 E 6.264 -3121 .78 10703.68 100.220 184.860 8876.69 8964.75 3044.33 N 1044.55 W 5962546.34 N 610699.33 E 1.015 -3089.84 10734.27 101.240 185.120 8870.99 8959.05 3014.39 N 1047.17 W 5962516.36 N 610697.16 E 3.437 -3060.05 --~,... 10775.22 100.350 183.670 8863.32 8951.38 2974.28 N 1050.25 W 5962476.21 N 610694.67 E 4.101 -3020.13 10815.88 98.210 183.240 8856.76 8944.82 2934.23 N 1052.67 W 5962436.13 N 610692.85 E 5.366 -2980.24 10862.59 98.930 180.940 8849.80 8937.86 2888.07 N 1054.35 W 5962389.95 N 610691.85 E 5.107 -2934.21 10911.35 96.940 181.030 8843.07 8931.13 2839.79 N 1055.18 W 5962341.66 N 610691.74 E 4.085 -2886.02 10958.13 95.290 180.080 8838.09 8926.15 2793.28 N 1055.63 W 5962295.15 N 610691.98 E 4.064 -2839.58 1 0991.79 92.960 180.630 8835.67 8923.73 2759.71 N 1055.84 W 5962261.58 N 610692.27 E 7.111 -2806.06 11024.18 90.250 180.400 8834.76 8922.82 2727.34 N 1056.13 W 5962229.21 N 610692.46 E 8.397 -2773.74 11054.49 87.880 177.030 8835.26 8923.32 2697.05 N 1055.45 W 5962198.93 N 610693.59 E 13.591 -2743.45 11087.42 88.190 177.520 8836.38 8924.44 2664.17 N 1053.89 W 5962166.08 N 610695.65 E 1.760 -2710.54 11119.86 89.510 175.020 8837.04 8925.10 2631.81 N 1051.78 W 5962133.76 N 610698.24 E 8.713 -2678.11 11149.63 88.890 174.490 8837.45 8925.51 2602.17 N 1049.06 W 5962104.16 N 610701.40 E 2.740 -2648.37 11182.94 89.570 174.700 8837.90 8925.96 2569.01 N 1045.92 W 5962071.05 N 610705.03 E 2.137 -2615.11 11216.73 92.830 169.990 8837.19 8925.25 2535.54 N 1041.42 W 5962037.65 N 610710.03 E 16.948 -2581.46 11248.10 94.160 169.950 8835.28 8923.34 2504.71 N 1035.97 W 5962006.91 N 610715.94 E 4.242 -2550.41 11294.71 95.100 168.760 8831.52 8919.58 2459.05 N 1027.39 W 5961961.38 N 610725.20 E 3.247 -2504.40 11344.01 92.710 168.080 8828.16 8916.22 2410.87 N 1017.52 W 5961913.35 N 610735.78 E 5.039 -2455.81 11375.89 90.250 170.460 8827.34 8915.40 2379.57 N 1011.58 W 5961882.14 N 610742.18 E 10.735 -2424.26 11408.00 90.220 173.180 8827.20 8915.26 2347.79 N 1007.01 W 5961850.43 N 610747.22 E 8.471 -2392.30 - 11439.77 89.910 169.950 8827.17 8915.23 2316.36 N 1002.36 W 5961819.08 N 610752.35 E 10.214 -2360.70 11486.59 91.570 172.380 8826.56 8914.62 2270.11 N 995.17 W 5961772.94 N 610760.23 E 6.285 -2314.16 11535.52 94.71 0 172.870 8823.88 8911.94 2221.66 N 988.89 W 5961724.59 N 610767.22 E 6.495 -2265.4 7 11580.63 93.860 171.030 8820.51 8908.57 2177.12 N 982.59 W 5961680.15 N 610774.18 E 4.483 -2220.69 11632.02 92.040 174.490 8817.87 8905.93 2126.22 N 976.13 W 5961629.35 N 610781.40 E 7.599 -2169.54 11679.61 89.780 175.980 8817.11 8905.17 2078.81 N 972.18 W 5961582.00 N 610786.06 E 5.688 -2121.99 11728.42 90.120 176.660 8817.15 8905.21 2030.10 N 969.04 W 5961533.34 N 610789.91 E 1.558 -2073.19 11775.78 88.490 176.150 8817.73 8905.79 1982.83 N 966.08 W 5961486.13 N 610793.59 E 3.606 -2025.84 11823.91 85.960 175.530 8820.06 8908.12 1934.89 N 962.59 W 5961438.24 N 610797.79 E 5.412 -1977.78 11872.43 86.460 172.760 8823.27 8911.33 1886.74 N 957.65 W 5961390.16 N 610803.44 E 5.789 -1929.45 11919.40 88.000 173.530 8825.54 8913.60 1840.16 N 952.05 W 5961343.68 N 610809.73 E 3.665 -1882.66 9 December, 2002 - 14:01 Page 30f5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA W Pad - W-32A PB1 MWD Your Ref: AP/S00292197070 Job No. AKMW22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11967.37 88.130 169.970 8827.16 8915.22 1792.72 N 945.17 W 5961296.34 N 610817.31 E 7.422 -1834.95 12015.24 85.490 172.580 8829.82 8917.88 1745.48 N 937.92 W 5961249.22 N 610825.27 E 7.749 -1787.43 12048.63 85.060 171.220 8832.57 8920.63 1712.54 N 933.23 W 5961216.35 N 610830.44 E 4.259 -1754.30 12081 .18 85.570 171.390 8835.23 8923.29 1680.47 N 928.33 W 5961184.36 N 610835.83 E 1.651 -1722.04 12110.47 86.930 170.280 8837.15 8925.21 1651.62 N 923.67 W 5961155.58 N 610840.91 E 5.988 -1693.00 12148.74 86.610 170.450 8839.30 8927.36 1613.95 N 917.28 W 5961118.01 N 610847.86 E 0.947 -1655.07 _r 12180.62 86.770 169.970 8841 .14 8929.20 1582.59 N 911.87 W 5961086.73 N 610853.74 E 1.585 -1623.49 12212.23 84.220 171.200 8843.63 8931.69 1551.50 N 906.71 W 5961055.73 N 610859.36 E 8.951 -1592.20 12244.52 83.340 170.790 8847.12 8935.18 1519.80 N 901.69 W 5961024.10 N 610864.85 E 3.003 -1560.30 12274.85 84.060 171.120 8850.45 8938.51 1490.03 N 896.95 W 5960994.40 N 610870.04 E 2.609 -1530.34 12307.84 84.450 167.780 8853.75 8941.81 1457.76 N 890.94 W 5960962.23 N 610876.52 E 10.143 -1497.82 12339.09 85.400 167.700 8856.52 8944.58 1427.34 N 884.33 W 5960931.91 N 610883.59 E 3.051 -1467.13 12370.21 86.340 167.440 8858.76 8946.82 1397.03 N 877.65 W 5960901.71 N 610890.72 E 3.133 -1436.54 12403.57 86.960 168.540 8860.71 8948.77 1364.46 N 870.72 W 5960869.24 N 610898.13 E 3.780 -1403.68 12434.95 87.720 169.130 8862.17 8950.23 1333.71 N 864.65 W 5960838.58 N 610904.66 E 3.065 -1372.68 12466.10 88.240 168.600 8863.26 8951.32 1303.16 N 858.64 W 5960808.13 N 610911.12 E 2.383 -1341 .88 12499.27 88.370 167.560 8864.25 8952.31 1270.72 N 851.79 W 5960775.79 N 610918.45 E 3.158 -1309.16 12561 .12 87.480 163.710 8866.49 8954.55 1210.86 N 836.46 W 5960716.16 N 610934.67 E 6.385 -1248.64 12594.05 89.780 162.810 8867.27 8955.33 1179.33 N 826.98 W 5960684.79 N 610944.62 E 7.500 -1216.71 12625.90 91.540 163.370 8866.91 8954.97 1148.86 N 817.71 W 5960654.46 N 610954.34 E 5.799 -1185.84 12658.02 92.800 162.690 8865.69 8953.75 1118.17 N 808.35 W 5960623.90 N 610964.16 E 4.457 -1154.74 12689.80 93.200 162.520 8864.03 8952.09 1087.88 N 798.86 W 5960593.76 N 610974.10 E 1.367 -1124.04 12722.02 92.400 162.250 8862.45 8950.51 1057.21 N 789.12 W 5960563.24 N 610984.29 E 2.620 -1092.95 - 12753.74 91.940 161.670 8861.25 8949.31 1027.07 N 779.30 W 5960533.25 N 610994.55 E 2.333 -1062.38 12785.33 92.580 161.790 8860.01 8948.07 997.10 N 769.41 W 5960503.42 N 611004.90 E 2.061 -1031.98 12817.48 92.800 160.750 8858.50 8946.56 966.68 N 759.10 W 5960473.17 N 611015.66 E 3.303 -1001.12 12849.43 93.480 162.300 8856.75 8944.81 936.43 N 748.99 W 5960443.06 N 611026.22 E 5.291 -970.42 12882.81 92.560 159.640 8854.99 8943.05 904.92 N 738.12 W 5960411.72 N 611037.55 E 8.421 -938.44 12914.03 91.510 159.490 8853.88 8941.94 875.68 N 727.22 W 5960382.65 N 611048.88 E 3.397 -908.73 12945.00 91.110 158.440 8853.17 8941 .23 846.78 N 716.11 W 5960353.92 N 611060.42 E 3.627 -879.34 12980.34 91.200 157.570 8852.46 8940.52 814.02 N 702.88 W 5960321.36 N 611074.14 E 2.474 -846.00 13025.00 91 .200 157.570 8851.52 8939.58 772.75 N 685.84 W 5960280.35 N 611091.79 E 0.000 -803.97 Projected Survey 9 December, 2002 - 14:01 Page 4 of5 Dri/lQuest 3.03.02.004 -., Sperry-Sun Drilling Services Survey Report forPBU_WOA WPad- W-32A PB1 MWD Your Ref: APlSO0292197070 Job No. AKMW22176, Surveyed: 26 November, 2002 BPXA North Slope Alaska All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 177.320° (True). Magnetic Declination at Surface is 25.836°(04-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13025.00ft., The Bottom Hole Displacement is 1033.21ft., in the Direction of 318.410° (True). -- Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9635.85 9665.00 13025.00 8743.08 8767.29 8939.58 3237.00 N 3253.05 N 772.75 N 520.56 W 517.99 W 685.84 W Tie On Point Window Point Projected Survey Survey tool program for W-32A PB1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) --- 0.00 9635.85 0.00 8743.08 9635.85 13025.00 8743.08 AK-1 BP _HG - BP High Accuracy Gyro(W-32) 8939.58 MWD Magnetic(W-32A PB1 MWD) 9 December, 2002 - 14:01 Page 50'5 DrillQuest 3.03.02.004 Nordic 2 CTD rig to perforate W-32A 12/06/02 ) ') Subject: Nordic 2 CTD rig to perforate W-32A 12/06/02 70l...,- zoq Date: Fri, 6 Dec 2002 16:36:56 -0600 From: "McCarty, Thomas M" <McCartTM@BP.com> To: "Winton Aubert (E-mail)" <winton_aubert@admin.state.akus> CC: "Sherwood, Alistair" <SherwooA@BP.com>, "Hubble, Terrie L" <HubbleTL@BP.com> Winton: We have had a change of plans for the Nordic 2 rig. W-32A sidetrack was recently completed with the rotary rig Doyon 14. W-32A was not perforated with Doyon 14 and plans were to have service coil perforate the well. Due to the fact that Nordic 2 was on W-pad and the W-32A perf job was a relatively large, complex operation the decision was made to move Nordic 2 over the well and perforate with it. The rig is currently moving over the well. The perf job should take the entire weekend and plans are to move Nordic 2 to M-09 when the perf job is complete. Please give me or Alistair Sherwood a call if you have any questions or concerns. Thank You, Thomas McCarty Coiled Tubing Drilling Engineer, Alaska Drilling & Wells BP Exploration (Alaska) Inc. 223-7156 ) ) Form 403 Request Change of Approved Program Change of Well Name Change of API Number It is requested that W-32L1 be changed to W32A and the existing perforations in the parent wellbore be permanently abandoned. During the drilling of the lateral leg at W- 32, a large, unmapped fault was encountered at ..... 10,500' MD. Lost circulation of 100+ ;""'" bph was immediately seen. The losses were controlled with LC~an? drilling has continued with only minor problems. This fault is located at the~ of the lateral in a water swept zone. In an effort to reduce future water production, it was decided to elminate the slotted liner and run a solid, fully cemented liner. Unfortunately, this will also eliminate access to the original perforations in W -32. The original perforations will be isolated with two barriers: the packer/whipstock assembly and cement. Prior to ,..,.....- cutting the window, the W -32 wellbore was successfully pressure tested to 3500 psi for 30 minutes against the whipstock and packer. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ) ) ilJGA- ii I tS/O'L ¡vtf...,.G "/2.i../o¿ eM" ,~ 1. Type of Request: 0 Abandon o Alter Casing 181 Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 o Suspend 0 Plugging 0 Time Extension 0 Perforate o Repair Well 0 Pull Tubing 0 Variance 181 Other o Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Change Name & API Ext. 5. Type of well: 6. Datum Elevation (OF or KB) Ia Development Planned KBE = 87.16' o Exploratory 7. Unit or Property Name o Stratigraphic Prudhoe Bay Unit o Service 4. Location of well at surface 735' SNL, 1442' WEL, SEC. 21, T11 N, R12E, UM At top of productive interval 3016' SNL, 2508 WEL, SEC. 16, T11N, R12E, UM (As Planned) At effective depth NIA At total depth 687' SNL, 1810' WEL, SEC. 21 , T11 N, R 12E, UM (As Planned) 8. Well Numz;¡e "_..-~ W-32 -. 9. Permit N ber .--.-... 202-209 10. API Number 50- 029-21970-01 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 13010 feet Plugs (measured) Set 5-1/2" Baker 'FB1' packer at 9692'; Set Whipstock true vertical 8940 feet on top of this packer (11/02) Effective depth: measured NI A feet Junk (measured) true vertical NI A feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 72 cu ft Concrete 110' 110' Su rface 2698' 13-3/8" 3840 cu ft Cold Set II & III 2698' 2698' Intermediate Production 9655' 9-5/8" 2017 cu ft Class 'G' 9655' 8759' Liner 863' 5-1/2" 340 cu ft Class 'G' 9377' - 9665' 8529' - 8768' Perforation depth: measured None NOV ~) ";> (, I RECEIVED true vertical None '~ '. r¡MS 8F L NOV 2 2 2002 Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Ia Description Summary of Proposal o Detailed Operations Program o BOP Sketch 14. Estimated date for commencing operation November 20, 2002 16. If proposal was verbally approved Winton Aubert Name of approver Contact Engineer Name/Number: Rob Tirpack, 564-4166 17. I hereby certify that the fore~oilí9 is true and correct to the best of my knowledge Signed Bill Isaacson U l ~. ." '- Title Senior Drilling Engineer Cøl11mis$iq~ OSfi'Onty Conditions of Approval: Notify Commission so representative may witness A I N --, 9 -:;, --;--,? pprova O·d). ,- --:):J I Plug integrity _ BOP Test Location clearance ¿. .... . Mechanicalln~eg,!ity Test _ . Subsequent fo~ requi~ec¡l ! 0- '-l ~ ..~ L Ail P,D lO ¿ - -z.~ c( ,o-~ol pay ~ + ,:>~p "dk.:þ ~yu:::. e.vfp ~ . Approved by order of the Commission : '" "OnÎOINAL' 9IOftCD DY Commissioner Form 10-403 Rev. 06/15",/88 ,\" :. M L 81, :. ~,II\:\'" f\ ^ r'" c-r:¡.,. ,",,-, c.lt\.q \ZßtHAS C:::\~W . U 'l W'\. I V\ l ~-,..... 15. Status of well classifications as: Ia Oil 0 Gas 0 Suspended 11/20/2002 Service Date Approved Prepared By NameINumber: Terrie Hubble, 564-4628 Date If I'lZ /02 Date j¡l6to/Or; Submit In t~iPlil~te ) ) W-3~A Proposed Completion Cellar Elevation = 54.76' Doyon 14 RKB 89.06' TREE = WELLHEAD = A CTUA TOR = KS. ELEV = SF. ELEV = KOP= Max A nHI.e = Datum MD = Datum TVD = 3-1/8" FMC 13-5/8" FMC SA KER 90.86' 54.76' 3100' 35 @ 10100' 9813' 8800'55 14-1/2" X-Nipple with 3.813" ID @ 2125' I L j ~ 113-3/8", 68#, L-80 Csg @ 2698'1 14-1/2" 12.6# 13Cr-80 Vam Ace Tubing with GLM's I GAS LIFT MANDRELS MD TVD Size Valve Type 6 3108' 3000' 1-1/2" DV 5 3958' 3750' 1-1/2" RP Shear ,4 5376' 5000' 1-1/2" DV I 3 6509' 6000' 1-1/2" DV 2 7659' 7000' 1-1/2" DV 1 8851' 8000' 1-1/2" DV L L L -1r -~ Tubing Tail Detail: 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 9-5/8" x 4-1/2" Baker 'S-3' Production Packer (9Cr) 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.75" seal bore. 4-1/2" Wire Line Entry Guide (6.00" OD) landed in ZXP liner top packer ~ 9-5/8"x 7" Baker Flex-Lok Liner Hanger 9-5/8"x 7" Baker HR ZXP Liner Top Packer Crossed over to 3. -1 !?>~ +/-9277' ~oPofcementlr~:~/1 Top of 5-1/2",17#, L-80 Liner @ 9377' I 9-5/8" CSG, 47#, NT-80S, ID=8.681" 1-1 9655' I ~ ~ / )3-1/2" 9.2#, L-BO, _~ I +/-13,765' I , ~ "--..: ~4-3/4" hole I ~ "iBaker Flow-Thru FB1 Packer at +/-9700' MD wi 3" ID - Plugged with whipstock I ~ ==- Fill Date 09/24/02 11/20/02 Rev By WDO RBT Comments PRUDHOE BAY UNIT WELL: W-32A API NO: ~110,240'1 Proposed Completion Change to Sidetrack GPB Drilling & Wells \ V ) ~~!Æ~E ~ } !Æ'~!Æ~~!Æ TONY KNOWLES, GOVERNOR ~ AI/A~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit W-32L1 BP Exploration (Alaska), Inc. Pennit No: 202-209 Surface Location: 735' SNL, 1442' WEL, Sec. 21, T11N, R12E, UM Bottomhole Location: 687' SNL, 1810' WEL, Sec. 21, TIIN, R12E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The pennit is for a new wellbore segment of existing well Prudhoe Bay Unit W-32, Permit No 189-091, API number 50-029-21970. Production should continue to be reported as a function of the original API number stated above. 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 tenns and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ 0uU~ camrn"";&chsli Taylor Chair BY ORDER OF THE COMMISSION DATED this~lßay of October, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. w..t 6A- 0/2..1 J éJ '- 12. Distance to nearest property line 13. Distance to nearest well I ADL 028262-2,3469' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9665' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 3-1/2" 9.3# L-80 IBT Hole 4-3/4' ) STATE OF ALASKA ", ALASKA ~IL AND GAS CONSERVATION COMMlvlloN PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 87.16' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028263-2 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number , W-32L 1 / 9. Approximate spud dat~ 10-18-02 /' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13765' MD 19027' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 98 0 Maximum surface 2820 "PSig, At total depth (TVD) 8800' I 3700 psig Setting Depth Top Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 4440' 9325' 8485' 13765' 9027' Uncemented Slotted Liner 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill III Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 735' SNL, 1442' WEL, SEC. 21, T11 N, R12E, UM At top of productive interval 3016' SNL, 2508 WEL, SEC. 16, T11 N, R12E, UM At total depth 687' SNL, 1810' WEL, SEC. 21, T11N, R12E, UM Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 1 0240 feet 9242 feet 9450 feet 8589 feet Length Plugs (measured) IBP set at 9450' (05101) Junk (measured) Pkr Rubbers at 9981 MD'; 1/2" x 1-3/4" KO Tool Arm Pin at 9902' MD and a 20' Perf Gun at 10095' MD. Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 110' 20" 2698' 13-3/8 " 9655' 9-5/8" 863' 5-1/2" 72 cu ft Concrete 3840 cu ft Cold Set II & III 110' 2698' 110' 2698' 2017 cu ft Class 'G' 340 cu ft Class 'G' 9655' 8759' 9i'rf!" V~tJ 9242' Perforation depth: measured Open (Below IBP): 9870' - 9880' I 9885' - 9897' 9901' - 9955' , 9966' - 9998' OCT 0 9 2002 20. Attachments true vertical Open (Below IBP): 8939' - 8947' ,8951' - 8961' 8964' - 9009' ,9018' - 9_ka Oi~& Gas Cons. Commission Anchorage III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Walter Quay, 564-4178 21. I hereby certify that t~i f~regoirg is ;r,ue and correct to the best of my ~nowl~~ge . Signed Bill Isaacson U~-U-. ~ _ I """ _,- Title Semor Drilling Engineer , Commi.$SionYse.'()nly. Prepared By Name/Number: Sandra Stewman, 564-4750 Date ðCT pI ~ . loöl Permit Number 202-...2.°7 Conditions of Approval: API Number APprovql\t~~el,") r¡ See cover letter 50- 029-21970-60 I (/ .7't~ I / /7\ for other reauirements Samples Required 0 Yes .B No Mud Log Requir d 0 Yes .m No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required È1 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Tës f- t~ PE ~ ~ ~O(.? (' S.. . 0oglOal Signed By Cammy Oechsli T aylof ¡Cøriimissiphef : I: ~! by order of I~ /" th~ commission II I· ,.__ Date 10 ~7J/o?-- Submit In Triplicate Approved Bv Form 10-401 Rev. 12-01-85 ",i"']"'"'''' ,,".>, "", "",,,,,,,,, ,.,,::reater prUdh()j Bay W-38L 1 Permitto Drill I· \"'.··11· ·a:.·.·.·.·m'.·:·. '.:. ·.ð.·.: '.:".: :1.:····~~/+f'Î~I,¡J~·tt,.:.'." ..,.. .~!Ii, ,..>, ..:..~. . .,~I'! :s:?~~J: ":.... I Type of Well (producer or injector): I Extended Horizontal Lateral Surface Location: 735 FNL, 1,442' FEL, Sec. 21, T11 N, R12E X = 611,789 Y = 5,959,518 3,016' FNL, 2,508' FEL, Sec. 16, T11 N, R12E X = 610,672 Y = 5,962,500 Z = 8,900' TVDss 687' FNL, 1,810' FEL, Sec. 21, T11 N, R12E X = 611,420 Y = 5,959,560 Z = 8,940' TVDss W-32L 1 Target Start: W-32L 1 Target End: I AFE Number: I PBD4P2020 I Rig: I Doyon 14 I Estimated Start Date: I Oct. 18tn 2002 I Operating days to complete: 129.9 I Well MD I 13,765' I I Well TVDrkb: TD I 9,027 I I Max Inc. I 98° I I KBE I 87.16' Well Design: Summary: Extended Horizontal Sidetrack Decomplete motherbore and sidetrack out of existing 17#, 5-1/2" casing in the Sag River formation, directionally drill 4-3/4" hole, land horizontally in the Ivishak Z4 sands. Geosteer horizontally through the Z4B target sands to TD at 13,731' MD. Run a slotted 3-1/2" liner, complete with a 4-%" chrome gas lift completion, with production from motherbore and sidetrack wellbore. Target Estimates: Estimated Reserves: Expected reserves 1.85 mmbo Formation Markers Formation Tops ft MD ft TVDss ft TVD Pore psi EMW (ppg) Hydrocarbons Base HRZ Base Miluveach Top Kingak Top Sag River 9,642 8,661 8,748 Top Shublick 9,676 8,689 8,776 TElL 9,802 8,787 8,874 TSADfTZ4B 9,821 8,800 8,887 3500-3700 8.0 Yes gs 45N 9,859 8,824 8,911 Yes 44N 9,920 8,856 8,943 Yes 43N 10,134 8,910 8,997 Yes TD 13,765 8,925 9,027 Yes CasinQrrubinQ ProQram ~ - - HóléSize 059] Wt/Ft Grade Conn Length Top Bottom TbgO.D. MDITVDrkb MD ITVDrkb 4-3/4" 3 Y2" Slotted 9.3# L -80 .I IBT 4,440' 9,325' 1 8,485' 13,765' 1 9,027' Tubing 4 %" GL 12.6# 13Cr-80 VAMACE 9,291' 34' 1 34' 9,325' 18,485' Mud ProQram 5-1/2" Window Milling Mud Properties: Density (ppg) Plastic vis 8.4 - 8.5 4 - 7 YP 22 - 26 I Low Density Quickdril API FL PH LSRV N/C 8.5 - 9.0 -25,000 cp I Low Density Quickdril pH MBT API FI 8.5 - 9.0 < 3 N/C MBT <3 4=-3/4" Production Hole Mud Properties: Density (ppg) Plastic vis YP 8.4 - 8.5 4 - 7 22 - 26 NOTE: See attached Baroid mud recommendation 1 0/9/2002 1 of 7 ) Greater Prudho_e Bay W-32L 1 Permit to Drill ) Cement Calculations Casin~ Size 13-%" 9.3 Ib/tt L-80 BTC-M Slotted - No Cement Basis I 3 Y2" Slotted Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint with no stop collar (i.e. free floating across the whole length of the joint) for the whole string. This strategy will be revisited during the drilling of the production hole and prior to running the liner. LOQQing Program 43/4" Hole Section: MWD / GR I Res Cased Hole: None Surface and Anti-Collision Issues Surface Shut-in Wells: Evaluate W-31 for the rig move on & off. · If the well house needs to be removed from an adjacent well, then the well needs to be shut-in prior to the move. Close Approach Wells: There are NO close approach wells associated with this profile. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Production Section- Maximum anticipated BHP: /3,700 psi @ 8,800' TVOss - Ivishak Maximum surface pressure: 2,820 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · · Planned BOP test pressure: · Planned completion fluid: 3,500 psi (The 7" casing will be tested to 3,500 psi) Estimated 8.6 ppg Seawater / 6.8 ppg ~iesel BOPE· Rating 5,000 psi Working Pressure (entire stack and valves . Planned·BOPE Test Pres. 3,500/250 psi Rams & Valves 2,500/250 psi Annular Disposal · NO ANNULAR INJECTION ON THIS WELL. · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 2 Greater Prudhoe Bay W-32L 1 Permit to Drill ) ) Drillina Hazards and Continaencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be normal pressured at 8.0 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Lost Circulation A. Lost circulation is possible. If it occurs, follow the LCM decision tree. B. W Pad has a history of lost circulation events while drilling in the reservoir section and normally occur when crossing faults. Three expected fault crossings have been identified for this hole section, however the risk of encountering losses at these faults is considered to be low risk (10-200/0). III. Kick Tolerance/Integrity Testing A. The 5-1/2"" liner was fully cemented with 15.7Ib/gal tail cement above the liner top packer @ -9377' MO. B. The Kick Tolerance for the production hole section is infinite with 8.5 ppg mud, 9.7 ppg FIT, and an 8.0 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECO's. C. Integrity Testing Test Point Test Depth . Test type EMW (Ib/gal) 5-1/2" window 20-ft minimum from the window FIT 9.7 IV. Hydrogen Sulfide A. W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: B. Adjacent producers at Surface: a. W -39 less than 10 ppm b. W -37 less than 10 ppm C. Adjacent producers at TO: a. Z-18 10 ppm b. W-09 10 ppm D. The maximum level of H2S recorded on the pad to date was less than 20 ppm. 3 ') Greater Prudhoe Bay W-32L 1 Permit to Drill ) Scope of Work CONSULT THE W PAD D4>TA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 1. Drift tubing and tag IBP @ ~'50'. Pull dummy from station #1 @ 9253'. Fill IA & tubing with seawater as needed. Displace the wellt'to"clean seawater by circulating down tubing through the GLM #1). Continue to circulate until clean seawater returns to surface. Freeze protect top 2,000' TVD with diesel. The well should not be left with methanol as a freeze protect fluid, diesel only. IA cannot be overbalanced in relation to tubing side during chemical cut. J 2. Retrieve IBP. Observe and note in report, the fluid levels after IBP is pulled. 3. RU E-line and chemical cutter. RIH, log up to orient, find the 10' pup above the X-nipple above the packer. Find the collar between the 2 x 10' pups(X-Nipple & GLM station @ 1) and position chemical cutter -3-5' below the collar and cut 3-1/2" tubing @ - 9277' (all depths referenced to Tubing Summary dated 9-17-89). This cut will be fished and the type and location of the cut is critical. As specified, the cut will leave approximately 5-6' of 3-%" tubing stub for fishing operations. 4. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger. Secure well. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU Doyon 14. Pull BPV. Circulate out freeze protection and displace well to seawater. 2. Set TWC. Nipple down tree. Nipple up and test BOPE. ../ .. 3. Pull and lay down the 9200' 3-%" tubing string from the E-line cut and above. I' 4. MU overshot for 3-%" tubing and RIH. Establish up, down & rotating weights. Engage 3-Y2" tubing stub. Release 'K' anchor from production packer and POH with remaining tubing down to production packer. If K- anchor will not release, pull seal loose and make another overshot run to recover latch. 5. MU 9-%" packer milling assembly with PRT (packer retrieving tool). RIH and mill 9-%" packer until free.' . 6. After packer drops, circulate bottoms up to remove any trapped gas. Push packer to top of 5-1/2" liner top @ ,,- -9377 MD. 7. Engage fish with PRT (in mill out extension below packer) & POH with remaining packer & tubing tail assembly. 8. MU clean-out BHA with TIW tieback polish mill & Scraper. RIH to 5-1/2" liner top and circulate and condition wellbore as required. 9. Run packer to top of 5-1/2" liner. Test 9-5/8" casing to 3000 psi. / 10. Use existing log and GR/CCL log to locate desired KOP. 11. PU flow through packer, RIH and set above perfs such that the whipstock can be set directly on the packer with minimal spacing requirements, POOH. 12. PU 5-1/2" whipstock assembly. Run a tubing spacer below the whipstock if needed to place the top of whipstock at -9665' when spacer bottoms-out on packer. Orient whipstock to -450 and set in packer. 13. Mill window in 5-1/2" liner at ± 9665' MD(Window Top). Perform FIT to 9.7 ppg EMW. POOH / 14. RIH with 4-3/4" KO drilling assembly (with MWD/GR) to whipstock. Kick-off and drill the 4-3/4" production section as per directional plan to an estimated TD @ ±13,765' MD (9,027' TVD). / 15. Retrieve Baker Whipstock. 16. Run a 3-Y2",9.2# L-80 productioh liner (combination solid and slotted) and or only slotted liner (w/1 solid joint & X-nipple below the liner hanger). Set/release from the liner. Displace well to clean brine and or seawater above the liner top packer. POH. 17. Run a 4-%",12.6# 13Cr-80 Vam ACE completion tying into the 4-%" liner top packer. 18. Set packer and test the tubing to 3,000 psi and annulus to 3,000 psi for 30 minutes. 19. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 20. Freeze protect the well to -2,000' TVD and secure the well. Rig down and move off. Post-Riq Work: 21. MIRU slickline. Pull the ball and rod / RHC plug from IX' nipple below production packer. 22. Pull out RP shear valve from bottom GLM. 23. Install gas lift valves. Detailed Drilling Procedure 4 Greater Prudhoe Bay W-32L 1 Permit to Drill ) All depths given are referenced to a 87. 16-ft 014 RKB/MSL elevation Job 1: MIRU Critical Issues ~ An adjacent wells (W-31) is approximately 35' from the W-32 wellhead. Establish a minimum distance of 5' from the W-31 well house. The well houses may need to be removed prior to the rig move. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of. a collision. If it appears the 5' distance will be crossed, the move should be stopped, the rig backed up, and the move re- attempted. ~ Contingency Wellhead Equipment: Have an extra tree and tubing spool on location prior to the rig move to be placed behind the rig for easy access if needed. There is the potential to have to replace the existing tree during the NU, prior to leaving the well due to corrosion, etc. ~ W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Water injection on W-Pad was initiated in late 2001, and H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: ~ Prior to moving the rig on to the well, complete a pre-rig inspection with the Pad Operator to assume responsibility for the well. Arrange for pad operator to be at the wellsite and in radio communication with the tool pusher when rig is spotted. Review the Pad Data Sheet and perform Pre-Spud meeting with all relevant personnel. Prepare location for rig move. ~ The perforations will not be abandoned due to the desire to retain production from the motherbore to capture the remaining reserves. The well should be overbalanced by -70 psi at surface with the diesel down to 2,000' TVD. Prior to moving over the well check the wellhead pressure to verify the well is dead. ~ Record and report the 9-%" x 13-%" annulus pressures before moving on the well. Repeat each day Doyon14 is on the well. Job 2: Decompletion Critical Issues ~ The top perforations are not isolated and tested, therefore monitor the well for gain/loss prior to beginning decompletion operations and while pulling the tubing and packer. ~ A Multi-Finger Caliper (PDS on 3/11/01) shows the tubing ranges from good to poor condition with respect to corrosive damage. Limit over-pull on tubing string to 80% of tensile strength, and if tubing will not pull free on initial attempt, RU e-line to make a second cut. }> Gas could be trapped below the packer and tailpipe assembly. Be sure to monitor for gains while milling the packer and circulate out any gas at a controlled rate through the choke, if necessary. }> NORM test all retrieved well head and completion equipment. o Ensure AOGCC has 24 hours notice for witness of the BOP test. Job 3: Whipstock/Mill Out 4-3/" Hole Critical Issues ~ Depth Control: Depth control will be very critical on this window. This window could require space out tubulars below the whipstock to allow the whipstock to land out on the FB-1 packer set just below the window. ~ Whipstock Orientation I Depth: The whipstock should be oriented to ±45° left of high side. This will allow for a better transition into the profile and allow for easier access into the window with the bent joint on the end of the 4-Y2" liner. Exact window depth to be based off of actual logs. Planned top of window depth is 9665' MD ~ Window Milling: It is critical to have a smooth uniform full length window. Extra time spent on the window milling will be well worth it when it comes time to get the bent joint through. Follow the BOT 5 ) representative during the milling of the window. FIT: An FIT of 9.7 ppg EMW is required at the 5-/12" shoe. The expected frac gradient for the Ivishak is 12.5 ppg EMW. Greater prUdhO) Bay W-32L 1 Permit to Drill ~ ~ Kick Tolerance: The kick tolerance for the 4-3/4" open hole section would be an infinite influx assuming a kick from the Ivishak at -13,800' MD. This is a worst case scenario based on an 8.0 ppg pore pressure gradient, a fracture gradient of 9.7 ppg at the 7" window (14,150' MD), and 8.5 ppg mud in the hole. Hole Cleaning: Well inclination at the planned kick off point angle is about 34°. Good window milling and hole cleaning practices will be critical to ensure that metal and formation cuttings are removed from the well. ~ ·~,r,l,IJm,l,-,-,:m,I,,6,I,-,I,I,\\I,I!,I,I,Im.-,~I,I,I,I,I,I,I,\I,~~I,I,I,\D,I.;\',I,:m.:,\'~-mlJ.:mw.w."',',I,\\aA',\I,lI,\I,I,:,I.',\I,I,IAIm.I.I,I,I,-',J,:,'-,-,I,-,I.I.,I,r,:U:,I,-, ,-.-.I',I,I,:m-.\I,\~I,I,I,I,'I,\I;,I,I,I"'I;I.¡';,I.\,\I.amml,lIm,1!,',I,I,,I,:m,:,I.:"'-,;r;,x.r,l,I,I,-,\IAI,I,I,I,~,\-.l.Im.I.al',I,'-ml,l,1"I,I,I,:,I,I"I,:,I.a,I,I,IJ,:m.!,!.I,:,I"-.a,I,I.I,,I.I.I,";,I,:.,:,1,1.\I,I,I"I,'-,:,I,I,','I),I,I,I,I,D,:,-J,-,I,o.a,I.I.I,':,'I~I,I,:,,a~l,I,w.,I.\\l.IA,a'.l.',\I;,I,\a,W,I,~I,I.I,al,'I.I.I,:'I.l.lmmmlml,l,1,1,1,I,1,I,1/,!.l.WW,I,I,IJ,I,\I,I"l,I,lmr,11"rm,I,I,;!Mm!,:,I,\IH'JJ¡,-,",I"I,I.l.I,I,I,'IA!AI~IA\\I~\I,I,'I.l.IAI~,lm,,'I.I.,'!.l.lp;~Mlm,:,I.'m.-m-m,l,l.li,r:.I,I,-,I. Job 7: Drill 4-3/4" Production Hole Critical Issues ~ Procedural recommendations for running drilling BHA through milled window: o Orient the BHA above the window before attempting to exit the window. Bit rotation may "catch" the edge of the Whipstock and damage the face making recovery operations more difficult. o If at any time during operations a problem is encountered tripping through the window area, a watermelon or string mill should be run in the drilling assembly to clean up the window area. o It is highly recommended that stabilizers (in the BHA) NOT be rotated until a minimum of 70' - 100' of progress is made outside the window. ~ Wellbore Profile: The directional objective for this wellbore is extremely difficult and is expected to be the most challenging aspect of this well. Two BHA's are planned to achieve the directional objective of this well. A 2.38° bent housing motor with a tricone bit will be used to help get the majority of the build and turn section and to avoid unnecessary undulations throughout this interval. Then a 1.5° bent housing motor with a PDC bit will be utilized to drill the tangent interval of the profile to TD. There will be a rigsite geologist on location to help with interpretations. ~ Lost Circulation: W Pad has a history of lost circulation events while drilling in the reservoir section. Typical loss rates have been in the 20 to 30 bph range, however there is a single case where W-12A crossed a fault and experienced losses at -100 bph. The majority of cases have been fault related and all were managed by pumping fiberous LCM pills. Good drilling practices to limit ECD's and surge pressures should be a standard. In the event, lost circulation is encountered, Follow the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Flow Chart'. ~ Faults: Three fault crossing have been identified in this hole section. The risk of encountering losses at these faults is considered to be low (10-20%). Follow the LCM Decision tree if losses are encountered. Have LCM products on location to treat any losses. ~ ECD/Hole Cleaning: Hydraulics modeling for W-32L 1 predicts a clean hole ECD of 9.4 ppg, a dirty hole ECD of 9.7 ppg with at TD, mud weight of 8.5 ppg. We will be drilling out with 8.4 - 8.5 ppg MW. Good drilling practices and connection practices must be followed. r-U-T- :lIIm;;.;..;..·.I;·I....I....·;·; ..;1\...·....1;...;.1;1 --;·ll--lrr<'l;.U".;;.·¡ 1111-- '1'--1-- _,_ 'IU-- "UIIUlUIIII!;..;...;I;..I,oI;UI_ -UlIIIII'IlUun.;;IMI;I'I.I,oI;;;.;UM;;·-;n;lr;·~T;U;IIMo;;I:;·<lM;¡"1"'-11;;1'1111"';;- '1'1'11'-;'1'-;1'1'1 I' -;)0.' '1''',,;-'1' T T ';--11;;;.'11111111I1".::1::. --;--.....;1;11----'1111I Job 8: Retrieve Whipstock Critical Issues . Orientation of Retrieval Hook: When scribing to align the MWD to the hook remember that the orientation of the hook will need to be 1800 from the orientation of the whipstock. Job 9: Run 3-%" Slotted Liner Critical Issues 6 Greater Prudhoe Bay W-32L 1 Permit to Drill )) » Have a Baker completion specialist onsite to supervise this liner job. . » Well Control: Prepare and review well control procedures for running the slotted liner. Develop a plan of what to do if an influx is noticed while MU the liner. » Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses. » Ensure that all casing, tubing, drill pipe, and accessories run are drifted with proper drift before being run into well. All components of the liner running string and the innerstring should be drifted to their specified drift. Drift specification for the workstring are as follows: Job 12: Run 4-%" Chrome Completion Critical Issues » Pipe Dope: On S-18a, problems were encountered when MU the chrome completion due to pipe dope issues. Multimake white is still the preferred pipe dope to be used on premium chrome connections in conjunction with Molly spray. This combination proved to be very beneficial to minimize galling tendencies while making up the connections. It is possible to have enough Jet lube on the slope in time to utilize on this completion. Therefore, confirm with Stores and or Tool Service prior to applying any dope on the pipe to see if the Jet Lube made it to the Slope in time. » Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. » See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig demob. Use spotters when moving the rig off of W -32. 7 TREE = 3-118" FMC WELLHEAD = 13-5/8" FMC ACTUATOR; .~ BAKER KS.liE'./= 90.86' BF. ELEV = 54.76' KOP = 3100' MaxArig"le:: 35 @ 10100' Datum MD = 9813' IfcÍtlJm 1\Ì Ö; 8aÓO;ss J. 13-:w' CS3, 68#, L-OO, D= 12.415' H 1f1B I W-32L 1 Proposed Completion I I I 2,125' 4-1/2" X-Nipple with 3.813" ID. L .. 4-1/2" 12.6# 13Cr-80 Vam Ace Tubing with GLM's / GAS LIFT MANDRELS MD Size Valve Type RP Shear DV DV DV DV DV ---.!:: 6 5 4 3 2 1 ----!: .. 4-1/2" 'X' Landing Nipple with 3.813" seal bore. ~ r 9-5/8" x 4-1/2" Baker '8-3' Production Packer 'I 4-1/2" 'X'Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.75" seal bore. 4-1/2" Wireline Entry Guide spaced-out into 3-1/2" liner tie-back sleeve. ~) ~~~-) --/ I I ~ ~ I(~~=~t \ [t"-..tY "-P. ý ~- - Tie Back Sleeve \ I TOP OF 5-1/2"LNR H 9377' I J;;!!: 9-5/8" X 5"(X-overto 3-1/2") 'HMC' Hydraulic liner Hanger ~ 9-518" CSG, 47#. NT-80S, D= 8.681" H 9655' I Window Milled from Whipstock Top of Window at +/-9665' MD --- Baker FB1 Packer at +/-9700' MD FlövJ - \? ~ ~\L V I 5-1/2" liner, 17 #/ft, L-80 H 10,240' I .. 3-112" 9.2#, L-80, IBT-M Slotted liner "$ -=:::: ;:;::-- ~ ~ ===-- Rev By Comments WDa Proposed Completion WDa Date 09/24/02 10/09/02 Fill Cellar Elevation::;: 54.76' Doyon 14 RKB 89.06' .~ I +/-13,765' I PRUDHOE BAY UNIT WELL: W-32L 1 API NO: 50-029-21970- GPB Drilling & Wells 3-1/8" FMC 13-5/8" FMC ···············SÄkER 90.86' 54.76' 3100' ""'35'@fTÖrõõ;' ..m.. . .m'gàf:f ..·..·88ÖO;S8' TREE = WELLHEAD = AcrUï-\'i'OR';' . ............ . ..... ............... KS. ELEV = SF. ELEV = KOP= 'Mã){"Äñgìe,m;" OatumMO= 'batÙn:ïi'\/Ö';;; . ') 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 2698' ~ Minimu m ID = 0.0" @ 9450' BAKER IBP 1 TOPOF 5-1/2" LNR 1-1 3-1/2" TBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" 1-1 9377' 9380' 9-5/8" CSG, 47#, NT-80S, 10 = 8.681" 1-1 9655' PffiFORATION SUrvtv1ARY REF LOG: BHCS ON 09/11/89 ANGLE AT TOP PERF: 34 @ 9870' Note: Refer to Production DB for histori:::al perf data SIlE SPF INTERVAL Opn/Sqz DA. TE 2" 4 9870-9880 0 05/11/90 2" 4 9885-9897 0 05/11/90 3-3/8" 4 9901-9955 0 05/11/90 2" 4 9966-9978 0 05/11/90 2-1/2" 4 9978-9988 0 05/11/90 1 PBTD H 10199' 5-1/2" LNR, 17#, L-80, 0.0232 bpf, ID = 4.892" H 10240' DATE 09/15/89 02/15/01 03/06/01 09/08/01 REV BY OOrvtv1ENTS ORIGINAL OOIVPLETION OON\!ffiTBJ TO CAN\! AS RNAL OORRECTIONS SIS-QAA S IS- L G RN'TP W-32 e L I . il: " : :8: j & I f ~ I ~., '~r ,\ ~¡ ~ ¡ .,'- ~ ,- , , 1/11II£. DA. TE REV BY COMrvENlS I SAFET )TES 2086' 1-13-1/2" OllS SSSV LA ND. NIP, ID = 2.75" I ~ GAS LIFT MANDRELS ST MO TV D ŒV TYPE V LV LATCH PORT DATE 6 2975 2883 8 OllS RA 5 5620 5215 29 OllS RA 4 7273 6674 33 OllS RA 3 8296 7538 33 OllS RA 2 8914 8052 34 OllS RA 1 9253 8335 34 OllS RA 9282' 1-1 3-1/2" OTB X NIP, ID= 2.750" 1 9292' IJ3-1I2" TIW SEAL ASSY 1 9306' 1--l9-5/8" x 3-1/2" llW HB-BPPKR, ID= 4.00" 9348' 9369' H 3-1/2" OTB X NIP, ID= 2.750" 1 1-1 3-1/2" OTB X NIP, ID= 2.750" I 9380' 9383' 1-13-1/2" WLEG I H ELMD TT LOG UNA V AILABLE I ) \fLÛ~ (\ , ",~'-'¡ GO 'f--,~.' e-¡) l-[2~ífrBAKER BP - OS/22/01 9825' 1-1 MARKER JONT I 9981' 1-1 PKR RUBBERS I 9902' U1/2" X 1-3/4" KO TOOL ARfv1 AN I I 10095' H2o' PffiF GUN I PRUOI-OE BA Y UNIT WELL: W-32 PERfv1IT No: 89-0910 A A No: 50-029-21970-00 Sec. 21, T11 N, R12E BP Exploration (Alaska) Plan: W·32Ll wp06(W.32ß>1an W-32LI) QealedBy: Ken Allen Date: 101312002 0Ied:ed: Date: Reviewed: Date: SURVEY PROGRAM D<pe. Fm Dcpch To s.wyJPIoa Tool 9660.00 13765.53 PIomod: W·32L1 wp06 V14 MWD>IFR+MS REFERENCE INFORMATION Co-oIdÏIIOIIo (NÆ) JtoIoroaot: W. c-c W-32, T... North VediaoI(1VD)~ 100I87.16'87.16 SocIioo (VS) Rcf_ Slot· (O.ODN,O.OOE) "'--dDopchR__ 100I87.16' 87.16 Cù:ù6oIaMcb>d: -.me::.- COMPANY DETAI13 8P~ Cù:ûIioD t.W>od: _~ == ~~Nort> W== ~~c.q d Slot NlA -' vSee Target 930.67 930.67 937.36 092.27 424.32 1400.09 1389.64 W-32A Agr A 1348.99 1178.81 1157.29 W-32A Agr B 1131.01 066.79 965.75 W-32A TJd 965.72 545.39 539.20. W-32A T4b 371.48 W-32A T5 WElL DETAILS Nome +NI-S +FJ·W Nortlóms -. LotiIade ~ W·32 2296.31 1903.S1 5959517.88 611789.DS 7O"17'S4.088N 149"O$4Q.84SW TARGET DETAI13 - 1VD +NI-S +FJ-W J'oIortIq -. Sbopo W·32A AI;t A 8932.16 2728.26 ·1048.67 S962230.oo 610700.00 PoiIII ~:~~B 8932.16 1816.34 -93U2 5961320.00 610830.00 Poft 89S3.16 1816.34 -93U2 5961320.00 610830.00 PoiDt W-32A T3d 8982.16 1264,42 -810..40 S96077O.oo 610960.00 PoiŒ W-32A .n 8987.16 2998.67 -1072.66 ~.OO 610672.00 PoiŒ W-32A Poly 8987.16 32046.88 -478.85 5962757.00 611262.00 Poly!"" W-32L1 Fal2 8987.16 1361.65 ~ S960865.oo 610810.00 Poly!"" W-32L1 Fod3 8987.16 393.2S ·743.35 S9S99OO.00 611040.00 Poly_ W·32L1 fa): 1 8987.16 3637.64 ·995.14 5963140.00 610740.00 Poly_ W·32A T4b 9012.16 389.54 -493.35 S9S99OO.oo 611290.00 PoiDt W·32A 1'5 9027.16 47.61 -368.41 S9S9S60.00 611420.00 PoiŒ SECTION DETAILS Azi TVD +N/-S +F1-W DLeg TFace 9.41 8762.99 3250.79 -518.36 0.00 0.00 5.33 8779.51 3261.96 -516.92 12.00 -75.00 348.50 8827.75 3297.42 -519.09 18.00 -75.00 293.79 8967.09 3434.68 -657.55 23.00 -70.00 183.63 8999.55 3207.05 -1021.77 22.00 -85.78 183.63 8941.48 2836.00 -1045.28 0.00 0.00 180.00 8932.16 2728.26 -1048.67 8.00 -155.18 171.85 8930.33 2523.76 -1034.11 4.00 -96.82 171.85 8930.12 1893.84 -943.90 0.00 0.00 171.00 8932.16 1816.34 -932.22 4.00 -164.28 169.70 8939.52 1727.80 -917.17 4.00 -159.06 169.70 8963.14 1519.48 -879.32 0.00 0.00 160.08 8982.16 1264.42 -810.40 4.00 -65.16 160.08 8982.16 1264.35 -810.38 4.00 156.08 160.08 9011.67 402.19 -497.96 0.00 0.00 159.93 9012.16 389.54 -493.35 4.00 -163.72 159.93 9027.16 47.61 -368.41 0.00 0.00 Size 3.500 TVD 9027.16 13765.52 3112" FORMATION TOP DETAILS No. TVDPatb MDPath Formation TSGR TSlRJ TElL TSADffZ4B 45N 44N 43N CASING DETAILS MD Name 9641.95 9675.74 9802.00 9820.89 9858.71 9919.95 10133.91 8748.00 8776.00 8874.00 8887.00 8911.00 8943.00 8997.00 1 2 3 4 5 6 7 No. 1 IDe 33.96 34.65 38.69 76.17 98.88 98.88 91.00 90.02 90.02 87.00 83.63 83.63 88.16 88.16 88.16 87.64 87.64 MD 9660.00 9680.00 9740.00 9990.00 10497.13 10873.44 10981.74 11186.94 11823.28 11901.69 11991.83 12204.86 12470.14 12470.21 13387.71 13401.18 13765.53 See 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 SIart Dir 121100 : 9660 MD, 8762.99'TVD TSGR /" ,/ SlartDir 18ßOO: 9680' MD. 8779.Sl'TVD TSYU -/ Start Dir23/100 : 9740' MD, 8827.7S'TVD End Dir : 11991.83' MD, 8939.S2' TVD ø j/~ ~~ {~ ~~ I~ ~~ ,I , ~ All TVD depths are ssTVD plus 87. 16'for 8700- ---' 1823.28' MD, 8930.1rIVD End Dir : 11186.94' MD, 893033'1VD SWt Dir4/IOO': 10981.74' MD. 8932.16'IVD ~ Start Dir &'100 : 10873.44' MD, 8941.48'TVD SWt Dir 4/100' I RKBE. MD. 8999.SS' 1VD 10497.13' r:f Y fr Dir -s-~ '00 i: - 43N &art D::r 22Il'xr : !mO' YD, 8967.09'"'VD ~ + ....... 12OCO ;m IÑ : 124702 . MD, 8982.' (J T d I GO 13000 GO SWt Dir 411 00' : ~ 22í" '86' M:>, 8963.140' VD Start Dir4/.00': 338771' M..:>, 901J,6TIVD End)u : 13401. 8' MtJ, 901::.16' 1VD \, W 32L1 wp06 ,:r- \\ g;, ~ 112" Total Depth: 376S S3' M".>, ~7.16' "VI> ~ ~ o =. 8850 ..c ! B .~ > ë !- 9000 I 1650 I 500 1350 1200 W-3Z (W-:I2) 900 1050 Vertical Section at 277.36° [150ft/in] 750 600 450 300 9150 Date: 101312002 Dale: Dale: PIan:W·32L1 wp06(W.3M'LmW-32LI QeokdBy: Ken AIIon Cbed:ed: Reviewed: WELL DErAILS Nordq EaoIina Lotimde ~17.88 611789.05 7OOI154.088N Tool MWD+IFR+MS Homo +W.s +FJ·W W·32 2296.31 1903.81 S\JIlVEY PROGRAM DepIh fin DepIh To SorveyIPIm 9660.00 1376S.S3 PIomod: W-32LI ..,œ VI4 REFERENCE INFORMATION ~ (N/E) RoIcraø: WeI c-..: W·32, T... Nodh V_(TVD>___ UBI7.II/I7.16 Socfioø (VS) RefctcDoo: Slot - (O.OOJI/,D.OOI!) Moo.red )<lIb RácRaoe: RKB 17.11/ 17.16 CaIcaIotiœ M_ Mïom.I1c.-. COMPANY DETA[[3 BP~ CaIcaIotiœ ModIøcI: Mïom.I1 c.- =~ ~~NoItb w":= ~~c-q ò Slot NiA EaoIina Shape 610100.00 PoU 610830.00 Pod 610830.00 Pod 610960.00 Po.. 610672.00 Po.. 611262.00 POIy&oD 610810.00 POIy&oD 61104(.00 POIySOD 610140.00 PoIy&oD 6112\10.00 Po.. 611420.00 Pod LoD&itado 149"OS'4O.84SW TARGET DETAILS 1VD +Ni-8 +EI·W Nora.q 8932.16 272&26 -1048.67 S962230.oo 8932.16 1816.34 -932.22 5961320.00 8953.16 1816.34 -932.22 5961320.00 8982.16 1264.42 -810.40 S%077O.oo 8987.16 2998.67 -1072.66 S962SOO.00 8987.16 3246.88 -478.8S S9Q757.oo 8987.16 1361.65 -9SU8 S96086S.00 8987.16 393.25 ·74335 59'-1900.00 8987.16 3637.64 ·995.14 5963140.00 9012.16 389.54 -49335 59'-1900.00 9027.16 47.61 ·368.41 S9S9S60.oo SECfION DETAILS +NI-S +EI-W Homo W.32AA¡v A W-32A A¡v B W-32A T2b W.32A 1'3<1 W·32A aT! W.32A Poly W·32L1 ñDJt2 W·32L1 ñDJt3 W·32L1 ñDJt I W.32A T4b W·32A TS W-32Ll F¿;aUlt I W-32 (W-32) ~ , Start Dir 221100': 9990' MD, 8967.09'1VD /' \ '>000 Start Oir 23/100': 9740' MD, 8827.751VD ~ Start Dir 18/100' : 9680' MD, 8779.51'lVD /\ ~~, Start Oir 12/100': 9660' MD, 8762.99'TVD 9000 ,/ \ '1 - ~ - E?'Í D ir : Q¿, r 13' MD, 8999.55' TVD - 360()- Tæget --- W-32A Agr A W-32AAgrB W-32A T3d W-32A T4b W-32A T5 vSec 930.67 930.67 937.36 1092.27 1424.32 1400.09 1389.64 1348.99 1178.81 1157.29 1131.01 1066.79 965.75 965.72 545.39 539.20 371.48 DLeg TFace 0.00 0.00 12.00 -75.00 18.00 -75.00 23.00 -70.00 22.00 -85.78 0.00 0.00 8.00 -155.18 4.00 -96.82 0.00 0.00 4.00 -164.28 4.00 -159.06 0.00 0.00 4.00 -65.16 4.00 156.08 0.00 0.00 4.00 -163.72 0.00 0.00 -518.36 -516.92 -519.09 -657.55 -1021. 77 -1045.28 -1048.67 -1034.11 -943.90 -932.22 -917.17 -879.32 -810.40 -810.38 -497.96 -493.35 -368.41 3250.79 3261.96 3297.42 3434.68 3207.05 2836.00 2728.26 2523.76 1893.84 1816.34 1727.80 1519.48 1264.42 1264.35 402.19 389.54 47.61 TVD 8762.99 8779.51 8827.75 8967.09 8999.55 8941.48 8932.16 8930.33 8930.12 8932.16 8939.52 8963.14 8982.16 8982.16 9011.67 9012.16 9027.16 MD IDC Azi 9660.00 33.96 9.41 9680.00 34.65 5.33 9740.00 38.69 348.50 9990.00 76.17 293.79 10497.13 98.88 183.63 10873.44 98.88 183.63 10981.74 91.00 180.00 11186.94 90.02 171.85 11823.28 90.02 171.85 11901.69 87.00 171.00 11991.83 83.63 169.70 12204.86 83.63 169.70 12470.14 88.16 160.08 12470.21 88.16 160.08 13387.71 88.16 160.08 13401.18 87.64 159.93 13765.53 87.64 159.93 See 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 8941.481VD 8932.16'lVD 'i Si4l 0.. 8/00' ,/ Sœr ,Dr 4/100' -< W nA"AgrA hN' v.. : f II ¡S..'J4°-"\.1.V, 8930.33' TVD ,/ lC 73.44' MD, :"to7'~1.74' MD, W-j2Aa 3000 2400 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 8748.00 9641.95 TSGR 2 8776.00 9675.74 TSHU 3 8874.00 9802.00 TElL 4 8887.00 9820.89 TSAD/TZ4B 5 8911.00 9858.71 45N 6 8943.00 9919.95 44N 7 8997.00 10133.91 43N CASING DETAILS No. TVD MD Name Size -.-'~ 1 9027.16 13765.52 3 112" 3.500 RKBE. All TVD depths are ssTVD plus 87. 16'for ~~ I ,I ~ ~'l~ ~~ ~~ , ., "v<q, 8930.121VD lE23.28' MD, W 'i: ~ ~ +' ~ ! ~ ::s ~ 800 1200 600 Slut D r 4/ 00 W-l, r2b ./ B '), ~ l!lO L Ir: I Wl.ðJ MD, 8939.52' TVD ~~tar Vir 4/1l J': 1:;:;204.86' MD, 8963.141VD ,("" -m F..,12 ~1bI[;' ,12410.2 'MD,8982.I6'TVD ,v.3¡A 13<1 ~ \ %~ \ \v Sw< D "'1<Y, 13381.11' MD, %11.6nvD V.-.J2L1 rwtt) I - ~nd Di : 13 01.18' MD, 9012.16' TVD W-JZA TIb '\ \ ,. W-3 T~ 3 112" ~ \ ~-3LI 'MJ06 f \ , Total Depth: 13765.53' MD, 9027.16' TVD I 600 I o ·600 West(-)/East(+) [6OOftIin] 200 o .' Ç9mp'~Y: Field: .$ire: .·WeU:··.i. . Wellpªtb: ~.~ .Ar'rlØ9ø' ~tod~B~~ .... PB W,p$ct W-32.......... .....,........ pian W~~2L1, ' ) ) BP KW A Planning Report MAP Dat~: .1q/å,go02 '.. ..Time: 16:25:40 Pªge: C~~rdbt'~(N¥)R.~f~ty..Çe: wen: W-32, True North VertitalŒ~)Reference: RKB 87.16' 87.2 SeWön(V$)Jlefel'ence:. Well (O.ooN,O.OOEt277~36Azi) SUl'Vey Calc~lation .Method: Minimum CurVature Db:,Orac/e. Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Dªtum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB W Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 47.83 ft Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 5957194.18 ft 609919.18 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 31.506 N 149 6 36.343 W True 0.84 deg Well: W-32 Slot Name: W-32 Well Position: +N/-S 2296.31 ft Northing: 5959517.88 ft Latitude: +FJ-W 1903.81 ft Easting : 611789.05 ft Longitude: Position Uncertainty: 0.00 ft 70 17 54.088 N 149 5 40.845 W Wellpath: Plan W-32L 1 Current Datum: Magnetic Data: Field Strength: Vertical Section: RKB 87.16' 8/1/2002 57510 nT Depth From (fVD) ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 W-32 9660.00 ft Mean Sea Level 25.92 deg 80.76 deg Direction deg 277.36 9/30/2002 14 From: Definitive Path Height 87.16 ft +N/-S ft 0.00 Principal: Yes Plan: W-32L 1 wp06 Date Composed: Version: Tied-to: Casing Points MD' il '.'. 13765.52 Formations TvD :·<:.Jti. 9027.16 J>iíl~ter"lJole'$~zei . . : Name ..... ." iri':··..·'r·::·' 3.500 4.750 3 1/2" 9641.95 9675.74 9802.00 9820.89 9858.71 9919.95 10133.91 Targets 8748.00 8776.00 8874.00 8887.00 8911.00 8943.00 8997.00 Name W-32A Agr A W-32A Agr B W-32A T2b W-32A T3d W-32A aT1 . ·lJithølògY.: Dip .·Djte¢ti6~ døg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 nip Angle . deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TSGR TSHU TElL TSADfTZ4B 45N 44N 43N . Map Map <- Latitude --> ~ Longitude--> Destriptión TVD +N/-$ +FJ-W Northing Easting Deg Min See Deg Min Sec Dip. Oil'. ft ft ft ft ft 8932.16 2728.26 -1048.67 5962230.00 610700.00 70 18 20.920 N 149 6 11.426 W 8932.16 1816.34 -932.22 5961320.00 610830.00 70 18 11.951 N 149 6 8.027 W 8953.16 1816.34 -932.22 5961320.00 610830.00 70 18 11.951 N 149 6 8.027 W 8982.16 1264.42 -810.40 5960770.00 610960.00 70 18 6.523 N 149 6 4.473 W 8987.16 2998.67 -1072.66 5962500.00 610672.00 70 18 23.579 N 149 6 12.126 W ) BP KW A Planning Report MAP ') ¢o~pany: ~PArnoco o.te: 10/3120Q2 Time: 16:25:4Q '-ichl: Ptodh()e' Bay C~;.ørdi~at~~)·.ªeference: Well: VV-32, TrueNorth·.·<,\:·...· Site: PBWPad V~Ì1it~1 <Tvp) Iteference: RKB61.16' 87.2.. '.',';" , Well: W-:32 ~ction(V~)Ref~rencel " Well (0.OON,O.00E.277.36Á;i) ',.'" " Wdlpatb: Plan W-321-1 Survey Çalc~.atioò Metbod: Minimum Curvature ,',t)~: Targets ,M~p·.··. ~ap <--.'~aijtude-'-> ~.,·i~4#gitud~"~.·". Description rVD +N¡'~ +E/-W ~9Ì'tþi~g Ji1it'ting Deg~in Sec,' ~~~(~~D S~" " Dip. Dir. ft ,'ft " '(t' ""'ff',' 'ft \".',,:'.,1',"::',"'\ " . W-32A Poly 8987.16 3246.88 -478.85 5962757.00 611262.00 70 18 26.021 N 149 5 54.810 W -Polygon 1 8987.16 3253.88 -478.75 5962764.00 611262.00 70 18 26.090 N 149 5 54.807 W -Polygon 2 8987.16 3568.76 -534.07 5963078.00 611202.00 70 18 29.187 N 149 5 56.421 W -Polygon 3 8987.16 3574.60 -926.06 5963078.01 610810.00 70 18 29.244 N 149 6 7.853 W -Polygon 4 8987.16 3280.37 -1183.49 5962780.00 610557.00 70 18 26.349 N 149 6 15.360 W -Polygon 5 8987.16 2399.63 -1212.60 5961899.00 610541.00 70 18 17.687 N 149 6 16.205 W -Polygon 6 8987.16 1759.42 -1140.10 5961260.00 610623.01 70 18 11.391 N 149 6 14.0138 W -Polygon 7 8987.16 1464.81 -968.45 5960968.00 610799.01 70 18 8.494 N 149 6 9.082 W -Polygon 8 8987.16 1266.07 -921.40 5960770.00 610849.00 70 18 6.539 N 149 6 7.709 W I -Polygon 9 8987.16 1079.24 -935.18 5960583.00 610838.00 70 18 4.702 N 149 6 8.110 W -Polygon 10 8987.16 -130.82 -678.13 5959377.00 611113.00 70 17 52.801 N 149 6 0.613 W -Polygon 11 8987.16 -73.18 -115.16 5959443.00 611675.00 70 17 53.368 N 149 544.202 W -Polygon 12 8987.16 921.48 -348.41 5960434.00 611427.00 70 18 3.151 N 149 5 51.003 W -Polygon 13 8987.16 1003.74 -633.25 5960512.01 611141.00 70 18 3.960 N 149 5 59.307 W -Polygon 14 8987.16 1230.20 -728.90 5960737.00 611042.00 70 18 6.187 N 149 6 2.097 W -Polygon 15 8987.16 1855.64 -884.62 5961360.00 610877.01 70 18 12.338 N \ 149 6 6.639 W ·Polygon 16 8987.16 3259.61 -863.74 5962764.00 610877.00 70 18 26.146 N 149 6 6.035 W W-32L 1 Fault 2 8987.16 1361.65 -958.98 5960865.00 610810.00 70 18 7.479 N 149 6 8.805 W -Polygon 1 8987.16 1361.65 -958.98 5960865.00 610810.00 70 18 7.479 N 149 6 8.805 W -Polygon 2 8987.16 1222.93 -710.99 5960730.00 611060.00 70 18 6.115 N 149 6 1.575 W W-32L 1 Fault 3 8987.16 393.25 -743.35 5959900.00 611040.00 70 17 57.955 N 149 6 2.515 W -Polygon 1 8987.16 393.25 -743.35 5959900.00 611040.00 70 17 57.955 N 149 6 2.515 W -Polygon 2 8987.16 386.41 -283.36 5959900.00 611500.00 70 17 57.888 N 149 5 49.106 W W-32L 1 Fault 1 8987.16 3637.64 -995.14 5963140.00 610740.00 70 18 29.863 N 149 6 9.868 W -Polygon 1 8987.16 3637.64 -995.14 5963140.00 610740.00 70 18 29.863 N 149 6 9.868 W -Polygon 2 8987.16 3253.93 -750.80 5962760.00 610990.00 70 18 26.090 N 149 6 2.741 W W-32A T 4b 9012.16 389.54 -493.35 5959900.00 611290.00 70 17 57.919 N 149 5 55.228 W W·32A T5 9027.16 47.61 -368.41 5959560.00 611420.00 70 17 54.556 N 149 5 51.585 W Plan Section Information MD "'i'lncl Azim TvD" +N/-S +ÊI-w "ÖLS : '~û'uCî""-"/turn 11FO' Tå.tgef_ ft deg deg ft ft ft deg/100ft deg/100ft deg/10Oft deg 9660.00 33.96 9.41 8762.99 3250.79 -518.36 0.00 0.00 0.00 0.00 9680.00 34.65 5.33 8779.51 3261.96 -516.92 12.00 3.45 -20.40 -75.00 9740.00 38.69 348.50 8827.75 3297.42 -519.09 18.00 6.74 -28.05 -75.00 9990.00 76.17 293.79 8967.09 3434.68 -657.55 23.00 14.99 -21.88 -70.00 10497.13 98.88 183.63 8999.55 3207.05 -1021.77 22.00 4.48 -21.72 -85.78 10873.44 98.88 183.63 8941.48 2836.00 -1045.28 0.00 0.00 0.00 0.00 10981.74 91.00 180.00 8932.16 2728.26 -1048.67 8.00 -7.27 -3.35 -155.18 W-32A Agr A 11186.94 90.02 171.85 8930.33 2523.76 -1034.11 4.00 -0.48 -3.97 -96.82 11823.28 90.02 171.85 8930.12 1893.84 -943.90 0.00 0.00 0.00 0.00 11901.69 87.00 171.00 8932.16 1816.34 -932.22 4.00 -3.85 -1.08 -164.28 W-32A Agr B 11991.83 83.63 169.70 8939.52 1727.80 -917.17 4.00 -3.73 -1.44 -159.06 12204.86 83.63 169.70 8963.14 1519.48 -879.32 0.00 0.00 0.00 0.00 12470.14 88.16 160.08 8982.16 1264.42 -810.40 4.00 1.71 -3.63 -65.16 W-32A T3d 12470.21 88.16 160.08 8982.16 1264.35 -810.38 4.00 -3.66 1.62 156.08 13387.71 88.16 160.08 9011.67 402.19 -497.96 0.00 0.00 0.00 0.00 13401.18 87.64 159.93 9012.16 389.54 -493.35 4.00 -3.84 -1.12 -163.72 W-32A T 4b 13765.53 87.64 159.93 9027.16 47.61 -368.41 0.00 0.00 0.00 0.00 W-32A T5 ') BP ) KW A Planning Report MAP Cornpa~y: BP Amoco D~~~:1Q/3/2002. . ................. . Tiriae: 16:2~:<40 Page: 3 . Field: prudhoê Bay CØ7~r~~...~è(~)~~~~~ee: i WeU:W~~;True North Site: PB W Pad Vertical (fvD) Reference;' RKaa<!ije'87.2 Well: W-32 Section (VS) Reference: Well. (Q;qoN,O.00E,277.36Azi) .... Wellpath: Plan W-32L 1 ,Stltye~Ç~lculation M¢~~()d: MînimUm.Curvature Db;·· .·.·Oracle Survey MJ)' Incl ' Azim T'V.Ìl SystVD M.pN DLS.,. '.' : ToQl/Comment ff deg . deg ftt ,'ft i~ ., de9!1~ø.ft:, 9641.95 33.82 8.88 8748.00 8660.84 5962750.36 611220.98 930.98 0.00 TSGR 9660.00 33.96 9.41 8762.99 8675.83 5962760.32 611222.43 930.67 1.80 Start Dir 12/100' : 9660' MD, 9675.00 34.46 6.33 8775.39 8688.23 5962768.68 611223.46 930.59 12.00 MWD+IFR+MS 9675.74 34.49 6.19 8776.00 8688.84 5962769.10 611223.50 930.60 12.00 TSHU 9680.00 34.65 5.33 8779.51 8692.35 5962771.51 611223.71 930.67 12.00 Start Dir 18/100' : 9680' MD, 9700.00 35.73 359.37 8795.86 8708.70 5962783.02 611224.00 931.68 18.00 MWD+IFR+MS 9725.00 37.46 352.40 8815.94 8728.78 5962797.84 611222.69 934.66 18.00 MWD+IFR+MS 9740.00 38.69 348.50 8827.75 8740.59 5962806.93 611221.02 937.36 18.00 Start Dir 23/100' : 9740' MD, 9760.00 40.46 341.83 8843.17 8756.01 5962819.18 611217.56 942.18 23.00 MWD+IFR+MS 9780.00 42.58 335.67 8858.15 8770.99 5962831.44 611212.57 948.53 23.00 MWD+IFR+MS 9800.00 45.01 330.02 8872.59 8785.43 5962843.65 611206.06 956.38 23.00 MWD+IFR+MS 9802.00 45.27 329.48 8874.00 8786.84 5962844.86 611205.33 957.25 23.00 TElL 9820.00 47.69 324.85 8886.40 8799.24 5962855.71 611198.09 965.68 23.00 MWD+IFR+MS 9820.89 47.82 324.63 8887.00 8799.84 5962856.24 611197.70 966.12 23.00 TSADrrZ4B, 9840.00 50.58 320.12 8899.49 8812.33 5962867.55 611188.69 976.35 23.00 MWD+IFR+MS 9858.71 53.45 316.05 8911.00 8823.84 5962878.36 611178.68 987.53 23.00 45N 9860.00 53.65 315.78 8911.77 8824.61 5962879.10 611177.95 988.34 23.00 MWD+IFR+MS 9880.00 56.87 311.77 8923.17 8836.01 5962890.28 611165.91 1001.57 23.00 MWD+IFR+MS 9900.00 60.20 308.06 8933.61 8846.45 5962901.01 611152.66 1015.95 23.00 MWD+IFR+MS 9919.95 63.63 304.59 8943.00 8855.84 5962911.22 611138.33 1031.34 23.00 44N 9920.00 63.64 304.58 8943.02 8855.86 5962911.24 611138.29 1031.38 23.00 MWD+IFR+MS 9940.00 67.15 301.31 8951.35 8864.19 5962920.89 611122.89 1047.78 23.00 MWD+IFR+MS 9944.74 67.99 300.56 8953.16 8866.00 5962923.09 611119.10 1051.80 23.00 W-32A T2b 9960.00 70.72 298.21 8958.54 8871.38 5962929.91 611106.56 1065.03 23.00 MWD+IFR+MS 9980.00 74.34 295.24 8964.55 8877.39 5962938.22 611089.40 1083.03 23.00 MWD+IFR+MS 9990.00 76.17 293.79 8967.09 8879.93 5962942.10 611080.54 1092.27 23.00 Start Dir 22/100' : 9990' MD, 10000.00 76.34 291.53 8969.47 8882.31 5962945.71 611071.53 1101.64 22.00 MWD+IFR+MS 10025.00 76.86 285.91 8975.26 8888.10 5962953.17 611048.39 1125.47 22.00 MWD+IFR+MS 10050.00 77.50 280.30 8980.82 8893.66 5962958.34 611024.58 1149.71 22.00 MWD+IFR+MS 10075.00 78.26 274.73 8986.07 8898.91 5962961.17 611000.32 1174.15 22.00 MWD+IFR+MS 10080.40 78.43 273.53 8987.16 8900.00 5962961.4 7 610995.04 1179.43 22.00 W-32L 1 Fault 1 10100.00 79.12 269.19 8990.98 8903.82 5962961.64 610975.82 1198.54 22.00 MWD+IFR+MS 10125.00 80.08 263.69 8995.49 8908.33 5962959.75 610951.32 1222.67 22.00 MWD+IFR+MS 10133.91 80.45 261.73 8997.00 8909.84 5962958.51 610942.62 1231.17 22.00 43N 10150.00 81.13 258.21 8999.58 8912A2 5962955.51 610927.03 1246.32 22.00 MWD+IFR+MS 10175.00 82.26 252.77 9003.19 8916.03 5962948.96 610903.19 1269.27 22.00 MWD+IFR+MS 10200.00 83.46 247.36 9006.30 8919.14 5962940.16 610880.01 1291.31 22.00 MWD+IFR+MS 10225.00 84.72 241.98 9008.88 8921.72 5962929.19 610857.70 1312.22 22.00 MWD+IFR+MS 10250.00 86.02 236.62 9010.90 8923.74 5962916.16 610836.48 1331.84 22.00 MWD+IFR+MS 10275.00 87.35 231.27 9012.34 8925.18 5962901.18 610816.53 1349.96 22.00 MWD+IFR+MS 10300.00 88.71 225.94 9013.20 8926.04 5962884.39 610798.05 1366.42 22.00 MWD+IFR+MS 10325.00 90.08 220.61 9013.46 8926.30 5962865.94 610781.19 1381.08 22.00 MWD+IFR+MS 10350.00 91.45 215.29 9013.13 8925.97 5962846.01 610766.12 1393.80 22.00 MWD+IFR+MS 10375.00 92.81 209.95 9012.20 8925.04 5962824.78 610752.97 1404.45 22.00 MWD+IFR+MS 10400.00 94.14 204.61 9010.68 8923.52 5962802.45 610741.87 1412.95 22.00 MWD+IFR+MS 10425.00 95.44 199.24 9008.59 8921.43 5962779.21 610732.91 1419.22 22.00 MWD+IFR+MS 10450.00 96.69 193.86 9005.95 8918.79 5962755.29 610726.19 1423.18 22.00 MWD+IFR+MS 10475.00 97.88 188.44 9002.77 8915.61 5962730.91 610721.76 1424.82 22.00 MWD+IFR+MS 10497.13 98.88 183.63 8999.55 8912.39 5962709.11 610719.78 1424.32 22.00 End Dir : 10497.13' MD, 8999. 10500.00 98.88 183.63 8999.10 8911.94 5962706.28 610719.64 1424.13 0.00 MWD+IFR+MS 10600.00 98.88 183.63 8983.67 8896.51 5962607.60 610714.86 1417.70 0.00 MWD+IFR+MS 10700.00 98.88 183.63 8968.24 8881.08 5962508.92 610710.08 1411.26 0.00 MWD+IFR+MS 10800.00 98.88 183.63 8952.81 8865.65 5962410.24 610705.30 1404.82 0.00 MWD+IFR+MS ') BP ") KW A Planning Report MAP '", BPA@p<;Q ç~~~.ny: J)j~e; ,1()/3~002 , " Time: 16:25:40 Pa.e: 4 ·F'i~.~: . ,:;)ru<:!tïøe Bay C:o.0rdi~t~~) Reference: Well: W-32, True North $ite; PSWPad Ye,rti¢al<TW1Referel1ce: RKB 87.16'81.2 ',,' " : . We'.: W-3,2, SecUøn(VS)ï!eference: Well (0.OON,O.OOE,271.36Azi) ,', ",. .Wellpatb: Plari"V-32L1 . SarveýÇalcU)ation Method: Minimum Curvature ,Db: Oracle Survey Aziß¡ TVD SystvD · .1\(~"l'l' vs DLS '·í:ooJlCommelÌt ~~g. ft ,It 'ft ft deg/1 OOft 10873.44 98.88 183.63 8941.48 8854.32 5962337.78 610701.79 1400.09 0.00 Start Dir 8/100' : 10873.44' M 10900.00 96.95 182.73 8937.82 8850.66 5962311.49 610700.72 1398.17 8.00 MWD+IFR+MS 10950.00 93.31 181.05 8933.35 8846.19 5962261.72 610699.82 1393.42 8.00 MWD+IFR+MS 10981.74 91.00 180.00 8932.16 8845.00 5962230.00 610700.00 1389.64 8.00 W-32A Agr A 11000.00 90.91 179.27 8931.86 8844.70 5962211.75 610700.39 1387.19 4.00 MWD+IFR+MS 11100.00 90.44 175.30 8930.68 8843.52 5962111.98 610706.60 1369.70 4.00 MWD+IFR+MS 11186.94 90.02 171.85 8930.33 8843.17 5962025.77 610717.61 1348.99 4.00 End Dir : 11186.94' MD, 8930. 11200.00 90.02 171.85 8930.33 8843.17 5962012.87 610719.65 1345.50 0.00 MWD+IFR+MS 11300.00 90.02 171.85 8930.29 8843.13 5961914.11 610735.30 1318.75 0.00 MWD+IFR+MS 11400.00 90.02 171.85 8930.26 8843.10 5961815.35 610750.94 1292.01 0.00 MWD+IFR+MS 11500.00 90.02 171.85 8930.23 8843.07 5961716.59 610766.59 1265.27 0.00 MWD+IFR+MS 11600.00 90.02 171.85 8930.19 8843.03 5961617.83 610782.23 1238.52 0.00 MWD+IFR+MS 11700.00 90.02 171.85 8930.16 8843.00 5961519.07 610797.88 1211.78 0.00 MWD+IFR+fy1S 11800.00 90.02 171.85 8930.13 8842.97 5961420.31 610813.52 1185.03 0.00 MWD+IFR+MS 11823.28 90.02 171.85 8930.12 8842.96 5961397.31 610817.16 1178.81 0.00 Start Dir 4/100' : 11823.28' M 11901.69 87.00 171.00 8932.16 8845.00 5961320.00 610830.00 1157.29 4.00 W-32A Agr B 11991.83 83.63 169.70 8939.52 8852.36 5961231.70 610846.36 1131.01 4.00 End Dir : 11991.83' MD, 8939. 12000.00 83.63 169.70 8940.42 8853.26 5961223.73 610847.94 1128.55 0.00 MWD+IFR+MS 12100.00 83.63 169.70 8951.51 8864.35 5961126.23 610867.15 1098.40 0.00 MWD+IFR+MS 12204.86 83.63 169.70 8963.14 8875.98 5961023.99 610887.30 1066.79 0.00 Start Dir 4/100' : 12204.86' M 12300.00 85.24 166.24 8972.36 8885.20 5960931.71 610908.40 1035.36 4.00 MWD+IFR+MS 12400.00 86.95 162.61 8979.17 8892.01 5960836.04 610936.61 996.48 4.00 MWD+IFR+MS 12470.14 88.16 160.08 8982.16 8895.00 5960770.00 610960.00 965.75 4.00 W-32A T3d 12470.21 88.16 160.08 8982.16 8895.00 5960769.93 610960.03 965.72 4.00 End Dir : 12470.21' MD, 8982. 12500.00 88.16 160.08 8983.12 8895.96 5960742.09 610970.59 952.07 0.00 MWD+IFR+MS 12600.00 88.16 160.08 8986.34 8899.18 5960648.65 611006.03 906.26 0.00 MWD+IFR+MS 12700.00 88.16 160.08 8989.55 8902.39 5960555.21 611041.47 860.44 0.00 MWD+IFR+MS 12800.00 88.16 160.08 8992.77 8905.61 5960461.76 611076.91 814.63 0.00 MWD+IFR+MS 12900.00 88.16 160.08 8995.98 8908.82 5960368.32 611112.35 768.82 0.00 MWD+IFR+MS 13000.00 88.16 160.08 8999.20 8912.04 5960274.87 611147.80 723.01 0.00 MWD+IFR+MS 13100.00 88.16 160.08 9002.41 8915.25 5960181.43 611183.24 677.20 0.00 MWD+IFR+MS 13200.00 88.16 160.08 9005.63 8918.47 5960087.99 611218.68 631.38 0.00 MWD+IFR+MS 13300.00 88.16 160.08 9008.85 8921.69 5959994.54 611254.12 585.57 0.00 MWD+IFR+MS 13387.71 88.16 160.08 9011.67 8924.51 5959912.58 611285.21 545.39 0.00 Start Dir4/100': 13387.71' M 13401.18 87.64 159.93 9012.16 8925.00 5959900.00 611290.00 539.20 4.00 W-32A T 4b 13500.00 87.64 159.93 9016.23 8929.07 5959807.78 611325.25 493.72 0.00 MWD+IFR+MS 13600.00 87.64 159.93 9020.35 8933.19 5959714.47 611360.93 447.68 0.00 MWD+IFR+MS 13700.00 87.64 159.93 9024.46 8937.30 5959621.15 611396.61 401.65 0.00 MWD+IFR+MS 13765.52 87.64 159.93 9027.16 8940.00 5959560.00 611419.98 371.49 0.00 W-32A T5 13765.51 87.64 159.93 9027.16 8940.00 5959560.01 611419.98 371.50 0.00 Total Depth: 13765.53' MD, 90 13765.53 87.64 159.93 9027.16 8940.00 5959560.00 611420.00 371.48 0.00 MWD+IFR+MS Tool MWD+IFR+'s SUR.VEY PROGRAM SoM:yiPlm I'tomcd W-32L1 wp06 VI. 0epIb & De>Ih To 9660.00 1316S.53 OOMPANY Ð£TAILS nAmoco CaIcûIioa MeÞd: Mi:irœm c.- &tor Syotom: ISCWSA Sam MeIbod: T_ CyIiodcr Norf¡ W'::= ~~CaiÐ& ANTI-COLLISION SETTINGS IDtc:rpoIation MedIod:MD 1nIerwI: 25.00 Depth Range From: 9660.00 To: 13765.53 Maximum Rqe: 1573.15 Reference: Plan; W-32LI SIo. NlA WElL Ð£T AJl.S Mcd>inc &.q LoIiIDcIo l..qjbIðe ~17A8 611789.05 1OOITS4.088N 149'1)S'.().34SW +EJ·W I90UI ~ +NI-8 W·J2 2296.3/ ~ -- waLPA 111 DETAILS !'1m W-32Ll P.... W~ W-32 r.....!oID: 9660.00 RiI: Rot lJoIImr RKB 81.16' 81.1611 v~ = +~ ~ 271.36" 0.00 0.00 0.00 VSOC TatfI"I 930.67 930.67 937.36 /09227 142432 1400.09 13119.64 W-32A Ap A 1348.99 1178.81 1157.29 W-32A Ap B 113\.01 1066.79 965.75 W-32A T3d 965.n· S4539 539.20 W-32A T4b 371.48 W-32A TS IEGEND -. MPOO1511 12 (MPOO1S1112), MoJor R;ü; - W-19A(W-J9A),MIIjo<Riå: - W-19(W·19),Maj«1ü* - W-24(W-24).Maj«1ü* = ~:~~:~~~~RS - W·J6 (W-36). Mojo< Iü* - PIao W-32t1 - W-32t1 wp06 1Focc 0.00 -75.00 -75.00 -70.00 -85.1& 0.00 -155.18 -96.82 0.00 -164.28 -159.06 0.00 ~.16 156.08 0.00 -163.n 0.00 ~ 0.00 12.00 18.00 23.00 22.00 0.00 8.00 4.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 4.00 0.00 SECI10N DETAILS +NI-8 +EI-W 3250.79 -518.36 3261.96 -516.92 3297.42 -519.09 3434.68 ~.55 3207.05 ·102\.71 2836.00 -1045.28 2728.26 -1048.67 2523.76 -1034.11 1893.34 -943.90 1816.34 -932.22 m7.80 -917.17 1519.48 -87932 1264.42 -810.40 126435 -810.38 402.19 -491.96 389.54 -493.35 47.61 -368.41 ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 6000 8000 11000 12000 15000 1VD 8162.99 8719.51 8827.75 8967.09 8999.55 8941.48 8932.16 8930.33 8930.12 8932.16 8939.52 8963.14 8982.16 8982.16 9011.67 9012.16 9027.16 ~ I W tv MD In< Azi 9660.00 33.96 9.41 9680.00 34.6S 533 9740.00 38.69 348.SO 9990.00 76.17 2!J3.79 10497.13 98.88 183.63 10873.44 98.88 183.63 10981.74 91.00 180.00 11186.94 90.02 I7U5 11823.28 90.02 I7US 1190\.69 81.00 171.00 11991.83 83.63 169.70 1220U6 83.63 169.70 12410.14 88.16 160.08 12470.21 88..6 160.08 13381.71 88.16 160.08 13401.1& 87.64 159.93 13165.53 81.64 159.93 From Colour o 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 o 6000 8000 II 000 12000 90 wp06 See 1 2 3 4 S 6 7 & 9 10 II 12 13 14 15 16 17 o -128 -120 -100 -0 270 -20 -40 -60 --80 -100 -120 -128 -60 ~o -20 --80 cÍ::'~ '~~J~J.3arati~:\1'in] . --. . -' - -- ~ - - ~ .-'~ --, - .&....;;- -'':~- _" ._ "'~ _~~;,_ --::: _~~;:-,:o--...;::,",,---:::_:: __~~";-'_. 18et 28 Tt~;~~f;~ind{~~~'(~p;~~:s ) ) BP Anticollision Report ,ço~pa~y:$PÅmqe;q Time: 15:52:20PII~è: '~¡~.~J..·.~ru.(f~~:i~~Y :Relèrence Site: et3 V\lPElØ . Co--ordiollte(NE)kefereooo: Well: W-32, True Nörth R.¢t~tè~(1eW~U: .... ./W-32, Vè~tal(l'VD)~~ference: RKB 87:16'87.2 'ª~"~~nce Wellp~~b:plan, W~32L1iJ)b:.,Oracle. GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There ar~"ells in thfil~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9660.00 to 13765.53 ft Scan Method: Trav Cylinder North Maximum Radius: 1573.15 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/1/2002 Validated: No Planned From To Survey ft ft 44.44 9660.00 1 : Schlumberger GCT multishot 9660.00 13765.53 Planned: W-32L 1 wp06 V14 Casing Points . MD , ft 13765.52 TVD ft 9027.16 ~~~r '~rf .... 3.500 Summary ";;Q~tWe,,~åth" . '. .:,:\V.eU' ,:'i),.'?':. '.' .', ,'.'1 PB MPTR3 PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad MP00151112 W-19A W-19 W-24 W-29 W-32 W-36 Site: PB W Pad Well: W-19A Wellpath: W-19A V5 ,~:ife~tff..· 10275.00 9012.34 10275.00 9012.34 10275.00 9012.34 10275.00 9012.34 10275.00 9012.34 ':Qft"~f ........ '.' . MD." .' ,'1VD': ." 'ft::·ft 9500.00 7714.80 9525.00 7733.25 9550.00 7751.73 9575.00 7770.23 9600.00 7788.75 ~~1~~$1~::. ......' :Nj~: ". '.,:'.:JQ".¡"':. 4.750 3 1/2" ;).:;'<":.,1, ,; 1>/::,", "I. ,':';;~ ,,', ":";", ·;.WçÜ;p,~~b.··: "':1,.0;" I'" MP00151112 V1 W-19A V5 W-19 V1 W-24 V1 W-29 V1 W-32 V1 W-36 V1 '. I··..""'" ¡;/ :. ¡.;: "'or I Version: 3 T oolcode GCT -MS MWD+IFR+MS '!RetÙênce:Ott~t ···~·.Mn, ·Mg ,::ft" ··ft .... Tool Name Schlumberger GCT multishot MWD + IFR + Multi Station ¢~~þ-'.No-Go . Distance' Area "ft ,. '. ft ";OW:~}~~~~,r · Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk FAIL: Major Risk Out of range 10260.93 9925.00 1516.70 162.97 1356.24 10260.93 9925.00 1516.70 162.97 1356.24 13098.87 8675.00 1266.72 152.46 1122.45 10603.21 9900.00 1516.67 192.99 1329.63 9671.30 9675.00 0.15 186.92 -179.18 ,&ÎJii.Måjø~:;Gi$'. ". .... .... ....' : . >. . . ...... ..... ". ,~~f" ~~~ ." ,1'~0+~:r;FO-HS.ÇasÎlig . .' ,·ft" " ..' ........ ;~.;:·:·¡,dElg . ",c:føg In 20.26 22.02 265.68 34.41 20.26 22.13 266.56 35.28 20.26 22.24 267.43 36.16 20.26 22.35 268.31 37.04 20.26 22.46 269.20 37.93 Rule Assigned: Inter-Site Error: C~"';;Cµo'No-GO .Di~ta~~Area :<ft·, ft 1570.03 159.93 1563.81 160.26 1557.92 160.59 1552.34 160.92 1547.12 161.26 Major Risk 0.00 ft "" ~i::~ ". W~~!'¢ 1421.53 Pass 1414.29 Pass 1407.39 Pass 1400.82 Pass 1394.62 Pass 10275.00 9012.34 9625.00 7807.25 20.26 10275.00 9012.34 9650.00 7825.72 20.26 10275.00 9012.34 9675.00 7844.17 20.26 10275.00 9012.34 9700.00 7862.59 20.26 10275.00 9012.34 9725.00 7881.01 20.26 10275.00 9012.34 9750.00 7899.42 20.26 10275.00 9012.34 9775.00 7917.82 20.26 10265.48 9011.86 9800.00 7936.22 20.06 10264.51 9011.81 9825.00 7954.62 20.04 10263.57 9011.75 9850.00 7973.02 20.02 10262.67 9011.70 9875.00 7991.42 20.00 10261.79 9011.65 9900.00 8009.81 19.98 10260.93 9011.60 9925.00 8028.20 19.96 10260.08 9011.55 9950.00 8046.57 19.94 10250.00 9010.90 9975.00 8064.91 19.73 10250.00 9010.90 10000.00 8083.22 19.73 10250.00 9010.90 10025.00 8101.49 19.73 10250.00 9010.90 10050.00 8119.73 19.73 10250.00 9010.90 10075.00 8137.95 19.73 10250.00 9010.90 10100.00 8156.17 19.73 22.57 270.10 22.68 270.99 22.77 271.90 22.84 272.80 22.89 273.71 22.94 274.63 22.99 275.55 22.90 278.42 22.93 279.55 22.98 280.67 23.05 281.78 23.15 282.89 23.24 284.00 23.34 285.11 23.32 288.03 23.42 288.97 23.53 289.90 23.64 290.83 23.75 291.75 23.86 292.67 38.82 39.72 40.62 41.53 42.44 43.36 44.27 45.12 46.03 46.95 47.87 48.80 49.72 50.64 51.41 52.35 53.28 54.21 55.13 56.06 1542.28 161.59 1388.84 1537.86 161.91 1383.50 1533.86 162.18 1378.66 1530.30 162.39 1374.34 1527.14 162.56 1370.48 1524.42 162.70 1367.12 1522.12 162.84 1364.20 1520.11162.141362.21 1518.61 162.20 1360.24 1517.52 162.31 1358.65 1516.84 162.48 1357.46 1516.57 162.72 1356.64 1516.70 162.97 1356.24 1517.25 163.23 1356.30 1518.36 162.68 1357.75 1519.78 162.99 1358.72 1521.63 163.30 1360.15 1523.91 163.62 1362.03 1526.60 163.95 1364.35 1529.68 164.29 1367.09 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass ') BP ') Anticollision Report ,ç~mJ)any: BP Amoco Date: 10/312002 Time: 15:52:20 , ". .J,f~~.~:,.',,' .':".' , """>' Prudhöe Bøy ., î~rereDe(\Sit~; PB W Pad Co-ordinate(NE) Referenee: ~eterençeW~~':; W~32 Vertical (TVD) Refetence: . Jle(erenee_'Y~llpath: PlanW~32L 1 Site: PB W Pad Well: W-19A Rule Assigned: Major Risk Wellpath: W~19A V5 Inter~Site Error: 0.00 ft .'R~~~ôçe otr~t '~~¡'M.j~r~is "","',. "" ",.""; 9~Ç~. No"<;o Auowa~I~)."',", i:'··" ~:':, :r:,:~':,: ":::'.\;' ;,::,:':: ....:;': ': ii, :: :' ". MD TVD ,MD TVD Ref Oflšêt TfO+AZI TFO-HS Casing niStanCé Area Deviation' '. W.rij~Dg ,.' 11 ft ft ft ,", ft ft deg deg in ft ft ft ,.1::..":, õ:' ,;'".,,':" 10250.00 9010.90 10125.00 8174.39 19.73 23.97 293.59 56.97 1533.13 164.63 1370.22 Pass 10250.00 9010.90 10150.00 8192.63 19.73 24.09 294.50 57.89 1536.94 164.98 1373.74 Pass 10250.00 9010.90 10175.00 8210.87 19.73 24.20 295.41 58.79 1541.08 165.32 1377.63 Pass 10250.00 9010.90 10200.00 8229.11 19.73 24.32 296.31 59.69 1545.59 165.67 1381.92 Pass 10250.00 9010.90 10225.00 8247.32 19.73 24.43 297.21 60.59 1550.49 166.00 1386.64 Pass 10250.00 9010.90 10250.00 8265.45 19.73 24.54 298.10 61.48 1555.86 166.33 1391.87 Pass 10250.00 9010.90 10275.00 8283.49 19.73 24.64 298.98 62.36 1561.70 166.64 1397.49 Pass 10250.00 9010.90 10300.00 8301.44 19.73 24.74 299.85 63.23 1568.00 166.95 1403.54 Pass Site: PB W Pad Well: W-19 Rule Assigned: Major Risk Wellpath: W-19 V1 Inter-Site Error: 0.00 ft ""<",",' ~g~~~'~¥VD ""',', ,()ffset ' ~mi-Major Axis ' dt~~tr,', No-Go" ',Allowabi~ ., '. : .\. :''':. ," :!,::,,' 'f·'·,' . ',:MD' TVD "'Ref Offset TFO+µI TF()~HS Casing Di~t~.ice ' Area ",", ineviatiou . WatÎdng,. ......,.. , : ,ft 'ft ' ".,',.:'ft " ,ft, ",ft ft ,deg deg in ',:;ft-' ft, ". ft .~ };.: :. ,,' ," .. ~.: ";" ï " 10275.00 9012.34 9500.00 7714.80 20.26 22.02 265.68 34.41 1570.03 159.93 1421.53 Pass 10275.00 9012.34 9525.00 7733.25 20.26 22.13 266.56 35.28 1563.81 160.26 1414.29 Pass 10275.00 9012.34 9550.00 7751.73 20.26 22.24 267.43 36.16 1557.92 160.59 1407.39 Pass 10275.00 9012.34 9575.00 7770.23 20.26 22.35 268.31 37.04 1552.34 160.92 1400.82 Pass 10275.00 9012.34 9600.00 7788.75 20.26 22.46 269.20 37.93 1547.12 161.26 1394.62 Pass 10275.00 9012.34 9625.00 7807.25 20.26 22.57 270.10 38.82 1542.28 161.59 1388.84 Pass 10275.00 9012.34 9650.00 7825.72 20.26 22.68 270.99 39.72 1537.86 161.91 1383.50 Pass 10275.00 9012.34 9675.00 7844.17 20.26 22.77 271.90 40.62 1533.86 162.18 1378.66 Pass 10275.00 9012.34 9700.00 7862.59 20.26 22.84 272.80 41.53 1530.30 162.39 1374.34 Pass 10275.00 9012.34 9725.00 7881.01 20.26 22.89 273.71 42.44 1527.14 162.56 1370.48 Pass 10275.00 9012.34 9750.00 7899.42 20.26 22.94 274.63 43.36 1524.42 162.70 1367.12 Pass 10275.00 9012.34 9775.00 7917.82 20.26 22.99 275.55 44.27 1522.12 162.84 1364.20 Pass 10265.48 9011.86 9800.00 7936.22 20.06 22.90 278.42 45.12 1520.11 162.14 1362.21 Pass 10264.51 9011.81 9825.00 7954.62 20.04 22.93 279.55 46.03 1518.61 162.20 1360.24 Pass 10263.57 9011.75 9850.00 7973.02 20.02 22.98 280.67 46.95 1517.52 162.31 1358.65 Pass 10262.67 9011.70 9875.00 7991.42 20.00 23.05 281.78 47.87 1516.84 162.48 1357.46 Pass 10261.79 9011.65 9900.00 8009.81 19.98 23.15 282.89 48.80 1516.57 162.72 1356.64 Pass 10260.93 9011.60 9925.00 8028.20 19.96 23.24 284.00 49.72 1516.70 162.97 1356.24 Pass 10260.08 9011.55 9950.00 8046.57 19.94 23.34 285.11 50.64 1517.25 163.23 1356.30 Pass 10250.00 9010.90 9975.00 8064.91 19.73 23.32 288.03 51.41 1518.36 162.68 1357.75 Pass 10250.00 9010.90 10000.00 8083.22 19.73 23.42 288.97 52.35 1519.78 162.99 1358.72 Pass 10250.00 9010.90 10025.00 8101.49 19.73 23.53 289.90 53.28 1521.63 163.30 1360.15 Pass 10250.00 9010.90 10050.00 8119.73 19.73 23.64 290.83 54.21 1523.91 163.62 1362.03 Pass 10250.00 9010.90 10075.00 8137.95 19.73 23.75 291.75 55.13 1526.60 163.95 1364 .35 Pass 10250.00 9010.90 10100.00 8156.17 19.73 23.86 292.67 56.06 1529.68 164.29 1367.09 Pass 10250.00 9010.90 10125.00 8174.39 19.73 23.97 293.59 56.97 1533.13 164.63 1370.22 Pass 10250.00 9010.90 10150.00 8192.63 19.73 24.09 294.50 57.89 1536.94 164.98 1373.74 Pass 10250.00 9010.90 10175.00 8210.87 19.73 24.20 295.41 58.79 1541.08 165.32 1377.63 Pass 10250.00 9010.90 10200.00 8229.11 19.73 24.32 296.31 59.69 1545.59 165.67 1381.92 Pass 10250.00 9010.90 10225.00 8247.32 19.73 24.43 297.21 60.59 1550.49 166.00 1386.64 Pass 10250.00 9010.90 10250.00 8265.45 19.73 24.54 298.10 61.48 1555.86 166.33 1391.87 Pass 10250.00 9010.90 10275.00 8283.49 19.73 24.64 298.98 62.36 1561.70 166.64 1397.49 Pass 10250.00 9010.90 10300.00 8301.44 19.73 24.74 299.85 63.23 1568.00 166.95 1403.54 Pass ) BP Anticollision Report ) Company: Elf) Amocc) ..Field: eru,dh()(;),:~åy JlefêrenceSite: R$W Pliiqi . Reference Well: . VY·32,. ""'" .'. 'Reference Wellpath: PlanW..32L1 Site: PB W Pad Well: W-24 Wellpatb: W-24 V1 Rer~rel1ce TVD ft 13415.55 9012.75 13408.62 9012.47 13401.66 9012.18 13397.30 9012.00 13393.04 9011.85 'Õtlstt ·$èüd2M¡j~Í'. ^*i~.·'··.··· ....../.,.:' '.' '·,>i··.'/'· "'.j" MD.·.·. TVD·.. ..... Ref··' Orrset<TFO+J\2:.ITJ.fº~"S.;Ç8¡hlg ft fre.:· ff·: . ft'·, . qeg' ·::cf~~,if;¡n·."·' 7750.00 7692.12 30.65 5.89 127.13 327.20 7775.00 7714.75 30.63 5.96 126.45 326.52 7800.00 7737.30 30.61 6.04 125.75 325.82 7825.00 7759.76 30.60 6.12 125.07 325.09 7850.00 7782.15 30.59 6.20 124.38 324.36 13387.71 9011.67 7875.00 7804.45 30.58 13382.17 9011.49 7900.00 7826.69 30.56 13375.03 9011.26 7925.00 7848.86 30.53 13367.94 9011.03 7950.00 7870.97 30.51 13360.87 9010.80 7975.00 7893.03 30.49 13353.78 9010.57 8000.00 7915.04 30.46 13346.59 9010.34 8025.00 7937.03 30.44 13339.21 9010.11 8050.00 7959.01 30.41 13331.60 9009.86 8075.00 7980.97 30.39 13323.75 9009.61 8100.00 8002.92 30.36 13315.69 9009.35 8125.00 8024.84 30.33 13307.42 9009.08 8150.00 8046.71 30.30 13298.96 9008.81 8175.00 8068.52 30.27 13290.34 9008.53 8200.00 8090.29 30.25 13281.55 9008.25 8225.00 8112.00 30.22 13272.59 9007.96 8250.00 8133.61 30.19 13263.45 9007.67 8275.00 8155.08 30.16 13254.16 9007.37 8300.00 8176.43 30.13 13244.75 9007.07 8325.00 8197.68 30.09 13235.25 9006.76 8350.00 8218.91 30.06 13225.65 9006.45 8375.00 8240.15 30.03 13215.92 9006.14 8400.00 8261.38 30.00 13206.02 9005.82 8425.00 8282.55 29.97 13195.92 9005.50 8450.00 8303.60 29.93 13185.62 9005.17 8475.00 8324.52 29.90 13175.13 9004.83 8500.00 8345.29 29.87 13164.47 9004.49 8525.00 8365.92 29.83 13153.69 9004.14 8550.00 8386.40 29.80 13142.82 9003.79 8575.00 8406.76 29.76 13131.90 9003.44 8600.00 8426.98 29.73 13120.92 9003.09 8625.00 8447.04 29.69 13109.90 9002.73 8650.00 8466.96 29.66 13098.87 9002.38 8675.00 8486.71 29.62 13087.87 9002.02 8700.00 8506.32 29.59 13076.88 9001.67 8725.00 8525.76 29.55 13065.93 9001.32 8750.00 8545.03 29.52 13054.97 9000.97 8775.00 8564.12 29.48 13043.98 9000.61 8800.00 8583.00 29.45 13033.02 9000.26 8825.00 8601.73 29.42 13022.09 8999.91 8850.00 8620.30 29.38 13011.18 8999.56 8875.00 8638.67 29.35 13000.35 8999.21 8900.00 8656.90 29.31 12989.57 8998.86 8925.00 8674.89 29.28 12978.83 8998.52 8950.00 8692.65 29.25 12968.07 8998.17 8975.00 8710.14 29.22 12957.25 8997.82 9000.00 8727.32 29.18 6.28 123.68 323.60 6.36 122.91 322.82 6.44 122.11 322.03 6.51 121.30 321.22 6.59 120.48 320.40 6.68 119.64 319.55 6.76 118.78 318.70 6.84 117.92 317.84 6.91 117.05 316.97 6.99 116.17 316.09 7.08 115.29 315.21 7.17 114.40 314.31 7.28 113.49 313.41 7.38 112.58 312.50 7.50 111.66 311.58 7.63 110.73 310.65 7.76 109.78 309.70 7.88 108.83 308.75 8.00 107.86 307.78 8.10 106.89 306.81 8.18 105.91 305.83 8.27 104.93 304.85 8.38 103.94 303.86 8.50 102.95 302.87 8.64 101.95 301.87 8.78 100.95 300.87 8.91 99.94 299.86 9.05 98.93 298.85 9.17 97.92 297.84 9.29 96.91 296.83 9.41 95.89 295.81 9.52 94.88 294.79 9.63 93.86 293.78 9.74 92.85 292.77 9.84 91.84 291.76 9.95 90.84 290.76 10.06 89.84 289.76 10.18 88.86 288.78 10.29 87.88 287.80 10.40 86.92 286.84 10.50 85.97 285.89 10.61 85.04 284.95 10.72 84.12 284.03 10.83 83.21 283.13 10.96 82.33 282.25 11.09 81.47 281.39 15:52:20 WeU:W-32. Trùø.·North RKB'.87.16' 81~2 Rule Assigned: Inter-Site Error: ·:'êtt4etr No;.(;ö ·.:Dhiance Area " . ···ff: . ft: 1566.38 144.44 1551.08 144.62 1536.21 144.80 1521.79 145.01 1507.82 145.22 Major Risk 0.00 ft AUówåble Deviition ft' 1463.09 1446.81 1430.94 1415.45 1400.41 1494.31 145.43 1385.80 Pass 1481.27 145.61 1371.66 Pass 1468.67 145.77 1357.97 Pass 1456.52 145.91 1344.71 Pass 1444.82 146.08 1331.87 Pass 1433.52 146.26 1319.41 Pass 1422.52 146.45 1307.25 pàss 1411.76 146.60 1295.38 Pass 1401.19 146.74 1283.70 Pass 1390.82 146.88 1272.23 Pass 1380.72 147.06 1260.98 Pass 1370.90 147.26 1249.99 Pass 1361.40 147.48 1239.31 Pass 1352.24 147.71 1228.95 Pass 1343.44 147.97 1218.93 Pass 1335.09 148.25 1209.34 Pass 1327.30 148.54 1200.31 Pass 1320.07 148.83 1191.84 Pass 1313.34 149.08 1183.91 Pass 1306.96 149.28 1176.37 Pass 1300.83 149.42 1169.18 Pass 1294.99 149.58 1162.25 Pass 1289.51 149.80 1155.66 Pass 1284.51 150.07 1149.51 Pass 1280.03 150.38 1143.87 Pass 1276.12 150.68 1138.81 Pass 1272.79 150.98 1134.38 Pass 1270.09 151.26 1130.59 Pass 1268.02 151.52 1127.50 Pass 1266.61 151.77 1125.10 Pass 1265.92 152.01 1123.45 Pass 1265.95 152.24 1122.56 Pass 1266.72 152.46 1122.45 Pass 1268.24 152.68 1123.13 Pass 1270.54 152.89 1124.62 Pass 1273.60 153.10 1126.91 Pass 1277.43 153.33 1129.97 Pass 1282.00 153.58 1133.79 Pass 1287.25 153.79 1138.36 Pass 1293.20 154.00 1143.66 Pass 1299.87 154.22 1149.72 Pass 1307.21 154.42 1156.49 Pass 1315.32 154.64 1164.03 Pass 1324.15 154.89 1172.32 Pass 1333.71 155.14 1181.34 Pass 1343.96 155.42 1191.07 Pass 'Påge: 3 ·'X'.,.'·.»:: ',' ',','" .,' ',' '" ' , ":;, :' :':, ',: ',,: : ,:: ,'::.,' ',: '.: : ", ,:i,',' <: . ' ,'~ /"',':~":::"',, ':' .:.,"",::, :,:,:':, ':< ,', '.:',' ".," , iijb:Ø,~de : : .' ;,':.: .:'; :;. '.. :':;,: I i: : : :, ';,: ::: ' .' :.', : .:, '::; :,; :" ...: ',' I :;' :', .'.. '\" ~ ~al'''i~'t;· Pass Pass Pass Pass Pass ) BP ') Anticollision Report Company: B~Amoco Date: 10/312002 Time: 15:52:20 Page: Fi~'d; .: ~Ï1J~,hoe Bay Co--9rdin,te(NE)J{~ferenee: Ref~r:ence Sit~: PBWPad Well: W;,;32 , True.North Reference WéU: W~32 VerQcal ('l'YD) Reference: RKB 87.16' 87.2 Ref~.rence Weltpath: ÞI~n W-32L 1 Db': Oracle. Site: PB W Pad Well: W-24 Rule Assigned: Major Risk Wellpath: W-24 V1 Inter-Site Error: 0.00 ft , '. Refe~nce ':i" .Offset,:.:, Se~-r4;\j~rAxis......... 'i '.,.ii, ...'ii" 9....Ct.- N{)~ô ' , Allowable ,~D "TVD " MD"1'tD ' . J{~!,' ;Øffset Tfq+AZI'J.'~9tIJ:SÇll:s¡iig , I)~t~..çe Ar~ ' Deviation Wål'ning ,>!~ ft ft "'ft,, ft, ' "ft ' '~eg 'øøQ,in ' ,ft ft, ", ' ft 12946.36 8997.47 9025.00 8744.30 29.15 11.22 80.64 280.55 1354.76 155.70 1201.37 Pass 12935.40 8997.12 9050.00 8761.14 29.12 11.35 79.81 279.73 1365.96 155.99 1212.03 Pass 12924.38 8996.77 9075.00 8777.91 29.09 11.49 79.01 278.93 1377.48 156.28 1222.94 Pass 12913.32 8996.41 9100.00 8794.65 29.05 11.63 78.22 278.14 1389.28 156.57 1234.17 Pass 12902.24 8996.05 9125.00 8811.37 29.02 11.71 77.45 277.36 1401.34 156.70 1245.86 Pass 12891.18 8995.70 9150.00 8828.13 28.99 11.73 76.68 276.60 1413.61 156.68 1257.95 Pass 12880.13 8995.34 9175.00 8844.97 28.96 11.76 75.93 275.85 1426.05 156.66 1270.22 Pass 12869.04 .8994.99 9200.00 8861.83 28.92 11.83 75.19 275.11 1438.69 156.76 1282.57 Pass 12857.90 8994.63 9225.00 8878.64 28.89 11.95 74.46 274.38 1451.56 157.00 1295.06 Pass 12846.67 8994.27 9250.00 8895.37 28.86 12.09 73.75 273.67 1464.68 157.30 1307.75 Pass 12835.32 8993.90 9275.00 8911.98 28.83 12.23 73.06 272.98 1478.09 157.60 1320.74 Pass 12823.88 8993.53 9300.00 8928.49 28.79 12.37 72.38 272.30 1491.76 157.91 1334.01 Pàss 12812.36 8993.16 9325.00 8944.91 28.76 12.52 71.72 271.64 1505.66 158.21 1347.54 Pass 12800.75 8992.79 9350.00 8961.26 28.73 12.65 71.08 270.99 1519.77 158.51 1361.31 Pass 12789.04 8992.41 9375.00 8977 .55 28.69 12.79 70.44 270.36 1534.06 158.79 1375.28 Pass 12777.23 8992.03 9400.00 8993.77 28.66 12.93 69.83 269.74 1548.53 159.08 1389.44 Pass 12765.33 8991.65 9425.00 9009.91 28.63 13.07 69.22 269.14 1563.17 159.38 1403.79 Pass Site: PB W Pad Well: W-29 Rule Assigned: Major Risk Wellpath: W-29 V1 Inter-Site Error: 0.00 ft ,·.'::Referêöçe "..(."i~}·:MD Off~tTVD ~lUi~~~jor Axis,'" .....' ..' '.'.' ,.'. ...". ,,' Çtr-ÇÙ,No..G~, Allowable '>:MD " TVD "R~f::;Offset l'FQ+AZITFO-Hs,:C~ing' ·I)istance . Ar~ .: " <neViatl6n' ' W~,rmÌ1g 'ft ft ':ft ft ff ' , 'ft ',~eg, deg il) ;i ft" ft ',' ft 10928.36 8934.90 9275.00 7931.18 25.92 24.24 231.55 49.78 1567.54 184.57 1403.26 Pass 10923.02 8935.37 9300.00 7950.24 25.91 24.33 232.43 50.47 1562.07 184.79 1396.78 Pass 10917.59 8935.89 9325.00 7969.25 25.90 24.42 233.31 51.17 1556.98 185.02 1390.67 Pass 10900.00 8937.82 9350.00 7988.21 25.86 24.41 234.65 51.92 1552.38 184.80 1385.28 Pass 10900.00 8937.82 9375.00 8007.12 25.86 24.55 235.32 52.60 1547.90 185.22 1379.74 Pass 10900.00 8937.82 9400.00 8025.99 25.86 24.69 236.00 53.28 1543.84 185.65 1374.62 Pass 10900.00 8937.82 9425.00 8044.82 25.86 24.84 236.68 53.96 1540.18 186.08 1369.91 Pass 10889.18 8939.21 9450.00 8063.64 25.84 24.88 237.77 54.68 1536.82 186.08 1365.75 Pass 10883.25 8940.03 9475.00 8082.43 25.82 24.97 238.68 55.39 1533.81 186.28 1361.85 Pass 10873.44 8941.48 9500.00 8101.20 25.80 25.02 239.74 56.11 1531.15 186.32 1358.42 Pass 10867.00 8942.47 9525.00 8119.95 25.79 25.17 240.41 56.79 1528.78 186.73 1355.06 Pass 10849.78 8945.13 9550.00 8138.70 25.78 25.31 241.09 57.46 1526.63 187.13 1351.96 Pass 10832.53 8947.79 9575.00 8157.43 25.77 25.45 241.76 58.14 1524.66 187.52 1349.05 Pass 10815.25 8950.46 9600.00 8176.16 25.77 25.59 242.44 58.81 1522.87 187.92 1346.33 Pass 10797.91 8953.13 9625.00 8194.87 25.76 25.73 243.11 59.49 1521.27 188.31 1343.81 Pass 10780.52 8955.82 9650.00 8213.55 25.75 25.87 243.79 60.16 1519.84 188.72 1341.47 Pass 10763.06 8958.51 9675.00 8232.20 25.74 26.02 244.46 60.84 1518.59 189.12 1339.31 Pass 10745.53 8961.22 9700.00 8250.83 25.73 26.16 245.13 61.51 1517.51 189.52 1337.34 Pass 10727.95 8963.93 9725.00 8269.41 25.72 26.31 245.80 62.18 1516.63 189.95 1335.57 Pass 10710.30 8966.65 9750.00 8287.94 25.72 26.46 246.47 62.85 1515.97 190.37 1334.03 Pass 10692.59 8969.39 9775.00 8306.42 25.71 26.60 247.14 63.51 1515.54 190.79 1332.73 Pass 10674.82 8972.13 9800.00 8324.85 25.70 26.75 247.80 64.18 1515.33 191.22 1331.66 Pass 10657.00 8974.88 9825.00 8343.23 25.70 26.91 248.47 64.84 1515.34 191.67 1330.81 Pass 10639.12 8977.64 9850.00 8361.56 25.69 27.06 249.13 65.50 1515.57 192.11 1330.19 Pass 10621.19 8980.40 9875.00 8379.85 25.69 27.21 249.79 66.16 1516.01 192.55 1329.80 Pass 10603.21 8983.18 9900.00 8398.09 25.68 27.37 250.44 66.82 1516.67 192.99 1329.63 Pass 10585.18 8985.96 9925.00 8416.30 25.68 27.52 251.10 67.47 1517.51 193.43 1329.67 Pass 10567.13 8988.75 9950.00 8434.51 25.68 27.67 251.75 68.12 1518.50 193.88 1329.88 Pass ) Company: BP Amoco Field: Prudhoe Bay Reference Site: PB W Pad Reference Well: W-32 ReferenceWellpath: Plan W-32L 1 Site: PB W Pad Well: W-29 Wellpath: W-29 V1 Reference Offset MD TVD MD ,TVD' ffq ft ftft" 1 0549.04 8991.54 9975.00 8452.71 10530.93 8994.33 10000.00 8470.90 BP Anticollision Report ','rhit~:.·;'/1óÎát2ÓO~": ' ',.,;.:",'./,,::.:'/',";';" ,\ ":j;'¡~:" 15';52:20 ) ;'.,'.:/:;-,:',"',': Pa~e: S 'C~o~n~~~)â~terence:' 'Well: W;.32, True North Vertical <JYD)lteference:, RKB 87~16'87.2 Db: Orade " ")"i""" 'I Semi~MajC)r Axis,,;, , ',::.\.i:,': , ',' Ref , ocrset TIfQ+~~¡:fQ~~~:Ç~¡p~ ft ," ' ft '~éft ::'~~;', :'0:.1(1, ,,' 25.67 27.81 252.40 68.77 25.67 27.96 253.04 69.42 10512.78 8997.13 10025.00 8489.09 25.67 10497.13 8999.55 10050.00 8507.29 25.67 10497.13 8999.55 10075.00 8525.50 25.67 10497.13 8999.55 10100.00 8543.72 25.67 10487.84 9000.95 10125.00 8561.95 25.52 10484.95 9001.37 10150.00 8580.18 25.48 10475.00 9002.77 10175.00 8598.42 25.33 10475.00 9002.77 10200.00 8616.68 25.33 10475.00 9002.77 10225.00 8634.92 25.33 10475.00 9002.77 10250.00 8653.14 25.33 10475.00 9002.77 10275.00 8671.34 25.33 10475.00 9002.77 10300.00 8689.51 25.33 10475.00 9002.77 10325.00 8707.66 25.33 10462.96 9004.37 10350.00 8725.78 25.09 10450.00 9005.95 10375.00 8743.87 24.84 Site: PB W Pad Well: W-32 Wellpath: W-32 V1 . 'Reference , " Mij TVD 'ft ft , 9671.30 8772.34 9696.23 8792.79 9720.69 8812.51 9744.47 8831.23 9767.04 8848.50 28.11 253.69 28.25 254.33 28.39 254.97 28.53 255.61 28.23 258.60 28.23 259.97 27.91 263.08 28.04 263.73 28.18 264.38 28.32 265.03 28.46 265.67 28.60 266.30 28.75 266.93 28.34 270.54 27.90 274.30 70.06 70.71 71.35 71.99 72.95 73.69 74.63 75.29 75.94 76.58 77.23 77.86 78.49 79.49 80.44 Rule Assigned: Inter-Site Error: cíf,:Ctr"No.;Go ÐiS~nce·:~~. ,:,ff: ;:ff, 1519.66 194.32 1520.96 194.76 Major Risk 0.00 ft Ällowable ' ,~~iation' W~rning ft 1330.25 Pass 1330.79 Pass 1522.41 195.17 1331.52 1523.98 195.58 1332.39 1525.82 196.00 1333.53 1528.00 196.42 1335.02 1530.35 194.95 1338.03 1533.11 194.76 1340.60 1536.28 193.09 1344.75 1539.61 193.48 1347.53 1543.27 193.90 1350.63 1547.24 194.32 1354.06 1551.52 194.74 1357.81 1556.10 195.16 1361.88 1561.01 195.62 1366.25 1565.96 193.33 1373.09 1571.62 191.01 1381.01 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pàss Pass Pass Pass Pass Pass Rule Assigned: Major Risk Inter-Site Error: 0.00 ft ~g!f~t~!::.~M·~~;~~!;~~~~S;{~~c"~~f.!~:~·,y~~~~,~ ,.... 9675.00 8776.06 25.61 25.64 111.01 103.93 0.15 186.92 -179.18 FAIL 9700.04 8796.85 25.83 25.98 112.42 111.96 1.66 189.17 -178.47 FAIL 9725.00 8817.64 25.95 26.20 110.93 117.38 5.15 191.15 -176.69 FAIL 9750.00 8838.50 25.94 26.30 109.30 122.34 10.60 191.99 -172.16 FAIL 9775.00 8859.38 25.76 26.21 106.58 126.98 18.14 192.37 -164.94 FAIL 9788.22 8864.15 9800.00 8880.27 25.44 9807.88 8878.11 9825.00 8901.16 25.01 9825.98 8890.39 9850.00 8922.03 24.51 9842.55 8901.10 9875.00 8942.85 23.99 9860.00 8911.77 9900.00 8963.62 23.38 9871.43 8918.40 9925.00 8984.32 22.95 9883.93 8925.30 9950.00 9004.98 22.49 9895.29 8931.24 9975.00 9025.61 22.07 9905.62 8936.36 10000.00 9046.21 21.71 9915.03 8940.78 10025.00 9066.76 21.40 9920.00 8943.02 10050.00 9087.27 21.23 9931.48 8947.94 10075.00 9107.75 20.91 9940.00 8951.35 10100.00 9128.18 20.67 9945.36 8953.39 10125.00 9148.60 20.55 9951.51 8955.63 10150.00 9168.97 20.42 9960.00 8958.54 10175.00 9189.33 20.23 9960.00 8958.54 10200.00 9209.69 20.23 9967.24 8960.85 10225.00 9230.04 20.11 9971.73 8962.21 10250.00 9250.40 20.04 9980.00 8964.55 10275.00 9270.76 19.91 9980.00 8964.55 10300.00 9291.12 19.91 9983.40 8965.44 10325.00 9311.48 19.86 9985.72 8966.04 10342.04 9325.35 19.83 25.95 103.86 130.57 25.56 101.39 133.46 25.09 99.15 135.76 24.60 97.11 137.57 24.02 95.05 139.27 23.64 93.54 140.09 23.20 92.00 140.98 22.80 90.61 141.70 22.46 89.34 142.28 22.18 88.18 142.75 22.07 87.45 142.86 21.75 86.12 143.44 21.54 85.08 143.77 21.44 84.36 143.89 21.34 83.57 144.06 21.22 82.56 144.35 21.29 82.41 144.20 21.22 81.55 144.43 21.21 80.97 144.52 21.16 80.00 144.76 21.24 79.91 144.67 21.27 79.46 144.72 21.30 79.16 144.75 27.71 191.33 -154.61 39.09 189.44 -141.49 52.04 187.31 -126.09 66.37 184.80 -108.88 81.93 181.63 -89.18 98.45 179.36 115.94 176.71 134.22 174.38 153.18 172.34 172.75 170.48 192.90 169.55 213.35 167.22 234.25 165.68 255.47 164.94 276.99 164.10 298.82 162.86 320.88 163.08 343.15 162.15 365.66 161.65 388.41 160.84 411.22 161.10 434.23 161.00 449.99 160.94 -70.21 -49.34 -27.64 -5.35 17 .42 38.91 64.03 88.34 111.61 135.64 161.26 182.85 208.46 232.93 259.70 282.17 306.69 323.51 FAIL FAIL FAIL FAIL FAIL FAIL FAIL FAIL FAIL Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass ') ~TANDARD ALASKA PROOUCTI~ COMPANY HELLHEAD LOCATION DATA ') 1 ) HELL: W-32 FIELD: Prudhoe Bay Unit 2) Hell Head Location 735 'from North 1 i ne 1442 'from East 1 i ne Sec t ion -ª-, T 11 N, R 12 E, UPM X. 611,789.05 Y .5,959,517.88 ASP Zone 4 LAT . 70°17'54.088" N, lONG. 149°05140.846" H 3) local BenchmarK Elevation Pad "r~on.-2" E1.47.83 4) Top Edge of Cellar 5) Kelly Bushing to Base Flange· 6) Kelly Bushing to Ground Level· 7) Base Flange Elevation 8) Kelly Bushing Elevation ·Measured by Drilling Foreman NE Corner E1. 53.16 36.10 37.70 54.76 NOTES: 90.86 Ft. AMSL· Ft. AMSL Ft. AMSL Ft. AMSL Ft. AMSL Ft. AMSL 1) The surveyor should fill in Items 2, 3 and 4. 2) The compl eted form should be returned to Dr; 11; n9 Dept. for distribution. CIRCULATION: North Slope Production Engineering (North Slope, BOC) - Reservoir Engineering Operations (MB9-2) - 1 North Slope - to Rig for Posting (North Slope, BOC) - 2 ~ell Records (LR2-l) - 11 ~ell Files (MB12-1) - 1 Drilling, Technical Assistant (MB12-l) - 1 Drilling, Completion Technical Assistant (MB12-1) - 1 Graphic Services, Supv.. Cartography (MB2-4) - 1 November 15, 1986 Date """"\\ ........ OF A l.. \, .,,~~ ..........4_r\ I. -,l.'r ... 1i.. \)1- 'a , ~ .. .. ~ , ", C? .. '-i: . .. Y , : 1t /49!!i"'~ \. ... ., ~'.~b-"..:::;.ï~.~J'/ ~ ~ ~ ... ...tI ~ .................... r ~, ... '\ . 1 : ~ ~ ~ ~. lDarn~r~ lOr:1UoIch ..c ~ 'I'~ f". ~ . - ,." .f c...... .. L.S. #'3798' S .' <~<." " A ":1:,-., .... ¿' ." ". ')- '. .. ~--, ., ., <C p_ ...... .... ~.:. _ , f¡;"F[~:. ::~k\. ~ ...." \,'\.",~,,,~ ~ ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME //¿¡ ¿V - 32 L / PTD# 202~ '- 7./':? <7 CHECK WIIA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well?J ... .~ h (f .14.) Permit NO'¡'i1- o? I API No. 50-' 1::>2. ~r-.2 ) 7 '7 c> Production should continue to be reported as a function' of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly.. differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing . exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. H 207122 DATE INVOICE I CREDIT MEMO 9/20/0= INV= C~091602L .,A j ." \' ¡ j I ~. j (/) .- DESCRIPTION PERMIT TO DRILL FEE THE ATTACHED CHECK IS IN PAVMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY TO THE ORDER OF B P tf t{ "j'" o or ...~.J> ALASKA OIL & GAS CONSERVATION COMMISSION 333 W. 7th AVE, STE 100 ANCHORAGE, AK 99501 DATE CHECK NO. GROSS 9/20/02 VENDOR DISCOUNT NET H207122 !' FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAl CITY BANK CLEVELAND. OHIO No. H 207122 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 --¡.j2 t:::~: . ~ ' DATE SEPT. 20, 2002 AMOUNT ****$100..00**** :r~~:~t~~~~1~O DAYS (·r:'f~rj1~"'· III 20 ? ~ 2 2 III I: 0 ~ ~ 2 0 j 8 q 5 I: 008 ~.... ~ q III Ii ~. - WELL PERMIT CHECKLIST COMPANY ð/X WELL NAME/ð4'" ¿v - .5>2 (' I PROGRAM: Exp _ Dev k Redrll _ Re-Enter _ Serv _ Wellbore seg ;:;<' FIELD & POOL b4r~ J. ç 0 INIT CLASS /)~./I/ / - ð/ / GEOL AREA &>7 r) UNIT# /1 4£1"7 ON/OFF SHORE -'L.00 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . r;. N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . Y N 6. Well located proper distance from other wells.. . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . Y N /h . I / 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . Y N /yc- /-Ef.1¡jtP ¿ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~~N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_ Y (Service Well Only) 14. All wells wlin y.. mile area of review identified. N ENGINEERING ~~ ¥~-N- AI/A-- ~ sloW ~ DD14Þ- 1<1 -¥-N-- N 1ft- &N ~Ai/A !i ,- æ. N f/lAt4 mlJ..l (}. 5 PPC¡ ~~ Wt~f 'lfz-o u1k. &N r ~.~ Y N /\LIlt- Y~ IT /ú{A APPR DATE \¡JC-;/t- i 01 Ii:> )01,- (Service Well Only) GEOLOGY APPR DATE /fþ--, /óf~ <-- (Exploratory Only) Rev: 07/12/02 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . 17. CMT vol ádequate to circulate on conductor & surf csg. . . 18. CMT vol adequate to tie-in long string to surf csg. . 19. CMT will cover all known productive horizons. . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . .. . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . .. . . . 24. If diverter required, does it meet regulations. . . . . . . '.' . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to 3500 psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable... . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... . GEOLOGY: RPCØ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH UIC ENGINEER JBR COMMISSIONER: COT DTS M L. f3 ~'Z 'Z.-JJ:> 't" SFD_ WGA ./ G:\geology\permits\checklist.doc MJW ( Commentsllnstructions: ') ) Well H ¡story File APPENDIX Infornlation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To inlprove the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special·effort has been made to chronologically organize this category of information. ) } Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 08 08:30:36 2003 Reel Heäder: Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/05/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOí"ÌN Continuation Number......Ol Previous Reel Name....... UNK1\f0W1\f Comments................ .STS LIS Writi.ng Lib.r:ary. Scientifi.c Technical Services Tape Header Service name.............LISTPE Date.....................OJ/05/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scienti.fic Technical Services Physical EOF Comment Record T.Ä.PE HEADER Prudhoe Bay Unit MWD/MAD LOGS 11 WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # ,JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW2217600000 T. MCGUIRE A. MADSEN LJOR NUlvIRER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW??]7600000 T. MCGUIRE A. MADSEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 11 MW22l"l60000U C.A. DEMOSKI L. V.r..UGHN # SURFACE LOCATION SECTION: TOWNSHI P: R.;;t..j G E : ["NL: FSL: FEL: FWL: ELEV.r..TION (FT fROM MSL 0) KELL":{ BUSHING: DCRRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) W-32A 500292197001 SP Exploration (Alaska), Inc. Sperry-Sun Drilling Services OS-MAY-03 MWD RUN 4 MW2217600000 T. MCGUI RE A. MADSEN MWD RUN 6 MW2217600000 T. MCGUIRE A. H.ADSEN MWD RUN 9 MW22]7600000 T. MCGUIRE L. VAUGHAN MÍI'JD RUN 10 IvlW2217600000 C.A. DEMOSKI L. VAUGHAN 21 11 12 ï~¡:: ,...}...} 144 88.06 54.76 C.i\SING SIZE: (HI) DRILLEF\.S DE:PTH (FT) ~- aÙCj //¡()7 ') ) 1ST STRING 2ND STRING JRD STRING PRODUCTION STRING 4.750 5.500 9665.0 # RENARKS : 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL Wl\S EFFECTED BY MEANS OF l\.N OPEN-HOLE SIDETRACK AT 12400'1'10 IN THE W-32A PB1 WELLBORE. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. THIS RUN WAS TO ORIENT THE WHIPSTOCK AND MTLL THE WINDOW - NO DATA ARE PRESENTED. 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH DUAL GI-\M]\1A RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 6. MWD RUNS 4, 6-11 COMPRISED DIRECTIONA.L WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELEC'l'RO¡V¡AGNETIC tl\TAVE RESISTIVITY PHASE-4 (EWE4). MAD PASS EWE4 DATA WEEE ACQUIEED OVEE THE RUN 3 INTERVl\L, PRIOE TO THE COMMENCEMENT OF DRILLING RUN 4. THESE MAD DATA ARE MERGED Ii"JIT!-[ RUN 4 mw DATA. THE EWR4 TOOL FAILED AT 13941'1'10 - THE LAST 9' OF DATA WERE LOST. 7. LOG AND DIGITAL DATA (LDWG) ONLY HERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN W-32A ON 3 JANUARY 2003. LOG HEADER DATA RETATN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 17 FEBRUARY 2003. 8. ~~D RUNS 1, 3, 4, 6, 7, 9-11 REPRESENT WELL W-32A WITH APIff: 50-029- 21970-01. THIS HELL REACHED A TOTAL DEPTH (TO) OF 13950'MD/8931'TVD. SROP ~ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGkC SMOOTHED GAi'1MA kAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SF,SP = SMOOTHI-',I) I-'HASI-~ SHII-"'-m',RIVF,I) RI-~S.lS'I'IV¡'\'Y (SHALLOW SPACING) . SEMP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEF SPACING) . SfXF. = SMOOTHF.D FORMATION F.XPOS(JRf~ TTMF.. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File He.=¡rle ¡- Service name.............STSLIB.OOl Service Sub Level Name... Version Numher.......... .1.0.0 D~to of Go~or3tio~.......03í05/08 Maximum Physical Record..65535 File Type................LO Previous File N~me.......STSLIB.OOO Comment Record tILE HEADER tILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREHENT: # FILE SU¡V¡¡V¡ARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ ) 1 ) and clipped curves; all bit runs merged. .5000 START DEPTH 9654.5 9658. .5 9658.5 9658.5 9658.5 9658.5 9693.0 STOP DEPTH 13900.5 13916.0 13916.0 13916.0 13916.0 13916.0 13961. 5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEJ.\SURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9654.5 9669.0 9682. .5 9689.5 9697.0 97 05.0 9710.5 9720.5 9735.5 9'142.0 9746.0 97,58.0 9765.0 9'/'/2. :> 9775.5 9778.5 9'/8~). ~ 9787.5 9792.0 ~)'f94.5 9798.0 9803.0 9806.5 9809.5 9811.5 9818.0 9823.5 9828.5 9832.0 9837.0 9842.0 9849.5 9856.5 9864.~) 9868.5 9872 .0 9880.0 9884.0 9891.0 9896.0 9907.0 9916.0 9927.5 9933.5 9946.0 9956.0 9968. () 99/0.:> 9980.5 9982.5 ~\~\8,). ') 9999.0 1000:2.5 GR 9651. 5 9667.0 9681.5 9688.0 9696.0 9704.0 9710.0 9719.0 9734.5 9'141.0 9745. 5 9757.5 9764.5 9 Tl 2 . 5 9773.5 9779.0 9'} 8 ~ . 0 9787.0 9791. 5 9/94.5 9797. .5 9802.0 9805.0 9807.0 9813.0 9818.0 9823.0 9827. :) 9831.0 9835.5 9841.0 9849.5 9855.5 9862.0 9666.5 9870.0 9tJ'l6.b 9882.0 9890.0 9896.5 9905.0 9913.0 9925.5 993:2. CI 9943.5 99.53.5 9966.0 9968.:' 99"77.5 9979.5 ~)~'~:H. ~) 9995.5 9998.5 ) ) 10020.0 10016.5 10ü22.ü 10019.5 10024.5 10022.0 10031.5 10031.0 1U039.~) 10(J36.~) 10080.0 10079.0 10089.5 10086.0 1011'7.5 10114.0 10127.0 10125.5 10134.5 10131. 0 10141. 0 10135..5 10150.0 10143.5 10157.0 10152.0 101.58.5 10155.0 10164.5 10160.5 10166.5 10163.0 10188.5 10184.5 10195.0 10190.0 10211. ü 10207.0 10248.0 10244.0 10249.5 10245.5 10255.5 102~)1.~) 10281.0 10277.5 10302.5 10299.0 10315.b 10313.5 10332.0 10325.0 10338.5 10330.0 10366.0 10356.5 10383.0 10381.0 10391.0 10389.0 10406.0 10402.5 10411.0 10407.5 10456.5 10455.0 10461.0 10460.0 10465.5 10465.0 10469.5 10471.5 10471.0 10473.0 10500.5 10500.0 10508.0 105ln. ~) 10525.5 10523.5 10536.0 1053·'1.5 10626.0 10623.5 10633.5 10629.5 10637.5 10633.5 10641. 5 10638.0 10660.5 10656.0 10669.0 10664..5 10705.5 10699.0 10711.5 10703.5 10739.5 10734.0 10745.5 10742.0 10756.0 10752.0 HrJ64.0 10762.0 10769.0 10768.0 10773.5 10770.5 lln 8 3 . (J 1 (J'j 80. ~) 10787.5 10784.5 10791.0 10790.5 10'796.0 10'7~)3.5 10840.0 10835.5 10864.5 10861.5 10919.5 10915.5 10940.0 10936.5 10961. 5 10957.0 10998.1} 10995.5 11032.0 11 0:2 7 . 1:1 11044.0 11039.5 11057.5 11050.0 11089.5 11082.5 11104.5 11099.5 11113.5 11109.0 11120.0 11115.0 11li3.5 11líU.'.:> 11183.(, 111 7 ,3 . (I 11::>~3. (I 1119:3.':; ) ) 11209.0 11203.5 11231.0 11225.0 11252.0 11247.0 11263.5 11257.0 112'73.5 11268.0 11312.5 11307.5 11335.5 11333.0 11363.0 11360. b 11.383.5 11378.0 11413.5 11409.0 11425.5 11421.5 11448.5 11443.0 11473.0 11466.5 11478.0 11473.0 11531.0 11525.0 11554.0 11548.0 11591.5 11586.5 11596.5 11590.5 11603.5 11598.5 11611.0 11606.0 11627.0 11626.0 11643.5 11640.~) 11661. 5 11656.0 11677.5 11674.0 11691.0 1168'1.0 11 704..5 11698.0 11716.5 11709.5 11723.5 11719.0 11741.0 11737.0 11769.5 11764.0 11782.0 11775.5 11785.0 11779.5 11807.0 11803.0 11813.0 11808..5 11817.0 11811.5 11824.5 11819.5 11833.5 11827.5 11843.5 11836.5 11864.~) 11859. ~) 11915.0 11909.0 11935.0 11930.0 11949.0 11944.5 11955.5 11952.0 11973.0 11968.0 12005.0 11997.0 12007.5 12000.0 12013.5 12005.5 12104.0 12094.5 12121.0 12114.0 12139.5 12133.0 12153.5 12146.5 12155.5 12149.0 1215'1.5 12151. 0 12166.5 12164.5 12176.5 12171. 5 12181.5 121'i5.(1 12184.5 121 77.5 12193.5 12189.0 12203.5 1219'1.5 12209.5 12203.0 12228.0 12220.5 12257.5 12251.0 12289.5 12282.0 12310.0 12303.5 12324.5 12318.5 1233(1.5 12322.0 12336.0 12328.0 12350.0 12343.0 12356.0 12347.5 1:2372.0 12363.5 12377.0 12368.5 12382.5 12371.0 124\.12.~) 12394. (0) 12446.0 12439.S 12'161.5 1 .: -1 5 5 . C' ) '.) 12489.5 12489.0 12:>06.0 12499.5 12515.0 12513.0 12527.5 12525.0 12540.~) 12~)38.5 12552.0 12549.0 12559.5 12554.0 12565.0 12558.5 12596.0 12588.5 12614.0 12607.5 12624.,5 12616. ,5 12647.0 12642.0 12651.0 12645.5 12662.0 12654.5 12667.0 12659.0 12675.0 12665.0 12696.0 12690.0 12707.0 12698.0 12770.0 12762.0 12774.5 12765.5 12792.5 12784.5 12'/94.0 12186.0 12797.0 12788.5 12801. 0 12790.5 12803.0 12794.0 12809.5 12801. 0 12815.5 12808.5 12839.0 12837.5 12851.5 12849.5 12867.5 12860.5 12878.0 12868.5 12893.0 12888.0 12897.5 12893.5 12924.,5 12919.0 12936.5 12930.5 12946.5 12938.:> 12956.0 12946.5 12965.5 12956.0 13002.5 12992.0 13049.0 13038.5 13052.5 13042.5 13059.:> 1j049.0 13063.5 13053.0 13089.0 13078.0 13095.0 13084.5 13100.0 13093.5 13106.5 13098.0 13111. 0 13101.5 13117.5 13109.5 13134.5 13124.5 13140.0 13129.5 13142.0 13131.5 13147.5 13136.5 13160.0 13150.0 13202.0 13193.5 13212.5 13202.~) 13219.5 13209.5 13219.0 13237.0 13252.5 13242. U 132ì8.0 13266.5 13287.5 13276.0 13296.5 13285.5 13310.0 13301.5 13320.0 13308.0 13344.5 13332. (I 13371.5 13360.5 13385.5 1 JJ' ¡:: ,', ....'.....;, 'o,J'. '-' 13412.0 13400.0 13125.0 13115.5 13445.5 13435.0 13459.0 1344"7.0 13172.0 13160.0 1j4i4.U 13461.') 13476.5 13463.S 131196.5 1 3 1 8 ,1 . 0 ') ,\ 13500.5 13524.0 13531.0 13540.0 13~88.0 13601.0 13605.5 1360'1.5 13630.0 13660.0 13705.5 13781.5 13795.0 13801.5 13808.5 13810.5 13815.0 13823.5 13827.5 13832.0 13961.5 13489.5 13513.0 13519.5 13528.0 13~)'14.0 13589.0 13593.0 135%.5 13617.5 13647.0 13693..5 13769.0 13783.5 13791. 0 13796.5 13798.5 13805.5 13814.0 13816.0 13820.5 13950.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWO MWO MHO MWO Míl\TD MWD è ,<' BI'l' RUN NO 3 4 6 7 9 10 11 IVIERGE TOP 9651.5 10473.0 10547.0 12140.0 12399.5 12428.0 13588.0 MERGE BASE 10473.0 10547.0 12140.0 12399.5 12128.0 13588.0 13950.0 # REMARKS: MERGED MAIN PASS. $ U Data Format Specification Record DaL'I Record 'l'ype.................. 0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni t.s . . . . . . . . . . . . . . . . . . . . _ . . Datum Sped fi cat. ion 810ck sob-type... (I Name Service Order Units Size Nsam Rep Code Offset Channel DEPT F'T 4 1 68 0 1 ROP MWO FT/H 4 1 68 4 ..., L GR MWD API 4 1 68 8 3 RPX MWD OHMH 4 1 68 12 4 RPS MWD OHHH 4 1 68 16 5 RPM HWO OHMM 4 1 68 2D 6 Rf'D HWO OI-!HM 4 1 68 ;24 7 FET ¡vrr'JD HOUR 4 1 68 28 8 Fir:::;t L.::lst Name Service Unit Hin Max Mean Nsam Reading Reading DEE'T FT 9654.5 13961.5 11808 8615 9654.5 13961.5 ROP MT^JD FT!H 0.06 211_11 57.8172 8538 9693 13961.5 GR. MWD .I\PI 2U./'d '::>0"/ .1 'I '::>.689/ 'd49j 96'::>4. '::> 139UO.'::> R?~\ IvíWD OHjv[jv¡ 0.62 2000 19.3017 8516 9658.5 13916 RPS ¡Vl\^JD ŒWlM 0.53 2000 23.1783 8516 9658.5 13916 RE'M MWD OI-!MH 0.16 2000 n.9632 'd~J16 965'd.5 13916 RfD HWD OHHN 0.4 Ó 2000 75.42ì7 8516 %58.5 1391G F'CT ~·1~~J 0 ¡lOUR 0.281 104.698 10_0142 8475 9658.5 13916 Fi~:::;t Rcading For Entire Filc....______9651_5 Last Rl?adin'J F,=,r Entirl? Fil'?..........13961.~1 ") File Trailer Service name.............STSLIB.001 Service Sub Level Naß~... Version Number...........1.0.0 Date ot Generation.......03/0b/OB Haximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... VeL'sion Numbec..........1. 0.0 Date of Generation.......03/05/08 Haximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comnænt ReCOL"d FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 2 \ header data for each bit run in separate files. 3 .5000 START DEI?TH 9651. .5 9691.5 STOP DEPTH 10433.0 10473.0 GR ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOF'r'V17ARE VERSION: DOWNHOLE SOFTWARE VERSION: DÞ.TA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG .MINIMUM ANGLE: W'l.XIMUM ANGLE: TOOL STRING (TOP TO BOTTO!ll[) VENDOR TOOL CODE TOOL TYPE G!II[ Dual GR .... -? it BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: HUD CHLORIDES (PP¡'¡): FLUID LOSS (C3): RESISTIVITY (OHt'1M) AT TEMPERATURE (DEGF) HUD AT HEf\SURED TEHPERATURE (IvIT): MUD AT MP~ CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: HDD CAKE AT MT: NEUTRON TOOL ll-NOV-02 InsiLe 1.3 Memory 10473.0 9691.0 10473.0 32.2 89.1 TOOL NUMBER 93091 4.750 9665.0 QUIKDRIL-N 8.45 41.0 9.1 140C' 8.. e .000 .0 . 0 0 0 1 9 0 . ,1 .000 .0 .000 .0 ) \ t-'lATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 'I'OO[' S'1'ANDOF'F (IN): EWR FREQUENCY (HZ): # REMARKS: ;-. .;> # Data format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Untt.s....................... Datum Speci.fi..cati.on Block sub-type... 0 Name Service Order Uni t.S Size Nsam Rep Code Offset Ch.::mnel DEPT FT 4 1 68 0 1 Rap MWD030 FT/H <I 1 68 4 ') GR MWD030 API 1 1 68 8 3 First Last Name Service Unit Mj..n Max Mean Nsam Reading Reading DEPT FT 9651.5 10473 10062.3 1644 9651. 5 10473 Rap MWD030 FT/H 0.58 205.19 46.1458 156tJ 9691.5 10473 GR MWD030 API 22.1'/ 479.65 ·n.924 1~:)64 96~)1. 5 10433 First Reading For Entire File..........9651.5 LäsL Reading Fa I.' Entin,~ File.......... .10473 f:i.le Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....03/05/08 Maximum Physical Record..65535 file Type................ LO Next File Name...........STSLIB.003 Physical EOF File HeadeL Service name............ .STSLI8.003 Service Sub Level Name... Version NumbeL".......... .1.0.0 Date of Generation.......03/05/08 Maximum Physical Record..65535 File Type............... .LO Freviou3 filc Nomc.. .... .STSLIB.OO= CC'lIlIlleIlL Record FI LE HEl\DER E'I LE NUtv1BER: RAW IvfwD Curve3 ond log heoder dato for each bit run in 3cparatc filc3. ßIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # :3 tILE SUHHARY VENDOR TOOL CODE RE'M RPS RPD STP..RT DEPTH 96~~. ~ 9655.5 9655.5 STOP DEPTH lU~Ui . ~ 1050Î.5 10507.5 ') FET RI?X GR ROI? $ 9655.5 9655.5 10433.5 10473.5 10507.5 10507.5 10493.5 10547.0 # LOG HEI\DER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (HEMORY OR REAL-TIME): TO DRILLER (F'l'): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMI\G. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): it BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT HAX CIRCULATING rrERHPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): E~'iJR FREQUENCY (IIZ): # REMARKS: $ ~ Data Format Specification Record Dat.a kecord Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units........... J::'eet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............lJndefined Absent value......................-999 Dept h Un i ts . . . . . . . . . . . . . . . . . . . . . . . Dat11m Spr,>.-:ifir:.'Jtinn Rl,-,r:k S1Ib-typl?..0 ) 12-NOV-0:¿ Insite 4.3 MemoL'y 10547.0 10473.0 10547.0 101.6 102.6 TOOL NUMBER 93091 178425 4.750 9665.0 QUIKDRIL-N 8.4!:) 42.0 8.8 1200 7.8 1.900 .770 1.800 2.200 72.0 187.0 72.0 '/2.0 Name Service Order Units Size Nsam Rep Code Offset Channel DF.PT FT 1 68 0 ROP ¡..n"m040 fT / II 1 68 ..., GR MWD040 API 1 68 8 l RP~": HWD040 OHÌ"Û"í 1 68 2 .:) RPS Mí^lDO 1 0 o Htv"Jv! 1 68 6 5 RPtv! MítY D IJ 4 I.ì OHMM 1 nH Cì () RPD ¡V¡WOCi.:! Ü OHJvljllI 1 68 ï FCT ¡"'[í"JOO 4 0 HOUR 1 68 8 0 ) \ Fin:;t Lo.st Name Servj.ce Un.it Min Max Mean Nsam Reading Readinq DEPT FT 9655.5 10547 10101.3 1784 9655.5 10547 ROP MWD040 FT/H 1.15 208.88 65.5224 148 10473.5 10547 GR MWD040 API 21. 94 133.38 51.4'16'1 121 10433.5 10493.b RPX MWD040 OHMM 0.62 1826.86 13.7837 1705 9655.5 10507.5 RPS MWD040 OHMM 0.63 2000 22.857 1705 9655.5 10507.5 RPM MWD040 OHMM 0.16 2000 17.1475 1705 9655.5 10507.5 RPD MWD040 OHMM 0.07 2000 34.1456 1705 9655.5 10507.5 FET M~"JDO 4 0 HOUR 1. 324 104.705 35.5293 1663 9655.5 10507.5 First Reading For Entire Filc..........9655.5 Last Reading For Entire File...........10547 File Trailer Service no.me.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/08 Maximum Physical Record..65b35 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.......03/05/08 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.003 Conullen l Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR 4 header data for each bit run in separate files. 6 .5000 FET RPD RPM RPS RFX ROF $ START DEPTH 10494.0 10508.0 10508.0 10508.0 10508.0 10508.0 10547.5 STOP DEPTH 12086.5 12100.5 12100.5 12100.5 12100.5 12100.5 12140.0 II LOG HEÞ.DER DÞ.TÞ. DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOh1J'JHOLE SOFT!^Jl\RE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOT TOl'-1 LOG INTERV}\L (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINItvIUM ANGLE: l'L~XIHUM ANGLE: 15-NOV-02 Insite '1.3 Memory 12140.0 lOS'17..C1 1214(J.u 8b.l 94./ TOOL STRING (TOP TO BOTTOM 1 ) VENDOR TOOL CODE GM EWR4 $ TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (f'1'): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPF.RATURE (DEGF') MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOL8 CORR8CTION (IN): ff TOOL STANDOFF (IN): EWR FREQUENCY (HZ): jf REMARKS: S·, " # Data Format Specification Record Data Record Type.................. 0 Data Specification Glock Type.....O Logging Direction....... ..... .... . Down Optical log depth units...........Feet Data Reference Point..............Undefincd Frame Spacing.....................6ü .1IN Max frames pe.c cecocd............. Undef i.ned l\bsent value...................... -999 Depth Units.................... . . . Datum Specification Block sub-Lype...O \ TOOL NUMBER 93091 17842::;' 4.750 9665.0 QUIKllRTT,-N 8.50 44.0 8.5 800 7.2 1.900 .860 1.900 2.300 69.0 161.0 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/I! 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM II 1 68 16 5 RI?M MtI\TD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 ï FET MWD060 HOUR 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DErT FT 10494 12140 11317 3293 10494 FWP M[^lD060 FT!H 0.24 244.11 79.5367 3186 10547.5 GR MWD060 ./\PI 20./13 200./~ 49.6203 31tH) 10494 RPZ IvIli\[) 0 6 0 o HMlvj 1. 64 30.59 13.372 3186 10508 R!?S MV'm060 OHMM 1. 67 19.86 11.6931 3186 10508 R!?M MWD060 OHMM 1. 96 62.38 1~.9204 3186 10~O8 RrD tvlWDOGO OHHH 2..3G 38..57 17.8872 3186 10508 fET MND060 I-lOUR 0.281 37..7883 1.95737 3186 10508 ~irst Readi~g Fo~ Enti~e File..........101l91 Last Reading for Entire File....... ... .12140 file T.t"ailer Service name.............STSLIB.004 L.:Jst Reading 12140 12140 1 OB6.b 1 100.5 1 100.5 1 1UO.~ 1 100.5 1 100.5 ''J I Service Sub Level Name... Version Number...........l.O.O Date of Generatiofl....... 03/05/08 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Phy::Ücal EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Nurrber...........l.O.O Date of Generation.......03/05/08 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.004 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 5 \ header data for each bit run in separate files. 7 .5000 START DEPTH 1208'1.0 12101.0 12101.0 12101.0 12101.0 12101. 0 12140.5 GR RPX FET RPD RPM RPS ROP $ jj LOG HEJI..DER DATA DATE: LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE: INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ s'rop DEPTH 12346.0 12360.5 12360.5 12360.5 12360.5 12360.5 12.399.5 BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH IFTI: BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: ¡'íUD CHLORIDES (nH): fLUID LOSS (C3): RESISTIVITY (OHMM) AT TEtv¡PER.A.TURE (DEGF) HUD il.T HE.A.SURED TEHPERA.TURE (HT): HUD I\T Hl\.'{ CIRCULI\TING TERrv¡PERI\TURE: MUD FILTR.A.TE Þ.T MT: 1'1U D CAKE AT tv!T: 18-NOV-02 Insite 4.3 Memory 12400.0 12140.0 12400.0 83.3 92.6 TOOL NUMBER 93091 178425 1.750 966~.U QUIKDRIL-N 8.40 13.0 8.8 350 9.6 l. 0 0 l. 0 ¿. . 0 69" 1:) 186.. t: 69.0 69.0 ) \ NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # D~ta Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record...........__Undefined Absent value...................... -999 Depth Unì ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specìficatj_on Block sub-type... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 6t! 0 1 Rap MWD070 FT/H <1 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1. 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RFM Hí<iJD070 OIIMM 1\ 1 68 20 6 RPD MWD070 OHMM <1 1 68 24 7 FET MWD070 HOUR <1 1 68 28 8 First Last Name Service Unit Mi.n Max Mean Nsam Reading Reading DEFT FT 12087 12399.5 12243.3 626 12087 12399.5 Rap MWD070 FT/H 1.31 101\ 51\. 61\26 519 12140.5 12399.5 GR MWDO'lO A.PI 23.99 332.96 99.4223 519 1208'1 12346 RPX MvIJD070 OHiV[M 9.09 23.23 14 .6365 520 12101 12360. ::) RFS MWD070 OHMM 9.21\ 32.1\6 16.1501 520 12101 12360.5 RPM MWD070 OHMM 9.5 50.:51 18.09tn 520 12101 12360.5 RPD MWD070 OHHM 11. 25 52 _ 92 20.4326 520 12101 12360.5 mT MWD070 ¡¡OUR 0.6552 36.4773 6.93541 520 1210l 12360.5 First Reading For Entire File..........12087 Last Reading For Entire File...........12399.5 Fil e T rai leI' Service n~me.............STSLIB.005 Service Sub Level Name... Version Number·.......... .1.0.0 Date of Generation.......03/05/08 Maximum Physical RecoI'd..65535 File Type................ LO Next File N~me..... ......ST8L18.006 !?hysic~l E.OF File Header· Service name.._..........STSLIB.006 Service Sub Level Name... Vers.L<:)!l ì,Juntl:Jer.......... .1.0. (, D~tc of Gcner~tion.......03¡05!08 Maximum Physical Record..65535 File Type.. ..............LO Previous File Name.......STSL1C.005 CommenL Record ) FILE HEADER I:'lLl:.: NUMBER: RAW MWD Curves and log .81 '1' RUN NlJMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPD FET RPX ROP $ 6 \ header data for each bit run in separate files. 9 .5000 START DEPTH 12346.5 1?361.0 12361.0 12361. 0 1:7.361.0 12361.0 12400.0 STOP DEPTH 12374.5 1?388.5 12388.5 12388.5 12388.5 12388.5 12428.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTv\ìARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REl\L-TIME): TO DRILLER (FT): TOP LOG INTERVAL (E"r): BOTTOM LOG INTERVAL (FT): BIT ROTATING ,SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING ('I'OP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) I\T TEMPERATURE (DEGf) MUD AT MEASURED TEMPERATURE (M'!'): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: If NEUTRON TOOL I\lIATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOfF (IN): EWR FREQUENCY (HZ): REMI\RKS: $ # Data format Specification Record Da t a Reco rd Type.................. U Data Specitication Block Type.....U Logging Dj~ection.................Down Optical log depth units. ......... .Feet Data ReÏerence Point..............Undef ned fro.mc Spo.cin';J..................... 60 .1 N Max frames per record.............Undet ned Ab~eIJL vdlue...................... -999 20-NOV-02 Insite 4.3 ~1ernory 12428.0 12400.0 12428.0 86.9 86.9 TOOL NUMBER 93091 1"18425 4.750 966.5.0 QUH\DRIL-N 8.40 44.0 8.9 200 8.6 1.900 .700 1. 800 2.500 '72. (I 208.0 72.0 72.0 ') I ) Depth Uni to. . . . . . . . . . . . . . . . . . . . . . . Datum Specifìcat.ion Block sub-type. . .0 Name Service Order Unit.s Size Nsam Rep Code Offset. Channel DEPT E'T 4 1 68 (I 1 ROP MWD090 F'I'/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPI'1 MWD090 OHMM 4 1 68 20 6 RPD MWD090 01-11'11'1 4 1 68 24 7 FET IvTWDO 9 0 HOUR 4 1 68 28 8 First Last Name Service Unit. Min Max Mean Nsam Reading Reading DEPT FT 12346.5 12428 12387.3 164 12346.5 12428 ROP MWD090 FT/H 0.08 8.48 4.91751 57 12400 12128 GR MWD090 API 39.52 71.'1~) !)4.3182 57 12346.~) 12374.5 RPX MWD090 OHMM 14.07 16.88 15.8291 56 12361 12388.5 RPS MWD090 OHMM 12.21 14.03 13.2559 56 12361 12388.5 RPH MWD090 OHMM 11.29 13.28 12.3546 56 12361 12388.5 RPD MWD090 OHMM 13 .12 15.59 14.5832 56 12361 12388.5 FE.'.T MWD090 flOUR 65.4058 71.1147 67.7252 56 12361 12388.5 First Reading For Entire File..........12346.5 Last Reading S~r Entire File... ... .....12428 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Nun~er...........l.O.O Date of Generation.......03/05/08 Maximum Physical Record. .65535 File Type................ LO Next File Name...........STSLIB.007 Physical EOr File Header Service name.............STSLIB.007 Service Sub Level Name... Version Nurnber...........1.0.0 Date of Generation.......03/05/08 Maximum Physical Record..65535 File Tyµe................LO Previous File Name.......STSLIB.006 Comment RecoL'd FILE HEADER FILE NUMBER: RAW ¡vrwo Curves ond log BIT RUN NUMBER: DEPTH INCREMENT: If FI LE SUt'L'-1ARY VENDOR TOOL CODE GR RP~': RE'S FET 7 heoder doto for each bit run in seporotc files. 10 .5000 RPD ST./l.RT DEPTH L::~:n~.o 12389.0 12389.0 12:.:H39.0 12389.0 STOP DEPTH L::I~)34 . 5 1354;:).5 135'18.5 13548.~ 13548..5 12428.5 135-18.5 13588.0 RPt-'l ROP .;; 12389.0 ff LOG HE./l.DER D.I\T.P.. D.i:\TE LOGGED: SOfTrJ.l\RC :2.:J -NOV-1:!:2 \, ) ) SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (OEG MINIMUM ANGLE: MAXIMUM l\NGL8: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR EWR4 ELECTROMAG. RESIS. 4 $ # BOREHOLE AND CASING DAT.~ OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BORE:HOI,¡:': CONIYI'I'lONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): F'T,UTD LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT ME}'..SURED TEMPER}!.,.TURE (MT): MUD AT M.AX CIRCULATING TF.R.MPERATURE: MUD FILTRATE AT MT: MUD CAKE .AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type.................. (\ Oat.B Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent vi:!lue..................... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Nùme Service Order Units Size Neam Rep Cod,) Offeet DEPT FT 4 1 68 0 ROI? MWDl 00 FT!H 4 1 68 4 GR M¡'JDlOO API 4 1 68 8 RPX MWD100 OHMM 4 1 68 12 RPS HWD100 OH¡VUv¡ 4 1 68 16 R!?M M'/'JD100 OHMM 1 1 68 20 RPD MWD100 OHMM 4 1 68 24 E'ET MiIl/DlOO HOUR 4 68 28 ) Insitc 4.3 Memor~' 13588. (I 12428.0 13588.0 84.2 92.7 TOOL NUMBER 93091 178425 4.750 9665.0 QUIKDRIL-N 8.45 43.0 9.0 250 8.3 1. 900 .690 1.850 2.600 70.0 205.8 70.0 70.0 Channel 1 .., ~ì 5 ~ 7 8 Fir--st L.:::::;t Name Service Unit Min Max Mean Nsam Readinq Readin DEFT í?T .lL...> I.:.) 13588 1:2981.~} ¿,-±LI 12]"7 ~) 13::, ,-. ROP MT^!D100 FT/H D.OE 21D.37 tJ3.7·'!73 ?,'~'n 1:::>128.5 135 Co GR MWD100 API n.~6 ~lXI .1 109.334 2320 123/.') 13~:>34 ..') R?X H1i'JD100 OH¡"wí 1. 22 2000 34.2767 2320 12389 13548.5 \, ) , RPS MWDI00 OHMM 0.53 2000 39.9803 2320 RPM MWDl 00 OHMM 0.34 2000 42.5325 2320 RPD MWDl 00 OHMM 0.81 2000 208.841 2320 FET Ml:r.JDl 0 0 HOUR 0.8625 96.2679 3.60557 2320 12389 12389 12389 12389 13548.5 13548.5 13548.5 13518.5 First Reading For Entire File..........12375 Last Reading For Entire File...........13588 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03!05/08 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.008 Physical EOF file Header Service name.............STSLIB.008 Service Sub Level Name... Version Nun~er...........l.O.O Date of Generation.......03/05/08 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: II FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX fET ROP $ 8 11 .5000 START DEPTH 13535.0 13549.0 135B.O 13549.0 13549.0 13549.0 13.588.5 STOP DEPTH 13889.0 13904.5 13904.5 13904.5 13904.5 13904.5 139.50.0 ff LOG HEADER DÞ.TÞ. DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (E'T): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: HA..'ZIMUN ANGLE: ~~6-NOV-02 Insite <1.3 Memory 13950.0 13588.0 13950.0 93.1 9G.J TOOL STRING (TOP TO VENDOR TOOL CODE GM Eí>'JR.4 $ BOTTOM) TOOL TYPE Dual GR ELEC':TR.O!'ÆP.G. RESIS. TOOL NUr-IBER 93091 178425 BOREHOLE _~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 1.750 9665.0 'II. ) ) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OJ-lMM) AT' TEMPEFì.A'l'URE (DEGE') MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MllD FILTRATE AT MT: MUD CAKE AT MT: QUlKDRlL-N 8.42 42. (I 9.0 175 9.2 1.700 .760 3.750 2.000 86.0 201. 2 86.0 86.0 NEUTRON TOOL IvIATRIX: MATRIX DENSITY: HOT,E CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMJl..RKS : $ Ii Data Format Specification Record Data Record Type..................O Data Specification Glock Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefincd Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specoi tication Block sUb-type... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 (J 1 ROP MítiIDl1 0 FT/H 4 1 68 4 ,.., L GR MWD1l0 API 4 1 68 8 3 RPX MWDl1 0 OHMIvI 4 1 68 12 4 RPS MWDl1 0 OHMM 1 1 68 16 5 RPM MtliIDl1 0 OHMM 4 1 68 20 n RPD HWDl1 0 OHMH 4 1 68 24 7 FET HítiIDl10 ¡IOUI\. 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13535 13950 13742.5 831 13535 13950 ROP MWDl10 FT/H 0.32 112.31 35.8665 724 13588.5 13950 GR MWDllO API 2J./S 398.12 66.2°n -109 13~)35 1388':1 RPX HWD110 OHHJvI 3.39 172.39 18.9639 712 13549 1390·1.5 RPS HWOl1 0 OHMM 2.53 156.97 19.1008 712 135iJ 9 13901.5 RPM HWD1l0 OHMH 1. 26 239.41 20.3835 /12 13549 13904.5 RPD MWDllO OHMM 2.37 1932.94 45.6336 712 13549 13904.5 fST MítiIOll 0 ¡¡OUR 0.841 39.9335 6.04526 712 13549 13904.5 first Reading for Entire File..........13535 Last Reading For Entire File... ...... ..13950 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Ver~iüfl Number.......... .1.0.0 Date of Generation.......03!05/08 Maximum Physical Record..6~S3~ tile Type................LO ~]c:·:t File N~mc...........STSLIB.O!:19 ". ) Physical Eor Tape '1',[a1leJ:: Service name...._........LISTPE Date. . . . _ . _ _ . . . _ . . . _ . _ . . .03/ 05( OB Orì9in. . . . . _ . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Nex.-l Tape Name........ _ _ . UNK'NOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scienti fi.c Technical Services Reel Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/08 Ori9in. . _ . . . . . . . . . _ . _ . . . . STS Reel Name................ UNKNOWN Continllat.ion NlImber:'...... 01 Next Reel Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Wri.ti.ng Library. Scienti fic Technical Services PhYGical EOr Physical EOF End Of LIS F1le ) ,) a Od·-a09 / /7CJ'6 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 07 07:49:08 2003 Reel Header Service name............ .LISTPE Date.................... .03/05/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/07 origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA W-32A PBl 500292197070 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 06-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW2217600000 T. MCGUIRE A. MADSEN MWD RUN 4 MW2217600000 T. MCGUIRE A. MADSEN MWD RUN 6 MW2217600000 T. MCGUIRE A. MADSEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW2217600000 T. MCGUIRE A. MADSEN MWD RUN 8 MW2217600000 T. MCGUIRE L. VAUGHAN / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 21 11 12 735 1442 MSL 0) 88.06 54.76 ) ) # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 9665.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. THIS RUN WAS TO ORIENT THE WHIPSTOCK AND MILL THE WINDOW - NO DATA ARE PRESENTED. 4. MWD RUN 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 4, 6 - 8 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS EWR4 DATA WERE ACQUIRED OVER THE RUN 3 INTERVAL, PRIOR TO THE COMMENCEMENT OF DRILLING RUN 4. THESE MAD DATA ARE MERGED WITH RUN 4 MWD DATA. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN W-32A ON 3 JANUARY 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 17 FEBRUARY 2003. 7. MWD RUNS 1, 3, 4, 6 - 8 REPRESENT WELL W-32A PBl WITH API#: 50-029- 21970-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13025'MD/8940'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. $ File Header ) Service name............ .STSLIB.001 service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 ) and clipped curves; all bit runs merged. .5000 START DEPTH 9654.5 9658.5 9658.5 9658.5 9658.5 9658.5 9693.0 STOP DEPTH 12980.0 12994.0 12994.0 12994.0 12994.0 12994.0 13033.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9654.5 9669.0 9682.5 9689.5 9697.0 9705.0 9710.5 9720.5 9735.5 9742.0 9746.0 9758.0 9765.0 9772.5 9775.5 9778.5 9785.5 9787.5 9792.0 9794.5 9798.0 9803.0 9806.5 9809.5 9814.5 9818.0 9823.5 9828.5 9832.0 9837.0 9842.0 9849.5 9856.5 9864.5 9868.5 GR 9651.5 9667.0 9681.5 9688.0 9696.0 9704.0 9710.0 9719.0 9734.5 9741.0 9745.5 9757.5 9764.5 9772.5 9773.5 9779.0 9785.0 9787.0 9791.5 9794.5 9797.5 9802.0 9805.0 9807.0 9813.0 9818.0 9823.0 9827.5 9831.0 9835.5 9841.0 9849.5 9855.5 9862.0 9866.5 ) ) 9872.0 9870.0 9880.0 9876.5 9884.0 9882.0 9891.0 9890.0 9896.0 9896.5 9907.0 9905.0 9916.0 9913.0 9927.5 9925.5 9933.5 9932.0 9946.0 9943.5 9956.0 9953.5 9968.0 9966.0 9970.5 9968.5 9980.5 9977.5 9982.5 9979.5 9985.5 9981.5 9999.0 9995.5 10002.5 9998.5 10020.0 10016.5 10022.0 10019.5 10024.5 10022.0 10031.5 10031.0 10039.5 10036.5 10080.0 10079.0 10089.5 10086.0 10117.5 10114.0 10127.0 10125.5 10134.5 10131.0 10141.0 10135.5 10150.0 10143.5 10157.0 10152.0 10158.5 10155.0 10164.5 10160.5 10166.5 10163.0 10188.5 10184.5 10195.0 10190.0 10211.0 10207.0 10248.0 10244.0 10249.5 10245.5 10255.5 10251.5 10281.0 10277.5 10302.5 10299.0 10315.5 10313.5 10332.0 10325.0 10338.5 10330.0 10366.0 10356.5 10383.0 10381.0 10391.0 10389.0 10406.0 10402.5 10411.0 10407.5 10456.5 10455.0 10461.0 10460.0 10465.5 10465.0 10469.5 10471.5 10471.0 10473.0 10500.5 10500.0 10508.0 10507.5 10525.5 10523.5 10536.0 10534.5 10626.0 10623.5 10633.5 10629.5 10637.5 10633.5 10641.5 10638.0 10660.5 10656.0 10669.0 10664.5 ) ) 10705.5 10699.0 10711.5 10703.5 10739.5 10734.0 10745.5 10742.0 10756.0 10752.0 10764.0 10762.0 10769.0 10768.0 10773.5 10770.5 10783.0 10780.5 10787.5 10784.5 10794.0 10790.5 10796.0 10793.5 10840.0 10835.5 10864.5 10861.5 10919.5 10915.5 10940.0 10936.5 10961.5 10957.0 10998.0 10995.5 11032.0 11027.0 11044.0 11039.5 11057.5 11050.0 11089.5 11082.5 11104.5 11099.5 11113.5 11109.0 11120.0 11115.0 11173.5 11170.5 11183.0 11178.0 11203.0 11198.5 11209.0 11203.5 11231.0 11225.0 11252.0 11247.0 11263.5 11257.0 11273.5 11268.0 11312.5 11307.5 11335.5 11333.0 11363.0 11360.5 11383.5 11378.0 11413.5 11409.0 11425.5 11421.5 11448.5 11443.0 11473.0 11466.5 11478.0 11473.0 11531.0 11525.0 11554.0 11548.0 11591.5 11586.5 11596.5 11590.5 11603.5 11598.5 11611.0 11606.0 11627.0 11626.0 11643.5 11640.5 11661.5 11656.0 11677.5 11674.0 11691.0 11687.0 11704.5 11698.0 11716.5 11709.5 11723.5 11719.0 11741.0 11737.0 11769.5 11764.0 11782.0 11775.5 11785.0 11779.5 11807.0 11803.0 11813.0 11808.5 11817.0 11811.5 11824.5 11819.5 11833.5 11827.5 ) ). 11.843.5 11.864.5 11.915.0 11.935.0 11.949.0 11.955.5 11.973.0 12005.0 12007.5 12013.5 12104.0 12121.0 12139.5 12153.5 12155.5 12157.5 12166.5 12176.5 12181.5 12184.5 12193.5 12203.5 12209.5 12228.0 12257.5 12289.5 12310.0 12324.5 12330.5 12336.0 12350.0 12356.0 12372.0 12377.0 12382.5 12402.5 13033.5 $ 11836.5 11859.5 11909.0 11930.0 11944.5 11952.0 11968.0 11997.0 12000.0 12005.5 12094.5 12114.0 12133.0 12146.5 12149.0 12151.0 12164.5 12171.5 12175.0 12177.5 12189.0 12197.5 12203.0 12220.5 12251.0 12282.0 12303.5 12318.5 12322.0 12328.0 12343.0 12347.5 12363.5 12368.5 12374.0 12394.0 13025.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 3 4 6 7 8 MERGE TOP 9651.5 10473.0 10547.0 12140.0 12847.0 MERGE BASE 10473.0 10547.0 12140.0 12847.0 13025.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ) ) ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9654.5 13033.5 11344 6759 9654.5 13033.5 ROP MWD FT/H 0.08 244.11 63.8775 6682 9693 13033.5 GR MWD API 20.78 479.65 64.9448 6652 9654.5 12980 RPX MWD OHMM 0.62 1971.07 30.6161 6672 9658.5 12994 RPS MWD OHMM 0.63 2000 42.2735 6672 9658.5 12994 RPM MWD OHMM 0.16 2000 48.9009 6672 9658.5 12994 RPD MWD OHMM 0.46 2000 114.911 6672 9658.5 12994 FET MWD HOUR 0.281 104.698 10.9804 6631 9658.5 12994 First Reading For Entire File......... .9654.5 Last Reading For Entire File.......... .13033.5 File Trailer Service name............ .STSLIB.001 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 F i 1 e Type..... . . . . . . . . . . . LO 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...... .03/05/07 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 3 .5000 START DEPTH 9651.5 9691.5 STOP DEPTH 10433.0 10473.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 11-NOV- 02 ) SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ) Insite 4.3 Memory 10473.0 9691.0 10473.0 32.2 89.1 TOOL NUMBER 93091 4.750 9665.0 QUIKDRIL-N 8.45 41.0 9.1 1400 8.8 .000 .000 .000 .000 .0 190.4 .0 .0 Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam First Reading Last Reading ) ) DEPT FT 9651.5 10473 10062.3 1644 9651.5 10473 ROP MWD030 FT/H 0.58 205.19 46.4458 1564 9691.5 10473 GR MWD030 API 22.17 479.65 77.924 1564 9651.5 10433 First Reading For Entire File......... .9651.5 Last Reading For Entire File.......... .10473 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 File Type................ LO 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...... .03/05/07 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM FET RPD GR ROP $ 3 header data for each bit run in separate files. 4 .5000 START DEPTH 9655.5 9655.5 9655.5 9655.5 9655.5 10433.5 10473.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) STOP DEPTH 10507.5 10507.5 10507.5 10507.5 10507.5 10493.5 10547.0 12-NOV-02 Insite 4.3 Memory 10547.0 10473.0 10547.0 101.6 102.6 ,} VENDOR TOOL CODE GM EWR4 $ TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER 93091 178425 4.750 9665.0 QUIKDRIL-N 8.45 42.0 8.8 1200 7.8 1.900 .770 1.800 2.200 72.0 187.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 FET MWD040 HOUR 4 1 68 24 7 RPD MWD040 OHMM 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9655.5 10547 10101.3 1784 9655.5 10547 ROP MWD040 FT/H 1.15 208.88 65.5224 148 10473.5 10547 GR MWD040 API 21.94 133.38 51.4767 121 10433.5 10493.5 RPX MWD040 OHMM 0.62 1826.86 13.7837 1705 9655.5 10507.5 RPS MWD040 OHMM 0.63 2000 22.857 1705 9655.5 10507.5 RPM MWD040 OHMM 0.16 2000 17.1475 1705 9655.5 10507.5 ) FET MWD040 HOUR RPD MWD040 OHMM 1.324 0.07 104.705 2000 ) 35.5293 1663 34.1456 1705 9655.5 9655.5 10507.5 10507.5 First Reading For Entire File......... .9655.5 Last Reading For Entire File.......... .10547 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 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...... .03/05/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX FET RPD RPM ROP $ 4 header data for each bit run in separate files. 6 .5000 START DEPTH 10494.0 10508.0 10508.0 10508.0 10508.0 10508.0 10547.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 12086.5 12100.5 12100.5 12100.5 12100.5 12100.5 12140.0 15-NOV-02 Insite 4.3 Memory 12140.0 10547.0 12140.0 85.1 94.7 TOOL NUMBER ) 1\ , GM Dual GR 93091 EWR4 ELECTRO MAG. RES IS. 4 178425 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 4.750 DRILLER'S CASING DEPTH (FT) : 9665.0 # BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL-N MUD DENSITY (LB/G) : 8.50 MUD VISCOSITY (S) : 44.0 MUD PH: 8.5 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 7.2 RESISTIVITY ( OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.900 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .860 161.0 MUD FILTRATE AT MT: 1.900 69.0 MUD CAKE AT MT: 2.300 69.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10494 12140 11317 3293 10494 12140 ROP MWD060 FT/H 0.24 244.11 79.5367 3186 10547.5 12140 GR MWD060 API 20.78 200.75 49.6203 3186 10494 12086.5 RPX MWD060 OHMM 1.64 30.59 13.372 3186 10508 12100.5 RPS MWD060 OHMM 1.67 49.86 14.6931 3186 10508 12100.5 RPM MWD060 OHMM 1.96 62.38 15.9204 3186 10508 12100.5 RPD MWD060 OHMM 2.36 38.57 17.8872 3186 10508 12100.5 ) FET MWD060 HOUR 0.281 37.7883 ) 1.95737 3186 10508 12100.5 First Reading For Entire File......... .10494 Last Reading For Entire File.......... .12140 File Trailer Service name............ .STSLIB.004 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM FET RPD ROP $ 5 header data for each bit run in separate files. 7 .5000 START DEPTH 12087.0 12101.0 12101.0 12101.0 12101.0 12101.0 12140.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR STOP DEPTH 12794.5 12808.5 12808.5 12808.5 12808.5 12808.5 12847.0 18 -NOV- 02 Insite 4.3 Memory 12847.0 12140.0 12847.0 83.3 92.6 TOOL NUMBER 93091 ) ) ,. EWR4 ELECTROMAG. RES IS. 4 178425 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 4.750 DRILLER'S CASING DEPTH (FT) : 9665.0 # BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL-N MUD DENSITY (LB/G) : 8.40 MUD VISCOSITY (S) : 43.0 MUD PH: 8.8 MUD CHLORIDES (PPM) : 350 FLUID LOSS (C3) : 9.6 RESISTIVITY ( OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.850 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .720 186.8 MUD FILTRATE AT MT: 1.850 69.0 MUD CAKE AT MT: 2.800 69.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record. . . . . . . . . . . . .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12087 12847 12467 1521 12087 12847 ROP MWD070 FT/H 0.08 147.46 57.6126 1414 12140.5 12847 GR MWD070 API 23.99 332.96 73.3268 1416 12087 12794.5 RPX MWD070 OHMM 5.02 26.14 13.6202 1416 12101 12808.5 RPS MWD070 OHMM 4.93 32.46 14.4892 1416 12101 12808.5 RPM MWD070 OHMM 4.9 50.31 15.6649 1416 12101 12808.5 RPD MWD070 OHMM 6.46 115.23 18.3414 1416 12101 12808.5 FET MWD070 HOUR 0.3411 36.4773 3.40304 1416 12101 12808.5 \ First Reading For Entire File......... .12087 Last Reading For Entire File.......... .12847 File Trailer Service name............ .STSLIB.005 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 F i 1 e Type................ LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 6 ) header data for each bit run in separate files. 8 .5000 START DEPTH 12795.0 12809.0 12809.0 12809.0 12809.0 12809.0 12847.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 12971.5 12985.5 12985.5 12985.5 12985.5 12985.5 13025.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 8M Dual GR EWR4 ELECTRO MAG. RES IS. 4 20-NOV-02 Insite 4.3 Memory 13025.0 12847.0 13025.0 91.1 93.5 TOOL NUMBER 93091 178425 '\ , $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ...... .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ~ ) 4.750 9665.0 QUIKDRIL-N 8.45 42.0 8.5 200 7.4 1.750 .000 1.650 2.250 75.0 .0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12795 13025 12910 461 12795 13025 ROP MWD080 FT/H 0.8 91.78 22.9988 356 12847.5 13025 GR MWD080 API 58.56 256.32 118.152 354 12795 12971.5 RPX MWD080 OHMM 23.9 1971.07 338.382 354 12809 12985.5 RPS MWD080 OHMM 29.88 2000 503.198 354 12809 12985.5 RPM MWD080 OHMM 38.8 2000 633.96 354 12809 12985.5 RPD MWD080 OHMM 97.47 2000 1775.75 354 12809 12985.5 FET MWD080 HOUR 1.9517 25.7843 8.50067 354 12809 12985.5 '\ > ~ First Reading For Entire File......... .12795 Last Reading For Entire File.......... .13025 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 F i 1 e Type................ LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/07 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. . . . . . . . . . . . . . . . . . . . .03/05/07 Origin. . . . . . . . . . . . . . . . . . . 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