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Home My WebLink About202-237 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 .. December 20, 2010 �N ;�� Mr. Tom Maunder +., 1 Alaska Oil and Gas Conservation Commission SAN 11 A 'Li I . 333 West 7 Avenue Anchorage, Alaska 99501 "fi',. 3tis. "vSiOtt Subject: Corrosion Inhibitor Treatments of GPB Y Pad ''finclv^,ge Dear Mr. Maunder, - 35®� n Enclosed please find multiple copies of a spreadsheet with a list of wells from Y Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12/20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal Y -01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y - 02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y -03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y -04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y -05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y -06A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y -07A 2071050 50029205600100 14.5 2.0 0.3 NA 1.70 8/4/2010 Y -08A 1880560 50029205720100 NA 4 NA 15.30 8/5/2010 Y -09A 1970830 500292057 §0100 19 1.5 3.6 NA 17.00 8/4/2010 Y -10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y -11C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y -13 1811120 50029206340000 NA _ 0.4 NA 3.40 4/15/2010 Y -14B 2011010 50029218320200 _ NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y -16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y -18 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y -19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y -20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y -21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y -22A 1881150 50029215580100 NA 0.5 NA 3.40 8/4/2010 Y -23B 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y - 25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y - 26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y - 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y - 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y - 29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 Y -30 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y - 1910560 50029221610000 NA 0.5 NA 3.40 4/12/2010 Y - 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y - 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y - 34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y -35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y - 1931310 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y - 37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS C~I~'~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated ~Ic~S~s~hi~l~ AID/MILL ~ ~ ?9 ?- ',.;.;.;, Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~At1C!~r"~~"` ' 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory 202-2370 - 3. Address: P.O. Box 196612 Stratigraphic (°~" Service 6. API Number: Anchorage, AK 99519-6612 50-029-22186-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 78.6 KB ' PBU Y-35A - 8. Property Designation: 10. FieldlPool(s): ADLO-047471 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12750 - feet Plugs (measured) None true vertical 8996.26 - feet Junk (measured) None Effective Depth measured 12750 - feet ~,'~~a~'r,' ..-!~;j`x '' ~~ true vertical 8996.26 - feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2694 10-3/4" 45.5# nt-80 Surface - 2694 Surface - 2694 5210 2480 Production 6680 7-5/8" 29.7 # I-80 Surface - 6680 Surface - 5926 6890 4790 Liner 4410 5-1/2" 17# I-80 6513 - 10923 5809 - 8846 7740 6280 SL 1990 3-1/2" 9.2# I-80 11148 - 12654 8952 - 8986 10160 10530 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.2# 13CR-80 SURFACE - 10737' 0 0 - Packers and SSSV (type and measured depth) 3-1/2" BKR SABL-3 PKR 10681' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 101 480 829 205 Subsequent to operation: 141 876 1170 225 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory ~ Development ]~ - Service 1~` Daily Report of Well Operations X 16. Well Status after proposed work: Oil ' Gas WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature ~'°f Phone 564-4944 Date 6/5/2009 Form 10-404 Revised 04/2006 ~.~ ~ ~...y Submit Ori ' I Onl Y-35A 202-237 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Y-35A 1/20/03 SL 11,142. 11,474. 8,950.72 8,982.43 Y-35A 1/20/03 SL 11,536. 12,229. 8,977.22 8,948.49 Y-35A 1/20/03 SL 12,324. 12,413. 8,952.92 8,960.65 Y-35A 1/20/03 SL 12,475. 12,654. 8,966.23 8,985.51 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ! • Y-35A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/27/2009 CTU #6 1.75" CT (Job Scope -Mill Scale /Acid Stimulation) MIRU, Safety I j Meeting, MU and RIH w/ BHA #1 2-1/8" BOT Motor and 2.625" Drag Mill Continued on WSR 5/28/09 t 5/27/2009~ASRC Test Unit #1, S/B for CTU, CTU on location, Assist CTU, ***Job in I progress**` _ 5/28/2009~ASRC Test Unit #1, Assist CTU, ""*Job in progress*'"' ____ _____ _. _ _.__.__ ____ ~__.._~. _______ ~ . _ _ _~... s. ___.. __ _. _ _ ~ 3 5/28/2009~T/I/0=200/1650/200 Temp= S/I Assist CTU (Acid job) Job preparations'`'`*Job continued on 5/29/09 WSR"*'' 5/28/2009 CTU #6 1.75" CT (Job Scope -Mill Scale /Acid Stimulation) Continued from WSR 5/27/09 Work ice plug out of Y-02 flowline for ASRC to take returns to production, Mill Scale w/ GL assist 11,142' - 12,000', Trip to above OGLV, SD j pump and allow well to unload. Well stabilized RIH and continue milling from ' .12,000' to 12,730' ctmd and short tripped after every 150-180' up to the Screened Orifice chasing Geovis sweeps. POOH and call for Acid ""`Job in Progress*** 5/29/2009 ASRC Test Unit #1, Assist CTU, Divert well thru test sep, ***Job in progress""* 5/29/2009 ***Job continued from 5/28/09 WSR"** Assist CTU; Pumped 5 bbls meth and 375 ~ bbls crude to load IA. FWHPs= 220/0/200 CTU in control of well at time of _ ~~ de arture. _ _ " ~ 5/29/2009 CT (Job Scope -Acid Stimulation) «<InterACT is Publishing»> CTU #6 1.75 I Continued from WSR 05/28/09 LRS loaded IA with dead crude to 10598' _ (Screened Orifice). Performed 360 bbl 12% HCL Acid Stim with Foam Diversions ~ .. L.li...J 17......- Fr...... A A A A~f~ F.. ~ rfGCA~ ..Iw...l ~l1r1LJ r, r+r! +. ~rr• • r.ll .. i.r fn A Q~/'~ ~~ ;POP well. RD. """Job Complete*** ~~~~~~~ ~ ~~~ ~ ~~~~ ~~~~~ ~~~~~ 5/30/2009 ASRC Test Unit #1, Conitnue acid flowback, *"*Job in progress"*" 5/31/2009iASRC Test Unit #1, Continue acid flowback, **'Job in progress*** 6/1/2009 ASRC Test Unit #1, Complete acid flowback, divert well to production R/D, no test per PE, ***Job complete'""'* FLUIDS PUMPED BBLS 170 50/50 METH 630 2% KCL XS 100 GEOvIS W/SC 45 DIESEL 365 12% HCI 355 2% KCI + F103 55 2% KCI + F103 + U067 28 2% KCI + J529 OILSEEKER 50 BIO 1790 Total 06/18/07 Schlumberger 5'GANNED JUN 2 1 Z007 NO. 4306 Well Job# Loa DescrìDtion Date BL Color CD L3-12 11695062 PRODUCTION PROFILE 06/06/07 1 GNI-03 11637128 PRESS/TEMP SURVEY 06/06/07 1 Y -11 C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 05-30 11801067 LDL 06/01/07 1 13-29L 1 11686753 LDL OS/28/07 1 Y-OSA 11628778 MEMORY INJECTION PROFILE OS/28/07 1 L5·23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROFIIPROF 06/05/07 1 Y-35A 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFilE 06/13/07 1 01-07 A 11626098 PRODUCTION PROFilE OS/28/07 1 13-29L 1 11686753 LDL OS/28/07 1 04-24 11773112 PRODUCTION lOG 05/19/07 1 12-19 11637343 lDL 06/13/07 1 G-23A 11638639 lDL 06/03/07 1 14-0SA 11813055 PPROF W/RST BORAX 06/11/07 1 K-12A 11745224 MEMORY PROD PROFILE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/08/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04/21/07 1 W-17A 40012333 OH EDIT MWD/LWD 09/19/05 2 1 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~oJ-B3~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 Date Delivered: "n ¡j,Jl ;/',n ZOO1 {/,l ~-7 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . . Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc ) WELL LOG TRANSMITTAL ) ... ('~ \\1 ,:) ~<O'" . (,\ '2. (; ?S\\)') . o c,\ìrolí\~\SS~ij%\ rf~ j31 1\\a~\'~a u\ .'. February 23, 2004 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: Y-35A, AI(-MW-22210 Y-35A: Digital Log Images: 50-029-22186-01 -J I }!Jr;c 5CANNEO NOV 0 2 2005 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob I(alish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: I NtH/dM~ Signed: 1lJ{!!JJ ÍÀð^ - <.1 7 I=':I~ ;... J FJ. ~ s" DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022370 Well Name/No. PRUDHOE BAY UNIT Y-35A Operator BP EXPLORATION (ALASKA) INC .sf uui ..z J ""'- JJ,~j API No. 50-029-22186-01-00 MD 12750 (;./". TVD 8996 /. Completion Date 1/21/2003 / Completion Status 1-01L Current Status 1-01L UIC N ---_._---~- REQUIRED INFORMATION Mud Log No Samples No Directional Survey C-) ". ....---=--'"---._~ DATA INFORMATION Types Electric or Other Logs Run: MWD.DIR, GR, PWD, RES Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Digital ~,~ed/Frmt ¿ßEl~ 0 (:ßPC Electr Dataset Number Name Directional Survey ~93 LIS Verification --US Verification '--' Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 1 6660 12750 Open 3/26/2003 MWD 6591 12695 Open 4/17/2003 6591 12695 Open 4/17/2003 6660 12750 Open 3/26/2003 6660 12750 Open 3/26/2003 MWD 6660 12750 Open 3/26/2003 25 1,3,4,5, 6680 12750 Open 2/26/2004 ROP, DGR, EWR- Horizontal Presentation - MWD 25 1,3,4,5, 6680 12750 Open 2/26/2004 ROP, DGR, EWR - Horizontal Presentation - ---- MWD 1,3,4,5, 6680 12750 Open 2/26/2004 ROP, DGR, EWR- Horizontal Presentation - MWD 1,3,4,5, 6680 12750 Open 2/26/2004 ROP, DGR, EWR - Horizontal Presentation - MWD Sample Set Sent Received Number Comments : Rpt Directional Survey I Rpt Directional Survey ¿ø 0 Directional Survey ¡ i t: C Pdf (í2428 Rate of Penetration C Pdf 12428 Induction/Resistivity r r/ d ED C Lis 12428 Rate of Penetration çD C Lis )2428 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Permit to Drill 2022370 MD 12750 ND 8996 ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? .--v-t~ Analysis ~~. Received? Comments: ----~--- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Well Name/No. PRUDHOE BAY UNIT Y-35A Completion Date 1/21/2003 ~ .Operator-BP EXPLORATION (ALASKA) INC Completion Status 1-01L Daily History Received? Formation Tops API No. 50-029-22186-01-00 Current Status 1-01L ~\ C!í/N (J/N Date: UIC N ",-~,- :2 Á- ¡v~ ~~j--- --- ) ) d Od ~cY3 '1- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23, 2004 RE: MWD Formation Evaluation Logs: Y-35A, AK-MW-22210 Y-35A: Digital Log Images: 50-029-22186-01 1 CD Rom /¿y-/~ 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 ~éEIVED Sign~\:" ~'-c (').~ F-:.~p 2 6 ?004 __....J ,-U\J 1~\1~5ka Œ~ 8: Gas Cons. Commission ÞJìriKwage ~~~~~ ) \ } I é1 O¿;;-d 3 7 / /093 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 3 33 West 7th A venue, Suite 100 Anchorage, Alaska April 08, 2003 RE: MWD Formation Evaluation Logs Y-35A, AK-MW-22210 1 LDWG formatted Disc with verification listing. API#: 50-029-22186-01 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: ~,~ Signed: RECEIVE~() APR 1 7 2003 Ala:ska Oi) & Gas Cons. CŒThl1i$&kIn AnchOf!ge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ) 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. N:~~I~~:~~t~~laSka) Inc. raç¡J~:{J 7, ~~~~3~umber 3. Address ~ ,",.1:2:L:.l2~ i 8. API Number P.O',BOX 196612, Anchorage, Alaska 99519-66j;~"~::"",,J 50-029-22186-01 4. Location of well at surface:>""'~'f",,,!,,,,¡"''ê'i:'' 9. Unit or Lease Name 1243' SNL, 4696' WEL, SEC. 34, T11 N, R13E, UM' ' X = 645395, Y = 5949024 Prudhoe Bay Unit At top of productive interval 249' SNL, 1613' WEL, SEC. 03, T10N, R13E, UM X = 648570, Y = 5944800 10. Well Number At total depth 1801' SNL, 1187' WEL, SEC. 03, T10N, R13E, UM X = 649029, Y = 5943257 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 78.6' ADL 047471 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/2/2003 r 1/18/2003 1/21/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12750 8996 FT 12750 8996 FT 1m Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, PWD, RES Classification of Service Well Y-35A 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2144' MD 1900' (Approx.) y{JtJerIV ~b?2D' ø¡;> 5'~2S"'"7VD 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' 10-3/4" 45# L-80 Surface 2694' 13-1/2" 2924 cu ft Coldset III & II 7-5/8" 29# L-80 Surface 6680' 9-7/8" 1601 cu ft Class 'G' 5-1/2" 17# L-80 6513' 10923' 6-3/4" 168 cu ft Class 'G' 3-1/2" 9.2# L-80 10751' 12749' 4-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-1/2" Slotted Section SIZE 3-1/2",9.2#, 13Cr80 19Cr TUBING RECORD DEPTH SET (MD) 10738' PACKER SET (MD) 10681' 25. MD 11142' -11474' 11536' - 12229' 12324' -12413' 12475' - 12654' TVD 8950' - 8982' 8978' - 8949' 8953' - 8961' 8966' - 8985' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 94 Bbls of Diesel 27. Date First Production February 4, 2003 Date of Test Hours Tested 3/1/2003 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD OIL-BBL 818 OIL-BBL GAs-McF 3,460 GAs-McF WATER-BBL 672 WATER-BBL CHOKE SIZE 54.78° OIL GRAVITY-API (CORR) GAS-OIL RATIO 4,228 Flow Tubing Casing Pressure CALCULATED Press. 281 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. . ,J' ¡.- ¡....... 'v Form 10-407 Rev. 07-01-80 R B 0 M S B F (, ;',1ßP ? ,""y~ubmit In Duplicate ) ) Marker Name Geologic Markers Measured Depth 30. Formation Tests 29. True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 10924' 8846' Shublik 10960' 8869' Sadlerochit 11128' 8946' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble r/~ ~~ Title Technical Assistant Date 03- 05-03 Y -35A 202-237 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Phil Smith, 564-4897 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 (OF, KB, etc.). ITEM 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 1/1/2003 1/14/2003 LOT FIT Y-35 Y -35A Test Type Test Depth (TMD) 67,080.0 (ft) 10,943.0 (ft) TestD~pth.(TVD) 5,945.0 (ft) 8,858.0 (ft) EMW 12.44 (ppg) 10.01 (ppg) AMW 10.50 (ppg) 8.60 (ppg) SurfacêPressorê 600 (psi) 650 (psi) L~a~···OffPrØ$sÚrê(a,HP) 3,843 (psi) 4,607 (psi) ~ ~ Printed: 1/27/2003 9:54:40 AM ) ) BP EXPLORATION '()peration$'Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From- To 12/29/2002 15:00 - 16:00 16:00 - 17:00 17:00 - 19:00 19:00 - 22:00 22:00 - 00:00 12/30/2002 00:00 - 03:00 1.00 MOB P 1.00 MOB P 2.00 MOB P 3.00 MOB P 2.00 MOB P 3.00 RIGU P 03:00 - 03:30 03:30 - 05:00 0.50 RIGU P 1.50 WHSUR P 05:00 - 07:30 2.50 PULL P 07:30 - 08:00 0.50 PULL P 08:00 - 08:30 0.50 PULL P 08:30 - 10:30 2.00 WHSUR P 10:30 - 12:30 2.00 BOPSUR P 12:30 -16:00 3.50 BOPSUR P 16:00 - 16:30 0.50 BOPSUR P 16:30 - 17:00 0.50 BOPSUR P 17:00 - 19:00 2.00 BOPSUR N 19:00 - 20:00 1.00 BOPSUR P 20:00 - 20:30 0.50 BOPSUR P 20:30 - 21 :00 0.50 PULL P 21 :00 - 21 :30 0.50 PULL P 21 :30 - 00:00 2.50 PULL P 12/31/2002 00:00 - 03:30 3.50 PULL P 03:30 - 04:30 04:30 - 05:00 05:00 - 09:30 1.00 PULL P 0.50 PULL P 4.50 CLEAN P 09:30 - 10:00 10:00 - 11 :00 11:00 -15:30 15:30 - 20:00 20:00 - 20:30 0.50 CLEAN P 1.00 CLEAN P 4.50 STWHIP P 4.50 STWHIP P 0.50 STWHIP P Code N PT Phase PRE PRE PRE PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WAIT DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT WEXIT WEXIT 20:30 - 21 :30 1.00 STWHIP P WEXIT 21 :30 - 00:00 2.50 STWHIP P WEXIT 1/1/2003 00:00 - 08:00 8.00 STWHIP P WEXIT 08:00 - 09:00 1.00 STWHIP P WEXIT 09:00 - 09:30 0.50 DRILL P WEXIT Page 1 of 11 Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 Description of Operations Move shop, pits, and camp. Move sub base off well. Move shop, pits, camp, and sub from H pad to Y pad Lay rig mats and herculite. spot sub base over Y-35A. Set shop and pit complex in place. Berm rig. Spot camp, shacks, and cuttings tank. Hook up lines to pits. Accept rig at 03:00. Hold pre spud meeting. Check for pressure on well. Bleed 150 psi off lower annulus. Install secondary annulus valve and connect lines. Reverse circulate diesel from tubing. Swap lines and pump safe clean sweep and displace diesel from annulus at 4 bpm, 320 psi. Blow down and unhook lines. Install TWC and test from below to 3,000 psi. NO tree and adapter. Bleed off control lines . Function LOS. Inspect hanger threads and check XO. NU BOP and RU to test. Test BOPE to 250 psi /3,500 psi as per AOGCC regs and BP policy. Witness of test waived by Winton Aubert of AOGCC. RD test equipment. Service top drive. Wait on DSM equipment. Pull TWC with lubricator. BOLDS. Pull hanger to rig floor. PU=98K. No over pull from tubing cut. LD hanger. Change handling equipment. RU spooling unit. LD 4 1/2", 13 Cr, TDS tubing with dual encapsulated control lines to SSSV. Continue to LD 41/2" tubing. Recovered 167 joints of tubing, one 19.88' cut joint, 2 GLMs, 1 SSSV w/ dual encapsulated control lines, 27 of 27 control line clamps, and 3 of 3 SS bands. LD tubing equipment. Clear rig floor. Install wear bushing. PJSM. RU eline unit. RIH with 6.75" gauge ring / junk basket and CCL POH. RIH w/ EZSV and set at 6,712' WLM. RD eline unit. Test casing to 3,500 psi for 30 minutes. PU whipstock BHA. Load MWD and test. RIH and PU 4" DP from 943' to 6,699'. Tag bridge plug at 6,699'. PU=135K, SO=120K. Orient whipstock and set at 89 degrees right of high side. Anchor set at 20K down. Pick up to check that anchor is set. Slack off and shear off whipstock at 32K down. Displace well bore to 10.5 ppg LSND fluid at 8 bpm, 1,442 psi. Mill window from 6,Ç.80' to 6,684'. Mill window and formation from 6,684' to 6,708'. Top of window=6,680'. Bottom ofwindow=6,692'. Work through window and circulate sweep around at 296 gpm, 2,260 psi. Perform LOT to 12.45 ppg EMW. Printed: 1/27/2003 9:54:53 AM ) ) BPI;XPLORATION Page 2 of11 OperationsSumrnary Rèport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From':' To Hours Task Code NPT Phase 1/1/2003 2.00 STWHIP P 1.50 STWHIP P 0.50 DRILL P 1.00 STWHIP P 2.00 DRILL P 09:30 - 11 :30 11 :30 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 16:30 16:30 - 18:00 1.50 DRILL P 18:00 - 21 :00 3.00 DRILL P 21 :00 - 22:00 1.00 DRILL P 22:00 - 00:00 2.00 DRILL N 1/2/2003 00:00 - 02:30 2.50 DRILL N 02:30 - 03:00 0.50 DRILL N 03:00 - 04:30 1.50 DRILL N 04:30 - 07:00 2.50 DRILL N 07:00 - 08:00 1.00 DRILL P 08:00 - 16:30 8.50 DRILL P WEXIT WEXIT WEXIT WEXIT INT1 INT1 INT1 INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 INT1 INT1 16:30 - 17:30 1.00 DRILL P INT1 17:30 - 18:00 0.50 DRILL P INT1 18:00 - 19:00 1.00 DRILL N DPRB INT1 19:00 - 19:30 0.50 DRILL N DPRB INT1 19:30 - 00:00 4.50 DRILL N DPRB INT1 1/3/2003 00:00 - 02:30 2.50 DRILL N DPRB INT1 02:30 - 03:30 1.00 DRILL N DPRB INT1 03:30 - 04:00 0.50 DRILL N DPRB INT1 04:00 - 09:00 5.00 DRILL N DPRB INT1 09:00 - 09:30 0.50 DRILL N DPRB INT1 09:30 - 12:00 2.50 DRILL N DPRB INT1 12:00 - 12:30 0.50 DRILL N DPRB INT1 12:30 - 13:30 1.00 DRILL N DPRB INT1 13:30 - 16:00 2.50 DRILL N DPRB INT1 Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 Descrlþtionöf Operations Pump dry job and POH from 6,650' to 924'. Stand back HWDP and LD DCs and mills. Mills in gauge. Clear rig floor. Flush stack. PU 6 3/4" BHA to 953'. Flow test MWD at 94'. Function Adjustable Gauge Stabilizer. 110 psi difference between open and closed. Slip and cut drilling line. Service top drive and crown. PU 4" DP from 953' to 5,299'. Fill pipe at 2,200'. Attempt to fill pipe and circulate at 5,299', Drill string plugged, unable to circulate. Drop rabbit. POH from 5,299' to 2,556', POH and stand back BHA. Bit nozzles plugged with metal. Break bit and clean. Break MWD and change out pulser. 2 cups of metal cuttings packed in MWD pulser and impeller. Clean rig floor. MU BHA. Flow test MWD, AGS, and motor. RIH from 921' to 6,607'. Break circulation every 500' starting at 3,716'. Orient motor and slide through window. Wash to 6,708'. Drill from 6,708' to 7,544'. AST=2.0, ART=3.2. 340 - 327 gpm, 3,850 psi - 4,340 psi. Slow rate to 327 gpm due to pump pressure. ROP sliding: 74 - 100 fph. ROP rotating 150 - 310 fph. Slide with 85 right TF from 6,708' - 6,798' to get away from old well bore. Neutral/ building 0.3 deg per 100' while rotating with AGS full gauge. Lost total returns while sliding at 7,535'. Monitor well. Static. POH from 7,544' to 6,690'. No over pulls. Monitor well. Static. RIH from 6,690' to 7,544'. No hole problems. Reciprocate pipe while pumping 40 bbl LCM pill at 4 bpm, 1,575 psi. LCM pill: 20 Ib/bbl Mix2 (M). Drill from 7,544' to 7,554' with no returns. Monitor well. Static. Pump dry job. POH from 7,554' to 2,150'. Stand back HWDP. LD MWD, AGS, motor, and bit. Read MWD in pipe shed off critical path. Clear and clean rig floor. MU mule shoe and float sub with solid float. RIH w/ HWDP, jars, and 4" DP to 1,674'. Circulate 9.8 ppg mud around at 270 gpm, 450 psi. No losses. RIH to 2,604'. Circulate 9.8 ppg mud around at 272 gpm, 610 psi. Continue to stage in hole and circulate 9.8 ppg at 2,604', 3,536',4,468', 5,400', and 6,614'. 30 bbls lost while circulating. RIH from 6,614' to 7,550', PU=135K, SO=120K. Circulate and condition mud staging pumps up slowly to 6.5 BPM, 1,090 psi. Increase pump rate to 450 gpm, 20 bph loss rate. Pump 107 bbls of 80 Iblbbl LCM pill at 11 bpm, 4,010 psi. Displace to clear drill pipe. POH from 7,554' to 5,956'. Squeeze away 30 bbls of LCM pill at 0.5 bpm. Increase rate to 0.75 bpm to achieve 700 psi surface pressure, Shut down Printed: 1/27/2003 9:54:53 AM ) ') BP EXPLORATION O:perationsSummary ,Røport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/3/2003 1/4/2003 1/5/2003 Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From- To Hours Task Code 'N PT Phase 13:30 - 16:00 2.50 DRILL N DPRB INT1 16:00 - 18:00 2.00 DRILL N DPRB INT1 18:00 - 18:30 0.50 DRILL N DPRB INT1 18:30 - 19:00 0.50 DRILL N DPRB INT1 19:00 - 21 :00 2.00 DRILL N DPRB INT1 21 :00 - 23:30 2.50 DRILL N DPRB INT1 23:30 - 00:00 0.50 DRILL N DPRB INT1 00:00 - 01 :30 1.50 DRILL N DPRB INT1 01 :30 - 02:30 1.00 DRILL N DPRB INT1 02:30 - 04:00 1.50 DRILL N DPRB INT1 04:00 - 09:00 5.00 DRILL P INT1 09:00 - 09:30 0.50 DRILL P INT1 09:30 - 10:30 1.00 DRILL P INT1 10:30 - 11 :30 1.00 DRILL P INT1 11 :30 - 16:30 5.00 DRILL P INT1 16:30 - 17:00 0.50 DRILL P INT1 17:00 - 18:00 1.00 DRILL P INT1 18:00 - 00:00 6.00 DRILL P INT1 00:00 - 06:30 6.50 DRILL P INT1 06:30 - 07:30 1.00 DRILL P INT1 07:30 - 12:00 4.50 DRILL P INT1 12:00 - 13:00 1.00 DRILL P INT1 13:00 -14:30 1.50 DRILL P INT1 14:30 - 00:00 9.50 DRILL P INT1 1/6/2003 00:00 - 11 :30 11.50 DRILL P INT1 11 :30 - 13:00 1.50 DRILL P INT1 13:00 - 13:30 0.50 DRILL P INT1 13:30 - 15:30 2.00 DRILL P INT1 15:30 - 21 :00 5.50 DRILL P INT1 Page 3 of 11 Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 Description of Operations pump. Pressure bled to 465 psi after 10 minutes. Calculated leak off 11.3 ppg with LCM in hole. Bled back 3 bbls. POH from 5,966' to 742'. Stand back HWDP. Clean rig floor. MU 6 3/4" BHA. Upload MWD. Function AGS. RIH from 925' to 6,610'. Service top drive. Orient to go through window. Circulate bottoms up. Full returns. Lots of LCM over shakers. Ream to bottom to clean out LCM. No hole problems. CBU at 7,554'. 225 gpm, 2,100 psi. Lots of LCM over shakers. Obtain SPRs. Drill from 7,554' to 8,002'. ECD=10.75. 285 gpm, 3,060 psi. ROP 120 - 150 fph. ART=3.65, AST=O. Start losing fluid at 8,022'. Lost 30 bbls. Pump 40 bbl LCM pill, 20 ppb Mix 2. Drill from 8,022' to 8,108'. ART=0.78, AST=O. Circu late out LCM pill at 8,108'. Drill from 8,108' to 8,483'. Control drill at 100 fph. ART=3.41, AST=0.30 CBU at 325 gpm, 3,100 psi. Short trip to 7,540'. No hole problems. No fill. Drill from 8,483' to 8,844'. Control drill at 120 fph. ART=4.95, AST=O. Continue drilling 6 3/4" hole to 9,277'. AST=0.3, ART=4.5. Crossed projected fault at 8,960'. Flow decreased and 13 bbls of mud lost. Shut down pumps and observe well. Flowed back 13 bbls of mud, well bore breathing. Continue drilling at 80 fph with well bore breathing. MW=10.0 ppg. ECD 11.2 ppg at 300 gpm. Slow pump to 280 gpm, ECD 11.15. Control drill at 80 fph. ECD increased to 11.3 ppg. CBU at 280 gpm, 3050 psi to reduce ECD to 11.2 ppg. Drill from 9,277' to 9,603'. Control drill at 100 fph. AST=O, ART=3.5. PU=175K, SO=125K, RT=145K. TO ON=8K, TO OFF=7K. Circulate sweep around at 280 gpm, 2,900 psi. Monitor well. Well flowed back 33 bbls in 10 minutes. Flow decreased from 20% to 9%. Short trip to 8,390'. Flow decreased after pulling 2 stands. Well flowed back a total of 57 bbls while POH to 8,390'. Hole in good condition. No fill. Drill from 9,603' to 10,200'. Control drill at 80 to 120 fph. ECD 11.2 ppg. AST=0.5, ART=6.7. Drilling with AGS closed to maintain inclination. Dropping slightly. PU=194K, SO=127K, RT=152K. TO ON=9K, TO OFF=8K. Drill from 10,200' to 10,816'. Rotate with AGS closed. 280 gpm, 2,950. Slide 78' to build angle. AST=1.6, ART=7.0. ECD climbed to 11.4 ppg and losses increased to 130 bbls on previous stand drilled. CBU at 10,816'. 250 gpm, 2,300 psi. ECD 11.2 ppg. Monitor well. Well flowed back 92 bbls of mud. Drill from 10,816' to section TD at 10,923'. ART=1.6, AST=O. Circulate sweep around and clean hole. Raise mud weight to Printed: 1/27/2003 9:54:53 AM ) ) BP EXPLORATION PageAof 11 OperatiqnsSummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 Date From - To Hou rs Task Code NPT Phase Description of Operations 1/6/2003 15:30 - 21 :00 5.50 DRILL P INT1 10.5 ppg. 21 :00 - 00:00 3.00 DRILL P INT1 Short trip from 10,923' to 7,571'. Hole in good condition to 7,602'. Work through 25K - 50K over pull at 7,602'. Working tight spot at 7,571'. 1/7/2003 00:00 - 01 :30 1.50 DRILL P INT1 Pulled 50K over at 7,571'. Unable to move pipe. No circulation. Work pipe. Pipe came free. RIH 2 stands. Establish circulation at 1.5 bpm, 650 psi after losing 50 bbls of mud. Well breathed back 131 bbls prior to pumping. 01 :30 - 02:30 1.00 DRILL P INT1 Back ream through tight spot at 7,571'. Work pipe back through without pump or rotation, ok. 02:30 - 03:00 0.50 DRILL P INT1 Continue to POH to 6,650'. No problems. Monitor well. Gained 145 bbls on short trip. 03:00 - 05:30 2.50 DRILL P INT1 RIH to 10,923'. Work through one tight spot at 7,965'. Fill pipe and break circulation at 8,855' 05:30 - 09:30 4.00 DRILL P INT1 Tag bottom at 10,923'. No fill. Stage up pump rate. Pump sweep and CBU. Circulate at 240 gpm, 2,150 psi. Lost 200 bbls of mud. Slow pump and reciprocate pipe. Build surface volume. Attempt to establish circulation. 09:30 - 12:30 3.00 DRILL P INT1 POH from 10,923' to 6,610'. Intermittent over pulls of 1 OK- 15K. 88 bbl gain on short trip. 12:30 - 16:00 3.50 DRILL P INT1 Circulate at 250 gpm, 2,100 psi and try to establish returns. Established 80% returns. Circulate casing clean and got some shale splinters over shakers. 16:00 - 17:30 1.50 DRILL P INT1 Slip and cut drilling line. Service top drive. 17:30 - 18:00 0.50 DRILL P INT1 Break circulation and monitor well. 18:00 - 19:00 1.00 DRILL P INT1 RIH from 6,610' to 8,014'. No hole problems. 19:00 - 20:30 1.50 DRILL P INT1 Circulate and establish partial returns at 175 gpm, 1,500 psi. Lost 92 bbls of mud. Well breathing with pumps off. 20:30 - 21 :30 1.00 DRILL P INT1 RIH from 8,014' to 9,416'. No hole problems. 21 :30 - 00:00 2.50 DRILL P INT1 Circulate and establish partial returns at 148 gpm. 1/8/2003 00:00 - 01 :00 1.00 DRILL P INT1 Continue to CBU at 9,416'. Returns increased to near full returns at 148 gpm. Started getting back fine cuttings. Well started giving some fluid back. Lost 79 bbls while circulating. 01 :00 - 01 :30 0.50 DRILL P INT1 RIH to 10,923'. No hole problems. No fill. Gained 22 bbls more than displacement. Well still breathing. 01 :30 - 03:30 2.00 DRILL P INT1 CBU. Stage pump rate up slowly to 123 gpm. Losing at 1.0 - 1.5 bpm. 03:30 - 05:00 1.50 DRILL P INT1 Spot 115 bbls liner running pill. Pump dry job. Lost 155 bbls total while circulating on bottom. Monitor well. Well breathing. Blow down surface lines. Drop rabbit. 05:00 - 09:00 4.00 DRILL P INT1 POH from 10,923' to 6,680'. SLM. No hole problems. 09:00 - 12:00 3.00 DRILL P INT1 LD excess DP and POH to 925'. Change elevators. 12:00 - 15:00 3.00 DRILL P INT1 LD BHA. Flush with fresh water. Down load MWD. Gained 130 bbls on trip out of hole. 15:00 - 15:30 0.50 DRILL P INT1 Clear rig floor. 15:30 - 16:30 1.00 CASE P INT1 RU casing equipment to run liner. 16:30 - 22:30 6.00 CASE P INT1 Run 107 joints of 51/2", 17#, L-80, Hydril 521 liner. MU torque 6,000 ft*lbs. Liner weight: PU=85K, SO=80K. 22:30 - 23:00 0.50 CASE P INT1 MU Baker flex lock liner hanger and ZXP liner top packer. 23:00 - 00:00 1.00 CASE P INT1 RIH with liner on 4" DP. 1/9/2003 00:00 - 01 :00 1.00 CASE P INT1 RIH with liner to 6,607'. 01 :00 - 02:30 1.50 CASE P INT1 Circulate liner and DP volume at 2.5 bpm, 420 psi. Partial returns. Losing at 1 bpm. Lost 59 bbls while circulating. Get Printed: 1/27/2003 9:54:53 AM ') ) BP'EXPLORATION Operations, Summary. Report Page 5 of11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1/9/2003 01 :00 - 02:30 1 .50 CASE P INT1 base liner torque value of 4,500 ft*lbs at 20 rpm. PU= 118K, SO=100K. 02:30 - 04:30 2.00 CASE P INT1 Run liner in open hole to 10,160'. Set 15K down at 7,619'. PU=180K, SO=1 05K. Liner started taking weight at 10,160'. Work liner in the hole from 10,160' to 10,400'. 04:30 - 06:00 1.50 CASE P INT1 Attempt to work liner in the hole with rotation and pump. Rotated with torque limit set to 11,000 ft*lbs and rotation stalled. DP pressured up to 400 psi and did not bleed off. Decide to POH and make cleanout run. 06:00 - 09:00 3.00 CASE N DPRB INT1 POH from 10,400' to 6,607'. 09:00 - 10:00 1.00 CASE N DPRB INT1 Circulate liner and DP volume at 2 bpm, 480 psi. Pump dry job. 10:00 - 11 :00 1.00 CASE N DPRB INT1 POH from 6,607' to 4,461'. 11:00-11:30 0.50 CASE N DPRB INT1 RU 5 1/2" liner equipment. 11:30-13:30 2.00 CASE N DPRB INT1 LD liner top packer and liner hanger assembly. LD 5 1/2" liner. 22 joints of liner torqued up. 13:30 - 15:30 2.00 CASE N DPRB INT1 Broke two casing tongs on tight joint. RU 13 3/8" tongs. 15:30 - 22:00 6.50 CASE N DPRB INT1 Continue to LD 5 1/2" casing. Heat up baker loced joint and break out. Remove centralizer and stop bands from joint #3. Cut off 2 stop bands and 1 centralizer from joint #2. Two stop bands and one centralizer were found just above the pin end of joint #2 and joint #3. Original placement of the stop bands were 10' from the end of each joint, with the centralizer free floating between. Clay packed above each centralizer. Little clay on float shoe. One side port plugged. 22:00 - 23:00 1.00 CASE N DPRB INT1 Stand back joints 1 and 2. RD casing equipment. 23:00 - 23:30 0.50 BOPSUR P INT1 Pull wear bushing. 23:30 - 00:00 0.50 BOPSUR P INT1 MU test assembly. 1/10/2003 00:00 - 03:00 3.00 BOPSURP INT1 Test BOPE to 250 psi / 3,500 psi as per BP policy and AOGCC regulations. Test witnessed by Chuck Scheve of AOGCC. RD test equipment. 03:00 - 03:30 0.50 BOPSUR P INT1 Pull test plug. Install wear bushing. 03:30 - 05:00 1.50 CASE N DPRB INT1 PJSM. MU cleanout BHA to 837'. 05:00 - 06:00 1.00 CASE N DPRB INT1 PU 4" DP from 837' to 3,538'. 06:00 - 09:30 3.50 CASE N DPRB INT1 RIH to 6,614'. 09:30 - 10:30 1.00 CASE N DPRB INT1 CBU at 220 gpm, 840 psi. Lost 49 bbls, gained back 31 bbls. Net Loss 18 bbls. 10:30 - 11 :00 0.50 CASE N DPRB INT1 RIH from 6,614' to 8,018'. 11 :00 - 13:00 2.00 CASE N DPRB INT1 Circulate and pump 40 bbls, 40 Ib/bbl LCM pill at 220 gpm, 950 psi. 80 - 90% returns. Lost 56 bbls with pump on. 13:00 - 13:30 0.50 CASE N DPRB INT1 RIH from 8,018' to 9,514'. Gained back 23 bbls. PU=165K, SO=125K, ROT= 145K. 13:30 - 16:30 3.00 CASE N DPRB INT1 Pump 40 bbl, 40 Ib/bbl LCM pill at 234 gpm, 1,180 psi. 80- 90% returns. Lost 54 bbls with pump on. 16:30 - 18:00 1.50 CASE N DPRB INT1 RIH from 9,514' to 10,923'. Work through tight spots from 10,300' to 10,351' and 10,762' to 10,793'. Setting down 40K to work through. Gained 64 bbls while RIH. 18:00 - 00:00 6.00 CASE N DPRB INT1 Circulate calculated bottoms up volume at 2.5 bpm. Losing 1.0 - 1.5 bpm. Pump 40 bbl, 40 Ib/bbls LCM pill. Lost 396 bbls while circulating on bottom. 1/11/2003 00:00 - 05:30 5.50 CASE N DPRB INT1 Continue circulating at 10,923'. Losing 1.5 - 3 bpm. Minimal returns. Slow pump rate and build 100 bbls of mud. Pump 2nd LCM pill, 40 bbls, 50 Iblbbl. Continue to pump at reduced rate Printed: 1/27/2003 9:54:53 AM ") .> BP EXPLORA TJON Operatio.ns Surnmary"Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES bate From ..To Hours Task Code NPT Phase 1/11/2003 00:00 - 05:30 5.50 CASE N DPRB INT1 05:30 - 10:00 4.50 CASE N DPRB INT1 10:00 - 15:30 5.50 CASE N DPRB INT1 15:30 - 18:00 2.50 CASE N DPRB INT1 18:00 - 18:30 0.50 CASE N DPRB INT1 18:30 -19:00 0.50 CASE N DPRB INT1 19:00 - 19:30 0.50 CASE N DPRB INT1 19:30 - 20:30 1.00 CASE N DPRB INT1 20:30 - 00:00 3.50 CASE N DPRB INT1 1/12/2003 00:00 - 02:00 2.00 CASE N DPRB INT1 02:00 - 03:00 1.00 CASE N DPRB INT1 03:00 - 04:00 1.00 CASE N DPRB INT1 04:00 - 05:00 1.00 CASE N DPRB INT1 05:00 - 07:30 2.50 CASE N DPRB INT1 07:30 - 08:00 08:00 - 18:00 0.50 CASE P 10.00 CASE P INT1 INT1 18:00 - 20:30 INT1 2.50 CEMT P Page 6 of'11 Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 Description of Operations due to loss rate. Build additonal 120 bbls of mud. Stage up flow rate after 2nd LCM pill reached suspected loss zone. Loss rate decreased and returns increased. Stage up rate to 245 gpm. Rotate at 110 rpm. Still losing at 1.5 - 3.0 bpm. Pump 3rd LCM pill, 40 bbls, 50 Ib/bbl at 210 gpm, 1,150 psi, 110 rpm. Losing at 1 bpm. Losses slowed to 0.4 bpm. Spot 230 bbls of new mud with 3% lubricants in open hole. Pump dry job. Monitor well. Gained 27 bbls after shutting down the pump. POH from 10,923' to 6,680'. No hole problems. Monitor well. Static. POH from 6,680' to 837'. LD HWDP, jars, DCs, and bit. Clear and clean floor. PJSM. RU to run 5 1/2" liner. PU 5 1/2" float equipment and check floats. Service top drive. Change out egged joint with insert landing collar. Change out power tongs to stacked tongs. Run 5 1/2", 17#, L-80, Hydril 521 liner to 2,050'. MU torque 10,000 ft*lbs. Continue running 5 1/2", L-80, 17#, Hydril 521 liner. Lost 11 bbls while picking up liner. MU Baker flex lock liner hanger and ZXP liner top packer. Change elevators. LD casing equipment. Clear rig floor. Break circulation, 3 bpm, 390 psi. PU=85K, SO=85K. RIH to window with 4" DP to 6,600'. PU=112K, SO=105K. Circulate liner and DP volume at 3 bpm, 490 psi. Losing at 0.5 bpm. Good returns. Lost 36 bbls. RIH with 5 1/2" liner from 6,600' to 10,900'. Had to work pipe from 10,200' to 10,900'. PU=200K. Slack off all the weight to work liner down. At 10,600' unable to work pipe down. Pulled 250K at 10,600' to break pipe free. Tight spots at 10,300' and 10,700'. 2 feet of progress at these depths. MU cement head. RIH to 10,923'. Break circulation slowly, 1 bpm, 756 psi. Increase to 2.5 bpm, 815 psi. PJSM with cementers. Attempt to stage up rate to 5 bpm. Packed off several times. Attempt to regain circulation. Establish circulation with continual packing off. Final circulating pressure 840 psi at 3.2 bpm. Pumped over 1,100 bbls to gain good circulation. Pump 5 bbls of water. Test lines to 4,500 psi. Displace water through "T". Pump 25 bbls mud push XL spacer at 11.5 ppg, 30 bbls 15.8 ppg class G cement. Wash up lines. Drop DP wiper dart. Displace cement with cement pumps. Plugs latched at 66.3 bbls. Good indication of lifting cement after cement exited shoe. Packed off with 10 bbls left in displacement. Pressure increased from 884 psi to 2,750 psi. Frac away last 10 bbls of displacement at 2,750 psi. Bump plug to 3,000 psi. CIP 19:45. Bleed off pressure and check floats, ok. Switch to rig pumps. Pressure up to 4,000 psi to release HR tool from liner. Pick up 5 feet to expose packer setting lugs. Set down 60K to set liner top packer. Good indication of packer set. Repeat 2 times to ensure packer is set. Test liner top packer to 3,500 psi for 5 minutes to confirm Printed: 1/27/2003 9:54:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) Page Tof t 1 SP EXPLORA TI ON Operations Summary Report Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 1/12/2003 Date From ..To Hours Task Code' NPT Phase 2.50 CEMT P INT1 1/13/2003 1/14/2003 1/15/2003 18:00 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 00:30 00:00 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 08:30 08:30 - 14:30 14:30 - 15:00 15:00 -17:00 17:00 -17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 00:00 00:00 - 15:00 15:00 - 15:30 15:30 - 16:00 0.50 CASE P 0.50 CASE P 1.00 CASE P INT1 INT1 INT1 1.00 CASE P 0.50 CASE P 0.50 CASE P 4.50 CASE P INT1 INT1 INT1 INT1 0.50 BOPSUR P 1.00 BOPSURP PROD1 PROD1 0.50 BOPSURP 2.00 DRILL P PROD1 PROD1 6.00 DRILL P PROD1 0.50 DRILL P 2.00 DRILL P 0.50 DRILL P 2.00 DRILL P 0.50 DRILL P 1.00 DRILL P 0.50 DRILL P 0.50 DRILL P 1.00 DRILL P 1.00 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 1.50 DRILL P PROD1 2.50 DRILL P PROD1 1.00 DRILL P 1.00 DRILL P PROD1 PROD1 18.00 DRILL P PROD1 15.00 DRILL P PROD1 0.50 DRILL N DFAL PROD1 0.50 DRILL N DFAL PROD1 Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 liner top packer is set. Pressure up to 500 psi and pull RS packoff out of seal area and unsting from liner top. CBU at 8 bpm, 1,975 psi. No cement returns. Test casing to 3,500 psi for 30 minutes. Displace well bore from liner top to surface to fresh water at 13 bpm, 2,600 psi. Reciprocate pipe. Pump dry job. LD cement head. RD circulating lines and valves. Cut and slip drilling line. Continue to cut and slip drilling line. Inspect brakes. POH from 6,513' to 3,800'. LD 4" DP from 3,800'. LD liner running tool. Clear floor. Pull wear bushing. Install test plug. Test lower variable pipe rams, annular preventor, and safety valves with 2 7/8" test joint to 250 psi / 3,500 psi.. Pull test plug. Install wear bushing. RU handling equipment. Prepare to PU BHA. Flush surface lines to clean any residual LCM. PJSM. MU 4 3/4" BHA. Upload to MWD. Surface check MWD. MU BHA and PU 2 7/8" DP to 2,627'. Fill pipe and flow test MWD at 160 gpm, 2,415 psi. Continue to PU BHA from 2,627' to 4,630'. Fill pipe and flow test MWD at 160 gpm, 2,580 psi. Continue to PU 2 7/8" DP from 4,630' to 6,506'. Fill pipe and flow test MWD at 148 gpm, 2,600 psi. RIH w/4" DP 6,506' to 8,840'. Service top drive. Fill pipe and flow test MWD. RIH with DP from 8,840' to 10,806'. Install blower hose. Wash and rotate from 10,806' to landing collar at 10,837'. 148 gpm, 3,400 psi. PU=145K, SO=125K, RT=135K, TO=3,400 ft*lbs. Drill landing collar and cement in shoe track to float shoe at 10,923'. Pump 50 bbls water spacer and 30 bbls viscous spacer. Displace well bore to 8.6 ppg Flo-Pro drilling fluid at 154 gpm, 3,100 psi. Reciprocate pipe. Establish baseline parameters. Up wt 140k, Dn wt 130k, Rot wt 135k, TO 3000 ftllbs. Drill 20' of new formation to 10,943'. Pull into casing and perform FIT test to 10.01 ppg EMW. Surface pressure 650 psi. w/ 8.6 ppg mud. Drill 4 3/4" directional hole 10,943' to 11,295'. Up wt 145k, Dn wt 125k, Rot wt 135k. RPM 60, TO off btm 3,900, TO on btm 4,300. Pump psi on btm 2,700, off btm 2,400 @157 GPM. AST= 6.25 hrs, ART= 8.5 hrs, ADT= 14.75 hrs. Drill 4 3/4" directional hole 11,295' to 11,558'. Up wt 145k, Dn wt 125k, Rot wt 135k. RPM 60, TO off btm 3,200, TO on btm 3,900. Pump psi on btm 2,900, off btm 2,550 @ 157 GPM. Motor stalling, ROP decreased by 50%, suspect MM damage. AST= 3.5 hrs, ART= 4.75 hrs, ADT= 8.25 hrs. Circulate and condition mud @ 120 GPM / 3,150 psi. Prepare for trip out of hole. POH w/4 3/4" bit to 51/2" casing shoe @ 10,923'. Hole in good shape. Printed: 1/27/2003 9:54:53 AM ) ) BP EXPLORATION Page 8of11 ' Operations Summary Report Flow check showing well static. Drop opening ball for circulating sub. Open circ sub wI 3,500 psi. Pump dry job. Blow down surface circulating system. POH w/ 4 3/4" bit racking 4" DP in derrick. Change out handling equipment to 2 7/8". Con't POH w/4 3/4" bit racking 2 7/8" DP & BHA in derrick. Flush MWD / MM w/ fresh water. LD MM. Down load MWD. LD MWD. Clear rig floor. Pull wear bushing. Install test jt. Test BOPE to BP & AOGCC regulations to 250 / 3,500 psi. Witness of test waived by Lou Grimaldi of AOGCC. Lay down test joint and install wear bushing. R/U handling equipment M/U motor and MWD, orient, up-load and surface test MWD at 63 spm and 1450 psi. TIH, fill pipe and test MWD at 2,632' and 5,223'. Continue in hole to 6511'. C/O handling equipment. RID 2 7/8" handling equipment. RIH from 6,511' to 8,387'. Fill pipe. Function MWD tools at 8,387' at 150 gpm and 2,050 psi. RIH from 8,387' to 10,904'. Service top drive. Install blower hose. Fill pipe. Function MWD tools at 10,904' at 150 gpm and 2,050 psi. RIH from 10,904' to 11,558'. Wash last 95 feet to bottom as precaution. Had drag of 25K from 11,200' to 11,235'. Drill from 11,558' to 11,743'. AST 1.9 ART 3.7 UP 145K, DN 125K, RT 140K, Tq Off Btm 3700, Tq On Btm 4000 Flow rate 155 gpm On Btm pressure 2550 psi, Off Btm pressure 2350 psi PROD1 Drill from 11,743' to 12,675'. AST 5.13 ART 11.16 P/U Wt. = 155,000 S/O Wt. = 125,000 Rot Wt. = 140,000 Tq On Btm 4900 Tq Off Btm 4400 Flow rate 155 gpm On Btm pressure 2700 psi, Off Btm pressure 2400 psi Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From -To Hours Task Code NPT Phase 1/15/2003 16:00 - 16:30 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 0.50 DRILL N 16:30 - 18:30 2.00 DRILL N 18:30 - 23:00 4.50 DRILL N 23:00 - 00:00 1.00 DRILL N 1/16/2003 00:00 - 01 :30 1.50 DRILL N 01 :30 - 05:30 4.00 BOPSUR P 05:30 - 06:00 0.50 DRILL N DFAL PROD1 06:00 - 07:30 1.50 DRILL N DFAL PROD1 07:30 - 12:00 4.50 DRILL N DFAL PROD1 12:00 - 12:30 0.50 DRILL N DFAL PROD1 12:30 - 13:30 1.00 DRILL N DFAL PROD1 13:30 - 14:00 0.50 DRILL N DFAL PROD1 14:00 - 14:30 0.50 DRILL N DFAL PROD1 14:30 - 15:00 0.50 DRILL P PROD1 15:00 - 15:30 0.50 DRILL N DFAL PROD1 15:30 - 16:00 0.50 DRILL N DFAL PROD1 16:00 - 00:00 8.00 DRILL P PROD1 1/17/2003 24.00 DRILL P 00:00 - 00:00 Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 Description of Operations' Slide 11776' to 11800' TF=40R at ROP=42 fph. Slide 11849' to 11895' TF=20R at ROP=200 fph. Slide 12115' to 12132' TF=160R at ROP=32 fph. Rolled TF over as approaching crest at top of interval. Following directional plan to drop inclination from 93 deg to -83 deg. Rotating ROP prior to crest at -12,175' average 50 fph. Slide 12180' to 12202' TF=180 at ROP=25 fph. Tough slide, sticky, suspect approaching base Shublik. Log Resistivity response similar to initial breakthrough into upper Ivishak. Slide 12239' to 12265' TF=180 at ROP=26 fph. Still sticky slide. Printed: 1/27/2003 9:54:53 AM ) ) BP EEXPLORATIÖN Page 9 of 11 , Q,perati()ns Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 Date " From - To Hours Täsk .. Phase Descri phon. of Operations 1/17/2003 00:00 - 00:00 24.00 DRILL P PROD1 Slide 12275' to 12298' TF= 180 at ROP=60 fph. Re-entered good zone at 12,300'. Rotating ROP after reaching crest and re-entering cleaner sand 75 - 100 fph. 1/18/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Drill from 12,675' to well TD at 12,750' MD, 8,996' TVD. ART= 1.25 AST=O.OO On Btm Pr = 2,700 psi Off Btm Pr = 2,400 psi P/U wt. = 155,000 S/O Wt. = 125,000 Rot. Wt. = 140,000 On Btm Tq = 4,900 Off Btm Tq = 4,400 Rig site geologist determined water contact approximately 12,670' MD, 8,987' TVD. Town geologist called TD at 12,750' MD, 8,996' TVD. 01 :30 - 03:30 2.00 DRILL P PROD1 Circulate Hi Vis sweep at 4 bpm, surface to surface, at 156 gpm and 2,400 psi. Reciprocate and rotate pipe. No increase of cuttings seen at surface. 03:30 - 04:30 1.00 DRILL P PROD1 Flow check showing well static. POOH up into 51/2" liner to 10,896'. Hole in good shape. 04:30 - 06:00 1.50 DRILL P PROD1 Slip & cut drlg line. Service TD. 06:00 - 07:00 1.00 DRILL P PROD1 RIH from 10,896' to 12,750'. No problems. 07:00 - 08:00 1.00 DRILL P PROD1 Circulate and spot 50 bblliner running pill in OH section. 08:00 - 09:00 1.00 DRILL P PROD1 Monitor well. Drop ball, POOH from 12,750' to 10,896'. No problems. 09:00 - 10:00 1.00 DRILL P PROD1 Shear circulating sub at 4,000 psi, CBU at 8 bpm and 3,500 psi. Pump a dry job. 10:00-11:30 1.50 DRILL P PROD1 POOH from 10,896' to 6,512'. 11 :30 - 12:00 0.50 DRILL P PROD1 R/U 2 7/8" handling equipment. 12:00 - 13:30 1.50 DRILL P PROD1 LID 27/8" drill pipe from 6,512' to 4,524'. 13:30 - 16:00 2.50 DRILL P PROD1 POOH from 4,524' to 71', stand back 2 7/8" drill pipe and SWDP. LID BHA. 16:00 - 18:30 2.50 DRILL P PROD1 Pump water through MWD, download MWD, LID MWD and motor. Clear rig floor. 18:30 - 19:00 0.50 DRILL P PROD1 R/U 3 1/2" handling equipment. 19:00 - 22:00 3.00 CASE P COMP PJSM. RIH with 3 1/2", 9.2#, Slotted I Solid, L-80 liner to 1,981'. P/U and S/O weight 40K. 22:00 - 22:30 0.50 CASE P COMP M/U 3 1/2" X 5 1/2" CPH C-2 liner top packer and HMC liner hanger and 1 stand of SWDP. Circulate through liner to verify clear. 22:30 - 00:00 1.50 CASE P COMP RIH with 31/2" liner from 2,095' to 4,330'. 1/19/2003 00:00 - 03:30 3.50 CASE P COMP RIH with 3/12" liner from 4,330' to 10,920'. Break circulation at 60 gpm and 1,000 psi. 03:30 - 04:30 1.00 CASE P COMP RIH with liner from 10,920' to 12,750'. Slack off weight while running in open hole 125K - 130K. P/U weight at 12,750' 165K. Pick up 1 foot off bottom. Guide shoe at 12,749' and CPH packerl Tie back sleeve at 10,752' MD. 04:30 - 05:30 1.00 CASE P COMP Drop ball, pump at 2.5 to 1 bpm. Pump on seat. Increase pressure to 2,400 psi to set hanger, Continue increase Printed: 1/27/2003 9:54:53 AM ) ) BPI;XPLORA TION Page100f 11 O'per.atlonsS,tUl1mary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y-35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From-To Hours Task Gode< NPT ,Phase 1/19/2003 04:30 - 05:30 1.00 CASE P COMP 05:30 - 07:00 1.50 CASE P COMP 07:00 - 11 :30 4.50 CASE P COMP 11 :30 - 12:00 0.50 CASE P COMP 12:00 - 14:00 2.00 CASE P COMP 14:00 - 15:00 1.00 CASE P COMP 15:00 - 22:00 7.00 CASE N RREP COMP 22:00 - 23:00 1.00 CASE P COMP 23:00 - 00:00 1.00 CASE P COMP 1/20/2003 00:00 - 00:30 0.50 CASE P COMP 00:30 - 01 :00 0.50 WHSUR P COMP 01 :00 - 03:00 2.00 RUNCOIVP COMP 03:00 - 12:00 9.00 RUNCOIVP COMP 12:00 - 18:00 6.00 RUNCOIVP COMP 18:00 - 18:30 0.50 RUNCOIVP COMP 18:30 - 19:30 1.00 RUNCOIVP COMP 19:30 - 20:00 0.50 RUNCOIVP COMP 20:00 - 21 :00 1.00 RUNCOIVP COMP 21 :00 - 23:00 2.00 RUNCOIVP COMP Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 pressure to 3,400 psi to blow ball seat. Rotate 15 revs. to release from hanger, P/U 6 feet. P/U weight 152K, verify release from hanger. Slack off 50K to set packer. Good surface indication packer set. Repeat packer set routine to confirm. LID 1 joint drill pipe. Circulate in 30 bbl viscous spacer and displace the well to seawater at 8 bpm and 4,300 psi. P/U Weight 145K, S/O weight 130K. Circulate 1.5 hole volumes until clean seawater returns. POOH, laying down 4" drill pipe 1x1, from 10,725' to 4,311'. R/U 2 7/8" handling equipment. POOH, laying down 2 7/8" drill pipe 1x1, from 4,311' to 2,004'. Service top drive. P/U 3 1/2" tubing equipment to rig floor. Rig repair. Repair skate - Driller side elevator. Scissor jack base-plate broke at weld. Required securing the elevator and re-welding the base plate, re-pinning the scissor jack. POOH, laying down 2 7/8" drill pipe 1x1, from 2,004' to 636'. Lay down SWDP from 636'. Lay down liner running tool. Finish lay down liner running tool. Clear rig floor. Pull wear bushing. Load completion jewelry in pipe shed. RU tongs, compensator, torque turn computer for 3 1/2" completion. P/U WLEG and 'XN' nipple wI pups, 'X' nipple wI pups, Baker 3 1/2" X 5 1/2" SABL-3 production packer, 'X' nipple wI pups, 1 full joint of 3 1/2", 9.2#, 13Cr-80, VAM ACE tubing, and first 3 1/2" X 1" KBG-2 GLM. Baker Lok all connections below packer. M/U remaining connections wI Torque Turn (M/U torque= 2,820 ft-Ibs). Utilize Jet Lube connection compound. M/U and RIH with 3 1/2", 9.2#, 13Cr-80, VAM ACE tubing to 6,412'. P/U Wt. = 70K, S/O Wt.= 70K RIH with 31/2", 9.2#, 13Cr-80, VAM ACE tubing from 6,412' to 10,705'. P/U Wt. = 100K, S/O Wt. 90K. Tag bottom of Tie-Back sleeve at 10,741'. P/U one joint and slack off again, tag at same depth. P/U one joint, set slips and add 2 1/2 turns RH rotation, slack off. Tag at same depth of 10,741'. P/U 3' from bottom-out depth to 10,738'. NOTE: Top of the 5 1/2" liner Tie-Back Sleeve is at 10,751' MD, and the Tie Back Sleeve bottom No-Go is at 10,757' MD. The tubing tally reflects that the wireline entry guide bottomed out at 10,741'; a difference of -16.0 feet from the tubing tally to the liner tally. Space out tubing. Ran 335 joints, plus required three pup joints of lengths 1.95', 9.96', and 9.97' to land tubing on depth. Make up tubing hanger and landing joint. Land tubing at 10,735'. RILDS. RIU to reverse-circulate in corrosion inhibitor. Reverse circulate in clean Seawater, displacing one tubing volume; continue reverse circulating with corrosion inhibitor, at 3 bpm and 600 psi. Printed: 1/27/2003 9:54:53 AM ) ) BPEXPLORATION Page 11 of 11 Operation~Summal)'Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-35 Y -35A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/30/2002 Rig Release: 1/21/2003 Rig Number: Spud Date: 12/30/2002 End: 1/21/2003 ,Date' From - To Hours Task Code NPT Phase · Descri ptibnof Operations 1/20/2003 23:00 - 23:30 0.50 RUNCOIVP COMP RID circulation line, drop 1 5/16" Ball and Rod, LID landing joint. 23:30 - 00:00 0.50 RUNCOIVP COMP Pressure up 31/2",9.2#, 13Cr-80, VAM ACE tubing to 4,500 psi and hold for 5 minutes to set Baker SABL-3 packer. Bleed pressure on tubing back to 3,500 psi. Test the tubing to 3,500 psi for 30 minutes. 1/21/2003 00:00 - 01 :00 1.00 RUNCOIVP COMP Finish testing tubing to 3,500 psi. Bleed tubing pressure to 1,500 psi and pressure back side to 3,500 psi. Test for 30 minutes and record. Bleed tubing pressure to initiate OCR shear. 01 :00 - 01 :30 0.50 WHSUR P COMP Install TWC and pressure test to 3,000 psi from below. 01 :30 - 03:00 1.50 BOPSUR P COMP NID BOP equipment 03:00 - 05:00 2.00 WHSUR P COMP N/U adapter flange and tree. Pressure test adapter flange and tree to 5,000 psi. 05:00 - 06:00 1.00 WHSUR P COMP R/U OSM and pull TWC with lubricator. RID OSM. 06:00 - 08:00 2.00 WHSUR P COMP R/U hot oil service, test lines to 3000 psi, displace annulus wI 94 bbls of diesel at 3 bpm 250 - 650 psi, u-tube diesel to tbg, freeze protect tbg and annulus at 2200' to surface 08:00 - 09:00 1.00 WHSUR P COMP Install BPV, test 3000 psi 09:00 - 10:00 1.00 WHSUR P COMP N/O secondary annulus valve, secure well, Release Rig AT 10:00 hours on 1/21/2003 Printed: 1/27/2003 9:54:53 AM ) ) 25-Feb-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Y-35A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,660.68 I MD Window / Kickoff Survey: 6,680.00' MD (if applicable) Projected Survey: 12,750.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) MAR 2 6 2003 Alaska OI~ & Gas Cons. Comm!tlioß Anchorage ójCQdò 7 Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_ WOA Y Pad Y-35A -- Job No. AKZZ22210, Surveyed: 18 January, 2003 Survey Report 21 February, 2003 Your Ref: API 500292218601 Surface Coordinates: 5949023.74 N, 645395.22 E (70016' 05.2343" N, 148049' 27.2134" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 I '- Surface Coordinates relative to Project H Reference: 949023.74 N, 145395.22 E (Grid) Surface Coordinates relative to Structure Reference: 528.23 N, 2342.68 W(True) Kelly Bushing: 78.60ft above Mean Sea Level Elevation relative to Project V Reference: 78.60ft Elevation relative to Structure Reference: 78.60ft SpE!r'I'Y-SUI! DFtlLLING'·· seFtVlé: es A Halliburton Company Survey Ref: svy11445 Sperry-Sun Drilling Services Survey Report for PBU_ WOA Y Pad - Y-35A Your Ref: API 500292218601 Job No. AKZZ22210, Surveyed: 18 January, 2003 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) 6660.68 45.980 131.410 5833.45 5912.05 1425.74 S 1527.47 E 5947627.77 N 646949.95 E 2010.70 Tie On Point AK-6 BP _IFR-AK - 6680.00 46.030 131.370 5846.87 5925.4 7 - 1434.93 S 1537.90 E 5947618.78 N 646960.55 E 0.299 2023.96 Window Point - 6726.06 46.150 134.570 5878.82 5957.42 1457.54 S 1562.17 E 5947596.64 N 646985.25 E 5.012 2055.88 6830.60 46.900 141.730 5950.80 6029.40 1514.00 S 1612.70 E 5947541.17 N 647036.86 E 5.020 2130.34 6914.41 47.660 147.340 6007.68 6086.28 1564.12 S 1648.38 E 5947491.75 N 647073.51 E 5.000 2191.70 6948.93 47.900 147.460 6030.88 6109.48 1585.66 S 1662.16 E 5947470.48 N 647087.69 E 0.741 2217.25 6979.82 48.100 148.270 6051.55 6130.15 1605.10 S 1674.37 E 5947451.28 N 647100.28 E 2.053 2240.20 7008.72 46.790 151 . 150 6071.09 6149.69 1623.47 S 1685.11 E 5947433.12 N 647111.37 E 8.627 2261.49 7040.81 46.770 152.830 6093.07 6171.67 1644.12 S 1696.09 E 5947412.69 N 647122.75 E 3.816 2284.83 7070.86 46.870 153.120 6113.63 6192.23 1663.64 S 1706.04 E 5947393.37 N 647133.08 E 0.778 2306.69 7101.62 46.980 153.230 6134.64 6213.24 1683.69 S 1716.18 E 5947373.51 N 647143.60 E 0.443 2329.09 7132.90 47.170 153.410 6155.94 6234.54 1704.15 S 1726.47 E 5947353.25 N 647154.28 E 0.739 2351.93 7196.66 47.540 153.220 6199.14 6277.74 1746.06 S 1747.53 E 5947311.76 N 647176.15 E 0.620 2398.68 7226.76 47.600 153.620 6219.45 6298.05 1765.93 S 1757.47 E 5947292.09 N 647186.47 E 1.001 2420.83 7289.52 48.150 153.740 6261.54 6340.14 1807.65 S 1778.11 E 5947250.77 N 647207.91 E 0.888 2467.20 7382.14 49.210 154.280 6322.69 6401.29 1870.18 S 1808.59 E 5947188.85 N 647239.59 E 1.225 2536.48 7474.75 48.250 151.320 6383.79 6462.39 1932.08 S 1840.39 E 5947127.57 N 647272.58 E 2.616 2605.90 7572.60 48.660 151.450 6448.68 6527.28 1996.37 S 1875.46 E 5947063.97 N 647308.89 E 0.431 2679.06 7665.58 48.490 151.380 6510.20 6588.80 2057.59 S 1908.82 E 5947003.41 N 647343.42 E 0.191 2748.71 7757.57 48.370 151.640 6571.24 6649.84 2118.07 S 1941.65 E 5946943.56 N 647377.41 E 0.248 2817.45 7853.89 48.290 152.130 6635.28 6713.88 2181.53 S 1975.55 E 5946880.77 N 647412.54 E 0.389 2889.30 7948.34 48.320 151 . 140 6698.10 6776.70 2243.59 S 2009.06 E 5946819.37 N 647447.24 E 0.783 2959.74 ~ 8041.76 48.480 151.960 6760.13 6838. 73 2305.01 S 2042.34 E 5946758.61 N 647481.70 E 0.678 3029.51 8135.52 48.590 151.910 6822.21 6900.81 2367.01 S 2075.39 E 5946697.26 N 647515.94 E 0.124 3099.67 8228.63 48.850 152.050 6883.64 6962.24 2428.78 S 2108.26 E 5946636.13 N 647550.00 E 0.301 3169.53 8322.82 49.130 152.500 6945.45 7024.05 2491.70 S 2141.33 E 5946573.87 N 647584.28 E 0.467 3240.48 8414.78 46.270 151 .120 7007.33 7085.93 2551.64 S 2173.44 E 5946514.55 N 647617.54 E 3.302 3308.39 8509.91 45.400 151.400 7073.61 7152.21 2611.48 S 2206.25 E 5946455.37 N 647651.50 E 0.939 3376.57 8602.68 45.630 151.360 7138.62 7217.22 2669.57 S 2237.95 E 5946397.89 N 647684.32 E 0.250 3442.69 8695.56 45.880 150.920 7203.42 7282.02 2727.85 S 2270.07 E 5946340.25 N 647717.55 E 0.433 3509.17 21 February, 2003 - 16:08 Page2of5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_ WOA Y Pad - Y-35A Your Ref: API 500292218601 Job No. AKZZ22210, Surveyed: 18 January, 2003 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) e/100ft) 8790.68 46.370 150.640 7269.35 7347.95 2787.69 S 2303.54 E 5946281.07 N 647752.18 E 0.557 3577.69 8882.74 45.250 150.900 7333.52 7412.12 2845.29 S 2335.78 E 5946224.10 N 647785.52 E 1.233 3643.66 8977.45 44.800 151.000 7400.46 7479.06 2903.86 S 2368.31 E 5946166.16 N 647819.18 E 0.481 3710.62 9070.92 44.570 150.670 7466.91 7545.51 2961.26 S 2400.34 E 5946109.40 N 647852.31 E 0.350 3776.30 9163.00 44.220 150.960 7532.71 7611.31 3017.50 S 2431.75 E 5946053.77 N 647884.80 E 0.439 3840.68 9256.08 44.020 150.770 7599.53 7678.13 3074.10 S 2463.30 E 5945997.79 N 647917.44 E 0.258 3905.44 '- 9349.31 44.120 151.020 7666.51 7745.11 3130.76 S 2494.84 E 5945941.76 N 647950.07 E 0.215 3970.24 9444.01 43.880 151.050 7734.64 7813.24 3188.31 S 2526.70 E 5945884.83 N 647983.03 E 0.254 4035.98 9537.05 44.010 1 51 . 180 7801.62 7880.22 3244.84 S 2557.89 E 5945828.91 N 648015.31 E 0.170 4100.49 9629.57 43.960 151.720 7868.19 7946.79 3301.28 S 2588.60 E 5945773.07 N 648047.10 E 0.409 4164.67 9723.31 43.840 151.870 7935.74 8014.34 3358.56 S 2619.32 E 5945716.39 N 648078.92 E 0.169 4229.59 9817.59 44.780 153.160 8003.20 8081.80 3416.99 S 2649.71 E 5945658.57 N 648110.43 E 1.381 4295.30 9909.35 44.740 152.910 8068.36 8146.96 3474.58 S 2679.00 E 5945601.56 N 648140.84 E 0.197 4359.74 10003.21 44.430 152.810 8135.21 8213.81 3533.21 S 2709.06 E 5945543.52 N 648172.02 E 0.339 4425.46 10096.01 44.290 152.600 8201.56 8280.16 3590.87 S 2738.81 E 5945486.44 N 648202.88 E 0.219 4490.19 10190.46 44.180 152.580 8269.23 8347.83 3649.36 S 2769.14 E 5945428.55 N 648234.34 E 0.117 4555.94 10284.02 43.930 152.980 8336.47 8415.07 3707.21 S 2798.90 E 5945371.28 N 648265.20 E 0.400 4620.84 10376.68 43.630 153.050 8403.37 8481.97 3764.34 S 2827.99 E 5945314.72 N 648295.39 E 0.328 4684.78 10470.21 43.670 153.530 8471.04 8549.64 3822.01 S 2857.01 E 5945257.63 N 648325.52 E 0.357 4749.14 10563.74 49.520 153.870 8535.28 8613.88 3882.91 S 2887.09 E 5945197.32 N 648356.78 E 6.260 4816.81 10655.63 50.260 153.780 8594.48 8673.08 3945.98 S 2918.10 E 5945134.86 N 648388.99 E 0.809 4886.82 10748.86 50.030 153.860 8654.23 8732.83 4010.20 S 2949.67 E 5945071.26 N 648421.80 E 0.255 4958.12 10840.86 49.820 154.180 8713.46 8792.06 4073.49 S 2980.51 E 5945008.58 N 648453.85 E 0.351 5028.22 ~ 10854.49 49.760 154.170 8722.26 8800.86 4082.86 S 2985.04 E 5944999.30 N 648458.57 E 0.444 5038.59 10932.90 49.020 153.850 8773.30 8851.90 4136.36 S 3011.13 E 5944946.31 N 648485.68 E 0.993 5097.87 10962.32 53.710 153.580 8791.66 8870.26 4156.96 S 3021.30 E 5944925.91 N 648496.25 E 15.958 5120.76 10995.85 59.920 150.760 8810.01 8888.61 4181.75 S 3034.42 E 5944901.38 N 648509.84 E 19.810 5148.76 11 027.17 61.740 149.210 8825.27 8903.87 4205.43 S 3048.10 E 5944877.97 N 648523.98 E 7.241 5176.09 11055.50 62.090 149.230 8838.61 8917.21 4226.90 S 3060.89 E 5944856.75 N 648537.18 E 1.237 5201.09 11089.60 67.810 152.250 8853.04 8931.64 4253.85 S 3075.96 E 5944830.10 N 648552.77 E 18.592 5231.95 11120.38 67.950 154.090 8864.63 8943.23 4279.29 S 3088.83 E 5944804.91 N 648566.13 E 5.557 5260.38 11149.81 74.290 155.110 8874.15 8952.75 4304.43 S 3100.77 E 5944780.00 N 648578.55 E 21.790 5288.06 11185.29 78.660 155.970 8882.45 8961.05 4335.83 S 3115.04 E 5944748.89 N 648593.43 E 12.540 5322.31 11213.82 78.850 156.200 8888.01 8966.61 4361.41 S 3126.39 E 5944723.54 N 648605.27 E 1.034 5350.07 11242.28 79.450 157.090 8893.37 8971.97 4387.07 S 3137.47 E 5944698.09 N 648616.84 E 3.725 5377.76 21 February, 2003 - 16:08 Page 3 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_ WOA Y Pad - Y-35A Your Ref: API 500292218601 Job No. AKZZ22210, Surveyed: 18 January, 2003 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) 11276.13 82.230 157.000 8898.76 8977.36 4417.84 S 3150.50 E 5944667.58 N 648630.46 E 8.217 5410.83 11300.30 82.310 157.070 8902.01 8980.61 4439.89 S 3159.85 E 5944645.71 N 648640.23 E 0.438 5434.54 11334.81 85.080 157.340 8905.80 8984.40 4471.51 S 3173.13 E 5944614.36 N 648654.13 E 8.064 5468.47 11367.98 91.040 155.900 8906.92 8985.52 4501.92 S 3186.28 E 5944584.20 N 648667.86 E 18.484 5501.29 11427.75 91 .410 158.340 8905.64 8984.24 4556.97 S 3209.51 E 5944529.61 N 648692.16 E 4.128 5560.42 11521.59 95.730 162.610 8899.80 8978.40 4645.20 S 3240.81 E 5944442.00 N 648725.15 E 6.466 5652.10 - 11615.28 92.060 163.540 8893.44 8972.04 4734.61 S 3268.02 E 5944353.14 N 648754.08 E 4.040 5742.68 11706.44 91.440 164.480 8890.65 8969.25 4822.20 S 3293.11 E 5944266.05 N 648780.86 E 1.235 5830.60 11799.39 92.430 166.560 8887.51 8966.11 4912.14 S 3316.34 E 5944176.57 N 648805.82 E 2.477 5919.57 11893.60 93.450 166.330 8882.68 8961.28 5003.60 S 3338.39 E 5944085.55 N 648829.64 E 1.110 6009.23 11985.16 92.860 167.010 8877.64 8956.24 5092.56 S 3359.47 E 5943997.02 N 648852.43 E 0.982 6096.25 12081.16 93.010 167.400 8872.73 8951.33 5186.05 S 3380.70 E 5943903.95 N 648875.46 E 0.435 6187.22 12172.49 90.830 167.730 8869.67 8948.27 5275.19 S 3400.36 E 5943815.22 N 648896.83 E 2.414 6273.65 12267.16 87.940 168.110 8870.68 8949.28 5367.74 S 3420.17 E 5943723.06 N 648918.43 E 3.079 6363.09 12311.31 85.650 167.880 8873.15 8951.75 5410.86 S 3429.33 E 5943680.13 N 648928.43 E 5.213 6404.72 12360.56 84.920 167.480 8877.20 8955.80 5458.81 S 3439.81 E 5943632.39 N 648939.82 E 1.689 6451.16 12453.76 84.860 167.650 8885.50 8964.10 5549.46 S 3459.80 E 5943542.14 N 648961.56 E 0.193 6539.06 12547.78 83.820 168.480 8894.77 8973.37 5641 .00 S 3479.15 E 5943450.99 N 648982.67 E 1.413 6627.39 12641.27 83.310 168.310 8905.25 8983.85 5732.00 S 3497.83 E 5943360.37 N 649003.12 E 0.575 6714.92 12712.89 83.660 168.440 8913.38 8991.98 5801.70 S 3512.17 E 5943290.96 N 649018.80 E 0.521 6781.97 12750.00 83.660 168.440 8917.47 8996.07 5837.83 S 3519.56 E 5943254.98 N 649026.89 E 0.000 6816.70 Projected Survey All data is in Feet (US Survey) 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 Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 148.810° (True). Magnetic Declination at Surface is 25.907°(30-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 12750.00ft., The Bottom Hole Displacement is 6816.72ft., in the Direction of 148.915° (True). 21 February, 2003 - 16:08 Page 4 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_ WOA Y Pad - Y-35A Your Ref: API 500292218601 Job No. A KZZ2221 0, Surveyed: 18 January, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6660.68 6680.00 12750.00 5912.05 5925.47 8996.07 1425.74 S 1434.93 S 5837.83 S 1527.47 E 1537.90 E 3519.56 E Tie On Point Window Point Projected Survey -' Survey tool proqram for Y-35A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 6660.68 0.00 6660.68 5912.05 12750.00 5912.05 BP High Accuracy Gyro(Y-35) 8996.07 AK-6 BP _IFR-AK(Y-35A) ..~./ 21 February, 2003 - 16:08 Page 5 of 5 DrillQuest 3.03.02.002 ) ) a 0ê)--d 77 (.) 25-Feb-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Y-35A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,660.68' MD Window / Kickoff Survey: 6,680.00' MD (if applicable) Projected Survey: 12,750.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, Attachment(s) RECEIVED MAR 2 6 2003 Alaska Ofi & Gas Coos. Cornmia..M Anchorage "ÐlIIWtVR William T. Allen Survey Manager Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_ WOA Y Pad Y-35A MWD --- Job No. AKMW22210, Surveyed: 18 January, 2003 Survey Report 21 February, 2003 Your Ref: API 500292218601 Surface Coordinates: 5949023.74 N, 645395.22 E (70016' 05.2343" N, 148049'27.2134" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~.J Surface Coordinates relative to Project H Reference: 949023.74 N, 145395.22 E (Grid) Surface Coordinates relative to Structure Reference: 528.23 N, 2342.68 W(True) Kelly Bushing: 78.60ft above Mean Sea Level Elevation relative to Project V Reference: 78.60ft Elevation relative to Structure Reference: 78.60ft spe........y-5UI! DRILLINt;- -seAVIc:-ès A Halliburton Company Survey Ref: svy11446 Sperry-Sun Drilling Services Survey Report for PBU_ WOA Y Pad - Y-35A MWD Your Ref: API 500292218601 Job No. AKMW22210, Surveyed: 18 January, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth IncI. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (tt) (tt) (tt) (tt) (tt) (tt) (tt) (0/100tt) 6660.68 45.980 131.410 5833.45 5912.05 1425.748 1527.47 E 5947627.77 N 646949.95 E 2010.70 Tie On Point MWD Magnetic 6680.00 46.030 131.370 5846.87 5925.47 1434.938 1537.90 E 5947618.78 N 646960.55 E 0.299 2023.96 Window Point 6726.06 46.150 134.570 5878.82 5957.42 1457.548 1562.17 E 5947596.64 N 646985.25 E 5.012 2055.88 6830.60 46.900 141.730 5950.80 6029.40 1514.008 1612.70 E 5947541.17 N 647036.86 E 5.020 2130.34 6914.41 47.660 147.020 6007.68 6086.28 1564.03 8 1648.53 E 5947491.85 N 647073.65 E 4.724 2191.69 ~/ 6948.93 47.900 147.370 6030.87 6109.47 1585.51 8 1662.38 E 5947470.63 N 647087.91 E 1.023 2217.24 6979.82 48.100 148.010 6051.54 6130.14 1604.91 8 1674.65 E 5947451.47 N 647100.55 E 1.670 2240.19 7008.72 46.790 151.020 6071.09 6149.69 1623.25 8 1685.45 E 5947433.35 N 647111.71 E 8.910 2261.48 7040.81 46.770 152.920 6093.07 6171.67 1643.89 8 1696.44 E 5947412.92 N 647123.09 E 4.315 2284.82 7070.86 46.870 153.140 6113.63 6192.23 1663.42 8 1706.37 E 5947393.59 N 647133.41 E 0.629 2306.68 7101.62 46.980 153.170 6134.64 6213.24 1683.47 8 1716.52 E 5947373.74 N 647143.94 E 0.365 2329.08 7132.90 47.170 153.390 6155.94 6234.54 1703.93 8 1726.82 E 5947353.48 N 647154.63 E 0.796 2351.92 7196.66 47.540 153.170 6199.13 6277.73 1745.828 1747.91 E 5947312.01 N 647176.52 E 0.633 2398.67 7226.76 47.600 153.820 6219.44 6298.04 1765.70 8 1757.82 E 5947292.32 N 647186.82 E 1.606 2420.81 7289.52 48.150 153.840 6261.54 6340.14 1807.48 8 1778.35 E 5947250.95 N 647208.15 E 0.877 2467.18 7382.14 49.210 154.430 6322.69 6401.29 1870.078 1808.69 E 5947188.95 N 647239.70 E 1.240 2536.44 7474.75 48.250 151.370 6383.79 6462.39 1932.03 8 1840.38 E 5947127.62 N 647272.58 E 2.691 2605.85 7572.60 48.660 152.110 6448.68 6527.28 1996.53 8 1875.06 E 5947063.80 N 647308.49 E 0.704 2678.99 7665.58 48.490 151.830 6510.20 6588.80 2058.07 8 1907.82 E 5947002.90 N 647342.44 E 0.291 2748.60 7757.57 48.370 151.780 6571.24 6649.84 2118.738 1940.34 E 5946942.89 N 647376.12 E 0.137 2817.33 7853.89 48.290 152.130 6635.28 6713.88 2182.23 8 1974.16 E 5946880.05 N 647411.17 E 0.284 2889.17 7948.34 48.320 151.470 6698.10 6776.70 2244.38 8 2007.49 E 5946818.55 N 647445.69 E 0.523 2959.60 --~ 8041.76 48.480 151.730 6760.13 6838.73 2305.83 8 2040.72 E 5946757.75 N 647480.09 E 0.270 3029.38 8135.52 48.590 151.920 6822.21 6900.81 2367.778 2073.89 E 5946696.47 N 647514.46 E 0.192 3099.54 8228.63 48.850 152.460 6883.64 6962.24 2429.66 8 2106.53 E 5946635.22 N 647548.29 E 0.518 3169.39 8322.82 49.130 152.730 6945.45 7024.05 2492.76 8 2139.25 E 5946572.77 N 647582.22 E 0.368 3240.31 8414.78 46.270 151.410 7007.33 7085.93 2552.85 8 2171.09 E 5946513.30 N 647615.21 E 3.286 3308.21 8509.91 45.400 151.440 7073.61 7152.21 2612.788 2203.73 E 5946454.01 N 647649.00 E 0.915 3376.37 8602.68 45.630 151.320 7138.62 7217.22 2670.88 S 2235.43 E 5946396.54 N 647681.82 E 0.265 3442.49 8695.56 45.880 150.890 7203.42 7282.02 2729.13 S 2267.58 E 5946338.92 N 647715.09 E 0.427 3508.98 21 February, 2003 - 16:06 Page 2 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_ WOA Y Pad - Y-35A MWD Your Ref: API 500292218601 Job No. AKMW22210, Surveyed: 18 January, 2003 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) 8790.68 46.370 150.450 7269.35 7347.95 2788.91 S 2301 .17 E 5946279.80 N 647749.83 E 0.614 3577.51 8882.74 45.250 151.190 7333.52 7412.12 2846.54 S 2333.35 E 5946222.81 N 647783.12 E 1.346 3643.47 8977.45 44.800 150.960 7400.46 7479.06 2905.18 S 2365.76 E 5946164.80 N 647816.65 E 0.505 3710.42 9070.92 44.570 150.750 7466.91 7545.51 2962.58 S 2397.77 E 5946108.02 N 647849.77 E 0.292 3776.11 9163.00 44.220 151.270 7532.71 7611.31 3018.93 S 2428.99 E 5946052.29 N 647882.07 E 0.548 3840.48 9256.08 44.020 150.870 7599.53 7678.13 3075.64 S 2460.34 E 5945996.19 N 647914.50 E 0.368 3905.23 ~ 9349.31 44.120 151.220 7666.51 7745.11 3132.38 S 2491.73 E 5945940.07 N 647946.99 E 0.282 3970.02 9444.01 43.880 151.080 7734.63 7813.23 3190.00 S 2523.47 E 5945883.08 N 647979.84 E 0.273 4035.75 9537.05 44.010 151.320 7801.62 7880.22 3246.58 S 2554.58 E 5945827.11 N 648012.03 E 0.227 4100.26 9629.57 43.960 151.940 7868.19 7946.79 3303.12 S 2585.11 E 5945771.17 N 648043.64 E 0.469 4164.44 9723.31 43.840 151.970 7935.74 8014.34 3360.48 S 2615.67 E 5945714.41 N 648075.31 E 0.130 4229.34 9817.59 44.780 153.260 8003.20 8081.80 3418.96 S 2645.95 E 5945656.52 N 648106.72 E 1.381 4295.05 9909.35 44.740 153.060 8068.36 8146.96 3476.61 S 2675.12 E 5945599.45 N 648137.00 E 0.160 4359.47 10003.21 44.430 152.890 8135.21 8213.81 3535.31 S 2705.06 E 5945541.34 N 648168.06 E 0.354 4425.18 10096.01 44.290 152.620 8201.55 8280.15 3592.99 S 2734.76 E 5945484.24 N 648198.87 E 0.253 4489.91 10190.46 44.180 153.310 8269.23 8347.83 3651.68 S 2764.71 E 5945426.15 N 648229.95 E 0.523 4555.63 10284.02 43.930 153.120 8336.47 8415.07 3709.75 S 2794.03 E 5945368.65 N 648260.38 E 0.302 4620.49 10376.68 43.630 153.090 8403.37 8481.97 3766.93 S 2823.03 E 5945312.04 N 648290.48 E 0.325 4684.42 10470.21 43.670 153.400 8471.04 8549.64 3824.58 S 2852.09 E 5945254.97 N 648320.65 E 0.233 4748.79 10563.74 49.520 153.670 8535.28 8613.88 3885.38 S 2882.36 E 5945194.75 N 648352.09 E 6.258 4816.48 10655.63 50.260 153.730 8594.48 8673.08 3948.39 S 2913.49 E 5945132.36 N 648384.44 E 0.807 4886.50 10748.86 50.030 154.040 8654.23 8732.83 4012.65 S 2945.00 E 5945068.72 N 648417.17 E 0.355 4957.79 10840.86 49.820 154.240 8713.46 8792.06 4076.00 S 2975.70 E 5945005.98 N 648449.10 E 0.282 5027.88 ~ 10854.49 49.760 154.090 8722.26 8800.86 4085.37 S 2980.24 E 5944996.70 N 648453.81 E 0.949 5038.25 10932.90 49.020 153.020 8773.30 8851.90 4138.66 S 3006.75 E 5944943.92 N 648481.34 E 1.401 5097.57 10962.32 53.710 153.730 8791.66 8870.26 4159.20 S 3017.04 E 5944923.59 N 648492.03 E 16.052 5120.47 10995.85 59.920 150.760 8810.01 8888.61 4184.01 S 3030.12 E 5944899.04 N 648505.59 E 19.946 5148.46 11 027.17 61.740 149.060 8825.27 8903.87 4207.67 S 3043.83 E 5944875.65 N 648519.76 E 7.498 5175.80 11055.50 62.090 149.280 8838.61 8917.21 4229.13 S 3056.64 E 5944854.44 N 648532.98 E 1.413 5200.80 11089.60 67.810 152.420 8853.04 8931.64 4256.10 S 3071.66 E 5944827.76 N 648548.52 E 18.731 5231.65 11120.38 67.950 154.070 8864.63 8943.23 4281.56 S 3084.50 E 5944802.55 N 648561.84 E 4.987 5260.08 11149.81 74.290 154.850 8874.15 8952.75 4306.68 S 3096.50 E 5944777.67 N 648574.32 E 21.688 5287.77 11185.29 78.660 155.710 8882.45 8961.05 4338.01 S 3110.91 E 5944746.63 N 648589.34 E 12.540 5322.04 11213.82 78.850 156.410 8888.01 8966.61 4363.58 S 3122.27 E 5944721.28 N 648601.19 E 2.497 5349.80 11242.28 79.450 156.610 8893.37 8971.97 4389.22 S 3133.41 E 5944695.87 N 648612.82 E 2.218 5377.50 21 February, 2003 - 16:06 Page 3 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_ WOA Y Pad - Y-35A MWD Your Ref: API 500292218601 Job No. AKMW22210, Surveyed: 18 January, 2003 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) 11276.13 82.230 157.680 8898.76 8977.36 4420.01 S 3146.39 E 5944665.33 N 648626.39 E 8.786 5410.56 11300.30 82.310 156.460 8902.01 8980.61 4442.07 S 3155.72 E 5944643.46 N 648636.15 E 5.013 5434.26 11334.81 85.080 156.880 8905.80 8984.40 4473.56 S 3169.30 E 5944612.23 N 648650.34 E 8.117 5468.24 11367.98 91.040 155.450 8906.92 8985.52 4503.87 S 3182.69 E 5944582.19 N 648664.31 E 18.477 5501.1 0 11427.75 91 .410 158.360 8905.64 8984.24 4558.83 S 3206.13 E 5944527.69 N 648688.81 E 4.907 5560.25 11521.59 95.730 162.660 8899.80 8978.40 4647.08 S 3237.37 E 5944440.06 N 648721.75 E 6.488 5651.92 ..~ 11615.28 92.060 163.660 8893.44 8972.04 4736.52 S 3264.44 E 5944351.15 N 648750.54 E 4.059 5742.46 11706.44 91.440 165.020 8890.65 8969.25 4824.26 S 3289.04 E 5944263.91 N 648776.83 E 1.639 5830.25 11799.39 92.430 166.560 8887.51 8966.11 4914.31 S 3311.84 E 5944174.32 N 648801.36 E 1.969 5919.10 11893.60 93.450 166.520 8882.68 8961.28 5005.81 S 3333.74 E 5944083.26 N 648825.03 E 1.084 6008.71 11985.16 92.860 167.340 8877.64 8956.24 5094.86 S 3354.41 E 5943994.62 N 648847.42 E 1.102 6095.60 12081.16 93.010 167.980 8872.73 8951.33 5188.52 S 3374.90 E 5943901.38 N 648869.71 E 0.684 6186.33 12172.49 90.830 167.950 8869.67 8948.27 5277.79 S 3393.93 E 5943812.49 N 648890.46 E 2.387 6272.55 12267.16 87.940 168.290 8870.68 8949.28 5370.41 S 3413.42 E 5943720.26 N 648911.74 E 3.074 6361.88 12311.31 85.650 168.170 8873.15 8951.75 5413.56 S 3422.41 E 5943677.29 N 648921.56 E 5.194 6403.45 12360.56 84.920 167.690 8877.20 8955.80 5461.56 S 3432.68 E 5943629.50 N 648932.75 E 1.772 6449.82 12453.76 84.860 167.710 8885.50 8964.10 5552.26 S 3452.45 E 5943539.20 N 648954.27 E 0.068 6537.65 12547.78 83.820 168.800 8894.77 8973.37 5643.86 S 3471.50 E 5943447.99 N 648975.08 E 1.598 6625.88 12641.27 83.310 168.950 8905.25 8983.85 5735.02 S 3489.42 E 5943357.19 N 648994.76 E 0.568 6713.14 12712.89 83.660 168.950 8913.38 8991.98 5804.85 S 3503.06 E 5943287.63 N 649009.75 E 0.489 6779.95 12750.00 83.660 168.950 8917.47 8996.07 5841.05 S 3510.13 E 5943251.58 N 649017.52 E 0.000 6814.57 Projected Survey All data is in Feet (US Survey) 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 Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 148.810° (True). Magnetic Declination at Surface is 25.907°(30-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 12750.00ft., The Bottom Hole Displacement is 6814.61ft., in the Direction of 148.997° (True). 21 February, 2003 - 16:06 Page 4 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_ WOA Y Pad - Y-35A MWD Your Ref: API 500292218601 Job No. AKMW22210, Surveyed: 18 January, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6660.68 6680.00 12750.00 5912.05 5925.47 8996.07 1425.74 S 1434.93 S 5841.05 S 1527.47 E 1537.90 E 3510.13 E Tie On Point Window Point Projected Survey ~ Survey tool program for Y-35A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 6660.68 0.00 6660.68 5912.05 12750.00 5912.05 BP High Accuracy Gyro(Y-35) 8996.07 MWD Magnetic(Y-35A MWD) '~ 21 February, 2003· 16:06 Page 5 of 5 DrillQuest 3.03.02.002 ') ,/ \, ) CQ?, :r ® ,,1:":"":1 IE cY) d ¡ru ~_ L~ ~ F ~~fÆ~~fÆ FRANK H. MURKOWSKI, GOVERNOR ~ AI',A.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH 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 Y -35A BP Exploration (Alaska), Inc. Pennit No: 202-237 Surface Location: 1243' SNL, 4696' Wel, Sec. 34, TI1N, R13E, UM Bottomhole Location: 1655' SNL, 1263' Wel, Sec. 03,TI0N, R13E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional permits 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 pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this pennit may result in the revocation or suspension of the pennit. 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, ~¡:?'~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this /?!!'day of December, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. vJ· b A:- 11.··1 1/ ~ -¿... Hole 6-314" 4-3/4" '¡) STATE OF ALASKA \ ALASKA .~" A- AND GAS CONSERVATION COMIV.._510N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 79.221 Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool (" ADL 047471 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / Y-35A Number 2S100302630-277 9. Approximate spud date Z-/2 1 {D 1.~.o..1J.G.1'103·~ ~" Amount $200,000.00 14. Numoer of acres in property 15. Proposed depth (MD and TVD) 2560 125881 MD /90091 TVD o 17. Anticipated pressure {s~20 AAC 25.035 (e) (2)} 95 Maximum surface 3075 psig, At total depth (TVD) 9009' I 3607 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 4428' 6535' 58251 109631 8854' 1788' 10800' 87431 125881 9009' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill 181 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 12431 SNL, 4696' WEL, SEC. 34, T11 N, R13E, UM At top of productive interval 128' SNL, 1667' WEL, SEC. 03, T10N, R13E, UM At total depth 1655' SNL, 1263' WEL, SEC. 03, T10N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 047472,12631 MD Y-08 is 951' away at 124861 16. To be completed for deviated wells Kick Off Depth 11650' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weight Grade Couplina 5-1/2" 17# L-80 Hydril 521 3-1/2" 9.2# L-80 IBT I SC Quantity of Cement (include staae data) 168 cu ft Class 'G1 Uncemented Slotted Liner / 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 11425 feet 9200 feet 11341 feet 9140 feet Length Plugs (measured) Perf Abandonment Plug TOC at 7995' (3/99) Junk (measured) 1258' of 1-3/4" Milling & Drilling BHA (Service Coil) was stuck (cemented) inside the tubing; TOF at 6755' (3/99) Cemented MD TVD Size Structural Conductor Su rface Intermediate Production Liner 110' 20" x 30" 2667' 10-3/4" 2924 cu ft Coldset III & II 10968' 7-5/8" 1601 cu ft Class 'G' 6901 5-1/2" 155 cu ft Class 'G' 1101 26941 1101 2694' 10995' 8892' IfE'C ~fV ~tj' - 9200' Perforation depth: measured None DEC 06 2002 AJasRa Oil & Gas Gons. Commission - , Anchorage 20. Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that ~hl ~o¡egOing\is true and correct to the best of my ~nowl~~ge . Signed Bill Isaacson /.-J..~ l. to Title Semor Dnlllng Engineer Date' 2 I ~ I 01- CQrrtmission U~ê.;Pnly."'..·, true vertical None Permit Number API Number ..20.2..- .2..3 7 50- 029-22186-01 Conditions of Approval: Samples Required 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: T-e~...tBC' P E to .~ S Cll? p! i · Approved By ORIGINAL SIGNED BY Form 10-401 Rev. 12-01-85 M L 001 See cover letter for other requirements DYes I2SI No Directional Survey Required EYes 0 No o 4K 05K 010K 015K 0 3.5K psi for CTU l' P~rov~1 D~, , : 1<1 [rr Mud Log LuJed .' Gonvnis$iot;ler, I I !i by order of the commission Date I 'ÔI !J~ Ie ?- ~ubmit Ih Triplicate \;: '/ ,.\ i! U II (, . L= I, ) ) IWell Name: IV-35A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 4 Bottom Hole Location: x = 645,395 Y = 5,949,024 12431 FNL, 4696' FEL Sec. 34, T11 N, R13E Umiat X = 648,514 Y = 5,944,919 TVDss 8772 128' FNL, 1667' FEL Sec. 3, T10N, R13E Umiat X = 648,950 Y = 5,943,400 TVDss 8930 16551 FNL, 1263' FEL Sec. ,3 T10N, R13E Umiat I AFE Number: I P8D4P2026 I I Estimated Start Date: 101/01/03 I RiQ: 1 Nabors 2ES /' I OperatinQ days to complete: 122.0 I MD: 112,588' 1 I TVD: 19,009' I 1 BF/MS: 150.72' I 1 KB: 128.5' I I KBE: 179.22' I I Well DesiQn (conventional, slim hole, etc.): I Horizontal Sidetrack /' I Objective: 1 Zone 48 Formation Markers Formation Tops (wp03) Ugnu Sand Base West Sakrr op Seabee HRZ Base HRZ/LCU Kingak Sag River Shublik Ivishak TD MD 4188' 6,584' 8,965' 9,228' 9,653' 10,963' 10,993' 11 ,136' 12,588' TVD 4,109' 5,859' 7,489' 7,669' 7,959' 8,854' 8,874' 8,949' 9009' TVDss 4,030' 5,780' 7,41 0' 7,590' 7,880' 8,775' 8,795' 8,870' 8,930' Comments TD Criteria: The well will reach TD according to well plan #03, or before IF water saturation is higher than expected. The subsurface team will determine this. Y -35A Sidetrack Page 1 ) ) CasinalTubina Proc ram - - ~ Hole Size Csg/ WtlFt Grade Cor Length Top Btm Tbg C.D. / MDrrVD MDrrVD 6 3/4" 51/2" 17.0# L-80 Hydril 521 -4,428' 6,535'/ 5825' 10,963'/ 8,854' 4 3/4" 3 Y2" 9.2# L-80 IST/ Spc. -1,788' 10,800'/8743' 12,588'/9,009' slotted Clearance Tubing 3 Y2" 9.2# 13Cr80 V AM ACE -10,700' GL 10,700'/8674' Directional KOP: 111,650' MD Maximum Hole Angle: -47.0° in 6-3/4" hole -94.5° in 4-3/4" horizontal section ""'l There is one close approach issue: V-08 fails major risk. It ist95~-V away at 12486' MD. V-08A, a sidetrack from V-08 passes. The origi~ellbore of V-08 was P&A'd during the sidetrack operations. V-35A passes with a 1 in 200 minor risk rating. MWD with IIFR/Cassandra from kick-off to TO Close Approach Well: Survey Program: Mud Program Section Milling Mud Properties: LSND I Whip Stock Window 7 5/8" I Density (ppg) Viscosity PV YP tauo MBT PH API FI 11.1 20 - 30 50 - 60 8.0 - 9.0 NC Intermediate Mud Properties: LSND I 6 3/4" hole section I Density (p,) 10-Sec Gel PV YP tauo MBT PH API FI 11.5 1 0 - 20 15 20 - 27 8.0 - 9.0 <6 Production Mud Properties: Flo-Pro Drill-in I 4 3/4" hole section I Density (ppg) LSRV PV YP LSYP MBT pH API FI 8.6 - 8.7 55,000+ 7 -11 20 - 25 4-8 <6 9.0 - 9.5 4-6 Loaging Program 63/4" Intermediate: Sample Catchers - from JD to casing point. Drilling: MWD Dir/GR/PWD- Real time GR/PWD throughout entire interval. Open Hole: None Cased Hole: None 43/4" Production: Sample Catchers - over entire interval, samples described and discarded. Drilling: MWD Dir/GR/Res- Real time GR/Res throughout entire interval. Open Hole: None Cased Hole: None V -35A Sidetrack Page 2 ') ) Cement Proaram Casing Size í 5 1/2" 17#, L-80 Intermediate Liner I Basis: Lead: None Tail: Based on 82' of 5 1/2" shoe track, 1000' of 5 Y2" X 6 %" open hole with 400/0 excess. Tail TOC: 9960' MD / 8170' TVD-bkb Fluid Sequence & Volumes: Pre 10bbls CW100 Flush Spacer 25bbls MudPUSH XL at 12.5ppg L;;1 ~~~~IS. 168 ft39aCkS Class G @ 15.8 ppg, 1.17 ft3/sack Casing Size 13 1/2", 9.2#, L-80 Slotted I Solid Production Liner Basis: I None. Uncemented solid/slotted liner Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system sch~matics on file with the AOGCC. Intermediate Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 7-5/8" Casing Test Integrity Test - 6-3/4" hole Production Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 7-5/8" Casing/5-1/2" Liner Test Planned completion fluids 13-5/8", 5~" ' MPL Gates with Annular (Hydril-13-5/8" GK) 3960 psi~Yppg @ 8,854' TVD) 3075 psi<-ffö psi/ft gas gradient to surface) 74 bbls with a 12.0 ppg LOT /' Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure /' FIT after drilling 20' outside window 13-5/8", 5~" PL Gates with Annular (Hydril-13-5/8" GK) 3607 psi 7 ,..ppg @ 9009' TVD) 2706 psi . 0 psi/ft gas gradient to surface) Infinite /' Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi ./ 3500 psi surface pressure 8.4 ppg Seawater / 6.8 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure SUmmary Y -35A Sidetrack Page 3 '} ) Sidetrack and Complete Procedure Summary Pre-RiCl Work: *Notify the field AOGCC representative with intent to plug and abandon* 1. Pressure test tubing and OA to 2500 psi. / 2. Pressure test Casing and Tubing pack-offs to 5000 psi 3. Rig up slickline. Drift and tag top of existing fish in 4-1/2" tujing. 4. Rig up e-line. Chemical cut 4-1/2" tubing at +\-6750' MD. 5. Fluid pack tubing and OA. Freeze protect same. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form RiCl Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection an~isplace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. /' 4. Pull tubing from chemical cut above fish. POOH laying down 4%" completion. 5. RU E-line and make GR/CCUJB run to to~f tubing cut. MU bridge plug. RIH and set at +\-6725'."- 6. Test wellbore to 3500 psi for 30 minutes. 7. RIH with 7-5/8" Baker whipstock assembly. Orient whipstock as desired and set on bridge plug. Mill window in 7-5/8" casing. Perform FIT to 12.0 ppg, POOH. "..". 8. MU 6-3/4" dJ.illing assembly with Dir/GR and RIH. Kick-off and 9£:ill the 6-3/4" intermediate interval, bUildin~r<'''3dy100' to 47°, landing in toe top of the Sag River. Drill ahead to an estimated casing point 0 1 0,~3' MD (8854' TVD). /' 9. Run a: :C'ement a 5-1/2", 17# drilling liner throughout the 6-3/4" wellbore and back into the 7-5/8" casing. Liner top to be at -6550' MD. Displace cement with drilling mud. / 10. MU 4-3/4" drilling assembly with Dir/GR/Res and RIH. Drill shoe track and displace hole over to drill- in fluid. Drill 20' of new hole and perform FIT to 1.0 ppg over mud weight. 11. Drill the 4-3/4" production interval, building at 12°/100' to 88°, landing iryvis"hak Zone 4B. Drill ahead, geo-steering to an estimated !Çtal depth of 12,588' MD (9009' TVD). /' 12. Runß.Rd""a 3-1/2",9.3# slott-éd production liner throughout the 4-3/4" wellbore and back into the 5-1/2" casing. Liner top to be q.t1 O,8J<3' MD. Displace well to seawater ab~ liner top. POOH. 13. Run 3-1/2", 9.3# 13Cr-@..c.hfupletion tying into the 3-1/2" liner top. 14. Set packer and test the tubing to 35.00 psi and annulus to 3500 psi for 30 minutes. /' 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 16. Freeze protect the well to -2200' and secure the well. 17. Rig down and move off. Post-Ri~ Work: 1. Install wellhouse and flow lines. 2. Pull the ball and rod 1 RHC plug from landing nipple below the production packer. Pull DCK valve. Install gas lift valves. Y -35A Sidetrack Page 4 ) ) Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move onto Y-35A. However, Y-03 is -30' to the West, and there is a cellar -30' to the East. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters will be used at all times. ~ Y~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: Closest SHL Wells: Closest BHL Wells: V -02 30ppm V -34A 10 ppm V-03 20ppm A-16 30 ppm The maximum level recorded of H2S on the pad was 110 ppm on Y-23A in 03/2002. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies ~ The lower section of this well should be isolated by 2 barriers - the coil fish with cement inside the /' 4-1/2" tubing, the production packer on the outside of the tubing and seawater to surface. The coil fish and packer will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ The existing wellhead is an FMC New Standard Slim Hole and has a 4-1/2" tubing hanger. Utilize a 4" type 'H' BPV. Verify the hanger type and connection. Be prepared with necessary equipment to remove. ,Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP _......._ "....·'''''~_IIIIII~mlt-'-...............··'-..............................;,,~...........................,,_I._·-:':-;,''*'...-- _ IIIII~I'. .1:-'_ Y -35A Sidetrack Page 5 ') ) Job 5: Drill 6 3/4" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in mid Seabee and drill the entire Kingak interval to the top of Sag River. Previous V-Pad wells drilled the Kingak with 9.8 to 10.2ppg mud weights. For this well, due to the long tangent at 470 inclination at a 1520 azimuth, maintain mud weight at 11.2ppg, minimally, to 5 1/2" liner point. Follow all shale drilling practices to minimize potential problems. ~ There is one fault crossing in the intermediate section. The fault will be crossed in the base of the Colville mudstone or top of the HRl, and is estimated to have a 25' throw. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ The Security Near Bit Reamer (NBR) will be utilized in drilling this intermediate section, to open the hole from 6 3,4" to 7" gauge. This should aid in getting the 5 Y2" liner to setting depth, within the Sag River. ~ KICK TOLERANCE: In the worst-case scenario of 9.6 ppg pore pressure at the Sag River depth, a fracture gradient of 12.0 ppg at)he 7 5/8" casing window, and 11.2 ppg mud in the hole, the kick tolerance is 74 bbls. (: Reference RP .:. "Shale Drilling, Kingak and HRl" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" <o.'M««o».__':':~'¡':'~««-___W_«<~«««<';'»:«_~««*:':~~««««««*-~"«««:n::>,"",*,""'^"''''''^'''''''"''I'''''''"'<'_O:O»:«.o»:.:o:«<<<-:__':«~*:':«*I««_-:'-_,»:~«««*:~'««'~~":«»>'':«<_~<:««,'ÿ,\:':'':'__«<.»:««««<~:«-::«oc<<<<:<<<<y'«<<<<w:.x._,<",:"",,:,:<<> Job 6: Install 5 1/2" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP ~",,»~~,,~,,,,,,__,,,,~_,,,,,~"'M"",,*_'*,,,~~~~~,,.,.,.~.,..,,..,,.,,,,.,.".,..~,.\,,;~~:,.)\,:\,~_~~_:~~~"_~~,»..,.~~~~~.;,.w."»~''''';_~'y>;>~,"'",__~-"">:"'«'1~",~~~_~:»>':«i"",,"~~,,_ Job 7: Drill 4 3/4" Production Hole Hazards and Contingencies ~ There are two potential fault crossings in lone 4B while drilling the production section. The faults are evident on the West side of the target polygon, but there is no conclusive evidence to support the presence of either fault along the wellpath. If present, the faults would have a small throw, approximately 10-15 feet. Lost circulation is not anticipated. Should the faults cause loses, follow the Lost Circulation Decision Tree. ~ A large NNW-SSE fault exists on the West side of the target polygon. Past attempts to cross this fault have resulted in massive loss circulation. The Y-35A well path runs parallel to this fault. Y -35A Sidetrack Page 6 ) ) Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP :-:«,~w.-:->:««':«>!««~N~_«-N*>;~·!o'_O»___~i~~~~«-~~*,*,,,»*»:O»:~~~_-:-:«_:««'__·_«<X«««««>:+:<<<>;IX<<<<(O:-K<<<'¡'I*:.<<<1<<<<>I(_<<__:-:<<<<<<-~___<~»o.::#)X.x<<o>;N+:<<<<oI>>>:o!~@1<N<< Job 9: Install 3 112" Slotted Production Liner Hazards and Contingencies >- The completion design is to run a 3 V2", 9.2#, L-80 slotted liner throughout the production interval. Solid liner will be placed across intervals of lower resistivity / higher water saturation, as determined by the subsurface team. >- Differential sticking is a concern. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 3 V2" liner will need to be run to extend -150' back up into the 5 1/2" intermediate liner. Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP :+:'_:-;'~__~~»:«<>'-:O:-:':-I·__'_-:-¡.m~___~:-m~rn»1'~"'~_:_~_~"'~_""""""""'·"',""""""""",''''......',Y,.·M'·...",·"...,....."'''',·,..........WM·,'·.·,''''''~''..·m··. "",""""'.,.,...."",...'''''',.,~"..."...,y~,,~,,.,,:..,»>1'_,______y;y,..,........,·,"',·.........."..·.......,·,,~w, "........"'",.,..........,....".....,....,.;.;.:¡.¡.,~~ Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ There are two neighboring wells at 30 foot center spacing. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig off the hole and about the pad. Reference RP .:. "Freeze Protecting an Inner Annulus" RP Y -35A Sidetrack Page 7 TREE = WELLHEAD= ACTuAToR; KS. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = " " ,. Datum1VD= 4-1/16" CIW FMC BAKER 87.32' 50.72' 3200' 54 @ 9900' 10989' 8800' SS ) Y -35 Pre-Rig 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 1-1 2694' r-JI 16755' CTM - Top of Fish 1 17995' CTM - Btm of Fish I ---- 7-5IS"X5-1/2"TWLNRHGRW/TEBACK H 10735' ~ ~ 4-1/2" TBG, 12,6#, 13-CR, 0,0152 bpI, ID = 3,958" H 10735' I "I } I I TOP OF 5-1/2" LNR 1-1 107471 7-5/8" eSG, 29.7#, ID = 6.875" 1-1 109811 5-1/2" LNR, 17#, 13-CR, .0232bpf, ID = 4.892" 1-1 114251 DATE 07/07/91 03/06/01 03/16/01 03/16/99 06/29/01 REV BY COMMENTS WL ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANVAS SIS-CS FINAL ABORT em SDTRK (CT FISH) Cl-VKAK CORRECTIONS DATE .4 ~ REV BY ) ~ -I +/-6725' MD - Tubing Cut I .// t I 1-8700' calc bottom of cement .. COMMENTS PRUDHOE BAY UNIT WELL: Y -35 ÆRMIT NO 99-09 API No: 50-029-22186-01 1243' FNL & 583' FWL, Sec. 34, T11 N, R13E BP Exploration (Alaska) ) Y-35 Decompleted TREE = WELLHEAD= ACTUA TOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumìVD= 4-1/16" CIW FMC BAKER 87.32' 50.72' 3200' 54 @ 9900' 10989' 8800' SS 10-3/4" CSG. 45.5#, NT-80, ID = 9.953" l-t 2694' ~ - 16755' CTM - Top of Fish 1 17995' CTM - Btm of Fish 1 7-5/S"X5-1/2"TMlLNRHGRW/TlEBAO< H 10735' ~ ~ 4-1/2" TBG, 12,6#, 13-CR, 0,0152 bpI, ID = 3.95S" H 10735' I ~l } I I TOP OF 5-1/2" LNR 1-1 10747' 7-5/8" CSG, 29.7#, ID = 6.875" 1-1 10981' 41 ) ~ /'" ~i:¡~i [,~: ':'I"i~ ij.':,"" ~.f; .' ~:;·"t ::,~t:< i,~~', "i':'I:':t:,~ -16700' MD - Bridge Plug 1 16725' MD - Tubing Cut 1 t I . ~ I 5-1/2" LNR, 17#, 13-CR, .0232bpf, ID = 4.892" l-t 11425' DATE REV BY COMMENTS DA TE REV BY 07107/91 MJL ORIGINAL COMA...ETION 03/06/01 SIS-QAA CONVERTED TO CANVAS 03/16/01 SIS-CS FINAL 03/16/99 ABORT CTD SDTRK (CT FISH) 06/29/01 CH/KAK CORRECTIONS COMMENTS PRUDHOE BAY UNIT WELL: Y -35 PERMIT NO 99-09 API No: 50-029-22186-01 1243' FNL & 583' FWL, Sec. 34. T11 N, R13E BP Exploration (Alaska) 10-314·. 45.5# ~ NT -80 BTRS 1 Top Of, Window 1 +1- 6,685' MO 1 Window Mill Max 001 =6.75· 1 Btm of Window I +/-6,700' MO I 17-5/8·,29.7# I~ NT-95HS, NSCC 15-1/2",17#, 13-CRI COMMENTS Proposed Sidetrack II ~ t. --- i t .' .......'...' .......'. ............ :::::::::::::::::::: :::: ............... ......... ............. ') Y -35A I 'X' Nipple with 2.813· bore @ +/- 2200' Mol ~12694' Mol ~ ~ 7-5/8· X 5-1/2" Baker Flex-Lok Liner Hanger wI HR Running Tool, ZXP Liner Top Packer and TBR @ +/- 6535' MO ) GLM Detail: All GLM's to be 9 Chrome Mandrels Station Mn TVO Si7e Type 6 2981' 2900' 3-1/2"X1-1/2" MMG 5 4181' 3900' 3-1/2"X1-1/2" MMG 4 6063' 5400' 3-1/2·X1-1/2" MMG 3 7613' 6500' 3-1/2·X1· KBG-2-9 2 8999' 7500' 3-1/2"X1· KBG-2-9 1 10550' 8500' 3-1/2"X1· KBG-2-9 Packer/Tailpipe Detail: 10'Pup GLM #1 10'Pup 1 Full joint of tubing 10'Pup 'X' Nipple - 2.813· 10' Pup Packer 20'Pup 'X' Nipple - 2.813" 20' Pup 'XN' Nipple - 2.75" nogo 10'Pup WLEG Tree= Wellhead= KB Elev= BF Elev= Datum MD= Datum TVD= 3-1/16" CIW FMC 87.32' 50.72' 10989' 8800'ss 3-1/2", 9.2# 13CR80, VAM ACE Production Tubing 5-1/2" X 3-1/2" Baker ./ SABL-3 Packer @ +/-10,700' MO ./ 5-1/2· X 3-1/2" Baker HMC Liner Hanger wI ZXP Liner Top Packer and TBR @ +/- 10,800 MO 110,963' MO / 8,854' TVO I 112,588' MO / 9,009' TVol ==~~~-~~~==~~~-~~~==~~~-~~~==~~~-~ I ~110,981' Mol 1 5-1/2", 17# 1 L-80, Hydril 521 . OA TE REV BY 08/22/02 COMMENTS 3-1/2", 9.2# Slotted Liner L-80, IBT w/ Special Clearance Collars PRUDHOE BAY UNIT WELL: Y -35A API No: 50-029-22186-01 1243' FNL & 583' FWL, Sec. 34, T11N, R13E BP Exploration (Alas ka) SURVEY PROGRAM Plan: Y-35A wp03 (Y-35/Plan Y-35A) Depth Fm Depth To Sum'yiPlan Tool Created By: Ken Allen Date: 9/26/. 6700.00 12587.91 Planned: Y-35A..p03 V9 MWD Checked: Date: Re\iewed: Date: WELL DETAILS Nazœ +Ni-S ~EJ-W Nor1hing Fasting Latitud> LoogiIUde Slot Y-35 528.99 -2343.78 594902433 64539520 70"16"0524œo1 148"49'27214W 35 TARGET DETAILS Nazœ lVD +Nf-S +EJ-W Northing Fasting Shape Y-35A 7·C5g 8851.22 -4164.95 3039.51 5944919.18 648514.35 Point Y·35A T2 894922 -5120.94 3379.79 5943970.01 648873.01 Pomt Y·35A T2a 894922 -5119.97 3329.79 5943970,01 648823.01 Point Y·35A Poly 897922 -451632 294135 5944566.01 648423.00 Polygon Y·35A Fltl;'2 897922 -4262.43 2433.12 5944810.01 647910.00 PoJygoo Y·35A Flt#3 897922 ·5100.97 2604.97 5943975.01 648098.01 PoJygon Y·35A T1 898922 -4469.96 3182.31 59446J7,0I 648663.00 Point Y-35A D 900922 -5626.82 3522.05 5943467.01 649025.01 Point Y-35A Da 900922 ·5692.36 3445.77 5943400.01 648950,01 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +FJ-W Dfeg TFace vSec Target I 6700.00 46.08 131.34 5939.54 -1444.10 1548.37 A·oo 0.00 2037.21 2 6720.00 46.34 134.65 5953.38 -1453.94 1558.93 12.00 85.00 2051.1 0 3 7145.62 46.92 152.23 6246.87 -1700.68 1741.65 3.00 93.46 2356.79 .---./ 4 10958.71 46.92 152.23 8851.22 -4164.95 3039.51 0.00 0.00 5137.00 Y-35A 7"csg 5 10973.71 46.92 152.23 8861.47 -4174.64 3044.62 0.00 0.00 5147.94 6 11125.27 65.86 152.90 8944.98 -4286.19 3102.44 12.50 1.89 5273.31 7 11131.37 65.86 152.90 8947.48 -4291.15 3104.98 0.00 0.00 5278.87 8 11332.21 90.00 160.00 8989.22 -4469.96 3182.31 12.50 16.94 5471.88 Y-35A Tl 9 11486.91 94.53 168.11 8983.10 -4618.42 3224.74 6.00 60.69 5620.86 10 11862.00 94.53 168.11 8953.49 -4984.32 3301.77 0.00 0.00 5973.76 II 12000.64 89.00 168.55 8949.22 -5I19.97 3329.79 4.00 175.45 6104.32 Y-35A T2a 12 12138.44 83.49 168.55 8958.24 -5254.69 3357.08 4.00 -179.95 6233.71 13 12587.91 83.49 168.55 9009.22 -5692.36 3445.77 0.00 0.00 6654.05 Y-35A T3a Ö COMPANY DETAILS REFERENCE INFORMATION BP Amoco Co-oodinate (N'E) Reference: Well Centre: Y -35. True Nooh Vertical (I'.'D) Reference: 7922' 7922 Cak:ulatiOll Method: Minimun Curvature Secûoo (VS) Reference: Slot· 35 (O.ooN,O.OOE) , . Enor Syst<m: ISCWSA MeaSUIed Depth Refeœnœ: 79.2I 7922 Scan Melhod: Tray Cylinlor North C~u1ation MeIbod: Minimum CUrvaIure Errol Surface: Elliptical· Casing Wamin¡¡ Method: Rul<s Based CASING DETAILS All TVD depths are No. TVD MD Name Size ssTVD plus 79.22'for RKBE. I 8854.22 10963.10 1/2' 5.500 2 9009.22 12587.90 II2' 3.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 5859.22 6584.43 B. WSakff.Seabee 2 7489.22 8964.57 THRZ 3 7669.22 9228. II LCU 4 7959.22 9652.71 Kingak 5 8854.22 10963.10 TSag 6 8874.22 10992.82 Shublik 7 8949.22 11135.68 Ivishak ~. Start Dir 12.5/100': 10973.71' MD, 886L47'TVD End Dir : 11125.2T MD, 8944.98' TVD / Start Dir 12.5/100' : II 13L37' MD, 8947.48'TVD / Start Dir 6{loo': 11332.21' MD, 8989.22'TVD ~ EndDir : 11486.9I'MD,8983J'TVD o / 0 00 /1 I ~ - .. ..., '" .. ' '" ,':?f '" .,' 7- " 12587.91' MD, 9009.22' TVD A _ Y-35A wp03 ~ Total Depth 3 112" ..I I ~ \ \ \ "mDir Start Dir 4/100' : '''-. " "- '-- '. re I~œ~. 1£U ' 1'0;. ....." i";;~t I®}-Q.._,,,,-__ '~, f2" ~~~ Iv sha( ...._'" 1 Start Dir 12/100': 6700' MD, 593954'fVD Start Dir 3/100': 6720' MD, 5953.38TVD 5600- 7145.62' MD, 6246.8T TVD End Di 6400 :5 7200 <ï: o ~ ..c: P.. Ö ~ '1:: -> ~ 8000 8800 I 8000 : 12138.44' MD, 8958.24' TVD 11862' MD, 8953.49'TVD I 7200 6400 5600 Y-35 Y-:5 I 4000 4800 Vertical Section at 148.81 0 [800ft/in] I 3200 I 2400 ----îli-l-tH--!! 1600 9600 Plan: Y-3SA wp03 (Y-3SlPlan Y-3SA) Tool Created By: Ken Allen Date: 9/26/2002 MWD Checked: Date: Re,iewed: Date: WFlL DETAILS NaJn¡, .w-s ~EJ-W Nonhing Easting Latitude Longitude Slot Y·35 528.99 -2343.78 594902433 64539510 7(),16'05.24ON 148"49'27214W 35 TARGET DETAILS Nmœ TVD +N'-S +EJ-W Nonhing Easting Shapo ¥-35A C$8 885122 4164.95 3039.51 5944919.1: 64851435 Point Y-35A T2a 894922 -5119.97 3329.79 5943970.0 648823.01 Point Y-35A Poly 891922 451632 294135 5944566.0 648423.00 Polygon Y-35A Flt#2 897922 4262.43 2433.12 5944810.0 647910.00 Polygon Y-35A Flt#1 891922 -5100.97 2604.97 5943975.0 64S098.0I Polygon Y-35A II 898922 -4469.96 318231 5944617.0 648663,00 Point Y·35A 13a 900922 ·569236 3445.77 5943400.0 648950.01 Point SURVEY PROGRAM Deptl1 Fm Deptl1 To SU,,",'yiPlan 6700.00 12587.91 PIarnrl Y-35A "]'03 V9 REFERENCE INFORMATION Co-ordinate (N/E) Reference: WeU Centre: Y-35. Trœ North Vertical (IVD) ReRrence: 79.22" 7922 Section (VS) Referenœ: Slot· 35 (O.ooN,O.OOE¡ Measured Depth Reference: 7922' 7922 Cakulatioo MeUKxI: Minimum CUrvature COMPANY DETAU.S BP Amo<o Calculation Method: Minimum C""..ture Em>< Sy"Sl<m: ISCWSA Scan Method: T BV Cyl_, NOI1h FlTor Surface: EIIipôca1" Casing Warnir;t MeIhod: Rules BasOO bp o ~ Target Y-35A 7"esg Y-35A Tl Y-35A T2a Y-35A T3a '~- c::> ""'iq, , " ., ,~';;::'" " ,,' FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 12/10)': '700' MD, 5939.54'TVD )ir 3/· 00' : 6720' MD, 5953.38'TVD 1 5859.22 6584.43 B.WSakIT.Seabee -"._--- 2 7489.22 8964.57 THRZ 3- 7669.22 9228.11 LCU End Dir :"7145.6~' MD, 6246.87' TVD 4 7959.22 9652.71 Kingak ~ 5 8854.22 10963.10 TSag 6 8874.22 10992.82 Shublik " 7 8949.22 11135.68 Ivishak ~ CASING DETAILS ""-, No. TVD MD Name Size __u_~ "- I 8854.22 10963.10 51/2" 5.500 \ ",,- 2 9009.22 12587.90 3 1/2" 3.500 ."",- , -.""\ All TVD depths are " \ ssTVD plus 79. 22'for RKBE. ... '\ \ \ \ \ '\ \ \ -- Síart D¡r _2.5/1()()': 10973.71' MD, 8861.47'TVD 2nd di.r ý1:dH'~šF' 8944.98' TVD Start rtr 1!.5/1oo' : 11131.37' MD, 8947.48'TVD Start \)ir 6/100' : 11332.21' MD, 8989.22'TVD Y-35..\ T ""ncl f)ir . 141\6.91' MD, 8983.1' TVD S'an Jlr ~/ll'" : 11862' MD, 8953.49'TVD - ---- --- / Y-:5AFltIl-3 2138.44' MD, 8958.24' TVD Depth: 12587.91' MD, 9009.22' TVD 5A 13a I I 2100 2800 3500 4200 4900 West( - )Æast(+) [700ft/in] VSee 2037.21 2051.10 2356.79 5137.00 5147.94 5273.31 5278.87 5471.88 5620.86 5973.76 6104.32 6233.71 6654.05 TFaee 0.00 85.00 93.46 0.00 0.00 1.89 0.00 16.94 60.69 0.00 175.45 -179.95 0.00 DLeg 0.00 12.00 3.00 0.00 0.00 12.50 0.00 12.50 6.00 0.00 4.00 4.00 0.00 SECTION DETAILS +Fl-W 1548.3 7 1558.93 1741.65 3039.51 3044.62 3102.44 3104.98 3182.31 3224.74 3301.77 3329.79 3357.08 3445.77 +N/-S -1444.10 -1453.94 -1700.68 -4164.95 -4174.64 -4286.19 -4291.15 -4469.96 -4618.42 -4984.32 -5 II 9.97 -5254.69 -5692.36 TVD 5939.54 5953.38 6246.87 8851.22 8861.47 8944.98 8947.48 8989.22 8983.10 8953.49 8949.22 8958.24 9009.22 Azi 131.34 134.65 152.23 152.23 152.23 152.90 152.90 160.00 168.11 168.11 168.55 168.55 168.55 Ine 46.08 46.34 46.92 46.92 46.92 65.86 65.86 90.00 94.53 94.53 89.00 83.49 83.49 MD 6700.00 6720.00 7145.62 10958.71 10973.71 11125.27 11131.37 11332.21 11486.91 11862.00 12000.64 12138.44 12587.91 See 1 2 3 4 5 6 7 8 9 10 II 12 13 -1400 -2100 -2800 1400 -3500 -4200 -4900 -5600 'C ~ o Ë +" J?: t: o ~ J?: :; o VJ ') ) BP KW A Planning Report MAP "·;.,ç~rii~·~~y:':,·',··:ßé"ßrnci9Q';".."'I'.'·'" ,i,' J¡;iehl:',.·, " . ,.:, '.:; , ,ptl!dnå~.,;~~~'. ", ., "",',"',',:.' 'Si~:)·':',;,...·, ,', )"Ifi!,B:XAad·,"':.:·,;':: ;".,.We~(:'..'. .""...,'.. '.1' 'Y: ,,;35.:':.',,""" :..,,',','..'..,", ,;",' ..,'.'." " ,',' . ."., '," ,W~~J~atb:",':J;II'~nY~~5Å;,':' "','/'!'.,:'., , ,.,',',',,',/ 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 . .:,:,.; -'1:.'1 .'"" 1","1 ,';,·;:'t,''-,', \:',i 1",',,::-,.,",:,,1. ';, ,I'·:"¡.";' ".'1,:, II 11::',;:1"'" ::::/;1::',:,".: )"'.,'"':,.',::,1,..:',,,,,,:,';,,:, '.;',' " I .I" I ,I I, II, "I L \';"'::'/!II':'I\~':'I : '1:',:";'1:: .",,,:"",;""",.";,:"",,',.".,:i::;>, ':1.1 ",,1,,1 ' I I' I; I ~'; I ' " I I ,I ':, I I ". 'I,' .., : 'I ; i: I': ,:1 : :; ':;:' i :.' ':' ,:'.' " ":,, I,: /'" I :;:;':,;':,'<':")".,:::;:,'::11",'"::;",,, I'~:I:/"'¡~"":""I:I/~":,' ",'," I~" ':.: ~,',' ,:II:'i,..:~'<I~:'I:':""~I"I":'I"I' 'I, ,:;,',': "I':' ""'.:: ~I '.:> I,;", '': I"",.,',':r :" :i,,',.;:' 'I.:../,':I.;!, :'~ ~ I': .:.... ", :'. ", ','" 1'1 ,." ,II ';..,:,,' ,;,:"",,'.:,:~t~t,~~ø~~'~~,~;i~;~~~~:;',¿,~~·~~á~'~'~+igŠ*r~~,.·~Ä~~'·".""'; '" '~~g~~,:",:.,:"" ','...,::,'~,:'".,:.,'....":.'.,:.'. ""·;'ii:'.,~.~m:i~~I'.Ø;¥J»i.~(~~~~'··"';.'!""",~,ø;œ~'~'¡:l$:'2'.'·':'",i'·.':ii!,,·:'.,"; "" .....··"·"1 ., "',', ,..,'", ",""1, , "S"':'··.,WS)'lb,·,t¡·"..· """"."""""", ;"'r'··W" II '('h'OI"iJ\tI'"OQJI: 1'488' '1'A:z""'~" I;,,';" , " , "",'" ",~~~?q.~',~;..;,;,I':',!~~~~,:,i';;·.>'/,;",','\ ,.,.;~.,. ì"j,.,~":i"'",,',,f'¡ ,.,.,.,.',:"", ',.,,'.," .,1", ,.,,' ;:,:' ',' ",~~rr:v..,~.'~~I~µþ:.i9nM~tlj~~;':': ,..,,;~'~lmW'l,ç!Jry~~Ure\,·,'.:',.:; ,·,.,",··.:';~þ:..'q~~þ~e Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Y-35 Y-35 Well Position: Well: 5948541.48 ft 647748.73 ft +N/-S 528.99 ft +E/-W~2343.78 ft Position Uncertainty: 0.00 ft Northing: Easting : 5949024.33 ft 645395.20 ft Well path: Plan Y -35A Current Datum: Magnetic Data: Field Strength: Vertical Section: 79.22' 8/2/2002 57524 nT Depth From (TVD) ft 0.00 Height 79.22 ft +N/-S ft 0.00 Principal: Yes Plan: Y -35A wp03 Casing Points 1\ID , ft 10963.10 12587.90 Formations TYD ft' 8854.22 9009.22 Map Zone: Coordinate System: Geomagnetic Model: Latitude: Longitude: North Reference: Grid Convergence: Slot Name: Latitude: Longitude: Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Date Composed: Version: Tied-to: Alaska, Zone 4 Well Centre BGGM2002 70 16 0.041 N 148 48 18.991 W True 1.12 deg 35 70 16 5.240 N 148 49 27.214 W Y-35 6700.00 ft Mean Sea Level 26.07 deg 80.78 deg Direction deg 148.81 9/24/2002 9 From: Definitive Path 51/2" 3 1/2" ·.'Dia~eter ., ·'·,HoleSiZ~' . .;in . in . 5.500 6.750 3.500 4.750 6584.43 8964.57 9228.11 9652.71 10963.10 10992.82 11135.68 Targets B.WSakIT.Seabee 0.00 0.00 THRZ 0.00 0.00 LCU 0.00 0.00 Kingak 0.00 0.00 TSag 0.00 0.00 Shublik 0.00 0.00 Ivishak 0.00 0.00 Map Map <- Latitude --> <- Longitude -> Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min Sec Dip. Dir. ft ft ft ft ft 8851.22 -4164.95 3039.51 5944919.18 648514.35 70 15 24.272 N 148 47 58.789 W 8949.22 -5119.97 3329.79 5943970.01 648823.01 70 15 14.878 N 148 47 50.356 W 8979.22 -4516.32 2941.35 5944566.01 648423.00 70 15 20.817 N 148 48 1.649 W 8979.22 -4816.84 3067.58 5944268.01 648555.01 70 15 17.861 N 148 47 57.980 W 8979.22 -5752.41 3136.53 5943334.01 648642.01 70 15 8.659 N 148 47 55.986 W 8979.22 -5778.02 3685.18 5943319.01 649191.01 70 15 8.405 N 148 47 40.028 W 8979.22 -4932.51 3411.44 5944159.01 648901.01 70 15 16.721 N 148 47 47.979 W 5859.22 7489.22 7669.22 7959.22 8854.22 8874.22 8949.22 Name Y -35A csg Y -35A T2a Y -35A Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 ') BP KW A Planning Report MAP ) I', .:,,':',', .:.,' ", ," I"" ",,',:,' ,1",: ': I ,:':' ,I . I " 'I ',I I ,,1"1 ·,ç~~p;\PY=',,'·'f3~:' A~9cO .." ..'.' "',, "., ',.,','::,,',:,:' ",,'" 'I"'i 1}1'.~~d,~:::",..,pr~~~Q~::,~~x.:, " ", ',. 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' " , , "', ,,' I" ,',,", v:~rtlc.I"Oì¥») ø:ef~reÎ1~~I"1 "'7:922"79·'21 ,'" ,,' I"" ' ',<', ""',~ ",' " 'i' 'I I I 'S~,titn I (VS) ,R(lfeié,~:, I" "I ,'~:~~I:'~'P';p~NI;p,#qE~14~,~l~i): ,',' .',": "i'. .' ,",." ,I, ""i I' Survef Ci"eµla~on Me~9d: 't1I1ll")i~µm:Cul'Mªtur;~"",":' ",',.",,'~b:.', :Pr~ç'~',I: I':'" .. "::'1,:..,1: :.i:,::.::\,· : ,1\1',,11:; I\";"I'I" I.' .,;., ::'",':',.,:',':"',,,'-,': I 'i\J#pi ':",'.:M~~I""','; ;' ",~*,;~~#~~ctê,~';.~',',','~~",'~~~.~ijI~e·7~~" ;'" "',' I '", ",', , ,',1 ":"".1"," ,', "",'TVÐ':·:.'.·", ',tNh$,'·· I ,tij(.,w,·,".."" ,~òì:tb~Q~ 'I."t.$~..~i",'. ;1":.' ~~g:"',Mli~:i':~,*,' ., ',,',;:','. .~e~"ì\1'nl".,,~e~',".: ,',.:.., I.Jt· ·I.,ft .1'.:' 1"1 I .,':~,;:'I'.<:I:..\'::I::,'I:, ..,..:',..,.,,~,!':.'....',."., :/'iff".:,': :':':':;"1',1 ,';':,."':>;:'~,, 1::,,','::'.1':: I!"';,:: 1<"1: ,',: ':',',.:"',' :"," ,,, , , " ", 'I, I I,':" ,i (,,1, 'I ' " I 1,·,0'/.':',', 'I"", I'" ':, ','.r' 'I', "., 1"11"1'1,'111 ..1 "",' 'I' I·. : I -Polygon 5 8979.22 -4514.74 3325.48 5944575.01 648807.00 70 15 20.831 N 148 47 50.474 W -Polygon 6 8979.22 -3354.49 3017.81 5945729.01 648477.01 70 15 32.243 N 148 47 59.411 W -Polygon 7 8979.22 -3573.83 2566.45 5945501.01 648030.00 70 15 30.087 N 148 48 12.545 W Y -35A Flt#2 8979.22 -4262.43 2433.12 5944810.01 647910.00 70 15 23.315 N 148 48 16.431 W -Polygon 1 8979.22 -4262.43 2433.12 5944810.01 647910.00 70 15 23.315 N 148 48 16.431 W -Polygon 2 8979.22 -4449.21 2833.62 5944631.01 648314.01 70 15 21.477 N 148 48 4.782 W -Polygon 3 8979.22 -4685.46 3257.17 5944403.00 648742.01 70 15 19.152 N 148 47 52.464 W -Polygon 4 8979.22 -4794.15 3447.12 5944298.01 648934.01 70 15 18.082 N 148 47 46.939 W -Polygon 5 8979.22 -4685.46 3257.17 5944403.00 648742.01 70 15 19.152 N 148 47 52.464 W -Polygon 6 8979.22 -4449.21 2833.62 5944631.01 648314.01 70 15 21.477 N 148 48 4.782 W Y -35A Flt#3 8979.22 -5100.97 2604.97 5943975.01 648098.01 70 15 15.068 N 148 48 11.440 W -Polygon 1 8979.22 -5100.97 2604.97 5943975.01 648098. 01 70 15 15.068 N 148 48 11.440 W -Polygon 2 8979.22 -5082.82 3063.44 5944002.01 648556.01 70 15 15.245 N 148 47 58.104 W -Polygon 3 8979.22 -4857.57 3260.84 5944231.01 648749.00 70 15 17.459 N 148 47 52.359 W -Polygon 4 8979.22 -4812.85 3482.77 5944280.01 648970.01 70 15 17 .898 N 148 47 45.903 W -Polygon 5 8979.22 -4857.57 3260.84 5944231.01 648749.00 70 15 17.459 N 148 47 52.359 W -Polygon 6 8979.22 -5082.82 3063.44 5944002.01 648556.01 70 15 15.245 N 148 47 58.104 W Y-35A T1 8989.22 -4469.96 3182.31 5944617.01 648663.00 70 15 21.272 N 148 47 54.639 W Y -35A T3a 9009.22 -5692.36 3445.77 5943400.01 648950.01 70 15 9.248 N 148 47 46.991 W Plan Section Information 'loci: Allin','" TVn.",.,' ",,~N/:.S '+E1~:w ' I,. ',I " "'." ,', '., ", ,'," ~årge.' · '. . MD,' I .. ;1' .",',I)LS, '""~~ild','.'ITµr~"i,, .'1'FQ; ft;, ~ê9, 'deg" ft ft' ",.·,i '.. ','ft! ' :~~~~1PQft~eq~1POft.~~Ql1..00ft: :.".,deg, '. , I· 0';" 6700.00 46.08 . 131.34 5939;54 -1444.10 1548.37 0.00 0.00 0.00 0.00 6720.00 46.,34 134.65 5953.38 -1453.94 1558.93 12.00 1.28 16.53 85.00 7145.62 46.,92 152.23 6246.87 -1700.68 1741.65 3.00 0.14 4.13 93.46 10958.71 46;92 152.23 8851.22 -4164.95 3039.51 0.00 0.00 0.00 0.00 Y -35A csg 10973.71 46.92 152.23 8861.47 -4174.64 3044.62 0.00 0.00 0.00 0.00 11125.27 65.86 152.90 8944.98 -4286.19 3102.44 12.50 12.49 0.44 1.89 11131.37 65.86 152.90 8947.48 -4291.15 3104.98 0.00 0.00 0.00 0.00 11332.21 90.00 160.00 8989.22 -4469.96 3182.31 12.50 12.02 3.54 16.94 Y-35A T1 11486.91 94.53 168.11 8983.10 -4618.42 3224.74 6.00 2.93 5.24 60.69 11862.00 94.53 168.11 8953.49 -4984.32 3301.77 0.00 0.00 0.00 0.00 12000.64 89.00 168.55 8949.22 -5119.97 3329.79 4.00 -3.99 0.32 175.45 Y -35A T2a 12138.44 83.49 168.55 8958.24 -5254.69 3357.08 4.00 -4.00 0.00 -179.95 12587.91 83.49 168.55 9009.22 -5692.36 3445.77 0.00 0.00 0.00 0.00 Y -35A T3a Survey MD Incl Azlm TVD . SY$TVD MapN Map£ VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/10Oft 6584.43 45.92 131.84 5859.22 5780.00 5947664.39 646907.81 1957.87 0.00 B.WSakIT.Seabee 6700.00 46.08 131.34 5939.54 5860.32 5947610.51 646971.06 2037.21 0.34 Start Dir 12/100' : 6700' MD, 6720.00 46.34 134.65 5953.38 5874.16 5947600.88 646981.80 2051.10 12.00 Start Dir 3/100' : 6720' MD. 5 6800.00 46.24 137.96 6008.67 5929.45 5947559.86 647022.54 2107.53 3.00 MWD 6900.00 46.25 142.12 6077.85 5998.63 5947505.43 647069.97 2178.89 3.00 MWD 7000.00 46.42 146.26 6146.90 6067.68 5947447.62 647113.39 2250.97 3.00 MWD 7100.00 46.73 150.37 6215.66 6136.44 5947386.60 647152.70 2323.56 3.00 MWD 7145.62 46.92 152.23 6246.87 6167.65 5947357.73 647169.24 2356.79 3.00 End Dir : 7145.62' MD, 6246.8 7200.00 46.92 152.23 6284.02 6204.80 5947322.96 647188.42 2396.44 0.00 MWD 7300.00 46.92 152.23 6352.32 6273.10 5947259.00 647223.70 2469.36 0.00 MWD 7400.00 46.92 152.23 6420.62 6341.40 5947195.05 647258.98 2542.27 0.00 MWD 7500.00 46.92 152.23 6488.92 6409.70 5947131.10 647294.25 2615.18 0.00 MWD 7600.00 46.92 152.23 6557.22 6478.00 5947067.15 647329.53 2688.09 0.00 MWD 7700.00 46.92 152.23 6625.52 6546.30 5947003.19 647364.81 2761.01 0.00 MWD ,'.,e~~·ø~ny.:·.·. .,ß,P"'A~~ç~: ,.' ~~~'~:",' .",,:pr4~~qe'3ay Site~" "". 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Survey .iijpl", "',fF,' 7800.00 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 8964.57 9000.00 9100.00 9200.00 9228.11 9300.00 9400.00 9500.00 9600.00 9652.71 9700.00 9800.00 9900.00 10000.00 10100.00 10200.00 10300.00 10400.00 10500.00 10600.00 10700.00 10800.00 10900.00 10958.71 10963.10 10973.71 10975.00 1 0992.82 11000.00 11025.00 11050.00 11075.00 11100.00 11125.27 11131.37 11135.68 11150.00 11175.00 11200.00 11225.00 ·',I~d. . .'·&im' i', .idea' " ',deSi 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 1,52.23 46;92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46;9,2 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 46.92 152.23 47.08 152.23 49.31 152.33 50.21 152.37 53.33 152.49 56.45 152.60 59.58 152.71 62.70 152.81 65.86 152.90 65.86 152.90 66.37 153.07 68.09 153.63 71.08 154.58 74.08 155.49 77.09 156.38 I. I, I; ,', ,'. ï!: . ,1', :";-', ,;',:-':,',,;'.',>",',: I I" ':", ,"'1'1 1,:,,1, I ) BP KW A Planning Report MAP i,"1 I·i\,¡:'. .:", 1"1)'.: ,I,,: :': I",:" I', ,',:¡ :':) I, ',,), '",' '" ""1:'1 "I ,1.1.' ," ", I ,1,' :J1~:',. .,,~ys1'yP~'. ,'.Iff ,:.,.',"',·,..."..,ff:'i ,'.".".'. ' 6693.82 6614.60 6762.12 6830.42 6898;72 6967;02 7035.32 7103.62 7171.92 7240.22 .7308.'52 7376.82 7445.12 7489.22 7513.42 7581.72 7650.02 7669.22 7718.32 7786.62 7854.92 7923.22 7959.22 7991.52 8059.82 8128.12 8196.42' 8264.72 8333.02 8401.32 8469.62 8537.92 8606.22 8674.52 8742.82 8811.12 8851.22 8854.22 8861.47 8862.34 8874.22 8878.86 8894.33 8908.71 8921.95 8934.01 8944.98 8947.48 8949.22 8954.76 8963.48 8970.97 8977.19 ) ':;,'" "1:, '.',<,1'..;, ,.'",¡ ',"..,',., ."""'". .' I "i·IJ>~~:,I:,'~12Ø/~ºØ2",":,,':'.:...·,.:,.\:'~lrne:i.1,'Prl:~â1Ô~"il~:'I,:., ,." .'il,:'~W3e:'·., ':'~'., "',. I, ,"I'.ço~~~'~"te(N:E}:ÄtÇf~r~,,~ç:':''',''W~I',:·.~r~e;~:rrµ~~prtJl· 'I , ii"::"·' , "..,',I:ye~~~l(11~:Q~'~efere~~':'·"~,'ìiØ;~~;I:'7f):2'1. ,.,.,1','., ""',',.',, ",".. ',,"',.,,'.' ".' , . '" .S~~~n¡:'~S)·~e~e"~~~'.,: .".wêll,(O';PQ~~9;'o.QE~:148::81Azi), '.',, '.' .' " ·$~J:v~y:C~~çûl~~'n¥~tbød::',:·.. .iM~'pi.p~m, C'ur¥ªt~~~. .,... '.',.',,~'t)þ.:'Or~~I~1 ',",1 1,:,1 :'111;" ,I 6682.90 6751.20 6819.50 6887.80 6956.10 7024.40 7092.70 7161.00 7229.30 7297.60 7365.90 7410.00 7434.20 7502.50 7570.80 7590.00 7639.10 7707.40 7775.70 7844.00 7880.00 7912.30 7980.60 8048.90 8117.20 8185.50 8253.80 8322.10 8390.40 8458.70 8527.00 8595.30 8663.60 8731.90 8772.00 8775.00 8782.25 8783.12 8795.00 8799.64 8815.11 8829.49 8842.73 8854.79 8865.76 8868.26 8870.00 8875.54 8884.26 8891.75 8897.97 ,'.-':.' I I,,': ~ ""'1, MapN I , "·."'~àpE" ~' '..I.·..~li':' 5946939.24 647400.08 I".','·.":'".."A,.',.S,..,,·,".:.','..,.',','. ".,,'. .:,,',, "~tSi;J:,~i' "" '", . "" "'..\ '~~~ltqQft'::',,'·":1 .'. 2833.92 0.00 MWD ',,'.',',' ,'toøI/CQ~...èpt:. ..: . 1,,:,,'" "1 I,',.., 1,1, 5946875.29 5946811.34 5946747.39 5946683.43 5946619.48 5946555.53 5946491.58 5946427.63 5946363.67 5946299.72 5946235.77 5946194.48 5946171.82 5946107.86 5946043.91 5946025.93 5945979.96 5945916.01 5945852.06 5945788.10 5945754.39 5945724.15 5945660.20 5945596.25 5945532.29 5945468.34 5945404.39 5945340.44 5945276.49 5945212.53 5945148.58 5945084.63 5945020.68 5944956.73 5944919.18 5944916.37 5944909.59 5944908.76 5944897.13 5944892.32 5944875.09 5944857.14 5944838.50 5944819.23 5944799.18 5944 794.27 5944790.80 5944779.12 5944758.25 5944736.82 5944714.91 647435.36 647470.63 647505.91 647541.19 647576.46 647611.74 647647.01 647682.29 647717.57 647752.84 647788.12 647810.90 647823.40 647858.67 647893.95 647903.86 647929.22 647964.50 647999.78 648035.05 648053.65 648070.33 648105.61 648140.88 648176.16 648211.43 648246.71 648281.99 648317 .26 648352.54 648387.81 648423.09 648458.37 648493.64 648514.35 648515.90 648519.65 648520.10 648526.50 648529.14 648538.56 648548.34 648558.44 648568.83 648579.61 648582.24 648584.10 648590.24 648600.88 648611.36 648621.66 2906.83 2979.74 3052.65 3125.57 3198.48 3271.39 3344.30 3417.21 3490.13 3563.04 3635.95 3683.03 3708.86 3781.78 3854.69 3875.19 3927.60 4000.51 4073.42 4146.34 4184.77 4219.25 4292.16 4365.07 4437.99 4510.90 4583.81 4656.72 4729.63 4802.55 4875.46 4948.37 5021.28 5094.20 5137.00 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 THRZ 0.00 MWD 0.00 MWD 0.00 MWD 0.00 Leu 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 Kingak 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 Y-35A csg 5140.21 0.00 5 1/2" 5147.94 0.00 Start Dir 12.5/100' : 10973.71 5148.88 12.50 MWD 5162.14 12.50 Shublik 5167.61 12.50 MWD 5187.21 12.50 MWD 5207.61 12.50 MWD 5228.77 12.50 MWD 5250.61 12.50 MWD 5273.31 12.49 End Dir : 11125.27' MO, 8944. 5278.87 0.00 Start Dir 12.5/100': 11131.37 5282.79 12.50 Ivishak 5295.96 12.50 MWD 5319.28 12.50 MWD 5342.99 12.50 MWD 5367.02 12.50 MWD , .'....'ç~,~~,~~'~'"',,::.,Bè,,.,Arnqc9,' 1f~~~d;,1 I', ,.. 'i " "Rfl~dI"lQ~ ,1j;3f,i1yi,..','" Si~e:":I"':' '.~B"v:,pad' "'" ,'w~~l;¡i,:",', ,'," y~35:,,::,,",··.," W~llp,ath: ' ,PI'a~X,.35ÄI, ',.,' ' Survey 11234.51 11250.00 11275.00 11300.00 11325.00 11332.21 11350.00 11400.00 11450.00 11486.91 11500.00 11600.00 11700.00 11800.00 11862.00 11900.00 12000.64 12100.00 12138.44 12200.00 12300.00 12400.00 12500.00 12587.90 12587.89 12587.91 'I~cl'". :~~g", 78.23 8.0.10 83.11 86.12 ......,',:,',.,',.,,',,',,',",,'"""I ~Im."',,, "d~9""" 156.71 157.24 158.09 158.93 89.13 159.76 90.00 160.00 90.52 160.93 9,1.99 163.,55 93.45 166.17 94.53 168.11 94.53 168.11 94.53 168.11 94.53 168.11 94.53 168.11 94.53 168.11 93.01 168.23 89.00 168.55 85.03 168.55 83.49 168.55 83.49 168.55 83.49 168.55 83.49 168.55 83.49 168.55 83.49 168.55 83.49 168.55 83.49 168.55 ) BP KW A Planning Report MAP ) 111>"\ """ ""'" ',:,:'", ',i,:"", "':",1 ,"""" ",,":,,1'..:"""': '::~~~::,,.I'~~?~/~()~?,','(':;}.. ,.,1~me; , '97:33;.07 "I'P~g~('I: "4 ",":", ".:':~:~~~\frjf~hij:;r~£Š;':I'",'.".,.~~~,k~7~~2GiŠ,,~o~h' ,,' '.'..'.':'..'.,",',, ,'.',.,,' ,"..".:,:'.., '""",',',:':"::' '":S~O#,II(~S~'~~~~,n,~~¡:.,,.,. '!,,::",,::.,:':' ,",.'.VV;~~I..(~';ge~:;9~~qE!:1~~:.a",,¥i)' '~ijry~yC~I~,.Iå~I~..M~tþp"';,¡ ,M'nlrn~1"11.9!.1~atun~.,I.,., ","".,g~,:,:,QfåélØ',,', ' I ',::';"'õ','-", ,I i :",1 "I" , ",:;,.,.' ,T~lIl "",:«' 8979.22 6982.13 8985:78 8988.13 8989..17 8989.22 8989.14 8988.04 8985.67 8983. ~ 0 8982.07 8974.17 8966.28 8958.38 8953.49 8950.99 8949.22 8954.40 8958.24 8965.23 8976.57 8987.91 8999.25 9009.22 9009.22 9009.22 1:.1"'1' ": :,\ '':';:,"" ," "Sy~t~:,;,' , ,ft""" 8900.00 8902.91 8906.56 8908.91 8909.95 8910.00 8909.92 8908.82 8906.45 8903.88 8902.85 8894.95 8887.06 8879.16 8874.27 8871.77 8870.00 8875.18 8879.02 8886.01 8897.35 8908.69 8920.03 8930.00 8930.00 8930.00 ':,:";.1""1',,,, ,,' ··'"M.~N'", , ",,' ",',f;"" " ,," 5944706.47 5944692.58 5944669.90 5944646.92 5944623.73 5944617.01 5944600.36 5944553.07 5944505.13 5944469.40 5944456.69 5944359.56 5944262.43 5944165.31 5944105.09 5944068.14 5943970.01 5943873.18 5943835.85 5943776.16 5943679.19 5943582.22 5943485.25 5943400.02 5943400.03 5943400.01 "I', Y$",', ,""Ð~~"', ""',1' '" ",',',',',.'" ",iOf)I(;~J;ß:~~nt'" ,", ,.", '"ft, ',I"ldØgt10Qf; ,:" ", ,"', ¡ ','1,,:, I,., I',,' :: ',': 648625.52 5376.22 12.50 Y-35A FIt#3 648631.74 5391.28 12.50 MWD 648641.57 5415.71 12.50 MWD 648651.14 5440.25 12.50 MWD 648660.40 648663.00 648669.28 648685.44 648699.41 648708.29 648711.23 648733.65 648756.06 648778.48 648792.38 648800.86 648823.01 648844.57 648852.89 648866.19 648887.80 648909.41 648931.01 648950.00 648950.00 648950.01 5464.80 12.50 MWD 5471.88 12.52 Y-35A T1 5489.30 6.00 MWD 5537.91 6.00 MWD 5585.91 6.00 MWD 5620.86 5633.17 5727.26 5821.35 5915.43 5973.76 6009.54 6104.32 6197.70 6233.71 6291.27 6384.79 6478.31 6571.83 6654.04 6654.03 6654.05 6.00 End Dir : 11486.91' MD, 8983. 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 Start Dir 4/100' : 11862' MD, 4.00 MWD 4.00 Y-35A T2a 4.00 MWD 4.00 End Dir : 12138.44' MD, 8958. 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 Y-35A T3a 0.00 Total Depth: 12587.91' MD, 90 0.00 MWD Y-35 Permit ) ) Subject: Y -35 Permit Date: Tue, 17 Dee 2002 14:31 :06 -0600 From: "Smith, Phil G (FAIR)" <SmithPG1@BP.eom> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Hubble, Terrie L" <HubbleTL@BP.eom> Winton, Today we are moving back to H-02A with Nabors 2ES. If it goes well there, we could be moving to Y-35A as soon as Dec 27th. With the holidays approaching we thought you might want to know. The sundry has been approved, only the permit is outstanding. Thanks, Phil 564-4897 p054962 DATE INVOICE I CREDIT MEMO 11/18/02 INV# CKl11402C THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ DATE 11/18/02 CHECK NO. P054962 GROSS VENDOR DISCOUNT NET TO THE ORDER OF . -- . - - . ALASKA OIL & GAS CÖNSERVAT~O~> COMMISSION 333 W. 7th A'i'E, STE. ANCHORAGE: tAK 99501 H RECEIVED ~~ 3~(} DEC 06 2(02 ~11aSKa Oil'& Gas Gons. OommissJmJ AnchoragQ ~~-"" 56-369 412 No. P 054962 NATIONAL CITY BANK Ashland, Ohio . ."- ------ .-, S..·.···· ..;.... p..... r:...... tr.... ..øm.. .1 JIIth.·.....·.·,.. ..,U.J.j.·..........,.:·..ø'.·.,.:.·.·"11 .f...:.t....'.,..~.' ... I 'tüaì: - - - -- }-., 1..,1.__- - :=-"Ji,.t: --d:~) ... ." ~..I.. Itllì #;¡ntf... .Hn..:~nn·T,.,·!' CONSOLIDATED COMMERCIAL ACCOUNT ." DATE <.., NOV~i 18) 2CtJ2 AMOUNT .::.., * ~ ** '* $.g;;pP . oþ* ~:* * * :;. ~~~r~~.:~~:~~:j/::~f.~~:i.:~~;~~:~:}~{g~~j .... :~1Æ~~::¡"""\".'"'''' ...... ..... k S?<~+{~:Jf:;ß~~;~:;~~;i::;,:jj"i ~ III 0 5 ~ t1 b 2111 .: 0 ~ . 20 j B 9 51: O. 2 ? a 9 b II· ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate 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. WELL PERMIT CHECKLIST COMPANY AI X WELL NAME f7IJCt y- 3.sA PROGRAM: Exp _ Dev _ Redrll L Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL ¡.::; '-;10/ S~ INIT CLASS (}e.v /-'1")/ / GEOL AREA ); J ô UNIT# /¡'~_ ç ~ ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . V': 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 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N L... l,.,.~ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N # ~ ~z. 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.. . . . . UI N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_ X~ N. A. (Service Well Only) 14. All wells w/in X mile area of review identified. . . . . . . . .. Y N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥--N- 16. Surface casing protects all known USDWs. . . . . . . . . . y.'-N- 'f 17. CMT vol adequate to circulate on conductor & surf csg. . . . '¥-N-IJ I A- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N J.J.. ~ +: 1 19. CMT will C,over all known ProductiV,e hor,iZ, ons.' . . .' . . . . . . ~.y" N ~, t¡P ILtd - (::=- y: CP(,~ 0 tL ,.\,-- ;h-tey/ffL.P ó . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N· . 21. Adequate tankage or reserve pit.. . . . .'. . . . . . . . . . . Y N Allt-bC? y,"-> Z£ç t 22. If a re-drill, has a 10-403 for abandonment been approved. . . '_ NiL I'~ { t9 '- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . , N 24. If diverter required, does it meet regulations. .. . . . . .. . ·~-#-Ai/Æ- 25. Drilling fluid program schematic & equip list adequate. . . . . ~ N ;114 fYlttJ II. "ç- f pCl . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 1A /' rJ APPR DATE 27. BOPE press rating appropriate; test to 7>S DO psig. ~ N 4v";;;, 'JP 7Ç- r f t ' '/ 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \JJ17A- , z- 11 O''"¿..· 29. Work will occur without operation shutdown. . . . . . . . . . .i I)L, ¡J' 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y .(hi! ~ [J P jOtY\... i'v'- t r-OL . 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N N/1ti- Y@ ~ Ai. 4. APPR DATE (Service Well Only) GEOLOGY APPR DATE ,,(fj~ IV~:z.. " (Exploratory 5nïy) i ~ 32. Permit can be issued w/o 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: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/lnstructions: RPC¡pt TEM JDH JBR COT /.:>je¡/ó:r- DTS I~) /fjþ ~ WGA /' MJW MLB /.t.//~¿ Rev: 10/15/02 SFD_ G:\geology\permits\checklist.doc ) ) Well History File APPENDIX Inforrnation of detailed nature that is not particularly gemlane to the Well Pennitling Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomìation. 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. '" I: ¡,' "I ) qCd-a3¡ / lip 93 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Apr 07 11:09:12 2003 Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 /04/07 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 Da t e. . . . . . . . . . . . . . . . . . . . . 03/04/07 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 Y-35A 500292218601 BP Exploration (Alaska) f Inc. Sperry Sun 07-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MW-22210 J. BOBBITT J. RALL MWDRUN 4 AK-MW-22210 J. BOBBITT J. RALL MWDRUN 5 AK-MW-22210 J. BOBBITT J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MW-22210 J. SACK R. BOARDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 34 iON 13E 1243 583 .00 78.60 ) N ) GROUND LEVEL: 50.72 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.630 6514.0 4.750 5.500 10922.0 # 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. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS AT ABOUT 6680'MD / 5926'TVD IN THE Y-35 WELLBORE. 4. MWD RUN 1 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. THESE DATA (SGRC) ARE INCLUDED WITH THE MWD RUN 3 DATA. 5. MWD RUN 2 DID NOT MAKE ANY FOOTAGE. NO DATA IS PRESENTED. 4. MWD RUNS 3 - 5 WERE DIRECTIONAL WITH DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). GAMMA RAY DATA (SGRC) FROM 6621.5' MD TO 6633.0' MD, (SENSOR DEPTHS) CAPTURED WHILE TRIPPING IN FOR MWD RUN 3 IS INCLUDED IN THE MERGED DATA. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 01/30/03. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1, 3 - 5 REPRESENT WELL Y-35A WITH API#: 50-029-22186-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12750'MD / 8996'TVD. SROP SGRC SEXP SESP SEMP SEDP SFXE SLIDE $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED GAMMA RAY COMBINED. SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SMOOTHED FORMATION EXPOSURE TIME. = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/07 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # # FILE SUMMARY PEU TOOL CODE GR ROP FET RPD RPM RPS RPX $ ) START DEPTH 6591.0 6708.5 10800.0 10800.0 10800.0 10800.0 10800.0 ) STOP DEPTH 12695.0 12749.5 12706.5 12706.5 12706.5 12706.5 12706.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PEU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 3 4 5 6 MERGED MAIN PASS. $ MERGE TOP 6591.0 7479.5 10787.0 11501.5 MERGE BASE 7552.5 10923.0 11557.0 12749.5 # 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 6591 12749.5 9670.25 12318 6591 12749.5 ROP MWD FT/H 0.14 466.22 99.0834 12083 6708.5 12749.5 GR MWD API 22.46 515.63 87.4963 12209 6591 12695 RPX MWD OHMM 0.33 2000 35.0632 3814 10800 12706.5 RPS MWD OHMM 0.15 2000 53.4178 3814 10800 12706.5 RPM MWD OHMM 0.15 2000 50.1808 3814 10800 12706.5 RPD MWD OHMM 0.06 2000 66.7276 3814 10800 12706.5 FET MWD HOUR 0.34 183.65 13.7144 3814 10800 12706.5 ') ;' ) First Reading For Entire File......... .6591 Last Reading For Entire File......... ..12749.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/07 Maximum Physical Record. .65535 File 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...... .03/04/07 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 6591.0 6708.5 STOP DEPTH 7478.5 7552.5 # 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: 02-JAN-03 Insite 4.3 Memory 7552.0 6691.0 7552.0 46.0 49.2 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 72829 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 6514.0 # ') j 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 Name Service Order DEPT ROP MWD030 GR MWD030 ) LSND 10.50 74.0 9.1 2800 5.0 .000 .000 .000 .000 .0 117.6 .0 .0 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6591 7552.5 7071.75 1924 6591 7552.5 ROP MWD030 FT/H 7.86 466.22 207.749 1689 6708.5 7552.5 GR MWD030 API 32.38 128.26 74.724 1776 6591 7478.5 First Reading For Entire File......... .6591 Last Reading For Entire File.......... .7552.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/07 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...... .03/04/07 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 GR ROP $ 3 ) header data for each bit run in separate files. 4 .5000 START DEPTH 7479.5 7553.0 STOP DEPTH 10849.5 10923.0 # 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 $ # 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: 06-JAN-03 Insite 4.3 Memory 10923.0 7552.0 10923.0 43.6 50.3 TOOL NUMBER 93091 6.750 6514.0 LSND 9.80 51.0 9.0 2700 4.8 .000 .000 .000 .000 .0 168.0 .0 .0 ) ) 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 DEPT ROP MWD040 GR MWD040 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7479.5 10923 9201.25 6888 7479.5 10923 ROP MWD040 FT/H 3.03 196.88 97.0116 6741 7553 10923 GR MWD040 API 22.71 308.64 99.2031 6741 7479.5 10849.5 First Reading For Entire File......... .7479.5 Last Reading For Entire File.......... .10923 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/07 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...... .03/04/07 Maximum Physical Record. .65535 File Type.. .. .. .. .. .. .. .. LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 ) RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ ) header data for each bit run in separate files. 5 .5000 START DEPTH 10787.0 10800.0 10800.0 10800.0 10800.0 10800.0 10923.5 STOP DEPTH 11507.5 11519.0 11519.0 11519.0 11519.0 11519.0 11557.0 # 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 VENDOR TOOL CODE GM EWR4 $ BOTTOM) 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: $ # 15-JAN-03 Insite 4.3 Memory 11558.0 10923.0 11558.0 49.0 95.7 TOOL NUMBER 72829 144955 4.750 10922.0 Flo-Pro 8.60 54.0 10.2 22000 6.4 .340 .270 .380 .440 67.0 187.3 67.0 67.0 ") ) 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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10787 11557 11172 1541 10787 11557 ROP MWD050 FT/H 0.7 133.94 31.1288 1268 10923.5 11557 GR MWD050 API 23.81 522.27 101.367 1442 10787 11507.5 RPX MWD050 OHMM 0.33 2000 70.5682 1439 10800 11519 RPS MWD050 OHMM 0.15 2000 119.521 1439 10800 11519 RPM MWD050 OHMM 0.15 2000 109.054 1439 10800 11519 RPD MWD050 OHMM 0.06 2000 136.029 1439 10800 11519 FET MWD050 HOUR 1.26 183.65 32.8612 1439 10800 11519 First Reading For Entire File......... .10787 Last Reading For Entire File......... ..11557 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/04/07 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...... .03/04/07 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 RPD RPM RPS RPX FET ROP $ 5 ') header data for each bit run in separate files. 6 .5000 START DEPTH 11501.5 11514.5 11514.5 11514.5 11514.5 11514.5 11557.5 STOP DEPTH 12695.0 12706.5 12706.5 12706.5 12706.5 12706.5 12749.5 # 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 VENDOR TOOL CODE GM EWR4 $ BOTTOM) 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: $ 18-JAN-03 Insite 4.3 Memory 12750.0 11558.0 12750.0 83.3 93.5 TOOL NUMBER 72829 144955 4.750 10922.0 Flo Pro 8.60 49.0 10.0 17500 6.0 .400 .150 .460 .580 72.0 203.0 72.0 72.0 ) ) # 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 11501.5 12749.5 12125.5 2497 11501.5 12749.5 ROP MWD060 FT/H 0.14 150.68 64.1134 2385 11557.5 12749.5 GR MWD060 API 20.84 173.1 56.2772 2388 11501.5 12695 RPX MWD060 OHMM 2.17 1871.15 13.5056 2385 11514.5 12706.5 RPS MWD060 OHMM 1.71 494.92 13.3225 2385 11514.5 12706.5 RPM MWD060 OHMM 1.91 953.53 14.4624 2385 11514.5 12706.5 RPD MWD060 OHMM 1.4 2000 24.6573 2385 11514.5 12706.5 FET MWD060 HOUR 0.34 29.64 2.22701 2385 11514.5 12706.5 First Reading For Entire File......... .11501.5 Last Reading For Entire File.......... .12749.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/07 Maximum Physical Record. .65535 File Type.. .. .. .. .. .. .. .. LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/04/07 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 Da t e. . . . . . . . . . . . . . . . . . . . . 03/04/07 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