The URL can be used to link to this page

Home My WebLink About205-128~ i Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ®~ - ~c~, (L Well History File Identifier Organizing (aone> RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other o,.a,~d iuuioiiuiuui DIGITAL DATA Diskettes, No. , ^ Other, No/Type: R~~a~~eeaea iiumiiaiuiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: D /s/ Project Proofing I II I II III III II I I II I BY: Maria Date: ~ ~ ~ /s/ Scanning Preparation ~ x 30 = ~_ + ~_ =TOTAL PAGES I I (Count does not i ~ dude cover sheet) BY: Maria Date: / °l ~ ~ ~ ~ ~/ V I Production Scanning Stage 7 Page Count from Scanned File: __~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~~ YES _ BY: Maria Date: ' a.. Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. -~P `fuiummduiu ReScanned BY: Maria Date: /s! Comments about this file: a~a~„~~e~k,a iiiuumuumu 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA* AND GAS CONSERVATION COMMIS. ` REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon fl Repair well f Plug Ferforations r Stimulate r Other 1;4- Jet Pump Straddle Alter Casing r Rill Tubing r Perf orate New Pool f Waiver r Time Extension j"°` Change Approved Program r Operat. Shutdown E Perforate j""' Re -enter Suspended Well '"° 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r' Exploratory r . 205 -128 3. Address: 6. API Number: Stratigraphic r Service r" P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 22975 - — 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028248 " 1 D - 34L1 - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 18350 feet Plugs (measured) None true vertical 6646 feet Junk (measured) None Effective Depth measured 18350 feet Packer (measured) 14938, 14952 true vertical 6646 feet (true vertucal) 6271, 6276 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20 117 117 SURFACE 9429 9.625 9463 4316 INTERMEDIATE 15130 7 15164 6348 PRODUCTION 723 3.5 15724 6532 L1 LINER 2602 2.375 18320 6642 RECEIVED' OCT 1 3 21111 Perforation depth: Measured depth: 15719'- 15941', 16067'- 16733', 16796'- 18286' True Vertical Depth: 6529'- 6575', 6573'- 6551', 6554' -6637' Alaska Gil &Gas Cons. Co ►nmisskn i e.crC rbrdo Tubing (size, grade, MD, and TVD) 3.5, L -80, 15059 MD, 6313 TVD Packers & SSSV (type, MD, and ND) NIPPLE - CAMCO 'DS' NIPPLE W /NO GO PROFILE @ 548 MD and 547 TVD PACKER - WEATHERFORD ER PACKER @ 14938 MD and 6271 TVD PACKER - WEATHERFORD ER PACKER @ 14952 MD and 6276 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable , . k i r ! `;'i! i4y Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation shut -in 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory I Development j; Service r Stratigraphic I 15. Well Status after work: Oil jar Gas r WDSPL r Daily Report of Well Operations XXX GSTOR WIND r WAG r GINJ r SUSP r SPLUG r 16. 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: none Contact John Peirce 265 -6471 Printed Name John Peirce Title Wells Engineer Signature ierta,`,Alriedim..-- Phone: 265 -6471 Date ./ o t iz i i Form 10-44 Revised 10/2010 /6 Submit Original Only RBDMS OCT 17 2011 y �� (6 ,i 1 D -34 Well Work DATE SUMMARY 7/16/11 MEASURED BHP @ 15690' SLM: APPSI. BRUSHED & FLUSHED TBG FRO 4920' TO 14980' RKB. TBG OPEN TO 2.76" TO 14995' RKB. IN PROGRESS. 7/17/11 RAN 304" DRIFT (2.74" TOP, 2 -3/8" SPACER PIPE, 2.74" BOTTOM) TO 14995' RKB. READY FOR E /L. 7/18/11 LOGGED 24 -ARM CALIPER FROM 15069' TO SURFACE TO DETERMINE OVERALL TUBING CONDITION. DATA SUBMITTED TO PDS FOR PROCESSING. 7/25/11 SET WEATHERFORD LOWER ER PACKER. MID - ELEMENT SET DEPTH 14955', CCL TO MID - ELEMENT 14.7', CCL STOP DEPTH 14940.3'. - 9/2/11 SET ER TESTTOOL IN ER PKR @ 14955' RKB.TESTED TBG.GOOD 9/3/11 REPLACED 1" GLV'S WITH 1" DV'S @ 12058' RKB 10325' RKB AND 7994' RKB.IN PROGRESS 9/4/11 REPLACED 1" GLV WITH 1" DV @ 3274' RKB.TESTED TBG.PULLED 3 1/2" ER TESTTOOL FROM ER PKR @ 14955' RKB.PULLED 1.5" DV FROM 14945' RKB.IN PROGRESS 9/5/11 SET 1.5" HFCV ON RK LATCH @ 14945' RKB.CONFIRMED SET WITH 1.72" LIB. 9/6/11 SET ER TEST TOOL IN PKR @ 14955' RKB. CIRCULATED 200 BBL INHIBITED 9.6 BRINE FOLLOWED BY 335 BBL DSL DOWN TBG, TAKING RETURNS OFF IA TO FLOWLINE. U- TUBED. IN PROGRESS. 9/7/11 ATTEMPTED CMIT, FAILED. PULLED ER TEST TOOL, TORN PKG. CREW CHANGE. RUN FRESH ER TEST TOOL. COMBO MIT T x IA TO 3500 PSI, PASSED. READY FOR UPPER PATCH ASS'Y. 9/10/11 SET 16.34' PATCH / JET PUMP ASS'Y @ 14938' RKB WITH HES' DPU. TESTED UPPER ER PKR, TBG, GOOD. COMPLETE. . . a .. KU • • 1D -34L1 ConocoP 11ll1 ' Well AALrib�tte IMax Angle & MD TD v'` �� Wellbore APIIUWI 'Field Name Well Status I lncl ( °) IMD (RKB) Act Btm (RKB) Al:6 1 «> Okw - 500292297560 KUPARUK RIVER UNIT (PROD 1 95.05 16,616.76 18350.0 • Comment H2S (ppm Mb ) An oration '. End Date KB (R) Rig Release Date W�IC«lfg ._ ?o- 4441,$'11/4Dit SSSV. NIPPLE 60 _I 9/16/2010 Last WO � 8/7/2001 _ 3541 _ 10/22/2000 A notat Depth RKB End Date Annotation Last Mod ... End Date Last Tag: I 15,742 0 8/2_ _5/200 Rev Reason: SET PATCH ASSY, GLV C/O ninam 9/11/2011 Casing Strings HANGER, 29 1.` ,. Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Sat Depth (ND) -. String Wt... String - String Top Thrd r , .'" L1 LINER 23/8 1995. I 15.717.6 I 18,320.0 6,641.4 4.60 L 80 STL Liner Details T op D I (ND) Top Inc1 None... Top 07103) (RKB) 1 (°) Item Description Comment ID (In) CONDUCTOR,__ 15,717.6 6,528.7 69.60 DEPLOY BTT SEAL BORE DEPLOYMENT SLEEVE 1.920 35117 18,286 1 6,637.0 8328 0-RING BTT 0-RING SUB 1.000 NIPPLE, 548 ------ ,. Perforations & Slots - - -- =- - -.._. - -- -_ Shot < Top (TVD) Stun (TVD) Donn Top (RKB) Ban (RKB) (RKB) (RKB) Zone Dab (oh... Type Comment 15,719 15,941 6.529.2 6,575.2 C4, 1D - 34L1 9/21/2005 40.0 SLOTS Alternating slotted/solid pipe GAS LIFT. __.._ _ _ _ _ . - __ — It , ._....�_ _�_ ____ __ __ 3,274 16,067 16,733. 6.572.6 6,550.6 C-4, C-3, 9/21/2005 40 -0 SLOTS Alternating slotted /solid pipe 1D -34L1 GAR LIT.__ — ,991 _ - _ - `— 16,796) 18286 6553.6 6,637.0 C4, C -3, C -2, 9/21/2005 40.0 SLOTS Alternating slotted /solid pipe 1D -34L1 Notes: General & Safety End Date Annotation 9/22/2005 NO I E'. MULTI LATERAL WELL 10-34 (C-SANDS) AND 1D 34L1 1/5/2009 ''NO I E: VIEW SCHEMATIC w /Alaska Schematic9.0 SURFACE, — _.. ,A 349.463 2/162009 NO FE: TAG OBSTRUCTION! 15726' WLM GAS LIFT, ilir 10,325 GAS LIFT, 12,059 Ili '... 13,584 L PACKER,__.... 14,938 PATCH, 14,940 - GAS LIFT,� . 14,943 PACKER, 14,952 NIPPLE, 14,996 ;2; iet Zit LOCATOR. 15,040 ■ SEAL ASS42 J 1 .1 iiitli 5,042 PRODUCTION. • 34- 15,164 APERF, 15,700-15,730 Lt WINDOW, 15,722- 15,730 IPERF, 15,730-15,735 - +_.1 FRAC, 15,730 APERF, 15,780.15$40'N SLOTS, 15,719-15,641 Mandrel Details Top Depth Top __..- -.. Port I ' [ (TVD) Inc1 OD Valve Latch Sue TRO Run Stn Top (ftKB5 (11KB1 Cl Make Model (in) Sery Type Type (m) (psi) Run Date Cron... csAND 1 _3,2743 2,418.6 67.26 CAMCO KBUG 1 Gas LS DMY RK 0.000 0.0 9/4/2011 11 30 LINER. ._ .. ___ 15,001 2 7,994.2 3,767.4 69.06 CAMCO KBUG 1 Gas Lift DMY BK-5 0.000 0.0 9/3/2011 12:00 3 10,325.3 4,620.2 69.34 CAMCO KBUG 1 Gas Lift DMY BKS 0.000 0.0 9/3/2011 7:30 SLOTS, 4.an , kc —ki 4 12,058.6 5,239.0 68.58 CAMCO KBUG 1 Gas Lift DMY BKS 0.000 0.0 9/3/2011 10:00 16,067 - 16,733 _ _ 5 13,583.9 5,790.0 68.80 CAMCO KBUG 1 Gas Lift DMY BKS 0.000 0.0 8/24/2005 1:30 6 14,943.3 6,271.2 67.75 CAMCO KBUG 1 12 Gas Lift HFCV RK 0.000 0.0 9/5/2011 12:00 SLOTS, 16,796- 18,286 1.1 LINER, 15,718- 18,320 TO (1D-3411), 18,350 DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051280 Well Name/No. KUPARUK RIV UNIT 1D-34L1 MD 18350 TVD 6647 Completion Date 9/22/2005 Operator CONOCOPHILLIPS ALASKA INC Completion Status 1-OIL Current Status 1-OIL API No. 50-029-22975-60-00 UIC N REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Log s Run: MWD DIR / GR Well Log Information: Log! Electr Data Digital Dataset Type MedlFrmt Number Name , _-- D Asc _ __- --- ---- Directional Survey f ~~ /~ yRpt Directional Survey ~D D Asc Directional Survey ~f2pt Directional Survey wog 14243 Gamma Ray g 14243 Gamma Ray pt 14243 LIS Verification r~ Lis V 14243-See Notes og 14244 Gamma Ray og, 14244 Gamma Ray pt 14244 LIS Verification ~~D C Lis __ 14244 =See Notes ~', apt 14312 Induction/Resistivity R t 14313 n/R Ind ti i ti it p uc s v y o es '-~ /'in ED C ~k„ae(~~S 14313~ duction/Resistivity ED C „La~~~ 14312~nduction/Resistivity Samples No Directional Survey Yes // (data taken from Logs Portion of Master Weli Data Maint Log Log Run Scale Media No Interval Start Stop OH / CH Received Comments 17875 18350 Open 10/4/2005 IIFR 17875 18350 Open 10/4/2005 IIFR 15699 18173 Open 10/4/2005 P6111FR 15699 18173 Open 10/4/2005 P6111FR 25 Blu 15730 18350 Open 11/17/2006 MD GR 21-Sep-2005 2 Blu 15730 18350 Open 11/17/2006 TVD GR 21-Sep-2005 15730 18350 Open 11/17/2006 Lis Veri 21-Sep-2005 Open 11/17/2006 Lis Veri w/Graphics 25 Blu 15730 18173 Open 11/17/2006 PB1 MD GR 18-Sep-2005 2 Blu 15730 18173 Open 11/17/2006 P61 TVD GR 18-Sep-2005 15730 18173 Open 11/17/2006 P61 LIS Veri 18-Sep-2006 0 0 Open 11/17/2006 LIS Veri w/Graphics 15715 18351 Open 1/10/2007 LIS Veri w.Graphics in LAS format 21-Sep-2005 REVISED 15730 18173 Open 1/10/2007 PB1 LIS Veri w.Graphics in LAS format 22-Dec-2006 REVISED 15730 18173 Open 1/10/2007 PB1 LIS Veri w.Graphics in LAS format 22-Dec-2006 REVISED 15715 18351 Open 1/10/2007 LIS Veri w.Graphics in LAS format 21-Sep-2005 REVISED DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051280 Well Name/No. KUPARUK RIV UNIT 1D-34L1 Operator CONOCOPHILLIPS ALASKA INC MD 18350 TVD 6647 Completion Date 9/22/2005 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / V~ Chips Received? ~`Tt~ ~'. Analysis Y / N Received? Comments: - -- -- -- l _ _- Compliance Reviewed By: __ ___.__ __ Date Daily History Received? ~ N Formation Tops ~ / N API No. 50-029-22975-60-00 UIC N J i 'T'ransmittal Form INTEQ To: AOGCC 333 West 7t" Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1D-34L1 & 1D-34L1PB1 Contains the following: ?~,~TT 1 LDw'G Compact Disc (Includes Graphic Image files) 1 LDWG lister summary ~~ ~ ,F ' BAKER HuGNES Anchorage GEOScience Center LAC Job#: 973737 Sent By: Deepa Joglekar Date: Dec.22;~~OD6 ~/ Received By: ~~ ~ ~~/~~~- Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 p j ' B ~ ~ ~ ~ ~ ~ 3 ~ ~ Baker Hughes INTEQ 7260 Homer Drive ~ ~ ~ ~ 3 ~ ~ ~ 8 ~ Anchorage, Alaska 9918 Direct: (907) 267-6612 FAX: (907) 267-6623 fA11 K4 ~ UOao~ pQf t <y1 ~.. - .. ~1 ~, . ..; I_ ..- ~_::•_ ~M - - ~~. ~~ Lam, I ___- ~-jj- -- I~ . ~; =: __ __ - ._. r~ _ :~ i ~ :~ i r i -- - i -_ • Transmittal Form INTEQ r~ u ~~%® saKEa HUGHES Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1 D-34L 1 PB 1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log ~~~~ JAN ~ LDO$ LAC Sob#: 973737 ~-~.. Sent By: Deepa Joglekar Date ;, ~ ,,~ ~'~ ', n Received By: `~ ~ f ~ Date `~ Inky .~ ~, ~ ~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 1i'~i~~~~~~d~ 99518 Direct. (907) 267-6612 ~t JAI ~L~~/ FAX: (907) 267-6623 I - C7 Transmittal Form rrt® BAKER NUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1D-34L1 Anchorage GEOScience Center r.,,~ ~,;~~,~~~ns t e o owing: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary I blueline - GR Measured Depth Log 1 blueline - GR TVD Log ~ LAC Job#: 973737 ~ { Sent By• Deepa Joglekar Date: Nov.O~). 2006 ;: ~' -- - Received By: (~~~(,~ - Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 ~U~~ ~ 1 ~ ~ ~' (~~~~--3 Direct: (907) 267-66iz FAX: (907) 267-6623 I: ~.I sur Aa.ia.be mnrwq ~.nK , 4 f __ i ... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC 2s.,os 2oAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 9/22/2005 ~ 12. Permit to Drill Number 205-128 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/10/2005 ' 13. API Number 50-029-22975-60-00 4a. Location of Well (Governmental Section): Surface: 447' FNL 42 ' FEL S C 7. Date T.D. Reached 9/20/2005 ~ 14. Well Name and Number: Kuparuk 1 D-34L1 , , 0 E . 23, T11N, R10E, UM Top of Productive Horizon: 784' FNL, 1512' FW L, SEC. 31, T11 N, R11 E, UM g, KB Elevation (ft): 34 15. Field /Pool(s): Kuparuk River Field / aruk River Pool Ku Total Depth: 1070' FNL, 4000' FWL, SEC. 31, T11N, R11E, UM 9. Plug Back Depth (MD+TVD) 18350 + 6647 Ft p 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 y- 5959219 Zone- ASP4 10. Total Depth (MD+TVD) 18350 ' + 6647 Ft 16. Property Designation: ADL 028248 TPI: x- 567978 y- 5948386 Zone- ASP4 Total bepth: x- 570469 Y- 5948122 Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: -----~--~-~------ -------------- -----------~ 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1753' 21. Logs Run: MWD DIR / GR T~GcJ' ~ ' tom} /S~ 7 Z~ `~'/p y (,~' ~ Tvr~ ~a .~,l.e~S~ 2. CASING, LINER AND EMENTING RECORD CiASING EITINO EPTH MD ETiINO EPTH TVp I~O~ MOUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 117' Surface 117' 30" 14 cu ds ABI T e III 9-5/8" 40# L-80 Surface 9463' Surface 4316' 12-1/4" 510 sx AS III Lite, 510 sx LiteCrete 7" 26# J-55 Surface 15164' Surface 6348' 8-1/2" 170 sx Class 'G' 3-1/2" 9.3# L-80 15001' 15724' 6294' 6532' 6-1/8" 00 sx Class 'G' 2-3/8" 4.6# L-80 15718' 18320' 6530' 6642' 3" Uncemented Slotted liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TuewG RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 15041' 15008' MD TVD MD TVD 15719' - 15941' 6530' - 6576' 1606T - 16733' 6573' - 6551' 25. AciD, FRACTURE, CEMENT SQUEEZE,' ETC. 16796' - 16286' 6554' - 6637' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 15724' op of Flow-Thru Whipstock 2500' Freeze Protect with 22 Bbls Diesel 26. PRODUCTION TEST Date First Production: October 1, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 10/15/2005 Hours Tested 24 PRODUCTION FOR TEST PERIOD OIL-BBL 169 GAS-MCF 2116 WATER-BBL 3 CHOKE SIZE 176 GAS-OIL RATIO 12503 Flow Tubing Press. 18 Casing Pressure 1050 CALCULATED 24-HOUR RATE OIL-BBL 169 GAS-McF 2116 WATER-BBL 3 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~ L~ ;'~~ None ~~ ~ t, ~ ~ ZflC1rJ ~ ~ • ZZ ~G${ tic:;;; "ED Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE I- r 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". (From 1 D-34) None Top Kuparuk C 15698' 6523' 1 D-34L1 Top Kuparuk B 15935' 6575' Base Kuparuk C 1601 T 6575' Top Kuparuk B 18300' 6639' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~a ~ / ~ Title Technical Assistant Date - Terrie Hubble ~ Kuparuk 1 D-34L1 205-128 Prepared By Name/Number• Terrie Hubble, 564-4628 Well Number Permit No. / A rOVdl NO. Drilling Engineer: Bras Worthington, 265-6802. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. trEM 4b: TPI (Top of Producing Interval). ITEM 8; The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only • • Well: 1 D-34L1 Accept: 09/07/05 Field: Kuparuk River Unit Spud: 09/10/05 API: 50-029-22975-60-00 Release: 09/22/05 Permit: 205-128 Rig: Nordic #2 PRE-RIG WORK 07/09/05 REMOVE ICE PLUGS BY PUMPING HOT DIESEL (140°F) THROUGH 1.75" DOWNJET NOZZLE. ENCOUNTER STRINGERS OF ICE DOWN TO 2500' CTMD. ESTABLISH INJECTIVITY RATE BY CLOSING IN CHOKE AND PUMPING DIESEL AT 1.5 BPM AND 2370 PSI. CONTACT DSO TO BRING WELL ON-LINE. 08/23/05 PULL STA# 3, 4 LGLV AND OV AT 10326', 12059'. JOB IN PROGRESS, CONTINUE IN AM. 08/24/05 PULL STA# 1, 2 LGLV'S AT 3275', 7995' RKB, SET DGLV'S AT STA# 1, 3, 4, 3275', 10326', 12059' RKB. 08/25/05 SET DUMMY AT STA# 2 AT 7995' RKB. RAN W/ 2.70 X 10' DUMMY DRIFT TO 15742' RKB, 8' SHY TARGET. ATTEMPT TO SET CS-2A TTP AT 15086' RKB, POOR ACTION. WHILE SETTING, PSI ON IA STARTED RISING INDICATING LEAK. RAN 3 1/2" D & D, ISOLATED LEAK. RAN KOT TO STA#4 12059'. 08/26/05 SET CS-2A BLANKING PLUG AT 14995' RKB. PULLED DUMMY AT 12059' RKB. LOAD TUBING AND IA W/ SEA WATER AND DIESEL. SET DUMMY STA # 4 AT 12059' RKB. MIT-IA 2500# 30 MIN, PULLING C-SUB 14995' RKB. JOB IN PROGRESS, CONTINUE TO 08-27-05 WSR. 08/27/05 ATTEMPTING TO PULL PLUG. MADE SEVERAL ATTEMPTS AT PULLING PRONG OF 2,81" CS-2A BLANKING PLUG 14995' RKB. UNABLE TO GET LATCHED INTO DUE TO ACTION OF TOOLS DUE TO FLUIDS AND DEVATION. PULLED STA# 1 AT 3275' RKB, LOADED 116 BBLS DIESEL TO FREEZE PROTECT TUBING AND IA. SET DUMMY AT SA. 08/28/05 PULL 2.81" CS-2A BLANKING PRONG AND BODY AT 14995' RKB. JOB COMPLETE. READY FOR CALIPER LOG. 08/30/05 A MULTI-FINGER CALIPER LOG WAS PERFORMED: TOOL SAT DOWN AT 15730'. CALIPER RUN FROM 15730' -15450'. LINER APPEARED IN GOOD SHAPE. POOH. • BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: 1 D-34 Common Well Name: 1 D-34 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ' From - To ' Hours Task i Code 9/7/2005 00:00 - 06:00 6.00 MOB P 06:00 - 07:30 1.50 MOB P 07:30 - 08:15 0.75 MOB P Start: 9/5/2005 Rig Release: 9/22/2005 Rig Number: Spud Date: 9/5/2005 End: 9/22/2005 08:15 - 08:30 0.25 MOB P PRE 08:30 - 11:00 2.50 BOPSU P PRE 11:00 - 11:45 0.75 BOPSU P PRE 11:45 - 18:00 6.25 BOPSU P PRE 18:00 - 19:30 1.50 BOPSU N SFAL PRE 19:30 - 20:10 I 0.671 BOPSUf~ P I I PRE 20:10 - 20:45 0.58 BOPSU~ N I SFAL PRE 20:45 - 21:15 0.50 BOPSU P PRE 21:15 - 23:30 2.25 BOPSU N SFAL PRE 23:30 - 00:00 0.50 BOPSU P PRE 9/8/2005 00:00 - 00:30 0.50 BOPSU P PRE 00:30 - 00:40 0.17 RIGU P PRE 00:40 - 02:50 2.17 RIGU P PRE 02:50 - 03:20 0.50 RIGU P PRE 0320 - 03:40 0.33 RIGU P PRE 03:40 - 05:30 1.83 RIGU P 05:30 - 06:15 0.75 STWHIP P 06:15 - 08:15 2.00 STWHIP P 08:15 - 09:00 0.75 STWHIP P 09:00-13:00 4.00 STWHIP P 13:00-13:45 0.75 STWHIP P 13:45 - 14:30 0.75 STWHIP P 14:30 - 15:00 0.50 STWHIP P 15:00-15:30 0.50 STWHIP P Move rig to location, rig accepted. Mobilise equipment, LD mats, clear area Conduct well/pad inspection with pad operator, driller, and company man. Inspection ok'ed. Spot rig on well, verify communications Conduct safety meeting, NU BOPE to wellhead. Tighten and grease fittings, valves, connections. Set new 2" long spool in cradle Test BOPE- 3500H, 500L. -HCR failed. Re-grease and re-test. Continue trying to complete BOP test. All passed except the Kill side HCR. Try greasing valve, still failed, and won't PT from either direction. Break out valve, and send crew to get a used valve from Nordic cold storage yard at price pad. Pre spud meeting with all night tour rig hands, MI town supervisor, BP town engineer and 2nd BP WSL. Discuss plan forward for this well, hazards, special situations, and contingincies. Continue working on removing defective HCR valve. Stab coil tubing into injector. Replace defective HCR valve with one obtained from Price pad. PT new Kill line HCR to 250 psi and 3500 psi. Passed ok. Body test Kill line to check connections that were broken to replace HCR valve. PJSM re: pumping slack management. Reverse circulate mud at 1 bpm to fill coil. Circulate at 2 bpm and 3200 psi for 20 minutes to displace slack. Cut coil to find end of wire. Got 8' of slack pumped into coil. 18890' of coil left on reel. Build coil eline CTC. Pull test to 35 klbs. After recent leak we had on 1 J-03 from flange below the master valve, the rig crew checked the same bolts on this wellhead. We found 4 of the 8 nuts to be finger loose, and needed to be tightened. All of the nuts, even the ones that were more than hand tight needed to be tightened up with the hammer wrench at least 1/2 turn. We averted a problem here. Continue making up ecoil head. PT CTC and inner reel valve. PJSM Re: deploying whipstock. Orient. WS with MWD BHA. PU and deploy WS assy and setting BHA. Pump slack at 1.5 bpm with 2.18 surge at 70'. Line returns to tiger tank, RIH at 75 fpm w/ CT, WS assy and setting BHA. Pump .75 bpm to 9500', SD pumps after. Monitoring pod problems on pump #1. Running on pump #2. Circulate 8.6 mud and displace well volume at 1.9 bpm. Hold depth at 15438'. Log down with GR from 15450' to 15518' at 2.5 fpm. -15' correction. CCL log down at 13 fpm from 15518' to 15700'. Check WS set depth with GR and CCL. RIH to 12730' (Bot. of WS), 15721' (Top of WS). Press. up to 4690, 5K overpull, did not set. Work pipe and WS +/-10'. Set down on WS, press up to 2600, 3K overpull. WS set. POOH. NPT Phase '! Description of Operations PRE PRE PRE PRE WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Printed: 9/26/2005 9:40:36 AM • BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: 1 D-34 Common Well Name: 1 D-34 Event Name: DRILL+COMPLETE Start: 9/5/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2005 Rig Name: NORDIC 2 Rig Number: Date 'From - To 9/8/2005 15:30 - 18:15 18:15 - 18:30 18:30 - 19:45 19:45 - 20:30 20:30 - 21:35 21:35 - 00:00 Hours ' Task ~ Code NPT ~~ Phase __ , 2.75 STWHIP P 0.25 STWHIP P 1.25 STWHIP P 0.75 STWHIP P 1.08 STWHIP P 2.42 STWHIP P 9/9/2005 100:00 - 00:15 0.25 STWHIP P 00:15 - 00:35 0.33 STWHIP P 00:35 - 02:00 ~ 1.42 STWHIP P 02:00 - 03:00 I 1.001 STWHIPI P 03:00 - 04:00 I 1.00 I STWHIPI P 04:00 - 05:00 I 1.001 STWHIPI P 05:00 - 06:00 I 1.001 STWHIPI P 06:00 - 09:00 3.00 STWHIP P 09:00-15:00 6.00 STWHIP P 15:00 - 18:15 3.25 STWHIP P 18:15-18:30 0.25 STWHIP P 18:30 - 19:00 I 0.501 STWHIPI P 19:00 - 19:15 ~ 0.251 STWHIPI P 19:15 - 21:00 I 1.751 STWHIPI P Spud Date: 9/5/2005 End: 9/22/2005 Description of Operations WEXIT POOH w/ Coil and WS setting assy. WEXIT PJSM Re: Undeploying Whipstock setting BHA. WEXIT Undeploy BHA #1, Whipstock setting BHA. WEXIT Make up MWD tool for milling window, check out on catwalk. WEXIT Deploy BHA #2, window milling BHA. WEXIT RIH with the window milling BHA. Following pressure schedule while RIH. WEXIT Continue RIH. WEXIT Log tie in pass down from 15440'. Make -14' correction. WEXIT RIH to begin milling. Dry tag at 15725'. Kick pumps on, free spin 3960 psi at 1.5 bpm. Tag top of WS at 15724'. Begin milling window. 1.5/1.5/4100 psi. DHWOB=250 psi. String wt = 4000 lbs. Pump pressures are a bit high, and string wt is very low. Going to be tough to make it to TD with current conditions. Current tube concentration in mud is 3.0%lubetex. Call for mud engineer to go to maximum lubricant concentration. Adding lubetex to 4.0%, and EMI-776 to 1.5%. WEXIT 15724.8', DHWOB=570 lbs. String wt = 2400 lbs. 1.5/1.5/4160 psi. IAP=372 psi, OAP=352 psi. PVT=440 bbls. WEXIT 15725.5', DHWOB=1000 lbs. String wt = 3500 lbs. 1.5/1.5/4300 psi. Currently have 4% Lubetex in the mud, and are about to start adding EMI-776 mud tube. WEXIT 15726.1', DHWOB=1600 lbs. String wt = 1250 lbs. 1.5/1.5/4350 psi. Currently still adding EMI-776 to mud. PVT=440 bbls. Not losing any mud to open perforations. Getting good metal hairs on the magnets. WEXIT 15726.8', DHWOB = 1440 lbs. String wt = 1700 lbs. 1.5/1.5/4280 psi. WEXIT 15727.8, DHWOB = 600 Ibs, String wt = 2300. 1.5/1.5/4120 psi. WEXIT Made break through casing. Ream window and drill 10' rathole. 380 WOB, 350 string wt, 1.5/1.5/4200 psi. 14'/hr. Problems with packing off when mill slips outside of window. Reduce pumps and pull back up, then slack off onto window again. WEXIT POH WEXIT Pump at full rate while POOH. Jog at surface. Got significant amounts of formation sand and metal debris during jog. Shutdown for crew change. WEXIT Communications have been down most of the day. The BOC corns guys are here to make repairs requiring hot work. Shut down undeployment proceedure until they have made repairs. We do not want SIMOP's with hot work while undeploying. WEXIT Hold PJSM with rig crews discussing undeployment of milling BHA. WEXIT Undeploy BHA #2, window milling BHA. Following SLB SOP checklist. BHA recovered with no metal debris or other unusual debris stuck to BHA. Mills recovered with swirl pattern on face of D0261 mill consistent with a good window. D0261 gauged 2.72 no go, 2.72" go. String mill recovered at 2.73" no go, 2.74" go. Shaft of D0261 mill, and pin end of string mill were polished as if they had been worked on by metal debris or cuttings. Unusually so. The wear on the shafts was not typical. This could be consistent with the packing off reported Printetl: 9/26/2005 9:40:36 AM • BP EXPLORATION Operations Summary Report Page 3 of 13 Legal Welt Name: 1 D-34 Common Well Name: 1 D-34 Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/5/2005 End: 9/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2005 Rig Name: NORDIC 2 Rig Number: Date From - To '~, Hours Task Code', NPT ~ Phase 9/9/2005 29:00 - 00:00 3.00 DRILL IP - - ~P PROD1 9/10/2005 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 01:00 0.25 DRILL P PROD1 01:00 - 02:00 1.00 DRILL P PROD1 02:00 - 04:30 2.50 DRILL P PROD1 04:30 - 05:10 0.67 DRILL P PROD1 05:10 - 07:00 1.83 DRILL P PROD1 07:00 - 14:00 I 7.001 DRILL I P I I PRODi 14:00 - 15:30 I 1.501 DRILL I P I I PROD1 15:30 - 16:15 I 0.751 DRILL I P I I PRODi 16:15 - 16:45 I 0.501 DRILL I P I I PROD1 16:45 - 18:00 I 1.251 DRILL I P I I PROD1 18:00 - 21:30 ~ 3.501 DRILL P PROD1 21:30 - 22:00 0.501 DRILL P PROD1 22:00 - 00:00 I 2.001 DRILL I P I i PRODi 9/11/2005 100:00 - 04:45 4.751 DRILL P PRODi 04:45 - 05:25 0.67 DRILL P PROD1 05:25 - 09:00 3.58 DRILL P PROD1 Description of Operations by the day tour. Rig up and pump coil slack management. Got audible indication of wire movement. Cut 60' of coil to find end of eline. Behead with CTC. Pull test to 35 klbs. Install BHI UOC. Finish reheading coil. Safety meeting prior to deploying next BHA. Pressure deploy BHA #3, first lateral section BHA with a 0.9 degree motor, and a Hughes 2.74" x 3" bi center bit. RIH with BHA #3, pumping at 1.5 bpm thru an open EDC to try to clean up hole. Log tie in pass down from 15450'. Make -14' correction. RIH thru window with a 30L tool face. Didn't see anything. Kick on pumps. Free spin is 3900 psi at 1.5 bpm. Tag bottom at 15740', begin drilling lateral section of hole. 1.51/1.45/4200 psi. Slight losses. CT string wt = 4400 lbs. DHWOB = 560 lbs. Drill ahead from 15740' to 15890'. 0= 1.48/1.42, 4200 - 3850 ~ press, 3400 CTW / 1500 WOB, 10-20'/hr. TF held at 70L. Occasional drilling breaks for 1-2' at 70'/hr. No apparent mud losses. -15800' sample showing 35% siderite -Perform short trip at 15800' to window -Perfrom short trip at 15850' to window Drill ahead from 15890' to 15915'. 0=1.25/1.22, 3600 - 3800 press, 2100-4300 CTW/ 1200-1600 WOB, 20-30'/hr, TF at 30L. No apparent mud losses. Drill ahead from 15915' to 15940'. 0=1.3!1.25, 3800 press, 1700 CTW/2400 WOB, 50'/hr, TF at 15L. Conduct wiper to window. 4K overpull to window. Once inside casing, no overpull problems. PU to 15460'. Log GR down at 2.5 fpm to 15480'.+.5' correction. RIH to 15740' and Tie in RA tags/whipstock. Drill ahead from 15940' to. 0= 1.35/1.35, 3800 press (3750 FS), -2500 CTW/ 2900 WOB, 20-60'/hr, 30L TF. Continue drilling ahead. Typical C sand ROP of 0-50 fph. 1.35/1.30/3760 psi. DHWOB=1000 Ibs, String wt = 2500 lbs. PVT=394 bbls. -AP=540 psi, OAP=470 psi. We are going to have to find some W08 if we are going to make it to TD. Wiper trip to window. Clean PU off bottom at 2550 Ibs. Clean in open hole. Clean back to bottom. Resume drilling. Free spin 4090 psi at i.5 bpm. Drilling at 1.5/1.47/4150 psi. DHWOB=400 Ibs, String wt = 2300 Ibs. PVT=391 bbls. IAP=600 psi, OAP=500 psi. Continue slow drilling in typical C sand. 0-30 fph. 1.5/1.45/4400 psi. DHWOB=2000 Ibs. String wt = -1000 Ibs. PVT=386 bbls. IAP=634 psi, OAP=510 psi. Pump 10 bbl high vis sweep. Continue drilling. High vis sweep out the bit. Chase up hole on a wiper. Making long wiper trip 2000' up inside tubing. Clean PU off bottom. Had overpull at 15957', had to back ream thru it. This is in the B shale. No problems pulling through window. Once through window, bring pump rate up to full (1.8 bpm) and open EDC. POOH at 70 fpm until well unloads cuttings. Close EDC at Printed: 9/26/2005 9:40:36 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 9/11 /2005 1 D-34 1 D-34 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 ', From - To Hours Task Code NPT ' Phase _- -- 05:25 - 09:00 3.58 I DRILL ~ P ~ ~ PROD1 09:00 - 12:00 3.00 DRILL P PROD1 12:00 - 12:45 0.75 DRILL P PROD1 12:45 - 13:45 1.00 DRILL P PROD1 13:45 - 18:00 4.25 DRILL P PROD1 18:00 - 19:00 I 1.001 DRILL I P I I PROD1 19:00 - 21:00 I 2.001 DRILL I P I I PROD1 21:00 - 00:00 I 3.001 DRILL I P I I PROD1 9/12/2005 ~ 00:00 - 00:15 ~ 0.25 ~ DRILL ~ P ~ ~ PROD1 00:15 - 01:10 ~ 0.92 ~ DRILL ~ P ~ PROD1 01:10 - 01:30 0.33 DRILL P PROD1 01:30 - 05:25 3.92 DRILL P PROD1 05:25 - 07:45 ~ 2.33 ~ DRILL ~ P ~ ~ PROD1 07:45 - 08:15 0.50 DRILL P PROD1 08:15 - 09:00 0.75 DRILL P PRODi 09:00 - 10:30 1.50 DRILL P PROD1 10:30 - 11:15 0.75 DRILL P PROD1 11:15 - 17:00 5.75 DRILL P PROD1 Start: 9/5/2005 Rig Release: 9/22/2005 Rig Number: Page 4 of 13 Spud Date: 9/5/2005 End: 9/22/2005 Description of Operations 12100'. PU several large cuttings beds and getting motor work. No cuttings beds above 10,000'. RIH at 100 fpm to 15740'. PU and log down to 1510 to 15740 at 2.5 fpm. -14' correction. Ream and work through shale from 15920' to 16000' several times. 25 fpm, .7 bpm, adjust TF to 40L, occasional stack out problems, max overpull of 3K. Drill ahead from 16247' to . 0=1.35/1.3, 3800 press, 2500 CTW/ 1500-3300 WOB, 9-20'/hr, 0 TF, 12.68 ECD. Occasional drilling breaks of 50-60'/hr. -C 15:15, adjust TF to 30R. -C~ 1645, adjust TF to 110E Drill ahead. ROP=30 fph. 1.5/1.5/4300 psi. PVT=79 bbls and taking on new mud. String wt = 1200 lbs. DHWOB=1000 lbs. New mud in the hole only has 4% lubtex and 8 ppb Kla-Gard. We are going to raise that after the pits are full with an additional 2% EMI-776, and bring Kla-Gard to 14 PPB. Precautionary wiper up to window to see how the B shale is acting. Clean PU off bottom. Stop reel 32' off bottom to make repairs to loose hardline inside reel. Pump 10 bbl high vis sweep off bottom to help hole cleaning. Motor work and slightly ratty from 15940' 15910', RBIH, and set down with motor work at 15955'. Ream back thru them slowly. Made it back to bottom ok. Back to bottom. Free spin 4000 psi at 1.5 bpm. Drilling at 1.5/1.45/4100 psi. PVT=431 bbls. IAP=590 psi, OAP=440 psi. String wt = 700 lbs. DHWOB=700 lbs. Still adding Kla-Gard and tubes to new mud. Pumping a 10 bbl sweep of 100 klsrv mud each hour to help clean the hole. Saw good cuttings returns from first sweep. Continue drilling lateral section. Pump 10 bbl sweep at midnight. Wiper trip to the shoe. Clean PU off bottom. Motor work and overpulls at 15940' on the way up, not bad on the way back down. We had 1 small weight bobble at 16010'. Back to bottom. Wait on orders from town. Back to bottom. Free spin 4200 psi at 1.5 bpm. Resume drilling 1.5/1.5/4300 psi. IAP=630 psi, OAP=460 psi. Long wiper trip to 10,000'. Slight problems through shale section (15930' - 16020') with 4600 psi (400 psi motor work) and 5K overpull. No problems through the window. No cuttings beds found. RIH to 15740'. Log down at 2.5 fpm. +11' correction. RIH to bottom. No noticable motor work or sticking. Shale section looked good. Drill ahead from 16514' to .4300 press, 1900 CTW/ 1200 WOB, 54'/hr, 120E TF, 13 ECD PU inside window, upgrade Slb's computer system RIH to bottom, Drill ahead from 16702' to 16800'. 0=1.5/1.45, 4100 press, -1500 to - 75000TW/ 1500 - 2000 WOB, 15-20'/hr, 120R TF, 13 ECD. Pump 10 bbl high vis sweeps every hour. No noticable stalling problems. No noticable mud losses. -C4 sand, fair amount of siderite Printed: 9/26/2005 9:40:36 AM • C7 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-34 1 D-34 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Date 'i From - To '~ Hours ~ Task I Code NPT _~_ _ 1 __ i 9/12/2005 117:00 - 17:30 I 0.501 DRILL I P 17:30 - 18:00 0.501 DRILL P 18:00 - 18:25 0.421 DRILL ( P 18:25 - 19:40 I 1.251 DRILL I P 19:40 - 23:05 3.421 DRILL P 23:05 - I O.OO I DRILL I P 9/13/2005 00:00 - 00:40 0.67 DRILL P 00:40 - 05:10 4.50 DRILL P 05:10 - 08:30 I 3.331 DRILL I P 08:30 - 09:00 0.501 DRILL P 09:00 - 10:30 I 1.501 DRILL I N I DPRB 10:30 - 13:00 2.50 DRILL N DPRB 13:00 - 13:15 0.25 DRILL N DPRB 13:15 - 14:30 1.25 DRILL N DPRB 14:30 - 15:45 1.25 DRILL N DPRB Page 5 of 13 Spud Date: 9/5/2005 Start: 9/5/2005 End: 9/22/2005 Rig Release: 9/22/2005 Rig Number: Phase Description of Operations PROD1 Drilling break: 60-70'/hr. Drilling from 16800' to 16826'. 0=1.48/i.45, 4300 press, -1500 to -3000 CTW/ 1300 - 1700 WOB, 100R TF, 13.11 ECD. PROD1 Drill ahead from 16826' to. 0= 1.48/1.45, 4300 press, -4400 CTW/ 1700 WOB, 90R TF, 13.11 ECD, 10-20'/hr. PROD1 Continue to drill ahead. PVT=394 bbls. Free spin = 4030 psi at 1.48 bpm. Drilling at 1.5/1.5/4300 psi. Continuing to pump a 10 bbls sweep each hour. PROD1 Wiper trip to window. Clean PU off bottom. Clean up thru open hole interval, including the B shale. Clean back to bottom. No problems at all. Kla-Gard and sweeps have cleaned up the hole very good. It is in much better shape than a couple of days ago. PROD1 Resume drilling. Free spin 4400 psi at 1.54 bpm. Pumping a sweep at this time, free spin will drop as it exits the coil. Drilling at 1.54/1.51/4460 psi. DHWOB=1400 lbs. String wt = -1100 lbs. ROP=60 fph. (For Now). PROD1 Wiper trip to the window. Clean PU off botom at 29 klbs. Clean in OH to PROD1 Continue back in hole on wiper trip. No problems. PROD1 Back at bottom. Free spin 4200 psi at 1.5 bpm. Drilling at 1.48/1.43/4300 psi. Pit vol = 383 bbls. IAP=780 psi, OAP=530 psi. Continuing to pump 10 bbl sweeps at a rate of 1 per hour. Seems to be cleaning hole just fine. PROD1 Make long wiper trip to 10000', up inside the tangent section of the cased hole. Clean PU off bottom C~J 29 klbs. Clean in open hole. No problems through the window, No beds in cased hole. Problems re-entering window- completely stacking out. Try multiple times to re-enter- failed every time. Attempt to circulate on top of window to clear it of possible debris. Failed. PU to 15715' (9' off window) and circ at 1.6 bpm. RIH to 15721 and circ. (stacking wt.) PROD1 PU to 15450', log down to 15470' and tie in with GR. +17.5' correction. RIH to tag up. PROD1 RIH to tag up (15540' corrected depth- window clear). Make sure TF is at 30L. PU to 15735' and circ at 1.43 bpm at 3800 psi. 12K CTW/ 200 WOB. Hold for several minutes. Slowly RIH to 15740'- O same, 3980 psi, 4400 CTW/ 550 WOB. Continue in hole to 15745' and stack out, press up to 4150 psi. Hold depth and see if we can drill off- press declines to 4000 psi, 3500 CTW/ 1400 WOB. Continue back in- press up to 4100 instantly, 3200 CTW/ 2700 WOB. PU to 15738' and drop pumps to .65 bpm. Turn TF as far to left as possible (90L) then turn it to as far right as possible (30R). No change in WOB. SD pump and run into tag up at 20 fpm. Complete stack out and no further movement. PU and re-enter tag up- press at 2300 psi at .5 bpm, still stacking wt- 5400 CTW/ 3500 WOB. Continue to lightly tag and immediately PU- attempted multiple times with no luck. POOH. PROD1 POOH to change BHA PROD1 Conduct safety meeting of un-deployment PROD1 Undeploy and LD BHA. PRODi PU and deploy new C/O BHA with cleanout mill. Printed: 9/26/2005 9:40:36 AM • Operations Summary Report Legal Well Name: 1 D-34 Common Well Name: 1 D-34 Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/5/2005 End: 9/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase BP EXPLORATION Page 6 of 13 9/13/2005 15:45 - 18:00 2.25 DRILL N DPRB 18:00 - 18:30 0.50 DRILL N DPRB 18:30 - 20:00 1.50 DRILL N DPRB 20:00 - 22:45 2.75 DRILL N 1.25 DRILL N 1.00 DRILL N 2.50 DRILL N 0.50 DRILL N 1.00 DRILL N DPRB DPRB DPRB DPRB DPRB DPRB 22:45 - 00:00 9/14/2005 100:00 - 01:00 01:00 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 06:15 1.25 DRILL N DPRB 06:15 - 06:45 0.50 DRILL P 06:45 - 12:20 5.58 DRILL P 12:20 - 14:10 14:10 - 18:00 18:00 - 20:30 1.831 DRILL I P 3.831 DRILL I P 2.501 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Description of Operations Run in hole with mill assembly. Log gr tie in. Subtract 14' correction. Pass through window ok at minimum rate. Orient to drilled tool face. Tag up at 15745'. PU and make a few runs at obstruction. Mill ahead slowly. 4100 psi fs @ 1.4 in/1.33 out. Motor work (200-300 psi) and WOB, 3k-4k#. Not looking good. Appear to be drilling formation. Attemp to RIH at min circ rate. Stacking out at 15,749'. Pull out of hole to pick up bi-center bit drilling assembly. Maintain WHP as per schedule. At surface. Hold PJSM. Undeploy BHA. Mill in good shape with some balling. No sign of having milled any metal. Pressure deploy BHA #5 (0.9 mfr w/ HCC bicenter bit) Stab coil. Get on well. Run in hole maintaining WHP as per schedule. Log gr tie in from 15,460'. Subtract 14' correction. RIH. Tag fill or ledge at 15,750'. 4000 psi fs at 1.50 in/1.44 out. Begin clean out with reduced circ rate (1.25 bpm). Numerous stalls. Clean pick ups from btm. Tag btm and backream to clean up hole. Maintain tool face as originally drilled. (65L) Take several 1/2 foot bites trying to find original hole. Clean out to 15760'. Appear to be at slightly higher near bit inclination than original hole. Adjust TF to 240E to try and drop slightly. Reamed down thru debris/cuttings bed in hole. Finally popped thru it. RIH at 10 fpm. Set down at 15950' in the B Shale. PU, ream down thru it. Ream back up to window to clean up hole. Continue back to bottom to resume drilling. PVT = 332 bbls. IAP=630 psi, OAP=430 psi. Free spin 4200 psi at 1.47 bpm. Tag bottom at 17156'. Resume drilling lateral section. 1.47/1.41/4300 psi. PVT=333 bbls. IAP=650 psi, OAP=430 psi. String wt =-3500 lbs. DHWOB=600 lbs. ROP = 60 fph. Pumping a 10 bbl high vis sweep each hour. Wiper trip to the window. Clean PU off bottom at 29 klbs. Clean in open hole. Pump an additional high vis sweep to exit the bit as we get to the B shale and sweep the heel of the well. Had a wt bobbles and had to work it up thru the B shale interval. Multiple overpulls. Weight cleaned up above the B shale to the window. RIH set down 1 time in B shale, went thru it slick the rest of the way. Clean back to bottom. Free spin pressure 4200 psi at 1.48 bpm. Resume drilling. 1.48/1.4/4300 psi. String wt = -2000 lbs. DHWOB=500 lbs. PVT=317 bbls. IAP=740 psi, OAP=480 psi. Drilling at fairly consistent 30 fph. Note - We caught a bottoms up sample from when we were working the B shale interval on the last wiper trip. The sample showed 65% shale in the sample with 50% being fresh angular pieces. It looks as if the B interval is starting to slough in. Consult with totem. Decide to hold 500 psi higher pressure when making long trips and tripping in and out of well. PROD1 Drill ahead from 15,427'. 4100 psi fs at 1.38 in/1.32 out. Printed: 9/26/2005 9:40:36 AM • BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: 1 D-34 Common Well Name: 1 D-34 Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/5/2005 End: 9/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2005 Rig Name: NORDIC 2 Rig Number: Date ;From - To I! Hours I Task Code NPT Phase 9/14/2005 ~ 18:00 - 20:30 ~ 2.50 i DRILL P PROD1 20:30 - 22:45 I 2.251 DRILL I P 22:45 - 00:00 I 1.251 DRILL I P 9/15/2005 ; 00:00 - 03:00 ~ 3.00 DRILL P 03:00 - 04:45 1.75 DRILL P 04:45 - 06:00 1.25 DRILL P 06:00-08:10 2.171 DRILL ~P 08:10 - 08:20 0.17 DRILL P 08:20 - 09:25 1.08 DRILL P 09:25 - 14:05 4.67 DRILL P 14:05 - 16:35 2.50 DRILL P 16:35 - 18:00 1.42 DRILL P 18:00 - 20:45 2.75 DRILL P 20:45 - 22:00 1.25 DRILL P 22:00 - 23:15 23:15 - 00:00 1.25 DRILL P 0.75 DRILL P 9/16/2005 100:00 - 03:00 3.001 DRILL I P PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PRODi Description of Operations 100-200 DPSI. DHWOB: 0.8 1.2k#. WHP/BHP/ECD: 26/4560/13.65 ppg. IA/OA/PVT: 760/485/305. INC/AZM/TF: 88.1/90.4/75L. ROP slow : 10-25 fph. Line up trucks for mud swap as drill solids are 0.8 % and system has 1000'+ on it. Pump 10 bbl hi vis sweeps every hour. Wiper trip to window. 3900 psi fs at 1.5 bpm as new mud exits coil. Slight mfr work at 15,950', 15,926, stall at 15,915'. Several 3-5k# overpulls. RIH maintaining drilled TF. Reduce circ rate to 1.22 bpm f/ 15,900 to 16,000'. Set down once at 15,965' w/ a stall. Resume pumping at 1.5 in. Continue to RIH. Smooth to TD. Noted a lot of formation material over shakers when new mud got to surface. No significant amounts of shale. Drill ahead from 17,470'. 3600 psi fs at 1.51 in/1.50 out. DHWOB increased f/ 0.7 to 1.5k# with new mud & wiper trip. Bringing mud tubes up to 2% & 4%. Drill ahead from 17,500'. 4700 psi fs at 1.52 in/1.47 out. 100-200 DPSI. DHWOB: 1.0 1.45k#. WHP/BHP/ECD: 22/4225/12.56 ppg. IA/OA/PVT: 811/502/32. INC/AZM/TF: 89.6/90.4/708. ROP slow : 10-25 fph. Drill ahead from 17,560'. Wiper trip to window. Time sweep to coincide with B shale interval. Continue wiper trip up to 10000', currently at 14500'. No cuttings beds observed inside production tubing. Wiper back to window. Log tie in pass over RA tag. Make +19' correction. Continue back to bottom on wiper trip. Slick thru the B shale. Free spin 3700 psi at 1.45 bpm. Tag bottom at 17631'. Resume drilling lateral section. Building angle to drill up into the Kalubik. 1.45/1.40/3830 psi. IAP=780 psi, OAP=480 psi. PVT=430 bbls. Bringing an additional 80 bbls on board. ROP=50 fph. String wt = -4500 Ibs, DHWOB=600 lbs. Continuing to pump high vis sweeps, 1 per hour at 10 bbl. Wiper trip to shoe. Clean PU at 29 klbs. Clean in OH up to the B shale. Slight overpull and motor bobble thru the shale. No real problems. RIH, No problems to bottom. Resume drilling. 1.53/1.41/4470 psi. ROP=50 fph. String wt = -2300 Ibs. DHWOB=300 Ibs. IAP=810 psi, OAP=490 psi. PVT=393 bbls. Drill ahead from 17,841'. 4300 psi fs at 1.53 in/1.26 out. Pvt: 383 bbls. Wiper trip to window. 28k# up wt off btm. Hole smooth to window on trip out except for one over pull with motor work at 15,920'. RIH. Smooth from window to btm. 3750 psi fs ~ 1.34 in. Drill ahead from 17,930'. 4050 psi fs at 1.48 in/1.43 out. 100-200 DPSI. DHWOB: 0.5 - 1.3k#. WHP/BHP/ECD: 33/4422/13.22 ppg. IA/OA/PVT: 815/483/365 bbls. INC/AZM/TF: 90.4/110/70L. ROP varying from 30 to 50 fph. Drilling ahead from 17,970'. Printed: 9/26/2005 9:40:36 AM • BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: 1 D-34 Common Well Name: 1 D-34 Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/5/2005 End: 9/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2005 Rig Name: NORDIC 2 Rig Number: Date I From - To ,Hours Task ' Code NPT Phase ! Description of Operations i - - - - _ _- 9/16/2005 ~ 03:00 - 04:15 ~ 1.251 DRILL P ( I PROD1 Drill ahead from 18050'. Weight transfer becoming a 04:15 - 06:00 I 1.751 DRILL I P 06:00 - 09:10 I 3.171 DRILL I P 09:10 - 09:30 I 0.33 i DRILL I P 09:30 - 01:45 I 16.251 DRILL I P 01:45 - 16:25 I 14.671 DRILL I P 16:25 - 17:00 0.58 DRILL P 17:00 - 18:30 1.50 DRILL P 18:30 - 20:00 1.50 DRILL N DFAL 20:00 - 22:30 2.50 DRILL N DFAL ', 22:30 - 00:00 ~ 1.501 DRILL N ~ DFAL problem. Able to make short (100') wipers, then drill ahead a few feet at 30-40 fph. POOH to pick up agitator tool. 27k# up wt off btm. PVT: 352 bbls Depth 14500', continue POH for Agitator tool. Following revised pressure schedule with 500 psi higher surface pressure as recommended by town engineer yesterday. Tag up at surface, make jog to flush cuttings. None observed. Trap 800 psi on WHP. Hold PJSM with rig crew and fire man. Discuss plan forward for undeploying BHA. Shut down fire work. Undeply BHA #4. Lay down motor. Change out DFS for Baker TT dart sub. Remove checks from UOC and install dummies. Function test BOP rams. Deploy BHA #5, 1.1 deg motor bend, Hycalog bicenter bit, Agitator tool. 540 psi on well after deployment complete. RIH with BHA #5. Stop at 500'. Perform shallow hole test with EDC. Good indication of Agitator vibration at surface. Open EDC. RIH following choke pressure schedule. Pumping thru an open EDC while RIH. Log tie in pass down from 15460'. Make -14' correction. RIH thru window slick. Close EDC. Kick on pumps to full rate, open choke. RIH to resume drilling. No problems down thru the B shale. Not even a bobble on weight. MWD tool comm problems at 17,277' Pull back into liner to trouble shoot MWD. Verify problem is down hole. Pull out of hole to repair MWD. Maintain WHP as per schedule. At surface. Hold PJSM to review undeploy procedure. SIWHP: 750 psi. Undeploy BHA. E-line tests ok. Found short in upper quick disconnecUflow sub. No evidence to indicate failure was related to agitator. Deploy BHA #7 (0.9 mfr w/ HYC bi & agitator). Stab coil. Test MWD. Get on well. Run in hole maintaining WHP as per schedule. Log gr tie in from 15,460'. Subtract 14'. Run in open hole. B shale ok. Smooth to btm. Drill ahead from 18,079' 4100 psi fs C~3 1.41 in/1.32 out. 100-200 DPSI. DHWOB: 0.5-.08 k#. WHP/BHP/ECD: 22/4493/13.4 ppg. IA/OA/PVT: 682!391/319 bbls. I NC/AZM/TF: 91.8/96.7/HS. Weight transfer appears to be improved with agitator. BHA & coil ran straight to btm with no stacking. ROP slow: appear to be on a hard spot. Drilling ahead with slow ROP. String wt = -6000 lbs. DHWOB=900 lbs. We expect ROP of 5 fph once we hit the Kalubik. We may have been just starting in it when we tripped for the Agitator. Plan to continue drilling and examine 18100' bottom up sample. Drilling at 1.3311.27/4200 psi. Reduced PROD1 PROD1 PROD1 PRODi ~ROD1 ~ROD1 'ROD1 'ROD1 'ROD1 'ROD1 9/17/2005 100:00 - 00:45 I 0.751 DRILL I N I DFAL I PROD1 00:45 - 03:00 2.25 DRILL N DFAL PROD1 03:00 - 03:15 0.25 DRILL N DFAL PROD1 03:15 - 05:00 1.75 DRILL N DFAL PROD1 05:00 - 06:00 1.00 DRILL P PROD1 06:00 - 08:30 I 2.50) DRILL I P I I PROD1 Printed: 9/26/2005 9:40:36 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 9/17/2005 06:00 - 08:30 08:30 - 09:25 09:25 - 10:00 10:00 - 10:45 Page 9 of 13 1 D-34 1 D-34 Spud Date: 9/5/2005 DRILL+COMPLETE Start: 9/5/2005 End: 9/22/2005 NORDIC CALISTA Rig Release: 9/22/2005 NORDIC 2 Rig Number: II Hours Task Code' NPT I Phase Description of Operations 2.501 DRILL I P 0.921 DRILL ~ P 0.581 DRILL I P 0.751 DRILL I P 10:45 - 11:30 0.75 DRILL N 11:30 - 15:50 4.33 DRILL N 15:50 - 16:10 0.33 DRILL N 16:10 - 18:30 2.33 DRILL N 18:30 - 19:30 19:30 - 22:30 1.001 DRILL IN 3.001 DRILL I N PROD1 pump rate due to high pressure. Pressure is the result of long coil string, 3-1/2" production tubing friction and the addition of the Agitator. PRODi 18100' sample is consistent with previous samples in the C. We are not in the Kalubik Shale. We do have 10-15% siderite. Able to drill, barely, but not setting any speed records as we are only making about 5 fph. BHI vibration tool does not show significant vibration on or off bottom. On 1J-03 when we picked up off bottom with the Agitator, the Vib tool would immediately go yellow showing significant vibration. It does not do that on this well at this depth. When we pick up off bottom we have to snub to max negative wt to get back to bottom. We may not be getting much benefit from the Agitator in this particular hole configuration. Discuss with town. Mix 40 bbl pill of MI Alpine course beads. Plan to pump it thru an open EDC and see if there is any benefit from reduced backside friction. Current drill solids in mud is at 0.5%. Call for mud swap to see if new mud will help us out. Discuss with Geo and DD the need to point tool face straight up if we are going to achieve the objective of hitting the Kalubik shale prior to being at lockup. PROD1 Begin pumping 42 bbl pill of neat mud with 6#/bbl course Alpine glass beads. Follow by neat mud. PROD1 PU off bottom PU weight with mud on the backside is 26500 Ibs and pumping at 1.27 bpm and 4050 psi. PU 200' pumping at full rate to clean hole. RIH 100' to have BHA in clean hole prior to displacing beads out of BHA. Difficult to RIH, possibly due to proximity to lock up, and cuttings from recent drilling on backside giving us additional friction. Slack off weight at 1.27 bpm is -4000 Ibs. Stop at 18000'. SD pumps. Open EDC. Coil volume = 50.5 bbls. 48.3 bbls since start of pill. 10 bbls into displacement of pill out of EDC pump #1 went down. Swap to pump #2. Begin to make repairs to pump #1. Overdisplace bead pill by 10 bbls. SD pumps. Try to close EDC. DPRB PRODi RIH with pump rate at 1.27 bpm. RIH wt is 1200 Ibs. PU wt is 25 klbs. Significant improvement in slack off weight, slight improvement in PU wt. Could probably drill like this. Unfortunately, the EDC is jammed in the open position, possibly by beads. Try to troubleshoot. Can't get EDC to shut. DPRB PROD1 Need to POOH to c/o EDC. Circulate new mud to bit and perform mud swap while POOH. Pull smooth in open hole and thru the B shale. POOH pumping at full rate in tubing. DPRB PROD1 PJSM prior to undeploying BHA #7. Discuss the EDC which is failed in the open position. Our 2 barriers to flow are the double dart valve sub and the Hydril. DPRB PROD1 Tag up at surface. Trap 770 psi on well. SI pumps. Position BHA for undeployment. Undeploy BHA #7. DPRB PROD1 Deploy BHA #8 (0.9 mtr w/ Hyc bi-center & agitator). Found 527 psi WHP. Stab coil. Test MWD. Get on well. DPRB PROD1 Test agitator at 200'. Working ok. Run in hole. 2nd mud sytem from MI also had a LSRV of 5-6k cp. Decided to treat system in pits while RIH. Lowered pH from 9.5 to 8.5 Printed: 9/26/2005 9:40:36 AM r1 BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 1 D-34 Common Well Name: 1 D-34 Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/5/2005 End: 9/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task 'Code NPT Phase ~ Description of Operations i~' --- - - - ~ -~ - - - -- _.---- 9/17/2005 19:30 - 22:30 ~ 3.00 (DRILL N DPRB I PROD1 ~ and LSRV increased to +/-20,000. Circulate while RIH to treat 22:30 - 23:00 ~ 0.50 ~ DRILL ~ N DPRB ~ PROD1 23:00 - 23:30 I 0.501 DRILL I N I FLUD I PROD1 23:30 - 00:00 0.50 DRILL N DPRB PROD1 9/18/2005 00:00 - 01:00 1.00 DRILL N DPRB PROD1 01:00 - 03:30 2.50 DRILL P 03:30 - 06:00 2.50 DRILL P 06:00 - 07:30 1.50 DRILL P 07:30 - 11:25 3.92 DRILL P 11:25 - 11:40 0.25 DRILL P 11:40 - 12:15 0.58 DRILL P 12:15 - 12:30 0.25 DRILL P 12:30 - 13:30 1.00 DRILL P 13:30 - 15:00 I 1.501 DRILL I P 15:00 - 15:15 0.25 DRILL P 15:15 - 16:45 1.50 DRILL P 16:45 - 19:30 0.00 STKOH P 19:30 - 20:00 0.50 STKOH P 20:00 - 21:15 1.25 STKOH P 21:15 - 22:00 0.75 STKOH P 22:00 - 00:00 9/2005 00:00 - 02:15 02:15 - 04:30 2.001 STKOH I P 2.25 STKOH P 2.25 STKOH P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PRODi PROD1 PROD1 PROD1 PROD1 entire system. Log gr tie in from 15,460'. Subtract 13' correction. Circ press 3900 psi at 1.38 in/1.34 out to continue treating mud system. Continue to circulate above window to condition mud. LSRV avg:21,000. Run in hole. C2 shale ok. Continue to run in hole. Circulate 10 bbls hivis sweep near btm. Drill ahead from 18,129'. 4150 psi @ 1.43 in/1.38 out. DPSI: 100-200. DHWOB: 0.75 - 1.5k#. WHP/BHP/ECD: 11/4360/12.99 ppg. IA/OA/PVT: 671/383/306 bbls. I NC/AZM/TF: 96.8/96.2/HS. 1.4k# do wt. Weight transfer appears improved with new mud. ROP still very low. Drill ahead from 18,147. ROP avg: 8 fph. Mix 80 bbls bead pill at 1.0 ppb. Pump 20 bbls beads. No apparent ROP improvment or weight transfer improvement. Grinding ahead. Making slow ROP of about 5 fph. DHWOB=1200 lbs. String wt = -5000 lbs. PVT=301 bbls. IAP=770 psi, OAP=430 psi. EDC=13.25 ppg, BHP=4446 psi. Drilling at 1.42/1.38/4420 psi. Geo confirms that we are at TD. We have drilled into the Kalubik shale as confirmed by cuttings and GR. This is TD, and gives the Geo a depth to pick the top of the C sand. POH to pick up the sidetrack BHA. Pump 10 bbl high vis sweep. Clean PU at 27 klbs. Clean in open hole and only 2 little wt bobbles with minor motor work thru the B shale interval. Pump at full rate thru an open EDC while POH. PJSM Re: Undeployment of BHA. Shut 2-3/8" Combi rams begin undeployment. Can't bleed down pressure in lubricator. Rams not holding. PJSM with new crew coming on tour, Day crew leaving, night crew swapping to days. Open Combi rams. Open EDC and jet accross rams in case there is debris on them. Shut Combi rams. They hold fine now. Proceed with BHA undeployment. Lay down BHA #8, Pick up BHA #9. Dropped Agitator, picked up BHI FVS and reinstalled checks in UOC. PJSM prior to picking up and deploying BHA #10. Deploy BHA #10, 1.7 degree motor, R-60 sidetrack bit with brass cap. No Agitator in the tool string. RIH with the sidetrack BHA to sidetrack well. Log gr tie in. Subtract 14' correction. Close EDC. Run in hole Tag Kalubik at 18,120'. Taking lots of weight and some motor work. Assume brass nose has been knocked off. Pull up hole to begin troughing. Trough three times at 20' per hour down from 17915' to 17935'. Avg near bit inclination dropped from 90.76 to 90.20 deg. Continue to trough from 17915' to 17935'. Begin time drill sequence at 17,934'. 1' per hr for 3'. After 2.1', Printed: 9/26/2005 9:40:36 AM • • BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date i Name: 1 ell Name: 1 e: Name: From - To - D-34 D-34 DRILL+C NORDIC NORDIC Hours OMPLE CALIS 2 Task _ TE TA Code PT Start Rig Rig Phase Spud Date: 9/5/2005 : 9/5/2005 End: 9/22/2005 Release: 9/22/2005 Number: Description of Operations - ___ 9/19/2005 02:15 - 04:30 2.25 STKOH P I PROD1 appear to be stacking weight with little or no movement of BHA. Need to re group. 04:30 - 06:00 1.50 STKOH P PROD1 Decide to restart time drill sequence. PU 10' for each tenth increment. RIH and stop 0.1' deeper, at a net rate of 1' per hour. 06:00 - 06:45 0.75 STKOH P PROD1 17935.1', Continue with the "Gary Goodrich" technique of time drilling at 1 fph and picking up 10' when getting every new tenth. It seems to be working fine. We get about 150 Ibs on the DHWOB sensor each time we do this, which then drills off to 0 WOB. Continue this at 1 fph to 17936', for a total of 2.0' drilled. 06:45 - 07:50 1.08 STKOH P PROD1 17936', we may be getting sidetracked. Near bit Inc is now ~ 89.7 deg, and was 92 deg in original hole. Continue at 1 fph for a while longer to be conservative. 07:50 - 08:30 0.67 STKOH P ; PRODi Try drilling at 6 fph to see if this is slow enough to sidetrack, but fast enough not to stick slip. We seem to be getting a ~ sidetrack. As we feed in pipe, WOB came up to 550 Ibs. ' ~ Continue at this rate until confirmed sidetracked. 08:30 - 09:30 1.00 STKOH P PROD1 17941'. Begin drilling at 30 fph. WOB=650 lbs. String wt = -3800 Ibs. 1.49/1.45/4060 psi. Free spin is 3980 psi at 1.5 bpm. WOB increasing as we drill ahead. Good sign! 09:30 - 10:00 0.50 STKOH P PROD1 Looks like we have a sidetrack. Need about 20' more, but going to take the time now to ream the window area able. Back ream up at 2 fpm. 10:00 - 10:20 0.33 STKOH P PROD1 Resume drilling sidetrack. 1.50/1.42/4100. DHWOB=600 Ibs. String st = -1000 Ibs. ROP=50 fph. 10:20 - 11:20 1.00 STKOH P PROD1 Good sidetrack completed. Make back reaming pass at 150E at 2 fpm. Ream from 17940'-17910'. Repeat at 150R. 11:20 - 14:45 3.42 STKOH P PROD1 POH to perform BOP test, perform coil slack management, and pick up lateral section BHA. 14:45 - 15:00 0.25 STKOH P PROD1 PJSM re: Undeployment of sidetracking BHA. 15:00 - 16:30 1.50 STKOH P PROD1 Tag up at surface. Undeploy sidetrack BHA following proceedure step by step. 16:30 - 21:00 4.50 BOPSU P PRODi Pressure test BOP stack. Test completed with no failures. Witness by the AOGCC waived by Jeff Jones. 21:00 - 23:00 2.00 DRILL P PROD1 Prep reel and coil for pumping slack. Circulate flo pro back through reel. Can hear a-line moving while reverse circulating. Get off well. RU to cut coil. Cut 155' of coil before finding a-line. 23:00 - 00:00 1.00 DRILL P PROD1 Re-head a-coil with Kendall coil connector. 9/20/2005 00:00 - 01:00 1.00 DRILL P PROD1 Continue to re-head a-coil. Electrical checks, pressure, and pull test. 01:00 - 02:30 1.50 DRILL P PROD1 MU BHA #10 (0.9 mtr w/ HCC bi-cent & agitator). Hold PJSM. Pressure deploy BHA. SIWHP: 341 psi. Stab coil. Test mwd. Get on well. 02:30 - 05:30 3.00 DRILL P PROD1 RIH to 200'. Flow test agitator. Open EDC. Circulate to complete slack management procedure. Continue to RIH maintaining whp as per schedule. 05:30 - 06:00 0.50 DRILL P PROD1 Log gr tie in from 15,450'. Make -13' correction. 06:00 - 07:00 1.00 DRILL P PROD1 Run to bottom. One small weight bobble in B shale, clean the rest of the way to TD. 07:00 - 07:30 0.50 DRILL P PROD1 Smooth thru OH sidetrack at 17935'. Free spin is 4300 psi at 1.4 bpm. No obvious vibration on BHI vib tool downhole either Printed: 9/26/2005 9:40:36 AM • • BP EXPLORATION Page 12 of 13 ~ Operations Summary Report Legal Well Name: 1 D-34 Common Well Name: 1 D-34 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ~, Hours Task Code NPT 9/20/2005 107:00 - 07:30 0.50 DRILL P ` 07:30 - 09:35 I 2.081 DRILL I P 09:35 - 10:00 i 0.421 DRILL I P 10:00 - 10:20 I 0.331 DRILL I N 10:20 - 12:30 I 2.171 DRILL I P 12:30 - 15:15 I 2.751 DRILL I P 15:15 - 16:30 I 1.251 DRILL I P 16:30 - 18:45 I 2.251 DRILL I P 18:45 - 22:25 I 3.671 DRILL I P 22:25 - 23:50 1.42 DRILL P 23:50 - 00:00 0.17 DRILL P 9/21/2005 00:00 - 01:45 1.75 DRILL P 01:45 - 02:45 1.00 DRILL P 02:45 - 03:10 0.42 DRILL P 03:10 - 04:35 1.42 DRILL P 04:35 - 04:40 I 0.081 DRILL I P 04:40 - 05:40 I 1.001 DRILL I P 05:40 - 09:00 3.33 DRILL P 09:00 - 10:00 1.00 DRILL P 10:00 - 10:30 0.50 CASE P 10:30 - 14:00 3.50 CASE P Spud Date: 9/5/2005 Start: 9/5/2005 End: 9/22/2005 Rig Release: 9/22/2005 Rig Number: I Phase Description of Operations PRODi off bottom or on bottom. Tag bottom at 17972'. Begin drilling at 1.4/1.32/4450 psi. ROP = 48 fph. String wt = +500 Ibs, DHWOB=500 Ibs. Seem to have more string wt than we did at this point in the well last time. ROP=50 fph. Maybe getting benefit of the Agitator. Also possibly nice clean hole with new mud. Lets see what happens when we get some cuttings in the hole. Pumping sweeps at 1, 10 bbls sweep of high vis mud each hour. PROD1 ROP building as we drill down structure. Now 70 fpm. String wt = -1200 Ibs. DHWOB=350 lbs. INC=80 deg. PROD1 Wiper trip to shoe Heavy pickup at 37 klbs. Cleaned up to 29 klbs. Pull clean in open hole. PROD1 Found slight dimple in Coil tubing. Examined gripper blocks and found damaged gripper. Change out gripper block. Damage to coil not serious. ', PROD1 Continue wiper trip to window. Pump sweep as we pulled thru B shale. PROD1 Resume drilling. Free spin = 4500 psi at 1.42 bpm. Drilling at 1.42/1.37/4600 psi. String wt = -1300 Ibs. DHWOB=500 psi. ROP = 60 fph. PVT=358 bbls. IAP=700 psi, OAP=405 psi. Getting much better ROP now than before with out the Agitator. If this is the same type of matrix, we have a big improvement in ROP, probably from the Agitator. It would probably be a good idea to get Geologist to give us some more information about lithology so we could draw some conclusions. PROD1 Drill ahead from 18,235'. Rop continue to be 30-50 fph. Weight transfer is good DHWOB: 0.5 - 1.Ok# PROD1 Wiper trip to window. Hole smooth on trip out. Problems with B shale from 16050' to 16195' PVT 387 PROD1 Drill from 18270' 1.26/1.18/4250/110L w/ 100-200 psi dill, 1.5-2.5k wob at 85 deg at 6527' TVD. Drill to 18279' and progress stopped w/ 2.25k wob-tentatively assume B shale (top of B3 later picked at 18300'). Drill ahead slowly and see GR change, but nothing definitive. Point TF straight down at 18300' and drill to 18350' and call TD PROD1 Wiper to window, 32k off bottom. Clean to window PROD1 Pull thru window, clean at 25k. Continue wiper to 10000' PROD1 Continue wiper in liner/tubing to 10000' PRODi Wiper back thru tubulars PROD1 Log tie-in down from 15460', then relog from 15450'. Add 12' PROD1 RIH thru window, clean. Set down at 15731' twice, but spud thru. Wiper to TD 1.12/3740 Had wt loss and MW at 15930'. Start 10 bbls neat 9.9# KW mud followed by 60 bbls KWM w/ 3 ppb beads at 16500' PROD1 Tag at 18350' w/ neat KWF at bit. PUH 28.9k and fin circ beads to bit PROD1 Wiper back to window 1.0/3830 at 50'/min leaving KWF w/ beads in OH. Flag at 15650' EOP PROD1 POOH for liner while finishing displacement to KWF PRODi At surface. Flow check well. Get off well. Unstab coil. LD drilling BHA. RUNPRD RU floor to run liner. Hold PJSM. RUNPRD MU 2-3/8" liner assembly (82 jts of 4.6#, L-80, STL slotted & i Printed: 9/26/2005 9:40:36 AM • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 1 D-34 Common Well Name: 1 D-34 Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/5/2005 End: 9/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2005 Rig Name: NORDIC 2 Rig Number: Date ~, From - To ~ Hours Task Code NPT Phase Description of Operations '~ _~ _~ -_ 9l2il2005 10:30 - 14:00 3.50 CASE P ~ RUNPRD solid). 14:00 - 14:30 0.50 CASE P RUNPRD MU Inteq mwd and GS spear. Stab liner. Stab coil. Test mwd. Get on well. 14:30 - 17:15 2.75 CASE P ~ RUNPRD Run in hole at 80 fpm. 6k# dn, 32k# up wt at 15650'. Through window ok at 30 fpm. Continue at 50 fpm. Through "B" interval ok. See flag #1 3T deep 17:15 - 18:10 0.92 CASE P RUNPRD Continue RIH w/ liner in OH wlo pump wl nary a bobble. Final RIH wt 4.2k at 50'/min 18:10 - 18:30 0.33 CASE P 'RUNPRD Park at second flag at 18330' CTD (which should put BOL at 18294'). Bring pump to 1.4/4500 psi and release at 24.5k. PUH 25k to 18030' (to log tie-in at 15650') 18:30 - 19:00 0.50 CASE P RUNPRD Log tie-in down from 18030' 1.0/0.95/3230. Corr -10'. This puts BOL at 18320' and top of deployment sleeve at 15718' (window 15724-730') 19:00 - 19:40 0.67 CASE P RUNPRD Open EDC, reset e-counter to GS depth of 15476'. Begin displacement to 8.45# KCI 1.8/1.55/4000 w/ 13.45 ECD 19:40 - 22:10 2.50 CASE P RUNPRD POOH displacing and recovering 9.9# KWF w/ 8.45# KCI following pressure schedule Safety mtg re: undeploy w/ 800 psi WHP 1 22:10 - 23:15 1.08 CASE P RUNPRD Undeploy w/ 700 psi. SI master and swab w/ 650 psi. LD LRT 23:15 - 23:30 0.25 WHSUR P POST MU nozzle BHA 23:30 - 00:00 0.50 WHSUR P POST RIH w/ nozzle assy to 2500' displacing KCI while pumping 22 bbls diesel 2.0/4000 w/ 800 psi bp. Displace CT w! KCI 9/22/2005 00:00 - 00:30 0.50 WHSUR P POST POOH leaving diesel in top 2500' of hole 1.0/1800 w/ 850 psi by 00:30 - 00:50 0.33 WHSUR P POST SI master, swab, SSV. Bleed off 850 psi whp to tiger tank Safety mtg re: CT pickle job 00:50 - 02:30 1.67 RIGD P POST Finish fill pit #5 w/ FW. Add powdered bleach to pit #4. Pump 10 bbls bleach followed by 60 bbls FW, 5 bbls McOH and 20 bbls inhibited diesel to tiger tank 02:30 - 04:15 1.75 RIGD P POST Safety mtg re: N2 Displace fluids in CT w/ N2 to tiger tank and bleed off 04:15 - 06:00 1.75 RIGD P POST Unstab CT from injector and pull back to reel 06:00 - 07:00 1.00 RIGD P POST Lower reel from rig on to low boy. Haul to SLB yard in Deadhorse. 07:00 - 10:00 3.00 RIGD P POST ND BOPs. Continue to clean pits. Stage equipment on location for move. Switch camp power off rig system. Release rig at 1000 hrs on 9-22-05 10:00 - 13:30 3.50 RIGD P POST Hold pre move PJSM with rig crew. Back off well. Stage on pad while rig mat placement is completed. 13:30 - 18:00 4.50 MOB P PRE Move from 1 D pad to 1 B pad. Printed: 9/26/2005 9:40:36 AM ~~~~ ConotoPhillips aker Hughes INTE Baker Hughes INTEQ Survey ~~~~ ~ Gas Conn-~'G-'s~art~~- Company: ConocoPhillips Alaska, Inc Date: 9/27/2005 Time: 1131:43 Page: 1 Field: Kuparuk River Unit Co-ordiuate(NE) Refereace: Well: 34, True North Site: Pad 1 D Vertical (TVD) Refereace: Wellhead(106') 106.0 Well: 34 Section (VS) Refereace: Well (O.OON,O.OOE,90.OOAzi) Wellpath: 1 D-34L1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086.90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 34 Slot Name: Well Position: +N/-S -447.33 ft Northing: 5959218.83 ft Latitude: 70 17 56.916 N +E/-W -419.97 ft Easting : 560670.62 k Longitude: 149 30 31.150 W Position Uncertainty; 0.00 ft Wellpath: 1 D-34L1 Drilled From: 1 D-34L1 PB1 Tie-on Depth: 17915.00 ft Current Datum: Wellhead(106') Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/12/2005 Declination: 24.24 deg Field Strength: 57610 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 90.00 Survey Program for Definitive Wellpath Date: 9!20/2005 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 100.00 1465.00 PGMS<0 - 1465'> (100.00-1465.00) (0) Good gyro Good Gyro 1559.71 15699.57 MWD<1560-16053'> (1559.71-16053.00) (O)AWD MWD -Standard 15724.00 17875.66 MWD (15724.00-18173.00) (1) MWD MWD -Standard 17915.00 18350.00 MWD (17915.00-18350.00) MWD MWD -Standard Annotation MD TVD ft ft 17875.66 6590.21 TIP 17915.00 6589.52 KOP 18350.00 6646.27 TD Survey: MWD Start Date: 9/20/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path a~> -~~8 .. ' ~ Conoco/Phillips aker Hughes INTEQ Baker Hughes INTEQ Survey Report ~-1r~ ~~~~~ i 1'I fC(~_. Company: ConocoPhillips Alaska, Inc Date: 9/27/2005 Time: 11:31:43 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 34, True North Site: Pad 1D Vertical (TVD) Reference: Wellhead(106') 106.0 Well: 34 Section fVS) Reference: Well (O.OON,O. OOE,90.OOAzi) Weilpath: 1 D-34L1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Aziro TVD SS TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 17875.66 90.42 110.92 6590.21 6484.21 -11176 .22 9246.40 5948118.70 570006.05 9246.40 0.00 MWD 17915.00 91.57 110.17 6589.52 6483.52 -11190. 02 9283.23 5948105.19 570042.99 9283.23 3.49 MWD 17925.38 89.83 112.53 6589.40 6483.40 -11193 .80 9292.89 5948101.49 570052.69 9292.89 28.25 MWD 17957.22 83.21 114.10 6591.33 6485.33 -11206 .37 9322.06 5948089.16 570081.95 9322.06 21.37 MWD 17990.09 80.36 109.18 6596.03 6490.03 -11218 .36 9352.29 5948077.41 570112.27 9352.29 17.16 MWD 18020.72 79.44 105.76 6601.40 6495.40 -11227. 42 9381.05 5948068.59 570141.10 9381.05 11.40 MWD 18051.42 80.23 101.37 6606.82 6500.82 -11234 .50 9410.41 5948061.74 570170.52 9410.41 14.31 MWD 18082.26 81.57 97.60 6611.70 6505.70 -11239. 52 9440.44 5948056.97 570200.59 9440.44 12.83 MWD 18110.96 82.32 93.24 6615.72 6509.72 -11242. 20 9468.73 5948054.52 570228.89 9468.73 15.27 MWD 18140.39 81.67 89.38 6619.82 6513.82 -11242. 87 9497.86 5948054.08 570258.02 9497.86 13.17 MWD 18171.49 81.76 84.13 6624.31 6518.31 -11241. 12 9528.57 5948056.07 570288.72 9528.57 16.71 MWD 18215.21 83.90 76.91 6629.77 6523.77 -11233. 98 9571.32 5948063.56 570331.41 9571.32 17.10 MWD 18245.76 85.04 72.04 6632.72 6526.72 -11225. 84 9600.61 5948071.94 570360.63 9600.61 16.30 MWD 18305.33 82.44 63.27 6639.23 6533.23 -11203. 36 9655.33 5948094.85 570415.15 9655.33 15.27 MWD 18316.34 80.72 63.48 6640.84 6534.84 -11198. 48 9665.06 5948099.81 570424.85 9665.06 15.74 MWD 18350.00 80.72 63.48 6646.27 6540.27 -11183. 65 9694.79 5948114.88 570454.45 9694.79 0.00 MWD __ o ~ zoa~ Conoc~hillips aker Hughes INTEQ ~~~ Raker Anahec TNTF,(1 Cl1rVPV >~~a-~ & G8S Gon~• Co_ x:, ~ ~.~ Company: ConocoPhillips Alaska, Inc Date: 9/27/2005 Timer 11:27:58 .Page: 1 Field: Kuparuk River Unit Co-ordiaate(NE) Reference: Well: 34, True North Sste: Pad 1D Vertical (TVD) Reference: Wellhead(106') 106.0 Well: 34 Section (VS) Reference: Welt (O.OON,O.OOE,90.OOAzi) Wellpath: 1 D-34L1 PB1 Survey Calculation Method.: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086.90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 34 Slot Name: Well Position: +N/-S -447.33 ft Northing: 5959218.83 ft Latitude: 70 17 56.916 N +E/-W -419.97 ft Easting : 560670.62 ft Longitude: 149 30 31.150 W Position Uncertainty: 0.00 ft Wellpath: 1 D-34L1 PB1 Drilled From: 1 D-34 Tie-oo Depth: 15699.57 ft Current Datum: Wellhead(106') Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/10/2005 Declination: 24.24 deg Field Strength: 57610 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 90.00 Survey Program for Definitive Wellpath Date: 8/10/2005 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 1465.00 PGMS<0 - 1465'> (100.00-1465.00) (0) Good_gyro Good Gyro 1559.71 15699.57 MWD<1560-16053'> (1559.71-16053.00) (O~AWD MWD -Standard 15724.00 18173.00 MWD (15724.00-18173.00) MWD MWD -Standard Annotation MD TVD ft ft 15699.57 6522.70 TIP 15724.00 6530.93 KOP 18173.00 6573.96 TD Survey: MWD Start Date: 9/15/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Conoco/Philli s ~aker Hu hes INTE p g Q Baker Hughes INTEQ Survey Report Company: ConocoPhillips Alaska, Inc Date: 9!27/2005 Time: 11:27:58 Page: 2 Field: Kuparuk River Unit Co-ordiuate(NE) Reference: Well: 34, True North Site: Pad 1 D Vertical (TVD) Reference: Wellhead(106') 106.0 Well: 34 Section (VS) Reference: Wetl (O.OON,O. OOE,90.OOAzi) Wellpath: 1 D-34L1 P61 Survey Calculatio n Method: Minimum Curvature Db: Oracle Survey MD Inc! Azim TVD SS TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft degl100ft 15699.57 70.36 154.31 6522.70 6416.70 -10898.16 7211.12 5948380.28 567968.79 7211.12 0.00 MWD 15724.00 70.26 154.45 6530.93 6424.93 -10918.90 7221.06 5948359.62 567978.90 7221.06 0.68 MWD 15755.25 73.44 149.91 6540.67 6434.67 -10945.15 7234.92 5948333.49 567992.98 7234.92 17.15 MWD 15786.99 75.46 145.42 6549.18 6443.18 -10970.97 7251.28 5948307.80 568009.54 7251.28 15.04 MWD 15813.83 77.77 141.71 6555.39 6449.39 -10991.97 7266.79 5948286.93 568025.21 7266.79 15.96 MWD 15839.26 78.94 138.24 6560.53 6454.53 -11011.04 7282.80 5948268.00 568041.38 7282.80 14.13 MWD 15869.44 79.11 133.04 6566.28 6460.28 -11032.22 7303.51 5948246.99 568062.25 7303.51 16.92 MWD 15902.63 82.50 129.35 6571.58 6465.58 -11053.78 7328.16 5948225.63 568087.07 7328.16 14.99 MWD 15936.07 86.27 128.37 6574.85 6468.85 -11074.66 7354.07 5948204.96 568113.15 7354.07 11.64 MWD 15967.01 90.26 125.40 6575.79 6469.79 -11093.22 7378.80 5948186.61 568138.02 7378.80 16.07 MWD 16000.81 92.38 122.05 6575.01 6469.01 -11111.97 7406.90 5948168.08 568166.27 7406.90 11.73 MWD 16030.52 91.43 118.68 6574.02 6468.02 -11126.98 7432.51 5948153.28 568192.01 7432.51 11.78 MWD 16060.77 92.32 116.63 6573.03 6467.03 -11141.01 7459.29 5948139.47 568218.89 7459.29 7.38 MWD 16090.46 91.92 113.83 6571.94 6465.94 -11153.66 7486.13 5948127.04 568245.83 7486.13 9.52 MWD 16121.63 92.26 107.90 6570.80 6464.80 -11164.75 7515.22 5948116.19 568275.01 7515.22 19.04 MWD 16150.30 92.41 104.26 6569.63 6463.63 -11172.68 7542.74 5948108.48 568302.59 7542.74 12.70 MWD 16180.64 89.03 96.08 6569.25 6463.25 -11178.03 7572.57 5948103.37 568332.46 7572.57 29.17 MWD 16210.02 88.39 87.17 6569.91 6463.91 -11178.86 7601.90 5948102.77 568361.79 7601.90 30.40 MWD 16241.76 89.89 79.27 6570.39 6464.39 -11175.12 7633.39 5948106.77 568393.25 7633.39 25.33 MWD 16282.64 94.84 83.85 6568.70 6462.70 -11169.13 7673.77 5948113.09 568433.57 7673.77 16.49 MWD 16310.10 91.95 88.87 6567.07 6461.07 -11167.39 7701.12 5948115.05 568460.90 7701.12 21.06 MWD 16341.79 92.66 95.06 6565.80 6459.80 -11168.47 7732.75 5948114.22 568492.54 7732.75 19.65 MWD 16369.93 92.22 101.97 6564.60 6458.60 -11172.63 7760.53 5948110.28 568520.35 7760.53 24.58 MWD 16402.25 91.70 102.18 6563.49 6457.49 -11179.39 7792.12 5948103.78 568551.99 7792.12 1.74 MWD 16431.69 90.66 99.55 6562.89 6456.89 -11184.94 7821.02 5948098.47 568580.93 7821.02 9.60 MWD 16461.65 92.22 93.02 6562.13 6456.13 -11188.21 7850.78 5948095.43 568610.71 7850.78 22.40 MWD 16490.86 92.16 89.71 6561.02 6455.02 -11188.91 7879.95 5948094.97 568639.89 7879.95 11.33 MWD 16520.10 92.35 82.81 6559.86 6453.86 -11187.01 7909.09 5948097.11 568669.01 7909.09 23.59 MWD 16550.66 93.02 79.03 6558.43 6452.43 -11182.19 7939.23 5948102.17 568699.10 7939.23 12.55 MWD 16584.19 91.80 75.48 6557.02 6451.02 -11174.80 7971.90 5948109.82 568731.71 7971.90 11.19 MWD 16616.76 95.05 80.64 6555.07 6449.07 -11168.07 8003.69 5948116.80 568763.44 8003.69 18.70 MWD 16649.87 93.08 86.50 6552.73 6446.73 -11164.38 8036.49 5948120.76 568796.21 8036.49 18.63 MWD 16682.24 92.32 90.36 6551.20 6445.20 -11163.49 8068.81 5948121.91 568828.52 8068.81 12.14 MWD 16712.54 90.41 93.72 6550.48 6444.48 -11164.57 8099.08 5948121.07 568858.79 8099.08 12.75 MWD 16742.04 88.48 94.23 6550.76 6444.76 -11166.62 8128.50 5948119.27 568888.23 8128.50 6.77 MWD 16772.90 86.51 99.68 6552.11 6446.11 -11170.35 8159.09 5948115.78 568918.84 8159.09 18.76 MWD 16800.54 85.84 101.87 6553.96 6447.96 -11175.50 8186.18 5948110.85 568945.97 8186.18 8.27 MWD 16830.17 84.67 101.49 6556.41 6450.41 -11181.48 8215.10 5948105.11 568974.93 8215.10 4.15 MWD 16863.83 84.89 98.60 6559.47 6453.47 -11187.33 8248.10 5948099.53 569007.98 8248.10 8.58 MWD 16892.72 85.50 92.69 6561.89 6455.89 -11190.16 8276.74 5948096.93 569036.63 8276.74 20.49 MWD 16924.76 84.76 89.36 6564.61 6458.61 -11190.73 8308.65 5948096.61 569068.55 8308.65 10.61 MWD 16957.21 86.21 84.00 6567.17 6461.17 -11188.85 8340.93 5948098.75 569100.81 8340.93 17.06 MWD 17000.35 86.11 76.12 6570.06 6464.06 -11181.43 8383.30 5948106.51 569143.11 8383.30 18.23 MWD 17036.61 87.19 73.33 6572.18 6466.18 -11171.89 8418.21 5948116.33 569177.94 8418.21 8.24 MWD 17066.55 88.60 76.85 6573.28 6467.28 -11164.20 8447.12 5948124.26 569206.78 8447.12 12.66 MWD 17097.23 86.91 80.75 6574.49 6468.49 -11158.24 8477.19 5948130.46 569236.80 8477.19 13.84 MWD 17135.44 87.04 87.42 6576.50 6470.50 -11154.31 8515.12 5948134.69 569274.69 8515.12 17.44 MWD 17165.46 86.82 90.18 6578.11 6472.11 -11153.69 8545.09 5948135.56 569304.65 8545.09 9.21 MWD 17195.47 86.63 92.74 6579.83 6473.83 -11154.45 8575.03 5948135.04 569334.60 8575.03 8.54 MWD 17224.72 87.96 96.58 6581.21 6475.21 -11156.82 8604.15 5948132.90 569363.73 8604.15 13.88 MWD 1726'1.89 $7.34 . 101.24 6582.73, 6476.73 -11162.57 8640.83 594$127.45. 569400.45 8640.83 12.64 MWD 17295.59 87.93 100.52 6584.12 6478.12 -11168.93 8fi73.89 5948121.36 569433.57 8673.89 2.76 MWD 17327.63 87.99 95.49 6585.27 6479.27 -11173.39 8705.59 5948117.16 569465.30 8705.59 15.69 MWD Conoc Phi~~i ~aker Hughes INTEQ ps Baker Hughes INTEQ Survey Report ~ ~'rr e:~•rEC~ ____~ Company: ConocoPhillips Alaska, Inc Date: 9/27/2005 Time: 11:27:58 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 34, True North Site: Pad 1D Vertical (TVD)Reference: Wellhead(106') 106.0 Well: 34 Section (VS) Reference: Welt (O.OON,O.OOE,90.OOAzi) Wellpatb: 1D-341.1PB1 Survey Calculation Metbod: Minimum Curvature Db: Oracle Survey MD Iocl Azim - TVD SS TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 17360.63 86.63 90.39 6586.81 6480.81 -11175. 08 8738.50 5948115.73 569498.21 8738 .50 15.98 MWD 17390.14 88.23 89.78 6588.14 6482.14 -11175. 12 8767.98 5948115.93 569527.69 8767 .98 5.80 MWD 17420.54 88.30 85.98 6589.06 6483.06 -11174. 00 8798.34 5948117.30 569558.04 8798 .34 12.50 MWD 17462.45 87.84 80.88 6590.47 6484.47 -11169. 21 8839.94 5948122.42 569599.59 8839 .94 12.21 MWD 17492.60 87.56 76.48 6591.68 6485.68 -11163. 29 8869.47 5948128.57 569629.07 8869 .47 14.61 MWD 17533.10 89.98 77.38 6592.55 6486.55 -11154. 14 8908.91 5948138.04 569668.43 8908. 91 6.37 MWD 17563.71 90.17 81.53 6592.51 6486.51 -11148. 54 8938.99 5948143.89 569698.47 8938 .99 13.57 MWD 17593.16 89.89 84.27 6592.50 6486.50 -11144. 90 8968.22 5948147.76 569727.66 8968. 22 9.35 MWD 17622.94 90.45 85.95 6592.41 6486.41 -11142. 36 8997.89 5948150.54 569757.30 8997. 89 5.95 MWD 17652.45 90.20 88.74 6592.24 6486.24 -11140. 99 9027.36 5946152.14 569786.76 9027 .36 9.49 MWD 17681.53 90.78 91.65 6591.99 6485.99 -11141. 09 9056.44 5948152.28 569815.84 9056. 44 10.20 MWD 17713.15 89.95 93.92 6591.79 6485.79 -11142. 63 9088.02 5948151.00 569847.42 9088. 02 7.64 MWD 17748.93 91.00 97.49 6591.49 6485.49 -11146. 18 9123.61 5948147.73 569883.04 9123 .61 10.40 MWD 17784.48 90.11 100.05 6591.15 6485.15 -11151. 60 9158.74 5948142.60 569918.21 9158. 74 7.62 MWD 17815.11 90.60 104.22 6590.96 6484.96 -11158. 04 9188.68 5948136.40 569948.20 9188. 68 13.71 MWD 17846.23 90.91 107.48 6590.55 6484.55 -11166. 54 9218.61 5948128.15 569978.19 9218. 61 10.52 MWD 17875.66 90.42 110.92 6590.21 6484.21 -11176. 22 9246.40 5948118.70 570006.05 9246. 40 11.81 MWD 17926.86 91.92 109.94 6589.16 6483.16 -11194. 08 9294.36 5948101.22 570054.16 9294. 36 3.50 MWD 17955.73 92.14 106.99 6588.14 6482.14 -11203. 22 9321.73 5948092.30 570081.59 9321. 73 10.24 MWD 17988.64 92.42 103.89 6586.83 6480.83 -11211. 97 9353.42 5948083.81 570113.35 9353. 42 9.45 MWD 18020.25 9223 99.94 6585.55 6479.55 -11218. 49 9384.32 5948077.54 570144.30 9384. 32 12.50 MWD 18051.82 91.77 96.67 6584.44 6478.44 -11223. 05 9415.53 5948073.23 570175.55 9415. 53 10.45 MWD 18080.76 91.92 96.23 6583.51 6477.51 -11226. 30 9444.28 5948070.22 570204.31 9444. 27 1.61 MWD 18112.10 96.35 93.10 6581.25 6475.25 -11228. 84 9475.42 5948067.92 570235.47 9475. 42 17.29 MWD 18140.29 97.03 88.16 6577.97 6471.97 -11229. 15 9503.41 5948067.84 570263.46 9503. 41 17.57 MWD 18173.00 97.03 88.16 6573.96 6467.96 -11228. 11 9535.85 5948069.15 570295.89 9535. 85 0.00 MWD ' r KRU 1 D-34L1 ConocoPhillips Alaska, Inc. 1 D-34L1 API: 500292297560 Well T :PROD An le TS: d TUBING to-t soaa, OD:3.500 SSSV Type: NIPPLE Orig Com letion: Angle @ TD: 81 deg @ 18350 , io:z.ssz> Annular Fluid: Last W/O: Rev Reason: NEW WELL, GLV DESIGN Reference L 29' RKB Ref L Date: Last U ate: 10/15/2005 Last Ta TD: 18350 ftK6 Last Ta Date: Max Hole An le: 95 de 16617 Casin Strin -COMMON STRINGS Descri lion Size To Bottom ND Wt Grade Thread PRODUCTION 7.000 0 15164 6348 26.00 J-55 BTC MOD _ CONDUCTOR 20.000 0 117 117 91.50 H-40 WELDED SURFACE 9.625 0 9463 4315 40.00 L-80 BTC 1 D-34 LINER TOP 3.500 15000 16048 6573 9.30 L-80 SLHT Window L1 3.500 15724 15730 6533 0.00 Casin Strin - L1 LINER Alternatin slotted/solid i e Descri lion Size To Bottom TVD Wt Grade Thread Li SLOTTED LINER 2.375 15717 18320 6641 4.60 L-80 STL Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 15040 6307 9.30 L-80 EUE 8rd Pertorations Summa Interval TVD Zone Status Ft SPF Date T e Comment 15719 - 15941 6529 - 6575 222 40 9/21/2005 SLOTS Altematin slotted/solid i 16067 - 16733 6573 - 6551 666 40 9/21/2005 SLOTS Altematin slotted/solid i 16796 - 18286 6554 - 6637 1490 40 9/21/2005 SLOTS Alternatin slotted/solid i Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3275 2421 CAMCO KBUG GLV 1.0 RK 0.156 1821 9/27/2005 2 79951 3767 CAMCO KBUG GLV 1.0 BK-5 0.188 1341 9/26/2005 3 10236 4589 CAMCO KBUG GLV 1.0 BK-5 0.188 1323 9/27/2005 4 12059 5239 CAMCO KBUG OV 1.0 BK-5 0.250 0 9/26/2005 5 13583 5790 CAMCO KBUG DMY 1.0 KB-5 0.000 0 8/24/2005 6 14943 6273 CAMCO MMG DMY 1.5 RK 0.000 0 8/24/2005 Other lu s e ui .etc. - L1 LINER JEW ELRY De th TVD T e Descri lion ID 15717 6529 Deploy to L1 BTT SEAL BORE DEPLOYMENT SLEEVE w/3" GS PROFILE 1.920 18286 6637 O-RING BTT O-RING SUB 1.000 Other lu s e ui .etc. -COMMON JEWELRY De th ND T e Descri lion ID '~ 548 547 NIP CAMCO'DS' NIPPLE w/NO GO PROFILE 2.875 14995 6291 NIP CAMCO 'DS' NIPPLE w/NO GO PROFILE 2.813 15000 6293 TIE BACK SLEEVE BAKER TIE BACK SLEEVE 4.375 15008 6296 PACKER BAKER ZXP LINER TOP PACKER 4.000 ~ 15041 6307 SEAL BAKER GBH-22 17' LONG 5.125" X3" SEAL ASSEMBLY w/15' STROKE 3.000 15086 6322 NIP 'XN' NIPPLE 2.750 15729 6532 Whi stock FLOW-THRU WHIPSTOCK FOR 1 D-34 PERFS 0.000 General Notes Date Note 9/22/2005 MULTI-LATERAL WELL: 1D-31 AND 1D-34L1 Pert ts~is-tssail = - I I I I I I I I I -- -_ 11 /09/04 - STATE O F ALASKA "~ OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to:.tiE~3.. ff`g~ ~ ~~r~'it3 _s~~.k f _.~K,~~. ksr,l', ~€~?::k~~nsi~;r~ ~iattr~:ir3 stat~,.ak.os ........................................k.N........__.._.._..._..................... Contractor: Nordic Rig No.: 2 DATE: 9/19/05 Rig Rep.: Holmes-Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Goodrich-Sarber E-Mails~~~c~~~c~~I~;rE~~~ic~'~~c~~lt?u~~E~E_~~~7:~_~r3 Well Name: 1 D-34L1 PTD # ~?5-128 Operation: Drlg: XXX Test: Initial: Test Pressure: Rams: 250-3500 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P Workover: Weekly: Annular: 250-3500 TEST DATA Test Result P P P BOP STACK: Quantity Size/Type Test Result Stripper 1 2" P Annular Preventer 1 7 1/16" P #1 Rams 1 Blind /Shear P #2 Rams 1 2" Combi P #3 Rams 1 2 3/8" Combi P #4 Rams 1 2" Combi P #5 Rams N/A NA Choke Ln. Valves 1 3 1/8" P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P Check Valve N/A NA CHOKE MANIFOLD: Quantity Test Result No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P Test Results Explor.: Bi-Weekly XXX Valves: 250-3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly NT Lower Kelly NT Ball Type 2 P Inside BOP NT MUD SYSTEM: Visual Alarm Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Quantity Test Result Inside Reel valves 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Closure 2100 P 200 psi Attained 16 sec P Full Pressure Attained 78 sec P Blind Switch Covers: All stations Y Nitgn. Bottles (avg): 4 cLD 2000 Number of Failures: 0 Test Time: 4.5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~~E~~.,_rg~r~~~~g~it3,s~~_tf.~~:u Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES NO X)OC c - Oper./Rig Waived By Jeff Jones c -Database Date 9/19/05 Time 08:00 c -Trip Rpt File Witness Sarber /Goodrich c -Inspector Test start 16:30 Finish 21:00 P P P P P P P P P P Coil Tubing BFL 11/09/04 Nordic 2 BOP 9-19-05p.xls l~ i 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: .EiE"~.. ~f'g~~~~r~i~3_s~~~f,~X:~~ S` c~L;l.~~_~:'...~!' iEt~B1C?£? . ~3f~'nr`t~C~~rIE~'~l_{1::~3`i~iF3_c~f~_E_e bC~l"; 51~;:1{E`t15~£if~,~x.;~~tTEi~3 Stc~'t~;,~?C.~.i:5 Contractor: Nordic Rig No.: 2 DATE: 917105 Rig Rep.: Holmes-Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Eiden-Sarber E-Mail si~~c~~uc~ri~r~€?_±~1t ~fE?U~~?US~tE~E 4r..7„I?~?_~_~~i Well Name: 1 D-34L1 PTD # 205-128 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-3500 Annular: 250-3500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" FP Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 25 sec P No. Valves 14 P Full Pressure Attained 104 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2125 Test Results Number of Failures: 1 Test Time: 10 Hours Components tested 29 Repair or replacement of equipment will be made within 1 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: ~~Eft,-i"E'L~' ~u~t~rri3_~~~_kf_~>t_u Remarks: The kill line HCR failed and was changed out with another and that HCR valve and flanges passed the 250 / 3500 psi test. Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES X)OC NO c - Oper./Rig Waived By c -Database Date 9/6/05 Time 15:00 c -Trip Rpt File Witness Lou Grimald i c -Inspector Test start 12:00 Finish 22:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 9-7-05p.xls 1~ +~,! ~ + • j ~ 'z ' ,~ ~ ,~ ' ~ ~ FRANK H. MURKOWSKI GOVERNOR a ~-7~ OII< ~i`JV t][0-7 333 W. T" AVENUE, SUITE 100 COI1TSFiRQA'1'IOl~T COril-IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Aras Worthington CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1 D-34L 1 ConocoPhillips Alaska Inc. Permit No: 205-128 Surface Location: 447' FNL, 420` FEL, SEC. 23, T 11 N, R 10E, UM Bottomhole Location: 1095' FNL, 3900' FWL, SEC. 3 1, R 11 N, R 11 E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to redrill the above development well. This permit 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 permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of Commission to witness any required test. Contact the Commission's petr field inspector at (907) 659- 3607 (pager). ~..-~ Chairman DATED this~day of August, 2005 Orman cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~! -~~' .~~ '~// f~.~ 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Bfanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: Kuparuk 1D-34L1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 18275 TVD 6529 12. Field /Pool(s): Kuparuk River Field / 4a. Location of Well (Governmental Section): Surface: 447' FNL 420' FEL SEC 23 T11N R10E UM 7. Property Designation: ADL 028248 Kuparuk River Pool , , . , , , Top of Productive Horizon: 790' FNL, 1502' FWL, SEC. 31, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 31, 2005 Total Depth: 1095' FNL, 3900' FWL, SEC. 31, T11N, R11E, UM 9. Acres in Property: 1920 14. Distance to Nearest Property: 1060' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 y- 5959219 Zone- ASP4 10. KB Elevation (Height above GL): 34 feet 15. Distance to Nearest Well Within Pool 1 J-03 is offset by 1325' 16. Deviated Wells: Kickoff Depth: 15721 feet Maximum Hole Angle: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3555 Surface: 2902 18. Casing Program: Size Specit`ications Setting Depth To Bottom uantrty of ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2639' 15711' 6420' 18350' 6479' Uncemented Slotted Liner 1g. PRESENT WELL CONDITIONSUMMARY{To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 16053 Total Depth TVD (ft): 6646 Plugs (measured): None Effective Depth MD (ft): 15981 Effective Depth TVD (ft): 6620 Junk (measured): None Casing Length Size Cement Volume MD TVD n t r 134' 20" 14 cu ds ABI T e III 117' 117' 9463' 9-5/8" 510 sx AS III Lite, 510 sx LiteCrete 9463' 4315' i t 15164' 7" 170 sx Class 'G' 15164' 6348' Pr ction 1049' 3-1 /2" 200 sx Class 'G' 15001' - 16050' 6294' - 6645' Perforation Depth MD (ft): 15700' - 15840' Perforation Depth TVD (ft): 6523' - 6571' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 265-6802 Printed Name Aras orthington Title CT Drilling Engineer Prepared By NamelNumber: Si nature -~`-' Phone 265-6802 Date i ~.~ s~~5 Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ~ -- ~~_ ~ API Number: 50- 029-22975-60-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes No Mud Log Required ^ Yes o Hydro n ulfide Measures ~~Yes ^ No Directional Survey Required Yes ^ No Other. ~ '~ ~~ ~~ ~ ~ ~ ~ ~ APPROVED BY A roved THE COMMISSION Date Form 10-401 I~ised 0 /200 ~""'~ S,(ibmit tin Duplicate K~1 D-34L1 Sidetrack Lateral -Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling unit will drill a lateral in producer KRU 1D-34 using the managed pressure. drilling technique (MPD, see description below). This horizontal lateral will target Kuparuk C sand reserves for production. CTD Drill and Comulete 1D-34 program: Planned for August 31, 2005 Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV 2. Test Packoffs - T&IC 3. Dummy GLV's 4. MIT-IA, MIT-OA 5. Caliper 3-112" liner, memory GL/CCL log 6. Drift tubing/liner with dummy whipstock Rig Work 7. MIRU Nordic 2. NU 7-1/16" BOPE, test. 8. Set 3-1/2" Baker whipstock @ ]5721' md. 9. Mill 2.74" window and 10' of open hole. 10. Drill 3" bicenter hole horizontal lateral from window to 18275' TD targeting Kuparuk C sands. 11. Kill well w/ brine & complete with 2 3/8" slotted liner from TD up into the 3-1/2" liner to 15711' md. 12. ND BOPE. RDMO Nordic 2. Post Rig work 13. Post CTD rig -Run GLVs, obtain SBHP. Mud Program: • Step 9: chloride-based biozan brine (8.6 ppg) • Steps 10: chloride-based Flo-Pro (8.6 ppg) • Steps 1 I: Potassium Formate KWF (10.8 ppg) Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • ID-34L1: 2 3/8", 4.6#, L-80, STL slotted liner from 15,711' and to 18,275' and Casing/Liner Information 9 5/8", L-80, 40#, Burst 5750; collapse 3090 psi. 7", J-55, 26#, Burst 4980; collapse 4320 psi 3'/s", L-80, 9.3#, Burst 10159; collapse 10533 psi Well Control: • Two well bore volumes 0320 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plans for 1D-34L1. STATE OF ALASKA ~,~~, ALASKA ~ AND GAS CONSERVATION COSSION , PERMIT TO DRILL ~uG ~ ~ ~~05 20 AAC 25.005 ~ ~~~~~ ~i! ~~~ ~''°''ss't~~` ia. Type of work ^ Drill ®Redrill ^ Re-Entry ib. Current Well Class ^ Exploratory ®Development ,Q ale Zone ^ Stratigraphic Test ^ Service ^ Develop Gas ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. ell Name and Number: Kuparuk 1 D-34L1 3. Address: Go P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 183 0 ~~ 6479 12. Field /Pool(s): Kuparuk River Field / 4a. Location of Well (Governmental Section): Surface: 44T FNL 420' FEL SEC 23 T11 N R10E UM 7. Prop ' si na ' SAD 8248 Kuparuk River Pool , , . , , , _ To~,nf.-P ~~'~'"` r 790' FNL, 1502' FW L, SEC. 32, T11 N, R11 E, UM d U ermit: 8. L- 13. Approximate Spud Date: August 31, 2005 Total Depth: l 1124' FNL, 3975' FWL S T11N, R11E, U , res in Property: 1920 14. Distance to Nearest Property: 1060' 4b. Location of Well (State Base Plane Coordinates): Surface: x-560671 -5959219 Zo 10. KB Elevation (Height above GL): 34 feet 15. Distance to Nearest Well Within Pool iJ-03 is offset by 1325' 16. Deviated Wells: Kickoff Depth: 57 et Maximum Hole Angle: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3555 Surface: 2902 s. as rig rogram: 'Size S ~ s Setting Depth To "' Bottom uantity o merit c.f. or sacks Hole Casin Wei ht G de Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L 8 STL 2639' 15711' 6420' 18350' 6479' Uncemented Slotted Liner 19. PRESENT ELL CONDITION SUMMARY (To tie completed focRedrill A ND Re-entry Operations) Total Depth MD (ft): 16053 Total De th TVD (ft): 646 Plugs (measured): None Effective Depth MD (ft): 15981 Effective Depth TVD (ft): 6620 Junk (measured): None Casin Len th Size Cement Volume MD TVD r 34' 20" 14 cu ds ABI T e III 117' 117' 463' 9-5/8" 510 sx AS III Lite, 510 sx LiteCrete 9463' 4315' 15164' 7" 170 sx Class 'G' 15164' 6348' Pro i 1049' 3-1/2" 00 sx Class 'G' 15001' - 16050' 6294' - 6645' Perforation Depth D (ft): 15700' - 15840' Perforation Depth TVD (ft): 6523' - 6571' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 265-6802 Printed Name Aras Worthington • Title CT Drilling Engineer Prepared By Name/NUmber: Si nature Phone 265-6802 Date -~ ~3' Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ~<-- -~ __ API Number: . - _ _____St}- U29 ~2g75-60-Q0_ Permit Approval Date: _- See cover letter for _- s PP P q ~ _ ~ ~_ Conditions of A royal: Hadro1eenRSulfide MeasurQ~-s~Lf Yes ~ No i Dim rre t onaSunre -R `~ Yes ~ No y g ~f~ y equ~red-.-__~'Yes ^ No Other: „~~_- __---- -- ----_ r= ~- APPROVED BY A roved B HE COMMISSION Date Form 10-401 Revised 06/2004 ~ ~~ ~ ~,~ @ ``~ ~"'~ ~,,,. Submit In Duplicate ~1 D-34L1 Sidetrack Lateral - Coile~bing Drilling Summary of Ouerations: A coiled tubing drilling unit will drill a lateral in producer KRU 1D-34 using the managed pre ure drilling technique (MPD, see description beIow). This horizontal IateraI will target Kuparuk C san reserves for production. and Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV 2. Test Packoffs - T&IC ~ 3. Dummy GLV's ,, 4. MIT-IA, MIT-OA 5. Caliper 3-1/2" liner, memory GL/CCL log 6. Drift tubing/liner with dummy whipstock ~~~~' Rig Work 7. MIRU Nordic 2. NU 7-1/16" BOPE, test. 8. Set 3-1/2" Baker whipstock @ 15721' md. 9. Mi112.74" window and 10' of open hole. 10. Dri113" bicenter hole horizontal lateral fro 11. Kill well w/ brine & complete with 2 3/8" 12. ND BOPE. RDMO Nordic 2. / Post Rig work 13. Post CTD rig -Run GLVs, obtain Mud Program: • Step 9: chloride-based biozan b ne (8.6 ppg) • Steps 10: chloride-based Flo-P o (8.6 ppg) • Steps l l : Potassium Formate WF (10.8 ppg) Disposal: • No annular injection on • Class II liquids to KRU • Class II drill solids to G~ • Class I wastes will go to low to 18350' TD targeting Kuparuk C sands. liner from TD up into the 3-1/2" liner to 15711' md. well. 'ad Class II disposal well & Inject at PBU Drill site 4 3 for disposal. Casing Program: • 1D-34L1: 2 3/8", 4.6# L-80, STL slotted liner from 15,711' and to 18,350' and 9 5/8", L-80, 40#, burst 5750; collapse 3090 psi. 7", J-55, 26#, Bur 4980; collapse 4320 psi 31h", L-80, 9.3#, ,$urst 10159; collapse 10533 psi Well Control: • Two well bore vo umes (320 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plans for 1D-34L1. • ~ K~1 D-34L1 Sidetrack Lateral - Coile~bing Drilling • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1D-34L1 is tJ-03 which is offset by 1325'. KRU boundary is 1060' away. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. Hazards • L1 will not cross any mapped faults, but loss circulation is a risk due to the measured depth causing high. ECD's. • Expect to encounter increasing pressure as lateral is drilled away from the mother well. • Well 1D-34 has a H2S reading of 124 ppm. Well 1J-03 has a close BHL to 1D-34 and has recorded 58 ppm H2S. All H2S monitoring equipment will be operational. Reservoir Pressure The most recent SBHP survey (May 2005) was gauged at 2,887 psi after having been SI for 10 days. Expect to encounter increasing pressure as lateral is drilled away from mother well. Max. expected pressure of 3555 psi (original reservoir pressure). The EMW is 10.5 ppg at 6530' TVD (L1 KOP). Max. surface pressure with gas (0.1 psi/ft) to surface is 2902 psi. Variance request • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 1D- 34L1 it will be routine to close the 2-3/8" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). This well does not have a tubing retrievable sub-surface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3550 psi at 6635' TVD, 10.3 ppg EMW. • Expected annular friction losses while circulating: 1460 psi (based on 80 psi/100 ft) • Planned mud density: 8.6 ppg equates to 2967 psi hydrostatic bottom hole pressure. • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 4429 psi or 12.8 ppg ECD • When circulation is stopped, a minimum of 730 psi surface pressure will be applied to maintain a 100 psi overbalance on the reservoir. • • KRU 1 D-34 ConocoPhillips Alaska, Inc. KRU 1 D-34L1 Producer Proposed Completion 3-1/2" Camco DB nipple, 2.875" min ID at 547' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing Conoco hilli s - p Alaska, Inc. 3-Yz" Camco KBUG GLM C~3 3275', 7995', 10326', 12059', & 13683' MD 9-5/8" 40# L-80 ~ 9463' 7" 2s# L-8o ~ 15164' MD L1 KOP 15721' MD Window in 3-1/2" C4 Sand perfs C3/C1 Sand perfs 3-Yz" Camco MMG GLM ~ 14943' MD 3-%z" Camco DS nipple, 2.813" min ID ~ 14995' MD Baker ZXP Packer w/SBE ~ 15,008' MD • ~ 2-3/8" Baker deployment sub ~ 15711' and 1 D-34L1 Lateral, TD C~ 18,275' and - 3 openhole '/z" whipstock 2-3/8" slotted liner 3-1/2" 9.3# L-80 I Fill ~ 16048' MD J 08/12/05 ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~i~ _ __ iNTE,C~._._.___~_ Company: ConocoPhillips Alaska, Ino Date: 8/12/2005 Time: 14:35:00 Page: Y Field:. Kuparuk RiverUnit Co-ord%nate(NE) Reference: Well: 34, True North .Site: Pad 1 D" Vertical (TVD) References , Wellhead(106') 106.0 Weli: 34 Sectioa(VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Wellpathc PIan5, 1 D-34L1 P81 Survey Calculation Method: Minimum Curvature Db; OraGe Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669 .52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086 .90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 34 Slot Name: Well Position: +N/-S -447.33 ft Northing: 5959218 .83 ft Latitude: 70 17 56.916 N +E/-W -419.97 ft Easting : 560670 .62 ft Longitude: 149 30 31.150 W Position Uncertainty: 0.00 ft Wellpath: PIan5, 1 D-34L1 P61 Drilled From: 1 D-34 Tie-on Depth: 15699.57 ft Current Datum: Wellhead(106') Height 106 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/10/2005 Declination: 24.24 deg Field Strength: 57610 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 90.00 Plan: Plan #5 Date Composed: 8/10/2005 Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <- Latitude -> <--...Longitude ---> Name Description TVD +N/-S +E/-W Northing' Easting Deg`Min Sec Deg Min Sec ,.Dip.... Dir. ft , ft ft g ft 1D-34L1PB1 Polygon 106.00 -10904.06 7163.27 5948374.00 567921.00 70 16 9.642 N 149 27 2.631 W -Polygon 1 106.00 -10904.06 7163.27 5948374,00 567921.00 70 16 9.642 N 149 27 2.631 W -Polygon 2 106.00 -11278.53 7340.27 5948001.00 568101.00 70 16 5.957 N 149 26 57.489 W -Polygon 3 106.00 -11276.10 7905.37 5948008.00 568666.00 70 16 5.976 N 149 26 41.040 W -Polygon 4 106.00 -11285.12 9023.44 5948008.00 569784.00 70 16 5.874 N 149 26 8.496 W -Polygon 5 106.00 -11364.73 9840.90 5947935.00 570602.00 70 16 5.081 N 149 25 44.704 W -Polygon 6 106.00 -10972.50 9818.06 5948327.00 570576.00 70 16 8.939 N 149 25 45.354 W -Polygon 7 106.00 -10964.12 8780.00 5948327.00 569538.00 70 16 9.034 N 149 26 15.571 W -Polygon 8 106.00 -10999.38 7449.54 5948281.00 568208.00 70 16 8.702 N 149 26 54.300 W -Polygon 9 106.00 -10864.65 7237.60 5948414.00 567995.00 70 16 10.029 N 149 27 0.466 W 1 D-34L1 P61 Target 2 6558.00 -11172.69 7981.21 5948112.00 568741.00 70 16 6.992 N 149 26 38.829 W 1D-34L1PB1 Target 1 6582.00 -11162.77 7495.23 5948118.00 568255.00 70 16 7.094 N 149 26 52.975 W 1D-34L1P61 Target4 6586.00 -11223.62 9705.02 5948075.00 570465.00 70 16 6.471 N 149 25 48.654 W 1 D-34L1 PB1 Target 3 6606.00 -11162.66 8968.42 5948130.00 569728.00 70 16 7.080 N 149 26 10.093 W Annotation MD TVD -,ft ft 15699.57 6522.70 TIP 15721.00 6529.92 KOP 15741.00 6536.41 End of 9°/100' DLS 15781.00 6548.00 4 ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~^ _ °~~ t 11TEt2 Company: ConocoPhillips Alaska, Inc Date: 8/12/2005 Time: 14:35:00 Page: 2 ..Field: Kuparuk RiverUnit Co-ordioate(NE) Reference: WeIL 34, True North Site: Pad 1D Vertical (TVD)Reterence: WeUhead(106');1.06.0 Well: 34 Section (VS) Reference: Well (O.OON17.00E,90.00Azi) Wellpath: PIan5, 1 D-34L4PB4 Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 16068.08 6579.78 5 16493.08 6560.36 6 16643.08 6557.54 7 16793.08 6561.67 8 17043.08 6576.87 9 17293.08 6591.15 10 17543.08 6603.51 11 17615.00 6605.15 Future KOP for L1 17618.08 6605.14 12 17868.08 6600.35 13 18143.08 6590.97 14 18350.00 6584.90 TD Ptan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft'deg/100ft deg 15699.57 70.36 154.31 6522.70 -10898.16 7211.12 0.00 0.00 0.00 0.00 15721.00 70.27 154.44 6529.92 -10916.36 7219.84 0.71 -0.42 0.61 126.35 15741.00 71.83 153.49 6536.41 -10933.35 7228.15 9.00 7.81 -4.74 330.00 15781.00 74.51 149.33 6548.00 -10966.95 7246.47 12.00 6.70 -10.40 303.30 16068.08 93.00 119.95 6579.78 -11163.46 7447.31 12.00 6.44 -10.23 300.00 16493.08 91.89 68.91 6560.36 -11195.12 7856.74 12.00 -0.26 -12.01 270.00 16643.08 90.25 86.84 6557.54 -11163.77 8002.77 12.00 -1.09 11.95 95.00 16793.08 86.62 104.48 6561.67 -11178.49 8151.37 12.00 -2.42 11.76 101.80 17043.08 86.57 74.43 6576.87 -11176.14 8398.04 12.00 -0.02 -12.02 269.00 17293.08 87.03 104.47 6591.15 -11173.79 8644.77 12.00 0.18 12.02 90.00 17543.08 87.43 74.44 6603.51 -11171.44 8891.61 12.00 0.16 -12.01 270.00 17618.08 90.08 83.04 6605.14 -11156.82 8965.07 12.00 3.53 11.47 73.00 17868.08 92,07 112.98 6600.35 -11191.24 9209.77 12.00 0.80 11.98 86.00 18143.08 91.73 79.97 6590.97 -11221.80 9479.09 12.00 -0.12 -12.01 270.00 18350.00 91.57 104.81 6584.90 -11230.35 9684.13 12.00 -0.08 12.00 90.00 Survey MD Incl Azim SS TVD N/S E/W MspN MapE DLS VS TFO Toot ft deg deg ft ft ft ft ft deg/10Oft ft deg 15700.00 70.36 154.31 6416.84 -10898.53 7211.29 5948379.92 567968.97 0.00 7211.29 0.00 MWD 15721.00 70.27 154.44 6423.92 -10916.36 7219.84 5948362.16 567977.66 0.71 7219.84 126.35 MWD 15725.00 70.58 154.25 6425.26 -10919.75 7221.48 5948358.78 567979.32 9.00 7221.48 330.00 MWD 15741.00 71.83 153.49 6430.41 -10933.35 7228.15 5948345.23 567986.10 9.00 7228.15 330.06 MWD 15750.00 72.43 152.55 6433.17 -10940.99 7232.03 5948337.63 567990.05 12.00 7232.03 303.30 MWD 15775.00 74.10 149.95 6440.37 -10961.97 7243.55 5948316.74 568001.73 12.00 7243.55 303.59 MWD 15781.00 74.51 149.33 6442.00 -10966.95 7246.47 5948311.78 568004.69 12.00 7246.47 304.34 MWD 15800.00 75.66 147.29 6446.89 -10982.58 7256.11 5948296.24 568014.46 12.00 7256.11 300.00 MWD 15821.63 76.99 145.00 6452.00 -11000.02 7267.82 5948278.89 568026.31 12.00 7267.82 300.52 1 D-34L1 15825.00 77.20 144.64 6452.75 -11002.71 7269.71 5948276.22 568028.22 12.00 7269.71 301.07 MWD 15850.00 78.76 142.03 6457.96 -11022.32 7284.31 5948256.73 568042.98 12.00 7284.31 301.15 MWD 15875.00 80.35 139.44 6462.49 -11041.35 7299.88 5948237.83 568058.69 12.00 7299.87 301.69 MWD 15900.00 81.95 136.87 6466.34 -11059.75 7316.35 5948219.56 568075.32 12.00 7316.35 302.16 MWD 15925.00 83.58 134.33 6469.49 -11077.47 7333.70 5948201.99 568092.81 12.00 7333.70 302.56 MWD 15950.00 85.21 131.80 6471.93 -11094.45 7351.88 5948185.15 568111.12 12.00 7351.88 302.88 MWD 15975.00 86.85 129.28 6473.66 -11110.66 7370.83 5948169.10 568130.20 12.00 7370.83 303.12 MWD 16000.00 88.50 126.78 6474.68 -11126.05 7390.51 5948153.87 568150.00 12.00 7390.51 303.30 MWD 16025.00 90.16 124.27 6474.97 -11140.57 7410.85 5948139.51 568170.45 12.00 7410.85 303.40 MWD 16050.00 91.81 121.77 6474.54 -11154.19 7431.81 5948126.07 568191.52 12.00 7431.80 303.43 MWD 16068.08 93.00 119.95 6473.78 -11163.46 7447.31 5948116.93 568207.10 12.00 7447.31 303.39 MWD 16075.00 93.00 119.12 6473.42 -11166.87 7453.32 5948113.57 568213.14 12.00 7453.32 270.00 MWD 16100.00 92.99 116.12 6472.11 -11178.44 7475.44 5948102.18 568235.34 12.00 7475.44 269.96 MWD 16125.00 92.98 113.11 6470.81 -11188.84 7498.14 5948091.96 568258.12 12.00 7498.14 269.80 MWD Conocoi~illips L Baker Hughes INTEQ Baker Hughes INTEQ Planning Report [iVTEt;~ Company: ConocoPhillipsAlaska, Inc Date: 8!1212005 Timer 14:35:00 Fage: 3 Field:. Kuparuk River Unit Co-ordiuate(NE) Reference: Well: 34, True Piorth Site: Pad 1 D Vertical (TVD) Reference: WeNhead(106')106.0 Well: 34 Section (VS) Reference: Well (O.OON ,O,OOE,90.OOAzi) Wellpath: -PIan5, 1D-34L1P61 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc! Azim SS TVD - N!S _ E/W MapN MapE DLS VS TFO Tool ft deg deg.. ft tt ' ft tt ft degl100ft- ft deg 16150.00 92.96 110.11 6469.52 -11198.03 7521.34 5948082.96 568281.40 12.00 7521.34 269.64 MWD 16175.00 92.93 107.11 6468.23 -11206.00 7545.00 5948075.18 568305.12 12.00 7545.00 269.49 MWD 16200.00 92.89 104.10 6466.97 -11212.71 7569.05 5948068.66 568329.22 12.00 7569.05 269.33 MWD 16225.00 92.84 101.10 6465.72 -11218.16 7593.41 5948063.41 568353.62 12.00 7593.41 269.18 MWD 16250.00 92.78 98.10 6464.49 -11222.32 7618.03 5948059.45 568378.27 12.00 7618.03 269.03 MWD 16275.00 92.72 95.09 6463.29 -11225.19 7642.83 5948056.78 568403.09 12.00 7642.83 268.88 MWD 16300.00 92.65 92.09 6462.12 -11226.75 7667.75 5948055.42 568428.02 12.00 7667.75 268.74 MWD 16325.00 92.58 89.09 6460.98 -11227.01 7692.72 5948055.37 568452.99 12.00 7692.72 268.60 MWD 16350.00 92.49 86.09 6459.87 -11225.96 7717.67 5948056.62 568477.93 12.00 7717.67 268.46 MWD 16375.00 92.40 83.09 6458.80 -11223.60 7742.54 5948059.18 568502.77 12.00 7742.54 268.33 MWD 16400.00 92.30 80.08 6457.78 -11219.95 7767.24 5948063.03 568527.45 12.00 7767.24 268.20 MWD 16425.00 92.20 77.08 6456.79 -11215.00 7791,73 5948068.17 568551.89 12.00 7791.73 268.08 MWD 16450.00 92.09 74.08 6455.86 -11208.78 7815.92 5948074.58 568576.03 12.00 7815.92 267.96 MWD 16475.00 91.97 71.08 6454.97 -11201.31 7839.76 5948082.25 568599.80 12.00 7839.76 267.85 MWD 16493.08 91.89 68.91 6454.36 -11195.12 7856.74 5948088.57 568616.73 12.00 7856.74 267.74 MWD 16500.00 91.81 69.74 6454.14 -11192.68 7863.21 5948091.06 568623.18 12.00 7863.21 95.00 MWD 16525.00 91.55 72.73 6453.40 -11184.65 7886.87 5948099.29 568646.77 12.00 7886.87 95.03 MWD 16550.00 91.28 75.72 6452.79 -11177.85 7910.91 5948106.28 568670.76 12.00 7910.91 95.11 MWD 16575.00 91.01 78.71 6452.29 -11172.32 7935.29 5948112.00 568695.08 12.00 7935.29 95.19 MWD 16600.00 90.73 81.70 6451.91 -11168.07 7959.92 5948116.45 568719.67 12.00 7959.92 95.25 MWD 16625.00 90.45 84.68 6451.65 -11165.11 7984.74 5948119.62 568744.47 12.00 7984.74 95.29 MWD 16643.08 90.25 86.84 6451.54 -11163.77 8002.77 5948121.10 568762.49 12.00 8002.77 95.32 MWD 16650.00 90.08 87.66 6451.52 -11163.44 8009.68 5948121.49 568769.39 12.00 8009.68 101.80 MWD 16675.00 89.47 90.59 6451.62 -11163.06 8034.67 5948122.07 568794.38 12.00 8034.67 101.80 MWD 16700.00 88.86 93.53 6451.98 -11163.96 8059.65 5948121.37 568819.36 12.00 8059.65 101.79 MWD 16725.00 88.25 96.47 6452.61 -11166.13 8084.54 5948119.40 568844.27 12.00 8084.54 101.75 MWD 16750.00 87.64 99.41 6453.51 -11169.58 8109.29 5948116.15 568869.04 12.00 8109.29 101.67 MWD 16775.00 87.05 102.35 6454.67 -11174.30 8133.81 5948111.63 568893.59 12.00 8133.81 101.57 MWD 16793.08 86.62 104.48 6455.67 -11178.49 8151.37 5948107.59 568911.18 12.00 8151.37 101.43 MWD 16800.00 86.60 103.65 6456.08 -11180.16 8158.07 5948105.96 568917.90 12.00 8158.07 269.00 MWD 16825.00 86.56 100.65 6457.57 -11185.42 8182.46 5948100.91 568942.33 12.00 8182.46 269:05 MWD 16850.00 86.52 97.64 6459.08 -11189.38 8207.09 5948097.14 568966.99 12.00 8207.09 269.23 MWD 16875.00 86.50 94.64 6460.60 -11192.05 8231.90 5948094.68 568991.82 12.00 8231.90 269.41 MWD 16900.00 86.48 91.63 6462.13 -11193.41 8256.82 5948093.51 569016.74 12.00 8256.81 269.59 MWD 16925.00 86.47 88.62 6463.67 -11193.47 8281.76 5948093.66 569041.69 12.00 8281.76 269.78 MWD 16950.00 86.48 85.62 6465.20 -11192.21 8306.68 5948095.11 569066.59 12.00 8306.68 269.96 MWD 16975.00 86.49 82.61 6466.74 -11189.66 8331.50 5948097.87 569091.39 12.00 8331.50 270.15 MWD 17000.00 86.51 79.61 6468.27 -11185.80 8356.15 5948101.93 569116.00 12.00 8356.15 270.33 MWD 17025.00 86.54 76.60 6469.78 -11180.66 8380.57 5948107.26 569140.37 12.00 8380.57 270.51 MWD 17043.08 86.57 74.43 6470.87 -11176.14 8398.04 5948111.92 569157.81 12.00 8398.04 270.70 MWD 17050.00 86.57 75.26 6471.28 -11174.34 8404.71 5948113.78 569164.46 12.00 8404.71 90.00 MWD 17075.00 86.58 78.27 6472.77 -11168.62 8429.00 5948119.69 569188.70 12.00 8429.00 89.95 MWD 17100.00 86.60 81.27 6474.26 -11164.19 8453.55 5948124.32 569213.22 12,00 8453.55 89.77 MWD 17125.00 86.62 84.28 6475.74 -11161.05 8478.31 5948127.66 569237.94 12.00 8478.31 89.59 MWD 17150.00 86.66 87.28 6477.21 -11159.21 8503.19 5948129.69 569262.81 12.00 8503.19 89.41 MWD 17175.00 86.70 90.29 6478.66 -11158.68 8528.14 5948130.43 569287.75 12.00 8528.14 89.24 MWD 17200.00 86.75 93.29 6480.08 -11159.46 8553.09 5948129.85 569312.70 12.00 8553.09 89.06 MWD 17225.00 86.82 96.29 6481.49 -11161.55 8577.96 5948127.96 569337.58 12.00 8577.96 88.89 M W D 17250.00 86.89 99.30 6482.86 -11164.93 8602.69 5948124.78 569362.34 12.00 8602.69 88.72 MWD 17275.00 86.97 102.30 6484.20 -11169.61 8627.21 5948120.30 569386.89 12.00 8627.21 88.56 MWD 17293.08 87.03 104.47 6485.15 -11173.79 8644.77 5948116.26 569404.49 12.00 8644.77 88.40 MWD 17300.00 87.03 103.64 6485.50 -11175.47 8651.47 5948114.64 569411.20 12.00 8651.47 270.00 MWD ConocoPhillips • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report i~:r~~____P. Company: ConocoPhillips Alaska, inc Dste: 8/12/2005 Time: -14:35:00 Page: 4 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeIL• 34, True. North Site: "Pad 1 D Vertical (TVD) Reference:. Wellhead(106') 106.0 Well: 34 Section (VS) Reference: We44 (O.OON ,O.OOE,90.OOAzi) Wellpath: PIanS, 1 D-34L1 P61 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SS TVD N/S - E/W MapN MapE DLS VS TFO Tool ft deg ::deg ft ft ft ft R degl109ft fl deg 17325.00 87.04 100.64 6486.80 -11180.72 8675.88 5948109.59 569435.65 12.00 8675.88 270.04 -- MWD 17350.00 87.05 97.63 6488.09. -11184.68 8700.53 5948105.82 569460.32 12.00 8700.53 270.20 MWD 17375.00 87.07 94.63 6489.37 -11187.35 8725.35 5948103.36 569485.16 12.00 8725.35 270.35 MWD 17400.00 87.11 91.63 6490.64 -11188.71 8750.28 5948102.20 569510.10 12.00 8750.28 270.51 MWD 17425.00 87.14 88.62 6491.89 -11188.77 8775.24 5948102.34 569535.06 12.00 8775.24 270.66 MWD 17450.00 87.19 85.62 6493.13 -11187.51 8800.18 5948103.80 569559.98 12.00 8800.18 270.81 MWD 17475.00 87.24 82.62 6494.34 -11184.95 8825.01 5948106.56 569584.80 12.00 8825.01 270.96 MWD 17500.00 87.31 79.61 6495.53 -11181.10 8849.68 5948110.61 569609.43 12.00 8849.68 271.10 MWD 17525.00 87.37 76.61 6496.69 -11175.95 8874.12 5948115.95 569633.82 12.00 8874.12 271.25 MWD 17543.08 87.43 74.44 6497.51 -11171.44 8891.61 5948120.61 569651.27 12.00 8891.61 271.39 MWD 17550.00 87.67 75.23 6497.81 -11169.63 8898.28 5948122.47 569657.93 12.00 8898.28 73.00 MWD 17575.00 88.55 78.10 6498.63 -11163.87 8922.59 5948128.43 569682.19 12.00 8922.59 72.97 MWD 17600.00 89.44 80.97 6499.07 -11159.33 8947.16 5948133.16 569706.72 12.00 8947.16 72.87 MWD 17618.08 90.08 83.04 6499.14 -11156.82 8965.07 5948135.82 569724.61 12.00 8965.07 72.82 MWD 17625.00 90.14 83.87 6499.13 -11156.03 8971.94 5948136.67 569731.47 12.00 8971.94 86.00 MWD 17650.00 90.35 86.86 6499.03 -11154.01 8996.86 5948138.89 569756.37 12.00 8996.86 86.00 MWD 17675.00 90.55 89.86 6498.83 -11153.29 9021.84 5948139.80 569781.35 12.00 9021.84 86.01 MWD 17700.00 90.76 92.85 6498.54 -11153.88 9046.83 5948139.41 569806.34 12.00 9046.83 86.04 MWD 17725.00 90.97 95.84 6498.17 -11155.78 9071.76 5948137.72 569831.27 12.00 9071.75 86.07 MWD 17750.00 91.17 98.84 6497.70 -11158.97 9096.54 5948134.73 569856.08 12.00 9096.54 86.12 MWD 17775.00 91.37 101.83 6497.15 -11163.45 9121.13 5948130.44 569880.70 12.00 9121.13 86.17 MWD 17800.00 91.56 104.83 6496.51 -11169.21 9145.44 5948124.88 569905.06 12.00 9145.44 86.24 MWD 17825.00 91.75 107.82 6495.79 -11176.24 9169.42 5948118.05 569929.09 12.00 9169.42 86.32 MWD 17850.00 91.94 110.82 6494.98 -11184.50 9193.00 5948109.98 569952.73 12.00 9193.00 86.40 MWD 17868.08 92.07 112.98 6494.35 -11191.24 9209.77 5948103.37 569969.55 12.00 9209.77 86.50 MWD 17875.00 92.07 112.15 6494.10 -11193.90 9216.15 5948100.77 569975.96 12.00 9216.15 270.00 MWD 17900.00 92.06 109.15 6493.20 -11202.71 9239.53 5948092.15 569999.40 12.00 9239.53 269.97 MWD 17925.00 92.05 106.15 6492.30 -11210.28 9263.33 5948084.77 570023.26 12.00 9263.33 269.86 MWD 17950.00 92.04 103.15 6491.41 -11216.60 9287.50 5948078.65 570047.48 12.00 9287.50 269.75 MWD 17975.00 92.02 100.15 6490.53 -11221.64 9311.97 5948073.80 570071.98 12.00 9311.97 269.65 MWD 18000.00 91.99 97.14 6489.65 -11225.40 9336.67 5948070.25 570096.71 12.00 9336.67 269.54 MWD 18025.00 91.96 94.14 6488.79 -11227.85 9361.53 5948067.99 570121.59 12.00 9361.53 269.44 MWD 18050.00 91.92 91.14 6487.94 -11229.01 9386.48 5948067.04 570146.55 12.00 9386.48 269.33 MWD 18075.00 91.88 88.14 6487.12 -11228.85 9411.47 5948067.40 570171.53 12.00 9411.47 269.23 MWD 18100.00 91.83 85.14 6486.31 -11227.38 9436.41 5948069.07 570196.45 12.00 9436.41 269.13 MWD 18125.00 91.78 82.14 6485.52 -11224.62 9461.24 5948072.04 570221.26 12.00 9461.24 269.03 MWD 18143.08 91.73 79.97 6484.97 -11221.80 9479.09 5948074.99 570239.09 12.00 9479.09 268.94 MWD 18150.00 91.73 80.80 6484.76 -11220.65 9485.91 5948076.20 570245.89 12.00 9485.91 90.00 MWD 18175.00 91.73 83.80 6484.00 -11217.30 9510.67 5948079.75 570270.62 12.00 9510.67 90.03 MWD 18200.00 91.72 86.80 6483.25 -11215.25 9535.57 5948082.00 570295.51 12.00 9535.57 90.12 MWD 18225.00 91.71 89.80 6482.50 -11214.51 9560.55 5948082.94 570320.47 12.00 9560.55 90.21 MWD 18250.00 91.69 92.80 6481.76 -11215.08 9585.53 5948082.57 570345.45 12.00 9585.53 90.30 MWD 18275.00 91.67 95.80 6481.03 -11216.95 9610.44 5948080.90 570370.38 12.00 9610.44 90.39 MWD 18300.00 91.64 98.81 6480.31 -11220.13 9635.23 5948077.92 570395.19 12.00 9635.23 90.47 MWD 18325.00 91.61 101.81 6479.60 -11224.60 9659.81 5948073.65 570419.80 12.00 9659.81 90.56 MWD 18350.00 91.57 104.81 6478.90 -11230.35 9684.13 5948068.10 570444.16 12.00 9684.13 90.64 MWD I LEGEND T Plan: Plan p6 (34/PIan5.10.34LiP81) ~'`I. ~ (16~) Azimuths to True North BP Amoco ~i - ~,(PIan5.1D-31L1) M Magnetic North: 24.24° CrealelieyBilMichaelson oate:ar72i2oo5 BAKER Pkns, 1D-3/L1PB7 - - - 11RII6HE5 by - 7>,~ ~ Ma netiC Field Contact m!o~mauon we~vlTn uruu gg n.as ~o-~t^' Strength: 57670nT Bm Michaelson Dip Angle: 80.76° 6vea. (907) 2s7-s624 a.r..t w.xa.w .ua1 \ 1~~.t1 Dale: B/10/2005 CeIP (907)301-73570 tw.a ra ~aaro.n Model: bggm2004 E-mail. bill mlchaelsonQmteQ.com tua: aw. woo.: r~y.l~nw.nrrlyalttos7 Wtaaaon V Mao OHOJ ~lFM lmn TVD so.oo• om om o.ao -10200 .. - I - REFERENCE INFORMATION ~ I I 1 1 ~ I 1 I~ ~ I I - i I ~ I ~~: I 1 -10300 ~- +~-f-*1 rr 1 +i- y r ~- {- 1 1 Co-oNinate (N/E) Relere ce: Well Centre. 34 Trua NoM I 1 ( -' t I I Vertlcal (TVD) Relere System Mean Sea Level ; i ' I ' ; ~ I 1 I ~ 1 ,. ~ { I 1 ~ ~ I I ~I '~F' ~ Sectwn (VS) Relere SI [ (O.OON O.OOE) 1 J Measured Depth Referen W IMead(106) 106.00 -10400 ,- - `i ~ ~ ~ { + `{ ~ . I -+ -I -; 1~ r • ~ I - { , t - ~ t Calwlafion McMod: Minimum Curvature I 1 I, i' ":! I';; I I f 1 ~ ~ I I I I w. ra.. w.s .... ,.,..e -10500 + - +~1 ~ •-i .: `1 +i r -•-~ ++ + ++ i . uwui ~ ntr... ~ _ ~ I I ~ ~ I I ( I ... re r. M ~. I' 1I .I.:^ ly.. 1 1 7 I1 ~I iy - 1- '~':T I ~ - ~ ! i 1 I I I. ~ imi~ r~ ip'~'~'.Iys 1lr..Y !'.. 1 i - -. I 1 %.'o n... -10600 : t + :_ • ~ . ,. ~ VV I _ 1 . i---+.1- ~ - ~ +r l~ + ~ _r~.,+.. - 7. - ,- r j , i~ m ail I I I j ~, I ~ i~ I I ' : I I , o:i"i C -10700 ~ .. ~. -.~I 11 ,+,~ ~j+ ~t_~~- 1h ~~~~~• ~~jlt .~;~ r - ~ a i~ jl ij II Tt~ i:~' «.n' ~ ~ "°°.rem ~ nP ~ `i'.. t i .. ( l•' I I:.. I I... I + 1( ~ I _ ~ ,I C -10800 u.o..r o.. ~_ ____e y...s Q KOP ,r. ., .,.-..~~ ..m. w .:w sM» ~ -10900 EM Ol9°/100'DLS Po: Porq.° rbram ~~ 'i°°"i W ~ 1 .•nr•xa ,°a.r,°e;?w'%.i emoo :+:nw evae.z vo.n ~-11000 1D-34L1P81 Ta t3 a.. r.• O -1111)0 \ 6 FuIUA I(OP(or L7 1D-31L1PB1 Ta e11 7 6 Z t0.34L1PB1 Tarwt 1 6 9 10 04 PIenS 1D-30L1 .maw ,.rrw .. .-.-11200 11 12 a 7t}3{L1PB1 Ta et2 13 =.r -11300 ~ a To 7 so 1o-a+ 5500 ~ ~-+ ~~ ~ -11400 I -.i,. .. I I 5600 ~ +` I 1 111500 .. III } III I~ ', I I ~ +r ' ~) I : I i ~ ~! II I~ I~:: 111 1 I 5700 , .-. i :: ~ i : -11600 .. 1 - } r - , - ~. __- )- ~ f .. :_ a"r5800 ~ '.. a. - -11700 ...~~;.; rrr r -t. t L 1 I a. + - r ti ~.. I ~ ~ r+ t+ :. C 5900 ~ '. I~ ~'~ 11800 ~. -L_{ I I i I I I I ~-.:-- ~ I '.~ ~1 ~ I~i II I l i I 1 I: ~ (; :' f ;iT is 1 ;;,~ I f I ' I;~ ~ i ,; 11 11!~,~ O ~; r",r6t00 - ~-1 ~-~---G,i 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 d West(-)/East(+) [100ft/in] ep szoo u~i a s3oo - ~v f nP I.. ~~ ~ KOP 70.39L1P81 Ta 11 - 1 6400 -1 - ~ 6 B ~ B Fuwre KOP for L1 1 1 8 I ' I ErM O18'I100'OLS 70 11 12 13 1di TD I 6500 ' h "- 7D-31U PB1 T et 1 - 1D-31L1PB7 Ta [ 2 - .. - .. .-r -~ I 3/ PIanS iD-31L1 I 10-3/L7PBITB t3 F 6600 ~~ C 11134 t+ ! I I I { I ', ; I 6700 I 1 _ ~ i f I- I ~ .~ I ' 1 ~-- I , ~, ~ ~ + I I I ... I ~ ~ i ~ ~ 4 1 I L~~ ~. I. .I ;!'I: I- 1 I I I~~ ~ 1 1~ 6800 -r- a 1--- -t I r + 1~ . I tt I ; I II 14 } ti y- _ +1~ ++. 1 - ~ k `• -r i T+' I i ~ r-. r++ - ,1 6900 4 ~ it I I ~ _ ~ _ ~F-. I~•I..-L-. t '.. ~'~ 11..,,~ ~. („ 1 ~ I' II ~ - ~' 1 ~i ~..I.~I~ ± ~.. ~1 ~. I I I I 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 990010000101001020070300 Vertical Section at 90.00° [100ft/in] PM • Conoco hillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ii14-><-~i1 ~_ Company: ConocoPhillips Alaska, Inc Date: 8/12/2005 Time: 14;35:28 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 34, True North Site:. Pad 1 D Vertical (TVD) Reference: Wellhead(106') 106.0 -Well: 34 Section (VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Wellpath: PIanS, 1D-34L1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086.90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 34 Slot Name: Well Position: +N/-S -447.33 ft Northing: 5959218.83 ft Latitude: 70 17 56.916 N +E/-W -419.97 ft Easting : 560670.62 ft Longitude: 149 30 31.150 W Position Uncertainty: 0.00 ft Wellpath: PIan5, 1D-34L1 Drilled From: PIanS, 1D-34L1P61 Tie-on Depth: 15699.57 ft Current Datum: Wellhead(106') Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/12/2005 Declination: 24.24 deg Field Strength: 57610 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 90.00 Plan: P-an #5 Date Composed: 8/12/2005 Sidetrakfrom L1P61 at 17615'MD Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets Map .Map <-- Latitude -> G-- Longitude ---> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Mi n See Dip. Dir. ft ft ft ft r $ 1D-34L1 Polygon 106.00 -10904.06 7163.27 5948374.00 567921.00 70 16 9.642 N 149 27 2.631 W -Polygon 1 106.00 -10904.06 7163.27 5948374.00 567921.00 70 16 9.642 N 149 27 2.631 W -Polygon 2 106.00 -11278.53 7340.27 5948001.00 568101.00 70 16 5.957 N 149 26 57.489 W -Polygon 3 106.00 -11276.10 7905.37 5948008.00 568666.00 70 16 5.976 N 149 26 41.040 W -Polygon 4 106.00 -11285.12 9023.44 5948008.00 569784.00 70 16 5.874 N 149 26 8.496 W -Polygon 5 106.00 -11364.73 9840.90 5947935.00 570602.00 70 16 5.081 N 149 25 44.704 W -Polygon 6 106.00 -10972.50 9818.06 5948327.00 570576.00 70 16 8.939 N 149 25 45.354 W -Polygon 7 106.00 -10964.12 8780.00 5948327.00 569538.00 70 16 9.034 N 149 26 15.571 W -Polygon 8 106.00 -10999.38 7449.54 5948281.00 568208.00 70 16 8.702 N 149 26 54.300 W -Polygon 9 106.00 -10864.65 7237.60 5948414.00 567995.00 70 16 10.029 N 149 27 0.466 W 1D-34L1 Target 1 6621.00 -11186.64 9460.29 5948110.00 570220.00 70 16 6.838 N 149 25 55.776 W 1D-34L1 Target2 6636.00 -11221.81 9605.02 5948076.00 570365.00 70 16 6.490 N 149 25 51.564 W Annotation MD ft TVD $ 17615.00 6605.15 KOP 17655.00 6607.91 End 20°/100' DLS 17715.00 6613.29 3 17990.00 6620.02 4 18115.00 6620.80 5 18275.00 6635.02 TD ~ • ~ ~~ ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report iw=c~i~---___ Company: ConocoPhillips Alaska, lnc Date: 8/12!2005 Time: 14:35:28. !'age: 2 Field:. Kuparuk River Jnit Co-ordinate(NE) Reference: Well: 34, True North Site: Pad 1D Vertical (1'VD) Reference: Wellhead(106')106.0 Well: 34 Sectioo (VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Wellpatb: PIanS, 1 D-34L1 Survey Calculation Method: -Minimum Curvature Db: Oracle Plan Section Information MD Inc! - Azim TVD +N/-S +E/ W ; DLS Build Turn TFO Target ft deg deg ft ft < ft deg/1 OOft deg/100ft deg/100ft deg 15699.57 70.36 154.31 6522.70 -10898.16 7211.12 0.00 0.00 0.00 0.00 15721.00 70.27 154.44 6529.92 -10916.36 7219.84 0.71 -0.42 0.61 126.35 15741.00 71.83 153.49 6536.41 -10933.35 7228.15 9.00 7.81 -4.74 330.00 15781.00 74.51 149.33 6548.00 -10966.95 7246.47 12.00 6.70 -10.40 303.30 16068.08 93.00 119.95 6579.78 -11163.46 7447.31 12.00 6.44 -10.23 300.00 ~, 16493.08 91.89 68.91 6560.36 -11195.12 7856.74 12.00 -0.26 -12.01 270.00 16643.08 90.25 86.84 6557.54 -11163.77 8002.77 12.00 -1.09 11.95 95.00 16793.08 86.62 104.48 6561.67 -11178.49 8151.37 12.00 -2.42 11.76 101.80 17043.08 86.57 74.43 6576.87 -11176.14 8398.04 12.00 -0.02 -12.02 269.00 17293.08 87.03 104.47 6591.15 -11173.79 8644.77 12.00 0.18 12.02 90.00 ~~, 17543.08 87.43 74.44 6603.51 -11171.44 8891.61 12.00 0.16 -12.01 270.00 17615.00 89.97 82.69 6605.15 -11157.20 8962.01 12.00 3.53 11.47 73.00 17655.00 82.09 84.09 6607.91 -11152.61 9001.62 20.00 -19.69 3.50 170.00 17715.00 87.63 79.46 6613.29 -11144.05 9060.72 12.00 9.23 -7.71 320.00 17990.00 89.64 112.41 6620.02 -11172.14 9330.39 12.00 0.73 11.98 87.00 ', 18115.00 89.65 97.41 6620.80 -11204.21 9450.84 12.00 0.01 -12.00 270.00 18275.00 80.21 80.61 6635.02 -11201.65 9609.43 12.00 -5.91 -10.50 240.00 Survey MD Iacl Azim S5 TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg 'ft ; ft ft ft ft degl100ft ft deg 15700.00 70.36 154.31 6416.84 -10898.53 7211.29 5948379.92 567968.97 0.00 7211.29 0.00 MWD 15721.00 70.27 154.44 6423.92 -10916.36 7219.84 5948362.16 567977.66 0.71 7219.84 126.35 MWD 15725.00 70.58 154.25 6425.26 -10919.75 7221.48 5948358.78 567979.32 9.00 7221.48 330.00 MWD 15741.00 71.83 153.49 6430.41 -10933.35 7228.15 5948345.23 567986.10 9.00 7228.15 330.06 MWD '~ 15750.00 72.43 152.55 6433.17 -10940.99 7232.03 5948337.63 567990.05 12.00 7232.03 303.30 MWD 15775.00 74.10 149.95 6440.37 -10961.97 7243.55 5948316.74 568001.73 12.00 7243.55 303.59 MWD 15781.00 74.51 149.33 6442.00 -10966.95 7246.47 5948311.78 568004.69 12.00 7246.47 304.34 MWD 15800.00 75.66 147.29 6446.89 -10982.58 7256.11 5948296.24 568014.46 12.00 7256.11 300.00 MWD 15825.00 77.20 144.64 6452.75 -11002.71 7269.71 5948276.22 568028.22 12.00 7269.71 300.52 MWD 15850.00 78.76 142.03 6457.96 -11022.32 7284.31 5948256.73 568042.98 12.00 7284.31 301.15 MWD 15875.00 80.35 139.44 6462.49 -11041.35 7299.88 5948237.83 568058.69 12.00 7299.87 301.69 MWD 15900.00 81.95 136.87 6466.34 -11059.75 7316.35 5948219.56 568075.32 12.00 7316.35 302.16 MWD !i 15925.00 83.58 134.33 6469.49 -11077.47 7333.70 5948201.99 568092.81 12.00 7333.70 302.56 M W D 15950.00 85.21 131.80 6471.93 -11094.45 7351.88 5948185.15 568111.12 12.00 7351.88 302.88 MWD 15975.00 86.85 129.28 6473.66 -11110.66 7370.83 5948169.10 568130.20 12.00 7370.83 303.12 MWD 16000.00 88.50 126.78 6474.68 -11126.05 7390.51 5948153.87 568150.00 12.00 7390.51 303.30 MWD 16025.00 90.16 124.27 6474.97 -11140.57 7410.85 5948139.51 568170.45 12.00 7410.85 303.40 MWD 16050.00 91.81 121.77 6474.54 -11154.19 7431.81 5948126.07 568191.52 12.00 7431.80 303.43 MWD 16068.08 93.00 119.95 6473.78 -11163.46 7447.31 5948116.93 568207.10 12.00 7447.31 303.39 MWD 16075.00 93.00 119.12 6473.42 -11166.87 7453.32 5948113.57 568213.14 12.00 7453.32 270.00 MWD I 16100.00 92.99 116.12 6472.11 -11178.44 7475.44 5948102.18 568235.34 12.00 7475.44 269.96 MWD ~ 16125.00 92.98 113.11 6470.81 -11188.84 7498.14 5948091.96 568258.12 12.00 7498.14 269.80 MWD 16150.00 92.96 110.11 6469.52 -11198.03 7521.34 5948082.96 568281.40 12.00 7521.34 269.64 MWD 16175.00 92.93 107.11 6468.23 -11206.00 7545.00 5948075.18 568305.12 12.00 7545.00 269.49 MWD 16200.00 92.89 104.10 6466.97 -11212.71 7569.05 5948068.66 568329.22 12.00 7569.05 269.33 MWD 16225.00 92.84 101.10 6465.72 -11218.16 7593.41 5948063.41 568353.62 12.00 7593.41 269.18 MWD 16250.00 92.78 98.10 6464.49 -11222.32 7618.03 5948059.45 568378.27 12.00 7618.03 269.03 MWD 16275.00 92.72 95.09 6463.29 -11225.19 7642.83 5948056.78 568403.09 12.00 7642.83 268.88 MWD ~I 16300.00 92.65 92.09 6462.12 -11226.75 7667.75 5948055.42 568428.02 12.00 7667.75 268.74 MWD 16325.00 92.58 89.09 6460.98 -11227.01 7692.72 5948055.37 568452.99 12.00 7692.72 268.60 MWD 16350.00 92.49 86.09 6459.87 -11225.96 7717.67 5948056.62 568477.93 12.00 7717.67 268.46 MWD 16375.00 92.40 83.09 6458.80 -11223.60 7742.54 5948059.18 568502.77 12.00 7742.54 268.33 MWD 16400.00 92.30 80.08 6457.78 -11219.95 7767.24 5948063.03 568527.45 12.00 7767.24 268.20 MWD 16425.00 92.20 77.08 6456.79 -11215.00 7791.73 5948068.17 568551.89 12.00 7791.73 268.08 MWD 16450.00 92.09 74.08 6455.86 -11208.78 7815.92 5948074.58 568576.03 12.00 7815.92 267.96 MWD ~% • • ConocoPhill~ps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report tPlTEi~ Companyc ConocoPhillipsAlaska; Inc Date: 8/12/2005 Time: 14:3528 Page: 3 Field: Kuparuk RiverUnit Co-ordinate(NE) Reference: Well: 34, True North Site: Pad 1D Vertical (TVDp:l3eference: Wellhead(106') 106.0 Well: 34 Section (VS) Reference: Well (O.OON ,O.OOE,90.OOAzi) Wellpath: PIan5, 1 D-34L1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl . _ Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool 'ft deg deg ft ft ft ft ft deg/100ft ft deg 16475.00 91.97 71.08 6454.97 -11201.31 7839.76 5948082.25 568599.80 12.00 7839.76 267.85 MWD 16493.08 91.89 68.91 6454.36 -11195.12 7856.74 5948088.57 568616.73 12.00 7856.74 267.74 MWD 16500.00 91.81 69.74 6454.14 -11192.68 7863.21 5948091.06 568623.18 12.00 7863.21 95.00 MWD 16525.00 91.55 72.73 6453.40 -11184.65 7886.87 5948099.29 568646.77 12.00 7886.87 95.03 MWD 16550.00 91.28 75.72 6452.79 -11177.85 7910.91 5948106.28 568670.76 12.00 7910.91 95.11 MWD 16575.00 91.01 78.71 6452.29 -11172.32 7935.29 5948112.00 568695.08 12.00 7935.29 95.19 M W D 16600.00 . 90.73 81.70 6451.91 -11168.07 7959.92 5948116.45 568719.67 12.00 7959.92 95.25 MWD 16625.00 90.45 84.68 6451.65 -11165.11 7984.74 5948119.62 568744.47 12.00 7984.74 95.29 MWD 16643.08 90.25 86.84 6451.54 -11163.77 8002.77 5948121.10 568762.49 12.00 8002.77 95.32 MWD 16650.00 90.08 87.66 6451.52 -11163.44 8009.68 5948121.49 568769.39 12.00 8009.68 101.80 MWD 16675.00 89.47 90.59 6451.62 -11163.06 8034.67 5948122.07 568794.38 12.00 8034.67 101.80 MWD 16700.00 88.86 93.53 6451.98 -11163.96 8059.65 5948121.37 568819.36 12.00 8059.65 101.79 MWD 16725.00 88.25 96.47 6452.61 -11166.13 8084.54 5948119.40 568844.27 12.00 8084.54 101.75 MWD 16750.00 87.64 99.41 6453.51 -11169.58 8109.29 5948116.15 568869.04 12.00 8109.29 101.67 MWD 16775.00 87.05 102.35 6454.67 -11174.30 8133.81 5948111.63 568893.59 12.00 8133.81 101.57 MWD 16793.08 86.62 104.48 6455.67 -11178.49 8151.37 5948107.59 568911.18 12.00 8151.37 101.43 MWD 16800.00 86.60 103.65 6456.08 -11180.16 8158.07 5948105.96 568917.90 12.00 8158.07 269.00 MWD 16825.00 86.56 100.65 6457.57 -11185.42 8182.46 5948100.91 568942.33 12.00 8182.46 269.05 MWD 16850.00 86.52 97.64 6459.08 -11189.38 8207.09 5948097.14 568966.99 12.00 8207.09 269.23 M W D 16875.00 86.50 94.64 6460.60 -11192.05 8231.90 5948094.68 568991.82 12.00 8231.90 269.41 MWD 16900.00 86.48 91.63 6462.13 -11193.41 8256.82 5948093.51 569016.74 12.00 8256.81 269.59 MWD 16925.00 86.47 88.62 6463.67 -11193.47 8281.76 5948093.66 569041.69 12.00 8281.76 269.78 MWD 16950.00 86.48 85.62 6465.20 -11192.21 8306.68 5948095.11 569066.59 12.00 8306.68 269.96 MWD 16975.00 86.49 82.61 6466.74 -11189.66 8331.50 5948097.87 569091.39 12.00 8331.50 270.15 MWD 17000.00 86.51 79.61 6468.27 -11185.80 8356.15 5948101.93 569116.00 12.00 8356.15 270.33 MWD 17025.00 86.54 76.60 6469.78 -11180.66 8380.57 5948107.26 569140.37 12.00 8380.57 270.51 MWD 17043.08 86.57 74.43 6470.87 -11176.14 8398.04 5948111.92 569157.81 12.00 8398.04 270.70 MWD 17050.00 86.57 75.26 6471.28 -11174.34 8404.71 5948113.78 569164.46 12.00 8404.71 90.00 MWD 17075.00 86.58 78.27 6472.77 -11168.62 8429.00 5948119.69 569188.70 12.00 8429.00 89.95 MWD 17100.00 86.60 81.27 6474.26 -11164.19 8453.55 5948124.32 569213.22 12.00 8453.55 89.77 MWD 17125.00 86.62 84.28 6475.74 -11161.05 8478.31 5948127,66 569237.94 12.00 8478.31 89.59 MWD 17150.00 86.66 87.28 6477.21 -11159.21 8503.19 5948129.69 569262.81 12.00 8503.19 89.41 MWD 17175.00 86.70 90.29 6478.66 -11158.68 8528.14 5948130.43 569287.75 12.00 8528.14 89.24 MWD 17200.00 86.75 93.29 6480.08 -11159.46 8553.09 5948129.85 569312.70 12.00 8553.09 89.06 MWD 17225.00 86.82 96.29 6481.49 -11161.55 8577.96 5948127.96 569337.58 12.00 8577.96 88.89 MWD 17250.00 86.89 99.30 6482.86 -11164.93 8602.69 5948124.78 569362.34 12.00 8602.69 88.72 MWD 17275.00 86.97 102.30 6484.20 -11169.61 8627.21 5948120.30 569386.89 12.00 8627.21 88.56 MWD 17293.08 87.03 104.47 6485.15 -11173.79 8644.77 5948116.26 569404.49 12.00 8644.77 88.40 MWD 17300.00 87.03 103.64 6485.50 -11175.47 8651.47 5948114.64 569411.20 12.00 8651.47 270.00 MWD 17325.00 87.04 100.64 6486.80 -11180.72 8675.88 5948109.59 569435.65 12.00 8675.88 270.04 MWD 17350.00 87.05 97.63 6488.09 -11184.68 8700.53 5948105.82 569460.32 12.00 8700.53 270.20 MWD 17375.00 87.07 94.63 6489.37 -11187.35 8725.35 5948103.36 569485.16 12.00 8725.35 270.35 MWD 17400.00 87.11 91.63 6490.64 -11188.71 8750.28 5948102.20 569510.10 12.00 8750.28 270.51 MWD 17425.00 87.14 88.62 6491.89 -11188.77 8775.24 5948102.34 569535.06 12.00 8775.24 270.66 MWD 17450.00 87.19 85.62 6493.13 -11187.51 8800.18 5948103.80 569559.98 12.00 8800.18 270.81 MWD 17475.00 87.24 82.62 6494.34 -11184.95 8825.01 5948106.56 569584.80 12.00 8825.01 270.96 MWD 17500.00 87.31 79.61 6495.53 -11181.10 8849.68 5948110.61 569609.43 12.00 8849.68 271.10 MWD 17525.00 87.37 76.61 6496.69 -11175.95 8874.12 5948115.95 569633.82 12.00 8874.12 271.25 MWD 17543.08 87.43 74.44 6497.51 -11171.44 8891.61 5948120.61 569651.27 12.00 8891.61 271.39 MWD 17550.00 87.67 75.23 6497.81 -11169.63 8898.28 5948122.47 569657.93 12.00 8898.28 73.00 MWD 17575.00 88.55 78.10 6498.63 -11163.87 8922.59 5948128.43 569682.19 12.00 8922.59 72.97 MWD 17600.00 89.44 80.97 6499.07 -11159.33 8947.16 5948133.16 569706.72 12.00 8947.16 72.87 MWD ~ . ConocoPh~ll~ps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~i'r<~ ~~~>~~._ Company: ConocoPhillips Alaska, inC Field: Kuparuk RiverlJnit Date: ' 8!12/2005 Time:. 14:35:28. Co-ordinate(NE) Reference: We11: 34, True North Page: d Site: Pad 1 D Vertical (TVD) Reference: Wellhead(106') 106.0: WeIL• 34 Sectioq(VS)Reference; Well (O.OON ,O.OOE,90.OOAzi) Wellpath: PIan5, 1 D-34L1, Survey Calculation Metbod: Minimum Curvature 10b: Orate Survey MD Inc! , Azim SS TVD N/S E/W MapN -MapE DLS VS TFO ; Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 17615.00 89.97 82.69 6499.15 -11157.20 8962.01 5948135.41 569721.55 12.00 8962.01 72.82 MWD 17625.00 88.00 83.04 6499.32 -11155.96 8971.93 5948136.74 569731.46 20.00 8971.93 170.00 MWD 17650.00 83.08 83.91 6501.27 -11153.12 8996.69 5948139.77 569756.19 20.00 8996.69 169.99 MWD 17655.00 82.09 84.09 6501.91 -11152.61 9001.62 5948140.33 569761.12 20.00 9001.62 169.93 MWD 17675.00 83.93 82.54 6504.34 -11150.29 9021.33 5948142.80 569780.81 12.00 9021.33 320.00 MWD 17700.00 8624 80.61 6506.49 -11146.64 9045.97 5948146.65 569805.41 12.00 9045.97 320.19 MWD 17715.00 87.63 79.46 6507.29 -11144.05 9060.72 5948149.36 569820.14 12.00 9060.72 320.35 MWD 17725.00 87.69 80.66 6507.70 -11142.33 9070.56 5948151.16 569829.97 12.00 9070.56 87.00 MWD 17750.00 87.85 83.66 6508.67 -11138.92 9095.31 5948154.76 569854.68 12.00 9095.31 86.95 MWD 17775.00 88.02 86.66 6509.57 -11136.81 9120.20 5948157.07 569879.56 12.00 9120.20 86.83 MWD 17800.00 88.20 89.65 6510.39 -11136.01 9145.17 5948158.08 569904.52 12.00 9145.17 86.73 MWD 17825.00 88.37 92.65 6511.14 -11136.51 9170.15 5948157.78 569929.50 12.00 9170.15 86.63 MWD 17850.00 88.56 95.65 6511.81 -11138.32 9195.07 5948156.17 569954.43 12.00 9195.07 86.54 MWD 17875.00 88.75 98.64 6512.40 -11141.43 9219.87 5948153.27 569979.25 12.00 9219.87 86.46 MWD 17900.00 88.94 101.64 6512.91 -11145.83 9244.47 5948149.07 570003.88 12.00 9244.47 86.39 MWD 17925.00 89.13 104.63 6513.33 -11151.50 9268.81 5948143.58 570028.27 12.00 9268.81 86.33 MWD 17950.00 89.33 107.62 6513.66 -11158.45 9292.82 5948136.84 570052.33 12.00 9292.82 86.28 MWD 17975.00 89.52 110.62 6513.92 -11166.63 9316.44 5948128.84 570076.01 12.00 9316.44 86.24 MWD 17990.00 89.64 112.41 6514.02 -11172.14 9330.39 5948123.45 570090.01 12.00 9330.39 86.21 MWD 18000.00 89.64 111.21 6514.09 -11175.85 9339.68 5948119.81 570099.32 12.00 9339.68 270.00 MWD 18025.00 89.64 108.21 6514.24 -11184.28 9363.21 5948111.57 570122.92 12.00 9363.21 270.01 MWD 18050.00 89.65 105.21 6514.40 -11191.47 9387.15 5948104.58 570146.91 12.00 9387.15 270.03 MWD 18075.00 89.65 102.21 6514.55 -11197.40 9411.43 5948098.85 570171.24 12.00 9411.43 270.04 MWD 18100.00 89.65 99.21 6514.70 -11202.04 9436.00 5948094.40 570195.84 12.00 9436.00 270.06 MWD 18115.00 89.65 97.41 6514.80 -11204.21 9450.84 5948092.35 570210.69 12.00 9450.84 270.08 MWD 18125.00 89.05 96.37 6514.91 -11205.41 9460.76 5948091.23 570220.63 12.00 9460.76 240.00 MWD 18150.00 87.56 93.77 6515.65 -11207.62 9485.65 5948089.23 570245.53 12.00 9485.65 240.01 MWD 18175.00 86.06 91.17 6517.04 -11208.70 9510.59 5948088.35 570270.47 12.00 9510.59 240.09 MWD 18200.00 84.58 88.55 6519.08 -11208.64 9535.50 5948088.61 570295.38 12.00 9535.50 240.23 MWD 18225.00 83.11 85.92 6521.76 -11207.44 9560.33 5948090.01 570320.19 12.00 9560.32 240.45 MWD 18250.00 81.65 83.28 6525.08 -11205.11 9584.99 5948092.54 570344.84 12.00 9584.99 240.73 MWD 18275.00 80.21 80.61 6529.02 -11201.65 9609.43 5948096.19 570369.25 12.00 9609.43 241.08 MWD _ LEGEND T Azimuths IO True North Plan: Plen u5 (3d/PIanS, 1D-34L7) ~~.. 31 (10.0 BP Amoco BAKER ~(PWnS,iD-31UPa1 M MagneticNOrth:24.24° createsRy RalMicnaelson ~ate:a/lzrzoo5 Reny. 1DJ1L1 w~~TM OOH ~~~~~~ ~~ Ran a5 ~ Magnetic Field Contact Inrrnmanon Strength: 57610nT &u M~rnae~son .wa,1 oau~ .ar.,a nxy.ur ~r~s, ~osalvn Dip Angle: 80.76° Direct: (907) 267-6624 n..a ra L~ 1L• U Date: B/12/2005 Cell: (907)301.73570 Yrn Model: bggm2004 E-.mad bnL michaelsonQa :nt~, zr~~. 141. ww,nr walw.rl~oaq 1oa.W11 v. ~4 one j ~~efw r°.e,ar~i ro oo.ao• om ooo o.ao '. _- REFERENCE INFORMATION -10700 ~" '.i ~ ~:i ; ~'-Il ~ I~.. ~ I _~II 1 I I i I 1~-. •f 1 '.I I : Co-ord nale N/E Relere ce~ Well C [ '. 34 True NDM 1 I I I I ' 1 _ VeNwl (NDj Relevance Syst Mea Sea Level -10750 t -*-`~-- '-+ 1. 1 -}-~ . ~ -~ -~ +. • , I-}ti -++ r-~+1-- - ~~-+ ~ • ,~ Sectbn (VS Rele ' Slot (O.OON O.OOE) I 1 4 l Measured Depth Refe W Iln ad(106) 106.00 I l I 1 I I' ;" 1 I~ " I 1 f ', calwlaoDn Memod-rrmmcm arvamre -10800 - ~-I I 1 i ~~! 11 ~' .I ~ f t~_- ' ! 1 I~_.~11.::_,I . .... ,._ .~- ~I I`~ ffI~ i IIf 1 i I ~ III ~ f1 I ~II I I ~C•` I~~;'I -losoo i+- ~ ~: .., ~- :~~ :li ., ~.a..a.. ~ ~ _.-~" YIMDT. b.:~ _ .~ r ~ ~ -11000. ~ . ! ,~ ND YO M„sfalbn ~,.. no - si..p. `~ I saw.ls rnlaoo Ka >x, om ~°i°', ' w°~°" ^ 11050 ...: ~- ! .,.y ~ .-.~ #.i! - i I 1111, asot.a~nsas.oo ova m•nao'DU ro-w+r°.q~wr ~ss'iaro ears, vYSm vw + ~ : :I ~;I :'}..:.: F ~ h aaoim m~a.oo a ~ ~ ; seam 1raaD.m ~ 1 1 . I ulaao u1la.oo e Z aea.o: lane.oo m ~.r -11100 Ens YO°n 00'OL +i Q KOP 3 I1 ~ I I °j -11150 ~ 1 1o-3sL1r e~1 PIan51D-31L1 1 I ~ I + I I _ -11200 ;~ .-r { 0 -11250 I1-~ I,.~ r ,~ 1 ~ 131 PIanS 10.31LIP81 } I 6050 ~ f~~ ~ ~ I 7'~ - 10JCL1T~e12 I ~ I 1 ! • I I I -11300 : +,~~ ; t .+t . 6100 '; '.1--~-`F-- `~ ' I ~ I '.+~ +:--t+_.... ~ . fi I ' 'I i . ' I ~ I I i : -11350' ~. r+ ~ ~ I ,.~.-.. -:.. I i , 6150 '~ ~~ ~ f t ~I'. 1 I I , I ~ ~ i ~ I ~ ~ 11400 I .. ~ - I ! L ~ I I ~ .. '. ~ r ; ' I II - -I Il ' ~ {I{ I I 0 6200 ++ :_t+ _~ ~I--- 71 . i - I ~ ,} II 1 I „ 1 -11450 -r -~- I ++; + r 6250 - I, 1 ~ '. I ~~ a ~+`fk ... '~ ..'l _ -, .. ~ l 1'~ ~I I I I .. !.. t ((( 1 ~ i..j f 1 -11500 ~ ~ I 1, e ,. -, - 1 X6300 1.1 - IT~ l ~+ I i `' T" ... 0,6350 --14 ~t _ 8900 8950 9000 9050 9100 9150 9200 9250 9300 9350 9400 9450 9500 9550 9600 9650 9700 9750 9800 9850 9900 99501~001005010100f0150 d I '.~ I~ ~ West(-)/East(+) [50ft/in] ~ V 6450 ~ ~. ~ _ 17 +~ I r ~.' , ; I . 3~ KOP End 20°/100' DL 30 RanS 7D33~1P01 I ' ' ' L f { ~ I H d 6500 - - - - ni54ii i _ 15 - i 1 -t~-I I ~ 1 rr -_ J 1 - ' PIan510.3411 1 _ ~~ i ~. 3 1 5 - iDJILi T--i r++ ~ _ 1, z ., ~ 1 ` 6600 r ~t I ~ l ~~ +{--`-~- + _,_ + ' _ i ~ I ~ 11 1 1 1 i I l 1 I I li, f - I .I { iI i I Vii. 11 ~~~, 1 I l ! ~ ~ I f tt T ::. 6650 I+ I - / : r ' -~ t i +.-- { - ~~ ~ r - F ( ~ ~' ..i r. 1 r + t +~- ~ ._ ~I I I I I 4 ~I I I ',I I I (1 ~ `+ ~ ~ I,.: :1 1~{:1 II 1 I- I II' II~ I, 6700 ,I ~ '~:. .{I ~ ! ._1 i+4~ ri ~~ r,f.~ 1 -+ _ ' .. {*+~i. ~~:.:~,,;~ ~.-I::..I I:~ I' ::.:~ 1~.:.1~ ~ jtl -.~ :l.~l , •;- !I- I.cl 11~ .:1},.. ~"I ~ -II :I ~ ~ -~ .. ~I.. ~1 1... I~ 6750 ..... ,:::., :...'. ~ _ „ I. '.~. ,-~,:I. ,... .... ,..:~. ., ',' ':'.~'~.,. .., ,..: ~ ~ , .. .. !. 1 8550 8600 8650 8700 8750 8800 8850 8900 8950 9000 9050 9100 9150 9200 9250 9300 9350 9400 9450 9500 9550 9600 9650 9700 9750 9800 9850 9900 9950100001005010100f0150102001025010300103501040010450 Vertical Section at 90.00° [50ft/in] • • • Kuparuk DOBCTD BOP configuration 2" CT Well Floor 7 1/16" 5000 psi, RX-46 Tree Size 2 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee I I ~ ~ I I -i SSV Master Valve Base Flan e Page 1 • PERMIT TO DRILL 20 AAC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (Z) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (P~ 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 The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and groduce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Comnany Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH Ali dry ditch sample sets submitted to the SAMPLE 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. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 -Well Name: KUPARUK RIV UNIT 1D-34L1 Program DEV Well bare seg ~ PTD#:2051280 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV 11-OIL GeoArea 890 Unit 11160 On1Off Shore On Annular Disposal ^ Administration 1 Permit fee attached- - - - Yes - - - - - - - - 2 Lease number appropriate - Yes - - - 3 Uni-quewell_nameandnumber________________________-__- __-__--__ Yes_ __,_.._- 4 Well located in.a-defined pool - - Yes - - - - 5 Well locatedproperdistancefromdrillingunit_boundary--------------- --- Yes_ ___________.- _________-.---_______---_________---_______--__-_ ____---__ 6 Well located properdistance-f[omotherwells_____________________ _________Yes_ ___-----____---_ 7 Sufficientacreageayailableindril_lingunit-_____________________ ______ __Yes_ ______. 8 If deviated,is_wellboreplat_included_____-__________________ _______ Yes- _--___________. 9 Operator only affected party- _ _ _ _ _ _ _ _ _ Yes _ - . 10 Ope[atorhasappropriate.bondinforce ------- -- -- --- -- --- -- Yes- ------ - - --- --- -------- - - -- -- -- -- -- --------- 11 Permit can be issued without conservation order - Yes - - - - - Appr Date 12 Permit_can be issued without administrative_approyal - _ - _ - Yes - - _ - - - - - RPC 8/24120D5 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized bylnjection Order # (put-10# in-comments)-(For- NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 Allwells_within114_mileareaofreyiewidentified(Fo[servicewellonly)_______ ________ NA__ ______-______________--__------_--_ _ 16 Pre-produced injector- duration of pre p[oduction less than 3 months_(For_service well-only) - - NA_ _ _ - - 17 AC_MP_FindingofConsistency_hasbeenissued_for-this pro]ect_____-_ -___ ____ NA_- -_-______________________-________. - - Engineering 18 Canduct_orstring_provided_______________________________ --_______ NA_- _ -___-_Con_ductorset-inmot_herbore,-1_D-34-(200-143).__--__-_-______-_-.__ ___-_--__-____-- 19 SurfacecasingprotectsallknownUSDWs_______________________ ________NA-- -___Allaquifers exempted, 40CFR-147.102(b)~3)._..-_--__--__..---_----.----___-__. 20 CMT_vol_ adequate_to circulate_o_n conductor & surf-csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ _ _ Surface casing set and cemented in_ motherbore. _ - - - - - _ - _ _ - _ - _ - _ _ _ _ _ _ - - - _ _ _ _ _ _ . - - - _ _ 21 CMT_vol_ adequate_to tie-in long string to surf csg_ .. _ . - - NA_ _ - - _ Long string set and_cemented in motherbore. --------------------- 22 CMT_willcoverallknow_nproductivehorizons______________________ _ ______No-__ __-_-Slotted linercompletionplanned.______-__-__________--______ 23 Casing designs adequate for C,T,B&-permafr_ost_____-_----------- --------NA___ ___.0[iginalconstructionmet design requirements.-__- --...--___-__.-..--_--__---_.-_--.- 24 Adequate tan_kage_or reserve pit _ _ - - - - _ _ _ _ Yes - - - Rig is-equipped with steetpits.. No rese_n!e_pitplanned, All waste to-approved disposal well(s). 25 Ifa_re-drill,has_a_1.0.403forabandonment been approved_____________ _____ __NA___ --__-______-__. -- 26 Adequate wellboreseparation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ . - . _ . -Proximity analysis performed, Nearest wellbore_is griginal_penetration. Well_paths diverge.. _ _ _ _ _ _ - - _ _ _ - _ 27 If_diverterrequired,doesitmeet_regulations_._______--___________ ________ NA___ ___--BOf?stack_willalready.beinplace,-___-___-_--_--__---_____--_--______-__-_____- Appr Date X 28 Drilling fiuid-program schematic & equip listadequate_ _ _ - _ _ - - - -Yes Mzximum expected formation-pressure 19.5 EMW. Managed-pressure drilling_planned-with 8,6_ppg fluid $pressur TEM 8/24/2005 ' 29 _B_OPEs, do they meet_regulation . - - - _ - - _ - Yes _ - - _ 2 hole volumes of kill_weight fluid_will be on_location-fgr_contingen_cy.- _ - - - ~'~ 30 BOPE_press rating approprate; test to-(put prig m comments) _ . _ _ Yes MASP calculated of 2902 psi Planned BOP_testpressure 3500 psi.- _ _ _ _ _ , _ _ . %r~Y~ °"' Y 31 Choke_manifold complies wlAPl_RP-53 (tulay 84) Yes _ _ _ 32 Work willoccurwilhoutoperationshutdown_-_-_____--__________ ________Yes__ ___----_____-__--________-__--________--_---_____ - -- 33 Is presence-of H2S gas-probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - -1D•34 produces H2S. Mud should preclude H2S on rig.-Rig hassensorsandalarms. - _ _ _ - _ - - . - - - - - - - . 34 Mechanical_cond_ition of wells within AOR verified (FO[sefvice well only) - _ _ - - _ NA_ - _ _ _ - _ - . - Geology 35 Pe[miteanbeissuedwlohydrogen.sul_fidemeasures_________________ __ _____ No--_ _______---_-______-.-__-____ -------------------------------------------- 36 Data_p_resentedon_potentialoverpressurezones---________________ _ ______NA___ ___--_--_________- - - - - Appr Date 37 Seismic analysis of shallow gas_zones- - - _ _ _ - NA - - - - - - - -- RPC 8/2412005 38 Seabed condition survey_(if cff-shore) _ _ - - _ -- NA -- -- -- -- 39 -Contact namelphone for_weekly progress_reports [exploratory only]- NA- - _ _ Geologic i C Engineering P Date Date: C i i Date oner: ommiss ~fi~ omm ss oner: C i ion r ~ C ~~~.~ ~~'~ 8-zs-~s 26 p~ • • Well History File APPENDIX Information of detailed nature that is not particuiarly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. ~I_\ i ,__. **** REEL HEADER **** MWD 06/11/08 BHI Ol LIS Customer Format Tape **** TAPE HEADER **** MWD 05/09/21 C: 973737 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File; ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 15730.0000: Starting Depth STOP.FT 18350.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-34L1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.916"N 149 deg 30' 31.150"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 21-Sep-05 API API NYUMBER: 500292297560 Parameter Information Block #MNEM.UNIT Value Description -- -- ----------- ------------- - - - SECT. 23 Section TOWN.N 11N Township RANG. l0E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casinq Depth OS1 DIRECTIONAL Other Services Line 1 Remarks • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1D-34 through a milled window in 3 1/2" liner. Top of Window 15724.0 ft.MD (6424.9 ft.SSTVD) Bottom of Window 15730.0 ft.MD (6426.9 ft.SSTVD) (8) The interval from 18320 ft.to 18350 ft.MD (6535.4 ft to 6540.3 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1D-34 at 15447.0 ft.MD (6334.5 ft.SSTVD) (10) This wellbore 1D-34L1 was kicked off the plugback wellbore 1D- 34L1PB1 at 17925 ft.MD (6483.35 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units} ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-34L1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-34L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 • • The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 9 Total Data Records: 42 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 50 Minimum record length: 54 Maximum record length: 4124 15730.000000 18350.000000 0.500000 feet records... bytes bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TALE: CONS MNEM VALU -------------------------------- wDFN 1D-34L1.xtf • LCC 150 CN ConocoPhillips Alaska In WN 1D-34L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame {value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 4 Total Data Records: 84 Tape File Start Depth = 15715.500000 Tape File End Depth = 18351.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 92 records... Minimum record length: 22 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/09/21 973737 01 • • **** REEL TRAILER **** MWD 06/11/08 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR 15730.0000 145.0500 15730.5000 82.1600 15800.0000 96.8800 15900.0000 87.0500 16000.0000 141.8700 16100.0000 98.2300 16200.0000 72.9000 16300.0000 101.3500 16400.0000 121.6600 16500.0000 119.6800 16600.0000 124.1800 16700.0000 108.1600 16800.0000 118.3000 16900.0000 107.5500 17000.0000 117.5200 17100.0000 121.2200 17200.0000 132.2200 17300.0000 158.5200 17400.0000 123.9200 17500.0000 145.1300 17600.0000 129.8700 17700.0000 109.7700 17800.0000 130.8500 17900.0000 128.6300 18000.0000 130.8000 18100.0000 97.2500 18200.0000 104.3400 18300.0000 125.7300 18350.0000 -999.2500 Tape File Start Depth = 15730.000000 Tape File End Depth = 18350.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX 15715.5000 -999.2500 15715.7500 -999.2500 15800.0000 96.8800 15900.0000 87.0500 16000.0000 141.8700 16100.0000 98.2300 16200.0000 72.9000 16300.0000 101.3500 16400.0000 121.6600 16500.0000 119.6800 16600.0000 124.1800 16700.0000 108.1600 16800.0000 118.3000 16900.0000 107.5500 17000.0000 117.5200 17100.0000 121.2200 17200.0000 132.2200 17300.0000 158.5200 17400.0000 123.9200 17500.0000 145.1300 17600.0000 129.8700 17700.0000 109.7700 17800.0000 130.8500 17900.0000 128.6300 18000.0000 130.8000 18100.0000 97.2500 18200.0000 104.3400 18300.0000 125.7300 18351.0000 -999.2500 Tape File Start Depth = 15715.500000 Tape File End Depth = 18351.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • • Tape 5ubfile 4 is type: LIS • **** REEL HEADER **** MWD 06/11/08 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/09/18 • ~~N~ JAN 2 ~ 200 973737 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 15730.0000: Starting Depth STOP.FT 18173.0000: Ending Depth 5TEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-34L1PB1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.916"N 149 deg 30' 31.150" W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 18-Sep-05 API API NUMBER: 500292297570 Parameter Information Block #MNEM.UNIT Value Description SECT. 23 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~(~5 - (~~S ~ ICI `e~~~~l r: • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Gamma Sub, Downhole Pressure and Downhole Weight on Bit), a Directional and Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1D-34 through a milled window in 3 1/2" liner. Top of Window 15724 ft.MD (6424.9 ft.SSTVD) Bottom of Window 15730 ft.MD (6426.9 ft.SSTVD) (8) The interval from 18143 ft.to 18173 ft.MD (6472 ft.to 6468 ft.SSTVD) was not logged due to sensor bit offset. (9} Tied to 1D-34 at 15447 ft.MD (6334.5 ft.SSTVD) (10) The well 1D-34L1 was kicked off this plugback wellbore 1D-34L1PB1 at 17925 ft.MD (6483.35 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 64 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-34L1PB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-34L1PB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 4 Total Data Records: 39 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 47 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** MWD .002 1024 15730.000000 18173.000000 0.500000 feet records... bytes bytes *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-34L1PB1.xtf LCC 150 • r1 U CN ConocoPhillips Alaska In WN 1D-34L1PB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 4 Total Data Records: 77 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 85 Minimum record length: 54 Maximum record length: 4124 **** TAPE TRAILER **** MWD 05109/18 973737 01 15730.000000 18173.000000 0.250000 feet records... bytes bytes • • **** REEL TRAILER **** MWD 06/11/08 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR. 15730.0000 145.0500 15730.5000 82.1600 15800.0000 96.8800 15900.0000 87.0500 16000.0000 141.8700 16100.0000 98.2300 16200.0000 72.9000 16300.0000 101.3500 16400.0000 121.6600 16500.0000 119.6800 16600.0000 124.1800 16700.0000 108.1600 16800.0000 118.3000 16900.0000 107.5500 17000.0000 117.5200 17100.0000 121.2200 17200.0000 132.2200 17300.0000 158.5200 17400.0000 123.9200 17500.0000 145.1300 17600.0000 129.8700 17700.0000 109.7700 17800.0000 130.8500 17900.0000 128.6300 18000.0000 112.4200 18100.0000 128.1900 18173.0000 -999.2500 Tape File Start Depth = 15730.000000 Tape File End Depth = 18173.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX 15730.0000 145.0500 15730.2500 113.6050 15800.0000 96.8800 15900.0000 87.0500 16000.0000 141.8700 16100.0000 98.2300 16200.0000 72.9000 16300.0000 101.3500 16400.0000 121.6600 16500.0000 119.6800 16600.0000 124.1800 16700.0000 108.1600 16800.0000 118.3000 16900.0000 107.5500 17000.0000 117.5200 17100.0000 121.2200 17200.0000 132.2200 17300.0000 158.5200 17400.0000 123.9200 17500.0000 145.1300 17600.0000 129.8700 17700.0000 109.7700 17800.0000 130.8500 17900.0000 128.6300 18000.0000 112.4200 18100.0000 128.1900 18173.0000 -999.2500 Tape File Start Depth = 15730.000000 Tape File End Depth = 18173.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • Tape Subfile 4 is type: LIS • **** REEL HEADER **** MWD 06/12/22 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/09/21 973737 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las • RECEIVED JAN 1 a 2007 A18S1(8 ~ & ~ COns• Cp111fnISS1On Anchora~~ Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 15730.0000: Starting Depth STOP.FT 18350.0000: Ending Depth STEP.FT 0.5000: Level Spacinq NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-34L1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.916"N 149 deg 30' 31.150"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 21-Sep-05 API API NYUMBER: 500292297560 Parameter Information Block #MNEM.UNIT Value Description ------------ ---- ------- ----- SECT. --- 23 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ,~° ~`r '~~ dos'- ~a~s ~ ~~c3-a • • (1} All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1D-34 through a milled window in 3 1/2" liner. Top of Window 15724.0 ft.MD (6424.9 ft.SSTVD) Bottom of Window 15730.0 ft.MD (6426.9 ft.SSTVD) (8) The interval from 18320 ft.to 18350 ft.MD (6535.4 ft to 6540.3 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1D-34 at 15447.0 ft.MD (6334.5 ft.SSTVD) (10) This wellbore 1D-34L1 was kicked off the plugback wellbore 1D- 34L1PB1 at 17925 ft.MD (6483.35 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-34L1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-34L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 • The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MGTD 68 1 F/HR 4 4 8 Total Data Records: 63 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 72 Minimum record length: 54 Maximum record length: 4124 15730.000000 18350.000000 0.500000 feet records... bytes bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU • • WDFN 1D-34L1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1D-34L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROP M4JD 68 1 F/HR 4 4 8 Total Data Records: 126 Tape .File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 135 Minimum record length: 54 Maximum record length: 4124 15715.500000 18351.000000 0.250000 feet records... bytes bytes **** TAPE TRAILER **** MWD • • 05/09/21 973737 O1 **** REEL TRAILER **** MWD 06/12/22 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 15730.0000 145.0500 -999.2500' 15730.5000 82.1600 -999.2500 15800.0000 96.8800 46.3500 15900.0000 87.0500 24.6300 16000.0000 141.8700 29.2100 16100.0000 98.2300 71.9200 16200.0000 72.9000 16.7300 16300.0000 101.3500 46.5100 16400.0000 121.6600 85.6300 16500.0000 119.6800 37.6200 16600.0000 124.1800 32.0000 16700.0000 108.1600 58.7700 16800.0000 118.3000 20.4300 16900.0000 107.5500 35.0200 17000.0000 117.5200 55.1300 17100.0000 121.2200 32.5500 17200.0000 132.2200 21.6200 17300.0000 158.5200 19.7200 17400.0000 123.9200 12.7700 17500.0000 145.1300 12.8000 17600.0000 129.8700 30.5700 17700.0000 109.7700 27.9900 17800.0000 130.8500 52.1400 17900.0000 128.6300 30.9400 18000.0000 130.8000 81.6300 18100.0000 97.2500 57.2700 18200.0000 104.3400 27.4000 18300.0000 125.7300 25.8500 18350.0000 -999.2500 16.4900 Tape File Start Depth = 15730.000000 Tape File End Depth = 18350.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 15715.5000 -999.2500 -999.2500 15715.7500 -999.2500 -999.2500 15800.0000 96.8800 46.3500 15900.0000 87.0500 24.6300 16000.0000 141.8700 29.2100 16100.0000 98.2300 71.9200 16200.0000 72.9000 16.7300 16300.0000 101.3500 46.5100 16400.0000 121.6600 85.6300 16500.0000 119.6800 37.6200 16600.0000 124.1800 32.0000 16700.0000 108.1600 58.7700 16800.0000 118.3000 20.4300 16900.0000 107.5500 35.0200 17000.0000 117.5200 55.1300 17100.0000 121.2200 32.5500 17200.0000 132.2200 21.6200 17300.0000 158.5200 19.7200 17400.0000 123.9200 12.7700 17500.0000 145.1300 12.8000 17600.0000 129.8700 30.5700 17700.0000 109.7700 27.9900 17800.0000 130.8500 52.1400 17900.0000 128.6300 30.9400 18000.0000 130.8000 81.6300 18100.0000 97.2500 57.2700 18200.0000 104.3400 27.4000 18300.0000 125.7300 25.8500 18351.0000 -999.2500 -999.2500 Tape File Start Depth = 15715.500000 Tape File End Depth = 18351.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • • Tape Subfile 4 is type: LIS ., {. ~~~ 4 **** REEL HEADER **** MWD 06/12/22 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/09/18 973737 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las RECEIVED JAN 1 0.2007 ~-lask8 0~ & G3S C011S. COtrrr~ion Version Information VERS. 1.20: CWLS loq ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 15730.0000: Starting Depth. STOP.FT 18350.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-34L1PB1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.916"N 149 deg 30' 31.150"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 18-Sep-05 API API NYUMBER: 500292297570 Parameter Information Block #MNEM.UNIT Value Description SECT. 23 Section TOWN.N 11N Township RANG. l0E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks 2os ,a~ ~ -y3~3 • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1D-34 through a milled window in 3 1/2" liner. Top of Window 15724.0 ft.MD (6424.9 ft.SSTVD) Bottom of Window 15730.0 ft.MD (6426.9 ft.SSTVD) (8) The interval from 18143 ft.to 18173 ft.MD (6472 ft to 6468 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1D-34 at 15447.0 ft.MD (6334.5 ft.SSTVD) (10) The wellbore 1D-34L1 was kicked off this plugback wellbore 1D- 34L1PB1 at 17925 ft.MD (6483.35 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN 1D-34L1PB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-34L1PB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 • • The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM - - - ODEP ------------ ---------------------- - -------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 59 Tape File Start Depth = 15730.000000 Tape File End Depth = 18173.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 68 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN 1D-34L1PB1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1D-34L1PB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MwD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 117 Tape File Start Depth = 15716.250000 Tape File End Depth = 18173.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 126 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/09/18 973737 01 **** REEL TRAILER **** MWD 06/12/22 BHI 01 Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes C7 • Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 15730.0000 145.0500 -999.2500 15730.5000 82.1600 -999.2500 15800.0000 96.8800 46.3500 15900.0000 87.0500 24.6300 16000.0000 141.8700 29.2100 16100.0000 98.2300 71.9200 16200.0000 72.9000 16.7300 16300.0000 101.3500 46.5100 16400.0000 121.6600 85.6300 16500.0000 119.6800 37.6200 16600.0000 124.1800 32.0000 16700.0000 108.1600 58.7700 16800.0000 118.3000 20.4300 16900.0000 107.5500 35.0200 17000.0000 117.5200 55.1300 17100.0000 121.2200 32.5500 17200.0000 132.2200 21.6200 17300.0000 158.5200 19.7200 17400.0000 123.9200 12.7700 17500.0000 145.1300 12.8000 17600.0000 129.8700 30.5700 17700.0000 109.7700 27.9900 17800.0000 130.8500 52.1400 17900.0000 128.6300 30.9400 18000.0000 112.4200 37.4500 18100.0000 128.1900 19.7000 18173.0000 -999.2500 6.9100 Tape File Start Depth = 15730.000000 Tape File End Depth = 18173.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 15716.2500 69.4500 -999.2500 15716.5000 74.1800 -999.2500 15800.0000 92.8500 58.4800 15900.0000 91.0100 25.0200 16000.0000 140.4600 28.1800 16100.0000 103.1100 71.4800 16200.0000 77.0800 16.0400 16300.0000 105.7400 45.9200 16400.0000 122.8400 91.1800 16500.0000 118.8900 37.0000 16600.0000 126.7800 32.1600 16700.0000 102.0600 57.8000 16800.0000 110.4800 20.6900 16900.0000 106.5300 34.0500 17000.0000 114.4200 55.0500 17100.0000 115.7400 31.9800 17200.0000 124.6800 21.6200 17300.0000 128.8800 19.5900 17400.0000 154.4000 12.7700 17500.0000 133.0900 15.3900 17600.0000 134.7827 30.5700 17700.0000 123.3600 28.2800 17800.0000 129.9400 52.1400 17900.0000 129.4100 32.6300 18000.0000 113.1100 41.0600 18100.0000 123.1000 20.1000 18173.0000 -999.2500 -999.2500 Tape File Start Depth = 15716.250000 Tape File End Depth = 18173.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • Tape Subfile 4 is type: LIS