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Home My WebLink About203-203 e e 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. ;)03 - ;<03 Well History File Identifier (Count does include cover sheet) ~YES Organizing (done) D Two-sided /I 111111111" 111111 R,CAN \Ø' Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: Date;).. L"i / D (., BY: -~ Project Proofing I Date: d-. ~3 DC, , , x30=be¡ + Date :J-}¡? /()~ BY: .~ Scanning Preparation BY: ~ .1- Production Scanning Stage 1 Page Count from Scanned File: 7 3 Page Count Matches Number in scannrg Pr1Paration: ~ Date: ;)./13/0& If NO in stage 1, page(s) discrepancies were found: BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed III II 1/111111111 III OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: fI1p 151 11111111111 11/111/1 151 mP J a- = TOTAL PAGES I1d- (Count does not include cover J,e~t) ¡f'AP 151 r r ~ 11111111111111 111I1 YES NO I,) ~f NO 151 III 111/1111I1111111 111/111111111111111 151 Quality Checked III 111/111111111111 10/6/2005 Well History File Cover Page.doc • • --,.. MICROFILMED 03/01/2008 DO NOT PLACE _*'~ ~~~ ANY .NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc 1 CJ ~6 DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2032030 Well Name/No. KUPARUK RIV U MELT 2P-424 Operator CONOCOPHILLlPS ALASKA INC ~~ 27 ~À.~~ J API No. 50-103-20475-00-00 MD TVD 5931,/ Completion Status P&A 1 0548 ~ Completion Date 1/10/2004 /' REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Den/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No ¿ Directional Survey -;----a> C Pdt 12481 Induction/Resistivity _"1~b C Lis 12481 Induction/Resistivity _..L~'" Induction/Resistivity Rpt Induction/Resistivity I .-eu C Pdf 12481 Neutron -ÆÖ C Lis 12481 Neutron 7 Neutron Rpt Neutron _/ED C Pdt 12481 Density 25 25 Blu 25 25 Blu 25 Current Status P&A UIC N Directional surve~~D (data taken tram Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received Comments .~ 108 1 0548 Open 2/6/2004 108 1 0548 Open 3/26/2004 Multiple Propagation Resistivity - Gamma Ray - RWD 108 1 0548 Open 3/26/2004 Multiple Propagation Resistivity - Gamma Ray - RWD 108 10548 Open 3/26/2004 Multiple Propagation Resistivity - Gamma Ray - RWD 108 1 0548 Open 3/26/2004 Multiple Propagation Resistivity - Gamma Ray - RWD 108 1 0548 Open 3/26/2004 Caliper Corrected Neutron, Optimized Rotational Density - RWD 108 10548 Open 3/26/2004 Caliper Corrected Neutron, Optimized Rotational Density - RWD 108 10548 Open 3/26/2004 Caliper Corrected Neutron, Optimized Rotational Density - RWD 108 10548 Open 3/26/2004 Caliper Corrected Neutron, Optimized Rotational Density - RWD 108 10548 Open 3/26/2004 Caliper Corrected Neutron, Optimized Rotational Density - RWD . . DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2032030 Operator CONOCOPHILLlPS ALASKA INC Well Name/No. KUPARUK RIV U MELT 2P-424 MD 1 0548 TVD 5931 Completion Date 1/10/2004 Completion Status P&A Current Status P&A ~D C Lis 12481 Density 25 108 10548 Open 3/26/2004 Log ... Density 25 Blu 108 1 0548 Open 3/26/2004 ì ~Pt Density 108 1 0548 Open 3/26/2004 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Çß Chips Received? ~ Daily History Received? Æ~ Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: ~ ----- Date: JhL;?~b . API No. 50-103-20475-00-00 UIC N Caliper Corrected Neutron, Optimized Rotational Density - RWD Caliper Corrected Neutron, Optimized Rotational Density - RWD Caliper Corrected Neutron, Optimized Rotational . Density - RWD . ConocJPhillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 March 16, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ]'h Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2P-424 (APD # 203-203/304-004) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Meltwater well 2P-424. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, T"<~ .~~ \ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad 1.00Á O,l(!G'~J.4L · STATE OF ALASKA a ALA Oil AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas U Plugged D Abandoned 0 20AAC 25.105 No. of Completions _ GINJ D 2. Operator Name: WINJ D WDSPL D ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM At Top Productive Horizon: 2133' FNL, 495' FWL, Sec. 21, T8N, R7E, UM Total Depth: 2623' FSL, 806' FWL, Sec. 21, T8N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 444010 ' y- TPI: x- 447708 y- Total Depth: x- 448017 . y- 18. Directional Survey: Yes 0 NoU 5868966 I 5862438 5861912 . Zone-4 Zone-4 Zone-4 Suspended D WAG D 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: January 10, 2004 6. Date Spudded: December 27,2003 7. Date TD Reached: r' January 6, 2004 8. KB Elevation (It): 28' RKB 9. Plug Back Depth (MD + TVD): 8326' MD I 4886' TVD 10. Total Depth (MD + TVD): ¡ 10548' MD / 5931' TVD I 11. Depth where SSSV set: none 19. Water Depth, if Offshore: NIA feet MSL 1b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: / 203-203 I 304-004 13. API Number. 50-103-20475-00 14. Well Name and Number. 2P-424 15. Field/Pool(s): Kuparuk River Field Meltwater Oil Pool ,/ 16. Property Designation: ADL 373112 I 389058 17. Land Use Permit: L32092 / 32409 20. Thickness of Permafrost: 1388' MD 21. Logs Run: GRlRes/Den/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# B Surface 108' 42" 15 bbl AS I 9.625" 40# L-80 Surface 3006' 12.25" 540sxASLite,314sxLiteCrete kickoff plug from 7096' - 6569' cement balanced plug #1 from 10548' to 9936' cement balanced plug #2 from 9936' to 9168' cement balanced plug #3 from 9168' to 8326' 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) N/A None 26. Date First Injection N/A Date of Test N/A Flow Tubing Hours Tested Casing Pressure press. 27. psi 24-Hour Rate -> 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED kickoff plug from 7096'-6569' 207 sx Class G all 3 abandonment plugs from 648 sx Class G total 10548' - 8326' WATER-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY - API (corr) 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". PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Abandoned Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL fë(1~~;¡C!~:¡- -. . IL!-?ð.)~ONE . ')1J ,~. -","'.'-~ -., .".. -, Form 10-407 Revised 2/2003 CORE DATA '1OO~ CONTINUED ON REVERSE SIDE nq1G1~\'!~L ROOMS r~fl. tl APRO 100~ Submit in duplicate 28. GEOLOGIC MARKER. 29. . FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2P-424 T3 T2 9849' 10332' 5590' 5822' N/A ~oðr- 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed N~ _ ~ _~:....ThOmps Signature '" ----, \ ~ - Title: nhone Kuparuk Team Leader '241""""' ir ~Ð Date ~I'(, (Oy Prepared by Sharon Allsup-Drake 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. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 0, p., ~L ,1\. ~tY-¡- of 12 Page 1 - . - ConocoPhillips Alaska Operations Summary Report 12/26/2003 1/18/2004 Spud Date End: Group 12/26/2003 1/1 8/2004 Start Rig Release: Rig Number: 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 Legal Well Name Common Well Name Event Name: Contractor Name Rig Name Operations Move rig ofl 2P-447. Spot rig over 2P-424, Pits, Pump, Motor, Boiler complexs Spot Rockwasher, Pipe shed, Hook up Air, Water, Steam & Glycol service lines, Rig up tank farm. Work on and complete rig acceptance check list. Accept rig @ 16:00 hrs 12/26/03 Take on water, Nipple up 21-1/4' Diverter, Mix spud mud. Change saver sub to 4-1/2" IF, Load pipe shed w/18 joints 5" drill pipe & pick up same. Function test Diverter system, Test waived by AOGCC Jeff Jones. Held dog house pre- spud meeting with all rig personnel. Fill conductor and check lor leaks, Tag Ice plug @ 36', Make up Bit. Motor & 1 stand HWDP. Clean out ice Irom conductor 1/36' to 108'. Make up Short NMDC, NM Stab, NMXO, MPR, NMXO, Orient motor, Program MWD. Pick up NMDC & RIH to 108'. Drill 1/108' to 2108' (1920' TVD) AST= 7.5 hrs., ART= 8.3 hrs., WOB 20í25K. RPM 80, 650 gpm ~ 2100 psi, UP 100K, DN 98K, ROT 100K, TO 6K on & off btm. (Note: Had 1805 units gas @ 1831')Pumping sweeps as needed to maintain clean hole. Drill 1/2108' to 2961' AST= 1.8 hrs., ART= 8.1 hrs.. WOB 30K, RPM 100,650 gpm (ij! 2300 psi, UP 105K, DN 90K, ROT 98K. TO 7K on, 6K 011. Ave BGG 80 units. Monitor well. Circ btm's up at 633 gpm @ 2000 psi, 100 RPM. Drill 1/2961' 10 3010' AST= 0 hrs., ART=.9 hrs., WOB 30K, RPM 100, 650 gpm @ 2300 psi, UP 105K. DN 90K, ROT 98K, TO 7K on. 6K 011. BGG 80 units. Pump Hi-vis sweep. Circ & condo mud at 633 gpm @ 2000 psi, 100 RPM. Monitor well. Circ btm's up. Back ream out 101850' at rate 01525 gpm @ 1500 psi, 80 RPM. Circ hole clean W/525 gpm @ 1400 psi, 100 RPM. Pump dry job, POOH to BHA @ 200'. POOH w/ BHA, Down load MWD, Lay down motor & bit. Rig to run 9-5/8" casing. PJSM, Run 9-5/8" casing. Finish running total of 77 joints 9-5/8", 40#, L-80 BTC casing to 2977', Make up Hanger & landing joint, Land csg @ 3005'. Circ & condo mud with Frank's fill up tool, Stage rate up to 5.0 bpm @ 290 psi, No Mud lost, No trip gas, BGG 5 units. Rig down Frank's fill up tool, Blow down top drive, Rig up Dowell circ swedge. Circ & cond mud, Pump rate of 3.5 bpm @ 90 psi, Reciprocate pipe 15', Wait on weather and Dowell cement unit due to Phase III weather. Note: Dowell cement van ran off road due to weather during convoy to rig. Circ & cond mud, Pump rate of 3.5 bpm @ 90 psi, Reciprocate pipe 15', UP 125K, DN 108K, Wait on weather and Dowell cement unit due to Phase III weather. Rig down Dowell circ swedge, Rig up Dowell cmt head. Circ & cond mud, Pump rate of 3.5 bpm @ 90 psi, Reciprocate pipe 15', UP 125K, DN 108K, Rig up Dowell pump truck, Position vacuum trucks, Printed: :48:28 PM 3/11/2004 Description of Phase RIGUP RIGUP SURFAC 2/28/2003 00:00 3:00 13.00 DRILL DRLG ! SURFAC 13:00 3:30 0.50. DRILL CIRC SURFAC 13:30 4:30 1.00 DRILL DRLG . SURFAC 14:30 - 15:30 1.001 DRILL CIRC SURFAC 15:30 - 16:00 0.50 DRILL CIRC : SURFAC 16:00 - 17:30 1.50 DRI LL TRIP SURFAC 17:30 - 18:30 1.00 DRILL CIRC SURFAC 18:30 - 20:00 1.50 DRILL TRIP SURFAC 20:00 - 22:00 2.00 DRILL PULD SURFAC 22:00 - 23:00 1.00 CASE RURD SURFAC 23:00 - 00:00 1.00 CASE RUNC SURFAC 2/29/2003 00:00 - 04:30 4.50 CASE RUNC SURFAC 04:30 - 07:30 3.00 CEMENTCIRC SURFAC 07:30 - 08:00 0.50 CEMENT PULD SURFAC 08:00 - 00:00 16.00 WAlTON WOW SURFAC 2/30/2003 00:00 - 09:00 9.00 WAlTON WOW SURFAC 09:00 - 09:15 0.25 CEMENT PULD SURFAC 09:15-11:15 2.00 CEMENTCIRC SURFAC MOVE MOVE MOVE RIGUP RIGUP SURFAC SURFAC SURFAC MOVE Sub Code MOVE MOVE MOVE RURD I i i I I ; ! 2.00 I WELCTL NUND 2.501 DRILL :PULD . i 0.50' WELCTY BOPE 0.50 DRILL I SFTY 1.00 DRILL ! PULD 22.00' DRILL DRLG PULD DRLG Code 3.00 MOVE 3.00 MOVE 4.00 MOVE .00 MOVE 0.50 DRILL 2.00! DRILL Hours To 06:00 - 09:00 09:00 - 12:00 12:00 - 16:00 16:00 - 17:00 17:00 - 19:00 19:00 - 21:30 21 :30 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 00:00 From Date 2/26/2003 12/27/2003 ..... - ConocoPhillips Alaska Operations Summary Report 2.00 CEMENTCIRC SURFAC PJSM wI all personnel. 2.75 CEMENT PUMP SURFAC Turn over to Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 4.5 bpm @ 80 psi, Shut down, Test lines to 3500 psi, Continue pumping CW1 00 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 4.2 bpm @ 120 psi, Shut down and drop btm plug, Mix & pump 540 sxs (428.0 bbls) Lead ArcticSet III Lite cmt mixed at 10.7 ppg w/ additives at rate of 6.5 bpm @ 170 psi, Followed by 314 sxs (150.0 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg wI additives at rate of 5.6 bpm @ 220 psi, Shut down and drop top plug, Displace cmt w/20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 197.0 bbls 10.4 ppg mud (total of 217.0 bbls to bump plug) at rate of 7.0 bpm @ 490 psi, Slowed rate to 3.0 bpm @ 285 psi for last 10 bbls of displacement, Bump plug w/1000 psi, Floats held- OK, CIP @ 14:00 hrs 12/30103, Had good returns thru out job, Reciprocate csg. 15' until MudPUSH to surface then pipe got tight, Had 231.0 bbls good cmt retums to surface. Rig down Dowell cmt, Lay down landing joint Clear rig floor of Casing & cementing equip. Nipple down Diverter system. Nipple up FMC Gen 5 wellhead, Test seals to 1000 psi-OK. Nipple up BOPE & set wear bushing. Pick up 90 joints 5' drill pipe from pipe shed, POOH & stand back in derrick. Pull wear bushing, Install test plug. Rig & test BOPE to 250 psi low & 5000 psi high, Hydril to 250 low & 3500 psi high, Test waived by AOGCC Jeff Jones, Rig down test equip., Set wear bushing. Pick up 90 joints 5' drill pipe, POOH & stand back in derrick. Repair hydralic hose on top drive. Finish POOH & stand drill pipe back in derrick. PJSM, Make up BHA, Orient motor, Program MWD, Load RA sources, RIH w/ NMDC's. RIH w/ HWDP, Surface test MWD- OK. Pick up 57 jts 5" drill pipe from pipe shed to 2880'. Break circ, Wash down to Float collar @ 2920'. Stand back 1 stand drill pipe, Rig & test 9-5/8" csg to 3500 psi f/30 min.-OK. Drill out Float collar @ 2920', Cmt, Shoe @ 3005',20' new hole to 3030' ART = 0.6 hrs. Pump sweep, Change over to new 10.5 ppg LSND mud w/5 ppb Fine LCM. Perform FIT of 18.0 ppg EMW with 932 psi, 2386' TVD, 10.5 ppg mud. Drill f/3030' to 3120' ART= 1.0 hrs WOB 10K, RPM 80, 500 gpm @ 2000 psi, UP 11 OK, DN 82K, ROT 97K, TQ 6K, ECD's 11.8 ppg, Ave. BGG 30 units Note: Outter annulas pressures are as follows Well Pressure 2P-432 750 2P-434 250 2P-447 0 12.00 DRILL DRLG PROD Drill f/3120'to 3870' ART=8.1 hrs AST= 0.6 hrs WOB5/20K, RPM 90, 550 gpm @ 2200 psi, UP 11 OK, DN 70K, ROT 85K, TO 3/9K on / 3/6K off, Ave. ECD's 11.8 to 12.0 ppg, Ave. BGG 35 units Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 .....,c. .,. .... :.. ."From _ To. ·..··.·H·...·.ou...··.··.·r:.·.·.S. C.:· ò..··... d'·····.·..'.e:.:.:...: .:..... CsOu·.·dbe···.. Pha.s.e. \;Dab~: ....:., .. . ...... 12/30/2003 09:15 -11:15 11:15 -14:00 14:00 - 15:00 1.00 CEMENT PULD SURFAC 15:00 - 15:30 0.50 CEMENT PULD SURFAC 15:30 - 17:00 1.50 WELCTL NUND SURFAC 17:00 - 18:00 1.00 WELCTL NUND SURFAC 18:00 - 20:00 2.00 WELCTL NUND SURFAC 20:00 - 23:30 3.50 DRILL PULD SURFAC 23:30 - 00:00 0.50 WELCTL BOPE SURFAC 12/31/2003 00:00 - 06:30 6.50 WELCTL BOPE SURFAC 06:30 - 09:45 3.25 DRILL RIRD SURFAC 09:45 - 11 :45 2.00 RIGMNT RGRP SURFAC 11:45 -12:30 0.75 DRILL PULD SURFAC 12:30 - 15:30 3.00 DRILL PULD SURFAC 15:30 - 16:00 0.50 DRILL TRIP SURFAC 16:00 - 18:00 2.00 DRILL TRIP SURFAC 18:00 - 18:30 0.50 DRILL CIRC SURFAC 18:30 - 20:00 1.50 DRILL DEQT SURFAC 20:00 - 21 :45 1.75 DRILL DRLG PROD 21:45 - 22:15 0.50 DRILL CIRC PROD 22:15 - 23:00 0.75 DRILL FIT PROD 23:00 - 00:00 1.00 DRILL DRLG PROD 1/1/2004 00:00 - 12:00 Page 2 of 12 Start: 12/26/2003 Rig Release: 1/18/2004 Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: .. . ... ... . . ... .. . .. .. Description of Oper~tiohS . Printed: 3/11/2004 1 :48:28 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ....,. - ConocoPhillips Alaska Operations Summary Report 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 Page 3 of 12 12/26/2003 1 /18/2004 Spud Date: 12/26/2003 End: 1/18/2004 Group: Start: Rig Release: Rig Number: " ";:;:, r Despriptionof Operations ." S .i p:roiTi ,- To Hours ,Cpde 'Udb. ,P,h~se; Coe, Date 1/1/2004 12:00 - 00:00 1/2/2004 00:00 - 13:15 12.00 DRILL DRLG PROD 13.25 DRILL DRLG PROD 13:15 - 13:45 0.50 DRILL CIRC PROD 13:45 - 16:00 2.25 DRILL TRIP PROD 16:00 - 16:30 0.50 DRILL CIRC PROD 16:30 - 17:00 0.50 DRILL TRIP PROD 17:00 - 17:45 0.75 DRILL TRIP PROD 17:45 - 18:30 0.75 DRILL CIRC PROD 18:30 - 20:00 1.50 DRILL TRIP PROD 20:00 - 23:00 3.00 DRILL PULD PROD 23:00 - 00:00 1.00 RIGMNT RSRV PROD 1/3/2004 00:00 - 02:00 2.00 DRILL PULD PROD 02:00 - 03:45 1.75 DRILL PULD PROD 03:45 - 04:30 0.75 DRILL PULD PROD 04:30 - 07:15 2.75 DRILL TRIP PROD 07:15 - 08:15 1.00 DRILL REAM PROD 08:15 - 00:00 15.75 DRILL DRLG PROD 1/4/2004 00:00 - 12:00 12:00 - 00:00 1/5/2004 00:00 - 16:00 16:00 - 16:45 16:45 - 18:45 18:45 - 19:30 19:30 - 20:45 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 16.00 DRILL DRLG PROD 0.75 DRILL 2.00 DRILL 0.75 DRILL 1.25 DRILL CIRC PROD WIPR PROD CIRC PROD WIPR PROD Drill 11 3870' to 4640' ART = 9.0 hrs AST = 0.2 hrs WOB 5/20K, RPM 90,550 gpm @ 2250 psi, UP 115K, DN 85K, ROT 98K, TO 9K on 16K off, Ave. ECD's 11.8 to 12.0 ppg, Ave. BGG 35 units Drill fl 4640' to 5661' ART = 9.4 hrs AST = 0.3 hrs WOB 5/20K, RPM 90, 550 gpm @ 2850 psi, UP 11 OK, DN 90K, ROT 107K, TO 6/1 OK on I 7/1 OK off, Ave. ECD's 11.8 to 12.2 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 ppb fine LCM in mud, Ave. BGG 30 units, Had LWD failure @ 5661'. Pump Hi-vis sweep & circ hole clean. Monitor well- static, Pump out of hole to 4086'. Circ btm's up & hole clean at rate of 550 gpm @ 2700 psi, (Had excess amount of clay cakes over shakers). POOH to 3725' - Hole tight 15K over & swabbing. Pump out of hole to 2997'. Circ btm's up @ 2997', Monitor well- OK, Pump dry job. POOH on elevators to BHA. PJSM, Remove R.A. Sources, Down load MWD tools, Trouble shoot LWD failure (Found short in Density/Neutron tool), Lay down BHA, Check bit. Slip & cut drilling line. Make up BHA #3, Bit, motor, MWD, LWD, Orient motor. Had bad communication with tool due to dirty connection, Break and reservice connections, Finish making up BHA, Program same. PJSM, Load A.A. Sources. RIH w/ HWDP, Surface test MWD tools- OK, RIH to 5540' with no problems. Make MAD Pass f/5540' to 5661', Pump Hi-vis sweep, Trip gas 131 units. Drill f/5661' to 6730' ART = 9.2 hrs AST = 2.1 hrs WOB 5/20K, RPM 90, 560 gpm @ 3050 psi, UP 150K, DN 97K, ROT 115K, TQ 8/11 K on I 11 K off, Ave. ECD's 11.8 to 12.0 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 ppb fine LCM in mud, Ave. BGG 15-25 units. Drill 11 6730' to 7600' ART = 8.4 hrs AST = 0.8 hrs WOB 10/15K, RPM 90, 570 gpm @ 2800 psi, UP 180K, DN 107K, ROT 123K, TQ 11 K on / 11 K off, Ave. ECD's 11.8 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 to 7 ppb fine LCM in mud, No mud lost, Ave. BGG 30 units. Drill f/7600' to 8384' ART = 6.4 hrs AST = 1.6 hrs WOB 10/20K, RPM 90,560 gpm @ 3100 psi, UP 205K, DN 109K, ROT 140K, TQ 11/15K on 115K off, Ave. ECD's 11.8 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 to 7 ppb fine LCM in mud, No mud lost, Ave. BGG 30 units. Drill f/ 8384' to 9343' ART = 10.4 hrs AST = 1.4 hrs WOB 10/20K, RPM 90,560 gpm @ 3200 psi, UP 225K, DN 110K, ROT 146K, TQ 14/18K on /17K off, Ave. ECD's 11.7 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 to 7 ppb fine LCM in mud, No mud lost, Ave. BGG 20 units. Note; Top of Cairn (T4.1) @ 5356' TVD, 9339' MD Pump Hi-vis weighted sweep, & circ hole clean, Monitor well- Static. POOH f/ wiper trip, Pump out to 7800' - Hole in very good shape. Circ btm's up @ 7800'. Monitor well, POOH to 5658' on elevators - hole in very good shape. Printed: 3/11/2004 1 :48:28 PM Page 4 of 12 . . ConocoPhillips Alaska Operations Summary Report 12/26/2003 1 /18/2004 Spud Date End: Group 12/26/2003 1/18/2004 Start: Rig Release: Rig Number: - DRILLING n1334@ppco.com Doyon 141 2P-424 2P-424 ROT Legal Well Name Common Well Name Event Name: Contractor Name Rig Name Monitor well, RIH f/5658' to 9343', Wash f/9288' to 9343'. Circ btm's up (Trip gas 70 units), Pump Hi-vis weighted sweep, Circ hole clean, Begin reducing mud weight to 10.2 ppg. Note; 2P-432 OA pressure= 700 psi, 2P-434 OA pressure= 200 psi, 2P-447 OA pressure= 0 psi. Fin circ out weighted hi-vis sweep after wiper trip Drilled 8 1/2" hole from 9,343' to 9.933' MD/5,632' TVD (590') ART 7.6 hrs, AST 0.6 hrs, 10-20K wob, 90 rpm's, 135 spm, 572 gpm, off btm pressure 2,800 psi, on btm 3,100 psi. off btm torque 15K ft-Ibs, on btm 18K ft-Ibs, rot wt 145K, up wt 256K. dn wt 111 K, ave BGG 20 units, pumped wt'd hi-vis sweeps every 3-4 stds with no change in cuttings, 10.3 ppg MW . ave ECD 11.3 ppg. Est Top of Cairn sand at ,9,339' MD/ 5.356' rvD Drilled from 9.933' to 10,478' MD/5,894' TVD, (545') ART 6.6 hrs. Est Top of Bermuda sand at 9,997' MD/ 5,656' TVD, ave BGG 20 units, max gas from Bermuda sand. 470 units at 10,094'. conn gas ranged from 5-15 units over BGG with 10.3 ppg MW and no mud loss Pumped wt'd hi-vis sweep while evaluating logs. pumped 30 bbl sweep at 2 Ib over MW Drilled from 10,478' to 10,548' MD/5.930' TVD (T.D.) ART 0.6 hrs, fin circ out sweep w/drlg with no increase in cuttings. drilled with 5-15K wob, 90 rpm's, 133 spm, 564 gpm, off btm press 2,900 psi. on btm 3.100 psi, off btm torque 18K ft-Ibs, on btm 19K ft-Ibs, 10.3 MW. ave ECD 11.2 ppg, ave BGG 20 units, rot wt 160K. up wt 270K, dn wt 106K Monitored well-static and circ btms up at 564 gpm at 2,900 psi Backreaming out of hole at drlg rate from 10.548' to 9,825' with no problems Outer Annulus Pressures: 2P 432-700 psi. 2P 434-250 psi, 2P 447 -0- psi Cont to back ream out of hole from 9,825' to 9.190' at 90 rpm's. 572 gpm at 2,800 psi with no problems. monitored well-static Circ 2.5x btms up at 9,190' and circ hole clean at 110 rpm's, 590 gpm at 2,700 psi. ave BGG 20 units Monitored well-static POOH wet 10 stds to 8,260' with no problems, pumped dry job and cont POOH to BHA at 1,114', SLM no corr. monitored well-static LD Ghost reamer, pump out sub, 2 jts HWD & Jars and stood back HWDP & flex DC's Held PJSM on removing radioactive sources Removed radioactive sources, downloaded MWD and LD BHA #3, cleared rig floor Pulled wear bushing Serviced rig, top drive, saver sub and grabber for top drive Slip & cut 61' of drlg line, changed out deadman nut's and bolts Evaluating logs, decision made to sidetrack well RU to run 3 1/2" Tbg cement stinger Installed wear bushing PU & MU 16 jts of 31/2" 9.3# L-80 EUE Mod tbg for cement stinger with muleshoe and XO's to 5" DP, Total length 502.34', RD 3 1/2" handling equipment TIH with 3 1/2" stinger on 5' DP to 9,275', broke circ every 20 stds W/RIH, string pu wt 170K, dn wt 103K Recieved extension on BOP test from Jeff Jones with AOGCC to test Operations Description of Sub· Code Code ¡ Phase ·.._--t-_· . WIPR ~PROD CIRC PROD DRILL DRILL 2.25 1.00 To ¡ Hours I --_....._~- 23:00 : 00:00 From 20:45 23:00 Date 1/5/2004 PROD PROD PROD CIRC DRLG DRLG I I I I I DRILL DRILL DRILL I 0.50 11.50 8.50 00:30 12:00 20:30 00:00 00:30 12:00 1/6/2004 .--- PROD PROD CIRC DRLG DRILL DRILL 0.50 .25 20:30 - 21 :00 22:15 21:00 PROD PROD CIRC TRIP 0.50 DRILL 1.25 DRILL 22:45 00:00 22:15 22:45 PROD TRIP DRILL 0.75 00:00 - 00:45 1712004 PROD CIRC DRILL : .25 02:00 00:45 i PROD PROD OBSV TRIP DRILL DRILL 0.25 5.25 02:15 07:30 02:00 02:15 PROD PULD DRILL .00 07:30 - 08:30 :48:28 PM 3/11/2004 Printed: PROD PROD DRILL i PULD PROD RIGMNT: RSRV PROD RIGMNT RSRV PROD DRILL OTHR PROD ABANDN RURD ABANDN ABANDNOTHR ;ABANDN ABANDN PULD : ABANDN ABANDNTRIP ABANDN SFTY PULD DRILL DRILL I I ¡ , i 0.25 2.00 0.50 1.25 1.50 2.50 0.50 0.50 1.25 5.25 08:45 10:45 11 :15 12:30 14:00 - 16:30 - 17:00 - 17:30 -18:45 18:45 - 00:00 08:30 08:45 10:45 11 :15 12:30 14:00 16:30 17:00 17:30 ..... - ConocoPhillips Alaska Operations Summary Report BOP's after setting cement plugs Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi. 2P 447 -0- psi Cont to RIH with 3 1/2' cement stinger on 5" DP. PU 16 add. jts of DP & tagged btm at 10,548' Circ and conditioned mud for setting cement plug. staged pump rate up to 13 bpm. 546 gpm at 1,500 psi, rotated DP at 50 rpm's on up stroke with 15K ft-Ibs torque, circ and evened MW at 10.4 ppg in & out. max gas at btms up 74 units, ave BGG 25 units and no mud loss. rot wt 137K. up wt 195K, dn wt 107K.Held PJSM with rig crew and Dowell on setting of plugs and batch mixed cement while circ hole 0.25 CEMENT RURD ABANDN LD 1 single of DP & MU pump-in sub and cement line 0.50 CEMENT PLUG ABANDN Turned over to Dowell, pumped 5 bbls FW and tested lines to 3,500 psi, cont to pump 10 bbls FW (15 total) then pumped 45 bbls, 216 sxs of Class "G' cmt with add. at 15.8 ppg and 1.17 yield. ave 3.5 bpm while pumping, initial press 680 psi. final 550, slowed rate to 2 3/4 bpm at 300 psi, followed cmt with 2 bbls FW, continued to reciprocate pipe while pumping cmt 0.75 CEMENTDISP ABANDN Displaced cement with rig pump, pumped 173 bbls of 10.4 ppg mud to balance plug. pumped at 4.5 bpm. initial press 350 psi. max press 700 psi. slowed rate last 10 bbls to 2.75 bpm at 500 psi, shut down with CIP @ 04:30. Est. TOC at 10,090' 0.75 CEMENTTRIP ABANDN POOH slow 9 stds from 10,548' to 9,700' at 1 std/2.5 min. plug balanced 2.50 CEMENTCIRC ABANDN Attempted to circ hole clean at 9.700'. rotated at 50 rpm's with 13K ft-Ibs torque on up stroke. 130K rot wt and staged pump rate up to 546 gpm at 2.000 psi, began to see mud loss w/circ. slowed pump to 420 gpm at 1.300 psi and losses stab, at btms up began to get back cement contaminated mud and losses increased, slowed pump rate to 106 gpm at 460 psi when lost full returns. max MW out 10.3 ppg, mud thick & clabbored up at flow line when returns were lost. lost 234 bbls while attempting to circ btms up. shut down with 460 psi back pressure on DP Beld off 460 psi on DP to -0- psi, well breathed back 72 bbls from DP POOH from 9,700' to 7.800', attempted to est circ at 2.5 bpm. 106 gpm's at 460 psi with no returns POOH from 7,800' to 5.900', calc hole fill, 14 bbls actual 7.5 bbls, attempted to circ hole at 106 gpm at 460 psi with no returns POOH from 5,900' to 4.030'. calc hole fill 8.1 bbls. actual 3.5 bbls, attempted to circ hole at 4,030' at 106 gpm at 450 psi with no returns POOH from 4,030' to 2.960', attempted to circ hole at 106 gpm at 450 psi and had slight returns POOH from 2,960' to 1,475' Est circ at 106 gpm, circ out thick cmt contaminated mud and a large amount of clay, staged pump rate up to 12 bpm (504 gpm) at 450 psi, circ & cond mud to 10.2 ppg and circ clean with no mud loss RIH with 3 1/2" cement stinger on 5" DP from 1,475' to 2,450' (11 stds) Est circ at 6 bpm (252 gpm) at 200 psi. circ out contaminated mud then staged pump rate to 12 bpm at 700 psi, circ a total of 2x btms up, last btms up at 12 bpm and clean at shakers and no mud loss RIH from 2,450 to 3.377' (11 stds) Est circ at 6 bpm (252 gpm) at 250 psi, circ out contaminated mud then staged pump rate to 13 bpm (546 gpm) at 850 psi, circ a total of 2x btms up. last btms up at 13 bpm and clean at shakers and no mud loss Legal Well Name: 2P-424 Common Well Name: 2P-424 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date : From - To Hours; Code i ¿;~dbe Phase ...-.-.-.--..- -. ..... - .... ~_. -- . 1/7/2004 18:45 - 00:00 5.25 ABANDI\ TRIP ABANDN 1/8/2004 00:00 - 01 :00 1.00 ABANDI\ TRIP ABANDN 01 :00 - 03:00 2.00 CEMENTCIRC ABANDN 03:00 - 03:15 03: 15 - 03:45 03:45 - 04:30 04:30 - 05:15 05:15 - 07:45 07:45 - 09:00 1.25 CEMENT TRIP ABANDN 09:00 - 10:15 1.25 CEMENTTRIP ABANDN 10:15-11:15 1.00 CEMENT TRIP ABANDN 11:15 -13:00 1.75 CEMENTTRIP ABANDN 13:00 - 14:00 1.00 CEMENTTRIP ABANDN 14:00 - 14:30 0.50 CEMENT TRIP ABANDN 14:30 - 15:30 1.00 CEMENTCIRC ABANDN 15:30 - 15:45 0.25 CEMENTTRIP ABANDN 15:45 - 16:15 0.50 CEMENTCIRC ABANDN 16:15 - 16:30 0.25 CEMENTTRIP ABANDN 16:30 - 17:30 1.00 CEMENTCIRC ASANDN Page 5 of 12 Start: 12/26/2003 Rig Release: 1/18/2004 Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: Description of Operations .. .m.. ..,...",_.. ..... .. . ..-. ---.------.-------... ..-..--... ...... .... Printed: 3/11/2004 1 :48:28 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ,'Frotn":To - 1/8/2004 17:30 - 17:45 17:45 - 19:15 19:15 - 19:30 19:30 - 20:45 20:45 - 21 :00 21:00-22:15 22:15 - 22:45 22:45 - 00:00 1/9/2004 00:00 - 00:15 00:15 - 00:45 00:45 - 02:00 02:00 - 02:45 02:45 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 06:45 06:45 - 07:30 07:30 - 08:45 - ..... ConocoPhillips Alaska Operations Summary Report Page 6 of 12 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 H '" "'C' <;'1" Sub , ,ours,",,' oue, C' d ,." ,,' ',";";';,' " 0 e Start: Rig Release: Rig Number: 12/26/2003 1/18/2004 Spud Date: 12/26/2003 End: 1/18/2004 Group: .. . . . ..... . '." Description' of Operations ". ; " Phase 0.25 CEMENTTRIP ABANDN RIH from 3,377' to 4,400' (11 stds) 1.50 CEMENT CIRC ABANDN Est circ at 6 bpm (252 gpm) at 250 psi, circ out contaminated mud at btms up then increased pump rate to 13 bpm (546 gpm) at 1,050 psi, circ a total of 2x btms up 0.25 CEMENT TRIP ABANDN RIH from 4,400' to 5,424' (11 stds) 1.25 CEMENT CIRC ABANDN Est circ at 6 bpm (252 gpm) at 250 psi, circ out contaminated mud at btms up, increased pump rate to 13 bpm (546 gpm) at 1,250 psi, circ a total of 2x btms up and clean at shakers 0.25 CEMENTTRIP ABANDN RIH from 5,424' to 6,424' (11 stds) 1.25 CEMENT CIRC ABANDN Est circ at 6 bpm (252 gpm) at 350 psi, at btms up, had fewer clay patties back at btms upand cleaned up quicker, increased pump rate to 13 bpm (546 gpm) at 1,250 psi, circ a total of 2x btms up, ave 10-20 units BGG 0.50 CEMENTTRIP ABANDN RIH from 6,424' to 7,740' (14 stds) 1.25 CEMENT CIRC ABANDN Est circ at 6 bpm (252 gpm) at 450 psi, at btms up had very little contaminated mud, only 1" to 2" clay patties, increased pump rate to 13 bpm (546 gpm) at 1,550 psi, circ a total of 2x btms up and last btms up at 13 bpm, with no mud loss and 10.2 ppg mud in & out, ave 10-20 units BGG, up wt 147K, dn wt 95K Lost 255 bbls mud last 24 hrs Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi, 2P 447 -0- psi Recieved add. extension on BOP test from Jeff Jones with AOGCC to test BOP's after setting cement plugs 0.25 CEMEN1 CIRC ABANDN Fin circ 2nd btms up at 7,740' at 13 bpm at 1,550 psi and clean at shakers 0.50 CEMENTTRIP ABANDN RIH from 7,740' to 9,047' (14 stds) 1.25 CEMENTCIRC ABANDN Est circ at 252 gpm at 550 psi, at 1st btms up circ out contaminated mud, staged pump rate to 546 gpm at 1,725 psi, circ 2x btms up and clean at shaker with no mud loss. 0.75 CEMENTTRIP ABANDN RIH from 9,047', washed down and tagged TOC at 9,936', set 15K wt on plug and had 400 psi increase in pump pressure 2.25 CEMEN1 CIRC ABANDN Est circ at 189 gpm at 475 psi, staged rate up to 546 gpm at 1,800 psi, at btms up had small amount of clay patties and contaminated mud, max gas at btms up 292 units, ave bgg 10-20 units, up wt 204K, dn wt 104K, held PJSM with crew and Dowell on setting cmt plug and batch mixed cement 0.50 CEMENTRURD ABANDN Stood back 1 std of 5" DP, MU 2 singles with pump in sub and cement line 0.50 CEMENT PUMP ABANDN Turned over to Dowell, pumped 5 bbls FW and tested lines to 3,500 psi, cont to pump 10 bbls FW (15 total) then pumped 45 bbls, 216 sxs of Class "G" cmt with add. at 15.8 ppg and 1.17 yield, ave 3.75 bpm while pumping, initial press 725 psi, final 425 psi, followed cmt with 2 bbls FW, reciprocate pipe while pumping cmt 0.75 CEMENTDISP ABANDN Displaced cement with rig pump, pumped 161 bbls of 10.2 ppg mud to balance plug, pumped at 4.5 bpm, initial press 225 psi, max press 700 psi, slowed rate last 10 bbls to 3 bpm at 500 psi, shut down with CIP @ 06:40, Calc TOC in 8 1/2" hole at 9,295' 0.75 CEMENT TRIP ABANDN LD 2 jts 5" DP and POOH slow at 1 std/2.5 min from 9,936' to 9,047', well balanced 1.25 CEMENT CIRC ABANDN Circ btms up at 9,047' after setting cmt plug, est circ at 6 bpm at 625 psi, staged up to 7 bpm at 800 psi, no cmt contaminated mud at btms up Printed: 3/11/2004 1 :48:28 PM . . Page 7 of 12 ConocoPhillips Alaska 12/26/2003 1/18/2004 Spud Date: End: Group: Operations Summary Report 12/26/2003 1/18/2004 Start: Rig Release Rig Number: Legal Well Name: 2P-424 Common Well Name: 2P-424 Event Name: ROT - DRILLING Contractor Name n 1334@ppco.com Rig Name Doyon 141 v' / v ./ Operations Cont to circ hole clean after cmtg, staged pump rate up to 420 gpm at 1,200 psi, circ hole while W.O.C. RIH from 9.047', washed down and tagged TOC @ 9,168', set 15K down on plug and had 350 psi increase in pump pressure Circ and cond mud for cement plug #3, staged pump rate up to 420 gpm at 1,200 psi, no mud loss, held PJSM and batch mixed cement while circ MU Pump in sub and cement line Turned over to Dowell, pumped 5 bbls FW and tested lines to 3,500 psi cont to pump 10 bbls FW (15 total) then pumped 45 bbls, 216 sxs of Class "G" cmt with add. at 15.8 ppg and 1.17 yield. ave 4 bpm at 600 psi. followed cmt with 2 bbls FW, reciprocate pipe while pumping cmt Displaced cement with rig pump. pumped 146 bbls of 10.2 ppg mud to balance plug. pumped at 4.5 bpm, ave 600 psi, slowed rate last 10 bbls to 2 bpm at 380 psi, shut down with CIP @ 16:00, Calc TOC in 8 t/2" hole at 8,527' LD single with pump in sub and POOH slow at 1 std/2.5 min to 8,210' Est circ at 6 bpm, circ btms up after cement job and had no cement back with 60 bbls of contaminated mud, staged pump rate up to 510 gpm at 1.850 psi while circ hole clean with 10.2 ppg mud, W.O.C. and waiting on Dowell to deliver cement for kick-off plug. PU wt 170K, DN wt 95K, ave BGG 10 units, Access road and pad in phase 2 condition at 21 :00 hrs, Jeff Jones with AOGCC was to come out and witness tag of cement plug but waived witnessing due to wGather Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi, 2P 447 -0- psi Cont to circ hole at 510 gpm at 1,850 psi and 10.2 ppg mud while W.O.C. and waiting on Dowell to deliver cement for kick-off plug. PU wt 170K, DN wt 95K, ave BGG 10 units, Access road and pad in phase 2 condition RIH from 8,210', est circ at 1.5 bpm and tagged TOC at 8.326', (200' above calc top) had 400 psi increase in pressure with 20K wt on plug. shut pump down and held 20K on plug for 15 min, Jeff Jones with AOGCC was to come out and witness tag of cement plug but waived witnessing due to weather POOH from 8,326' to 7,592' to spot weighted hi-vis pill. Dowell arrived location with kick-off plug cement Pump and spotted 35 bbl, weighted (11/ over mw) hi-vis pill from 7,592' to 7,100', pumped at 4.5 bpm at 475 psi POOH from 7,592' to 7,096' Circ 1 complete circ at 7,096', Est circ at 6 bpm at 650 psi and staged rate up to 8 bpm at 900 psi, had no wt'd hi-vis pill at btms up with 10.2 ppg mud in & out MU pump in sub and cement hose. batch mixed cement Dowell pumped 5 bbls FW, tested lines to 3,500 psi. pumped 5 add. bbls FW, then pumped 37 bbls. 207 sxs of class "G" cement at 17.0 ppg and 1.0 yield, ave 4.5 bpm at 600 psi, followed with 1.5 bbls water, reciprocated pipe, up wt 145K, dn wt 93K Rig displaced cement with 112 bbls of 10.2 ppg mud to balance plug, ave 4.5 bpm at 500 psi, slowed to 1.5 bpm at 350 psi. CIP at 05:30 hrs calc TOC in 8 1/2" hole at 6,569' POOH 8 stds slow from 7,096' to 6,353', pulled a balanced Printed: plug :48:28 PM stdi3 min's, 3/11/2004 Description of Phase ABANDN ABANDN ABANDN 0.50 CEMENT. RURD ABANDN 0.50 CEMENT PUMP ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN CEMENTRURD ABANDN CEMENT PUMP ,ABANDN ABANDN ABANDN ABANDN Sub Code Code CEMENT,CIRC i ! CEMEN~TRIP CEMENTCIRC CIRC CIRC TRIP CIRC ¡ CEMENT DISP CEMENT TRIP CEMENTCIRC 0.50 CEMENT DISP TRIP TRIP TRIP .00· DRILL DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 1.25 DRILL DRILL . Hours ...-..-.--...-.... . 2.25 0.25 3.25 0.50 1.00 7.00 0.75 0.25 0.25 0.75 From - To :00 4:30 15:00 15:30 11 :15 6:00 17:00 00:00 03:15 04:30 04:30 - 04:45 04:45 - 05:00 05:00 - 05:30 00:00 - 00:45 15 01:45 02:45 05:30 - 06: 15 11 01 :00 08:45 4:30 15:00 15:30 15 16:00 17:00 00:45 15 01:45 02:45 03:15 11 11 01 Date 1/9/2004 1/1 0/2004 page 8 of 12 . . ConocoPh ps Alaska Operations Summary Report 12/26/2003 1 /18/2004 Spud Date End: Group: 12/26/2003 1 /18/2004 Start: Rig Release Rig Number: Operations Description of Phase Legal Well Name: 2P-424 Common Well Name: 2P-424 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 _.... Date Fr~~__~To i Ho~rs I ~.Od~. ! ~~u~~. 1/10/2004 06:15 - 08:30 2.25 DRILL iCIRC ,y Circ btms up after cement job at 6 bpm at 750 psi, reciprocated pipe on up stroke, at btms up had 75 bbls of cement contaminated mud, max wt out 10.8 ppg, cant to circ hole and circ add. btms up, staged pump rate to 9 bpm at 1,600 psi Monitored well-static, pumped dry job and POOH from 6,353' to 3,103'. inspected DP on trip out and found cement inside DP at 3.103' RU & POOH LD 87 jts of 5" DP with cement built up inside from 1/8" to 1/4" RU & POOH LD 16 jts of 31/2" tbg stinger, also had cement inside. cleared rig floor & pulled wear bushing RU & tested BOPE, tested valves, manifold and rams to 250 psi low and 5,000 psi high. tested annular to 250 psi and 3.500 psi. Installed wear bushing & RD Note: Jeff Jones W/AOGCC waived witnessing of BOP test MU 81/2" Bit 113 on BHA #4 and RIH to 199'. oriented & initialized MWD. held PJSM and loaded Radioactive sources TIH with HWDP & BHA #4 to 1,114' and MU ghost Reamer Access road and pad still in phase 2 Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi. 2P 447 -0- psi Fin MU BHA #4, Shallow tested MWD PU 102 jts of 5" dp from pipe shed & TIH to 4,300' with BHA #4 and broke circ. TIH from 4.300' to 5,300' with dp out of derrick. inspected & rattled pipe and ck ok Circ 1 dp cap to clear dp and check MWD. 420 gpm at 1,800 psi, 60 rpm's with 6K ft-Ibs off btm torque TIH from 5,300' to 6.312' Circ and cond mud at 6,312', circ out contaminated mud and circ hole clean at 460 gpm at 2,200 psi, circ 2x btms up, with 10.2 ppg mw had 11.0 ECD clean hole Washed down from 6.312' to tag TOC, washed at 106 gpm at 350-600 psi. washed down to 6,957' and did not tag firm cement, calc TOC was at 6,569', Circ and cond mud at 6.957, circ out contaminated cement at 460 gpm at 2,250 psi with no firm cmt at btms up, rot wt 117K, up wt 168K. dn wt 98K, 60 rpm's with 8K ft-Ibs off btm torque, PU to 6,870' KOP Time drilling 8 1/2" hole for open hole sidetrack from 6,870' MD/ 4,194' TVD to 6.931' MD/4,224' rvD (61 ') AST 13 hrs, 0-5K wob. 560 gpm at 3,000 psi, rot wt 117K, up wt 168K, dn wt 98K, building new 10,2 ppg LSND mud in pits while drilling, ave BGG 15-20 units Outer Annulus Pressures: 2P 432-700 psi. 2P 434·250 psi, 2P 447 -0- psi Cont to Time drill 8 1/2" hole from 6.931' to 6,940', AST 1 hr, displaced out mud in hole with new 10.2 ppg LSND mud, check shot survey , showed well to be sidetracked Drill, slide & survey per directional plan from 6,940' to 7.665' MDt 4,539' TVD, (725') ART 4.2 hrs, AST 3.6 hrs, 5-15K wob. 90 rpm's, 560 gpm, ,off btm pressure 2,950 psi, on btm 3.000 psi. off btm torque 10K ft-Ibs, on btm 11 K ft-Ibs, rot wt 126K, up wt 182K. dn wt 107K. 10.2 ppg mw, ave ECD 11.2 ppg. ave BGG 45 units. conn gas 10 units over BG Drill from 7,665' to 8.352' MD/4.776' TVD (687') ART 9.2 hrs, AST -0-, 5-10K wob, 90 rpm's, 560 gpm. off btm pressure 2.950 psi, on btm :48:28 PM 3/11/2004 Printed: ABANDN 08:30· 10:15 : .75! DRILL TRIP ABANDN 10:15 - 12:30 ; 2.25 ¡ DRILL PULD 'ABANDN ! ; 12:30 - 14:30 2.00 DRILL PULD ABANDN ! 14:30 - 19:30 i 5.00! WELCTL BOPE PROD i 3.50 I DRILL 19:30 - 23:00 : PULD PROD 23:00 . 00:00 1.00 DRILL TRIP ~ PROD ! 1/11/2004 '00:00 - 00:15 0.25. DRILL PULD ! PROD 00:15-03:30 ¡ 3.25; DRILL PULD PROD ; 03:30 - 04:30 1.00 DRILL TRIP ,PROD , ! I 0.25 ¡DRILL 04:30 - 04:45 CIRC PROD i 04:45-05:15 ¡ 0.50' DRILL TRIP PROD 05:15·06:45 . 1.50 DRILL CIRC PROD , i . . ! 06:45 - 09:00 ¡ 2.251 DRILL REAM PROD ! :09:00 - 10:15 1.25, DRILL CIRC 'PROD i I i :10:15-00:00 ' 3.751 DRILL DRLG PROD i , I ! 1/12/2004 : 00:00 - 01 :00 ~ 1.00 DRILL DRLG ,PROD i ,01:00 -12:00 11.00, DRILL DRLG PROD , ¡ 2:00 - 00:00 2.00 DRILL DRLG : PROD ... ConocoPhillips Well bore Name 424 Well Name 424 Slot Name slot #424 lrištallatiön Name Drill Site 2P Name Meltwater Created By Comments ~~'D\\\ ~ 8103 -êC3 eonocoPhillips AlasAc.,slot #424 Drill Site 2P, Meltwater,North Slope, Alaska wellb.424 Well path: MWD wISe <0-2937'><3069-10548'> Date Printed: 3-Feb-2004 "~i. BAKER HUGHES INTEQ I Created 29-Dec-2003 I Last Revised 29-Jan-2004 I Govemment ID I Last Revised 12-SeD-2003 Grid NorthinQ 5868966.1677 I Grid EastinQ 444010.4943 I Latitude N70 3 9.5700 lEast 2053.45E I LonQitude W150 26 53.0200 I North 909.778 I Eastino Northino I Coord Svstem Name INorth Alionment 441964.238 5869891.466 AK-4 on NORTH AMERICAN DATUM 1927 datum True I Eastino Northino I Coord SYStem Name INOrth Alionment 441964.238 5869891.466 AK-4 on NORTH AMERICAN DATUM 1927 datum True RECEIVF ",.,.0 FEe 0 6 2004 Alaska nil.& Gas Cons. Cl1fr:";'I:.~¡on Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 8112.60 Feet on azimuth 149.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .,./ ConocoPhillips eonocoPhillips Alas.c.,slot #424 Drill Site 2P, Meltwater,North Slope, Alaska wellb.424 Wellpath: MWD wISe <0-2937'><3069-10548'> Date Printed: 3-Feb-2004 r'.. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing rdeQ/100ftl Sectionrftl 0,00 0.00 0.00 0.0<;' 0.001\ O.OOF O.OQ 0.0<;' 44401 0.4~ 5868966.1' 1 08.Q( 0.00 O.OQ 1 08.Q( 0.001\ O.OOF 0.0<;' 0.0<;' 44401 0.4~ 5868966.1' 208.1:< 0.25 16.20 208.1:<, 0.211\, 0.06E 0.25 -0.15 44401 0.5~ 5868966.31 301.0" 0.46 180.6' 301.0" 0.031\ 0.11F 0.761 O.O~ 444010.6' 5868966.2( 392.3' 3.21 170.71;, 392.2~ 2.86S 0.52F 3.0" 2.n 444010.9~ 5868963.3' 483.1¿ 5.56 169.3:< 482.8' 9.69S 1.74E 2.59 9.27 444012.1~ 5868956.4! 574.2(' 9.56 159.1 " 573.1 ~ 21.11 ~ 5.26F 4.61 20.9' 444015.6( 5868945.0: 664.8' 12.07 152.7:<' 662.0(' 36.55~ 12.281:- 3.07 37.7~ 444022.5( 5868929.5: 755.17 12.98 154.2¿ 750.27 54.09E 21.02E 1.07 57.3; 444031.1' 5868911.9: 846.2:;' 14.21 154,12 838.7€ 73.35~ 30.341; 1.35 78.6~ 444040.2~ 5868892.6( 935.0~ 16.361 153.1( 924.4~ 94.31~ 40.761:- 2.44 102.0(' 444050.5~ 5868871.5' 1026.~ 18.65 150.4:< 1011.5' 118.48E 53.791; 2.66 129.5(, 444063.4( 5868847.3( 1125Z 23.0C, 148.8~ 1103.9. 148.78~ 71.60E 4.44 164.(¡¿., 444080.9~ 5868816.81 1218.4E 23.31;. 149.5' 1189.~ 180.31~ 90.421:- 0.5Q 201.3(' 444099.5~ 5868785.2' 1312.2~ 23.36 151.67 1275.6~ 212.70E 108.681; 0.91 238.S<! 444117.5~ 5868752.7( 1405.2( 25.21 151.0" 1360.4~ 246.25~ 127.02E. 2.01 276.7(' 444135.6~ 5868719.0: 1497.4~ 28.75 148.9€ 1442.6f 282.47~ 147.98E. 3.961 318.6" 444156.3( 5868682.6< 1590.3~ 31.78 148.8:<, 1522.8~ 322.56E, 172.171; 3.26 365.4:<, 444180.2" 5868642.3! 1680.6~ 34.44 149.3(' 1598.5, 364.88~ 197.50E. 2.961 414.7L." 444205.2~ 5868599.81 1774.~ 37.35 149.5~ 1674.3~ 412.18~ 225.38~ 3.11 469.6L." 444232.8: 5868552.3~ 1867.0~ 39.99 151.3:; 17 46. 7~ 462.55E, 253.901; 3.08 527.5:; 444260.9~ 5868501.8' 1959.8f 43.261 151.7€ 1816.1; 516.78~ 283.27~ 3.54 589.H 444289.9~ 5868447.3' 2053.9, 45.9~ 151.8( 1883.1( 574.97!; 314.48~ 2.84 655.1 € 444320.7' 5868388.9( 2147.2~ 48.89 151.21: 1946.2~ 635.37E 347.23E 3.20 723.8E, 444353.0' 5868328.3: 2240.6~ 52.22- 150.47 2005.6' 698.38~ 382.351; 3.63 795.9~ 444387.6~ 5868265.01 2331.7' 55.27 149.3~ 2059.4; 761.89~ 419.14E 3.4& 869.3€ 444423.9~ 5868201.2! 2423.8~ 58.24 148.97 2109.9~ 828.04E, 458.61E 3.25 946.4(, 444462.9~ 5868134.81 2516.7i 60.51 149.3~ 2157.21 896.70~ 499.62E 2.461 1026.3; 444503.4~ 5868065.9( 2611.0( 61.n 148.1(' 2202.8' 967.27~ 542.451;. 1.69 1108.9( 444545.7~ 5867995.0: 2703.6' 62.11 149.~ 2246.3~ 1037.20~ 584.63E 1.47 1190.5~ 444587.4~ 5867924.81 2796.3~ 62.461 148.6~ 2289.5' 1107.67~ 626.75E. 1.04 1272.~ 444629.0: 5867854.0; 2888.6~ 62.45 148.2~ 2332.2( 1177 .42~ 669.56E. 0.3:;. 1354.4~ 444671.3' 5867783.9i 2937.2i 62.46 147.5:<, 2354.6E 1213.93~ 692.461; 1.4C 1397.5~ 444693.9~ 5867747.3( 3069 .4~ 61.7e.. 146.81;, 2416.5( 1312.17~ 755.76E. 0.661 1514.2~ 444756.5' 5867648.6' 3161.5~ 61.25 146.6" 2460.4; 1379.87~ 800.14E. 0.631 1595.0; 444800.3~ 5867580.5! 3255.2~ 61.5C 147.9(, 2505.3~ 1449.02~ 844.591; 1.23 1677.1~ 444844.3: 5867511.1: 3348.1; 61.94 149.2€. 2549.3; 1518.87~ 887.24E. 1.3~ 1759.0( 444886.4( 5867440.9' 3439.8, 62.8~ 149.8C, 2591.7; 1588.89~ 928.42E. 1.15 1840.2: 444927.1; 5867370.6! 3534.4~ 63.62- 149.0~ 2634.~ 1661.64~ 971.37E 1.02 1924.7~ 444969.5: 5867297.61 3627.S<! 63.37 149.4:<' 2675.9( 1733.26~ 1013.97E. 0.42 2008.0: 445011.6( 5867225.6, 3720.1' 62.83- 149.7:<' 2717.7~ 1804.44~ 1055.78E. 0.65 2090.5~ 445052.8~ 5867154.2( 3814.2~ 62.56 149.1E, 2760.9~ 1876.50~ 1098.33E, 0.6C 2174.2~ 445094.8~ 5867081.8: 3907.8.. 62.31 149.5C 2804.2i 1947.81~ 1140.62E 0,42 2257.1; 445136.6~ 5867010.2: 3999.3; 62.02 149.4:( 2846.9E 2017.51~ 1181.741;. 0.331 2338.Q~ 445177.21 5866940.2: 4092.6~ 61.69 149.47 2891.0~ 2088.34~ 1223.56E, 0.36 2420.~ 445218.5~ 5866869.0! 4184.6; 61.3~ 150.o¿" 2934.8~ 2158.22~ 1264.311;. 0.6~ 2501.2; 445258. 7~ 5866798.9: 4278.0; 62.061 151.11;, 2979.0E 2229.90~ 1304.661;. 1.3Q 2583.4~ 445298.6( 5866726.91 4370.7~ 62.42, 151.G¿ 3022.2~ 2302.02~ 1343.80E, 0.74 2665.5' 445337.2( 5866654.51 4462.5E 62.2~ 151.3~ 3064.9' 2373.56~ 1382.501;. 0.531 2746.8, 445375.3( 5866582.7' 4556.7' 62.07 150.37 3108.8f 2446.24~ 1423.04E' 0.9" 2830.0: 445415.3~ 5866509.7" 4649.8( 61.72. 150.5f. 3152.7' 2517.68~ 1463.53E. 0.41 2912.1¿ 445455.3~ 5866438.0< All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 8112.60 Feet on azimuth 149.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Saker Hughes Incorporated .. Conoc;Pt,illips eonocoPhillips Alaslnc.,slot #424 Drill Site 2P, Meltwater,North Slope, Alaska wellb.424 Wellpath: MWD wISe <0-2937'><3069-10548'> Date Printed: 3-Feb-2004 "ii. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing IdeQ/100ftl Sectionlftl 4742.4¡ 62.4IJ. 152.6~ 3196.0~ 2589.68~ 1502.45E, 2.17 2993.9~ 445493.7; 5866365.T 4835.3~ 63.72, 152.2!;. 3238.1 ' 2663.17~ 1540.79E, 1.3~ 3076.7( 445531.5' 5866292.0" 4928.5~ 63.37 151.1£ 3279.6¿ 2736.67~ 1580.33E. 1.08 3160.1~ 445570.5' 5866218.2: 5021.1 ' 63.0f¡ 151.6" 3321.3¡ 2809.19~ 1619.86E, 0.5, 3242.n 445609.5' 5866145.4; 5114.2¡ 62.6G¡ 151.4(;, 3363. 7~ 2882.02~ 1659.39E, 0.51 3325.6( 445648.4t 5866072.3" 5206.4( 62.32 151.5E, 3406.4~ 2953.90~ 1698.45E. 0.39 3407.3~ 445687.0: 5866000.1 f 5300.Q.I 62.21 152.3!;. 3449.9~ 3026.99~ 1737.40E, 0.77 3490.1~ 445725.4~ 5865926.71 5392.0( 61.9G¡ 151.9~ 3493.0' 3098.85~ 1775.34E. 0.45 3571.3~ 445762.8~ 5865854.6~ 5484.8~ 60.81 152.3(, 3537.4( 3170.87~ 1813.40E. 1.26 3652.7~ 445800.3~ 5865782.3' 5578,5f 60.51 152.0~ 3583.4' 3243.18~ 1851.54E. 0.3f! 3734.4¿ 445837.9{ 5865709.7~ 5670.2~ 60.81 151.84 3628.3' 3313.68~ 1889.10E, 0.41 3814.2( 445875.0' 5865639.0: 5762.7~ 61.75 152.57 3672. 7~ 3385.46~ 1926.95E. 1.24 3895.3i 445912.3~ 5865566.9" 5856.1:: 62.07 152.7~ 3716.7~ 3458.65~ 1964.76E 0.4<;' 3977.6~ 445949.5t 5865493.5' 5949.3' 61.7~ 152.4( 3760.61 3531.62~ 2002.60E, 0.52 4059.7~ 445986.8t 5865420.2' 6041.0~ 61.9Q 151.8~ 3803.9i 3603.09~ 2040.42E. 0.59 4140.5i 446024.11 5865348.5: 6135.1( 61.7Q 150.3~ 3848.3i 3675.66~ 2080.52E, 1.4<;' 4223.4i 446063.7' 5865275.61 6228.0( 61.74 150.3l" 3892.3l 3746.77~ 2121.02E, 0.02, 4305.3( 446103.7' 5865204.21 6319.4( 62.1 e, 148.9i 3935.3l 3816.42~ 2161.82E. 1.43 4386.0~ 446143.9t 5865134.3- 6412.9f 62.31 148.0€. 3978.8~ 3886.99~ 2205.05E, 0.82, 4468.7~ 446186.6! 5865063.41 6506.0~ 61.61 147.8!;. 4022.61 3956.63~ 2248.61 E, 0.7~ 4550.8< 446229.7' 5864993.51 6598.3~ 61.87 147.8E 4066.3~ 4025.45~ 2291.86E 0.28 4632.Oi 446272.4t 5864924.31 6692.3¿ 62.25. 149.1i" 4110.3f 4096.26~ 2335.26E, 1.2IJ. 4715.0~ 446315.3{ 5864853.21 6784.5f 61.5C 149.37 4153.8~ 4166.17~ 2376.85E, 0.84 4796.4: 446356.4; 5864783.0! 6877.3¿ 62.06 148.17 4197.7~ 4236.06~ 2419.23E 1.29 4878.1 ¿ 446398.2t 5864712.81 6969.6i 62.9!J, 148.2~ 4240.3~ 4305.69~ 2462.38E. 1.01 4960.0~ 446440.9; 5864642.9; 7063.1( 62.4Q 147.44 4283.1¿ 4375.98~ 2506.59E. 0.97 5043.0( 446484.6~ 5864572.3' 7156.2~ 61.79 146.03 4326.7' 4444.85~ 2551.78E 1.50 5125.2¿ 446529.2t 5864503.1 : 7249.3~ 61.8~ 148.47 4370.6f 4513.83~ 2596.151;. 2.31 5207.H 446573.1' 5864433.8: 7343. H 62.0~ 151.1¡ 4414.7~ 4585.40~ 2637.81E. 2.51 5289.9f 446614.2~ 5864361.9~ 7436.2~ 61.56, 150.7C 4458.7~ 4657.11~ 2677. 70E. 0.69 5372.0~ 446653.6~ 5864289.9/ 7528.0( 60.9~ 150.8<.. 4502.8< 4727.30~ 2716.98E, 0.6G¡ 5452.4¿ 446692.3t 5864219.41 7620.9' 60.2G¡ 150.97 4548.4:: 4798.04~ 2756.34E, 0.8C 5533.3~ 446731.2; 5864148.4' 7714.2~ 60.6:; 151.2¿ 4594.4( 4869.10~ 2795.57E. 0.48 5614.5~ 446769.9~ 5864077.1 : 7807.3l 60.6::- 150.3(;, 4640.1~ 4939.91~ 2835.19E, 0.86- 5695.6f 446809.0; 5864006.0< 7899.8< 60.8~ 151.9(' 4685.3~ 5010.57~ 2874.15~ 1.5IJ. 5776.3~ 446847.4t 5863935.11 7992.6~ 61.2~ 151.6f.. 4730.2~ 5082.19~ 2912.52E 0.56 5857.5i 446885.2t 5863863.21 8084.8f 61.761 151. 7~ 4774.2¿ 5153.56~ 2950.92E, 0.51 5938.5i 446923.1" 5863791.51 8177.9' 62.74 150.7( 4817.5~ 5225.72~ 2990.55E, 1.4G¡ 6020.8i 446962.2/ 5863719.1: 8268.4~ 62.04 150.47 4859.5~ 5295.60~ 3029.95E. 0.81 6101.1~ 447001.1' 5863648.9/ 8364.1¡ 62.22, 151.17 4904.2¿ 5369.44~ 3071.19E, 0.67 6185.6( 447041.8~ 5863574.8; 8458.2i 62.5G¡ 150.1 ~ 4947.8f 5442.17~ 3112.06E. 1.02, 6269.0l 447082.1" 5863501.8' 8550.9( 62.3C. 149.9i 4990.8~ 5513.37~ 3153.10E. 0.34 6351.2( 447122.6" 5863430.3: 8643.3' 62.32 148.5' 5033.7( 5583.61~ 3194.93~ 1.37 6433.0( 447163.9t 5863359.71 8736.6( 62.74 148.3~ 5076.7¿ 5654.14~ 3238.24E O.4Q 6515.7( 447206.T 5863288.9: 8830.4( 62.5:; 148.3E, 5119.8~ 5725.13~ 3281.96E 0.23 6599.0~ 447249.91 5863217.6: 8923.1f 61.77 148.3~ 5163.2( 5794.92~ 3324.95E 0.82, 6681.0¡ 447292.4~ 5863147.S. 9015.8i 61.861 148.7i" 5206.9f 5864.62~ 3367.57E, 0.3Q 6762.6~ 447334.5~ 5863077.5: 9107.7~ 62.27 149.0:¡ 5250.0~ 5934.11~ 3409.52E. 0.52, 6843.8~ 447375.9~ 5863007.7' 9198.8f 62.61 149.1(;, 5292.1f 6003.41~ 3451.05E, 0.3e. 6924.6: 447416.9t 5862938.1 ~ 9293.1i 63.12, 149.2i" 5335.1f 6075.46~ 3494.06E, 0.5Q 7008.5: 447459.4/ 5862865.7\ 9385.8< 63.07 149.37 5377.1~ 6146.52~ 3536.24E. 0.14 7091.1( 447501.1~ 5862794.4: All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 8112.60 Feet on azimuth 149.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .,/ ConocoPhillips ConocoPhillips AlasAc.,slot #424 Drill Site 2P, Meltwater,North Slope, Alaska wellb.424 Wellpath: MWD wISe <0-2937'><3069-10548'> Date Printed: 3-Feb-2004 r'.. BAKER HUGHES INTEQ WeUpath .(Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing fdeç¡/100ftl Sectionfftl 9479.1~ 63.3~ 149.1' 5419.1~ 6218.11~ 3578.851;, 0.42. 7174.4: 447543.1t 5862722.5: 9572.5( 62.8Q 149.7C, 5461.3i 6289.83~ 3621.261;, 0.8Ç. 7257.7f 447585.0' 5862650.5' 9665.0~ 62.4E 149.37 5503.8¿ 6360.66; 3662.92E, 0.52 7339.9~ 447626.2' 5862579.31 9758.1' 62.1(;, 149.8~ 5547.1' 6431.73~ 3704.571;, 0.64 7422.3: 447667.3~ 5862508.0' 9850.6i 61.85 149.7(' 5590.6( 6502.37~ 3745.641;, 0.3Q 7504.0¿ 447707.8' 5862437.01 9943.0' 61.77 149.27 5634.2~ 6572.50; 3786.93E, 0.48 7585.4~ 447748.6' 5862366.6! 10034.7t 61.3G, 149.1l" 5677.9~ 6641.83~ 3828.251;, 0.47 7666.1 ¡ 447789.4' 5862297.0: 10127.9~ 61.21 149.3( 5722.6~ 6712.01~ 3870.05E. 0.21 7747.n 447830.7~ 5862226.51 10219.7: 60.86 148.8E. 5767.1¿ 6780.91; 3911.30E 0.55 7828.0~ 447871.4~ 5862157.31 10312.5t 60.34 149.4( 5812.7' 6850.33~ 3952.78~ 0.74 7908.9~ 447912.4~ 5862087.6< 10405.1~ 60.0E 149.2~ 5858. 7~ 6919.47~ 3993.79E. 0.31 7989.3~ 447952.9~ 5862018.2: 10461.0~ 59.59 148.6' 5886.8( 6960.83; 4018.72E 1.32 8037.6' 447977.5- 5861976.6' 10548.0t 59.59 148.6' 5930.8, 7024.86~ 4057.78E 0.00 8112.6( 448016.1~ 5861912.3f All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 8112.60 Feet on azimuth 149.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated y ConocoPhillips ConocoPhillips Alaslnco,slot #424 Drill Site 2P, Meltwater,North Slope, Alaska well. 424 Wellpath: MWD wISe <0-2937'><3069-10548'> Date Printed: 3-Feb-2004 r,i.. BAKER HUGHES INTEQ Comments MDfftl ITVDfftl J Northrftl I Eastrftl I Comment 10548.od 5930.8 7024.86~ 4057.78~Proiected Data - NO SURVEY Hôlè Sections Diameter Start finl MDfftl 12 1/L 81/2 Start TVDfftl 0.00 3010.0C Start Start Northrftl Eastrftl 0.00 0.00t\, 2388.5~ 1268.14~ O.OOE, 727.20E End End End Start Wellbore MDfftl TVDrftl Northrftl Eastrftl 3010.0( 2388.5~ 1268.14~ 727.201;424 10548.0C 5930.8~ 7024.86~ 4057.78E 424 Casin.a$ Name Top MDfftl Top TVDfftl O.OC O.OÇ, O.OQ O.OC O.OC 0.00 Top Top Northfftl Eastfftl 0.001\. O.OOE 0.001\. O.OOE 0.00r-.. O.OOE. Shoe Shoe Shoe Shoe Well bore MDfftl TVDfftl Northfftl Eastfftl 108.0( 108.0( 0.001\. O.OOF 424 3005.0C 2386.1f 1264.43~ 724.801;.424 10428.0( 5495.1 ( 7322.75~ 3574.48E.424A 16" Conductor 9 5/8" Casina 51/2" CasinQ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 8112.60 Feet on azimuth 149.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e . B03-dQ3 Transmittal Form '&ill BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 2P-424 Contains the following: 1 LDWG Compact Disc J () Lie¿; I (Includes Graphic Image files) 1 LDWG lister summary 1 blue line - MPR Measured Depth Log 1 blueline - MPR TVD Log 1 blueline - CCN-ORD Measured Depth Log 1 blue line - CCN-ORD TVD Log LAC Job#: 605575 Sent By: Glen Horel Date: Mar 25, 2004 <:~ . ~'"". Received By: 1~-},_u.~~') \.s.-(""~"fbr'ý'. Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVED \ ? 6 inn;1 \ ""_ . ...._I..¡.',J'...} ;';¡];;i;~S Oil 8: Gas Cons. Commission ,!\,,~.·.·f'h.orjV1e iY~.; L1H h...~ K~\')rf\ ~ ~_<o-;"" ConocgiJlips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265·6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com January 8, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry Approval to plug back well 2P-424 Dear Sir / Madam: ConocoPhillips Alaska, Inc. hereby files this Application for Sundry Approval to plug back well 2P-424. A permit application for the sidetrack, 2P-424A, will be submitted shortly. Attached are the plug back procedure and a well bore schematic. ConocoPhillips hereby requests a waiver of the tagging requirement on the lower abandonment plugs - our plan is to tag the uppermost plug only. The plugs will be set from the bottom of the hole to approximately 600 ft MD above the Cairn interval to ensure isolation. If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, ~\~- Randy Thomas GKA Drilling Team Leader RECEIVED JAN 0 8 2004 Alaska Oil & Gas Cons. Commission Anchorage ORtG\NAL , . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D '\ 1. Type of Request: D Repair well D D Suspend Perforate D D o Alter casing D D Abandon Plug Perforations Stimulate Change approved program Pull Tubing Perforate New Pool 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 28' RKB, 252' AMSL 8. Property Designation: ADL 373112/389058 / L 32092/32409 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D Variance D Time Extension D )Î-\ 115 DflJ ;;/., <b1 lilt Annular Dispos.O Other D Re-enter Suspended Well D 5. Permit to Drill Number: 203-203 6. API Number: 50-103-20475-00 9. Well Name and Number: 2P-424 10. Field/Pools(s): Kuparuk River Field / Meltwater Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth rvD (ft): Plugs (measured) Junk (measured): 5930 MD TVD Burst Collapse 11. Total Depth MD (ft): 10548 Casing Structural Conductor Surface Intermediate Production Total Depth rvD (ft): Effective Depth MD (It): 5930 10548 Length Size 80' 2977 16" 108 3005 108 2386 9.625" Liner Perforation Depth MD (ft): Perforation Depth rvD (ft): Tubing Size: Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch D Exploratory D Development 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/8/2004 Oil D Gas D 16. Verbal Approval: Yes Dat~11712004 WAG D GINJ D Commission Representative: Tom Maunder ._ 17. I hereby certify that the foregoing is true and correct to the best of y knowledge. Contact Printed Name R. Thomas Signature ~~ Title Kuparuk Team Leader Phone 265-6830 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integritý12l BOP Test D Mechanical Integrity Test D Location Clearance D Other: (.CJ(\.\ØC\ I-~<::.,\>~c:\(:::)' .~ \().~ \~S-\ ~hJS 5750 3090 Tubing Grade: Tubing MD (ft): Service D Plugged D WINJD Abandoned 0 WDSPL D Philip Havden @ 265-6481 Date \ f? r¿, f" Prp,narP.r1 bv PhiUn havdRn Sundry Number: 3o'Í-ðO¥- "t:CEIVED JAN 0 8 2004 Subsequent Form Required: ~CJ "\ IØJMS BfL Alaska Oil & Gas Cons. Commission JAM 0 9 10M Anchorage Approved by: Original Signed By Sarah Palin BY ORDER OF THE COMMISSION COMMISSIONER Form 10-403 Revised 2/2003 ORIGjf~AL Date: I~ð& SUBMIT IN DUPLICATE . . 2P-424 Pluq Back Procedure Purpose To isolate the Bermuda and Cairn formations from one another and from the proposed sidetrack 2P-424A. General A total of 4 plugs x 450 ft MD will be set in the well to form a continuous column of cement from TD to 600 ft above the top of the Cairn interval (See attached figure). An open hole, low side sidetrack is planned from approximately 7000 ft MD (to be confirmed when final bottom hole location has been determined). 1. Contact inspector to witness job. 2. PU +/- 500' cement stinger w/ slotted flow diverting joint on bottom. 3. RIH with stinger and 5" DP to TD. 4. Circulate and condition mud. 5. Spot the first 450 ft MD balanced cement plug to cover the lower part of the Bermuda interval from 10548 ft MD to 10098 ft MD. Reciprocate pipe until cement reaches the end of the plug back string. Spot plug at 4-5 BPM. Cement recipe and volume calculations to be provided by Dowell. 6. Pull stinger and DP out of plug no faster than 1 stand /2 minutes. Pull out to 250 - 300 ft above the cement. Circulate up spacers and contaminated mud/cement the long way at maximum rate. Monitor for cement in returns. 7. When the next cement batch has been mixed, wash down to previous planned TOC or where cement is detected and spot the second balanced cement plug. Repeat the procedure as for the first plug, again monitoring returns for cement. Adjust cement excess for plugs 3 and 4 based on observed cement returns. 8. Repeat procedure for plugs 3 and 4. Final TOC is planned to be 8847 ft MD approximately. 9. Circulate up spacers and contaminated mud/cement the long way at maximum rate. 10. POOH and UD cement stinger. Check 5" DP for cement contamination. 11. Test BOP equipment. 12. Only the top of plug # 4 will be tested with the drilling BHA - pending approval of the AOGCC. · . 2P-424 Planned P&A 16" @ 108' MD / TVD 95/8" @3005' MD Provisional sidetrack point @ 7000' MD Top Plug #4 @ 8748' MD ¡Þ Top Cairn @ 9347' MD Bottom Cairn @ 9391' M D Top Plug #3 @ 9198' MD Top Plug #2 @ 9648' MD Top Bermuda @ 9909' MD Top Plug #1 @ 10098' MD Bottom Bermuda @ 10332' MD 8 %" hole @ 10548' MD / 5930' TVD Re: 2P-424 Planned P&A . . Subject: Rc: 2P-424 Planned P&A From: STMaunderØ;aol.com Date: Thu, 08 Jan 2004 01:15:50 -0500 (EST) To: Philip.Hayden(~conocophillips.com CC: tom__maunder@admin.statc.ak.us, Randy. L.Thomas(qjconocophi ll.ips.com, darron .b.j ac kson(q,}conocophi II ips.com, je f(j oncs@)admin.state.aleus, j im _regg(4?admin.state.ak. us Philip, et al: Your plan looks good and I do appreciate the care with which you are planning to plug the open hole. Your plan to tag the uppermost plug only is acceptable. Given that you are going to lay in the total plug in 4 sections, the placement of each section will essentially tag the prior section. Please have the company man contact the Inspector so that he can have the option of witnessing the tagging of plug 4. Tom Maunder, PE AOGCC 1 of 1 1/8/2004 12: 54 PM 2P-424 Planned P&A . . . Sub.iect: 2P-424 Planned P&A From: "f laydcn~ Philip" <PhilipJ-laydcn~Dconocophillips.com> Date: Wed, 07 Jan 2004 18:51 :34 -0900 To: stmaunder@aol.co01 CC: "T0111 Maunder (E-mail)..<tom_._01aundcr(~f~admin.state.ak..us>. "'1.'ho01a8, Randy L" <Randy.L.Thomas@conocophillips.com>, "Jackson, Darron B." <darron.b .jackson@~conocophi 11 i ps.com> Tom, As discussed on the telephone we have decided, with partner approval, to P&A well 2P-424 and sidetrack it to a new location. The planned abandonment is summarised in the attached schematic but for quick reference: The potential hydrocarbon bearing zones in the open hole, the Bermuda and Cairn intervals, will be isolated from one another and from the proposed sidetrack by a continuous column of cement from TD to 600 ft MD above the top of the Cairn. This column of cement will be placed in the wellbore in 4 plugs, each 450 ft MD in length. It is our intention to tag only the uppermost plug - with your approval - as we consider this to be sufficient proof of isolation. We are being quite cautious in our abapdonment of this well vis-a-vis the height and quantity of the cement but this is due to our desire to eliminate any possibility that the currently exposed strata could be utilised for MI transportation/communication in the future. If you have any questions or comments please contact me on my mobile phone, 240-5858. Regards Philip «2P-424 plug Back Schematic.ppt» plug Back Content-Type: Content-Encoding: . . . 2P-424 plug Back Content-DescrIptIon. S h t· t cerna lC.pp application/vnd.ms- powerpoint base64 1 of 1 1/812004 12:55 PM . . FRANK H. MURKOWSKI, GOVERNOR .A 1,.4.SIiA. OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510-0360 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field 2P-424 ConocoPhillips (Alaska), Inc. Permit No: 203-203 Surface Location: 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM Bottomhole Location: 2626' FSL, 801" FWL, Sec. 21, T8N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill 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 the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). ".2L.: . , / /.. BY ORDER Q~ THE COMMISSION DATED this.LQ. day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. It . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Á-¡~ > ExploratoryU Development Oil ~ Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 2P-424 6. Proposed Depth: 12. Field/Pool(s): MD: 10544' . rvD: 5898' . Kuparuk River Field 7. Property Designation: 1a. Type of Work: Drill ~ Redrill U Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM Top of Productive Horizon: 2218' FNL, 552' FWL, Sec. 21, T8N, R7E, UM Total Depth: 2626' FSL, 801' FWL, Sec. 21, T8N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 444010 16. Deviated wells: Kickoff depth: 300 18. Casing Program Size Hole Casing 42' 16" 12.25" 9.625" 8.5" 5.5' 8.5" 3.5" --- 19 Total Depth MD (It): Casing Structu ral Conductor Detailed Operations Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee Property Plat /1 b. Current Well Class: Stratigraphic Test 0 ADL 373112/389058 8. Land Use Permit: L32092 I 32409 9. Acres in Property: 5760 10. KB Elevation y- 5868966 Zone- 4 252' AMSL feet Well within Pool: 2P-422 , 46.93 17. Anticipated Pressure (see 20 MC 25.035) ft. Maximum Hole Angle: Max. Downhole Pressure: 2424 psig Setting Depth 62.12° Specifications Top Bottom Weight Grade Coupling Length MD TVD MD TVD 62.5# H-40 Weld 80 28' 28' 108' 108' 40# L-80 BTC 3005 28' 28' 3033 2386 15.5# L-80 BTCM 9270 28' 28' 9298 5315 9.3# L-80 EUE8RDM 1246 9298 5315 10544 5898 Meltwater Oil Pool 13. Approximate Spud Date: 1/2/2004 14. Distance to Nearest Property: 2218' @ Target 15. Distance to Nearest I Max. Surface Pressure: 1801 psig Quantity of Cement c. f. or sacks (including stage data) ArticSet I (preinstalled) 561 sx AS Lite & 294 sx LiteCRETE 381 sx LiteCRETE (Included above) (To be completed for Redrill and Re-Entry Operations) / Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD rvD Pf:CEI\Jeo '.. . U : 2003 AfQOf&t: . . ~=Commi&!J(¡n Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Length Size o o BOP SketchU Diverter Sketch 0 /perfOration Depth TVD (ft): Drilling Program~ Timev. Depth PlotU Seabed Report 0 Drilling Fluid Program 0 21. Verbal Approval: Commission Representative: Date: Printed Name 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ?'" 1 Contact Philip Hayden 265-6481 Title Kuparuk Drilling Team Leader Phon~.. '--bo 50 Date l (( 2 6/0"> ....b5 PreDared bv PhiliD Havden Commission Use Only Permit to Drill I API Number: / Permit Approval ~ - Isee cover letter Number: 2.D 3 r '203 5O-/D 3" ,2.6 ¥7Ç-.. ó() Date: /;2l/é '(:; for other requirements Coodmo", at ",pro,,",' Samples "",W"", 0 y., ~JIo Mod log ,eqo', þ{ 0 y" g No Hydrogen sulfide measures 0 Yes ~ No Directional survey required ~es' Ò No Signature R. Thomas ~ç~~ Other: ~SQa f~\ ""'\t"\\"'-'-..J""- ~\' ~~~ Approved by: Original Signed By :saran I-'alln BY ORDER OF THE COMMISSION COMMISSIONER Form 10-401 Revised 3/2003 . D",IJ/lê:JÓ 8 Submit in duplicate e .lication for Permit to Drill, Well 2P-424 Revision No.O Saved: 25-Nov-03 Permit It - Meltwater Well #2P-424 Application for Permit to Drill Document MoximizE Well I/glu~ Table of Contents 1. Well Name...... ...... ...... ...... ......... ....... ................. ....... ........ .................... ..... ................ 2 Requirements of 20 AAC 25.005 (f)..... ........ .... ..... .................. ................ .... ...... ....... ...... ...... ..... .... ..........2 2. Location Sum mary . .......... ........... ...................... ........ ....... .............. ................. ... ...... 2 Requirements of 20 AAC 25.005(c)(2) .............................. ............. .......... ........ ... .................. ...... ...........2 Requirements of 20 AAC 25. 050(b).. ..... ......................... ..... ........ ..... ..... ......... ....... ................ ........ ......... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ............. ................ ..... ......, ............. ................ ....... ....... ............... 3 4. Dri II i ng Hazards Information .................. ........ ........ ........ ................ ......... ................ 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) .. ...... ..................... ..................... ......... .................... ....... ............. 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) . .... ....... ....................... ............... ......... ....... ....... ................. .........4 8. Dri II i ng FI u id Program ..... ........... ................. .......... ....... ...................... ..... ................ 5 Requirements of 20 AAC 25.005(c)(B) ........... ................................... .................,.... ..... ............ ,.. ........... 5 Surface Hole Mud Program (extended bentonite) ..................................................................................5 Production Hole Mud Program (LSND) .... ........ .......................... ........... ...... ...... ....................... .............. 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seism ic Analysis ........ ...... ........... .................... ........ .......... ............. .......................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bonding ...............................................................................................6 ORIGINAL 2P-424 PERM/T IT.doc Page 1 of 7 Printed: 25-Nov-03 · .I.ication for Permit to Drill, Well 2P-424 Revision No.O Saved: 25-Nov-03 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................6 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ........ ........ .......... ...... ..... ........................... ..... .......... ..... ................ ...... ... 7 Attachment 1 Directional Plan (13 pages) .............................................................................................. 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 7 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 7 Attachment 4 Well Schematics (1 page) ................................................................................................ 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b}. For a well with multiple well branches, each branch must simi/arly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2P-424. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an Item a/ready on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing {A}the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to govemmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; {C} the proposed depth of the well at the top of each objective formation and at total depth; j Location at Surface NGS Coordinates Northings: 5,868,966 · Eastings: 444,010 .. 910' FNL, 2050' FWL, Section 17, T8N, R7E, UM I RKB Elevation I 252' AMSL Pad Elevation 224' AMSL Location at Top of Productive Interval (Bermuda Sand) NGS Coordinates Northings: 5,862,352 2218' FNL, 552' FWL, Section 21, T8N, R7E, UM Eastings: 447,764 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 9,975 5,632 5,380 Location at Total Depth NGS Coordinates Northings: 5,861,915 Eastings: 448,012 2626' FSL, 801' FWL, Section 21, T8N, R7E, UM Measured Depth, RKB: 10,544 Total Vertical Depth, RKB: 5,898 Total Vertical Depth, 55: 5,646 and ORIGINAL 2P-424 PERMIT /T.doc Page 2 of 7 Printed: 25-Nov-03 · *lication for Permit to Drill, Well 2P-424 Revision No.O Saved: 25-Nov-03 (D) other information required by 20 MC 25.0S0(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated., the application for a Permit to Dril/ (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including aI/ adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wel/bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25. 035, 20 MC 25.036, or 20 MC 25.037, as applicable; An API 13 5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 2P-424. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered., aiteria used to determine it, and maximum potential surface pressure based 017 a methane gradient,· The expected reservoir pressures in the Bermuda sands in the 2P-424 area vary from 0.26 to 0.42 psi/ft, or 5.1 to 8.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from existing wells on the field together with reservoir model forecasts. .r* The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Bermuda sand formation is 1801 psi, calculated as follows: MPSP =(5809 ft)(0.42 - 0.11 psi/ft) / =1801 psi (B) data on potential gas zones; Due to the presence of high annular pressures on some of the Meltwater wells (2P-431, 451 & 438) there -~ is the risk of encountering a pressured shallow zone. This interval may be encountered through the C-80 ?'f\ formation to the top of the Bermuda. The original high pressures recorded in these annuli were of concern but as can be seen from the following table a series of annular bleeds together with an observed natural decline in pressures have reduced the potential maximum pressure considerably: Original Latest C-80 C-80 Equivalent Surface Fluid C-80 Pressure Gradient (ppg) Pressure Level Pressure 1751 13.85 1200 193 1678 1541 12.23 750 1392 1020 1245 9.83 800 768 1216 Well Surface Pressure 1600 1380 879 Fluid Level 2387 2160 895 C-80 Equivalent Gradient (ppg) 13.27 8.10 9.60 ~ 2P-431 2P-451 2P-438 ORIGINAL 2P-424 PERM/T IT. doc Page 3 of 7 Printed: 25-Nov-03 · .. lication for Permit to Drill, Well 2P-424 Revision No.O Saved: 25-Nov-03 Using the latest annular pressures available the highest pressure that would be expected is approximately ,/ 1678 psi at 2461 ft 1VD or 13.11 ppg EMW. Most of the previously drilled Meltwater wells have had an FIT/LOT of approximately 16 ppg thus indicating that this pressured interval, should it exist, can be safely controlled with standard well control methods. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting fO/mation integrity tests, as required under 20 MC 25.030(f}; 2P-424 will be completed with 9 5/8" surface casing landed above the C-80 mudstone interval. The casing shoe will be drilled out and a leak off test will be performed in accordance with the "Leak Off Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Ho/e Top 8tm Csg/Tbg Size Weight Length MDfTVD MOfTVO 00 (in) (in) (/bltt) Grade Connection (tt) (tt) (tt) 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 5/8 12 1f4 40 L-80 BTC 3005 28 / 28 3033 / 2386 3 V2 8 V2 9.3 L-80 EUE8RD Mod 1246 Cement Program Cemented to surface with ArticSet I Cement to Surface with 561 sx ASLite Lead, 294 sx LiteCRETE Tail 28/28 9298/5315 Cement Top planned @ 9298/ 5315 10544/ 5898 8998' MD/ 5175'1VD. Cemented w/ 381 sx LiteCRETE 5 V2 8 V2 15.5 L-80 BTCM 9270 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dril/ must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h}(2}; ORIGINAL 2P-424 PERM/T IT. doc Page 4 of 7 Printed: 25-Nov-03 . ... lication for Permit to Drill, Well 2P-424 . Revision No.O . Saved: 25-Nov-03 A 21 %", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 2P-424. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the fol!owing Items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, Including a diagram and description of the drilling fluid system, as required by 20 MC 25. 033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Initial Value Final Value Density (ppg) 8.6 ~9.2 Funnel Viscosity 250 250 (seconds) Yield Point 35-45 35-45 (cP) pH 9-9.5 9-9.5 API Filtrate 6 6 (cc /30 min)) Chlorides (mg/l) <600 <600 *9.6 ppg if hydrates are encountered Production Hole Mud Program (LSND) 95/8" Casing Shoe to TD Initial Value Final Value 9.6 9.6 22-28 10-15 9-9.5 9-9.5 4-6 4 Density (ppg) Yield Point (cP) pH API Filtrate (cc / 30 min)) HTHP @ 15d' (cc)) <12 <12 Base of Permafrost to 9 5/8" Casing Point Initial Value Final Value ~9.2* 9.6 150-200 55-65 30-35 12-15 9-9.5 9-9.5 4-6 4-6 ,/ <600 <600 (/ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Pem/it to Drill must be accompanied by each of the following Items, except for an Item already on file wIth the commission and Identified In the application: (9) for an exploratory or stratigraphic test well a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dli!! must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. ORIGINAL 2P-424 PERMIT IT. doc Page 5 of 7 Printed: 25-Nov-03 · .lication for Permit to Drill, Well 2P-424 Revision No.O Saved: 25-Nov-03 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating dnlling vessel an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (12) eVIdence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a PermIt to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test (conductor has already been installed and cemented). 2. Spud and directionally drill 12 %" hole to casing point at 3033' MD / 2386'1VD as per directional plan. Run MWD tools as required for directional monitoring and LWD tools as required for data acquisition. 3. Run and cement 95/8",40# L-80, BTC casing to surface. Displace cement with mud. Perform top job if required. 4. Remove diverter system and install wellhead and test. InstaU 13 5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 5. PU 8 V2" bit and 6 %" drilling assembly, with MWD and LWD. RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 6. Drill out cement and 20' of new hole. Perform LOT or FIT to 18.0 ppg EMW, recording results. 7. Directionally drill to 5 V2" X 3 '12" casing point at 10544 MD / 5898'1VD. 8. Run 5 V2", 15.5# L-80, BTC Mod x 3 V2", 9.3# L-80, EUE8RD Mod casing to TD. Pump cement and displace with water and mud. Note that the cross over and seal bore extension for the completion will be positioned 200' MD above the Cairn interval, if present, as this is an interval that may be produced later in the life of the field. 9. Make up completion string as required and RIH to depth. Locate seal bore extension, space out and land completion. Pressure test completion and production casing to 3500 psi for 30 minutes and record results. Shear RP shear valve in gas lift mandrel. 10. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV 11. Freeze protect well with diesel by pumping into the annulus, taking returns from tubing and allowing to equalize. Carry out LOT and injection test on the outer annulus. Sweep the annulus with water and freeze protect. 12. Set BPV and move rig off. 13. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in gas lift mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). Perforate well and rig down wire line unit. ORIGINAL 2P-424 PERMIT IT. doc Page 6 of 7 Printed: 25-Nov-03 · .IiCatiOn for Permit to Drill, Well 2P-424 Revision No.O Saved: 25-Nov-03 14. Carry out fracture stimulation. 15. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 2P Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 2P Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on the pad in accordance with a permit from the State of Alaska. At the end of drilling operations, an application may be submitted to permit 2P-424 for annular disposal of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 Directional Plan (13 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematics (1 page) ORIGINAL 2P-424 PERMIT IT. doc Page 7 of 7 Printed: 25-Nov-03 . . ConocoPhillips Alaska, Inc. Created by bmlchael Dote plotted: 18-Nov-2003 Plot Reference Is 2P-424 Ven¡13.b. COordinates ore in feet reference slot #424_ True Vertical Deþ~hs Qre reference¡ RKB (Doyon 141). lIIit. BAD_ - INTEQ 400 Structure: Drill Site 2P Field : Meltwater Well : 424 Location: North Slope, Alaska East (feet) -> o 400 800 1200 1600 2000 2400 2800 3200 3600 4000 SURFACE LOCATION: 910' FNL, 2050' FWL SEC. 17, T8N, R7E 149.99 AZIMUTH 7606' (TO TARGET) ***Plane of Proposal.** 4 TRUE TARGET LOCATION: 2218' FNL, 552' FWL SEC. 21, TBN, R7E Torget Top Bermudo(T3) TD LOCATION: 2626' FSL, 801' FWL SEC. 21, T8N, R7E i ~,;'A I ú ;,~ ".!) ¡'J /~¥;..') ~ ConocoPhillips 4400 4800 400 - 0 - 400 - 800 - 1200 - 1600 - 2000 - 2400 - 2800 U) 0 C - 3200 -+- :r ..---., -+. - 3600 CD CD -+- '-'" - 4000 I V - 4400 - 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - 7200 400 - 800 - 1200 - 1600 - ........... +- (].) 2000 - (].) 0 '+- '-'" ...c ::::t:) +- 2400 - Q. - (].) 0 G) 2800 - 0 - () Z - 3200 - I.... (].) » > r- Q) 3600 - ::J I.... l- I 4000 - V 4400 - 4800 - 5200 - 5600 - 6000 - ConocoPhillips Alaska, I Inc. y ConocoPhillips o - ! RKB Elevation: 252' Well : 424 structure : Drill Site 2P Field : Meltwater Location : North Slope, Alaska KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 It 8.00 Build 3/100 13.00 16.00 19.00 DLS: 3.00 deg per 1 DO It 22.00 25.00 28.00 Base Permafrost 31.00 34.00 40.00 46.00 52.00 Base West Sak 58.00 Creoted by bmk::hoel Dote plotted: 1B-Nov-2003 Plol Reference is 2P-424 Vers#3.b. Ccordínotes are in feet reference slot #424. True Vertical Deplh5 ore reference RK8 (Doyon 11II. ..,. INTEQ - 149.99 AZIMUTH 7606' (TO TARGET) ...Plane 01 Prapasal... EOC '0<1 9 5/8 Casing ~ C80 C50 C40 TANGENT ANGLE 62.12 DEG e ~ T7 5 1/2 x 3 1/2 XO T4.1 (Top Cairn) 2P-424 Tap Berm TGT 24 Jul 03 Target Top Bermuda(T3) OWC T2 (Base Bermuda) TO - Casing PL o 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 Vertical Section (feet) - > Azimuth 149.99 with reference 0.00 N, 0.00 E from slot #424 I I ConocoPhillips Alaska, Inc. ¥ Created by bmlchoel Structure: Drill Site 2P Well : 424 ConocoPhillips Dote plotted: 18-Nov-2003 ~Jot Reference is 2P-424 Vers#3.b. Field : Meltwater Location : North Slope, Alaska Coordinates ore in feet reference sial #424. Vertical Depths ore reference RKB (Doyon III.. ..... INTEQ -- PROF~LE COMMENT DATA ==== - ----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100 0 KOP 300.00 0.00 149.99 300.00 0.00 0.00 0.00 0.00 Build 3/100 800.00 10.00 149.99 797.47 -37.69 21.77 43.52 2.00 ::0 - Base Permafrost 1388.19 27.65 149.99 1352.00 -201.37 116.31 232.55 3.00 (j) Base West Sak 2169.75 51.09 149.99 1952.00 -627.67 362.55 724.85 3.00 - Z EOC 2537.36 62.12 149.99 2154.01 -893.03 515.82 1031.30 3.00 » 9 5/8 Casing 3033.4 7 62.12 149.99 2386.00 -1272.77 735.16 1469.83 0.00 r- C80 3193.86 62.12 149.99 2461.00 -1395.53 806.08 1611.60 0.00 C50 4442.77 62.12 149.99 3045.00 -2351.47 1358.24 2715.56 0.00 C40 5011.62 62.12 149.99 3311.00 -2786.89 1609.74 3218.39 0.00 e C37 5424.36 62.12 149.99 3504.00 -3í 02.80 1792.22 3583.22 0.00 17 8061.18 62.12 149.99 4737.00 -5121.08 2958.02 5914.00 0.00 5 1/2 x 3 1/2 XO 9298.28 62.12 149.99 5315.48 -6067.99 3504.97 7007.52 0.00 T4.1 (Top Cairn) 9498.28 62.12 149.99 5409.00 -6221.07 3593.39 7184.30 0.00 Target Top Bermuda(T 9975.17 62.12 149.99 5632.00 -6586.10 3804.23 7605.84 0.00 OWC 10263.87 62.12 149.99 5767.00 -6807.08 3931.87 7861.04 0.00 T2 (Base Bermuda) 10353.69 62.12 149.99 5809.00 -6875.83 3971.58 7940.43 0.00 ,/ TO - Casinq PL 10543.69 62.12 149.99 5897.85 -7021.26 4055.59 8108.38 0.00 ConocoPhillips Alaska, Inc. Dote plotted: 18-Nov-2003 Plot VersIf3.b. sl01 #424-. Field : Meltwater Location : North Slope, ..... Co no co Phil lips Created by bmkhQe! Structure: Drill Site 2P Well : 424 TRUE NORTH 340 20 330 .30 320 49 \ @ 4 100g / 310 \ 0 \ 300 60 290 70 280 80 270 90 260 100 250 110 120 230 130 220 140 210 200 160 190 180 170 Normal Plane Iling Cylinder Feet All depths shown are Measured depths on rence Well ska, Inc. CreQted by· b-mkhae! Structure : Drill. Site 2P Field: Well : ~". Co no co Phillips [)(¡te p!otted : i8-NO\f-2003 P!pt Referenc~ is 2P-424 V<JrsIlJ.b. Coordinates are in feat rnf¡¡¡rance slot '42+_ Vertical Depths RKB LOCQtioo : North Slope, AIQskq INTEQ 80 I 40 , o 40 I 80 240 280 320 360 400 440 80 120 '\ 1500 160 \. 1600 \ - 200 1400 \. ~ - 240 7", (/) .,1500 - 280 0 C \ -+ \ :J 1700 - 320 ........... -h () () 1600 -+ - 360 '---' I V 400 440 1800 - 480 - 520 - 560 1900 600 640 - 680 -720 Creoted by bm!choe! Date plotted: 19-Nov-2003 Plot Reference is 2P-424 Vf;J('s#3.b, ocoPhillips Alaska, Structure: Drill Site 2P Field : Meltwater Coordif'lotes ore in feet raf-arsnca $101 1424_ ue Vertical Depths are RKB (Doyon 141). -~ INTEQ 200 400 600 800 1000 Well : 424 '../ ConocoPhillips Location : North Slope, Alaska East (feet) -> 1200 1600 1800 1400 2000 " " ".2500 " , " '" 2800 " " '. 4600 4900 2200 2400 2500 2800 400 ~.~~ 600 - 800 - 1000 1200 - 1400 - 1600 - 1800 3100 2000 - 2200 3400 ~ """" - 2400 () () -+ '--'" ..~ - 2600 I Ý76' _ V - 2800 - 3000 \ .,3100 4300 3200 \ 700 \ 3400 460ð \ ~ 3600 - - 3800 - 4000 - 4200 1400 Creole<! by bmkhoeJ Date plotted : 18-Npv- 2003 Plot R<rderencl')- is 2P-424Vf:)(sIl3.b. Coa.rdinotß$ ore in feat fefßfS:I1Ct"l slot 1142.4- Depths ore RKB (Doyon INTEQ 1600 1800 2000 2200 Structure: Drill Site 2P ConocoPhillips Alaska, Well : 424 Field: Meltwater 2400 2600 ~ , 2800 East (feet) -> 3200 4000 4300 \ \ \ \ 3000 , \ 520Ò\ \ 4900 3700 Location : North Slpp<;¡, 3400 3600 , ~ " 5800 \ \, 4000 ¥ ConocoPhillips 3800 4000 4200 4400 4600 3400 - 3600 - 3800 5500 ,4600 4000 - 4200 '. 4900 " 4400 "'~- 4600 - 4800 5000 (j) 0 c: - 5200 -+- :::J ~ -k 4300 - 5400 () () \ -+- '---" - 5600 I V - 5800 '\ 4 600 - 6000 \ ~ 6200 - 6400 - 6600 - 6800 5800 7000 - 7200 \ \ \ \ e . ConocoPhillips Alaska, Inc. Drill Site 2P 424 slot #424 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-424 Vers#3.b prop45l7 Date printed Date created Last revised 5-Sep-2003 25-Feb-2001 5-Sep-2003 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.571,w150 26 53.022 Slot Grid coordinates are N 5868966.260, E 444010.429 Slot local coordinates are 909.67 S 2053.38 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL e ConocoPhillips Alaska, Inc. Drill Site 2P,424 Meltwater,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 4.00 6.00 8.00 10.00 13.00 1000.00 1100.00 1200.00 1300.00 1388.19 16.00 19.00 22.00 25.00 27.65 1400.00 1500.00 1600.00 1700.00 1800.00 28.00 31. 00 34.00 37.00 40.00 1900.00 2000.00 2100.00 2169.75 2200.00 43.00 46.00 49.00 51. 09 52.00 2300.00 2400.00 2500.00 2537.36 3000.00 55.00 58.00 61. 00 62.12 62.12 3033.47 3193.86 3500.00 4000.00 4442.77 62.12 62.12 62.12 62.12 62.12 4500.00 5000.00 5011.62 5424.36 5500.00 62.12 62.12 62.12 62.12 62.12 6000.00 6500.00 7000.00 7500.00 8000.00 62.12 62.12 62.12 62.12 62.12 8061.18 8500.00 9000.00 9298.28 9498.28 62.12 62.12 62.12 62.12 62.12 0.00 0.00 0.00 0.00 2.00 0.00 149.99 149.99 149.99 149.99 0.00 100.00 200.00 300.00 399.98 499.84 599.45 698.70 797.47 895.45 992.25 1087.61 1181. 27 1272.96 1352.00 1362.45 1449.47 1533.80 1615.20 1693.46 1768.34 1839.66 1907.21 1952.00 1970.81 2030.29 2085.47 2136.22 2154.01 2370.35 2386.00 2461. 00 2604.15 2837.96 3045.00 3071.76 3305.57 3311.00 3504.00 3539.37 3773.18 4006.98 4240.78 4474.59 4708.39 4737.00 4942.20 5176.00 5315.48 5409.00 R E C TAN G U L A R COO R DIN ATE S 0.00 N 0.00 N 0.00 N 0.00 N 1. 51 S 6.04 S 13 .59 S 24.14 S 37.69 S 54.95 S 76.63 S 102.66 S 132.99 S 167.51 S 201.37 S 206.14 S 248.78 S 295.30 S 345.58 S 399.48 S 456.85 S 517.54 S 581.37 S 627.67 S 648.18 S 717.78S 789.98 S 864.58 S 893.03 S 1247.15 S 1272.77 S 1395.53 S 1629.86 S 2012.57 S 2351.47 S 2395.28 S 2777.99 S 2786.89 S 3102.80 S 3160.70 S 3543.41 S 3926.12 S 4308.84 S 4691.55 S 5074.26 S 5121. 08 S 5456.97 S 5839.68 S 6067.99 S 6221. 07 S 0.00 E 0.00 E 0.00 E 0.00 E 0.87 E 3.49 E 7.85 E 13.94 E 21. 77 E 31. 74 E 44.26 E 59.30 E 76.81 E 96.75 E 116.31 E 119.07 E 143.70 E 170.57 E 199.61 E 230.74 E 263.88 E 298.93 E 335.81 E 362.55 E 374.40 E 414.60 E 456.30 E 499.39 E 515.82 E 720.37 E 735.16 E 806.08 E 941. 43 E 1162.49 E 1358.24 E 1383.55 E 1604.61 E 1609.74 E 1792.22 E 1825.67 E 2046.73 E 2267.79 E 2488.85 E 2709.91 E 2930.97 E 2958.02 E 3152.03 E 3373.09 E 3504.97 E 3593.39 E Dogleg Degl100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 e PROPOSAL LISTING Page 1 Your ref 2P-424 Vers#3.b Last revised 5-Sep-2003 Vert Sect 0.00 0.00 0.00 0.00 2.00 0.00 0.00 0.00 0.00 KOP 1. 75 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 149.99 2.00 2.00 2.00 2.00 3.00 6.98 15.69 27.88 43.52 63.46 3.00 3.00 3.00 3.00 3.00 88.49 118.56 153.58 193.45 232.55 Base Permafrost 3.00 3.00 3.00 3.00 3.00 238.06 287.30 341. 02 399.09 461. 33 3.00 3.00 3.00 3.00 3.00 527.58 597 . 67 671.39 724.85 Base West Sak 748.54 3.00 3.00 3.00 3.00 0.00 828.92 912.30 998.45 1031. 30 EOC 1440.24 0.00 0.00 0.00 0.00 0.00 1469.83 9 5/8" Casing 1611.60 C80 1882.21 2324.18 2715.56 C50 0.00 0.00 0.00 0.00 0.00 2766.15 3208.11 3218.39 C40 3583.22 C37 3650.08 4092 . 05 4534.02 4975.99 5417.95 5859.92 5914.00 T7 6301. 89 6743.86 7007.52 5 1/2 x 3 1/2 XO 7184.30 T4.1 (Top Cairn) All data is in feet unless otherwise stated. Coordinates from slot #424 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 8108.38 on azimuth 149.99 degrees from wellhead. Total Dogleg for wellpath is 62.12 degrees. Vertical section is from wellhead on azimuth 149.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL e e ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Drill Site 2P,424 Your ref 2P-424 Vers#3.b Meltwater,North Slope, Alaska Last revised 5-Sep-2003 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I NA T E S Deg/100ft Sect 9500.00 62.12 149.99 5409.81 6222.39 S 3594.15 E 0.00 7185.82 9975.17 62.12 149.99 5632.00 6586.10 S 3804.23 E 0.00 7605.84 2P-424 Top Berm TGT 24 Ju1 03 10000.00 62.12 149.99 5643.61 6605.10 S 3815.21 E 0.00 7627.79 10263.87 62.12 149.99 5767.00 6807.08 S 3931. 87 E 0.00 7861. 04 OWC 10353.69 62.12 149.99 5809.00 6875.83 S 3971. 58 E 0.00 7940.43 T2 (Base Bermuda) 10500.00 62.12 149.99 5877 . 42 6987.81 S 4036.27 E 0.00 8069.76 10543.69 62.12 149.99 5897 . 85 7021. 26 S 4055.59 E 0.00 8108.38 TD - Casing Pt. All data is in feet unless otherwise stated. Coordinates from slot #424 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 8108.38 on azimuth 149.99 degrees from wellhead. Total Dogleg for wellpath is 62.12 degrees. Vertical section is from wellhead on azimuth 149.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ O· ,R'· rr::INf ^ t '_.J:f ~ . ~ ~~pJ ~ ß '-, I~ L e e ConocoPhillips Alaska, Inc. Drill Site 2P,424 Meltwater,North Slope, Alaska PROPOSAL LISTING page 3 Your ref 2P-424 Vers#3.b Last revised: 5-Sep-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 0.00 N 0.00 E KOP 1388.19 1352.00 201.37 S 116.31 E Base Permafrost 2169.75 1952.00 627.67 S 362.55 E Base West Sak 2537.36 2154.01 893.03 S 515.82 E EOC 3033.47 2386.00 1272.77 S 735.16 E 9 5/8" Casing 3193.86 2461. 00 1395.53 S 806.08 E C80 4442.77 3045.00 2351. 47 S 1358.24 E C50 5011.62 3311.00 2786.89 S 1609.74 E C40 5424.36 3504.00 3102.80 S 1792.22 E C37 8061.18 4737.00 5121. 08 S 2958.02 E T7 9298.28 5315.48 6067.99 S 3504.97 E 5 1/2 x 3 1/2 XO 9498.28 5409.00 6221. 07 S 3593.39 E T4.1 (Top Cairn) 9975.17 5632.00 6586.10 S 3804.23 E 2P-424 Top Berm TGT 24 Jul 03 10263.87 5767.00 6807.08 S 3931.87 E OWC 10353.69 5809.00 6875.83 S 3971.58 E T2 (Base Bermuda) 10543.69 5897.85 7021. 26 S 4055.59 E TD - Casing Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 3033.47 2386.00 1272.76S 735.16E 9 5/8" Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 2P-424 Top Berm TGT 447764.000,5862352.000,999.00 5632.00 6586.10S 3804.23E 14-Aug-2003 () fj '. t ~''í \ø' ~ 'Ì' e e ConocoPhillips Alaska, Inc. Drill Site 2P 424 slot #424 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-424 Vers#3.b prop45l7 Date printed Date created Last revised l8-Nov-2003 25-Feb-200l l8-Nov-2003 Field is centred on 44l964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.571,w150 26 53.022 Slot Grid coordinates are N 5868966.260, E 444010.429 Slot local coordinates are 909.67 S 2053.38 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIG~NúÄL e e ConocoPhillips Alaska, Inc. PROP05AL LI5TING Page 1 Drill Site 2P,424 Your ref 2P-424 Vers#3.b Meltwater,North Slope, Alaska Last revised : 18-Nov-2003 Measured Inclin Azimuth True Vert R E C TANGULAR G RID COO R D 5 G E o G RAP HIe Depth Degrees 'Degrees Depth C 0 0 RDINATE5 Easting Northing C 0 ORDINATE 5 0.00 0.00 0.00 0.00 O.OON O.OOE 444010.43 5868966.26 n70 09.57 w150 26 53.02 100.00 0.00 149.99 100.00 O.OON O.OOE 444010.43 5868966.26 n70 09.57 w150 26 53.02 200.00 0.00 149.99 200.00 O.OON O.OOE 444010.43 5868966.26 n70 09.57 w150 26 53.02 300.00 0.00 149.99 300.00 O.OON O.OOE 444010.43 5868966.26 n70 09.57 w150 26 53.02 400.00 2.00 149.99 399.98 1. 515 0.87E 444011.29 5868964.74 n70 09.56 w150 26 53.00 500.00 4.00 149.99 499.84 6.045 3.49E 444013 .87 5868960.19 n70 09.51 w150 26 52.92 600.00 6.00 149.99 599.45 13.595 7.85E 444018.17 5868952.61 n70 09.44 w150 26 52.80 700.00 8.00 149.99 698.70 24.145 13.94E 444024.19 5868942.01 n70 09.33 w150 26 52.62 800.00 10.00 149.99 797 .47 37.695 21.77E 444031.91 5868928.41 n70 09.20 w150 26 52.40 900.00 13 .00 149.99 895.45 54.955 31. 74E 444041. 74 5868911.08 n70 09.03 w150 26 52.11 1000.00 16.00 149.99 992.25 76.635 44.26E 444054.10 5868889.30 n70 08.82 w150 26 51. 75 1100.00 19.00 149.99 1087.61 102.665 59.30E 444068.94 5868863.16 n70 08.56 w150 26 51.31 1200.00 22.00 149.99 1181. 27 132.995 76.81E 444086.22 5868832.70 n70 08.26 w150 26 50.81 1300.00 25.00 149.99 1272.96 167.515 96.75E 444105.89 5868798.03 n70 07.92 w150 26 50.24 1388.19 27.65 149.99 1352.00 201.375 116.31E 444125.19 5868764.03 n70 07.59 w150 26 49.67 1400.00 28.00 149.99 1362.45 206.145 119.07E 444127.91 5868759.23 n70 3 07.54 w150 26 49.59 1500.00 31. 00 149.99 1449.47 248.785 143.70E 444152.21 5868716.42 n70 3 07.12 w150 26 48.88 1600.00 34.00 149.99 1533.80 295.305 170.57E 444178.72 5868669.70 n70 3 06.67 w150 26 48.11 1700.00 37.00 149.99 1615.20 345.585 199.61E 444207.38 5868619.20 n70 3 06.17 w150 26 47.27 1800.00 40.00 149.99 1693.46 399.485 230.74E 444238.10 5868565.07 n70 3 05.64 w150 26 46.38 1900.00 43.00 149.99 1768.34 456.855 263.88E 444270.79 5868507.46 n70 05.08 w150 26 45.42 2000.00 46.00 149.99 1839.66 517.545 298.93E 444305.38 5868446.51 n70 04.48 w150 26 44.42 2100.00 49.00 149.99 1907.21 581.375 335.81E 444341.76 5868382.40 n70 03.85 w150 26 43.35 2169.75 51.09 149.99 1952.00 627.675 362.55E 444368.15 5868335.91 n70 03.40 w150 26 42.58 2200.00 52.00 149.99 1970.81 648.185 374.40E 444379.84 5868315.31 n70 03.19 w150 26 42.24 2300.00 55.00 149.99 2030.29 717.785 414.60E 444419.51 5868245.41 n70 3 02.51 w150 26 41.09 2400.00 58.00 149.99 2085.47 789.985 456.30E 444460.65 5868172 .90 n70 3 01.80 w150 26 39.89 2500.00 61.00 149.99 2136.22 864.585 499.39E 444503.17 5868097.98 n70 3 01. 07 w150 26 38.64 2537.36 62.12 149.99 2154.01 893.035 515.82E 444519.38 5868069.41 n70 3 00.79 w150 26 38.17 3000.00 62.12 149.99 2370.35 1247.155 720.37E 444721. 20 5867713.78 n70 2 57.30 w150 26 32.28 3033.47 62.12 149.99 2386.00 1272.775 735.16E 444735.80 5867688.05 n70 2 57.05 w150 26 31.86 3193.86 62.12 149.99 2461. 00 1395.535 806.08E 444805.77 5867564.76 n70 2 55.84 w150 26 29.82 3500.00 62.12 149.99 2604.15 1629.865 941.43E 444939.32 5867329.43 n70 2 53.54 w150 26 25.92 4000.00 62.12 149.99 2837.96 2012.575 1162.49E 445157.44 5866945.09 n70 2 49.77 w150 26 19.56 4442.77 62.12 149.99 3045.00 2351. 475 1358.24E 445350.59 5866604.73 n70 2 46.44 w150 26 13 .93 4500.00 62.12 149 .99 3071.76 2395.285 1383. SSE 445375.55 5866560.74 n70 2 46.01 w150 26 13 .20 5000.00 62.12 149.99 3305.57 2777.995 1604.61E 445593.67 5866176.39 n70 2 42.24 w150 26 06.84 5011.62 62.12 149.99 3311.00 2786.895 1609.74E 445598.74 5866167.46 n70 2 42.16 w150 26 06.69 5424.36 62.12 149.99 3504.00 3102.805 1792.22E 445778.79 5865850.19 n70 2 39.05 w150 26 01. 44 5500.00 62.12 149.99 3539.37 3160.705 1825.67E 445811.78 5865792.04 n70 2 38.48 w150 26 00.48 6000.00 62.12 149.99 3773.18 3543.415 2046.73E 446029.90 5865407.69 n70 2 34.71 w150 25 54.12 6500.00 62.12 149.99 4006.98 3926.125 2267.79E 446248.02 5865023.35 n70 2 30.95 w150 25 47.76 7000.00 62.12 149.99 4240.78 4308.845 2488.85E 446466.13 5864639.00 n70 2 27.18 w150 25 41. 40 7500.00 62.12 149.99 4474.59 4691. 555 2709.91E 446684.25 5864254.65 n70 2 23.42 w150 25 35.04 8000.00 62.12 149.99 4708.39 5074.265 2930.97E 446902.37 5863870.30 n70 2 19.65 w150 25 28.69 8061.18 62.12 149.99 4737.00 5121. 085 2958.02E 446929.05 5863823.28 n70 2 19.19 w150 25 27.91 8500.00 62.12 149.99 4942.20 5456.975 3152.03E 447120.48 5863485.96 n70 2 15.89 w150 25 22.33 9000.00 62.12 149.99 5176.00 5839.685 3373.09E 447338.60 5863101.61 n70 2 12.12 w150 25 15.98 9298.28 62.12 149.99 5315.48 6067.995 3504.97E 447468.72 5862872 .32 n70 2 09.87 w150 25 12.18 9498.28 62.12 149.99 5409.00 6221. 075 3593.39E 447555.96 5862718.59 n70 2 08.37 w150 25 09.64 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #424 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 8108.38 on azimuth 149.99 degrees from wellhead. Total Dogleg for wellpath is 62.12 degrees. Vertical section is from wellhead on azimuth 149.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAl r.. ."~i,,~ e . ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Drill Site 2P,424 Your ref 2P-424 Vers#3.b Meltwater,North Slope, Alaska Last revised : 18-Nov-2003 Measured Inclin Azimuth True Vert R Ee TANGULAR G RID e 0 0 R D S G E 0 G RAP H I e Depth Degrees Degrees Depth C o 0 R DIN ATE S Easting Northing e 0 0 RDINAT E S 9500.00 62.12 149.99 5409.81 6222.398 3594.15E 447556.72 5862717.26 n70 2 08.35 w150 25 09.62 9975.17 62.12 149.99 5632.00 6586.10S 3804.23E 447764.00 5862352.00 n70 2 04.78 w150 25 03.58 10000.00 62.12 149.99 5643.61 6605.10S 3815.21E 447774.83 5862332.91 n70 2 04.59 w150 25 03.27 10263.87 62.12 149.99 5767.00 6807.08S 3931.87E 447889.94 5862130.08 n70 2 02.60 w150 24 59.91 10353.69 62.12 149.99 5809.00 6875.83S 3971. 58E 447929.12 5862061. 03 n70 2 01. 92 w150 24 58.77 10500.00 62.12 149.99 5877 . 42 6987.81S 4036.27E 447992.95 5861948.57 n70 2 00.82 w150 24 56.91 10543.69 62.12 149.99 5897.85 7021.26S 4055.59E 448012.01 5861914.98 n70 2 00.49 w150 24 56.36 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot *424 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 8108.38 on azimuth 149.99 degrees from wellhead. Total Dogleg for wellpath is 62.12 degrees. vertical section is from wellhead on azimuth 149.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid OR~G~~J e e Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. Drill Site 2P,424 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref 2P-424 Vers#3.b Last revised : 18-Nov-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - -- - -- - - - - - - - - -- 300.00 300.00 O.OON O.OOE KOP 800.00 797.47 37.69S 21. 77E Build 3/100 1388.19 1352.00 201. 37S 116.31E Base Permafrost 2169.75 1952.00 627.67S 362.55E Base West Sak 2537.36 2154.01 893.03S 515.82E Eoe 3033.47 2386.00 1272.77S 735.16E 9 5/8" Casing 3193.86 2461. 00 1395.53S 806.08E e80 4442.77 3045.00 2351.47S 1358.24E e50 5011.62 3311.00 2786.89S 1609.74E e40 5424.36 3504.00 3102.80S 1792.22E e37 8061.18 4737.00 5121.08S 2958.02E T7 9298.28 5315.48 6067.99S 3504.97E 5 1/2 x 3 1/2 xo 9498.28 5409.00 6221. 07S 3593.39E T4.1 (Top Cairn) 9975.17 5632.00 6586.10S 3804.23E 2P-424 Top Berm TGT 24 Ju1 03 10263.87 5767.00 6807.08S 3931. 87E owe 10353.69 5809.00 6875.83S 3971.58E T2 (Base Bermuda) 10543.69 5897.85 7021. 26S 4055.59E TD - Casing Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 0.00 0.00 O.OON O.OOE 3033.47 2386.00 1272.76S 735.16E 9 5/8" Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- -- - - - - - - - -- 2P-424 Top Berm TGT 447764.000,5862352.000,999.00 5632.00 6586.10S 3804.23E 14-Aug-2003 OR"·· I· .^ ! ~ ., . , '. ,¡ '1.. . . E 'V Company: Fiëld: ..... Re(erencë Site: Rëference Well: R~ï'erence Wellpath: 'aker Hughes Incorporatl Anticollision Report ConöcoPhiliips Alaska, Inc. MeltWater 2P Pad 424 2P-424 Vers#3.b "à·:.. NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 0.00 to 10543.69 ft Maximum Radius: 5280.00 ft Survey Program for Definitive Wellpath Date: 8/18/2003 Validated: No Planned From To Survey ft ft 0.00 10543.69 Planned: 2P-424 Vers#3b V6 Casing Points MD ft 3033.47 10543.69 TVD Diameter. H~I~i~ize Name ft.,. In.,,., 2386.00 9.625 12.250 95/8" 5897.85 7.000 8.500 7" Summary < Site 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad Meltwater North#1 Meltwater South #1 MWN#2 MWN#2 9ffset Wellpath:?:' :"""" > ... Well ... Well path 406 414 415 415 416 417 419 420 422 422 427 429 431 432 434 438 441 MWN#1 MWS#1 MWN#2 MWN#2 2P-406 Vers#2.A V2 Pia 2P-414 Vers#3a V1 Plan 2P-415 VO 2P-415A VO 2P-416 Version#O.A VO 2P-417 VO 2P-419 Vers#3.A V1 Pia 2P-420 VO 2P-422 V7 422A VO 2P-427 VO 2P-429 VO 2P-431 V1 2P-432 V11 2P-434 Vers#9b V1 Plan 2P-438 VO 2P-441 VO MWN#1 VO MWS#1 VO MWN#2 VO MWN#2A VO If"'>.. if') f< ~ i" ! ~ ~ ~~ n' il ~~"¡,¡-- ~ \, to . '·'Date: . .. .... ..... 11/19/2003";;' /,;Time:1 OJO:38 , ;,'Page: .. . .......... . . ..... .... .. ........... . ... ....... .. ............ .. ... ..... . '. :,,' 'Co-ordinate(NE) Refer~It~~:"::; Vertical (TVD) Reference:. Well: 424, True North .... Doyon 141 (0Id2) 252.0" Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Reference: Error Model: Scan Method: Error Surface: Version: Toolcode Tool Name MWD+SAG MWD + Sag correction Reference Offset Ctr-Ctr' No-Go . , Allowable .. MD" . MD Distancë . Area .;;" Deviation Warning ft ft ft "ft ft 584.66 575.00 360.27 10.96 349.31 Pass: Major Risk 679.86 675.00 198.13 13.52 184.61 Pass: Major Risk 299.95 300.00 180.40 5.81 174.59 Pass: Major Risk 299.95 300.00 180.40 5.81 174.59 Pass: Major Risk 857.09 850.00 163.70 17.14 146.56 Pass: Major Risk 849.66 850.00 139.99 16.25 123.74 Pass: Major Risk 1138.02 1125.00 118.48 27.95 90.53 Pass: Major Risk 675.33 675.00 80.05 12.17 67.88 Pass: Major Risk 1379.31 1375.00 46.93 38.37 8.56 Pass: Major Risk 1379.31 1375.00 46.93 38.37 8.56 Pass: Major Risk 424.24 425.00 60.58 7.75 52.82 Pass: Major Risk 646.62 650.00 101.23 12.44 88.80 Pass: Major Risk 373.90 375.00 142.18 7.26 134.92 Pass: Major Risk 422.99 425.00 160.76 8.45 152.30 Pass: Major Risk 446.93 450.00 201.25 8.95 192.30 Pass: Major Risk 348.60 350.00 280.80 6.84 273.97 Pass: Major Risk 420.79 425.00 340.93 8.00 332.93 Pass: Major Risk 7847.42 4675.00 3517.71 316.43 3201.29 Pass: Major Risk Out of range 4629.04 3825.00 2436.31 177.47 2258.84 Pass: Major Risk 4507.74 3725.00 2480.39 178.66 2301.72 Pass: Major Risk e e MEL TW A TER - DRILLING HAZARDS SUMMARY 12 1,4" Open Hole & 9 5/8" Surface Casing Interval Event Broach of conductor Gas Hydrates Running sands & gravel -iJ( Drill surface hole into shallow pressured interval- C-80 charged Hole swabbingfTight hole on trips Stuck surface casing Stuck pipe Lost circulation Risk Level Low Low Moderate Low Moderate Low Low Low Mitigation Strategy I Contingency Monitor cellar continuously during interval If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Do not exceed the surface hole TD as detailed in the individual well plans, ensure that all stands (in the derrick or in the hole) are accounted for at all times Circulate hole clean prior to trip, proper hole filling (use of trip sheets), pumping out of hole as needed Clean the hole before running casing, pump high density high viscosity sweeps, wiper trip Keep hole clean, use high density high viscosity sweeps, keep pipe moving/rotating with pumps on whenever possible Keep hole clean. If losses occur - reduce pump rates and mud rheology, use LCM 8 Iii' Open Hole & 5 Vi' x 3 Iii' Production Casing Interval ~ Event Drill through a shallow pressured interval: C-80 to C-37 Insufficient or undetermined LOT High ECD / Tight hole on trips/ Swabbing Differential sticking Barite sag Lost circulation ~ Risk Level Moderate Moderate Moderate Moderate Low High UnR~ ~d Mitigation Strategy I Contingency Carry out well control drills. Kill fluid stored on location, contingency 7" casing string on location, heightened awareness Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 18 ppg MW equivalent Condition mud & clean hole prior to trips. Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever possible Good drilling practices as documented in well plan Pretreat mud before drilling reservoir section, keep hole clean - use PWD to monitor hole cleaning. If losses occur - reduce pump rates and mud rheology, use LCM Meltwater Drilling Hazards Summary Prepared by Philip Hayden 11/25/2003 Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 11/18/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 108 ft. MD I I < Base of Permafrost at 1,388 ft. MD (1,352 ft. rvD) < Top ofTail at 1,633 ft. MD < 95/8",40.0#, L-80 grade BTC, AB Modified in 12 1/4" OH TO at 3,033 ft. MD (2,386 ft. rvD) Mark of Schlumberger .. 2 P-424 CemCADE"Preliminary'j';" ,:., Des" .. 9 5/8" Surface Ca . ,:". Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 450% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 245' below base of permafrost.) Lead Slurry (minimum pump time 223 min.) ArcticSet III Lite @ 10.7 ppg, 4.28 ft?/sk 3 0.7632 ft 1ft x (108') x 1.00 (no excess) = 3 0.3132 ft 1ft x (1388' - 108') x 5.50 (450% excess) = 0.3132 ft31ft x (1633' - 1388') x 1.45 (45% excess) = 82.4 ft3 + 2204.9 ft3+ 111.3 ft3 = 2398.6 ft3 1 4.28 ft3/sk = Round up to 561 sks 82.4 ft3 2204.9 ft3 111.3 ft3 2398.6 ft3 560.4 sks Have 410 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 162 min.) LiteCRETE @ 12.0 ppg - 2.28 ft3/sk 0.3132 ft31ft x (3033' - 1633') x 1.45 (45% excess) = 0.4257 ft3/ft x 80' (Shoe Joint) = 635.8 ft3 + 34.1 ft3 = 669.9 ft31 2.28 ft3/sk = Round up to 294 sks 635.8 ft3 34.1 ft3 669.9 ft3 293.8 sks BHST = 58°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2 SF/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 30 6.0 18.0 MudPUSH II 6 40 6.7 24.7 Drop Bottom Plug 4.0 28.7 Lead Slurry 7 428 61.1 89.8 Tail Slurry 5 119 23.8 113.6 Drop top plug 4.0 117.6 Water 5 20 4.0 121.6 XO to rig pumps 4.0 125.6 Displacement 7 184 26.3 151.9 Bump Plug 3 20 6.7 158.6 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-20, Ty ? 20-25 Centralizers: Recommend 2 on shoe track and 1 per joint for next 700 feet to assist in mud removal Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 11/18/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com I Previous Csg. < 95/8",40.0#, L-80 grade BTC, AB Modified at 3,033 ft. MD - 2 P -424 CemCADE" Preliminary Job Design 51/2" x 31/2" Casing Preliminary Job Design based on limited Input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above top of Cairn formation. Tail Slurry (minimum thickening time 146 min.) LiteCRETE wI D600G, D65 @ 12.5 ppg, 2.2 ft?lsk 0.2291 felft x 300' x 1.75 (75% excess) = 0.3272 ft31ft x (10544' - 9298') x 1.75 (75% excess) = 0.0488 ft3/ft x 60' (Shoe Joint) = 120.3 ft3 + 713.5 ft3 + 2.9 ft3 = 836.7 ft31 2.2 ft3/sk = Round up to 381 sks 120.3 ft3 713.5 ft3 2.9 ft3 836.7 ft3 380.3 sks BHST = 146°F, Estimated BHCT = 124°F. (BHST calculated using a gradient of 2.5°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time < 51/2", 15.5#, L-80 grade (bbl) (min) BTC, AB Modified CW100 5 10 2.0 2.0 in 8 1/2" OH Pressure test lines 10.0 12.0 5 50 10.0 22.0 Drop wiper Plug 5.0 27.0 MudPUSH II 6 30 5.0 32.0 Tail Slurry 7 149 21.3 53.3 < Top ofTail at Drop Top Plug 5.0 58.3 Displacement 8 217 27.1 85.4 8,998 ft. MD Bump Plug 3 15 5.0 90.4 < X-over at 9,298 ft. MD < Top of Caim Fm. at 9,498 ft. MD < 3 1/2", 9.3#, L-80 grade EUE, 8rd Modified in 8 1/2" OH TO at 10,544 ft. MD (5,898 ft. TVD) Mark of Schlumberger MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 16-20, Ty? 30-33 Centralizers: Recommend 1- Y:z bow centralizers pre joint from TD t TOC to aid in good mud removal for proper cement placement ~ A U Meltwater 2P-424 "ducer Proposed Completion Schematic 3-1/2" Completion String 30" x 16" 62.6# @ +1- 108' MD (Insulated) Depths are based on Doyon 141 RKB Surface csg. 95/8" 40.0# L-80 BTC +1- 3033' MD I 2386' TVD r II rll I ~ I 111-- II~II J i ~ ~ '- I ~ I '- I I ~ ~ I I I I l ~ I ~I i ~ ; ~ I I .. I I I ~ I I I ~ '- I I ~ I I I I I I a I I I ~ I ~ I I 2 ~ I ~ I ~ ~ E ~ ~ Iii Ii ~ ~ I I ~ I I ~ I ..,l I '- I I ~ L I I .~ I I I I ~ 2 I I I I I ~ ~ I ~ I 2 I I I I ~ I . ~ I I I 2 I ~ I ~ I I I ~ 2 ~ I I ~ 2 I I I __ ~ ~ ~ ~ I I ~ ! I , - I +- I II1!I!III!IIIi ~ ~ ,~ 1 . '~i 5 y," 15.5# L-80 BTCM x 3 y," 9.3# L-BO EUE8RD Mod crossover at +1- 9298' MD I 5315' TVD Future Perforations Production csg 5 W 15.5# L-80 BTCM x 3 y," 9.3# L-80 EUE8RD Mod +1- 10544' MD I 5898' TVD ..... ~ e ~Ph.ll. Coooœ·' 1 ,Jpt I I I I I I I I I ~ 3 y," FMC Gen 5 Tubing Hanger, 3 W L-80 EUE8RD Mod pin down 3 y," 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3 y," 9.3# L-80 EUE8RD Mod Tubing to Surface 3 W Camco 'DS' nipple wI 2.875" No-Go Profile. 3 y," x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at +1- 500' MD 3 W 9.3# L-80 EUE8RD Mod tubing to landing nipple 4 x 3 W x 1" Camco 'KBG-2-9' mandrels 3 W x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 y," x 1" Camco 'KBG-2-9' mandrel wI shear valve, pinned for 3000 psi shear (casing to tubing differential), 3 y," x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 y," Baker 'CMU' sliding sleeve wI 2.813" Camco DS profile, EUE8RD Mod box x pin. 3 W x 6' L-80 EUE8RD Mod handling pup installed above 3 y," Cameo 'D' nipple wI 2.75" No-Go profile. 3 y," x 12' L-80 EUE8RD Mod spacaeout pup installed above, 3 y," x 6' handling pup installed below 3 W Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3 W L-80 EUE8RD Mod box up, 3 y," x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 W BTCM x 3 W EUE8RD Mod SBE set at +1- 200' MD above the top of the Bermuda interval (or 200' MD above the Cairn if present) nr'q ~ (r{ ;: 11t1'~ , \' ¡~ 11/25/2003 Conoc~hillips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com November 26, 2003 ~ECEIV€D I.. 0 AJlJðka Oil" '. : 2003 " GasQ, .4111""-. .. IfIS. COm¡'ni.;-s WifJf8ge ..··~Of'¥ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permits to Drill, Meltwater injector, 2P-443 and producer 2P-424 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injection well and an onshore production well in the Bermuda sands of the Meltwater oil pool. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005 for both of these wells. The expected spud dates are as follows: 2P-424 January 2, 2003 2P-443 January 23, 2004 If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, ~~..~-?> Randy Thomas Greater Kuparuk Area Drilling Team Leader e e J.;)" I I 2/'y.... gATE /( UZ~_:ý II . ~..t1./311 51 PAYTOTHE S¡-tfTEOr AL._'1sr-fl 'llcbcc I $ (GO CJ/) !¡ ORDEROF~ I . fT , (' /;. . L- ~l . v--- {/v.L /;LÙ:.~-<-JVécl jð 1t:.2?'5 t,,--d./ ru.CJœ) . -------OOLLARS tD 1;::i¡:;::::' ;;, ~; i1 ~... CHASE Cho.o M",hot'"n Bonk USA, N.A. Valid Up To 5000 Dollars o~: ., 2DO White Clay Cent(!r 0'" N_.rlt. DE 19111 . . .: ¡P -41f-?ecCJ:tif''''''7ø:;,JJ¿k I: 0 j ~ ~ 0 0 ~ ~ ~ I: 2 ~ 8 ~ 7 ~ 90 7 9 2 7 b II- ~ 0 ~ j SHARON K. ALLSUP-DRAKE CONOCOPHILUPS 3760 PERENOSA ANCHORAGE AK 99515 1013 î; ì ¡ ¡_C e . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡¿I!?¿( 2-P-t/¿{ PTD# 2D.3 - 2.0 :3 CHECK WHAT APPLIES Rev: 07/1 0/02 C\jody\templates ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, API No. Production should continue to be reported as a function· of tbe original API number stated above. HOLE In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance witb 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals througb target zones. Field & Pool KUPARUK RIVER, MELTWATER OIL - 490140 Well Name: KUPARUK RIV U MELT 2P-424 Program DEV Well bore seg D PTD#: 2032030 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ~ Administration 1 Permit fee attached - - - - - - - - - - - - Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 .Lease number aPRrORriate. . . - - - - - - - - - - - - - - - - - - - - Yes. . . . . - - - - - - - - - - - - - - - - 3 .U11i~ue well.n.ar:ne .aod lJumbe( . . . . . . . . . . . . . . . . . . . . . . . . ... . . .... Yes. . - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - -. - 4 WeJIJocated In .a. defined pool. - - - - -- · . . . . Yes.. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 5 WeJIJocated proper dlstaoce. f(om driJlin9 unitboundary. . . - - - - - - · . . . . Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 6 WeJIJo.cated proper di$tance.f(om. other wells. . - - - - - - . . Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - 7 .Sufficient acrea~e.aYailable In.drilJilJ~ unit. . . . . . . . . . . .Yes.. - - - - - - - - - - -- - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - 8 Jf.deviated, is.wellboJe platincJuded . . . . . . . . . . . . . . . . - - - - Yes. . - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 9 .Operator onl}'. affected pa.rty. . - - - - - -- - - - - -- . .. . ... . . Yes.. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 .oper.ator ba.s.approprlate.b.ood In Jorce. . . . . . . . . . . . . . . . . . . . ... .. . .. . Yes.. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - 11 PermitC<lIJ be Lssu.ed witbo.ut conservation order. . . . - ~ - - - - · .. . . .Yes. - - - - - - - - - ~ - - - - - - - - - - - - - - ~ - - - - - - - - - - - ~ ~ - - - - - - - - - ~ - - - - - Appr Date 12 Pe(mitcan be i$su.ed without ad.mini~trativ.e.approval . . . . . . . . . . . Yes. - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 12/9/2003 13 Can permit be approved before 15-day wait Yes . 14 WeJlJo.cated within area and.strata autborized by.llJjection O(de("# (puUO# In.comr:nelJts).(for. NA - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - 15 All wells.within .1l4.rlJile.are.a.of (eyiew idelJt[fied (Fpr.s.ervice well onl}'.). . . . . . . . . . . . . . . NA. . . - - - - - . - - - - - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre-produced injector; dl.lratjonof pre-production less. tban. 3. months. (for .seryiçe well only) . . NA - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 AÇMPFinding .of Con$isteoc.)'.has been is.sued. fpr.tbis proiect . . . . . . . . . NA. . New weIlJror:n.exi$tjn.g.driIJ site, . - - - - - - - - - - - - - - - - - Engineering 18 ç~)lJC\uçtor ~tr.in~LPrQvLded . . . . . . . . . . . . . . - - - - - - - - - - . . . Yes.. - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 .8ul"facecasing.protects all.known USQW~ . . . - - - - - - - NA All. aquifeJ~ exer:npted 40 CfR j47~ 102 !b)(3).. . . . . . . . - - - - - - - - - - - - - - - - - - - - 20 .CMTvol.a.dequate.to ci(culate.o11.cond.uctor.& surf.C$9 . . - - - - -- · . . . . .Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 ÇMTvol.a.dequ.atetotie-inJongstringto.surfcs.g.............. . N.o. . Annular di~posal may be r.eQue$ted. - - - - - - - - - - - - - - - - - - - - - - - - 22 CMTwill coyer all knownproductiye borizon$. - - - - - - - - - - - - - - - - Yes. - - - - - - - - - - - - - - - ~ - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - 23 .C.asiIJ9 design~ ad.eQuate fo( C,.T, B .&permaJrost. - - - - - - - -- Yes. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate.tanka~e.orreserve pit. . . . . . . . . . . . . . - - - - -- Yes Big equpped. with.steel. Rits.. No (eyerse pit Rlanned.. Waste to .ao apPJoved ann.ul.us or disposal welt . . . . . . 25 Jf.a.re-d(ill, bas.a. 10-4.03 fOJ aba.ndon.me11t. beelJ approved. . . . . . . . . . . . . . . . . . . . . . NA . - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate.w.ellbore.$.eparatio11propo~ed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . I:'ro~imity. analysis PerformeJj, Çlose appro.ach iden.tified, .Travellng çyli11der pl.ot iIJCluded.. . . . . . . . . . . . . 27 Jf .diverter required. do.es it meet regulations. . . . . - - - - - - - - - - - - - - -- . . . .. .. Yes.. - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- Appr Date 28 .DrilJin9 fluid program schematlc.&. equip Jist.adequate. . . . . . . . . . . . . - - - - - - - - - .Yes. . Expected BHr in .Be(muda 5..1.- 8..0EMW.. Planned MW 9.6 ppg.Ri~k.oJ shallower bigher p(es~ure. identified, Tk~2Q03 E BOPEs, .do .they rn.eetregula.tion . . . . . . . . . . . . . . - - - - - - - - - - -- Yes. Su.rface. $.hoe integrjty is .geneJally greate( than 1.5,0. EMIlV Jndicatin.gstandard well cOntrol appJies. e .BOPEpre.ss rating appropr.iate; .test to.(pu.t p~ig ¡ncomments). . . . . . . . . . . . . . . . . . Yes. . MASr calc.ulate.d JorBermu.da j SQ1p$t .3500. Rsi app(op(iate. . rrco.u.sually test$ .to 50.00 psi. Choke manifold compJies. w/APIRF'-53 (May 84). . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - - - - - - - - - - - 32 WOJkwilloccurwithout.operatlon.sbutdown............................... .Yes. - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - 33 Js. Rresßnce. of H2S gas. pJQb.able. . . . . . . . . . . . . . . . - - - - - -- - - - - -- ..... N.o.. - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mecha.nicalcondjtLoo of. weJls wi.thin AOB yerified. (for.servlce we] onJy). . . . . . . . . . . NA. . - - - - - - - - - - -- - - - - - - - - - - - - - - - - - -- - - - - - - -- Geology 35 Pe(mitcalJ be i$su.ed wlohydr.ogen.sulfide measuœs. . . . . . . - - - - -- . . . . .Yes. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 36 PatapreselJted on. Rote11tial overpres.sure zones. . . . . . . - - - - - - Yes Some potential for pres$.uredshallow zone, Interval. will be drilled. wit.h .9,2 - .9,6. RP9 mud Appr Date 37 .8eismlc.analysjs.oJ shaJlow 9as.zPlJeS NA Beser:voir expected. to be normaUo unde(pre.ssured~ wlll.be d(Ïlled wlth 9.6 pp~ mud.. - - - - - - - - - - - - - - - - - - - SFD 12/9/2003 38 Seabed condition survey.(if off-~hoœ) . . . . . . . . . . . NA - - - - - - 39 . Contaç! namelphoneJorweekly progre~s.rep.orts [e1<ploratory .only). . . . - - - - -- ..... NA Geologic Date: Engineering Public Commissioner Commissioner: Date c~"e' /~ DrS G \Q 13 e e Well History File APPENDIX Information of detailed nature that is not particularly 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 infomlation, infomlation of this lature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. e **** REEL HEADER **** LDWG 04/03/25 AWS 01 **** TAPE HEADER **** LDWG 04/03/25 01 *** LIS COMMENT RECORD *** e 806""&05 I). '-(ß \ RECEIVED t·1..~!) ?6 ;"00¿1 ~ .J " \. '- ...... 'J ,¡. ;:,;:157\ì'}). Q!! &, Gas Cons, Commisttm /""..J.,...~ ~'r'i,;:r;HY,,,,,~¥' !! ! ! ! !! ! ! ! !!!!! ! ! !! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER MELTWATER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 C. WONG D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 2P-424 501032047500 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 25-MAR-04 MWD RUN 2 2 D. LABREQUE F. HERBERT MWD RUN 3 3 G. SUTING F. HERBERT 17 8N 7E 252.00 224.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 12.250 PRODUCTION STRING 8.500 # REMARKS: 16.000 9.625 108.0 3005.0 10548.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE ~~()'\ Gb e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 03' 9.571" LONG: W150 DEG 26' 53.022" LOG MEASURED FROM D.F. AT 252.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a Multiple Propagation Resistivity (MPR) and Gamma Ray with Near Bit Inclination services from 108 - 3010 feet MD (108 - 2389 TVD). (2) Baker Hughes INTEQ runs 2 & 3 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), along with Drill Collar Pressure (DCP) and MPR Resistivity services from 3010 - 10548 feet MD (2389 - 5931 TVD). (3) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) Depth of 9 5/8" Casing Shoe - Logger: 3005 feet MD (2386 TVD) Depth of 9 5/8" Casing Shoe - Driller: 3005 feet MD (2386 TVD) (2) The interval from 2962 to 3010 feet MD (2366 - 2389 TVD) was not logged due to the presence of the 9 5/8" casing. (3) No density data is presented in the interval 5323 - 5476 feet MD (3461 - 3533' TVD) due to a failure of the ORD (Optimized Rotational Density) tool on MWD run 2. (4) The interval from 5522 to 5662 feet MD (3556 - 3624 TVD) was logged up to 19.4 hours after being drilled due to a tripout to change the MWD/LWD tools. (5) The interval from 10507 to 10548 feet MD (5910 - 5931 TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 84 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!! ! ! !!!!!!!!!! !! !!!!!! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and LDWG File Version 1.000 Extract File: FILE001.HED 1 clipped curves; all bit runs merged. e e DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ .5000 START DEPTH 108.0 STOP DEPTH 10548.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 108.0 2962.0 5593.0 MERGE BASE 2962.0 5593.0 10548.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------~~~~~~~~~~~~~~~~~~~~~~~~ WDFN LCC CN WN FN COUN STAT 2p-424_5.xtf 150 ConocoPhillips Alaska 2P-424 Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE # 64) Data record type is: 0 Datum Frame Size is: 52 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: 19 One depth per frame (value= 0) e e Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1099 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 108.000000 10548.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 1148 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!! !!!!!!!!!!!! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD 2 log header data for each bit run in separate files. 1 .2500 START DEPTH 90.0 STOP DEPTH 2962.0 $ e # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: e 27-DEC-03 MSB 18655 8.25 MPR MEMORY 3010.0 90.0 2962.0 o .0 62.4 TOOL NUMBER DHA 7113 MPR 8028 SRIG 58017 12.250 108.0 Spud 9.60 .0 .0 200 .0 .000 .000 .000 .000 100.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1 (MWD Run 1). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) e e $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-424.xtf 150 ConocoPhillips Alaska 2P-424 Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 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: 19 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 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 e e 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 605 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 90.000000 2962.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 704 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 2 .2500 START DEPTH 2962.0 STOP DEPTH 5593.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 02-JAN-04 MSB 18655 6.75 TC MEMORY 5662.0 2962.0 5593.0 o 61.2 63.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY TOOL NUMBER DHA 99030 CCN 71631 ORD 46894 MPR 6245 SRIG 92230 e $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # e 8.500 3005.0 LSND 10.50 .0 .0 300 .0 .000 .000 .000 .000 120.0 .0 .0 .0 Sandstone .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/MPR/ORD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-424.xtf 150 ConocoPhillips Alaska 2P-424 Meltwater Unit North Slope Alaska e e *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 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: 14 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 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 Total Data Records: 752 Tape File Start Depth 2962.000000 e e Tape File End Depth 5593.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet **** FILE TRAILER **** Tape Subfile: 4 862 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!! ! ! ! !!!!!!!!!! Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 3 .2500 START DEPTH 5593.0 STOP DEPTH 10548.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 06-JAN-04 MSB 18655 6.75 TC MEMORY 10548.0 5593.0 10548.0 o 60.3 62.3 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY TOOL NUMBER DHA 75787 CCN 71630 ORD 12103 MPR 97378 SRIG 5306 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3005.0 # BOREHOLE CONDITIONS MUD TYPE: LSND e e MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 10.35 .0 .0 300 .0 .000 .000 .000 .000 139.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Sandstone .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 2RRl (MWD Run 3) . GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-424.xtf 150 ConocoPhillips Alaska 2P-424 Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL GRAM RPCL RPSL GRAM RPD RPM 0.0 0.0 0.0 .. e e RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 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: 14 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 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 Total Data Records: 1416 Tape File Start Depth 5593.000000 Tape File End Depth 10548.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet **** FILE TRAILER **** Tape Subfile: 5 1526 records... .. ..., Minimum record length: Maximum record length: **** TAPE TRAILER **** LDWG 04/03/25 01 **** REEL TRAILER **** LDWG 04/03/25 AWS 01 Tape Subfile: 6 Minimum record length: Maximum record length: e e 8 bytes 4124 bytes 2 records... 132 bytes 132 bytes