The URL can be used to link to this page

Home My WebLink About204-063 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. ~ 0 Y-- 0 b 3 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: & q (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES (Ma,;;;j Dale 7/17 /0 b If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 11111111111 ""1111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: Dale 7 lï/Ob Dale 7. "7 / Dc' ~ x 30 = 10 tJ + Dale 7, 1710h BY: ~ Project Proofing BY: ~~ Scanning Preparation BY: ~ 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 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: MP ,~"IIIIIIIIII "111m r 151 £S = TOTAL PAGES &, <6 (Count does not include cover sheet) \AA If) 151 I r ~ r 11/11111111111 "III NO 151 'V\1p NO YES 151 11/11111111I1111111 1/1/1111111 "' "III 151 Quality Checked 1111111111111111111 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 . . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 May 10, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 1 8 2007 .Alaska Oil & Gas Cons. Commission Anchorage Subject: Well Completion Report for 2N-311 Dear Commissioner: ~Ùlt-003 ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the ~ recent P&A operations on the Kuparuk well 2N-311. If you have any questions regarding this matter, please contact me at 265-6830 or Jason Brink at 265-6419. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling ~~NED JUL 1 J 2007 RT Iskad . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED MAY 1 8 2007 WELL COMPLETION OR RECOMPLETION REPORT ,A.NP,.LOG ion 1a. Well Status: Oil D Gas U Plugged ~ . Abandoned 0 . Suspended D 1 u. uv" ~,a't~:' ~ 20MC 25.105 20MC 25.110 Development ~nchorîQ~oratOry D GINJ D WlNJ D WDSPL D WAG D Other D No. of Completions: Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., I" ~.1.q.o'" 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: March ~ 2007 204-063 1 307-023 1 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 February 27, 2004 50-103-20491-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 27' FNL, 617' FEL, Sec. 3, T9N, R7E, UM April 24, 2004 2N-311 Top of Productive Horizon: 8. KB (ft above MSL): 150' AMSL 15. Field/Pool(s): 298' FSL, 327' FWL, Sec. 26, T10N, R7E, UM Ground (ft MSL): 119' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + 1VD): Tarn Oil Pool 683' FSL, 398' FWL, Sec. 26, T1 ON, R7E, UM 2774' MD 12287' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + 1VD): 16. Property Designation: Surface: x-460976 y- 5911981 Zone- 4 8657' MD 15614' TVD ADL 375074,380054,380053 TPI: x-461941 y- 5917580 Zone- 4 11. SSSV Depth (MD + 1VD): 17. Land Use Permit: Total Depth: x- 462013 y- 5917964 Zone- 4 none 31961,32027,32026 18. Directional Survey: Yes D N00 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 MC 25.050) N/A (ft MSL) 1196' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): GRlReslDens/Neutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH 1VD HOLE AMOUNT CEMENTING RECORD PULLED CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 16" 62.5# H-40 30' 139' 30' 139' 42" ArcticSet 9.625" 40# L-80 30' 3000' 30' 2402' 12.25" 275 sx ASLite, 330 sx LiteCRETE 23. Open to production or injection? Yes D No 0 If Yes, list each 24. TUBING RECORD Interval open (MD+ 1VD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Conventional Core(s) Acquired? Yes ] No 0 Sidewall Cores Acquired? Yes [J No 0 If Yes to either question, list formations and intervals cored (MD+ 1VD of top and bottom of each), and summarize lithology and presence of oil, gas or water .~ (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 MC 25.071. f--'-·'''';'''',_ ì e0r,!r;.[Ti8~ I ~1! ! I :5~' ·c 7· NONE ¡ I !~ L= ~__. --:.1 Form 10-407 Revised 2/2007 o RIG I N A CNllNUED ON REVERSE SRI!DMS BFL MAY %~\ 1 ß !>·t.1·ð>7 ~ f/T?6? c; 28. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD Permafrost - Top ground surface Permafrost - Bottom 1220' TVD ground surface 1196' 29. FORMATION TESTS Well tested? Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. T-3 T-2 8116' 8274' 5240' 5348' N/A Formation at total depth: T-3 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 265-6419 Printed N~ . ~~ Thomas . Title: Signature \~. \ ~Phone . l DrillinQ Team Leader 4\6'81.0 Date Ç/(Olb? Sharon AI/sup-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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 21: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Form 10-407 Revised 2/2007 · ~ ConocoPhillips Time Log Summary We/lvlew Wet> Reponing Well Name: 2N-311 Job Type: DRILLING SIDETRACK 03/14/2007 13:30 15:00 1.50 2,774 2,774 MIRU MOVE PSIT P Move rig and spot over well. Level rig and Rig up over 2N-311. Rig accepted this day at 1500 hrs. 15:00 17:00 2.00 2,774 2,774 MIRU MOVE RURD P Berm up rig, spot out bigs, RU circ hoses and tes same wI air. 17:00 19:00 2.00 2,774 2,774 MIRU MOVE WOEQ NP Stby wI WO hardline and seawater. Spot high-line power trlr. Clean up and organize rig for uQÇominq ops. 19:00 22:30 3.50 2,774 2,774 MIRU MOVE RURD P RU hardline to kill tank. T-test all to 1500 psi. Fill pits wI sea-water for displacement procedure. 22:30 00:00 1.50 2,774 2,774 MIRU WELC KLWL P 250 psi on lA, pull BPV wI lubricator. Start pump seawater down tbg wI returns up IA @ 3 bpm to displace out diesel freeze protection. CJ3/15/2007 00:00 01:00 1.00 ~2,774 2,774 MJRU : ...INELCT èl.Rc P Finish displace out diesel with :....,.;" seawater. FTP 0.0, FCP 0.0., well balanced. Drain and blow down circulating lines. RD, clear area for ND of tree. 01:00 02:00 1.00 2,774 2,774 MIRU WELC1 NUND P Cont. drain and blow down circ lines, RD, clear area for ND. Set BPV. 02:00 03:00 1.00 2,774 2,774 MIRU WELC NUND P ND tree, clean hanger. thread, set blanking plug. 03:00 06:00 3.00 2,774 2,774 MIRU WELC' NUND P PJSM, NU BOP stack. 06:00 07:00 1.00 2,774 2,774 MIRU WElC1 NUND P Finish NU Stack, prepare for testing ops. 07:00 12:00 5.00 2,774 2,774 MIRU WELC1 BOPE P Fill BOPE, test all 250psi 10 - 3500psi high. All testing OK. Test witnessed by John Crisp, AOGCC inspector. 12:00 13:30 1.50 2,774 2,774 MIRU RPCOI\ NUND P PJSM, RD test equiþment, BOLJ & blanking plug, LD. Pull BPV, PU and MU LJ in hanger, BO LDS, pull hanger to floor and LD. 13:30 14:00 0.50 2,774 2,774 MIRU RPCOI\ NUND P CBU @ 5 bpm 1190 psi. 14:00 17:00 3.00 2,774 2,774 MIRU RPCOI\ PULD P PJSM, POOH LD 31/2" kill string. 17:00 22:00 5.00 2,774 2,774 MIRU RPCOI\ NUND P Set test plug clo upper rams to 4". Test upper & lower rams to 250psi 10, 3500 psi hi, OK. RD test eq, pull test plug and set wear ring. 22:00 00:00 2.00 2,774 2,774 MIRU DRILL PULD P PJSM, PU BHA # 1 wI Bit #1. 03/16/2007 00:00 02:30 2.50 2,774 2,774 PROD1 DRILL PULD P Continue MU BHA#1. Load tools, shallow test MWD, Blow down top drive. -S!:-__ . . ~ 03/16/2007 02:30 03:30 1.00 2,774 2,774 PROD1 DRILL PULD P MU 1 flex collar, Clean out nuke source ports on MWD, PJSM, load radioactive logging sources. 03:30 04:30 1.00 2,774 2,774 PROD1 DRILL PULD P MU Jar, RIH wI 4" HWDP. 04:30 05:30 1.00 2,774 2,774 PROD1 DRILL TRIP P TIH wI BHA #1 on 4" DP f/ 664' - 2277' wI BHA#1. 05:30 07:30 2.00 2,774 2,774 PROD1 DRILL OTHR P RU and csg test on 9 5/8" surface - csg. Testing to 2500 psi for 30 min wI ~ chart record. Test successful, no re-tests. ?? 07:30 10:00 2.50 2,774 2,774 PROD1 RIGMN RGRP T Repair BOP accumulator pump. 10:00 10:30 0.50 2,550 2,550 PROD1 DRILL TRIP P PJSM, RIH 4" DP to tag cmt stringer ~~ at 2550 ft. ~ 10:30 12:00 1.50 2,550 2,550 PROD1 DRILL CIRC P Circ I displace w$lIbore to 9.6 ppg drill ~ fluids. 12:00 18:30 6.50 2,562 3,000 PROD1 CEMEf\ DRLG P Commence drill out emt plug in 9-5/8 csg 2562 - 3000' 9-5/8 shoe depth. 18:30 19:00 0.50 3,000 3,038 PROD1 DRILL DDRL P Cont drill ahead. 100% new formation .. 011,. returns at 3038 ft. ~' 19:00 20:00 1.00 3,038 3,038 ¡rROD1 DRILL FIT P Circ and condition mud for LOT. Mud ~ .... wt 9.7 ppg. Pull into shoe, BDTD, RU - test eq fl test. . - :. ._.-- Æ"' 20:00 21:00 1.00 3,038 3,038 PROD1 DRILL FIT P Perform LOT to 15.0 ppg MWE wI leak off. Followed LO wI 3 bbls mud ^ pumped away. Total fld pumped fl LOT 3.9 bbls, total returned 2.5 bbls. 21:00 23:00 2.00 3,038 3,169 PROD1 DRILL DRLG P Drlg f/3038' - 3169'. Developed power I problems, PU off bottom. 23:00 00:00 1.00 3,169 3,169 PROD1 RIGMN RGRP T Developed power problems wI traction motor on #1 pump and transformer on top drive. Unable tQ drill wI diagnosing , problem. 03/17/2007 00:00 02:30 2.50 3,169 3,169 PROD1 RIGMN RGRP T C/O transformer to allow operation of top drive. Pull into shoe to continue rig diagnostics and repairs. 02:30 06:00 3.50 3,169 3,169 PROD1 RIGMN RGRP T Work on diagnosing and repair of rig electrical systems. 06:00 00:00 18.00 3,169 3,169 PROD1 RIGMN RGRP T Rig Repair: Work on electrical and c/o of pump traction motor. 03/18/2007 00:00 06:00 6.00 3,169 3,169 PROD1 RIGMN RGRP T Rig downtime I repair. Work on clo of I pump traction motor. 06:00 00:00 18.00 3,169 3,169 PROD1 RIGMN RGRP T Rig downtime 1 repair. Work on c/o of I pump traction motor. 03/19/2007 00:00 06:00 6.00 3,169 3,169 PROD1 RIGMN RGRP T Finishing install of replacement pump 2 traction motor, preparina for test. 06:00 09:30 3.50 3,169 3,169 PROD1 RIGMN RGRP T Finish wire-in of #2 Pump traction motor. Load test, OK, test other SCR assignments, OK. TIH to below shoe for load test on system, i.e. full pump rate. 'J fr . . SARAH PALIN, GOVERNOR AItASIiA OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 100360 . i~"'NED JAN 252007 Anchorage, AK 99510 SCru1l Re: Kuparuk River Field, Tarn Oil Pool, 2N-311 Sundry Number: 307-023 iL....O b~ ~Ð..,- Dear Mr. Thomas: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Encl. . . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocÓ¡)hillips p, O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 January 11, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 1 1 2007 Alaska Oil & Gas Cons. Cûmmission Anchorage Subject: Application for Sundry Approval for 2N-311 (APD # 204-063) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 2N-311. We intend to re-enter this suspended well to drill a sidetrack. If you have any questions regarding this matter, please contact me at 265-6830 or Jason Brink at 265-6419. Sincerely, ~~\~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad ,/ JA~lt!:t na ¡¿. r.,,^ n 1, Type of Request: Abandon ~~¡~ Suspend 0 Operational Shutdown D Perforate 0 )tai~ff IS v. "mlSijgQr D D D 0 nc ora~ Alter casing o Repair well Plug Perforations Stimulate Time Extension Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well 0 2. Operator Name: 4, Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 204-063 . 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20491-00 7, If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes D No 0 2N-311 9. Property Designation: 10. KB Elevation (ft): 11. FieldJPool(s): ADL 375074 ì 380054 'J 380053 . AMSL 150' Kuparuk River Field J Tarn Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8657' 5614' . 2774' 2287' 2774'-3400', 7857'-8657' Casing Length Size MD TVD Burst Collapse CONDUCTOR 109' 16" 139' 139' SURFACE 2970' 9-518" 3000' 2402' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3-1/2" L-80 2272' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory D Development 0 Service D 15. Estimated Date for 16. Well Status after proposed work: ~~",>,,-\ Commencing Operations: February 25, 2007 Oil ~. Gas D Plugged 0 Abandoned "~ 17. Verbal Approval: Date: WAG D GINJ D WINJ 0 WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 265-6419 Printed Name Randv Thomas Title: Drilling Engineer Signature ~~ Phone 265-6830 Date Vldo? \ Commission Use Only Sundry ?!l;:J. Conditions of approval: Notify Commission so that a representative may witness .. " - Oól.~ Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: ~~OÐ ~ l ~\" \ ~ù Ii,",,- \::£J ~ k .l. S,b"q,oot Fo~ Req"""o ~(Z~ ~ RBDMS 8Ft JAN 2 9 2007 Appro", by -r ~/ ) ~MISSIONER APPROVED BY Date: /,~Þ"Dl- THE COMMISSION Form 1 0-403 Revised 06J200(¡ p,\ r:; \ ~L '-- ~ ~ubmit in Duplicate {,;a.I"" ~ /' 2.'J;.o7 · STATE OF ALASKA .\I~,,\ RECEIVED ALASKA OILAND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL JAN 1 1 2007 20 MC 25 280 AI . . Proposed 2N-311 Re-Entry Program: 1. Move in / rig up Nordic Rig 3. ~\..)~ \-'t.~~ ~O ~ ~c ~sa()~, ~~'\""'ü~ .~?111 2, Pull 3-1/2" kill string set at 2272' MD. l/;).'-\. 3, PU 8 112" bit and 6 3f4" drilling assembly, with MWD and LWD (GR, resistivity & neutron density), RIH to top of P&A cement plug at 2774' MD. Pressure test 9-5/8" casing to 3000 psi for 30 minutes and record results. 4. Drill out cement to surface casing shoe and sidetrack 20' of new hole, Perform LOT or FIT to 16,0 ppg EMW, recording results, ~ f.T'I'\Þ... \ "'- \ '" 'J ~ \' \LC....... '-\ a .L # . 2N-311 Current Schematic 9/27/06 Top of Cement KO plug @ 2771f MD 9·518" 40# L80 @ 2999 MD Bottom of Cement KO plug @ 3400 MD TOC=7857 MD TOC=8157MD 3-;1," kill string @ 2272' MD FIT = 18ppg EMWw/9.6 ppg mud@ 3000' MD . ConocÓPhilnps Open Hole LOT @ 7900 MD /5098 TVD = 11.6 ppg EMW Control drilled pay with 10.6 PP9 MW ECD avg 11.3 ppg EMW @ 455 gpm ftowrate Bermuda Top8115 MD/5239 TVD Bermuda Bottom 8272 MD /5347 TVD 8-Wopen hole TD@ 8657 MD/5613 TVD ~ 1~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 7/3/2006 Permit to Drill 2040630 Well Name/No. KUPARUK RIV U TARN 2N-311 Operator CONOCOPHILLlPS ALASKA INC J~ 3J~ ~'1 API No. 50-103-20491-00-00 MD 8657 / TVD 5614 ,- Completion Date 6/16/2004 /' Completion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION Mud Log No Samples No Directional surve~ DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Dens/Neutron (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~t Directional Survey Open 7/1/2004 MWD P C Lis 12625 Induction/Resistivity 25 120 8657 Open 8/20/2004 Ind Res, Neutron tkog Induction/Resistivity 25 Blu 2 120 8657 Open 8/20/2004 ORD, RWD, GR, CCN l!og Induction/Resistivity 25 Blu 2 120 5580 Open 8/20/2004 ORD, RWD, GR, CCN -rog Neutron 25 Blu 2 120 8657 Open 8/20/2004 ORD, RWD, GR, CCN, DSN 12625 v(og Neutron 25 Blu 2 120 8657 Open 8/20/2004 ORD, RWD, GR, CCN, DSN 12625 j;q)t 12625 LIS Verification 8657 Open 8/20/2004 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . ADDITIONAL INFORMATION Well Cored? y~ Chips Received? ~ v / N Daily History Received? c;/N ð/N Formation Tops Analysis Received? ~ Comments: Permit to Drill 2040630 MD 8657 TVD 5614 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 7/3/2006 Well Name/No. KUPARUK RIV U TARN 2N-311 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20491-00-00 l~el;O" Dale 6/16/2004 Completion Status SUSP Current Status SUSP J L UIC N Date: ).. '-t).(, Q ~ It- . . . ConocÓÂ,illips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 April 25, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 RECEI\/Er) APR 2 7 2005 Alaska Oil & Gas Cons. Commission Anchorage Subject Well Completion Report for 2N-311 (APD # 204-063 I 304-227) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Kuparuk well 2N-311. If you have any questions regarding this matter, please contact me at 265-6830 or Jake Flora at 265-6040. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad · STATE OF ALASKA I ALASKA Oil AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned ~ 20AAC 25.105 No. of Completions _ GINJ 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: WlNJ 0 WDSPL 0 P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 27' FNL, 617' FEL, Sec. 3, T9N, R7E, UM At Top Productive Horizon: 298' FSL, 327' FWL, Sec. 26, T10N, R7E, UM Total Depth: 683' FSL, 398' FWL, Sec. 26, T10N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460976 / y- TPI: x- 461941 y- Total Depth: x- 462013 / y- 18. Directional Survey: Yes 0 NoU 5911981 <' 5917580 5917964 / Zone- 4 Zone- 4 Zone- 4 21. Logs Run: GRlReslDens/Neutron 22. Suspended 0 WAG 0 1 b. Well Class: 20AAC 25.110 Development 0 Exploratory 0 Other Service 0 Stratigraphic Test 0 ~ 12. Permit to Drill Number: 5. Date Com ,S~s~ or Aband.: ne 16, 2004 204-063/304-227 6. Date SpuddedJ~ '3 7,...1Vt..../ ft... 13. API Number: .F"bruary 27,2004 . t;.i1.;"" 50-103-20491-00 7. Date TD Reach.:?;........ 13/ ?:L;>(>' _ 14. Well Name and Number: ",dp~il ~,2oo.. :;'¡z.'''''¡;' 2N-311 8. KB Elevation (ft): 15. Field/Pool(s): 150' AMSL Kuparuk River Field 9. Plug Back Depth (MD + ìVD): Tarn Oil Pool 2774' MD /2287' TVD 10. Total Depth (MD + ìVD): , 8657' MD /5614' TVD ,/ / 16. Property Designation: ADL 375074/380054/380053 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A 17. Land Use Permit: ALK 31961/32027/32026 20. Thickness of feet MSL Permafrost: 1220' MD CASING SIZE wr. PER FT. 16" 62.5# 9.625" 40# GRADE H·40 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ìVD TOP BOTTOM TOP BOTTOM 30' 139' 30' 139' 30' 3000' 30' 2402' 23. Perforations open to Production (MD + ìVD of Top and Bottom Interval, Size and Number; if none, state "none"): none I / 26. Date First Production HOLE SIZE AMOUNT PULLED CEMENTING RECORD 42" 12.25" 275 sx ASLite, 330 sx LiteCrete cement plug from 8657'-7857' , cement plug from 3400'·2774' 24. TUBING RECORD DEPTH SET (MD) 2272' none SIZE PACKER SET 3.5" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8657'-7857' 245 sx GasBlok, 146 sx GasBlok 3400'-2774' 312 sx Class G PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Plugged and Abandoned Production for OIL-BBL GAS-MCF Test Period .-> Flow Tubing Casing Pressure Calculated press. psi 24-Hour Rate .> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Date of Test Hours Tested OIL-BBL RBDMS 8Fl MAY 1 2 2005 NONE Form 10-407 Revised 12/2003 WATER-BBL CHOKE SIZE IGAS-OIL RATIO GAS-MCF OIL GRAVITY - API (corr) not available WATER-BBL .$~>r¿4</ "d ¡;. . ('¿if RECEIVED APR 2 7 2005 c,r: Alaska Oil & Gas Cons. Commission Anchorage Æ CONTINUED ON REVERSE 28. GEOLOGIC MARKERS. 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2N-311 T-3 T-2 8116' 8274' 5240' 5348' N/A 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: Jake Flora @ 265-6040 Printed N~__ ~ndy Thomas Title: Signature \ --1 \ ~ Phone KUDaruk DrillinQ Team Leader Z-l::,Ç6'8So Date '-f (2-6 í6.> 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). RECEIVED APR 2 7 2005 Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-311 / 2N-311 ROT - DRILLING Nordic Calista Services Nordic 3 as a Oil & Gas Cons. Commission Sp~öøreg8/3/2004 End: 6/16/2004 Group: Start: 6/2/2004 Rig Release: 6/16/2004 Rig Number: 3 3.50 MOVE MOVE MOVE Prep rig for move from 2N-306 to 2N-311. Move rig off 2N-306 and secure tree for 2N-311 in cellar. Remove equipment form behind cellar and relocate behind 2N-311. Spot rig over 2N-311. Accept rig @ 05:30 hours Install Hand-y-berm NIU dtvefter, divertèr line and riser Hold pre-spud meeting w/ crew on tour Continue hooking up new riser. Riser section too short. Add spacer to top of annular and finish hooking up diverter Ftme:IIOI.t......tIIverler RIU floor to drill 12-1/4" hole. Change tongs. RID tubing tongs and RIU d.p. spinner. Bring jars and xo's into shed. Take on spud mud into pits. Cut and slip drilling line Service drawworks and topdrive UD 4-3/4" drilling jars P/U 6-1/4" jars P/U motor. M/U bit, pony collar, stab, XO, and hwdp Tag @ 139'. Fill hole w/ mud and check for leaks. Clean out to 150' Drill from 150' to 233' Ý POOH, blowdown top drive. POOH to stab. M/U MWD tools and BHA Pulse test MWD Drill from 233' to 268' ,/ Run gyro survey Drill from 268' to 361' Run gyro survey Drill from 361' to 410'. TVD=410' ART=2.0, AST=1.2, ADT=3.2 Drill from 410' to 454' AST=.2, ART=.6 Run gyro survey Drill from 454' to 1100'. TVD= 991', ART=1.8, AST=5. 7, P/U=62k, S/O=62k, Rotary=80 rpm, WOB=10-15k, Pump=1500 psi @ 160 spm (475 gpm) Drill from 1100' to 1479' Replace grabber switch (top drive) in control cabinet Drill from 1479' to 1777' TVD=1671', ART=2.3, AST=5.1, ADT=7.4, P/U=70k S/O=60k, Rpt=65k, Torque= 2500 off/3900 on. Rotary=80 rpm. WOB=10-20k, Pump=1900 psi @ 160 spm (475 gpm) Drill from 1777' to 2160' Service blocks and top drive Drill from 2060' to 2160' Replace leaking air boot on riser Orient motor and drill from 2160' to 2251' TVD=1997', P/U=72k, S/O=60k, rot=68k, ART=2.1, AST=3.9, ADT=6.0, Torque=4300 on/ 3600 off. Rotary=80 rpm, WOB=10-25, Pump=2000 psi @ 160 spm (475 gpm) Work on air boot on riser Repair air boot in riser Drill from 2251' to 2818'. TVD= 2310'. ART=4.1, AST=1.9 P/U=75k, S/O=55k, Rot=68k, Torque=6700 on/ 4600 off, Rotary=80 rpm, WOB=15-25k, Pump=2500 psi @ 180 spm (533 gpm) Drill from 2818'to 3010'. TVD=2412', ART=1.9, AST=.3 Pump weighted sweep and 4 bottoms up Back ream to 1022'. UD ghost reamer 6/2/2004 02:00 - 05:30 05:30 - 07:00 1.50 MOVE OTHR MOVE 07:00 - 12:00 5.00 WELCTL NUND SURFAC 12:00 - 13:00 1.00 DRILL SFTY SURFAC 13:00 - 18:00 5.00 WELCTL NUND SURFAC 18:00 - 18:30 0.50 WELCTL BOPE SURFAC 18:30 - 21 :00 2.50 DRILL OTHR SURFAC 21 :00 - 22:30 1.50 RIGMNT RSRV SURFAC 22:30 - 23:30 1.00 RIGMNT RSRV SURFAC 23:.30 - 00:00 0.50 DRILL PULD SURFAC 6/3/2004 00:00 - 00:15 0.25 DRILL PULD SURFAC 00:15 - 02:15 2.00 DRILL PULD SURFAC 02:15 - 02:45 0.50 DRILL CIRC SURFAC 02:45 - 04:00 1.25 DRILL DRLG SURFAC 04:00 - 04:30 0.50 DRILL TRIP SURFAC 04:30 - 08:00 3.50 DRILL PULD SURFAC 08:00 - 08:30 0.50 DRILL DEQT SURFAC 08:30 - 09:15 0.75 DRILL DRLG SURFAC 09:15 - 09:30 0.25 DRILL SURV SURFAC 09:30 -11:15 1.75 DRILL DRLG SURFAC 11:15 -11:30 0.25 DRILL SURV SURFAC 11 :30 - 12:00 0.50 DRILL DRLG SURFAC 12:00 -13:00 1.00 DRILL DRLG SURFAC 13:00 -13:15 0.25 DRILL SURV SURFAC 13:15 - 00:00 10.75 DRILL DRLG SURFAC 6/4/2004 00:00 - 06:15 6.25 DRILL DRLG SURFAC 06:15 - 06:45 0.50 RIGMNT RGRP SURFAC 06:45 - 12:00 5.25 DRILL DRLG SURFAC 12:00 - 15:45 3.75 DRILL DRLG SURFAC 15:45 - 16:15 0.50 RIGMNT RSRV SURFAC 16:15 - 18:30 2.25 DRILL DRLG SURFAC 18:30 - 21 :00 2.50 RIGMNT RGRP SURFAC 21 :00 - 23:45 2.75 DRILL DRLG SURFAC 23:45 - 00:00 0.25 RIGMNT RGRP SURFAC 6/5/2004 ,00:00 - 03:00 3.00 RIGMNT RGRP SURFAC 03:00 - 12:00 9.00 DRILL DRLG SURFAC 12:00 - 14:45 2.75 DRILL DRLG SURFAC 14:45 - 18:00 3.25 DRILL CIRC SURFAC 18:00 - 21 :30 3.50 DRILL WIPR SURFAC Printed: 4/20/2005 3:21 :31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-311 2N-311 ROT - DRILLING Nordic Calista Services Nordic 3 Alaska Oil &~JImft¿;~ Start: 6/2/2004 Anchorsge 6/16/2004 Rig Release: 6/16/2004 Group: Rig Number: 3 6/5/2004 21 :30 - 22:30 1.00 DRILL CIRC SURFAC Circulate and condition mud @ 1014' 22:30 - 23:30 1.00 DRILL WIPR SURFAC Pump hwdp out of the hole 23:30 - 00:00 0.50 DRILL WIPR SURFAC Incorrect hole fill w/6 stand hwdp out. No flow. RIH 6/6/2004 00:00 - 03:00 3.00 DRILL WIPR SURFAC RIH Work through bridges @ 809', 2347', 2682'. 03:00 - 03:45 0.75 DRILL CIRC SURFAC Circulate and condition mud 03:45 - 04:00 0.25 RIGMNT RGRP SURFAC Patch riser leak 04:00 - 04:45 0.75 DRILL CIRC SURFAC Circulate and condition mud 04:45 - 08:00 3.25 DRILL TRIP SURFAC Pump out of hole 10 stands and POOH on trip tank 08:00 - 10:00 2.00 DRILL PULD SURFAC UD BHA 10:00 - 11 :00 1.00 CASE OTHR SURFAC Flush stack 11:00-14:15 3.25 CASE RURD SURFAC RIU casers 14:15 - 14:45 0.50 CASE OTHR SURFAC Make dry run wI landing jt and hanger. UD landing jt. 14:45 - 15:00 0.25 CASE SFTY SURFAC Safety meeting wI all involved 15:00 - 17:45 2.75 CASE RUNC SURFAC Run 9-5/8" casing to 580' 17:45 - 00:00 6.25 RIGMNT RGRP SURFAC Repair leaking airboot in riser 6/7/2004 00:00 - 02:30 2.50 RIGMNT RGRP SURFAC Repair riser and CBU 102:30 - 08:30 6.00 CASE RUNC SURFAC RIH w/9-5/8" surface casing from 580' to 2999.98'. Break circulation and M/U landing joint 08:30 - 09:00 0.50 CEMENT PULD SURFAC UD fillup tool and M/U cement head 09:00 - 11 :30 2.50 CEMENT CIRC SURFAC Circulate and condition mud 11 :30 - 12:45 1.25 CEMENT PUMP SURFAC Mix and pump 10 bbl CW100. Pressure test lines to 3500 psi. Mix and pump 30 bbl CW100. Mix and pump 40 bbl Mudpush II wI red dye. Drop bottom plug. Mix and pump 218 bbl ASL Lead @ 10.7 ppg and 145 bbl Litecrete Tail @ 12.0 ppg. Reciprocated pipe until 115 bl Tail pumped away. Dropped top plug and Pumped 19.7 bbl water and switched to rig pump for displacement 12:45 - 13:45 1.00 CEMENTDISP SURFAC Displaced w/2850 stx. @ 1200 strokes pumped had Mudpush II wI dye in returns and sent returns to vac trucks. Bumped plug w/1330 psi (800 psi over circulating pressure). CIP @ 13:32 hrs 6/7/04. Checked floats-OK 13:45 - 15:30 1.75 CEMENTPULD SURFAC Blow down surface lines. UD cement head, casing elevators and landing jt 15:30 - 20:00 4.50 WELCTL NUND SURFAC Flush and nipple down diverter. 20:00 - 00:00 4.00 WELCTL NUND SURFAC N/U and test casing head to 1000 psi LLDS @ 27.41' ULDS @25.16', GL @ 29.83' mats @ 29.31' 6/8/2004 00:00 - 06:30 6.50 WELCTL NUND SURFAC Continue N/U BOPE 06:30 - 11 :00 4.50 WELCTL BOPE SURFAC RIµ and tJIst·8OPE to 250 ps!1ow and 5000 psi high except hydrill 250 psi low _ 3WO psi high. John CriSp, AOGCC, waived witnessing the ·00Pe test. 11 :00 - 11 :30 0.50 WELCTL NUND SURFAC Set wear ring and run in LDS's 11 :30 - 12:00 0.50 RIGMNT RSRV SURFAC Service rig and grease top drive 12:00 - 14:30 2.50 DRILL PULD SURFAC M/U BHA #2 and orient MWD 14:30 - 15:45 1.25 DRILL PULD SURFAC Upload MWD, safety meeting, load sources 15:45 - 16:45 1.00 DRILL PULD SURFAC M/U BHA and shallow test MWD 16:45 - 17:30 0.75 DRILL TRIP SURFAC RIH wI HWDP amd P/U ghost reamer 17:30 - 18:30 1.00 DRILL TRIP SURFAC P/U 23 jts 4" d.p. from pipe shed 18:30 - 19:30 1.00 DRILL TRIP SURFAC RIH w/ stands out of derrick and tag @ 2919' 19:30 - 20:30 1.00 DRILL CIRC SURFAC CBU @ 4 bpm @ 440 psi 20:30 - 21 :30 1.00 CASE MIT SURFAC RIU and test casing to 2500 psi for 30 minutes on chart. RID 21 :30 - 23:00 1.50 CEMENT DSHO SURFAC Drill float collar, shoe track, and float shoe. Clean out old hole to 3010' and drill 20' of new hole to 3030'-2422' TVD 23:00 - 00:00 1.00 DRILL FIT SURFAC RIU and perform FIT to 18.0 ppg EMW. (1060 psi, shoe @ 2407' TVD, Printed: 4120/2005 3:21 :31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-311 2N-311 ROT - DRILLING Nordic Calista Services Nordic 3 Alaska OiP&~~etms?ffil~!\iOI1 Start: 6/2/200~ Ën : 6Tfs/2004 Rig Release: 6/16/2004 Gr ~orage Rig Number: 3 6/8/2004 23:00 - 00:00 1.00 DRILL FIT SURFAC MW=9.6 ppg) 6/9/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill from 3030' to 3980'. TVD= 2936'. ART=6.5, AST=1.2, P/U =90, S/O = 60, Rot=74, Torque= 5300 on, 4300 off. Rotary=85, WOB=5-15, Pump= 2700 psi @ 204 spm, (500 gpm) 12:00 - 00:00 12.00 DRILL DRLG PROD Drill from 3980' to 5055'. TVD=3514'. ART=7.3, AST=.7, P/U=83k, S/O=75k, Rot=75k, Torque= 7300 on/5500 off. Rotary=85, WOB= 5-15k, Pump= 3050 psi @ 204 spm (500 gpm) 6/10/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill from 5055' to 5086'. TVD=4013'. AST=1.3, ART=7.3, P/U=130k, S/O=65k, Rot=85k, Torque=7100 on/6700 off, Rotary=85 rpm, 12:00 - 00:00 I WOB=10-25k, Pump=3600 psi @ 204 spm (500 gpm) 12.00 DRILL DRLG PROD Drill from 5986' to 7065'. TVD=4591'. AST=.5, ART=8.0, P/U=140k, I S/O=74k, Rot=90k, Torque=9030 on17600 off, Rotary=85, WOB=10-25k, Pump=3700 psi @ 204 spm (500 gpm) 6/11/2004 00:00 - 06:30 6.50 DRILL DRLG PROD Drill 8 1/2" hole from 7,065' to 7,575', (510') 10-25K wob, 85 rpm's, 204 spm, 500 gpm, off btm pressure, 3,600 psi, on btm 3,850 psi, off btm torque, 9K ft-Ibs, on btm 9.1 K ft-Ibs, rot wt 93K, up wt 146K, dn wt 73K, 10.0 ppg MW, ave ECD 10.9-11.0 ppg, pumped 1-wt'd hi vis sweep with little increase in cuttings back 06:30 - 07:00 0.50 RIGMNT RSRV PROD Serviced rig 07:00 - 12:00 5.00 DRILL DRLG PROD Drill 8 1/2" hole from 7,575' to 7,900' MD/5.093' TVD, (325') ART 6.5 hrs, AST 1.6 hrs, Total drlg time last 24 hrs 8.1 hrs, 1 0-15K wob, 85 rpm's, 204 spm, 500 gpm, off btm pressure, 3,450 psi, on btm 3,7000 psi, off btm torque, 9.5K ft-Ibs, on btm 1 OK ft-Ibs, rot wt 95K, up wt 145K, dn wt 75K, 10.0 ppg MW, ave ECD 10.9-11.0 ppg 12:00 - 14:00 2.00 DRILL CIRC PROD Pumped weighted hi vis sweep and circ out of hole 14:00 - 15:00 1.00 DRILL WIPR PROD Precautionary backreamed out at drlg rate from 7,900' to 6,726', no problems 15:00 - 17:30 2.50 DRILL WIPR PROD POOH on elevators from 6,726' to 3,034', no problems 17:30 - 18:00 0.50 DRILL CIRC PROD Circ btms up for LOT, 10.0 ppg mud wt in & out 18:00 - 19:00 1.00 DRILL LOT PROD RU & performed LOT to 11.6 ppg EMW 19:00 - 19:30 0.50 RIGMNT RSRV PROD Serviced top drive 19:30 - 22:00 2.50 DRILL WIPR PROD RIH from 3,034' to 7,772', washed 90' to 7,862' 22:00 - 00:00 2.00 DRILL CIRC PROD Circ hole raising MW from 10.0 ppg to 10.5 ppg, circ at 465 gpm at 3,700 psi, pumps on up wt 11 OK, dn wt 95K 6/12/2004 00:00 - 02:30 2.50 DRILL CIRC PROD Fin circ and raising MW from 10.0 to 10.6 ppg, ECD ave 11.0 ppg with no mud losses, circ at 465 gpm at 3,700 psi 02:30 - 06:30 4.00 DRILL CIRC PROD Circ and raised MW from 10.6 to 10.8 ppg, ECD ave 11.25 ppg with no mud losses, lowered pump rate to 455 gpm at 3,600 psi 06:30 - 00:00 17.50 DRILL DRLG PROD Control drilled 8 1/2" hole due to ECD's and for log quality from 7,900' to 8,611' MD/5,582' TVD (711') ART 15.1 hrs, AST -0- hrs, 5-15Kwob, 80 rpm's, 455 9pm, off btm pressure 3,700 psi, on btm pressure 3,850 psi, off btm torque 10.9K ft-Ibs, on btm 12K ft-Ibs, 10.8 ppg MW, ave ECD 11.3 ppg, max ECD 11.4, rot wt with pumps on 105K, up wt 125K, dn wt 100K, pumps off up wt 175K, dn wt 77K Est top of Bermuda at 8,115' MD/ 5,239' TVD, Base of Bermuda at 8,272' MD/ 5,347' TVD 6/13/2004 00:00 - 01 :30 1.50 DRILL DRLG PROD Control drilled 8 1/2" hole due to ECD's from 8,611' to 8,657' MD/5,613' / TVD (46') (T.D.) ART 1.2 hrs, AST -0- hrs, 5-15K wob, 80 rpm's, 455 gpm, off btm pressure 3,700 psi, on btm pressure 3,850 psi, off btm torque 1 0.9K ft-Ibs, on btm 12K ft-Ibs, 10.8 ppg MW, ave ECD 11.3 ppg, max ECD 11.4, rot wt with pumps on 105K, up wt 125K, dn wt 100K, pumps off up wt 175K, dn wt 77K 01 :30 - 04:00 2.50 DRILL CIRC PROD Monitored well-static, Circ hole for trip out of hole, pumped hi vis sweep Printed: 4120/2005 3:21 :31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-311 2N-311 ROT - DRILLING Nordic Calista Services Nordic 3 Alaska Oil & Gas Cons. Commission S~Hét1~tfë 6/3/2004 End: 6/16/2004 Group: Start: 6/2/2004 Rig Release: 6/16/2004 Rig Number: 3 6/13/2004 01 :30 - 04:00 2.50 DRILL CIRC PROD 04:00 - 06:00 2.00 DRILL TRIP PROD 06:00 - 11 :00 5.00 DRILL TRIP PROD 11 :00 -13:00 2.00 DRILL PULD PROD 13:00 -14:00 1.00 DRILL PULD PROD 14:00 - 18:30 4.50 DRILL OTHR PROD I 18:30 - 21:00 2.50 ABAND" OTHR ABANDN 21 :00 - 00:00 3.00 ABAND" RURD ABANDN 6/14/2004 00:00-01:15 1.25 CEMENT PULD ABANDN 01:15 - 02:00 0.75 CEMENTRURD ABANDN 02:00 - 05:30 3.50 CEMENT TRIP ABANDN 05:30 - 07:00 1.50 CEMENTCIRC ABANDN 07:00 - 08:00 1.00 CEMENT PUMP ABANDN 08:00 - 08:30 08:30 - 10:00 0.50 CEMENT TRIP ABANDN 1.50 CEMENTCIRC ABANDN 10:00 - 10:30 0.50 CEMENT PUMP ABANDN 10:30 - 11 :30 1.00 CEMENT TRIP ABANDN 11 :30 - 13:30 2.00 CEMENTCIRC ABANDN 13:30 - 17:30 4.00 CEMENT PULD ABANDN 17:30 -19:30 2.00 CEMENTCIRC ABANDN 19:30 - 19:45 0.25 CEMENT CIRC ABANDN 19:45 - 20:15 0.50 CEMENT PULD ABANDN 20:15 - 21 :00 0.75 CEMENTCIRC ABANDN and circ a total of 3X btms up. circ at 455 gpm at 3,800 psi and 80 rpm's, had 25% increase in cuttings back from sweep Precautionary backreamed out 12 stds from 8,657' to 7,480' with no problems, found a small washout at the connection on a std of 4" HT 38 DP while backreaming out POOH on elevators from 7,480' to 206', stood back HWDP, no problems POOH Stood back std of flex DC's, held PJSM, removed radioactive sources and downloaded MWD, sent logs to town LD MWD and MM Evaluated open hole logs in town, pulled wear bushing, serviced rig and top drive, flushed out stack and cleared BHA from rig floor NOTE: Decision was made to P & A welt Installed wear bushing, LD flex DC's, prepared to unload 5 1/2" csg and uloaded top row of 5 1/2" csg from pipe shed while waiting on 2 7/8" cement stinger Unloaded 35 jts of 2 7/8" 6.5# L-80 EUE-M tbg into pipe shed and strapped, RU 2 7/8" handling tools and held PJSM on plugging operations MU 2 7/8" cement stinger and RIH to 1,068', MU 2 7/8" Mule shoe. 34 jts of 2 7/8" 6.5#.. L-80 EUE-M tbg and XO's back to 4" DP (1,068') RD tbg tongs and repositioned HWDP in derrick TIH with cement stinger on 4" DP, est circ and....UJitl'futa,657'. st up wt 135K. dn wt 68K Circ anc cond mud for cement plug #1, circ at 455 gpm at 3,800 psi, 10.8 ppg MW in & out, Held PJSM with rig crew, Dowell and APC drivers on setting cement plugs and batched mixed cement Turned over to Dowell and pumped 5 bbls FW, tested lines to 3,500 psi, pumped add. 5 bbls FW followed with 51 bbls (245 sxs) of 15.8 ppg. 1.17 yield class "G" Gasblok cmt w/additives, ave 4 bpm Initial circ pressure 840 psi, final 500 psi, pumped 1 bbl FW and rig displaced cement with 78.5 bbls of 10.8 ppg mud to balance plug, CIP @ 08:00 ~witbEatTOO."157 POOH slow from 8,657' to 8,136' CiR': btms tip froftt8, 136', no cmt at btms up, circ at 455 gpm at 3,800 psi with 10.8 ppg MW in & out for cement plug #2 Dowell pumped 10 bbls FW, 30.5 bbls (146 sxs) of 15.8 ppg, 1.17 yield class "G" Gasblok cmt w/additives, followed with 1 bbl FW and rig displaced cement with 74 bbls of 10.8 ppg mud to balance plug, CIP @ 10:30 hrs with est TOC@ 7.857', had full returns while pumping both piug& POOH slow from 8,136' to 7,347' Dropped DP wiper dart and circ DP and hole clean, ~cm1ent contaminated mud back lit bb'ns up then cont to circ till clean at shakers with 10.8 ppg MW in & out, circ at 430 gpm at 2,900 psi POOH with cement stinger LD 4" DP from 7,347' to 3,810', LD 112 jts 4" DP I Circ and condition mud while waiting on Dowell to deliver new cement blend for top plug, circ at 280 gpm at 1,000 psi Pump&d_.~40bbI, 300 \lis piHfrom 3,810', est top of pill at 3,400' POOH LD 4" DP from 3,810' to 3,400', LD 13 jts 4" DP Circ btms up evening MW in & out at 10.9 ppg, saw very little of hi vis Printed: 4/2012005 3:21 :31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-311 2N-311 ROT - DRILLING Nordic Calista Services Nordic 3 Start: 6/2/2004 Rig Release: 6/16/2004 Rig Number: 3 Anchorage Spud Date: 6/3/2004 End: 6/16/2004 Group: 6/14/2004 20:15 - 21 :00 0.75 CEMENTCIRC ABANDN pill at btms up, circ at 385 gpm at 1,950 psi 21 :00 - 21 :45 0.75 CEMENT PUMP ABANDN Dowell pumped 10 bbls FW, pressure tested lines to 3,500 psi, then pumped 54 bbls (312 sxs) of 17.0 ppg, 1.0 yield class "G" cmt w/additives, followed with 1 bbl FW and rig displaced cement with 25 bbls of 10.9 ppg mud to balance plug, ave 4 bpm, initial circ press 500 psi, final pressure 300 psi, CIP @21:45 hrs with est TOC@2,774', ,¡ had fuU r~f\$ __ pumf)ing plug 21 :45 - 22:30 0.75 CEMENT TRIP ABANDN POOH slow from 3,400' to 2,550' 22:30 - 23:00 0.50 CEMENT CIRC ABANDN Dropped DP wiper dart and circ DP and hole clean, had 20-30 bbls of cement contaminated mud back at btms up, circ 1.5x btms up and clean at shakers with 10.9 ppg MW in & out, circ at 400 gpm at 1,350 psi 23:00 - 00:00 1.00 CEMENTPULD ABANDN RD cement line, POOH from 2,550' to 2,200' LD 11 jts of 4" DP 6/15/2004 00:00 - 04: 15 4.25 CEMENT PULD ABANDN Fin POOH LD 4" Dp and 34 jts of 3 1/2" cement stinger 04:15 - 08:30 4.25 DRILL PULD ABANDN LD 22 stds of 4" DP F/Derrick 08:30 - 09:15 0.75 DRILL OTHR ABANDN RU & flushed out BOP stack 09:15 -11 :00 1.75 DRILL PULD ABANDN RIH w/9 stds HWDP, POOH LD same, pulled wear bushing 11 :00 - 13:00 2.00 DRILL OTHR ABANDN Removed 5 1/2" and 3 1/2" csg along with 3 1/2" completion tbg from pipe shed 13:00 - 14:00 1.00 RIGMNT RSRV ABANDN Slip and cut 49' of drlg line 14:00 - 14:45 0.75 CMPLTN RURD ABANDN RU to run 3 1/2" kill string 14:45 - 16:45 2.00 WELCTL EORP ABANDN Changed out lower set of 4" pipe rams to 3 1/2" and tested to 250 psi low, 5,000 psi high 16:45 - 20:45 4.00 CMPL TN PULD ABANDN PU andRIRwlth72 jt$of 31/2" 9.3#, L-SO, EUE-Mtbg for kihtring, ¡/ MU h41nget ...tended kif! string with end of tbg at 2,272', RILDS, st up wt 3IKt down~ 341< 20:45 - 21 :45 1.00 CMPL TN DEQT ABANDN RU....testèðš~t:ê Shòe cement plug to 2,000 for 30 min, NoI&;.JétfJcmes WlltAOOOC¥.IitnesMd test 21 :45 - 00:00 2.25 WELCTL NUND ABANDN LD Landing Jt, installed BPV, ND riser and BOP's 6/16/2004 00:00 - 03:00 3.00 WELCTL NUND ABANDN NU FMC 11" 5M adapter and 3 1/16" 5M Tree, tested void and tree to 5,000 psi, pulled TWC, moved camp to 1 G-08 03:00 - 05:15 2.25 CMPL TN FRZP ABANDN Held PJSM, RU Little Red, pressure tested lines and freeze protected well with 150 bbls diesel, put tbg and annulus in communication and allowed to U-tube, RD Little Red 05:15 - 06:00 0.75 WELCTL EORP ABANDN Installed BPV and secured well, RELEASED RIG @ 06:00 Hrs, rig to move to 1 G-08 Printed: 4/2012005 3:21 :31 PM y ConocoPhillips ;Wellbore Name _2N-311 Will ..... ? .,,' . '. ''^~' ", : Name 311 §tot Name slot #311 _taID. Name Pad 2N Field Name Tarn ConocoPhillips AI!, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska wellb.2N-311 Well path: GSS <0-264'>MWD wI Sag <393-8657'> Date Printed: 24-Jun-2004 mi. BAKER HUGHES INTEQ ~Ô Northino System Name AK-4 on NORTH AMERICAN DATUM 1927 I Last Revised I 17-Jun-2004 I Created 4-Jun-2004 I Govemment ID i 50-103-20491-00 I Last Revised I 2-Jun-2004 I Eastino 461651.5943 I NorthinQ 5927841.6325 I Coord Svstem Name ·>1 North Alionment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True I Grid NorthinO 5911980.5571 I Grid Eastino 460976.1391 18 50.6500 10 13.7000 All data is in Feet unless othelWise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 6072.05 Feet on azimuth 9.54 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ;{ OL( - D~> \ ~ t>-J.I\/ ConocJ'Phillips ConocoPhillips AI., Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska wellb.2N-311 Wellpath: GSS <0-264'>MWD w/Sag <393-8657'> Date Printed: 24-Jun-2004 ria. .Au INTEQ Wellpath (Grid) .Report MD[ft] Inc[deg] Azi[deg] I TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionrftl 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 460976.14 5911980.56 150.00 0.00 0.00 150.00 O.OON O.OOE 0.00 0.00 460976.14 5911980.56 170.00 0.20 68.00 170.00 0.01N 0.03E 1.00 0.02 460976.17 5911980.57 264.00 0.30 24.00 264.00 0.30N 0.28E 0.22 0.34 460976.43 5911980.85 393.92 1.60 6.82 393.90 2.41N O.64E 1.01 2.48 460976.79 5911982.96 485.75 2.59 7.91 485.67 5.74N 1.08E 1.08 5.84 460977 .24 ~911986.29 577.31 4.03 10.42 577.07 10.95N 1.94E 1.58 11.12 460978.14 5911991.50 670.88 7.64 13.64 670.14 20.23N 4.00E 3.87 20.62 460980.25 5912000.77 764.09 11.90 11.59 761.98 35.68N 7.40E 4.58 36.41 460983.72 5912016.19 857.84 13.63 12.31 853.41 55.94N 11.70E 1.85 57.10 460988.12 5912036.43 950.65 16.79 11.03 942.96 79.79N 16.59E 3.42 81.43 460993.14 5912060.25 1053.09 19.00 8.82 1 040.43 110.79N 21.98E 2.26 112.90 460998.69 5912091.22 1147.54 20.80 10.90 1129.24 142.46N 27.51E 2.05 145.04 461004.38 5912122.85 1239.77 24.92 12.07 1214.21 177.55N 34.67E 4.49 180.84 461011.72 5912157.91 1337.06 25.95 9.47 1302.07 218.59N 42.46E 1.56 222.61 461019.72 5912198.91 1432.08 29.06 6.84 1386.35 262.02N 48.63E 3.51 266.46 461026.12 5912242.30 1526.83 32.88 9.47 1467.58 310.26N 55.61E 4.28 315.1ß 461033.34 5912290.50 1622.84 34.68 9.61 1547.37 362.90N 64.46E 1.88 368.56 461042.46 5912343.09 1716.30 37.24 9.34 1623.02 417.03N 73.49E 2.74 423.44 461051.77 5912397.16 1811.07 40.05 9.30 1697.03 475.43N 83.07E 2.97 482.62 461061.65 5912455.50 1904.00 43.06 10.54 1766.56 536.14N 93.71E 3.36 544.25 461072.60 5912516.15 2000.48 46.48 11.13 1835.05 602.86N 106.49E 3.57 612.17 461085.72 5912582.80 2094.40 48.51 10.74 1898.50 670.84N 119.62E 2.18 681.38 461099.20 5912650.70 2189.08 51.21 9.85 1959.53 742.05N 132.54E 2.94 753.75 461112.49 5912721.84 2283.08 52.07 9.34 2017.87 814.73N 144.82E 1.01 827.46 461125.15 5912794.44 2377.41 55.51 8.96 2073.59 889.86N 156.92E 3.66 903.55 461137.63 5912869.50 2473.11 55.99 9.08 2127.45 967.98N 169.32E 0.51 982.66 461150.43 5912947.56 2567.65 58.17 7.07 2178.83 1046.55N 180.45E 2.92 1061.98 461161.97 5913026.06 2662.94 58.57 8.08 2228.80 1126.97N 191.15E 1.00 1143.07 461173.08 5913106.42 2757.03 58.43 8.81 2277.96 1206.33N 202.93E 0.68 1223.28 461185.27 5913185.70 2851.72 57.85 8.36 2327.94 1285.85N 214.94E 0.73 1303.69 461197.68 5913265.15 2946.84 58.03 8.48 2378.43 1365.59N 226.74E 0.22 1384.29 461209.89 5913344.83 3039.19 57.47 9.19 2427.71 1442.77N 238.73E 0.89 1462.38 461222.28 5913421.93 3134.01 57.06 9.85 2478.99 1521.43N 251.93E 0.73 1542.14 461235.88 5913500.52 3228.15 56.83 8.86 2530.34 1599.28N 264.75E 0.91 1621.04 461249.11 5913578.29 3322.83 56.37 8.13 2582.46 1677.46N 276.43E 0.81 1700.07 461261.19 5913656.40 3418.94 57.13 9.29 2635.16 1756.90N 288.60E 1.28 1780.44 461273.77 5913735.77 3513.86 59.28 11.19 2685.17 1836.28N 302.96E 2.83 1861.10 461288.53 5913815.07 3608.32 58.72 10.39 2733.82 1915.82N 318.12E 0.94 1942.05 461304.10 5913894.51 3703.80 58.25 9.02 2783.73 1996.04N 331.84E 1.32 2023.44 461318.23 5913974.66 3797.81 57.01 9.54 2834.06 2074.41N 344.64E 1.40 2102.84 461331.44 5914052.95 3892.58 56.89 9.54 2885.74 2152.74N 357.81E 0.13 2182.27 461345.01 5914131.21 3987.10 57.21 9.20 2937.15 2231.00N 370.72E 0.45 2261.59 461358.32 5914209.39 4081.88 57.44 8.61 2988.32 2309.82N 383.07E 0.58 2341.36 461371.08 5914288.14 4176.39 57.22 9.40 3039.34 2388.39N 395.52E 0.74 2420.92 461383.93 5914366.64 4271.27 57.58 10.06 3090.46 2467.18N 409.03E 0.70 2500.85 461397.85 5914445.34 4365.95 57.73 10.10 3141.11 2545.93N 423.03E 0.16 2580.83 461412.25 5914524.02 4459.48 57.48 10.73 3191.22 2623.60N 437.31E 0.63 2659.80 461426.92 5914601.61 4553.44 57.39 10.17 3241.80 2701.48N 451.67E 0.51 2738.97 461441.69 5914679.40 4648.01 57.37 10.21 3292.78 2779.87N 465.76E 0.04 2818.62 461456.18 5914757.71 4743.42 57.30 10.03 3344.27 2858.94N 479.88E 0.17 2898.94 461470.70 5914836.70 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 6072.05 Feet on azimuth 9.54 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~illips ConocoPhillips Alia, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska wellb.2N-311 Wellpath: GSS <0-264'>MWD w/Sag <393-8657'> Date Printed: 24-Jun-2004 .¡. BAKER HUGHES INTEQ Wellpath (Grid) Report MO[ft] Inc[deg] Azi[deg] I TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionfftl 4838.14 57.19 9.28 3395.52 2937.47N 493.24E 0.68 2978.59 461484.46 5914915.15 4932.57 56.94 9.95 3446.86 3015.61N 506.47E 0.65 3057.85 461498.10 5914993.22 5026.78 56.51 9.75 3498.55 3093.22N 519.95E 0.49 3136J)~ 461511.98 5915070.74 5121.17 57.44 9.09 3549.99 3171.29N 532.90E 1.15 3215.75 461525.33 5915148.74 5216.73 57.68 9.19 3601.26 3250.91N 545.71E 0.27 3296.39 461538.55 5915228.29 5311.08 58.07 9.31 3651.43 3329.78N 558.55E 0.43 3376.30 461551.80 5915307.07 5406.20 58.32 8.87 3701.56 3409.60N 571.32E 0.47 3457.13 461564.98 5915386.82 5501.95 58.30 8.95 3751.86 3490.09N 583.94E 0.07 3538.60 461578.01 5915467.24 5596.72 57.94 8.85 3801.91 3569.59N 596.39E 0.39 3619.07 461590.87 5915546.67 5691.42 57.37 8.58 3852.58 3648.68N 608.51E 0.65 3699.07 461603.40 5915625.68 5787.18 57.17 9.21 3904.35 3728.26N 620.97E 0.59 3779.62 461616.26 5915705.19 5879.53 57.08 9.06 3954.48 3804.84N 633.28E 0.17 3857.18 461628.97 5915781.70 5975.00 57.81 9.59 4005.85 3884.24N 646.32E 0.90 3937.65 461642.42 5915861.03 6069.84 57.63 9.47 4056.50 3963.32N 659.60E 0.22 4017.83 461656.10 5915940.03 6164.52 57.63 8.97 4107.19 4042.25N 672.41 E 0.45 4097.80 461669.32 5916018.89 6258.89 57.27 9.50 4157.97 4120.77N 685.18E 0.61 4177.34 461682.49 5916097.33 6354.38 57.15 9.62 4209.68 4199.93N 698.51E 0.16 4257.62 461696.22 5916176.41 6447.69 58.24 9.24 4259.55 4277.73N 711.43E 1.22 4336.48 461709.54 5916254.13 6541.60 57.99 9.90 4309.15 4356.36N 724.69E 0.65 4416.22 461723.20 5916332.68 6636.16 57.78 9.35 4359.42 4435.32N 738.08E 0.54 4496.31 461737.00 5916411.57 6731.31 57.47 9.58 4410.37 4514.59N 751.29E 0.38 4576.67 461750.62 5916490.76 6825.62 57.22 9.17 4461.26 4592.93N 764.23E 0.45 4656.07 461763.96 5916569.02 6921.05 57.20 9.76 4512.94 4672.06N 777.42E 0.52 4736.30 461777.56 5916648.08 7007.72 56.47 10.36 4560.35 4743.50N 790.09E 1.02 4808.84 461790.60 5916719.44 7110.14 56.44 9.90 4616.95 4827.53N 805.10E 0.38 4894.20 461806.04 5916803.38 7205.16 56.24 9.98 4669.62 4905.43N 818.76E 0.22 4973.29 461820.09 5916881.21 7299.36 55.81 9.64 4722.26 4982.40N 832.07E 0.55 5051.40 461833.80 5916958.11 7393.64 55.10 9.37 4775.72 5058.99N 844.89E 0.79 5129.06 461847.02 5917034.62 7490.15 54.38 9.48 4831.44 5136.73N 857.79E 0.75 5207.86 461860.32 5917112.29 7584.15 52.45 9.58 4887.46 5211.17N 870.29E 2.05 5283.34 461873.20 5917186.65 7678.86 50.55 9.29 4946.41 5284.28N 882.44E 2.02 5357.46 461885.73 5917259.69 7773.71 48.73 9.30 5007.84 5355.61N 894.12E 1.92 5429.73 461897.77 5917330.94 7868.25 47.17 9.71 5071.15 5424.84N 905.71E 1.68 5499.93 461909.71 5917400.11 7963.12 47.10 9.45 5135.69 5493.41 N 917.28E 0.21 5569.46 461921.64 5917468.61 8057.56 47.00 9.80 5200.04 5561.56N 928.84E 0.29 5638.59 461933.54 5917536.70 8152.24 47.09 10.26 5264.56 5629.80N 940.90E 0.37 5707.88 461945.96 5917604.86 8246.98 46.48 10.27 5329.43 5697.74N 953.21E 0.64 5776.92 461958.62 5917672.73 8340.86 46.55 10.48 5394.03 5764.74N 965.48E 0.18 5845.03 461971.23 5917739.66 8430.54 46.20 9.71 5455.91 5828.65N 976.85E 0.73 5909.94 461982.93 5917803.51 8528.40 45.88 9.95 5523.84 5898.06N 988.88E 0.37 5980.38 461995.32 5917872.84 8569.83 45.40 10.87 5552.80 5927.19N 994.23E 1.97 6010.00 462000.82 5917901.95 8657.00 45.40 10.87 5614.01 5988.14N 1005.94E 0.00 6072.05 462012.84 5917962.83 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Nordic III 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 6072.05 Feet on azimuth 9.54 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ¥ ConocòPhillips ConocoPhillips Ala, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska wellb.: 2N-311 Wellpath: GSS <0-264'>MWD w/Sag <393-8657'> Date Printed: 24-Jun-2004 _i. 'W:. INTEQ Comments MOrft] I TVOrft] 3010.00 II 2412.05 8657.00 5614.01 I Northrft] 1418.44N 5988.14N I Eastfft] I Commént 234.85E ~ Proiected Oata - NO SURVEY 1005.94E I Proiected Oata - NO SURVEY Hole Sections Diameter Start Start Start Start End End End Start Wellbore fin] MDrft] TVOfft] Northrft] Eastfft] MDfft] TVOrft] Northrftl Eastfft] 12 1/4 0.00 0.00 O.OON O.OOE 3010.00 2412.05 1418.44N 234.85E 2N-311 81/2 3010.00 2412.05 1418.44N 234.85E 8657.00 5614.01 5988.14N 1005.94E 2N-311 CasinQs Name Top Tpp Top ¡TOP Shoe Shoe Shoe Shoe Wellbore MOrftl TVOrft] Northtft] Eastfft] MOfft] TVOfft] Northfft] Eastfftl 16" Conductor 0.00 0.00 O.OON O.OOE 120.00 120.00 O.OON O.OOE 2N-311 9 5/8" CasinQ 0.00 0.00 O.OON I O.OOE 3000.00 2406.71 1410.09N 233.54E 2N-311 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Nordic III 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 6072.05 Feet on azimuth 9.54 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e RECE\VE~ AUG~ b 2004 _."' ~r Ai_a Oil & GasGonS· Anchorage Transmittal Form INTEQ ../ð~"::'O~ "])s/Û /zCø~ ,,¡_ BAKER HUGHES To: Anchorage GEOScience Center AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin D"""on .¡¡ d...-d. tJu...--..- Reference: 2N-311 Contains the following: I LDWG Compact Disc (Includes Graphic Image files) I LDWG lister summary I blueline - GRlMPR Measured Depth Log I blueline - GRlMPR TVD Log I blueline - CCN/ORD Measured Depth Log 1 blueline - CCN/ORD TVD Log LAC Job#: 692973 Received .~ Date:' Aug ï' 2004 Date: g¡3rf;/ 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 e MEMORANDUM e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'L/. ( (. ( P.I. Supervisor f"./'1f & ~7 t4 FROM: Jeff Jones Petroleum Inspector Section: 3 Lease No.: Operator Rep.: Pete Wilson Township: 9N Drilling Rig: Nordic 3 CasinQ/TubinQ Data: Conductor: O.D. Shoe@ Surface: O.D. Shoe@ Intermediate: 95/8" O.D. Shoe@ 3000' MD Production: O.D. Shoe@ Liner: O.D. Shoe@ Tubing: O.D. Tail@ DATE: June 15,2004 SUBJECT: Plug & Abandonement 2N-311 CPAI/2N Pad Tarn KRU .l,u~3 NON- CONFIDENTIAL Range: 7E Rig Elevation: Meridian: UM Total Depth: 10040 CasinQ Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Founded on Bottom of Cement 3100' MD PluQQinQ Data: Top of Cement Depth Verified? 2774' MD No Pressure Test Applied 2000 psi Tvpe PluQ (bottom up) Open Hole Balanced Type PluQ Open Hole Perforation Annulus Casing Stub Surface Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag No Mud Weight above plug 10.9 ppg June 15, 2004: I traveled to Nordic rig 3 to witness the pressure test of a cement abandonment plug in Conoco-Phillips' KRU well 2N-311. Nordic 3 personnel were rigging up to pressure test the abandonment plug on my arrival. Top of cement was estimated to be at 2774' MD +/-. 2000 psi was applied to the plug and monitored for 30 minutes. 10 minutes into the test I noted a slight leak on the test pump hose which was tightened, stopping the leak. The test pressure then stabilized at 1900 psi, passing the test. Summary: I witnessed a successful pressure test of a cement abandonment plug in CPAI's KRU well 2N-311. ~ Distribution: orig - Well File c - Operator c - DNR/DOG c - Database c - Rpt File c - Inspector Rev.:5/28/00 by L.R.G. Attachments: Pressure Chart, Ops report, schematic (4) P&A KRU 2N-311 6-15-04 JJ.xls 6/29/2004 ç e e I JOB NUMBER I EVE~TDC;DE 124 HRS PROG I FIELD NAME I OCS NO. Nordic 3 Tarn ACCIDENTS LAST 24 HRS.? IDFS 5,613.0 12.00 DAlLYTANG 8,468.0 0 DAILY INT WIO MUD o IREPTNO. ¡DATE 13 6/14/2004 ICUM. TANGO CUM INTANG WI MUD o 2N-311 SUPERVISOR I RIG NAME & NO. G.R. Whitlock/P. Wilson n1433@ppco.co CURRENT STATUS LD Excess DP & HWDP from Derrick 24 HR FORECAST Fin LD DP, Unload Pipe Shed, Run Kill String, NDI NU Tree RR LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM LASTCASING 6/13/2004 8,657.00 45.400 10.870 9.625 (in) @ DATE OF LAST SAFETY MEETING DAILY 6/14/2004 I LEAKOFF 18.08 10034253 I NEXT CASING 2,999.9 (ft) 3.500 (in) @ 2,300.0 (ft) LAST BOP PRES TEST 61812004 00:00 01:15 1.25 CEMENT XGEOL PULD 01:15 02:00 0.75 CEMENT XGEOL RURD 02:00 05:30 3.50 CEMENT XGEOL TRIP 05:30 07:00 1.50 CEMENT XGEOL CIRC 07:00 08:00 1.00 CEMENT XGEOL PUMP 08:00 08:30 08:30 10:00 0.50 1.50 CEMENT XGEOL CEMENT XGEOL TRIP CIRC 10:00 10:30 0.50 CEMENT XGEOL PUMP 10:30 11:30 1.00 CEMENT XGEOL TRIP 11:30 13:30 2.00 CEMENT XGEOL CIRC 13:30 17:30 4.00 CEMENT XGEOL PULD 17:30 19:30 2.00 CEMENT XGEOL CIRC 19:30 19:45 0.25 CEMENT XGEOL CIRC 19:45 20:15 0.50 CEMENT XGEOL PULD 20:15 21:00 0.75 CEMENT XGEOL CIRC 21:00 21:45 0.75 CEMENT XGEOL PUMP ABANDN MU 2 7/8" cement stinger and RIH to 1,068', MU 2 7/8" Mule shoe, 34 jts of 2 7/8" 6.5#,. L-80 EUE-M tbg and XO's back to 4" DP (1,068') ABANDN RD tbg tongs and repositioned HWDP in derrick ABANDN TIH with cement stinger on 4" DP, est circ and tagged btm at 8,657', st up wt 135K, dn wt 68K ABANDN Circ anc cond mud for cement plug #1, circ at 455 gpm at 3,800 psi, 10.8 ppg MW in & out, Held PJSM with rig crew, Dowell and APC drivers on setting cement plugs and batched mixed cement ABANDN Tumed over to Dowell and pumped 5 bbls FW, tested lines to 3,500 psi, pumped add. 5 bbls fW followed with51bbls(245sxs)of15;8ppg, 1.17 yield class "G" Gasblok cmt w/additives, ave 4 bpm Initial circ pressure 840 psi, final 500 psi, pumped 1 bbl FW and rig displaced cement with 78.5 bbls of 10.8 ppg mud to balance plug, CIP @ 08:00 hrswitrrEStTOC@8,157 ABANDN POOH slow from 8,657' to 8,136' ABANDN Circ btms up from 8,136', no cmt at btms up, circ at 455 gpm at 3,800 psi with 10.8 ppg MW in & out for cement plug #2 ABANDN Dowell pumped 10 bbls FW, 30.5 bbls(t46SXS)of 15.8 ppg, 1.17 yield class "G" Gasblok cmt wladditives, followed with 1 bbl FW and rig displaced cement with 74 bbls of 10.8 ppg mud to balance plug, CIP @ 10:30 hrs withe~tTOC @7,857', had full returns while pumping both plugs ABANDN POOH slow from 8,136' to 7,347' ABANDN Dropped DP wiper dart and circ DP and hole clean, had cement contaminated mud back at btms up then cont to circ till clean at shakers with 10.8 ppg MW in & out, circ at 430 gpm at 2,900 psi ABANDN POOH with cement stinger LD 4" DP from 7,347' to 3,810', LD 112 jts 4" DP ABANDN Circ and condition mud while waiting on Dowell to deliver new cement blend for top plug, circ at 280 gpm at 1,000 psi ABANDN Pumped and spotted 40 bbl, 300 vis pill from 3,810', est top of pill at 3,400' ABANDN POOH LD 4" DP from 3,810' to 3,400', LD 13 jts 4" DP ABANDN Circ btms up evening MW in & out at 10.9 ppg, saw very little of hi vis pill at btms up, circ at 385 gpm at 1,950 psi ABANDN Dowell pumped 10 bbls FW, pressure tested lines to 3,500 psi, then pumped 54 bbls (312 sxs) of 17.0 ppg, 1.0 yield class "G" cmt wladditives, followed with 1 bbl FW and rig displaced cement with.25 bbls of 10.9 ppg mud to balance plug, ave 4 bpm, initial circ press 500 psi, final pressure 300 psi, CIP Printed: 6/1512004 5:55:19 AM e e 2N-311 I JOB NUMBER I EVE~;~DE 124 HRS PROG ITMD TVD IDFS 8,657.0 5,613.0 12.00 I REPT NO. 13 I DATE 6/14/2004 WELL NAME [FROM 21:00 21:45 22:30 HÒURS' 0.75 0.75 0.50 GQDETRoùàlÈ CEMENTXGEOL PUMP CEMENT XGEOL TRIP CEMENT XGEOL CIRC TO 21:45 22:30 23:00 23:00 00:00 1.00 CEMENT XGEOL PULD ABANDN @21:45 hrswith'est TOC @ 2,774', had full returns while pumping plug ABANDN POOH slow from 3,400' to 2,550' ABANDN Dropped DP wiper dart and circ DP and hole clean, had 20-30 bbls of cement contaminated mud back at btms up, circ 1.5x btms up and clean at shakers with 10.9 ppg MW in & out, circ at 400 gpm at 1,350 psi ABANDN RD cement line, POOH from 2,550' to 2,200' LD 11 jts of 4" DP 24 HR SUMMARY: MU 2 7/8" Tbg Stinger & RIH on 4" DP to TD, Circ & Cond Mud FI Cmt Plugs, Set 2 Btm Plugs WIEst TOC @ 7,857', POOH LD DP to 3,810', Spot Hi Vis Pill, POOH to 3,400', Set Csg Shoe Plug #3 F/3,400' to Est TOe @ 2,774', POOH to 2,550 CBU, Began LD DP CØMPA~ M-I Drilling Fluids Nordic Calista Services Baker Hughes Inteq - D Pf:·RSONNEL,Ö~-rA ...... . H0t:.II~S.. . 4'b1pÃ!ílY '" 2 Baker Hughes Inteq 3 Fahweather E&P Service 1 Nordic Calista Services 1 2 23 Fuel Water, Drilling gals bbls 1IIIAiERí~~'5I~titsístfíMPT(Øt.f; iJSAG.E· .' ONHÄr;,f¡); ·'IT~~' .'. 100 5,300 Water, Potable 123 183 ···...·.4N1TŠ. bbls 35 46 Printed: 6/1512004 5:55:19 AM . 'm PHILLIPS Alaska, Inc. ,~ A Subsidiary of PHillIPS PETROLEUM COMPANY e e Calculations Chart Subject ~~~Â 2f'-(-3H I By Sheet number of File Date : ¡ , , ¡ .... .; C¡, "'/~ I · · ~ð2 ~ , ~i...... ~(C H';:- ,<) ;lid ~.... J ~' ¿-I C~ b~ /(J.C , . -/'l 4 ;c C> :t-,,, 8 l:>~ . , .....,..¡"/",, , j , I ~r.- -: _J..,:. ~. t ;::: : ! "Z. 'Î ,,,.. ¿,.... \' " .~ , K '(': ~ cf 4- /ß( P<..- r..- \/ '-" -- - , ~ , f I ~ ..... --- --r - -' -C~ Gi L..'" UI.:. I '.i......- . v. ~ , y \ v~. '_J :.... .,,' ~ ,\,..... 1:L 3 L' 't' '. '..a_ , lS7 frt I ' .,/ .1 ' r !~ I . t~· j , !/ \. ü (... A ~A . ,--, i- ;-0 .Jf ( ) ":t. ~s I _ 3".~ ~b , :~ iDC bô\. '<- - 1 " ,~ ./N1 ( i ......, ''\= ,,"\ .- .... ~ :: ~~ ~: , i ,(; I~: , oc: ..I.j. ~3 .: f.. D ¡ ... ·h&.f~ ...(\/ ()C ~~.~~ )::¡o 'oz '::.... lö ~ ....., ..... J;:¡" ~ . . .¡ 10 .~ -"" f :¡.-. <B b b I "- '(1.<1. .., \ f"\, ~ ì . . . .i - --.- l '.' ) ·'s " I .f '." 7~ ~S 7 ..l- i"<:'" ¡ . ;¡\. - A >. \ ........ .L. 3 I~ --t 0 ";[0 Zi I. 'is = '='0.. s-þ ~t 2':; \. ! ¡ " I---- ( .;.-- 'L ""'í:il. :f,I 2 ..- Xj , "".. -" (" . .':i I L- - ¡..... " y '~- ' ,- i'2 \ .. .. ..... I So L '. l.- ' , -<;( =:1or-*l,o ::ro Z"'" I. <I.t.':. q \,k1 ¡¡ { , " l-. I L P/~ .J,I. J: 'r;;O ¡ .,. K.t: \ {'}o/. -> //1 /1 ."A i.', ~/ ¡, , . .f.. J f ~ 9J1t. ~. - 'j< _ t i .:.- - t .... -- -, if - ... l ¡;, ,., I';K; ,<,.:; I ~ /Y 2f ,0- ¡~L --- j iJ ,., ""- ~ .'- '--" I ,¡.f! I \ , Q,l. PRINTING {907) 563-4743 159-5881 e e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ~ ConocoPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 14, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 2N-311 (APD # 204-063) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to suspend the Kuparuk well 2N-311. If you have any questions regarding this matter, please contact me at 265-6830 or Kelly McLure at 265-6059. Sincerely, '\~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling JUN 1 ..12004 RT /skad aD/SINAL Change approved program o Alter casing 0 o STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION r.~ r= .¡ '., ;,.... APPLICATION FOR SUNDRY APPROVAL"¡'N 20 AAC 25.280 J U Operational shutdown 0 o D {)o-J Ç/IS(1- A Ç;,(w e e Repair well o D D Perforate 1 ¡! '2004 ;·:;)\/.JG¡j\Aiìri~ßílpos.D Time ~~IiE1fiiJ Other D 1. Type of Request: Abandon Suspend Plug Perforations Stimulate Pull Tubing Perforate New Pool Re-enter Suspended Well 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 150' AMSL 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: Exploratory D Service D .204-063 6. API Number: 50-103-20491-00 9. Well Name and Number: 2N-311 8. Property Designation: ADL 375074/380054/3800531 ALK 31961132027/32026 11. Total Depth MD (ft): 8657' Casing Total Depth TVD (ft): Effective Depth MD (h): 5613' Length 10. Field/Pools(s): Kuparuk River Field / Tarn Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): Size Surface 80' 2970' 16" MD TVD Burst Collapse 139' 139' 3000' 2402' Structural Conductor 9.625" Intermediate Production Liner Perforation Depth MD (ft): None Packers and SSSV Type: None Perforation Depth TVD (ft): None Packers and SSSV MD (ft): Tubing Size: None Tubing Grade: None Tubing MD (ft): None None 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: 6/14/2004 Oil 0 Gas D 16. Verbal Approval: !rt?'w\ I Date: "I ..; H WAG D GINJ D Commission Representative: . . . I W(.I).. /14 (J Service D Plugged D WINJ D Abandoned D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kelly McLure @ 265-6059 Printed Name Randy Thomas Signature .~~ Title Kuparuk Drilling Team Leader Phone 265-6830 COMMISSION USE ONLY Date 6 (1'1'(0'1 Conditions of approval: Notify Commission so that a representative may witness Plug IntegrityD BOP Test D Mechanical Integrity Test D location Clearance D Sundry Number: ~1J1 ;?? 7 Other: . 'i"~ . ~ :,IJ;'lll >jl\ .: . \,0\ Approved by: COMMISSIONER BY ORDER OF THE COMMISSION Daœ cG,ft6ftý ./ Form 10-403 Revised 2/2003 nQ\r;\t\\AL SUBMIT IN DUPLICATE e e Allsup-Drake, Sharon K From: Sent: To: Cc: Subject: McLure, Kelly Monday, June 14, 2004 10:49 AM Tom Maunder (E-mail) Thomas, Randy L; Hayden, Philip; Nordic 3 Company Man; Bennett, Lara 0; Hand, Jim; NSK Fld Drlg Supv; Allsup-Drake, Sharon K RE: 2N-311 Suspension of the well- Procedure Revision 6-14-04 A revision of the abandonment has been discussed with the and a plan forward has been approved verbally by the AOGCC, Tom Maunder. The plan forward will be the two cement plugs covering from the bottom of the hole 8657' MD up to 7857' MD, 300' above the top of the Bermuda Interval. The change will be to not run a cement retainer, but to set SOD' viscous pill from 3900' MD-3500'MD. Then place a sidetrack cement plug for a later sidetrack, 15.8 ppg Class G from 3400' MD up to 200' inside the 9-5/8" surface casing shoe. The full length of the second plug is 600', with 400' below the shoe and 200' inside the surface casing. The well will be freeze protect and letted with a 3-1/2" kill string in the hole. When the kill string is placed the plug, surface casing will be pressure tested. The well will be suspended until a sidetrack location can be evaluated at a later date. -----Original Message----- From: McLure, Kelly Sent: Sunday, June 13, 2004 6:26 PM To: Tom Maunder (E-mail) Cc: Thomas, Randy L; Allsup-Drake, Sharon K; Hayden, Philip; Nordic 3 Company Man; Bennett, Lara D Subject: 2N-311 Suspension of the well Tom, I would like to inform you that I just spoke with Wenton from the AOGCC in town, June 13,2004,6:00 PM. We discussed the Suspension of the 2N-311 well. The well was drilled to a total depth of 8657' MD with the target T3 Bermuda Sand. The zone came in at a depth of 8115' to the bottom at 8272', however the net pay was only 8 feet and not sufficient to complete the well. The reason for the suspension instead of permanent P&A is to evaluate the data and reserve the option to sidetrack at a later date. The plan for suspension approved by Wenton is as follows: Using a 2-7/8" stinger on 4.0" drillpipe run in the hole to the total depth. Pump and place a SOD' Class G 15.8 ppg cement w/ gas block plug from 8657' up to 8157' MD. We would pull above the cement plug and pump a second 300' cement plug of Class G 15.8 cement with the top of cement at 7857' MD in the 8-1/2" open hole. Pulling up out of the second cement plug we would pull out of the hole and pick up a cement retainer and run back in the hole to 50' inside the 9-5/8" casing shoe. Final steps is setting the cement retainer and squeezing 1 DO' of Class G 15.8 cement below the retainer and placing 50' of class G 15.8 ppg cement on top of the retainer. We will file the Sundry for 2N-311 on Monday morning June 14, 2004. Any questions please contact me. Kelly McLure Kelly McLure Kuparuk Drilling Engineer Drilling & Wells Anchorage 907-265-6059 (direct) 907-265-1535 (fax) RE: 2N-311 Suspension of the well- Procedure Revision 6-14-04 e e Subject: RE: 2N-31 1 Suspension of the well- Procedure Revision 6-14-04 ~ From: "McLure, Kelly" <Kelly.A.McLure@conocophillips.com> Date: Mon, 14 Iun 2004 18:00:53 -0500 T():"Tom Maupder(E-mail)..<tQmjmaunder@adn1Ïn.state.ak.us> ç(:: "ThoqIas, RandyL" <Rangy.LThomas@con.ocopÞillips.com>,"Hayden, Philip" <Philip.Hayden@conocophillips.com>, Norgic $ Company Man <nI433@conocQphi11ips.com> d-OY. -OG ~ Tom, I was incorrect in the sidetrack plug set at the shoe weight. The weight of the cement slurry will be 17.0 ppg instead of the weight referenced below of 15.8 ppg. I was unable to catch the outgoing paperwork to change that before it was sent to you. Regards, Kelly McLure -----Original Message----- From: McLure, Kelly Sent: Monday, June 14, 2004 10:49 AM To: 'Tom Maunder (E-mail)' Cc: Thomas, Randy L; Hayden, Philip; Nordic 3 Company Man; Bennett, Lara D; Hand, Jim; NSK Fld Drlg Supv; Allsup-Drake, Sharon K Subject: RE: 2N-311 Suspension of the well- Procedure Revision 6-14-04 A revision of the abandonment has been discussed with the and a plan forward has been approved verbally by the AOGCC, Tom Maunder. The plan forward will be the two cement plugs covering from the bottom of the hole 8657' MD up to 7857' MD, 300' above the top of the Bermuda Interval. The change will be to not run a cement retainer, but to set 500' viscous pill from 3900' MD-3500' MD. Then place a sidetrack cement plug for a later sidetrack, 15.8 ppg Class G from 3400' MD up to 200' inside the 9-5/8" surface casing shoe. The full length of the second plug is 600', with 400' below the shoe and 200' inside the surface casing. The well will be freeze protect and lefted with a 3-1/2" kill string in the hole. When the kill string is placed the plug, surface casing will be pressure tested. The well will be suspended until a sidetrack location can be evaluated at a later date. -----Original Message----- From: McLure, Kelly Sent: Sunday, June 13, 2004 6:26 PM To: Tom Maunder (E-mail) Cc: Thomas, Randy L; Allsup-Drake, Sharon K; Hayden, Philip; Nordic 3 Company Man; Bennett, Lara D Subject: 2N-311 Suspension of the well Tom, I would like to inform you that I just spoke with Went on from the AOGCC in town, June 13, 2004, 6:00 PM. We discussed the Suspension of the 2N-311 well. The well was drilled to a total depth of 8657' MD with the target T3 Bermuda Sand. The zone came in at a depth of 8115' to the bottom at 8272', however the net pay was only 8 feet and not sufficient to complete the well. The reason for the suspension instead of permanent P&A is to evaluate the data and reserve the option to sidetrack at a later date. The plan for suspension approved by Went on is as follows: Using a 2-7/8" stinger on 4.0" drillpipe run in the hole to the total depth. Pump and place a 500' Class G 15.8 ppg cement w/ gas block plug from 8657' up to 8157' MD. We would pull above the cement plug and pump a second 300' cement plug of Class G 15.8 cement with the top of cement at 7857' MD in the 8-1/2" open hole. Pulling up out of the second cement plug we would pullout of the hole and pick up a cement retainer and run back in the hole to 50' inside the 9-5/8" casing shoe. Final steps is setting the cement retainer and squeezing 100' of Class G 15.8 cement below the retainer and placing 50' of class G 15.8 ppg cement on top of the retainer. We will file the Sundry for 2N-311 on Monday morning June 14, 2004. Any questions please contact me. lof2 6/14/20044:04 PM Re: 2N-311 Suspension of the well Subject: Re: 2N-311 Suspension ofthe well From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 14 Jun 2004 07:09:57 -0800 To: "McLure, Kelly" <Kelly.A.McLure@conocophillips.com> JOL\~O(Q ~ Ke 11 Y , Your proposal is generally acceptable, however the cement volume below the retainer needs to fill 100' below the casing shoe not 100' below the retainer (20 AAC 25..112(b) (2). Our normal practice when plugs are set on bottom is to not require tagging provided that lost returns or other problems are not encountered while placing the plugs. I look forward to the sundry. Please call with any questions. Tom Maunder, PE AOGCC - McLure, Kelly wrote: Tom, I would like to inform you that I just spoke with Went on from the AOGCC in town, June 13, 2004, 6:00 PM. We discussed the Suspension of the 2N-311 well. The well was drilled to a total depth of 8657' MD with the target T3 Bermuda Sand. The zone came in at a depth of 8115' to the bottom at 8272', however the net pay was only 8 feet and not sufficient to complete the well. The reason for the suspension instead of permanent P&A is to evaluate the data and reserve the option to sidetrack at a later date. The plan for suspension approved by Went on is as follows: Using a 2-7/8" stinger on 4.0" drillpipe run in the hole to the total depth. Pump and place a 500' Class G 15.8 ppg cement w/ gas block plug from 8657' up to 8157' MD. We would pull above the cement plug and pump a second 300' cement plug of Class G 15.8 cement with the top of cement at 7857' MD in the 8-1/2" open hole. Pulling up out of the second cement plug we would pullout of the hole and pick up a cement retainer and run back in the hole to 50' inside the 9-5/8" casing shoe. Final steps is setting the cement retainer and squeezing 100' of Class G 15.8 cement below the retainer and placing 50' of class G 15.8 ppg cement on top of the retainer. We will file the Sundry for 2N-311 on Monday morning June 14, 2004. Any questions please contact me. - Kelly McLure Kelly McLure Kuparuk Drilling Engineer Drilling & Wells Anchorage 907-265-6059 (direct) 907-265-1535 (fax) 1 of 1 6/14/20044:32 PM . . FRANK H. MURKOWSKI, GOVERNOR AI,ASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 2N-311 ConocoPhillips Alaska, Inc. Permit No: 204-063 Surface Location: 27' FNL, 617' FEL, SEC. 3, T9N, R7E, UM Bottomhole Location: 539' FSL, 370' FWL, SEC. 26, TlON, 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 :&om obtaining additional permits or approvals required by law :&om 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 commissionp witness any required test. Contact the Commission's North Slope petroleum field inspector 6 607 (pager). éil (J. ~ir BY ORDER OF THE COMMISSION DATED this2:J. day of April, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1a. Type of Work: DrillW Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION RedrillU PERMIT TO DRILL 20 AAC 25.005 4t RECEIVED ~ APR 14 2004 AI.,,!.-. Qil & Gas Cons.. Commi~nn ExploratoryU Develop~lI'~ Multiple Zone U Service 0 Development Gas 0 AnChOra~gle Zone 0 5. Bond: W Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 2N-311 6. Proposed Depth: 12. Field/Pool(s): MD: 8468' TVD: 5474' Kuparuk River Field 11 b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 27' FNL, 617' FEL, Sec. 3, T9N, R7E, UM ,/ Top of Productive Horizon: 313' FSL, 332' FWL, Sec. 26, T10N, R7E, UM Total Depth: 539' FSL, 370' FWL, Sec. 26, T10N, R7E, UM " 4b. Location of Well (State Base Plane Coordinates): / Surface: x- 460976 16. Deviated wells: Kickoff depth: 300 . 18. Casing Program Size Hole 42" 12 1/4" 81/2" 81/2" Casing 16" 9 5/8" 5.5" 3.5" 19 Total Depth MD (It): Casing Structural Conductor Detailed Operations Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee 0 Property Plat 0 y- 5911981 ft. Maximum Hole Angle: Weight 62.5# 40# 15.5# 9.3# Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTCM L-80 EUE8RD 7. Property DeSig~ation: I / ADL 375074/380054/380053 8. Land Use Permit: L31961/32027/32026 9. Acres in Property: 2560 10. KB Elevation / / Zone- 4 150' AMSL feet 17. Anticipated Pressure (see 20 MC 25.035) Max. Downhole Pressure: 3000 psig Setting Depth 57.69° Top Bottom Length MD TVD MD TVD 120 30.3' 30.3' 150' 150' 2958 30.3' 30.3' 2988 2400 7914 30.3' 30.3' 7944 5104 524 7944 5104 8468 5474 PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Length Size BOP Sketch 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: Tarn Oil Pool 13. Approximate Spud Date: 5/11/2004 14. Distance to Nearest Property: 27' @ Surface 15. Distance to Nearest Well within Pool: 2N-307, 1730 /' I Max. Surface Pressure: 2456 psig Quantity of Cement c. f. or sacks (including stage data) Artic Set I 277 sx ASL & 331 sx LiteCRETE 393 sx GasBLOK Included above (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD IPerfOration Depth TVD (ft): Drilling Program ~ Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: Printed Name 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 Contact Philip Hayden 265-6481 Title Kuparuk Drilling Team Leader Phone ZbS' f,<Ø 3ò Date '-{llvlor Preoared bv Phi/io Havden R. Thomas ~~~ Commission Use Only Permit to Drill , / A/ I API Number: I //J I Permit Approval Number: ;:2..0~:3 50-/03....2DïïY'-DD Date: f/;)-t/plf Conditions of approval: Sampl s required ld Yes ~ No Mud log required H 09 n sulfide measures ~ Yes tJ No Directional survey required Signature Other: ~ \ ""-.\.\. ""-' ~ \> -\<t ~ \- , Form 10-401 Revised 3/2003 . COMMISSIONER ORIGINAL BY ORDER OF THE COMMISSION Isee cover letter for other requirements Jd Yes I}š. No .Þ't Yes tr No ,., D,.¡f¥f Submit in duplicate · .PPlication for Permit to Drill, Well 2N-311 Revision No.O Saved: 14-Apr-04 Permit It - Tarn Well #2N-311 Application for Permit to Drill Document M(Jximiz'; W~II I/Qlue Table of Contents 1. Well Name..... .............. ..... ......... ............ ..,................. ........ ................. ............ ............ 2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Summary......... ...... ............. ....... ........... ...... .... ........ ....... ...................... ...... 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. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 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 uid Program .... ........ ............ .......... .............. .... ..... ..................... ........ ....... 4 Requirements of 20 MC 25.005(c)(B) . ....................... ................ ................... ................... ............... ...... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 4 Production Hole Mud Program (LSND) .................................................................................................. 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 1 O. Seismic Analysis ....... ..... ........ ............. ........ ............ ............. .................... ......... ....... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bonding ...............................................................................................5 ORIGINAL 2N-311 PERMIT IT. doc Page 1 of 7 Printed: 14-Apr-04 · .PPlication for Permit to Drill, Well 2N-311 Revision No.O Saved: 14-Apr-04 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................5 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................6 15. Attachments .................... ........"". ......."". ........""". I'll'. "I'. .....""" ....... ......." ..."" ............" ......"." 7 Attachment 1 Directional Plan (17 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 branchef:,~ each branch must similarly 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 2N-311. 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 already on file with the commission and identified in the application: {2j 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 eacl¡ objective formation, and at total depth, referenced to governmental 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; Location at Surface NGS Coordinates Northings: 5,911,981 Eastings: 460,976 27' FNL, 617' FEL, Section 3, T9N, R7E, UM I RKB Elevation I 150' AMSL Pad Elevation 120' AMSL Location at Top of Productive Interval (Bermuda Sand) NGS Coordinates Northings: 5,917,595 313' FSL, 332' FWL, Section 26, Tl0N, R7E, UM Eastings: 461,946 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8,144 5,245 5,095 Location at Total Depth NGS Coordinates Northings: 5,917,821 Eastings: 461,985 539' FSL, 370' FWL, Section 26, nON, R7E, UM Measured Depth, RKB: 8,468 Total Vertical Depth, RKB: 5,474 Total Vertical Depth, 55: 5,324 and ORIGINAL 2N-311 PERMIT IT. doc Page2of7 Printed: 14-Apr-04 · .PPlication for Permit to Drill, Well 2N-311 Revision No.O Saved: 14-Apr-Q4 (D) other Information required by 20 MC 25.050{b),· Requirements of 20 AAC 25.050(b) If a well Is to be Intentionally deviatect the application for a Permit to Drill (Form 10-401) must (1) Include a plat; drawn to a suitable scale, showing the path of the proposed wellbore, including a/l adjacent wellbores within 200 feet ol any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (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 (B) state that the applicant I.., 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 DJiIl must be aŒompanied by each of the following Item!>~ except for an Item already 017 file with the commission and identified in the application: (3) a diagram and description ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 MC 25.036; or 20 MC 25.03~ as appllcable/ An API 11" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 2N-311. Please see information on the Nordic Rig 3 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 PemJlt 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 (liilling hazards, including (A) the maximum downhole pressure that may be encountere~ criteria used to determine it and maximum potential surface pressure based on a methane gradient/ The expected reservoir pressures in the Bermuda sands in the 2N-311 area vary from 0.49 to 0.57 psijft, .I or 9.5 to 11.0 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. 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 2456 psi, calculated as follows: MPSP =(5340 ft)(0.57 - 0.11 psijft) =2456 psi I (8) data on potential gas zones; No potential gas zones are expected. and (C) data concerning potential causes ol hole problems such a8 abnormally gee-pressured strata, 108t 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 Dnll must be accompanied by each of the following items, except for an item already on file witt¡ the commission and Identified in the application: (5) a description of the procedure for conducting formation integJity test~ as required under 20 MC 25. 030(f}/ ORIGINAL 2N-311 PERMIT IT. doc Page 3 of 7 Printed: 14-Apr-04 · .PPlication for Permit to Drill, Well 2N-311 Revision No.O Saved: 14-Apr-04 2N-3ll 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 Pemlit to Drill must be accompanied by each of the following item~ 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 25.034 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 Hole Top 8tm CsglTbg Size Weight Length MOffVO MOffVO 00 (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) 16 42 62.5 H-40 Welded 120 30.3 / 30.3 150 / 150 9 5/8 12 V4" 40 L-80 BTC 2958 30.3 / 30.3 2988 / 2400 3 V2 8 V2 9.3 L-80 EUE8RD Mod 524 30.3 / 30.3 7944/ 5104 Cement Program Cement to surface ArticSet I Cement to Surface with 277 sx ASLite Lead, 331 sx LiteCRETE Tail 7944/ 5104 Cement Top planned @ 8468 / 5474 7572' MD/ 4859' WD. Cemented w/ 393 sx GasBLOK 5 V2 8 V2 15.5 L-80 BTCM 7914 7. Diverter System Information Requirements of 20 AAC 25.005(c}(7) An application for a Permtt to Drill must be accompanied by each of the following Item~ 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 AAC 25.035(h)(2); A 21 V4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 2N-311. Please see diagrams of the Nordic 3 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 following item~ except for an item already on file wIth the commission and identified in the application: (8) a drilllilg fluid program, including a diagram and description of the dnlling 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 Density (ppg) Funnel Viscosity Initial Value 8.6 250 Final Value ~9.2 250 Base of Permafrost to 95/8/' Casing Point Initial Value Final Value ~9.2* 9.6 150-200 55-65 ,/ ORIGINAL 2N-311 PERMIT IT. doc Page 4 of 7 Printed: 14-Apr-04 · .PPlication for Permit to Drill, Well 2N-311 Revision No.O Saved: 14-Apr-04 (seconds) Yield Point 35-45 35-45 30-35 12-15 (eP) pH 9-9.5 9-9.5 9-9.5 9-9.5 ,/ API Filtrate 6 6 4-6 4-6 (ee /30 min)} Chlorides (mg/I) <600 <600 <600 <600 *9.6 ppg if hydrates are encountered Production Hole Mud Program (LSND) Density (ppg) Yield Point (eP) pH API Filtrate (ee /30 min)} HTHP @ 1Srf (ee}) 95/8" Casin,q Shoe to TO Initial Value Final Value 9.8 10.3 22-28 10-15 ,/ 9-9.5 4-6 <12 9-9.5 4-5 <12 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 Nordic Rig 3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application fòr a Permit to On/I must be accompanied by each of the following item~ except for an item already on file wIth the commission and Identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.0J3(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 Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (10) for an exploratOlY or stratigraphic test wel¿ 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. 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 Item~ except for an Item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platfom7, mobile bottom-founded structur~ jack-up rig, or ffoating drilling vesse¿ 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 Item~ 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. ORIGINAL 2N-311 PERMIT IT. doc Page 5 of 7 Printed: 14-Apr-04 · .PPlication for Permit to Drill, Well 2N-311 Revision No.O Saved: 14-Apr-Q4 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each or the following items, except for an item already on file with the mmmission 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 Nordic Rig 3. Install 21 1f4" Annular with 16" diverter line and function test (conductor will have been installed and cemented). 2. Spud and directionally drill 12 1f4" hole to casing point at 2988' MD / 2400' 1VD as per directional plan. Run MWD tools as required for directional monitoring. 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. Install and test 11" 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 3J4" drilling assembly, with MWD and LWD (GR, resistivity & neutron density). 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 'h" x 3 V2" casing point at 8468' MD / 5474' 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. 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. 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 AAC 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 or how the operator plans to dispose or drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 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 2N 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 2N 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. ORIGINAL 2N-311 PERMIT IT. doc Page 6 of 7 Printed: 14-Apr-04 · .PPlication for Permit to Drill, Well 2N-311 Revision No.O Saved: 14-Apr-04 At the end of drilling operations, an application may be submitted to permit 2N-311 for annular disposal of fluids occurring as a result of future drilling operations on 2N pad. 15. Attachments Attachment 1 Directional Plan (17 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematics (1 page) ORIGINAL 2N-311 PERMIT IT. doc Page 7 of 7 Printed: 14-Apr-04 "" 0 -500 Ii) N II E () -0 ~ m () (/) 500 1000 1500 - - ~ 2000 - - - .s::. ã. 2500 - () C ns 3000 (.) t () > 3500 () :J '- I- 4000 . V 4500 5000 5500 6000 6500 . . ilia. ~ ConocoPhillips Alaska, Inc. Slot: Well: Well bore: ConocJPhillips Location: North Slope, Alaska Field: Tarn Installation: Pad 2N slot #311 311 311 ___~T~___ IN'mQ Created by : Planner Date plolled: S-Apr-2004 Plot reference is 311. Refwellpath is 2N-311 Ver#1.A. Coordinates are in feet reference slot #311, True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 150.00 ft/ Plot North is aligned to TRUE North. WELL PROFILE DATA Point MD Inc Azi TVD North East de9/100ft V. Sect 0.00 0.00 000 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 800.00 10.00 9.50 797.47 42.93 7.18 2.00 43.52 2389.71 57.69 9.51 2080.00 891.18 149.21 3.00 903.58 7316.03 57.69 9.51 4713,03 4997.64 836,83 0.00 5067.22 7950.59 45.00 9.50 5108.58 5485.38 918.48 2.00 5561,75 8143.52 45.00 9.50 5245.00 5619.93 940.99 0.00 5698.17 8467.87 45.00 9.50 5474.35 5846.14 978.85 0.00 5927.52 Tie on End of Hold KOP End of BuildlTurn iRKS Elevation: 150' End of Hold End of DroplTurn KOP 4.00 8.00 Build 3/100 16.00 22.00 Base Permafrost Top West Sak DLS: 3.00 deg/100ft Target 2N-311 Top Berm T.D. & End of Hold Drop 2/100 54.01 T7 48.01 ~~ 1:À{f~8'f5bng 51/2 x 3 1/2 XO T3 (Top Bermuda Target) "T4¡¿ '-.\"<7 5 (K3) Þ311 TO - 500 -0 500 Scale 1 cm = 250 ft 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 Vertical Section (feet) -> Azimuth 9Ö w~ rGTKfÄ' CO E from slot #311 Rii. aa.u (NTRQ . ConocoPhillips Alaska, Inc. Slot: Well: Well bore: Location: North Slope, Alaska Field: Tarn Installation: Pad 2N slot #311 311 311 Scale 1 em = 200 ft -400 0 400 East (feet) -> 800 1200 1600 2000 2400 I TO LOCATION: I 539' FSL, 370' FWL SEC. 26, T10N, R7E ~11 ~5(K3) . T2 2N-311 Top Bermuda Tgt RVSD 18 Mar 04 -: fJYop Bennuda Target) 5 1/2in Casing rr êri{fó'fDYðpXO . T7 I TARGET LOCATION: I 313' FSL, 332' FWL . Drop 2/100 SEC. 26, T10N, R7E C37 C40 (K5) C50 cao (K10) 9 5/8in Casing EOC Base West Sak Top West Sak Base Permafrost Build 3/100 KOP ESTIMATED SURFACE LOCATION: 27' FNL. 617' FEL .I SEC. 3. T9N, R7E ORIGINAL . ConocJí'hillips Created by: Planner Date plorted : 2-Apr-2004 Plot reference is 311. Refwellpath is 2N-311 Ver#1 A Coordinates are in feet reference slot #311. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 150.00 ft. Plot North is aligned to TRUE North. 2800 - 6400 - 6000 - 5600 - 5200 - 4800 - 4400 - 4000 - 3600 ^ I - 3200 Z 0 ;:¡ ::J" - 2800 ;; () .... - - 2400 - 2000 - 1600 - 1200 800 400 (J) () Q) ãJ 0 () 3 II - -400 "-> 0 0 ;::I> location: North Slope, Alaska Field: Tarn Installation: Pad 2N ConocoPhillips Alaska., Inc. Slot: slot #311 Well: 311 Welibore: 311 ~/ ConocoPhimps Created Planner Date 5~Apr~2004 Plot reference is 311 , is 2N~311 Ver#1 A feet reference slot #311. reference Datum reference Rig Rig Datum: Datum Rig Datum to mean sea level: 150.00 ft. Plot North is aligned to TRUE North. 350 TRUE NORTH o ~'0 \ 20 \ 3600 30 340 330 320 40 310 50 ~ '" C~~~ 290~, ~'" 60 70 90 110 210 200 \t 60 190 180 170 \ Noem" R,,, 1m"'''"9 C"mde;" F'~ All depths shown are Measured depths on Reference Well Location: North Slope, Alaska Field: Tarn Installation: Pad 2N ConocoPhillips Alaska, Inc. Slot: slot #311 Well: 311 Wellbore: 311 Con Scale 1 em = 10 ft -140 -120 -100 -80 Planner Q-Apr-2004 Plot reference is 311. is 2N-311 Ver#1 A feet reference slot #311. True Vertical Datum Measured reference Rig Rig Datum: Planned Datum Rig Datum to mean sea level: 150.00 ft. Plot North is aligned to TRUE North. <- West (feet): East (feet) -> -60 -40 -20 0 20 40 60 140 240 1200 220 200 1600 180 160 ^ . 140 120 100 80 800 TVD 60 40 400 TVD l~= 20 11:r7 0 (j) 0 I)) -20 ill 0 3 -40 II 0 ;::Þ , ~~4 80 100 120 320 300 280 260 TVD ConocoPhillips Alaska., Inc.. Alaska Field: Tarn Installation: Pad 2N Scale 1 em = 10 ft -60 -40 -20 -0 2000 TVD 1900 TVD Well: Well bore: ~/ ConocoPhillips Planner Ref well path is 2N-311 Ver#1 A Coordînates are in feet reference slot #311. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planneq Datum Rig Datum to mean sea level: 150.00 ft. Plot North is aligned to TRUE North. 20 East (feet) -> 40 60 80 100 120 140 160 180 200 1700 TVD 1800 TVD I í 1/\ ¡t-'¡ M1 -.1 I I (~ (;:/ hi r .J I i ! 600 580 560 I I I 1800 TVD ¡ 540 I I 520 1600 TVD 1900 TVD TVD I i I I 1800 TVD 1300 1500 TVD 1400 TVD 1 300 TVD &f;' I &f;) ~,/ 500 480 460 ^ 440 · z o ;¡ 420 .a: ø' m 400~ 380 360 340 320 300 en () ID 280 ro ->. () 3 260 II ->. 0 240 ;::þ I ConocoPhillips Alaska, Inc.. c slot#311 Well: 311 Wellbore: 311 Field: Tarn Installation: Pad 2N Scale 1 em = 50 ft -500 -400 -300 -200 -100 o East (1Feet) -> 1 00 200 300 3000 TVO 2900 TVO 2800 TVO 2700 TVO 2700 TVO ! 2600 TVO / 2600 TVO 2500 TVd ! ! 2300 TVO 2400 TVd ! / 1 ! / 2300 T'Ì/O ! I 2100 TVO 1 22do 2300 TVO 2500 TVO 2000 TVO 1900 TVO created by' Planner Date plotted. 5-Apr-2004 . Þlot¡:eference is 311 . Ref well path is 2N_311 Ver#1 A Coordinates are in feet reference slot #311 , True Vertical Depths are reference Rig Datum Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 150.00 ft Plot North is aligned to TRUE North. 400 500 600 700 800 900 2300 TVO ~ 2400 2300 2200 2100 2000 3400 TVO 1900 3300 TVO 1800 3200 TVO 3100 TVD 1700 ^ 3000 TVD 1600 , 2900 TVO 1500 2800 TVO 1400 1300 1200 2400 TVO 2200 TVO 1100 1000 900 (j) 800 (1 ß) ¡¡¡ (1 700 3 II 01 0 600 ;::¡, I 2200 TVO 2100 TVO ~Î 240~~~/ ~//...// - ¡ L Scale 1 em = 125 ft -750 -500 -250 3800 TVD ~600 \ ~ ConocoPhillips Alaska, Inc. Sio!: slot #311 Well: 311 Weilbore: 311 Cono Location: North Slope, Alaska Field: Tarn Installation: Pad 2N iIIips Planner 5-Apr-2004 is 2N-311 Ver#1 A feet reference slot #311. are reference Datum. Measured reference Rig Rig Datum: Planned Datum Rig Datum to mean sea level: 150.00 ft. Plot North is aligned to TRUE North, - 6000 - 5750 5500 - 5250 - 5000 - 4750 - 4500 - 4250 ^ . 3800 TVD - - 4000 - 3750 - 3500 - 3250 - 3000 - 2750 - 2500 - 2250 (j) (') ro ro - 2000 (') 3 II - 1750 N 01 :=Þ -0 East (feet) -> 500 750 1000 1250 1500 1750 2000 2250 2500 250 5200 TVD 5000 TVD 4800 TVD 4600 TVD 4400 TVD 4200 TVD 4000 TVD 3800 TVD 3600 TVD 3600 TVD 3400 TVD 6250 . . conocd>hillips ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 1 Wellbore: 311 Wellpath: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 _i. BAKER HUGHES INTEQ Wellbore Name 311 27-Jan-2004 I Last Revised 2-Apr-2004 Well Name 311 I Govemment 10 I Last Revised 27-Jan-2004 Name slot #311 I Grid NorthinQ 5911980.5571 I Grid EastinQ 460976.1391 I Latitude N70 10 13.7000 I LonQitude W150 · 18 50.6500 I North 25.90S lEast 617.11W Installation Name Pad 2N I Eastina j Northinol Coord SYStem Name I North Alianment 461593.315 5912003.323 AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name Tarn I EastinQ · 461651.5943 I Northino 5927841.6325 I Coord Svstem Name I North Alionment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated f·~!GINAL · - conoc~illipS ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 2 Well bore: 311 Well path: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 Ri. BAKER HUGHU INTEQ Wellpath (Grid & LatlL()n~l Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Northing Easting Latitude Longitude Vertical Sectionrftl 0.00 0.00 0.00 0.00 5911980.56 460976.14 N70 10 13.7000 W150 18 50.6500 0.00 100.00 0.00 0.00 100.00 5911980.56 460976.14 N70 10 13.7000 W150 18 50.6500 0.00 200.00 0.00 0.00 200.00 5911980.56 460976.14 N70 10 13.7000 W150 18 50.6500 0.00 300.00 0.00 0.00 300.00 5911980.56 460976.14 N70 10 13.7000 W150 18 50.6500 0.00 400.00 2.00 9.50 399.98 591198228 460976.44 N70 10 13.7169 W150 18 50.6416 1.75 500.00 4.00 9.50 499.84 5911987.43 460977.33 N70 10 13.7677 W150 18 50.6166 6.98 600.00 6.00 9.50 599.45 5911996.02 460978.81 N70 10 13.8522 W150 18 50.5749 15.69 700.00 8.00 9.50 698.70 5912008.03 460980.88 N70 10 13.9705 W150 18 50.5167 27.88 800.00 10.00 9.50 797.47 5912023.44 460983.54 N70 10 14.1222 W150 18 50.4419 43.52 900.00 13.00 9.50 895.45 5912043.08 460986.93 N70 10 14.3156 W150 18 50.3465 63.46 1000.00 16.00 9.50 992.25 5912067.75 460991 .19 N70 10 14.5584 W150 18 50.2268 88.49 1100.00 19.00 9.50 1087.61 5912097.38 460996.31 N70 10 14.8501 W150 18 50.0830 118.56 1200.00 22.00 9.50 1181.27 5912131.88 46100227 N70 10 15.1897 W150 18 49.9155 153.58 1300.00 25.00 9.50 1272.96 5912171.16 461009.05 N70 10 15.5765 W150 18 49.7248 193.45 1400.00 28.00 9.50 1362.45 5912215.12 461016.65 N70 10 16.0092 W150 18 49.5113 238.06 1500.00 3100 9.50 1449.47 5912263.64 461025.03 N70 10 16.4868 W150 18 49.2758 287.30 1600.00 34.00 9,50 1533.80 5912316.57 461034.17 N7D 10 17.0080 W150 18 49.0188 341.02 1700.00 37.00 9.51 1615.20 5912373.78 461044.05 N70 10 17.5712 W150 18 48.7410 399.09 1800.00 40.00 9.51 1693.46 5912435.11 461054.65 N70 10 18.1749 W150 18 48.4431 461.33 1900.00 43.00 9.51 1768.34 5912500.39 461065.92 N70 10 18.8176 W150 18 48.1261 527.58 2000.00 46.00 9.51 1839.66 5912569.44 461077.85 N70 10 19.4974 W150 18 47.7908 597.67 2100.00 4900 9.51 1907.21 5912642.08 461090.40 N70 10 20.2125 W150 18 47.4380 671.39 2200.00 52.00 9.51 1970.81 5912718.10 461103.53 N70 10 20.9609 W150 18 47.0688 748.54 2300.00 55.00 9.51 2030.29 5912797.30 461117.21 N70 10 21.7405 W150 18 46.6842 828.92 2389.71 57.69 9.51 2080.00 5912870.86 461129.92 N70 10 22.4648 W150 18 46.3269 903.58 2400.00 57.69 9.51 2085.50 5912879.44 461131.40 N70 10 22.5492 W150 18 46.2853 912.28 2500.00 57.69 9.51 2138.95 5912962.71 461145.79 N70 10 23.3690 W150 18 45.8808 996.80 2600.00 57.69 9.51 2192.39 5913045.99 461160.18 N70 10 24.1888 W150 18 45.4763 1081.32 2700.00 57.69 9.51 2245.84 5913129.26 461174.56 N70 10 25.0086 W150 18 45.0718 1165.84 2800.00 57.69 9.51 2299.29 5913212.54 461188.95 N70 10 25.8285 W150 18 44.6673 1250.35 2900.00 57.69 9.51 2352.74 5913295.82 461203.34 N70 10 26.6483 W150 18 44.2628 1334.87 3000.00 57.69 9.51 2406.19 5913379.09 461217.72 N70 10 27.4681 W150 18 43.8583 1419.39 3100.00 57.69 9.51 2459.64 5913462.37 461232.11 N70 10 28.2879 W150 18 43.4538 1503.91 3200.00 57.69 9.51 2513.08 5913545.64 461246.49 N70 10 29.1078 W150 18 43.0493 1588.43 3300.00 57.69 9.51 2566.53 5913628.92 461260.88 N70 10 29.9276 W150 18 42.6447 1672.94 3400.00 57.69 9.51 2619.98 5913712.20 461275.27 N70 10 30.7474 W150 18 42.2402 1757.46 3500.00 57.69 9.51 2673.43 5913795.47 461289.65 N70 10 31.5672 W150 18 41.8356 1841.98 3600.00 57.69 9.51 2726.88 5913878.75 461304.04 N70 10 32.3870 W150 1841.4311 1926.50 3700.00 57.69 9.51 2780.32 5913962.02 461318.43 N70 10 33.2069 W150 18 41.0265 2011.02 3800.00 57.69 9.51 2833.77 5914045.30 461332.81 N70 10 34.0267 W150 18 40.6219 2095.53 3900.00 57.69 9.51 2887.22 5914128.58 461347.20 N70 10 34.8465 W150 18 40.2173 2180.05 4000.00 57.69 9.51 2940.67 5914211.85 461361.58 N70 10 35.6663 W150 18 39.8127 2264.57 4100.00 57.69 9.51 2994.12 5914295.13 461375.97 N70 10 36.4861 W150 18 39.4081 2349.09 4200.00 57.69 9.51 3047.57 5914378.40 461390.36 N70 10 37.3060 W150 1.8 391)035 2433.61 4300.00 57.69 9.51 3101.01 5914461.68 461404.74 N70 10 38.1258 W150 18 38.5988 2518.12 4400.00 57.69 9.51 3154.46 5914544.96 461419.13 N70 10 38.9456 W150 18 38.1942 2602.64 4500.00 57.69 9.51 3207.91 5914628.23 461433.52 N70 10 39.7654 W150 18 37.7896 2687.16 4600.00 57.69 9.51 3261.36 5914711.51 461447.90 N70 10 40.5852 W150 18 37.3849 2771.68 4700.00 5769 9.51 3314.81 5914794.79 461462.29 N70 10 41.4051 W150 18 36.9802 2856.20 4800.00 57.69 9.51 3368.26 5914878.06 461476.68 N70 10 42.2249 W150 18 36.5756 2940.71 4900.00 57.69 9.51 3421.70 5914961.34 461491.06 N70 10 43.0447 W150 18 36.1709 3025.23 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Of<IGINAL · e Conoc6Phillips ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 3 Wellbore: 311 Wellpath: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 .¡. BAKER HUGHES INTEQ Wellpath {Grid & LatlLonç ) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Northing Easting Latitude Longitude Vertical Section[ft] 5000.00 57.69 9.51 3475.15 5915044.61 461505.45 N70 10 43.8645 W150 18 35.7662 3109.75 5100.00 57.69 9.51 3528.60 5915127.89 461519.83 N70 10 44.6843 W150 18 35.3615 3194.27 5200.00 57.69 9.51 3582.05 5915211.17 461534.22 N70 10 45.5041 W150 18 34.9568 3278.79 5300.00 57.69 9.51 3635.50 5915294.44 461548.61 N70 10 46.3240 W150 18 34.5521 3363.30 5400.00 57.69 9.51 3688.95 5915377.72 461562.99 N70 10 47.1438 W150 18 34.1473 3447.82 5500.00 57.69 9.51 3742.39 5915460.99 461577.38 N70 10 47.9636 W150 18 33.7426 3532.34 5600.00 57.69 9.51 3795.84 5915544.27 461591 .77 N70 10 48.7834 W150 18 33.3378 3616.86 5700.00 57.69 9.51 3849.29 5915627.55 461606.15 N70 10 49.6032 W150 18 32.9331 3701.38 5800.00 57.69 9.51 3902.74 5915710.82 461620.54 N70 10 50.4230 W150 18 32.5283 3785.90 5900.00 57.69 9.51 3956.19 5915794.10 461634.92 N70 10 51.2428 W150 18 32.1236 3870.41 6000.00 57.69 9.51 4009.64 5915877.37 461649.31 N70 10 52.0627 W150 18 31.7188 3954.93 6100.00 57.69 9.51 4063.08 5915960.65 461663.70 N70 10 52.8825 W150 18 31.3140 4039.45 6200.00 57.69 9.51 4116.53 5916043.93 461678.08 N70 10 53.7023 W150 18 30.9092 4123.97 6300.00 57.69 9.51 4169.98 5916127.20 461692.47 N70 10 54.5221 W150 18 30.5044 4208.49 6400.00 57.69 9.51 4223.43 5916210.48 461706.86 N70 10 55.3419 W150 18 30.0996 4293.00 6500.00 57.69 .9.51 4276.88 5916293.75 461721.24 N70 10 56.1617 W150 18 29.6947 4377.52 6600.00 57.69 9.51 4330.32 5916377.03 461735ß3 N70 10 56.9815 W150 18 29.2899 4462.04 6700.00 57.69 9.51 4383.77 5916460.31 461750.01 N70 10 57.8014 W150 18 28.8851 4546.56 6800.00 57.69 9.51 4437.22 5916543.58 461764.40 N70 10 58.6212 W150 18 28.4802 4631.08 6900.00 57.69 9.51 4490.67 5916626.86 461778.79 N70 10 59.4410 W150 18 28.0753 4715.59 7000.00 57.69 9.51 4544.12 5916710.14 461793.17 N70 11 0.2608 W150 18 27.6705 4800.11 7100.00 57.69 9.51 4597.57 5916793.41 461807.56 N70 11 1.0806 W150 18 27.2656 4884.63 7200.00 57.69 9.51 4651.01 5916876.69 461821.95 N70 11 1 .9004 W150 18 26.8607 4969.15 7300.00 57.69 9.51 4704.46 5916959.96 461836.33 N70 11 2.7202 W150 18 26.4558 5053.67 7316.03 57.69 9.51 4713.03 5916973.31 461838.64 N70 11 2.8516 W150 18 26.3909 5067.22 7400.00 56.01 9.51 4758.94 5917042.58 461850.60 N70 11 3.5336 W150 18 26.0541 5137.52 7500.00 54.01 9.50 4816.28 5917123.30 461864.55 N70 11 4.3282 W150 18 25.6617 5219.44 7600.00 52.01 9.50 4876.44 5917202.00 461878.14 N70 11 5.1 029 W150 18 252791 5299.31 7700.00 50.01 9.50 4939.36 5917278.58 461891.37 N70 11 5.8568 W150 18 24.9068 5377.03 7800.00 48.01 9.50 5004.94 5917352.95 461904.21 N70 11 6.5890 W150 18 24.5453 5452.52 7900.00 46.01 9.50 5073.13 5917425.03 461916.65 N70 11 7.2985 W150 18 24.1950 5525.66 7950.59 45.00 9.50 5108.58 5917460.58 461922.79 N70 11 7.6485 W150 18 24.0222 5561.75 8000.00 45.00 9.50 5143.52 5917495.01 461928.74 N70 11 7.9875 W150 18 23.8549 5596.69 8100.00 45.00 9.50 5214.23 5917564.68 461940.77 N70 11 8.6733 W150 18 23.5164 5667.40 8143.52 45.00 9.50 5245.00 5917595.00 461946.00 N70 11 8.9718 W150 18 23.3690 5698.17 8200.00 45.00 9.50 5284.94 5917634.35 461952.79 N70 11 9.3592 W150 18 23.1777 5738.11 8300.00 45.00 9.50 5355.65 5917704.03 461964.82 N70 11 10.0451 W150 18 22.8391 5808.82 8400.00 45.00 9.50 5426.36 5917773.70 461976.85 N70 11 10.7310 W150 18 22.5005 5879.53 8467.87 45.00 9.50 5474.35 5917820.99 461985.02 N70 11 11.1965 W150 18 22.2707 5927.52 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O,OOE on azimuth 9.51 degrees Bottom hole distance is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAl · e ....' ConocoPhillips ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 4 Well bore: 311 Well path: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 .¡. BAKER HUGHES INTEQ Comments MDrftl TVorm Northrftl Eastf ft 1 Comment 300.00 300.00 O.OON O.OOE KOF 800.00 797.47 42.93N 7.18E Build 3/100 1220.25 1200.00 159.05N 26.62E Base Permafrost 1274.74 1250.00 180.41 N 30.20E Top West Sak 2132.00 1928.00 686.16N 114.88E Base West Sak 2389.71 2080.00 891.18N 149.21 E EOC 2988.42 2400.00 1390.25N 232.78E 9 5/8 CSG 3128.75 2475.00 1507.22N 252.36E C80 (K1Q) 5589.07 3790.00 3558.09N 595.78E C50 6094.23 4060.00 3979.18N 666.29E C40 (K5) 6515.20 428500 4330.09N 725.05E C37 7316.03 4713.03 4997.64N 836.83E DroD 2/100 7573.12 4860.00 5205.58N 871.64E T7 7943.52 5103.5B 5480.45N 917.65E 51/2x31l2XO 7950.59 5108.58 5485.38N 918.48E End of DroD 8072.81 5195.00 5570.62N 932.74E T4.1 8143.52 5245.00 5619.93N 940.99E T3 (ToD Bermuda Taraet) 8277.87 5340.00 5713.63N 956.67E T2 8398.07 5425.00 5797.46N 970.70E C35 (K3) 8467.87 5474.35 5846.14N 978.85E TO HoleSections Diameter Start Start Start Start End End End Start Wellbore [inl MDlftl TVOlftl Northlftl Eastlftl MDfftl TVDlftl Northlftl Eastlftl 121/4 0.00 0.00 O.OON O.OOE 2988.42 2400.00 1390.25N 232.78E 311 81/2 2988.42 2400.00 1390.25N 232.78E 8467.87 5474.35 5846.14N 978.85E 311 Casinas Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDrftl TV.Drftl Northrftl Eastfftl MDrftl worftl Northrftl EasUftl 9 5/8in Casina 0.00 0.00 O.OON O.OOE 2988,42 2400.00 1390.25N 232.78E 311 5 1/2in Casinq 0.00 0.00 O.OON O.OOE 7943.52 5103.59 5480,45N 917.65E 311 3 1/2in Casina 7943152 5103.59 5480,45N 917.65E 8467.87 5474.35 5846.14N 978.85E 311 Targets Name Northrftl Eastfftl TVOrm 1.atitude Lonaitude Eastina Northina Last Revised 2N-311 Top 5619.93N 940.99E 5245.00 N70 11 8.971f W150 1823.36 461946.00 5917595.00 30-Jan-2004 Bermuda Tgt RVSD 18 Mar 04 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIG!~,JAL . . Conoc~illips ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 1 Wellbore: 311 Wellpath: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 ,&¡. BAKER HUGHES INTEQ Wellbore Name 311 I Created 27-Jan-2004 I Last Revised 2-Apr-2004 Well Name 311 I Last Revised 27-Jan-2004 Slot Name slot #311 I Grid Northinq I Grid EastinQ I Latitude 5911980.5571 '" 460976.1391'/ N70 10 13.7000 W150 18 50.6500 I North 25.90S Eåst 1W Installation Name Pad 2N I Eastino 461593.3157 I Northino 5912003.3237 I Coord Svstem Name North Alionment AK-4 on NORTH AMERICAN DATUM 1927 datum True "..,. Field Name Tarn I Eastino 461651.5943 I Northino 5927841.6325 I Coord Svstem Name INorth Alionment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated nRIGI~\Jff~\ ~"';;" <. \, " \'Q;¡.>'- á ,., ...,,; .-' '. . . ConocJ'Phillips ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 311 Wellpath: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 "~i. BAKER HUGHES INTEQ WeUpath Report MD[ft] Ino[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertioal Station Comment rdeq/100ftl Seotio n 1ft 1 0.00 0.00 0,00 0.00 O.OON O.OOE 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 O.OON O.OOE 0.00 0.00 200.00 0.00 0.00 200.00 O.OON O.OOE 0.00 0.00 300.00 0.00 0.00 300.00 O.OON O.OOE 0.00 0.00 KOP. End of Hold ./ 400.00 2.00 9.50 399.98 1.72N 029E 2.00 1.75 500.00 4.00 9.50 499.84 6.88N U5E 2.00 6.98 600.00 6.00 9.50 599.45 15.48N 2.59E 2.00 15.69 700.00 8.00 9.50 698.70 27.50N 4.60E 2.00 27.88 800.00 10.00 9.50 797.47 42.93N 7.18E 2.00 43.52 Build 3/100, 3DXS Kick off Point 900.00 13.00 9.50 895.45 62.59N 10A7E 3.00 63.46 1000.00 16.00 9.50 992.25 87.28N 14.61E 3.00 88.49 1100.00 19.00 9.50 1087.61 116.93N 19.57E 3.00 118.56 1200.00 22.00 9.50 1181 27 151.47N 25,35E 3.00 153 58 1220.25 22.61 9.50 1200.00 159.05N 26.62E 3.00 161.26 Base Permafrost 1274.74 24.24 9.50 1250.00 180.41N 30.20E 3.00 182.92 Top West Sak 1300.00 25.00 9.50 1272.96 190.79N 31.93E 3.00 193.45 140D.00 28.00 9.50 1362.45 234.79N 39.30E 3.00 238.06 1500.00 31.00 9.50 1449.47 283.36N 47.43E 3.00 287.30 1600.00 34.00 9.50 1533.80 336.34N 56.30E 3.00 341.02 1700.00 37.00 9.51 1615.20 393.61N 65.89E 3.00 399.09 1800.00 40.00 9.51 1693.46 455.00N 76.17E 3.00 461.33 1900.00 43.00 9.51 1768.34 520.34N 87.11 E 3.00 527.58 2000.00 46.00 9.51 1839.66 589.46N 98.69E 3.00 597.67 2100.00 49.00 9.51 1907.21 662.17N 110.86E 3.00 671.39 2132.00 49.96 9.51 1928.00 686.16N 114.88E 3.00 695.71 Base West Sak 2200.00 52.00 9.51 1970.81 738.26N 123.60E 3.00 748.54 2300.00 55.00 9.51 2030.29 817.54N 136.88E 3.00 828.92 ~389.71 57.69 9.51 2080.00 891.18N 149.21E 3.00 903.58 EGC. End of BuildlTum 2400.00 57.69 9.51 ~085.50 899.76N 150.64E 0.00 912.28 2500.00 57.69 9.51 2138.95 983.12N 164.60E 0.00 996.80 2600.00 57.69 9.51 2192.39 1066.47N 178.56E 0.00 1081.32 2700.00 57.69 9.51 2245.84 1149.83N 192.52E 0.00 1165.84 2800.00 57.69 9.51 2299.29 1233.19N 206.47E 0.00 1250.35 2900.00 57.69 9.51 2352.74 1316.55N 220.43E 0.00 1334.87 2988.42 57.69 9.51 2400.00 1390.25N 232.78E 0.00 1409.61 9 5/8 CSG 3000.00 57.69 9.51 2406.19 1399.90N 234.39E 0.00 1419.39 3100.00 57.69 9.E1 2459.64 1483.26N 248.35E 0.00 1503.91 3128.75 57.69 9.51 2475.00 1507.22N 252.36E 0.00 1528.20 C801K1Q) 3200.00 57.69 9.51 2513.08 1566.62N 262.31 E 0.00 1588.43 3300.00 57.69 9.51 2566.53 1649.97N 27627E 0.00 167/.94 3400.00 57.69 9.51 2619.98 1733.33N 290.22E 0.00 1757.46 3500.00 57.69 9.51 2673.43 1816.69N 304.18E 0.00 1841.98 3600.00 57.69 9.51 2726.88 1900.05N 318.14E 0.00 1926.50 3700.00 57.69 9.51 2780.32 1983.41N 332.10E 0.00 2011,02 3800.00 57.69 9.51 2833.77 2066.76N 346.06E 0.00 2095.53 3900.00 57.69 9.51 2887.22 2150.12N 360.01E 0.00 2180.05 4000.00 57.69 9.51 2940.67 2233.48N 373.97E 0.00 2264.57 4100.00 57.69 9.51 2994.12 2316.84N 387.93E 0.00 2349.09 4200.00 57.69 9.51 3047.57 2400.19N 401.89E 0.00 2433.61 4300.00 57.69 9.51 3101.01 2483.55N 415.85E 0.00 2518.12 4400.00 57.69 9.51 3154.46 2566.91 N 429.81 E 0.00 2602.64 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distanoe is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Inoorporated nR' u IGINAL . . Conocó'Phillips ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 3 Wellbore: 311 Wellpath: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 Hi. BAKER HUGHES INTEQ WellpathReport MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Station Comment fdeq/100ftl Sectìonfftl 4500.00 57.69 9.51 3207.91 2650.26N 443.76E 0.00 2687.16 4600.00 57.69 9.51 3261.36 2733.62N 457.72E 0.00 2771.68 4700.00 57.69 9.51 3314.81 2816.98N 471.68E 0.00 2856.20 4800.00 57.69 9.51 3368.26 2900.34N 485.64E 0.00 2940.71 4900.00 57.69 9.51 3421.70 2983.70N 499.60E 0.00 3025.23 5000.00 57.69 9.51 3475.15 3067.05N 513.55E 0.00 3109.75 5100.00 57.69 9.51 3528.60 3150.41N 527.51E 0.00 3194.27 5200.00 57.69 9.51 3582.05 3233.77N 541.47E 0.00 3278.79 5300.00 57.69 9.51 3635.50 3317.13N 555.43E 0.00 3363.30 5400.00 57.69 9.51 3688.95 3400.48N 569.39E 0.00 3447.82 5500.00 57.69 9.51 3742.39 3483.84N 583.34E 0.00 3532.34 5589.07 57.69 9.51 3790.00 3558.09N 595.78E 0.00 3607.62 C50 5£00.00 57.69 9.51 3795.84 356720N 597.3OE 0.00 3616.86 5700.00 57.69 9.51 3849.29 3650.55N 611.26E 0.00 3701.38 5800.00 57.69 9.51 3902.74 3733.91 N 625.22E 0.00 3785.90 5900.00 57.69 9.51 3956.19 3817.27N 639.18E 0.00 3870.41 6000.00 57.69 9.51 4009.64 3900.63N 653.13E 0.00 3954.93 6094.23 57.69 9.51 4060.00 3979.18N 666.29E 0.00 4034.57 C40 (K5) 6100.00 57.69 9.51 4063.08 3983.99N 667.09E 0.00 4039.45 6200.00 57.69 9.51 4116.53 4067.34N 681.05E 0.00 4123.97 6300.00 57.69 9.51 4169.98 4150.70N 695.01E 0.00 4208.49 6400.00 57.69 9.51 4223.43 4234.06N 708.97E 0.00 4293.00 6500.00 57.69 9.51 4276.88 4317.42N 722.92E 0.00 4377.52 6515.20 57.69 9.51 4285.00 4330.09N 725.05E 0.00 4390.37 C37 6600.00 57.69 9.51 4330.32 4400.77N 736.88E 0.00 4462.04 6700.00 57.69 9.51 4383.77 4484.13N 750.84E 0.00 4546.56 6800.00 57.69 9.51 4437.22 4567.49N 764.80E 0.00 4631.08 6900.00 57.69 9.51 4490.67 4650.85N 778.76E 0.00 4715.59 7000.00 57.69 9.51 4544.12 4734.20N 792.72E 0.00 4800.11 7100.00 57.69 9.51 4597.57 4817.56N 806.67E 0.00 4884.63 7200.00 57.69 9.51 4651 .01 4900.92N 820.63E 0.00 4969.15 7300.00 57.69 9.51 4704.46 4984.28N 834.59E 0.00 5053.67 7316.03 57.69 9.51 4713.03 4997.64N 836.83E 0.00 5067.22 Drop 2/100, End of Hold 7400.00 56.01 9.51 4758.94 5066.97N 848.44E 2.00 5137.52 7500.00 54.01 9.50 4816.28 5147.77N 861.97E 2.00 5219.44 7573.12 52.55 9.50 4860.00 5205.58N 871.64E 2.00 5278.05 T7 7600.00 52.01 9.50 4876.44 5226.55N 875.15E 2.00 5299.31 7700.00 50.01 9.50 4939.36 5303.20N 887.99E 2.00 5377.03 7800.00 48.01 9.50 5004.94 5377.65N 900.45E 2.00 5452.52 7900.00 46.01 9.50 5073.13 5449.79N 912.52E 2.00 5525.66 7943.52 45.14 9.50 5103.59 5480.45N 917.65E 2.00 5556.74 5112 x 3112 XO. 5 1/2in Casina 7950.59 45.00 9.50 5108.58 5485.38N 918.48E 2.00 5561.75 End of Drop, End of DroplTurn 8000.00 45.00 i).50 5143.52 5519.84N 924.24E 0.00 5596.69 8072.81 45.00 9.50 5195.00 5570.62N 932.74E 0.00 5648.17 T4.1 8100.00 45.00 9.50 5214.23 5589.58N 935.91E 0.00 5667.40 8143.52 45.00 9.50 5245.00 5619.93N 940.99E 0.00 5698.17 T3 (Top Bermuda Target), 2N-311 Top Bermuda Tgt RVSD 18 Mar 04, End of Hold 8200.00 45.00 9.50 5284.94 5659.32N 947.58E 0.00 5738.11 8277.87 45.00 9.50 5340.00 5713.63N 956.67E 0.00 5793.17 T2 8300.00 45.00 9.50 5355.65 5729.07N 959.25E 0.00 5808.82 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ G I ~\'ð I ,.,' /è... " :',; ¡, ", ,',',' Ij¡ ,~ .......-' \i .,' ~,t.; ~ ~"',.~ . . conocJ'Phillips ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 311 Well path: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 Bi. BAKER HUGHES INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] NQrth[ft] East[ft] Dogleg Vertical Station Comment [deql100ftl Sectìon[ftl 8398.07 45.00 9.50 5425.00 5797,46N 970.70E 0.00 5878.17 C35 (K3) 8400.00 45.00 9.50 5426.36 5798.81 N 970.92E 0.00 5879.53 8467.87 45.00 9.50 5474.35 5846.14N 978.85E 0.00 5927.52 TO, 3 1/2in Casinq, End of Hold All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR· 1[:;.'1 ë ',..,.II . . . ConocJPhillips ConocoPhillips Alaska, Inc.,slot #311 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 5 Wellbore: 311 Well path: 2N-311 Ver#1.A Date Printed: 5-Apr-2004 R¡. BAKER HUGHES INTEQ Comments MDfftl TVDrftl Northrftl Eastrftl Comment 300.00 300.00 O.OON O.OOE KOF 800.00 797.47 42.93N 7.18E Build 3/100 1220.25 1200.00 159.05N 26.62E Base Permafrost 1274.74 1250.00 180.41 N 30.20E Top West Sak 2132.00 1928.00 686.16N 114.88E Base West Sak 2389.71 2080.00 ß91.18N 149.21E EOC 2988.42 2400.00 1390.25N 232.78E 9 5/8 CSG 3128.75 2475.00 1507.22N 252.36E C801K1Q) 5589.07 3790.00 3558.09N 595.78E C50 6094.23 4060.00 3979.18N 666.29E C40 (K5) 6515.20 4285.00 4330.09N 725.05E C37 7316.03 4713.03 4997.64N 836.83E DrOD 2/100 7573.12 4860.00 5205.58N 871.64E T7 7943.52 5103.59 5480.45N 917.65E 51/2x31/2XO 7950.59 5108.58 5485.38N 918.48E End of DrOD 8072.81 5195.00 5570.62N 932.74E T4.1 8143.52 5245.00 5619.93N 940.99E T3 (T OD Bermuda T araet) 8277.87 5340.00 5713.63N 956.67E T2 8398.07 5425.00 5797.46N 970.70E C35 (K3) / 8467.87 5474.35 .I 5846.14N 978.85E TO Hole Sections Diameter Start Start Start Start End End End Start Well bore [inl MDfftl TVDlftl Northfftl Eastfftl MDfftl TVDfftl Northfftl Eastfftl 12 1/4 0.00 0.00 O.OON O.OOE 2988.42 2400.00 1390.25N 232.78E 311 81/2 2988.42 2400.00 1390.25N 232.78E 8467.87 5474.35 5846.14N 978.85E 311 CasinQs Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDrftl T\LDrftl Northfftl Eastrftl MDrttl TVDrftl Northrftl Eastrftl 9 5/8in Casina 0.00 0.00 O.OON O.OOE 2988.42 2400.00 1390.25N 232.78E 311 5 1/2in Casinq 0.00 0.00 O.OON O.OOE 7943.52 5103.59 5480.45N 917.65E 311 3 1/2in Casina 7943.52 5103.59 5480.45N 917.65E 8467.87 5474.35 5846.14N 978.85E 311 TarQets Name Northrftl Eastrftl TVDrftl Latitude Lonaitude Eastina Northina Last Revised 2N-311 Top 5619.93N 940.99E 5245.00 N70 11 8.9718 W150 18 23.3691 461946.00 5917595.00 30-Jan-2004 Bermuda Tgt RVSD 18 Mar 04 Survey Tool PrOqram Reference ISurvev Name 645213 I Planned IMDfftl 8467.87 ITVDfftl I 5474.35 I Survey Tool ISCWSA MWD I Error Model MWD+SAG - ISCWSA - 28 Jan 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 9.51 degrees Bottom hole distance is 5927.52 Feet on azimuth 9.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated (ì \,,/ .. Baker Hughes Incorporated Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria InterpolationMethod: MD Interval: 25.00 ft Depth Range: 0.00 to 8467.87 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Plan: 2N-311 Ver#1.a & NOT PLANNED J ~OGf ISCWSA Ellipse Trav Cylinder North Ellipse Plan: 2N-311 Ver#1.a Date Composed: Version: Tied-to: 3/18/2004 9 From Surface Principal: Yes Summary Tarn #2 Tarn#2 Tarn#2 VO Out of range Tarn #3 Tarn#3 Tarn#3 V1 5974.54 4025.00 1823.46 205.67 1617.79 Pass: Major Risk Tarn #3 Tarn#3 Tarn#3A VO 5487.42 3050.00 2137.02 179.44 1957.58 Pass: Major Risk Tarn #4 Tarn#4 Tarn#4 VO Out of range Tarn Drillsite 2N 302 2N-302 V1 452.67 450.00 131.96 6.93 125.03 Pass: Major Risk Tarn Drillsite 2N 303 2N-303 V1 427.06 425.00 121.42 5.24 116.18 Pass: Major Risk Tarn Drillsite 2N 304 2N-304 V1 325.25 325.00 103.43 4.08 99.34 Pass: Major Risk Tarn Drillsite 2N 304 2N-304PB1 V1 325.25 325.00 103.43 4.08 99.34 Pass: Major Risk Tarn Drillsite 2N 305 2N-305 V1 502.48 500.00 95.91 7.11 88.81 Pass: Major Risk Tarn Drillsite 2N 306 2N-306 VO Plan: 2N-306 1029.04 1025.00 76.52 20.87 55.65 Pass: Major Risk Tarn Drillsite 2N 307 2N-307 V1 675.24 675.00 56.36 9.87 46.49 Pass: Major Risk Tarn Drillsite 2N 308 2N-308 V1 677.97 675.00 50.61 11.22 39.39 Pass: Major Risk Tarn Drillsite 2N 309 2N-309 V1 599.87 600.00 27.87 9.09 18.78 Pass: Major Risk Tarn Drillsite 2N 310 2N-310 VO Plan: 2N-310 425.05 425.00 15.99 5.59 10.39 Pass: Major Risk Tarn Drillsite 2N 312 2N-312 VO Plan: 2N-312 424.67 425.00 16.23 5.58 10.66 Pass: Major Risk Tarn Drillsite 2N 313 2N-313 V1 324.88 325.00 31.30 3.31 28.00 Pass: Major Risk Tarn Drillsite 2N 314 2N-314 V1 125.00 125.00 45.12 0.04 45.09 Pass: Major Risk Tarn Drillsite 2N 315 2N-315 V1 299.99 300.00 61.00 3.00 58.00 Pass: Major Risk Tarn Drillsite 2N 316 2N-316 V1 349.50 350.00 75.22 3.81 71.40 Pass: Major Risk Tarn Drillsite 2N 317 2N-317V1 423.24 425.00 91.55 5.30 86.25 Pass: Major Risk Tarn Drillsite 2N 318 2N-318 V1 275.00 275.00 1 04.77 2.25 102.53 Pass: Major Risk Tarn Drillsite 2N 319 2N-319 V1 398.28 400.00 121.80 4.74 117.06 Pass: Major Risk Tarn Drillsite 2N 320 2N-320 V1 422.83 425.00 133.10 6.23 126.87 Pass: Major Risk Tarn Drillsite 2N 321 2N-321 V2 299.94 300.00 152.89 2.72 150.17 Pass: Major Risk Tarn Drillsite 2N 321 2N-321A V1 299.94 300.00 152.89 2.72 150.17 Pass: Major Risk Tarn Drillsite 2N 323 2N-323 VO 299.95 300.00 182.21 3.02 179.19 Pass: Major Risk Tarn Drillsite 2N 325 2N-325 VO 1.00 1.00 209.94 0.00 209.94 Pass: Major Risk Tarn Drillsite 2N 326 2N-326 VO 324.24 325.00 226.89 4.09 222.80 Pass: Major Risk Tarn Drillsite 2N 329 2N-329 VO 396.44 400.00 269.68 4.58 265.09 Pass: Major Risk Tarn Drillsite 2N 331 2N-331 VO 299.99 300.00 301.51 2.71 298.80 Pass: Major Risk Tarn Drillsite 2N 332 2N-332 VO 0.00 0.00 315.03 0.00 315.03 Pass: Major Risk Tarn Drillsite 2N 332 2N-332PB1 VO 0.00 0.00 315.03 0.00 315.03 Pass: Major Risk Tarn Drillsite 2N 335 2N-335 VO 466.33 475.00 360.12 6.35 353.77 Pass: Major Risk Tarn Drillsite 2N 337 2N-337 V1 347.42 350.00 389.83 3.86 385.96 Pass: Major Risk Tarn Drillsite 2N 337 2N-337PB1 V1 347.42 350.00 389.83 3.86 385.96 Pass: Major Risk Tarn Drillsite 2N 339 2N-339 V1 370.88 375.00 417.28 4.04 413.24 Pass: Major Risk Tarn Drillsite 2N 341 2N-341 VO 347.08 350.00 451.86 3.84 448.02 Pass: Major Risk Tarn Drillsite 2N 343 2N-343 V1 346.93 350.00 479.81 3.59 476.22 Pass: Major Risk Tarn Drillsite 2N 345 2N-345 VO 393.56 400.00 511.25 4.89 506.36 Pass: Major Risk Tarn Drillsite 2N 345 2N-345A VO Plan: 2N-34 393.56 400.00 511.25 4.89 506.36 Pass: Major Risk Tarn Drillsite 2N 347 2N-347 VO 323.28 325.00 540.31 3.32 536.99 Pass: Major Risk Tarn Drillsite 2N 348 2N-348 VO 369.71 375.00 556.30 5.00 551.30 Pass: Major Risk Tarn Drillsite 2N 349 2N-349 VO 323.20 325.00 570.38 3.29 567.09 Pass: Major Risk Tarn Drillsite 2N 349 2N-349A V2 0.00 0.00 570.02 0.00 570.02 Pass: Major Risk Tarn Drillsite 2N 350 2N-350 VO 346.36 350.00 581.92 4.55 577.38 Pass: Major Risk --- . . 2N-311 - DRILLING HAZARDS SUMMARY 12 l¡4" Open Hole & 9 5/8" Surface Casing Interval Event Broach of conductor Gas Hydrates at base of Permafrost Risk level Low Moderate I Gas at base of West Sak Moderate / Running sands & gravel Moderate Hole swabbingfTight hole on trips Moderate Stuck surface casing Low Stuck pipe Low Mitigation Strategy I Contingency Monitor cellar continuously during interval Minimum mud weight of 9.6 ppg, control drill, reduce pump rates, reduce drilling fluid temperatures, pretreat mud for hydrates Minimum mud weight of 9.6 ppg before reaching base of West Sak, reduce mud viscosity after drilling out of the Permafrost, control drill Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections 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 8 l/i' Open Hole & 5 Vi' x 3 Vi' Production Casing Interval Event Risk level Mitigation Strategy I Contingency Swabbing Campaignian Moderate Minimum mud weight of 9.6 ppg, mandatory v' sands (50 ft TVD below C- flow check above sands on all trips 80) Insufficient or undetermined Moderate Importance of LOT communicated to all parties, LOT 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 High ECD / Tight hole on Moderate Condition mud & clean hole prior to trips. trips/ Swabbing 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) Differential sticking Moderate Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever possible II Barite sag Low Good drilling practices as documented in well plan Lost circulation Low Keep hole clean - use PWD to monitor hole cleaning. If losses occur - reduce pump rates and mud rheology, use LCM "f^ ¡ "'f, l"~~\ 2N-3ll Drilling Hazards Summary Prepared by Philip Hayden 4/912004 Rig: Doyon 141 Location: Tarn Client: CPAI Revision Date: 4/9/2004 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 150 ft. MD < Base of Permafrost at 1,220 ft. MD (1,200 ft. TVD) < Top of Tail at 1,270 ft. MD '-! I < 95/8", 40.0#, L-80 grade BTC, AB Modified in 12 1/4" OH TD at 2,988 ft. MD (2,400 ft. TVD) Mark of Schlumberger 1Gb beliBel' Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 225% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 50' below base of permafrost. Lead Slurry (minimum pump time 198 min.) ArcticSet III Lite @ 10.7 ppg, - 4.43 ft3/sk 3 0.7632 ft 1ft x (150') x 1.00 (no excess) = 0.3132ft3/ft x (1220' -150') x 3.25 (225% excess) = 3 0.3132 ft 1ft x (1270' - 1220') x 1.45 (45% excess) = 114.5 ft3 + 1089.2 ft3+ 22.7ft3 = 1226.4 ft3 / 4.43 ft3/sk = Round up to 277 sks 114.5 ft3 1089.2 ft3 22.7 ft3 1226.4 ft3 276.8 sks Have 230 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 166 min.) LiteCRETE @ 12.0 ppg - 2.46 ft3/sk 0.3132 ft3/ft x (2988' - 1270') x 1.45 (45% excess) = 0.4257 ft31ft x 80' JShoe Joint) = 780.2 ft3 + 34.1 ft = 814.3 ft31 2.46 ft3/sk = Round up to 331 sks 780.2 ft3 34.1 ft3 814.3 ft3 331 sks BHST = 63°F, Estimated BHCT = 7rF. (BHST calculated using a gradient of 2.6"F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 40 8.0 8.0 Drop Bottom Plug 12.0 20.0 MudPUSH II 7 40 5.7 25.7 Lead Slurry 7 219 31.3 57.0 Tail Slurry 5 145 29.0 86.0 Drop Top Plug 12.0 98.0 Displacement 7 200 28.6 126.6 Bump Plug 3 20 6.7 133.3 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 1 per joint across zones of interest for proper cement placement. nn"...... '.. .î!'¥« ¡ ~ .1 ,,' '," '" .... ':" .. Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Tarn Client: CPAI Revision Date: 4/9/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 emaH: martin13@slb.com Volume Calculations and Cement Systems Volumes are based on 75% excess. Top of tail slurry is designed to be 571' above Bermuda formation. Tail Slurry (minimum thickening time 141 min.) Class G wI GasBLOK additives per lab testing @ 15.8 ppg, 1.16 ft3/sk 3 0.2291 ft 1ft x 371' x 1.75 (75% excess) = 0.3272 ft31ft x (8468' - 7943') x 1.75 (75% excess) = 0.0488 ft3/ft x 120' (Shoe Joint) = 148.7 ft3 + 300.6 ft3 + 5.9 ft3 = 455.2 ft3/1.16 ft3/sk = Round up to 393 sks Previous Csg. < 95/8",40.0#, L-80 grade STC, AS Modified at 2,988 ft. MD 148.7 ft3 300.6 ft3 5.9 ft3 455.2 ft3 392.4 sks BHST = 143°F, Estimated BHCT = 122°F. (BHST calculated using a gradient of 2.6°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 40 8.0 8.0 in 8 1/2" OH Drop Bottom Plug 3.0 11.0 MudPUSH II 6 40 6.7 17.7 Tail Slurry 6 81 13.5 31.2 Drop Top Plug 3.0 34.2 Displacement 6 178 29.7 63.9 < Top of Tail at Bump Plug 3 15 5.0 68.9 7,572 ft. MD < X-over at 7,943 ft. MD MUD REMOVAL < TopofT4.1. at 8,072 ft. MD Recommended Mud Properties: 10.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv? 19-22, Ty ? 22-29 < 31/2",9.3#, L-80 grade in 8 1/2" OH Centralizers: Recommend 1- Y:z per joint across zones of interest for proper cement placement. TO at 8,468 ft. MD (5,475 ft. TVD) Mark of Schlumberger Of~fGI~J.&~ Tarn 2N-311 plducer Proposed Completion Schematic 3-1/2" Completion String C~ocóPhiUi'ps ~ r r r ~ i! ~ i ~ ~ ~ ~ 3 Y:z" FMC Gen 5 Tubing Hanger, 3 %" L-80 EUE8RD Mod pin down ~ ~ § § ~ I ~ ~ ~ ~ ~ 3 %" 9.3# L-80 EUE8RD Mod Spaceout Pups as Required ~ ~ ~ ~ ~ ~ ~ ~ ~ '- ~ ~ ~ I ~ '- 3 %" 9.3# L-80 EUE8RD Mod Tubing to Surface - ~ ~ ~ ~ ~ I Tubing & hanger TO BE DRIFTED TO 2.91" I ~ ~ ~ ~ J. ~ ~ ---- I '- ~ '- ~ 3 %" Camco 'DS' nipple wI 2.875" No-Go Profile. 3 %" x 6' L-80 handling pups ~ ~ ~ I '- I 30" x 16" 62.6# ~ ~ I ~ installed above and below, EUE8RO Mod, set at +1- 500' MO ~ ~ ~ @ +1-150 ft i ~ ~ ~ ~ ~ ~ ~ (Insulated) '- ~ ~ I ~ '- ~ I I I ~ I '- ~ ~ ~ 3 %" 9.3# L-80 EUE8RD Mod tubing to landing nipple ~ i ~ ~ ~ '- ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ '- ~ ~ I ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ I '- ~ ~ ~ ~ ~ ~ I I ~ ~ I I '- 4 ea 3 %" x 1" Camco 'KBG-2-9' mandrels 3 %" x 6' L-80 handling pups installed ~ ~ I ~ ~ ~ I '- above and below, EUE8RO Mod ~ ~ I '- ~ ~ I '- ~ I I ~ 9 5/8" Surface csg. ~ ~ ~ I I ~ @ 2988 ft MD I 2400 ft TVO I ~ ~ I I I ~ ~ I ~ I I I ~ 3 %" x 1" Camco 'KBG-2-9' mandrel wI shear valve, pinned for 3000 psi shear I I I ä (casing to tubing differential), 3 %" x 6' L-80 handling pups installed above and '- I ~ I below, EUE8RO Mod I I I ~ ~ I ~ a I ~ I 3 %" Baker 'CMU' sliding sleeve wI 2.813" Cameo OS profile, ~ I ~ I EUE8RO Mod box x pin. 3 %" x 6' L-80 EUE8RD Mod handling pup ~ installed above ~ ~ I I I ~ --- I 3 %" Camco 'D' nipple wI 2.75" No-Go profile. 3 %" x 12' L-80 EUE8RD Mod ~ I spaceout pup installed above, 3 %" x 6' handling pup installed below ~ ~ i ~ I i I ~... - I +- 3 %" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3 %" L-80 5 %" x 3 %" Crossover W @ 7944 ft MD 15104 ft TVD EUE8RO Mod box up, 3 %" x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 %" BTCM x 3 %" EUE8RD Mod SBE set at +1- 200' MD above the top of the Bermuda interval Future Perforations 5 %" x 3 %" Production csg @ 8468 ft MO 15474 ft TVD .. ~ OR~G~~,I.A\L" 04/09/04 SFD \ Expected reservoir pressure in 2N-311 . . Subject: Expected reservoir pressure in 2N-311 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> Date: Tue, 20 Apr 2004 10:06:07 -0800 To: tom _ maunder@admin.state.ak.us CC: "Bennett, Lara D" <Lara.D.Bennett@conocophillips.com> Tom, With reference to your query regarding the expected reservoir pressure in 2N-311 I would like to make some clarifications: 1. For maximum surface pressure calculations we have used the maximum possible reservoir pressure (11.0 ppg) as indicated by our reservoir engineer. 2. For the planned mud weight we have used the expected reservoir pressure (10.3 ppg). 3. Although we will be prepared for the worst case scenario, Le. 11.0 ppg, the confidence interval around the expected value is high enough for us to conclude that drilling into the reservoir with the planned mud weight will be acceptable. If you need any more information please let me know Regards Philip 1 of 1 4/20/200412:17 PM . . ª ~ ~ ~ . ~ o DOLLARS fD PAY TO THE ORDER OFtJ _ Dol... "' B nk USA, N.A. Valid Up TO~í2' - L ---- 'M"" " '_...~~: _,.,." ". .. CHASE 200Whll,CI.yC,nte' ..fk~~"- j l/Jy___'_ _.~~: '" ~ · . 1#-"",- §6' ." - "~_. o 7 g 2-; b III ~ 0 5 0 MEMO I.. 1..1: 2 ~ 8 I.. 7 ~ g ·03~~OO~ I. UNIVERSAL . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ¿ea :2-D~ ,-- a3 WELL NAME PTD# / Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Z~r3/ I Exploration Stratigraphic ~'CLUEn Tbe permit is for a new well bore segment of existing well Permit No, API No. Production.sbould continue to be reported as a function 'of the original API number. stated above. BOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of 11 conservation order approving a spacing exception. {CompanY Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample intervals tbrougb target zones. f)ß Geologic Commissioner: 4f~rr~~{~ \ ~. ~\ b* Date 35 36 37 38 39 Conta.ct namelphone.for.we~~ly progress reports [explor¡:¡tory :onQ r No. .Y~s NA NA .NA Appr SFD Date 4/16/2004 .S~¡:¡bedcondjtioo survey -Of off-shoœ) S~isrnic.analysjs. of shaJlow gas.z~)r)es. P~(mit .D.ata.pres~oted on. pote.ntial oveJpres.sur~ .zones No, offset wells 2N-303 & .2N-305 !11~asured20& 2.5 .pprn H2Son f3l25'-02 &.1 j '-11/03 (espectiv.ely. Exp~cted reservojr pre.ssure in .are.a Jan~es from 9.5 to 11.0 ppg .EMW; wjll b.e .drilled wjtb 1 0.3 pp~ mud.. Geology catl be issued w!o. hyd(ogen sulfide rneas.u(es 32 33 34 Wor~ will OCCUI .Is presetlce. of . Mecha.nic¡:¡I.coodjliotl Qf wells within Jl.OR yerified (for.s.e/'Vjce w~ onJy) Date 4/20/2004 ,¡~ Appr TEM 18 19 20 21 22 23 24 25 26 27 28 29 30 31 H2S gas. proQable .C.hokemanjfold compJies w/APIRf>-53 (May 84) without oper¡:¡tjo.nshutdown .BOPEs,dQ.they me~treguJation BOPE.press ratiog app(op(iate; .test to (pu.t psig in.comments) .Drilliog fluid. program sch~rnatic.& eq.uip Jistadequate Jf.a.re-d(iII~ has. a 10-403 for abandonment .Adequ<'lte well bore separ¡:¡tioÐ .proposed it .me~t Jf.djv~r:ter req.uired, does r~guJations. .Adequ<'ltetan.k¡:¡ge.oJ re.sef'Ye pit be~o approved .CMT will coyeraJl C<'lsiog de.si~tlS ad.equaie fo( CoT, B.&.p.ermafrQst koow.n .productiye horizon.s .CMT v.ol ad~q u.ate. to known USDVlls .CMT v.ol adeq uate. to circ.utate. on .conductor. tie-in long .stritlg to .surf csg. &. SUJf.csg .Y~s NA .Y~s No. .Y~s .Y~s .Y~s NA .Y~s .Y~s .Y~s .Y~s .Y~s .Y~s .Y~s No. NA Mud sh.ould pœclude. H2.S. o.n the rig. .Ri~ is equipped with. s.etlSOJs. and alarms. Ml\5i> calculate.dat 2459 psi. 35QOpsLapprpnate. Ci>AI JikeJy to test to 50QOpst Possibl~BHP.range gc5.- .11 .0 .EMW.. Expected BHf> beJow. 0.3 ppg. prQ~irniy .atlalysis.Rerfor!11~d.. Tr¡:¡lle!in~ cyUn.der. plot included. Rig is equipped with steel.pjts. No r~se.rvepjtp!anoe.d, Wa.steto an appwyed annulus orCJass I we Jl.nn.ula( disposal !11.ay be propo.sed. Engineering . Appr SFD 4/16/2004 12 13 14 15 16 17 .5.urface .casing. protects all .CQtlductor st(ing.provided Ord~r ¡ tlO# e/'Vjce well ,. ..'..., _ . . ~ than 3 mOnths. (Forseryice well on!y) ACMP Finding.of Consistency has bee.n.issued. for. this pr.olect 1l4.mile.area.of (eyiew Pre-produ.ced itljector; duraijo.n.of pr~-productioo I~s~ Well .AJI w~l]s. within id~olified (Fo( nnl,,\ located within area and.strata .authorized by. Itljectioo in cQrn!11~ots). (For Date PTD#: 2040630 Administration .Oper.ator bas.appropriate. Qond in .force conservation order inc!u.ded .Ope(ator only affected party IOCÇIt d p(oper .S.uffjcient_ Jfd~viated, is. weJlbore pl¡:¡t ~crea~e.aYail<'lble in.drilliog unjt Well Well Well locat~d pr.oper .distance. from driJling unitb.ound<'lry. distance. from other welJs Leas~ .numberappropriate. .U.nique well. n.a!11~ .aocJ ol!mb~( IOCÇIt~d in.a. d.efjne.d pool Company CONOCOPHILLlPS ALASKA P~(mit fee attached 2 3 4 5 6 7 8 9 10 11 (,! Kup<'l(Uk Rjver~ Tarn Oil Pool~ CO 430A Field & Pool KUPARUK RIVER, TARN OIL - 490165 Can permit P~(mit P~(mit NC Initial ClasslType .Y~s Yes .Y~s .Y~s .Y~s .Y~s .Y~s .Y~s .Y~s .Y~s .Y~s .Y~s Yes NA .NA NA NA M aquifers ex~rnpted,40CFR 147.102 (b)~3).. w~ drilled from existiog pad. catl be iSSl!ed witbout c.atl be i.sSl!ed without be approved before 15-day wait ¡:¡dminist(atille. approval Well Name: KUPARUK RIV U TARN 2N-311 DEV I PEND GeoArea 890 Unit 11160 Program DEV On/Off Shore On Well Annular Disposal bore seg D D 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 infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infomlation. bs ¡...J (2- (p '2.. ..5 e **** REEL HEADER **** LDWG 04/08/18 AWS 01 **** TAPE HEADER **** LDWG 04/08/18 01 *** LIS COMMENT RECORD *** e RECEIVED AUG 2 C 2004 Alaska Oí/ & Gas Cons. Commission Anchorage ;<. t!) ~-o (p :, LDWG File Version 1.000 , Extract File: LISTAPE.HED !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! TAPE HEADER TARN UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 2 C. WONG G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 2N-311 501032049100 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 18-AUG-04 MWD RUN 3 9N 7E 149.60 119.30 MWD RUN 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 9.625 120.0 3000.0 8657.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N 70 DEG 10' 13.698" LONG: W150 DEG 18' 50.646" LOG MEASURED FROM D.F. AT 149.60 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 2 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), with Multiple Propagation Resistivity (MPR), Gamma Ray, and Drill Collar Pressure (DCP) services from 3010 - 8657 feet MD (2412-5614' TVD). REMARKS: (1) Depth of 9 5/8" Casing Shoe - Driller: 3000 feet MD (2407' TVD) Depth of 9 5/8" Casing Shoe - Logger: 3005 feet MD (2409' TVD) (2) The interval from 5329 to 5396 feet MD (3661 - 3696' TVD) has no Neutron Porosity data due to sensor lock-up. (3) The interval from 7852 to 7902 feet MD (5060 - 5094' TVD) was logged up to 19.6 hours after drilling due to a short trip to the 9 5/8" casing shoe for an open hole formation integrity test (FIT). (4) The interval from 8615 to 8657 feet MD (5585 - 5614' TVD) was not logged due to sensor-bit offset at TO. $ Tape Subfile: 1 74 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 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3000.0 STOP DEPTH 8657.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- e e BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 2 3000.0 MERGE BASE 8657.0 # 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 2n-311 5.xtf 150 ConocoPhillips Alaska, Inc. 2N-311 Tarn North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAFM 0.0 RPD RPD RPCLM 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPCHM 0.0 RPX RPX RPCSHM 0.0 RHOB RHOB BDCFM 0.0 DRHO DRHO DRHFM 0.0 PEF PEF DPEFM 0.0 NPHI NPHI NPCKSFM 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 48 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: 21 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 e 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 ------- 44 Total Data Records: 539 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3000.000000 8656.500000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 584 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: FILEO 11. HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 e log header data for each bit run in separate files. 2 .2500 START DEPTH 2950.0 STOP DEPTH 8657.0 # 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: 13-JUN-04 MSB 18704 6.75 TC MEMORY 8657.0 2950.0 8614.0 o 45.4 e # MAXIMUM ANGLE: 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 # 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 59.3 TOOL NUMBER 10103633 10085479 10008424 6218 10092229 8.500 3000.0 LSND 10.35 .0 .0 300 .0 .000 .000 .000 .000 150.0 .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) 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 '" , ,. 'f e e WDFN LCC CN WN FN COUN STAT 2n-311. xtf 150 ConocoPhillips Alaska, I 2N-311 Tarn North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAFM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCFM 0.0 DRHM DRHM DRHFM 0.0 DPEM DPEM DPEFM 0.0 NPCK NPCK NPCKSFM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 64 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: 15 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 15 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 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 ROPA MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 .. f ..-? e Total Data Records: 1522 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2950.000000 8656.250000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 1630 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/08/18 01 **** REEL TRAILER **** LDWG 04/08/18 AWS 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes e 60