Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
206-179
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y Samantha Carlisle at 7:54 am, May 02, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1 & 862 &RQRFR3KLOOLSV&1 %UHQQHQ*UHHQ ( Q #FRQRFRSKLOOLSVFRP 5HDVRQ ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ \RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ ; 3KRWR GRFXPHQW EHIRUH DQG DIWHU / '65 ; '/% 97/ GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.05.03 09:20:19 -08'00' RBDMS SJC 050422 32%2; $1&+25$*($/$6.$ 0D\ &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 'HDU&RPPLVVLRQHU&KPLHORZVNL 3OHDVHILQGWKHHQFORVHGDSSOLFDWLRQIRU6XQGU\$SSURYDOIURP&RQRFR3KLOOLSV $ODVND,QFIRUZHOO.581$ 37' WRH[WHQGWKHFRQGXFWRU 6XPPDU\ &RQGXFWRUKDVVXEVLGHGRUZHOOKDVJURZQa´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a´ :LWKDSSURYDOWKHFRQGXFWRUH[WHQVLRQZLOOUHTXLUHWKHIROORZLQJJHQHUDOVWHSV 5HPRYHODQGLQJULQJIURPFRQGXFWRULIQHFHVVDU\ ([WHQGWKHFRQGXFWRUWRVWDUWHUKHDG )LOHZLWKWKH$2*&&SRVWUHSDLU /DVW7DJ $QQRWDWLRQ 'HSWK IW.% (QG'DWH :HOOERUH /DVW0RG%\ /DVW7DJ 5.% (VW RI5DWKROH 1$ ]HPEDHM /DVW5HY5HDVRQ $QQRWDWLRQ (QG'DWH :HOOERUH /DVW0RG%\ 5HY5HDVRQ 8SGDWHG7DJ'HSWK 1$ ]HPEDHM &DVLQJ6WULQJV &DVLQJ'HVFULSWLRQ &21'8&725 2' LQ ,' LQ 7RS IW.% 6HW'HSWK IW.% 6HW'HSWK 79' « :W/HQ O« *UDGH + 7RS7KUHDG :(/'(' &DVLQJ'HVFULSWLRQ 685)$&( 2' LQ ,' LQ 7RS IW.% 6HW'HSWK IW.% 6HW'HSWK 79' « :W/HQ O« *UDGH / 7RS7KUHDG %7& &DVLQJ'HVFULSWLRQ ,17(50(',$7( 2' LQ ,' LQ 7RS IW.% 6HW'HSWK IW.% 6HW'HSWK 79' « :W/HQ O« *UDGH / 7RS7KUHDG %7&0 &DVLQJ'HVFULSWLRQ /,1(5 2' LQ ,' LQ 7RS IW.% 6HW'HSWK IW.% 6HW'HSWK 79' « :W/HQ O« *UDGH / 7RS7KUHDG ,%70 /LQHU'HWDLOV 7RS IW.% 7RS 79' IW.% 7RS,QFO ,WHP'HV &RP 1RPLQDO,' LQ 3$&.(5 %$.(5&=;3/,1(57233$&.(5 +$1*(5 %$.(5)/(;/2&./,1(5+$1*(5 6%5 6($/%25((;7(16,21 ;2%86+,1* ;2%86+,1*%7&%R[;,%73LQ 7XELQJ6WULQJV 7XELQJ'HVFULSWLRQ 78%,1* 6WULQJ0D« ,' LQ 7RS IW.% 6HW'HSWK IW« 6HW'HSWK 79' «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mage I~ject Well History File C~er 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. ~ ~ - 1 ~ ~ Well History File Identifier Or anizin (aone> Two-sided III II~III II II I II III ^ Rescan Needed III (I'I II (~ I (III III y y RESC DIGI AL DATA OVERSIZED (Scannable) olor Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ~er Items Scannable by a Large Scanner L ~ e-r~' ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: /~ ^ Other:: BY: Maria Date: ~ ~ (,~ - Isl Pro "ect Proofing II I II II II I I III I I III BY: Maria Date: ~; /s/ Scannin Pre aration ~~ x 30 = ~`~~ + ~ =TOTAL PAGES / BY. g M na ~ ~ F, ~ ~~ (Count does not include cover sheet) Date: lL' ~ ~ ~ /s/ ~l Production Scanning Stage 1 Page Count from Scanned File: 1 ~ ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ~ ~ ~ ~ Isl ~l Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scannin is complete at this point unless rescanning is required. II I II II II I II II I I III 9 ReScanned III (I'III IIIII II III BY: Maria Date: Isl Comments about this file: Quality Checked III II'll) III II'I II p r 10/6/2005 Well History File Cover Page.doc i • .~ ~~ _, ~ -_ ~.. ~~- . . ~ --r 4. ~- -- -. ~ ~ ~: A -Q ~~~•a" . .~ ~~ ~ .MICROFILMED 6/30/2010 DO NOTPLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc u vt -t, DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2061790 Well Name/No. KUPARUK RIV U TARN 2N-311A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20491-01-00 MD 8747 TVD 5705 Completion Date 5/8/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Y DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neutron, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / meairrrrn ~~umuc~ rvame ~caiC inCwa rvo quart atop ~.n rcecervea ~ommenrs Cement Evaluation 5 Col 1 0 8030 Case 4/20/2007 USIT, CEL, GR, CCL 6- Apr-2007 C Las 15117~ Mud Log 2900 8800 Open 5/8/2007 Mud Log LAS Data w/Graphics Word, PDF, LAS 15117 Report: Final Well R 0 0 Open 5/8/2007 Final Well Report, Table of Cont, Equip & Crew, Well Details, Geo Data, Pres/Formation Strength, Drilling Data, Daily („~~b ~, a ,~ Reports, Formation Logs. 15117 Fo fion-h~ticro-Im~t 2 Col 3000 8747 Open 5/8/2007 MD Formation Log I 15117 ~~ Foisrj~• t-.-IVticro~n~ a 2 Col 3000 8747 Open 5/8/2007 I TD Formation Log ', 15117 Lithology 2 Col 3000 8747 Open 5/8/2007 MD Lithology Log 15117 Lithology 2 Col 3000 8747 Open 5/8/2007 TVD Lithology Log 15117 Gas Analysis 2 Col 3000 8747 Open 5/8/2007 TVD Gas Ratio Log 15117 Gas Analysis 2 Col 3000 8747 Open 5/8/2007 MD Gas Ratio Log 15117 See Notes 2 Col 3000 8747 Open 5/8/2007 MD Drilling Dynamics 15117 See Notes 2 Col 3000 8747 Open 5/8/2007 TVD Drilling Dynamics D Asc Directional Survey 2946 8747 Open 6/12/2007 DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2061790 Well Name/No. KUPARUK RIV U TARN 2N-311A Operator CONOCOPHILLIPS ALASKA INC , 'euon vale ~iaituui ~.ornpieuon macaws '-v" "` ED C Lis 15242~Induction/ResistV ty 2571 8747 Open 6/25/2007 LIS Veri, GR, NPHI, NCNT, RHOB, FET, ROP w/Graphics txt and PDF L I,~rVerification 2571 8747 Open 6/25/2007 D C / 17489~See Notes 0 0 1/20/2009 EWR Togs in PDS, EMF and CGM graphics og Induction/Resistivity 25 Col 2900 8747 Open 1/20/2009 MD ROP, DGR, EWR, C~ ,ALD 13-Apr-2007 og Induction/Resistivity 25 Col 2353 5704 Open 1/20/2009 ROP, DGR, EWR, CTN, ALD 13-Apr-2007 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /® Chips Received? `Y71~' Analysis ~FN Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops API No. 50-103-20491-01-00 Comments: q ~a~~( Compliance Reviewed By: '~ Date: • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 2N-311A January 5, 2009 AK-MW-4957755 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-311A 2" x 5" MD RESISTNITY & GAMMA RAY Logs: 1 Color Log 50-103-20491-01 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-103-20491-01 Digital Log Images 1 CD Rom 50-103-20491-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: ~., r ~ i. Date: - Signed: ~ ~r ;~ ' Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: ~~1~-T3-3~~5 Bryan. B u ruldar'h al lib urton. com BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 -~ ~~ .. ~.~. • • ConocoPhiNips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: '~EcF oer °~Fo A/e$k~ DiJ~ Ga ~ 2 ~OpJ Aneh° a~'° CO~issi Oq ~6b~~31~A ~- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRiJ). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ~~ :~ M.J. vel d ConocoPhillips Well Integrity Projects Supervisor . • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-~03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n!a 10 9/27/2007 2N-313 198-091 5" n/a 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2N-311A June 20, 2007 AK-MW-4957755 1 LDWG formatted CD Rom with verification listing. APl#: 50-103-20491-0 1. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 I~/'~~? 4~~ ~~ `~ _~ 2or~ Date: '~~ C~1 & Gas C,u~~~s. Gomrnissicn I~ncttcx~ar,~e Signed: , ConocoPhillips May 29, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2N-311A (APD 206-179) Dear Commissioner: ~E~~~~~® MAY ~ 0 2007 Alaska Oil & has Cons. Commission. Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2N-311A. 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 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 26C~-1~i STATE OF ALASKA ~ SAY 3 ~ ZOO7 ALASKA OIL AND GAS CONSERVATION COMMISSION II s Cons. Commissi WELL COMPLETION OR RECOMPLETION REPORT A~ ~~hnrano 1a. Well Status: Oil a - Gas Plugged Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development 0 Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~f/a a!'1AD7 oraband.: A 007 12. Permit to Drill Number: 206-179 ! 307-023 ! 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~` !]7 3~,b ~,3~,v March , 2007 13. API Number: 50-103-20491-01 4a. Location of Well (Governmental Section): Surface: 27' FNL, 617' FEL, Sec. 3, T9N, R7E, UM ~ 7. Date TD Reached: April 12, 2007 14. Well Name and Number: 2N-311A Top of Productive Horizon: 68' FSL, 780' FWL, Sec. 26, T10N, R7E, UM 8. KB (ft above MSL): 149' AMSL . Ground (ft MSL): 119' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 397' FSL, 551' FWL, Sec. 26, T10N, R7E, UM 9. Plug Back Depth (MD + ND): Tarn Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460976 ~ y- 5911981 ' Zone- 4 10. Total Depth (MD + ND): - 8747' MD / 5705' ND 16. Property Designation: , ADL 375074, 380054, 380053 TPI: x- 462393 y- 5917347 Zone- 4 Total Depth: x- 462165. y- 5917677 f Zone- 4 11. SSSV Depth (MD + ND): Camco landing nipple @ 523' 17. Land Use Permit: 31961, 32027,32026 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1196' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): /s,~f9 ~~~~J•D, Qj~ ~7"yD GR/Res/Dens/Neutron, USIT J~*~ b ~.3/-D7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 30' 139' 30' 139' 42" pre-installed 9.625" 40# L-80 30' 3000' 30' 2402' 12.25" 275 sx ASLite, 330 sx LiteCRETE 7" 26# L-80 30' 8050' 30' 5165' 8.5" 13s sx LiteCRETE 4.5" 12.6# L-80 7855' 8747' 5017' 5705' 6.125" 29 bbls Class G 23. Open to production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 7909' 7857' 8240'-8255' MD 5311'-5323' TVD 6 spf ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7050'-8085' 65 sx Class G 7940'-8085' 267 sx Class G 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) shut-in -waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No ~ • If Yes to either question, list formations and intervals cored (MD+ND 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 AAC 25.071. ~. `',, ... ......11~. ~6Y` t NONE ~ _,,,Cr; i c 1 • E+ •O a Form 10-407 Revised 2/2007 uRIGiNAL CONTINUED ON REVERSE S1DE ~~~ ~ ~ zoos WR~ A~ ~ S•3(.d~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Pemlafrost -Bottom 1220' 1196' needed, and submit detailed test information per 20 AAC 25.071. T-3 8112' 5212' T-2 8289' 5349' N/A Formation at total depth: T-3 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: Jason Brink @ 265-6419 Printed N Ra s Title: Drilling Team Leader S l ~~~~~' ~ ~~ ` Signature -- ~-~._.~-~'He~ Date 2..~ S 6-~'> G INSTRUCTIONS Sharon Allsup-Drake 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 27: 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 AAC 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 AAC 25.071. Form 10-407 Revised 2/2007 c: • ConocoPhillips Time Log Summary We(Jv7pw Web feeDD?Yi14g Well Name: 2N-311 Job Type: DRILLING SIDETRACK Time Loys Date From To __ Dur S. De>th E. De th Phase Code Subcode T COM 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 da at 1500 hrs. 15:00 17:00 2.00 2,774 2,774 MIRU MOVE RURD P Berm up rig, spot out blgs, RU circ hoses and tes same w/ air. 17:00 19:00 2.00 2,774 2,774 MIRU MOVE WOEO NP Stby w! WO hardline and seawater. Spot high-line power trlr. Clean up and or anize ri for u comin o s. 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 w/ sea-water for dis iacement rocedure. 22:30 00:00 1.50 2,774 2,774 MIRU WELCT KLWL P 250 psi on IA, pull BPV w/lubricator. Start pump seawater down tbg w/ returns up IA @ 3 bpm to displace out diesel freeze rotection. 03/15/2007 00:00 01:00 1.00 2,774 2,774 MIRU WELC CIRC 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 N D of tree. 01:00 02:00 1.00 2,774 2,774 MIRU WELCT 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 blankin lu . 03:00 06:00 3.00 2,774 2,774 MIRU WELCT NUND P PJSM, NU BOP stack. 06:00 07:00 1.00 2,774 2,774 MIRU WELCT NUND P Finish NU Stack, prepare for testing o s. 07:00 12:00 5.00 2,774 2,774 MIRU WELC BOPE P Fill BOPE, test all 250psi to - 3500psi high. All testing OK. Test witnessed b John Crisp, AOGCC ins ector. 12:00 13:30 1.50 2,774 2,774 MIRU RPCOf~ NUND P PJSM, RD test equipment, 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 RPCOh NUND P CBU @ 5 bpm / 190 psi. 14:00 17:00 3.00 2,774 2,774 MIRU RPCO11 PULD P PJSM, POOH LD 3 1/2" kill string. 17:00 22:00 5.00 2,774 2,774 MIRU RPCOh NUND P Set test plug c/o upper rams to 4". Test upper & lower rams to 250psi lo, 3500 psi hi, OK. RD test eq, pull test lu and set wear rin . 22:00 00:00 2.00 2,774 2,774 MIRU DRILL PULD P PJSM, PU BHA # 1 w/ 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. ~r 3~~i Time Logs Date From To Dur SDe~th E Depth Phase Code Subco_de T COM 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 to in sources. 03:30 04:30 1.00 2,774 2,774 PROD1 DRILL PULD P MU Jar, RIH w/ 4" HWDP. 04:30 05:30 1.00 2,774 2,774 PROD1 DRILL TRIP P TIH w/ BHA #1 on 4" DP f/ 664' - 2277' w/ 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 w/ 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 /displace wellbore to 9.6 ppg drill fluids. 12:00 18:30 6.50 2,562 3,000 PROD1 CEME~ DRLG P Commence drill out cmt plug in 9-5/8 cs 2562 - 3000' 9-5/8 shoe de th. 18:30 19:00 0.50 3,000 3,038 PROD1 DRILL DDRL P Cont drill ahead. 100% new formation returns at 3038 ft. 19:00 20:00 1.00 3,038 3,038 PROD1 DRILL FIT P Circ and condition mud for LOT. Mud wt 9.7 ppg. Pull into shoe, BDTD, RU test a f/ test. 20:00 21:00 1.00 3,038 3,038 PROD1 DRILL FIT P Perform LOT to 15.0 ppg MWE w/ leak off. Followed LO w/ 3 bbls mud pumped away. Total fld pumped f/ 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 roblems, PU off bottom. 23:00 00:00 1.00 3,169 3,169 PROD1 RIGMN' RGRP T Developed power problems w/ traction motor on #1 pump and transformer on top drive. Unable to drill w/diagnosing roblem. 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 ri dia nostics and re airs. 02:30 06:00 3.50 3,169 3,169 PROD1 RIGMN RGRP T Work on diagnosing and repair of rig electricals stems. 06:00 00:00 18.00 3,169 3,169 PROD1 RIGMN RGRP T Rig Repair: Work on electrical and c/o of um traction motor. 03/18/2007 00:00 06:00 6.00 3,169 3,169 PROD1 RIGMN RGRP T Rig downtime /repair. Work on c/o of ump traction motor. 06:00 00:00 18.00 3,169 3,169 PROD1 RIGMN' RGRP T Rig downtime /repair. Work on c/o of um 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, re arin 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. ~_ ~~-.,.,~ ~._ _ ~ ~ag~ ~ of f~ T Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/19/2007 09:30 11:30 2.00 3,169 3,169 PROD1 RIGMN' RGRP T Run up pumps and testing electrical systems. Test failed when Pump #1 traction motor failed. SD to switch from Hi-line to rig power due to field re uirements. 11:30 12:00 0.50 3,169 3,169 PROD1 RIGMN WOEL NP Switch from Hi-line to rig power. 12:00 00:00 12.00 3,169 3,169 PROD1 RIGMN RGRP T Work on repair of Pump #1 traction motor. 03/20/2007 00:00 00:00 24.00 3,169 3,169 PROD1 RIGMN RGRP T Repairing traction motor on #1 pump. Remove motor from pump shed, compare with replacement, install mounting hub /components from old motor to new motor. 03/21/2007 00:00 23:30 23.50 3,169 3,169 PROD1 RIGMN RGRP T PJSM, RU /ready pump motor for installation. Place same in position. Begin connections. Complete swap hubs to motors. Terminate wiring. Troubleshoot /test SCR assi ments. 23:30 00:00 0.50 3,169 3,169 PROD1 RIGMN RGRP T RIH 2940 to 3037 ft for tests. 03!22/2007 00:00 04:00 4.00 3,169 3,169 PROD1 RIGMN RGRP T MU top drive, circ #1 and #2 pumps in parralel. Monitor pumps, test elect systems while running. 200 spm at 1400 psi. Perform top drive RPM / for ue test. All tests successful. 04:00 05:00 1.00 3,169 3,169 PROD1 DRILL TRIP T PJSM, POH for BHA maintenance download data ,BOP test. 05:00 10:00 5.00 3,169 3,169 PROD1 DRILL PULD T Handle BHA, stand back HWDP/flex collars. PJSM, remove RA source, download data. UD BHA. 10:00 15:30 5.50 3,169 3,169 PROD1 WELCT BOPE T PJSM, RU /test BOPE all components 250 / 3500 psi ,all tests successful, no re-tests. Witness waived b Mr Chuck Scheve AOGCC. 15:30 22:30 7.00 3,169 3,169 PROD1 DRILL PULD T PJSM, MU BHA #2 /bit run #2. Load RA source, RIH same, test motor / MWD ass . 22:30 23:30 1.00 3,169 3,169 PROD1 DRILL TRIP T Flow check, PJSM, follow BHA with 4" DP to 3047 ft. Wash to to at 3169 ft. No fill. 23:30 00:00 0.50 3,169 3,187 PROD1 DRILL DDRL P Drill ahead 8-1 /2 hole dretnl 3169 - 3187 ft. AST .17 hrs. ART 0 hrs. 03/23/2007 00:00 01:00 1.00 3,187 3,230 PROD1 DRILL DDRL P Drill ahead 8-1/2 hole dretnl 3187 - 3230 ft AST .75 hr 01:00 02:00 1.00 3,230 3,230 PROD1 DRILL SRVY P Surveys for "IIFR/Caz" 02:00 03:00 1.00 3,230 3,230 PROD1 RIGMN RGRP T Troubleshoot mud pumps #1 and #2. Oil ressure. 03:00 06:30 3.50 3,230 3,456 PROD1 DRILL DDRL P Resume drill ahead 8-1/2 hole dretnl 3230 - 3456 ft. Discover mud pumps runnin backwards. 06:30 07:00 0.50 3,456 3,456 PROD1 DRILL TRIP T PJSM, flow check, POH to shoe for um re airs. 07:00 08:00 1.00 3,456 3,456 PROD1 RIGMN RGRP T Re-wire mud pumps for correct rotation. ~~ ~ ~ _. es~ gage ~ of '1 ~ ~ ~ Time Logs i _ _ Date _ _ From _ I"o Dur _S___Depth E Depth Phase Code Subcode T COM ______ 03/23!2007 08:00 08:30 0.50 3,456 3,456 PROD1 DRILL TRIP T Flow check, RIH to 3425 ft. 08:30 09:00 0.50 3,456 3,456 PROD1 DRILL CIRC T Precaution wash to btm at 3456 ft. No fill. 09:00 00:00 15.00 3,456 4,340 PROD1 DRILL DDRL P Drill ahead 8-1/2 hole dretnl 3456 - 4340 ft. WOB 8-10, RPM 60-80, SPP 2040, SPM 210 Up 107, Dn 80, Rot 90, Ave ROP = 105 fph AST = 3.68 hrs, ART = 10.6 hrs On btm 3950, Off btm 3500 No gain /losses, returns to shaker normal uantit / ualit . 03/24/2007 00:00 07:30 7.50 4,340 4,847 PROD1 DRILL DDRL P Drill ahead 8-1/2 hole dretnl 4340 - 4847 ft. Note increasing drag /torque on connections. 07:30 08:30 1.00 4,847 4,847 PROD1 DRILL CIRC P Circ hi-vis / wt pill around. Approx 10% increase in cuttings return to surface. H d tali er = ua a hole. 08:30 10:30 2.00 4,847 4,847 PROD1 DRILL TRIP P PJSM, flow check, POH wiper trip to 9-5/8 shoe. Tight at 4402 ft with 25K over pull. Backream 4402, 4176, 3890, 3607, 3321 ft. No packoff /gain / losses. Correct hole fill. 10:30 11:00 0.50 4,847 4,847 PROD1 DRILL CIRC P Cont circ, unload annulus. Clumps clay to surface, cont circ wellbore clean. 195 SPM, 475 m, 1730 si. 11:00 11:30 0.50 4,847 4,847 PROD1 DRILL TRIP P Flow check, resume POH to 9-5/8 shoe. 11:30 12:00 0.50 4,847 4,847 PROD1 RIGMN SVRG P Service rig. 12:00 14:00 2.00 4,847 4,847 PROD1 RIGMN OTHR P Slip / cut drlg line. 14:00 15:00 1.00 4,847 4,847 PROD1 RIGMN SVRG P PJSM, C/O saver sub. 15:00 16:30 1.50 4,847 4,847 PROD1 DRILL TRIP P PJSM, flow check, RIH to 4752 ft. normal do dra . Correct dis lacement. 16:30 17:00 0.50 4,847 4,847 PROD1 DRILL CIRC P Precaution wash to btm at 4847 ft No fill. 17:00 00:00 7.00 4,847 5,260 PROD1 DRILL DDRL P Drill ahead 8-1/2 hole dretnl 4847- 5260 ft. WOB 8-10, RPM 60-80, SPP 2250, SPM 210 Up 122, Dn 82, Rot 990, Ave ROP = 111 fph AST = 2.85 hrs, ART = 7.7 hrs On btm 3950, Off btm 3500, Max gas 46 units No gain /losses, returns to shaker normal uanti / ualit . e .~ ®~ v ~~~ ~ 03 'f ~ i ~ Time Logs Date From_ To Dur 5 De~th__E,_Depth Phase Code _ Srrbcode T COM _ 03/25/2007 00:00 20:30 20.50 5,260 6,559 PROD1 DRILL DDRL P Drill ahead 8-1/2 hole dretnl 5260 - 6559 Note increased up drag on connections (25K), torque buildup. Sweeps bringing 15% increase in cuttings. Prepare for wiper trip. WOB 8-10, RPM 60-80, SPP 26000, SPM 210 Up 130, Dn 88, Rot 105, Ave ROP = 87 fph AST = 2.46 hrs, ART = 13.59 hrs On btm 6400, Off btm 5500, Max gas 76 units No gain /losses, returns to shaker normal quantity /quality. ECD 10.37 - 10.7 20:30 22:00 1.50 6,559 6,559 PROD1 DRILL CIRC P Pump Hi-vis ! Wt sweep around. Approx 10% increase in cuttings return to shaker. 22:00 23:30 1.50 6,559 6,559 PROD1 DRILL TRIP P PJSM, flow check, POH wiper trip to interval start depth at 4847 ft. 25 / 30K drag 6120 to 5070 ft. No swab /gain ! losses. Correct hole fill. 23:30 00:00 0.50 6,559 6,559 PROD1 DRILL CIRC P Flow check, circ shaker clean. Clays / sands. 180 spm / 1700 psi. WOB 3-6, RPM 60-80, SPM 2550, SPM 206 Up 160, Dn 93, Rot 118, Ave ROP = 80 fph AST = 4.67 hrs, ART = 7.73 hrs On btm 7200, Off btm 6100, Trip gas 291, Conn gas 250, Bkgrnd 32 No gain f losses, returns to shaker normal quantity /quality. ECD 10.35 - 10.71 03/26/2007 00:00 01:00 1.00 6,559 6,559 PROD1 DRILL CIRC P Circ wellbore clean at 4847 ft following wi er tri . 01:00 02:00 1.00 6,559 6,559 PROD1 DRILL TRIP P Flow check, RIH, precaution wash 90 ft to btm. No fill. No do drag, no gain / losses. Correct dis lacement. 02:00 11:00 9.00 6,559 7,067 PROD1 DRILL DDRL P Flow check, orient mwd, commence drill ahead 8-1 /2 hole dretnl 6559 - 7067 ft. Note sands blindin shakers. 11:00 14:30 3.50 7,067 7,067 PROD1 DRILL CIRC NP Circ / cond fluids / re-cip pipe, regain 100% flow across shakers. 14:30 00:00 9.50 7,067 7,550 PROD1 DRILL DDRL P Drill ahead 8-1/2 hole dretnl 7067 - 7550, WOB 3-6, RPM 60-80, SPM 2550, SPM 206 Up 160, Dn 93, Rot 118, Ave ROP = 80 fph AST = 4.67 hrs, ART = 7.73 hrs On btm 7200, Off btm 6100, Trip gas 291, Conn gas 250, Bkgrnd 32 No gain /losses, returns to shaker normal quantity /quality. ECD 10.35 - 10.71 ~..®~.m ~ .~~. ~ 1~~~~ ~f 13 Time Logs ~ ___ _ _ Date Frorn To Dur S. De th E. De th Phase Code Subcode T COM 03/27/2007 00:00 01:00 1.00 7,550 7,606 PROD1 DRILL DDRL P Drill ahead 8-1 /2 hole dretnl 7550 - 7606 ft. 01:00 06:30 5.50 7,606 7,606 PROD1 DRILL CIRC NP Area under phase 3 weather conditions. Circ, wait on weather. 06:30 14:30 8.00 7,606 8,065 PROD1 DRILL DDRL P Weather condition raised to Phase 2. Drill ahead to intermediate csg TD at 8065' MD. 14:30 17:00 2.50 8,065 8,065 PROD1 DRILL CIRC P Pump weighted hi-vis sweep to clean hole in re for short tri . 17:00 22:00 5.00 8,065 806 PROD1 DRILL CIRC NP Area under Phase 3 weather conditions. Circ, wait on weather, fuel and water. 22:00 00:00 2.00 8,065 8;065 PROD1 DRILL TRIP P Recieve fuel, weather lifted, short trip 15 stands 8065' - 6559'. Hole condition ood. 03/28/2007 00:00 00:30 0.50 8,065 8,065 PROD1 DRILL TRIP P Finish short trip. 00:30 03:30 3.00 8,065 8,065 PROD1 DRILL CIRC P Circulate and recip dp w/pumping sweep to condition and clean hole for 7" csg run. CBU x 3. Pump dry-job for TOH. 03:30 06:30 3.00 8,065 8,065 PROD1 DRILL TRIP P Trip out of hole to run 7" intermediate casin . 06:30 11:00 4.50 8,065 8,065 PROD1 DRILL TRIP P Finish TOH, standing back DP. 11:00 12:30 1.50 8,065 8,065 PROD1 DRILL PULD P UD 2 jts HWDP, Jars and NMDC. PJSM, remove radioactive sources from to in tools. 12:30 15:30 3.00 8,065 8,065 PROD1 DRILL PULD P Download MWD. 15:30 17:00 1.50 8,065 8,065 PROD1 DRILL PULD P Finish UD of BHA. 17:00 20:00 3.00 8,065 8,065 PROD1 DRILL RURD P R/U to wash stack, remove lots of cla .Pull wear rin . 20:00 23:00 3.00 8,065 8,065 PROD1 WELCT EORP P pull mouse hole, C/O 4" Rams w! 7" in upper set. MU & install lower test plug, test rams. No test, re-dress test plug, no test, swap w/ upper test plug, successful) test to 3500psi, charted same. 23:00 23:30 0.50 8,065 8,065 PROD1 CASINO OTHR P Finish clearing out pipe shed of BHA components and bringing in csg e ui ment. 23:30 00:00 0.50 8,065 8,065 PROD1 CASINO RURD P C/O elevator links and RU for casing run. 03/29/2007 00:00 02:00 2.00 8,065 8,065 PROD1 CASINO RURD P Rigging up to run casing. 02:00 06:00 4.00 8,065 8,065 PROD1 CASINO RNCS P Running 7" 26# L-80 BTCM Csg @ 2926 ft. 06:00 07:00 1.00 8,065 8,065 PROD1 CASINO CIRC P CBU @ 3 bpm, 400 psi. 07:00 10:00 3.00 8,065 8,065 PROD1 CASIN RNCS P RIH w/Csg f/ 2926' - 5220'. Had tight spot, work through, w/ attempt to break circulation, minimal returns. 10:00 11:30 1.50 8,065 8,065 PROD1 CASIN OTHR NP POOH and LD 2 jts csg to 5140'. Attem t to break circ, no returns. ~~. w_ . ~. _.~~ -~~® ~a~e 6 of 9~~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/29/2007 11:30 14:30 3.00 8,065 8,065 PROD1 CASINC OTHR T PJSM, POOH UD 13 jts csg to 4588'. RU and attempt circulation. Rate to 25 s m and 220 si, no returns. 14:30 20:30 6.00 8,065 8,065 PROD1 CASINC OTHR T POOH w /csg 4167' -3271'. Attempt to break circulation, no returns. Consult w/ town, decide to cunt RIH to TD w/ cs w/ or w/o circulatin abili 20:30 00:00 3.50 8,065 8,065 PROD1 CASIN RNCS P RIH w/ csg 3271' - 5012', unable to circ but hole stays full w/ not pumping. Cont RIH. 03/30/2007 00:00 05:30 5.50 8,065 8,065 PROD1 CASINC RNCS P PU and RIH w/ 7" 26# L-80 BTC-M csg to 8050 ft. (189 jts} Unable to circ w/ running but hole stays full when not um in or movin i e. 05:30 06:00 0.50 8,065 8,065 PROD1 CASINC RURD P PU & MU 7" csg hanger w/ landing jt. 06:00 08:00 2.00 8,065 8,065 PROD1 CASIN RURD P Circ @ 5 spm, 480 psi w/minimal returns w/ recip csg and RU cementers. RU, install cmt head and load lu s. 08:00 11:30 3.50 8,065 8,065 PROD1 CEME DISP P PJSM, perform cmtjob. Pump 10 bbls CW-100, Pressure test lines 3000 psi, pump 10.33 bbls CW-100, pump 30 bbls 11 ppg Mudpush spacer, drop bottom plug, pump 36 bbls 12.5 ppg LiteCrete cmt. Drop top plug and displace w/ 312 bbls 11.5 ppg mud. Bump plug w/ 2000 psi. Bleed off and check flts, OK. Had minimal returns throughout cmt rocedure. 11:30 12:00 0.50 8,065 8,065 PROD1 CEME RURD P Wash up and R/D cementers and release. 12:00 13:00 1.00 8,065 8,065 PROD1 CASIN RURD P R/D csg elevators, pull landing jt and LD. Pump out and drain stack. Set Pack-off. Test to 5000 si. 13:00 15:00 2.00 8,065 8,065 PROD1 WELCT EQRP P Pull mousehole, C/O upper pipe rams f/ 7" to 4". 15:00 16:00 1.00 8,065 8,065 PROD1 MOVE PSIT NP Prep rig for move. Jack and re-center ri over well. 16:00 16:30 0.50 8,065 8,065 PROD1 CASINC OTHR P PJSM w/ Lil Red. Flush 7" x 9 5/8" annulus w/ 120 bbls Seawater and freeze rotect w/ 90 bbls diesel. 16:30 18:00 1.50 8,065 8,065 PROD1 DRILL RURD P Center BOP stack, re-install choke and kill lines, set test plug and prep for ROPE test. 18:00 23:00 5.00 8,065 8,065 PROD1 WELCT BOPE P Test all BOPE w/ 250 psi low & 3500 si hi h. OK. 23:00 00:00 1.00 8,065 8,065 PROD1 DRILL RURD P RD and blow down test equipment. Set wear rin in stack. 03/31/2007 00:00 02:30 2.50 8,065 8,065 PROD1 DRILL RURD P C/O elevator links, rig tongs, top-drive saver sub and grabber dies. Prepare to PU BHA_ 02:30 04:30 2.00 8,065 8,065 PROD1 RIGMN SVRG P Slip and cut drill-line. 04:30 06:00 1.50 8,065 8,065 PROD1 DRILL PULD P P/U and MU BHA #3 w/ 6 1/8" bit. ~._.~...~.~. ~ ~~ s ~<a~+: 7 ~t ~ 9 Time Logs -- - - -- - Date From To Dur S. De th E. Depth Phase_ Code Subcode T _COM __ ~ 03/31/2007 06:00 07:00 1.00 8,065 8,065 PROD1 DRILL PULD P Finish P/U and MU BHA #3. 07:00 09:00 2.00 8,065 8,065 PROD1 DRILL PULD P Test and Program MWD Toot, Shallow test MWD. 09:00 10:00 1.00 8,065 8,065 PROD1 DRILL PULD P P/U (1) NMDC, prep MWD tools for loading radioactive sources. PJSM, Load Sources. 10:00 12:00 2.00 8,065 8,065 PROD1 DRILL PULD P Cont P/U BHA & RIH w/ DP - 4318'. 12:00 15:00 3.00 8,065 8,065 PROD1 DRILL TRIP P Cont to RIH f/ 4318' - 7922'. 15:00 17:00 2.00 8,065 8,065 PROD1 DRILL CIRC P Circ & Condtion mud, 80 spm, SPP 1760 si. 17:00 19:30 2.50 8,065 8,065 PROD1 DRILL DHEO P B/D topdrive, stand back 1 stc for csg test. RU & test csg to 3000 psi. Psi loss of 60 psi, test OK. BD and RD test a ui ment. 19:30 00:00 4.50 8,065 8,065 PROD1 DRILL MILL P Finish RIH,Tag top plug & drill out f/ 7955' - 8027' drlrs depth. PU 158k, SO 83k, Rot 113k, 85 spm & 1800 psi. Little to no cmt on to of lu . 04/01/2007 00:00 03:00 3.00 8,065 8,085 PROD1 DRILL MILL P Drill out shoe track and cmt to 8065'. Cmt quality good. Circ out gas, flow check well. Continue drill-out to 8085' for LOT. 03:00 04:00 1.00 8,085 8,085 PROD1 DRILL DRLG P CBU, check mud and pull into shoe for LOT. 04:00 05:00 1.00 8,085 8,085 PROD1 DRILL LOT P Perform MWE LOT. Achieved 13.18 ppg LOT w/ 11.5 ppg mud in system. grilling plan required higher LOT due to potential res press. Discuss options w! town. Circ while W/O orders. 05:00 06:00 1.00 8,085 8,085 PROD1 DRILL WOOR NP Wait on orders f/plan forward w/ res ect to oor LOT results. 06:00 12:00 6.00 8,085 8,085 PROD1 DRILL CIRC T Order out LCM materials and mud. Begin bui-ding wellbore strengthening mud system w/ circulating. Circulating at 3 bpm & 900 psi spp. Well stable. 12:00 17:00 5.00 8,085 8,085 PROD1 DRILL CIRC T Continue to mix WBS w/ circulating welt. Noted 112 bbl loss while pumping w/mud wt at 11.7. Circulatin at 3 b m, 900 si s 17:00 20:00 3.00 8,085 8,085 PROD1 DRILL OWFF T SI pumps, BD top drive. Fill trip tank, monitor well while finishing mixing WBS materials. 20:00 23:30 3.50 8,085 8,085 PROD1 DRILL CIRC T Finish mixing WBS treatment. Pump down DP w/ LCM @ 1 bpm w/minimal returns. Back down rate to .5 bpm with no losses. Prepare to build Form-a-S ueeze ill. 23:30 00:00 0.50 8,085 8,085 PROD1 DRILL OWFF T Monitor well w/ pumps SI. Watch for flow back. Gained 2.2 bbls. Bldg Form-a-s ueeze itl. ~asc~ ~ ~; ~ 9 ~ ~ Time Logs Da_te____ From To D_ur _ S_ Depth E. Depth Pha e Code _ Subcode - T COM _ _--- 04/02/2007 00:00 06:00 6.00 8,085 8,085 PROD1 DRILL CIRC T Circulate at low rate while working on building Form-a-Squeeze pill. Problems encountered w/ mix hopper, barite settling and plugged lines. Transferring fluid to empty pit to work on line issues. Vary circ rate w/ WBS to counter losses, unsuccessful. Observe losses w/any flow exceeding .5 b m. 06:00 06:30 0.50 8,085 8,085 PROD1 DRILL CIRC T Circ WBS material at low rate w/ re in Forma--s ueeze ill. 06:30 09:30 3.00 8,085 8,085 PROD1 DRILL CIRC T PJSM, pump Form-a-Squeez @ 2 bpm 720 psi. Displace 2 bbls H2O, 28 bbls Formasqueeze, 2 bbls 2 bbls H2O. Displace on bottom, POOH f/ 8085' - 7171'. Lost 5 bbls w/ displacing, gained 9 bbls on TOH. Wellbore breathin . 09:30 12:00 2.50 8,085 8,085 PROD1 DRILL CIRC T Start squeeze. pressure 50 psi f/ 10 min. 80 psi /f 10 min, 100 psi f/ 10 min. 150 psi f/ 10 min, 200 psi f/ 10min. Squeeze 5 bbls @ 5 spm 270 psi. Squeeze 5 bbls @ 6 spm 310 psi. squeeze 5 bbls @ 4spm 290 si. Bleed to 120. 12:00 16:00 4.00 8,085 8,085 PROD1 DRILL CIRC T Cont squeeze procedure. Squeeze 2 bbls @ 4spm 290 psi, bled to 120. Bleed to 0 and flow check, none. Squeeze 5 bbls @ 4spm 310 psi. Hold and monitor pressure. Form-a-set pill appears to be ineffective, unable to hold static pressure. Plan forward is to perform cmt s ueeze on shoe and OH below. 16:00 17:00 1.00 8,085 8,085 PROD1 DRILL CIRC T RIH f/ 7171' - 8085. 17:00 19:30 2.50 8,085 8,085 PROD1 DRILL CIRC T Circulate 1 bpm @ 640 psi, 2 bpm 890 psi, 1/2 bpm 460 psi. Vary rate to observe returns. Lose 70 bbls w/ circulatin . 19:30 20:30 1.00 8,085 8,085 PROD1 DRILL CIRC T BD top drive, monitor well for returns. Well flowed back 7 bbls. 20:30 21:00 0.50 8,085 8,085 PROD1 DRILL TRIP T POOH f/ 8030' - 7554'. Well flowed back 7 bbls. 21:00 22:00 1.00 8,085 8,085 PROD1 DRILL OWFF T Monitor well w/mixing dry job. Well static. 22:00 23:00 1.00 8,085 8,085 PROD1 DRILL TRIP T TOH f! 7554' - 6603'. Empty trip tank and monitor for flow. Well static. 23:00 00:00 1.00 8,085 8,085 PROD1 DRILL TRIP T Continue POOH f/ 6603' - 4892'. 04/03/2007 00:00 05:00 5.00 8,085 8,085 PROD1 DRILL TRIP T POOH, rack back BHA. PJSM, retrieve radioactive sources from MWD, plug in, download and turn off MWD. Rack back all. 05:00 06:00 1.00 8,085 8,085 PROD1 DRILL PULD T Pick up 33 jts 3 1/2" tubing tail w/ mule shoe for cement squeeze rocedure. RIH w/ tb on 4" DP. ~ ~ I Time Logs Date From To Dur 5. Depth E_ Depth Phase Code Subco e T C_O_M____________ ___ 04/03/2007 06:00 07:00 1.00 8,085 8,085 PROD1 DRILL TRIP T RIH w/ 3 1/2" stinger - 1061' 07:00 10:00 3.00 8,085 8,085 PROD1 DRILL TRIP T C/O spinners, Cont RIH w/ 4" DP to 8064'. 10:00 12:30 2.50 8,085 8,085 PROD1 DRILL CIRC T PJSM: Circulate 5 spm & 190 psi w/ WO cementers. 12:30 15:00 2.50 8,085 8,085 PROD1 CEME RURD T RU SLM cementers. 15:00 17:00 2.00 8,085 8,085 PROD1 CEME RURD T PJSM. PT cmt lines, pump cmt per prog. Pumped 20 bbls Mudpush, 26 bbls 12.5 ppg LiteCrete 13 bbls Mudpush. Displace all w/ 71 bbls mud. Break out cmt lines. Cmt in place at 1630. hrs. Open wellbore. Flowback at DP and annulus. Approx 6-8 bbls. 17:00 17:30 0.50 8,085 8,085 PROD1 CEME TRIP T TOOH wet string, rack back 9 stds. to 7133 ft. 17:30 18:00 0.50 8,085 8,085 PROD1 CEME CIRC T Circulate out drillpipe @ 5 bpm w/ 880 si. No cmt to surface. 18:00 19:30 1.50 8,085 8,085 PROD1 CEME SQEZ T Hesitation squeeze. Pump do DP and annulus. Total volume squeezed away in 4 pressure cycles 22 bbls. Initial Squeeze pressure 490 psi, 2nd 370 psi, 3rd 390 psi, 4th 360. Pressure bled back to 290 psi between pump intervals. Hold final ressure w/ WOC. 19:30 00:00 4.50 8,085 8,085 PROD1 CEME WOC T WOC. Bled off pressure w/working pipe, immediate flow back of 2 bbls w/ pressure buildup to 240 psi in 10 minutes. 04/04/2007 00:00 01:00 1.00 8,085 8,085 PROD1 CEME WOC T Prepare for RIH to tag cmt. @ 0130 hrs, SIDP 240 psi, open well and bleed back total of 11 bbls mud w/ fast early rate then taper to 0 flow. Establish circulation to flush cmt out of strin . 01:00 02:00 1.00 8,085 8,085 PROD1 CEME CIRC T Strip in hole 60 ft to place top drive below windwalls. Circulate at 7173 ft to balance out well fluids. Attempt to break out connection revealed severe imbalance. Returns were LCM and some cmt contaminated mud. 02:00 04:00 2.00 8,085 8,085 PROD1 CEME TRIP T Wash to bottom at 8085 ft w/ DP & Tbg to locate TOC and prep for 2nd s ueeze rocedure. Ta no cmt. 04:00 06:30 2.50 8,085 8,085 PROD1 CEME CIRC T Circulate and condition mud even out weight for next squeeze procedure. Trace contaminates to surface. 06:30 07:30 1.00 8,085 8,085 PROD1 WELC OWFF T PJSM, observe well, breathing, flow back 24 bbls, cunt flow check, well static. 07:30 09:30 2.00 8,085 8,085 PROD1 WELCT CIRC T Circ reduced rate, 2 bpm / 650 psi. determine optimum rate with minimum breathing for cmt squeeze #2. No gain / loss, flow back 2 bbls. well static. Time Lois ~ _ Date From To Dur S. De th E. D th Phase Code Subcode T COM 04/04/2007 09:30 _ 13:00 3.50 8,085 8,085 PROD1 CEME CIRC T C/C drilling fluids. 4bpm / 900 psi, no ain /loss. 13:00 16:30 3.50 8,085 8,085 PROD1 CEME PLUG T PJSM, RU cmt equip, batch mix cmt, test lines 2500 psi. Pump 12 bbls Mudpush, 32 bbls cmt - Litecrete 12.5 ppg, 5 bbls Mudpush for ba-anced plug, at 1 bpm. ICP 420 psi. Displace with 70 bbls mud ICP 430 psi, increasing linearly to FCP at 700 psi. Entire job at 1 bpm. No gain /loss with 100% returns. 16:30 17:30 1.00 8,085 8,085 PROD1 CEME TRIP T POH 12 stds to 6935 ft. No swab / losses. Wet strin with no flow. 17:30 18:00 0.50 8,085 8,085 PROD1 CEME CIRC T Drop wiper dart, circ possible residual cmt from DP 18:00 00:00 6.00 8,085 8,085 PROD1 CEME SQEZ T Close in well w/annular preventer, perform hesitation squeeze as follows: Pump 1 bbl, 560 psi, broke back to 350 psi. WOC 2 hrs, SPf 250 psi. Pump 1.2 bbls broke back at 1000 psi to 360 psi. Pump addnl 5 bbls WOC .5 hr SP 430 psi., WOC 2 hrs SPf 360psi. Pump .8 bbl SP 510 psi, WOC 2 hrs SPf 390 psi. Est TOC 7460 ft 625' column . 04/05/2007 00:00 05:30 5.50 8,085 8,085 PROD1 CEME SQEZ T Cont w/Squeeze Operation as follows: Pump .8 bbls, SP 710 psi, WOC 2 hrs, SPf 590 psi. Pump .5 bbls SP 870 psi, WOC 2 hrs, SPf 810 psi. Pump .5 bbls SP 1030 psi, WOC 1 hr SPf 820 si. 05:30 06:00 0.50 8,085 8,085 PROD1 CEME SQEZ 7 Bleed off pressure on DP, 0.5 bbl returned. Monitor well, static. Prepare to circulate and RIH to locate TOC. 06:00 08:30 2.50 8,085 8,085 PROD1 CEME DRLG T PJSM, Wash !circ 6926 - 7950 ft. No tag cmt. Cmt contaminate returns. Treat mud. 08:30 13:00 4.50 8,085 8,085 PROD1 CEME CIRC T C/C fluids 5 bpm / 960 psi. 13:00 13:30 0.50 8,085 8,085 PROD1 WELC OWFF T Flow check, 1 bbl return. Cont flow check, well static. 13:30 16:30 3.00 8,085 8,085 PROD1 CEME TRIP T PJSM, POH 4" DP to 1064 ft at 3-1/2 tb . 16:30 17:00 0.50 8,085 8,085 PROD1 CEME TRIP T RU floor for 3-1/2 tbg handling. 17:00 18:00 1.00 8,085 8,085 PROD1 CEME TRIP T UD 3-1 /2 tbg, break out mule shoe. 18:00 18:30 0.50 8,085 8,085 PROD1 CEME PULD T RU floor to run DP. 18:30 22:00 3.50 8,085 8,085 PROD1 CEME TRIP T PJSM, PU BHA, upload MWD, shallow ulse test. 22:00 22:30 0.50 8,085 8,085 PROD1 CEME PULD T PJSM, Load radioactive sources in MWD. 22:30 23:00 0.50 8,085 8,085 PROD1 CEMEf~ PULD T PU remaining BHA. _. Pie 9'i oaf ~~ Time Logs Date From To Dur S. Depth E Depth__Phase Code Subcode T COM 04/05/2007 23:00 00:00 1.00 8,085 8,085 PROD1 CEME TRIP T RIH w/ 4" DP f/ 612' - 3750': 04/06/2007 00:00 02:00 2.00 8,085 8,085 PROD1 CEME TRIP T TIH to 7850'. Break circulation 1 bpm, increase rate gradually, check mud properties, ramp up rate and wash to 7950, CBU and condition mud. 02:00 03:00 1.00 8,085 8,085 PROD1 CEME CIRC T Circulate and condition mud. Ramp press 1 bpm increments. CBU. At 4 bpm losing mud. Lose 12 bbls total. SD pumps, had 10 bbls return 15 minutes, 2 bbls 15 minutes for 12 bbls total return. 03:00 03:30 0.50 8,085 8,085 PROD1 CEME DRLG T @ 3.5 bpm, wash to bottom. Initial loss of 6 bbls then static w/ circulatin No cmt to ed. 03:30 05:30 2.00 8,085 8,085 PROD1 CEME CIRC T CBU, work rate to 4 bpm. Losses start increasing, back rate to 3.5 bpm. Losses still increasing, back rate to 3, 2.5, 2, 1.5, 1 bpm in attempt to achieve bottoms up. Unable to circulate, lost 69 bbls total. SD pumps monitor for flow back, none. Had cmt contamination in mud. 05:30 06:00 0.50 8,085 8,085 PROD1 CEME OTHR T Work pipe, wait on orders. Order out eline for bond to .Pre to POOH. 06:00 12:00 6.00 8,085 8,085 PROD1 CEME TRIP T PJSM, POH 4" DP to BHA, flow check, well static. Total gain while POH 30 bbls. Gain same at any trip s eed. 12:00 14:00 2.00 8,085 8,085 PROD1 CEME TRIP T Stand back BHA, Remove source RA, LD PWD. 14:00 16:30 2.50 8,085 8,085 PROD1 EVAL WOEQ T WO arrival E-log crew /equip. 16:30 18:00 1.50 8,085 8,085 PROD1 EVALVI~ RURD T PJSM, place E-line equip rig floor, RU same. 18:00 19:30 1.50 8,085 8,085 PROD1 EVAL ELOG T RIH w/ USIT Log, 0 - 4015'. Unable to go further due to gelled mud. POOH to ick u additional wt and rollers. 19:30 00:00 4.50 8,085 8,085 PROD1 EVALVI~ ELOG T PU, 5 1/2" Inline rollers and Wt. RIH w/ USIT Lo t/ TD. Lo in CH. 04/07/2007 00:00 03:00 3.00 8,085 8,085 PROD1 EVALVI~ ELOG T Finish CH USIT Logging. Review logs, xmit same to Anch office. POOH, RD Release SLB wireline. WOO. 03:00 04:30 1.50 8,085 8,085 PROD1 EVAL WOOR T Wait on orders. 04:30 05:30 1.00 8,085 8,085 PROD1 CEMEI~ TRIP T PJSM: PU C/O BHA #6, RIH to circ out clobbered mud. Order out cmt retainer & running tool. Notify cementers of endin s ueeze 'ob. 05:30 06:00 0.50 8,085 8,085 PROD1 CEME RURD T PJSM, MU c/o BHA. 06:00 07:00 1.00 8,085 8,085 PROD1 CEME TRIP T Finish MU c/o BHA and RIH. Stop and circulate at 968' and 2014'. At 2014', bottoms up revealed thick clobbered mud. Decision made to wash and ream remainin stands to bottom. ~ ~ ~E. v~_® ___~._ __.~.~. ~...~. _~.._. P~~;s i~,;~,1 Time Logs Date From__To Dur 5 D~th E_Depth Phale Code Subcode T COM r 04/07/2007 07:00 12:00 5.00 8,085 8,085 PROD1 CEME~ TRIP T CBU @ 3 bpm. Continue wash ream thick contaminated mud out of csg from 2014' - 3821'. CBU x3 @ 3060' w/ ramping rate up to 5 bpm. No losses. 12:00 00:00 12.00 8,085 8,085 PROD1 CEMEP CIRC T Continue wash ream thick contaminated mud in 7" csg from 3821' - 7533'. Stop every 1000' to CBU and treat contaminated mud. Losses va - 3 - +3 bbls. 04/08/2007 00:00 01:30 1.50 8,085 8,085 PROD1 CEMEt~ CIRC T Circulate and wash to 8008'. At conclusion of wash/ ream, total loss 3 bbls mud. Bleed off OA w! start pressure 450 psi. Bleed 10 bbls diesel w/final pressure 100 psi. SI and monitor. 01:30 03:30 2.00 8,085 8,085 PROD1 CEME~ CIRC T CBU x 2 and condition mud w/ flowback of 2 bbls. @ 68 spm (2.75 bpm). SD pumps and monitor well. Flow back 6 bbls 15 min, 2 bbls 15 min for total flow back 8 bbls 30 minutes plus 3 prior for 11 total. PU next stand to wash to bottom. OA ressure 270 si 0330 hrs. 03:30 04:00 0.50 8,085 8,085 PROD1 CEME~ CIRC T Wash ream to bottom at 2 bpm. 0 bbls loss. Circulate at 2 bpm 30 min w/ no loss. Increase rate to 3 bpm and continue CBU. OA pressure 300 si 0400 hrs. 04:00 05:00 1.00 8,085 8,085 PROD1 CEME~ CIRC T Cont CBU @ 3 bpm. Inital loss 6 bbls mid CBU. At bottoms up total losses 3 bbls for 3 bbl flow back. OA ressure 350 si 0500 hrs. 05:00 06:30 1.50 8,085 8,085 PROD1 CEME~ CIRC T Cont CBU w/ ramping pump rate up at 0.5 bpm intervals. Pump 3.5 bpm / 10 min net gain 3 bbl. Pump 4 bpm / 15 min 6 bbls loss. Pump 4.5 bpm 15 min 3 bbl loss. Pump 5 bpm 15 min 1 bbl loss. Pump 93 spm 1 bbl gain, f/ total loss 6 bbls. from start um in . 06:30 07:30 1.00 8,085 8,085 PROD1 CEME~ LOT T PJSM, Perform LOT (8050 MD, 5200 TVD, 11.5 ppg) Resulting in 300 psi surface press = 12.61 EMW. 07:30 08:00 0.50 8,085 8,085 PROD1 CEME~ CIRC T Mix / pump wt pill. 08:00 09:30 1.50 8,085 8,085 PROD1 RIGMN SVRG T S-ip / cut drlg line. 09:30 13:00 3.50 8,085 8,085 PROD1 CEME TRIP T PJSM, flow check, POH 4" DP to BHA. 11 bbl ain, no loss. 13:00 13:30 0.50 8,085 8,085 PROD1 CEME~ TRIP T Flow check, well static. Handle BHA. 13:30 14:30 1.00 8,085 8,085 PROD1 CEME~ TRIP T Dummy run EZSV run tool. Drift hgr / 7" cs . MU EZSV, RIH same. ,~ ~ ~ ~ ~ _~~~._..e.~ ~.. _~. ~.~......._. m~ ~'<;~~ ~3 oaf 13 Time Logs __ Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/08/2007 14:30 23:00 8.50 8,085 8,085 PROD1 CEME TRIP T PJSM, flow check, follow BHA with 4" DP. Slow going, tight clearance. Stop to circulate at 4000 ft. CBU, 2 bpm @ 360 psi. RIH to 7940' Drlrs de th.. 23:00 00:00 1.00 8,085 8,085 PROD1 CEME PACK T RU to circulate and set retainer. Circulate 2 bpm @ 690 psi. CBU, set Halliburton Fast-Drill squeeze packer at 7940. 04/09!2007 00:00 01:00 1.00 8,085 8,085 PROD1 CEME RURD T RU P-test 4" x 7" annulus to 1500 psi, OK. RU cementers, Hold PJSM for s ueeze rocedure. 01:00 02:00 1.00 8,085 8,085 PROD1 CEME OTHR T Prepare for squeeze. Bleed OA. Start pressure 300 psi. Bleed 4 bbls, final press 20 psi. SI, press climbing. Transfer mud & water, prime cmtrs. Perform injection test w/ rig, 2 bpm @ 360 si, in~ect 4 bbls. 02:00 03:00 1.00 8,085 8,085 PROD1 CEME CIRC T P-test cmtrs, Start pumping schedule, unab-e to proceed due to high press (960 psi @ .5 bpm) SD to diagnose problem. Drain and BD cmt lines. OA press 135 psi @ 0230, 250 psi @ 0245. 03:00 05:00 2.00 8,085 8,085 PROD1 CEME CIRC T Diagnose pressure problem. Chk all lines, and valves for obstruction. Able to reverse circulate at normal pressure, Reverse out entire DP & hole vol. Final rates bpm @ 1260 psi. Circulate long way, final rate 5 bpm @ 1020 psi. Noted slug of cement in returns. Swap lines and prepare for cementing operations. OA press 350 0430. 05:00 05:30 0.50 8,085 8,085 PROD1 CEME OTHR T Re-connect cmt lines. Re-prime cementers, P-test cmt lines. Start pumping schedule for squeeze rocedure. OA ress 325 0530. 05:30 09:00 3.50 8,085 8,085 PROD1 CEMEP SOEZ T Close annular BOP, line upon choke. Commence pump cmt plug for squeeze. Hold 320 psi to choke for cmt imbalance. Pump 10 bbls H2o, pump 50 bbls "G", 15.8 ppg cmt, 10 bbl H2o, 16 bbf mud. Sting into EZSV, cont. displace with 70 bbls mud. Sting out EZSV, bleed 4 X 7 annulus. Plug holding. PU 40 ft, string wet. Pump 2 bbls mud to clear DP. DP on vacuum. Linear increase in press as cmt exits DP. ICP = 325 psi, FCP = 885 psi. No peaks / vallys in press curve. No increase at 4 X 7 or 7 X 9-5/8 annulus. 09:00 10:30 1.50 8,085 8,085 PROD1 CEME CIRC T RU /reverse circ clean. 1 bbl cmt contaminate to surface. 10:30 14:30 4.00 8,085 8,085 PROD1 CEME TRIP T PJSM, POH 4" DP for drlg BHA. ~'z~cJ~ ~•^, gat 1~ Time Logs - - - - _ _ . - Date From To Dur S De th E. De th Phase Code Subcode T COM 04/09/2007 14:30 15:00 0.50 8,085 8,085 PROD1 CEME PULD T LD EZSV run tool. Flow check. Well static. 15:00 17:30 2.50 8,085 8,085 PROD1 RIGMN SVRG T Clear floor, service rig, C/O saver sub, service to drv. 17:30 21:00 3.50 8,085 8,085 PROD1 DRILL PULD T PJSM, P/U BHA. C/O Battery and arts in MWD. 21:00 21:30 0.50 8,085 8,085 PROD1 DRILL CIRC T RU, shallow test MWD and motor, OK. 21:30 22:30 1.00 8,085 8,085 PROD1 DRILL PULD T P/U PJSM, load radioactive sources in nuke logging tools. RIH w/ remaining BHA. 22:30 00:00 1.50 8,085 8,085 PROD1 DRILL TRIP T TIH f/ 612' - 4600 ft 04/10/2007 00:00 00:30 0.50 8,085 8,085 PROD1 CEME CIRC T Fill DP and break circulation. 00:30 01:30 1.00 8,085 8,085 PROD1 CEME TRIP T TIH f/ 4607' - 6000', Fill DP. 01:30 03:30 2.00 8,085 8,085 PROD1 CEME TRIP T TIH f! 6000' - 7100'. Prepare to break circulation and wash/ ream to TOP of retainer. 03:30 05:30 2.00 8,085 8,085 PROD1 CEME CIRC T Start Wash into hole to tag cmt and top of retainer. Tag up at 7938' drillers de th. Drill 2 ft cmt to retainer. 05:30 06:30 1.00 8,085 8,085 PROD1 CEME DRLG T Milling retainer, 2-3000 WOB, 80 RPM, 173 Motor RPM. Retainer drilled, flow check. 06:30 12:30 6.00 8,085 8,065 PROD1 CEME DRLG T Drill hard cmt 7943 - 8065 ft. Dense, dried cmt to surface. 12:30 14:00 1.50 8,065 8,065 PROD1 CEME CIRC T Motor failure, no differential press, no footage. C/C fluids, prepare POH for motor. Flow check, back out to drv. 14:00 17:00 3.00 8,065 612 PROD1 CEME TRIP T PJSM, POH 4" DP to BHA. 17:00 19:30 2.50 8,085 8,085 PROD1 CEME TRIP T PJSM -removing nukes, Handle BHA, LD motor, ins ect bit, M/U new motor 19:30 21:30 2.00 8,085 8,085 PROD1 CEME TRIP T Upload MWD, PJSM -loading nukes, RIH with BHA, surface test dretnl ass . 21:30 00:00 2.50 8,085 8,085 PROD1 CEME TRIP T RIH 7934 ft, fill pipe and test tools 04/11/2007 00:00 01:00 1.00 8,085 8,085 PROD1 CEME CIRC T Wash to 8065 ft, 100spm / 2000 psi. No fill. No ain /loss. 01:00 02:00 1.00 8,085 8,085 PROD1 CEME DRLG T Resume drill cmt plug 8065 - 8085 ft. No ain /loss. 02:00 03:30 1.50 8,085 8,085 PROD1 CEME FIT T C/C fluids, in prep for FIT. 5 - 15% formation returns. 03:30 05:30 2.00 8,085 8,085 PROD1 CEME FIT T PJSM, perform FIT /LOT at 8085 MD / 5200 TVD. 11.5 ppg. Resulting in LOT at 760 psi surface press, EMW 14.3 05:30 09:30 4.00 8,085 8,085 PROD1 CEMEP CIRC T R/D test equip, clear floor. Displace with new 11.5 drl fluids. 09:30 10:00 0.50 8,083 8,087 PROD1 DRILL DDRL P PJSM, drill ahead 6-1/8 hole dretnl 8083-8087 ft. v iii f~~ ~ ~f ~~ j I T~ me Logs D From To_ Dur _ S Dew E De th Phase _Code SubcodE T COM_ _ ~ 04/11/2007 10:00 11:30 1.50 8,087 8,087 PROD1 DRILL DDRL P No progress, ROP "0". Vary parameters, attempt to regain ROP. No success. 11:30 12:30 1.00 8,087 8,087 PROD1 DRILL TRIP T PJSM, POH 12 stds, RIH, wash 30 ft to btm. No fill. 12:30 14:00 1.50 8,087 8,087 PROD1 DRILL DDRL T Attempt drill ahead, vary parameters. Ultimate solution, max WOB 5000. Will not drill with 6000. 14:00 16:00 2.00 8,087 8,087 PROD1 DRILL DDRL P Drill ahead. Stop to sample cuttings. Penetrated the Bermuda formation. 16:00 00:00 8.00 8,087 8,087 PROD1 DRILL DDRL P Drill ahead 6-118 hole dretnl 8160-8381 Flow check between connections, well static. WOB 5, RPM 60-80, SPM 100, GPM 248, SPP 2580 Up 175, Dn 83, 100, On btm 7800, Off btm 6720 Cuttings normal quantity !quality. No gain /loss. Well static at connections, Bkgrnd gas ave 93, Conn gas 90 Connection drag normal, no swab / do dra .AST = 3 hrs, ART = 5.15 hrs 04/1212007 00:00 09:30 9.50 8,087 8,747 PROD1 DRILL DDRL P Drill ahead 6-1/$ hole dretnl 8381 - 8747, (TD determined this date 4/12/07 0330 hrs) as per geologist. AST = 1.47 hrs, ART = 5.97 hrs. Background gas 91, Connection gas 25. Peaks 09:30 11:30 2.00 8,747 8,747 PROD1 DRILL CIRC P Pump sweep, C/C drlg fluids. Cuttings normal quantity /quality. Shaker clean. No ain !loss. 11:30 13:00 1.50 8,747 8,747 PROD1 DRILL TRIP P PJSM, flow check, POH wiper trip to 7" shoe 8050 ft. Slight overpull 8381 - 8747. 25K. Precaution back ream. Correct hole fill. Flow check at shoe, RIH, no obstruction /fill. Correct dis lacement. 13:00 22:00 9.00 8,747 8,747 PROD1 DRILL CIRC T Break circ slowly, experience lost circ (85 bbls / .5 hrs) Pull up 100ft, Flow check, well static. Resume circ with dymamic losses 160 bbls hr. Drop to 2 bpm. Treat system with combo grain Calcium Carb 20 pbb. Losses reduced to "0" in 4 hrs. Cont circ at 2 bpm. Well static, total losses 142 BBLS. 22:00 23:30 1.50 8,747 8,747 PROD1 DRILL TRIP P Pump 35 BBL 40 PPB pill. Pull 15 stands (6587) gained 17.5 BBLS. Sto for flow check. 23:30 00:00 0.50 8,747 8,747 PROD1 DRILL OWFF P Flow check. Gained 1.5 BBL in 30 minutes. 04/1312007 00:00 08:00 8.00 8,747 8,747 PROD1 DRILL TRIP P PJSM, flow check, Pump wt pill, POH 30 fpm, monitor gain /loss ali stands. Gain a rox 11 bbls at BHA. 08:00 11:00 3.00 8,747 8,747 PROD1 DRILL PULD P Flow check, handle BHA, download LWD data, LD BHA. e _s~_~_e ~e .~ ~w~_~ ~~ ~~c~~ ~=~ ~1 ~t9 • Time Los _ _ - -~ _ _ --- Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/13/2007 11:00 11:30 0.50 8,747 8,747 COMPZ RIGMN SVRG P Clear floor, prepare for finer run. 11:30 18:30 7.00 8,747 8,747 COMPZ WELCT BOPE P PJSM, flow check, Set test plug, C/O to 4-1/2 rams, test BOPE all components 250 / 3500 psi. All tests successful, no re-tests. Witness waived Mr Chuck Scheve AOGCC. 18:30 20:00 1.50 8,747 8,747 COMPZ CASINC RURD P PJSM, place 4-1/2 liner run equip to ri floor, R/U same. 20:00 23:30 3.50 8,747 8,747 COMPZ CASINC RUNL P PJSM, running liner. Liner not sliding freely after 10 joints. Drained stack to check for obstructions, all clear. Started nudging liner in with topdrive. Liner would not slide at all starting at joint 17. Pushed joints 17-19. Joints 20&27 run w/o centralizers and slid freely. Ran 837' of -iner, PU 50k SO 40k 23:30 00:00 0.50 8,747 8,747 COMPZ CASIN RUNL P PU & MU sealbore extension and liner to acker. 04/14/2007 00:00 01:30 1.50 8,747 8,747 COMPZ CASIN RURD P Change pipe handling equipment from 4-1/2" liner to 4" drillpipe. MU liner hgr / kr. 01:30 09:30 8.00 8,747 8,747 COMPZ CASINC RUNL P Follow pkr with 4" DP, slow going 30 fpm to 7742 ft. A rox 7 bbls loss. 09:30 11:00 1.50 8,747 8,747 COMPZ CASIN CIRC P Wash liner 7742 - 8031 ft, 2 bpm at 610 si. 11:00 12:00 1.00 8,747 8,747 COMPZ CASINC CIRC P Circ while MU cmt hd, rack in pipe skate. 12:00 14:00 2.00 8,747 8,747 COMPZ CASINC RUNL P Wash to 8697. MU cmt hd, wash to TD 8747, no fill. 11 bbls losses. 14:00 17:00 3.00 8,747 8,747 COMPZ CASINC CIRC P Cont C/C fluids for liner cmt. 2 bpm 650 si. 17:00 18:00 1.00 8,747 8,747 COMPZ CEME~ OTHR P PJSM, pump 2 bbls H2o, test lines 4000 psi. Pump 20 bbls Mudpush 14 ppg, pump 29 bbls cmt (G, 15.8 ppg. 1.17 yld), clean lines, drop plug, confirm plug dropped, Schlumberger displace with 98.6 bbls drlg mud. Bump /latch up at 3 bpm 970 psi. Buld to 3603 psi, set hgr. Bleed,. floats holding. ICP = 481 psi 2 bpm, FCP = 970 psi 2 bpm. Re-cip string entire job. No cmt to surface during lacement. Cmt in lace at 19:15 hrs. 18:00 20:00 2.00 8,747 8,747 COMPZ CASINC CIRC P Release from hgr. Circulate 2 bottoms up, clean excess cement out of hole. Approx 8 - 10 bbls contaminated cmt to surface. 20:00 21:00 1.00 8,747 8,747 COMPZ CASIN OTHR P Set pkr, indicated shear at surface. Circ Hgr / Pkr I.D. clean. Final depths = Shoe 8747, Float 8684, Liner hgr 7874, liner kr 7857 ft. 21:00 21:30 0.50 8,747 8,747 COMPZ CEME~ RURD P Lay down cement head / cmt equip, and two sin les. -----_ - ----I __...._...... _ __e~__.~._.._._ . ~'aqe 1 ~ of 19 i • Time Logs Date From To Dur S De th E_ Depth Phase Code Subcode T COM _ _ 04/14/2007 21:30 00:00 2.50 8,747 8,747 COMPZ CEME~ CIRC P Continue to circulate hole clean while prepare to pull drill pipe out of hole. Organize pipe shed for laying down drill i e. PU 128k SO 70k 04/15/2007 00:00 01:00 1.00 8,747 8,747 COMPZ CEME~ CIRC P Circulate hole clean 01:00 09:30 8.50 8,747 8,747 COMPZ CEME TRIP P Pump dry job, trip out of hole, laying down drill i e 09:30 10:30 1.00 8,747 8,747 COMPZ CASINC RURD P UD liner run tools. 10:30 11:30 1.00 8,747 8,747 COMPZ DRILL TRIP P RIH 4" DP from mast for lay down. 11:30 13:00 1.50 8,747 8,747 COMPZ RIGMN SVRG P PJSM, Slip / cut drlg line. 13:00 15:00 2.00 8,747 8,747 COMPZ DRILL TRIP P PJSM, POH UD remaining 4" DP, HWDP and cement head. 15:00 17:30 2.50 8,747 8,747 COMPZ WELCT BOPE P PJSM, Pull wear ring, set test plug, change to 3-1/2 rams, test rams /door seals 250 / 3500 si. 17:30 19:30 2.00 8,747 8,747 COMPZ RPCOh RURD P PJSM, RU for 3-1/2 completion. 19:30 21:30 2.00 8,747 8,747 COMPZ RPCOh TRIP P PJSM, RIH with 3-1/2 completion to 925'. Stopping before running in Chemical In'ection Mandrel. 21:30 22:30 1.00 8,747 8,747 COMPZ RPCOR RCST P Attempt to test packer. String does not weight enough to offset pressure. Called Engineer to discuss options. Postponing test until completion fully run. 22:30 00:00 1.50 8,747 8,747 COMPZ RPCO TRIP P Resume running in hole with 3-1/2 tubing and chemical injection mandrel control line. 04/16/2007 00:00 05:30 5.50 8,747 8,747 COMPZ RPCO TRIP P Running completion 05:30 07:00 1.50 8,747 8,747 COMPZ RIGMN RGRP T Repair casing tongs. 07:00 10:30 3.50 8,747 8,747 COMPZ RPCOh TRIP P Resume RIH 3-1/2 completion string, normal downdrag, correct dis lacement. 10:30 13:30 3.00 8,747 8,747 COMPZ RPCOh HOSO P Idle pump at 300 psi, stab in SBE with seal assy, confirmed stab in with press rise. Stop pump, bleed. Space out, determine pups needed to land. MU pups, tbg hgr , Idg jt. Connect inj line, test /hold ress on line. 13:30 16:00 2.50 8,747 8,747 COMPZ RPCOh CIRC P PJSM, Displace wellbore fluids with seawater, spot CRW-132 corrosion inhibitor to annulus (Liner hgr to lower GLM 16:00 17:00 1.00 8,747 8,747 COMPZ RPCOti HOSO P Sting in SBE, drain stack, land tbg hgr. RILDS. Final depths Seal assy 7875, D nipple 7831, Sliding sleeve 7750, mandrel 7664, GLM 7052, Mandrel 6970, GLM 5389, GLM 3184, DS ni le 523, Tb H r 25.9 ~~ ~- ~~e_ ~a~~~ 4~ sat ~~ Time Logs i Date From __ _ _ To Dur S. Depth E De th Phase Code Subcode -- T COM - . - _ 04/16/2007 _ --T 17:00 19:30 2.50 8,747 8,747 COMPZ RPCO __ DHEO P - PJSM, Press tbg to 2500 psi / 15 min (annulus open), bleed tbg to 1500 psi. While hold 1500 psi on tbg, press 3-1/2 X 7 annulus to 2500 psi / 30 min as liner / csg test. All tests successful. No re-tests. Bleed tbg to "0" psi shearing DKV. Tbg / ann equalize. RU and circ tbg to annulus, confirm DKV full o en. 19:30 21:30 2.00 8,747 8,747 PROD1 RPCOh OTHR P Set backpressure valve 21:30 00:00 2.50 8,747 8,747 PROD1 RPCOti NUND P PJSM, nipple down stack 04/17/2007 00:00 01:30 1.50 8,747 8,747 PROD1 RPCOh NUND P Terminate chemical injection line and ni le ada ter. 01:30 06:00 4.50 8,747 8,747 PROD1 RPCO NUND P Break down tree valves and reassemble per Drill Site Operator. Orient tree /win valves. 06:00 07:00 1.00 8,747 8,747 PROD1 RPCOh SFEQ P Pull back pressure valve, set tubing test plug, test tree 250/5000 psi for 10 minutes. 07:00 08:00 1.00 8,747 8,747 PROD1 RPCOh NUND P Pull Tubing test plug, rig up to freeze protect, PJSM with Little Red, ressure test lines 08:00 10:00 2.00 8,747 8,747 PROD1 RPCO FRZP P Freeze protect well, pump 110 BBLS down inner annulus, final pressure 1300 si. U-tube for 1 hour 10:00 12:00 2.00 8,747 8,747 PROD1 RPCOti NUND P Set back pressure valve, rig down, move off well. NORDIC RIG 3 RELEASED THIS DATE 1200 HRS F'~c;~ tJ ref i~ • Halliburton Company Survey Report c umpany: ConocoPhillips Alaska Inc . Date: 4/27/2007 Tame: 10:17:21 - __ Page: I icl<l: Kuparuk River Unit Co -ordinate(NE) Raferrnrc: Well: 2N-311, True North tine: Kuparuk 2N Pad Vertical(T~'D)Re fereucc: 2N-311A:149.4 ~~ell: 2N-311 Section (VS)Reference:_ Well (O.OON,O.OOE,11.40Azi) Wellpath: 2N-311A - _ ___-__ Survey Calculation Method: Minimum Curvat ure Db: Oracle Field: Kuparuk River Unit North Slope Alaska j United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 2N-311 Slot Name: Well Position: +N/-S 10.41 ft Northing: 5911980.38 ft Latitude: 70 10 13.698 N +E/-W 43.99 ft Easting : 460976.28 ft Longitude: 150 18 50.646 W Position Uncertainty: 0.00 ft Wellpath: 2N-311A Drilled From: 2N-311 1032049101 Tie-on Depth: 2946.24 ft Current Datum: 2N-311A: Height 149.40 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 3/10/2007 Declination: 23.15 deg Field Strength: 57578 nT Mag Dip Angle: 80.66 deg ~, 4 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg i 30.10 0.00 0.00 11.40 ~I Survey Program for Definitive Wellpath Date: 4/27/2007 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name ft ft 149.40 2946.24 2N-311 (149.40-8656.40) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2999.00 8700.39 2N-311A (2999.00-8 700.39) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey M11D Incl. Azim T~'D Sys TVD N/S E~~~ MapN MapE Tool ft ' deg deg ft ft ft ft ft ft 11 +I 149.40 0.00 0.00 149.40 0.00 0.00 0.00 5911980.38 460976.28 FR-AK-CAZ-SC I MWD 169.40 0.20 68.00 169.40 20.00 0.01 0.03 5911980.39 460976.31 MWD+IFR-AK-CAZ-SC 263.40 0.30 24.00 263.40 114.00 0.30 0.28 5911980.68 460976.57 MWD+IFR-AK-CAZ-SC 393.32 1.60 6.82 393.30 243.90 2.41 0.64 5911982.79 460976.93 MWD+IFR-AK-CAZ-SC 485.15 2.59 7.91 485.07 335.67 5.74 1.08 5911986.11 460977.39 MWD+IFR-AK-CAZ-SC 576.71 4.03 10.42 576.47 427.07 10.95 1.94 5911991.32 460978.28 MWD+IFR-AK-CAZ-SC ' 670.28 7.64 13.64 669.54 520.14 20.23 4.00 5912000.59 460980.39 MWD+IFR-AK-CAZ-SC 763.49 11.90 11.59 761.38 611.98 35.68 7.40 5912016.01 460983.86 MWD+IFR-AK-CAZ-SC 857.24 13.63 12.31 852.81 703.41 55.94 11.70 5912036.25 460988.26 MWD+IFR-AK-CAZ-SC 950.05 16.79 11.03 942.36 792.96 79.79 16.59 5912060.07 460993.28 MWD+IFR-AK-CAZ-SC i 1052.49 19.00 8.82 1039.83 890.43 110.79 21.98 5912091.05 460998.83 MWD+IFR-AK-CAZ-SC 1146.94 20.80 10.90 1128.64 979.24 142.46 27.51 5912122.68 461004.52 MWD+IFR-AK-CAZ-SC 1239.17 24.92 12.07 1213.61 1064.21 177.55 34.67 5912157.73 461011.86 MWD+IFR-AK-CAZ-SC 1336.46 25.95 9.47 1301.47 1152.07 218.59 42.46 5912198.73 461019.86 MWD+IFR-AK-CAZ-SC 1431.48 29.06 6.84 1385.74 1236.34 262.03 48.63 5912242.13 461026.26 MWD+IFR-AK-CAZ-SC 1526.23 32.88 9.47 1466.98 1317.58 310.26 55.61 5912290.32 461033.48 MWD+IFR-AK-CAZ-SC 1622.24 34.68 9.61 1546.77 1397.37 362.90 64.46 5912342.91 461042.60 MWD+IFR-AK-CAZ-SC 1715.70 37.24 9.34 1622.42 1473.02 417.03 73.49 5912396.99 461051.91 MWD+IFR-AK-CAZ-SC 1810.47 40.05 9.30 1696.43 1547.03 475.43 83.07 5912455.33 461061.79 MWD+IFR-AK-CAZ-SC 1903.40 43.06 10.54 1765.96 1616.56 536.14 93.71 5912515.97 461072.74 MWD+IFR-AK-CAZ-SC 1999.88 46.48 11.13 1834.45 1685.05 602.86 106.49 5912582.62 461085.86 MWD+IFR-AK-CAZ-SC 2093.80 48.51 10.74 1897.90 1748.50 670.84 119.62 5912650.53 461099.34 MWD+IFR-AK-CAZ-SC 2188.48 51.21 9.85 1958.93 1809.53 742.05 132.54 5912721.66 461112.63 MWD+IFR-AK-CAZ-SC 2282.48 52.07 9.34 2017.27 1867.87 814.73 144.82 5912794.27 461125.29 MWD+IFR-AK-CAZ-SC i 2376.81 55.51 8.96 2072.99 1923.59 889.86 156.92 5912869.33 461137.77 MWD+-FR-AK-CAZ-SC 2472.51 55.99 9.08 2126.85 1977.45 967.98 169.32 5912947.38 461150.57 MWD+IFR-AK-CAZ-SC ~I 2567.05 58.17 7.07 2178.23 2028.83 1046.55 180.45 5913025.88 461162.11 MWD+IFR-AK-CAZ-SC 2662.34 58.57 8.08 2228.20 2078.80 1126.97 191.15 5913106.24 461173.22 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/27/2007 Time: 10:17:21 Yagec Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 2N-311, True North Site: Kuparuk 2N Pad Vertical (I'VD) Reference: 2N-311A: 149.4 Nell: 2N-311 Section(VS)Reference: Well (O.OON,O.OOE,11':40Azi) ~Vellpath: 2N-311A Survey Calculation Method: MinimumCurvature Db: Oracle Sun~cv - ___ A1D Incl Azim "I'VD S}, 1l'D N/S E/W MapN ~IaIrE Tool ft deg. `deg ft ft ft ft ft ft 2756.43 58.43 8.81 2277.36 2127.96 1206.33 202.93 5913185.53 461185.41 MWD+IFR-AK-CAZ-SC 2851.12 57.85 8.36 2327.34 2177.94 1285.85 214.94 5913264.98 461197.82 MWD+IFR-AK-CAZ-SC j 2946.24 58.03 8.48 2377.83 2228.43 1365.59' 226.74 5913344.65 461210.04 MWD+IFR-AK-CAZ-SC I c 2999.00 57.71 ~ 8.88 2405.89 2256.49 1409.76 233.48 5913388.78 461217.01 MWD+IFR-AK-CAZ-SC 3070.28 54.11 11.78 2445.85 2296.45 1467.82 244.03 5913446.78 461227.85 MWD+IFR-AK-CAZ-SC 3161.95 52.89 16.56 2500.39 2350.99 1539.24 262.04 5913518.09 461246.23 MWD+IFR-AK-CAZ-SC 3260.38 53.64 20.55 2559.28 2409.88 1613.99 287.14 5913592.71 461271.71 MWD+IFR-AK-CAZ-SC 3355.04 55.82 22.29 2613.94 2464.54 1685.92 315.38 5913664.49 461300.32 MWD+IFR-AK-CAZ-SC 3450.70 57.85 23.07 2666.27 2516.87 1759.80 346.26 5913738.20 461331.58 MWD+IFR-AK-CAZ-SC 3545.00 59.91 23.10 2715.00 2565.60 1834.06 377.91 5913812.29 461363.61 MWD+IFR-AK-CAZ-SC 3640.77 60.18 23.16 2762.82 2613.42 1910.37 410.51 5913888.42 461396.59 MWD+IFR-AK-CAZ-SC 3736.25 60.68 21.95 2809.94 2660.54 1987.06 442.36 5913964.93 461428.83 MWD+IFR-AK-CAZ-SC ~ 3830.89 60.58 22.48 2856.36 2706.96 2063.41 473.54 5914041.12 461460.41 MWD+IFR-AK-CAZ-SC i ~ 3925.82 62.22 21.86 2901.80 2752.40 2140.59 504.99 5914118.13 461492.25 MWD+IFR-AK-CAZ-SC 4021.16 61.52 21.21 2946.75 2797.35 2218.80 535.85 5914196.17 461523.51 MWD+IFR-AK-CAZ-SC 4116.06 61.45 22.23 2992.05 2842.65 2296.27 566.71 5914273.47 461554.77 MWD+IFR-AK-CAZ-SC ~ 4211.25 62.17 22.14 3037.02 2887.62 2373.95 598.39 5914350.98 461586.84 MWD+IFR-AK-CAZ-SC 4305.77 60.75 21.35 3082.18 2932.78 2451.08 629.15 5914427.94 461618.00 MWD+IFR-AK-CAZ-SC 4400.68 61.41 21.84 3128.08 2978.68 2528.32 659.73 5914505.01 461648.97 MWD+IFR-AK-CAZ-SC 4496.23 61.92 21.85 3173.43 3024.03 2606.38 691.02 5914582.91 461680.67 MWD+IFR-AK-CAZ-SC 4591.60 61.31 23.79 3218.77 3069.37 2683.71 723.56 5914660.06 461713.60 MWD+IFR-AK-CAZ-SC 4686.37 60.53 23.42 3264.83 3115.43 2759.60 756.72 5914735.78 461747.15 MWD+IFR-AK-CAZ-SC 4780.04 60.84 22.44 3310.69 3161.29 2834.82 788.54 5914810.82 461779.35 MWD+IFR-AK-CAZ-SC 4874.18 60.88 21.70 3356.53 3207.13 2911.02 819.44 5914886.85 461810.64 MWD+IFR-AK-CAZ-SC 4972.53 60.25 23.85 3404.87 3255.47 2989.99 852.59 5914965.65 461844.19 MWD+IFR-AK-CAZ-SC i 5067.59 59.89 25.42 3452.30 3302.90 3064.88 886.92 5915040.34 461878.91 MWD+IFR-AK-CAZ-SC 5161.70 60.65 24.85 3498.97 3349.57 3138.86 921.63 5915114.14 461914.00 MWD+IFR-AK-CAZ-SC 5256.96 61.28 23.19 3545.21 3395.81 3214.93 955.53 5915190.03 461948.28 MWD+IFR-AK-CAZ-SC I 5351.37 62.34 20.95 3589.81 3440.41 3292.04 986.79 5915266.97 461979.93 MWD+IFR-AK-CAZ-SC !~ 5447.01 62.24 20.89 3634.28 3484.88 3371.13 1017.02 5915345.89 462010.57 MWD+IFR-AK-CAZ-SC 5542.69 61.32 20.85 3679.53 3530.13 3449.91 1047.05 5915424.50 462041.01 MWD+IFR-AK-CAZ-SC 5637.51 60.33 20.00 3725.75 3576.35 3527.49 1075.95 5915501.93 462070.30 MWD+IFR-AK-CAZ-SC 5732.83 60.19 20.66 3773.03 3623.63 3605.10 1104.70 5915579.38 462099.45 MWD+IFR-AK-CAZ-SC 5828.15 59.97 22.07 3820.58 3671.18 3682.03 1134.80 5915656.15 462129.94 MWD+IFR-AK-CAZ-SC 5923.21 61.25 22.36 3867.23 3717.83 3758.71 1166.11 5915732.66 462161.64 MWD+IFR-AK-CAZ-SC 6018.67 60.62 24.28 3913.61 3764.21 3835.33 1199.14 5915809.10 462195.06 MWD+IFR-AK-CAZ-SC 6113.74 59.91 24.29 3960.76 3811.36 3910.57 1233.09 5915884.16 462229.40 MWD+IFR-AK-CAZ-SC i 6208.64 61.06 23.30 4007.51 3858.11 3986.14 1266.40 5915959.54 462263.10 MWD+IFR-AK-CAZ-SC i 6303.15 60.46 22.88 4053.68 3904.28 4062.00 1298.75 5916035.23 462295.83 MWD+IFR-AK-CAZ-SC 6398.49 59.62 22.58 4101.29 3951.89 4138.18 1330.66 5916111.24 462328.13 MWD+IFR-AK-CAZ-SC 6492.29 58.66 21.92 4149.41 4000.01 4212.70 1361.15 5916185.60 462359.00 MWD+IFR-AK-CAZ-SC 6587.31 58.87 19.38 4198.68 4049.28 4288.72 1389.80 5916261.46 462388.04 MWD+IFR-AK-CAZ-SC 6683.32 57.37 18.30 4249.39 4099.99 4365.88 1416.13 5916338.47 462414.77 MWD+IFR-AK-CAZ-SC 6778.06 56.47 16.65 4301.10 4151.70 4441.59 1439.97 5916414.05 462439.00 MWD+IFR-AK-CAZ-SC ~ 6871.83 54.99 14.28 4353.91 4204.51 4516.26 1460.65 5916488.60 462460.05 MWD+IFR-AK-CAZ-SC 6968.77 53.95 12.20 4410.25 4260.85 4593.04 1478.72 5916565.29 462478.52 MWD+IFR-AK-CAZ-SC 7064.03 51.95 10.50 4467.64 4318.24 4667.57 1493.70 5916639.73 462493.88 MWD+IFR-AK-CAZ-SC 7160.16 50.60 7.92 4527.78 4378.38 4741.59 1505.72 5916713.67 462506.28 MWD+IFR-AK-CAZ-SC 7254.39 49.38 4.30 4588.38 4438.98 4813.33 1513.42 5916785.36 462514.35 MWD+IFR-AK-CAZ-SC 7349.60 47.90 2.14 4651.29 4501.89 4884.66 1517.44 5916856.67 462518.74 MWD+IFR-AK-CAZ-SC 7444.73 45.78 357.60 4716.38 4566.98 4954.02 1517.34 5916926.02 462518.99 MWD+IFR-AK-CAZ-SC j I' 7537.12 44.01 354.00 4781.84 4632.44 5019.03 1512.59 5916991.05 462514.58 MWD+fFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inca Date: 4/27/2007 Time: 10:17;21 Page: 3 FicW': Kuparuk River Unit Co-ordinate(NE) kcfc~ence: Well: 2N-311, True North site: Kuparuk 2N Pad Vertical (TVD) Reference: 2N-311A: 149.4 ~~ell: 2N-311 Section(VS)Reference: We!1(O.OON,O.OOE,11.40Azi) weupath: 2N-311A Survey Calculation Method: Minimum Curvature Db: Oracle __ Survcv MD Tncl ,~ziin TVD Sys TVT) N/S El~V MapN ft deg deg ft ft ft ft ft 7634.34 42.55 350 .75 4852 .62 4703. 22 5085 .07 1503 .78 5917057.13 7729.21 41.77 345 .71 4922 .96 4773. 56 5147 .37 1490 .82 5917119.49 7824.76 42.04 340 .00 4994 .10 4844. 70 5208 .30 1472. 01 5917180.51 7919.47 41.32 336 .76 5064 .85 4915. 45 5266 .84 1448. 83 5917239.16 7988.35 39.92 332 .08 5117 .14 4967. 74 5307 .27 1429. 50 5917279.69 8069.74 39.48 329 .19 5179 .77 5030. 37 5352 .57 1404. 02 5917325.12 8169.78 39.05 323 .73 5257 .25 5107. 85 5405 .31 1369. 07 5917378.03 8265.89 40.16 324 .11 5331 .29 5181. 89 5454 .83 1332. 99 5917427.73 8359.92 ~ 39.59 324 .84 5403 .46 5254. 06 5503 .89 1297. 97 5917476.96 I 8439.14 38.26 324 .87 5465 .09 5315. 69 5544 .59 1269 .31 5917517.80 8550.98 39.37 325 .38 5552 .23 5402. 83 5602 .10 1229 .23 5917575.52 8645.85 38.78 325 .33 5625 .88 5476. 48 5651 .30 1195 .24 5917624.88 8700.39 38.51 325 .79 5668 .47 5519 .07 5679 .39 1175 .98 5917653.07 t' 8747.00 38.51 325 .79 5704 .95 ~ 5555 .55 5703 .39 1159 .66 5917677.15 MapE Tnol ft __ -- 462506.11 MWD+IFR-AK-CAZ-SC ~ 462493.47 MWD+IFR-AK-CAZ-SC 462474.98 MWD+tFR-AK-CAZ-SC i 462452.10 MWD+IFR-AK-CAZ-SC 462432.99 MWD+IFR-AK-CAZ-SC 462407.74 MWD+IFR-AK-CAZ-SC 462373.07 MWD+IFR-AK-CAZ-SC 462337.25 MWD+IFR-AK-CAZ-SC 462302.48 MWD+IFR-AK-CAZ-SC 462274.04 MWD+IFR-AK-CAZ-SC 462234.26 MWD+IFR-AK-CAZ-SC 462200.52 MWD+IFR-AK-CAZ-SC 462181.41 MWD+IFR-AK-CAZ-SC ~ 462165.22 '• PROJECTED to TD • ~.-- -~_ ~~-~C~C~Phillips Als~t~, n+~. KRU 2N-311A . .. ------- 2N-311 A __ ______ - TU81NG ~ - - -~ - (0-7908, OD:3.500, ~ ID:2.992) RODUCTION (a6oso, OD:7.000, Wt:26.00) LOCATOR (78747875, OD:5.000) APL 501032049101 Welf T e: PROD An le TS: d SSSV T e: NIPPLE Ori Com letion: 4/17/2007 An le TD: d Annular Fluid: Last W/O: Rev Reason: PERFS, GLV C/O Reference L 26' RKB Ref L Date: Last U ate: 5/17/2007 Last Ta : 8636' RKB TD: 8745 ftKB I ast Tan nate~ 5/19/90n7 Max Hole Annle• o deo (a7 Tubing String -.TUBING `Size Top Bottom _ TVD VVt Grade Thread :i 500 ~ 0 ; 4OS ; 408 ~ 9 .i0 ~ ~-80 ElJEBrdM~D _ Perforations Strmma Interval TVD Zone Status Ft SPF Date _ T e _ Comment 8240 - 8255 8240 - 8255 15 6 5/8/2007 (PERFS H SD JH 2506 Charges, 60 - __ " _ _ decd phase _ _ _Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 3184 3184 CAMCO KBMG DMY 1.0 BK-5 0.000 0 4/16/2007 2 5389 5389 CAMCO KBMG DMY 1.0 BK-5 0.000 0 4/16/2007 3 7052 7052 CAMCO KBMG DMY 1.0 BK-5 0.000 0 5/13/2007 4 - 7664 7664 CAMCn - KBMG OV 1.0 BEK 0.313 0 5/13/2007 In'ection Mandreis/Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 5 6970 6970 CAMCO KBMG-LTS DMY 1.0 BK-5 0.000 0 4/16/2007 1 1. CHEMICAL INJECTION MANDREL -- - -. Other iu s, a ui ., etc.} COMPLETfON _ - Depth ~ TVD ~ TYPe I Description I ID ~ 26 26 HANGER FMC TUBING HANGER 4.500 3000 3000 KOP SIDETRACK KICK OFF POINT 6.500 7750 7750 SLEEVE BAKER DS / CMU SLIDING SLEEVE 2.812 7831 7831 NIP CAMCO'D' NIPPLE 2.750 7874 7874 LOCATOR BAKER LOCATOR SUB 2.990 7875 7875 .Other (plug De th TVD SEAL s, equip., T e BAKER SEAL ASSEMBLY etc.) -LINER DETAIL Descri tion 2.950 ', ID 7857 7857 PACKER BAKER "C-2" ZXP LINER TOP PACKER 5.250 7875 7875 HANGER BAKER FLEX-LOCK TUBING HANGER 4.410 7885 7885 PBR/SBR BAKER PBR/SBR 4.000 General Notes LINER (7855-8745, OD:4.500, Wt:12.60) - _ _ ~ _ _ .Casing String -ALL CASINGS • 2N-311A Well Events Summary DATE Summary 5/7/07 TAGGED TD @ 8379' RKB. REPLACED DCK WITH DV @ 7664' RKB. MIT TBG 3500 PSI WITH 1500 PSI ON IA. MIT IA 3500 PSI WITH 1500 PSI ON TBG. DRIFTED TBG WITH 2.5" x 10' DUMMY TO 8347' WLM; TARGET DEPTH 8240 TO 8255'. 5/8/07 PRE-FRAC PERFORATE INTERVAL 8240'-8255' W/ HSD HJ 2506 CHARGES, 6 SPF, / 60 DEGREE PHASING. WHP 3000 PSI PRIOR TO PERFORATION -DOWN TO 900 PSI WHEN BACK AT SURFACE 5/9/07 DRIFT TUBING W/ 2.7" CENT TO 8300' SLM. PERFORMED SBHPS @ 8250' = 2750 psi @ 140 deg F & GRADIENT STOP AT 8100'. 5/10/07 PUMPED T3 SAND FRAC USING 50# XL GEL AND 16/20 CARBOLITE PROPANT. PUMPED A TOTAL OF 2601 BBLS OF WATER AND 2786 BBL SLURRY W/ 179,211# OF 16/20. PLACED 154025# (88% OF DESIGN) BEHIND PIPE BEFORE PLUGGING OFF THE SURFACE EQUIPMENT. WELL NOT FREEZE PROTECTED. 5/11/07 FCO frac sand from surface with SSW and Duovis sweeps to hard tag at 8633'. Bullhead 25 Bbls. 5/12/07 TAG BOTTOM @ 8636' RKB, EST. 381' RATHOLE. IN PROGRESS. 5/13/07 PULLED DV & SET 1" DV @ 7052' RKB, PULLED DV & SET 1" 5/16 OV @ 7664' RKB. JOB COMPLETE. 11-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-311A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 2,946.24' MD Window /Kickoff Survey 2,999.00' MD (if applicable) Projected Survey: 8,747.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ,Z.01-d Si ned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~Z~~- l~~ ~I~t10~C~~'11~~1 S TRANSMITTAL FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7m Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: 2N-311A Permit: 206-179 DATE: 05/08/2007 Kuparuk River Unit 2N-311A Tarn Field North Slope, Alaska CDROM and Hardcopy report ~~~ /~, Final Well report, Epoch Mudlogging, Inc.; Browne, Bietting, Isbon ; , 2007 Equipment and Crew; well details; geological data,drilling data; daily reports, pressure/formation strength data Formation Logs Co%rp/ots Formation log (MD) and (TVD), LWD Lithology log (MD) and (TVD); Gas Ratio (MD) and (TVD) Dri//ing/ogs Drilling Dynamics (MD) and (TVD) Please check off each item as received, promptly sign and return the transmittal to address below. data recipients: Al/ data is confrdentia/until State ofA/aska desir7nated AOGCC re%ase date CC: CPAI 2N-311A well data transmittal folder MAY p 8 2007 Receipt: Date: ~iaska Oii & Gas Cons. Commissi©n Anchorage -. ~~ GIS-Technical Data Management ~ ConocoPhillips I Anchorage, A/aska I Ph: 907.265.6947 Sandra. D. L emkela~Conocophillips. com c7U(o -- !'~-~ ~- C 5 t l ~- ~, ~; ,, ~Ch1~1111~~~'~~r APR 2 0 1_.0~!~l .~9,~..d~.; ~a ~1~a 1~~'~„a ~?f)il~.: rt3"y .t'%li ~.hC;ta Schlumberger-DCS ~ ~ e fi~~a 2525 Gambell Street, Suite 400 ~~ Anchorage, AK 99503-2838 ATTN: Beth r= ~~C--1 Well Job # Log Description N0.4219 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Date BL Kuparuk Color CD 04/20/07 1A-10 11638846 INJECTION PROFILE 04/05107 1 2L-313 11628996 LDL 04/08/07 1 1D-137 11628997 INJECTION PROFILE 04109/07 1 2N-31.1A NIA USIT 04/06/07 1 2N-3376 11638852 SCMT 04111107 1 1J-184 11638853 SBHP 04112/07 1 1 H-10 11638844 GLS 03/20107 1 2W-03 11649957 MEM LDL/PPROF 04/10/07 1 1 E-112 11638856 INJECTION PROFILE 04114107 1 1J-156 11638857 INJECTION PROFILE 04115107 1 1J-127 11638859 INJECTION PROFILE 04117/07 1 1J-105 11628994 USIT 04/06107 1 1J-164• 11638858 INJECTION PROFILE 04116/07 1 1J-164 ~ 11638860 INJECTION PROFILE 04/17/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. !J~ Re: 2N-311A (206-179) change of plan to top set • C~ Subject: Re: 2N-3 t 1A (206-179) change of plan to top set From: Thomas Maunder <tom_maundcr~admin.state.ak.us> Date: Fri, 16 Mar 2007 13:33:02 -0800 To: "Billingsley, Tim," <Tim.A.Billingslc_ti~crc~~nocophillips.com> C'C: ,~ l~h~~mas, Ran~i~ I." -1'an~iy.L.Thonrl,~ ci~c~~n~~cophiilii».~~_~m . "f3rink. Jason A" lason.F3rinl:~r~i~nucophillips.com>, "Tonic, Maureen" ~-~~1aurccn. [,~~i~i~•u.c~~noc~~i~hillii~s.cr~n~ Tim, Thanks for the update. Based on the information you have, top setting sound prudent. I will place a copy of this message in the file. Nothing further is needed. Call or message with any questions. Tom Maunder, PE AOGCC Billingsley, Tim A wrote, On 3/16/2007 1:25 PM: Tom, As we discussed on the phone, recently been obtained offset pressure information for the drilling of 2N-311A (APD #206-179) indicates we may need a 13.3 ppg mud or slightly higher to control the reservoir as opposed to the 10.7 ppg that we had planned. Therefore, instead of attempting to drill all the way to TD with a single 8-1/2" production hole, we have decided to top set 7" casing at appx 8060'MD. Then drill a 6-1/8" hole through the high pressure Bermuda pay interval to TD of 8620' MD: Here is a revised schematic which shows the 7" top set and the 4-1/2" liner to TD instead of the tapered 7" x 4-1/2" long string: «2N-311A Topset Schematic rev 3-16-07.vsd» The revised 7" intermediate and 4-1/2" liner cement volumes are being finalized and we will send those volumes to you in a follow-up E-mail, probably Monday. Tim 1 of 1 3/16/2007 1:33 PM C~ 2N-311A SIDETRACK TOPSET Top of Cement KO plug @ 2774' MD 9-SIS" 40# L80 @ 2999' MD Sidetrack KOP @ +/- 3000' MD, 2406' TVD \\ \\ ,•-~ , , - +v-nc~+~v-P~ i 1 I f ~ Circulate corrosion inhibitor before landing tubing hanger. Inhibit corrosion up to GLM #3. 3 '/:" FMC Gen 5 Tubing Hanger, 3'/:" L-80 EUE8RD Mod pin down 3 '/:" 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3 %" 9.3# L-80 EUE8RD Mod Tubing to Surface - Tubing 8 hanger TO BE DRIFTED TO 2.91" 3 %" Cameo'DS'nipple w/2.875" No-Go Profile. 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at+/- 500' MD 3 %" 9.3# L-80 EUE8RD Mod tubing to landing nipple 3'/::" x 1" Camco'KBMG' mandrels 3 %" x 6' L-80 handlingpups installed above and below,EUEBRD Mod 3 %" x 1" Camco'KBMG' mandrel wl shear valve, pinned for 3000 psi shear (casing to tubing differential), 3 '/:" x 6' L-80 handlingpups installed above and below, EUE8RD Mod 3 %" Baker'CM U' sliding sleeve w/2.813" Camco DS profile, EUE8RD Mod boxxpin.3 %" x6' L-80 EUE8RD Mod handling pup installed above 3'/," Cameo'D' nipple w/2.75" No-Go profile.3 %" x 72' L-80 EUE8RD Mod spaceout pup installed above, 3'/,"x6' handling pup installed below BOT 80-40 GBH-22 Locator Sub w/ 3-%" EUE box BOT seal assembly w/ 15 stroke and'/: mule shoe C-2 ZXP liner top packer w/tie back extension ID=5.250 Flexlock liner hanger 80-40 seal bore extension 5" BTC box x 4.75" Acme pin x-over sub 4.75" stub acme box x 4-'/:" IBT pin Tubinn Jewelry: 2.875" DS nipple +/-500' MD # TVD MD OD Type Company 1 2500 3166 1.00 Dummy Camco 2 3600 5155 1.00 Dummy Camco 3 4450 6695 1.00 Dummy Camca 4 5024 7663 1.00 Shear Camco NOTE: mandrel #4 set 1 jt above sliding sleeve CMU Sliding Sleevewl2.813" DS profile one joint above D nipple 2.75" D nipple w. no go ID(<70 deg.) one joint above seal assembly Bottom of Cement KO plug @ 3400 MD ~~ ~~ / %~ LOT @ 509 'TVD = 11. ppg EMW ~~-' ~,. LLL T._. _.-. -.. .~.. ~ Top Liner set at 7860' MD i i _ 8-1/2" hole size 7" 26.0# L-80 BTCM 8060 M D / 5174 TV D TOC = 500' above 7" sho Bermuda top @ 8160 MD/5250 TVD 8-'/:"open hole 4-%"centralization: • one perjoint Bowspring centralizers on stopco 7" cen Valuation: • One perjointto 300' above TOC. Bowsprings. • One perjointfor 200' above surface casing shoe. Centering guides. • One per third joint from surtace to 500' MD. Centering guides. Production Hole Logging: Longstring -LWD Topset- LWD 6-1/8" hole size 4'/z' 12.6# L-80 I BTM 8620 MD/ 5700 TVD CEMENTED Billingsley 3/16/07 Re: 2N-311 A Directional plan change • Subject: Re: 2N-3llA Directional plan change From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 21 Feb 2D07 11:00:27 -0900 T'o: "Brink, Jason ,~" <~-Jason.Brink(u~conocophillips.com= C(`: "F3illiil~~slcy, Tim .~" -Tire..~Ll3illingsle<<<i`conocophillips.com==. ~'Sh,Iron.K.~~llsuh-Drake~uconocophillips.corli> Jason, Tim and Sharon, This information is sufficient. No new permit is needed. I will place this information in the well file. Tom Maunder, PE AOGCC Brink, Jason A wrote, On 2/21/2007 10:44 AM: Tom ".=~Ilsuh-Dr~~e. Sharon K~~ 2N-311A has an approved permit to drill (206-179). Conocophillips proposes to change 2N-311A directional plan from wp02 to wp03. Prefer to intersect the Bermuda target at a 325 degree azimuth versus the orginial plan wp02 intersection azimuth was 16 degrees (for frac purposes). This proposed change does not change the x,y target of the top of Bermuda location. Proposed change of azimuth does move the TD of the well 328' from the original TD (x,y). Attached is the proposed wellplan wp03. Does this change require a revised APD? «2N-311Awp03 PlanSummary.pdf» Jason Brink Drilling Engineer Phone: 907-265-6419 Office: ATO-1582 1 of 1 2/21/2007 11:01 AM • • ConocoPhillips Alaska, Inc. CPAI Report _ Com,~;uiy: ConocoPhillips Alasb:a Inc- _ Date: 21~.~I2007 _ Time: 15:43:5 Poi~_e: t Field: Kuparuk River Unit Co-ordinate(i~l~) RcFcrence: Well: 2N-311, True North .tiitc: Kuparuk 2N Pad Vertical (TVD) Kctcrcnce: 2N-311: 150.0 1vcll: 2N-311 Section (VS)Hefere~ncc: Well (O.OON,O.OOE.11.40Azi) '1'lellp>itlr. Plan''N-311A 5unc~~ C,ikul~tion ~tcthud: Minirnuni Curvature Db: Oracle Plan: 2N-311Awp03 Date Composed: 11/14/2006 Version: 5 Principal: Yes Tied-to: From: Definitive Path Field: Kuparuk River Unit ----- North Slope Alaska ~ United States ~ Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre i Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~ Site: Kuparuk 2N Pad Site Position: Northing: 5911970.20 ft Latitude: 70 10 13.596 N From: Map Easting: 460932.24 ft Longitude: 150 18 51.920 W i ~' Position Uncertainty: 0.00 ft North Reference: True ~ Ground Level: 0.00 ft Grid Convergence: -0.30 deg i~ Well: 2N-311 ---- _- _-- - Slot Name: ' j Well Position: +N/-S 10.41 ft Northing: 5911980.38 ft Latitude: 70 10 13.698 N +E/-W 43.99 ft Easting : 460976.28 ft Longitude: 150 18 50.646 W ' Position Uncertainty: 0.00 ft Wellpath Plan: 2N-311A Drilled From: 2N-311 j j Tie-on Depth: 3000.00 ft I, Current Datum: 2N-311: Height 150.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/28/2006 Declination: 23.41 deg j Field Strength: 57565 nT Mag Dip Angle: 80.65 deg i Vertical Section: Depth From (TVD) +N/-S +E/-W Direction t ft ft ft deg 30.70 0.00 0.00 11.40 Survey Program for Definitive Wellpath I I Date: 11/14/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information ~IU Incl ~iim TVD -\i-S +E/-~~~ 1>Lt Build Turn 170 lnrvel ft deg deg ft ft ft degl100ft deg%100ft d eg!i60ft deg __ 3000.00 57.71 8.89 2406.71 1410.09 233.54 0.00 0.00 0.00 0.00 3200.00 53.99 17.46 2519.10 1571.04 270.92 4.00 -1.86 4.28 120.00 3463.14 60.53 22.72 2661.39 1778.57 347.21 3.00 2.49 2.00 35.56 6576.88 60.53 22.72 4193.09 4279.16 1394.26 0.00 0.00 0.00 0.00 8159.91 40.00 325.00 5250.00 5396.28 1367.02 3.00 -1.30 -3.65 -132.51 2N-311Awp02 T-3 ~~ 8747.34 40.00 325.00 5700.00 5705.59 1150.44 0.00 0.00 0.00 0.00 • • ConocoPhillips Alaska, Inc. CPAI Report (~ompanp: ConocoPhillips Alaska Inc. Date: 211 512 0 07 Time: 15:43:52 Pale: ? L~icld: Kuparuk River Unit c-o-o r~linnlclVE)ltcfcrcncc: Well_ 2N-311, True North tiilc: Kupan)k 2N Rad ~~crlic;il (ll D}Relcrauc: 2N-317: 150.0 «cll: 2N-311 Section (~"SI Refemnce: NJell (O.OON O.OOE1 1.40Azij ~Fcllpalh: Plan_ ~N-311A Gn~~cy (:~Iculation Mettt~d: ~Ainir'num Curvature Ub: Oracle lone. ail) Incl ~ckm Till Ry, "1~ ll V/S E'N ft deg deg ft ft ft ft -- ___ ~ 3000.00 57.71 8.89 2406.71 2256.71 1410.09 233.54 3100.00 55.78 13.08 2461.56 2311.56 1492.16 249.43 3200.00 53.99 17.46 2519.10 2369.10 1571.04 270.92 3300.00 56.45 19:55 2576.14 2426.14 1648.92 297.01 3400.00 58.94 21.53 2629.58 2479.58 1728.05 326.67 3463.14 60.53 22.72 2661.39 2511.39 1778.57 347.21 3500.00 60.53 22.72 2679.53 2529.53 1808.17 359.61 3600.00 60.53 22.72 2728.72 2578.72 1888.48 .393.24 3700.00 60.53 22.72 2777.91 2627.91 1968.79 426.86 3800.00 60.53 22.72 2827.10 2677.10 2049.09 460.49 3900.00 60.53 22.72 2876.29 2726.29 2129.40 494.12 4000.00 60.53 22.72 2925.49 2775.49 2209.71 527.74 4100.00 60.53 22.72 2974.68 2824.68 2290.02 561.37 4200.00 60.53 22.72 3023.87 2873.87 2370.33 595.00 4300.00 60.53 22.72 3073.06 2923.06 2450.64 628.62 4400.00 60.53 22.72 3122.25 2972.25 2530.94 662.25 4500.00 60.53 22.72 3171.44 3021.44 2611.25 695.87 4600.00 60.53 22.72 3220.64 3070.64 2691.56 729.50 4700.00 60.53 22.72 3269.83 3119.83 2771.87 763.13 4800.00 60.53 22.72 3319.02 3169.02 2852.18 796.75 4900.00 60.53 22.72 3368.21 3218.21 2932.49 830.38 5000.00 60.53 22.72 3417.40 3267.40 3012.79 864.01 5100.00 60.53 22.72 3466.59 3316.59 3093.10 897.63 5200.00 60.53 22.72 3515.78 3365.78 3173.41 931.26 5300.00 60.53 22.72 3564.98 3414.98 3253.72 964.89 5400.00 60.53 22.72 3614.17 3464.17 3334.03 998.51 5500.00 60.53 22.72 3663.36 3513.36 3414.34 1032.14 5600.00 60.53 22.72 3712.55 3562.55 3494.64 1065.77 5700.00 60.53 22.72 3761.74 3611.74 3574.95 1099.39 5800.00 60.53 22.72 3810.93 3660.93 3655.26 1133.02 5900.00 60.53 22.72 3860.13 3710.13 3735.57 1166.65 6000.00 60.53 22.72 3909.32 3759.32 3815.88 1200.27 6100.00 60.53 22.72 3958.51 3808.51 3896.19 1233.90 6200.00 60.53 22.72 4007.70 3857.70 3976.50 1267.53 6300.00 60.53 22.72 4056.89 3906.89 4056.80 1301.15 6400.00 60.53 22.72 4106.08 3956.08 4137.11 1334.78 6500.00 60.53 22.72 4155.28 4005.28 4217.42 1368.41 6576.88 60.53 22.72 4193.09 4043.09 4279.16 1394.26 6600.00 60.07 22.13 4204.55 4054.55 4297.73 1401.92 ~ 6700.00 58.08 19.51 4255.95 4105.95 4377.88 1432.42 I i 6800.00 56.14 16.78 4310.26 4160.26 4457.65 1458.59 6900.00 54.27 13.92 4367.33 4217.33 4536.82 1480.35 7000.00 52.47 10.93 4426.99 4276.99 4615.17 1497.64 7100.00 50.75 7.80 4489.10 4339.10 4692.48 1510.42 7200.00 49.12 4.51 4553.48 4403.48 4768.55 1518.65 7300.00 47.58 1.06 4619.94 4469.94 4843.16 1522.30 7400.00 46.16 357.44 4688.32 4538.32 4916.10 1521.38 7500.00 44.85 353.66 4758.42 4608.42 4987.19 1515.87 7600.00 43.67 349.70 4830.05 4680.05 5056.23 1505.79 7700.00 42.64 345.58 4903.01 4753.01 5123.02 1491.18 7800.00 41.76 341.31 4977.10 4827.10 5187.38 1472.08 I` 7900.00 41.04 336.91 5052.13 4902.13 5249.14 1448.52 8000.00 40.50 332.39 5127.88 4977.88 5308.12 1420.59 ~1ap~ M~pE DI_ti ~S (um ft ft degl100ft ft 5913389.11 461217.06 0.00 1428.44 9 5/8" 5913471.08 461233.37 4.00 1512.02 5913549.85 461255.27 4.00 1593.60 5913627.58 461281.76 3.00 1675.09 5913706.55 461311.83 3.00 1758.53 5913756.96 461332.63 3.00 1812.11 5913786.49 461345.17 0.00 1843.57 5913866.62 461379.21 0.00 1928.95 5913946.74 461413.25 0.00 2014.32 5914026.87 461447.28 0.00 2099.69 5914107.00 461481.32 0.00 2185.06 5914187.12 461515.36 0.00 2270.43 5914267.25 461549.39 0.00 2355.80 5914347.37 461583.43 0.00 2441.17 5914427.50 461617.47 0.00 2526.54 5914507.63 461651.50 0.00 2611.91 5914587.75 461685.54 0.00 2697.28 5914667.88 461719.58 0.00 2782.65 5914748.01 461753.61 0.00 2868.02 5914828.13 461787.65 0.00 2953.39 5914908.26 461821.69 0.00 3038.76 5914988.38 461855.73 0.00 3124.13 5915068.51 461889.76 0.00 3209.50 5915148.64 461923.80 0.00 3294.87 5915228.76 461957.84 0.00 3380.24 5915308.89 461991.87 0.00 3465.61 5915389.01 462025.91 0.00 3550.99 5915469.14 462059.95 0.00 3636.36 5915549.27 462093.98 0.00 3721.73 5915629.39 462128.02 0.00 3807.10 5915709.52 462162.06 0.00 3892.47 5915789.64 462196.09 0.00 3977.84 5915869.77 462230.13 0.00 4063.21 5915949.90 462264.17 0.00 4148.58 5916030.02 462298.20 0.00 4233.95 5916110.15 462332.24 0.00 4319.32 5916190.27 462366.28 0.00 4404.69 5916251.88 462392.45 0.00 4470.32 5916270.40 462400.20 3.00 4490.04 5916350.39 462431.12 3.00 4574.64 5916430.02 462457.69 3.00 4658.01 5916509.06 462479.86 3.00 4739.92 5916587.31 462497.55 3.00 4820.14 5916664.55 462510.73 3.00 4898.45 5916740.56 462519.35 3.00 4974.64 5916815.15 462523.39 3.00 5048.50 5916888.09 462522.83 3.00 5119.83 5916959.20 462517.69 3.00 5188.42 5917028.28 462507.98 3.00 5254.10 5917095.14 462493.71 3.00 5316.69 5917159.59 462474.94 3.00 5376.00 5917221.46 462451.71 3.00 5431.89 5917280.58 462424.08 3.00 5484.19 • ConocoPhillips Alaska, Inc. CPAI Report (~ompany: ConocoPhillipsAlaska Inc. note: 2!15;200% lUaie_ 15-43-52 P;i~c: 3 Field: K.up2+uk Ri ver unit lt~-ord inatc(~~'I') Refere nce: VJe!I: 2N-311, True Nor€h siic_ Kuparuk 2N Pad vertical ('P ll}Reference: 2P:-?11 ~ 150.0 ~1 ell: 2N-311 tiection (VS) Reference: Well f0.00N,0-OOE,11.40Azi) ~~e]Ipaih: Plan: 2tJ ?11 A S~nvey Calculatim~ blet hbd: Minimum Curvat~ir~' nh: Oracle tiui~c~ ~4n incl ~zim TVD tics 7~~`U \/S F:-~~ ~T:y~A~ _.. _, ~IapF DLS 1~ti (~oimne~t ft deg deg ft ft ft ft ft ft deg/100ft it I 8100.00 40.13 - 327.78 _ 5204.15 5054.15 - _ 5364.17 1388.35 5917336.79 __ _ 462392.14 3.00 5532.76 8159.91 40.00 325.00 5250.00 5100.00 5396.28 1367.02 5917369.01 462370.97 3.00 5560.02 2N-311Awp02 T- 8200.00 40.00 325.00 5280.71 5130.71 5417.39 1352.24 5917390.19 462356.30 0.00 5577.79 8300.00 40.00 325.00 5357.32 5207.32 5470.04 1315.37 5917443.03 462319.70 0.00 5622.12 8400.00 40.00 325.00 5433.92 5283.92 5522.70 1278.50 5917495.87 462283.11 0.00 5666.45 8500.00 40.00 325.00 5510.53 5360.53 5575.35 1241.63 5917548.71 462246.52 0.00 5710.77 ~ 8600.00 40.00 325.00 5587.13 5437.13 5628.01 1204.76 5917601.55 462209.92 0.00 5755.10 j 8700.00 40.00 325.00 5663.74 5513.74 5680.66 1167.89 5917654.38 I 462173.33 0.00 5799.43 8747.34 40.00 325.00 5700.00 5550.00 5705.59 1150.44 5917679.40 462156.01 0.00 5820.41 31/2" Targets 14ap _ _ \Tap ----- La6tudr ----> -~--- Lonriludc --=' \;nue Deuription llrD t V%-ti +I~:'-~1 V'ort6ing F atitin;; I?eg Min See nc~ ~iin Sec Ihp. vir. n n n ft ft 2N A ? 3 5250 00 5396.28 1367.02 5917369.01 462370.97 70 11 6.770 N 150 18 11.015 W ; Plan hitpa get - - I Annotation ~M ll I . `,ll _ ft ft _3000.00-..2406.71 - KOP; 4 DLS __ -_ _ _ _ --- -----_ - - _--___ _-- - --- -- _ - - Casing Points - lin ll'n Dianu•tc r I~o lcSin• \nmc - ft ft in ire ~ 3000.00 2406.71 9.625 1 2.250 9 5/8" I 8159.91 5250.00 5.500 8.500 51/2" 8747.34 5700.00 3.500 8.500 31/2" - ~ Formations - -- tiID FID Form ations I-ith ology ])ip ,~uLle nip Direction ~. ~.- ~~ ..a ~ . ,OG ' "+'~ ~ ~ CPU H ~~' ti m ~ vi s~ ~..~~~ ~u ~~~,~{ na ~ N ti a F t' " 7 W - a w a ~; r}~ 4 w ~ ~ W ~} ~~ .r '~ m r~-r ~ ~~ '} ~~ •n~ r°n r r~ ~ ~ ~~--++ 4 W ~ G W ~'~ '~ ~-' ~I ,~ w ;4 ,~ ~ hl G ~iG cv m r'i %r ca i ~ti? '. G 4 a + W ~ y ~~ c. ~~ ~~ p~+ ~ Y ~ ~ r+ d H _;7 ~ w F ~ " d E Rr ~; ~~~ o a ~ H A 7', ~ M ~~' '" m .~ ~! ,;y P. F ~ a a x ,~ A ~~~ 4~ m + ro U] rT ~' n d c ~ ~~, ~l G tl ~ ~~ p ~ ~ ~ .-~ h; G ~ a _ . :., ~; o fl~ 3~ ~i~ z Wo~, m n N ~ ° ° ~ ~ .~a~~~ G.~r a rG w ~ :-~ ~.,~-i F ~f'r~M~ 04 Mai L} .. .. .v a a+ 21 .. w ~.~.w„ w ~~4 w ~~_~G~ ~~~~'~ ~,~r, b`- o .'~~- i ~ r` . r;~' -_ ,~' { C t I ..... ~~ ~i ~. • ConocoPhillips Alaska, Inc. Anticollision Report (lnupanv: ConocoPhillips Alaska Inc. pale: 2?15i2007 lime: 15-3~I55 Pa>~r. I Field: Kuparuk River Ur it Rcfcrcnrc Site' Kuparuk 2N Pad Co-ordinate(\F) Itc1'erenee: VVeIC 2N-37 i. True North 12efercuce t\ell: 2PJ-:~11 ~~ertical (C~Ut Itefercuce: 2N-311: 150-0 12cfercncc ~~cllpath: Plan: 2N-311A _ _ pb: Oracle ~ GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 2N-311Awp03 & NOT PLANNED P+ Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 30.70 to 8747.34 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1071.66 ft Error Surface: Ellipse + Casing Casing Points ~1p l~~D Diameter Hole Sire lame ft ft in in 3000.00 2406.71 9 625 ___ 12.250 9 5/8" __ __ ~ 8159.91 5250.00 5 500 8.500 5 1 /2" ~ 8747.34 5700.00 3 500 8.500 3 1 /2" 11Awp03 et e mposed: --_ / -- _--- ---- - -~- ~ i D tYro ncipaL• Yes Pr , ~ From: Defnitive Path , Summary -___ -------------------- Uffset Wellpalh ---- -----------------> Keference (Iflsrt (U-Ctr No-Go ,>_Ilnwablc tiiu• ~l'eN 1~cllpath alp )Ip I1i,tance Area llccialion ~~arninh ft ft ft ft ft Kuparuk 2N Pad 2N-302 2N-302 V11 `s72.43 375.00 130.23 5.721 124.45 Pass: Major Risk ': Kuparuk 2N Pad 2N-303 2N-303 V4 395.03 400.00 120.12 5.48 114.64 Pass: Major Risk Kuparuk 2N Pad 2N-305 2N-305 V6 345.91 350.00 91.31 5.08 8623 Pass: Major Risk i, Kuparuk 2N Pad 2N-307 2N-307 V7 720.28 725.00 55.67 9.78 45.89 Pass: Major Risk Kuparuk 2N Pad 2N-308 2N-308 V2 900.29 900.00 53.82 14.95 38.87 Pass: Major Risk Kuparuk 2N Pad 2N-311 2N-311 V1 3025.00 3025.00 0.17 63.82 -63.65 FAIL: Major Risk as v~~l4 °~r'~ °~d~~es~n° ~ _ ~ € ~ ~ ~ ~ 1 i ~ ~i ~' -~ i i ' ~ - ~-s f .I I ~~ ~-, _ ~-~ _ _ - - __ ~ ~ ~, ~ ,-°4 ` - as ~ . ~ _ ..., 1~ ~ ~', ~ r ~ ~' o ~ ~ ~. •. ~ _ Q b _. t ,., + ~ o r T' ~' ~ ,r i - . d {! ' _ ---._ ~ '~~~/~ 'C~ 'kk .. : -' ~ .~ ~ .. o - - ~,r a .-~ r~ t t l' o ~ ep ~9;~°C+~ ri .Ca ~µ~i~4~iS ~o t ~ ~06 ~~ OQ G60~ _$ .- t=arsi ~[~aa Ca .-I'-1 r1r-1 MfF a .~ as tU~~ t+ p k h0 'L~ t ~Dc, F y i1 Ti ~' ~~ ry; ~i~ ~ 3 ~ ~" , Y,- 3.~~ ~ i l~ ~ _,ti ~ 'a ~ i '1 I ,-~ i ~~ q AL~SSA OIL A11TD Gr~-S C011TSERQAZ`I011T COMIIIISSI011T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk, Tarn OiI Pool 2N-311A ConocoPhillips (Alaska), Inc. Permit No: 206-179 Surface Location: 27' FNL, 617' FEL, Sec. 03, T09N, R07E, UM Bottomhole Location: 453' FSL, 863' FWL, Sec. 26, T10N, R07E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does- not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. w ~~ ?red ,~ ~ Sincet~,is Suspended, a Sundry Application (Form 403) must be obtained to re- enter the well in preparation to redrill. H2S has been reported in association with production at 2N-Pad. H2S measures must be in place at all times while operations are conducted on 2N-311A. 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. When providing notice for a representative of the C fission to witness any required test, contact the Commission's petroleum field in ect rat (907) 659-3607 (pager). John. Norman DATED this~l~day of December, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~illips Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.I.thomas@conocophillips.com December 15, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 2N-311A Dear Commissioner: i~ 1.~. ~ ! V L.! Alaska pi- ~ ~~~ Coon Commission - Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 2N-311A, a development well. Please reference 2N-311 P&A sundry approval document dated 6/16/04. Also, reference 2N-311 P&A completion report dated 4/26/05. A 3-1/2" kill string was set at 2272' MD and the top of P&A cement plug inside 9-5/8" surface casing is at 2774' MD. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The expected spud date is February 25, 2007.' If you have any questions or require any further information, please contact Jason Brink at 265-6419 or Tim Billingsley at 265-6531. Sincerely, ,..__~ Randy Thomas GKA Drilling Team Leader .STATE OF ALASKA ~~c 1 s zoos ALASKA OIL AND GAS CONSERVATION COMMISSI PERMIT TO DRILL ~` ~'~5~ Alaska a`o & Gas Cons. Commission 20 AAC 2s.oos Anchorage 1a. Type of Work: Drill ^ Re-drill ^~ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil Q Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^/ 1c. Specify if well is proposed for. Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 - 11. Well Name and Number: 2N-311A - 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 8620' - ND: 5700' - 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 27' FNL, 617' FEL, Sec. 3, T09N, R07E, UM • 7. Property Designation: ADL 375074/380054/380053 Tarn Oil Pool Top of Productive Horizon: 90' FSL, 758' FWL, Sec. 26, T10N, R07E, UM 8. Land Use Permit: LK 31961/32027/320 13. Approximate Spud Date: 2/25/2007 Total Depth: 453' FSL, 863' FWL, Sec. 26, T10N, R07E, UM 9. Acres in Property: 2560 14. Distance to ~ ! wci 6. A Nearest Property: > es /s ,p fZ-~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460976 .. y- 5911980 " Zone- 4 10. KB Elevation (Height above GL): 30' RKB feet 15. Distance t~ rem ~~~~~ Well within Pool:`pDn€, t~-LD~D(, 16. Deviated wells: Kickoff depth: 3000 ' ft. Maximum Hole Angle: 57.7° deg 17. Maximum Anticipated Pressures in psig (see 20AAC 25.035) Downhole: 2620-psig Surface: 2043 psig 18. Casing Program if S ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (inGuding stage data) 8.5" 7" 15.5# L-80 BTCM 7770' 30' 30' 7800' ~ 5081' . 160 sx LiteCRETE 8.5" 4.5" 12.6# L-80 IBTM 820' 7800' 5081' ~ 8620' 5700' - see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" pre-installed 139' 139' Surface 2970' 9-5/8" 275 sx AS Lite, 330 sx LiteCRETE 3000' 2402' Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jason Brink @ 265-6419 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ' =~,~,~ ~~-~ "~~,~~ Phone ~~:.s ' C- `7 ~, Date l 2.. ~ (j ~C, Pr h n D k Commission Use Only Permit to Drill Number: 2.~ -~ ~ API Number: ~t 50- ~~J ~~/ ~' [/ / Permit Approval Date: See cover letter for other requirements Conditions Of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed m thane, gas hydrates, or g ntained in shales: 1 Samples req'd: Yes ^ No ~ Mud I req'd: Yes ^ No [~ Other: ~~~ r~`~f ~~-'~~ ~~~'~5~ H2S measures: Yes -[~ No Irection svy req' Yes [~ No ^ BY THE COMMISSION DATE: rp~" ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ti ~ ~:, ~~`~ r~ ~ `-~ t V Submit in Duplicate Re: 2N-311 and 2N-311 A • • Subject: Re: 2N-311 and 2N-311 A From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 21 DEC 2006 15:29:13 -0900 To: "Thom<<s, Rand~~ L" ~~Randv.L. Th~~nuiscr conocopl~illi[~s.com-= ('C: "E3rin}:. Jas~~n ;1~~ . Jas,n.l3rinl."~l:cot~~~c~,hhilli~s.com -, Ste~~e D~~~~ies stcv~ d<l~i~~s~a.ad~nin.slalt.ak.u~ Randy, That should be fine. Just need to have the sundry in place before the work begins. Tom Thomas, Randy L wrote, On 12/21/2006 3:26 PM: Jason is out for a couple weeks. There should be time to get this in when he gets back. We expect the rig to go to the Tarn program at the end of January. If you think you need this right away, let me know and I'll get someone else to address it in Jason's absence. Randy L. Thomas Kuparuk Drilling Team Lead 907-265-6830 office 907-244-5205 cell 907-222-6088 home Randy . L . Thomascacorocarfl"i l l i xis . com -----Original Message----- From: Thomas Maunder [rnailto:tom maunder:~admir_.st~a`~e.ak.zs] Sent: Thursday, December 21, 2006 2:10 PM To: Brink, Jason A Cc: Thomas, Randy L; Steve Davies Subject: 2N-311 and 2N-311A Jason, I am reviewing the permit application for 2N-311A. Hate to ask for more paperwork, but since this well's status is suspended a 403 is necessary to conduct the first 3 steps of your procedure. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 12/26/2006 9:08 AM • A~tion for Permit to Drill, Well 2N-311A Revision No.O Saved: 15-Dec-06 Permit It -Tarn Well #2N-311A •~~~° r.~ ~t Application for Permit to Drill Document •,,~;•., f~It~~cW~ll M d x i m i~ g 1Mell VQlue 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 lnformation ................................................................................... 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. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................. Error! Bookmark not defined. Production Hole Mud Program (LSND) .................................................................................................. 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. 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 2N-311A PERMIT IT Page 1 of 6 Printed: 15-Dec-06 OR161NAL • Requirements of 20 AAC 25.005 (c)(12)....... Appl~n for Permit to Drill, Well 2N-311A Revision No.O Saved: 15-Dec-06 ....... 5 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan (17 pages) .............................................................................................. 6 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 6 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 6 Attachment 4 Well Schematics (1 page) ................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fi) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2'0 AAC 25.05'0(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding e~ 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-311A. 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: (2) a plat identifying the property and the property's owners and showing (A)che coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (t3) 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 27' FNL, 617' FEL, Sec. 3, T9N, R7E, UM US State Plane 1927, NAD 27, Alaska Zone 04 RKB Elevation 150' AMSL ' Northings: 5,911,980- Eastings: 460,976 ~ PadE/evation 120'AMSL Location at Top of 90' FSL, 758' FWL, Sec. 26, T10N, R7E, UM Productive Interval Bermuda Sand US State Plane 1927, NAD 27, Alaska zone o4 Measured De th, RKB: 8033 Northings: 5,971,369 Eastings: 462,371 Total Vertical Depth, RKB: 5250 Total Vertical Depth, SS: 5100 Location at Total De th 453' FSL, 863' FWL, Sec. 26, T10N, R7E, UM US State Plane 1927, NAD 27, Alaska Zone 04 Measured Depth, .RKB: 8620 Northings: 5,917,731 Eastings: 462,477 Total Vertical Depth, RKB: 5700 - Total Vertical De th, SS: 5550 2N-311A PERMIT IT Page 2 of 6 Printed: 15-Dec-06 ORIGINAL • and (D) other information required by ZO AAC 25.050(6); A~tion for Permit to Drill, Well 2N-311A Revision No.0 Saved: 15-Dec-06 Requirements of 20 AAC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill (Form i 0-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Piease see Attachment 1: 13irectianal 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 ce,~tified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 11" x 5,000 psi BOP stack will be utilized to drill and complete well 2N-311A. 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 Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum do:vnho/e pressure that maybe encountered, 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-311A area vary from 0.45 to 0.50 psi/ft, or 8.6 to 9.7 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 2043 psi, calculated as follows: MPSP =(5239 ft)(0.50 - 0.11 psi/ft) =2043 psi (B) data on potential gas zones; No potential gas zones are expected. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differentia! sticking; Please see Attachment 2: DriNing Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); 2N-311A PERMIT IT Page 3 of 6 Printed: 15-Dec-06 Q~I~l~A~. • Appl~n for Permit to Drill, Well 2N-311A Revision No.O Saved: 15-Dec-06 2N-311 currently is completed with 9 5/8" surface casing landed at 2999' MD and a 3-1/2" kill string at 2272' MD. The casing shoe with P&A cement plug top at 2774' MD 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 fora ,permit to Drill must be accompanied by each of the following items, except for an item already on frle with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in) (in) (Ib/ft) Grade Connection ft (ft) (ft) Cement Pro ram 16 42 62.5 H-40 Welded 109 30 / 30 109 / 109 Cemented to surface ArticSet I 9 5/8 12 ~/a" 40 L-80 BTC 2969 30/ 30 2999 / 2406 Cemented to Surface with 218 bbl ASLite Lead, 115 bbl LiteCRETE Tail 7 8 '/2 15.5 L-80 BTCM 7770 30/ 30 ~ J800 / 5081- Cement Top planned @ 4'/z 8 ~/2 12.6 L-80 IBTM 820 7800 / 5081- 8620 / 5700 7533' MD. Cement w/ 160 sx LiteCRETE 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) 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: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); N/A. Sidetrack will utilize the current surface hole and casing. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties: Production Hole Mud Program (LSND) 9 5/8" Casin Shoe to TD Initial Value Final Value Density (ppg) 9,6 10.0 Yield Point (cP) 22-28 22-28 pH 9-9.5 9-9.5 2N-311A PERMIT IT Page 4 of 6 Printed: 15-Dec-06 ~R161NAL • APl Filtrate (cc / 30 min)) 5-6 4-6 HTHP @ 15f~ (cc)) < 12 < 10 A~tion for Permit to Drill, Well 2N-311A Revision No.O Saved: 15-Dec-06 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 for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(!]; 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 items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.06i(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 items, except for an item already on file with the commission and identifred in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fle with the corrm;'ssion and identifred in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dri(1 must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Move in /rig up Nordic Rig 3. 2. Pull 3-1/2" kill string set at 2272' MD. 3. PU 8 ~/z" bit and 6 3/4".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. 5. Directionally drill to 7" x 4 ~/z" casing point at 8620' MD / 5700' TVD. 2N-311A PERMIT IT Page 5 of 6 Printed: 15-Dec-06 ORDINAL • Appl~n for Permit to Drill, Well 2N-311A Revision No.0 Saved: 15-Dec-06 6. Run 7", 26# L-80, BTC Mod x 4 ~/z", 12.6# L-80, IBT Mod casing to TD. Pump cement and displace with water and mud. 7. 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. 8. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV 9. 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. 10. Set BPV and move rig off. 11. 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. 12. Carry out fracture stimulation. 13. 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: (i4) a General description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids " into a permitted annulus on 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 At the end of drilling operations, an application may be submitted to permit 2N-311A for annular disposal of fluids occurring as a result of future drilling operations on 2N pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematics 2N-311A PERMIT /T Page 6 of 6 Printed: 15-Dec-06 WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot 2N-311 10.41 43.99 5911980.38 460976.28 70°10'13.698N 150°18'S0.646W N/A WELLPATH DETAILS Plan: 2N-311 A Parent Wellpath: 2N-311 Tie on MD: 3000.00 Rig: Ref Datum: 2N-311: 150.OOft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 14.33° 0.00 0.00 30.70 ~.....i T M Azimuths to True North Magnetic North: 23.41 ° Magnetic Field Strength: 57565nT Dip Angle: 80.65° Date: 7/28/2006 Model: bggm2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 3000.00 8620.50 Planned: 2N-311Awp02 V4 MWD+IFR-AK-CAZ-SC a .2000 -- a I 2 .. '... F ti~ ~; 2N-311A~ I 0 2000 400( Vertical Section at 14.13° [2000ft/in] 6000 +^ n ti West(-)/East(+) [2000ft/inJ PLAN DETAILS 2N-311Awp02 Version 4 11/14/2006 StaCt POIDt MD Inc Azi TVD +N/-S +E/-W 3000.00 57.71 8.89 2406.71 1410.09 233.54 HALLtsuRTC~nr COnvcoPhilllpS ~p~ry Drilling Services Alaska REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: 2N-311, True North Vertical (TVD) Reference: 2N-311: 150.00 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: 2N-311: 150.00 Calculation Method: Minimum Curvature e ~OriOCOPhllll s Alaska, In A CPAI Report Compam~: ConocoPhillips Alaska Inc. Date: 11/14/2006 "time: 10:24:31 Nag_e: 1 Field: Kuparuk River Unit Co-ordinate(NG) Reference: Well: 2N-311, True North - Site: Kuparuk 2N Pad Vertical (TVll) Reference: 2N-311: 150.0 Well: 2N-311 Section (VS) Reference: Well (O.OON,O.OOE,14.33Azi) ~~'ellpadi: Plan: 2N-311A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 2N-311Awp02 Date Composed: 11/14/2006 Version: 4 Principal: Yes Tied-to: From: Definitive Path Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Kuparuk 2N Pad Site Position: Northing: 5911 970.20 ft Latitude: 70 10 13.596 N From: Map Easting: 460932.24 ft Longitude: 150 18 51.920 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.30 deg Well: 2N-311 Slot Name: Well Position: +N/-S 10.41 ft Northing: 5911 980.38 ft' Latitude: 70 10 13.698 N +E/-W 43.99 ft Easting : 460976.28 ft - Longitude: 150 18 50.646 W Position Uncertainty: 0.00 ft Wellpath: Plan: 2N-311A Drilled From: 2N-311 Tie-on Depth: 3000.00 ft Current Datum: 2N-311: Height 150.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/28/2006 Declination: 23.41 deg Field Strength: 57565 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.70 0.00 0.00 14.33 Survey Program for Definitive Wellpath Date: 11/14/2006 Validated: No Version: 3 Actual From To Survey Toolcode To ol Name ft ft Plan Section Information _. ~1D [ncl ~zim TVD +N/-S +E/-W DLS Build __ __ Turn TFO Tar~_;et ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg - -- - 3000.00 57.71 8.89 2406.71 1410.09 233.54 0.00 0.00 _ -_ 0.00 0.00 3200.00 53.99 17.46 2519.10 1571.04 270.92 4.00 -1.86 4.28 120.00 3292.73 56.50 15.98 2571.96 1644.01 292.82 3.00 2.70 -1.60 -26.36 7483.21 56.50 15.98 4885.11 5003.27 1254.49 0.00 0.00 0.00 0.00 8033.07 40.00 15.98 5250.00 5396.28 1367.02 3.00 -3.00 0.00 179.99 2N-311Awp02 T-3 8620.50 40.00 15.98 5700.00 5759.28 1470.97 0.00 0.00 0.00 0.00 ~~~~~~~~ i ~!"onocoPhillips Alaska, In~ CPAI Report ('ompany: Conoco Phillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 2N Pad N'cll: 2N-311 W~cllpath: PIan:2N-311A Survey '11U lncl ft deg 3000.00 57.71 3100.00 55.78 3200.00 53.99 3292.73 56.50 3300.00 56.50 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7483.21 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 56.50 55.99 52.99 49.99 46.99 43.99 40.99 Date: 11/14/2006 Timc: 10:24:31 Pa~,c: 2 Co-ordinate(NE) Rci'erence: Well: 2N-311, Tfue North ~`ertical ("I'C'U) Kefercnce: 2N-311: 150.0 Section (~'S) Reference: Well (O.OON,O.OOE,14.33Azi) !, Sur~c~ ('alculation Method: Minimum Curvature Ub: Oracle ~zim T~'D S}°s'C~D .A'/S E/~~' deg ft ft ft ft 8.89 2406.71 2256.71 1410.09 233.54 13.08 2461.56 2311.56 1492.16 249.43 17.46 2519.10 2369.10 1571.04 270.92 15.98 2571.96 2421.96 1644.01 292.82 15.98 2575.98 2425.98 1649.83 294.49 15.98 2631.18 2481.18 1730.00 317.44 15.98 2686.38 2536.38 1810.16 340.39 15.98 2741.58 2591.58 1890.33 363.34 15.98 2796.78 2646.78 1970.49 386.28 15.98 2851.98 2701.98 2050.66 409.23 15.98 2907.18 2757.18 2130.82 432.18 15.98 2962.38 2812.38 2210.98 455.13 15.98 3017.58 2867.58 2291.15 478.08 15.98 3072.78 2922.78 2371.31 501.03 15.98 3127.98 2977.98 2451.48 523.98 15.98 3183.18 3033.18 2531.64 546.93 15.98 3238.38 3088.38 2611.80 569.88 15.98 3293.58 3143.58 2691.97 592.83 15.98 3348.78 3198.78 2772.13 615.77 15.98 3403.98 3253.98 2852.30 638.72 15.98 3459.18 3309.18 2932.46 661.67 15.98 3514.38 3364.38 3012.63 684.62 15.98 3569.58 3419.58 3092.79 707.57 15.98 3624.78 3474.78 3172.95 730.52 15.98 3679.98 3529.98 3253.12 753.47 15.98 3735.18 3585.18 3333.28 776.42 15.98 3790.38 3640.38 3413.45 799.37 15.98 3845.58 3695.58 3493.61 822.32 15.98 3900.78 3750.78 3573.78 845.26 15.98 3955.98 3805.98 3653.94 868.21 15.98 4011.18 3861.18 3734.10 891.16 15.98 4066.38 3916.38 3814.27 914.11 15.98 4121.58 3971.58 3894.43 937.06 15.98 4176.78 4026.78 3974.60 960.01 15.98 4231.98 4081.98 4054.76 982.96 15.98 4287.18 4137.18 4134.93 1005.91 15.98 4342.38 4192.38 4215.09 1028.86 15.98 4397.58 4247.58 4295.25 1051.81 15.98 4452.78 4302.78 4375.42 1074.75 15.98 4507.98 4357.98 4455.58 1097.70 15.98 4563.18 4413.18 4535.75 1120.65 15.98 4618.38 4468.38 4615.91 1143.60 15.98 4673.58 4523.58 4696.08 1166.55 15.98 4728.78 4578.78 4776.24 1189.50 15.98 4783.98 4633.98 4856.40 1212.45 15.98 4839.18 4689.18 4936.57 1235.40 15.98 4885.11 4735.11 5003.27 1254.49 15.98 4894.44 4744.44 5016.69 1258.34 15.98 4952.51 4802.51 5094.94 1280.74 15.98 5014.77 4864.77 5170.16 1302.27 15.98 5081.03 4931.03 5242.15 1322.88 15.98 5151.12 5001.12 5310.70 1342.51 15.98 5224.85 5074.85 5375.63 1361.11 '11ap\ ~1apL DI:S ~'S ft ft deg/100ft ft 5913389.11 461217.06 0.00 1424.03 9 5/8" 5913471.08 461233.37 4.00 1507.47 5913549.85 461255.27 4.00 1589.22 5913622.69 461277.54 3.00 1665.33 5913628.51 461279.24 0.00 1671.39 5913708.55 461302.60 0.00 1754.74 5913788.59 461325.96 0.00 1838.09 5913868.62 461349.32 0.00 1921.44 5913948.66 461372.68 0.00 2004.79 5914028.70 461396.04 0.00 2088.14 5914108.73 461419.40 0.00 2171.49 5914188.77 461442.76 0.00 2254.84 5914268.81 461466.12 0.00 2338.19 5914348.84 461489.48 0.00 2421.54 5914428.88 461512.84 0.00 2504.89 5914508.92 461536.20 0:00 2588.24 5914588.96 461559.56 0.00 2671.59 5914668.99 461582.92 0.00 2754.94 5914749.03 461606.28 0.00 2838.29 5914829.07 461629.64 0.00 2921.64 5914909.10 461653.00 0.00 3004.99 5914989.14 461676.36 0.00 3088.34 5915069.18 461699.72 0.00 3171.69 5915149.21 461723.08 0.00 3255.04 5915229.25 461746.44 0.00 3338.39 5915309.29 461769.80 0.00 3421.74 5915389.32 461793.16 0.00 3505.09 5915469.36 461816.52 0.00 3588.44 5915549.40 461839.88 0.00 3671.79 5915629.44 461863.24 0.00 3755.14 5915709.47 461886.60 0.00 3838.49 5915789.51 461909.96 0.00 3921.84 5915869.55 461933.32 0.00 4005.19 5915949.58 461956.68 0.00 4088.54 5916029.62 461980.04 0.00 4171.89 5916109.66 462003.40 0.00 4255.24 5916189.69 462026.76 0.00 4338.59 5916269.73 462050.12 0.00 4421.94 5916349.77 462073.47 0.00 4505.29 5916429.81 462096.83 0.00 4588.64 5916509.84 462120.19 0.00 4671.99 5916589.88 462143.55 0.00 4755.34 5916669.92 462166.91 0.00 4838.69 5916749.95 462190.27 0.00 4922.04 5916829.99 462213.63 0.00 5005.39 5916910.03 462236.99 0.00 5088.74 5916976.63 462256.43 0.00 5158.10 5916990.02 462260.34 3.00 5172.05 5917068.15 462283.14 3.00 5253.41 5917143.25 462305.07 3.00 5331.62 5917215.12 462326.05 3.00 5406.47 5917283.57 462346.03 3.00 5477.75 5917348.40 462364.95 3.00 5545.26 Commct~f~ ORIGINAL nocoPhilli s Alaska, Inc P CPAI Report Compan}: ConocoPhillips Alaska Inc. Hield: Kuparuk River Unit Date: 11/14/2006 Time: 10:24:31 Pale: 3 Co-ordinate(NE) Reference: Well: 2N-311, True North Site: Kuparuk 2N~ Pad Vertica l (TVD) Referen ce: 2N-311: 150.0 1i"e11: 2N-311 Section (VS) Reference: Well (O.OON,O.OOE,14.33Azi) Wellpa[h: Plan'. 2N-311A Survey Calculation Method: Minimum Curvature Ub: Oracle Surcev - ~1D Incl 4zim TVD' Sys TVD N/S E/W MapN nr~ MapF. ULS ~'S Co t . ft deg deg ft ft ft ft ft ft deg/100ft ft 8033.07 40.00 15.98 5250.00 5100.00 5396.28 1367.02 5917369.01 462370.97 3.00 5566.73 2N-311Awp02 T- 8100.00 40.00 15.98 5301.27 5151.27 5437.64 1378.86 5917410.30 462383.02 0.00 5609.73 8200.00 40.00 15.98 5377.88 5227.88 5499.43 1396.56 5917472.00 462401.04 0.00 5673.98 8300.00 40.00 15.98 5454.48 5304.48 5561.23 1414.25 5917533.70 462419.05 0.00 5738.23 8400.00 40.00 15.98 5531.09 5381.09 5623.02 1431.95 5917595.39 462437.06 0.00 5802.49 8500.00 40.00 15.98 5607.69 5457.69 5684.82 1449.65 5917657.09 462455.08 0.00 5866.74 8600.00 40.00 15.98 5684.29 5534.29 5746.61 1467.34 5917718.79 462473.09 0.00 5930.99 ' 8620.50 40.00 15.98 5700.00 .5550.00 5759.28 1470.97 5917731.44 462476.78 0.00 5944.16 7" Targets _. __ - -- Map Map <----` Latitude ----> <--- Longitude ---> ~i Sarne Description TVD +N/-5 +E/-W Northing Easting Deg Nlin Sec Dcg D1in Sec Dip. Dir. ft ft ft ft ft - __ 2N-311Awp02 T-3 5250.00 5396.28 1367.02 5917369.01 462370.97 70 11 6.770 N 150 18 11.015 W~ -Plan hit target Annotation -- _- - !VfD T~'tl n ft -- --- f - 3000.00 2406.71 KOP; 4 DLS Casing Points MD TVD Diameter Hole Size Name _ ft ft in in 3000.00 2406.71 9.625 1 2.250 9 5/8" 8620.50 5700.00 7.000 8.500 7" Formations - -- MU f'Vl) Formations Lithology Uip:inglc Dip Direction ~1~;~R,t ~~ 4 ~onocoPhillips Alaska, In'~! Anticollision Report Compan~~: ConoeoPhillipsAlaska Inc. - _ _ - - Date: 11/14/2006 Tins. 10:20:26 Page: 1 Wield: Kuparuk River Unit Re1'crcnce Site: Kuparuk 2N Pad Co-ordinate(~N:) Kcfercncc: Well: 2N-311, True North Reference Well: 2N-311 ~'crtical (I'VU) 1eference: 2N-311: 150.0 Rel'crcncc ~Vellpath: Plan: 2N-311A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 2N-311Awp02 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 30.70 to 8620.50 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1058.98 ft Error Surface: Ellipse + Casing Casing Points ~~1D ~f~'D Diameter Hule Size Vame ft ft in in 3000.00 2406.71 9.625 12.250 9 5/8" 1 L 8620.50 5700.00 7.000 8.500 7" Plan: 2N-311Awp02 Date Composed: 11 /14/2006 Version: 4 Principal: Yes Tied-to: From: Definitive Path Summary -_ _ - __ <------- ---------- -Offset Wellpath -------> Reference Offset Ctr-Ctr - No-Go 1ltowable Sile Well N'ellpath '11D ~-U Distance :1rca Deviation ~~'arning ft ft ft ft ft _ Kuparuk 2N Pad 2N-303 2N-303 V4 395.03 400.00 120.12 _ 5.48 114.64 Pass: Major Risk Kuparuk 2N Pad 2N-305 2N-305 V6 345.91 350.00 91.31 5.08 86.23 Pass: Major Risk Kuparuk 2N Pad 2N-307 2N-307 V7 720.28 725.00 55.67 9.78 45.89 Pass: Major Risk Kuparuk 2N Pad 2N-308 2N-308 V2 900.29 900.00 53.82 14.95 38.87 Pass: Major Risk Kuparuk 2N Pad 2N-311 2N-311 V1 3025.00 3025.00 0.17 63.82 -63.65 FAIL: Major Risk parent well )GRAM ORIGINAL \Vlil.l. UI~:I AII..~ Nan. ~N S }: }\' Nunlun_ 1.: nc LaLtuJc 1 ~ J~ ~lo~ 2N~311 IUJI 43.`)`J j`II 17%C 3% JaM)7G 2% 7U'I01l G7RN IiU-1x~1.CJGW NA ANrI-CC)I.I.IJICIN til~: I'7'INCiJ CUMI'ANY UI~:1 All.s Imcr}x.lation MclhtdMD Intcr~ul. 25 On ~nnucul'hill~ps Alaska ln~ 13~},a, xane~ Prum ulno 0o rn xezo su E"e-~"""~~° Mavmum R.t0cc IUiR n3 kcrcrcn<e_PLut ?N :IlAvvl.i"_ Calculation MethuJ. hLmmum Cunawrc I~.rrm S\slcm ISCWSA ' nMetlu+J. 'I'rav CrlinJ.~r N~ntli Error Surfnee. 171ipueal ~ Casing \Vamine MctlivJ kulcs Ilax.J From Culour 'Ib MD 0 250 250 500 500 750 750 1000 1000 1250 1250 6750 6750 7000 7000 7250 SlM\'Ll' [~H~ W HAXI Uryw Fm pynn ~ au~.n I Inn r,wi .,wuw sx asa l.~.d I\~~M,•\+ T a.vn ..v.v I1 17 o~ 7 %aa: Pl-?IIA YarmrNNynaN. ?\-?II rlc as Ap)_ ?UW.W wE: k.~t aaiwn: L~-?II. 150.00!1 l.S.~ctiun U,Siu X~Em vu~ md~ fir:-w rra ~~I~v From Colour To MD 0 250 250 500 inn 750 1000 1250 6750 7000 7250 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separatiou [25tt/inJ s~~o MD m~ A<i 'rvu m--s -E-w uL~g 'rra« vs« 'rargm LEC~IND 2N-303 (2N--303 ~_Mviur Risk ~ 2N-30xi2N-u~%i. M,il.~~kisk 'N-30±12N-31U~-Mayor Risk ~ Nlvn .N-311n '_K-it~7 t2N-3671. Maioi l:~.k ~ =N-311AvvPo2 0 I 3000. W 17 71 %X7 2 32M.(Nl 53.79 17 JG 3 3272.73 X..50 15 7R J 7JR3.21 54.50 15.73 5 %033.07 .1U W I5.'1R G 8620.50 NI GO I5.'JS 2JIM %1 2il'J 1~1 2571'1!. Jri%5 I I 12511 UlI j7alo0 laio ar I S71 (1J I MJ.UI jai3 27 i3'M 2N 575`128 2:3.jJ Ira} u3X> lazy o3 2%0.`12 .1(X1 12(11X1 1539.22 2`)2 K2 ?INl -26.36 1661 i3 1211..17 Ua1 Oal 515%.10 1367.02 3 tX1 IT).99 55!,!.73 2N-311AN}+02 T-? IJ7U.77 trlx) 0.1X) 5`}1,1.16 • Travelling Cylinder Azimuth (TFO+AZf) (deg] vs Centre to Centre Separation [ft] • ~ 2N-311A -DRILLING HAZARDS SUMMARY 81/2" Open Hole & 7" x 41/2" Production Casing Interval Event Risk Level Miti ation Strategy /Contin ency Swabbing Campaignian Moderate Minimum mud weight of 9.6 ppg, mandatory sands (50 ft TVD below C- flow check above sands on all trips 80 High reservoir pressure Moderate , 10.0 ppg minimum mud weight in reservoir. 7" Contin enc to set available 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 16 MW a uivalent 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, ro er hole fillin use of tri sheets Differential sticking Moderate Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever ossible Barite sag Low Good drilling practices as documented in well Ian Lost circulation Low Keep hole clean -use PWD to monitor hole cleaning. If losses occur- reduce pump rates and mud rheolo ,use LCM 2N-311A Drilling Hazards Summary ORIGINAL ' Schlumberger CemCADE Preliminary Job Design 4 1/2" to 7" Lon string Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Location: Tarn Client: ConocoPhillips Alaska Revision Date: 11/16/2006 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com ^ revlous sg. 9 5/8", 26.0# casing 2999' MD 7", 40# casing < Top of Tail at 7,533' MD Taper at 7,800' MD 4 1/2", 12.6# casing in 8 1/2" OH TD at 8,620' MD ~5,~00' rvD~ Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail Slurry Minimum thickening time: 230 min. (pump time plus 120 min.) 12.5 ppg LiteCRETE + 0.05% B155 + 0.30% D65 + 0.2 gps D47 - 2.53 ft3/sk Annular Volume (7" casing): 0.1268 ft3/ft x (7800' - 7533') x 1.40 (40% excess) = 47.4 ft3 Annular Volume (4.5"casing): 0.2836 ft3/ft x (8620' - 7800') x 1.40 (40% excess) = 325.6 ft3 Shoe Volume: 0.0854 ft3/ft x 80' x 1.00 (no excess) = 6.8 ft3 Totals: 47.4 ft3+ 325.6 ft3+ 6.8 ft3= 379.8 ft3 379.8 ft3/ 2.53 ft3/sk = 150.1 sks Round up to 160 sks BHST = 145, Estimated BHCT = 112`F. (BHST calculated using a gradient of 2.6/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 5 20 4 4 Pressure Test 10 14 CW 100 5 20 4 18 Drop Wiper Plug 5 23 MudPUSH II 5 40 8 31 Tail Slurry 6 68.2 11.4 42.4 Drop Top Plug 5 47.4 Water 4 20 5 52.4 Switch to rig pump 5 57.4 Displacement 7 269.2 38.5 95.8 Slow to Bump 3 20 6.7 102.5 MUD REMOVAL Recommended Mud Properties: 10.0 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 perjoint from 7533' MD to TD for proper cement placement. ORIGINAL r ~ Schlumherger CemCAD Ewell cementing recommendation for Longstring Operator : ConocoPhillips Well 2N-331A Country :USA Field Tarn State :Alaska Prepared for :Jason Brink Location Proposal No. Service Point Date Prepared : 12-11-2006 Business Phone FAX No. Prepared by :Maureen Torrie Phone 1-907-265-6336 E-Mail Address mtorrie@slb.com ~~~ G7 C ~G 9~~ ATE Prudhoe Bay (907659-2434 (907) 659-2538 Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that maybe achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring I l well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger ^^161NAL Client ConocoPhillips Well 2N-331A String Longstring District Prudhoe Bay Country USA Loadcase 7 to 41-2 Inter, LC Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :8620.0 ft BHST :145 degF Bit Size : 8 1/2 in Previous String MD OD Weight ID ft in Ib/ft in 2999.0 9 5/8 40.0 8.835 Landing Collar MD :8540.0 ft S~Irg~r Casing/liner Shoe MD :8620.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 7780.0 7 40.0 26.0 6.276 L-80 5410 7240 BTCM 8620.0 41/2 40.0 12.6 3.958 L-80 7500 8430 IBTM Mean OH Diameter :8.500 in Mean Annular Excess :40.0 Mean OH Equivalent Diameter: 9.125 in Total OH Volume :454.7 bbl (includin excess Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 7800.0 8.500 40.0 9.033 8620.0 8.500 40.0 9.646 MD ft Frac. Ib/ al Formation Data Pore Name Ib/ al Lithology 3130.0 12.50 8.30 C80 5530.0 12.50 8.30 C50 6030.0 12.50 8.30 C40 6400.0 12.50 8.30 C37 7430.0 12.50 8.30 T7 7830.0 12.50 9.00 T4 8030.0 11.60 9.00 T3 8230.0 11.60 9.00 T2 8620.0 11.60 9.00 C35 Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1300.0 1269.4 30 0.4 8620.0 5700.0 145 2.1 2N-331ASidetrack Cementciw;l&14-2006; LoadCase7to41-2lnter,LC;Versionwcs-cem45_89 • Page 2 ^RIGINAL • Client ConocoPhillips Well 2N-331A String Longstring District Prudhoe Bay Country USA Loadcase 7 to 41-2 Inter, LC Max. Deviation Angle : 58 deg Max. DLS :4.281 deg/100ft Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. 0.0 0.0 0.0 0.0 0.000 30.7 30.7 0.0 0.0 0.000 130.7 130.7 0.0 0.0 0.000 230.7 230.7 0.3 35.4 0.250 330.7 330.7 1.0 9.4 0.743 430.7 430.7 2.0 7.4 1.041 530.7 530.5 3.3 9.4 1.303 630.7 630.2 6.1 12.7 2.802 730.7 729.2 10.4 12.1 4.281 830.7 827.0 13.1 12.1 2.760 930.7 923.8 16.1 11.3 2.988 1030.0 1018.6 18.5 9.3 2.490 1130.0 1112.9 20.5 10.6 2.016 1230.0 1205.2 24.5 12.0 4.066 1330.0 1295.7 25.9 9.6 1.694 1430.0 1384.4 29.0 6.9 3.378 1530.0 1470.2 33.0 9.5 4.162 1630.0 1553.1 34.9 9.6 1.951 1730.0 1633.7 37.7 9.3 2.774 1830.0 1711.3 40.7 9.6 3.014 1930.0 1785.2 44.0 10.7 3.417 2030.0 1855.1 47.1 11.0 3.127 2130.0 1921.6 49.5 10.4 2.453 2230.0 1985.1 51.6 9.6 2.134 2330.0 2045.7 53.8 9.1 2.253 2430.0 2103.4 55.8 9.0 1.972 2530.0 2158.5 57.3 7.8 1.824 2630.0 2211.7 58.4 7.7 1.123 2730.0 2264.0 58.5 8.6 0.742 2830.0 2316.7 58.0 8.5 -0.506 2930.0 2369.7 58.0 8.5 0.020 3000.0 2406.9 57.7 8.9 -0.665 3030.0 2423.1 57.1 10.1 -4.081 3130.0 2478.8 55.2 14.4 -4.003 3230.0 2536.1 54.8 17.0 -2.133 3330.0 2592.5 56.5 16.0 1.865 3430.0 2647.7 56.5 16.0 0.000 3530.0 2702.9 56.5 16.0 0.000 3630.0 2758.1 56.5 16.0 0.000 3730.0 2813.3 56.5 16.0 0.000 3830.0 2868.5 56.5 16.0 0.000 3930.0 2923.7 56.5 16.0 0.000 4030.0 2978.9 56.5 16.0 0.000 4130.0 3034.1 56.5 16.0 0.000 4230.0 3089.3 56.5 16.0 0.000 4330.0 3144.5 56.5 16.0 0.000 4430.0 3199.6 56.5 16.0 0.000 4530.0 3254.8 56.5 16.0 0.000 4630.0 3310.0 56.5 16.0 0.000 4730.0 3365.2 56.5 16.0 0.000 4830.0 3420.4 56.5 16.0 0.000 4930.0 3475.6 56.5 16.0 0.000 ~f~1~[~~r~r 2N-337ASidetrackCement.cfw;12-14-2006; LoadCase7to41-2lnter,LC;Versionwcs-cem45_69 • Page 3 !'RIGINAL U Client ConocoPhillips Well 2N-331A String Longstring District Prudhoe Bay Country USA Loadcase 7 to 41-2 Inter, LC MD ft Directional Survey Data ND Deviation Azimuth (ft) de de Dogleg Sev. de /100ft) 5030.0 3530.8 56.5 16.0 0.000 5130.0 3586.0 56.5 16.0 0.000 5230.0 3641.2 56.5 16.0 0.000 5330.0 3696.4 56.5 16.0 0.000 5430.0 3751.6 56.5 16.0 0.000 5530.0 3806.8 56.5 16.0 0.000 5630.0 3862.0 56.5 16.0 0.000 5730.0 3917.2 56.5 16.0 0.000 5830.0 3972.4 56.5 16.0 0.000 5930.0 4027.6 56.5 16.0 0.000 6030.0 4082.7 56.5 16.0 0.000 6130.0 4137.9 56.5 16.0 0.000 6230.0 4193.1 56.5 16.0 0.000 6330.0 4248.3 56.5 16.0 0.000 6430.0 4303.5 56.5 16.0 0.000 6530.0 4358.7 56.5 16.0 0.000 6630.0 4413.9 56.5 16.0 0.000 6730.0 4469.1 56.5 16.0 0.000 6830.0 4524.3 56.5 16.0 0.000 6930.0 4579.5 56.5 16.0 0.000 7030.0 4634.7 56.5 16.0 0.000 7130.0 4689.9 56.5 16.0 0.000 7230.0 4745.1 56.5 16.0 0.000 7330.0 4800.3 56.5 16.0 0.000 7430.0 4855.5 56.5 16.0 0.000 7530.0 4911.7 55.1 16.0 -1.430 7630.0 4971.1 52.1 16.0 -3.000 7730.0 5034.6 49.1 16.0 -3.000 7830.0 5102.0 46.1 16.0 -3.000 7930.0 5173.3 43.1 16.0 -3.000 8030.0 5248.1 40.1 16.0 -3.000 8130.0 5324.6 40.0 16.0 -0.070 8230.0 5401.2 40.0 16.0 0.000 8330.0 5477.8 40.0 16.0 0.000 8430.0 5554.4 40.0 16.0 0.000 8530.0 5631.1 40.0 16.0 0.000 8620.0 5700.0 40.0 16.0 0.000 2N-331ASidetrackCementctw;l2-14-2006; LoadCase7to41-2lnter,LC;Versionwcs-cem45_69 Page 4 ORIGINAL Client ConocoPhillips Well 2N-331A String Longstring District Prudhoe Bay Country USA Loadcase 7 to 41-2 Inter, LC Section 2: centralizer placement Top of centralization :150.0 ft Bottom Cent. MD :8613.3 ft Casing Shoe :8620.0 ft NB of Cent. Used :72 NB of Floating Cent. :55 ~c~luma~rg~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 3020.0 24 1/3 4" CENTERING GUIDE 4 0.0 3000.8 7100.0 0 0/0 0.0 3020.0 7780.0 17 1/1 S1102570-7-4-25 (3/16")A 0.0 7119.2 8620.0 31 3/2 S1103641-4 1/2-4-36E 1/8" B 26.0 7786.7 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ibf Ibf S1103641-41/2-4- S11025 4" 4 7 8.750 8.750 No Weatherto N.A. 36E (1/8")B 70-7-4- CENTE rd 25 RING (3/16")A GUIDE (1) -Centralizer pertormance data is based on tests by WEATHERFORD as per the current API 10D specifications 2N- 331 A Sidetrack Cement.cfw ; 12-14-2006: loadCase 7 to 4 1-2 Inter, LC ;Version wcs-cem45_89 ORIGINAL Page 5 N.A. N.A. I Client ConocoPhillips ~I ~~~~ Well 2N-331A String Longstring District Prudhoe Bay Country USA Loadcase 7 to 41-2 Inter, LC Section 3: fluid description Fluid No: 1 Rheo. Model : BINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type :Fresh Mud DESIGN Density :10.OOIb/gal P~ :19.000 cP Tv :12.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :289.2 bbl MUDPUSH II DESIGN Fluid No: 2 Density : 11.00 Ib/gal Rheo. Model : HERSCHEL_B. k : 6.20E-2 Ibf.s"n/ft2 At temp. :120 degF n :0.315 Ty :9.011bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :40.0 bbl CW100 DESIGN Fluid No: 4 Density : 8.33 Ib/gal Rheo. Model :NEWTONIAN At temp. : (degF) Viscosity :5.000 cP Gel Strength : (Ibf/100ft2) Job volume :40.0 bbl LiteCRETE 12.5ppg DESIGN Fluid No: 5 Density : 12.00 Ib/gal Rheo. Model : HERSCHEL_B. k : 4.70E-3 Ibf.s^n/ft2 At temp. :117 degF n :0.850 Ty :1.861bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid :9.750 gal/sk Job volume :68.2 bbl Dry Density : 199.77 Ib/ft3 Yield :2.53 ft3/sk Quantity :151.37 sk Sack Weight : 94 Ib Porosity :51.5 % Solid Fraction :48.5 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Base Fluid :9.550 gal/sk Additives Code Conc. Function D065 0.300 %BWOC DISPERSANT D047 0.200 gal/sk blend antifoam 6155 0.050 %BWOC retarder 2N-331ASidetrackCement.cfiv;12-14-2006; Loadcase]to41-2lnter,LC;Versionwcs-cem45_69 Page 6 '~~'~~~~~ql a +~ Client ConocoPhillips ~~I~lr~~r Well 2N-331A String Longstring District Prudhoe Bay Country USA Loadcase 7 to 41-2 Inter, LC Section 4: fluid sequence Original fluid Mud 10.00 Ib/gal P~ :19.000 cP Tv :12.00 Ibf/100ft2 Displacement Volume 309.2 bbl Total Volume 457.5 bbl TOC 7533.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al CW100 40.0 1263.2 5006.7 8.33 viscosity:5.000 cP MUDPUSH II 40.0 1263.2 6269.8 11.00 k:6.20E-2 Ibf.s^n/ft2 n:0.315 Tv:9.01 Ibf/100ft2 LiteCRETE 12.5ppg 68.2 1087.0 7533.0 12.00 k:4.70E-3 Ibf.s^n/ft2 n:0.850 Tv:1.86 Ibf/100ft2 Water 20.0 7559.6 8.30 viscosity:5.000 cP Mud 289.2 0.0 10.00 P~:19.000 cP Tv:12.00 Ibf/100ft2 Static Security Checks Frac 313 psi at 2999.0 ft Pore 213 psi at 2999.0 ft Collapse 5134 psi at 7780.0 ft Burst 7179 psi at 6269.8 ft Cs .Pum out 59 ton Section 5: pumping schedule Name CW 100 Pause CW 100 Pause MUDPUSH II LiteCRETE 12.5ppg Pause Water Pause Mud Mud Flow Rate (bbl/min) 5.0 0.0 5.0 0.0 5.0 6.0 0.0 4.0 0.0 7.0 3.0 Volume (bbl) 20.0 0.0 20.0 0.0 40.0 68.2 0.0 20.0 0.0 269.2 20.0 Pumping Schedule Stage Time Cum.Vol (min) (bbl). 4.0 20.0 10.0 0.0 4.0 40.0 5.0 0.0 8.0 40.0 11.4 68.2 5.0 0.0 5.0 20.0 5.0 0.0 38.5 269.2 6.7 289.2 Inj. Comments Temp. (degF) 80 80 Pressure Test 80 80 Drop Wiper Plug 80 80 80 Drop Top Plug 80 80 Switch to Rig Pumps 80 80 Slow to Bump Plug Total 01:42 457.5 bbl hr:mn Dynamic Security Checks Frac 45 psi at 8030.0 ft Pore 206 psi at 7830.0 ft Collapse 5024 psi at 6291.6 ft Burst 6721 si at 0.0 ft Temperature Results BHCT 112 degF I Simulated Max HCT 145 degF Simulated BHCT 112 degF Max HCT Depth 8620.0 ft CT at TOC 111 degF Max HCT Time 00:00:00 hr:mn:sc 2N-331ASidetrackCement.ciw;12-14-2006; LoadCase7to41-2lnter,LC;Versionwcs-cem45_89 Page 7 ORIGINAL • Client ConocoPhillips Well 2N-331A String Longstring District Prudhoe Bay Country USA Loadcase 7 to 41-2 Inter, LC Ibrgal ft 8 10 12 0 NSn. Hydrostatic ''. Max. Dynanc '~.. - Nin. Dynamic '. --• Frac - Pore Hydrostatic ~ i ~~ 0 0 o iII ', . _ ..-i f 0 Flui d Sequence Dynamic Well Security O O O_ X N 1Z0 N y d I% 'Q o Schlumhcrg~r 14 ~ °o ~ Ic. Wmp Ress. c. WHP .a ~O a° 2 O 0 40 80 120 Time (min) 0 0 40 80 120 Time (min) ueptn = ae~u n Collapse Time (min) m +T a ~o ~~ N N a` C C Q W 0 10 20 30 40 50 60 70 80 90 100 110 Time (min) 2N- 331 A Sidetrack Cement.cfw ; 12-14-2006: LoadCase 7 to 41-2lnter, LC; Version wcs-cem45_89 G~IGINAL Page 8 Client ConocoPhillips Well 2N-331A String Longstring District Prudhoe Bay Country USA Loadcase 7 to 41-2 Inter, LC Secti on 6: WELLCLEAN I I Simulator ft 0 100 0 ~ 0 1 - tvlud Contarrination -Uncontaminated Slurry o O O lf) • deg 30 -..... _. O O O O Fluid Sequence Cement Coverage Fluids Concentrations s° 3 a o aooa- s~wa ,,., 3404-; 3}04 ,.-- z ~. ~a0a~ '. s ~aoa r , . r .~< ~ soaa aaoo ~ 6ooa-`' 6aaa ~aoa- ~ooo eaoa- aaoa I•A ud '~~.+Jaker 0 LiteCRETE 12.5ppg D t•AUDPUSH II D CVJ100 z r s 3404 ,.-- ~a0a t soda g 600a ~4oa 8004 0 High Low 0 Medium 0 FJone Page 9 2N-331ASidetrackCement.cfw;12-14-2006: LoadCase1to41-2lnter,LC;Versionwcs-cem45_69 Uncontaminated Slurry Schlumdurg~r Deviation Risk Mud on the Wall ~ i ~ 0 2N-311A SIDETRACK Longstring Top of Cement KO plug @ 2774' MD 2999' MD Sidetrack KOP @ +/- 3000' MD, ' 2406' TVD Tubing Jewelry: 2.875" DS nipple +/-500' MD Bottom of Cement KO plug @ 3400 MD 4-'/z' centralization: • one perjoint. Bowspring centralizers on stopcollars. LOT @ 509 "fVD = 11.6 p pg EMW 10C=7357 MD # TVD MD OD Type Company 1 2500 3166 1.00 Dummy Camco 2 3600 5155 1.00 Dummy Camco 3 4450 6695 1.00 Dummy Camco 4 5024 7663 1.00 Shear Camco NOTE: mandrel #4 set 1 jt above sliding sleeve CMU Sliding Sleeve w/ 2.813" DS profile one joint ', above D nipple 2.75" D nipple w. no go ID(<70 deg.) one joint above seal assembly 7" 26.0# L-80 BTCM ~~ Cement 7800 MD / 5081 TVD Plug #2 (x-over 200' MD above Bermuda) 7" centralization: • One per joint to 300' above TOC. Bowsprings. • One per joint for 200' above surface casing shoe. Centering guides. • One per third joint from surface to 500' MD. Centering guides. Production Hole Logging: Longstring -LWD Topset -LWD IOC=s i 5. MD 4-''/2' 12.6# L-80 IBTM ~" ~~ Cement 8620 MD! 5700 TVD Plug #1 8-1/2" hole size TOC = 500' above Bermuda ~ Bermuda top @ 8033 MD/ 5250 TVD Brink 11/14/06 8 '/2' open hole /"1 ~ ~ ~'1 ~ ~ ~~ • ~ o+~aPhll~ s Circulate corrosion inhibitor before landing tubing hanger. Inhibit corrosion up to GLM #3. 3'/2' FMC Gen 5 Tubing Hanger, 3'/z' L-80 EUE8RD Mod pin down 3'/z" 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3'/z" 9.3# L-80 EUE8RD Mod Tubing to Surface - Tubing & hanger TO BE DRIFTED TO 2.91" 3'/i' Camco 'DS' nipple w/ 2.875" No-Go Profile. 3'/2' x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at +/- 500' MD 3'/2' 9.3# L-80 EUE8RD Mod tubing to landing nipple 3'/2' x 1"Camco'KBMG' mandrels 3'/z' x 6' L-80 handling pups installed above and below, EUE8RD Mod 3'/z" x 1"Camco'KBMG' mandrel w/ shear valve, pinned for 3000 psi shear (casing to tubing differential), 3'/2' x 6' L-80 handling pups installed above and below, EUE8RD Mod 3'/2' Baker'CMU' sliding sleeve w/ 2.813" Camco DS profile, EUE8RD Mod box xpin. 3'/z' x 6' L-80 EUE8RD Mod handling pup installed above 3'/2' Camco 'D' nipple w/ 2.75" No-Go profile. 3'/z" x 12' L-80 EUE8RD Mod spaceout pup installed above, 3 Yz' x 6' handling pup installed below 3 %2' Baker 80-40 GBH-22 Locator Sub w/ 3'/2' EUE mod box Baker seal assembly w/ 15' stroke w/'/2 mule shoe BOT x-over sub 7" BTC mod box x Stub Acme box BOT 80-40 Seal Bore Extension, Stub acme pin x pin, 20' (set +/- 200' MD above the top of the Bermuda interval) BOT x-over sub, Stub Acme box x 4-''/2' IBTM pin 4-''/2' 12.6# L-80 IBTM pup joint • • SHARON K. ALLSUP-DRAKE CONOCOPHtLLIPS ATO 1530 700 G ST. ANCHORAGE AK 99501 j PAY TO THE ST~T,E ~ ~ / ~1.i {~~ ORDER OF v1 Lw7{' ~~G- 3 ~-Uc~ / ,P /G~ w `-~ (YG«i G~fiLC~c~'v`2-~- ~~(~C~ '~-~ ~Gl~ DOLLARS ~ ~%~,u= .....1166 DATE /`~ ~e~~~~/ Fr15 /441 J PMorganChase ~ Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH MEMO --- - ~~" , L~.~~! ~ '~~ --- -- -- -E~~-- ~:044~L55i1~:528747~907927u'LL66 • • T~I~SM~T1'E~~. ~EZ'Z'ER ~~~CK~..jST wELL NAME ~~G~ 2~(/•'3l1 •~ PTD# ~' ~ ~9 " Ueve(opment Serviee Exploratory Strati ra hic Test g P _ Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK j ADD-ONS WHAT j (OPTIONS) APPLIES ~ MULTI LATERAL (If last two digits in API number are between 60-69) TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing we l l Permit No. , API No. 50- - _ Production should continue to be reported as a function of the original API number stated above. PLOT HOLE ~ In accordance with 20 AAC 25.00~(f), all records, data and logs j ;acquired for the pilot hole must be clearly differentiated in both i j well name ( PH} and API number (50- - -_) from records, data and logs ~ j .acquired for well !SPACING EXCEPTION I ' ~ j The permit is approved subject to full compliance with 20 AAC ~ 25.055. Approval to perforate and produce ; inject is contingent i upon issuance of a conservation order approving a spacing j I exception. assumes the ~ ~ liability of any protest to the spacing exception that may occur. i ~ j DRY DITCH j All dry ditch sample sets submitted to the Commission must be in SAMPLE ~ no greater than 30' sample intervals from below the permafrost or ~ ~ I from where samples are first caught and IO' sample intervals i ~ i C through target zones. ~ ` Non-Conventional I ~ Please note the following special condition of this permit: i ,production or production testing of coal bed methane is not allowed ! I Well ~ for (name of welly until after (Companv Name) has designed and j implemented a water well testing program to provide baseline data ;' on water quality and quantity. (Companv Name) must contact the ~ Commission to obtain advance approval of such water well testing Rev: 1 /2~r06 C:`jody\transmittal checklist • • ~_~ : „ ; N ~, ° a ~ , N~ : i ~o ~ ~ ~ : o~ .~ . ~ ~ ~ ~ ~~~ ~~~ , ~~ ~~~ ~~ ~ ~~ Q ' 3 ~ ~, N, c . v ~ ; ; ~ ~ a , ; ; a 4 ~ c, _; O Z ~ o ~: ~ o a i c, ' ~ O~ ~ ~ ~ ~ ~ ~ p a ~ o ~ M. ~ o ~ N, ~ ~ .°c ao. ; o, ~ ; ; ; ; ; ~ °oi ~, °~ ' ~ 'u c ~ °: i o co w ~ fl: o D: ~ O ~ ~ ~ ~ ~ ~ _ ~ ~, ~~ 7, o r ~ 4 ~ ~ N. , ,r O. O. O ~ ~ O, ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ O, 3 a ~ ~' ~ O; ~ ~ L' N' C ~ Nh V, g ~~ ~ ~ 4 ~ O ~ ~ ~°~ tp, ° °?; , n. M. o. ,~ ~ m, ~ o c ° a, ' O' I j ~ J. 4. ~ .Q, ~ y ~, 3. w o, ~ tA, ~ N N f6 a, _ ~ ~~ ~ O. ~ N. O. ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~~ ~~ ~ ~~ c 7 ~ o to ~ ~ . y o y i c. a, •~ ° ~ N, M ~, N. t. ~ ~ ~ ~ ~ ~ '"' ~ ' W c 7 o W Z N ~ ~ pr ° ~ 3 ~, ~ ~ ~ ~ ~ ~ ~ ~ M' ~ ~ ~ a c, ~ ~' N o, fl. ~, ~ Or ~ , ~ ~ ~ rn N. Or :~~ ~' Y' ~ ~ N 7 7 ~ r: ~ N Q N ~ ~ ~ ~ r ~ ~ N, N~ N, , ~ 7. ~ , ~ ~ ~, ~ ~ . ~ ~~ , 7, 01, ~~ I ~ 3 . M a ~ 01 ~, c ~ 0 3' ~, ~ 'x. ~~ V °~ m ao ^ ° ~ U N N' C' p. 4 N N N' V, X , M, >. ~ y , • ~~ N. `~ U. ~ ~ . Z. N. M N O °. ~ ~ ~ N O ( 3 N O c O ~ ~ ~ ~ . ~ ~ M . ~ M ~ O' ~ Q ~ ~. O' d ~ S m Q; . O, a~' .~ . ~ N y ~ ~ ~ M: -p. C' ~~ Z, a> ~ ~, ~ M, . ~~ y, ~ fl, .~ O, m a ~ N, ~ ~ p. ~ N' a 4 ~ YI m c 'c, o ~ °c. ~, c, E ai rn 3, °' •y ~, U ~ o a 0 •o o c ' c ~ a • ~, ~; ~; , 4 o ui o ; o ~''~ o a N , ~ , ~ ~ 3 x u i ~a O 0, - Qo Qo a0 ; ° w ° °~ a °i >; m ~ ; cf4i ; o; a, _°, aci; Z Z ~ ~~ M, O. M• M• M, ~ ~ ~ ~ ~ ~~ 7. U: U N O ~' cp ' O' 0) ' ~ Z w ° U ~: ° O ~ c.~ Q O' O' U c.~ o' -_ o: o. U ¢ u~ o. m a~, o. ~ ~ a O. m. m ~ Q. ~ N, , I ~, X- c ~ Y w a , ~ Q o , . , : , t ; ; ; O N, ~.. N, ~' N, N, N. ~ ~ ~ N, N, N, ~' ~ ~ N, N, N, ~ ~ ~' ~ ~ N ~ Q, Q, Q, Q, Z Z Z Z Q, Q, Q, Q, N, f/} N~ N~ N, N, N, N, N, ~ N~ Q, N, N~ N~ N, N. N, N , N, ~, O N, Q, Q, Q, ~ , ~ , . ~ ~ , , , , , ~ , , , Z, Z, Z, Z, }, ~, ~, }, }, Z } } } ~ ~ } Z, } Z Z Z i ~ ~ ~ ~ ~ •~ ; ; E. ; 3; ; ; ; ; ; , ~ m. , I ~ ~ I • : : Z O' I U ~' ~ ~ ~ ~ : g ~, t ° a- il ~ o ~ i ._ T o U l ~ ~ 3; ~ y 3. o; rn l O. ~, `'~ , c~ Z, O ~ ~ ~ ~ ~ ~ ~, O y, N, ~ N~ ~ ~ ~ ~ ~ N. ~ O. ~ ~ O. N, ~ ~ °- Z ~ c, ~ ~ ~ ~ ~ y c. ~: N. ~ ~ U ~ ~ ~ Q ~ ~ is ~ U ~ ~~ d, ~ N, N ° . > N W ~ ~ Of ~~ ""' •~, ~ ~ O~ ~ 3 ~ ~, ~ M. o a ~, ~ ~~ O N. N ~ c n ~ ~ O, ~ ~, T ~ a . .~ °~ ~ : ~ ~~ . N` a, d~ ~ o~ c: _ ~ ~ ~~ 4 °. ~ o o, ~ ° a q . ~ ~ °~ ~ U Y Z , -o, t ~ o' c, a ` Z ~ o a~' •c. m a ~ 3' o m 4 N' c. rn t S, o. c, m c' y' m. o. o, o' ~ rn a~' i° ° t, Q' ui' m' ar a~ o c. of . . ~ ~ ~ E ~ - a C E C .- _ N O M' C' c y C O f-'' ~S~ w~ ~' ~ ~ ' N' a N t a c C ~ ~ , ~ °" , °" , , V ~ Q p 7 _ a N V ~ ~ „ 1] ~ > N T Q ~ d ~ ° O, c U ~~ c a' ' ' N ~ y~ ~ ~: ~ O' ~ ~ ~, ~ ~ ~ ~ O, ~~ V~ flt ~~ N' N. ~: ~ ~ ~~ lq~ O: Qj~ d, , '~, ~~ Q. (0, ~ S, ~, m ~ ~ f0' O. p' p~ > ~~ N Ul C Ul i Y I Q ~ ' O. ~~ R ~ , ~~ -oa m >i O 7 7 ~ ; ~ , a a N ~ w~ ~; ; ~' ~ ; 4 . O ~ ~~ °~ •m; ~ ~ 4 ~; a ; ~ ; ` °~ a ~- 3~ . ~ i , m. ~ o ~ ~ , . m: o. ti ~ ~ ~ o~ ~ ' a ~ o~ a, E. , m' ~ ~, ~ a o o' •~, c ~ ~ ~ ~ M. ~, ._, a i ~ o ~, ~ ~, ° ~ °, Q 3 , - o' ' m' h o' ~ w ° ~ o n. Q ° a ' ,c' a , m' ~ v > ~ 3. 3 . a ~ a i > ° ~' ~ ,o .~ ~ 'v, ..-, o' m ° ~, ~ o' ~ n 'a ~, m N m, o. ~ a i 3, o' _: ~, w U 0 a -~ a, o n c , m ai o, _ . , o, o, ~, a~' Q a i a a ~ o. ~ o o co o~ c ~ o ~' m o, o, c ° Y ' ' 6 m, o', o N' ' a E' ' , m. a a~ E' r m c. .o, ~ a. o: m, °: ,~ ti; ' ' a~ c. ~ ~ S m _: a. m ° o ~ m E a~. o< rn ~ m, ° ° ~ O. N O °- O. ~ v; v, •o, t' a o -_ ~i m O: m ? a o ~ ~ ~ of m m ~ m a ~; c v. '3, ' ... N, o ° c N ° ~'~ o o n v. , . ~ , o, ' o. m 3 ~ ~ .N .y, m a~ ~ .c: ~ 3. ' ~ ~, ~, ,~, m. ~: c a >, a. 3 _ c ~ o . m O iL _ o` .a c _: a a ,~ a. °, x ar ar ~ .o. a c~ f0' .o a w' a~ °~ _ o o. > `~' • ' , .4? r, ~ , , a , , . . ~, ° °, °,I , _o a ° ° , ~~ U O m' E a>~ a~, ar ~~ m a' o .c, c c, c ~ v. 3' ° m' a a o '~ ° ca m' cv o 3 v, :6 -, o' o a ~ o: o o. ' m' ~ o m, ; ' c c. a~ c, ° c' m, o m. m, ' m. ~, o m m. E ~ m. c i o , ° ~ a~ o o ~ _ ~, m v m ° a ~ - 5 3 ~ v . ~ m, ,n m, c a '~ ~ O N m a ° ° _ : o: o' . ~, '>, m, m, a . , ° m. n ~ .o, ~, >' > 3 ~ . . : c. a. a. a a~ O1 . u w: w. Y, : o' ax ~ , °- •E, ~' ~ :°' ,, °? Y >, U c m; a, aoi J, _ ~~ °~ °~ S, ~, ~; - °~ ~; ~ ~', U, w; 4 4 a~ ~ O, O, a; a; m U - ~ 3 ~ oc ~, Q', a, z' o; ~ ~; ~ ~ cn U U U U ~ ~ a ~ a; U ¢ ~; ¢ ~ ~~ »-; o; ,~ O; O. ~; °~ m m U ~ °- ~ ~ N ~ a~; ~ ~ao~i; af6i; to a D U o; U ~ ~ W a , , , , , , , , , , , , , , ~ , , , , , r N M ' ' ~ (O ~ 0 O ~ N M V~ CO I~ W T O ~ N M~~ O ~ W O O M M M j ~ ° U ._. ._____ d . I 0 O ~ ~ ~ __.._______ ~ _ ~ r ~ ~ ~ ~ N N N N N N N N N N M M _--________ __..__-. M M M M M U i ~ ~ `~ O N 0 `~ 0 N i ~ O `~ N N O ~ W_ ~ •i ~ N a ~ ~ N~~ ~~ ~ ~~ OI N O m ' ~ M a+ '~, ~ ~ O ~ N .1 N C d i 01 O O o E o. ~ ~ a ~ j c n U U Q W ~ a ¢ a ~ w a ~ ~ Q n Well f-iistory 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 information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 2N311A004122007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Tun 14 10:00:04 2007 Reel Header Service name .............LISTPE Date . ...................07/06/14 Ori gin ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/06/14 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: 2N-311A API NUMBER: 501032049101 OPERATOR: Conoco Phillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 13-JUN-07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 Job NUMBER: w-0004957755 w-0004957755 w-0004957755 LOGGING ENGINEER: 0. OBI 0. OBI A. MENEZES OPERATOR WITNESS: D. MORRIS D. BREEDEN D. BREEDEN MWD RUN 6 JOB NUMBER: w-0004957755 LOGGING ENGINEER: 0. OBI OPERATOR WITNESS: D. MORRIS SURFACE LOCATION SECTION: 3 TOWNSHIP: 9N RANGE: 7E FNL: 27 FSL: FEL: 617 FWL: Page 1 ~OCoM 1 `~ ~' j5 a~/~ • ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 2N311A00412200755N.txt 149.40 119.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 2999.0 2ND STRING 6.125 7.000 8050.0 3RD STRING PRODUCTION STRING REMARKS: C~ 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON (CTN), AND PRESSURE WHILE DRILLING (PWD). RUNS 3-6 ALSO INCLUDED AT-BIT INCLINATION (ABI). MINIMAL PROGRESS (20'MD) WAS MADE ON MWD RUN 3 - ONLY SROP DATA ARE INCLUDED. NO PROGRESS WAS MADE ON MWD RUNS 4 & 5 DUE TO HOLE PROBLEMS. 4. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER PHONE CONVERSATION ON 6/12/07 BETWEEN D. KLEIBACKER (CPAI) AND B. BRYANT (SDS). MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-6 REPRESENT WELL 2N-311A WITH API#: 50-103-20491-O1. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8747'MD/5705'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). Page 2 2N311A004122007SSN.txt SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALDSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED: RUNS 1, 6 (8.5~~, 6.125~~) ; ACAL-DERIVED: RUN 2 (8.5~~ BIT) MUD WEIGHT: 9.7-12.0 PPG MUD SALINITY: 800-1200 PPM CHLORIDES FORMATION WATER SALINITY: 19130 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all, bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2571.5 8681.0 RPM 2980.0 8688.0 RPS 2980.0 8688.0 NPHI 2980.0 8653.0 FCNT 2980.0 8653.0 NCNT 2980.0 8653.0 DRHO 2980.0 8668.5 RHOB 2980.0 8668.5 RPD 2980.0 8688.0 PEF 2980.0 8668.5 FET 2980.0 8688.0 RPx 2980.0 8688.0 RoP 2999.0 8747.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 1 2571.5 3170.0 2 3170.0 8065.0 3 8065.5 8085.0 Page 3 MWD 6 REMARKS: MERGED MAIN PASS. 2N311AO04122007SSN.txt 8085.0 8747.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2571.5 8747 5659.25 12352 2571.5 8747 FCNT MWD CNTS 137.82 3541.81 993.875 11347 2980 8653 NCNT MWD CNTS 15195 213288 135028 11347 2980 8653 RHOB MWD G/CM 0.065 2.941 2.30261 11378 2980 8668.5 DRHO MWD G/cM -3.997 0.387 0.0237004 11378 2980 8668.5 RPD MWD OHMM 0.08 2000 15.2509 11417 2980 8688 RPM MWD OHMM 1.07 2000 12.6417 11417 2980 8688 RPS MwD oHMM 1.1 2000 4.74723 11417 2980 8688 RPX MWD OHMM l.ll 1812.61 4.48325 11417 2980 8688 FET MWD HOUR 0.35 361.07 6.04393 11417 2980 8688 GR MWD API 38.76 218.6 116.325 12220 2571.5 8681 PEF MWD BARN 1.8 19.14 3.45741 11378 2980 8668.5 RoP MwD FT/H 0.06 375.89 87.4158 11497 2999 8747 NPHI MwD Pu-s 8.9 66.06 33.6701 11347 2980 8653 First Reading For Entire File..........2571.5 Last Reading For Entire File...........8747 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Page 4 2N311AO04122007SSN.txt Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD i Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2571.5 3134.5 FONT 2980.0 3078.0 NPHI 2980.0 3078.0 NCNT 2980.0 3078.0 PEF 2980.0 3091.0 RHOB 2980.0 3091.0 RPS 2980.0 3127.0 RPM 2980.0 3127.0 RPX 2980.0 3127.0 DRHO 2980.0 3091.0 FET 2980.0 3127.0 RPD 2980.0 3127.0 RoP 2999.0 3170.0 LOG HEADER DATA DATE LOGGED: 16-MAR-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3170.0 TOP LOG INTERVAL (FT): 2572.0 BOTTOM LOG INTERVAL (FT): 3170.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 175785 EWR4 ELECTROMAG. RESIS. 4 115502 CTN COMP THERMA L NEUTRON 231174 ALD Azimuthal L itho-Dens 186328 Page 5 • 2N311A004122007SSN.txt BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 2999.0 BOREHOLE CONDITIONS MUD TYPE: LignOSUlf anate MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 47.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.300 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.190 77.0 MUD FILTRATE AT MT: 1.100 70.0 MUD CAKE AT MT: 1.900 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWDO10 CNTS 4 1 68 4 2 NCNT MWDO10 CNTS 4 1 68 8 3 RHOB MWDO10 G/CM 4 1 68 12 4 DRHO MWDO10 G/CM 4 1 68 16 5 RPD MwD010 OHMM 4 1 68 20 6 RPM MWDO10 OHMM 4 1 68 24 7 RPS MWDO10 OHMM 4 1 68 28 8 RPX MwD010 OHMM 4 1 68 32 9 FET MWDO10 HOUR 4 1 68 36 10 GR MwD010 API 4 1 68 40 11 PEF MWDO10 BARN 4 1 68 44 12 RoP MwD010 FT/H 4 1 68 48 13 NPHI MwD010 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2571.5 3170 2870.75 1198 2571.5 3170 FCNT MWDO10 CNTS 579.03 1175.97 755.796 197 2980 3078 Page 6 a • 2N311A004122007SSN.txt NCNT MWDO10 CNTS 116075 161989 128844 197 2980 3078 RHOB MWDO10 G/CM 0.41 2.652 2.08794 223 2980 3091 DRHO MWDO10 G/CM -3.045 0.238 -0.132942 223 2980 3091 RPD MwD010 OHMM 0.08 2000 212.592 295 2980 3127 RPM MWDO10 OHMM 1.87 2000 74.4313 295 2980 3127 RPS MWDO10 OHMM 1.78 2000 23.1824 295 2980 3127 RPX MWDO10 OHMM 1.66 1812.61 16.2093 295 2980 3127 FET MwD010 HOUR 0.44 26.03 4.50386 295 2980 3127 GR MwD010 API 38.76 142.23 72.6567 1127 2571.5 3134.5 PEF MwD010 BARN 2.12 13.09 5.22937 223 2980 3091 ROP MWDO10 FT/H 21.44 228.33 109.575 343 2999 3170 NPHI MwD010 Pu-s 32.66 66.06 49.1974 197 2980 3078 First Reading For Entire File..........2571 Last Reading For Entire File...........3170 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 3078.5 7970.0 FCNT 3078.5 7970.0 NCNT 3078.5 7970.0 PEF 3091.5 7983.5 RHOB 3091.5 7983.5 DRHO 3091.5 7983.5 RPM 3127.5 8021.0 FET 3127.5 8021.0 RPX 3127.5 8021.0 RPS 3127.5 8021.0 RPD 3127.5 8021.0 GR 3135.0 8028.5 ROP 3170.5 8065.0 Page 7 i r 2N311A004122007SSN.txt LOG HEADER DATA DATE LOGGED: 27-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8065.0 TOP LOG INTERVAL (FT): 3170.0 BOTTOM LOG INTERVAL (FT): 8065.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.9 MAXIMUM ANGLE: 62.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuthal Litho-Dens 224807 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 2999.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 52.0 MUD PH: 10.4 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): 1.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.300 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .780 120.2 MUD FILTRATE AT MT: 1.500 69.0 MUD CAKE AT MT: 1.200 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Page 8 • • 2N311AO041220075SN.txt Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MwD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPx MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 ~ 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 Pu-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3078.5 8065 5571.75 9974 3078.5 8065 FCNT MWD020 CNTS 657.85 3541.81 1076.78 9784 3078.5 7970 NCNT MWD020 CNTS 127685 213288 150453 9784 3078.5 7970 RHOB MWD020 G/CM 1.714 2.647 2.31041 9785 3091.5 7983.5 DRHO MWD020 G/CM -0.082 0.37 0.0523775 9785 3091.5 7983.5 RPD MWD020 OHMM 1.15 13.42 4.21982 9788 3127.5 8021 RPM MWD020 OHMM 1.07 15.32 4.10052 9788 3127.5 8021 RPS MWD020 OHMM 1.1 16.69 4.01814 9788 3127.5 8021 RPX MWD020 OHMM l.ll 18.62 3.91121 9788 3127.5 8021 FET MwD020 HOUR 0.35 146.33 2.32315 9788 3127.5 8021 GR MWD020 API 47.47 211.3 120.427 9788 3135 8028.5 PEF MwD020 BARN 1.8 8.26 2.85005 9785 3091.5 7983.5 ROP MWD020 FT/H 0.91 375.89 91.9071 9790 3170.5 8065 NPHI MwD020 Pu-s 8.9 54.4 33.7603 9784 3078.5 7970 First Reading For Entire File..........3078.5 Last Reading For Entire File...........8065 File Trailer Service name... .......STSLIB.003 Service Sub Level~Name... Version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Page 9 • • Comment Record FILE HEADER 2N311A004122007SSN.txt FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8065.5 8085.0 LOG HEADER DATA DATE LOGGED: O1-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8085.0 TOP LOG INTERVAL (FT): 8065.0 BOTTOM LOG INTERVAL (FT): 8085.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8050.0 BOREHOLE CONDITIONS MUD TYPE: LignOSUlfanate MUD DENSITY (LB/G): 11.70 MUD VISCOSITY (S): 48.0 MUD PH: 10.3 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .680 67.0 MUD AT MAX CIRCULATING TERMPERATURE: .490 95.0 MUD FILTRATE AT MT: .900 67.0 MUD CAKE AT MT: 1.200 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn Page 10 • 2N311A00412200755N.txt optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8065.5 8085 8075.25 40 8065.5 8085 ROP MWD030 FT/H 5.33 174.67 42.9625 40 8065.5 8085 First Reading For Entire File..........8065.5 Last Reading For Entire File...........8085 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header service name... .......STSLI6.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 7970.5 8653.0 NCNT 7970.5 8653.0 FCNT 7970.5 8653.0 DRHO 7984.0 8668.5 RHOB 7984.0 8668.5 PEF 7984.0 8668.5 RPM 8021.5 8688.0 Page 11 • 2N311A004122007SSN.txt RPD 8021.5 8688.0 RPX 8021.5 8688.0 FET 8021.5 8688.0 RPS 8021.5 8688.0 GR 8029.0 8681.0 ROP 8085.5 8747.0 LOG HEADER DATA DATE LOGGED: 12-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8747.0 TOP LOG INTERVAL (FT): 8085.0 BOTTOM LOG INTERVAL (FT): 8747.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.5 MAXIMUM ANGLE: 40.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 CTN COMP THERMAL NEUTRON 110041 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8050.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 11.50 MUD VISCOSITY (S): 48.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 180 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .650 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .390 118.0 MUD FILTRATE AT MT: .800 68.0 MUD CAKE AT MT: 1.100 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Page 12 • • 2N311A004122007SSN.txt Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FONT MWD060 CNTS 4 1 68 4 2 NCNT MWD060 CNTS 4 1 68 8 3 RHOB MWD060 G/CM 4 1 68 12 4 DRHO MWD060 G/CM 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MwD060 OHMM 4 1 68 28 8 RPX MwD060 OHMM 4 1 68 32 9 FET MWD060 HOUR 4 1 68 36 10 GR MwD060 API 4 1 68 40 11 PEF MwD060 BARN 4 1 68 44 12 ROP MwD060 FT/H 4 1 68 48 13 NPHI MwD060 Pu-s 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7970.5 8747 8358.75 1554 7970.5 8747 FONT MWD060 CNTS 137.82 1004.27 434.423 1366 7970.5 8653 NCNT MWD060 CNTS 15195 36745.4 25435.5 1366 7970.5 8653 RHOB MWD060 G/CM 0.065 2.941 2.28188 1370 7984 8668.5 DRHO MWD060 G/CM -3.997 0.387 -0.155624 1370 7984 8668.5 RPD MWD060 OHMM 1.18 2000 52.5497 1334 8021.5 8688 RPM MwD060 OHMM 1.12 2000 61.6471 1334 8021.5 8688 RPS MWD060 OHMM 1.16 1237.35 6.02009 1334 8021.5 8688 RPX MWD060 OHMM 1.19 1466.86 6.08744 1334 8021.5 8688 FET MWD060 HOUR 0.94 361.07 33.6851 1334 8021.5 8688 GR MwD060 API 57.82 218.6 123.273 1305 8029 8681 PEF MwD060 BARN 4.02 19.14 7.50692 1370 7984 8668.5 ROP MWD060 FT/H 0.06 116.04 49.8091 1324 8085.5 8747 NPHI MwD060 PU-S 18.43 50.74 30.7847 1366 7970.5 8653 First Reading For Entire File..........7970.5 Last Reading For Entire File...........8747 File Trailer Service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/06/14 Page 13 J r 2N311A00412200755N.txt Origin ...................5T5 Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................5T5 LIS writing Library. scientific Technical Services Reel Trailer Service name .............LISTPE Date . ...................07/06/14 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................5T5 LIS Writing Library. Scientific Technical Services Physical EOF Physical EoF End Of LIS File Page 14 ~ ConocoPhillipsp,a=,,,~~ FINAL WELL REPORT ConocoPhillips Alaska, Inc. TARN 2N-311A 117' FNL, 996' FEL Sec 3 - T9N - R7E, UM North Slope, Alaska Approved by: Compiled by: Lees F. Browne, Jr. Mark Bietting Charles Isbon April 14, 2007 • [~ F,POCH Gor~oaoPtw~~ Tarn 2N 311 A TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT 8~ CREW .................................................................. 3 1.1 Equipment Summary .................................................................................... 3 1.2 Grew ............................................................................................................... 4 2. GENERAL WELL DETAILS .................................................................................... 5 2.1 Objectives ...................................................................................................... 5 2.2 Well Summary ...............................................................................................6 3. GEOLOGICAL DATA ..............................................................................................8 3.1 Li#hostratigraphy ........................................................................................... $ 3.2 Mudlog Summary .......................................................................................... 9 3.3 Sampling Program /Sample Dispatch ...................................................... 23 3.4 Cali Bond Gas Bag Sample and IsoTube Inventory ................................. 24 4. PRESSURE !FORMATION STRENGTH DATA ................................................... 25 4.1 Formation Integrity/Leak Off Tests ............................................................ 25 4.2 Pore Pressure Evaluation introduction .....................................................25 4.3 Pore Pressure Summary ............................................................................. 26 • 5. DRILLING DATA ................................................................................................... 27 5.1 Daily Activity Summary .............................................................................. 27 5,2 Bit Record .................................................................................................... 31 5.3 Survey Record ............................................................................................. 32 5.4 Mud Record ................................................................................................. 35 Enclosures 2"=100' Scale Mudlog 2"=100' Scale LWD Combo Log 2"=100' Scale Gas Ratia Log 2"=100' Scale Drilling Dynamics Log • ~1 EPOCH z • • • MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Cvt10C~o~P11~I~l75 Tarn 2N 311A Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM electric gas trap Flame ionisation total & chromato ra h detector - H2S Detector (H2S) Variable resistivity cell. Sample line, drill floor, mud its & shakers - Rate of penetration (ROP) BEI Encoder- Primary draw works block position indicator - Pum stroke counter SPM RIGWATCH Turck Ma netic roximit sensor - Hook Load HLKD I Wei ht on bit WOB RIGWATCH Ametek H draulic ressure cell - Tor ue RTOQ To Drive Feed - Not receivin Tor ue si nal from Totco To drive rota RPM To Drive Feed - Totco Wits feed Stand i e & eosin ressure SPPJCSIP Totco H draulic ressure cell - Mud flow out FLO Totco Flow Paddle - Totco Wits Feed Pit levels x 6 Ball Float sensors in all its & tri tank - Totco Wits Feed Mud to in unit com uter s stem Com ac Pentium III - Gealo fist's workstation Com ac Pentium III Totco Workstation Com an Man's workstation Gom ac Pentium III - Totco Workstation Tool usher's workstation Cam ac Pentium III - Totco Workstation Driller's workstation E och Azonix Touch Screen Class IDiv II - Totco Workstation ~1 EPOCH • • • G0110~OrPhd~~pS Tarn 2N 811A 1.2 Crew Unit Type Arctic Unit Number : ML012 Mudloggen3 Years "1 Geotechnicians Years Technician Trainees Lees F. Browne Jr. 26 Dan K. Hillegeist 1 Charles Isbon 18 Mainuddin Chowdhury 1 Allen Odegaard 10 Paul Iverson 1 Mark Bietting 1 Kevin McMullen 1 R' Years experience as Mudlogger Additional Comments Two spare poly-flaw gas lines were run through a heated umbilical to insure non freezing for the gas lines and rig air lines to the unit. The QGM gas trap was rou#inely Leaned of drilling mud and the gas lines blown back with rig air. ~1 EPOCH ~~~ Tarn 2N 311A 2. GENERAL WELL. DETAILS 2.1 Obiectives The 2N-311 was drilled to a depth ofi 8657' MD. The well was subsequently plugged back and suspended. The well was se# with three cement plugs after perceived lack of reservoir quality sands prior to Klein's TMWCC log models. The 2N-311A sidetrack is to capture rates and reserves as originally planned. The bottom hole location is targeting the hot gamma lithic turbidite deposits of the Bermuda reservoir. The 2N311A well commenced on March 16, 2007 and reached a Total Depth of 8,747' on April 12, 2007. Potential risks are reservoir quality and thickness, lateral continuity and pressure support from offset injectors. • • E~ f;POCH 5 • • • 2.2 Well Summary ~a~~/~~I~PS' Tarn 2N 311A Well 2N-311A AFE 10166030 Classification Development Pad: 2N Rig Name / Nordic Drilling/ Land Surface 27' FNL, 617' FEL, RKB Elevation 151' AMSL PAD Elevation 120.9" Nordic #3 Co-Ordinates S 3, T9N, R7E, UM AMSL Primary Target Bermuda T3, T2 Primary Target 8033' MD/ Secondary Iceperg Secondary 7852'MD/ Depth -5151.79 SS TVD Target Target Depth -4864 SSTVD Spud Date 3/16/07 TD Depth 8747' MD/ TD Formation C-35 (K-3) fiD Date 4/12/07 -5705.23 SS TVD Completion Run Production Liner Suspension N/A Days Drilling 27 Days T®sting N/A Status Date Hole Maximum De th TD Formation Mud Weight Deviation Coring Casing Shoe De th FIT Section MDRT ft TVDSS ft (ppg) (°inc) ! Liner MDRT ft TVDSS ft (ppg) 8.5" 8065' -5,026' T4 9.6 - 9.9 39.92 NONE 7" 2999' -2,255' 6.125" 8747' -5705' C-35 11.5-11.7 38.51 NONE x x x ~ EPOCH ~~~ Tarn 2N 311A Additional Comments: Epoch commenced fogging the 2N-311A {sidetrack of the 2N-311) on 3116/07 at 2999' drilling out cement from the 2N-311 well. Services provided consisted of continuous FID {Flame laniza#ion Detection} Gas Detection utilizing bath Total Hydrocarbon Analyzer and Gas Chromatograph, QGMT"'' Gas Trap, sample collection, geachemical gas sample collection,. litholagy descriptions, and Digital Sample Photography through the reservoir sections. Samples were caught at 50' intervals to 8065' above the Bermuda formation. Gas bags were collected at 500' intervals and at gas kicks. Sample catchers were used throughout the well. IsoTubes were collected in 30' intervals starting from 300' above the Bermuda Formation {8090'} and a ten foot sampling program was started with ditch cuttings. Drilling kicked off the old well bore of 2N-311 at 54.11° drilling with a mud motor and the inclination was brought down to 60° by 3640'. The inclination was held to 6303', in which angle was dropped to 39° at 8065'. No hole problems were encountered while drilling from 2999' to the top of the Bermuda. Good hole cleaning techniques were used drilling the deviated hole with high viscosity sweeps and good flow rates. Each connection allowed circulating #ime to clean the hole of cuttings above the BHA. All hole trips showed no drag or sticking. Both rig mud pumps {#1 and #2) traction motors had to be replaced, as well as troubleshooting rig electrical problems from 3117107 to 3122107. • C~ EPOCH ~ • • • Conoco`C'h~~~ps Tarn 2N 311A 3. GEOLOGICAL DATA 3.1 Lithostratigraphv Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geologist. FORMATION PROGNOSED DRILLING PICK ACTUAL WIRELINE PICK HIGH/LOW MDRT ft TVDSS ft MDRT ft TVDSS ft MDRT ft TVDSS ft (ftl C-80 K10 3140' -2335' 3140' -2335' 3140' -2333' -2 G50 5838' -3680' 5838' -3680' 5825' -3669' -11 C-40 6306' -3910' 6306' -3910' 6259' -3882' -28 C-37 6706' -4110' 6706' -4110' 6655' -4084' -26 T-7 7640' -4710' 7640' -4710' 7526' -4624' -86 T-4 ICEBERG 8014' -4990' 8014' -4990' 7852' -4864' -126 7" CASING SHOE 8060' -5023' 8060' -5023' 8065' -5026' +3 T-3 70P RESERVOIR 8159' -5250' 8159' -5250' T-2 BASE RESERVOIR 8285' -5347' 8285' -5347' C35 8448' -5473' 8448' -5473' Total Depth 8747' -5550' 8747' -5550' ~ EPOCH. • ~~~ Tarn 2N 311A 3.2 Mudloci Summary The following text provides a brief summary of the defining lithologica! and drilling characteristics for that part of the well, over which drill cuttings were collected. Kick off to G-80 2,999' to 3,140' MDRT (-2,255` to -2,333' TVDSS) The 2N-311 A kicked off as a sidetrack of the 2N-311 well under the surface casing depth of 2999'. Formation was encountered at 3005' and 100% by 3025' with excess cement of the 2N-311 diminished. Hard and stiff granular cements gave way to samples comprised of predominantly of claystone: very light gray to yellowish gray, very soft, lumpy to clumpy, clustered to clotted, gelatinous with some becoming mushy to pasty and slimy. Samples were non to very slightly cohesive and slight to moderate adhesive with a general amorphous fracture and a massive habit. The clays are very hydrophilic with most going into solution leaving globs on the shale shakers for samples. The clays have a moderate to bright satin and earthy lustre showing a colloidal to sub clay texture. Secondary silts and minor unconsolidated sands {in the fine to very fine grain size) noted throughout the section. Mud weight was 9.6 ppg. With a Leak Off Test at 3038' with an EMW of 15.0 ppg. Down time gases of 110 units were recorded after the Leak Off Test. Drill Rate ftlhr Total Gas °k Maximum Minimum Avera a Maximum Minimum Avera e 175 85 138 37 3 77 ~ EPOCH 9 • ~~~~ Tarn 2N 311A c-$o to c-~a 3,140' to 5,825' MDRT (-2,333' #o -3,669' TVDSS) The C-80 section is noted with a ciaystone top grading into a siltstone midsection and a sandstone basement. The claystone interval is composed of 80 to 100°fo claystone. Colours range from yellowish gray {3400') to a pale yellowish brown {3900') to light brownish gray. All claystones are very soft with various consistencies and tenacity: lumpy to clumpy, clustered to clotted, mushy to pasty and sometimes slimy. Clays have no to a slight cohesiveness and a non to slight adhesive. Samples are very hydrophilic with most going into solution resulting in a "pillow" like habit and a moderate earthy lustre. with a colloidal to slight clayey texture. At 4000' the claystanes are grading into siltstones. The siltstones are light brownish gray to pale yellowish brown with poor to some moderate induration. Overall the siltstones are crumbly to crunchy, stiff, slight to moderate cohesive, non to slight adhesive with a earthy fracture and sub nodular habit. Silts show a gemeral earthy lustre with gritty to silty textures in a massive homogeneous bed with minor gradations of sandstone and claystone. At 4140' a slowing of the ROP and drop of background gas presented a less than 5' zone of recrystalized calcite mixed with silt and denitrified ash. Colourwas white to pinkish gray to yellowish gray with various hues of all. Overall brittle showing a crystalline structure grading to silts. Appears reworked and heavily interbedded with silt, clay and very fine grained sand and denitrified ash. From 5300' to 5800' samples were predominantly sandstone light yellowish gray to very light gray, slightly friable to moderately consolidated, very tine lower to fine lower clast size, angular to sub round, poorly sorted, moderately argillaceous with quartz grains and abundant lithics. Secondary quark overgrowth enlargements noted and some grading to siltstone. Na show of any sample fluorescence ar oil cuts. Drill Rate itlhr Total Gas °~6 Maximum Minimum Avera a Maximum Minimum Avera e 245 10 94 66 6 34 • ~ EPOCH z o ~'~~~ Tarn ltd 311A C-50 to C-4Q 5,825' to 6,259' MDRT (-3,669' to -3,882' TVDSS) r1 f~ The C-50 succession is generally a siltstane with secondary carbonaceous silts. The siltstane is pale yellowish brown becoming slightly gray at the base with ail showing poor induration and being brittle to crumbly. Some silts are slightly sectile in sub shale grading to clay in parts. Silts display a very slight cohesiveness to a slight adhesiveness in clay sections. Overall fracturing is sub planar to planarwith a sub platy to platy habit displaying a gradation to carbonaceous silt and increased clay content than the C-50. Samples show a moderate earthy lustre and a silty to colloidal texture as the brittle induration goes into solution. The silts are grading in#o micro laminated beds of carbonaceous sil#s with planar orientation starting at 5930'. The carbonaceous siltstane is very light gray (such as the siltstane), but is mottled and striated with light brownish gray to pale yellowish brown and various hues of both. As with the siltstane these gradational beds show poor induration and are briti~e. Some fragments are slightly crumbly and becoming sectile along carbon laminations. The carbon silt is non to very slightly cohesive to non and very slightly adhesive wi#h planarfractures. The general habit is sub platy with a earthy to sligh~y greasy lustre in carbons. Textures range from silty to striate with massive micro laminations. Drill Rate ftJhr Total Gas °~ Maximum Minimum Avera a Maximum Minimum Avera e 273 20 77 87 19 44 EPOCH 11 . ~~~~~ Tarn 2N 311A C-40 to C-37 6,259' to 6,655' MDRT {-3,882' to -4,084` TVDSS) The C-40 shows carbonaceous silts to siltstone. The siltstones are gradational with the clays. The colours are very light gray to yellowish gray and various hues of both. Samples show poor and occasional moderate induration with brittle and scattered s#iff fragments. Overall the silt is crumbly to crunchy with a slight to moderate cohesiveness and being non adhesive. The fracture is sub planar to planar with a sub platy to platy habit. Samples show a moderate earthy lustre and a silty texture. Overall the section is a massive gradational bed of dominant silt with scattered clays and micro laminations of carbonaceous silt with planar orientation with trace calcite. The carbonaceous siltstones are grayish brown mottled brown to brownish black and various hues of all. Samples are brittle, flexible with micro pianarfracture,floky to scaly thin habit, greasy lustre, silty texture with massive micro laminations of silts and very carbonaceous silt with planar orientation and very heterogeneous. Drift Rate ftlhr Total Gas °10 Maximum Minimum Avera a Maximum Minimum Avera e 152 43 103 125 1 51 C-37 to T-7 6,655' to 7,526' MDRT (-4,084' to -4,624' TVDSS) The C-37 interval is represen#ed by sequences of siltstones grading into massive sand and sandstones a# 6925'. From 6925' to 7100' gas increased from 30 units background to a maximum of 485 units with other kicks of 268, 288, 30 and 282 units. Samples were predominantly sand clear to milky and offwhite, unconsolidated to slightly consolidated, fine to medium grained, angular #o sub angular, poorly sorted with quartz and abundant lithics containing metamorphics and volcanics, na oil staining visible with same fluorescence but mostly mineral or mud additives. Samples graded to mostly unconsolidated sands after 7100 to the top of the T7. Sands were very light gray to very dark gray (salt and pepper overall appearance}, clayt size ranges from medium grains to fine upperwith no abundant faction, subround to sub angular moderate developed sphericity, loose unconsolidated grains with moderate to some well soreting, impacted to pitted textures with a submature to mature nature with very slight silic cement and a slight calcareous cement in minor sandstones, dominant grain support with minor secondary silt/ash support. Overall very clean arenaceous appearance. Drill Rate ft/hr Total Gas % Maximum Minimum Avera a Maximum Minimum Avera e 526 16 96 485 18 82 • ~ ~P~H 12 ~~~ Tarn 2N 311A T-7 toT-4 7,526' to 7,852' MDRT (-4,624' to -4,864' NDSS) The T-7 sequence displayed uniform siltstones with minor beds of sandstone and very minor shale. The silts#ones are light gray to light brownish gray, brittle, very poor to poor induration, crumbly, very slight to slight cohesiveness, non adhesiveness, planar fracture with a sub platy habit. Lustre was earthy with a silty texture with massive uniform silt. Drill Rate ftlhr Total Gas °~ Maximum Minimum Avera a Maximum Minimum Avera e 331 21 92 85 14 39 T-4 to T-3 {TOP RESERVOIR} 7,852' to 8,159' MDRT (-4864' to -5,250' NDSS~ The t-4 interval displayed sandstone and siltstone layers and very minor shale. The sandstone and sand was clear to off white; light green traces on off-white; fine grained with traces of very fine and medium grained; angular to sub-rounded; moderately sorted; moderately to very argiHaceous; predominately quartz grains wi#h abundant iithics; glauconitic occasionally; non to slightly calcareous; no to trace visual porosity; petroleum mud additive (lubricant} causes contamination in sample show analysis; salt & pepper at times. The siltstones were pale to dark yellowish brown with trace medium gray; very firm; gritty and earthy texture, very argillaceous, moderately sandy; very fine grained to fine grained; occasional disseminated carbonaceous material; non to slightly calcareous; no visible porosity; oil indicators masked by lubricant {petroleum} in mud. Drill Rate ftlhr Total Gas °!o Maximum Minimum Avera a Maximum Minimum Avera e 407 11 76 259 2 61 C~ EPOCH 13 l~ u T-3 to T-2 (BASE RESERVOIR) 8,159' to 8,285' MDRT (-5,250' to -5,347' TVDSS) Overall, the sandstone was yellowish gray to very light gray in cleaner (non silted) sands. Sandstones had a sub salt and pepper appearance with lithic content. Grain size ranged from very fine upper to very fine lower with a sub round shape and moderate developed sphericity. Sorting was fair with no abundant faction. Textures showed a general polished look and a sub mature nature. Moderate to abundant clay structured matrix was present with pore filling and loosely to moderately attached clays being very argillaceous throughout. The matrix was slightly to moderately acting as a lithification agent and composed of chert and various dark lithic fragments and being quartz poor. Porosity appeared to be poor to fair in gas increased beds. Estimated fair permeability overall. Samples were of very poor sample quality with abundant graphite and calcite mud additives in the mud system. Cuttings displayed one to five percent even moderate to bright green sample fluorescence with a light brown weak oil stain. Trace pin point oil was also noted on sandstone fragments. Sandstones exhibited a instant slow streaming cloudy blue white cut with a very pale weak residue stain. Maximum background gas recorded from 8,159' to 8,285' was 861 units with 11.5 mud weight. Samples consisted of sandstone and unconsolidated sand. Both the sand and sandstone were very light gray to very light yellowish gray. Grain size ranged from very fine upper to very fine lower with a sub round and displaying a moderate developed sphericity. Sorting was moderate in gas bearing zones to poor in others. Textures were impacted to pitted with a sub mature nature. Matrix content was slight and loosely attached with some secondary quartz overgrowths with poor porosity and permeability. • ~ EPOCH 14 1.J r1 ~J ~~~~~ Tarn 2N 311A Drill Rate ffJhr Total Gas °~ Maximum Minimum Avera a Maximum Minimum Avera e 179 13 51 861 6 213 E~ EPOCH 1 s • • • ~~ EPOCj-i 16 ~~~~~~ Tarn 2N 311A • COI'1000~~(I~pS Tarn 2N 311A T-2 to C-35 8,285' to 8,448' MDRT (-5,347' to -5,473' TVDSS) Dominated by siltstones and decreasing sandstones, the siltstones are brownish gray to pale yellowish brown and various hues of both colours. The cuttings are very brittle displaying poor induration and becoming crumbly. There are no adhesive qualities with non to very slight cohesiveness. Fractures are earthy to sub blocky with a sub blocky habit. Texture is silty with overall hydrophilic quality with most silt going into solution. Drill Rate ft/hr Total Gas °k Maximum Minimum Avera a Maximum Minimum Avera e 84 26 56 503 46 85 ~~ EPOCH 17 • • i ~ ~ ~. 2 _, ~~ ~" ~~ COr1000~~n~6 Tarn 2N 311A ~: 'i • ~~ EPOCH 1 s COnOCa~~~1135 Tarn 2N 311A C-35 to TD (8,747') 8,448' to 8,747' MDRT (-5,473' to -5,705' TVDSS) Below the C-35 comprises a sequence of minorcarbonaceous siltwith gradational clay and silt with thin sandstone stringers. The carbonaceous shale is dark brown to black with a very brittle quality with very small cuttings size and micro planarfracturing. Cuttings display very small cuttings size with a dull earthy lustre and silty to smooth textures. These thin beds grade to siltstone and claystones. Samples continue to be very poor quality with abundant graphite and calcite mud additives resulting in samples displaying less than 5% true cuttings. Drill Rate ft/hr Total Gas °~ Maximum Minimum Avera a Maximum Minimum Avera e 83 8 53 195 23 69 r1 U `~ ~ EPOCH 19 • ~~~i1K Tarn 2N 311A -~rAl1 `1. ~.Y, p ~. ~ ~ i ~ ~ t- ~ Tan fG .,~,~~ ~' ~ 1 r '~ ' ~~ !~ ~ ~- ~_ } ~ "+ _- ~- 4'~~ ]ye~~~ ~'1 @ r~ w ~/.. ~~ ~~~t ~+~ ~. BPhil ' ' ~, Sldpe Borough; Ai(~ IA3`-20491~~- ~ ~ •~ r~ ~.`.~ ~ ~~ ~ ~~~ ~ . . _ ~ `,t'` ~ - ~'~ Y ~~+ ! -'~ ~' ~~ ~"; !~ r ! ~~ ~:rocx 2 0 N a M Z N ~; C7 ~, R .. x • • ~~~ Tarn 2N 311A ~,~~~~ SHOW REPORT NO. 1 COMPANY ConocoPhillips WELL# Tarn 2N-311A LOCATION North Slope Borough, AK DEPTH INTERVAL: 8,159' TO 8,285' {MD) TOTAL FTG: 126' 5,250' TO 5,347' {TVD) BiT INFORMATION: BIT TYPE: PDC-IiCM505Z BIT HOURS: 10.2 AVERAGES: BEFORE DURING AFTER MAXIMUM ROP {fph) 29.0 51.3 50.2 178.5 WOB 18.7 17.7 14.2 42.0 RPM {wifh mud motor) 34.1 66.4 83.1 85 MUD WT OUT 11.5 ! 48 11.5148 11.5 t 48 11.5 / 48 CHLORIDES 180 180 160 180 TOTAL GAS $u 212u 99u 861u C1 {ppmy 1,327 34,070 15,838 138,201 C2 {ppm) 79 2,911 996 8,577 C3 {ppm) 47 1,279 610 5,202 C4 {ppm) 21 555 259 2,251 C5 {ppm) 6 162 76 658 CUTTINGS FLUORESCENCE%: INTENSITY: 34-40% Moderate MUD FLUORESCENCE: Pale Straw-Yellow COLOR: Straw Yellow CUT: Blue-White FORMATION DESCRIPTION: Sandstone =yellowish grey with common pale orange hues to very light grey; blocky to irregular cuttings habit; sub-vitreous to vitreous luster; ctast size ranges from very fine upper to very fine lower sand size; composed predominantly of quartz and lithic fragments and plots as lithic sandstone on QLF ternary; quartz is clear and colorless to pale white with yellowish hues; sub-angular to sub-rounded; low sphericity; poor to moderate sorting; lithic fragments an: predominantly metanocratic and are bladed to wedge-tike to occasionally platy in habit disseminated in sandstone; sandstone is oast supported with poorly developed cement; rare accessory glauconite; no visible sideri#e; low visible porosity and permeability; common pale brown ail staining; strong ir~tescent sheen; very strong petroleum odor at shakers and in unwashed samples; very strong straw yellow fluorescence; slow streaming to cloudy blue white cut with very pale straw yellow resrclual stain. • LOGGING GEOLOGIST(S): Mark Bietting ~i EPOCH a a • • • ~~~~~d~~ Tarn 2N 311A 3.3 Sampling Program 1 Sample Dispatch Set T / Pu ose Interval Fre uenc Dis atched to A Unwashed (WET) 3,000' - 8,065' S0' Bayview Warehouse 8,065' - 8,747' 10' ConocoPhillips Alaska, Inc. ABV 100 8105 Eleusis Drive Anchorage, AK 99502 Attn: D. PrzywojskitM. McCracken B Washed, screened & dried 3000' - 8065' S0' Bayview Warehouse Dry Samples 8065' - 8,74T 10' ConocoPhillips Alaska, Inc. ABV 100 8105 Eleusis Drive Anchorage, AK 99502 Attn: D. Przywojski/M. McCracken C Washed, screened & dried 3,000' - 8,065' S0' Bayview Warehouse Dry Samples 8,065' - 8,74T 10' ConocoPhiltips Alaska, Inc. ABV 100 8105 Eleusis Drive Anchorage, AK 99502 Attn: D. Przywojski/M. McCracken D Gas Bags 3 500' - 8,065' 500' or gas ISOTECH LABORATORIES Box "A" 2940-9000' kicks 1308 Parkland Court Box "B" 9000-9420' Champaign, IL. 61821 E ISOTUBES 8,090' - 8,747 30' ISOTECH LABORATORIES One Box of 25 1308 Parkland Court Champaign, IL. 61821 Sample frequency was locally altered according to drill rate constraints. ~ EPC)CH 23 Ci01'10GOPI~~PS Tarn 2N 311A 3.4 Cali Bond Gas Bap Sample and IsoTube Inventory Gas Ba # De th Gas Units IsoTube # De th Gas Units 1 2527' 2527 1 8190' 99 2 3500' Ba Failed 2 8210' 200 3 4003' 31 3 8220' 80 4 4501' 37 4 8250' 160 5 5001' 31 5 8280' 470 6 5501' 38 6 8310' 77 7 6000' 45 7 8340' 86 8 6508' 38 8 8370' 53 9 6551' 124 9 8400' 93 10 6963' 145 10 8430' 81 11 6893' 220 11 8460' 66 12 7000' 125 12 8490' S8 13 7016' 268 13 8520' S6 14 7022' 330 14 8550' 30 15 7027' 410 15 8580' 34 16 7044' 240 16 8610' 64 17 7077' 310 17 8640' 88 18 7090' 280 18 8670' 74 19 7276' 113 19 8700' 157 20 7501' 41 20 8730' 112 21 7861' 185 21 8745' 141 22 8000' 58 • ~~~~ Tarn 2N 311A 4. PRESSURE /FORMATION STRENGTH DATA 4.1 Formation IntearitvlLeak Off Tests Equivalent mud weight (EMW) is calculated from rotary table (RT). MDRT ft TVDSS ft LOT t FIT EMW FORMATION 3038' -257T 12.0 CSG SHOE + 30' 8085' -5191' 14,3 CSG SHOE + 35' LOT (Leak Otf Test} in bold italics. 4.2 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of this well; . Background Gas {BG} Connection Gas {CG) Trip Gas (TG} Corrected D exponent {DXC) 1 Mud Weight (MW) Hale Conditions (HC) Wire{ine Density (WDEN) Resistivity {RES} Sonic (SON} Pressure Tests (RFT) • E~ EPOCH 2 5 • • GO11OGO1~1~~~p5 Tarn 2N 311A 4.3 Pore Pressure Summary Equivalent mud weight (EMV1n is calculated from rotary table (RT). Formation Primary Interval To s Pore Pressure EMW Trend Indicators Source of Quantitative Interval Lithology MDRT ft TVDSS ft Min Max Trend Estimate C80 CLST 3,140' -2,333' 9.7 9.7 EVEN BG EXTRAP C50 GLST/SLTST/ SS 5,825' -3,669' 9.8 9.8 SL INGR CG/TG/WG EXTRAP C40 SLTST/GARB SHALE 8,259' -3,882' 9.8 9.8 SL INCR GG/BG EXTRAP C37 SS/SLTST 6,655' -4,084' 9.8 g,8 EVEN CG/BG MW T7 SS/SLTST/ CLAY 7,526' -4,624' 9.9 9.9 INGR MW/CG/BG EXTRAP T4 ICEBERG SH/GLAY 7,852' -4,864' 9.8 9.8 DECK MW/GG EXTRAP T3 OP RESEVOIR SS 8,159' -5,250' 11.0 11.2 INGR HCIMW/CG/TG RPT T2 BASE SS/SLTST 8,285' -5,347' 11.1 11.3 INGR HC/MW/TG/WG MW C35 SLTST 8,448' -5,473' 11.2 11.4 INGR BG/CG MW TOTAL DEPTH SLTST 8,747' -5,705' 11.2 11.4 EVEN BG/MW RFT Refer to Section 4.3 for explanation of abbreviations used. ~ EPOCH a 6 • GOnO~OPf~NI~S Tarn 2N 311A 5. DRILLING DATA 5.1 Daily Activity Summary 3116/07 Make up BHA and load MWD tools. Run in the hole and shallow test MWD tools. Load nuke sources and run in the hole with 4" HWDP. Run in the hole with 4° drill pipe to 2277'. Test casing to 2500 psi and run in the hole to 2550', in which the string took weight. Displace the hole to 9.6 ppg mud (Trip gas = 949 units}. Drill cement from 2562' to 2994'. Drill new hole to 3038'. Circulate and condition mud for Leak Off Test. Run LOT to 15.0 ppg EMW and drill formation to 3169'. Encounter rig power problems with rig pump #2. 3/17/07 Rig pump #2 traction motor field windings failed. Remove bull wheel guards, belts and unwire traction motor. Circulate drilling mud at 3 bbUmin1230psi. 3118107 Pulled the bit into the casing shoe and skidded new traction motor to mud pump #2 and wired in new traction motor. 3119107 Completed the traction motor installation and tested mud pump #2. Pump tested out fine and ran into the hole to 3041' and test mud pump #1 and #2 at full drill rate at 200 spm (Wiper Gas was 52 units}. Shut down pumps and swapped rig from Highline power back to rig power. Stage pump #2 up to 100 spm and pull up into casing at 2940' and installed head pin and broke circulation at 4 bblslmin. • 3120107 Troubleshoot rig electrical problems and remove traction motor from pump #1. Rig up and bring in new traction motor and prepare to install. 3/21107 Pick up new traction motor and Toad behind pump #1. Remove hub from motor shaft and terminate wiring on the motor. Remove hub from original traction motor and rig up traction motor hub and let cool. Install and set up traction motor. Check mud pump #1 and pump 40 spm at 230 psi. Run in the hole to 3027' and circulate at 200 spm. Trip Gas was 71 units. 3/22/07 Pull out of the hole and rack back HWDP and download tools and lay down BHA. Test BOPE and makeup BHA #2. Upload MWD and load nukes. Shallow test the tools and run in the hole to 3027'. Kelly up and wash down to 3168'. Trip gas s 67 units and drilled ahead. [~ EPOCH a ~ ~~~ Tarn 2N 311A 3/23/07 Drill and slide fiormation to 3230' and take surveys of the hole. Troubleshoot tube oil pumps on pumps #1 and #2 and drill to 3452'. Circulate bottoms up and pull aut of the hole to the shoe (2999') and monitor the well. Swap rotation of mud pump #1 + #2 and run in the hole to 3425' and wash down to 3456' and drill ahead. Wiper Gas was 80 units. 3/24/07 Drill and slide formation to 4847', pumped a sweep and circulated the hole dean. Pul{ed out of the hole to 3230' and reamed tight spots at 4402', 4176', 3890', 3607' and 3321'. Circulated bottoms up and pulled out of the hole to the shoe. Moni#ored the well and serviced the rig and cut and slipped new drill line. Ran in the hole to 4752' and washed to the bottom of the hole. Wiper gas was 156 units and drilling progressed ahead. 3/25/07 Drill and slide formation to 6559' and circulated and conditioned the hole and mud system. Begin to pull out of the hole for a wiper trip. 3/26/07 Run into the hale after the wiper trip from 4847' to 6484' and wash dawn to 6559'. Wiper gas was 291 units. Drill and slide formation to 7067' and circulate and condition the drilling mud and hole and drilled ahead to report time. 3/27/07 Drilled to 7606' and circulated and conditioned the drilling mud while waiting out bad weather. Total time circulating was 5'/2 hours. Drilled ahead to 8065' and pumped a sweep and circulated the hole. Begin to pull out of the hole with a wiper trip to 6633'. 3128/07 Finished the wiper trip and run in the hole to 8065'. Pumped a 40 bbl hi vis weighted pill and circulated bottoms up three times and Wiper gas was 387 units. Pulled out of the hole to surface and lay down BHA #2. Changed out to 7" rams and tested BOPE. Rigged up to run 7" casing. 3129/07 Trip in hole to 2926' and circulated bottoms up. Trip in hole to 5220'. Tight spot found. Circulated with minimum returns. Set 1 joint back and attempted to circulate. No returns. Trip out of hole far a total of 15 joints to 4588' and tried to circulate. No retums. Trip in hale to 3271' and attempted to circulate with no returns. Began to trip in hale with casing. 3/30107 Continue tripping in hole with 7" casing and set down with no problem. Pump cement and pumped plug to 2000 psi and held solid. Cement in place at 11 a.m. Rig down cement equipment. Rig up and test B.O.P.'s. ~ EPQCH a 8 • COr1000~fl~ Tarn 2N 311A 3/31107 Assemble BHA #3 and directional tools. Trip in hole to 7955' and tag tap of plug. Continue drilling operation. Drilling. 4101107 Drilling shoe to 8085'and performed FIT to 13.1 ppg. Circulate and conditioned mud to build 35 ppb WBS fluid and bring weight up to 13.0 ppg. Weight up to 11.7 ppg. Observed losses to formation. Pickup and increase LCM content to 40 ppb. 4102/07 Continue mixing Form-A-Squeeze Piil and weighted up with barite to 12.4 ppg. Pumped at 8085'. Trip out of hole to 7171' and attempt squeeze. Trip back m hole to 8085'. Circulate with partial returns. Trip out of hole @ report to pick up cement tools to pump cement squeeze. 4/03!07 Continue to trip ou# of hole stand back BHA in derrick. Rig up and run 3.5„ cement stinger to 1064' and 4" drill pipe to 8064'. Pump 13 bbfs. Mud. Push 12.0 ppg, 26 bbls. Cement. Displace with 71 bbls. Mud with rig pump as per program. Trip out of hole to 7148'. Perform hesitation squeeze and wait on cement at report. 4/04/07 Circulate at 7148'. Observed material mixed in mud push, wash down to 8085'. Circulate and condition system. Observed 24 bbl. Flow back. Circulated 11 bbfs. Lost. Shut down pump gained 11 bbls. Mixed and pumped 12 bbfs. Mud push 12.0 ppg. Trip out of hole to 6926'. Hesitation squeeze and wait on cement at report. 4/05/07 Continue hesitation squeeze. Trip in hole from 6926' to 7905'. Wash down CBU. Trip out of hole and lay down 3.5" tubing. Pick up BHA #4 and trip in hole with drilling assembly at report time. 4J06107 Continue to trip in hole @ 7950'. Circulate and condition system. Trip in hale and tag @ 8085. Observed losses to formation. Trip out of hole. Lay down BHA. Rig up wire line lag tools. Bond logging at report. 4/07/07 Continue wireline log. Trip out of hole and rig down. Mud up. Clean out BHA. Run in hole. Stage in treating mud system each 1000' interval. Trip depth in at 7533'. Washing down. 4108/07 Cement band log, pull out of hole, run in hole, circulate. ~ EPOCH 2 9 ~J CiOt10f~0~~~p5 Tarn 2N 311A 4109/07 Run in hole; circulate. 4/10/07 Rig up cement equipment and test lines; perform injection test; pumped 10 bbl. of water, 50 bbl. of cement and 10 bbl. of water; chased with 70 bbl, of 11.5 ppg. mud; pull out of hole to 7703' and reverse circulate; pumped dry jab and pulled out of hole; pick up battam hole assembly and shallow test tools; trip in hole. 4/11 /07 Trip in hole; wash and ream to 7938' and tag the top of the retainer; drill through retainerto 7940'; drill cement to 8065'; circulate hole clean; pump dry job and pull out of hole, standing back bottom hole assembly; change out mud motor and run in hole with new bottom hole assembly; shallow test tools and run in hole to 7934 ;circulate and condition mud. 4112107 Washed to 8065' and drilled to 8083' prior to circulating hale clean for FIT (14.3 ppg EMW); displaced well overto new LSND mud and conditioned same; drilled to 8087' and pull out of hole to 7900'; returned to bottom and continued drilling to 8160'; after flaw check, drilled to 8628'. 4/13/07 Drilled to 8747'; pumped sweep and circulated hole clean; pull out of hole to 8272' and back-reamed through tight spot at 8029'; went back to bottom, circulated and started loosing to the formation; pumped a low fluid loss, Cal-Garb pill and spot in the open hole; monitored well - 5 bbl flow back after 10 minutes; pull out of hole, monitoring well on trip tank. r~ LJ 4114107 Pumped a dry job, pull out of hale and lay down bottom hole assembly; pulled wear ring and set test plug; change out lower pipe rams to 4.5"and tested blow out preventers; pulled test plug and set wear ring; rig up and run 4.5" liner. ~ EPOCH 3 a • • • 5.2 Bit Record ,r COr1000Phi~~ Tarn 2N 311A Bit ! Run Make Type Jets /Size Depth In ft Total Footage Bit Hrs Av. ROP ftihr WOB (klbs) RPM PP (psi) Wear BHA 8.5" hole 1 HTC CM605 5X14 2,999' 5,066' 59.42 95 25 56 2,138 NA #1+#2 6.125" HOLE 2 HCM 5052 5X10 8,065' 8,747' 21.75 50 15 64 1,890 NA #3 ~~CH 31 • ~ • 5.3 Survey Record r COr1000Phi1~ Tarn 2N 311A Measured De th Inclination Azimuth TVD Coordinates Dog Leg Feet Degrees Degrees Depth N / S E / W Degreesl 100 ft 2994.00 57.74 8.84 2403.51 1405.08N 232.75E 0.89 3070.2$ 54.11 11.78 2446.24 1467.23N 244.02E 5.73 3161.95 52.89 16.56 2500.79 1538.65N 262.03E 4.40 3260.38 53.64 20.55 2559.6$ 1613.40N 287.14E 3.34 3355.04 55.82 22.29 2614.34 1685.33N 315.37E 2.75 3450.70 57.85 23.07 2666.66 1759.21 N 346.25E 2.23 3545.00 59.91 23.10 2715.40 1833.47N 377.90E 2.18 3640.77 60.18 23.16 2763.22 1909.77N 410.50E 0.29 3736.25 60.68 21.95 2810.34 1986.46N 442.35E 1.22 3830.89 60.58 22.48 2856.75 2062.82N 473.53E 0.50 3925.82 62.22 21.86 2902.20 2140.OON 504.98E 1.82 4021.16 61.52 21.21 2947.15 2218.21 N 535.84E 0.95 4116.06 61.45 22.23 2992.45 2295.68N 566.70E 0.95 4211.25 62.17 22.14 3037.42 2373.36N 59$.38E 0.76 4305.77 60.75 21.35 3082.58 2450.48N 629.15E 1.67 4400.68 61.41 21.84 3128.47 2527.73N 659.72E 0.83 4496.23 61.92 21.85 3173.71 2605.88N 690.95E 0.53 4591.60 61.31 23.79 3219.05 2683.21 N 723.48E 1.90 4686.37 60.53 23.42 3265.11 2759.10N 756.65E 0.89 4780.04 60.84 22.44 3310.97 2834.32N 788.47E 0.97 4874.18 60.88 21.70 3356.81 2910.52N 819.36E 0.69 4972.53 60.25 23.85 3405.15 2989.49N 852.51E 2.01 5067.59 59.89 25.42 3452.58 3064.37N 886.85E 1.48 5161.70 60.65 24.85 3499.25 3138.36N 921.56E 0.96 5256.96 61.28 23.19 3545.49 3214.43N 955.46E 1.66 5351.37 62.34 20.95 3590.09 3291.54N 986.71E 2.37 5447.01 62.24 20.89 3634.56 3370.63N 1016.94E 0.12 ~1 EPOCH 3 2 • • • ~~~~/~~PS Tarn 2N 311A Measured De th Inclination Azimuth TVD Goordinates Dog Leg Feet Degrees Degrees Depth N ! S E / W Degrees/ 10Q ft 5542.69 61.32 20.85 3679.81 3449.41 N 1046.9$E 0.96 5637.51 60.33 20.00 3726.03 3526.99N 1075.87E 1.30 5732.83 60.19 20.66 3773.31 3604.60N 1104.63E 0.62 5828.15 59.97 22.07 3820.86 36$1.53N 1134.72E 1.30 5923.21 61.25 22.36 3867.51 3758.21N 1166.04E 1.37 6018.67 60.62 24.28 3913.89 3834.83N 1199.06E 1.88 6113.74 59.91 24.29 3961.04 3910.07N 1233.01E 0.75 6208.64 61.06 23.30 4007.79 3985.64N 1266.33E 1.51 6303.15 60.46 22.88 4053.96 4061.50N 1298.67E 0.74 6398.49 59.62 22.58 4101.57 4137.6$N 1330.59E 0.92 6492.29 58.66 21.92 4149.6$ 4212.20N 1361.08E 1.19 6587.31 58.87 19.38 4198.96 428$.22N 1389.72E 2.30 6683.32 57.37 18.30 4249.67 4365.37N 1416.06E 1.$3 6778.06 56.47 16.65 4301.38 4441.09N 1439.90E 1.74 6871.83 54.99 14.28 4354.19 4515.76N 1460.57E 2.62 6968.77 53.98 12.20 4410.52 4592.54N 1478.65E 2.05 7064.03 51.95 10.50 4467.92 4667.07N 1493.63E 2.54 7160.16 50.60 7.92 4528.06 4741.09N 1505.64E 2.52 7254.39 49.38 4.30 4588.65 4812.82N 1513.34E 3.21 7349.60 47.90 2.14 4651.57 4884.16N 1517.37E 2.31 7444.73 45.78 357.60 4716.66 4953.52N 1517.26E 4.13 7537.12 44.01 354.00 4782.11 5018.53N 1512.52E 3.35 7634.34 42.55 350.75 4852.90 5084.57N 1503.70E 2.74 7729.21 41.77 345.71 4923.24 5146.87N 1490.74E 3.66 7824.76 42.04 340.00 4994.38 5207.80N 1471.94E 4.00 7919.47 41.32 336.76 5065.13 5266.34N 1448.75E 2.40 7988.35 39.92 332.08 5117.42 5306.77N 1429.43E 4.87 8069.74 39.4$ 329.19 5180.05 5352.07N 1403.94E 2.33 8169.78 39.05 323.73 5257.52 5404.81 N 1369.00E 3.48 8265.89 40.16 324.11 5331.57 5454.33N 1332.92E 1.18 8359.92 39.59 324.84 5403.74 5503.39N 1297.89E 0.78 8439.14 38.26 324.87 5465.36 5544.09N 1269.24E 1.68 ~~CH 3 3 • • • COnoao`PhiOips Tarn 2N 311 A Measured De th Inclination Azimuth TVD Coordinates Coordinates Feet Degrees Degrees Depth N/ S E I W Degrees! 100 ft 8550.98 39.37 325.38 5552.51 5601.60N 1229.16E 1.03 8645.85 38.7$ 325.33 5626.16 5650.80N 1195.16E 0.62 8700.39 38.51 325.79 5668.75 567$.89N 1175.90E 0.72 8747.00* 38.51 325.79 5705.23 5702.89N 1159.59E 0.00 *Projection to total depth. ~1 EPOCH 34 • • • 5.4 Mud Record Contractor: M-I Drilling Fluids ~a'toaorPhii~Ps Tarn 2N 311A Mud Type: SEAWATER to 3,169' Mud Type : LSND to 8,747' Date Depth MW Vis PV YP Gels API FL Solids OiUWater Sand PH CI Ca 3/16/07 3,169' 9.7 47 10 24 11/14/16 5.6 6 !94 Tr 10.1 700 1200 3117!07 3,169' 9.7 47 10 24 11/14/16 5.6 6 /94 Tr 10.1 700 1200 3/18/07 3,169' 9.7 49 10 25 11/15/17 5.6 6 1/94 Tr 10.2 700 800 3/19/07 3,169' 9.7 49 10 25 11/15/17 5.6 6 1/94 Tr 10.2 700 800 3/20/07 3,169' 9,6 50 10 26 11/15/17 5.8 6 1/93 Tr 10.4 800 600 3/21/07 3,169' 9.7 50 10 26 11/15/17 5.8 6 1/93 Tr 10.2 800 400 3/22/07 3,170' 9.7 50 11 24 9/14/16 5.2 6 1/93 Tr 10.4 800 140 3/23/07 4,340' 9.7 52 14 27 10/20/26 5.0 6.5 1/93 Tr 10.4 700 80 3124/07 5,260' 9.7 50 13 24 8/11115 4.0 7.5 1192 Tr 10.1 600 100 3/25/07 6,559' 9.8 56 15 30 12/17/19 3.6 8 2/90 Tr 9.7 400 20 3!26!07 7,425' 9.8 48 14 24 10/11/12 4.6 8 1/91 0.25 9.5 400 60 3/27!07 8,065' 9.9 45 12 23 10/12/14 4.4 8.5 1/91 0.40 9.5 400 80 3!28/07 8,065' 10.0 47 12 22 9/11/12 4.6 8.5 1/91 0.50 10.0 400 80 3/29/07 8,065' 10.2 58 14 23 11/13/14 4.1 10 1/89 0.5 9.5 400 60 3/30/07 8,065' 10.2 56 14 23 10/12/14 4.2 10 1/89 0.5 9.4 400 60 3/31/07 8,065' 11.5 47 16 25 8/9/10 5.2 11 tr/89 Tr 9.6 1000 200 4/1/07 8,085' 11.6 47 15 24 9/12/14 4.6 13 tr/87 1.5 10.3 800 280 4/2/07 8,085' 11.7 51 14 27 9/11!13 4.4 14 Tr/86 0.09 10.0 800 200 4!3/07 $,085' 11.6 48 14 25 8!9!10 4.4 14 !$6 10 9.7 800 160 4/4/07 8,085' 11.5 59 17 29 9/12/17 11.0 14 /86 1.0 10.8 500 120 4!5/07 8,085' 11.5 55 21 43 14/28/35 14.0 15 1/84 1.0 10.5 500 180 4/6/07 8,085' 11.5 52 25 29 13/21/34 16.4 14 2185 0.75 10.7 500 1120 4/7/07 8,085' 11.5 48 15 26 8/18120 18.0 14 1/85 0.5 10.0 500 880 4/8!07 8,085' 11.5 48 14 26 8/18/20 16.0 14 1185 0.5 10.0 500 1000 4/9/07 8,085' 11.5 4$ 15 26 12/19/26 15.5 15.5 2/83 0.25 10.2 500 1040 4/10/07 $,085' 11.5 45 16 26 11/16/20 1$.0 14 2/85 0.25 10.0 500 1080 4/11/07 8,381' 11.5 48 17 25 8/10/12 3.8 15 1/85 Tr 9.7 180 640 4/12/07 8,747' 11.5 48 17 25 10/12!14 3.4 9.5 1/85 Tr 9.5 180 440 4!13!07 8,747 11.5 50 16 27 10/14/17 4.0 14 1/86 1.5 9.0 200 400 ~1 EPOCH 35 • • • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~, 2N-311A REPORT FOR WRIGHT DATE 3/17/07 DEPTH 3168.00000 PRESENT OPERATION RIG SERVICE TIME 6 AM YESTERDAY 3000.00000 24 HOUR FOOTAGE 168' CASING INFORMATION 9.625" @ 2999' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HTC CM605 7102575 5X14 2550' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 175.0 @ 3030.00000 85.0 @ 3000.00000 138.7 112.00000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 9 @ 3126.00000 2 @ 3091.00000 5.1 6.40000 KLBS ROTARY RPM 88 @ 3168 25 @ 3108 78 0 RPM PUMP PRESSURE 1858 @ 3157 949 @ 3168.00000 1556 235 PSI DRILLING MUD REPORT DEPTH 3169' MW 9.7 VIS 47 PV 10 YP 24 FL 5.6 Gels 11/14/16 CL- 700 FC 1/ SOL 6 SD TR OIL - MBL 2.5 pH 10.1 Ca+ 1200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 37 @ 3047.00000 3 @ 3018.00000 16.4 TRIP GAS 949 @ 2800' CUTTING GAS 0 @ 3168.00000 0 @ 3168.00000 0.0 WIPER GAS 110 @ LOT CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 7023 @ 3047.00000 582 @ 3018.00000 2945.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 75 @ 3047.00000 6 @ 3018.00000 31.0 AVG 0 PROPANE (C-3) 23 @ 3047.00000 0 @ 3012.00000 10.3 CURRENT 0 BUTANE (C-4) 12 @ 3047.00000 0 @ 3076.00000 0.9 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 3168.00000 0 @ 3168.00000 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE, SAND, SILT PRESENT LITHOLOGY 3150' = 70% CLAYSTONE, 20% SAND, 10% SILT MAKE UP BHA AND LOAD TOOLS, SHALLOW TEST MWD, LOAD NUKES, RUN IN THE HOLE WITH 4" HWDP, DAILY RUN IN THE HOLE WITH 4" DRILL PIPE TO 2277', TEST CASING TO 2500 PSI, RUN IN THE HOLE TO ACTIVITY 2550' (TOOK WEIGHT), DISPLACE HOLE TO 9.6 MUD, TRIP GAS 949 UNITS, DRILL CEMENT FROM 2562' TO SUMMARY 2994', DRILL NEW HOLE TO 3038', CIRCULATE AND CONDITION MUD FOR LEAK OFF TEST, RUN LOT TO 15.0 PPG EMW, DRILL FORMATION TO 3169', POWER PROBLEMS ON RIG WITH MUD PUMP #2, PULL INTO CASING AND TROUBLE SHHOT. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 10/2007 n U Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~, 2N-311A REPORT FOR WRIGHT DATE Mar 18, 2007 DEPTH 3168.00000 PRESENT OPERATION WORK ON MUD PUMP #2 TIME 6 AM YESTERDAY 3168.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HTC CM605 7102575 5X14 2550' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3169' MW 9.7 VIS 47 PV 10 YP 24 FL 5.6 Gels 11/14/16 CL- 700 FC 1/ SOL 6 SD TR OIL - MBL 2.5 pH 10.1 Ca+ 1200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units} HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 3165 ' = 70% CLAYSTONE, 20% SAND, 10% SILTSTONE DAILY ACTIVITY CONTINUE TO TROUBLESHOOT RIG MUD PUMP #2 TRACTION MOTOR, FIELD WINDINGS FAILED, SUMMARY REMOVE AND UNWIRE TRACTION MOTOR, BIT PULLED INTO SHOE EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 n LJ • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~,~ 2N-311A REPORT FOR WRIGHT DATE Mar 19, 2007 DEPTH 3168.00000 PRESENT OPERATION C/O TRACTION MOTOR MUD PUMP #2 TIME 6 AM YESTERDAY 3168.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 3025' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HTC CM605 7102575 5X14 2550' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3169' MW 9.7 VIS 49 PV 10 YP 25 FL 5.6 Gels 11/15/17 CL- 700 FC 1/ SOL 6 SD TR OIL 1 MBL 2.5 pH 10.2 Ca+ 800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SKID NEW MUD TRACTION MOTOR TO MUD PUMP #2 AND WORK AROUND PUMP, WIRE IN SUMMARY TRACTION MOTOR. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 c: • Daily Report Page 1 of 1 CONOCOPHILLIPS tarn DAILY WELLSITE REPORT ~,~~~ 2N-311A REPORT FOR Wright DATE Mar 20, 2007 DEPTH 3168.00000 PRESENT OPERATION TROUBLESHOOT ELECTRICAL TIME 6 AM YESTERDAY 3168.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 3025' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HTC CM605 7102575 5X14 2999' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 52 WG @ 3041' 1 @ 3041' 4 CIRC TRIP GAS CUTTING GAS @ @ WIPER GAS 52 @ 3041' CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ 607 CONNECTION GAS HIGH ETHANE (C-2) @ @ 23 AVG PROPANE (C-3) @ @ 19 CURRENT BUTANE (C-4) @ @ 121 CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY FINISH WIRING IN TRACTION MOTOR AND TEST MUD PUMP #2 (OK), RUN IN THE HOLE TO 3041' AND TEST DAILY MUD PUMP #1 AND #2 AT FULL DRILL RATE @ 200 SPM (WIPER GAS = 52 UNITS), SHUT DOWN AND SWAP ACTIVITY RIG FROM HIGHLINE POWER BACK TO RIG POWER, STAGE PUMP #2 UP TO 100 SPM, PULL UP INTO SUMMARY CASING @ 2940', INSTALL HEAD PIN AND BREAK CIRCULATION, CONTINUE TO LOAD 7" CASING AND TROUBLESHOOT ELECTRICAL PROBLEM. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • file://C: \Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 10/2007 • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~,~, 2N-311A REPORT FOR WRIGHT DATE Mar 21, 2007 DEPTH 3168.00000 PRESENT OPERATION INSTALL TRACTION MOTOR TIME 6 AM YESTERDAY 3168.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HTC CM605 7102575 5X14 2999' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3169' MW 9.6 VIS 50 PV 10 YP 26 FL 5.8 Gels 11/15/17 CL- 800 FC 1/2 SOL 6 SD TR OIL 1 MBL 2.5 pH 10.4 Ca+ 600 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY REMOVE TRACTION MOTOR FROM PUMP #1, RIG UP AND BRING IN NEW TRACTION MOTOR AND SUMMARY BEGIN TO INSTALL. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT - ~~ 2N-311A REPORT FOR WRIGHT DATE Mar 22, 2007 DEPTH 3168.00000 PRESENT OPERATION PULL OUT OF HOLE TIME 6 AM YESTERDAY 3168.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" HTC CM605 7102575 5X14 2999 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3168' MW 9.7 VIS 50 PV 10 YP 26 FL 5.8 Gels 11/15/17 CL- 800 FC 1/2 SOL 6 SD TR OIL 1% MBL 2.5 pH 10.2 Ca+ 400 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 71 @ 3168 1 @ 3168 8 TRIP GAS CUTTING GAS @ @ WIPER GAS 71 @ 3168' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 8515 @ 3168 @ CONNECTION GAS HIGH ETHANE (C-2) 79 @ 3168 @ AVG PROPANE (C-3) 52 @ 3168 @ CURRENT BUTANE (C-4) 31 @ 3168 @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 45 @ 3168 @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY PICK UP NEW TRACTION MOTOR AND LOAD BEHIND PUMP #1, REMOVE HUB FROM MOTOR SHAFT, DAILY TERMINATE WIRING ON MOTOR, REMOVE HUB FROM ORIGINAL TRACTION MOTOR, RIG UP TRACTION ACTIVITY MOTOR HUB, INSTALL AND ALIGN, CHECK MUD PUMP #1 AND PUMP 40 SPM @ 230 PSI, RUN IN THE HOLE SUMMARY TO 3027' AND CIRCULATE AT 200 SPM (WIPER GAS = 71 UNITS), BREAK CIRCULATION, STAGE MUD PUMPS 1 + 2 UP IN 10 STROKE INCREAMENTS TO 200 SPM/1430 PSI, PULL OUT OF THE HOLE FROM 3130' EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • file://C:\Documents%20and%20 S ettings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 10/2007 • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~(~~, 2N-311 A REPORT FOR WRIGHT DATE Mar 23, 2007 DEPTH 3435.00000 PRESENT OPERATION DRILLING TIME 6 AM YESTERDAY 3169.00000 24 HOUR FOOTAGE 266' CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 rr1 8.5" HTC CM605 7102575 5X14 2999' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 197.7 @ 3343.00000 18.9 @ 3257.00000 95.6 138.79785 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 16 @ 3248.00000 0 @ SLIDE 9.0 7.85460 KLBS ROTARY RPM 81 @ 3212.00000 1 @ SLIDE 39.3 0.00000 RPM PUMP PRESSURE 1929 @ 3208.00000 1278 @ 3170.00000 1648.6 1540.74841 PSI DRILLING MUD REPORT DEPTH 3170' MW 9.7 VIS 50 PV 11 YP 24 FL 5.2 Gels 9/14/16 CL- 800 FC 1/2 SOL 6 SD TR OIL 1/93 MBL 5 pH 10.4 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 41 @ 3350.00000 6 @ 3257.00000 20.9 TRIP GAS 67 @ 3168' CUTTING GAS @ @ WIPER GAS 19 @ 3229' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6890 @ 3349.00000 1099 @ 3247.00000 3696.6 CONNECTION GAS HIGH 9 ETHANE (C-2) 43 @ 3177.00000 5 @ 3257.00000 18.0 AVG 9 PROPANE (C-3) 24 @ 3177.00000 2 @ 3257.00000 8.7 CURRENT 9 BUTANE (C-4) 20 @ 3184.00000 0 @ 3249.00000 5.1 CURRENT BACKGROUND/AVG 35 PENTANE (C-5) 42 @ 3190.00000 0 @ 3251.00000 9.7 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HRS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE, SILTSTONE PRESENT LITHOLOGY 3350' = 80% CLAYSTONE, 20% SILTSTONE FINISH PULLING OUT OF THE HOLE FROM 3130', RACK BACK HWDP, REMOVE NUKES AND DOWNLOAD LAY DOWN BHA, TEST BOPE, RIG DOWN AND MAKE UP B TOOLS HA #2, UPLOAD MWD, LOAD NUKES AND , DAILY RUN IN THE HOLE TO 3027', KELLY UP AND WASH DOWN TO 3169', TRIP GAS = 67 SHALLOW TEST TOOLS , ACTIVITY TAKE SURVEY'S OF THE HOLE AND PULL OUT OF THE HOLE TO THE SHOE, DRILL AHEAD TO 3230' UNITS , , SUMMARY TROUBLESHOOT LUBE OIL PUMPS FOR PUMPS 1 + 2, TRIP IN THE HOLE TO BOTTOM AND DRILL/SLIDE AHEAD, WIPER GAS = 19 UNITS EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20 Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • • • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~,~, 2N-311A REPORT FOR WRIGHT DATE Mar 24, 2007 DEPTH 4741.00000 PRESENT OPERATION DRILLING TIME 6 AM YESTERDAY 3435.00000 24 HOUR FOOTAGE 1306' CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4625' 3235.81 4211.25 62.17 22.14 3037.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 rr1 8.5" HTC CM605 7102575 5X14 2999' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 245.6 @ 3816.00000 21.9 @ 3628.00000 90.4 81.66228 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 26 @ 3540.00000 1 @ SLIDE 9.6 4.57875 KLBS ROTARY RPM 84 @ 4007.00000 1 @ SLIDE 55.9 81.00000 RPM PUMP PRESSURE 2171 @ 3676.00000 598 @ 3813.00000 1882.2 2023.47607 PSI DRILLING MUD REPORT DEPTH 4340' MW 9.7 VIS 52 PV 14 YP 27 FL 5 Gels 10/20/26 CL- 700 FC 1/2 SOL 6.5 SD TR OIL 1% MBL 11.25 pH 10.4 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 62 @ 3637,00000 2 @ 4638.00000 34.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 80 @ 3452' CHROMATOGRAPHY (ppm) SURVEY 19 METHANE (C-1) 10375 @ 3895.00000 1236 @ 4024.00000 5526.1 CONNECTION GAS HIGH 30 ETHANE (C-2) 80 @ 3895.00000 8 @ 3770.00000 36.5 AVG 20 PROPANE (C-3) 23 @ 4432.00000 0 @ 3536.00000 8.1 CURRENT 24 BUTANE (C-4) 9 @ 4121.00000 0 @ 4183.00000 0.4 CURRENT BACKGROUND/AVG 40 PENTANE (C-5) 0 @ 4638.00000 0 @ 4638.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE, SILTSTONE, SAND, SANDSTONE, TRACE CALCITE PRESENT LITHOLOGY 70% SILTSTONE, 20% CLAYSTONE, 10% SANDSTONE (VERY FINE GRAINED) DAILY ACTIVITY DRILL/SLIDE FORMATION TO 3452', CIRCULATE BOTTOMS UP AND PULL OUT OF THE HOLE TO THE ' SHOE, MONIT OR THE WELL @ 2994', SWAP ROTATION OF MUD PUMP 1 + 2, RUN IN THE HOLE TO 3425 SUMMARY AND WASH DOWN FROM 3425' TO 3456' DRILL AND SLIDE AHEAD WIPER GAS 80 UNITS EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Doctaments\My%20 Wells\CON... 4/ 10/2007 Daily Report Page 1 of 1 • r~ ~~ r~ GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 66 @ 4841.00000 13 @ 4949.00000 33.2 TRIP GAS CUTTING GAS 0 @ 5530.00000 0 @ 5530.00000 0.0 WIPER GAS 156 @ 4847' CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 12020 @ 4841.00000 2358 @ 4949.00000 5915.8 CONNECTION GAS HIGH 20 ETHANE (C-2) 128 @ 4841.00000 20 @ 5200.00000 49.7 AVG 10 PROPANE (C-3) 53 @ 4841.00000 2 @ 5033.00000 13.0 CURRENT 0 BUTANE (C-4) 25 @ 4841.00000 0 @ 4787.00000 2.2 CURRENT BACKGROUND/AVG 38 PENTANE (C-5) 0 @ 5530.00000 0 @ 5530.00000 0.0 HYDROCARBON SHOWS TRACE DEAD OIL TAR @ 5300 TO 5400' NO OIL CUTS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, SILTSTONE, CLAYSTONE PRESENT LITHOLOGY 5530' = 70% SANDSTONE, 30% SILTSTONE DAILY DRILUSLIDE TO 4847', PUMP A SWEEP AND CIRCULATE THE HOLE CLEAN, PULL OUT OF THE HOLE AND ACTIVITY REAM TIGHT SPOTS: 4402', 4176', 3890', 3607', 3321', CIRCULATE BOTTOMS UP AT 3230', PULL OUT OF THE SUMMARY HOLE TO THE SHOE @ 2945', MONITOR THE WELL, SERVICE THE RIG AND CUT/SLIP NEW DRILL LINE, RUN IN THE HOLE TO 4752' AND WASH TO BOTTOM, WIPER GAS 156 UNITS, DRILL/SLIDE TO REPORT TIME. CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~ 2N-311 A REPORT FOR WRIGHT DATE Mar 25, 2007 DEPTH 5700 PRESENT OPERATION DRILLING TIME 6 AM YESTERDAY 4741.00000 24 H OUR FOOTAGE 959' CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5530 3673.21 SURVEY DATA 5161.70 60.65 24.85 3499.25 4874.18 60.88 21.70 3356.81 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 rr1 8.5" HTC CM605 7102575 5X14 2999' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 189.4 @ 5061.00000 10.1 @ 4847.00000 91.9 106.65719 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 50 @ 5326.00000 0 @ SLIDE 18.4 8.91303 KLBS ROTARY RPM 91 @ 4866.00000 1 @ SLIDE 52.3 80.00000 RPM PUMP PRESSURE 2343 @ 5460.00000 1321 @ 4943.00000 2158.1 2149.20410 PSI DRILLING MUD REPORT DEPTH 5260' MW 9.7 VIS 50 PV 13 YP 24 FL 4 Gels 8/11/15 CL- 600 FC 1/2 SOL 7.5 SD TR OIL 1% MBL 16.25 pH 10.1 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 Daily Report ~1 r Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~~~ 2N-311 A REPORT FOR BREEDEN/MORRIS DATE Mar 26, 2007 DEPTH 6816 PRESENT OPERATION DRILLING TIME 6 AM YESTERDAY 5700 24 HOUR FOOTAGE 1116' CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6492.29 58.66 21.92 4149.68 SURVEY DATA 6398.49 59.62 22.58 4101.57 6303.15 60.46 22.88 4053.96 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE H OURS T/B/C PULLED 1rr1 8.5" HTC CM605 7102575 5X14 2999' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 273.9 @ 6179.00000 20.3 @ 6167.00000 89.8 103.90810 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 56 @ 5725.00000 5 @ SLIDE 26.5 13.01351 KLBS ROTARY RPM 92 @ 6557.00000 1 @ SLIDE 68.1 79.00000 RPM PUMP PRESSURE 2674 @ 6389.00000 1056 @ 6199.00000 2401.0 2434.02979 PSI DRILLING MUD REPORT DEPTH 6559' MW 9.8 VIS 56 PV 15 YP 30 FL 3.6 Gels 12/17/19 CL- 400 FC 1/2 SOL 8 SD TR OIL 2% MBL 20 pH 9.7 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 125 @ 6554.00000 1 @ 6501.00000 47.3 TRIP GAS CUTTING GAS @ @ WIPER GAS 291 @ 6559' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 22764 @ 6554.00000 204 @ 6501.00000 7960.0 CONNECTION GAS HIGH 76 ETHANE (C-2) 1051 @ 6554.00000 8 @ 6501.00000 214.9 AVG 40 PROPANE (C-3) 1118 @ 6262.00000 2 @ 6501.00000 102.3 CURRENT 42 BUTANE (C-4) 140 @ 6554.00000 0 @ 6501.00000 29.8 CURRENT BACKGROUND/AVG 26 PENTANE (C-5) 23 @ 6549.00000 0 @ 6525.00000 2.5 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SANDSTONE, CLAYSTONE, CARBON SILT PRESENT LITHOLOGY 90% SILTSTONE, 10% SANDSTONE (VERY FINE GRAINS) CIRCULATE AND CONDITION THE HOLE, WIPER TRIP TO 4800', CIRCULATE DRILL AND SLIDE TO 6559' , DAILY ACTIVITY AT 4800' MAX GAS = 53 UNITS, RUN IN THE HOLE TO BOTTOM AND CIRCULATE OUT 291 UNITS OF SUMMARY WIPER GAS DRILL AHEAD. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS tarn DAILY WELLSITE REPORT E'{~I~ 2N-311A REPORT FOR WRIGHT DATE Mar 27, 2007 DEPTH 7603.00000 PRESENT OPERATION CIRCULATE MUD BLIZZARD TIME 6 AM YESTERDAY 6816.00000 24 HOUR FOOTAGE 787' CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6968.77 53.95 12.20 4410.52 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1rr1 8.5" HTC CM605 7102575 5X14 2999' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 526.0 @ 7335.00000 16.2 @ 7152.00000 92.1 71.10268 FT/HR SURFACE TORQUE 9 @ 7216.00000 0 @ 7562.00000 4.7 7.76486 AMPS WEIGHT ON BIT 78 @ 7539.00000 22 @ 6845.00000 49.4 46.10187 KLBS ROTARY RPM 84 @ 6848.00000 1 @ 7431.00000 46.1 79.00000 RPM PUMP PRESSURE 2630 @ 7281.00000 1962 @ 7057.00000 2325.5 2377.06470 PSI DRILLING MUD REPORT DEPTH 7425 MW 9.8 VIS 48 PV 14 YP 24 FL 4.6 Gels 10/11/12 CL- 400 FC 1/2 SOL 8 SD 0.25 OIL 1% MBL 18 pH 9.5 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 485 @ 7032.00000 18 @ 7361.00000 86.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 42084 @ 7028.00000 2837 @ 7361.00000 11761.0 CONNECTION GAS HIGH 250 ETHANE (C-2) 5385 @ 7028.00000 136 @ 7361.00000 836.9 AVG 43 PROPANE (C-3) 2252 @ 7083.00000 58 @ 7361.00000 357.9 CURRENT 24 BUTANE (C-4) 1071 @ 7083.00000 16 @ 7530.00000 175.9 CURRENT BACKGROUND/AVG 20 CIRC PENTANE (C-5) 591 @ 7091.00000 0 @ 6861.00000 65.8 HYDROCARBON ICEBERG GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6925 TO 7100' SAND/SANDSTONE BEFORE 30 PEAK 485 SAND = CLR-OFFWHT, UNCONS, FGR-MGR, ABNT AFTER 65 LITHIC FRAGS, N STN, N OIL CUTS LITHOLOGY SAND, SANDSTONE, SILTSTONE, SHALE, CLAYSTONE PRESENT LITHOLOGY 7600' = SILTSTONE 70%, SANDSTONE 20% SHALE 10% DAILY ACTIVITY DRILL/SLIDE TO 7067' ROTATE AND CIRCULATE THE HOLE AND CONDITION THE MUD, DRILL/SLIDE SUMMARY AHEAD 707604', PICK UP AND CIRCULATE PHASE THREE BLIZZARD. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 10/2007 Daily Report • Page 1 of 2 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~ 2N-311A REPORT FOR WRIGHT DATE Mar 28, 2007 DEPTH 8065.00000 PRESENT OPERATION POOH FOR CASING TIME 6 AM YESTERDAY 7603.00000 24 HOUR FOOTAGE 462' CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8065 5176.47 7988.35 39.92 332.08 5117.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1rr1 8.5" HTC CM605 7102575 5X14 2999 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 407.5 @ 7926.00000 21.3 @ 7735.00000 95.5 59.23500 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 98 @ 8022.00000 8 @ 7690.00000 49.2 62.08400 KLBS ROTARY RPM 81 @ 8060.00000 1 @ SLIDE 35.9 RPM PUMP PRESSURE 2684 @ 8026.00000 2073 @ 7920.00000 2386.0 PSI DRILLING MUD REPORT DEPTH 8065' MW 9.9 VIS 45 PV 12 YP 23 FL 4.4 Gels 10/12/14 CL- 400 FC 1/2 SOL 8.5 SD 0.4 OIL 1% MBL 17.5 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 259 @ 7875.00000 14 @ 7604.00000 60.1 TRIP GAS CUTTING GAS @ @ WIPER GAS 387 @ 8065' CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 39584 @ 7875.00000 2340 @ 7604.00000 9239.6 CONNECTION GAS HIGH 16 ETHANE (C-2) 2661 @ 7875.00000 134 @ 7604.00000 536.9 AVG 12 PROPANE (C-3) 1647 @ 7875.00000 55 @ 7604.00000 329.7 CURRENT 12 BUTANE (C-4) 801 @ 7875.00000 25 @ 7604.00000 169.8 CURRENT BACKGROUNDIAVG 0 PENTANE (C-5) 237 @ 7875.00000 1 @ 7650.00000 47.0 HYDROCARBON GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 7860 TO 7888' SANDSTONE, SAND AND BEFORE 18 MAX SN + SS W/ HEAVY SILT, FINE GR, MOD TO V SILTSTONE 259 AFTER 22 ARGILLACEOUS, POOR PORO NO OIL CUTS OR FLUOR LITHOLOGY SANDSTONE, SAND, SILTSTONE, MINOR SHALE (SILTY) PRESENT LITHOLOGY 8065' = 90% SILTSTONE, 10% SANDSTONE DAILY ACTIVITY FINISHED CIRCULATING FOR BAD WEATHER AFTER 5 1/2 HOURS, DRILLED TO 8065', PUMPED A HI VIS SUMMARY SWEEP AND CIRCULATED, WIPER TRIP TO 6633', RAN IN HOLE TO BOTTOM AND CIRCULATED OUT 387 UNITS OF WIPER GAS, CIRCULATE AND BEGIN PULLING OUT OF THE HOLE EPOCH PERSONNEL ON BOARD 4 DAILY COST file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 10/2007 Daily Report REPORT BY LEES F. BROWNE JR. ~~ ~~ Page 2 of 2 file://C : \Documents%20and%20 Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~, 2N-311A REPORT FOR WRIGHT DATE Mar 29, 2007 DEPTH 8065.00000 PRESENT OPERATION RUN CSG TIME 6 AM YESTERDAY 8065.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8065 5176.47 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1rr1 8.5" HTC CM605 710275 5X14 2999 8065 5066 59.42 NA TD/CSG DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8065' MW 10.0 VIS 47 PV 12 YP 22 FL 4.6 Gels 9/11/12 CL- 400 FC 1/2 SOL 8.5 SD 0.5 OIL 1% MBL 17.5 pH 10.0 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8065' = 9 0% SILTSTONE, 10% SANDSTONE DAILY ACTIVITY PULLED OUT OF THE HOLE AND LAY DOWN 2 JOINTS OF HWDP, REMOVE SOURCES AND DOWNLOAD SUMMARY MWD DATA, LAY DOWN BHA #2, WASH THE STACK, BEGIN TO RUN CASING STRING IN THE HOLE EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. r file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 10/2007 Daily Report • Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~,~ 2N-311A REPORT FOR WRIGHT DATE Mar 30, 2007 DEPTH 8065.00000 PRESENT OPERATION RIH W/ 7" CSG TIME 6 AM YESTERDAY 8065.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2999' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8065 5176.47 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8065' MW 10.2 VIS 58 PV 14 YP 22 FL 4.2 Gels 10/12/14 CL- 400 FC 1/2 SOL 10 SD 0.5 OIL 1% MBL 18.5 pH 9.5 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ CIRC 0 @ CIRC 2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 806 5' = 90% SILTSTONE, 10% SANDSTONE RUN IN THE HOLE WITH 7" CASING TO 2926', CIRCULATE BOTTOMS UP AT 3 BPM @ 400 PSI, RUN IN THE HOLE WITH 7" CASING TO 5220', ATTEMPT TO CIRCULATE WITH MINIMAL RETURNS, LAY DOWN 2 JOINTS OF DAILY CASING (514 0') ATTEMPT TO CIRCULATE WITH NO RETURNS, LAY DOWN 3 JOINTS OF CASING (5010') PJSM, ACTIVITY LAY DOWN 1 0 JOINTS OF CASING (4588'), RIG UP CIRC. LINE AND BREAK CIRC @ 17 SPM @ 170 ,INCREASE SUMMARY RATE TO 25 SPM @ 220 PP WITH NO RETURNS, LAY DOWN 10 JOINTS OF CASING AND RIG UP CIRC LINE, PULL OUT OF THE HOLE WITH CASING FROM 4167' TO 3271', BREAK CIRC LINE AND RIG UP AND RUN IN THE HOLE WITH 7" CASING FROM 3271' TO 8065' EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 I.J Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~,~ 2N-311A REPORT FOR WRIGHT DATE Mar 31, 2007 DEPTH 8065.00000 PRESENT OPERATION TEST BOPE TIME 6 AM YESTERDAY 8065.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 8060' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8065' 5176.47' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8065' MW 11.5 VIS 48 PV 15 YP 22 FL 5 Gels 8/9/10 CL- 400 FC 1/2 SOL 12 SD 0 OIL 0 MBL 6 pH 9.7 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ limited returns 0 @ limited returns 1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY land casing at 8060' and circulate @ 5 spm/480 psi, rig up cement head, continue to circulate @ 5 spm/250 psi, SUMMARY Pump cement to casing, rig down cement equipment, pump out the stack, change out the upper rams from 7" to 4", begin to test bope. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. C] file : //C : \Documents%20and%20 S ettings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 10/2007 w r~ Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~~,~ 2N-311 A REPORT FOR B. WRIGHT DATE Apr 01, 2007 DEPTH 8085' PRESENT OPERATION CIRCULATING TIME 6 AM YESTERDAY 8065' 24 HOUR FOOTAGE 20 CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 1/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 160.2 @ 8066' 10.5 @ 8080' 53.7 55.6 FT/HR SURFACE TORQUE 7 @ 8076' 5 @ 8077' 6.6 6.4 AMPS WEIGHT ON BIT 62 @ 8065' 2 @ 8066' 28.7 31.0 KLBS ROTARY RPM 36 @ 8075' 29 @ 8068' 30.2 30.0 RPM PUMP PRESSURE 2103 @ 8074' 1732 @ 8066' 1971.3 1955.2 PSI DRILLING MUD REPORT DEPTH 8065' MW 11.5 VIS 47 PV 16 YP 25 FL 5.2 Gels 8/9/10 CL- 1000 FC 1/2 SOL 11 SD TR OIL TR/89 MBL 6 pH 9.6 Ca+ 200 CCI MWD SUMMARY INTERVAL 8085 TO present TOOLS LWD and Downho le motor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 54 @ 8065' 7 @ 8085' 19.9 TRIP GAS 1230u CUTTING GAS 0 @ 8085' 0 @ 8085' 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) 6777 @ 8065' 846 @ 8080' 2219.6 CONNECTION GAS HIGH NA ETHANE (C-2) 506 @ 8065' 109 @ 8080' 173.8 AVG NA PROPANE (C-3) 401 @ 8065' 91 @ 8080' 136.5 CURRENT NA BUTANE (C-4) 231 @ 8065' 22 @ 8080' 54.6 CURRENT BACKGROUND/AVG 40u PENTANE (C-5) 78 @ 8065' 3 @ 8080' 10.9 HYDROCARBON SHOWS None in past 24 hrs. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Drilling in Siltstone and some sandstone in past 24 hrs. PRESENT LITHOLOGY A/A DAILY ACTIVITY SUMMARY Test Bops's, trip in hole w/ down hole motor, drill cement, drill formation, press test EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY C. Isbon / K. McMullen • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • r: Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~~~ 2N-311 A REPORT FOR B. WRIGHT DATE Apr 02, 2007 DEPTH 8086' PRESENT OPERATION CIRCULATING-MIXING MUD TIME 6 am YESTERDAY 8085' 24 HOUR FOOTAGE 1' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 1/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8085' MW 11.7 VIS 48 PV 15 YP 25 FL 4.4 Gels 9/11/14 CL- 800 FC 1 SOL 14 SD 1.5 OIL 0 MBL 8 pH 9.6 Ca+ 220 CCI MWD SUMMARY INTERVAL 8065' TO PRESENT TOOLS LWD AND DOWNHOLE MOTOR GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 3 units PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% Siltstone and 20% Sandstone DAILY ACTIVITY SUMMARY Mostly circulating and conditioning mud to increase mud wt. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY KEVIN MCMULLEN • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~,~ 2N-311 A REPORT FOR B. WRIGHT DATE Apr 03, 2007 DEPTH 8085' PR ESENT OPERATION TRIP IN HOLE. TIME 6 am YESTERDAY 8085' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 1/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8085' MW 11.7 VIS 49 PV 13 YP 26 FL 4.4 Gels 8/10/12 CL- 800 FC 1 SOL 14 SD 1.0 OIL 0 MBL 8.5 pH 9.7 Ca+ 180 CCI MWD SUMMARY INTERVAL 8065' TO PRESENT TOOLS LWD AND DOWNHOLE MOTOR GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 4 units PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% Siltstone and 20% Sandstone Mix FORM-A-SQUEEZE pill and weight up mud to 12.4 ppg.; pumped at 8085', pull out of hole to 7171' and DAILY ACTIVITY attempt to squeeze; run in hole back down to 8085'; circulate with pa rtial returns; pull out of hole and pick up SUMMARY cement tools to pump cement squeeze; trip in hole. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY KEVIN MCMULLEN /MARK BIETTING C] file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT E~ 2N-311 A REPORT FOR Duane Vaagen DATE Apr 04, 2007 DEPTH 8085' PRESENT OPERATION CEMENT/TRIPPING TIME 5:30am YESTERDAY 8085' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 2/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH 8085' MW 11.5 VIS 47 PV 14 YP 23 FL 4.6 Gels 8/9/10 CL- 800 FC 1 SOL 14 SD 10 OIL 0 MBL 8.5 pH 9.6 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS 85u CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG 15u PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 7u BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 7u PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% SILTSTONE 20% SANDSTONE DAILY ACTIVITY SUMMARY CEMENTATION, PRESSURE TESTING, CIRCULATING AND TRIPPING TO SHOE EPOCH PERSONNEL ON BOARD MARK BIETTING, DAN HILLEGEIST, CHUCK ISBON DAILY COST REPORT BY MARK BIETTING • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 10/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT ~~ ~~, 2N-311 A REPORT FOR Duane Vaagen DATE Apr 05, 2007 DEPTH 8085' PRESENT OPERATION Circulating TIME 06:14:07 YESTERDAY 8085' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 2/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 8085' 0 @ 8085' 0.0 FT/HR SURFACE TORQUE 0 @ 8085' 0 @ 8085' 0.0 AMPS WEIGHT ON BIT 0 @ 8085' 0 @ 8085' 0.0 KLBS ROTARY RPM 0 @ 8085' 0 @ 8085' 0.0 RPM PUMP PRESSURE 0 @ 8085' 0 @ 8085' 0.0 PSI DRILLING MUD REPORT DEPTH 8085' MW 11.5 VIS 59 PV 17 YP 29 FL .0 Gels 9112/17 CL- 500 FC 2 SOL 14 SD 1 OIL 0 MBL 8 pH 10.8 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 8085' 0 @ 8085' 0.0 TR{P GAS CUTTING GAS 0 @ 8085' 0 @ 8085' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 8085' 0 @ 8085' 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 8085' 0 @ 8085' 0.0 AVG PROPANE (C-3) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BUTANE (C-4) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 8085' 0 @ 8085' 0.0 HYDROCARBON SHOWS INTERVAL ~ LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% SILT STONE 20% SANDSTONE DAILY ACTIVITY SUMMARY CEMENTATION/CIRCULATING EPOCH PERSONNEL ON BOARD MARK BIETTING, DAN HILLEGEIST, CHUCK ISBON DAILY COST REPORT BY MARK BIETTING • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE ~ ~T~~LT 1 lam REPORT . 2N-311A REPORT FOR DAVE MORRISI DUANE VAAGEN DATE Apr 06, 2007 DEPTH 8085' PRESENT OPERATION CIRCULATING TIME 05:34:07 YESTERDAY 8085' 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE H OURS T/B/C PULLED 2 6 2/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 8085' 0 @ 8085' 0.0 FT/HR SURFACE TORQUE 0 @ 8085' 0 @ 8085' 0.0 AMPS WEIGHT ON BIT 0 @ 8085' 0 @ 8085' 0.0 KLBS ROTARY RPM 0 @ 8085' 0 @ 8085' 0.0 RPM PUMP PRESSURE 0 @ 8085' 0 @ 8085' 0.0 PSI DRILLING MUD REPORT DEPTH 8085' MW 11.5 VIS 55 PV 21 YP 43 FL 14 Gels 14/28/35 CL- 500 FC 2 SOL 15 SD 1 OIL 1 MBL 8 pH 10.5 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 65u CUTTING GAS 0 @ 8085' 0 @ 8085' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 8085' 0 @ 8085' 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 8085' 0 @ 8085' 0.0 AVG 10u PROPANE (C-3) 0 @ 8085' 0 @ 8085' 0.0 CURRENT 10u BUTANE (C-4) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BACKGROUND/AVG 10u PENTANE (C-5) 0 @ 8085' 0 @ 8085' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% SILTSTONE, 20% SANDSTONE DAILY ACTIVITY SUMMARY SQUEEZING CEMENT, POOH TO PICK UP TOOLS, CIRCULATING EPOCH PERSONNEL ON BOARD MARK BIETTING, DAN HILLEGEIST, CHUCK ISBON, PAUL IVERSON DAILY COST REPORT BY MARK BIETTING file://C:\Documents%20and%20 Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • Daily Report Page 1 of 1 CONOCOPHILL{PS DAILY WELLSITE REPORT ~ ~~~~,~ 2N-311A REPORT FOR Dave Morris, Duane Vaagen DATE Apr 07, 2007 DEPTH 8085' PRESENT OPERATION CEMENT BOND LOG TIME 06:00:00 YESTERDAY 8085' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 2/8" PDC HCM505Z 7009677 8085' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 8085' 0 @ 8085' 0.0 FT/HR SURFACE TORQUE 0 @ 8085' 0 @ 8085' 0.0 AMPS WEIGHT ON BIT 0 @ 8085' 0 @ 8085' 0.0 KLBS ROTARY RPM 0 @ 8085' 0 @ 8085' 0.0 RPM PUMP PRESSURE 0 @ 8085' 0 @ 8085' 0.0 PSI DRILLING MUD REPORT DEPTH 8085' MW 11.6 VIS 47 PV 14 YP 25 FL 20 Gels 8/20/28 CL- 500 FC 2 SOL 14 SD 0.5 OIL 1 MBL 8 pH 10.0 Ca+ 880 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 8085' 0 @ 8085' 0.0 TRIP GAS CUTTING GAS 0 @ 8085' 0 @ 8085' 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 0 @ 8085' 0 @ 8085' 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 8085' 0 @ 8085' 0.0 AVG PROPANE (C-3) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BUTANE (C-4) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 8085' 0 @ 8085' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% SILT STONE 20% SANDSTONE DAILY ACTIVITY SUMMARY CIRCULATING; CEMENT BOND LOG EPOCH PERSONNEL ON BOARD MARK BIETTING, DAN HILLEGEIST, CHUCK ISBON, PAUL IVERSON DAILY COST REPORT BY MARK BIETTING • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 :7 L' Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT ~~~~,~ 2N-311A REPORT FOR Dave Morris, Duane Vaargen DATE Apr 08, 2007 DEPTH 8085' PRESENT OPERATION Circulating TIME 05:00:00 YESTERDAY 8085' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FO OTAGE HOURS T/B/C PULLED 2 6 2/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 8085' 0 @ 8085' 0.0 FT/HR SURFACE TORQUE 0 @ 8085' 0 @ 8085' 0.0 AMPS WEIGHT ON BIT 0 @ 8085' 0 @ 8085' 0.0 KLBS ROTARY RPM 0 @ 8085' 0 @ 8085' 0.0 RPM PUMP PRESSURE 0 @ 8085' 0 @ 8085' 0.0 PSI DRILLING MUD REPORT DEPTH 8085' MW 11.5 VIS 48 PV 15 YP 25 FL 18 Gels 8/18/20 CL- 500 FC 2 SOL 14 SD 0.5 OIL 1 MBL 8 pH 10.0 Ca+ 880 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 8085' 0 @ 8085' 0.0 TRIP GAS 125u CUTTING GAS 0 @ 8085' 0 @ 8085' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 8085' 0 @ 8085' 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 8085' 0 @ 8085' 0.0 AVG 15u PROPANE (C-3) 0 @ 8085' 0 @ 8085' 0.0 CURRENT 20u BUTANE (C-4) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BACKGROUND/AVG 20u PENTANE (C-5) 0 @ 8085' 0 @ 8085' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% SILTSTONE 20% SANDSTONE DAILY ACTIVITY SUMMARY CEMENT BOND LOG, POOH HOLE, RIH, CIRCULATE EPOCH PERSONNEL ON BOARD MARK BIETTING, DAN HILLEGEIST, CHUCK ISBON, PAUL IVERSON DAILY COST REPORT BY MARK BIETTING • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT ~`~ ~,~~~ 2N-311A REPORT FOR Dave Morris, Duane Vaagen DATE Apr 09, 2007 DEPTH 8085' PRESENT OPERATION RIH, CIRCULATE, HIGH-PRESSURE TESTING TIME 06:00:00 YESTERDAY 8085' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FO OTAGE H OURS T/B/C PULLED 2 6 2/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 8085' 0 @ 8085' 0.0 FT/HR SURFACE TORQUE 0 @ 8085' 0 @ 8085' 0.0 AMPS WEIGHT ON BIT 0 @ 8085' 0 @ 8085' 0.0 KLBS ROTARY RPM 0 @ 8085' 0 @ 8085' 0.0 RPM PUMP PRESSURE 0 @ 8085' 0 @ 8085' 0.0 PSI DRILLING MUD REPORT DEPTH 8085' MW 11.5 VIS 48 PV 14 YP 26 FL 16 Gels 8/18120 CL- 500 FC 2 SOL 14 SD 0.5 OIL 1 MBL 8 pH 10.0 Ca+ 1000 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 8085' 0 @ 8085' 0.0 TRIP GAS 44u CUTTING GAS 0 @ 8085' 0 @ 8085' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 8085' 0 @ 8085' 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 8085' 0 @ 8085' 0.0 AVG 4u PROPANE (C-3) 0 @ 8085' 0 @ 8085' 0.0 CURRENT 4u BUTANE (C-4) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BACKGROUNDIAVG 4u PENTANE (C-5) 0 @ 8085' 0 @ 8085' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% SILTSTONE 20% SANDSTONE DAILY ACTIVITY SUMMARY RIH, CIRCULATE EPOCH PERSONNEL ON BOARD MARK BIETTING, DAN HILLEGEIST, CHUCK ISBON, PAUL IVERSON DAILY COST REPORT BY MARK BIETTING file://C:\Documents%20and%20 Settings\RigUser\My%20Documents\My%20W ells\CON... 4/ 1012007 I'~1 ~.J ~-~ ~_..~ Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT ~~°~~,~ 2N-311 A REPORT FOR Dave Morris, Duane Vaagen DATE Apr 10, 2007 DEPTH 8085' PRESENT OPERATION TRIP IN HOLE. TIME 06:00:00 YESTERDAY 8085' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 2/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 8085' 0 @ 8085' 0.0 FT/HR SURFACE TORQUE 0 @ 8085' 0 @ 8085' 0.0 AMPS WEIGHT ON BIT 0 @ 8085' 0 @ 8085' 0.0 KLBS ROTARY RPM 0 @ 8085' 0 @ 8085' 0.0 RPM PUMP PRESSURE 0 @ 8085' 0 @ 8085' 0.0 PSI DRILLING MUD REPORT DEPTH 8085' MW 11.5 VIS 48 PV 15 YP 26 FL 18 Gels 12/19/26 CL- 500 FC 2 SOL 15.5 SD 0.25 OIL 2 MBL 8 pH 10.0 Ca+ 1040 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 8085' 0 @ 8085' 0.0 TRIP GAS 44u CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) 0 @ 8085' 0 @ 8085' 0.0 CONNECTION GAS HIGH NA ETHANE (C-2) 0 @ 8085' 0 @ 8085' 0.0 AVG 4u PROPANE (C-3) 0 @ 8085' 0 @ 8085' 0.0 CURRENT 4u BUTANE (C-4) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BACKGROUND/AVG 3u PENTANE (C-5) 0 @ 8085' 0 @ 8085' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 80% SILTSTONE 20% SANDSTONE Rig up cement equipment and test lines; pertorm injection test; pumped 10 bbl. of water, 50 bbl. of cement and 10 DAILY ACTIVITY bbl. of water; chas ed with 70 bbl. of 11.5 ppg. mud; pull out of hole to 7703' and reverse circulate; pumped dry job SUMMARY and pulled out of hole; pick up bottom hole assembly and shallow test tools; trip in hole. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY Allen Odegaard • file://C: \Documents%20and%20 Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 10/2007 r1 ~J • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~,{~,~, 2N-311 A REPORT FOR Dave Morris /Scott Lapiene DATE Apr 11, 2007 DEPTH 8085' PRESENT OPERATION Circulate & condition mud. TIME 6 am YESTERDAY 8085' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 1/8" PDC HCM505Z 7009677 8065' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 8085' 0 @ 8085' 0.0 FT/HR SURFACE TORQUE 0 @ 8085' 0 @ 8085' 0.0 AMPS WEIGHT ON BIT 0 @ 8085' 0 @ 8085' 0.0 KLBS ROTARY RPM 0 @ 8085' 0 @ 8085' 0.0 RPM PUMP PRESSURE 0 @ 8085' 0 @ 8085' 0.0 PSI DRILLING MUD REPORT DEPTH 8085' MW 11.5 VIS 45 PV 16 YP 26 FL 18 Gels 11/16/21 CL- 500 FC 1 SOL 14 SD 0.25 OIL 2 MBL 85 pH 10.0 Ca+ 1080 CCI MWD SUMMARY INTERVAL TO TOOLS LWD AND DOWNHOLE MOTOR GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 8085' 0 @ 8085' 0.0 TRIP GAS 86u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ 8085' 0 @ 8085' 0.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 8085' 0 @ 8085' 0.0 AVG 0 PROPANE (C-3) 0 @ 8085' 0 @ 8085' 0.0 CURRENT 0 BUTANE (C-4) 0 @ 8085' 0 @ 8085' 0.0 CURRENT BACKGROUND/AVG 14u PENTANE (C-5) 0 @ 8085' 0 @ 8085' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGYlREMARKS GAS DESCR{PTION LITHOLOGY PRESENT LITHOLOGY 80% Siltstone and 20% Sandstone DAILY Trip in hole; wash and ream to 7938' and tag the top of the retainer; drill through retainer to 7940'; drill cement to 8065'; circulate hole clean; pump dry job and pull out of hole, standing bac k bottom hole assembly; change out mud ACTIVITY SUMMARY motor and run in hole with new bottom hole assembly; shallow test tools and run in hole to 7934'; circulate and condition mud. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY Allen Odegaard • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 11 /2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~,~ 2N-311A REPORT FOR Dave Morris / Scott Lapiene DATE Apr 12, 2007 DEPTH 8628' PRESEN T OPERATION Drilling ahead. TIME 6 am YESTERDAY 8085' 24 HOUR FOOTAGE 543' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8550' 39.37 325.38 5552.51 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HO URS T/B/C PULLED 2 6 1/8" PDC HCM505Z 7009677 8065' 563' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 178.5 @ 8229' 8.2 @ 8546' 50.4 64.6 FT/HR SURFACE TORQUE 8 @ 8264' 0 @ 8548' 6.2 7.8 AMPS WEIGHT ON 81T 43 @ 8552' 0 @ 8112' 16.0 10.4 KLBS ROTARY RPM 85 @ 8256' 2 @ 8101' 62.5 73.0 RPM PUMP PRESSURE 512 @ 8277' 44 @ 8145' 128.9 79.5 PSI DRILLING MUD REPORT DEPTH 8381' MW 11.5 VIS 48 PV 17 YP 25 FL 3.8 Gels 8/10/12 CL- 180 FC 1/2 SOL 15 SD Tr OIL 1 MBL 7.5 pH 9.7 Ca+ 640 CCI MWD SUMMARY INTERVAL TO TOOLS LWD AND DOWNHOLE MOTOR GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 861 @ 8260' 2 @ 8109' 93.3 TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 84192 @ 8260' 53 @ 8102' 9107.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 13477 @ 8271' 0 @ 8103' 1149.9 AVG 0 PROPANE (C-3) 12994 @ 8260' 0 @ 8103' 1032.7 CURRENT 0 BUTANE (C-4) 7839 @ 8260' 0 @ 8103' 606.6 CURRENT BACKGROUND/AVG 49 PENTANE (C-5) 3150 @ 8271' 0 @ 8101' 252.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Washed to 8065' and drilled to 8083' prior to circulating hole clean for FIT (14.3 ppg EMW); displaced well over to SUMMARY new LSND mud and conditioned same; drilled to 8087' and pull out of hole to 7900'; returned to bottom and continued drilling to 8160'; after flow check, drilled to present depth. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY Allen Odegaard • file://C: \Documents%20and%20 S ettings\RigUser\My%20Documents\My%20 Wells\CON... 4/ 12/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~,~{~ 2N-311A REPORT FOR Dave Morris /Scott Lapiene DATE Apr 13, 2007 DEPTH 8747' PRESENT OPERATION Pulling out of hole. TIME 6 am YESTERDAY 8628' 24 HOUR FOOTAGE 119' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8700' 38.51 ° 325.79° 5668.75' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HO URS T/B/C PULLED 2 6 1/8" PDC HCM505Z 7009677 8065' 8747' 682' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 64.1 @ 8693' 22.5 @ 8742' 50.8 49.8 FT/HR SURFACE TORQUE 8 @ 8730' 7 @ 8652' 8.1 8.3 AMPS WEIGHT ON BIT 11 @ 8654' 3 @ 8694' 8.4 8.2 KLBS ROTARY RPM 75 @ 8632' 73 @ 8739' 74.5 74.0 RPM PUMP PRESSURE 235 @ 8732' 57 @ 8691' 117.8 189.3 PSI DRILLING MUD REPORT DEPTH 8747' MW 11.5 VIS 48 PV 17 YP 25 FL 3.4 Gels 10/12/14 CL- 160 FC 2 SOL 14.5 SD Tr OIL 1 MBL 10 pH 9.5 Ca+ 440 CCI MWD SUMMARY INTERVAL TO TOOLS LWD AND DOWNHOLE MOTOR GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 195 @ 8665' 33 @ 8695' 96.9 TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) 30580 @ 8665' 5312 @ 8695' 15134.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 2124 @ 8665' 372 @ 8695' 1058.7 AVG 0 PROPANE (C-3) 1386 @ 8665' 244 @ 8695' 693.7 CURRENT 0 BUTANE (C-4) 514 @ 8665' 89 @ 8695' 255.2 CURRENT BACKGROUND/AVG 9 PENTANE (C-5) 160 @ 8665' 28 @ 8695' 80.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE, SILTSTONE, SAND, SANDSTONE PRESENT LITHOLOGY SHALE 10%, SILTSTONE 20%, SAND 10%, SANDSTONE 60% Drilled to 8747'; pumped sweep and circulated hole clean; pull out of hole to 8272' and backreamed through tight DAILY spot at 8029'; went back to bottom, circulated and started loosing to the forma tion; pumped a low fluid loss, Cal- ACTIVITY Carb pill and spot in the open hole; monitored well - 5 bbl flow back after 10 minutes; pull out of hole, monitoring SUMMARY well on trip tank. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY Allen Odegaard • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 13/2007 • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~,~, 2N-311 A REPORT FOR Dave Morris /Scott Lapiene DATE Apr 14, 2007 DEPTH 8747' PRESENT OPERATION Running Liner in hole. TIME 6 am YESTERDAY 8747' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8747' MW 11.5 VIS 50 PV 16 YP 26 FL 4 Gels 10/14/17 CL- 200 FC 112 SOL 14 SD 1.5 OIL 1 MBL 7.5 pH 9.0 Ca+ 400 CCI MWD SUMMARY INTERVAL TO TOOLS NO TOOLS IN HOLE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG NA PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY NO NEW LITHOLO GY DAILY ACTIVITY Pumped a dry job, pull out of hole and lay down bottom hole assembly; pulled wear ring and set test plug; change SUMMARY out lower pipe rams to 4.5" and tested blow out preventers; pulled test plug and set wear ring; rig up and run 4.5" liner. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY Allen Odegaard ~~ ~J file://C:\Documents%20and%20 S ettings\RigUser\My%20Documents\My%20Wells\CON... 4/ 14/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~ 2N-311A REPORT FOR Dave Morris /Scott Lapiene DATE Apr 15, 2007 DEPTH 8747' PRESENT OPERATION Laying down drill pipe. TIME 6 am YESTERDAY 8747' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 8050' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8747' MW 11.6 VIS 48 PV 13 YP 20 FL 3.8 Gels 7/9/11 CL- 200 FC 1/2 SOL 14 SD 1.5 OIL 1 MBL 10.0 pH 9.8 Ca+ 200 CC1 MWD SUMMARY INTERVAL TO TOOLS NO TOOLS IN HOLE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 224 CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ C URRENT BACKGROUND/AVG 20 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY NO NEW LITHOLOGY Run in hole to 7742'; washed to 8031' and circulated; continued to run in hole to 8697' and rigged up cement head; DAILY tagged bottom at 8753' whil e pumping at 1 bpm; continued circulating while rigging up cement lines and equipment; ACTIVITY tested lines to 4000 psi and pumped 156 bbls of water, cement and mud push; released liner hanger and circulated SUMMARY excess cement out of the hole; pull out of hole laying down drill pipe. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY Allen Odegaard ~~ ~J file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 4/ 15/2007
