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Thank you. • a ~~ _ ~.~, DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2052100 Well Name/No. KUPARUK RIV U TARN 2L-309 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20521-00-00 MD 14963 TVD 5916 Completion Date 2/24/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Su ey Ye~ DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Den/NEU Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D Asc Directional Survey QED D Asc Dir tional Survey 1410~erification } ~t 14107 LIS Verification ''~ 1412 eport: Final Well R Log Log Run Scale Media No I Log ~ 14121 Mud Log 2 Col Log,/ 14121 Mud Log 2 Col Log (/ 14121 See Notes 2 Col I~ Lo / 14121 Se N t 2 C l g e o es o Log ~ 14121 See Notes 2 Col ' Lo ~ 14121 e Notes S 2 C l , g e o ', Log 14121 See Notes 2 Col Log 14121 See Notes 2 Col (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 4303 __ __- __- 14960 --- Open 4/17/2006 --- ---__.--------- 33 9203 Open 4/17/2006 PB 1 4298 5586 Open 8/30/2006 Lis Veri, GR, FET, ROP w/Graphics 4309 9203 Open 8!30/2006 PB1 Lis Veri, GR, FET, NPHI, RHOB, ROP w/Graphics 0 0 9/5/2006 Final Well Report w/Graphics, Mudlogging Equip & Crew, Well Details, Geo Data, Pres/Form Strength Data, ~ Morning Rep, Well Logs 4300 14960 Case 9/5/2006 MD Formation Log 17-Feb- 2006 2377 5916 Case 9/5/2006 TVD Formation Log 17- Feb-2006 4300 14960 Case 9/5/2006 MD Drilling Dynamics 17- Feb-2006 2377 5916 Case 9/5/2006 TVD Drilling Dynamics17- Feb-2006 4300 14960 Case 9/5/2006 MD Combo Log 17-Feb- 2006 2377 5916 Case 9/5/2006 TVD Combo Log 17-Feb- 2006 4300 14960 Case 9/5/2006 MD Gas Ratio 17-Feb-2006 2377 5916 Case 9/5/2006 TVD Gas Ratio 17-Feb- ~ I 2006 ~ DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2052100 Well Name/No. KUPARUK RIV U TARN 2L-309 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20521-00-00 MD 14963 TVD 591 Completion Date 2/24/2006 Comple tion Status 1-OIL Current Status 1-OIL UIC N pt 14122 eport: Final Well R 0 0 9/5/2006 P61 Final Well Report w/Graphics, Mudlogging Equip & Crew, Well Details, Geo Data, ', Pres/Form Strength Data, ', Morning Rep, Well Logs Log ~ 14122 Mud Log 2 Col 985 9203 Case 9/5/2006 P61 MD Formation Log 21- ' ' / Log J 14122 Mud Log 2 Col 985 5667 Case 9/5/2006 Jan-2006 PB1 TVD Formation Log I 21-Jan-2006 Log 14122 See Notes 2 Col 985 9203 Case 9/5/2006 PB1 MD Drilling Dynamics v 21-Jan-2006 Log 14122 See Notes 2 Col 985 5667 Case 9/5/2006 P61 TVD Drilling Dynamics 21-Jan-2006 Log / 14122 See Notes 2 Col 985 9203 Case 9/5/2006 PB1 MD Combo Log 21- ~ Jan-2006 Log 14122 See Notes 2 Col 985 5667 Case 9/5/2006 PB 1 ND Combo Log 21- I Jan-2006 I Log ~ 14122 See Notes 2 Col 985 9203 Case 9/5/2006 PB 1 MD Gas Ratio 21-Jan- 2006 ', Log/ 14122 See Notes 2 Col 985 5667 Case 9/5/2006 PB1 TVD Gas Ratio 21- ~, '~ s T r~ G~w~4~~ -- 5 Blu 1 0 12400 Case 7/3/2007 Jan-2006 Gas Lift Survey, Spin, Temp, Pres, GR, CCL, ' t Grad 21-Jun-2007 Vcctg `y Gas-,{krr~aiy~is '~f wd ~ ~ ~ ~ 1 Blu 1 50 14505 Case 7/25/2007 Gas Lift Survey. Pres, Temp, GR, CCL 7-Jul-2007 ti Induction/Resistivity 25 Col 115 14960 Open 3/24/2008 MD ROP, DGR, CTN, EWR, ALD 18-Feb-2006 og Induction/Resistivity 25 Col 115 5916 Open 3/24/2008 TVD DGR, CTN, EWR, ALD 18-Feb-2006 ~g Induction/Resistivity 25 Col 115 9203 Open 3/24!2008 P61 MD ROP, DGR, ~ EWR, CTN, ALD 24-Jan- 2006 ' Induction/Resistivity 25 Col 115 5667 Open 3/24/2008 P81 TVD DGR EWR C 16050 ~~ e~5 a Notes 0 0 Open 3/24/2008 CTN, ALD 24-Jan-2006 MD and TVD graphics in CGM, EMF and PDF DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2052100 Well Name/No. KUPARUK RIV U TARN 2L-309 Operator CONOCOPHILLIPS ALASKA INC MD 14963 TVD 5916 Completion Date 2/24/2006 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /Y~ Chips Received? '°'9" htd-~ Analysis `7'tiV~ Received? Comments: Compliance Reviewed By: Daily History Received? Formation Tops ~ N Date: API No. 50-103-20521-00-00 UIC N rJ 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 2L-309+PB 1 March 11, 2008 AK-MW-4150952 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2L-309+PB1 2" x 5" MD TC Logs: 1 Color Log 50-103-20521-00 2" x 5" TVD TC Logs: 1 Color Log 50-103-20521-00 2" x S" MD TC PB 1 Logs: 1 Color Log 50-103-20521-00,70 2" x 5" TVD TC PB 1 Logs: 1 Color Log 50-103-20521-00,70 Digital Log Images 1 CD Rom 50-103-20521-00,70 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. An~~~l~s~~s8 ~~-ago ~ ~1~05~ Date: ,~ + ~ ~~ ,~ ~o~,;.,., Si ed: Ci- ~ .. , ~ .~ ;: ,, r ~ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~ Dear Mr. Maunder: Enclosed please find a (revised 10/3/07)spreadsheet with a list of wells from the KuparLilc field (KRU). 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. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, on Arend ConocoPhillips Well Integrity Field Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 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-303 201-239 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 20" 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 18" n/a 18" 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 _. • • ConocoPhillips ~~ 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: • l~c~ oer /VF® A/a~k~ Di18r Ga ®2 ?Op7 gnc~v aFls C~m~ss; o~ ~' ~ d ~O Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. 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) Date Kuparuk Field 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" nla 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 19&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 0~/12l07 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 8 ~ _. ~ ,..-~.w-n ~~UL ~ ~ 2007 d\~~~~ ~1~ <g, ~~S ~fi~il"n. ~Ut119T11Sal()11 ~nchar~~' X05 =a ~ o Log Description N0.4332 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1C-125 (REDO) NIA MEM INJECTION PROFILE 05/05107 1 1E-31 11629042 GLS 07/09/07 1 1 R-20 11839632 LDL 07/06/07 1 3F-19A 11839634 PRODUCTION PROFILE 07/08107 1 2L-309 11839633 GLS 07107107 1 1J-122 11629039 USIT 07/05107 1 2N-342 11629036 FMI 07/04107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 06/28/07 I~ ~~~~~~~ Schlumberger -DCS 2525 Gambelt Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 2L-309 11665452 GLS 06121/07 1 3C-06 11632721 PRODUCTION PROFILE 06/21/07 1 1D-41 11632723 GLS 06/23107 1 N0.4315 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD J U I_. 0 3 20Q7 h3)asS~a Gil Gas Gins. C~tmi ' , ~n~h coos ark Log Description Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Conoc Philli s TRANSMITTAL ~~~I~~~ CONF/DENT/AL DATA S E P 0 ~ 2006 FROM: Sandra D. Lemke, AT01486 TO: Librarian ConocoPhillips Alaska, Inc. AOGCC Alaska t7il ~ Gas Cons. Commission P.O. Box 100360 333 W. 7`h Ave, Suite 100 Anchorage Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2L-309P61, 2L-309 Permit:. 205-210 DATE: 9/5/2006 ae Kuparuk River Unit 2L-309PB1 501032052170 ~ I`,lt%~ 2L-309 501032052100 ~' ~~~/~~I ~~ Hardcopy report and CDROM digital data Epoch -Final well report /Mud Logging Data; 1/27/2006; includes color prints in both MD and TVD for Formation Log; !, Drilling Dynamics; Gas Ratio;Combo Log; CDROM contains Final well report; morning reports; LAS data; DML Data; lithology remarks; ~~ and .pdf format color log image files Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for iyour records. To all data recipients: All data is confidential until State of Alaska desi Hated AOGCC release date CC: Andy A~jndreou,,,CPAI Geologist Receipt: ~ ~,~~------- Date: ~~ ~~ ~. '" (! - .... t~-~ GIS-Technical Data Management ~ ConocoPhillips ~ Anchorage, Alaska ~ Ph: 907.265.6947 Sandra. D. LemkeC~Conocophillips. com • • WELL LOG TRANSMITTAL To: State of Alaska August 21, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2L-309 & 2L-309 PB1, AK-MW-4150952 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20521-00, 70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSNIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 3 ~~ 1 ~. _ 4~~ w:~ ..:~~N Signed: ( y a ~,..- _ 5 - ~ t C5 ~ d ~l ~ 0~~- ConocoPhillips April 13, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2L-309 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2L-309. If you have any questions regarding this matter, please contact me at 265-6830 or Tim Billingsley at 265-6531. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ~ t:,--~ ~ ~ ~~0~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ~4~N0-L'~~'~' "t'mmission 1a. Well Status: Oil a Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: " "`" '' c~ Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: February 24, 2006 12. Permit to Drill Number: 205-210 / 306-030 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 12, 2006 13. API Number: 50-103-20521-00 / 50-103-20521-70 4a. Location of Well (Governmental Section): Surface: 164' FNL, 631' FEL, Sec. 22, T10N, R7E, UM 7. Date TD Reached: February 17, 2006 14. Well Name and Number: 2L-309'/ 2L-309P61 At Top Productive Horizon: 1447' FNL, 977' FEL, Sec. 25, T10N, R7E, UM S. KB Elevation (ft): 34' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1646' FNL, 796' FEL, Sec. 25, T10N, R7E, UM 9. Plug Back Depth (MD + TVD): 14753' MD / 5734' TVD Tarn Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 461019 y- 5927681 • Zone- 4 10. Total Depth (MD + TVD): - 14960' MD / 5916' TVD 16. Property Designation: - ADL 380051/ 380052 / 380053 TPI: x- 471209 y- 5921073 Zone- 4 Total Depth: x- 471389 - 5920874 - Zone- 4 11. Depth where SSSV set: Landing Nipple @ 506' 17. Land Use Permit: ALK 4601 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1200' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 34' 115' 34' 115' 24" 9 cu yds High Early 9-5/8" 40# L-80 34' 4340' 34' 2388' 12.25" 480 sx AS Lite, 340 sx LiteCrete 7" 26# L-80 34' 14364' 34' 4944' 8.5" 170 sx Class G 3.5" 9.2# L-80 14214' 14960' 5283' 5916' 6.75" 140 sx Class G ' kick off plug @ 4124'-4530' MD abandonment plug back @ 8612'-9203' MD 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 14259' 14214' 14504'-14524' MD 5521'-5538' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED kick off plug @ 4124'-4530' 170 sx Class G plug back @ 8612'-9203' 230 sx Class G 26. PRODUCTION TEST Date First Production April 2, 2006 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 4/8/2006 Hours Tested 30 hours Production for Test Period --> OIL-BBL 2905 GAS-MCF 1760 WATER-BBL 50 CHOKE SIZE Not available GAS-OIL RATIO 946 Flow Tubing press. 492 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1927 GAS-MCF 1823 WATER-BBL 40 OIL GRAVITY -API (corr) Not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE Z•_Zy _.J>°'s ~ ~E~~ !~ ~,~__ .o.« ". r . ~., - ` i Form 10-407 Revised 12/2003 s ~ ~, I ~ ~ ~ CONTINUED ON REVERSE /~ ~pr;~~ ~ p~, //~ ' ,.. 28. 29- GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2L-309 T3 14431' 5460' T2 14544' 5555' N/A 2L-309P61 TD 9203' 5667' 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: Tim Billingsley @ 265-6531 Printed N Rand Thomas Title: Greater Kuaaruk Area Drilling Team Leader ~ ((~ ~66 \ Signature -~ Phone - - Date ZC-aS ~ 6$ Sv INSTRUCTIONS Prepared by 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. Item 1a: Classification of Service. wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 2Z: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2L-309 Event Name: ROT -DRILLING Contractor Name: d14cm@conocophillips.com Rig Name: Doyon 14 Date 1 /8/2006 1 /9/2006 1 /10/2006 1 /11 /2006 1/12/2006 From - To ' Hours Code !Code Phase 15:00 - 16:00 1.00 MOVE ~ DMOB MOVE 16:00 - 18:30 ' 2.50 ,MOVE DMOB MOVE 18:30 - 22:00 I 3.50' MOVE ! DMOB MOVE 22:00 - 00:00 '', 2.00', MOVE MOB MOVE 00:00 - 00:00 I. 24.00'': MOVE MOB MOVE 00:00 - 00:00 '; 24.00', MOVE ~I MOB MOVE 00:00 - 03:30 3.50 ~ DRILL I RIRD RIGUP 03:30 - 05:00 ' 1.50 !, DRILL 'RIRD RIGUP 05:00 - 06:00 1.00 !DRILL 'RIRD ~ RIGUP 06:00 - 12:00 ! 6.00 li DRILL RIRD RIGUP 12:00 - 13:00 13:00 - 15:30 15:30 - 18:00 18:00 - 20:30 20:30 - 21:00 21:00 - 22:30 22:30 - 00:00 ', 00:00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 14:30 14:30 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 00:00 1.00 2.50 2.50 2.50 0.50 1.50 1.50 2.50 0.50 0.50 1.50 1.00 1.00 7.50 1.50 2.00 1.00 5.00 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL SFTY RIRD RIRD PULD RIRD PULD PULD PULD SFTY SURFAC :RIGUP RIGUP ,RIGUP 'RIGUP RIGUP 'SURFAC SURFAC (SURFAC 1 /13/2006 ', 00:00 - 16:00 1 /14/2006 16:00 - 17:00 17:00 - 19:00 19:00 - 20:30 20:30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 01:00 01:00 - 00:00 1/15/2006 00:00 - 00:30 00:30 - 03:00 03:00 - 06:30 06:30 - 07:00 07:00 - 08:30 08:30 - 10:30 10:30 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 18:00 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL CIRC DRLG TRIP TRIP DRLG TRIP WIPR TRIP DRLG SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC 16.00 I DRILL DRLG SURFAC 1.00', DRILL 2.001 DRILL 1.50', DRILL 1.50', RIGMNT 0.50' DRILL 1.50' DRILL 1.00; DRILL 23.00 DRILL CIRC TRIP TRIP RSRV TRIP TRIP TRIP DRLG 0.50 DRILL ',DRLG 2.50 DRILL 3.50' DRILL 0.50 DRILL 1.50', DRILL 2.00'.. DRILL 3.00' DRILL 2.00' DRILL 0.501 DRILL 2.00 ~'~ CASE ',CIRC WIPR OTHR -WIPR CIRC ;TRIP TRIP '..PULD IOTHR SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC !SURFAC ',SURFAC SURFAC SURFAC SURFAC 'SURFAC SURFAC ',SURFAC SURFAC Page 1 of 14 Spud Date: 1/12/2006 Start: 1/11/2006 End: 2/24/2006 Rig Release: 2/24/2006 Group: Rig Number: Description of Operations PJSM,Skid floor Move off well Install Boosters wheels ,Moving rig from MP to Tarn Moving rig to Tarn Moving rig to Tarn ', Remove Booster wheels, spot rig over well Repair skid eye on rig jacks Skid rig floor I~ Nipple up Diverter and riser and diverter liner, Rig accepted @ 0600 1 /11 /2006 ' Pre-Spud meeting with crews ,Finish Nipple up,Change out handling Equipment Load pipe shed with 5" pipe and service rig ~i Picking up pipe and standing in derrick Switch over to High line power ~~ Finish picking up 5" pipe Clear rig floor, Picking up BHA 'Picking up 5" HWD pipe, and BHA ', Function test Diverter, the right to witness test was wavier by John 'Crisp AOGGC ', Pjsm, Fill hole with mud, check for leaks Washed out ice plug, washed to 115', Drill to 215' POH, Pick up flex collars, RIH Drilling 215 to 616' Running Gyro every 100 ft . Poh, no trucks Waiting on Trucks, service rig Rih, washed last stand to bottom Drilling 616' to 990' with 65 rpms, 475 Gpm, 1400 psi, P/u 93K, S/o 92K, R/T 92K, Tq 2K, AST 3.2, Art 1.83, Adt 5.03 Drill 990 to 2399' with 60 rpms, 475 Gpm, 1750 psi, Hydrates @ 1046' 'and 1415' no problem mud wt up to 10.2 @ 2399' Circ, three bottoms up with 60 rpms, 500 gpm, 2000 psi ;Pump out hole with full drilling rate Stand back BHA, set motor back to 1.5, check bit 'Slip and cut drilling, Double cut, service top drive ,Run in hole to 704, Calibrate Epoch Rih to 2200' 'wash last stand to bottom, Recalibrate Epoch tools 'Drilling 2399' to 4330' with 550 gpm, 2200 psi, 80 rpms AST 2.84, ART !,15.01 Drill 4330' to 4350' (2388' TVD) with 80 rpms,550 gpm, 2200 psi ~! on-2130 psi off- PU 113k- SO 92k- ROT 100k- Tq on 8.5k- Off 5.5k- !ICirc, three bottoms up with 550 gpm, 2200 psi, 80 rpms Pump out to HWDP with full drilling rate ~ Flow check- Blow down Top Drive ~ RIH- precautionary wash last stand to bottom. Circ. bottoms up 3x- R&R DP 80 rpm- 550 gpm- 1920 psi. I Pump out to HWT w/ full drilling rate. Stand back HWT., LD BHA Clearfloor ~'I RU to run casing Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Page 2 of 14 Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2 L-309 Event Name: ROT -D RILLING Contractor Name: d 14cm@ conocophillips.com Rig Name: Doyon 1 4 Date 'From - To Hours Code ' Sub 'Code j Phase 1, 1/15/2006 ,18:00 - 00:00 6.00 CASE ~ RUNC ~ ',SURFAC 1/16/2006 100:00 - 01:00 1.00 I RUNC CASE 'SURFAC '.01:00 - 02:00 1.00 CASE I CIRC 'SURFAC 02:00 - 02:30 ~ 0.50 CASE i OTHR SURFAC 02:30 - 04:00 1.50 CASE CIRC SURFAC I ~ 04:00 - 06:00 '~, 2.00 ~, 1 CEMENl PUMP i SURFAC II 06:00 - 07:00 I II 1.00 I 1 1 CEMENT DISP SURFAC I 07:00 - 07:30 'i 'I 0.501 CEMENT PULD SURFAC 07:30 - 10:00 ' 2.50 CEMENT RURD ',SURFAC 10:00 - 13:00 ' 3.00 1 WELCTL' NUND 'SURFAC 13:00 - 21:00 ', 8.00 WELCTL, NUND 'SURFAC 21:00 - 22:00 I 22 00 00 00 1.00 2 00 WELCTL' ROPE WELCTL BOPE 'SURFAC SURFAC : - : . ., 1/17/2006 ' 00:00 - 03:00 ', ,' i 3.00 WELCTL,! BOPE ,SURFAC i 03:00 - 04:00 '', 1.00 WELCTLI, EORP SURFAC !I 04:00 - 06:30 2.50 i WELCTL) BOPE :SURFAC 06:30 - 08:00 II t 1.50 ~ WELCTL BOPE SURFAC 08:00 - 08:30 Ii 0.501 WELCTL, BOPE 'SURFAC 08:30 - 09:00 '~ 0.501 DRILL ', RIRD SURFAC i l 09:00 - 11:00 ~ 2.00 DRILL ~, PULD SURFAC i II 11:00 - 14:00 ~'~, 3.00 WELCTL EORP ',SURFAC 1114:00 - 14:30 0.50 WELCT BOPE SURFAC 114:30 - 15:30 I 1.00 WELCT~I BOPE '~! SURFAC I '115:30 - 16:30 1.00 DRILL I PULD ' INTRM1 16:30 - 20:00 I 3.50 ~ DRILL I, PULD ' INTRM1 20:00 - 22:30 22:30 - 00:00 1 2.50 1.50 ~'1 DRILL 1 TRIP RIGMNT RSRV INTRM1 ' INTRM1 1!18/2006 100:00 - 00:30 0.50 I DRILL ',CIRC ' INTRM1 00:30 - 01:30 1.00 C DRILL 1, PULD '' INTRM1 01:30 - 02:30 I 1.00 DRILL CIRC INTRM1 02:30 - 03:00 0.50I~ DRILL I RIRD '' INTRM1 03:00 - 04:00 1.001 CASE I MIT ' INTRM1 04:00 - 04:30 '~ 0.50' DRILL I RIRD ' INTRM1 04:30 - 06:30 ~ 2.00 i DRILL DRLG ' INTRM1 06:30 - 07:30 1.0011 DRILL 'CIRC 'INTRMI 07:30 - 08:00 0.50 i DRILL RIRD 'INTRMI 08:00 - 08:30 0.501 DRILL FIT 'INTRMI Spud Date: 1/12/2006 Start: 1/11/2006 End: 2/24/2006 Rig Release: 2/24/2006 Group: Rig Number: Description of Operations ~~ PJSM- Run 9 5/8" 40# L80 BTC surface casing to 3600' 'Continue run 9 5/8" csg f/ 3600' to 4335' ',Circulate BU ~~, Rig down Franks fill up tool- RU cement head- blow down T.D. ',Circ. & condition mud f/ cement job- reciprocate casing. Hold PJSM w/ all involved in cementing operation. '~, Pump cement- 10 bbls H2O- Test lines to 3500 psi- 40 bbls CW100- '', Drop btm plug- 50 bbls 10.5 ppg Mudpush II-Lead, Mix & pump 375 bbls ASL 10.7 ppg, yield 4.44cf/sx- Tail, 152 bbls "DeepCreet" 12.0 ppg, yield 2.57 cf/sx Displace cement- Pumping w/ rig pump at 10 bpm to catch cmt. Pumping 6 bpm 450 psi- Bump plug w/ 500 psi over final Circ. pressure. :304 bbls pumped. Recovered 25 bbls good cement back. CIP @ 07:00 Bleed pressure- Check floats- OK- Rig down cement head. Back out landing jt- Flush stack, Clear floor ;Nipple down Diverter,Nipple up head test seal to 1000 psi for ten min Nipple up BOPS, Go choke hose spool !Rig up to test Bops, .Testing Bops and manifold, 250 psi low, 3500 psi high, annular '.250-2500 psi, Chasing leaks, the right to witness test was wavier by John Crisp AOGCC Testing Bops and Manifold 250-3500 psi, Annular 250-2500 psi, chasing leaks,change out top rams Change out top 3 1/2" X 6" VBR rams to 5" Rams Con't Testing BOP's - 250 low - 3500 high - 5 mins each test - 5" top rams - IBOP upper /lower -Floor safety valves - Attempt to test blind rams - No test Blow down choke manifold -Choke /Kill lines Rig up to pick up 5" Drill pipe from pipe shed in mouse hole -standing 'back in derrick ,Pick up 45 joints of 5" -stand back in derrick ', Pull Blind rams out -Rams scarred up -PJSM -Change out block rubber on blind rams -Install rams in stack Retest Blind rams 250 low - 3500 high - 5 mins each test -Test good Pull test plug -Install long wear ring - RD testing equipment -Close 'annulus valves -Blow down PJSM -Mobilize BHA to rig floor MU BHA -Bit -Motor -MWD -Nukes -Orient - Up-Load MWD -Nukes -Test MWD - PU DC's - RIH with HWDP -Jars ,RIH with 5" DP 1 x 1 -Fill pipe @ 25 stands ',Cut Drlg line -Service Top drive 'CBU -Level mud out -Out of balance Con't PU 5" Dp from pipe shed 1 x 1 ', Taking weight @ 4210' -CBU Rig up testing equipment to test casg ', Test casg to 3500 psi for 30 mins record on chart -Table top stripping 1 drill with crew ', Rig down test equipment -Blow down lines 'I Wash down from 4210' to 4259' top of float collar -Drill float collar - '~ Shoe tract -Shoe to 4340' - 30' new hole to 4370' Displace mud with new LSND 9.6 ppg mud -Clean hole ECD 10.4 ppg 1 Rig up testing equipment for FIT Perform FIT -Mud weight 9.6 -Surface pressure 810 - MD 4340 - TVD Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2L-309 Event Name: ROT -DRILLING Contractor Name: d14cm@conocophillips.com Rig Name: Doyon 14 Date From - To Hours I Code 1/18/2006 08:00 - 08:30 i 0.50: DRILL 08:30 - 00:00 ~, i 15.501 DRILL 1/19/2006 t 00:00 - 15:00 15.001 DRILL Sub Phase Code !FIT i INTRMI ,DRLG I INTRMI I DRLG 'INTRMI 15:00 - 16:30 I 1.50 DRILL CIRC !, INTRM1 16:30 - 19:30 3.00 DRILL WIPR 'INTRMI 19:30 - 21:00 ' 1.5011 DRILL !..21:00 - 23:00 ! 2.00 III DRILL I ', 23:00 - 00:00 ' I 1.00 I DRILL 4.501 DRILL DRLG CIRC INTRM1 WIPR IIINTRM1 DRLG 1/20/2006 11100:00 - 00:00 'I 24.00 DRILL I DRLG INTRM1 1 1/21/2006 00:00 - 04:30 04:30 - 05:00 05:00 - 07:30 07:30 - 12:30 12:30 - 00:00 0.50 i DRILL I CIRC 2.501 DRILL I CIRC INTRM1 INTRMI ',INTRMI ;INTRMI 5.00 DRILL CIRC ', INTRM1 11.501 DRILL DRLG ' INTRM1 Page 3 of 14 Spud Date: 1/12/2006 Start: 1/11/2006 End: 2/24/2006 Rig Release: 2/24/2006 Group: Rig Number: Description of Operations 2386 = EMW 16.1 ppg Directional Drill from 4370' to 5806' - WOB 10 to 20 -RPM 80 - TO ', on9k -off 7k -GPM 550 - PP on 2400 -off 2200 -PUW 150 -SOW 112 - ROTW 130 -ECD - 11.6 'SPR -Time 17:30 - MD 5242' - TVD 2895' #1 30 spm 390 - 40 spm 420 #2 30 spm 390 - 40 spm 410 2.92 Rotating - 6.04 Slide Directional Drill from 5806' to 6931' - WOB 10 to 20 -RPM 80 - TO on8k -off 8k -GPM 550 - PP on 2780 -off 2480 -PUW 167 -SOW 120 - ROTW 138 -ECD - 11.8 SPR -Time 17:30 - MD 5242' - TVD 2895' #1 30 spm 390 - 40 spm 420 #2 30 spm 390 - 40 spm 410 !CBU4X-GPM 2490-RPM 80-T07-ECD 11.23 Pump out to shoe from 6931' to 4300' -GPM 550 -Tight @ 6145' to ~I 6115' -packing off- Reduce pump to GPM 480 - Con't pump out to 14900' -Pulling 20K with pump increase from 4900' to 4300' -Pump and work through cuttings beds -GPM 480 ~I CBU 4 X -Shakers loaded -Pump Hi-vis sweep -Shakers cleaned up - I GPM 500 -RPM 40 - TO 6 to 7 - ICP 2250 psi /Mud weight 10.1+ / ~I ECD 11.48 - FCP 2100 /Mud weight 9.9 /ECD 11.10 ~I RIH from 4300' to 6836' -Precautionary wash from 6836' to 6931' - ',GPM 550 - PP 2400 -ECD 10.91 '~ SPR -Time 23:00 - MD 6931' - TVD 4266' ~I #1 30 spm 390 - 40 spm 490 ~I #2 30 spm 390 - 40 spm 490 I, Directional Drill from 6931' to 7077 - WOB 10 to 20 -RPM 80 - TO on 110k -off 9k -GPM 550 - PP on 2730 -off 2350 -PUW 170 -SOW 123 - ROTW 143 -ECD - 11.2 3.43 Rotating - 5.88 Slide ';Directional Drill from 7077 to 8625' - WOB 10 to 20 -RPM 80 - TO on 19k -off 20k -GPM 550 - PP on 2510 -off 2440 -PUW 220 -SOW 120 - ROTW 152 -ECD - 10.9 - 13 current gas -Max 68 @ 7740 'Control drill from 8350' to 9000' @ 50' to 60' feet per hour Directional Drill from 8625' to 8809' - WOB 5 to 20 -RPM 80 - TO on 19k -off 20k -GPM 550 - PP on 2570 -off 2350 -PUW 225 -SOW '.125 - ROTW 156 -ECD - 10.73 - (Raising mud weight to 9.8 ppg from "9.6 ppg) Gas data - 8709 626 units - 8741 2830 units - 8748 2930 units ',CBU -Gas incresed from 40 units to 450 units @ 8666' - @ 871 T 600 'units to slow climb to 2000 units -Flow check @ 871 T slight flow - Drilled to 8809' - 2930 units @ 8747 - BG 2300 to 2600 units to 8809' - ', On bottoms up gas background dropped to 600 units j Flow check well -Well flowing -Bring pump back on -Circulate - ~~ Raising weight from 9.8 ppg to 10.0 -Flow check -Well flowing with 1 pumps off -CBU - 1 ppg cut in mud weight on bottoms up I Weight up from 10 ppg to 10.3 ppg - 500 GPM - 2280 psi -RPM 80 I!, Directional Drill from 8809' to 9120' - WOB 5 to 15 -RPM 80 - TO on ~' 15k -off 14k -GPM 450 - PP on 2090 -off 1960 -PUW 210 -SOW 1135 - ROTW 160 -ECD - 11.51 - (Circulate bottoms up after each connection before drilling ahead -maintain ECD at or below 11.6) Gas data - 8850 280 units - 8990 70 units - 8994 150 units - 9089 185 units - 9100 75 units Printed: 4/102006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Page 4 of 14 Legal Well Name: 2L-309 Common Well Name: 2L-309 Spud Date: 1/12/2006 Event Name: ROT -DRILLING Start: 1/11/2006 End: 2/24/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 2/24/2006 Group: Rig Name: Doyon 14 Rig Number: Date From - To ', Hours ' Code 'Code Phase ' Description of Operations 1/22/2006 ', 00:00 - 02:00 2.00 DRILL ~ DRLG 'INTRMI I Directional Drill from 9120' to 9203' - TD 8 1/2" Pilot hole - WOB 5 to 15 02:00 - 04:30 2.50 04:30 - 05:00 ' 0.50 05:00 - 06:00 ' 1.00 06:00 - 08:00 ! 2.00 08:00 - 08:30 ' 0.50 08:30 - 10:30 2.00 110:30 - 13:00 ', 13:00 - 14:00 j VIII 14:00 - 16:00 1,,16:00 - 00:00 I, 1 /23/2006 it 00:00 - 05:00 105:00 - 07:00 I ' 07:00 - 08:00 ~' 08:00 - 00:00 I 1 /24/2006 00:00 - 05:00 05:00 - 08:00 08:00 - 10:30 .10:30 - 11:30 ' 11:30 - 12:00 12:00 - 13:30 II 13:30 - 14:30 ~~,14:30-17:30 1 /25/2006 17:30 - 19:00 'I 19:00 - 20:30 ' 20:30 - 22:00 ', 22:00 - 23:30 ', 23:30 - 00:00 00:00 - 02:00 i; 02:00 - 03:30 ', - RPM 80 - TO on 14k -off 14k -GPM 450 - PP on 2110 -off 1990 - PUW 212 -SOW 140 - ROTW 170 -ECD 11.51 DRILL it CIRC ''INTRMI ',CBU 3 X -RPM 80 - TO 19 - PP 1990 -ECD 11.4 DRILL OBSV INTRM1 '~ Flow check -Well flowing -CBU DRILL CIRC ' INTRM1 ',CBU 1 X -GPM 448 - PP 1980 -RPM 80 - TO 14K -Gas cut mud on ,bottoms up - 4000 units DRILL 'CIRC '', INTRM1 Weight up from 10.4 ppg to 10.7 ppg -Slow pump to 400 GPM - ', Keeping ECD to 11.6 ppg or below DRILL ! OBSV I INTRM1 Flow check 30 mins -Fluid level dropped 4" in 30 mins in bell nipple DRILL CIRC INTRMI CBU 2 X -GPM 398 - PP 1700 -RPM 80 - TO 15K -Max gas on bottoms up 300 units -Circulate additional BU to level out mud 2.50', DRILL , WIPR INTRMI 'Pump out from 9203' to 6839' -Pump at drlg rate GPM 400 - PP 1720 1.00', DRILL , WIPR INTRMI RIH from 6839' to 9203' -Precautionary wash last stand to bottom - ' 'GPM 400 - PP 1750 2.00' DRILL ~ CIRC INTRMI ',CBU 2 X -GPM 280 to 400 - PP 1110 to 1450 -Trip gas max on I 'bottoms up 458 units I 8.00 ! WAITON WOW INTRM1 ~, Circulate -GPM 387 - PP 1450 -RPM 80 - TO 20 to 22 -ECD 11.39 - i ~i POW 240 -SOW 135 - ROTW 170 -Waiting on weather to break 5.00' WAITON WOW INTRM1 !,Circulate -Waiting on weather to break -Phase 2 -GPM 386 - PP 1500 2.00 1.00 16.00 5.00 3.00 2.50 1.00 0.50 1.50 1.00 3.00 'I ~'~ -RPM 78 -TO 20 to 23 -ECD 11.39 -PUW 240 -SOW 135 - ROTW I 170 -Gas BG 40 to 50 units -Lost 250 psi pump pressure DRILL ,TRIP I INTRM1 I Pump out of hole -GPM 182 - PP 450 looking for wash out -Found I, wash out @ 1375' -Wash out 2 feet below tool joint in slip area - II ~ Change out joint TRIP I INTRM1 DRILL ! RIH to TD @ 9203' WAITON WOW ! INTRM1 Circulate -Waiting on weather to break -Phase 3 -GPM 373 - PP 1410 ~ -RPM 80 - TO 18 -ECD 11.57 -PUW 225 -SOW 137 - ROTW 170 - Trip gas 3110 units - BG 50 DRILL CIRC ; INTRM1 '~~ Circulate -Wait on weather to break -Phase 3 -GPM 373 - PP 1410 - RPM 80 - TO 18 -ECD not working -PUW 225 -SOW 137 - ROTW 170 - BG 50 -Lost 90 psi -Flow check DRILL i TRIP INTRM1 Pump out for wash out -GPM 275 - PP 750 -Found wash out @ 3000' i ' I -Changed washed out joint -Wash area 5' below box in slip area , TRIP 'INTRMI DRILL Con't pump out to 4500' -Started packing off @ 6000' Tight hole from i i 4700' to 4500' back ream trough that section -Clean up hole -GPM ', ~I 350 - PP 1300 DRILL ~ CIRC ', INTRM1 'I CBU 2 X to clean up hole before con't pump out to shoe -GPM 400 - I PP 1370 -RPM 60 - TO 5K DRILL TRIP INTRM1 ~, Con't pumping out from 4500' to shoe @ 4300' -GPM 400 - PP 1370 DRILL 'CIRC i INTRM1 ;CBU at shoe -GPM 480 - PP 1810 -RPM 80 - TO 7 -Flow check - ~~ Well static -Pump dry job DRILL 'TRIP ' INTRMI ~, POH from 4300' to BHA @ 742' DRILL ',TRIP INTRMI I BHA -Stand back HWDP -Jars -Collars -PJSM -Pull sources -Down ii load MWD LD -MWD -Motor -Bit 1.50' ABANDN PULD INTRM1 I Clear rig floor -Mobilize tongs -Tubing running equipment to floor , 1.50'; ABANDN TRIP INTRMI ', PJSM -Run 3 1/2" 8 rd tubing 1.50', ABANDN TRIP INTRMI I RIH with tubing to 4350' 1.50 RIGMNT~I RSRV INTRM1 ~I PJSM - Cut drlg line -Service top drive - 0.50IABANDN TRIP I INTRM1 ~ ~I Con't RIH with 3 1/2" tubing to 5830' 2.00 CEMEN TRIP INTRM1 ! Con't RIH with 3.5" cementing string from 5830' to 6100' Break , I circulation -Break Circulation 60 spm 430 psi - Con't RIH to 9197 1.50', ABANDN, CIRC I, INTRMI 'Circulate Bottoms up - 97 spm @ 1030 psi - Recprocate string - no Printed: 4/102006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2L-309 Event Name: ROT -DRILLING Start: 1/11/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 2/24/2006 Rig Name: Doyon 14 Rig Number: Date 1 /25/2006 From - To 'Hours ~I 02:00 - 03:30 ' 1.50 03:30 - 04:00 ' 0.50 04:00 - 04:30 ' 0.50 04:30 - 05:00 ! 0.50 :05:00 - 07:00 ' 2.00 ', 07:00 - 10:00 '', 3.00 1,10:00 - 13:00 ~I, 3.00 ',13:00 - 15:00 I 2.00 I I i I ',15:00 - 18:00 1~ .00 18:00 - 18:30 I 0.50 18:30 - 19:30 1.00 19:30 - 00:00 I 4.50 Phase INTRMI INTRMI I~ INTRM1 11! INTRMI 'INTRMI INTRM1 INTRM1 ',INTRMI I i i 1 INTRM1 INTRM1 INTRMI ~I INTRM1 Code Sub JCode ABANDN CIRC CEMENT~PLUG III it CEMENT DISP ABANDN TRIP ABANDN CIRC ABANDN TRIP ABANDN CIRC ABANDN TRIP ABANDNi TRIP ABANDN PULD ABANDN TRIP ABANDN CIRC 1/26/2006 ~ 00:00 - 00:30 0.501 DRILL CIRC ~ INTRMI 100:30 - 01:00 0.50 DRILL CIRC '~1 INTRMI 101:00 - 01:30 ~I 0.50 DRILL TRIP INTRMI ~ 101:30 - 02:00 0.50' DRILL OBSV INTRMI it 02:00 - 03:30 1.50' DRILL ,TRIP ~, INTRMI 03:30 - 04:00 I~ ~ 0.50!. CEMENT PULD 04:00 - 05:30 ' I 1.50! ABANDN PULD 05:30 - 07:30 I 2.00 ~, ABANDN TRIP 07:30 - 08:30 '~ 1.00' ABANDN CIRC INTRM1 INTRMI INTRMI INTRM1 08:30 - 09:00 I 0.50'1 ABANDN CIRC ! INTRM1 Page 5 of 14 Spud Date: 1/12/2006 End: 2/24/2006 Group: Description of Operations ~, rotary - PU 190 - SO 120 -Trip gas 1325 max 'Give to Schlumberger Pump 5 bbls water ' Test lines to 3500 psi ;Pump 18 bbls water Pump 47.5 bbls 230 sxs 15.8 ppg 1.16 cufUsx Class G Cement :Pump 3 bbls water Give to rig Displace cement with 138 bbls mud - 2 bbls short @ 7.5 BPM 620 psi to 940 psi -Break off cement line -Well static ' POH slowly from 9200' to 8000' -Cement not dropping out string each stand full mud Circ nut plug sweep -Circulate bottoms up 10 bpm 1340 psi - 400 ;strokes past bottoms up cement contaiminated mud to surface -Lost (returns ', Pumping out at 2 to 3 bpm trying to establish circulation -Rotating @ 10 rpm while pulling stands -Pump to shoe @ 4340' -With out returns I~1 Building mud volume 10.8 ppg - 360 bbls in pits ', Pump @ 3 bpm -Rot 40 RPM -Pulling out hole - No returns -Pull additional 6 stands with out pumping Attempt to circulate @ 3754 while 'working pipe -Partial returns -Pull additional 5 stands with out pump to 3287 -Attempt to circulate while working pipe -Partial returns -Pull I stand -Break off top drive -well u-tubing -Make up top drive let well u-tube through fill up line POH from 3288' to 3 1/2" tubing @ 942' -Change out handling ',equipment - LD 3 1/2" tubing 11 Clear rig floor 1, MU 8.5" Clean out assy - MU bit -Bit sub -HWDP -Jars -HWDP - 1 Establish circulation RIH -Break circulation -Circulate bottoms up each time, circulating out contaminated, clabbered mud - 544' 214 gpm @ 230 psi RPM 65 Max ',gas 74 units - 1013' 214 gpm @ 230 psi RPM 70 Max gas 48 units - ~,1483' 214 gpm @ 230 psi Max gas 62 units RPM 70 - 1953' 214 gpm I, @ 230 psi Max gas 26 units RPM 85 - 2423' 290 gpm @ 370 psi Max ~, gas 105 units RPM 85 - 3357 290 gpm @ 420 psi Max gas 115 units RPM 85 - 4294' 425 gpm @ 770 psi Max gas 453 units RPM 85 - 5045' 1~ 425 gpm @ 680 psi RPM 85 Max gas 1420 units - (surface to 2500' ~I thick clabbered contaminated mud -From 2500 to 5045 thick but not clabbered mud) Condition mud - 400 gpm @ 660 psi - 80 RPM - TQ 8 Spot 17 bbl 10.7 ppg Polymer pill @ 5045' - 3 to 5 BPM - PP 160 to 300 - RPM 30 - TQ 5K POH to shoe slowly -From 5045' to 4300' ii Flow check well -Well static -Pump dry job -Blow down Top drive POH from 4300' to BHA @ 544' -Stand back HWDP -Jars -HWDP - LD Bit sub /Bit ', RU tubing handling equipment ~I PU 3.5" tubing cement string RIH with 3.5" cementing string to 4851' ', CBU -GPM 400 - PP 710 - PU 110 - SO 80 - Max trip gas Max 940 ',units Pump Forma Plug with Shlumberger - ';Pump 23 bbls 10.7 ppg polymer pill Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 1/26/2006 108:30-09:00 09:00 - 09:30 09:30 - 11:30 11:30 - 12:00 12:00 - 13:00 13:00 - 14:00 2 L-309 2 L-309 ROT -DRILLING d14cm@conocophillips.com Doyon 14 Hours Code Code ' Phan 0.50 - ~~~ ABANDN CIRC ~ INTRM1 0.50'~ABANDNTRIP 2 OOABANDNCIRC INTRM1 INTRMI . 0.50 ABANDN TRIP INTRM1 ~I 1.00 ABANDN CIRC INTRM1 1.00; CEMENT PLUG INTRM1 14:00 - 15:00 15:00 - 16:00 16:00 - 18:30 18:30 - 20:30 20:30 - 00:00 1 /27/2006 ' 00:00 - 01:00 ~' 01:00 - 03:30 03:30 - 05:00 ', 05:00 - 05:30 'I ~I 05:30 - 11:00 11:00 - 14:00 III 14:00 - 16:00 1 /28/2006 16:00 - 16:30 16:30 - 17:00 '17:00-17:30 '! ;17:30-19:301 19:30 - 21:00 I, ' 21:00 - 22:00 22:00 - 00:00 ~', 00:00 - 02:00 I, 02:00 - 05:30 1.00 1.00 2.50 2.00 3.50 1.00 2.50 ABANDN TRIP INTRM1 ABANDN, CIRC INTRM1 ABANDN TRIP INTRMI DRILL ' RIRD INTRM1 CEMENTSEOT INTRM1 DRILL PULD ' INTRM1 DRILL 1.50' DRILL 0.50' DRILL 5.50 DRILL 3.00; DRILL PULD ! INTRM1 TRIP INTRM1 REAM ' INTRM1 PULD ', INTRM1 REAM IINTRM1 2.00!, DRILL ,CIRC (INTRMI 0.50 DRILL 'TRIP ~INTRM1 0.50 i DRILL ABSV INTRM1 0.501 RIGMNT' RSRV INTRMI 2.00 DRILL TRIP INTRM1 1.501 DRILL 'TRIP INTRMI 1.00 CEMENTTRIP I INTRM1 2.00 CEMENTTRIP INTRM1 2.00 j CEMENTTRIP ' INTRM1 3.50' CEMENl~CIRC ', INTRM1 Start: 1 /11 /2006 Rig Release: 2/24/2006 Rig Number: Page 6 of 14 Spud Date: 1/12/2006 End: 2/24/2006 Group: Description of Operations 17 bbls 10.2 ppg Forma plug :' 3 bbls 10.7 ppg polymer pill i Give to rig -Displace with 70.6 bbls mud - 5.7 bpm @ 400 to 500 psi POH slowly from 4851 to 4200' !.Pump around nut plug sweep -GPM 400 - PP 540 - PU 95 - SO 80 - Con't to circulate to give Forma plug time to set ,RIH from 4200' to 4630' ',CBU @ 4630 -GPM 342 - PP 580 -Max trip gas 320 units PJSM -Give to Schlumberger Pump 5 water Test lines to 3000 psi Pump 17 bbls water - 5 bpm @ 595 Pump 31.7 bbls - 176 sxs 17 ppg Class G -yield 1.01 cuft/sx - 3 bpm @ 513 Pump 3 water - 2.5 bpm @ 300 Give to rig ', Displace with mud - 61.9 bbls - 5 bpm @ 375 -Under displace 3 bbls Displace with 62 bbls mud 5.5 bpm @ 450 psi POH to 4157 -Pump 3 bbls - POH to 3692' 'CBU -Pump nut plug sweep -GPM 400 - PP 450 -Flow check -Pump dry job -Blow down top drive POH from 3692' to 3 1/2" tubing @ 879' -Change handling equipment - ', LD 3 1!2" tubing ;Clear floor - PU Geo-Skid set in place -Pull wear ring -Install test plug - ', RU testing equipment -Open annulus valves -Fill stack Testing BOPs -Annular 250 low 2500 high 5 mins each test -Top pipe rams -Choke manifold - HCR Choke /Kill -Manual Choke /Kill valves - Upper /Lower (BOP -Floor safety valves - Btm rams -Perform Accumulator test -Test Blind rams - 250 low 3500 high 5 mins each test -Chuck Scheve with AOGCC witnessed BOP test RD testing equipment -Close annulus valves -Pull test plug -Install wear ring - Moblize BHA to rig floor MU BHA - MU bit -motor- MWD - Up load MWD - PWD -Surface test - GPM 457 PP 1030 -Test good -RIH Flex DC's - 5" HWDP -Jars - 5" HWDP ~!, RIH from 714' to 3700' Wash from 3700' to 4000' - 40 RPM TO 6 -GPM 381 - PP 1030 psi PU / MU 5" DP from pipe shed -Stand back in derrick 'Wash from 4000' to shoe @ 4340' -GPM 450 - PP 1280 -RPM 40 - 8K -Did not tag up on cement plug - Con't wash from 4340' to 4530' -GPM 380 - PP 1000 -RPM 40 - TQ 8K Circ - W/O Orders from town -Slack off with no pumps -Cement held 10K '',Pump out to shoe Blow down top drive -Flow check well -Weil static Rig service - Lub rig Pump dry job - POH from 4300' to 714' @ BHA Stand back HWDP -Flex DC's -Jars - LD MWD -Motor -Bit Clear floor - RU tubing handling equipment PU 3.5" tubing for setting kick off plug -Change to 5" handling equipment Change out handling equipment -RIH from 1005' to 4530' CBU -GPM 168 to 252 - PP 170 to 230 - PU 105 - SO 85 -Shakers Printed: 4!10!2006 2:38:05 PM ConocoPhillips Alaska Opera#ions Summary Report Page 7 of 14 Legal Well Name: 2L-309 Common Well Name: 2L-309 Spud Date: 1/12/2006 Event Name: ROT -DRILLING Start: 1/11/2006 End: 2/24/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 2/24/2006 Group: Rig Name: Doyon 14 Rig Number: Date From - To Hours ' Code 'Code 'I' Phase ' Description of Operations 1/28/2006 02:00 - 05:30 3.50 CEMENI~CIRC INTRM1 ~i loaded - Circ clean up well before pumping kick off plug -Trip gas 65 units 05:30 - 07:30 'i 2.00', CEMENT PLUG INTRM1 i, Give to Schlumberger -Batch mix 11.3 ppg Mud Push spacer -Cement 07:30 - 08:00 0.501 CEMEN TRIP INTRM1 !08:00 - 09:00 ~ 1.00' CEMENT CIRC ~, INTRM1 109:00 - 10:00 ' 1.00 CEMEN TRIP INTRM1 10:00 - 11:30 ~ RIGMNT~RSRV 1.50 INTRMI 11:30 - 12:30 , 1.00 ~! CEMENTi PULD ~ INTRMI ':12:30 - 14:00 1.50' CEMENT PULD ', INTRM1 ',14:00 - 14:30 II CEMENT RURD 0.501 ' INTRM1 ~I 14:30 - 16:30 '~ 1 2.00 DRILL PULD ', INTRM1 16:30 - 18:00 'I 1.50, DRILL TRIP INTRMI 18:00 - 19:00 ' 1.001 DRILL CIRC INTRM1 19:00 - 19:30 0.50 f WAITON~ CMT INTRM1 19:30 - 21:30 2.00'i WAITON. CMT ' INTRM1 21:30 - 00:00 2.50' WAITONI CMT INTRM1 1/29/2006 ~I~ 00:00 - 03:00 ' 3.00 WAITON'I CMT '~, INTRM1 03:00 - 04:30 1.50 DRILL REAM INTRM1 ~ 04:30 - 05:00 0.50 DRILL i CIRC INTRM1 05:00 - 13:30 I 8.50' WAITONII CMT ~I INTRM1 I 13:30 - 14:00 i 0.50! DRILL 'REAM I INTRM1 14:00 - 15:00 ', 1.00 DRILL 'REAM INTRM1 15:00 - 16:30 ' 1.501 DRILL i DRLG INTRM1 16:30 - 18:00 ', 1.50. DRILL ;CIRC INTRMI :18:00 - 19:00 ~ 1.00' DRILL ,CIRC ' INTRM1 ~' 19:00 - 20:00 ! i i 1.00 RIGMNT RURD ''~ INTRMI 20:00 - 00:00 '', 4.00',, DRILL I DRLG j INTRM1 1/30/2006 ', 00:00 - 02:00 I, 2.00 DRILL ~ DRLG INTRM1 17 ppg plug - Pump 2 bbls water Test lines to 3000 psi Pump 36.7 bbls 11.3 ppg Mud Push -bpm 3.5 @ 360 Pump 30.5 bbls 17 ppg 170 sxs Class G -Yield 1.01 Cement -bpm 4 @ 400 Pump 5 bbls 11.3 ppg Mud Push -bpm @ 300 Give to rig for 56.2 bbls mud -bpm @ 400 -Cut displacement by 4 bbls POH slowly from 4530' to 3963' -Pump 3.5 bbls to displace cmt out string - Con't POH from 3963' to 3700' Circulate nut plug sweep -GPM 400 - PP 510 -Reciprocate string Flow !check -Well static -Pump dry job- Blow down top drive -Choke ,Flow check -Well static -Pump dry job -Blow down top drive -Choke - POH to 3.5" tubing @ 1005' 'Slip cut drlg line -Rig service LD 5" drill pups -Single - C/O 3 1/2" to 5" Handling equipment PJSM - LD 3 1/2" Tubing C/O Handling equipment to 5" -Clear floor of tubing equipment MU BHA -Bit -motor -MWD -Orient same -Surface test MWD -GPM '~, 500 - PP 1200 RIH from 714' to 3700' CBU 1 X -GPM 252 - PP 610 -RPM 50 - TQ 6 -Trip gas 101 units Blow down Top drive -Inspect saver sub PJSM -Change out saver sub Service top drive - Drawworks chain's -Mud pumps WOC - UCA results for 1000 psi compressive strength - 19:47 hrs - ~, Wash from 3700' to 4240' - No firm cement found -GPM 400 - PP 1220 ~ -RPM 40 - TO 6K - 60 units gas while wash down CBU -GPM 400 - PP 1220 -RPM 40 - TO 6K -Sample on bottoms up 90% soft cement 10% siltstone Pull one stand -Blow down top drive -Charge accumulator -Grease ',.electric motors on top drive -Fix drain on drip pan -Change sprokets # ' 2 conveyor -Hook up Geo-span skid to mud manifold -Work on boiler # 3 -Change out quick releases on drawworks - WOC RIH -Tag cement with 10K no pump no rotation @ 4240' -Circulate out ~', thick mud -GPM 450 - PP 1550 -RPM 40 - TO 6 -Mud temp on 'bottoms up 60.8 degrees Dress off cement to 4345' -GPM 500 - PP 1760 -RPM 40 - TO 6 Orient 60L -Time drill from 4345' to 4350 - Con't slide to 4371' Pull into casing -Circulate GPM 500 - PP 1500 -RPM 50 - TO 7 - PUW it 120 -SOW 80 - ROTW 100 -Clean hole ECD 10.6 ', PJSM -Displace well with 9.7 ppg LSND -Pump 30 bbl sweep - 235 bbls LSND -GPM 450 - PP 1100 -RPM 40 - TO 6K ',Clean surface equipment -Flush gun lines -Hole fill lines ~ RIH to 4371' -Directional Drill from 4371' to 4558' - WOB 10 to 20 - RPM 80 - TO on 8.5 -off 7 -GPM 550 - PP on 1850 -off 1670 - PU 123 -SO 70-ROT 90-ECD- 10.98 Directional Drill from 4558' to 4741' - WOB 10 to 20 -RPM 80 - TQ on !8.5-off7-GPM550-PPon1850-off 1670-PU123-S070-ROT Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Page 8 of 14 Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2L-309 Spud Date: 1/12/2006 Event Name: ROT -DRILLING Start: 1/11/2006 End: 2/24/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 2/24/2006 Group: Rig Name: Doyon 14 Rig Number: Date 1 /30/2006 02:00 - 03:00 1.00', DRILL 'CIRC 03:00 - 20:00 ~, 17.00''. DRILL 'DRLG 20:00 - 21:00 1.00 DRILL 'CIRC 21:00 - 23:30 2.50 DRILL I TRIP From - To Hours Code '' Code' Phase Description of Operations. 00:00 - 02:00 2.00' DRILL 'DRLG INTRM1 ~ 90 -ECD - 10.98 - BG 15 units -Connection gas 4462 14, 4556' 100 23:30 - 00:00 ~~ 0.50', DRILL 1/31/2006 00:00 - 01:00 ''~ 1.00'' DRILL 01:00 - 03:00 i 2.00 03:00 - 05:00 2.00 05:00 - 08:00 I 3.00 2/1 /2006 2/2/2006 2/3/2006 08:00 - 11:30 ', 3.50 11:30 - 00:00 '~ 12.50 00:00 - 19:00 ' 19.00 19:00 - 21:00 21:00 - 00:00 ' 00:00 - 04:00 04:00 - 05:30 2.00 3.00 4.00 DRILL DRILL DRILL DRILL DRILL CIRC CIRC TRIP PULD PULD PULD DRLG II units- (Drilled to 4741' hole packing off -Circulate clean up hole) INTRMI 'CBU 2.5 X -Managing high ECD's -GPM 500 - PP 1700 -RPM 80 - TQ 7.5to5-ECD11.93ppg-11.18ppg INTRMI INTRM1 INTRM1 1 NTRM 1 INTRM1 I NTRM 1 I NTRM 1 I NTRM 1 INTRMI INTRM1 DRILL li DRLG INTRM1 DRILL (CIRC 'INTRM1 DRILL TRIP ~~:INTRM1 DRILL 'TRIP 'JNTRM1 1.50; DRILL ;CIRC '' INTRM1 05:30 - 07:00 07:00 - 09:30 09:30 - 10:30 10:30 - 12:30 12:30 - 13:30 13:30 - 16:00 16:00 - 22:00 22:00 - 23:30 23:30 - 00:00 00:00 - 01:00 01:00 - 09:30 09:30 - 10:00 1.50 ~, RIGMNT' RSRV ', INTRM1 2.501, DRILL TRIP ', INTRM1 1.00' DRILL 'CIRC INTRM1 2.00', DRILL ;TRIP INTRM1 1.00' DRILL 'TRIP I~INTRM1 2.50IDRILLTRIP ~INTRM1 6.00'! DRILL ' OTHR INTRM1 1.50'. DRILL ',TRIP INTRM1 0.50! DRILL',CIRC INTRM1 1.00': DRILL ii CIRC INTRM1 8.501 DRILL 'DRLG INTRM1 0.50 ~' RIGMNTi RSRV INTRMI Directional Drill from 4741' to 5585' - WOB 10 to 20 -RPM 80 - TQ on 18.5-off7-GPM550-PPon 1820-off 1670-PU 115-S090-ROT 102 -ECD - 11.38 -Connection gas average 112 units - ;CBU3X-GPM500-PP1650-RPM 80-T05-ECD-10.8 Pump out from 5585' to 4277' @ shoe -Pumping rate 450 - PP 1410 to -1150' -ECD 11.2 -Tight packing off @ 5280', 5090' - No other ;problems CBU -GPM 500 - PP 1650 -RPM 40 - TQ 5 CBU 4 X -GPM 500 - PP 1560 -RPM 40 - TO 5K -Lots Clay balls- ', Well clean -ECD - 10.71 -Flow check -Well static -Pump dry job POH from 4277 to 714' @ BHA ', Stand back 5" HWDP -Jars -Flex dc's -Down load MWD - LD MWD - ' Flush motor -Break bit - LD motor MU BHA - PU Geo Pilot assy - Up Load MWD -Surface test MWD GPM 460 - PP 860 ', PU 15 jts 5" DP from pipe shed - Con't RIH to 5585 Directional Drill -From 5585 to 6530' - WOB 5 to 10 -RPM 150 - TO on 8-off8-GPM550-PPon2200-off 2120-PUW 130-SOW90- ~ ROTW 107 -ECD 11.6 -Rotating hrs 3.63 -Deflected hrs 5.05 hrs - Trip gas 591 units - BG gas avg 45 units Directional Drill from 6530' to 7660' - WOB 5 to 10 -RPM 150 - TO on 10 -off 8 -GPM 550 - PP on 2420 -off 2400 -PUW 130k -SOW 90k - ROTW 113k -ECD 11.6 -Rotating hrs 1.11 -Deflected hrs 12.21 hrs -BG gas avg 60 units ~I Circ three bottoms with 550 gpm, 2310 psi, 150 rpms, tq 6k, shakers clean, no cuttings Pumping out,7660 to 6000' hole tight and packing off, had to pull slow, '~ hole unloading (real fine cuttings), screens blinding off, mud loss over ~~ shakers ,screen down Pumping out,6000' to 4298' hole tight and packing off, had to pull slow, II hole unloading (real fine cuttings), had to back ream bit in to csg balled uP Flow check well, Pump high vis sweep, circ sweep around, 575 gpm, 40 rpms, 2100 psi Ecd 10.6 Slip and cut drill line, service top drive Pumping out of csg 4298' to 1400' with 500 gpm Circ, @ 1400 with 520 gpms 1250 psi, 60 rpms POH, down load MWD Inspect Geo-Pilot,bit Trip in to 4340' Monitor well, wait on New mud from mud plant, inspect drawworks i RIH, no problems wash last stand to bottom Circ. Displace well with new 9.6 mud Dispace well with new 9.6 mud, Ecd after displacement 10.75 with 575 GPM, trip gas 900 units Directional Drill from 7660 to 8223' - WOB 5 to 10 -RPM 150 - TO on ~~ 10 -off 8 -GPM 575 - PP on 2100, ECD 10.7 starting, Rig service Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Page 9 of 14 Legal Well Name: 2L-309 Common Well Name: 2L-309 Spud Date: 1/12/2006 Event Name: ROT -DRILLING Start: 1/11/2006 End: 2/24/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 2/24/2006 Group: Rig Name: Doyon 14 Rig Number: bate From - To 'Hours 2/3/2006 Ii 10:00 - 17:00 I 7.00 II 17:00 - 18:00 1.00 18:00 - 00:00 I 6.00 2/4/2006 2/5/2006 00:00 - 01:00 I 1.00 1.50 4.00 101:00 - 02:30 ' 02:30 - 06:30 ' 06:30 - 08:00 08:00 - 11:30 '11:30-13:00' .13:00 - 13:30 '.13:30 - 18:00 I 18:00 - 20:00 20:00 - 22:00 22:00 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 11:30 11:30 - 12:00 12:00 - 00:00 2/6/2006 00:00 - 02:00 '.02:00 - 04:00 04:00 - 08:00 ' 08:00 - 09:30 !.09:30 - 10:30 ' 10:30 - 00:00 2/7/2006 ' 00:00 - 22:30 1.50 3.50 1.50 0.50 4.50 2.00 2.00 2.00 2.50 0.50 8.50 0.50 12.00 2.00 2.00 4.00 1.50 1.00 13.50 22.50 Code 'Sub ' Code ~' DRILL ~ DRLG DRILL ~ CIRC i DRILL I DRLG I i DRILL DRLG DRILL CIRC DRILL !.TRIP DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL Phase ', Description of Operations INTRMI Directional Drill from 8223' to 8692' - WOB 5 to 10 -RPM 150 - TO on 10 -off 8 -GPM 575 - PP on 2200, Ecd 11.6 INTRMI Circ. 30 bbl high Vis sweep, with 150 rpms, 150 gpm 2150 psi INTRM1 ''Directional Drill from 8692 to 911 T - WOB 5 to 10 -RPM 150 - TO on i 10 -off 8 -GPM 575 - PP on 2370 -off 2275 -PUW 148k- SOW 98K - ROTW 119K- ECD 11.3 starting, ECD now 11.5 -Rotating hrs 3.09 ' Deflected hrs 12.61 hrs -BG gas avg 40 units INTRMI 'Directional Drill from 9117 to 9160' - WOB 5 to 10 -RPM 150 - TO on ' 10 -off 8 -GPM 575 - PP on 2370, Ecd 11.6 INTRM1 'Circ three bottoms up with 150 rpms, 575 gpm, 2370 psi, pump hi-vis ',sweep INTRM1 ', Pumping out with full drilling rate, hole slick for 13 stands, started getting tight and packing off 7800' worked up to 6900' CIRC INTRM1 ',Circ and rotate @ 6900', 150 rpms, circ bottms up, pump sweep ,TRIP INTRM1 'Pumping out to 4340' with 400 gpm CIRC '~ INTRM1 I~ Circ bottoms up from Csg shoe ,TRIP INTRMI ' II Trip out to Ghost Reamer and lay down same. TRIP I INTRM1 Rih, fill pipe ever 20 stands, wash last stand to bottom, Pump hi- vis ' (weight sweep DRLG INTRM1 it Directional Drill from 9160' to 9340' - WOB 5 to 10 -RPM 150 - TO on ~', li 10 -off 8 -GPM 575 - PP 2400 -Starting ECD 11.5, dropped to 11.3 ' ', I I before we had the packoff , REAM ', INTRM1 ~~ Packed off on corm., working and pulled two stands, trying to get Circ., broke pack off @ 9080', circ and reamed to bottom,( lost 27 bbls of mud ~~ total) I DRLG ', INTRM1 Directional Drill from 9340' to 9435' - WOB 5 to 10 -RPM 150 - TQ on ~, 10 -off 8 -GPM 575 - PP on 2470 -off 2470 -PUW 150k- SOW 100K - ', ROTW 120K- ECD 11.5 starting, ECD now 11.4 -Rotating hrs .67 ' ' Deflected hrs 2.93 hrs -BG gas avg 40 units DRILL 'DRLG 'INTRMI I Directional Drill from 9435' to 9666' - WOB 5 to 10 -RPM 150 - TO on ' ', 110-off8-GPM575-PPon2500-Ecds11.6 RIGMNT RSRV ',INTRMI ,Circ and replace discharge seat on mud pump DRILL DRLG INTRM1 'I Directional Drill from 9666' to 10062'- WOB 5 to 10 -RPM 150 -GPM ' ~', 550- PP 2500 psi, ECD 11.8 DRILL ~ CIRC ~ INTRMI II Circ to lower ECDs, starting 11.8, Dropped to 11.6 DRILL DRLG I, INTRMI Directional Drill from 10062' to 10658'- WOB 5 to 10 -RPM 150 - TO I I on 10 -off 8 -GPM 550 - PP 2550 -PUW 158k- SOW 100K - ROTW ~ 1,125K- ECD 11.6 starting, ECD now 11.7 -Rotating hrs 1.72 Deflected ' ~ hrs 15.17 hrs -BG gas avg 50 units DRILL CIRC ', INTRM1 Circ Three bottoms up with 550 gpm, 2550, 150 rpms DRILL I TRIP ~~ INTRM1 Pump out with 500 gpm, 10658 to 9050 with no problems, hole slick DRILL TRIP INTRM1 Back reaming with 500-300 gpm, hole tight and packing off 9050-8490', pull good from 8490 to 8035', lost 100 bbls of mud while fighting packoffs, 9050 to 8490' DRILL I TRIP INTRM1 Rih, wash last stand to bottom DRILL CIRC INTRM1 I Pump Hi-vis pill, circ out I DRILL DRLG INTRM1 Directional Drill from 10658' to 11400' - WOB 5 to 10 -RPM 150 - TQ I on 12 -off 11 -GPM 550 - PP 2800 -PUW 165k- SOW 98K - ROTW 127K- ECD 11.6 -11.7 -Rotating hrs 1.09 Deflected hrs 9.24 hrs -BG gas avg 50 units DRILL DRLG I INTRM1 Directional Drill from 11400' to 12546' - WOB 5 to 10 -RPM 150 - TO !~ on 12 -off 11 -GPM 550 - PP 2800 -PUW 165k- SOW 98K - ROTW 127K- ECD 11.6 -11.7+ -Rotating hrs 1.43 Deflected hrs 14.59 hrs -BG Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2L-309 Event Name: ROT -DRILLING Contractor Name: d14cm@conocophillips.com Rig Name: Doyon 14 Date 2n/2oos From - To ' Hours ' Code 100:00 - 22:30 1'~, 22.50!. DRILL ~~ 22:30 - 00:00 ~~, 1.50', DRILL 100:00 - 01:30 ~ 1.50, DRILL 01:30 - 04:30 li 3.00' DRILL 04:30 - 08:30 4.00', DRILL 1108:30 - 15:30 ICI 7.001 DRILL 15:30 - 18:00 I''1 2.501 DRILL 18:00 - 21:00 I~ 3.00 'i DRILL 21:00 - 00:00 ~, 3.00 i WELCTL I I 'i 2/9/2006 i 00:00 - 13:00 ' 13.00 I WELCTL '113:00-14:00' '14:00-16:30 '' '16:30-18:30' ',18:30-20:30 '.20:30 - 00:00 2/10/2006 ' 00:00 - 02:00 ', 02:00 - 04:00 2/11 /2006 2/12/2006 2/13/2006 04:00 - 00:00 00:00 - 12:30 1.00'', WELC 2.50 ~, DRILL 2.00'', DRILL 2.001 RIGMI 3.50, DRILL 2.00''.. DRILL 2.00 DRILL 20.00' DRILL 12.50' DRILL ', Sub Phase 'Code DRLG INTRMI !CIRC INTRM1 'CIRC INTRMI LTRIP ''INTRMI (TRIP INTRM1 IITRIP (INTRMI TRIP ! INTRM1 TRIP !INTRMI BOPE ! INTRM1 ~BOPE (PULD ,TRIP RSRV ';TRIP 'TRIP REAM DRLG DRLG 12:30 - 15:30 I 3.00 DRILL CIRC 15:30 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 06:30 06:30 - 07:00 07:00 - 19:00 7.00' DRILL 0.50' DRILL 1.00' DRILL 3.00' DRILL 0.50! DRILL 3.00'' DRILL 0.50 ~ DRILL 12.00'' DRILL 'WIPR '.CIRC ''WIPR 'WIPR REAM CIRC CIRC TRIP 19:00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 01:30 01:30 - 02:00 02:00 - 03:30 3.001, DRILL 1.0011 DRILL 1.00 i DRILL 1.501 DRILL 0.50 DRILL 1.50 ~i DRILL TRIP PULD PULD TRIP PULD OTHR NTRM 1 INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 I NTRM 1 INTRMI !~ INTRM1 ,INTRMI '; INTRMI INTRM1 j INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 'INTRMI NTRM 1 ~ INTRMI I NTRM 1 03:30 - 04:30 ' 1.001 CASE I RURD I INTRM1 Page 10 of 14 Spud Date: 1/12/2006 Start: 1/11/2006 End: 2/24/2006 Rig Release: 2/24/2006 Group: Rig Number: Description of Operations ~, gas avg 40 units, reaming ever stand twice to keep Ecd down. ',Circ four bottoms up with 550 gpm, 2800 psi, 150 rpms 'Continue CBU 4x- 550 gpm- 2800 psi-150 rpm ', Flow check- Pump out of hole w/ 400 gpm 80-100 rpm 12546 to 10376 !with no problems Pulling tight & packing off- Pump w/ 120 gpm 400 psi- 100 rpm 60-100 feet per hour from 10,376-10,094' & cleaned up Pump out of hole w/ 300 gpm- 780 psi- 120 rpm 10,094' to 9 5/8" shoe at 4340' with no problems ',Monitor well- Pump out to 2000' w/ 400 gpm- Poh, stand back BHA, lay down MWD and Geo-Pilot, bit ',Clear floor, rig up to test Bops, Test Annular 250-3500 psi, 5 min per test, Testing Bops and manifold 250-3500 psi, 5 min per test, the right to witness test was wavier by John Crisp AOGCC, chasing leaks Testing Bops and manifold 250-3500 psi, 5 min per test, the right to ~I witness test was wavier by John Crisp AOGCC, chasing leaks, upper IBP and lower (BOP, failed (change out) and tested, 12 Manifold valve ~I failed and service and passed, Hcr on kill failed service and passed, Rig down test Equipment,install wear ring, blow down top drive Pickup BHA #11, bit and Geo-Pilot,Mwd and up load, surface test MWD ~I Rih to 4270 I Circ bottoms up, While service rig and cut drilling line ',Rih, fill pipe every 25 stands ~', Continue RIH f/ 10,281 to 12,486' Screw in Top Drive- Wash last stand down- 60' fill f/ 12,486' to 12,546. Circulate hole clean. ~1 Drilling 12546' to 13760' w/ 550 gpm 3000 psi- 150 rpm- 5-10k WOB- ~, 11.5-11.7 ECD- PU 195k, SO 100K, ROT 140K- Tq on 18k off 16k , ', Rotating hrs 1.96 Deflected hrs 11.71 hrs -BG gas avg 80 units, ~~ reaming ever stand twice to keep Ecd down. !,Drilling 13760' to 14,364' (8 1/2" TD) w/ 550 gpm 3000 psi- 150 rpm- 5-10k WOB- 11.5-11.7 ECD- PU208k, SO 112K, ROT 145K- Tq on 20k 'I off 18k ,Rotating hrs 0 Deflected hrs 7.08 hrs -BG gas avg 80 units, ' reaming ever stand twice to keep Ecd down. 'Circ. hole clean w/ 550 gpm 2850 psi- R&R DP w/ 150 rpm- ECD after CBU 11.25 EMW. Back ream & pump out to ? 8,000' w/ 300 gpm- 120 RPM Circ 320 gpm 970 psi ' Rih to 10,000' Continue RIH f/ 10,000' to 14,282' Wash stand down f/ 14,282' to 14,364'- 500 gpm, 120 rpm- 40' fill Circulate hole clean (3X BU )- 500 gpm 2700 psi- 150 rpm Spot 40 bbl "G-Seal" & tube pill at bit. 'Back ream & pump out of hole w/ 320 gpm 1100 psi- 120 rpm (string ', tube pill f/ TD to 14,000', 12000' and 9000', ). to 4340, i Flow check, pump out 4340 to 2,000' with 450 gals per min. Laying down drill pipe from 2000' to 713' Laying down BHA, HWDP,Collars Continue LD BHA 1 Clear rig floor I~ PJSM- Pull wear ring- Install test plug- Change top rams to 7"- Test I same. '1 RU to run 7" casing. Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2L-309 Event Name: ROT -DRILLING Start: 1/11/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 2/24/2006 Rig Name: Doyon 14 Rig Number: Date From - To 2/13/2006 :04:30 - 05:30 05:30 - 00:00 2!14/2006 00:00 - 01:00 01:00 - 02:30 02:30 - 03:00 03:00 - 04:30 04:30 - 05:30 05:30 - 07:00 07:00 - 07:30 I ''' 07:30 - 08:30 j 08:30 - 12:00 ;12:00 - 12:30 ~~ ';12:30 - 13:00 !i !13:00-15:30' 2/15/2006 2/16/2006 15:30 - 16:30 16:30 - 18:00 '~, 18:00 - 20:00 '' 20:00 - 21:00 21:00 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 09:00 09:00 - 09:30 09:30 - 10:30 !, 10:30 - 11:00 11:00 - 13:30 13:30 - 15:00 ' 15:00 - 23:30 23:30 - 00:00 00:00 - 01:30 01:30 - 02:00 02:00 - 17:00 17:00 - 19:00 ' 19:00 - 20:30 20:30 - 23:00 ' Hours ' Code Sub Code 1.001 CASE SFTY 18.50' CASE ~, RUNC 1.00' CASE I RUNC 1.50 i CASE II CIRC 0.50: CASE RURD 1.50 CEMENli CIRC 1.00'' CEMEN i PUMP ', 1.501 CEMEN~f DISP 0.50',, CEMENT PULD 1.00 CEMENI~RURD 3.50~I CEMEN RURD 0.50 I WELCT NUND 0.501 WELCTL EORP 2.50 ~, WELCTL~ EORP 1.00' DRILL ~ PULD 1.50', RIGMNT I , RSRV 2.00! RIGMNT ~RURD 1.001 DRILL RIRD 3.00 DRILL I PULD 3.00' DRILL PULD I 0.50' RIGMNT , RGRP 5.50':, DRILL PULD 0.50' DRILL I RIRD 1.00 I DRILL ~, RIRD 0.50', DRILL I RIRD 2.50'; DRILL 'PULD 1.50 DRILL IOTHR 8.50' DRILL !PULD 0.50 DRILL j CIRC 1.50''; DRILL ', PULD ~ ~ 0.50, i DRILL ~TRIP 15.00'. DRILL PULD 2.00 DRILL ', REAM 1.50! DRILL ,CIRC 2.50' CASE ~, MIT 23:00 - 00:00 ', 1.00!, CEMENTDSHO Page 11 of 14 Spud Date: 1/12/2006 End: 2/24/2006 Group: Phase ' Description of Operations -- -- INTRM1 'PJSM on running 7" casing INTRMI PU float jts.- Baker lock same- Check floats-OK- Run 7" 26# L-80 BTC-M casing. Fill every jt- Break circ. every 25 jts.-CBU at 9 5/8" ;shoe- Continue run casing INTRMI ' Continue to Run 7" 26# L-80 BTC-M Casing to 14307 INTRMI Break circ. slowly- Wash down & tag bottom at 14,364'- CBU w/ 5 bpm, i 750 psi.- Reciprocate pipe w/ up wt 225k, dw, 100k. INTRM1 RD Franks tool- RU cement head. INTRMI 'Circulate 1+ casing volume INTRMI 'Give to Dowell- Pump 5 bbls H2O- Test lines to 3000 psi-OK- Pump 30 bbls CW100- 30 bbls 12.5 ppg Mud Push Spacer- Drop bottom plug- 35 ; bbls(170 sx) 15.8 ppg Class "G" Cement w/ 0.2%D046-0.3% D065-0.35%D167-0.040%6155- Drop top plug & kick out w/ 10 bbls 'H2O. INTRM1 Displace w/ rig pumps- 9.6 ppg mud to 5530 stks (strokes to bump + 1/2 shoe track volume). Did not bump plug. Full returns & reciprocate !throughout job- PU 275k- SO 100k. CIP @ 0700 hrs. INTRM1 'Hold 350 psi f/ 10 min- Bleed off & check floats- OK- RD cement head. INTRMI ,Flush stack- Blow down casing f/ cut off INTRM1 'PJSM- ND BOPE f/ cut- Set slips w/ 200k- Cut & dress 7" casing- NU BOPE. INTRMI ' Con't NU Flow line INTRM1 'Set Pack-off -Test to 4200 psi for 10 mins -Test good INTRM1 'PJSM -Install test plug - C/O Rams to 2 7/8" X 5" -Test Top Rams ', 250 low - 3500 high - 5 mins each test -Recorded on chart -Test good - Pull test plug -install wear ring INTRMI ,Clear rig floor - LD casg equip - LD long bales INTRM1 PJSM -Cut drlg line -Rig service Top drive /blocks /crown INTRM1 ';Change out saver sub -Dies -Bell guide INTRMI RU bales -elevators - I-R rails -Tie off tugger in derrick INTRM1 'PJSM - LD 5" DP from derrick INTRMI ' LD 5" dp from derrick INTRMI ',Change out roughneck spinner motor -service rig INTRMI ~ Con't LD 5" DP from derrick INTRM1 ~ Change out pipe handling equipment from 5" to 4" INTRM1 ' PU 4" DP from pipe shed -Stand back 10 stands INTRM1 'Change out elevators to 3 1/2" INTRM1 ,Make up BHA - Up Load MWD INTRM1 PJSM -Load nuke source -RIH with flex collars -Test MWD INTRM1 ,RIH with 4" HT DP 1X1 from 385' to 9763' -fill every 1000' -Casing '.,..drag -SOW 50K INTRM1 'CBU -GPM 240 - PP 2190 - PUW 140 -SOW 50 - ROTW 92 -RPM 40 - TO 8.5 INTRMI ' Con't PU 4" DP 1 X 1 from 9763' to 10082 -Taking block weight to !move string in hole INTRM1 ', Pull 10 stands from 10082' to 9123' INTRM1 Con't PU 4" DP 1 x 1 from 9123' to 13149 INTRM1 I Wash from 13149 to 14234' -Taking weight cmt stringers -GPM 214 - PP 2660 -RPM 30 - TO 15 INTRMI !CBU -GPM 252 - PP 2870 -RPM 35 - TO 15 INTRMI ', RU testing equipment -Test casg to 3500 psi 30 mins -Record on !chart -Test good - RD testing equipment -Blow down kill line INTRMI ;Drill cmt stringers from 14234' to 14258' -tag hard cemet @ 14258 - Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2L-309 Event Name: ROT -DRILLING Contractor Name: d14cm@conocophillips.com Rig Name: Doyon 14 Date. From - To ~, Hours ' Code ''Code Phase 2/16/2006 23:00 - 00:00 ' 1.00 2/17/2006 100:00 - 00:30 ', 0.50 ~~ 00:30 - 01:00 ' 0.50 ~~ 01:00 - 02:30 !, 1.50 102:30 - 04:30 ', 2.00 ~i, 04:30 - 05:00 '', 0.50 05:00 - 05:30 ~I 0.50 05:30 - 15:30 '~, 10.00 '~ 15:30 - 17:00 'i 1.50 17:00 - 23:30 li 6.50 2!18/2006 23:30 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 07:00 07:00 - 10:30 :10:30 - 11:00 11:00 - 14:30 14:30 - 15:00 .15:00 - 16:30 -16:30 - 17:00 17:00 - 18:00 18:00 - 21:00 21:00 - 23:00 i 23:00 - 00:00 2/19/2006 ,.00:00 - 03:00 03:00 - 05:30 05:30 - 06:30 06:30 - 09:00 09:00 - 09:30 09:30 - 19:00 ':19:00 - 21:00 ' 21:00 - 21:30 21:30 - 22:00 22:00 - 00:00 CEMENTDSHO ',INTRM1 CEMENT DSHO INTRMI DRILL !i DRLG I INTRM1 DRILL !~ CIRC ~ INTRMI DRILL CIRC 'I INTRM1 DRILL ! RIRD '; INTRM1 DRILL I~ FIT 'INTRMI DRILL DRLG I PROD DRILL CIRC PROD DRILL .DRLG i PROD 0.50', DRILL 2.50 ~~ DRILL 1.001 DRILL 0.50'. DRILL 3.00 DRILL 3.50 DRILL 0.50 DRILL 3.50 DRILL 0.50, DRILL 1.50! DRILL 0.50 DRILL 1.00 DRILL 3.00'' DRILL 2.00' DRILL 1.00'. DRILL 3.00; DRILL 2.50!. DRILL 1.00 CASE 2.50 ,CASE 0.501 CASE 9.50', CASE 2.00 0.50 0.50 2.00 CIRC ',PROD CIRC '', PROD TRIP 'PROD OBSV '~, PROD TRIP PROD CIRC 'PROD OBSV ', PROD CIRC ', PROD TRIP I' PROD OBSV I PROD 'TRIP 'PROD OBSV I~ PROD 'TRIP PROD PULD ~IPROD .CIRC II PROD '~, TRIP II PROD PULD (PROD ~I RURD i CMPLTN PULR I CMPLTN ',CIRC I CMPLTN RUNL II CMPLTN CASE :CIRC CMPLTN CASE 'RUNL CMPLTN CASE IOTHR CMPLTN CASE II CIRC CMPLTN Page 12 of 14 Spud Date: 1/12/2006 Start: 1/11/2006 End: 2/24/2006 Rig Release: 2/24/2006 Group: Rig Number: Description of Operations ;Drill plug / cmt to float collar 14277 to Drill float collar cmt to 14283' Con't drill shoe track from 14283' to 14364' -GPM 282 - PP 3600 - 50 - ITO 15 Drill 20' new hole from 14364' to 14384' -GPM 225 - PP ;CBU -GPM 227 - PP 2650 -RPM 50 - TO 14 !'Displace hole with 10 ppg mud -Pump 110 bbl high vis sweep -Pump 510 bbls 10 ppg mud -GPM 250 - PP 2950 LD top single - RU testing equipment -Pump thru choke /kill line Perform FIT to 16 ppg - MD 14364' - TVD 5404 -Mud weight 10.1 ppg - 'Surface pressure 1690 psi = EMW 16 ppg ,Continue drilling f/ 14384' to 14,762'- WOB 3 -RPM - TQ on 15 -off 15 ' -GPM 210 - PP on 2070 -off 1980 - PU 226 - SO 75 -ROT 123 -ECD !11.99-BG ;Circulate bottoms up w/ 200 gpm - pp 2000 psi ', Con't Drill from 14762' to 14960' - WOB 2 -RPM 90 - TO on 16 -off 16 ', -GPM 220 - PP on 2130 -off 2000 - PU 225 - SO 75 -ROT 123 -ECD '',11.78 - BG 35 units -Connection gas 200 units average I CBU -GPM 220 - PP 2020 CBU 3 X -GPM 225 - PP 2000 -Flow check -Slight flow ~, Pump out from 14960' to 14360' -Pump out @ drlg rate 220 gpm - 0 fill 'Ion 7 stand trip out -Did not take proper fill - ~, Monitor well -slight flow -RIH from 14360' to 14960' -Precautionary !,wash last stand to bottom -GPM 220 - PP 2050 ',CBU 3 X -GPM 220 - PP 2000 -Trip gas 324 / 218 - BG 30 ',Slowly increase mud weight to 10.2 +ppg.- 225 gpm 2000 psi.- No ', noticable gains or losses during operation- ECD's 11.9-12.0 ',Monitor well- Still flowing- Monitor f/ 10 more min.- Still flowing slightly. ',Increase mud weight to 10.4+ ppg- Pumping 200 gpm 1850 psi- 70 ~' rpm- ECD's 11.9-12.0- PU 230k- SO-85k. ', Pump out f/ 14,960' to 14300' (64' inside 7" casing) w 190 gpm 1510 ', psi. ,Monitor well f/ 45 min. w/ slight flow- Monitor f/ 45 min- OK POH 10 stds- From 14300 to 13340' -Good fill ',Monitor well while mixing dry job.- Pump dry job POH from 14300' to 5573' ', PU 49 jts of HWDP 1 X 1 - (HWDP will be used for push pipe for liner if needed) -From 5573' to 7231' ',Circulate pipe volume -GPM 200 - PP 1400 -Pump Dry job ', POH from 7231' to BHA @ 389' ', LD BHA -Down load Nukes / MWD -Flush motor -Break bit - LD motor j -Clear rig floor of tools Rig up liner tools - PJSM running liner ', Pick up 3 1/2" liner -Make up Seal bore extension -Hanger - ZXP liner I~ top packer -Make up one stand 4" DP- PU wt 60k- SO 58k I Circulate liner volume -GPM 190 - PP 560 psi ', RIH with liner on 4" DP from 760' to 14,344 - (7" shoe at 14,364). -Fill I every 10 stands going in hole Circ. pipe volume- 140 gpm- PP 1180 - PU 210k- SO 82k -Pump 2 ~ bbls 776 tube ~ RIH with liner from 14344' to 14931' MU plug dropping head to single -Wash down tag up @ 14960' - PU 225 - SO 84 ,CBU -GPM 156 - PP 1450 -Reciprocate 20' strokes while circulating - Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2L-309 Common Well Name: 2L-309 Event Name: ROT -DRILLING Start: 1/11/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 2/24/2006 Rig Name: Doyon 14 Rig Number: Date From - To 2/19/2006 22:00 - 00:00 2/20/2006 100:00 - 01:00 2/21 /2006 2/22/2006 x;01:00-01:30 01:30 - 02:00 i 02:00 - 02:30 '', 02:30 - 03:30 ; 03:30 - 04:00 04:00 - 04:30 ' 04:30 - 05:30 ' 05:30 - 07:00 07:00 - 11:00 11:00 - 11:30 ' 11:30 - 19:30 19:30 - 20:30 ' 20:30 - 21:30 ' 21:30 - 00:00 00:00 - 01:00 01:00 - 01:30 01:30 - 09:30 09:30 - 00:00 ' 00:00 - 15:30 15:30 - 19:30 ' 19:30 - 20:30 20:30 - 00:00 Hours Code Sub Code 2.00 CASE ;,CIRC 1.00 CASE 'CIRC 0.50 I CEMENT PUMP I ' i 0.50', CEMENTDISP i ~I I i Phase Page 13 of 14 Spud Date: 1/12/2006 End: 2/24/2006 Group: Description of Operations CMPLTN Keeping pressure below 1500 as per Baker Rep CMPLTN '...Circulate condition mud /hole -GPM 170 PP 1400 -Reciprocate string ' 20 strokes -GPM @ 170 keeping pressure below 1500 psi as per Baker rep CMPLTN 'Cement Liner -Give to Schlumberger - Pump 5 bbls CW 100 ~, ', Test lines to 4500 psi -Test good ~j ~ Pump 25 bbls CW 100 - 2.8 bpm @ 1030 psi ~', 'Pump 30 bbls Mud Push II -mixed @ 12.5 ppg - 4 bpm @ 1420 psi ~I j Pump 29.4 bbls - 140 sxs Class Gcement -Mixed 15.8 ppg - 4 bpm @ ~ 1400 psi Shut down -Wash up cement line - ', Drop dart kick out with 2 bbls water Give to rig for displacement CMPLTN Diplace with rig 4 to 4.5 bpm - PP 1300 to 1700 psi -Slow rate to 2.5 j bpm @ 1300 psi last 5 bbls pumped -Bump plug with 3200 psi to release slips -Reciprocated liner through out cement job -Set liner on depth last 5 bbls displacement pumped 0.50 CASE I OTHR ',CMPLTN I Holding 3200 psi -Slack off 45K to set hanger -Psi up to 4500 psi to set packer -Bleed off pressure - PU 10K -Rotate to right 20 rounds - 1.00' CASE CIRC 0.50, CASE 'RURD 0.50. DRILL I CIRC 1.00 DRILL j TRIP 1.50' DRILL ~ OTHR 4.00' DRILL ,'TRIP 0.50' DRILL ~ PULD 8.00' DRILL ,PULD I 1.00' DRILL I CIRC 1.00''. CASE ' DEOT 2.50' DRILL CIRC 1.00', DRILL 'CIRC 0.50 j DRILL ' OBSV 8.00 DRILL ,PULD 14.50'' WAITON', WOW 15.501 WAITONI WOW 4.00' DRILL 'PULD release off liner -Pressure up to 1000 psi - PU T pressure dropped off confirming liner is released ',,CMPLTN Circulate cement off top liner -BPM 7.5 - PP 3450 psi -Approximately 6 ', to 8 bbls contaminated cement back - I CMPLTN ' RD cementing lines - LD plug dropping head - LD 2 singles -Stand 1 stand back ',CMPLTN ~j Circulate 1 bottoms up -BPM 8.4 - PP 3190 -Reciprocate string 90 feet CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN PROD PROD PROD PROD PROD PROD 1.00 CMPLTNI RURD i CMPLTN 3.501 CMPLTNI RUNT 'CMPLTN Flow check -Pump dry job - POH 10 stds. ~I Cut drilling line- Service rig POH w/ liner running tool LD & inspect Liner running tool. MU bit, 7" casing scraper, XO's - RIH on 4" DP - 4" HWDP -Tag TOL 114213'-PUW210-S085 CBU -GPM 350 - PP 3740 -RPM 50 - TO 10 III RU testing equipment -Test casing /liner top to 3500 psi -Record on chart for 30 mins -Test good PJSM -Displace well to 8.5ppg Sea water Pump 100 bbls of polymer hi-vis spacer -GPM 318 - PP 2560 I Pump 350 bbls fresh water -GPM 420 - PP 3690 ~~ Pump 40 bbls weighted polymer spacer -GPM 205 - PP 1310 Pump 770 bbls 8.5 ppg Sea water -GPM 420 - PP 3720 ~', Con't Displace with sea water -GPM 381 - PP 3500 -RPM 50 - TO 10 ' Flow check for 30 mins Lay down 4" DP -Total Stands layed down 90 -All 4" HWDP layed ~idown 'Shut down operations -Phase 3 weather conditions 'I Operations shut down -Phase 3 weather conditions ~ Weather conditions down graded to Phase 2 -PJSM LD 4" DP -Lay ,down 4" DP ', Laying down 4" DP Clear rig floor -Pull wear ring - RU Completion 'running tools PJSM - PU /Run 3 1/2" Completion string - 125 joints in hole Printed: 4/10/2006 2:38:05 PM ConocoPhillips Alaska Operations Summary Report. Page 14 of 14 Legal Well Name: 2L-309 Common Well Name: 2L-309 Event Name: ROT -DRILLING Start: 1/11/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 2/24/2006 Rig Name: Doyon 14 Rig Number: Date From - To 'Hours 2/23/2006 00:00 - 11:30 ' 11.50 ~~ 11:30 - 13:00; 1.50 13:00 - 14:00 ' 1.00 i 14:00 - 15:30 ', 1.50 15:30 - 16:30 1.00 16:30 - 20:30 ~ 4.00 I, 20:30 - 21:30 'I ~~~ 21:30 - 23:30 ICI 23:30 - 00:00 2/24/2006 ' 00:00 - 00:30 i ~~ 00:30 - 01:30 01:30 - 02:00 ~!, 02:00 - 03:00 Spud Date: 1/12/2006 End: 2/24/2006 Group: Code :Code Phase Description of Operations CMPLTN RUNT ~'~, CMPLTN ~ Run 3 1/2" completion - CMPLTN SOHO ~, CMPLTN Space out tubing - PUW 138 -SOW 70 -Blow down top drive RIGMNT RSRV CMPLTN i Replace Swivel packing on top drive -Test same CMPLTN i CIRC 'CMPLTN Displace well to inhibited 8.5 ppg sea water -GPM 350 - PP 1810 CMPLTN SOHO ~ CMPLTN MU FMC Tubing hanger -Land tubing - RILDS CMPLTN DEOT 'CMPLTN ~I RU to test tubing -Test tubing /seals to 3500 psi for 30 mins -Record 'I Ion chart -test good -Bleed off tubing pressure to 1500 -Pressure up ', ~I annulus to 3500 psi for 30 mins -record on chart -test good -Bleed off ', tubing pressure -Shear RP valve - RD testing lines - LD landing joint - L ' 'Install TWC -Test TWC to 1000 psi -For 5 mins -test good -Bleed off ~! - BLow down - RD lines -Drain stack CMPLTN! NUND ',CMPLTN PJSM - ND stack -Change out saver sub -Dies -Bell guide on toR ~ drive I CMPLTN CMPLTN: NUND NU Adapter flange /Tree -Test Adapter to 5000 psi for 10 mins -Test ', ' I 'good -Test tree to 5000 psi 10 mins -Test good CMPLTN' FRZP '', CMPLTN .PJSM - RU lines -Test to 3000 -Freeze protect 7" X 3 1/2" and 3 1!2" ~~ 'tubing to 1300 TVD - 46 bbls diesel @ 1.7 bpm 1200 psi 1.00 2.00 0.50 37 bbls diesel 1.3 bpm @ 900 psi -Shut down pressure 700 - RD Little 'Red RURD ~ CMPLTN CMPLTNi 'Blow down lines - RD lines - in cellar I CMPLTN, OTHR CMPLTN ',Install BPV -Secure well -Install all valve handles -Close all valves - 'I ~, ',Suck out cellar -Remove secondary valve from IA annulus -Install all ', ~, ',gauges -Release rig @ 03:00 hrs 0.50 !CMPLTN', FRZP I CMPLTN I Con't freeze protect 7" X 3 1/2" annulus and 3 1/2" tubing to 1300 TVD - 1.7 bpm @ 1200 psi -Shut down pressure 250 1.00 CMPLTN FRZP ~ CMPLTN ' U-tube IA - RU to OA -Test lines to 3000 psi -Freeze protect OA with i 0.50 1.00 Printed: 4/10/2006 2:38:05 PM 2L-309 Well Events Summary i DATE Summary 03/07/06 01:00 PM RAN A MEMORY LOG FOR PERFORATING TIE IN. LOGGING PASSES FROM 14000' TO 14600' CTMD. FP WELL WITH 30 BBLS. DIESEL. IN PROGRESS. 03/08/06 09:00 AM PERFORATED WELL FROM 14504' TO 14524' WITH 2 1/2"-2506 HJ - RDX 6 SHOT PER FOOT GUN. FP WELL WITH 37 BBLS DIESEL. 03/09/06 06:00 AM GAUGED TBG TO 2.71" TO 14672' SLM. IN PROGRESS. 03/10/06 06:00 AM DELAYED START FOR WEATHER. MEASURED BHP @ 14514' RKB: 2895 psi. ATTEMPTED PULL SOV @ 14146' RKB. IN PROGRESS. 03/11/06 06:00 AM WEATHER DELAYED START. SET BTM LATCH DV @ 14146' RKB. MITIA, GOOD. READY FOR FRAC. 03/19/06 07:00 AM PUMP FRACTURE TREATMENT WITH 50# X-LINKED GEL AT 20 BPM. PUMPED A TOTAL OF 171,094# OF 16/20 CERAMIC PROPPANT. FLUSHED JOB TO COMPLETION PLACING 169,648# BEHIND PIPE WITH 10 PPA ON PERFS. PUMP 120 BBLS OF FLUSH WITH 50 BBLS OF DIESEL FOR FREEZE PROTECT 03/27/06 06:00 AM COIL TUBING POST FRAC FILL CLEAN OUT. CLEAN OUT LINER TO 14857' HARD TAG WITH 2-1/4"JET NOZZLE DIESEL GEL SWEEPS. ONE TO ONE RETURNS THROUGHOUT JOB. FREEZE PROTECT WELL WITH DIESEL TO 2500'+ TVD. OTIS CAP REPACED ON TREE... 03/28/06 06:00 AM TAGGED @ 14753' WLM, EST. 229' RATHOLE. PULLED DV @ 14146' RKB. LRS DISPLACED IA WITH DSL TO CLEAN UP. IN PROGRESS. 03/29/06 06:00 AM SET 5/16" PORT OV @ 14146' RKB. . Halliburton Company, Global Report Comp:u~~: ConocoPhillips Alaska Inc. Field: Kupanik River Unit Uarc: 3/23/2006 Dime: 15:1332 Page: Co-ordinate(\t.) 12cCcrcncc: Well: 2L-309. True North site: Kuparuk 2L Pad ~"ertical (I~ I)) Ilefe rcncc 2L-309: 151 ~1 1Fcll: 2L-309 Section (~~5~ ItcFerc ucc Well (O.OON.O.OOE,135.93Azi) ~~ ctlp:uh: 2L-309 Sune~~ ('alcularinn ~Iethnd: Minimum Curvatu re Uh: Oracie Survey: Start Date: Company: Engineer: Tool: Tied-to: 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: bggm2005 Site: Kuparuk 2L Pad Site Position: Northing: 5927695.13 ft Latitude: 70 12 48.272 N From: Map Easting: 461077.91 ft Longitude: 150 18 50.048 W Position Uncertainty: 0.00 ft North Reference: True Ground Level 0.00 ft Grid Convergen ce: -0.30 deg We1L• 2L-309 Slot Name: Well Position: +N/-S -13.97 ft Northing: 5927681.46 ft • Latitude: 70 12 48.135 N +E/-W -58.37 ft 'Position Uncertainty: 0.00 ft Easting : 461019.47 ft ~ Longitude: 150 18 _ 51.743 W Wellpath: 2L-309 Drilled From: 2L-309PB1 501032052100 Tie-on Depth: 4303.49 ft Current Datum: 2L-309: Height 151.08 ft Above System Datum: Mean Sea Level Magnetic Data: 1/8/2006 Declination: 23.78 deg Field Strength: 57524 nT Mag Dip Angle: 80.64 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.78 0.00 0.00 135.93 Survey Program for Definitive Wellpath Date: 3/23/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 115.00 441.00 2L-309P61 gyro (115.00-441.00) CB-GYRO-SS Camera based gyro single shot 477.26 4303.49 2L-309PB1 (477.26-9165. 90) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4345.00 14922.05 2L-309 (4345.00-14922.05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~lD lncl ,~zim 71U S ~s'I'~~U 1/S H;n~' flapA' ~7apl', 7~onl ft deg deg ft ft ft ft ft ft 35.78 0.00 0.00 35.78 -115.30 0.00 0.00 5927681.46 461019.47 TIE LINE 115.00 0.57 131.39 115.00 -36.08 -0.26 0.30 5927681.20 461019.76 CB-GYRO-SS 172.00 1.17 133.03 171.99 20.91 -0.85 0.93 5927680.61 461020.40 CB-GYRO-SS 262.00 1.22 137.41 261.97 110.89 -2.18 2.25 5927679.27 461021.71 CB-GYRO-SS 353.00 1.90 121.46 352.94 201.86 -3.68 4.20 5927677.76 461023.65 CB-GYRO-SS 441.00 3.05 104.62 440.86 289.78 -5.03 7.71 5927676.39. 461027.15 CB-GYRO-SS 477.26 3.76. 105.68 477.05 325.97 -5.60 9.78 5927675.81 461029.22 MWD+IFR-AK-CAZ-SC 567.56 6.22 104.71 567.00 415.92 -7.64 17.37 5927673.73 461036.80 MWD+IFR-AK-CAZ-SC 658.80 10.60 102.75 657.24 506.16 -10.75 30.34 5927670.56 461049.75 MWD+IFR-AK-CAZ-SC 752.28 10.98 108.76 749.07 597.99 -15.51 47.16. 5927665.71 461066.54 MWD+IFR-AK-CAZ-SC 845.49 15.53 106..25 839.77 688.69 -21.86 67.55 5927659.26 461086.90 MWD+IFR-AK-CAZ-SC 939.39 19.63 104.60 929.27 778.19 -29.35 94.89 5927651.62 461114.20 MWD+IFR-AK-CAZ-SC 1033.45 21.47. 104.46 1.017.34 866.26 -37.64 126.86 5927643.17 461146.12 MWD+IFR-AK-CAZ-SC 1127.48 25.46 103.01 1103.58 952.50 -46.49 163.23 5927634.14 461182.44 MWD+IFR-AK-CAZ-SC 1222.20 26.89 103.14 1188.58 1037.50 -55.94 203.92 5927624.47 461223.08 MWD+IFR-AK-CAZ-SC 1315.99 31.96 103.36 1270.25 1119.17 -66.50 248.76 5927643.68 461267.86 MWD+IFR-AK-CAZ-SC 1397.68 35.34 .103.27 1338.24 1187.16 -76.93 292.80 5927603.03 461311.84 MWD+IFR-AK-CAZ-SC • Halliburton Company Global Report Cumpan.: ConocoPhillipsAlaska Inc. Darc: 3/23/2006 7imc: 15:13'32 Pa;;c 2 I~icld: Ku paruk River U nit Cu-or Jinatc(\1~) Kc frrcnce: W ell: 2L-309.. True North tiitc: Ku paruk 2L Pad ~crtic al I~f~~Dl Kcfc rcncr. 2L -309 _ 151.1 «'rll: 2L -309 ticctiu n 1~'S) ltcfcre ncc: W ell (O.OON,O OOE, 135.93Azi) 11'cllpath: 2L -309 tiurce c Calcul,3tion ~lcthnd: Mi nimum Curvature Dh: Orade __ Sung ~~11) Incl ~zin~ 1~1U ticsl~'I) ~ \iS f.~1' ~la~iA ~lahh: l'nol ft deg deg ft ft ft ft ft ft 1493.33 39.53 106.37 1414.18 1263.10 -91.86 348.96 5927587.81 461367.92 MWD+IFR-AK-CAZ-SC 1587.90 47.93 105.69 1482.45 1331.37 -109.87 411.74 5927569.48 461430.60 MWD+IFR-AK-CAZ-SC 1682.68 50.28 105.58 1544.50 .1393.42 -129.18 480.73 5927549.82 461499.48 MWD+IFR-AK-CAZ-SC 1778.52 54.21 106.33 1603.17 1.452.09 -150.01 553.57 5927528.61 461572.20 MWD+IFR-AK-CAZ-SC 1869.69 57.85 106.17 1654.10 1503.02 -171.17 626.15 5927507.08 461644.66 MWD+IFR-AK-CAZ-SC 1963.02 60.32 106.83 1702.05 1550.97 -193.91 702.91 5927483.94 461721.30 MWD+IFR-AK-CAZ-SC 2059.85 62.44 106.34 1748.43 1597.35 -218.17 784.37 5927459.27 461.802.63 MWD+IFR-AK-CAZ-SC 2151.12 66.42 107.18 1787.82 1636.74 -241.91 863.18 5927435.12 461881.31 MWD+IFR-AK-CAZ-SC 2249.08 72.26 104.27 1822.37 1671.29 -266.70 951.38 5927409.88 461969.36 MWD+IFR-AK-CAZ-SC 2345.52 74.05 103.64 1850.32 1699.24 -288.95 1040.95 5927387.16 462058.81 MWD+IFR-AK-CAZ-SC 2447.33 74.06 103.25 1878.28 1727.20 -311.71 1136.16 5927363.91 462153.89 MWD+IFR-AK-CAZ-SC 2529.06 73.99 102.97 1900.78 1749.70 -329.54 1212.69 5927345.70. 462230.32 MWD+IFR-AK-CAZ-SC 2630.53 73.89 102.98 1928.85 1777.77 -351.43 1307.71 5927323.32 462325.22 MWD+IFR-AK-CAZ-SC 2726.40 72.84 106.59 1956.30 1805.22 -374.86 .1396.51 5927299.43 462413.89 MWD+IFR-AK-CAZ-SC 2820.34 73.51 105.74 1983.49 1832.41 -399.89 1482.87 5927273.96 462500.11 MWD+IFR-AK-CAZ-SC 2913.01 73.90 104.91 2009.50 1858.42 -423.40 1568.65 5927250.01 462585.76 MWD+IFR-AK-CAZ-SC 3007.74 75.12 103.86 2034.79 1883.71.. -446.08. . 1657.08 5927226.88 462674.06 MWD+IFR-AK-CAZ-SC 3101.97 74.97 105.10 2059.11 1908.03 -468.84 1745.22 5927203.66 462762.08 MWD+IFR-AK-CAZ-SC 3185.18 75.52 105.82 2080.31 1929.23 -490.29 1822.78 5927181.82 462839.51 MWD+IFR-AK-CAZ-SC 3286.82 75.17 106.01 2106.02 1954.94 -517.25 1917.34 5927154.37 462933.93 MWD+IFR-AK-CAZ-SC 3378.69 75.32 105.01 2129.42 1978.34 -541.01 2002.94 5927130.17 463019.40 MWD+IFR-AK-CAZ-SC 3474.86 74.72 103.49 2154.28 2003.20 -563.88 2092.98 59271.06.84 463109.31 MWD+IFR-AK-CAZ-SC. 3568.59 74.70 103.88 2179.00 2027.92 -585.27 2180.83 5927085.00 463197.03 MWD+IFR-AK-CAZ-SC 3661.05 73.16 103.82 2204.59 2053.51 -606.53 2267.09 5927063.29 463283.18 MWD+IFR-AK-CAZ-SC 3753.31 73.75 103.54 2230.86 2079.78 -627.45 2353.02 5927041.93 463368.99 MWD+IFR-AK-CAZ-SC 3846.81 73.95 103.63 2256.87 2105.79 -648.55 2440.32 5927020.39 463456.17 MWD+IFR-AK-CAZ-SC 3941.22 73.33 105.40 2283.46 2132:38 -671.25 2528.01 5926997.24 463543.73 MWD+IFR-AK-CAZ-SC 4036:65 72.80 106.11 2311.26 2160.18 -696.03 2615.87 5926972.00 463631.46 MWD+IFR-AK-CAZ-SC 4131.06 76.02 106.26 2336.63 2185.55 -721.38 2703.19 5926946.21 463718.64 MWD+IFR-AK-CAZ-SC 4226.57 76.29 106.07 2359.49 2208.41 -747.20 2792.26 5926919.93 463807.56 MWD+IFR-AK-CAZ-SC 4303.49 76.57 104.99 2377.53 2226.45 -767.22 2864.30 5926899.54 463879.49 MWD+IFR-AK-CAZ-SC 4345.00 76.16 106.65 2387.32 2236.24 -778.21 2903.11 5926888.35 463918.24 MWD+IFR-AK-CAZ-SC 4430.65 77.13 107.28 2407.10 2256.02 -802.53 2982.82 5926863.62 463997.81 MWD+IFR-AK-CAZ-SC 4518.92 76.21 107.04 2427.45 2276.37 -827.87 3064.89 5926837.86 464079.74 MWD+IFR-AK-CAZ-SC 4612.08 75.33 106.59 2450,35 2299.27 -853.99 3151.33 5926811.29 464166.04 MWD+IFR-AK-CAZ-SC 4709.89 74.62 104.16 2475.71. 2324.63 -879.04 3242.40 5926785.78 464256.97 MWD+IFR-AK-CAZ-SC 4803.07 74.16 104.37 2500.79 2349.71 -901.15 3329.38 5926763.22 464343.82 MWD+IFR-AK-CAZ-SC 4896.89 74.33 104.02 2526.26 2375.18 -923.30 3416.92 5926740.63 464431.24 MWD+IFR-AK-CAZ-SC 4990.76 73.69 104.09 2552.12 2401.04 -945.21 3504.45 5926718.26 464518.65 MWD+IFR-AK-CAZ-SC 5086.48 73.95 104.30 2578.79 2427.71 -967.75 3593.57 5926695.26 464607.65 MWD+IFR-AK-CAZ-SC 5178.27 73.56 104.09 2604.47 2453.39 -989.36 3679.01 5926673.21 464692.96 MWD+IFR-AK-CAZ-SC 5271.54 73.23 103.68 2631.13 2480.05 -1010.81 3765.78 5926651.32 464779.61 MWD+IFR-AK-CAZ-SC 5365.92 73.04 104.33 2658.51 2507.43 -1032.67 3853.41 5926629.01 464867.12 MWD+IFR-AK-CAZ-SC 5459.79 73.51. 106.55 2685.52 2534.44 -1056.60 3940.06 5926604.63 464953.63 MWD+IFR-AK-CAZ-SC 5550.68 72.57 105.67 2712.04 2560.96 -1080.73 4023.58 5926580.08 465037.02 MWD+IFR-AK-CAZ-SC 5653.80 72.92 108.08 2742.63 2591.55 -1109.31 4117.81 5926551.01 465131.09 MWD+IFR-AK-CAZ-SC 5747.61 73.10 110.44 2770.04 2618.96 -1138.91 4202.50 5926520.99 465215.62 . MWD+IFR-AK-CAZ-SC 5838.31 72.79 111.29 2796.65 2645.57 -1169.79 4283.52 5926489.69 465296.47 MWD+IFR-AK-CAZ-SC 5935.88 73.42 114.17 2825.01 2673.93 -1205.86 4369.62 5926453.18 465382.37 MWD+IFR-AK-CAZ-SC 6027.26 74.40 114.89 2850.33 2699.25 -1242.31 4449.49 5926416.31 465462.05 MWD+IFR-AK-CAZ-SC 6121.26 75.28 113.94 2874.92 2723.84 -1279.81 4532.10 5926378.39 465544.46 MWD+IFR-AK-CAZ-SC 6214.19 75.61 115.64 2898.27 2747.19 -1317.53 4613.76 5926340.26 465625.91 MWD+IFR-AK-CAZ-SC 6306.60 75.03 116.13 2921.69 2770.61 -1356.55 4694.18 5926300.83 465706.13 MWD+lFR AK-CAZ-SC Halliburton Company Global- Report ('ompan~: ConocoPhi~lips Alaska Inc. I)atc: 3/23/20D6 "time: 15:13'32 I'aic: 3 I~icld: Ku paruk River U nit ('o-ord inate(\I?) Itc ference: Well: 2L-309. True North Sic: Ku paruk 2L Pad Vcrtict ~l (~I~U) Rcic rcncc: 2L -309:151.1 ~~cll: 2L -309 ccclio n (~'SI Itcfcrc ncc: W ell (O.OON,O.OOE135-93Azi) ~~cll~~ath: 2L -309 Sun~eF (calculation ~~Icrhod: Mi nimum Curvatu re Db: Oracle tiunce ~I1) Incl ,~zim ~1~1U Sttil~U \S H:;~V ~{;~~~A' ~IapE fool ft deg deg ft ft ft ft ft ft 6400.75 74.71 117.05 2946.26 2795.18 -1397.23 4775.46 5926259.73 465787.18 MWD+IFR-AK-CAZ-SC 6495.60 74.58 116.41 2971.38 2820.30 -1438.37 4857.15 5926218.17 465868.65 MWD+IFR-AK-CAZ-SC 6593.77 73.99 116.34 2997.97 2846.89 -1480.35 4941.81 5926175.76 465953.08 MWD+IFR-AK-CAZ-SC 6687.81 73.42 117.38 3024.36 2873.28 -1521.13 5022.33 5926134.57 466033.39 MWD+IFR-AK-CAZ-SC 6781.32 73.49 118.39 3050.99 2899.91 -1563.06 5101.56 5926092.24 466112.39 MWD+IFR-AK-CAZ-SC 6874.51 73.54 120.19 3077.43 2926.35 -1606.77 5179.49 5926048.13 466190.09 MWD+IFR-AK-CAZ-SC 6969.92 73.74 121.52 3104:31 2953.23 -1653.72 5258.08 5926000.78 466268.43 MWD+IFR-AK-CAZ-SC 7063.09 74.06 122.68 3130.15 2979.07 -1701.29 .5333.91 5925952.82 466344.00 MWD+IFR-AK-CAZ-SC 7156.99 74.06 124.32 3155.94 3004.86 -1751.12 5409.20 5925902.61 466419.02 MWD+IFR-AK-CAZ-SC 7250.68 73.96 125.40 3181.74 3030.66 -1802.60 5483.10 5925850.75 466492.65 MWD+IFR-AK-CAZ-SC 7345.04 74.38 126.75 3207.49 3056.41 -1856.06 5556.47 5925796.93 466565.74 MWD+IFR-AK-CAZ-SC 7438.67 74.00 128.22 3233.00 3081.92 -1910.88 5627.95 5925741.74 466636.93 MWD+IFR-AK-CAZ-SC 7533.83 73.94 129.26 3259.27 3108.19 -1968.11 5699.29 5925684.15 466707,96 MWD+IFR-AK-CAZ-SC 7627.17 74.58 131.16 3284.60 3133.52 -2026.11 5767.90 5925625.80 466776.26 MWD+IFR-AK-CAZ-SC 7722.10 74.18 131.75 3310.16 3159.08 -2086.63 5836.41 5925564.93 466844.46 MWD+IFR-AK-CAZ-SC 7817.20 74.01. 131,28 3336.22 3185.14 -2147.55 5904.63 5925503.67 466912.36 MWD+IFR-AK-CAZ-SC 7911.24 73.61 131.50 3362.44 3211.36 -2207.56 5972.12 5925443.32 466979.53 MWD+IFR-AK-CAZ-SC 8006.66 74.71 132.39 3388.48 3237.40 -2268.92 6040.40 5925381.61 467047,48 MWD+IFR-AK-CAZ-SC 8097.52 75.09 131.65 3412.15 3261.07 -2327.64 6105.57 5925322.56 467112.34 MWD+IFR-AK-CAZ-SC 8187.51 74.51 131.41 3435.75 3284.67 -2385.21 6170.58 5925264.66 467177.05 MWD+IFR-AK-CAZ-SC 8283.15 74.52 131.91 3461.28 3310.20 -2446.48 6239.44 5925203.04 467245.58 MWD+IFR-AK-CAZ-SC 8376.54 74.44 132.87 3486.27 3335.19 -2507.14 6305.90 5925142.04 467311.72 MWD+IFR-AK-CAZ-SC 8470.97 73.88 133.99 3512.05 3360.97 -2569.59 6371.87 5925079.26 467377,36 MWD+IFR-AK-CAZ-SC 8568.74 73.88 136.53 3539.20 3388.12 -2636.30 6437.98 5925012.22. 467443.12 MWD+IFR-AK-CAZ-SC 8657.02 74.26 136.60 3563.43 3412.35 -2697.95 6496.34 5924950.28 467501.16 MWD+IFR-AK-CAZ-SC 8750.07 73.95 137.56 3588.91 3437.83 -2763.48 6557.28 5924884.44 467561.75 MWD+IFR-AK-CAZ-SC 8848.13 74.66 137.93 3615.44 3464.36 -2833.35 6620.76 5924814.24 467624.87 MWD+IFR-AK-CAZ-SC 8943.49 74.52 136.92 3640.78 3489.70 -2901.05 6682.96 5924746.23 467686.70 MWD+IFR-AK-CAZ-SC 9036.93 ..74.51 137.54 3665.73 3514.65 -2967.15 6744.10 5924679.82 467747.50 MWD+IFR-AK-CAZ-SC 9129.26 74.97. 136.83 3690.03 3538.95 -3032.49 6804.64 5924614.18 467807.70 MWD+IFR-AK-CAZ-SC 9211.63 74.59 137.05 3711.65 3560.57 -3090.57 6858.91 5924555.83 467861.66 MWD+IFR-AK-CAZ-SC 9309.80 74.20 137.30 3738.06 3586.98 -3159.91 6923.18 5924486.16 467925.57 MWD+IFR-AK-CAZ-SC 9401.29 74.78 137.02 3762.53 3611.45 -3224.55 6983.13 5924421.22 467985.17 MWD+IFR-AK-CAZ-SC 9499.18 74.72. 135.69 3788.27 3637.19 -3292.89 7048.31 5924352.55 468049.99 MWD+IFR-AK-CAZ-SC 9593.40 74.53 134.57 3813.26. 3662.18 -3357.28. 7112.40 5924287.84 468113.74. MWD+IFR-AK-CAZ-SC 9688.47 74.71 134.76 3838.47 3687.39 -3421.72 7177.59 5924223.07 468178.60 MWD+IFR-AK-CAZ-SC 9781.21 74.75 133.35 3862.90 3711.82 -3483.92 7241.89 5924160.54 468242.56 MWD+IFR-AK-CAZ-SC 9872.64 73.15 134.40 3888.17 3737.09 -3544.82 7305.23 5924099.33 468305.58 MWD+IFR-AK-CAZ-SC 9966.28 71.66 134.27 3916.48 3765.40 -3607.19 7369.07 5924036.63 468369.09 MWD+IFR-AK-CAZ-SC 10055.41 73.12 135.60 3943.45 3792,37 -3667.20 7429.20 5923976.32 468428.91 MWD+IFR-AK-CAZ-SC 10154.62 75.74 136.09 3970.07 3818.99 -3735.76 7495.77 5923907.42 468495.11 MWD+IFR-AK-CAZ-SC 10245.64 76.30 136.33 3992.06 3840,98 -3799.52 7556.89 5923843.35 468555.90 MWD+IFR-AK-CAZ-SC 10337.38 76.48 135.73 4013.65 3862.57 -3863.69 7618.79 5923778.87 468617.47 MWD+IFR-AK-CAZ-SC 10436.79 75.92 135.42 4037.36 3886.28 -3932.64 7686.37 5923709.58 468684.68 MWD+IFR-AK-CAZ-SC 10532.53 75.09 135.24 4061.33 3910.25 -3998.56 7751.53 5923643.33 468749.49 MWD+IFR-AK-CAZ-SC 10627.13 74.77 135.59 4085.92 3934,84 -4063.61 7815.65 5923577.95 468813.27 MWD+IFR-AK-CAZ-SC 10721.63 74.19 136.09 4111.21 3960.13 -4128.93 7879.09 5923512.31 468876.36 MWD+IFR-AK-CAZ-SC 10811.83 73.94 135.90 4135.97 3984.89 -4191.32 7939.34 5923449.62 468936.29 MWD+IFR-AK-CAZ-SC. 10910.43 73.50 136.18 4163.61 4012.53 -4259.45 8005.04 5923381.16 469001.63 MWD+IFR-AK-CAZ-SC 11006.40 73.61 136.45 4190.78 4039.70 -4326.01 8068.62 5923314.28 469064.85 MWD+IFR-AK-CAZ-SC 11099.27 74.27 136.16 4216.47 4065.39 -4390.54 8130.27 5923249.44 469126.17 MWD+IFR-AK-CAZ-SC 11191.94 74.71 136.44 4241.25 4090,17 -4455.09 8191.96 5923184.57 469187.52 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report (~ompanp: ConocoPhillips Alaska Inc. Field: Kuparuk River U nit 5itc: Kuparuk 2L Pad ~~ cl I: 2 L-309 ~l'cllpath: 2L-309 tiuru•c ~~Ill Intl . ~zim ft deg deg 11286.61 74.91 136.73 11381.68 74.40 136.52 11476.21 74.14 135.58 11570.87 73.87 136.28 11656.41 74.27 136.35 11760.77 74.45 136.41 11854.75 74.39 136.26 11948.50 75.10 136.01 12043.11 74.44 1.35.52 12136.37 74.20 135.49 12231.28 75.35 135.53 12323.21 75.73 136.08 12421.01 76.49 135.91 12514.81 12608.87 12702.93 12797.96 12891.50 75.08 73.68 72.71 74.07 75.35 135.68 135.59 136.31 136.77 136.12 12984.04 13078.60 13173.91 13268.49 13362.55 13456.95 13551.11 13646.07 13740.54 13834.53 13929.58 14023.64 14118.60 14210.42 14306.89 14333.95 14406.32 (4454.12 14550.61 14646.97 14742.60 14837.22 14922.05 14960.00 74.78 73.54 72.59 71.74 71.09 68.90 66.09 63.02 59.85 56.35 52.57 48.47 44.40 41.04 35.93 34.56 33.33 32.98 32.33 30.91 29.75 28.62 27.37 27.37 136.11 136.59 136.99 136.94 137.01 136.54 136.34 136.17 135.20 134.48 133.88 132.61 133.62 134.69 137.04 137.31 137.70 137.90 137.53 137.55 137.66 137.35 137.27 137.27 Dale: .°,/23/2006 'l'ime: 15:13:32 Pa,e: ~ Cu-urdinatc-(,AE) Kcfcrcncc: Well: 2L-309. True North ~'crtical f~l~~'DI Kcfcrcncc: 2L-309 ~ 151.1 ~cctiun l~~ti) Kcfcrcncc: Wall (0.OON,O.OOE.135.93Azi) sur~c~~ C'alculalion ~Icthod: Minimum Curvature Dh: Oracle 71D ti}sIVD ft ft 4266.06 4114.98 4291.22 4140.14 4316.84 4165.76 4342.93 4191.85 4366.41 4215.33 4394.54 4243.46 4419.78 4268.70 4444.45 4293.37 4469.30. 4318.22 4494.51 4343.43 4519.43 4368.35 4542.39 4391.31 4565.86 4414.78 4588.90 4437.82 4614.22 4463.14 4641.42 4490.34 4668.58 4517.50 4693.25 4542.17 4717.10 4566.02 4742.91 4591.83 4770.67 4619.59 4799.64 4648.56 4829.62 4678.54 4861.91 4710.83 4897.95 4746.87 4938.74 4787.66 4983.91 4832.83 5033.57 4882.49 5088.81 4937.73 5148.60 4997.52 5214.03 5062.95 5281.48 5130.40 5356.97 5205.89 5379.07 5227.99 5439.11 5288.03 5479.13 5328.05 5560.36 5409.28 5642.42 5491.34 5724.96 5573.88 5807.56 5656.48 5882.47 5731.39 5916.17 5765.09 \!1 1:-tit' ft ft -4521.46 .8254.75 -4588.10 8317.72 -4653.61 8380.87 -4718.98 8444.16 -4778.47 8500.97 -4851.22 8570.30 -4916.71 8632.80 -4981.91 8695.48 -5047.32 8759.16 -5111.37 8822.09 -5176.70 8886.26 -5240.52 8948.32 -5308.81 9014.27 -5373.99 9077.67 -5438.75 9141.01 -5503.46 9203.61 -5569.56 ....9266.25 -5634.95 9328.42 -5699.39 9390.40 -5765.21 9453.19 -5831.66 9515.62 -5897.47 9577.06 -5962.65 9637.90 -6027.28 9698.64 -6090.32 9758.58 -6152.26 9817.86 -6211.62 9875.81 -6267.88 9932.37 -6321.78 9987.82 -6371.53 10040.68 -6418.53 10090.91 -6461.90 10135.61 -6504.92 10177.44 -6516.37 10188.05 -6546.16 40215.35 -6565.53 10232'.91 -6604.05 10267.94 -6641.32 10302.05 -6676.98 10334.61 -6711.00 10365.77 -6740.27 10392.77 -6753.09 10404.61 \l:rhA ~~Iap(~: Tnul ft ft 5923117.89 . 469249.96 MWD+IFR-AK-CAZ-SC 5923050.93 469312.57 MWD+IFR-AK-CAZ-SC 5922985.11 469375.38 MWD+tFR-AK-CAZ-SC 5922919.41 469438.32 MWD+IFR-AK-CAZ-SC 5922859.64 ` - 469494.82 MWD+IFR-AK-CAZ-SC 5922786.54 469563.77 MWD+IFR-AK-CAZ-SC 5922720.74 469625.93 MWD+IFR-AK-CAZ-SC 5922655.21 469688.26 MWD+IFR-AK-CAZ-SC 5922589.48 469751.59 MWD+IFR-AK-CAZ-SC 5922525.12 469814.19 MWD+IFR-AK-CAZ-SC 5922459.47 469878.02 MWD+IFR-AK-CAZ-SC 5922395.33 469939.73 MWD+IFR-AK-CAZ-SC 5922326.71 470005:33 MWD+IFR-AK-CAZ-SC 5922261.21 470068.38 MWD+IFR-AK-CAZ-SC 5922196.13 470131.38 MWD+IFR-AK-CAZ-SC. 5922131.10 470193.64 MWD+IFR-AK-CAZ-SC 5922064.68 470255.93 MWD+IFR-AK-CAZ-SC 5921998.98 470317.76- MWD+IFR-AK-CAZ-SC 5921934.23 470379.40 MWD+IFR-AK-CAZ-SC 5921868.09 470441.85 MWD+IFR-AK-CAZ-SC 5921801.32 470503.92 MWD+IFR-AK-CAZ-SC 5921735.20 470565.02 MWD+IFR-AK-CAZ-SC 5921669.72 470625.51 MWD+IFR-AK-CAZ-SC 5921604.78 470685.91 MWD+IFR-AK-CAZ-SC 5921541.45 470745.52 MWD+IFR-AK-CAZ-SC 5921479.21 470804.47 MWD+IFR-AK-CAZ-SC 5921419.55 470862.11 MWD+IFR-AK-CAZ-SC 5921363.00 470918.38 MWD+IFR-AK-CAZ-SC 5921308.82 470973.54 MWD+IFR-AK-CAZ-SC 5921258.81 471026.13 MWD+IFR-AK-CAZ-SC 5921211.55 471076.12 MWD+IFR-AK-CAZ-SC 5921167.96 471120.58 MWD+IFR-AK-CAZ-SC 5921124.73 471162.19 MWD+IFR-AK-CAZ-SC 5921113.22 471172.75 MWD+IFR-AK-CAZ-SC 5921083.29 471199.89 MWD+IFR-AK-CAZ-SC 5921063.84 471217.35 MWD+IFR-AK-CAZ-SC 5921025.14 471252.17 MWD+IFR-AK-CAZ-SC 5920987.70 471286.08 MWD+IFR-AK-CAZ-SC 5920951.87 471318.45 MWD+IFR-AK-CAZ-SC 5920917.69 471349.44 MWD+IFR-AK-CAZ-SC 5920888:29 471376.28 MWD+IFR-AK-CAZ-SC 5920875.41 471388.06 PROJECTED to TD Halliburton Company Global Report ('ompam: ConocoPhillips Alaska Inc. Dart: 3/23/2006 1 ime: 15:01:05 Pa~,c 1 Field: Kuparuk River Unit Co-orilinatc(\1:) Re ference: Weli: 2L-309, Tru e North tiitc: Kuparuk 2L Pad ~"c~tical ("C~,DI Kcfc rcncc 2L-309PB9 : 151. 1 ~~cll: 2L-309 ticctio^ I~~X) Kcfcrc ncc: Well (O.OON.O OOE.135-93Azi) ~~~ell~~adi: 2L-309PB1 Surcc~ (calculation ~lcthod: Minimum Curvatu re Dh: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Piane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnefic Model: bggm2005 Site: Kuparuk 2L Pad Site Position: Northing: 5927695.13 ft Latitude: 70 12 48.272 N From: Map Easting: 461077.91 ft Longitude: '150 18 50.048 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: -0.30 deg Well: 2L-309 Slot Name: We11 Position: +N/-S -13.97 ft Northing: 5927681.46 ft Latitude: 70 12 48.135 N +E/-W -58.37 ft Easting : 461019.47 ft Longitude: 150 18 51.743 W Position Uncertainty: 0.00 .> ft - Wellpath: 2L-309PB1 Drilled From: Well Ref. Point 501032052170 Tie-on Depth: 35.78 ft Current Datum: 2L-309PB1 : Height 151.08 ft Above System Datum: Mean Sea Level Magnetic Data: 1/8/2006 Declination: 23.78 deg Field Strength: 57524 nT Mag Dip Angle: 80.64 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.78 .0.00 0.00 135.93 Survey Program for Definitive Wellpath Date: 1/17/2006 Validated: No .Version: 5 Actual From To Survey Toolcode Tool Name ft ft 115.00 441.00 2L-309P61 gyro (115.00-441.00) CB-GYRO-SS Camera based gyro single shot 477.26 9165.90 2L-309PB1 (477.26-9165. 90) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~1D Incl ~zim ll~D S ~sl~'U V'S E;~V ~9apA ~lapC; Cool ft deg deg ft ft ft ft ft ft 35.78 0.00 0.00 35.78 -115.30 0.00 0.00 5927681.46 461019.47 TIE LINE 115.00 0.57 131.39 115.00 -36.08 -0.26 0.30 5927681.20 461019.76. CB-GYRO-SS 172.00 1.17 133.03 171.99 20.91 -0.85 0.93 5927680.61 461020.40 CB-GYRO-SS 262.00 1.22 137.41 261.97 110.89 -2.18 2.25 5927679.27 461021.71 CB-GYRO-SS 353.00 1.90 121.46 352.94 201.86 -3.68 4.20 5927677.76 461023.65 CB-GYRO-SS 441.00 3.05 104.62 440.86 289.78 -5.03 7.71 5927676.39 461027.15 CB-GYRO-SS 477.26 3.76 105.68 477.05. 325.97 -5.60 9.78 5927675.81 461029.22 .MWD+IFR-AK-CAZ-SC 567.56 6.22 104.71 567.00 415.92 -7.64 17.37 5927673.73 461036.80 MWD+IFR-AK-CAZ-SC 658.80 10.60 102.75 657.24 506.16 -10.75 30.34 5927670.56 461049.75 MWD+IFR-AK-CAZ-SC 752.28 10.98 108.76 749.07 597.99 -15.51 47.16 5927665.71 461066.54 MWD+IFR-AK-CAZ-SC 845.49 15.53 106.25 839.77 688.69 -21.86 67.55 5927659.26 461086.90 MWD+IFR-AK-CAZ-SC 939.39 19.63 104.60 929.27 778.19 -29.35 94.89 5927651.62 461114.20 MWD+IFR-AK-CAZ-SC 1033.45 21.47 104.46 1017.34 866.26 -37.64 126.86 5927643.17 461146.12 MWD+IFR-AK-CAZ-SC 1127.48 25.46 103.01 1103.58 952.50 -46.49 .163.23 5927634.14 461182.44 MWD+IFR-AK-CAZ-SC 1222.20 26.89 103.14 1188.58 1037.50 -55.94 203.92 5927624.47 461223.08 MWD+IFR-AK-CAZ-SC 1315.99 31.96 103.36 1270.25 1119.17 -66.50 248.76 5927613.68 461267.86 MWD+IFR-AK-CAZ-SC 1397.68 35.34 103.27 1338.24 1187.16 -76.93 292.80 5927603.03 461311.84 MWD+IFR-AK-CAZ-SC 1493.33 39.53 106.37 1414.18 1263.10 -91.86 348.96 5927587.81 461367.92 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report Cumpxn~~: Conoco Phillips Alaska Inr. Date: 3?23/2006 lima: 15:01'05 Pa,r. Field: Ku paruk Rive r Unit Cu-urd inatclAI~) Kc f~rcuce: Well: 2L-309. True North Sire Ku paruk 2L P ad ~'crtic al ("f~D) Itcfc rcncc: 2L -309PB1 : '151. 1 \1cll: 2L -309 Scctiu~ i (~~tit Kcfcre ncc: Well 10 OON,O-OOE_135.93Azi) ~~'dlpath: 2L -309PB1 Surcc~ ('alculation >lcthod: Mi nimum Curvatu re Db: Oracle Sung SID lucl ~zuu [~~D Svs IUD ~/S F~ti~ ~11n1~A ~1~3ph. Inol ft deg deg ft ft tt ft ft ft 1587.90 47.93 105.69 1482.45 1331.37 -109.87 411.74 5927569.48 461430.60 MWD+IFR-AK-CAZ-SC 1682.68 50.28 105.58 1544.50 1393.42 -129.18 480.73 5927549.82 461499.48 MWD+IFR-AK-CAZ-SC 1778.52 54.21 106.33 1603.17 1452.09 -150.01 553.57 5927528.61 461572.20 MWD+IFR-AK-CAZ-SC 1869.69 57.85 106.17 1654.10 1503.02 -171.17 626.15 5927507.08 461644.66 MWD+IFR-AK-CAZ-SC 1963.02 60.32 106.83 1702.05. 1550.97 -193.91 702.91 5927483.94 461721.30 MWD+IFR-AK-CAZ-SC 2059.85 62.44 106.34 1748.43 1597.35 -218.17 784.37 5927459.27 461802.63 MWD+IFR-AK-CAZ-SC 2151.12 66.42 107.18 1787.82 1636.74 -241.91 863.18 5927435.12 461881.31 MWD+IFR-AK-CAZ-SC 2249.08 72.26 104.27 1822.37 1671.29 -266.70 951.38 5927409.88 461969.36 MWD+IFR-AK-CAZ-SC 2345.52 74.05 103.64 1850.32 1699.24 -288.95 1040.95 5927387.16 462058.81 MWD+IFR-AK-CAZ-SC 2447.33 74.06 103.25 1878.28 1727.20 -311.71 1136.16 5927363.91 462153.89 MWD+IFR-AK-CAZ-SC 2529.06 73.99 102.97 1900.78 1749.70 -329.54 1212.69 5927345.70 462230.32 MWD+IFR-AK-CAZ-SC 2630.53 73.89 102.98 1928.85 1777.77 -351.43 1307.71 5927323.32 462325.22 MWD+IFR-AK-CAZ-SC 2726.40 72.84 106.59 1956.30 1805.22 -374.86 1396.51 5927299.43 462413.89 MWD+IFR-AK-CAZ-SC 2820.34 73.51 105.74 1983.49 1832.41 -399.89 1482.87 5927273.96 462500.11 MWD+IFR-AK-CAZ-SC 2913.01 73.90 104.91 2009.50 1858.42 -423.40 1568.65 5927250.01 462585.76 MWD+IFR-AK-CAZ-SC 3007.74 75.12 103.86 2034.79 1883.71 -446.08 1657.08 5927226.88 462674.06 MWD+IFR-AK-CAZ-SC 3101.97 74.97 105.10 2059.11 1908.03 -468.84 1745.22 5927203.66 462762.08 MWD+IFR-AK-CAZ-SC 3185.18 75.52 105.82 2080.31 1929.23 -490.29 1822.78 5927181.82 462839.51 MWD+IFR-AK-CAZ-SC 3286.82 75.17 106.01 2106.02 1954.94 -517.25 1917.34 5927154.37 462933.93 MWD+IFR-AK-CAZ-SC 3378.69 75.32 105.01 2129.42 1978.34 -541.01 2002.94 5927130.17 463019.40. MWD+IFR-AK-CAZ-SC 3474.86 74.72 103.49 2154.28 2003.20 -563.88 2092.98 5927106.84 463109.31 MWD+IFR-AK-CAZ-SC 3568.59 74.70 103.88 2179.00 2027.92 -585.27 2180.83 5927085.00 463197.03 MWD+IFR-AK-CAZ-SC 3661.05 73.16 103.82 2204.59 2053.51 -606.53 2267.09 5927063.29 463283.18 MWD+IFR-AK-CAZ-SC 3753.31 73.75 103.54 2230.86 2079.78 -627.45 2353.02 5927041.93 463368.99 MWD+IFR-AK-CAZ-SC 3846.81 73.95 103.63 2256.87 2105.79 -648.55 2440.32 5927020.39 463456.17 MWD+IFR-AK-CAZ-SC 3941.22 73.33 105.40 2283.46 2132.38 -671.25 2528.01 5926997.24 463543.73 MWD+IFR-AK-CAZ-SC 4036.65 72.80 106.11 2311.26 2160.18 -696.03 2615.87 5926972.00 463631.46 MWD+IFR-AK-CAZ-SC 4131.06 76.02 106.26 2336.63 2185.55 -721.38 2703.19 5926946.21 463718.64 MWD+IFR-AK-CAZ-SC 4226.57 76.29 106.07 2359.49 2208.41 -747.20 2792.26 5926919.93 463807.56 MWD+IFR-AK-CAZ-SC 4303.49 76.57 104.99 2377.53 2226.45 -767.22 2864.30 5926899.54 463879.49 MWD+IFR-AK-CAZ-SC 4364.07 75.97 107.42 2391.91 2240.83 -783.64 2920.81 5926882.83 463935.91 MWD+IFR-AK-CAZ-SC 4409.66 72.41 109.29 2404.33 2253.25 -797.44 2962.44 5926868.82 463977.46. MWD+IFR-AK-CAZ-SC 4455.66 69.41 111.26 2419.38 2268.30 -812.49 3003.21 5926853.55 464018:15 MWD+IFR-AK-CAZ-SC 4504.54 68.09 110.93 2437.09 2286.01 -828.89 3045.71 5926836.94 464060.56 MWD+IFR-AK-CAZ-SC 4548.48 65.85 111.93 2454.28 2303.20 -843.66 3083.35 5926821.97 464098.12 MWD+IFR-AK-CAZ-SC 4596.89 62.93 112.93 2475.21 2324.13 -860.31 3123.70 5926805.12 .464138.38 MWD+IFR-AK-CAZ-SC 4641.02 60.70 113.28 2496.05 2344.97 -875.57 3159.47 5926789.67 464174.07 MWD+IFR-AK-CAZ-SC 4690.60 58.50 112.69 2521.14 2370.06 -892.27 3198.84 5926772.77 464213.35 MWD+IFR-AK-CAZ-SC 4737.29 56.71 113.13 2546.15 2395.07 -907.62 3235.15 5926757.24 464249.58 MWD+IFR-AK-CAZ-SC 4786.55 55.15 113.81 2573.74 2422.66 -923.87 3272.58 5926740.80 464286.92 MWD+IFR-AK-CAZ-SC 4830.62 .53.42 112.59 2599.47 2448.39 -937.97 3305.46 5926726.53 464319.72 MWD+IFR-AK-CAZ-SC 4879.05 51.28 114.38 2629.05 2477.97 -953.24 3340.63 592&711.08 464354.81 MWD+IFR-AK-CAZ-SC 4923.90 48.88 114.41 2657.83 2506.75 -967.44 3371.96 5926696.72 464386.06 MWD+IFR-AK-CAZ-SC 4973.43 46.46 116.16 2691.18 2540.10 -983.07 3405.06 5926680.92 464419.08 MWD+IFR-AK-CAZ-SC 5018.01 44.60 117.13 2722.41 2571.33 -997.33 3433.50 5926666.51 464447.44 MWD+IFR-AK-CAZ-SC 5066.63 42.25 119.63 2757.72 2606.64 -1013.20 3462.90 5926650.50 464476.76. MWD+IFR-AK-CAZ-SC 5113.18 39.62 120.98 2792.89 2641.81 -1028.58 3489.24 5926634.98 464503.01 MWD+IFR-AK-CAZ-SC 5159.49 37.72 123.43 2829.05 2677.97 -1043.99 3513.72 5926619.45 464527.41 MWD+IFR-AK-CAZ-SC 5206.58 35.21 126.37 2866.92 2715.84 -1059.98 3536.68 5926603.34 464550.28 MWD+IFR-AK-CAZ-SC 5256.59 33.49 130.76 2908.21 2757.13 -1077.54 3558.75 5926585.67 464572.26 MWD+IFR-AK-CAZ-SC 5300.31 32.20 134.82 2944.94 2793.86 -1093.63 3576.15 5926569.49 464589.57 MWD+IFR-AK-CAZ-SC 5347.05 30.77 140.69 2984.81 2833.73 -1111.66 3592.56 5926551.38 464605.89 MWD+IFR-AK-CAZ-SC Halliburton Companys Global Report ('on~pau~: ConocoPhillips Alaska Inc. I)atr 3123/20D6 7in,c: 15:01:05 Pa~,r. 3 Ficl~l: Kuparuk Rfver Unit Co-ordinate(\I?) Rcferencr. Well: 2L-309, True North tiitc: Kuparuk 2L Pad ~ crtical (1'1~ll) Ilcfercucc: 2L-309PB1 _ 151.1 Nell: 2L-309 Section (151 Kefercnce: Weli f0.00N.0.00E,135-93Azi1 11'clllrith: 2L-309P61 Sun~ev Chlculatinn Slcthnd: Minimum Curvature Dh: QraGle Surcc~ VIII lucl brim ll'D S~sT~~l) V'%S I~~;l~' 11ahA ~IapE Tool ft dey deg ft ~ ft ft ft ft ft 5393.23 30.22 143.28 3024.61 2873.53 -1130.12 3606.99 5926532.85 464620.23 MWD+IFR-AK-CAZ-SC 5442.74 29.75 .149.03 3067.50 2916.42 -1150.64 3620.77 5926512.25 464633.89 MWD+IFR-AK-CAZ-SC 5486.89 28.94 152.30 3105.99 2954.91 -1169.49 3631.37 5926493.35 464644.40 MWD+IFR-AK-CAZ-SC 5535.34 27.71 155.80 3148.64 2997.56 -1190.15 3641.44 5926472.64 464654.36 MWD+IFR-AK-CAZ-SC 5579.63 26.20 159.58 3188.12 3037.04 -1208.71 3649.07 5926454.05 464661.89 MWD+IFR-AK-CAZ-SC 5627.65 25.22 164.66 3231.39 3080.31 -1228.51 3655.48 5926434.21 464668.20 MWD+IFR-AK-CAZ-SC 5673.41 24.16 170.37 3272.97 3121.89 -1247.15 3659.62 5926415.56 464672.25 MWD+IFR-AK-CAZ-SC 5723.54 24.17 177.77 3318.72 3167.64 -1267.52 3661.74 5926395.18 464674.26 MWD+IFR-AK-CAZ-SC 5766.09 23.66 181.31 3357.62 3206.54 -1284.76 3661.88 5926377.94. .464674.31 MWD+IFR-AK-CAZ-SC 5814.87 24.16 186.40 3402.21 3251.13 -1304.47 3660.55 5926358.24 464672.87 MWD+IFR-AK-CAZ-SC 5861.75 23.88 188.72 3445.04 3293.96 -1323.39 3658.04 .5926339.34 464670.27 MWD+IFR-AK-CAZ-SC 5910.55 24.23 194.71 3489.60 3338.52 -1342.84 3654.00 5926319.91 464666.13 MWD+IFR-AK-CAZ-SC 5955.63 23.61 198.25 3530.81 3379.73 -1360.36 3648.82 5926302.42 464660.86 MWD+IFR-AK-CAZ-SC 6001.65 23.89 204.75 3572.94 3421.86 -1377.58 3642.03 5926285.23 464653.98 MWD+IFR-AK-CAZ-SC 6050.59 24.36 211.00 3617.62 3466.54 -1395.23 3632.68 5926267.63 464644.55 MWD+IFR-AK-CAZ-SC 6098.87 24.62 211.53 3661.55 3510.47 -1412.34 3622.30 5926250.58 464634.07 MWD+IFR-AK-CAZ-SC 6146.75 25.66 .217.01 3704.90 3553.82. -1429.12 3610.84 5926233.86 464622.53 MWD+IFR-AK-CAZ-SC 6192.31 27.33 224.11 3745.69 3594.61 -1444.51 3597.62 5926218.54 464609.23 MWD+IFR-AK-CAZ-SC 6241.49 29.74 231.34 3788:90 3637.82 -1460.24 3580.23 5926202.90 464591.76 MWD+IFR-AK-CAZ-SC 6289.53 32.56 237.33 3830.02 3678.94 -1474.67 3560.03 5926188.57 464571.49 MWD+IFR-AK-CAZ-SC 6334.49 34.74 239.25 3867.45 3716.37 -1487.75 3538.83 5926175.60 464550.23 MWD+IFR-AK-CAZ-SC 6382.43 37.26 242.36 3906.23 3755.15 -1501.47 3514.23 5926162.01 464525.56 MWD+IFR-AK-CAZ-SC 6428.30 39.20 244.92 3942.27 3791.19 -1514.06 3488.80 5926149.56 464500.06 MWD+IFR-AK-CAZ-SC 6476.04 42.02 247.61 3978.51 3827.43 -1526.55 3460.35 5926137.22 464471.56 MWD+IFR-AK-CAZ-SC 6523.75 44.29 250.48 4013.31 3862.23 -1538.20 3429.88 5926125.73 464441.03 MWD+IFR-AK-CAZ-SC 6571.91 46.88 252.31 4047.02 3895.94 -1549.16 3397.28 5926114.93 464408.37 MWD+IFR-AK-CAZ-SC 6617.06 48.21 255.53 4077.50 3926.42 -1558.38 3365.28 59261.05.89 464376.33 MWD+IFR-AK-CAZ-SC 6664.49 49.88 256.55 4108.58 3957.50 -1567.01 3330.52 5926097.43 464341.53. MWD+IFR-AK-CAZ-SC 6710.75 51.08 258.16 4138.02 3986.94 -1574.82 3295.70 5926089.80 464306.67 MWD+IFR-AK-CAZ-SC 6802.07 55.49 258.85 4192.60 4041.52 -1589.39 3223.98 5926075.60 464234.88 MWD+IFR-AK-CAZ-SC 6895.04 54.90 258.32 4245.67 4094.59 -1604.50 3149.15 5926060.88 464159.99 MWD+IFR-AK-CAZ-SC 6990.98 54.85 258.38 4300.87 4149.79 -1620.34 3072.30 5926045.44 464083.06 MWD+IFR-AK-CAZ-SC 7085.67 54.17 258.89 4355.84 4204.76 -1635.54 2996.71 5926030.63 464007.41 MWD+IFR-AK-CAZ-SC 7179.63 55.10 261.61 4410.23 4259.15 -1648.50 2921.21 5926018.06 463931.84 MWD+IFR-AK-CAZ-SC 7274.62 54.69 260.95 4464.86 4313.78 -1660.28 2844.40 5926006.68 463854.98 MWD+IFR-AK-CAZ-SC 7368.98 54.04 261.14 4519.83 4368.75 -1672.22 2768.64 5925995.13 463779.17 MWD+IFR-AK-CAZ-SC 7463.75 55.97 262.35 4574.18 4423.10 -1683.36 2691.81 5925984.40 463702.29 MWD+IFR-AK-CAZ-SC 7558.08 55.16 262.49 4627.52 4476.44 -1693.62 2614.69 5925974.53 463625.13 MWD+IFR-AK-CAZ-SC 7649.01 54.76 261.76 4679.73 4528.65 -1703.82 2540.95 5925964.71 463551.34 MWD+IFR-AK-CAZ-SC 7744.35 57.58 260.27 4732.81 4581.73 -1716.20 2462.74 5925952.74 463473.07 MWD+IFR-AK-CAZ-SC 7838.11 57.55 260.65 4783.10 4632.02 -1729.32 2384.70 5925940.02 463394.97 MWD+IFR-AK-CAZ-SC 7933.06 56.72 260.17 4834.62 4683.54 -1742.60 2306.06 5925927.15 463316.28 MWD+IFR-AK-CAZ-SC 8027.04 56.58 259.61 4886.29 4735.21 -1756.38 2228.77 5925913.77 463238.93 MWD+IFR-AK-CAZ-SC 8120.84 57.02 261.26 4937.65 4786.57 -1769.42 2151.38- 5925901.13 463161.48 MWD+IFR-AK-CAZ-SC 8213.53 56.58 261.52 4988.40 4837.32 -1781.03 2074.70 5925889.92 463084.74 .MWD+IFR-AK-CAZ-SC 8305.32 55.92 261..28 5039.40 4888.32 -1792.44 1999.23 5925878.89 463009.23 MWD+IFR-AK-CAZ-SC 8400.25 55.64 261.87 5092.79 4941.71 -1803.95 1921.59 5925867.80. 462931.53 MWD+IFR-AK-CAZ-SC 8495.15 55.27 261.99 5146.60 4995.52 -1814.92 1844.19 5925857.22 462854.09 MWD+IFR-AK-CAZ-SC 8589.25 54.91 261.15 5200.45 5049.37 -1826.23 1767.86 5925846.31 462777.71 MWD+IFR-AK-CAZ-SC 8632.68 53.82 261.60 5225.75 5074.67 -1831.52 1732.96 5925841.19 462742.78 MWD+IFR-AK-CAZ-SC 8680.37 51.74. 261.93 5254.60 5103.52 -1836.97 1695.38 5925835.95 462705.18 MWD+IFR-AK-CAZ-SC 8727.56 49.79 263.22 5284.45 5133.37 -1841.69 1659.14 5925831.41 462668.92 MWD+IFR-AK-CAZ-SC 8773.54 47.18 265.43 5314.92 5163.84 -1845.11 1624.89 5925828.17 462634.65 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report (~ompanc: ConocoPhillips Alaska Inc. Field: Kuparuk River U nit Site: Kuparuk 2L Pad ~~ cIL 2L-309 ~~ cllp.ith: 2L-309PB1 Suncv ~~ID [ncl brim ft deg deg 8823.02 43.75 265.56 8867.35 41.77 265.10 8913.95 38.47 265.17 8960.97 36.15 265.32 9009.63 33.60. 264.73 9057.29 29.15 263.19 9102.92 26.74 261.31 915.1.95 24.12 262.18 9165.90 23.51 262.18 9203.00 23.51 262.18 t)atc: 3123;~OOo -Time: 15:01'05 Pn:;c: -4 Cu-urdinatclAI:1 Reference: Well: 2L-309. True North ~~crtical CI'~~D) Rcfercucr. 2L-309PB1 . 151.'1 Section ('til Reference lNe!! (0-OON.O ODE,135.93Azi) Sur~~ev Cnlcul;tfiun ~icthud: Minimum Curvature Db: Oracle l ~~ U S~~s l \I) S/S P:-~1 ~lapA ~Iaf~E C~xil ft ft ft ft ft ft 5349.62 5198.54 -1847.88 1589.73 5925825.58 462599.48 MWD+IFR-AK-CAZ-SC 5382.17 5231.09 -1850.33 1559.74 5925823.28 462569.48 MWD+IFR-AK-CAZ-SC 5417.80 5266.72 -1852.88 1529.82 5925820.89 462539.55 MWD+IFR-AK-CAZ-SC 5455.19 5304.11 -1855.24 1501.42 5925818.68 462511.14 MWD+IFR-AK-CAZ-SC 5495.11 5344.03 -1857.65 1473.70 5925816.41 462483.42 MWD+IFR-AK-CAZ-SC 5535.79 5384.71 -1860.24 1449.03 5925813.95 462458.74 MWD+IFR-AK-CAZ-SC 5576.10 5425.02 -1863.11 1427.85 5925811.19 462437.54 MWD+IFR-AK-CAZ-SC 5620.37 5469.29 -1866.14 1407.02 5925808.27 462416.69 MWD+tFR-AK-CAZ-SC 5633.14 5482.06 -1866.90 1401.44 .5925807.53 462411.11 MWD+IFR-AK-CAZ-SC 5667.16 5516.08 -1868.92 1386.77 5925805.59 462396.44 PROJECTED to TD ~~^, • • 10-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2L-309 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,303.49' MD Window /Kickoff Survey: 14,922.05' MD (if applicable) Projected Survey: 14,960.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ®~ Si ned Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 10-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2L-309 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 33.98' MD Window /Kickoff Survey: 9,165.90' MD (if applicable) Projected Survey: 9,203.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) bus -~c~ ~.1~. • • ^~ ~ t ~ ~ I ~a I ~$~ ~ -~ F ~ ~ . ~" ~~ ~ ~...' ~,s~ ~ ~ ~ ~~ ~~ FRANK H. MURKOWSKI, GOVERNOR G1® -~t~ ~T ^®~ p 333 W. 7TM gVENUE, SUITE 100 ~~~~ai~d~ R~® ~~® A ANCHORAGE, ALASKA 99501-3539 / PHONE (907) 279-1433 Randy Thomas FAx (907) 27sasa2 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River, 2L-309 Sundry Number: 306-030 Dear Mr. Thomas: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Jr. Commissioner ,~(-f DATED this=`~day of January, 2006 Encl. • ConocoPhillips January 23, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 2L-309 Dear Commissioner: • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6930 ,SAN ~ ~' ~{etka 0~ & Gas ~.,.,, ,~~~. ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 2L-309. We are planning to plug and abandon the pilot hole. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Winfree at 265-6820. Sincerely, ~~~ X '`~ ~~ Randy T°h`o~ma~s Kuparuk Drilling Team Leader CPAI Drilling and Wells RT/skad • STATE OF ALASKA ~~;-,' ALASKA OIL AND GAS CONSERVATION COMMISSION RE~!~.f" J/~~V2~;;.> APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Sk8 Oii & G8S i.., .......~t31:;lii;;i;;i0t1 1. Type of Request: Abandon ~ Sus end ^ O erational shutdown ^ p p ^ Perforate Waiver tif~ij8 Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current WeII Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 205-210 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20521-00 7. KB Elevation (ft): 9. Well Name and Number: 150' AMSL 2L-309 8. Property Designation: 10. Field/Pools(s): ADL 380051 / 380052 / 380053 / ALK 4601 Ku aruk River Field / Tarn Oil Pool 11. PRESENT WELL CONDIT ION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 9205' 5667' 9205' 5667' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 115' 115' Surface 2979' 9.625" 4340' 2388' Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/24/2006 Oil ^~ Gas ^ Plugged ~ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Winfree Cc~ 265-6820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Lea der Signature ` _ Phone 265-6830 Date I /Z~/06 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. PCO'J _Y1Q ©DC[~Cx~ ~O~C>,~ 'Q'C~~(j~~ MS c:~C-Q, ~ ` P `'iL(~uJl 1 T` W l \` h~~ `.~~ ~ ~~~~SS~.r-~ ~ ~S P ~~ ;~ ~ Subsequent Form Required: t'~ i ~~ 1 G' `\ CC '' APPROVED BY / ~ Approve COMMISSIONER THE COMMISSION Date: ~ Form 10-403 Revised 7/2005 ^ I ^ i ~ A L SUBMIT IN DUPLICATE Conductor Casing Shoe @ 115', 16", 62.5#, API 5L Grade B Surface Casing: 9-5/8", 40.0#, L-80, BTC 4340' MD / 2388' TVD KO Plug +/- 180 cf Class "G" cement Yield = 1 TVD hoe and 300' in OH D, TVD 'ud 10.7 PP9 Pc T Botto n to pump a Production PI pilot hole. Bottom plug to i a yield of 1.16 cf per sac excess volume over 8-' ss "G" cement with a yielc Run in hole to TD with a Prod Plug, a +/_743' (finis 9205' to +/- 8615' . POOH to 8615' and circa POOH to 5175'. Lay in +/- 4888' followed by a 1 to 4677' followed by a 3 4640'. Pick up to +/- 3700'. Ciri hours. RIH to top of Forma-Plus Lay in Kick Off Plug, a +, 4640' to 4240' (100' in 9- POOH and lay down 3-'i maKe up amm~g assemory and Kih, caggrng cop or K~ Plug. Class "G" cement Yield = 1.16 ft'/sk (230 sks) -oyon 14 =Rig Floor = 0 feet levation = 149.6 feet 14.3 feet above pad. eduction Plug p at 8615' MD 5225' TVD :lination = 53 deg ~I: 47.5 bbls Top of Bermuda Formation at 8962' MD 5455 TVD Inclination = 36 deg i 8-1 /2" Open Hole „_05' MD, 5667' TVD, Inclination = 24 deg ~,,,~ Tarn 2L-309 Pilot Hole Plu In Prepared byM.A. Wnfree Ct~1'1©CaPh ~ ~ ~ ~ ~i5 gg 9 2L-309 Plugback Schematic 2 vsd Schematic and Operations 1/23i2oos LJ ~~g ` _ ~ .~ ~ ~ ~ F z 3 ~ ~ $ ~ E p~} ..- ~ .s ~~ S-, #~ ~~) ~~ ~ ~ ~"`"'~ ~~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~~ ;~~ 333 W. 7T" AVENUE, SUITE 100 ~ll~ ~~ ~~® 6tp' ANCHORAGE, ALASKA 99501-3539 I PHONE (907) 279-1433 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 FAX (907) 276-7542 Re: KRU Tarn 2L-309 ConocoPhillips Alaska, Inc. Permit No: 205-210 Surface Location: 164' FNL, 631' FEL, Sec. 22, TlON, R7E Bottomhole Location: 1620' FNL, 812' FEL, Sec. 25, T10N, R7E Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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. In accordance with 20 AAC 25.005(fl, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (KRU Tarn 2L- 309PB 1) and API number (50-103-20571-70) from records, data and logs acquired for KRU Tarn 2L-309. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). 205-210 DATED this day of January, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • ConocoPhillips Alaska, Inc. 700 G Street Anchorage, Alaska 99501 December 21, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 907-279-1433 RE: Application for Permit to Drill 2L-309 and 2L-309PB1 Dear Sir or Madam, • ~~ ~~ ~~~~ ~~~ ~ ~Q Alaska ~i~ & Gas Cans: Ggmm~ssion Atl~h€~tag ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the producer we112L- 309 and pilot hole 2L-309PB1:" The well will be drilled and completed using Doyon Rig 14. The planned spud date for 2L-309/2L309PB1 is January 6th 2006. The pilot hole is intended to investigate the gas/oil contact to the west and updip of the proposed 2L-309 BHL. The information acquired from the pilot hole will be used in planning future Tarn development wells. The pilot hole will be drilled prior to the 2L-309 intermediate interval and plugged back to a suitable kick off point. GR/RES/Density-Neutron will be run through the entire pilot hole interval and through the production interval of 2L-309. If you have any questions or require further information, please contact Mike A. Winfree at 907-265-6820. Sincerely, ~~ ~ ~~~ ~~ 5 Randy Thomas Kuparuk Drilling Team Leader ORIGINAL RECEIVED DEG ~ `~ 2QO5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~~ Alaska (]il & Gas Cnns, Cpmmission PERMIT TO DRILL /~"'~~ Anch9ra~l~ 20 AAC 25.005 3 1a. Type of Work: Drill^/ Redrill Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ~ Multiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone Q 2. Operator Name: ConocoPhillips Alaska, Inc. ~ 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 2L-309 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14960' ~ TVD: 5924' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 164' FNL, 631' FEL, Sec. 22, T10N, R7E, UM " 7. Property Designation: ~~q~!,~ t , . i7~ ADL 380052 / 380053' ~ Tarn Oil Pool - Top of Productive Horizon: 1433' FNL, 993' FEL, Sec. 25, T10N, R7E, UM " 8. Land Use Permit: ALK 4601 13. Approximate Spud Date: 1/6/2006 Total Depth: 1620' FNL, 812' FEL, Sec. 25, T10N, R7E, UM ` 9. Acres in Property: 2560 14. Distance to:~t~--'~~ '~'•'~ k~~- k=cxv. c..•+.~ Nearest Property: 3749' ~~ ~,p , 4b. Location of Well (State Base Plane Coordinates): Surface: x- 461019 " y- 5927681 Zone- 4 10. KB Elevation (Height above GL): 150' AMSL feet 15. Distance to Nearest l ~ ~<^4. Well within Pool: 2L-317/e42082 • 16. Deviated wells: Kickoff depth: 400 ft. • Maximum Hole Angle: 74.5° deg 17. Maximum Anticipated Pressures in psig (see 20 aaC 25.035) Downhole: ~sig .~3L=~-'~~' Surface: 2666 psig` 18. Casing Program ecifications S Setting Depth i• 3•ck Quantity of Cement Size p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 80' 34' 34' 115' 115' 260 sx AS1 12.25" 9-5/8" 40# L-80 BTCM 4314' 34' 34' 4347' - 2393' ~ 480 sx AS Lite, 340 sx LiteCRETE 8.5" 7" 26# L-80 BTCM 14228' 34' 34' 14364' 5410' - 170 sx Class G ~ 3.5" 9.3# L-80 EUE 8rd 700' 14214' 5354' 14960' • 5924' 140 sx Class G ~i.~7s 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ff): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch Drilling ProgramQ Time v. Depth Plot Shallow Hazard Analysis Q 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 Mike unfree @ 265-6820 Printed Name 'R/andy Thomas Titie Greater Kuparuk Area Drilling Team Leader Signature ~dr~(Jj G /~ ~~~~ G Phone iZ ~L ~5,~. Date <~'/ ~ (r~ rT /°~ S Pr ar b ha n D k Commission Use Only Permit to Drill Number: ~®~ `p ~, ~ API Number: 50- ,~ ~~ ~- ~t~s~ t _ Q V Permit Approval Date: ~ - ~- ~ (jj See cover letter for other requirements Conditions of approval Samples required Yes ^ No ~ Mud log required Yes ^ No H rogen sulfide measures Yes ~ No ^ Directional survey required Yes ,~ No ^ Other: '~ S~ ~I~+a~74`~l Q~ `'C:~ APPROVED BY _ ~~~ Approved by THE COMMISSION Date: Form 10-401 e ' ed 06/2004` ^ ~ ^ I A L Submit in Duplicate Permit It - Kuparuk Well 2L-309 Application for Permit to Drill Document ~tion for Permit to Drill, Well 2L-309 Saved: 22-Dec-{15 NlpximixE we11 vc,~u~ 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) .................................................................................................... 2 3. Blowout Prevention Equipment Information ............................................................ 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................ 3 4. Drilling Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ............................................................................................... 3 5. Procedure for Conducting Formation Integrity Tests ............................................. 3 Requirements of 20 AAC 25.005 (c)(5) ............................................................................................... 3 6. Casing and Cementing Program ................................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................ 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................ 4 8. Drilling Fluid Program ................................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................ 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 ........................................................................................ 6 Requirements of 20 AAC 25.005 (c)(11) ............................................................................................. 6 12. Evidence of Bonding ................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ............................................................................................. 6 13. Proposed Drilling Program ......................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ............................................................................................. 6 ORIGINAL 2L-309 PERMIT IT Page 1 of 7 Printed: 22-Dec-05 C ~ation for Permit to Drill, Well 2L-309 Saved:22-Dec-05 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ........................7 Requirements of 20 AAC 25.005 (c)(14) ............................................................................................. 7 15.Attachments ..................................................................................................................7 Attachment 1 Directional Plan ............................................................................................................ 1 Attachment 2 Drilling Hazards--.• .........................................................................•.-..-..........2 Attachment 3 WeII Schematic .............................................................................................3 Attachment 4 Cement Program Summary .......................................................................................... 4 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and APl number by adding a suffix to the name designated for the well by the operator and to the number assigned to the welt by the commission. The well for which this application is submitted will be designated as 2L-309 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)the coordinates of the proposed location of the weN at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) 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 welt at the top of each objective formation and at total depth; Location at Surface 163.94' FNL, 631.49' FEL, Sec 22, T10N, R07E, UM NGS Coordinates RKB Elevation 149.6 AMSL - Northings: 5,927,681.46 Eastings: 461,019.47 Pad Elevation 115.3 Location at Top of Productive Interval (Bermuda Sands: T3) 1433' FNL, 993' FEL, Sec 25, T10N, R07E, UM NGS Coordinates Measured De th, RKB: 14,440' Northings: 5, 921, 087.00 Eastings: 471,193.00 Total Vertical Depth, RKB: 5474' Total Vertical Depth, SS: 5325' Location at Total Depth 1620' FNL, 812' FEL, Sec 25, T10N, R07E, UM NGS Coordinates Measured Depth, RKB: 14,960' Northings: 5,920,899.38 Eastings: 471,372.70 Total Vertical Depth, RKB: 5924' Total Vertical Depth, SS: 5775' and {D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a welt Is to be intentionally deviated, the application for a Permit to Drill {Form 10-401) must (1) include a p/at, drawn to a suitable scale, showing the path of the proposed weltbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional plan for both the pilot hole (2L-309PB1) and the well bore to be completed (2L-309). and {2) for all wells within 200 feet of the proposed weltbore r ~ . ~1~~~, 2L-309 PERMIT IT Page 2 of 7 Printed: 22-Dec-05 • ~tion for Permit to Drill, Well 2L-309 Saved: 22-Dec-0S (A) fist the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable: The BOPE includes a 13-5/8" RSRRA 5M stack. Please reference BOP schematics on file for Doyon 14 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 frle with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Current model predictions estimate a max BHP of 3300 psi at 5924' TVD for the 2L-309 location. Equivalent Mud Weight @TD = 3300psi =10.7 ppg 5924'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling 2L-309 is calculated using the predicted 3300 psi reservoir pressure, a 0.11 psi/ft gas gradient, and Bermuda TVD of 5924'. MPSP = ~Gradient~,~ - Gradientc~, TVD GradientM„d =10.7 ppg x 0.052 = 0.56 f tt t GYadientGp~, = 0.11 f l t TVD = 5924 ft MPSP = 0.56 psa - 0.11 psa 5924 ft = 2666psi ~` ft ft (8) data on potential gas zones; The 2L wells have encountered gas hydrates while drilling at -1200' TVD, just below the base of the permafrost. There are also gas shows at the base of the West Sak 1900' TVD. - and (C) data concerning potential causes of hole problems such as abnormaNy geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; LOT/FIT will be conducted in accordance with the Kuparuk LOT/FIT procedure CPAI has on file with the ('~ A/O~GCAC.' A LOT/FIT will be performed at the surface shoe drill out and intermediate shoe drill out stages. ®K ~ 1 ~1' ~\~ ~ L 2L-309 PERMIT IT 1 ~ ff V t •• II ~, Page 3 of 7 Printed: 22-Dec-05 ~tion for Permit to Drill, Well 2L-309 Saved:22-Dec-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted finer, pre- periorated liner, or screen to be installed; Casing and Cementing Program Csg/Tbg Hole Size Weight Grade Connection Length Top MD/TVD Btm MD/TVD Cement Program OD (in) fn (lb/ff) MD (ft) ft ft 16" 24" 62.5 H-40 Welded 80' 34.3'/34.3' 115'/115' 260 sx 15.8 ppg AS1 Lead: 480 sx 10.7 ppg AS Lite 9-5/8" 12-1/4" 40 L-80 BTCM 4314' 34.3'!34.3' 4347'12393' Tail: 340 sx 12.0 ppg LiteCRETE Planned TOC=Surface 170 sx 15.8 ppg Class G 7" 8-1/2" 26 L-80 BTCM 14228' 34.3'/34.3' 14364'/5410' w/additives Planned TOC=13,564 MD 3-1 /2" " 9.3 L-$0 EUE 8RD 700' 14214'/5354' 14960'/5924' 140 sx 15.8 ppg Class G ~ w/ additives ~.1~5~~1~i~y(s5 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 fli/e 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); The BOPE includes a 21-1/4" 2M diverter with 16" line. Please reference diverter schematic on file for Doyon 14. 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 fife 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 the mud properties listed for their respective intervals. V R ~ G i ~ / 1 ~ 2L-309 PERM/T IT Page 4 of 7 Pr+nted: 22-Dec-05 • Surface Hole Mud Program (Spud Mud) ~tion for Permit to Drill, Well 2L-309 Saved: 22-Dec-05 Base of Permafrost to 9 5/8" Spud to Base of Permafrost Casing Point Initial Value Final Value Initial Value Fina! Value Density (ppg) 9.6 <9.8 <9.6 10.2 Funne( viscosity 250 250 150-200 55-65 (seconds Yield Point 35-45 35-45 30-35 12-15 cP pH 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate 6 6 4-6 4-6 (cc / 30 min)) Chlorides (mg/l) <600 <600 <600 <600 Intermediate Hole Mud Program (LSND) Also applies to 9 5/8" Casin Shoe to Intermediate. TD g pilot hole Initial Value Final Value Density (ppg) 9.6 10.0 Yield Point 22_28 10-15 cP pH 9-9.5 9-9.5 API Filtrate 4-6 4-5 (cc / 30 min HTHP @ 150° (CC) <12 <12 Production Hole Mud Program (LSND) 7"Casing Shoe to TD /nitial Value Final Value Density (ppg) 10 11 Yield Point (cP) 22_28 10-15 pH 9-9.5 9-9.5 API Filtrate cc / 30 min 4-6 4-5 HTHP @ 150° (CC) <12 <12 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please refer to information on file for diagrams and descriptions of the fluid system of Doyon 14. 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 fr/e 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(f); N/A -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: {70) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061 {a); N/A -Application is not for an exploratory or stratigraphic test well. ORIGINAL 2L-309 PERMIT IT Page 5 of 7 Printed: 22-Dec-05 • ~tion for Permit to Drill, Well 2L-309 Saved: 22-Dec-05 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (?T) for a well driNed 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); N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 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 Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Doyon 14 on 2L-309 Conductor. 2. NU and function test diverfer system and prepare spud mud. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (4347' MD/ 2393' TVD) according to directional plan. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface.l Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job or stage job with port collar (installed +/- 1000') if required to bring cement to surface. 5. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 7. RIH clean out to float collar 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. 9. Directionally drill 8-1/2" pil, of hole to 9195' MD/ 5675' TVD. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Plug and abandon pilot well bore and set kick off plug. P8~A program to follow ~''~©34pp~t Co~~~~~,v~f~'' 11. Kick off top of cement plug and directionally drill 8-1/2° hole to 14,364' MD! 5410' TVD. Run ~ 1.... MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 12. Run 7" 26# L-80 BTCM casing and cement. 13. Install packoff test BOPE 14. RIH clean out to float collar 15. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 16. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. 17. Directionally drill 6-1/8" hole to TD (14,960' MD/ 5925' TVD) according to directional plan. .~ ORIGINAL 2L-309 PERMIT IT Page 6 of 7 Printed: 22-Dec-05 r~tion for Permit to Drill, Well 2L-309 Saved: 22-Dec-05 18. Run 3-1/2" 9.3# L-80 EUE 8RD MOD liner and Baker ZXP hanger/Packer assembly. Pump cement followed by DP wiper plug and brine displacement fluid. Set packer 150' above intermediate casing shoe to provide appropriate liner lap. Reverse out. 19. Shut in BOP's and pressure test casing and liner to 3000 psi per AOGCC regulations. Record results 20. Run and land 3-1/2" completion tubing string and pressure test to 3000 psi. Record results. 21. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 22. Freeze protect outer annulus with diesel to below the permafrost. Set BPV. Release rig. 23. Clean location and RDMO. 24. MIRU Coil or E-Line, perforate well 25. RU Dowell, frac well. 26. RD Dowell, secure well, handover to production 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application fora Permit to DriN mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (74} a general description of how the operator p/ans to dispose of drilling mud and cuttings and a statement of whefher the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Incidental drilling fluids should be disposed of by annular disposal. Injection crews are expected to follow the ConocoPhillips Alaska recommended practices for annular injection which will be monitored by the Drilling Supervisor onsite. The appropriate injection logs will be maintained while operating and forwarded to ConocoPhillips Alaska drilling (Fax # 265-6224) on a daily basis. All issues concerning annular disposal will be brought to the Drilling Supervisor's attention. If annular disposal is not an option, incidental drilling fluids will have to be hauled to a KRU Class II disposal well (currently located at KRU 1 R-18) Fluids taken to a disposal well will require manifesting as specified in the Kuparuk Waste Management Plan (ENV-003: Green Book). Contact Kuparuk environmental group prior to commencing operations on any disposal well. Cement rinseate can only be disposed of down an annulus. Drill cuttings that are not disposed of via annular injection will either be stored in a temporary pit on the drill site, in DS 2X reserve pit (during bridge out), or hauled to Prudhoe for disposal at DS4 (if frozen). A list of approved 2N/2L well annuli is maintained by Sharon Allsup-Drake at 263-4612. The maximum volume of fluids approved by the AOGCC to be pumped down an annulus should never exceed 35,000 bbls. Accurate injection records are mandatory - 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Attachment 3 Well Schematic Attachment 4 Cement Program Summary L 2L-309 PERMIT tT Page 7 of 7 Printed: 22-Dec-05 2L-309 drilling Hazards iummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 12-1/4" Surface Hole / 9-5/8"" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate - Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Anti-collision Low Fellow directional plan as close as practical. Run SSG ros on surface interval 8-1/2" Intermediate/Pilot Hole / 7" Casing Interval Hazard Risk Level Miti ation Strate Gas Hydrates Low - Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe High Good hole cleaning practices, maintain optimum mud parameters, monitor PWD tool, decreased mud wei ht. Lost circulation Moderate Reduced um rates, mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 61-/'2" Production Hole / 3-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, material on Pressure location for increased mud wei ht. Stuck Pipe High Good hole cleaning practices, maintain optimum mud parameters, monitor PWD tool decreased mud wei ht Lost Circulation Moderate Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets um in out f ~ 2L-309 Drilling Hazards Summary 2L-309 Produce Proposed Completion Schematic Topset - 3-'/z' Monobore Completion 16" 62.6# Conductor +/- 115' MDlrVD TAM 9-5/8"Port Collar Grade BTC Threads (+/- 1000' MD/TVD) ConoaiPhillips 3-1/2" FMC Gen V Tubing Hanger, 3-1 /2" L-80 EUE8RD pin down Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface Special Drift 2.91" 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. Use of port collar at the discretion of the drilling team. Place GLMs at the following planned depths- adjust accordingly at TD TVD MD GL Valve #1 2250 3800 1.0" Camco #2 3750 9350 1.0" Camco #3 4700 12,900 1.0" Camco #4 5278 14,200 1.0" Camco Surface csg. 9-5/8" 40# L-80 BTC +/- 4,347' MD/ 2,393' TVD GLM: Camco 3-'/2' x 1" KBG-2-9' Mandrel w/DV and Latch 3-1/2" Camco 'D' nipple w/ 2.813" No-Go Profile. 3-1/2" x 6' L-80 (14,200' MD). Handling pups installed above and below 3-1/2" Baker GBH-22 casing seal assembly w/ 15' stroke, 3-1l2" L-80 EUE8RD box up Liner Assembly Arun on drillp%pe). 150' of liner overlap 7" 26.0# L-80 BTCM +/- 14,364' MD / 5,410' TVD Future , Perforations 3-1/2" 9.3# L-80 EUE +/- 14,960' MD / 5,924' TVD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with C-2 profile Baker 7" x 5" 80 KSI Hydraulic 'Flexlock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" BTC box x 3-1/2" EUE pin L 12/20/2005 CJ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-309 Plan: 2L-309 Plan: 2L-309wp06 Proposal Report 21 December, 2005 • M,AL.L1E31~.~~Tt~N SpellRry Dlri~ling Services ORIGINAL • • .,.....1......°..........11.......1.1...1.111..1............1.1...1.....1...11.1...1.1.....1..................1....nii~1.....1...1.11...1.1.....1...11.....1.........11,....1.....1...1.1...11.1.1.1.....1...1........1.....1....1......................~a,~na,.......a.-...nnn.m.,.°,.ann.m.,.m.,nn,.m.,.m.nnn.n,.,., Calala40n MetyyhoA: Minimum CurvaNre Scan Mell,di:s Trav~. Cy n°Ser Narth =~~`Fli~~1~5 E,ro,su,la°a: ~,,; a,~°n;~ Kuparuk River Unit € ~„'°`°;" WamingMMaE: ~"~~a`°° Kuparuk 2L Pad e ~ Gm°e°c DaWm: NAD 19]] QJADCON CONUS) Meg,e9c Mo°d: 905 2 L-309wp06 Plan: 2L-309 HALUBURTON -,ro,~~,d ~e~ec 11 S7U RKB' Planned Cbyon 14 vY 149.61H[(Doyon l4 (3°_~~715-3)) Plan: 2L-309 sper.y o.7u7~y services ,,,,r,~~giASP Y' SPZ76A7 aCi 2L-309wp06 ~:iu, nsP x aFio7~a-, 9-~ 7 sa Ft•L a s3z Fe: s~-rlwar~ FGdcQ Wit(3° qS, 105° TFO, 392 MD, 392ND 0 ~ Cafre Di', 4° IXS,CP TFO, 725ND, 72dND _ Sal S9; 74.5° INC, 23381vD, 7855 TVD I Si~-adc Rr#436TMD, 239TND, 0' DLS, 0' TFO 9 58" Cas-12 L4" Fide ~` '~9R4346MD,239zTVD C Ca6xe D'r,1° DLS, 93°TFO, 5338' MD, 2UiT TW o -2000 0 Sat Sai.74.S' INC, 8315 fvD.. 3471'iW ~+ ~z -4000 .~. Caine a; 4° DLS,180' TF0,133z8 MD, 48'IQTW -6000 7"Cs~ I6,2'Hale 7"CaJPt 743saMn, s4o9ND 74o5Fi°1L8 7Cg1 FEL.~~edST1QJR7lE Tag?tFaarleo-Sal Sai, 30'r7c, 74440MD, 5174ND Toe; 149602o'MD, 5924.6JT~D,162(i Fi°L&812F73; Ser2~iT7aJRfT/E , 0 2000 4000 6000 8000 West(-1/East(+l (2000 ft/inl - st trrrr~&63ZFH; c,~~T'IWI~/E Q w~aPoi# 3' DLS, 7~ TfD, 3921v1D, ~2TVD __ cnir.e Di 4° OIS, 0' TFO, 72i lv1D, 724'TVD 1 ~ 2 __ SatSi;745°BJC,23381v1D,7ffi6TW N 2000 S~'~~#43611vD,239TTVD,O'DLS,O"TFO _ ~-- ~ c«i„ea;,°as,sa°rro,5a3er,-n,2~'Tw ... m ~ sse^c~yPt4~sron,23azTw sransat7a.sir~c,s37snn,347rTw ca U 4000 m > '~ ~ ~--~ 6000 CasMa,A 0 2000 Cative Dr, 4° OLS, 18(P TFD, 13323 MD, 4874 TVD T'CSg-872'Fble T'C9g F; 7436P MD, 5409 TW,1406 Fi~l.& 102Q F$: S~rT1CN7m7E TargelRmm-SalS3i; 30' NC, 144401v1D, 5414 ND roe; 74s6oz6nn,~za.6o7w, 7sa~ r~a67zFe; seQSriarr~>E 4000 6000 8000 10000 -372'Lrr-61B'Fble 10000 312'Lrr-61B'Fiole ° 12000 t ) ~J ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2L Pad Welt: Plan 2L-309 Wellbore: PIan:2L-309 Design: 2L-309wp06 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: ND Refierence: MD Reference: North Reference: Survey Calculation Method: HALLIBURTON Sperry Drilling Services Well Plan: 2L-309 Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (F,cact solution) ~ System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) - Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan: 2L-309 Well Poskion +N/-S 0.00 ft Northing: 5,927,681.46 ft Latitude: 70° 12' 48.135" N +FJ-W 0.00 ft Easting: 461,079.47 ft Longkude: 150° 18' 51.743" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 115.30 ft __ Weltbore Plan: 2L-309 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 _ 12/20!2005 23.80 80.64 57,522 ___ Design 2L-300wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 4,367.00 Vertical Section: Depth From (ND) +N!-S +E/-W Direction (ft) (ft) (ft) (°) 34.30 0.00 0.00 135.93 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NlS +FJ-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°HOOft) (°HOOft) (°It00ft) (°) 4,367.00 74.50 105.00 2,397.85 -779.50 2,909.12 0.00 0.00 0.00 0.00 5,338.33 74.50 105.00 2,657.42 -1,021.75 3,813.23 0.00 0.00 0.00 0.00 8,315.66 74.50 135.92 3,471.36 -2,456.07 6,251.89 1.00 0.00 1.04 94.22 13,328.02 74.50 135.92 4,810.47 -5,926.16 9,611.80 0.00 0.00 0.00 0.00 14,440.64 30.00 135.94 5,474.60 -6,542.49 10,208.44 4.00 -4.00 0.00 179.99 14,960.26 30.00 135.94 5,924.60 -6,729.19 10,389.12 0.00 0.00 0.00 0.00 12/21/2005 3:06:16PM Page 2 of 7 COMPASS 2003.11 Build 50 ~` ~ .~~ ~..~ ~ • ~-! Sperry Drilling Services HALLIBURTON Conaco Philli s p Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Singl e User Db Local Co-ordinate Reference: Well Plan: 2L-309 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Project: Kuparuk River Unit MD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Site: Kuparuk 2L Pad North Reference: True Well: Plan : 2L-309 Survey Calculation Method: Minimum Curvatu re Wellbore: PIan: 2L-309 Design• 2L-309wp06 Planned Survey 2L-309wp06 Map Map i MD Inclination Azimuth TVD SSTVD +NlS +E1-W Northing Easting DLSEV Vert Section ii (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (~) (°fl0tlft) Iftl 100.00 0.00 0.00 100.00 -49.60 0.00 0.00 5,927,681.46 461,019.47 ~ 0.00 0.00 200.00 0.00 0.00 200.00 50.40 0.00 0.00 5,927,681.46 461,019.47 0.00 0.00 400.00 D.22 -' 105.00 400.00 250.40 0.00 0.01 5,927,681.46 461,019.48 0.11 0.01 500.00 3.22 105.00 499.94 350.34 -0.78 2.92 5,927,680.66 461,022.39 3.00 2.59 600.00 6.22 105.00 599.59 449.99 -2.91 10.88 5,927,678.49 461,030.33 3.00 9.66 700.00 9.22 105.00 698.67 549.07 -6.39 23.86 5,927,674.94 461,043.29 3.00 21.19 800.00 12.97 105.00 796.82 647.22 -11.33 42.29 5,927,669.91 461,061.69 3.74 37.55 900.00 16.97 105.00 893.41 743.81 -18.01 67.23 5,927,663.10 461,086.60 4.00 59.70 1,000.00 20.97 105.00 987.96 838.36 -26.42 98.62 5,927,654.53 461,117.94 4.00 87.58 1,100.00 24.97 105.00 1,080.01 930.41 -36.52 136.30 5,927,644.24 461,155.56 4.00 121.04 1, 200.00 28.97 105.00 1,169.12 1,019.52 -48.26 180.09 5,927,632.28 461,199.29 4.00 159.93 1,300.00 32.97 105.00 1,254.85 1,105.25 -61.57 229.78 5,927,618.71 461,248.91 4.00 204.06 1,400.00 36.97 105.00 1,336.78 1,187.18 -76.40 285.13 5,927,603.60 461,304.17 4.00 253.21 1,500.00 40.97 105.00 1,414.52 1,264.92 -92.67 345.86 5,927,587.01 461,364.81 4.OD 307.14 1,600.00 44.97 105.00 1,487.68 1,338.08 -110.31 411.68 5,927,569.04 461,430.54 4.00 365.60 1,700.00 48.97 105.00 1,555.91 1,406.31 -129.22 482.27 5,927,549.76 461,501.02 4.00 428.28 1,800.00 52.97 105.00 1,618.87 1,469.27 -149.32 557.29 5,927,529.27 461,575.92 4.00 494.90 1,900.00 56.97 105.00 1,67626 1,526.66 -170.51 636.36 5,927,507.68 461,654.88 4.00 565.13 2,000.00 60.97 105.00 1,727.81 1,578.21 -192.69 719.11 5,927,485.08 461,737.51 4.00 638.61 2,100.00 64.97 105.00 1,77325 1,623.65 -215.74 805.13 5,927,461.59 461,823.40 4.00 715.00 2,200.00 68.97 105.00 1,812.37 1,662.77 -239.55 894.01 5,927,437.32 461,912.14 4.00 793.93 2,300.00 72.97 105.00 1,844.97 1,695.37 -264.01 985.30 5,927,412.39 462,003.30 4.00 875.00 2,400.00 74.50 105.00 1,872.19 1,722.59 -288.91 1,078.24 5,927,387.01 462,096.10 1.53 957.54 2,500.00 74.50 105.00 1,898.91 1,749.31 -313.86 1,171.32 5,927,361.59 462,189.04 0.00 1,040.20 2,600.00 74.50 105.00 1,925.64 1,776.04 -338.80 1,264.40 5,927,336.17 462,281.98 0.00 1,122.86 2,700.00 74.50 105.00 1,952.36 1,802.76 -363.74 1,357.48 5,927,310.76 462,374.92 0.00 1,205.52 2,800.00 74.50 105.00 1,979.08 1,829.48 -388.68 1,450.56 5,927,285.34 462,467.86 0.00 1,288.18 2,900.00 74.50 105.00 2,005.81 1,856.21 -413.62 1,543.64 5,927,259.92 462,560.81 0.00 1,370.84 3,000.00 74.50 105.00 2,032.53 1,882.93 -438.56 1,636.72 5,927,234.50 462,653.75 0.00 1,453.50 3,100.00 74.50 105.00 2,059.26 1,909.66 -463.50 1,729.80 5,927,209.08 462,746.69 0.00 1,536.16 3,200.00 74.50 105.00 2,085.98 1,936.38 -488.44 1,822.88 5,927,183.66 462,839.63 0.00 1,618.82 3,300.00 74.50 105.00 2,112.70 1,963.10 -513.38 1,915.96 5,927,158.25 462,932.57 0.00 1,701.48 3,400.00 74.50 105.00 2,139.43 1,989.83 -538.32 2,009.04 5,927,132.83 463,025.51 0.00 1,784.14 3,500.00 74.50 105.00 2,166.15 2,016.55 -563.26 2,102.12 5,927,107.41 463,118.45 0.00 1,866.80 3,600.00 74.50 105.00 2,192.88 2,043.28 -588.20 2,195.20 5,927,081.99 463,211.39 0.00 1,949.46 3,700.00 74.50 105.00 2,219.60 2,070.00 -613.14 2,288.28 5,927,056.57 463,304.33 0.00 2,032.12 3,800.00 74.50 105.00 2,246.32 2,096.72 -638.08 2,381.36 5,927,031.15 463,397.27 0.00 2,114.78 3,900.00 74.50 105.00 2,273.05 2,123.45 -663.02 2,474.44 5,927,005.74 463,490.21 0.00 2,197.44 4,000.00 74.50 105.00 2,299.77 2,150.17 -687.96 2,567.52 5,926,980.32 463,583.15 0.00 2,280.10 4,100.00 74.50 105.00 2,326.49 2,176.89 -712.90 2,660.60 5,926,954.90 463,676.09 0.00 2,362.76 4,200.00 74.50 105.00 2,353.22 2,203.62 -737.85 2,753.68 5,926,929.48 463,769.03 0.00 2,445.42 4,300.00 74.50 105.00 2,379.94 2,230.34 -762.79 2,846.76 5,926,904.06 463,861.97 0.00 2,528.08 4,346.99 ~ 74.50 105.00 2,392.50 2,242.90 -774.51 2,890.49 5,926,892.12 463,905.64 O.DO 2,566.92 9 518" Cgs -12 1/4" Hole 4,367.00 74.50 105.00 2,397.85 2,248.25 -779.50 - 2,909.12 5,926,887.03 463,924.24 0.00 2,583.46 Sidetrack Point; 4367' MD, 2397' TVD, 0° DLS, 0° TFO 4,400.00 74.50 105.00 2,406.67 2,257.07 -787.73 2,939.84 5,926,878.64 463,954.91 0.00 2,610.74 4,500.00 74.50 105.00 2,433.39 2,283.79 -812.67 3,032.92 5,926,853.23 464,047.85 0.00 2,693.40 4,600.00 74.50 105.00 2,460.11 2,310.51 -837.61 3,126.00 5,926,827.81 464,140.79 0.00 2,776.06 12/21/2005 3:06:16PM Page 3 of 7 COMPASS 2003.11 Build 50 ~ ~~~ ~-' • Sperry Drilling Services ConocoPh~lli 5 HALLIBURTC]N AI~ a Planning Report -Geographic g~~ Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 2L-309 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Project: Kuparuk River Unit MD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Site: Kuparuk 2L Pad North Reference: True Well: Plan: 2L-309 Survey Calculation Method: Minimum Curvature Wellbore: PIan:2L-309 Design: 2L-309wp06 Planned Survey 2L-309wp06 Map Map ', MD Inclination Azimuth TVD SSTVD +NI~S +E/-W Northing Easting pLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 4,700.00 74.50 105.00 2,486.84 2,337.24 -862.55 3,219.07 5,926,802.39 464,233.73 0.00 2,858.72 4,729.05 74.50 105.00 2,494.60 2,345.00 -869.79 3,246.11 5,926,795.01 464,260.73 0.00 2,882.73 C80 (K10) 4,800.00 74.50 105.00 2,513.56 2,363.96 -887.49 3,312.15 5,926,776.97 464,326.67 0.00 2,941.38 4,900.00 74.50 105.00 2,540.29 2,390.69 -912.43 3,405.23 5,926,751.55 464,419.61 0.00 3,024.04 5,000.00 74.50 105.00 2,567.01 2,417.41 -937.37 3,498.31 5,926,726.13 464,512.55 0.00 3,106.70 5,100.00 74.50 105.00 2,593.73 2,444.13 -962.31 3,591.39 5,926,700.72 464,605.49 0.00 3,189.36 5,200.00 74.50 105.00 2,620.46 2,470.86 -987.25 3,684.47 5,926,675.30 464,698.43 0.00 3,272.02 5,300.00 74.50 105.00 2,647.18 2,497.58 -1,012.19 3,777.55 5,926,649.88 464,791.38 0.00 3,354.68 5,338.33 74.50 105.00 2,657.42 2,507.82 -1,021.75 3,813.23 5,926,640.14 464,827.00 0.00 3,386.36 Continue D}r; f ° DLS, 94° TFO, 5338' MD, 265T TVD 5,400.00 74.46 105.64 2,673.93 2,524.33 -1,037.45 3,870.54 5,926,624.14 464,884.22 1.00 3,437.50 5,500.00 74.39 106.67 2,700.78 2;551.18 -1,064.25 3,963.06 5,926,596.87 464,976.59 1.00 3,521.11 5,600.00 74.32 107.71 2,727.75 2,578.15 -1,092.72 4,055.05 5,926,567.93 465,068.43 1.00 3,605:54 5,700.00 74.27 108.75 2,754.82 2,605.22 -1,122.83 4,146.48 5,926,537.35 465,159.70 1.00 3,690.77 5,800.00 7421 109.78 2,781.98 2,632.38 -1,154.58 4,237.33 5,926,505.13 465,250.37 1.00 3,776.78 5,900.00 74.16 110.82 2,809.23 2,659.63 -1,187.97 4,327.57 5,926,471.28 465,340.42 1.00 3,863.53 6,000.00 74.12 111.86 2,836.56 2,686.96 -1,222.98 4,417.17 5,926,435.81 465,429.83 1.00 3,951.00 6,100.00 74.08 112.90 2,863.96 2,714.36 -1,259.60 4,506.09 5,926,398.74 465,518.56 1.00 4,039.16 6,200.00 74.05 113.94 2,891.41 2,741.81 -1,297.82 4,594.33 5,926,360.07 465,606.58 1.00 4,127;99 6,300.00 74.02 114.98 2,918.92 2,769.32 -1,337.63 4,681.84 5,926,319.81 465,693.88 1.00 4,217.46 6,400.00 73.99 116.02 2,946.47 2,796.87 -1,379.01 4,768.60 5,926,277.99 465,780.42 1.00 4,307.54 6,500.00 73.98 117.06 2,974.06 2,824.46 -1,421.96 4,854.59 5,926,234.60 465,866.18 1.00 4,398.21 6,600.00 73.96 118.10 3,001.68 2,852.08 -1,466.45 4,939.78 5,926,189.67 465,951.13 1.00 4,489.43 6,700.00 73.95 119.14 3,029.31 2,879.71 -1,512.49 5,024.14 5,926,143.20 466,035.24 1.00 4,581.18 6,800.00 73.95 120.18 3,056.96 2,907.36 -1,560.05 5,107.65 5,926,095.22 466,118.50 1.00 4,673.44 6,900.00 73.95 121.22 3,084.61 2,935.01 -1,609.11 5,190.28 5,926,045.73 466,200.87 1.00 4,766.16 7,000.00 73.96 122.26 3,112.25 2,962.65 -1,659.67 5,272.01 5,925,994.76 466,282.32 1.00 4,859.34 7,100.00 73.97 123.30 3,139.87 2,990.27 -1,711.71 5,352.81 5,925,942.31 466,362.85 1.00 4,952.92 7,200.00 73.99 124.34 3,167.48 3,017.88 -1,765.21 5,432.66 5,925,888.40 466,442.41 1.00 5,046.90 7,300.00 74.01 125.38 3,195.05 3,045.45 -1,820.15 5,511.53 5,925,833.06 466,520.99 1.00 5,141.23 7,400.00 74.03 126.42 3,222.58 3,072.98 -1,876.53 5,589.40 5,925,776.28 466,598.56 1.00 5,235.90 7,500.00 74.06 127.46 3,250.06 3,100.46 -1,934.32 5,666.24 5,925,718.11 466,675.09 1.00 5,330.87 7,600.00 74.10 128.50 3,277.49 3,127.89 -1,993.50 5,742.04 5,925,658.54 466,750.58 1.00 5,426.11 7,700.00 74.14 129.54 3,304.85 3,155.25 -2,054.05 5,816.77 5,925,597.61 466,824.98 1.00 5,521.59 7,800.00 74.19 130.58 3,332.13 3,182.53 -2,115.97 5,890.40 5,925,535.32 466,898.29 1.00 5,617.29 7,900.00 74.24 131.62 3,359.34 3,209.74 -2,179.22 5,962.91 5,925,471.69 466,970.47 1.00 5,713.18 8,000.00 74.30 132.65 3,386.46 3,236.86 -2,243.80 6,034.29 5,925,406.76 467,041.50 1.00 5,809.22 8,100.00 74.36 133.69 3,413.47 3,263.87 -2,309.67 6,104.51 5,925,340.53 467,111.37 1.00 5,905.39 8,200.00 74.42 134.73 3,440.38 3,290.78 -2,376.83 6,173.54 5,925,273.03 467,180.05 1.00 6,001.65 8,300.00 74.49 135.76 3,467.18 3,317.58 -2,445.24 6,241.37 5,925,204.27 467,247.52 1.00 6,097.99 8,315.66 74.50 135.92 3,471.36 3,321.76 -2,456.07 6,251.89 5,925,193.39 467,257.98 1.00 6,113.08 Start Sail; 74.5° iNC, 8315' MD, 3471' TVD 8,400.00 74.50 135.92 3,493.90 3,344.30 -2,514.46 6,308.42 5,925,134.72 467,314.21 0.00 6,194.35 8,500.00 74.50 135.92 3,520.61 3,371,01 -2,583.69 6,375.45 5,925,065.15 467,380.87 0.00 6,290.72 8,600.00 74.50 135.92 3,547.33 3,397.73 -2,652.92 6,442.49 5,924,995.58 467,447.54 0.00 6,387.08 8,700.00 74.50 135.92 3;574.04 3,424.44 -2,722.15 6,509.52 5,924,926.01 467,514.21 0.00 6,483.45 8,800.00 74.50 135.92 3,600.76 3,451.16 -2,791.38 6,576.55 5,924,856.44 467,580.88 0.00 6,579.81 8,900.00 74.50 135.92 3,627.48 3,477.88 -2,860.61 6,643.58 5,924,786.87 467,647.55 0.00 6,676.18 12/21/2005 3:06:16PM Page 4 of 7 COMPASS 2003.11 Bulld 50 R1 • ~-' h Sperry Drillin g Services HALLIBURTC~N Conaco ~lli P ps Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Singl e User Db Lo cal Co-ordinate Reference: Well Plan: 2L-309 Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Planned Doyon 1 4 @ 149 60ft (Doyon 14 (34.3 + 115.3)) Project: Kupanik River Unit MD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Site: Kuparuk 2L Pad North Reference: True Well: Plan ; 2L-309 Su rvey Calculation Method: Minimum Curvatu re Wellbore: Plan ; 2L-309 Design: 2L-309wp06 Planned Survey 2L-309wp06 Map Map MD I nclination Azimuth ND SSTVD +Nl-S +E/-W Northing Easting DLSEY Yert Section Ift) (°) (°) fft) (ft) (ft) (ft) (ft) (ft) (°1100ft) Iftj 9,000.00 74.50 135.92 3,654.19 3,504.59 -2,929.84 6,710.62 5,924,717.30 467,714.21 0.00 6,772.54 9,100.00 74.50 135.92 3,680.91 3,531.31 -2,999.07 6,777.65 5,924,647.73 467,780.88 0.00 6,868.91 9,200.00 74.50 135.92 3,707.62 3;558.02 -3,068.30 6,844.68 5,924,578.16 467,847.55 0.00 6,965.27 9,300.00 74.50 135.92 3,734.34 3;584.74 -3,137.53 6,911.71 5,924,508.59 467,914.22 0.00 7,061.64 9,400.00 74.50 135.92 3,761.06 3,611.46 -3,206.76 6,978.75 5,924,439.03 467,980.88 0.00 7,158.01 9,500.00 74.50 135.92 3,787.77 3,638.17 -3,276.00 7,045.78 5,924,369.46 468,047.55 0.00 7,254.37 9,600.00 74.50 135.92 3,814.49 3,664.89 -3,345.23 7,112.81 5,924,299.89 468,114.22 0.00 7,350.74 9,700.00 74.50 135.92 3,841.20 3,691.60 -3,414.46 7,179.84 5,924,230.32 468,180.89 0.00 7,447.10 9,800.00 74.50 135.92 3,867.92 3,718.32 -3,483.69 7,246.88 5,924,160.75 468,247.55 0.00 7,543.47 9,900.00 74.50 135.92 3,894.64 3,745.04 -3,552.92 7,313.91 5,924,091.18 468,314.22 0.00 7,639.83 10,000.00 74.50 135.92 3,921.35 3,771.75 -3,622.15 7,380.94 5,924,021.61 468,380.89 0.00 7,736.20 10,012.16 74.50 135.92 3,924.60 3,775.00 -3,630.57 7,389.09 5,924,013.15 468,389.00 0.00 7,747.91 C50 10,100.00 74.50 135.92 3,948.07 3,798.47 -3,691.38 7,447.97 5,923,952.04 468,447.56 0.00 7,832.56 10,200.00 74.50 135.92 3,974.78 3,825.18 -3,760.61 7,515.01 5,923,882.47 468,514.22 0.00 7,928.93 10,300.00 74.50 135.92 4,001.50 3,851.90 -3,829.84 7,582.04 5,923,812.90 468,580.89 0.00 8,025.29 10,400.00 74.50 135.92 4,028.22 3,878.62 -3,899.07 7,649.07 5,923,743.33 468,647.56 0.00 8,121.66 10,500.00 74.50 135.92 4,054.93 3,905.33 -3,968.30 7,716.10 5,923,673.77 468,714.23 0.00 8,218.02 10,600.Q0 74.50 135.92 4,081.65 3,932.05 -4,037.53 7,783.14 5,923,604.20 468,780.90 0.00 8,314.39 10,700.00 74.50 135.92 4,108.36 3,958.76 -4,106.76 7,850.17 5,923,534.63 468,847.56 0.00 8,410.75 10,800.00 74.50 135.92 4,135.08 3,985.48 -4,176.00 7,917.20 5,923,465.06 468,914,23 0.00 8,507.12 10,900.00 74.50 135.92 4,161.80 4,012.20 -4,245.23 7,984.24 5,923,395.49 468,980.90 0.00 8,603.48 11,000.00 74.50 135.92 4,188.51 4,038.91 -4,314.46 8,051.27 5,923,325.92 469,047.57 0.00 8,699.85 11,100.00 74.50 135.92 4,215.23 4,065.63 -4,383.69 8,118.30 5,923,256.35 469,114.23 0.00 8,796.21 11,200.00 74.50 135.92 4,241.94 4,092.34 -4,452.92 8,185.33 5,923,186.78 469,180.90 0.00 8,892.58 11,300.00 74.50 135.92 4,268.66 4,119.06 -4,522.15 8,252.37 5,923,117.21 469,247.57 0.00 8,988.94 11,322.23 74.50 135.92 4,274.60 4,125.00 -4,537.54 8,267.27 5,923,101.75 469,262.39 0.00 9,010.37 C40 11,400.00 74.50 135.92 4,295.38 4,145.78 -4,591.38 8,319.40 5,923,047.64 469,314.24 0.00 9,085.31 11,500.00 74.50 135.92 4,322.09 4,172.49 -4,660.61 8,386.43 5,922,978.08 469,380.90 0.00 9,181.67 11,600.00 74.50 135.92 4,348.81 4,199.21 -4,729.84 8,453.46 5,922,908.51 469,447.57 0.00 9,278.04 11,700.00 74.50 135.92 4,375.52 4,225.92 -4,799.07 8,520.50 5,922,838.94 469,514.24 0.00 9,374.40 11,800.00 74.50 135.92 4,402.24 4,252.64 -4,868.30 8,587.53 5,922,769.37 469,580.91 0.00 9,470.77 11,900.00 74.50 135.92 4,428.96 4,279.36 -4,937.53 8,654.56 5,922,699.80 469,647.57 0.00 9,567.14 12,000.00 74.50 135.92 4,455.67 4,306.07 -5,006.76 8,721.59 5,922,630.23 469,714.24 0.00 9,663.50 12,100.00 74.50 135.92 4,482.39 4,332.79 -5,075.99 8,788.63 5,922,560.66 469,780.91 0.00 9,759.87 12,126.99 74.50 135.92 4,489.60 4,340.00 -5,094.68 8,806.72 5,922,541.88 469,798.91 0.00 9,785.88 C37 12,200.00 74.50 135.92 4,509.10 4,359.50 -5,145.23 8,855.66 5,922,491.09 469,847.58 0.00 9,856.23 12,300.00 74.50 135.92 4,535.82 4,386.22 5,214.46 8,922.69 5,922,421.52 469,914.25 0.00 9,952.60 12,400.00 74.50 135.92 4;562.54 4,412.94 -5,283.69 8,989.72 5,922,351.95 469,980.91 0.00 10,048.96 12,500.00 74.50 135.92 4,589.25 4,439.65 -5,352.92 9,056.76 5,922,282.38 470,047.58 0.00 10,145.33 12,600.00 74.50 135.92 4,615.97 4,466.37 -5,422.15 9,123.79 5,922,212.82 470,114.25 0.00 10,241.69 12,700.00 74.50 135.92 4,642.68 4,493.08 -5,491.38 9,190.82 5,922,143.25 470,180.92 0.00 10,338.06 12,800.00 74.50 135.92 4,669.40 4,519.80 -5,560.61 9,257.85 5,922,073.68 470,247.58 0.00 10,434.42 12,900.00 74.50 135.92 4,696.12 4,546.52 -5,629.84 9,324.89 5,922,004.11 470,314.25 0.00 10,530.79 13,000.00 74.50 135.92 4,722.83 4,573.23 -5,699.07 9,391.92 5,921,934.54 470,380.92 0.00 10,627.15 13,100.00 74.50 135.92 4,749.55 4,599.95 -5,768.30 9,458.95 5,921,864.97 470,447.59 0.00 10,723.52 12/21/2005 3:06:16PM Page 5 of 7 COMPASS 2003.11 Build 50 ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2L Pad Well: Plan: 2L-309 WeNbore: PIan:2L-309 Design: 2L-309wp06 Planned Survey 2L-309wp06 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBtJRTON Spelrry Drilling Sen-ices Well Plan: 2L-309 Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +NlS +E!-W Northing Easting DLSEV Vert Section (ft} (°) (°) (ft} (ft) (ft) (ft) lft) (ft) (°It00ft) (ft} 13,100.19 74.50 135.92 4,749.60 4,600.00 -5,768.44 9,459.08 5,921,864.84 470,447.72 0.00 10,723.70 Iceberg zone - - est 13,200.00 74.50 135.92 4,776.26 4,626.66 -5,837.53 9,525.98 5,921,795.40 470,514.25 0.00 10,819.88 13,300.00 74.50 135.92 4,802.98 4,653.38 -5,906.76 9,593.02 5,921,725.83 470,580.92 0.00 10,916.25 13,328.02 74.50 135.92 4,810.47 4,660.87 -5,926.16 9,611.80 5,921,706.34 470,599.60 0.00 10,943.25 Continue Dir; 4° DLS, 180° TFO, 13328' MD, 4810' TVD 13,400.00 71.63 135.92 4,831.43 4,681.83 -5,975.63 9,659.69 5,921,656.63 470,647.24 4.00 11,012.10 13,500.00 67.63 135.93 4,866.24 4,716.64 -6,042.96 9,724.89 5,921,588.97 470,712.07 4.00 11,105.83 13,600.Q0 63.63 135.93 4,907.50 4,757.90 -6,108.39 9,788.23 5,921,523.22 470,775.08 4.00 11,196.89 13,700.00 59.63 135.93 4,955.01 4,805.41 -6,171.59 9,849.42 5,921,459.71 470,835.93 4.00 11,284.86 13,800.00 55.63 135.93 5,008.55 4,858.95 -6,232.26 9,908.15 5,921,398.75 470,894.34 4.00 11,369.30 13,900.00 51.63 135.93 5,067.84 4,918.24 -6,290.09 9,964.14 5,921,340.63 470,950.03 4.00 11,449.80 14,000.00 47.63 135.93 5,132.61 4,983.01 -6,344.82 10,017.12 5,921,285.64 471,002.72 4.00 11,525.97 14,100.00 43.63 135.93 5,202.53 5,052.93 -6,396.17 10,066.83 5,921,234.04 471,052.15 4.00 11,597.43 14,200.00 39.63 135.93 5,277.26 5,127.66 -6,443.89 10,113.02 5,921,186.08 471,098.09 4.00 11,663.85 14,300.00 35.63 135.94 5,356.45 5,206.85 -6,487.75 10,155.47 5,921,142.01 471,140.31 4.00 11,724.88 14,364.38 33.05 135.94 5,409.60 5,260.00 -6,513.84 10,180.72 5,921,115.79 471,165.42 4.00 11,761.19 7" Csg Pt; 14364' MD, 5409' TVD; 1405' FNL 8 1020' FEL; Sec25-T10N-ROTE - 7" Csg - 8 1/2" Hole 14,400.00 31.63 135.94 5,439.70 5,290.10 -6,527.53 10,193.97 5,921,102.03 471,178.60 3.99 11,780.25 14,417.44 30.93 135.94 5,454.60 5,305.00 -6,534.04 10,200.26 5,921,095.50 471,184.86 4.01 11,789.30 T3.1 14,440.64 30.00 135.94 5,474.60 5,325.00 -6,542.49 10,208.44 5,921,087.00 471,193.00 4.00 11,801.06 Target Romeo -Start Sail; 30° INC, 14440' MD, 5474' TVD - T3 -Top Bermuda - 2L309wp06 Romeo Target 14,500.00 30.00 135.94 5;526.01 5,376.41 -6,563.82 10,229.08 5,921,065.57 471,213.53 0.00 11,830.74 14,596.52 30.00 135.94 5,609.60 5,460.00 -6,598.50 10,262.65 5,921,030.72 471,246.91 0.00 11,879.01 T2 -Base Reservoir 14,600.00 30.00 135.94 5,612.61 5,463.01 -6,599.75 10,263.85 5,921,029.46 471,248.11 0.00 11,880.74 14,700.00 30.00 135.94 5,699.21 5,549.61 -6,635.68 10,298.63 5,920,993.36 471,282.69 0.00 11,930.74 14,769.73 30.00 135.94 5,759.60 5,610.00 -6,660.73 10,322.87 5,920,968.18 471,306.80 0.00 11,965.61 C-35 (K-3) 14,800.00 30.00 135.94 5,785.81 5,636.21 -6,671.61 10,333.40 5,920,957.25 471,317.27 0.00 11,980.74 14,900.00 30.00 135.94 5,872.42 5,722.82 -6,707.54 10,368.17 5,920,921.14 471,351.85 0.00 12,030.74 14,960.26 30.00 135.94 5,924.60 5,775.00 -6,729.19 10,389.12 5,920,899.39 471,372.69 0.00 12,060.87 Ice; 14960.26' Mb, 5924.60' TYD, 1620' FNL 8 812' FEL; Sec25-T10N-ROTE - 3 1/2 " Lnr - Geologic Targets Plan : 2L-309 TVD Target Name +NIS +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 5,474.60 2L-309wp06 Romeo Target -6,542.49 10,208.44 5,921,087. 00 471,193.00 - Circle (rad ius 100.00) 1?J21/2005 3:06:16PM Page 6 of 7 COMPASS 2003.11 Build 50 ~~ Sperry Drilling Services ConocoPh~llips Planning Report -Geographic Alaska HALLI~URTON Sperry Drilling Services Database: EDM 2003.11 Single User Db Locat Co-ordinate Reference: Well Plan: 2L-309 Company: Conoco Phillips Alaska (Kuparuk) TVD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Project: Kuparuk River Unit MD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Site: Kuparuk 2L Pad North Reference: True Well: Plan: 2L-309 Survey Calculation Method: Minimum Curvature Wellbore: Plan 2L-309 Design: 2L-309wp06 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ftl (ftl (") (") 4,346.99 2,392:50 9S/8 12-1/4 14,364.38 5,409.60 7 8-112 14,960.25 5,924.60 3-1/2 ~ Prognosed Formation Intersection Points Measured Vertical 1 Depth Inclination Azimuth Depth +Nl-E +FJ-W (ft) (°) (°) (ft) (ftl (ft) Name 4,729.05 74.50 105.00 2,494.60 -869.79 3,246.11 C80 (K10) 10,012.16 74.50 135.92 3,924.60 -3,630.57 7,389.09 C50 11,322.23 74.50 135.92 4,274.60 -4,537.54 8,267.27 C40 12,126.99 74.50 135.92 4,489.60 -5,094.68 8,806.72 C37 13,100.19 74.50 135.92 4,749.60 -5, 768.44 9,459.08 Iceberg zone - - est 14,417.44 30.93 135.94 5,454.60 -6,534.04 1Q200.26 T3.1 14,440.64 30.00 135.94 5,474.60 -6,542.49 10,208.44 T3 -Top Bermuda 14,596.52 30.00 135.94 5,609.60 -6,598.50 10,262.65 T2 -Base Reservoir 14,769.73 30.00 135.94 5,759.60 -6,660.73 10,322.87 C-35 (K3) 12/21/2005 3:06:16PM Page 7 of 7 COMPASS 2003.118ui1d 50 ~~ '. • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-309 Plan: 2L-309PB1 Plan: 2L-309PB1wp06 Proposal Report 21 December, 2005 C7 Sperry Dri~Elnc~ Services ORIGINAL • • ~unnnnnumnnwnnnmmnnninnnmuwnumm~wwmwmmmnunnnnunnunnmm~mimnunnwmnnnnmwmwnnnmumm~wmwmnmwnuwnmmmmm~nnnnnnnunnnnnnnnmiunnmiwxnwmmm~nmmnnnnmm~nnunnmm~mnwiw =_ calaWEm MMyy OJ: Minimum Curvature ` Scan MnMJ: Trav~. Cyli aSa North _CKid'1UCC7P`~l~~~liJS E~su~a~n: ~,,; ,c ; Kuparuk River Unit ~, ~ € •~:.".;., WamirgMeOhod: Pw~e=Ba"° Geoeenc °an,m: ruD isn rvaocon conus~ = _ ~""~°a° ~ Kuparuk 2L Pad Plan: 2L-309 2L-309PB1 wp06 _FiALLIBURTON ero~~on~.~'°~~~~ n;.x~ _ - HKa r ,,,.i y<,~,±a:,.~~cnlrl~yo„iaf-;a3,a~,.l~ Plan: 2L-309PB1 CRY DAlling s.rv~c.a rvortn~nc~yasa v e ra;i .- 2L-309P61 wp06 Ea4ir ASP%. 4f,11~~9s. SFL; 167 FTL&632f~-; Se[22 T1W RLT/E Krklf R.Y# 3' DLS 1Cb° TFO, 39Z ND, 392ND 0 CAf14lB DI; 4° pS, 0' TFO,TS ND, 724 TVD Sal Sa{ 74S° NC, 23361vD,1~'TW /'\ ~~ ~~ ' Cos-121kP Floe 956 °~ -600 96B'CS9Pt43461vD,23B2ND ± Catiiis a; 5° OLS,156° TFO, 43T ND, Zi97ND 0 z -1200 .~ O 5}ai 5ai; 56.36° ric, ease ND, 424Q ND ~ Tayellw~~aEarMD.szza'ND -1800 812' Ta9e1(rcek 9195MD, 5674 ND, 2733 R~L&453T R3; Sed3TI0NRfT/E 9 ~ 0 600 1200 1800 2400 3000 3600 West(-)/East(+) (600 ft/in) - 511;,64' FTL&632 r8; Scc22-T,Wfd77E O ° FGdct]rRrR 3 IXS,105TFO, 397MD, 392ND .--. CatiteDF,4°DI-SO°TF0,7251vD,72CTW ~_ ~ 1 ~ ~ _ StatlBai; 74.5 NC, Zi38' MD,1855TVD _ 2000 ' 956'CcS-12V4"FkJe ' _ z CsgPk4?46MD,2392TVD 9fie3 ~ _ _ ,~, ^ v _ t? ~~~ Co'§taDi;50.S,156°1F0.436T1uD.2~7'TVD m ~ U = ~ 4000 Sat~i:56.36° NC, f668' MD, 424(7 ND _ > `~ a, ~ Tagel (F~idk 86D0'MD, 5224'TW __ t` loel~agmre--eS = 812' Flole __ TayaRoe~slssnn,~7atw,a~rry.aastrr~sadar~a~~ ~ ~ = 309PB 7 wp~6 t -4000 -2000 0 iuMmMm MmnwMnMmMwunmunuwnnwnmwawnmmnunu~imunwixa~i- iwn tio 2000 4{{000\ 6000 8000 n at 1 3.93° (2000. I U i n 1 n~~nmwwwmnnwnmm~wmwimniwmimnun - 4~ n-. P ~ '~t 5 ~~ I ~~ E ~... C©nocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2L Pad Well: Plan: 2L-309 Wellbore: PIan:2L-309P61 Design: 2L-309 PB 1 wp06 Sperry Drilling Services Planning Report -Geographic Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBURTCIN Sperry Drilling Services Well Plan: 2L-309 Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (F~cact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan: 2L-309 Well Position +N/S 0.00 ft Northing:. 5,927,681.46 ft Latitude: 70° 12' 48.135" N +E/_yy 0.00 ft Easting: 467,079.47ft Longitude: 150° 18' 51.743" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 115.30ft Wellbore Plan: 2L-309P81 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 12/20/2005 23.80 80.64 57,522 Design - - 2L-309P61wp06 _ _ _ -- _ - - _---_ - - - - __ Audit Notes: Version: Phase: PLAN Vertical Section: Depth From (TVD) +NlS (ft) (ft) 34.30 0.00 Tie On Depth: +er-w (ft) 0.00 34.30 Direction (°) 135.93 Plan Summary Measured Vertical Dogleg Build Turn Depth inclination Azimuth Depth +N!-S +E/-W Rate Rate Rate TFO (ft) (°) (°) lit) (ft) (ft) (°/100ft) (°110aft) (°/10Qft) (°) 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 392.50 0.00 0.00 392.50 0.00 0.00 0.00 0.00 0.00 0.00 725.83 10.00 105.00 724.14 -7.51 28.03 3.00 3.00 0.00 105.00 1,225.83 30.00 105.00 1,191.61 -51.55 192.37 4.00 4.00 0.00 0.00 2,338.33 74.50 105.00 1,855.71 -273.53 1,020.85 4.00 4.00 0.00 0.00 4,367.00 74.50 105.00 2,397.85 -779.50 2,909.12 0.00 0.00 0.00 0.00 6,868.65 55.36 261.42 4,240.53 -1,600.10 3,167.64 5.00 -0.76 6.25 156.29 8,600.01 55.36 261.42 5,224.60 -1,812.58 1,759.08 0.00 0.00 0.00 0.00 9,195.95 25.00 261.42 5,674.60 -1,869.27 1,383.31 5.09 -5.09 0.00 180.00 12/21/2005 10:42:14AM Page 2 of 6 COMPASS 2003.11 Build 50 ConocoPhittips Alaska Database: Company: Project: Site: Well: Wellbore: Design: EDM 2003.11 Single User Db ConocoPhillips Alaska {Kuparuk) Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-309 Plan: 2L-309P61 2L-309PB1wp06 Planned Survey 2L-309 PB 1 wp06 Sperry Drilling Services Planning Report -Geographic Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: MAIrLl1BURT~N Sperry Drilling Services Well Plan: 2L-309 Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +NlS +FJ-W Northing Easting DLSEV Vert Section Ift) (°) (°) (ft) (ft) (ft) (ft) (ft) {ft) (°/tilOft) (ftj ~ 34.30 0.00 0.00 34.30 -115.30 0.00 0.00 5,927,681.46 461,019.47 0.00 0.00 $HL; 164' FNL $ 632' FEL ; Sec22-T10N-R07E 100.00 0.00 0.00 100.00 -49.60 0.00 0.00 5,927,681.46 461,019.47 0.00 0.00 200.00 0.00 0.00 200.00 50.40 0.00 0.00 5,927,681.46 461,019.47 0.00 0.00 392.50 0.00 0.00 392.50 242.90 0.00 0.00 5,927,681.46 461,019.47 0.00 0.00 Kick-off Point; 3° DLS, 105° TFO, 392' MD, 392' TVD 400.00 0.22 105.00 400.00 250.40 0.00 0.01 5,927,681.46 461,019.48 3.00 0.01 500.00 3.22 105.00 499.94 350.34 -0.78 2.92 5,927,680.66 461,022.39 3.00 2.59 600.00 6.22 105.00 599.59 449.99 -2.91 10.88 5,927,678.49 461,030.33 3.00 9.66 700.00 9.22 105.00 698.67 549.07 -6.39 23.86 5,927,674.94 461,043.29 3.00 21.19 725.83 10.00 105.00 724.14 574.54 -7.51 28.03 5,927,673.81 461,047.45 3.00 24.89 Continue Dir; 4° DLS, 0° TFO, 725' MO , 724' TVD 800.00 12.97 105.00 796.82 647.22 -11.33 42.29 5,927,669.91 461,061.69 4.00 37.55 900.00 16.97 105.00 893.41 743.81 -18.01 67.23 5,927,663.10 461,086.60 4.00 59.70 1,000.00 20.97 105.00 987.96 838.36 -26.42 98.62 5,927,654.53 461,117.94 4.00 87.58 1,100.00 24.97 105.00 1,080.01 930.41 -36.52 136.30 5,927,644.24 461,155.56 4.00 121.04 1,200.00 28.97 105.00 1,169.12 1,019.52 -48.26 180.09 5,927,632.28 461,199.29 4.00 159.93 1,225.83 30.00 105.00 1,191.61 1,042.01 -51.55 192.37 5,927,628.93 461,211.55 4.00 170.84 1,300.00 32.97 105.00 1,254.85 1,105.25 -61.57 229.78 5,927,618.71 461,248.91 4.00 204.06 1,400.00 36.97 105.00 1,336.78 1,187.18 -76.40 285.13 5,927,603.60 461,304.17 4.00 253.21 1,500.00 40.97 105.00 1,414.52 1,264.92 -92.67 345.86 5,927,587.01 461,364.81 4.00 307.14 1,600.00 44.97 105.00 1,487.68 1,338.08 -110.31 411.68 5,927,569.04 461,430.54 4.00 365.60 1,700.00 48.97 105.00 1,555.91 1,406.31 -129.22 482.27 5,927,549.76 461,501.02 4.00 428.28 1,800.00 52.97 105.00 1,618.87 1,469.27 -149.32 557.29 5,927,529.27 461,575.92 4.00 494.90 1,900.00 56.97 105.00 1,676.26 1;526.66 -170.51 636.36 5,927,507.68 461,654.88 4.00 565.13 2,000.00 60.97 105.00 1,727.81 1,578.21 -192.69 719.11 5,927,485.08 461,737.51 4.00 638.61 2,100.00 64.97 105.00 1,773.25 1,623.65 -215.74 805.13 5,927,461.59 461,823.40 4.00 715.00 2,200.00 68.97 105.00 1,812.37 1,662.77 -239.55 894.01 5,927,437.32 461,912.14 4.00 793.93 2,300.00 72.97 105.00 1,844.97 1,695.37 -264.01 985.30 5,927,412.39 462,003.30 4.00 875.00 2,338.33 74.50 105.00 1,855.71 1,706.11 -273.53 1,020.85 5,927,402.69 462,038.79 4.00 906.57 Start Sail; 74.5° INC, 2338' MD, 1855' TVD 2,400.00 74.50 105.00 1,872.19 1,722.59 -288.91 1,078.24 5,927,387.01 462,096.10 0.00 957.54 2,500.00 74.50 105.00 1,898.91 1,749.31 -313.86 1,171.32 5,927,361.59 462,189.04 0.00 1,040.20 2,600.00 74.50 105.00 1,925.64 1,776.04 -338.80 1,264.40 5,927,336.17 462,281.98 0.00 1,122.86 2,700.00 74.50 105.00 1,952.36 1,802.76 -363.74 1,357.48 5,927,310.76 462,374.92 0.00 1,205.52 2,800.00 74.50 105.00 1,979.08 1,829.48 -388.68 1,450.56 5,927,285.34 462,467.86 0.00 1,288.18 2,900.00 74.50 105.00 2,005.81 1,856.21 -413.62 1;543.64 5,927,259.92 462,560.81 0.00 1,370.84 3,000.00 74.50 105.00 2,032.53 1,882.93 -438.56 1,636.72 5,927,234.50 462,653.75 0.00 1,453:50 3,100.00 74.50 105.00 2,059.26 1,909.66 -463.50 1,729.80 5,927,209.08 462,746.69 0.00 1,536.16 3,200.00 74.50 105.00 2,085.98 1,936.38 -488.44 1,822.88 5,927,183.66 462,839.63 0.00 1,618.82 3,300.00 74.50 105.00 2,112.70 1,963.10 -513.38 1,915.96 5,927,158.25 462,932.57 0.00 1,701.48 3,400.00 74.50 105.00 2,139.43 1,989.83 -538.32 2,009.04 5,927,132.83 463,025.51 0.00 1,784.14 3,500.00 74.50 105.00 2,166.15 2,016.55 -563.26 2,102.12 5,927,107.41 463,118.45 0.00 1,866.80 3,600.00 74.50 105.00 2,192.88 2,043.28 -588.20 2,195.20 5,927,081.99 463,211.39 0.00 1,949.46 3,700.00 74.50 105.00 2,219.60 2,070.00 -613.14 2,288.28 5,927,056.57 463,304.33 0.00 2,032.12 3,800.00 74.50 105.00 2,246.32 2,096.72 -638.08 2,381.36 5,927,031.15 463,397.27 0.00 2,114.78 3,900.Q0 74.50 105.00 2,273.05 2,123.45 -663.02 2,474.44 5,927,005.74 463,490.21 0.00 2,197.44 4,000.00 74,50 105.00 2,299.77 2,150.17 -687.96 2,567.52 5,926,980.32 463,583.15 0.00 2,280.10 12/21/2005 10:42:14AM Page 3 of 6 COMPASS 2003.11 Build 50 ConocoPhi!lips Alaska Sperry Drilling Services Planning Report -Geographic HALLIBE.JRTON Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Coordinate Reference: Well Plan: 2L-309 Company: ConocoPhillips Alaska (Kuparuk) 7VD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Project: Kuparuk River Unit MD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Site: Kuparuk 2L Pad North Reference: True Weil: Plan: 2L-309 Survey Calculation Method: Minimum Curvature Wellbore: PIan: 2L-309P61 Design: 2L-309 PB 1 wp06 Planned Survey 2L-309PB1w p06 Map Map MD Inclination Azimuth TVD SSTVD +N(-S +EJ-W Northing Easting DLSEV Vert Section ii (ft) (°) (°) {ft) {ft) (ft) (ft) (ft) (ft) (°/t00tt) (ft) 4,100.00 74.50 105.00 2,326.49 2,176.89 -712.90 2,660.60 5,926,954.90 463,676.09 0.00 2,362.76 4,200.00 74.50 105.00 2,353.22 2,203.62 -737.85 2,753.68 5,926,929.48 463,769.03 0.00 2,445.42 4,300.00 74.50 105.00 2,379.94 2,230.34 -762.79 2,846.76 5,926,904.06 463,861.97 0.00 2,528.08 4,346.99 74.50 105.00 2,392.50 2,242.90 -774.51 2,890.49 5,926,892.12 463,905.64 0.00 2,566.92 95/8" Csg Pt; 4346' MD, 2392' TVD - 9 518" Cgs -12 1/4" Hole 4,367.00 74.50 105.00 2,397.85 2,248.25 -779.50 2,909.12 5,926,887.03 463,924.24 0.00 2,583.46 Continue Dir; 5° DLS, 156° TFO, 4367' M D, 2397' ND 4,400.00 72.99 105.69 2,407.08 2,257.48 -787.88 2,939.67 5,926,878.49 463,954.74 5.00 2,610.73 4,500.00 68.43 107.87 2,440.11 2,290.51 -815.10 3,030.01 5,926,850.81 464,044.94 5.00 2,693.13 4,600.00 63.90 110.19 2,480.51 2,330.91 -844.88 3,116.47 5,926,820.58 464,131.23 5.00 2,774.66 4,631.24 62.50 110.95 2,494.60 2,345.00 -854.68 3,142.58 5,926,810.65 464,157.28 5.00 2,799.86 C80 (K10) 4,700.00 59.42 112.69 2,527.98 2,378.38 -877.01 3,198.37 5,926,788.04 464,212.96 5.00 2,854.71 4,800.00 54.98 115.44 2;582.15 2,432.55 -911.22 3,275.11 5,926,753.43 464,289.51 5.00 2,932.66 4,900.00 50.61 118.50 2,642.61 2,493.01 -947.27 3,346.09 5,926,717.02 464,360.30 5.00 3,007.94 5,000.00 46.34 121.96 2,708,90 2,559.30 -984.88 3,410.78 5,926,679.08 464,424.79 5.00 3,079.95 5,100.00 42.18 125.95 2,780,52 2,630.92 -1,023.76 3,468.68 5,926,639.91 464,482.48 5.00 3,148.16 5,200.00 38.19 130.62 2,856.93 2,707.33 -1,063.61 3,519.36 5,926,599.80 464,532.94 5.00 3,212.04 5,300.00 34.41 136.16 2,937.53 2,787.93 -1,104.14 3,562.42 5,926,559.05 464,575.79 5.00 3,271.11 5,400.00 30.94 142.84 3,021.72 2,872.12 -1,145.04 3,597.54 5,926,517.98 464,610.70 5.00 3,324.92 5,500.00 27.88 150.91 3,108.85 2,959.25 -1,185.99 3,624.45 5,926,476.89 464,637.39 5.00 3,373.06 5,600.00 25.40 160.61 3,198.27 3,048.67 -1,226.68 3,642.95 5,926,436.11 464,655.68 5.00 3,415.16 5,700.00 23.66 171.92 3,289.29 3,139.69 -1,266.80 3,652.89 5,926,395.94 464,665.42 5.00 3,450.90 5,800.00 22.85 184.44 3,381.23 3,231.63 -1,306.05 3,654.21 5,926,356.69 464,666.53 5.00 3,480.02 5,900.00 23.05 197.27 3,473.37 3,323.77 -1,344.13 3,646.88 5,926,318.66 464,659.01 5.00 3,502.28 6,000.00 24.26 209.39 3,565.02 3,415.42 -1,380.74 3,630.98 5,926,282.13 464,642.91 5.00 3,517.53 6,100.00 26.31 220.08 3,655.48 3,505.88 -1,415.62 3,606.61 5,926,247.38 464,618.37 5.00 3,525.64 6,200.00 29.05 229.11 3,744.07 3,594.47 -1,448.49 3;573.96 5,926,214.68 464,585.55 5.00 3,526.54 6,300.00 32.29 236.59 3,830.10 3,680.50 -1,479.10 3;533.28 5,926,184.28 464,544.72 5.00 3,520.25 6,400.00 35.89 242.79 3,912.93 3,763.33 -1,507.23 3,484.89 5,926,156.41 464,496.19 5.00 3,506.80 6,414.46 36.44 243.59 3,924.60 3,775.00 -1,511.08 3,477.27 5,926,152.60 464,488.55 5.01 3,504.26 C50 6,500.00 39.76 247.96 3,991.92 3,842.32 -1,532.65 3,429.14 5,926,131.28 464,440.31 5.00 3,486.29 6,600.00 43.83 252.33 4,066.47 3,916.87 -1,555.18 3,366.47 5,926,109.08 464,377.53 5.00 3,458.88 6,700.00 48.03 256.09 4,136.02 3,986.42 -1,574.64 3,297.34 5,926,089.98 464,308.32 5.00 3,424.78 6,800.00 52.35 259.38 4,200.04 4,050.44 -1,590.88 3,222.30 5,926,074.12 464,233.20 5.00 3,384.26 6,868.65 55.36 261.42 4,240.53 4,090.93 -1,600.10 3,167.64 5,926,065.18 464,178.50 5.00 3,352.87 Start Safi; 55.36° INC, 6868' MD, 4240' ND 6,900.00 55.36 261.42 4,258.34 4,108.74 -1,603.95 3,142.14 5,926,061.47 464,152.98 0.00 3,337.90 6,928.60 55.36 261.42 4,274.60 4,125.00 -1,607.46 3,118.87 5,926,058.08 464,129.70 0.00 3,324.23 C40 7,000.00 55.36 261.42 4,315.18 4,165.58 -1,616.22 3,060.78 5,926,049.62 464,071.57 0.00 3,290.13 7,100.00 55.36 261.42 4,372.02 4,222.42 -1,628.49 2,979.43 5,926,037.77 463,990.16 0.00 3,242.36 7,200.00 55.36 261.42 4,428.86 4,279.26 -1,640.77 2,898.07 5,926,025.92 463,908.75 0.00 3,194.59 7,300.00 55.36 261.42 4,485.70 4,336.10 -1,653.04 2,816.72 5,926,014.06 463,827.34 0.00 3,146.82 7,306.86 55.36 261.42 4,489.60 4,340.00 -1,653.88 2,811.13 5,926,013.25 463,821.75 0.00 3,143.54 C37 12/21/2005 10:42:14AM Page 4 of 6 COMPASS 2003.11 Build 50 Sperry Drilling Services ConocoP hilli s p Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Gompany: ConocoPhillips Alaska (Kuparuk) TUD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2L Pad North Reference: Welf: Plan: 2L-309 Survey Calculation Method: Wellbore: PIan:2L-309P81 Design: 2 L-309 PB 1 wp06 Planned Survey 2L-309P81wp06 C] HALLIBtJRT~IV Sperry Drilling Services Well Plan: 2L-309 Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) True Minimum Curvature Map MD Inclination Azimuth TVD SSTVD +N/-S +EI-W Northing (ft) (°) (°) (ftl (ft) (ft) (ft) (ft) 7,400.00 55.36 261.42 4,542.54 4,392.94 -1,665.31 2,735.36 5,926,002.21 7,500.00 55.36 261.42 4,599.38 4,449.78 -1,677.58 2,654.00 5,925,990.36 7,600.00 55.36 261.42 4,656.21 4,506.61 -1,689.86 2,572.65 5,925,978.51 7,700.00 55.36 261.42 4,713.05 4,563.45 -1,702.13 2,491.29 5,925,966.66 7,764.30 55.36 261:42 4,749.60 4,600.00 -1,710.02 2,438.98 5,925,959.04 Iceberg zone - - est 7,800.00 55.36 261.42 4,769.89 4,620.29 -1,714.40 2,409.94 5,925,954.81 7,900.00 55.36 261.42 4,826.73 4,677.13 -1,726.67 2,328.58 5,925,942.96 8,000.00 55.36 261.42 4,883.57 4,733.97 -1,738.95 2,247.22 5,925,931.11 8,100.00 55.36 261.42 4,940.41 4,790.81 -1,751.22 2,165.87 5,925,919.26 8,200.00 55.36 261.42 4,997.24 4,847.64 -1,763.49 2,084.51 5,925,907.40 8,300.00 55.36 261.42 5,054.08 4,904.48 -1,775.76 2,003.16 5,925,895.55 8,400.00 55.36 261.42 5,110.92 4,961.32 -1,788.04 1,921.80 5,925,883.70 8,500.00 55.36 261.42 5,167.76 5,018.16 -1,800.31 1,840.44 5,925,871.85 8,600.01 55.36 261.42 5,224.60 5,075.00 -1,812.58 1,759.08 5,925,860.00 Target (Pilot); 8600' MD, 5224' TVD -2L-309P81wp06 T1 8,700.00 50.27 261.42 5,285.02 5,135.42 -1,824.46 1,680.34 5,925,848.53 8,800.00 45.17 261.42 5,352.27 5,202.67 -1,835.49 1,607.20 5,925,837.87 8,900.00 40.08 261.42 5,425.82 5,276.22 -1,845.59 1,540.26 5,925,828.12 8,937.10 38.19 261.42 5,454.60 5,305.00 -1,849.08 1,517.11 5,925,824.75 T3.1 8,962.33 36.90 261.42 5,474.60 5,325.00 -1,851.38 1,501.91 5,925,822.54 T3 9,000.00 34.99 261.42 5,505.10 5,355.50 -1,854.68 1,480.04 5,925,819.35 9,100.00 29.89 261.42 5,589.47 5,439.87 -1,862.67 1,427.02 5,925,811.63 9,123.08 28.71 261.42 5,609.60 5,460.00 -1,864.36 1,415.85 5,925,810.00 T2 9,195.95 25.00 261.42 5,674.60 5,525.00 -1,869.27 1,383.31 5,925,805.26 Target (Toe); 9195' MD, 5674' TVD, 2033' FNL & 4531' FEL; Sec23-T 10N-R07E - 8 1 J2" Hole Geologic Targets Plan : 2L-309P61 Map Fasting (ft) 463, 745.93 463,664.52 463, 583.11 463, 501.70 463,449.35 DLSEV Vert Section (°HOOft) Ift) 0.00 3,099.05 0.00 3,051.29 0.00 3,003.52 0.00 2,955.75 0.00 2,925.03 463,420.29 0.00 2,907.98 463,338.88 0.00 2,860.21 463,257.47 0.00 2,812.44 463,176.06 0.00 2,764.67 463,094.65 0.00 2,716.91 463,013.24 0.00 2,669.14 462,931.82 0.00 2,621.37 462,850.41 0.00 2,573.60 462,769.00 0.00 2,525.83 462,690.20 5.09 2,479.59 462,617.02 5.09 2,436.65 462,550.03 5.09 2,397,35 462,526.86 5.10 2,383.75 462,511.65 5.09 2,374.83 462,489.77 5.09 2,361.99 462,436.72 5.09 2,330.86 462,425.54 5.10 2,324.30 462,392.97 5.09 2,305.20 TVD Target Name +NI-S +E/-W Northing Fasting (ft) -Shape ft ft (ft) (ft) i 5,224.60 2L-309P61wp06 T1 -1,812.58 1,759.08 5,925,860.00 462,769.00 - Paint 12/21/2005 10:42:14AM Page 5 of 6 COMPASS 2003. J 1 Build 50 r Sperry Drilling Services HAi_LIBtJRTON ConocoP hilhps Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 2L-309 Company: Conoco Phillips Alaska (Kuparuk) TVD Reference: Planned Doyon 14 @ 149 60ft (Doyon 14 (34.3 + 115.3)) Project: Kuparuk River Unit MD Reference: Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Site: Kuparuk 2L Pad North Reference: True Well: Plan: 2L-309 Survey Calculation Method: Minimum Curvature Welibore: PIan:2L-309P61 Design: 2L-309PB1 wp06 '~ Prognosed Casing Points l Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 4,346.99 2,392.50 9Sf8 12-114 9,195.95 5,674.60 8-1/2 8-1/2 __ _____ Prognosed Formation Intersection Points _ _ _ _ _ _ ___ _ _ _ _ _ - - -_ Measured Vertical I Depth Inclination Azimuth Depth +N/-E +FJ-W ~ (ft) !°1 (°! (ft) (ft) (ft) i Name 4,631.24 62.50 110.95 2,494.60 -854.68 3,142.58 C80 (K10) 6,414.46 36.44 243.59 3,924.60 -1,511.08 3,477.27 C50 6,928.60 55.36 261.42 4,274.60 -1,607.46 3,118.87 C40 7,306.86 55.36 261.42 4,489.60 -1,653.88 2,811.13 C37 7,764.30 55.36 261.42 4,749.60 -1,710.02 2,438.98 Iceberg zone--est 8,937.10 38.19 261.42 5,454.60 -1,849.08 1;517.11 T3.1 8,962.33 36.90 261.42 5,474.60 -1,851.38 1,501.91 T3 9,123.08 28.71 261.42 5,609.60 -1,864.36 1,415.85 T2 12/21/2005 10:~{42y14AM Page 6 of 6 COMPASS 2003.11 Build 50 F iL. t . i,'. .. • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-309 Plan: 2L-309 2L-309wp06 Anticollision Report 21 December, 2005 • HALLIBt,~R'TC~N Sperry Qrifling Services ORIGINAL 0 ~MALLIBURTON ~~Sperry Drilling Services °: lam. feein CNav Te Ye ~- ... ..~ :bn+n °-. , .,,- ~, '~,.- ~, ~ ~...-nsa sou .,s °soo Critical Issues: • :[TC' NEGATIVE TFMA:i values from the Survey Editor or Trovallin0 Cylinder Report should be plotted on tha leh aide of the Travellin0 Cylinder. Trn~e0htg C'3linder Arlmuth (TFO+AZII I°I ie Centre to Centre Separation X40 0lin~ Tnvelliag f5linder .4:imutA tTFO+AZD I°~ .x Centre to Centre ticpannoa 15 fUin~ SEC'TIOti DETAlIS Sec hm Inc Azi T\D r\')-S +Fl-N DLeg TFace l'Sx 7eryet 1 1367.00 71.50 105.00 219791 -779.!0 2909.12 0.00 0.00 3583./6 3 51/8 U ]/.50 10(00 2457./3 -1031.]5 i8i3.Li 0.00 0.00 i36e 1ti 1 831(66 7/.50 13(93 )17116 -2/56.07 6351.89 1.00 9/.22 611108 { IU28.03 74.50 13(92 4810.475934.14 961 L80 0.00 0.00 109{i,25 5 1/{40.61 30.00 135.9{ 47{.60 6512.49 10208.6{ /.00 179.99 11601.06 2L-109wp06 Rumen TargH 6 1/960.26 30.00 135.91 5934.60 .4]39.19 10389.13 0.00 0.00 12060.8'/ 0 AM • Conoco~illps Alaska Sperry Drilling Services Anticollision Report Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 2L Pad Site Error: O.OOft Reference Well: Plan: 2L-309 Well Error: O.OOft Reference Wellbore Plan: 2L-309 Reference Design: 2L-309wp06 Locat Coordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: Output ertors are at Database: Offset TVD Reference: • HALLIBURTON Sperry Drilling Services Well Plan: 2L-309 Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum teference ZL-309wpG6 'filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Merpolation Method: MD Interval 25.OOft Error Model: ISCWSA lepth Range: 4,367.00 to 14,960.26ft Scan Method: Trav. Cylinder North tesuks Limited by: Maximum center-center distance of 1,692.60ft Error Surface: Elliptical Conic Yarning Levels evaluated at 0.00 Sigma Suroay Tool Program Date 12/20/2005 ~~ From To (ft) (ft) Survey (Welltwre) Tool Name Description 34.30 800.00 2L-309PB1wp06 (Plan: 2L-309P81) CB-GYRO-SS Camera based gyro single shot 800.00 4,367.00 2L-309P61wp06 (Plan: 2L-309P81) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,367.00 14,960.26 2L-309wp06 (Plan: 2L-309) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Cerrtre Distance Deviation Warning Site Name Depth Depth Distance (ft} from Plan Offset Well - Wellbore -Design (ft) (g} (ft} (ft) Kuparuk 2L Pad 2L-03 - 2L-03 - 2L-03 Out of range 2L-03 - 2L-03 Baker Plan - 2L-03 Baker Plan Out of range 2L-305 - 2L-305 - 2L-305 Out of range 2L-307 - 2L-307 - 2L-307 4,377.07 4,525.00 929.93 21625 807.52 Pass -Major Risk 2L-311 - 2L-311 - 2L-311 4,367.00 4,475.00 410.27 137.29 331.11 Pass -Major Risk 2L-313 - 2L-313 - 2L-313 4,373.06 4,800.00 975.74 226.24 817.34 Pass -Major Risk 2L-315 - 2L-315 - 2L-315 Out of range 2L-317 - 2L-317 - 2L-317 14,725.33 14,161.00 368.71 63.01 368.21 Pass -Minor 1/200 2L-317 - 2L-317A - 2L-317A 11,016.65 10,725.00 872.96 613.54 393.31 Pass -Major Risk 2L-319 - 2L-319 (Oscar) - 2L-319 wp02 4,387.07 4,650.00 1,190.61 144.45 1,046.98 Pass -Major Risk 2L-321 - 2L-321 - 2L-321 4,385.88 5,025.00 1,656.60 235.60 1,440.23 Pass -Major Risk 2L-323 - 2L-323 - 2L-323 Out of range 2L-325 - 2L-325 - 2L-325 Out of range CC -Min cenfre to center distance or covergent point, SF -min separation factor. ES -min ellipse separation 1 1/2005 10:5 : 2A Page 2 of 2 COMPASS 2003.11 Build 50 ~~r • Plan: 2L-309PB 1wp06 (Plan: 2L-309/Plan: 2L-309PB 1) 40. 35. 30. u 25. >~ 0 .~ ~, >~ 20. U 0 Y Q~ U 15. 10. 5. 0. Measured Depth [ft] 2L-3()9PBlv.1~()< 2L-03, 2L-03 Baker Plan, 2L-03 Bake!'P~/02L~)3, 2L-03, 2L-03 V2 211305, 2L-305, 2L305 V2 2L-307, 2J13W, 21x307 V2 211311, 2]1311, 2L-311 VO 211313, 2L313, 21x313 V2 2L-315, 211315, 211315 V2 2L-317, 2L-317, 2Lr317 V2 21x317, 2I1317A, 2L-317A V4 2L-319, 21.x319 (Oscar), 2L-319 wp02'0'~~ 2L-321, 2L-321, 2L321 V2 2L•323, 2L-323, 2L-323 V2 2L-325, 2I13?5, 2L-325 V2 -500 0 500 1000 1500 2000 l ~ ~ ~ ~ ..~.....~. ~ .................... .......o..o =EE rym. .._... _... 'R P ~RN i ~ ~~~i L .....: .----- O ~ ... _ 8q ~~A ~ !!! .__.. 1--- O O O ._.. __ N f 3.~ N i ~ I ~ L 9B' ~ ! I ' 1 I! ,~ ! _. __..- 00 ._. _ _ _....-----.._--_ j- -.. _ __.~ l i O i l ~ k i C i s ~ $ i ,' ~ ~. p L ~ _ .. l c m~a O ;a~1M a i ~ i NNN ~ -Y Y C C O o. as a ~ ~''lL~-~l 7 ~- ` N YYm O m •- m d '~ . y c0 ~ a i n ~ - o ~~, - - _ _ - i = ~~ ~ ~~~ ~ ~~ ~ E ° ~~~#~ ; - O O - ~'- N - ~ .*J O Z O _._ ~._- _.. ~.. ......_ O O i C m Q J J ~ °o °0 0 0 Z' °° ~ ~ r a °o °o go a ~ ~ i . dJ ..~ (u!R! 008) (+)43~oN/(-)43rtoS ORIGINAL ORIGINAL • 8 8 8 8 ~ ~ 8 S 8 8 8 9zzsLo ~ S S 9ZZZC9 9zzlL4 9ZZOC4 9ZZ696 9ZZ894 € ~ Y p~ ~ t 9ZZC94 ~ < ~ 6 ~ ~ ~ 9ZZ994 9ZZS94 9ZZ496 - 9ZZE9V a a ° $ ~ ~ 9ZZZ9V I I ~ Z194 I > I ~ L° 2094 l-1 Ul~os / 1.I 4NoN ~----- c I o m I N > d I 1 ~ € 3 a ~ _°c ~ -O1 w O> j I ^ I I I n I ~ I ~ I I - - J I I O Q I I N 0 ^ ~ ~ ~ ~ M i i I -= r- M C M ~ ~ I s~ ~ °N.~N N y ~ N O O i 3 ~ O ~ ~ I n ~ N M i ~ I O O O O~ ~ ~___ __ x s /A~ ~, W~ O M CO i U1 Z ~ N N ~ i . m ~ I ~ I u I N L i ~ o ___ y y o° d s ~ ~ U ORIGINAL z ~ o ~. • m 3 w a g ai ~ I _~ _.- . - -~-- 9L l91 9LIS1 9L 141 9L l£1 r' N I 9L1Z1 ~- r_ - I ry 1 9L1I1 N MM,, N cu - 9L 101 - 9L16 _m c 6 I _m __~."-- 9LIC~ R c O x ~ i - ~ - o n° 8 _- - ~ - - 9L19s u m ` ~. i o 0 ~ ' 9L1S ~ a~ a - ~ 9LIb 9Ll£ - 9LIZ 9Lfl 9L1 4L8- ~- I 4L81 -~_ i 4Z8L- vass- _1 qz~- 41tl a4 ~o ~iyaa~ arul waysAS m a ~. ~w x, ~... Closest in POOL Closes t Approach: Reference We ll: 2L-309wp06 Plan Offset Well: 2 L-317 Coords. - Coords. - 3-D etr- ASP ASP ctrMin. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. ND E(+)/W(-) (135.93°) Comments Depth Angle Azi. ND E(+)/W(-) (135.93°) Comments in is ance POOL Min Distance (472.9 ft) in POOL (472.9 ft) in POOL (5325 - 5460 Subsea (5325 - 5460 Subsea TVD) to 2L-309wp06 472.9 14440.64 30 135.94 5325.312 5921086 471193.8 11801.08 ND) to 2L-317 13850 54.46 123.64 5453.338 5920966 470754.6 11583.63 Plan Closes t Approach: Reference We ll: 2L-3 09wp06 Plan Offset Well: 2 L-317A Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)IS(-) View VS Dist. Depth Angle Azi. ND E(+)IW(-) (135.93°) Comments Depth Angle Azi. ND E(+)/W(-) (135.93°) Comments in is ance in istance (2082.02 ft) in (2082.02 ft) in POOL (5325 -5460 POOL (5325 - 5460 Subsea ND) to 2L- Subsea ND) to 2L- 2082.02 14440.64 30 135.94 5325.312 5921086 471193.8 11801.08 317A 12350 53.49 106.73 5446.361 5922546 469714.8 9723.357 309wp06 Plan Closes t Approach: Reference We ll: 2L-309wp06 Pian Offset Well: 2 L-321 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist.. Depth Angle Azi. ND E(+)/W(-) (135.93°) Comments Depth Angle Azi. ND E(+)/W(_) (135.93°) Comments O in Distance POOL Min Distance (2893.53 ft) in (2893.53 ft) in POOL (5325 - 5460 POOL (5325 - 5460 Subsea ND) to 2L- Subsea ND) to 2L- 2893.53 14440.64 30 135.94 5325.312 5921086 471193.8 11801.08 321 11875 55.85 128.95 5452.888 5921535 468338.3 9501.146 309wp06 Plan POOL Summaryl.xls 12/21!2005 3:03 PM ~J ~ti~visiao ~aH WWiD ~_ iii h,~:_,1 _.. I '_~6ci:cl?f ~ ~3~ l 5' :uaq?aS f ~ 3 d=ol a6ue,y 55s~ nZ9l - ~PJ~ ~ II :uey~ua~xa N ULO :diysuW,o1 ------ rxv~rinosap Je6a~ -J -- - -- - 6s btC.ti'.6~~ - ~~. E9 ~.L~ lLh x i - -- :saaewpioo~ 6uyiei 5 f~~o LZr~tlNl uarp~uasa0l~'al ;) .~. 11 >n :siruN ,• anal :2uo? aura alea5 ,.? 4~oS ~ arol ;auo? INlil J saai6aplewc~ap~ 2pn1!6ua~apni!~e`I ..~ ~ G:i<el~ :ucvkra~ a LcrJ"N~ :wnl?Q I ' _. ~_~. 3oZ 90dM60~~IZ Irt S~f ^ttae~n~+e~! ... .... ... ~, to 1 wiC u2t ~'ti i. 0 _~......_...._._.~.„_._l..__....._.... j b'9~r0~nL ~ ~3j 3~p9rOtl I ~ lhJj j _ _- -- -- - ---- -------- j 97 :~~oga2~ I II i i :ue~l~y~¢ j i I h~ SLLI by~ :,~ 3 r:UU ;a6uey N 0 LO f i :tl~ysu~na J; ~ ~ I ~459t1~t~ ~ I _. _.- __ _.- --._-. _- _..--__-- Ualj(~11~~ 0~3 ~ QI- l-' _ _ __ _.. Sa _ld JUO 1iW 12 ' - >p P J 4 iS ' r_. _._.- _. _.. ___.__.____. __.. _. ~ _.. _. _._ _-__-_._ _-. _. _. _.____. _-__.___ -_-_. _.. _._. -. _ f~JUat~l~4~f'J?UOfJ'iJ l)~S~QI`-*"'"~ .'..~ ~ ~ ~ _.. ~ I ~J ~f~~." ~ p~.3? ~ r ~ . id-=r.' ~`NuPI ~ anrl~ ;auo~ I auFjd aieiS „1 I I ~ il-=n sirup ~ t auaZ ?ueld aieig .f, i rJin[3J ~ 2nrl ~ ;aUaG i G~-l rl ..) i 5 ~ r'41n175 ...r ,_~~.~ :aUQ~ ~~.N i ~ ::a2r6a ] IPwrr 0~ apnp6uo~fapnuiel ,3 ~ ~ .a,;~Ear~ leuuinar~ aPnN.6u4lfaPni!iel .3 4 {~ °-1=eIF' uo~a ~ cr HN auniF ~ i o~-elF' :ua!62 '~ ~C'hJ wnie ~---- - - -__- --- - -- ---- °l-' I _--- - - ---- - -- - ------ ----- tool j _i ~~ - _ - t ~ .r.•; ~~ _. ~ ;- I i (° iJ `r' :s~a+(~ I,~~ t~ :aunt 2ueld as°iS 't fi € ~ I 41noS ~ ~ :auv~ Wl(t .1 I'. >aai6agleunaarl~~^a'pnl![u^l~aPnN~'l ,} ' G~.~ c ~~ele :urn6a}~ --°~ L?_..._ 7 N~ :wnieq ;u~~a ~uTS~~ «~ yodM6oE~z • • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-309 Plan: 2L-309PB1 2L-309PB1wp06 Anticollision Report 21 December, 2005 HALL..~BUR"fC~N Sperry Qrilling Services ~~~g~. ~ ~~acoi~hilEips ar:~;~i, MALLIBURTON Sperry Drilling Services ~• -~F~ cmwmvedps aessa lUwsn*1 "~' vme~ nwanx w„e.um Sae- esd~ 2l Paa - y _ Wee. %en: 21399 Paenl WNI: WeMMre. PMn: 21.399461 rolatb M thud. MD Inlenat 45Slalbns C I lath Meth d. MI C lure U R ~. f.,-, 31.30 To 919595 E o Model ISCWSA ximum Rarpe 1694.59 51 368 7 9 7 3 : .:,~~.. Error Surface, Elliptical Comc RMennce Well: Plan: 2L-309PB1wp08 Warning Method: Rules Basad SIRI'f l' rROGRA. 1 Date: 20D5~1I.10TUU_ulLllU deli laiin. l.s ~enion: Ueylh from Dep182o .1i i..~1'Ini~ li.,l 7130 IOBOOU .'I ~JU'~I'I41~„~Ur (It-1:1 HO~SS e. rr.n. eNw. r Mo .. .. - _ - . _;~~; -uq ....~ „- _~ ~~,YN irec~ ~wYr] Critical Issues: • Travelling Cliixder .trimrah I7 F'll+.{zq I`I ,'r centre b centre 4pxnlinu Is Nin SECTION DETAIIS Sec SN loc Ad PD +S!S +E!-N' Dl.eg iF.« 3'Sa 7vga i JI.JD D.ao o.aD 3uo o.oo o.oo o.oD a.oo o.ao 2 7925D 0.00 O.OD 393_50 0.00 0.00 0.00 0.00 0.00 t ]2581 10.00 105.00 721.11 -751 28.03 1.00 IM.00 2189 1 1225.83 30.00 105.00 1191.61 -51 t5 19237 0.00 0.00 17081 5 SJiB.JJ 71.50 105.00 1855.71 -273.(1 1020.85 6.00 D.00 9065] 6 IK7.00 71.W 105.00 119785 -7]9.50 2909.12 0.00 0.00 358JA6 7 0868.65 5538 361A3 131051 -1800.10 llti7.ti1 5.00 158.29 13538] 8 9600.01 SlJ6 261.12 5221.60 -IBIi58 1759.08 0.00 O.OD 2525.81 2L-309PBIep0671 9 919595 35.00 361.!1 5671.60 -IBti9.2] 138131 5.09 180.00 3.105.20 ~2 AM • Note: NEGATNE TFOeAzI vNws from the Survey Editor or Travelling CyIIMsr Report should be plotlad on the left aide d the Trswlling Cylinder TnceBing C)iiuder Azimuth 1TFO~AZII I`I rs C'eWre lu Centre Seperallon 110 Niul ConocoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Uni[ Reference Site: Kuparuk 2L Pad Ske Error: 0.00[t Reference Well: Plan: 2L-309 Well Error: 0 OQft Reference Wellbore Plan. 2L-309P81 Reference Design: 2L-309P61wp06 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HAl..LIBURTON Sperry Qrilling Services Well Plan: 2L-309 Planned Doyon 14 @ 149-60ft (Doyon 14 (34.3 + 115.3)) Planned Doyon 14 @ 149.60ft (Doyon 14 (34.3 + 115.3)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum eference 2L-309PB1wp06 filter type: NO GLOBAL FILTER: Using user defined selection 8 fiRertng criteria nerpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Swn Method: Trav. Cylinder North ~.esults Limited by: Maximum center-center distance of 1,692.60ft Error Surface: Elliptical Conic farnin5l Levels evaluated at 0.00 Siyma Survey Tool Program Date 12/20(2005 From To (ft) (ft) Survey (Wellbore) Tool Name Description 34.30 1,080.00 2L-309P81wp06 (Plan: 2L-309P81) CB-GYRO-SS Camera based gyro single shot 1,080.00 9,195.95 2L-309P61wp06(PIan:2L-309P81) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation blaming Ske Name Depth Depth Distance {ft) from Plan Offset Well - Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 2Lpad 2L-03 - 2L-03 - 2L-03 767.89 750.00 94.98 14.61 80.68 Pass -Major Risk 2L-03 - 2L-03 Baker Plan - 2L-03 Baker Plan 708.22 700.00 93.82 13.24 80.81 Pass -Major Risk 2L-305 - 2L-305 - 2L-305 759.80 750.00 48.71 13.38 35.51 Pass -Major Risk 2L-307 - 2L-307 - 2L-307 1,605.87 1,575.00 68.10 44.07 24.91 Pass -Major Risk 2L-311 - 2L-311 - 2L-311 603.98 600.00 25.43 10.99 14.46 Pass -Major Risk 2L-313 - 2L-313 - 2L-313 427.58 425.00 59.93 7.20 52.73 Pass -Major Risk 2L-315 - 2L-315 - 2L-315 328.49 325.00 91.96 5.54 86.42 Pass -Major Risk 2L-317 - 2L-317 - 2L-317 706.54 725.00 105.80 5.83 100.16 Pass -Minor 1!200 2L-317 - 2L-317A - 2L-317A 754.11 775.00 106.69 15.31 91.73 Pass -Major Risk 2L-319 - 2L-319 (Oscar) - 2L-319 wp02 1,069.33 1,125.00 112.36 24.57 88.85 Pass -Major Risk 2L-321 - 2L-321 - 2L-321 425.76 425.00 178.74 7.14 171.60 Pass -Major Risk 2L-323 - 2L-323 - 2L-323 425.32 425.00 209.47 7.00 202.48 Pass -Major Risk 2L-325 - 2L-325 - 2L-325 303.37 300.00 241.93 5.34 236.59 Pass -Major Risk CC -Min centre to center distance or ceveryent point, SF -min separation factor, ES -min ellipse separation 1221/2005 9:36:26AM Page 2 of 2 COMPASS 2003.11 Build 50 ~~~°,. Sperry Drilling Services Anticollision Repott Plan: 2L-309PB 1 wp06 (Plan: 2L-309/Plan: 2L-309PB 1) 40. 35. 30. u 25. >~ 0 Y ~-I ^~ ~1 20. U Y ~i U 15. 10. 5. 0. Measured Depth [ft] 21r3()9PBIwp0(i 2L-03, 2L-03 Baker Plan, 2L43 Bakr~'T'~er/021; 03, 2L-03, 2L-03 V2 2L-305, 2L-305, 21x305 V2 21x307, 21,307, 21x307 V2 2L311, 21x311, 2L-31 I VO 21x313, 2L-313, 21x313 V2 2L-315, 21x315, 21x315 V2 21x317, 2L-317, 2L-317 V2 21x317, 2L-317A, 2L-317A V4 21.x319, 21.x319 (Oscan, 2L-319 wp02w'~' 2L-321, 2L-321, 2L-321 V2 21.x323, 2Ir323, 2L-323 V2 21x325, 2L-325, 2L-325 V2 ORIGINAL -500 0 500 1000 1500 2000 0 z [/'~~ ~•' CakJetlon Metlwd: MlMmum DUevalue i~rY~! f 11~~~~~~ Waml Me1Fwd:llC~Ba~d +'~IC~:ka c~a+kDm,m: ruD,enMnocowca~us~ MagMk MOtlel: BGGMA05 H L8 L. L. I l'~S L1 Pi T O N Ana ~OYaI „sa6 RKB: Planne,l D y r. t1 ~n~ 139.Ii0ft ~cy„n t 1 '1 S - 1'1,.31) my/gSPY 5927681.35 Sperry Drilling Services ..,9/asPx. as,o,s3 c_ 0 In r 0 2 t 0 N Project: Kuparuk River Unit Site: Kuparuk 2L Pad Well: PIan:2L-309 Wellbore: PIan:2L309P61 Plan: 2L-309PB1wp06 No 1W MD fis,r , 292.fA 0.Wi9B 95'r'Cg~•12,N"Ible z ss~em s,ssss e,mlal. -650 0 650 1300 1950 2600 3250 3900 4550 West(-)/East(+) (650 Win) @ Project: KuparukRiverUnit W~Q~Q~~~E~~S Site: Kuparuk 2L Pad i Alaska Well: PIan:2L309 Wellbore: PIan:2L309P61 HALLIBURTON Plan:2L309P61wp06 `~ j Sperry Drilling Services c.~,~~~,a ~ ~ ,,5 sa J amt ar„ N.. rrhincyASP Y'. 5517651 ai.~t~ ~~uiiylASP%_ 46t0~'la' / i.~ro ~, 00 000 -500 ~~I ~ 2L-329, 2L-329, 2L-329 V2 - I ~ / ~ 0 0 0 2L-329, 2L-329A, 2L-329A V2 -- 1 2L-309PB 1 wp06 ~ 50 0 ~ .~ ~ _----------- 2L-325, 2L-325, 2L-325 V2 2L-315, 2L-315 V2 2L-305, 2L-305 V2 0 2L-323, 2L-323, 2L-323 V2 ~07, 2L-307, 2L-307 V2 - ~ o 0 0 ~-_.__ 1 _ ~ 500 \ I 2L-313, 2L-313, 2L-313 V2 2L-321, 2L-321, 2L-321 V2 ~L-311, 2L-311, 2L-311 VO ~ ~ LL-~'I /, LL-317A, 2L-317A V4 ~ 500 2L-317, 2L-317, 2L-317 V2 -~ • • 2L-309PB1wp06 Surface Location ~~ - From: ---- __ _ -- - - _ ___ ----- ---- -1 i Datum l4r~D2' Region ala_f;a < ~ ~ Datr~n rd'.D27 Fie~on" alask.a < ~ ~' LatitudotLongitu~ Decimal Degrees ~ j f i CH deft u~ _..__e i ''~ UTt>q ~UV1B_ ~~ f saUt}'r ~' State Plane ,'w-~: ~~ klnits_ ,r,-.ft < I ;rartingL'cordalat.~s _ _- _ _- ----------..1 ~: 461 D1 S. d? ~' 59~; 6g1.4r ! f ; ~ r _r Gn9t1 Deoimal Gegreas ~~ t'° UTM done Tn,e r South. I ~ f' St~tc, Plane Zone_ True < Units: u~.-fr, . ! j C: Legal Description {Nb.41i or;9yj ~ ~'~. ~I -Legal Descriptir.,n _ - -- _ ._ _ ' Township: i i1 i i N . Range: p, q E < ~ i i hAeeidian: U ~eLtion, ~~ ~ FNL < lb -9413 FEL < 631.48x63 ! Trartsftum ! Quit ~ Help. 2L-309PB 1 wp06 Toe ~:=r .. .:.~1 i From _ _----- ____-. __ _- --- ------ ~-Tv: -.... __.. _ _ -- -_____ ~. -------- _ 1 Datum. M4D2r ~. Regioh: al.-~F.a ~ j ! Datum: ~NaD'_1 +~ ~e9~t al.3ska f t" LatitudelL»rtgitude Drr_imalDearees ~.~~' ~ ~ LeEihadelLongittede D?cimylDrgre?s < ~ i ~' UTM Loner"'~'+` ~"' South ~ j #'" llTM done: True ~ Sduth 1 I L ~` €ate Plane Zone: < q-'~~ Units' t~.rs-lt . I ~ , ' Stele F1anf Gene: True < Urets: ~u~ k < ~` -- irt,-,~ r ~ ~. ~ ~" Legal Description fN~.D2? ordy] Starting Cvorde7atr;a - --_ -- - - --j ,- Legal Description--- - - ___ _ - -- _--• ~' 4F??g' 4 , ~ ~ Township:. U10 P! <: Range: Dp; E +' Y: 55258n5.26 i h4eridisn: U Section~~ { r i FtJL - ~fi :;3413 FEL ~ 14~_i~~19~31 Transform t6uri H € ~~ F ~~ ~ ~# a ~~ ~ c '~ ~ ~ ~ a Fib '~ ~ ~...,_ ,. CemCADE Preliminary Job Design 9 5/8" Surface Preliminary Job Design based on limited input data. For es6maie purposes only. Rig: Doyon 14 Location: Tam Client: ConocoPhillips Alaska, Inc. Revision Date: 12/22/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 110' MD < Base of Permafrost at 1,200' MD (1,169' TVD) ScYu~abw~r Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be at 2,600' MD. Lead Slurry Minimum pump time: 240 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.7632 ft3/ft x (110') x 1.00 (no excess) = 84 ft3 0.3132 ft3/ft x (1200' - 110') x 4.00 (300% excess) = 1365.6 ft3 0.3132 ft3/ft x (2600' - 1200') x 1.50 (50% excess) = 657.7 ft3 84 ft3 + 1365.6 ft3+ 657.7 ft3 = 2107.3 ft3 2107.3 ft3 / 4.45 ft3/sk = 473.6 sks Round up to 480 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 190 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.57 ft3/sk 0.3132 ft3/ft x (4347' - 2600') x 1.50 (50% excess) = 820.7 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 820.7 ft3 + 34.1 ft3 = 854.8 ft3 854.8 ft3/ 2.57 ft3/sk = 332.6 sks Round up to 340 sks BHST = 62°F, Estimated BHCT = 71°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time bbl min < Top of Tail at 2,600' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 4,347' MD (2,393' ND) * Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 ASL 6.0 375.3 62.5 97.5 DeepCRETE 5.0 152.2 30.4 127.9 Drop top plug 0.0 0.0 5.0 132.9 Water 5.0 20.0 4.0 136.9 Switch to rig 0.0 0.0 5.0 141.9 Mud 7.0 294.6 42.1 184.0 Slow & bump plug 3.0 9.0 3.0 187.0 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, TY < 15 Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, TY ? 20-25 Centralizers: 1 per joint on bottom 500 feet, 2 per joint on shoe track ORIGINAL ,, Rig: Doyon 14 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 12/22!2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. < 9 5/8", 40.0# casing at 4,347' MD < Top of Tail at 13,564' MD S~, < 7", 26.0# casing in 8 1!2" OH ~. TD at 14,364' MD (5,410' TVD) • ~~~~ CemCADE Preliminary Job Design 7" Intermediate Casing on purposes Volume Calculations and Cement Systems Volumes are based on 75% excess. Tail slurry is designed for 800' MD annular length. Tail Slurry Minimum thickening time: 200 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.04%B155, 0.35% D167 - 1.16 ft3/sk 0.1268 ft3/ft x 800' x 1.75 (75% excess) = 177.5 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 177.5ft3+17.2ft3= 194.7 ft3 194.7 ft3/ 1.16 ft3/sk = 167.8 sks Round up to 170 sks BHST = 140°F, Estimated BHCT = 109°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Drop bottom plug 0.0 0.0 5.0 23.0 MUDPUSH II 5.0 30.0 6.0 29.0 Tail Slurry 6.0 34.7 5.8 34.8 Drop top plug 0.0 0.0 5.0 39.8 Water 5.0 10.0 2.0 41.8 Switch to rig 0.0 0.0 5.0 46.8 Mud 6.0 500.0 83.3 130.1 Slow for ECD 5.0 24.5 4.9 135.0 Slow & bump plug 3.0 12.0 4.0 139.0 MUD REMOVAL Recommended Mud Properties: 10 ppg, Pv < 15, TY < 25. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH" II, Pv ? 21 - 23, TY ? 38 - 40 Centralizers: Recommend 3 per 2 joints from 13564 to 14284 and 2 per joint on the shoe track ~~~, ~,~~ ~ .; y • CemCADE Preliminary Job Design 3 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 14 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 12/22/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2631207 Mobile: (907) 748-6900 email: martin13@slb.com Top of Tail at < 14,114' MD < Liner Top at 14,214' MD Previous Csg. 7", 26.0# casing at 14,364' MD < 3 1/2", 9.3# casing in 6 1/8" OH ~- TD at 14,960' MD (5,925' TVD) Mark of Schlumberger ScHemMrge~ Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 4.0"- 14.0# drill string. Tail Slurry Minimum thickening time: 130 min. (pump time plus 90 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.02% B155 + 0.3% D65 + 0.2 gps D47 -1.17 ft3/sk Liner Cap: 0.1276 ft3/ft x 100' x 1.00 (no excess) = 12.8 ft3 Liner Lap: 0.1480 ft3/ft x (14364' - 14214') x 1.00 (no excess) = 22.2 ft3 Annular Volume: 0.1378 ft3/ft x (14960' - 14364') x 1.50 (50% excess) = 123.2 ft3 Shoe Volume: 0.0488 ft3/ft x 90' x 1.00 (no excess) = 4.4 ft3 Totals: 12.8 ft3 + 22.2 ft3 + 123.2 ft3 + 4.4 ft3 = 162.6 ft3 162.6 ft3/ 1.17ft3/sk = 139 sks Round up to 140 sks BHST = 154°F, Estimated BHCT = 119°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (mint CW100 4.5 30.0 6.7 6.7 MUDPUSH II 4.5 30.0 6.7 13.4 Tarn GasBLOK 4.5 29.0 6.4 19.8 Drop wiper dart 0.0 0.0 5.0 24.8 Water 4.5 10.0 2.2 27.0 Switch to rig 0.0 0.0 5.0 32.0 Mud 4.5 140.7 31.3 63.3 Sluw, p/u plug & bump 2.0 9.0 4.5 67 8 MUD REMOVAL Recommended Mud Properties: 11.0 ppg, Pv < 15, TY < 20 Spacer Properties: 12.0 ppg MudPUSH" II, Pv ? 20 - 22, TY ? 38 - 40 Centralizers: Recommend 3 per 2 joints from TOL to shoe track and 2 per joint on the shoe track MD to TD for proper cement placement. !?R!GINAL 1127. SHARON K. ALLSUP-DRAKE CONOCOPH~LL~PS E J7_.~ J%~~6-i-551(441 ATO1530 ~~T C~-~ 700 G ST. ANCHORAGE AK 99501 p~J~~~ ~~ ^ ,,.` ~ ~~ G~ PAYT07HE S~ t~~ ~ ~ ~~i/ i.ir' / C (~f ORDER OF ~ ~ % / _~~.-~'~'' 8 ~ e a (~~'~.Q~ ~ ~///~G~ ~'~ pOLLARS a ^~° a ~ ~' ' v5 ~--i ,/' ~{Q 5 ~,, Valid Up To 5000 Dollars , ~PMorganChase ~ 1 ' ~% ~ .~~ f ' JPMorgan Chase Bank,N.A. `y. , Columbus, OH I _____- ~ -- G MEMO ,,~~ ~;044LL55~L~:528747L907927i-'LL27 ~ • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLiDED IN TRAN5vIITTAL LETTER WELL N A~IE ~ ~~Z~ ,~Gr r ~ l._.~-~~~ PTD# ~~ ~ '! ~ ~ ~ - ~~v c~`OQ~~sc~v`~- CHECK WHAT i ADD-ONS APPLIES (OPTIONS MIiTLTI LATERAL (If A.PI number last two (2) digits are between 60-69) PILOT HOL ~~ "CLUE" The permit is for a new wellbore segment of existing well , Permit No, _ API No. _._ Production should continue to be reported as a function of .the original API number stated above. E In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both ! name name on permit plus P~ ~~ ~ ~~._ 7a ~I' G ` ~~.4 c~ / /1 I f~ and API number (~0 `~~ `' ', X0/80) from records, data and Logs acquired 1. for well (name on permit). SPACL'~iG 'i The permit is approved subject to full EXCEPTION ', compliance with ZO AAC ?5.055. Approval to '~, ~~, perforate and produceliniect is contingent ', upon issuance of a conservation order approving a spacing exception. (Company Nam_~assumes the liability of any protest to the spacing exception that may occur. DRY DITCH S AMPLE Ail dry ditch sample sets submitted to the , Commission must be in no greater than 30' I. sample intervals from below the permafrost or from where samples are first caught and '; 10' sample intervals through target zones. Rev: 04/01!05 C\jodv\transmittal checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, TARN OIL-490165 Well Name: KUPARUK RIV U TARN 2L-309 Program DEV Well bore seg ^ PTD#:2052100 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ Administration 1 Permit fee attached Yes 2 Lease number appropriate_ _ - _ _ - - - -Yes - . _ - _ - -Surface locatipn in ADL 38Q052; Pilpt_hol_e TD_in ADL 380051, top of produotiv_e interval & TD_in ADL 380053. _ . . 3 Uniquewell_nameandnumb_er_-__________________________ _________Yes_ -_-_---_-_-__.._ 4 Well locatedin.a-defined_pool____---------------------- ---------Yes- .___KUPARUKRIVER,_TA_RN_OIL-490165,gove[nedby CO430A.__________________________--__ 5 Well located proper distance from drilling unit_boundary_ Yes - - - - . - -Well will lie within_the KRU, about 9000' from the KRU bpundary and 3750' from the CQ 430A_area_bounda_ry, - _ - 6 Well located proper distance from other wells_ - _ _ - . _ - _ - Yes Conforms to_Conservatipn Order_No. 430A_ Rule 3, which specifies 10-ac_re spacing. 7 Sufficient acreage available in_dril_ling unit- _ . - . - .. - - - . -Yes - - - .... - - . - ---------------------------------------------------------------- 8 If_deviated,is_wellbpreplat_inclu_ded___________-„ ----------- ---------Yes- -_--.-._.--__-_______ ---------------------------------------------------- 9 Operatorpnlyaffectedparry___________________ ___________ _________Yes_ --_- 10 OpQ[atorhas_appropriate-bond in force- - - -- ------ - - -- -Yes- ---- -- - - -- ------ -- ------ --- -- ---------- -- -- ---------- -- 11 Permit can be issued without conservation order -- Yes - -- - - Appr Date 12 Permit_can be issued without administrative-approval - _ _ - - - Yes SFD 1!3/2006 13 Can permit be approved before 15-day wait Yes 14 Well Ipcated within area and strata authprfzed by Injection Order # (put_(O# in_comments)_(Fpr_ NA_ - 15 Allwells_within114_mileareaofreyiewidentified(Forservieewellpnly)______ _________ NA__ _-___--__--_________-__--__-________-_- ----------------------------------- 16 Pre-prpducedinjectpr;duration.ofprep[oduction lessthan3mpnths(Fpr_servfcewell_only)___N_A__ ________________________________________________---__-_-,--_.____--__._ ACMP_Finding of Consistency_has been issued_for_this project - - - - - - - - - - - - - - - - - - - NA- - _ - _ _ - _ , _ _ _ _ - _ _ _ _ _ . _ , - -------------------------------------------------- Engineering 18 Conduoto[string,provided_______ ________________________ _________Yes _--__.._ - - 19 Surface-casing_prptects all known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ - - _ - -All aquifers exempted, 40 CFR.147.1 Q2~b)(3}. _TEM 9-518" casing will-be cemented tp surface. SFD- - - - - _ _ . - 20 CMT_vol_adequate_tpcircvlate-on cpnductpr & surf_csg Yes 21 CMT-voladequate-to tie-fn long string to surfcsg_____ ____________ _________NO-- _--_--All hydrocarbon zoneswilll-be_covered,-_-___-._-----._--,_--_--_--.-__-_____-.-__, X1 22 CMT_willcover_allkno_wn,productiyehorizons_____________________ __,_____Yes_ ______Cementedlinercpmpletionpl_anned,________ __ _______ . __-___________________ ___- 23 Casing designs adequate for C, T, B & permafr_ost_ . . . . . . . .. . . . . .. . . ..... . . .Yes - _ - _ _ _ _ .. - . ----------------------------------------------------- 24 Adequate tan_kage_o_r reserve pit - - - - - - - - - - - - - - - - Yes - Rig is_equipped with st_eel_pits. -No_ rese_nte_pitplanned, All waste to_apprpved annlus_ or disposal_wells. 25 If a_re-drill, has-a_ 10-403 for abandpnment been approved NA- - _ - - - - _ 26 Adequate wellbore separationproppsed__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ Proximity analysis performed, Close approaches identified._ Trav_elinq cylinder plot included, _ - _ _ _ _ _ - _ _ _ - _ 27 Ifdiverterrequired,doesitmeetregulations________-_._________ _-_--___- Yes- --------------------__---- - - - -- - Appr Date 28 Dritlingfluid-program schematic,& equip list adequate_ Yes . . - - - - -Maximum expected fo[matipn pressure at TD 10.7 EMW. Planned MW_up to 11.0 ppg- - - - - - - - - - - - - - - - - TEM 1!312006 29 BOPEs, do the meet_ re ulatipn _ - _ Y 9 - -- _ _ _ _ Yes _ _ (~ ~ 30 BOPE.press rating appropriate; test to_(put psig in cpmments)_ - - - Yes - - - ... - MASP calculated at 2666 psi,. 3500-psi-appropriate. CPAI plans-tp test_tp 5000-psi, - .. - _ - - _ _ - ~1• X 31 Choke_manifoldcpmpliesw/API-RP-53(.May84)___________________ _________Yes_ _______-___._ 32 Work willoccurwithoutoperationshutdown______________________ __ _Yes- _______ _____ 33 Is presence_of H2$ gas-prpbable .. . .. . .. . . . . . .. . . . . .. Yes H2S is repprted_in nearby wells. Mud should preclude H2S on rig. _ Rig has_sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA_ Geology 35 Pe[mitean be issued wlo hydrogen_ sulfide measures No- _ _ _ - - _ - ti2S is present in reservoir, 2L,317A (nearest well) measured-10_ppm on 11118/2004 next_closest well, 2L-321. . 36 Data_presented on_ potential oyerpressur_e zones - - - - - - - - - - - - - - - - - - - - - - - - - Yes . ... - -measured 80 ppm pn 11.11912.004. Expected_ reservoir pressure is 10.7 PPG_E_MW; will be_drilled with 11.0 ppg mu Appr Date 37 Seismic analysis-of shallpw gas_zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- - _ _ - _ _ _ Hydrates-have teen encountered at -1200' ND-on wells frpm thispad, and gas shpws, have been encountered _ _ SFD 1!312006 38 Seabed condition survey_(if off-shore) _ - - NA- - _ _ - - - - in the-West Sak at about 1900'-TVD. Mitigatipn measures discussed in_Drilling Hazards section. SFD- - - - - - - - 39 Contact namelpho_ne for weekly-progress reports-[exploratory only] - - - - - - - - - - - - - - - N_A_ Geologic Engineering Pu is Commissioner: Date: Commissioner: Date C is loner Date s • • Well History File APPENDIX Information of detailed nature that is not particularly germane io 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 organi2e this category of information. f Sperry-Sun Dri`i7ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 18 14:30:25 2006 • RECEIVED AUG 3 0 2006 Reel Header Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Alaska Oi! & Gas Cons. Commission Anchorage Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Tarn MWD/MAD LOGS WELL NAME: 2L-309 API NUMBER: 501032052100 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18-AUG-06 JOB DATA MWD RUN 5 MWD RUN 6 MWD RUN 7 JOB NUMBER: MW0004150952 MW0004150952 MW0004150952 LOGGING ENGINEER: C. ZAWADZKI C. ZAWADZKI C. ZAWADZKI OPERATOR WITNESS: E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 8 MWD RUN 9 JOB NUMBER: MW0004150952 MW0004150952 LOGGING ENGINEER: R. FRENCH R. FRENCH OPERATOR WITNESS: J. HABERTHUR J. HABERTHUR SURFACE LOCATION SECTION: 22 TOWNSHIP: lON RANGE: 7E FNL: 164 FSL: FEL: 631 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 149.28 GROUND LEVEL: 115.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS alp #/tIZO~- BIT S~ (IN) 1ST STRING 8.500 2ND STRING 6.125 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) 9.625 4340.0 7.000 14364.0 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. THIS WELL EXITS THE 2L-309 PB1 PILOT HOLE AT THE 9 5/8" CASING SHOE, 4340'MD/2386'TVD. IT WAS KICKED-OFF VIA A CEMENT PLUG. 4. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 5. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), STABILIZED LITHO-DENSITY (SLD), COMPENSATED THERMAL NEUTRON (CTN), ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD) . 6. NO PROGRESS WAS MADE ON RUN 4. 7. MWD RUNS 5-9 COMPRISED DIRECTIONAL, DGR, EWR4, AND PWD. MWD RUNS 6-8 ALSO INCLUDED GEOPILOT ROTARY STEERABLE BHA (GP) MWD RUN 9 ALSO INCLUDED CTN AND AZIMUTHAL LITHO-DENSITY (ALD). 8. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 8/17/06, FROM D. KLEIBACKER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 9. MWD RUNS 1-3,5-9 REPRESENT WELL 2L-309 WITH API#: 50-103-20521-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14960'MD/5916'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). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 10.00-10.15 PPG MUD SALINITY: 450-550 PPM CHLORIDES FORMATION WATER SALINITY: 31000 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.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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 4298.5 14904.0 RPD 4325.0 14911.0 RPX 4325.0 14911.0 RPS 4325.0 14911.0 FET 4325.0 14911.0 RPM 4325.0 14911.0 ROP 4340.0 14960.5 NPHI 14345.0 14876.0 NCNT 14345.0 14876.0 RHOB 14345.0 14891.0 DRHO 14345.0 14891.0 PEF 14345.0 14891.0 FCNT 14345.0 14876.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 5 4298.5 6 5586.0 7 7659.0 8 12546.0 9 14364.0 REMARKS: MERGED MAIN PASS. MERGE BASE 5586.0 7659.0 12546.0 14364.0 14960.5 Data Format Specification ReZ!~rd 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 FONT 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 Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4298.5 14960.5 9629.5 21325 4298.5 14960.5 FCNT MWD CNTS 215.37 840.58 451.077 1063 14345 14876 NCNT MWD CNTS 17826.1 34328.4 25557.2 1063 14345 14876 RHOB MWD G/CM 0.535 2.982 2.38614 1093 14345 14891 DRHO MWD G/CM -3.27 0.375 0.00519213 1093 14345 14891 RPD MWD OHMM 0.9 2000 16.5081 21173 4325 14911 RPM MWD OHMM 0.92 2000 12.5499 21173 4325 14911 RPS MWD OHMM 0.88 1691.72 4.70269 21173 4325 14911 RPX MWD OHMM 0.86 1374.11 4.45383 21173 4325 14911 FET MWD HOUR 0.21 356.9 2.70438 21173 4325 14911 GR MWD API 46.1 281.71 124.784 21212 4298.5 14904 PEF MWD BARN 3.45 14.47 5.14364 1093 14345 14891 ROP MWD FT/H 0.74 3675.97 91.0424 21242 4340 14960.5 NPHI MWD PU-S 19.35 37.78 28.0257 1063 14345 14876 First Reading For Entire File..........4298.5 Last Reading For Entire File...........14960.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 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..........~0.0 • Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4298.5 5544.5 RPM 4325.0 5536.5 RPX 4325.0 5536.5 RPS 4325.0 5536.5 FET 4325.0 5536.5 RPD 4325.0 5536.5 ROP 4340.0 5586.0 LOG HEADER DATA DATE LOGGED: 30-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5586.0 TOP LOG INTERVAL (FT) 4345.0 BOTTOM LOG INTERVAL (FT) 5586.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.6 MAXIMUM ANGLE: 76.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 4340.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.65 MUD VISCOSITY (S) 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1600 FLUID LOSS (C3) 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.100 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.400 86.0 MUD FILTRATE AT MT: 3.700 65.0 MUD CAKE AT MT: 3.100 65.0 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 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4298.5 5586 4942.25 2576 4298.5 5586 RPD MWD050 OHMM 3.16 2000 35.9691 2424 4325 5536.5 RPM MWD050 OHMM 2.67 703.1 6.22651 2424 4325 5536.5 RPS MWD050 OHMM 2.56 1691.72 6.26803 2424 4325 5536.5 RPX MWD050 OHMM 2.49 1374.11 5.74959 2424 4325 5536.5 FET MWD050 HOUR 0.29 356.9 7.28176 2424 4325 5536.5 GR MWD050 API 46.1 144.8 106.726 2493 4298.5 5544.5 ROP MWD050 FT/H 0.74 201.26 96.8793 2493 4340 5586 First Reading For Entire File..........4298.5 Last Reading For Entire File...........5586 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 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.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 5537.0 7613.5 RPX 5537.0 7613.5 RPD 5537.0 7613.5 FET 5537.0 7613.5 RPM 5537.0 7613.5 GR 5545.0 7621.0 ROP 5586.5 7659.0 LOG HEADER DATA DATE LOGGED: O1-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7659.0 TOP LOG INTERVAL (FT) 5586.0 BOTTOM LOG INTERVAL (FT) 7659.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.9 MAXIMUM ANGLE: 75.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE. TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 4340.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.65 MUD VISCOSITY (S) 43.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.500 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.430 104.0 MUD FILTRATE AT MT: 3.900 70.0 MUD CAKE AT MT: 3.200 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 i~ Data Specification Block~pe.....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 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5537 7659 6598 4245 5537 7659 RPD MWD060 OHMM 2.93 10.93 4.84659 4154 5537 7613.5 RPM MWD060 OHMM 2.68 14.27 4.68183 4154 5537 7613.5 RPS MWD060 OHMM 2.6 14.36 4.51851 4154 5537 7613.5 RPX MWD060 OHMM 2.54 14.43 4.40235 4154 5537 7613.5 FET MWD060 HOUR 0.21 16.72 1.07473 4154 5537 7613.5 GR MWD060 API 64.36 154.38 114.927 4153 5545 7621 ROP MWD060 FT/H 2.33 693.29 110.817 4146 5586.5 7659 First Reading For Entire File..........5537 Last Reading For Entire File...........7659 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: header data for each bit run in separate files. 7 .5000 ~ • FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 7614.0 12501.0 RPX 7614.0 12501.0 FET 7614.0 12501.0 RPM 7614.0 12501.0 RPD 7614.0 12501.0 GR 7621.5 12508.5 ROP 7659.5 12546.0 LOG HEADER DATA DATE LOGGED: 07-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12546.0 TOP LOG INTERVAL (FT) 7659.0 BOTTOM LOG INTERVAL (FT) 12546.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 71.7 MAXIMUM ANGLE: 76.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 4340.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 50.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 400 FLUID LOSS '(C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 4.500 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.740 126.0 MUD FILTRATE AT MT: 4.300 74.0 MUD CAKE AT MT: 5.400 72.0 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 .12N 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 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7614 12546 10080 9865 7614 12546 RPD MWD070 OHMM 2.02 32.26 4.80415 9775 7614 12501 RPM MWD070 OHMM 1.89 66.92 4.63157 9775 7614 12501 RPS MWD070 OHMM 1.49 12.68 4.22088 9775 7614 12501 RPX MWD070 OHMM 1.25 9.22 4.04136 9775 7614 12$01 FET MWD070 HOUR 0.34 31.15 1.36897 9775 7614 12501 GR MWD070 API 56.6 281.71 132.002 9775 7621.5 12508.5 ROP MWD070 FT/H 2.4 3675.97 86.1011 9774 7659.5 12546 First Reading For Entire File..........7614 Last Reading For Entire File...........12546 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 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 BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH RPS 12501.5 RPD 12501.5 RPX 12501.5 RPM 12501.5 FET 12501.5 STOP DEPTH 14320.5 14320.5 14320.5 14320.5 14320.5 GR 12509. ROP 12546.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 14328.5 14364.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 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 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 11-FEB-06 Insite 66.37 Memory 14364.0 12546.0 14364.0 34.6 75.4 TOOL NUMBER 149206 96540 8.500 4340.0 Polymer 9.65 52.0 10.0 400 4.2 2.200 78.0 1.320 134.0 3.500 78.0 2.000 78.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 ~ RPS MWD080 OHMM 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12501.5 14364 13432.8 3726 12501.5 14364 RPD MWD080 OHMM 1.28 9.05 4.72643 3639 12501.5 14320.5 RPM MWD080 OHMM 1.18 9.65 4.56814 3639 12501.5 14320.5 RPS MWD080 OHMM 1.18 9.8 4.39854 3639 12501.5 14320.5 RPX MWD080 OHMM 1.13 10.93 4.31729 3639 12501.5 14320.5 FET MWD080 HOUR 0.38 54.12 2.16159 3639 12501.5 14320.5 GR MWD080 API 68.66 194.21 127.033 3640 12509 14328.5 ROP MWD080 FT/H 13.1 194.34 92.5729 3636 12546.5 14364 First Reading For Entire File..........12501.5 Last Reading For Entire File...........14364 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 14321.0 14911.0 RPM 14321.0 14911.0 FET 14321.0 14911.0 RPS 14321.0 14911.0 RPD 14321.0 14911.0 GR 14329.0 14904.0 FCNT 14345.0 14876.0 NCNT 14345.0 14876.0 RHOB 14345.0 14891.0 DRHO 14345.0 14891.0 NPHI 14345.0 14876.0 PEF 14345.0 14891.0 ROP 14364 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 14960.5 17-FEB-06 Insite 68.18 Memory 14960.0 14364.0 14960.0 27.4 33.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ALD Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 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 TOOL NUMBER 64004 1844674407370955 167218 183652 6.125 14364.0 Polymer 10.00 53.0 9.5 450 5.5 4.900 72.0 2.880 127.3 3.500 72.0 3.400 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD090 CNTS 4 1 68 4 2 ~ • NCNT MWD090 CNTS 1 68 8 3 RHOB MWD090 G/CM 4 1 68 12 4 DRHO MWD090 G/CM 4 1 68 16 5 RPD MWD090 OHMM 4 1 68 20 6 RPM MWD090 OHMM 4 1 68 24 7 RPS MWD090 OHMM 4 1 68 28 8 RPX MWD090 OHMM 4 1 68 32 9 FET MWD090 HOUR 4 1 68 36 10 GR MWD090 API 4 1 68 40 11 PEF MWD090 BARN 4 1 68 44 12 ROP MWD090 FT/H 4 1 68 48 13 NPHI MWD090 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14321 14960.5 14640.8 1280 14321 14960.5 FCNT MWD090 CNTS 215.37 840.58 451.077 1063 14345 14876 NCNT MWD090 CNTS 17826.1 34328.4 25557.2 1063 14345 14876 RHOB MWD090 G/CM 0.535 2.982 2.38614 1093 14345 14891 DRHO MWD090 G/CM -3.27 0.375 0.00519213 1093 14345 14891 RPD MWD090 OHMM 0.9 2000 150.756 1181 14321 14911 RPM MWD090 OHMM 0.92 2000 143.337 1181 14321 14911 RPS MWD090 OHMM 0.88 1176.38 7.06267 1181 14321 14911 RPX MWD090 OHMM 0.86 1163.88 5.81007 1181 14321 14911 FET MWD090 HOUR 0.88 138.18 11.7669 1181 14321 14911 GR MWD090 API 73.59 220.13 131.064 1151 14329 14904 PEF MWD090 BARN 3.45 14.47 5.14364 1093 14345 14891 ROP MWD090 FT/H 6.23 117.76 45.9411 1193 14364.5 14960.5 NPHI MWD090 PU-S 19.35 37.78 28.0257 1063 14345 14876 First Reading For Entire File..........14321 Last Reading For Entire File...........14960.5 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Scientific Technical Services • • Physical EOF Physical EOF End Of LIS File r Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 18 14:09:13 2006 Reel Header Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Tarn MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0004150952 R. FRENCH E. VAUGHN / RECEIVED AUG 3 0 2006 Ica Uil & Gas Cons. Commission Anchorage Scientific Technical Services Scientific Technical Services 2L-309PB1 501032052170 ConocoPhillips Alaska, Inc. Sperry Drilling Services 18-AUG-06 SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 22 lON 7E 164 631 149.28 115.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4340.0 ago ~~lo~- REMARKS: • 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. THIS WELL WAS A PLANNED PILOT HOLE. 4. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 5. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4), STABILIZED LITHO-DENSITY (SLD), COMPENSATED THERMAL NEUTRON (CTN), ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD) . 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 8/17/06, FROM D. KLEIBACKER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3 REPRESENT WELL 2L-309 PB1 WITH API#: 50-103-20521-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9,203'MD/5,667'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/ACAL- DERIVED 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) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.5" MUD WEIGHT: 9.6-10.4 PPG MUD SALINITY: 400-700 PPM CHLORIDES FORMATION WATER SALINITY: 31000 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.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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 4309.5 9161.5 FET 4320.0 9154.0 RPX 4320.0 9154.0 RPM 4320.0 9154.0 RPD 4320.0 9154.0 RPS 4320.0 9154.0 NPHI 4340.0 9110.0 PEF 4340.0 9123.0 CALA 4340.0 9113.0 DRHO 4340.0 9123.0 RHOB 4340.0 9123.0 NCNT 4340.0 9110.0 FONT 4340.0 9110.0 ROP 4350.5 9203.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA {MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 4309.5 9203.0 REMARKS: MERGED MAIN PASS. 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 CALA MWD INCH 4 1 68 4 2 FCNT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 ~ RPD MWD OHMM 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 4309.5 9203 6756.25 9788 4309.5 9203 CALA MWD INCH 8.43 12.3 9.32613 9511 4340 9113 FCNT MWD CNTS 727.43 3977.78 1141.41 9541 4340 9110 NCNT MWD CNTS 126905 220561 157174 9541 4340 9110 RHOB MWD G/CM 1.548 2.79 2.32785 9567 4340 9123 DRHO MWD G/CM -0.128 0.492 0.0667219 9567 4340 9123 RPD MWD OHMM 1.32 2000 12.232 9669 4320 9154 RPM MWD OHMM 1.02 1743.45 6.59765 9669 4320 9154 RPS MWD OHMM 1.03 1134.46 4.44496 9669 4320 9154 RPX MWD OHMM 0.91 2000 4.59965 9669 4320 9154 FET MWD HOUR 0.18 80.6 1.439 9669 4320 9154 GR MWD API 43.07 216.84 122.713 9705 4309.5 9161.5 PEF MWD BARN 1.19 8.83 2.65929 9567 4340 9123 ROP MWD FT/H 1.81 558.34 159.036 9706 4350.5 9203 NPHI MWD PU-S 4.16 48.76 32.392 9541 4340 9110 First Reading For Entire File..........4309.5 Last Reading For Entire File...........9203 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 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.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 4309.5 STOP DEPTH 9161.5 0 RPX 4320. 9154.0 FET 4320.0 9154.0 RPS 4320.0 9154.0 RPD 4320.0 9154.0 RPM 4320.0 9154.0 PEF 4340.0 9123.0 NPHI 4340.0 9110.0 DRHO 4340.0 9123.0 RHOB 4340.0 9123.0 NCNT 4340.0 9110.0 FCNT 4340.0 9110.0 CALA 4340.0 9113.0 ROP 4350.5 9203.0 LOG HEADER DATA DATE LOGGED: 22-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9203.0 TOP LOG INTERVAL (FT) 4350.0 BOTTOM LOG INTERVAL (FT) 9203.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23.5 MAXIMUM ANGLE: 76.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 SLD STABILIZED LITHO DEN 78609 CTN COMP THERMAL NEUTRON 1844674407370955 ACAL Acoustic Caliper 143789 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 4340.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.65 MUD VISCOSITY (S) 56.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 4.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.780 71.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.780 114.4 MUD FILTRATE AT MT: 1.710 71.0 MUD CAKE AT MT: 3.200 71.0 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 ~e.....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 GALA MWD030 INCH 4 1 68 4 2 FCNT MWD030 CNTS 4 1 68 8 3 NCNT MWD030 CNTS 4 1 68 12 4 RHOB MWD030 G/CM 4 1 68 16 5 DRHO MWD030 G/CM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 RPM MWD030 OHMM 4 1 68 28 8 RPS MWD030 OHMM 4 1 68 32 9 RPX MWD030 OHMM 4 1 68 36 10 FET MWD030 HOUR 4 1 68 40 11 GR MWD030 API 4 1 68 44 12 PEF MWD030 BARN 4 1 68 48 13 ROP MWD030 FT/H 4 1 68 52 14 NPHI MWD030 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4309.5 9203 6756.25 9788 4309.5 9203 GALA MWD030 INCH 8.43 12.3 9.32613 9511 4340 9113 FCNT MWD030 CNTS 727.43 3977.78 1141.41 9541 4340 9110 NCNT MWD030 CNTS 126905 220561 157174 9541 4340 9110 RHOB MWD030 G/CM 1.548 2.79 2.32785 9567 4340 9123 DRHO MWD030 G/CM -0.128 0.492 0.0667219 9567 4340 9123 RPD MWD030 OHMM 1.32 2000 12.232 9669 4320 9154 RPM MWD030 OHMM 1.02 1743.45 6.59765 9669 4320 9154 RPS MWD030 OHMM 1.03 1134.46 4.44496 9669 4320 9154 RPX MWD030 OHMM 0.91 2000 4.59965 9669 4320 9154 FET MWD030 HOUR 0.18 80.6 1.439 9669 4320 9154 GR MWD030 API 43.07 216.84 122.713 9705 4309.5 9161.5 PEF MWD030 BARN 1.19 8.83 2.65929 9567 4340 9123 ROP MWD030 FT/H 1.81 558.34 159.036 9706 4350.5 9203 NPHI MWD030 PU-S 4.16 48.76 32.392 9541 4340 9110 First Reading For Entire File..........4309.5 Last Reading For Entire File...........9203 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/18 Origin .................. Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF Writing Library Scientific Technical Services Scientific Technical Services End Of LIS File ~}oGc~ ~.,r.~-~ i¢ 2a s ~ a J t~ ~ ~~(~al ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA _ _ ~. Provided by: ~` ~~` E .., 1 ~ - ~; _^. E~ EPOCH Compiled by: Lees Browne Jr. Brian O'Fallon Date: 1 /27/06 L~ ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA 2L-309 Provided by: [~ EPOCH ~RE~EIVEQ S E P p 5 2006 Alaska Oil & Gas Cons. Gotnmission Anchorage Approved by: Derik Kleibacker Distribution: Compiled by: Brian O'Fallon Date: 2/20/06 ~~~~~~~ 2L-309 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............................................................................................. .. 2 1.1 Equipment Summary .................................................................................................................... .. 2 1.2 Crew ............................................................................................................................................. .. 3 2 WELL DETAILS ................................................................................................................................... .. 4 2.1 Well Summary .............................................................................................................................. .. 4 2.2 Hole Data ..................................................................................................................................... .. 4 3 GEOLOGICAL DATA .......................................................................................................................... .. 6 3.1 Lithostratigraphy ..........................................................................:................................................ ..6 3.2 Mudlog Summary ......................................................................................................................... .. 7 3.3 Gas Samples ................................................................................................................................ 15 3.4 Connection Gases ........................................................................................................................ 17 3.5 Sampling Program /Sample Dispatch ......................................................................................... 18 4 PRESSURE /FORMATION STRENGTH DATA ................................................................................. 19 4.1 Formation Integrity/Leak Off Tests ............................................................................................... 19 4.2 Wire line Formation Tests ............................................................................................................ 19 4.3 Pore Pressure Evaluation Introduction ......................................................................................... 19 4.4 Pore Pressure Evaluation Conclusions ........................................................................................ 19 4.5 Pore pressure evaluation ............................................................................................................. 21 5 DRILLING DATA ................................................................................................................................. 24 5.1 Survey Data .................................................................................................................................. 24 5.2 Bit Record ..................................................................................................................................... 28 5.3 Mud Record .................................................................................................................................. 29 6 MORNING REPORTS ......................................................................................................................... 30 Enclosures 2"/100' Formation Log (MD) 2"/100' Gas Ratio Log 2"/100' LWD / Lithology Log C] ~POC,H 1 • • • 1 MUDLOGGING EQUIPMENT 8~ CREW 1.1 Equipment Summary Cf~170O0~1t~~~~5 2L-309 Parameter Equipment Type /Position TO~i Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. Insulated umbilical with three of ow lines. 0 No problems, no missing data. Hook Load / Wei ht on bit H draulic ressure transducer 0 No roblems, no missin data. Rate of penetration Primary draw-works block position indicator O tical encoder on draw-works 0 No problems, no missing data. Mudlo in unit com uter s stem HP Coma Pentium 4 X2, DML & Ri watch 0 On UPS should ower shut down on ri Mudlo in unit DAC box In-unit data collection/distribution center 0 On UPS should ower shut down on ri Mud Flow In Derived from Strokes/Minute and Pum Out ut 0 see um stroke counters below Pum stroke counters 2 um s Ma netic roximi sensors 0 No roblems, no missin data. Epoch commenced logging the 2L-309 on January 29, when sidetracking begun at 4345'. The Epoch unit was already running as it had been rigged up for 2L- 309PB1. Some minor problems with ditch gas were encountered early. The base plate on the gas trap allows mud into the trap fihrough a 2" diameter hole. A'/<" mesh screen covering the hole to prevent large rocks from entering the trap and breaking agitator prongs, was partially plugging in the thick mud and restricting flow into the trap. This screen was removed at 5000', as large rocks or cement fragments were no longer in the mud, and the flow was efficient thereafter. Occasionally the trap would be washed out as a preventive measure to help ensure reliable gas readings during shows. Also, two spare polyflow gas lines were utilized should freezing or plugging occur. One spare was rigged up to rig air to blowback lines to keep free of moisture and drilling mud. The second spare was kept as a back up gas line. Periodic rig power outages (highline generator) presented no problem to the Epoch unit, as all computers and sensors were on UPS. The few power outages were of a short duration, and never drained the UPS batteries. ~;POCH 2 • • ~ 1.2 Crew Unit Type Arctic Series 10 Skid Unit Number ~ ML030 ~,r ~i]I'1C3~OD~11~~1~35 2L-309 Mudloggers Years Da~s Sample Catchers Years Days Technician Days Trainees Days Brian O'Fallon 18 20 Lar Turner 7 3 Lees F. Browne Jr. 24 20 James Kvidera 2 3 Mike Menzel 2 13 Jason Duncan 1 17 Patrick Walker 1 4 'Years experience as Mudlogger .2 Days at well site between spud and total depth of well Additional Comments Technician required to work on DAC box. EPOCH ~O~IOC~'ll~~lp5 2L-309 • 2 WELL DETAILS 2.1 Well Summary Well: 2L-309 API Index #: 50-103-20521-00 Field: Tarn Surface Co-Ordinates: N: 5,927,681.46 E: 461,019.47 SEC 22 T10N R7E 163.94' FNL 631.48' FWl Borough: North Slope Primary Target Depth: 14444' MD State: Alaska TD Depth: 14960' MD 5916.16'TVD Rig Name /Type: Doyon #14 /Arctic Triple Suspension Date: None Primary Target: Bermuda Permit #: 205-210 Spud Date: 1/29/06 Ground Elevation: 117.1' AMSL Completion Date: 2/20/06 RT Elevation: 151.08' AMSL Completion Status: Production Liner Run Secondary Target De the None Classification: Development TD Date: 2/18106 TD Formation: Bermuda Days Testing: None Days Drilling: 20 2.2 Hole Data Maximum Depth Mud i / Shoe De th FIT TD Deviation ng Cas Hole Section MD NDSS Formation Weight (°inc) Coring Liner MD NOSS (PP9) ft ft (Pp9) (ft) (ft Conductor 119 32 Permafrost 9.9 0 NA 16" 119 32 NA 13 1/2" 4345 -2237 C85 10.2 76.57 NA 9 5/8" 4340 -2235 16.00 8 1/2" 1 X36 -5253 Iceberg 9.6 34.56 NA 7" 14364 -5253 16.0 7" 96 14 -5765 C35 10.0 27.37 NA 3'/z" 14960 -5765 NA 0 Additional Comments The 2L-309, spudded on January 29, after plugging procedures were completed on the 2L-309PB1, the pilot hole drilled to 9302' TD. Sidetracking began off the cement plug in the pilot hole at 4345', just below the 9 5/8" casing shoe. The 2L-309 included an 8'/2° intermediate hole from 4345' to 14364', and a 6 1/8" production hole through the Bermuda reservoir, from 14364' to total depth at 14960'. The intermediate hole was drilled as a long 75 (plus or minus) degree tangent until dropping down to 34.56 degrees just above the Bermuda reservoir and setting a 7° liner. The sidetrack was initiated with a mud motor assembly and mill tooth bit, from 4355' to 5586', and continued with arotary geo-steering assembly and PDC bit to 14364' (casing depth). The mill tooth and mud motor assembly was chosen to drill out cement and directionally drill deep enough at least until the ghost reamer was in open hole. The sidetrack was initiated with one hour timed drilling, sliding from 4345' to 4350'. Sliding continued at roughly 50- feet per hour to 4369', where the hole was cleaned out and the mud changed out. The mud used to begin the sidetrack was the same mud used to finish 2L-309P61. Minimal sliding was then needed to maintain tangent to 5586', when the mill tooth bit and mud motor assembly was pulled in favor of the rotary assembly. The hole had been packing off at connections, and control drilling was initiated after 4830', at the top of the C80 formation. Intentions were to drill to 5872', but some packing off continued, and the decision was the hole could be better maintained with high continuous rotary rpm. i Drilling proceeded slower than expected with the rotary assembly due to hole conditions, with ROPs reduced from ('~~~1 ,f-7 4 rr_.' ~a14CO~11~~tp5 2L-309 nearly 200 feet per hour to start, to averaging around 80 feet per hour below 6500'. Periodic wiper trips and sweeps • were used to clean the hole. Weighted sweeps were pumped at 6787', 7240', and 8692' while drilling. Twenty-five barrels were lost when the hole packed off at 9341', and at 10062' bottoms up was circulated to reduce high ECDs. Wiper trips were made at 7658', 9159', 10657', and 12546', a three stand wiper trip at 14150' to pick up 9 joints of drill pipe, and a final wiper trip at 14364', casing depth. During all trips it was necessary to pump out, but trips in mostly went well. At 7658' after pumping out to the shoe and circulating bottoms up, continued to pump out to 1400' and circulated four bottoms up. After downloading MWD, inspecting the Geopilot, waiting on mud, and tripping to bottom, the mud was displaced with a new mud without glycol additive (less dispersion of clays?). At the 9159' trip, pumped out to 6906', circulated 3 bottoms up, pumped out to the shoe and circulated out, and pulled out to the ghost reamer, removing it thinking it interfered with circulation and the cleaning of the hole. A weighted sweep was pumped at 9068' before drilling ahead. At 10657' pumped out to 9040', back reamed to 8490' due to packing off, losing 100 barrels of mud, pumped out to 8035', tripped in to 10,565', and pumped a nut plug pill around before drilling ahead. A full trip at 12546' was necessary to test BOPs and download MWD, pumping out to 2000', and working a tight spot from 10376' to 10094'. The trip in went well having only to wash to bottom from 12486' to 12546'. It should be noted that tripping out was much more successful pumping at 300-325 gpm, and over that caused packing off problems. After casing point at 14364', the hole was conditioned for three bottoms up before pumping and back reaming out to 8000', and tripping back to bottom. After washing to bottom from 14282', three bottoms up was circulated out, and pills were pumped at 14364', 12000', and 9000', en route to pumping out to 2000', and pulling out to run casing. The 7" casing run went very well, except it was necessary to push the casing down with the top drive, and the plug failed to bump while cementing. The production hole commenced 2/17/06 at 14364', and went welt, drilled to a total depth of 14960'. The mud was changed out at 14384', after an FIT of 16.0 ppg emw, with 510 bbls of 10.1 ppg mud. Drilling proceeded at a slow rate to contain ECD, averaging 47 feet per hour. A flow check at 14758' revealed the hole was breathing and possibly underbalanced, but drilling continued to total depth with pore pressure easily held in check with ECD. Following a wiper trip at TD, the mud weight was raised first from 10.0 to 10.2 ppg, and after some minor flow, raised to 10.4+ before tripping out to run a 3 %" production liner. The liner was cemented on February 20, and • Epoch was instructed to rig down. T~,,P(~C',H ~OCIQCO~~I~~~IpS 2L-309 3 GEOLOGICAL DATA • • 3.1 Lithostratigraphy Drilling picks & actual wire line tops refer to provisional picks provided by the well site Geologist. Intermediate and Production Hole PROGNOSED ACTUAL WIRELINE PICK HIGH/LOW FORMATION MDRT ft TVDSS ft MDRT ft TVDSS ft (ft) Sidetrack Point 4367 -2247 4345 -2236 11 C80 (K10) 4729 -2345 4833 -2358 -13 C50 10,012 -3775 10,001 -3776 -1 C40 11,322 -4125 11,437 -4155 -30 C37 12,127 -4340 12,124 -4340 0 Iceberg Zone 13,100 -4600 13,106 -4600 0 7" Casing Point 14,364 -5260 14,364 -5253 7 T3.1 14,417 -5305 14,420 -5300 5 T3 Top Bermuda 14,441 -5325 14,444 -5320 5 T2 Base Reservoir 14,597 -5460 14,594 -5446 14 C35 (K3) 14,770 -5610 14,755 -5584 26 TD 14,960 -5775 14,960 -5765 10 A h',PC~C,,H ~~1dC0~71~~~~5 2L-309 • 3.2 Mudlog Summary Sidetrack Point to C80 (K10) 4345' to 4833' MD -2236' to -2359' TVDSS Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 206 4.9 121 97 4 17 This section was a massive claystone with some interbedded siltstone. The claystone was light gray to pale yellowish brown, very soft to soft and amorphous due solubility in the mud system, with very slightly to occasionally moderately silty and slightly gritty textures, including mostly quartz silts to very fine grains, slight to trace carbon silts and fines, and minor other detrital matter. The clays were non to slightly calcareous with an occasional calcite streak. Interbedded siltstone was pale yellowish brown to light brownish gray, moderately to very clayey, very poorly indurated, with some very fine to fine sand grains, and minor carbon silts and fines. Overall there was very poor visible porosity and permeability, with no fluorescence or oil cuts. Maximum gas for the interval was 97 units, attained while drilling out cement with contaminated drilling mud from the pilot hole. The maximum gas peak after changing out mud was 28 units. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 4632 28 4390 119 126 87 AVE 17 2264 65 75 74 30 • C80 (K10) to C50 4833' to 10001' MD (-2358' to -3776' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 252 7.1 101 167 0 45 Three distinctive intervals are described here, from 4833' to 5523', 5523' to 9760', and 9760' to 10001'. This top section included a minor show in sand and sandstone interbedded with claystone in the upper 200 feet. The sand was less coarse but of similar composition to the conglomeratic sand observed in the pilot well. A thick bed of ash also occurred in the upper 200'. claystone, grading to shale and siltstone, was the dominant lithology in the upper interval. The second interval includes a clean gamma interval at the top, then from 5538' to 9760' was a massive gritty argillaceous section of little variation in composition, but gradational from argillaceous siltstone to silty/gritty claystone to argillaceous sandstone, with occasional thin beds of cleaner sandstone. Some minor show was reported between 5500' and 5800'. The bottom section had very high gamma and was dominantly carbonaceous. Shows were not observed in the third interval. The upper sand and sandstone was medium gray overall with very faint olive hue, a dominant fraction of very fine to occasionally medium angular to subrounded grains, and a scattered coarse to very coarse fraction of angular to rounded grains and concretions. The main sand body from 5050 to 5100' was poorly to moderately sorted, variably argillaceous and matrix and grain supported, and moderately to well consolidated as grades to grain supported sandstone with a siliceous matrix. Composition was 65% clear to translucent quartz, and 35% black dark brown gray to green to amber to gray silicates and partially siliceous lithics. Visible porosity was very poor. Show properties were considered poor, with 50% very faint to dull to rare spotty moderate greenish yellow fluorescence, a trace instant to slight diffuse light yellow cut, and a trace light yellow residue. A very fine • to silty sandstone associated with ash fall tuff but only 10% of cuttings, had a trace of fluorescence and cut ~ EPOCH COInOC~O~1l~~I~!S 2L-309 from 5020-5040', as did some minor sand near the C80 top. Show gas peaked at 134units in the main sand body at 5085'. A thick ash interval comprised 25% of the sample from 5000-5050', was very light gray to pale green, greasy, soft to brittle, and occasionally graded to soft sandy green chloritic clay. Traces of similar ash were observed in later samples, some possibly washing from this bed. Claystone, from 4833' to 5523', was medium gray to medium light gray, often with faint brownish to locally faint greenish hues, and mostly soft and amorphous due solubility in drilling mud and water. Cuttings not in solution were generally subblocky, separating easily into planar to uneven fragments, with some incipient fissilty or shaliness. Texture varied from slightly silty to silty, and from clayey to earthy. With increasing silt would occasionally grade to siltstone. Clays were very slightly organic over all, and slight silts and flakes of carbonaceous matter were pervasive throughout. Lower in the section, carbonaceous matter would occasionally increase to grading medium dark gray carbonaceous shales with a matte texture. Claystone higher in the section was generally non calcareous, to mostly slightly calcareous with a slow pervasive pin point effervescence in 10% HCL lower. Slightly scattered undifferentiated calcareous debris was also noted lower in the section, as were traces of hard blocky to angular calcareous concretions. Some uncharacteristic dark gray to brownish gray to medium gray shales were identified at 5200', with incipient fissility to platy fracture, earthy to silty texture, and occasionally a polished luster on partially siliceous pieces. A trace of hard platy to angular chert was observed associated with this shale, and traces of hard dark gray to black cherts with slightly scattered pyrite were observed a little lower. A 15 foot bed with clean gamma and a resistivity spike from 4 to 22 ohms caps the massive gritty argillaceous section at 5523-5538'. This bed was not readily identified in samples, and is possibly a dense clean sandstone with minor show gas. Minor calcareous debris was identified in the cuttings. • The middle section, from 5538'-9760', was dark gray to light gray, with brownish hues, and brownish gray to light brownish gray. Texture throughout was silty and gritty, due mostly to angular to subangular silt to fine grains of predominantly quartz, including quartz overgrowth, but in part due calcite. Often silty to gritty argillaceous cuttings would dissolve in 10% HCL to mostly clay residue, and only slight detrital silts and fines. Cuttings were mostly subblocky with common incipient fissility evidenced by faintly terraced rounded edges, and were slightly to moderately firm with a crunchy to crumbly tenacity. Occasional cuttings exhibited greater shaliness with slightly elongate1/4-1/2" splinters. Luster was earthy due to mostly slightly organic clays. Slight silts to fine (and locally coarse) flakes of carbonaceous matter, were pervasive throughout, scattered to linearly oriented along bedding planes. Other constituents, more common in argillaceous sandstone, included traces to slight interstitial tan matter, possibly siderite but rarely effervescing in 10%HCL, traces of chlorite (or glauconite), an occasional flake of biotite, and minor other silicates. Cuttings were overall slightly calcareous, with a slow pervasive pin point effervescence in 10% HCL, and overall moderately soluble including minor hydrophilic expansion with claystone. Locally, in thin beds, sandstone was less argillaceous, but typically dense, with either siliceous cement or calcareous cement, and calcite or quartz overgrowth. The lower section from 9760' to 10001' was dominated by claystone and shale grading to carbonaceous shale. Cuttings were medium dark gray to dark gray with brownish hues; moderately soft and soluble claystone, to moderately firm in some shale, and were only a trace to slightly calcareous. Clay content was slightly carbonaceous overall, but with slight to some moderate carbonaceous silts, flakes, and micro partings of carbonaceous matter and residue. Some minor siltstone, sandstone, and ash fall tuff was observed, apparently as scattered laminations to thin beds. A 10-foot zone from 9940-50' with relatively low gamma, is hard to define, with only slight amounts of sandstone and ash observed in the cuttings. • [~ ~PC~CH 8 ~tlO-C~~~11~~I~5 2L-309 DEPTH GAS units C1 m CZ m C3 m C4 m C5 m 5085 134 23475 363 158 113 65 5761 167 23558 1218 1107 1051 728 AVE 45 6941 293 238 215 137 C50 to C40 10001' to 11437' MD (-3776' to -4155' TVDSS) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 145 5.2 77 104 12 45 The C50 section included mostly claystone and siltstone, with incipient fissility grading to shale and locally common carbonaceous partings grading to carbonaceous shale. Sandstone was poorly developed or thinly bedded, some associated with ash fall tuff. Local thin calcite beds were also noted. Gas did not increase noticeably over background through any sandy intervals, and no distinctive oil cuts were observed. Only at 10702', did resistivity increase in a sandy interval, spiking at 10 ohms. Sandstone was medium gray to medium light gray with brownish hues, very fine to fine grained, angular to subrounded, poorly to moderately sorted, thinly bedded and laminated in siltstone and silty claystone, variably silty and argillaceous, and both grain and matrix supported. Most sandstone was poorly to moderately consolidated with clay matrix and slight calcareous cement. Some dense well consolidated sandstone had siliceous cement including quartz overgrowth. Composition included 70-90% quartz, and 30-10% mostly carbon silts and fines, slight glauconite or chlorite, and traces of tan interstitial matter possibly siderite. Visible porosity appeared to be very poor. Sandstone did not appear to fluoresce or cut, and some weak fluorescence and cut from mud products contamination was indistinguishable from possible oil cuts. Three clean gamma thin zones of less than ten feet, with low gamma spikes at 10081', 10232', and 10702', were hard to identify as sandstone with 50-foot samples, or as clean hard dense sandstone or calcite concretions with no inflection in drill rate. Sandstone often appeared to have an argillaceous ashy matrix, and at around 10700' appeared to grade to a grainy light gray ash fall tuff. Locally common light brown to white microcrystalline to cryptocrytallinecalcite, and scattered calcite debris were noted between 10050' and 10250'. claystone, shale, and siltstone was medium gray to dark gray, often with various brownish hues, moderately soft to firm with a crunchy to crumbly to brittle tenacity, and soluble to slightly soluble, except locally where slightly siliceous and brittle. Cuttings were subblocky to subplaty to occasional slightly elongate splinters, with common incipient fissility noted by terraced subplaty fracture or tabular habit. Traces to slight silts, fines and flakes, and scattered partings of carbonaceous matter persisted throughout. Graded to carbonaceous clay with increasing carbon clay content or locally increased micro partings of carbon residue. Graded to argillaceous siltstone and argillaceous silty sandstone with mostly quartz grains, and traces of glauconite (or chlorite), especially as grades to sandstone. Slight calcareous debris persisted throughout. Slight disseminated mica flakes were noted on some non carbonaceous shale. The peak gas of 104 units was tailing off after trip gas and after pumping a pill, and 82 units was the highest peak recorded of representative drill gas. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 10819 82 12022 687 569 501 336 AVE 45 6172 441 327 248 146 C40 to C37 11437' to 12124' MD -4019' to -4340' TVDSS Drill Rate (ft/hr) Total Gas (units) [~ EPOCH 9 7~O~il~~1~35 2L-309 C7 Maximum Minimum Avera a Maximum Minimum Avera e 190 12.2 81 73 18 43 The C40 was very clayey, with carbonaceous shale, claystone, shale, siltstone, some sandstone lamina, and minor light gray greasy ash fall tuff. No shows were observed. Carbonaceous shale was medium gray to dark gray to dark brownish gray, overall slightly firm and moderately soluble with variably carbonaceous (organic) clays, and scattered to bookleaf micro partings of carbonaceous matter and carbon residue. Graded to moderately soft claystone with lessening organics and carbon matter, while darker firmer cuttings exhibited more shaliness. Cuttings included traces of micro mica and micro pyrite, were mostly non calcareous, and some slightly to occasionally moderately calcareous. siltstone was light brownish gray to medium gray with brownish hue to medium light gray, .moderately soft to firm, with earthy to resinous luster, and silty to matte texture. Grains were dominantly quartz, with slight carbon silts and flakes, and traces of chlorite and other silicates. Clay content appeared to be both ashy and argillaceous, with a trace pin point effervescence in 10% HCL. Scattered throughout were micro partings of carbon residue and slight disseminated micro micas. siltstone was gradational with claystone and shale and minor very fine grained sandstone, and also occurred as laminations as did sandstone. Sandstone was more prominent above the C37. Sandstone at the base was medium light gray to light gray, very fine with scattered fine grains, subangular to angular, poorly to occasionally moderately sorted, matrix and grain supported, and mostly friable to poorly consolidated. The matrix was an ashy argillaceous clay with traces of calcite. Grains included quartz, feldspar, carbonaceous lithics, and chlorite. Probably occurs as thin beds and laminations grading to light brownish gray to light gray siltstone. Overall non to very poor visible porosity, and no fluorescence or cut. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 11765 73 9815 680 375 214 136 AVE 43 6157 475 269 173 99 Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 241 13.5 88 133 17 60 Top C37 to Iceberg Zone 12124' to 13106' MD -4340' to -4600' TVDSS The C37 section included carbonaceous shale, claystone, siltstone, shale, and minor sandstone at the top, and is much sandier with decisively less carbon matter below 12400'. Sandstone below the C40 was generally thinly laminated or thinly bedded gradational to siltstone, and similar in character and composition to the C40, as was carbonaceous shales. Some fluorescene and cut was likely from mud products, with no distinguishable oil cuts. claystone and shale was medium gray to medium dark gray, with common brownish hues and occasional faint olive hues, to light brownish gray to brownish gray. Cuttings ranged from moderately firm to soft, crumbly to crunchy to mushy, subblocky to subplaty to tabular, with some irregular planar fracture due incipient fissility, and a clayey to silty/gritty texture, from mostly quartz silts to very fine grains. Trace to slight carbon silts and flakes persisted throughout, reworked into the clays to give a mottled appearance grading into the Iceberg section. Cuttings were non calcareous to occasionally slightly calcareous, with locally traces of light gray microcrystalline calcite streaks noted. siltstone was medium gray to medium light gray, with common brownish hues, to brownish gray, and some medium dark gray below the C40. Cuttings were overall moderately firm to moderately soft, crunchy to friable • ~PO~H 10 ~CIr1OC~~11~~~~5 2L-309 . to mushy, subplaty to subblocky to tabular with common incipient fissility and some subplanar fracture, mostly very clayey, except as grading to coarse siltstone and sandstone. Silts were mostly quartz, with a trace to slight carbon silts and flakes persisting throughout, scattered micro partings of carbon residue, common traces disseminated mica flakes, and traces of greenish grains possibly glauconite. Cuttings were a trace to occasionally slightly calcareous, except locally calcareous grading light gray calcareous sandstone. Sandstone and sand below 12,400' was very light gray to medium light gray to light brownish gray, very fine to fine grained, angular to subrounded, subangular overall, poorly to moderately sorted, and grain and matrix supported. From 12400' to 12850' was light to very light gray sandstone, dominantly very fine grained to grading coarse siltstone, moderately well consolidated with a slight clay matrix and mostly calcareous and some siliceous cement, to some poorly consolidated with increasing clay support and non to slightly calcareous, and grains 85-90% quartz, and 10-15% mostly dark carbon or possible meta lithics, often partially siliceous to chert, and traces of tan interstitial matter (possible siderite). Below 12850' was mostly poorly consolidated sandstone and sand, visibly mostly clay supported and non to slightly calcareous, and abundant loose grains in sample commonly lightly frosted with white clay. Composition below 12850' appeared to change toward the base. Initially grains were 85% clear to translucent quartz, and 15% black to dark brown to gray to green to rust grains, including partially siliceous lithics, and minor chlorite (or glauconite) and hematite staining. Basal sands included 75% quartz, and very light gray to gray to dark gray to rare dark green lithics, including possibly weathered feldspar, partially siliceous lithics, and rare chlorite (or glauconite). Traces of aggregate pyrite was scattered in the basal sands. Visible porosity was poor to very poor as either dense sandstone or with clay infil. Gas never increased much over background drilling through sands, and some dull green fluorescence and faint cut was likely from mud products, indistinguishable from possible oil cuts. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 12983 133 18415 1572 980 703 495 AVE 60 7653 653 446 352 267 . Iceberg Zone to T3.1 13106' to 14420' MD -4600' to -5300' TVDSS Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 155 15 92 138 8 81 The Iceberg Zone includes massive beds of mostly poorly consolidated sandstone with intervals of mostly siltstone and claystone down to 13900', the base of the lowermost sand at 13733'. Below 13900' included some carbonaceous shale, and interbedded claystone, shale, siltstone and sandstone. Despite some minor resistivity peaks of up to 10, 8, and 9 ohms in a sandstone at 13320', and sands at 13445-60', and 13690- 733', respectively, there were no shows observed above casing point. After casing, a sandstone from 14380- 11420' had a minor show, with gas up to 133 units with a background of 25 units. Sandstone and sand above 13900' was mostly light gray to medium light gray, some light brownish gray below the C37, and locally medium gray. Grains were medium to very fine upper, and locally lightly scattered coarse lower, angular to subrounded, mostly subangular to subrounded, and mostly moderately sorted, to locally poorly sorted or well sorted. Sandstone or sand was mostly grain and some matrix supported, primarily unconsolidated in samples, some poorty consolidated with a slight silty clay matrix and weak siliceous cement, and occasionally moderately consolidated in the upper sandstone with either calcareous or siliceous cement. Composition in the upper sandstone was 60% clear to translucent quartz, and 40% gray to black to brown to white to rare tan and green grains, including partially siliceous lithics, minor chert and other silicates, trace biotite, and trace aggregated pyrite. Lower sands included 80% quartz, and 20%chert, lithics, possible meta lithics, and minor tuff fragments. Porosity was observed or estimated to be very poor in the upper sandstone, while some fair to good in the lower sands. . claystone above 13900' was medium gray to medium light gray to medium dark gray, occasionally with ~PQCH 11 ~"f7f1CI<CO'~11~~f~5 2t_-309 • brownish hues to light brownish gray, subblocky to tabularwith some incipient fissility, occasionally grading to shale. Cuttings had a clayey to moderately silty texture, dull to slightly greasy luster, were slightly mottled with slight dark carbonaceous matter and flakes in non to slightly carbonaceous light clays, and were non to very slightly calcareous. Some sandy cuttings indicated possible thin inter beds or streaks of sandstone. • • Below 13900' claystone was medium gray to medium dark gray, some with brownish hues, moderately soft to moderately firm, and subplaty to subblocky with some terraced incipient fissility grading shale. Clays were non to slightly carbonaceous/organic. Carbonaceous silts and fines were lightly scattered throughout, and flakiness along micro partings of carbonaceous residue was scattered to some common, grading carbonaceous shale. Texture was mostly clayey to silty, and luster dull to earthy, except some matte texture and resinous luster due slight disseminated pyrite on faint carbon residue. Claystone commonly graded to siltstone and occasionally exhibited grittiness as graded to sandstone. Cuttings were non to slightly calcareous. siltstone overall was medium gray to medium light gray, often with various brownish hues, to brownish gray to light brownish gray, moderately soft to moderately firm, subblocky to subplaty with faint to terraced incipient fissilty and some planar flakiness to subplanar fracture, a dull luster, silty texture to grading claystone or shale, trace to slight carbon silts or flakes, scattered micro partings of carbon residue below 13900', and non to slightly calcareous. Occasionally textures were gritty as graded to sandstone, including some clayey to clean thin beds of very fine to fine and scattered medium grained sandstone above the T3.1. The sandstone from 14380' to 14420' was medium gray to medium light gray, very fine to fine grained, subangular to angular, moderately to poorly sorted, grain and some matrix supported with slight light gray to some white clay matrix, and moderately consolidated to some friable with mostly siliceous and scattered calcareous cement. Composition included 85% quartz, and 15% mostly carbonaceous lithics, minor silicates, and a trace of chlorite (or glauconite) and tuff. Visible porosities were very poor. Minor show properties are difficult to distinguish from mud contaminants, and included a 10% faint to dull yellow green fluorescence and a trace diffuse cut. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 13444 138 14549 1148 730 459 283 14414 133 19749 1599 879 480 257 AVE 81 10932 933 638 421 260 T3.1 to T3 (Top Bermuda) 14420' to 14444' MD (-5300' to -5320' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 69 8.6 50 44 19 28 This brief interval includes claystone and shale, siltstone, and minor sandstone and ash fall tuff, similar to the basal Iceberg. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 14421 44 6346 547 315 182 118 AVE 28 4057 341 197 116 84 T3 (Top Bermuda) to T2 (Base Reservoir) 14444' to 14594' MD -5320' to -5446' TVDSS Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 78 18.9 55 401 14 213 [~ ~,PO~H 12 w-s ~~t1~~-~11)~I~S 2L-309 The T3 sandstone reservoir was easily distinguished from the overlying sandstones. The sandstone was light gray to medium light gray to occasionally yellowish gray, medium lower to fine grained with scattered medium upper and very fine upper grains, subangular to angular, moderately well to moderately sorted, and dominantly grain supported with a very slight white to light gray to tan matrix of mostly clay and traces of calcite. Grains were mostly unconsolidated in samples, some lightly frosted with clay, but often cuttings were variably well to poorly consolidated with some siliceous and traces of calcareous cement. Composition included 75% quartz, and 25% gray to black to dark brown to rare green and trace tan lithics including partially siliceous lithics and silicates. Some fair porosity is inferred, but visible sandstone porosity was poor. Oil properties included traces of light brown stain on clay, and 50-70% mostly dull to occasionally moderate light greenish yellow fluorescence over the entire interval, associated with show gas. Cut was a slow diffuse faint greenish yellow, with a slight light yellow fluorescent residue not visible in white light. Resistivity measured consistently 6-10 ohms. DEPTH GAS units C1 m CZ m C3 m C4 m C5 m 14479 390 44180 5845 4674 2928 1426 14500 155 15148 2075 1751 1202 689 14548 401 38647 5561 4741 3136 1519 14580 55 5502 640 566 447 289 AVE 213 22055 3014 2531 1691 863 T2 (Base Reservoir) to C35 (K3) 14594' to 14755' MD -5446' to -5584' NDSS U Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 84 11.1 50 123 38 72 Below the base of the reservoir and a thin shaley carbonaceous cap, is a dense sandstone from approximately 14600-40' of similar composition and grain size as the reservoir, but overall moderately well consolidated with siliceous cement, some apparent intebedded shale and siltstone, and only minor show indicators. Maximum gas was 123 units, with minor faint 10% yellowy fluorescence and a trace diffuse cut. The remaining section included shale, gradational to claystone and carbonaceous shale, siltstone, some thinly bedded sandstone, and ash fall tuff. The tuff is mostly grainy grading to sandstone, is prominent in the samples from 14640-14730', and likely massive to thinly interbedded with the other lithologies. Gas tapers off to average only 50 units through this section, with no apparent oil fluorescence, and minor cuts probably from mud contaminants. Drill rate, normally fairly uniform, was erratic through much of the ashy zone. claystone and carbonaceous shale was medium gray to medium dark gray with some brownish hues, slightly firm to moderately firm, with clayey to silty texture, and earthy to resinous luster. Slight to moderate irregular micropartings of carbonaceous matter invariably organic/carbonaceous clays diminishes to trace carbon silts and flakes as grades to a silty texture and a medium light gray siltstone. Traces of isolated micro pyrite associated with carbonaceous matter and residue, and traces of disseminated micro mica flakes are scattered throughout. Cuttings exhibit non to trace pin point effervescence in 10% HCL. The ash/sandstone was very light gray to medium gray, and appears to grade from a dense slightly soluble grainy ash to ashy sandstone to streaks of greasy soft ash. Grains range from fine to coarse and trace pebble sized, from angular to subrounded, with some angular grains appearing to be fragments of siliceous ash. Composition includes a light gray slightly soluble to soluble siliceous to possibly feldspathic matrix supporting quartz grains and fragments, minor carbonaceous matter and trace local micro partings of carbonaceous matter, occasional yellowy to white calcite, and trace greenish chlorite (or glauconite). • DEPTH GAS units C1 m C2 m C3 m C4 m C5 m ~1" ~C~ 13 ~~1~~1~?5 2L-309 • • 14637 123 10003 1480 1536 1318 768 AVE 72 6196 818 832 715 423 C35 (K3) to TD 14755' to 14960' MD (-5584' to -5765' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 60 21.6 37.1 74 21 37 The C35 is dominantly sand with some minor interbedded siltstone throughout. Sample quality was very poor from 14780' to 14810', and abundant mud lubricant was noted in these samples and in lesser degrees throughout this interval. Mud additives gave possible false oil cuts. The sands were very uniform with slight local increases in grain size. The sands were very light gray, with very fine lower to very fine upper grains, and locally some fine lower beginning 14870', subangular to subrounded with overall moderate developed sphericity, and moderate to some well sorted. Sands were mostly unconsolidated in samples, with an inferred overall very slight clay/silt matrix. Some poorly consolidated sandstone had a non to very slight siliceous cement; and a non to very slight claylsilt matrix. Composition included mostly quartz with very minor chert, argillite, and trace various lithic fragments. Porosity and permeability is estimated fair to good. Possible oil indicators include very dull light green sample fluorescence with no petroleum odor, sheen or stain. Most samples had a very weak hazy light green cut to 14825', decreasing to very poor cut at 14870', and decreasing to sporatic and finally zero cuts to TD. Resistivity measured only 3-5 ohms throughout. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 14851 35 5242 320 201 140 110 14955 74 9860 671 416 251 143 AVE 37 4802 317 220 166 127 E1 EPOCH 14 1~C0~11{~I~?5 2L-309 • 3.3 Gas Sam0les 1unit = 0.05% Methane Equivalent Gas Baas -Intermediate Hole • • Sam le De th Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=0.05% M,E. (ppm) (ppm (ppm) (ppm) (ppm) (ppm) (ppm) 1 4500 14 2460 41 50 49 2 4881 15 2621 58 56 45 3 5000 12 1710 23 18 7 27 10 22 4 5503 45 6756 112 113 32 96 61 71 5 6000 40 7372 106 78 23 85 37 53 6 6500 42 8415 127 99 37 107 25 41 7 7000 51 9651 488 356 67 187 45 70 8 7500 64 8712 392 209 55 148 49 61 9 8000 60 8668 328 314 83 253 150 242 10 8500 48 8541 401 245 45 130 60 76 11 9000 34 7048 381 233 38 110 57 56 12 9500 36 5334 278 222 50 151 44 81 13 10000 47 7086 310 192 40 111 37 61 14 10500 18 1526 204 147 30 88 22 55 15 11000 61 9100 649 525 105 303 116 163 16 11500 25 3775 279 89 33 87 68 50 17 12000 30 4759 366 258 39 104 39 69 18 12500 32 5208 382 234 41 119 40 19 19 13000 88 12074 976 622 117 377 160 256 20 13500 97 14342 1291 904 134 452 136 211 21 14000 68 9469 927 705 138 359 79 120 ~i ~17~~H 15 ~~1i~~1~'S 2L-309 • I~ntuha~ _ Prndur_tinn Hnlp Sam le De th Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1u=0.05% M.E. (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) 1 14400 93 14000 1049 530 74 205 64 90 2 14420 49 6967 601 345 52 145 44 72 3 14440 23 3555 277 145 16 64 15 24 4 14455 315 35715 4596 3661 592 1693 416 576 5 14485 Misrun with pumps off repeated ly -gas circulated out to connection depth before chromatograph cycled 6 14500 155 15148 2075 1751 287 915 279 410 7 14520 205 18681 2790 2498 435 1345 389 581 8 14539 248 22861 3376 2980 513 1597 462 678 9 14550 400 38782 5567 4730 781 2325 611 874 10 14560 153 14422 2146 1918 324 996 269 391 11 14580 56 5502 640 566 106 341 118 171 12 14600 81 7597 1039 950 174 552 170 258 13 14620 114 9525 1392 1421 282 905 273 400 14 14654 94 7676 1081 1127 232 760 242 356 15 14675 55 4019 556 620 135 453 155 227 16 14703 41 3201 393 424 93 315 107 170 17 14750 59 7630 655 541 101 317 117 160 18 14800 24 2584 198 171 37 118 59 94 19 14850 35 4131 253 162 23 92 37 52 20 14904 28 3237 216 150 28 104 34 43 21 14950 65 9914 671 408 60 184 61 80 EPOCH 16 C0~1i~~ip5 2L-309 • 3.4 Connection Gases There was no true connection gas in the intermediate hole. An uphole connection gas was encountered immediately after beginning the sidetrack, and continued throughout the intermediate section. This connection gas always peaked between 2200 and 2600 strokes, lagging to just below the casing shoe, and ranged from 65 to 410 units over background gas, depending on the length of the connection or relative background gas. A second peak lagging surface to surface, began after tripping for the rotary assembly at 5586', and diminished or became indistinguishable from background gas. This second peak averaged 10-15 units over background and was logged as kelly gas (KG). A third gas event began after dropping angle, beginning at 13961', and lagged to all successive pulling off bottom events, including back reaming before a connection. This was labeled back ream gas and ranged from 10 to 125 units over background. The only true connection gases were encountered in the two successive connections above total depth in the production hole. In fact, a triple peak, including backream gas, connection gas, and kelly gas occurred with both connections. All connections for the production hole are listed below with the observed connection gas. 1 unit = 0.05% Methane Equivalent Depth(TVD) feet Gas units/BG Depth(TVD) feet Gas units/BG Depth(ND) feet Gas units/BG 14393(5428) 0 14587(5591) 0 14778(5755) 112 14488(5507) 0 14681(5671) 0 14873(5839) 281 • .G~~~~ 17 ~D~ll~~~~?5 2L-309 3.5 Sampling Program /Sample Dispatch • • For Intermediate and Production Hole (2L-309) Set T e / Pur ose Fre uenc Interval Dis atched to Bayview Warehouse Unwashed Biostratigraphy 50' 4350' -14364` MD ConocoPhillips Alaska, Inc. ABV 100 A CPAI 10' 14364 -14960 MD 8105 Eleusis Drive Anchorage, AK 99502 SNOWS Attn: 0. P o'ski/M. McCracken Bayview Warehouse Washed Gas Peak ConocoPhillips Alaska, lnc. ABV 100 B Cuttings, stored wet 10' 14364' -14960' MD 8105 Eleusis Drive CPAI Anchorage, AK 99502 Attn: D. P o ski/M. McCracken Bayview Warehouse Washed, screened & 50 4350' -14364` MD ConocoPhillips Alaska, Inc. ABV 100 C dried Reference Samples , 14364' -14960' MD 8105 Eleusis Drive CPAI 1 ~ SNOWS Anchorage, AK 99502 ' ski/M. McCracken Attn: D. P o Bayview Warehouse Washed, screened & 50' 4350' - 14364` MD ConocoPhillips Alaska, Inc. ABV 100 D dried Reference Samples 10' 14364' -14960' MD 8105 Eleusis Drive CPAI Anchorage, AK 99502 SNOWS Attn: D. P o'ski/M. McCracken Bayview Warehouse Washed, screened & 50' 4350' -14364` MD ConocoPhillips Alaska, Inc. ABV 100 E dried Reference Samples 10' 14364' -14960' MD 8105 Eleusis Drive CPAI SNOWS Anchorage, AK 99502 Attn: D. Przywojski/M. McCracken Gas Bags Routine intervals or ' 4500' - 14000' MD lsotech Laboratories, Inc. F si nificant eaks above 9 P 500 Show Peaks 1308 Parkland Court Champaign, IL 61821 back round Isotubes 20-foot samples through ' 14400' - 14960' MD Isotech Laboratories, Inc. G Bermuda reservoir and 20-50 Show Peaks 1308 Parkland Court Champaign, IL 61821 25-50 sam les to TD. SET A: 2 BOXES each 1 cubic foot (Do Not Freeze) SET B: 1 BOX -1 cubic foot (Do Not Freeze) SET C,D,E: 1 each 6-pack bundle 10"x10"x16" (total 3) SET F: 1 BOX -10"X10"X18" -Hazardous Gas, 21 CALI-BOND Gas Bags (warehouse to re-package) SET G: 1 BOX - 8'/" X 8 %2" X 10'/z" -Hazardous Gas, 21 metal Isotubes (warehouse to re-package) Total 8 boxes EPOCH 18 ~' CtN10C0~11~~1~]5i 2L-309 CJ • 4 PRESSURE /FORMATION STRENGTH DATA 4.1 Formation Integrity/Leak Off Tests Equivalent mud weight (EMW) is calculated from rotary table. LOT (Leak Off Test) in bold italics. MD TVDSS FIT /LOT FORMATION (ft) ft) (pp EMW 4370' -2244 16.0 C37 14384' -5269 16.0 Iceber 4.2 Wire line Formation Tests HYDROSTATIC DEPTH TVD TVDSS Before After F Press Mobility PPG Calc Formation No Data 4.3 Pore Pressure Evaluation Introduction Trend Indicators Background Gas (BG) Trip Gas (TG) Downtime Gas (DTG) Mud Weight (MW) Resistivity (RES) Wiper Gas (WG) Corrected D exponent (DXC) Hole Conditions (HC) Connection Gas (CG) Pressure Test Wire line (PT) Survey Gas (SG) Pore Pressure (PP) Equivalent Circulating Density (ECD) The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of a well; Quantitative Methods The primary indicators used for PP evaluation were gas trends, including BG, CG, TG, WG, and DTG, and HC including flows and gas from swabbing or backreaming. Wire line testing was not conducted on this well. Epoch was not monitoring RPM, necessary for DXC calculations, and therefore DXC plots were not utilized. Factors such as controlled drill rates, alternate sliding and rotating intervals, variations in angle building, PDC bits, and the absence of clean shale baselines to establish compaction trends, tend to make DXC plots unreliable, anyway. RES plots tend to be reliable in determining a permafrost base, and suggesting compaction trends with depth, although the presence of hydrocarbons skews this data. However, generally, low RES and low gas indicate shaliness. 4.4 Pore Pressure Evaluation Conclusions 8'/:" intermediate and 61/8" production hole (MD:4345' to 14960'; TVD: 2388'916') Since the production hole was only 600', the two hole sections are combined. Casing point for 7" casinc was 14364' (5404' TVD) and is noted on the plots. • Pore pressure in the intermediate hole first appeared to be approaching mud weight at 13961' (5108'TVD), in the lower Iceberg, where gas surges from backreaming indicated some swabbing of the ~PO~H 19 Cflf10t~0~11~~1~ 2L-309 hole. However, as there were no true connection gases throughout the intermediate section, pore pressure remained below the 9.6 to 9.7 mud weights recorded throughout the intermediate hole. Some of the "swabbing" may have been due to dropping angle. After drilling a 75 degree tangent to approximately 13000 feet, the angle had been dropped to approximately 52 degrees by 13900, and 34 degrees by casing point. Some increased torque and difficulties in hole cleaning while dropping angle may suggest additional "reaming of the hole" when pulling off bottom, with some pore pressure increases also possibly contributing to the formation swabbing into the hole. ECDs were fairly constant in the intermediate section, dropping briefly after trips (TVD:2722', 3293', 3698', 4094', and 4597'), but averaging around 11.6 ppg. Pore Pressure in the intermediate hole is estimated to have remained fairly constant between 9.1 and 9.2 ppg to possibly as high as 9.4 ppg approaching casing point. The production hole was drilled with a 10.1+ to 10.0 ppg mud. ECD gradually dropped from 12.5 ppg in the clay rich Iceberg, to 11.8 ppg in massive C35 sands. A lack of connection gas despite high show gas indicated the mud weight was easily over pore pressure through the Bermuda reservoir. Upon entering the C35, a flow check at 14758' revealed some minor flow with a downtime gas 30 units over background. Connection gases following the flow check were 112 and 281 units over background on the two successive connections to total depth at 14960', and 200 units was observed for a momentary downtime at TD. A back ream gas of 10, 25, and 40 units over background was observed for these same three events, respectively. Background gas, constant at about 30 units above 14920', gradually increased to 75 units just above TD, indicating a slight pressure trend. A wiper trip at total depth resulted in 324 units of trip gas with a 10.0 mud, and the well flowed when checking flow after pumping out to the shoe. After weighting up to 10.2, the well continued to flow and 131 units of downtime gas lagged to the flow check. The mud weight was increased to 10.4+ before tripping out to the shoe and monitoring the well, with no flow observed. • Pore pressure in the production hole is estimated to have increased to 9.6 ppg entering the reservoir, increasing again to 9.8 entering the C35, and trending upward to total depth to 10.1 ppg. Some losses occurred while drilling and much of the flow is likely due to the formation breathing after being charged by the high ECD, and not solely attributed to pore pressure. The following chart and plots summarize the conclusions for pore pressure. • EPOCH 20 • 4.5 Pore pressure evaluation ~s i ~! C~1i1UC~0~'11~~~~?S 2L-309 Primary Secondary Interval To s Pore Pressure EMW T d Source of Formation Interval Lithology (%) Lithology (%) MD ft TVD ft Min Max Trend ren Indicators Quantitative Estimate Sidetrack Point CI st 80% Sltst 20% 4345 2387 9.1 9.2 Flat BG RES C80 Sltst 50% CI st 30% 4833 2509 9.1 9.2 Flat BG,TG RES C50 Sh-CI st 60% Sltst 25% 10001 3927 9.1 9.2 Flat BG,TG RES C40 Sh-CI st 60% Sltst 30% 11437 4306 9.1 9.2 Flat BG,TG RES Iceber Zone Sh-CI st 40% Sd-Ss 30% 13106 4751 9.1 9.4 Sli U BG,HC,TG RES T3 Bermuda Ss-Sd 50% Sh-CI st 20% 14444 5471 9.6 9.7 Sli U BG RES C35 Sd-Ss 80% Sltst 10% 14755 5735 9.8 10.1 U BG,CG,HC RES TD NA NA 14960 5916 10.1 10.1 NA HC,TG RES NOTE: Clyst = Claystone/Clay, Sd =Sand, Sltst = Siltstone, Sh =Shale, Ss =Sandstone EPOCH 21 • • s COrl000~11~~Ip5 2L-309 100 10 1 0.1 RES and GAS vs TVD ~~ EPOCH f GAS(me+0.1) • RES(deep) 22 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 • • • COt1000~'11~~Ip5 2L-309 ECD,MW,PP and GAS vs TVD 15 14.5 14 13.5 13 12.5 12 11.5 11 10.5 10 9.5 9 8.5 8 -t- GAS(me+8) I ~~MW(pp9) • ECD(pp9) j PP(pp9) 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 ~~ EPOCH 23 ,~.' ~'11~~Ip5 2L-309 . 5 DRILLING DATA • 5.1 Survey Data (includes surface hole data from 2L-309PB) Measured p D~ ft~ h Incl. (°) Azim. (°) True Vertical Depth ft Latitude (ft) Departure ~ft1 Vertical Section (ft) Dogleg Rate (°/100ft) 34.3 0 0 34.3 0 0 0 0 115 0.57 131.39 115 -0.27 0.3 0.4 0.71 172 1.17 133.03 171.99 -0.85 0.94 1.26 1.05 262 1.22 137.41 261.97 -2.18 2.26 3.14 0.12 353 1.9 121.46 352.94 -3.68 4.2 5.57 0.88 441 3.05 104.62 440.86 -5.04 7.71 8.98 1.53 477.26 3.76 105.68 477.05 -5.6 9.79 10.83 1.97 567.56 6.22 104.71 567 -7.64 17.37 17.57 2.73 658.8 10.6 102.75 657.24 -10.75 30.35 28.83 4.81 752.28 10.98 108.76 749.07 -15.51 47.16 43.95 1.27 845.49 15.53 106.25 839.77 -21.86 67.56 62.7 4.92 939.39 19.63 104.6 929.27 -29.36 94.9 87.1 4.4 1033.45 21.47 104.46 1017.34 -37.64 126.86 115.28 1.96 1127.48 25.46 103.01 1103.58 -46.49 163.23 146.94 4.29 1222.2 26.89 103.14 1188.58 -55.94 203.93 182.04 1.51 1315.99 31.96 103.36 1270.25 -66.51 248.76 220.81 5.41 1397.68 35.34 103.27 1338.24 -76.93 292.81 258.93 4.14 1493.33 39.53 106.37 1414.18 -91.87 348.97 308.72 4.8 1587.9 47.93 105.69 1482.45 -109.87 411.75 365.33 8.9 1682.68 50.28 105.58 1544.5 -129.18 480.74 427.19 2.48 1778.52 54.21 106.33 1603.17 -150.02 553.58 492.82 4.15 1869.69 57.85 106.17 1654.1 -171.17 626.15 558.5 4 1963.02 60.32 106.83 1702.05 -193.92 702.92 628.23 2.72 2059.85 62.44 106.34 1748.43 -218.17 784.38 702.32 2.23 2151.12 66.42 107.18 1787.82 -241.92 863.19 774.2 4.44 2249.08 72.26 104.27 1822.37 -266.7 951.38 853.34 6.58 2345.52 74.05 103.64 1850.32 -288.96 1040.96 931.64 1.96 2447.33 74.06 103.25 1878.28 -311.72 1136.17 1014.21 0.37 2529.06 73.99 102.97 1900.78 -329.54 1212.69 1080.24 0.34 2630.53 73.89 102.98 1928.85 -351.44 1307.71 1162.07 0.1 2726.4 72.84 106.59 1956.3 -374.87 1396.51 1240.66 3.77 2820.34 73.51 105.74 1983.49 -399.9 1482.87 1318.72 1.12 2913.01 73.9 104.91 2009.49 -423.41 1568.66 1395.27 0.96 3007.74 75.12 103.86 2034.79 -446.08 1657.08 1473.07 1.67 3101.97 74.97 105.1 2059.11 -468.84 1745.23 1550.73 1.28 3185.18 75.52 105.82 2080.3 -490.29 1822.78 1620.08 1.07 3286.82 75.17 106.01 2106.02 -517.26 1917.35 1705.23 0.39 3378.69 75.32 105.01 2129.42 -541.01 2002.95 1781.84 1.07 L~l~~~~ 24 1~D~1i~~t~iS 2L-309 • • • Measured Depth (ft) Incl. (~) Azim. ~~~ True Vertical Depth ft Latitude (ft) Departure (ft) Vertical Sefton () Dogleg oR00ft) 3474.86 74.72 103.49 2154.28 -563.88 2092.99 1860.89 1.65 3568.59 74.7 103.88 2178.99 -585.27 2180.83 1937.36 0.4 3661.05 73.16 103.82 2204.59 -606.54 2267.1 2012.64 1.67 3753.31 73.75 103.54 2230.86 -627.46 2353.03 2087.44 0.7 3846.81 73.95 103.63 2256.87 -648.55 2440.32 2163.31 0.23 3941.22 73.33 105.4 2283.46 -671.25 2528.02 2240.62 1.92 4036.65 72.8 106.11 2311.26 -696.04 2615.88 2319.54 0.9 4131.06 76.02 106.26 2336.63 -721.39 2703.2 2398.48 3.41 4226.57 76.29 106.07 2359.48 -747.2 2792.27 2478.98 0.34 4303.49 76.57 104.99 2377.53 -767.22 2864.31 2543.47 1.41 4345 76.16 106.65 2387.32 -778.22 2903.12 2578.37 4.01 4430.65 77.13 107.28 2407.1 -802.54 2982.82 2651.28 1.34 4518.92 76.21 107.04 2427.45 -827.88 3064.89 2726.56 1.08 4612.08 75.33 106.59 2450.35 -854 3151.33 2805.46 1.05 4709.89 74.62 104.16 2475.71 -879.05 3242.41 2886.8 2.51 4803.07 74.16 104.37 2500.79 -901.16 3329.38 2963.18 0.54 4896.89 74.33 104.02 2526.26 -923.3 3416.92 3039.98 0.4 4990.76 73.69 104.09 2552.12 -945.22 3504.46 3116.61 0.69 5086.48 73.95 104.3 2578.79 -967.76 3593.58 3194.79 0.34 5178.27 73.56 104.09 2604.47 -989.37 3679.01 3269.74 0.48 5271.54 73.23 103.68 2631.12 -1010.82 3765.78 3345.5 0.55 5365.92 73.04 104.33 2658.51 -1032.68 3853.42 3422.16 0.69 5459.79 73.51 106.55 2685.52 -1056.61 3940.06 3499.62 2.32 5550.68 72.57 105.67 2712.03 -1080.74 4023.58 3575.05 1.39 5653.8 72.92 108.08 2742.63 -1109.32 4117.81 3661.13 2.26 5747.61 73.1 110.44 2770.04 -1138.91 4202.5 3741.29 2.41 5838.31 72.79 111.29 2796.64 -1169.8 4283.53 3819.84 0.96 5935.88 73.42 114.17 2825 -1205.87 4369.62 3905.64 2.9 6027.26 74.4 114.89 2850.33 -1242.32 4449.5 3987.38 1.31 6121.26 75.28 113.94 2874.91 -1279.82 4532.11 4071.79 1.35 6214.19 75.61 115.64 2898.27 -1317.54 4613.76 4155.68 1.81 6306.6 75.03 116.13 2921.69 -1356.56 4694.19 4239.65 0.81 6400.75 74.71 117.05 2946.26 -1397.24 4775.46 4325.41 1 6495.6 74.58 116.41 2971.38 -1438.38 4857.15 4411.79 0.66 6593.77 73.99 116.34 2997.97 -1480.36 4941.81 4500.84 0.6 6687.81 73.42 117.38 3024.35 -1521.14 5022.34 4586.14 1.22 6781.32 73.49 118.39 3050.98 -1563.07 5101.57 4671.37 1.04 6874.51 73.54 120.19 3077.43 -1606.78 5179.5 4756.98 1.85 6969.92 73.74 121.52 3104.3 -1653.73 5258.08 4845.38 1.35 7063.09 74.06 122.68 3130.14 -1701.3 5333.91 4932.3 1.24 7156.99 74.06 124.32 3155.93 -1751.13 5409.2 5020.47 1.68 7250.68 73.96 125.4 3181.74 -1802.61 5483.1 5108.86 1.11 ~Pt7CH 25 ~~I~~~~ 2L-309 • Measured Depth (ft) Incl. (~l Azim. (~~ True Vertical Depth ft Latitude (ft) Departure (ft) Vertical Sefton O Dogleg °/R100ft) 7345.04 74.38 126.75 3207.48 -1856.07 5556.47 5198.29 1.45 7438.67 74 128.22 3232.99 -1910.89 5627.96 5287.4 1.56 7533.83 73.94 129.26 3259.27 -1968.12 5699.3 5378.14 1.05 7627.17 74.58 131.16 3284.59 -2026.12 5767.9 5467.53 2.08 7722.1 74.18 131.75 3310.15 -2086.64 5836.42 5558.67 0.73 7817.2 74.01 131.78 3336.22 -2147.56 5904.64 5649.89 0.18 7911.24 73.61 131.5 3362.44 -2207.57 5972.13 5739.95 0.51 8006.66 74.71 132.39 3388.48 -2268.93 6040.4 5831.52 1.46 8097.52 75.09 131.65 3412.15 -2327.65 6105.57 5919.04 0.89 8187.51 74.51 131.41 3435.75 -2385.22 6170.58 6005.63 0.69 8283.15 74.52 131.91 3461.28 -2446.49 6239.44 6097.54 0.5 8376.54 74.44 132.87 3486.27 -2507.15 6305.9 6187.35 0.99 8470.97 73.88 133.99 3512.04 -2569.6 6371.87 6278.11 1.29 8568.74 73.88 136.53 3539.19 -2636.31 6437.98 6372.02 2.5 8657.02 74.26 136.6 3563.42 -2697.96 6496.35 6456.9 0.44 8750.07 73.95 137.56 3588.91 -2763.49 6557.29 6546.37 1.05 8848.13 74.66 137.93 3615.44 -2833.37 6620.77 6640.73 0.81 8943.49 74.52 136.92 3640.78 -2901.06 6682.96 6732.63 1.03 9036.93 74.51 137.54 3665.72 -2967.17 6744.11 6822.65 0.64 9129.26 74.97 136.83 3690.02 -3032.5 6804.65 6911.71 0.89 9211.63 74.59 137.05 3711.65 -3090.58 6858.91 6991.17 0.53 9309.8 74.2 137.3 3738.06 -3159.92 6923.19 7085.7 0.47 9401.29 74.78 137.02 3762.52 -3224.57 6983.13 7173.84 0.7 9499.18 74.72 135.69 3788.27 -3292.91 7048.31 7268.28 1.31 9593.4 74.53 134.57 3813.25 -3357.29 7112.4 7359.12 1.16 9688.47 74.71 134.76 3838.47 -3421.73 7177.6 7450.76 0.27 9781.21 74.75 133.35 3862.89 -3483.94 7241.89 7540.17 1.47 9872.64 73.15 134.4 3888.17 -3544.83 7305.23 7627.98 2.07 9966.28 71.66 134.27 3916.48 -3607.21 7369.07 7717.2 1.6 10055.41 73.12 135.6 3943.44 -3667.21 7429.2 7802.14 2.17 10154.62 75.74 136.09 3970.07 -3735.77 7495.77 7897.7 2.68 10245.64 76.3 136.33 3992.06 -3799.53 7556.89 7986.02 0.67 10337.38 76.48 135.73 4013.64 -3863.7 7618.8 8075.18 0.67 10436.79 75.92 135.42 4037.36 -3932.65 7686.37 8171.72 0.64 10532.53 75.09 135.24 4061.32 -3998.57 7751.54 8264.41 0.$9 10627.13 74.77 135.59 4085.92 -4063.63 7815.66 8355.75 0.49 10721.63 74.19 136.09 4111.2 -4128.95 7879.09 8446.8 0.8 10811.83 73.94 135.9 4135.97 -4191.33 7939.35 8533.54 0.34 10910.43 73.5 136.18 4163.61 -4259.46 8005.05 8628.18 0.52 11006.4 73.61 136.45 4190.78 -4326.02 8068.62 8720.23 0.29 11099.27 74.27 136.16 4216.47 -4390.55 8130.27 8809.47 0.77 11191.94 74.71 136.44 4241.25 -4455.11 8191.97 8898.76 0.56 ~ EPOCH 26 ~0~11~~1~?S 2L-309 • • L` Measured Deft; h p Incl. (°) Azim. (°) True Vertical Depth ft Latitude (ft) Departure (ft) Vertical Section (ft) Dogleg Rate (°/100ftj 112$6.61 74.91 136.73 4266.05 -4521.47 8254.76 8990.12 0.36 11381.68 74.4 136.52 4291.21 -4588.11 8317.72 9081.79 0.58 11476.21 74.14 135.58 4316.84 -4653.62 8380.87 9172.78 1 11570.87 73.87 136.28 4342.92 -4719 8444.16 9263.78 0.77 11656.41 74.27 136.35 4366.4 -4778.48 8500.97 9346.03 0.47 11760.77 74.45 136.41 4394.54 -4851.23 8570.3 9446.52 0.18 11854.75 74.39 136.26 4419.78 -4916.72 8632.8 9537.04 0.17 11948.5 75.1 136.01 4444.44 -4981.93 8695.48 9627.49 0.8 12043.11 74.44 135.52 4469.3 -5047.33 8759.16 9718.78 0.86 12136.37 74.2 135.49 4494.5 -5111.38 8822.09 9808.56 0.26 12231.28 75.35 135.53 4519.43 -5176.71 8886.26 9900.14 1.21 12323.21 75.73 136.08 4542.38 -5240.53 8948.32 9989.16 0.71 12421.01 76.49 135.91 4565.86 -5308.82 9014.28 10084.09 0.8 12514.81 75.08 135.68 4588.89 -5374 9077.67 10175.02 1.52 12608.87 73.68 135.59 4614.22 -5438.76 9141.01 10265.6 1.49 12702.93 72.71 136.31 4641.41 -5503.48 9203.62 10355.64 1.27 12797.96 74.07 136.77 4668.58 -5569.57 9266.25 10446.7 1.5 12891.5 75.35 136.12 4693.24 -5634.96 9328.42 10536.92 1.52 12984.04 74.78 136.11 4717.09 -5699.41 9390.41 10626.34 0.62 13078.6 73.54 136.59 4742.9 -5765.23 9453.2 10717.3 1.4 13173.91 72.59 136.99 4770.66 -5831.68 9515.62 10808.47 1.07 13268.49 71.74 136.94 4799.63 -5897.49 9577.07 10898.49 0.9 13362.55 71.09 137.01 4829.61 -5962.66 9637.9 10987.63 0.69 13456.95 68.9 136.54 4861.9 -6027.3 9698.64 11076.32 2.37 13551.11 66.09 136.34 4897.94 -6090.33 9758.58 11163.29 2.99 13646.07 63.02 136.17 4938.73 -6152.27 9817.86 11249.03 3.24 13740.54 59.85 135.2 4983.9 -6211.64 9875.81 11331.99 3.47 13834.53 56.35 134.48 5033.56 -6267.9 9932.38 11411.75 3.78 13929.58 52.57 133.88 5088.8 -6321.8 9987.82 11489.05 4.01 14023.64 48.47 132.61 5148.59 -6371.54 10040.68 11561.55 4.4$ 14118.6 44.4 133.62 5214.02 -6418.54 10090.91 11630.26 4.35 14210.42 41.04 134.69 5281.47 -6461.92 10135.61 11692.51 3.74 14306.89 35.93 137.04 5356.97 -6504.93 10177.44 11752.51 5.51 14333.95 34.56 137.31 5379.07 -6516.39 10188.06 11768.13 5.1 14406.32 33.33 137.7 5439.1 -6546.18 10215.36 11808.52 1.73 14454.12 32.98 137.9 5479.12 -6565.55 10232.92 11834.65 0.77 14550.61 32.33 137.53 5560.36 -6604.06 10267.94 11886.69 0.7 14646.97 30.91 137.55 5642.41 -6641.33 10302.05 11937.19 1.47 14742.6 29.75 137.66 5724.95 -6677 10334.61 11985.46 1.21 14$37.22 28.62 137.35 5807.56 -6711.02 10365.77 12031.58 1.2 14922.05 27.37 137.27 5882.46 -6740.29 10392.77 12071.38 1.47 14960- ro' 27.37 137.27 5916.16 -6753.1 10404.61 12088.83 0 ~1'OC1H 27 • 5.2 Bit Record ~. s • ~'~~~~~~ 2L-309 Depth In Total Bit Aug' WOB PP Bit Make Type Jets / TFA MD / TVDSS Footage Hrs ROP (Klbs) RPM psi) Wear BHA ft ft/hr 8 1/2" Hole 4 HTC MXL-1 3 18' 4345' 1246' 16:29 100 18 NA NA 1-1-NO-G-E-I- 5 X NO-BHA 5 SEC FSF2565 5X16 5586' 8781' 105:12 94.6 8.0 NA NA 0-0-NO-AL-X-I- NO-TD 6-g 6 1/8" Hole 6 HTC STX 405 5X14 14364' 596' 13:33 47 3.6 NA NA 1-1-NO-AL-X-I- NO-TD 10 EPOCH 28 LI 5.3 Mud Record Contractor :MI SWACO Mud Tvpe :LSND to TD ~,• ~C)i'1t7C~OP'~11~~~~?S 2L-309 Date Depth MW VIS s~ t PV YP Gels FL cc FC Sols % OIVU Ratio Sd % MBT pH CI ml/I Ca ml/l 8 1l2" Intermediate Hole Section 1/29/06 4580 9.6 52 10 20 9/11 8 2/ 6.5 0/93.5 0.2 4 9 1600 320 1/30/06 4699 9.6 40 8 20 8!13/18 6 1/ 6 1.5/92.5 .33 7 9.5 800 200 1/31/06 6152 9.6 43 10 24 11/20/34 5 2/ 6 1/93 TR 15 9.5 800 20 2/1 /O6 7658 9.6+ 47 15 25 20/45/58 5 1 / 8 2/90 TR 15 9.5 700 40 2/2/06 7658 9.6 50 10 21 11/15/16 8 2/ 5.5 0/94.5 0 7 9.0 400 0 2/3/06 9117 9.6 48 13 27 14/18/22 3.1 1 / 6 2/92 .25 10 8.0 400 0 2/4/06 9435 9.6 53 14 29 16/26/32 5.4 2/ 8 2/90 .25 17 8.0 400 0 2/5/06 10658 9.6 50 17 26 11/18/23 5.3 2/ 7.5 2.5/90 .25 17 8.0 400 0 2/6/06 11400 9.6 50 18 27 11/17/21 4.7 2/ 8 2/90 .50 17 8.0 400 0 2/7/06 12544 9.6 50 17 25 10/15/19 4.8 2/ 8.5 3/88.5 TR 20 8.0 400 0 2/8/06 12546 9.6 52 15 22 10/14/18 4.8 2/ 8.5 3/88.5 TR 20 8.3 400 0 2/9/06 12546 9.6 52 15 23 10/21/25 4.7 2/ 8 2/90 TR 20 8.5 400 0 2/10/06 13850 9.6 52 17 25 13/37/49 4.2 2/ 9 3/88 TR 20 10.0 400 0 2/11/06 14364 9.6 55 17 26 11/31/43 4.1 2/ 10 2/88 TR 20 10.5 400 0 2/12/06 14364 9.6 45 11 15 8/15/22 5.0 2/ 9 2/89 TR 20 10.0 400 0 2/13/06 14364 NO REPORT 61/8" Production Hole Section 2/14!06 14364 10.0 54 12 24 11 /16/19 4.9 2/ 8 1 /91 0 8 8.0 400 0 2/15/06 14364 9.6 46 13 19 10/45/48 5.5 2/ 9 1/90 TR 15 12.0 500 900 2!16/06 14364 9.8 53 12 29 11/30/48 5.5 2/ 9 1/90 TR 15 12.0 550 950 2/17!06 14813 10.0 51 15 19 6/8/10 4.5 2/ 9 .5/90.5 .30 12 9.5 450 20 2/18/06 14960 10.4 50 15 19 7/9/11 4.5 2/ 11 1/88 TR 12.5 9.5 450 20 Abbreviations MW =Mud Weight Gels =Gel Strength Sd =Sand content WL = Water or Filtrate Loss CI =Chlorides VIS =Funnel Viscosity Ca =Hardness Calcium PV =Plastic Viscosity Sols =Solids YP =Yield Point ECD =Effective Circulating Density FC =Filter Cake O/W =Oil to Water ratio EPCJCH 29 ~~~~~~`' 2L-309 MORNING REPORTS ~;~ocH 30 ConocoPhillips Alaska Inc. Exploration Well ZL-309 • • Report for: VAUGHN/BROWN KLEI6ACKER Date: 1/28/06 Time: 12 AM Current Depth: 4530 Operation: Prep to RiH Yesterdays Depth: 4530 24 hr Footage: 0' rlrillinn Porama4cre ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 2242 Time: 25:00 Circulation: Strokes: Time: ECD: Current: 9.7 Max: Mi ir• Prnnartiac MW: 9.8 FV: 45 PV: 10 YP: 16 FL: 8 Gels: 7/15/24 Sol: 9 H: 11.5 CI-~ 550 Ca++~ 120 MW Change: Depth: 4530 From: 10.7 To: 9.8 Reason: add H2o Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: so ~rc~ De the 4000' C~ac Fvant•c WIPER De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks De th TG C1 C2 C3 C41 C4N C51 C5N No. De th TG C1 C2 C3 C41 C4N C51 C5N 3as Sam les Lithologies: Current: Last 24 hrs: R/D BOP test equipment, M/U BHA, upload to MWD and surface test, TIH Opperational Summary: t/3700; wash t/4000 (max gas 60 units) M/U DP wash f/4000-4340; W/O orders; pump OOH 4530 to 4300; blow down top drive; observe well; Tube rig; pump slug; POOH; stand back BHA, DC; UD BHA Calibrations: No Failures: none Day Rate: $ 2,700.00 J ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHN/BROWN KLEIBACKER • Date: 1/29/06 Time: 12 AM Current Depth: 4530 Operation: Wait on Cement Yesterdays Depth: 4530 24 hr Footage: 0' rlrillinn Paramatarc • ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 2242 Time: 25:00 Circulation: Strokes: Time: ECD: Current: 9.7 Max: M~ ir• Prnnartiac MW: 9.7 FV: 42 PV: 12 YP: 15 FL: 8 Gels: 7/16/24 Sol: 8.5 H: 11.5 CI~- 550 Ca++~ 100 MW Change: Depth: 4530 From: 9.8 To: 9.7 Reason: oriu out Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: s ab Depth: 4532 mac FvPntc TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N 4530 65 4581 562 500 121 368 162 254 SWAB GAS De th TG C1 C2 C3 C41 C4N C51 C5N 4530 216 21479 2630 2338 475 1328 401 593 TRIP GAS 3700 101 PPakc De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: M/U BHA TIH t/4532 circ mud Trip Gas 65 units, cond mud Swab Gas 216 Opperational Summary: units, pump cement, POOH t/4140 pump nut plug, flow check, POOH t/ 3.5 tubing, Cut/Slip DL, LID tubing, M/U BHA, test MWD, RIH t/3700 Trip Gas 101 units, wait on cement. Calibrations: YES • Failures: none ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHN/BROWN KLEIBACKER Date: 1/30/06 Time: 12 AM Current Depth: 4560 Operation: DRILLING Yesterdays Depth: 4346 24 hr Footage: 214' rlrillinn Pcrama4orc • ROP: Current: 150 Max: 185 Tor ue: Current: 0 Max: 0 WOB: Current 22 Max: 42 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 2183 Time: 16 Circulation: Strokes: 6934 Time: 52 ECD: Current: 10.61 Max: Mi ir• Prnnartias MW: 9.6 FV: 52 PV: 10 YP: 20 FL: 8 Gels: 9/11/- Sol: 6.5 H: 9 CI-~ 1600 Ca~~ 320 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: ~5 Max: s7 De the 4365 (,mac Gvcntc TRIP De th TG C1 C2 C3 C41 C4N C51 C5N 4130 207 CONN GAS De th TG C1 C2 C3 C41 C4N C51 C5N 4556 ~o0 13978 2141 1733 985 317 4462 14 De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks No. De th TG C1 C2 C3 C41 C4N C51 C5N 1 4500 14 2460 41 50 49 .as Sam les Lithologies: Current: 90% CLAY, 10% SILT Last 24 hrs: CLAY TRACE SILT WOC, wash f/3713 to 4130, CBU (207 units of TG), P/U to 4185', WOC, RIH Opperational Summary: to 4240', circ out thick mud, drill f/ 4240' to 4350', POOH to csg &circ and prep for mud displacement, displace w/ 9.7ppg, RIH t/4371' drill ahead. Calibrations: no Failures: none ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHN/BROWN KLEIBACKER • Date: 1/31/06 Time: 12 AM Current Depth: 5586 Operation: POOH Yesterdays Depth: 4560 24 hr Footage: 1026" rlrillinn Peramctere • Paakc ROP: Current: 0 Max: 217 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 61 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 2726 Time: 21:00 Circulation: Strokes: Time: ECD: Current: 11.83 Max: Mud Pro erties MW: 9.8 FV: PV: YP: FL: Gels: Sol: H: CI-~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: ~~ De the 5085' r,ac Fvantc WIPER De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Swab Gas POOH 475 Connection Gas AVE 112 De th TG C1 C2 C3 C41 C4N C51 C5N 5085 134 23475 363 158 31 82 29 36 5215 107 15748 718 605 120 324 82 122 r~ac Ran Samnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 4 5503 45 6756 112 113 32 96 61 71 3 5000 12 1710 23 18 7 27 10 22 2 4881 15 2621 58 56 45 1 4500 14 2460 41 50 49 Lithologies: Current: 80% siltstone, 20% clay Last 24 hrs: Clay and silt Drilling to 5586' w/ connection gases averge 112 units, circulate bottoms up Opperational Summary: and pump out to the shoe, Max Swab Gas pulling to the shoe = 475 units / average = 100 Calibrations: no Failures: none ConocoPhillips Alaska Inc. Exploration Well 2L-309 LJ Report for: VAUGHN/BROWN KLEIBACKER Date: 2/1/06 Time: 12 AM Current Depth: 6500 Yesterdays Depth: 5586 24 hr Footage: 914' r)rillinn Pararr~atarc Operation: DRILLING ROP: Current: 122 Max: 251 Tor ue: Current: 0 Max: 0 WOB: Current 18 Max: 21 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3146 Time: 24:48 Circulation: Strokes: 8702 Time: 64.9 ECD: Current: 10.9 Max: Muni PrnnPrties MW: 9.6 FV: 43 PV: 10 YP: 24 FL: 5 Gels: 11/20/34 Sol: 6 H: 9.5 CI-~ 800 Ca++~ 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: as Max: ~s~ De the 5761 C~ac Fvantc TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N 5586' 591 De th TG C1 C2 C3 C4t C4N C51 C5N Connection Gas AVE 215 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 5761 167 23558 1218 1107 255 796 295 432 (;aS Ran Samnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 6 6500 42 8415 127 99 37 107 25 41 5 6000 40 7372 106 78 23 85 37 53 4 5503 45 6756 112 113 32 96 61 71 3 5000 12 1710 23 18 7 27 10 22 Lithologies: Current: 80% siltstone, 20% clay Last 24 hrs: Clay and silt trace sandstone CBU 2.5X @ the shoe, flow check, POOH, stand back BHA, down load MWD, Opperational Summary: UD BHA, M/U BHA, upload MWD, surface test MWD, P/U 5" DP, TIH to bottom and drill ahead. TRIP GAS = 591 UNITS. Calibrations: no Failures: none • ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHURNVILLOUGHBY KLEIBACKER Date: 2/2/06 Time: 12 AM Current Depth: 7658 Operation: WIPER TRIP Yesterdays Depth: 6500 24 hr Footage: 1158 f)rillinn Paramatarc n ROP: Current: 0 Max: 170 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 15 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3676 Time: 28.5 Circulation: Strokes: 8702 Time: 64.9 ECD: Current: 10.9 Max: Mi ~r• Prnnartiac MW: 9.6 FV: 43 PV: 10 YP: 24 FL: 5 Gels: 11/20/34 Sol: 6 H: 9.5 CI"~ 800 Ca++~ 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: 73 De the 7362 C~ac FvPntc TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 178 PPakc De th TG C1 C2 C3 C41 C4N C51 C5N 7362 73 9772 586 404 70 176 65 96 7555 69 10053 444 344 70 198 70 99 6720 54 9643 542 426 86 236 83 127 C~ac Ran Samnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 8 7500 64 8712 392 209 55 148 49 61 7 7000 51 9651 488 356 67 187 45 70 6 6500 42 8415 127 99 37 107 25 41 5 6000 40 7372 106 78 23 85 37 53 Lithologies: Current: 7658' = 70% SILT, 30% SANDSTONE Last 24 hrs: SILTSTONE, SANDSTONE, CLAYSTONE Opperational Summary: DRILL FORMATION Calibrations: no Failures: none EPOCH DAYRATE = 82700,00 r1 ~J ConocoPhillips Alaska Inc. Exploration Well 2L-309 KLEIBACKER • Date: 2/3/06 Time: 12 AM Current Depth: 7658 Yesterdays Depth: 7658 24 hr Footage: 0 I~rillina Parameters Report for: VAUGHN Operation: CIRC OFF BOTTOM ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3676 Time: 28.5 Circulation: Strokes: 8702 Time: 64.9 ECD: Current: Max: Mi ~r• Prnnartias MW: 9.6 FV: 43 PV: 10 YP: 24 FL: 5 Gels: 11/20/34 Sol: 6 H: 9.5 Cf~ 800. Ca++~ 20 Ditch Gas: Current: o Max: sao Depth: TG8 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data gas Events :7 TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N 7658 940 128086 16519 10980 1570 3750 1181 1149 De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 178 PPakc De th TG C1 C2 C3 C41 C4N C51 C5N 7362 73 9772 586 404 70 176 65 96 7555 69 10053 444 344 70 198 70 99 6720 54 9643 542 426 86 236 83 127 Gas Bao Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N 8 7500 64 8712 392 209 55 148 49 61 7 7000 51 9651 488 356 67 187 45 70 6 6500 42 8415 127 99 37 107 25 41 5 6000 40 7372 106 78 23 85 37 53 Lithologies: Current: 7658' = 70% SILT, 30% SANDSTONE Last 24 hrs: SILTSTONE, SANDSTONE, CLAYSTONE Drill to 7658', POOH to the shoe (Wiper Trip), hole packing off and tight, Opperational Summary: continue to POOH, down load MWD, and TIH to the shoe and wait on new mud, TIH to bottom and circ out 940 units Trip Gas circ drill mud. Calibrations: no Failures: none EP©GH DAYRATE _ $700.00 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHNNVILLOUGHBY KLEIBACKER Date: 2/4/06 Time: 12 AM Current Depth: 9100 Yesterdays Depth: 7658 24 hr Footage: 1442' r)rillinn PPramPtars Operation: DRILLING ROP: Current: 92 Max: 189 Tor ue: Current: 0 Max: 0 WOB: Current 14 Max: 19 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4340 Time: 33.6 Circulation: Strokes: 7699 Time: 60 ECD: Current: Max: 11Ai ir• Prnnartiac r~ MW: 9.6 FV: 50 PV: 10 YP: 21 FL: 8 Gels: 11/15/16 Sol: 5.5 H: 9.0 CI-~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: as Max: s2 De the 7938 Comae Fventc TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 164 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 7938 92 13826 668 645 182 538 184 293 7663 84 8052 1134 1272 252 704 186 243 C~ac Ran Samnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 11 9000 34 7048 381 233 38 110 57 56Q 10 8500 48 8541 401 245 45 130 60 76 9 8000 60 8668 328 314 83 253 150 242 8 7500 64 8712 392 209 55 148 49 61 Lithologies: Current: 9100' = 80% SILTSTONE, 10% SANDSTONE, 10% ASH FALL TUFF Last 24 hrs: SILTSTONE, SANDSTONE, CLAYSTONE Opperational Summary: DRILL FORMATION w/ connection gases @ 2555 strokes every connection Calibrations: no Failures: none EPOCH DAYRATE = $2700A0 • • r~ ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHN/WILLOUGHBY KLEIBACKER Date: 2/5/06 Time: 12 AM Current Depth: Yesterdays Depth 24 hr Footage: nrillina Parameters 9450 Operation: DRILLING 350' ROP: Current: 92 Max: 130 Tor ue: Current: 0 Max: 0 WOB: Current 12 Max: 22 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4500 Time: 34 Circulation: Strokes: 9724 Time: 73 ECD: Current: Max: Mud Properties MW: 9.6 FV: 53 PV: 14 YP: 29 FL: 5.4 Gels: 16/26/32 Sol: 8 H: 8 CI-~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 9341' Volume: 25 bbls Gas Data Ditch Gas: Current: 42 Max: s2 De the 9171 Comae Fvcn4e WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N 9159 668 WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N 3 STANDS 9341 473 Connection Gas AVE 102 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 9171 82 7759 992 979 188 538 149 208 9169 79 8122 1055 1019 193 554 150 214 ras Ran Samnlas No. De th TG C1 C2 C3 C41 C4N C51 C5N 11 9000 34 7048 381 233 38 110 57 56 10 8500 48 8541 401 245 45 130 60 76 9 8000 60 8668 328 314 83 253 150 242 8 7500 64 8712 392 209 55 148 49 61 Lithologies: Current: 9450' = 90% SILTSTONE, 10% SANDSTONE Last 24 hrs: SILTSTONE, SLIGHT AMOUNTS OF SANDSTONE, CLAYSTONE Drill to 9161', circ bottoms up X3, pump out of the hole to 6906', circ bottoms Opperational Summary: up X3, pump out of the hole to 4340', circulate bottoms up X1, POOH to 1275, UD ghost reamer, RIH to 9068' WIPER GAS = 668 units, drill to 9341 hole packing off pumped away 25 bbls without returns, WIPER GAS = 473 units. Calibrations: YES Failures: none EPOCH DAYRATE _ $2700.00 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHNNVILLOUGHBY • • KLEIBACKER Date: 2/6/06 Time: 12 AM Current Depth: 10657 Operation: WIPER TRIP Yesterdays Depth: 9450 24 hr Footage: 1207' rlrillinn Paramotarc ROP: Current: 78 Max: 145 Tor ue: Current: 0 Max: 0 WOB: Current 9 Max: 18 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5053 Time: 38 Circulation: Strokes: 9886 Time: 74 ECD: Current: Max: 11/li ir• Prnnartias MW: 9.6 FV: 53 PV: 14 YP: 29 FL: 5.4 Gels: 16/26/32 Sol: 8 H: 8 CI"- 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 3o Max: ao De the 10070 C~ac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 130 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 10070 80 11173 958 652 106 277 71 106 [was Ran Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N 14 10500 18 1526 204 147 30 88 22 55 13 10000 47 7086 310 192 40 111 37 61 12 9500 36 5334 278 222 50 151 44 81 11 9000 34 7048 381 233 38 110 57 56 Lithologies: Current: 11657' = 80% CLAYSTONE, 20% SILTSTONE Last 24 hrs: SILTSTONE, CLAYSTONE Opperational Summary: Drill formation to 10657', continued connection gases at 2575 strokes (B/U = 5053 strokes), circulate out hole for wiper trip. Calibrations: no Failures: none EPOCH DAYRATE _ $2700.00 • • ConocoPhillips Alaska Inc. Exploration We112L-309 Report for: VAUGHNIWILLOUGHBY KLEIBACKER Date: 2/7/06 Time: 12 AM Current Depth: 11400 Operation: DRILLING Yesterdays Depth: 10657 24 hr Footage: 743' rlrillinn PPramatarc ROP: Current: 80 Max: 141 Tor ue: Current: 0 Max: 0 WOB: Current 25 Max: 70 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5395 Time: 40 Circulation: Strokes: 10650 Time: 81 ECD: Current: Max: Mi ir• Prnnartiac MW: 9.6 FV: 50 PV: 17 YP: 26 FL: 5.3 Gels: 11/18/23 Sol: 7.5 H: 8 CI-~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 5o Max: Boa De the 10658 C~ac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N 10657 659 De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 220 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 10658 104 13560 975 899 159 382 119 165 (sae Ran ~amnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 15 11000 61 4100 649 525 105 303 116 163 14 10500 18 1526 204 147 30 88 22 55 Lithologies: Current: 11400' = 50% CARBONACEOUS SHALE/CLAY, 20% SHALE, 20% CLAY, 10% SILT Last 24 hrs: SILTSTONE, CLAYSTONE, SHALE, CARBON CLAY, ASH {TRACES) Opperational Summary: POOH to 8800' hole tight at 9100', work hole, TIH to bottom WIPER GAS = 659 units, drilling ahead with connection gases @ 220 units over background. Calibrations: no Failures: none EPOCH DAYRATE _ $2700.00 Paakc ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHURNVILLOUGHBY KLEI BACKER Date: 2/8/06 Time: 12 AM Current Depth: Yesterdays Depth: 24 hr Footage: 12546 Operation: CIRC HOLE & POOH rlrillinn Paramatarc ROP: Current: 0 Max: 190 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 14 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5920 Time: 44 Circulation: Strokes: 11056 Time: 93 ECD: Current: 11.71 Max: Mori PrnnPrtiac MW: 9.6 FV: 50 PV: 18 YP: 27 FL: 4.7 Gels: 11/17/21 Sol: 8 H: 8 CI-~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: so Max: toa De the 10658 fS:~c wcn4e WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 96 De th TG C1 C2 C3 C41 C4N C51 C5N 11765 73 9815 680 375 152 214 56 80 11400 55 7346 939 645 119 317 167 111 C~ac Ran ~amnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 18 12500 32 5208 382 234 41 119 40 19 17 12000 30 4759 366 258 39 104 39 69 16 11500 25 3779 279 89 33 87 68 50 15 11000 61 4100 649 525 105 303 116 163 Lithologies: Current: 12546' = 20% SANDSTONE, 30% SILT, 30% CLAY, 10% SHALE, 10% CARB SHALE Last 24 hrs: SILTSTONE, CLAYSTONE, SHALE, CARBON CLAY, SANDSTONE Opperational Summary: Drill formation to 12546' circulate out samples and condition mud to POOH Calibrations: no Failures: none EPOCH DAYRATE _ $2700.00 • ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHURNVILLOUGHBY KLEI BACKER • Date: 2/9/06 Time: 12 AM Current Depth: Yesterdays Depth 24 hr Footage: f~rillina Perimeters • ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5920 Time: 44 Circulation: Strokes: 11056 Time: 93 ECD: Current: 11.71 Max: Mi ir• PrnnartiPc MW: 9.6 FV: 52 PV: 15 YP: 22 FL: 4.8 Gels: 10/14/18 Sol: 8.5 H: 8.3 CI-~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 5o Max: Boa De the 10658 C~ac FvPntc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks No. De th TG C1 C2 C3 C41 C4N C51 C5N 18 12500 32 5208 382 234 41 119 40 19 17 12000 30 4759 366 258 39 104 39 69 16 11500 25 3779 279 89 33 87 68 50 15 11000 61 4100 649 525 105 303 116 163 3as Ba Sam les Lithologies: Current: 12546' = 20% SANDSTONE, 30% SILT, 30% CLAY, 10% SHALE, 10% CARB SHALE Last 24 hrs: Finish circulating bottom's up X4, pump out of the hole to 10376', work tight Opperational Summary: andtpumplout7of thelhole to 2000p POOH to BHA,tUD BHA and beg n to test BOPE. Calibrations: no Failures: none EPOCH DAYRATE = $2700.00 12546 Operation: TEST BOPE • ;~ ConocoPhillips Alaska Inc. Exploration We112L-309 Report for: HABERTHUR/WILLOUGHBY KLEIBACKER Date: 2/10/06 Time: 12 AM Current Depth: 12546 Operation: TIH TO DRILL Yesterdays Depth: 12546 24 hr Footage: 0' f)rillinn Paramatarc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5920 Time: 44 Circulation: Strokes: 11056 Time: 93 ECD: Current: 11.71 Max: Mi ira Drnncrtice MW: 9.6 FV: 52 PV: 15 YP: 22 FL: 4.8 Gels: 10/14/18 Sol: 8.5 H: 8.3 CI"~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: o De the 0 C~ac Fvpntc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N 12546 1450 192305 83996 89871 16516 39210 8208 9615 Connection Gas AVE 'eaks De th TG C1 C2 C3 C41 C4N C51 C5N No. De th TG C1 C2 C3 C41 C4N C51 C5N 18 12500 32 5208 382 234 41 119 40 19 17 12000 30 4759 366 258 39 104 39 69 16 11500 25 3779 279 89 33 87 68 50 15 11000 61 4100 649 525 105 303 116 163 ias Ba Sam les Lithologies: Current: 12546' = 20% SANDSTONE, 30% SILT, 30% CLAY, 10% SHALE, 10% CARB SHALE Last 24 hrs: Opperational Summary: Test BOPE, prep to run in hole (MWD), TIH to shoe circulate out Trip Gas, cut and slip drill line, TIH. Calibrations: no Failures: none EPOGN DAYRATE _ $2700.00 • ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHUR/WILLOUGHBY KLEIBACKER Date: 2/11/06 Time: 12 AM Current Depth: Yesterdays Depth 24 hr Footage: 13700 Operation: DRILLING 1154 r)rillinn Paramatarc ROP: Current: 97 Max: 241 Tor ue: Current: 0 Max: 0 WOB: Current 9 Max: 19 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 6451 Time: 48 Circulation: Strokes: 12578 Time: 97 ECD: Current: 11.67 Max: ~Ai ir• Prnncrtice MW: 9.6 FV: 52 PV: 17 YP: 25 FL: 4.2 Gels: 13/37/49 Sol: 9 H: 10.0 CI-~ 400 Ca++ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: as Max: ~3s De the 13444 WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 289 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 13444 138 14549 1147 730 115 342 119 163 rye Ran C~mnlee No. De th TG C1 C2 C3 C41 C4N C51 C5N 20 13500 97 14342 1291 904 134 452 136 211 19 13000 88 12074 976 622 117 377 160 256 18 12500 32 5208 382 234 41 119 40 19 Calibrations: no Failures: none EPOCH DAYRATE = 82700.00 Last 24 hrs: Opperational Summary: Finish tripping to bottom, work tight hole on the last stand, drill formation. Lithologies: Current: 13700' = 70% SAND, 30% SILT L~ r ~ LJ • ConocoPhillips Alaska Inc. Exploration We112L-309 Report for: HABERTHUR/WILLOUGHBY KLEIBACKER Date: 2/12/06 Time: 12 AM Current Depth: Yesterdays Depth 24 hr Footage: 14367 Operation: WIPER TRIP @ TD rlrillinn Paramatarc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 6756 Time: 50 Circulation: Strokes: 12578 Time: 97 ECD: Current: 11.67 Max: Mi irl Prnnarfiiec MW: 9.6 FV: 52 PV: 17 YP: 25 FL: 4.2 Gels: 13/37/49 Sol: 9 H: 10 CI"~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: ~2o De the 13838' C~ac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 271 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 13838 120 15619 1208 856 154 438 79 177 (,ac Ran ~amnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 21 14000 68 9469 927 705 138 359 79 120 20 13500 97 14342 1291 904 134 452 136 211 19 13000 88 12074 976 622 117 377 160 211 18 12500 32 5208 382 234 41 119 40 19 Lithologies: Current: 14367' (TD) = 50% SILTSTONE, 20% CLAY, 20%SANDSTONE, 10% SHALE Last 24 hrs: Opperational Summary: Drill formation to 14367', circulate out samples, pump out of the hole to 7800' and circulate out 269 units of gas, begin to trip back to bottom. Calibrations: no Failures: none EPOCH DAYRATE _ $2700.00 • - - - ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHURNVILLOUGHBY KLEIBACKER • Date: 2/13/06 Time: 12 AM Current Depth: 14364 Operation: PREP FOR CASING Yesterdays Depth: 14364 24 hr Footage: 0' • Pc~lre I~rillina PerametPrs ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: Mi ir• Prnnartiac MW: 9.6 FV: 55 PV: 17 YP: 26 FL: 4.1 Gels: 11/31/43 Sol: 10 H: 10.5 CI~~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: say De the POOH mac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N 14364 1070 156794 20808 13216 1715 5007 1056 1569 De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE De th TG C1 C2 C3 C41 C4N C51 C5N as Ba Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 14364' = 50% SILT, 20% SANDSTONE, 20% CLAY, 10% SHALE Last 24 hrs: Finish Wiper Trip to bottom, circulate out 1070 units of gas, pump out of the Opperational Summary: hole. Maximum gas pumping out was 341 units. Finish pulling out of the hole and prep to run casing. Calibrations: no Failures: none EPOCH DAYRATE = 5270000 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHURNVILLOUGHBY KLEIBACKER • Date: 2/14/06 Time: 12 AM Current Depth: 14364 Operation: RUNNING CASING Yesterdays Depth: 14364 24 hr Footage: 0' _ • rlrillinn Paramatarc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: Mi ir• Prnnartiac MW: 9.6 FV: 45 PV: 11 YP: 15 FL: 5.0 Gels: 8/15/22 Sol: 9 H: 10 CI-~ 400 Ca++~ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: a5 Max: ss5 De the TIH (,mac wcn4c WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE De th TG C1 C2 C3 C41 C4N C51 C5N :aks as Ba Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 14364' = 50% SILT, 20% SANDSTONE, 20% CLAY, 10% SHALE Last 24 hrs: Opperational Summary: Prep to run casing. Begin to run 7" casing. Max gas tripping in the hole 695 units (circ at the shoe). Calibrations: no Failures: none EP©GH DAYRATE = 52700.00 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHUR/BROWN KLEIBACKER • Date: 2/15/06 Time: 12 AM Current Depth: 14364 Operation: Wait on Cement Yesterdays Depth: 14364 24 hr Footage: 0' • r)rillinn Paramatarc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: mua rro ernes MW: FV: PV: YP: FL: Gels: Sol: H: CI-~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: De the (~~c Fvcn4c WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N 14364 695 Connection Gas AVE De th TG C1 C2 C3 C41 C4N C51 C5N yaks as Ba Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 14364' = 50% SILT, 20% SANDSTONE, 20% CLAY, 10% SHALE Last 24 hrs: Finish tripping in the hole with casing. Trip Gas 695 units (just under the shoe), Opperational Summary: circulate string while tripping in gas peaks from 187 units to 485 units. Cement casing and prep to drill out cement and formation. Calibrations: no Failures: none EPOCH DAYRATE _ X2700,00 U ConocoPhillips Alaska Inc. Exploration Well ZL-309 Report for: HABERTHUR/BROWN KLEIBACKER • Date: 2/16/06 Time: 12 AM Current Depth: 14364 Operation: P/U DP RIH + WOC Yesterdays Depth: 14364 24 hr Footage: 0' • ftrillinn Paramatarc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: mua rro ertles MW: FV: PV: YP: FL: Gels: Sol: pH: CI"~ Ca~~ MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: De the C~ac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE De th TG C1 C2 C3 C41 C4N C51 C5N :aks as Ba Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 14364' = 50% SILT, 20% SANDSTONE, 20% CLAY, 10% SHALE Last 24 hrs: Opperational Summary: Change out drill pipe. Wait on cement. Make up new BHA. Trip in shallow and circulate drilling mud. Max gas 50 units in shallow hole. Calibrations: no Failures: none EPOGH DAYRATE _ $2700.00 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHUR/BROWN KLEIBACKER Date: 2/17/06 Time: 12 AM Current Depth: 14364 Operation: DRILLING CEMENT Yesterdays Depth: 14364 24 hr Footage: 0' • flrillinn Paramatarc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3192 Time: 24 Circulation: Strokes: 8171 Time: 126 ECD: Current: 0 Max: AAi ir• PrnnartiAc MW: 9.8 FV: 53 PV: 12 YP: 29 FL: 5.5 Gels: 11/30/48 Sol: 9 H: 12 CI~ 550 Ca++~ 950 MW Change: Depth: 14364 From: 9.6 To: 9.8 Reason: Bermuda Mud toss event: Depth: Volume: Gas Data Ditch Gas: Current: 25 Max: a3 De the TD C~ac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N 14364 43 Connection Gas AVE De th TG C1 C2 C3 C41 C4N C51 C5N yaks as Ba Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 14365' = 100% CEMENT Last 24 hrs: Operational Summary: Continue to P/U drill pipe and run in the hole. Maximum gas running in the hole with drill pipe = 58 units. Test casing at 14204'. Drilling out cement. Calibrations: YES Failures: none EPOCH DAYRATE = 52700.00 i• ConocoPhillips Alaska Inc. Exploration Well 2L-309 • • Report for: HABERTHUR/BROWN KLEIBACKER Date: 2/18/06 Time: 12 AM Current Depth: 14960 Operation: CIRC @ 14960' Yesterdays Depth: 14364 24 hr Footage: 596' f)rillinn Pararr~tprs ROP: Current: 47 Max: 178 Tor ue: Current: 0 Max: 0 WOB: Current 3 Max: 12 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3316 Time: 66 Circulation: Strokes: 9062 Time: 164 ECD: Current: 0 Max: Mi irr Prnnartiac MW: 10 FV: 51 PV: 15 YP: 19 FL: 4.5 Gels: 6/8/10 Sol: 9 H: 9.5 CI-- 450 Ca~~ 20 MW Change: Depth: 14364 From: 9.8 To: 10.0 Reason: Bermuda Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: s5 Max: aot De the 14548 f;ac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 200 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 14548 401 38646 5561 4741 786 2350 623 894 14479 390 44180 5845 4673 743 2185 600 825 14552 387 37924 5496 4735 787 2364 626 900 IsntuhPS SamnlPS (maxi No. De th TG C1 C2 C3 C41 C4N C51 C5N 7 14250 205 18681 2790 2498 435 1345 389 581 8 14539 248 22861 3376 2980 513 1597 462 678 9 14550 400 38782 5567 4730 781 2325 611 874 10 14560 153 14422 2146 1918 324 996 269 391 Lithologies: Current: 14960' = 70% SAND, 20% SILT, 10% CARBONACEOUS SILT Last 24 hrs: Drill out shoe track and 20' of new hole, CBU and add 510 bbls of new 10.1 Operational Summary: ppg mud to the active system, R/U and perform 16 EMW FIT. Drill formation to 14760 and CBU, drill to 14960' and circulate. Calibrations: YES Failures: none EPOCH DAYRATE _ $2700.00 • ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHUR/BROWN KLEI BACKER Date: 2/19/06 Time: 12 AM Current Depth: 14960 Operation: POOH Yesterdays Depth: 14960 24 hr Footage: 0' • f)rillinn ParamPtarG ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: M~ ir• Prnnartiac MW: 10 FV: 51 PV: 15 YP: 19 FL: 4.5 Gels: 6/8/10 Sol: 9 H: 9.5 CI-~ 450 Ca~~ 20 MW Change: Depth: 0 From: 0 To: 0 Reason: o Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: sea De the 14960 C~ac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N 14960 324 TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 0 De th TG C1 C2 C3 C41 C4N C51 C5N yaks tubes Sam les max No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 14960' = 70% SAND, 20% SILT, 10% CARBONACEOUS SILT Last 24 hrs: Operational Summary: Continue to circulate at 14960' (TD), Wiper Trip 7 stands WG = 324 units, continue to circulate drilling mud, begin to POOH. Calibrations: no Failures: none EPOCH DAYRATE _ $2700.00 • ~~ ~ ~f ~~'~ Ll~ ~ ~~~~aa ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA 2L-309PB1 ,~ jy .- -_ k y1" :na. Provided by: ~~ EPOCH Compiled by: Lees Browne Jr. Brian O'Fallon Date: 1/27/06 ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA 2L-309PB1 Provided by: [~ EPOCH F~E~EIVED SEP 0 5 2006 A{asks t)il & Gas Cons. Corranission Anchorage • Approved by: Derik Kleibacker Distribution: Compiled by: Lees Browne Jr. Brian O'Fallon Date: 1 /27/06 v.' CD~000~11~II~K 2L-309 BP1 TABLE OF CONTENTS • 1 MUDLOGGING EQUIPMENT &CREW .................................................................................................... ..2 1.1 E ui ment Summa .............................................................. q P ry ............................................................ ..2 1.2 Crew .................................................................................................................................................... ..3 Z WELL DETAILS .........................•---......,...........................................................................----....................... ..4 2.1 Weli Summary .................................................................................................................................... ..4 2.2 Hole Data ............................................................................................................................................ ..4 3 GEOLOGICAL DATA ................................................................................................................................. ..6 3.1 Lithostratigraphy ..........................••-•---.................................................................,.........,..................... ..6 3.2 Mudlog Summary .............................................................................................................•-----....------.. ..7 3.3 Gas Samples .......................................................••-••...............---••...................................................... 16 3.4 Connection Gases ....................................................................•---.............................----...............----.. 16 3.5 Sampling Program /Sample Dispatch .............................................................................................. 17 4 PRESSURE /FORMATION STRENGTH DATA ...................................................................................... 18 4.1 Formation Integrity/Leak Off Tests ..................................................................................................... 18 4.2 Wire line Formation Tests .............•--......-•-----..........................---......--••-•---...........-•---......................... 18 4.3 Pore Pressure Evaluation Irrtrcxluction .................................._........................................................... 18 4.4 Pare Pressure Evaluation Conclusions ............................................................................................. 18 4.5 Pore pressure evaluation .................................................................................................................... ZO 5 DRILLING DATA ........................................................................................................................................ 24 5.1 Survey Data ......................................................................................................................................... 24 5.2 Bit Record ........................................................................................................................................•--- 28 5.3 Mud Record ....................•---...................................................-...........----.............---••----.......---.............. 29 6 MORNCNG REPORTS .........................................•---...........------.......----.........---••----..................................... 30 Enclosures • 2"/100' Formation Log {MD} 2"!100' Gas Ratio Log 2"f100' LWD / Lithology Log • E~ EPQ~H • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary • • -.-. '~~~~~" 2L-309 BP1 Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. Insulated umbilical with three of low lines. 0 No problems, no missing data after 986' Hook Load / Wei ht on bit H draulic ressure transducer 0 No roblems no missin data after 986' Rate of penetration Primary draw-works block position indicator O tical encoder on draw-works 0 No problems, no missing data after 986. Mudlo in unit com uter s stem HP Com a Pentium 4 X2 DML & Ri watch 0 On UPS should ower shut down on ri Mudlo in unit DAC box In-unit data collection/distribution center 0 On UPS should ower shut down on ri Mud Flow In Derived from Strokes/Minute and Pum Out ut 0 see um stroke counters below Pum stroke counters 2 um s Ma netic roximi sensors 0 No roblems no missin data after 986' Epoch had anticipated logging from under the conductor pipe, but instead commenced logging at 986'. The Epoch unit needed to be repositioned with a crane, and after the delay and subsequent time needed to rig up, the unit was not able to commence logging until after surface hole drilling had begun. Gas values for the 12'/<" surface hole were difficult to measure, as rig crews had problems with excessive cuttings, but gas recording for the 8'r~" hole went well. Mud flow into the possum belly where the gas trap was set often had restricted flow and no flow at all due to the excessive cuttings in the surface hole. This was especially prominent from 2400' to 2800', in which cleaning of the gas trap and possum belly was routinely an "on-going'" action item. The base plate on the gas trap, with a two inch diameter hole covered with a %4' mesh screen, had to be removed as the screen would be continuously plugged from clay cuttings and a hi vis mud. To remove only the screen and not the base plate would trap rocks inside the barrel which would likely break the prongs on the agitator. Removing the base plate allowed rocks to flow freely in and out of the bottom of the trap. However, removing the base plate made the trap more sensitive to the mud level in the possum belly. The base plate with screen was re-attached at 7690'. Occasionally the trap would be washed out as a preventive measure to help ensure reliable gas readings during shows. Also, two spare polyflow gas lines were utilized should freezing or plugging occur. One spare was rigged up to rig air to blowback lines to keep free of moisture and drilling mud. The second spare was kept as a back up gas line. Periodic rig power outages (highline generator) presented no problem to the Epoch unit, as all computers and sensors were on UPS. The few power outages were of a short duration, and never drained the UPS batteries. EPOCH • • • 1.2 Crew Unit Type Arctic Series 10 Skid Unit Number ~ ML030 C,~'tl~~l~i5 2L-309 BP1 Mudloggers Years Da~s Sample Catchers Years Days Technician Days Trainees Days Crai Silva 25 4 Lar Turner 7 17 Howard Lam 3 Brian O'Fallon 18 13 James Kvidera 2 17 Lees F. Browne Jr. 24 17 ~' Years experience as Mudlogger .z Days at well site between spud and total depth of well Additional Comments Technician required to work on DAC box. EPOCH CEN1JD~~iI~~~~S 2L-309 BP1 2 WELL DETAILS 2.1 Well Summary • Well: 2L-309 API Index #: 50-103-20521-00 Field: Tarn Surface Co-0rdinates: N: 5,927,681.46 E: 461,019.47 SEC 22 T10N R7E 163.94' FNL 631.48' FWL Borough: North Slope Primary Target Depth: 8660' MD State: Alaska TD De the p 9203' MD 5667.16'TVD Rig Name /Type: Doyon #14 /Arctic Triple Suspension Date: None Primary Target: Bermuda Permit #: 205-210 Spud Date: 1113!06 Ground Elevation: 117.1' AMSL Completion Date: 128/06 RT Elevation: 151.08' AMSL Completion Status: Cement Plug Secondary Target De #h: None Classiification: Pilot Hale TD Date: 122!06 TD Formation: Bermuda Days Testing: none Days Drilling: 10 2.2 Hole Data Maximum De th TD Mud D i ti C i / Shoe De th Hole Section MD ~ TVDSS ~ Formation Weight (~ ev a on .. (mc) Coring as ng Liner MD ~ TVDSS ~ FIT tPPg) Conductor 119 32 Permafrost 9.9 0 NA 16" 119 32 NA 131/2" 4350 -2237 C85 10.2 76.57 NA 95/8" 4340 -2235 16.0 81/2" 9203 -5516 C35 10.4 23.51 NA Ptu NA NA NA Additional Comments The 2L-309PB, included a 13'/z" surface hole drilled to 4500 feet, and an 8'h° pilot hole drilled to 9302 feet. The picot hole was subsequently plugged back for the 2L-309 to begin sidetracking belowthe 9 5/8" casing shoe. The 2L- 309P6 was spudded on January 12, 2006, and total depth reached on January 22. Plugging procedures were completed on January 28. The surface hole was directionally drilled, starting with 9.9 ppg spud mud, increasing to 10.2 at 2399', and maintaining 10.2 to 4350'. Slides were conducted for directional hole, and after each connection the stand was back reamed and surveys taken. No significant problems were encountered. The 8'~" pilot hole was a corkscrew type directiona! hole with continuous angle or azimuth changes sothat surveys were taken Twice per stand. Each stand was back reamed prar to each connection. A wiper trip at 6931 `produced onty 24 un~s of trip gas. Mud weight was maintained at appro~amately 9.7 to 8808', where high gas and some flow occurred. The mud weight was subsequently raised to a 10.4 ppg, which was maintained to TD. Connection gases were noted from 6744' through TD, with routine swab gases after 8808', Flow rates had to be reduced after weighting up to 10.4, to maintain an ECD below 11.7 ppg. ECD was monitored be Sperry Sun. A controlled drift rate of 50-70 feet per hour was conducted from 8350' to total depth, to allow Epoch to catch 10 foot samples, and Sperry Sun to acquire more data paints through the reservoir. Upon reaching TD the hole was circulated outthree times to insure proper cleaning of the hole. After monitoring the well and having the pumps off for 32 minutes, 4000 units of downtime gas was recorded. The mud weight was raised from 10.4 to 10.7. A wiper trip to 6800' resulted in 458 units of wiper gas. ~ F~PC~(~,H ~OI1QClfl~~~?S 2L-309 BP1 Cement plugging procedures were delayed while waiting on weather for 2 days, and two washouts occurred. The first occurred 1335' from the rotary table, and after tripping 14 stands, 3110 units of trip gaswas recorded. The mud weight was subsequently increased #010.8. After a second washout, the rig pumped out to casing, pulling tigh#from 4700' to 4500', and puffed out of the hole to rig up for cement. Trip gas after returning to bottom was 1330 units. The cement plug was pumped in stages, and some problems occurred. The first stage was pumped on bottom after running in with 3.5" tubing. After pulling out of the hole to 8000', and circulating out a nut plug sweep to clean the pipe of cement, circulation was lost after cement came to surtace. Only partial returns were established while pulling out of the hole to change the BHA. After standing back tubing and making up a BNA with a bit, bottoms up was circulated every 5 stands while tripping into 6500'. Trip gas at 8500' was 1410 units, and a polymer pill was pumped before tripping to the shoe for a flaw check and dry job, and puffing out of the hole for a stingec and tubing to continue cement procedures. Two subsequent plugs were pumped on the next trip in, a forma plug at 4851', and a kick off plug at 4630' When attempting to kick-off for the intermediate section (ZL-309), cement was no# encountered above the shoe as expected, as apparently the k~k off plug was lost to formation. A few stringers were encountered down to 4532', where cement was tagged. Trip gas with a 10.7 mud was 60 units. After tripping for the stinger and tubing, another k~k-off plug was pumped at 4532'. Trip gas, with now a 9.7 ppg mud, was only 85 units- Plugging procedureswere completed on the 2L-309PB on the morning of January 28. Sidetracking was an#icipated to begin earfythe following morning, but sidetracking was again delayed as the cement had not yet firmed up, due to the retardant in the cement. The sidetrack spudded the evening of January 29, officially the intermediate section of we112L-309. • ~Clf1000~11~f1F35 2L-309 BP1 GEOLOGICAL DATA • 3.1 Lithostratiaraphv Drilling picks 8~ actual wire tine tops refer to provisrona! picks provided by the we(( site Geologist. Surtace and Picot Hote PROGNOSED ACTUAL WIRELIKE PICK HIGHlLOW FORMATION MDRT ft TYDSS ft MDRT ft TVDSS ft (ft) Permafrost Base Permafrost 1200 -1019 NIA N/A N/A 9 5/8" Casing Point 4347 -2243 4350 -2237 6 Sidetrack Point 4367 -2247 4367 -2241 6 C80(K10) 4631 -2345 4668 -2359 -14 C50 6414 -3775 6234 -3631 144 C40 6929 -4125 6764 -4019 106 C37 7307 -4340 7139 -4236 104 Iceberg Zone 7764 -4600 7518 -4454 146 T3.1 8937 -5305 8572 -5040 265 T3 Top Bermuda 8962 -5325 8661 -5092 233 T2 Base Reservoir 9123 -5460 8876 -5238 222 C35(K3) N!A N/A 8905 -5260 N/A TD 9195 -5516 9203 -5516 0 ~1 F,Pf~C'.H ~:: ~~~~~~~ 2L-309 BP7 . 3.2 Mudlog Summary Permafrost to 9 5t8" Casing Poin# Commenced Loaaina 986' to 4350' MD (-822' to -2237` TVDSS) Drift Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 953 9 172 683 0 62 This. section includes the permafrost, and undefined formations down to casing point. The base of the permafrost was expected at 12043', and without resistivity data, that pick was not confirmed. Drill rate averaged 172 feet per hour; and sometimes drifted better in cleaner sands, but overall lithofogy variafior~ were difficuttto conclude from drill rate. Basic lithologies are sand or conglomeratic sand, sandstone, clay or claystone (sometimes grading to siltstone), and minor coal. The character of the clay or claystone was relatively uniform throughout, and briefly described in the following paragraph. Sands varied and are described in successive intervals. Onty one to three units of gas was reported above 2300', and a brief discussion of shows concludes with each interval described below this depth. Peak gases for these intervals are listed in the table at the end of this section.. Clay or claystone was medium gray to medium brownish gray to medium olive gray with many subtle variations in gray and brown secondary hues. Despite many slight color and texture changes most clays are fairly homogeneous being very soft to soft, as also very soluble or hydrophilic. Some incipient shaliness was evident on less soluble, slightly firm cuttings. Sills, of largely quartz and some various detritus, occurred in varying percentages to locally grading clay rich sittstone. Over the shakers the clays were seen as flattened and structuretess, and fairly readily dissolved into the mud system. Traces of carbonaceous matter were common as organics contributed to brownish hues and matte textures. claystone occasionally graded to carbonaceous shale with abundant flakes and clasts in variably organic clay. Carbonac~uswoody clasts were observed lower in the section. Occasional thin beds or clasts of coat were commonly associated with carbonaceous zones. The interval from 986' to 1500' was predominantty sand, locally conglomeratic, with some interbedded claystone the last 400 feet, and occasional increasing carbonaceous matter in the clays. The sands were almost entirety disaggregated, medium gray to medium dark gray with varying medium to tight alive gray secondary hues. Grains were fine upper to pebble, predominantly medium upper to coarse upper, with locally "floating" larger conglomerate clasts, alternating fractions of rounded to subrounded grains versus angular to subangular grains from 40% to 60%, as many of the largest clasts were weft rounded. A matrix of very soluble clay ~ inferred. Composfion is lithic arenite to compositional graywacke (>30% iithics}, with a diverse group of lithics including dense and porous chert, chalcedony, and other forms of cryptosilica, hard argillite and other meta tittrics, various igneous intrusives, silica and calcite replaced racks, arxi various hardened sedimentary rip- up lasts. Quartz often has a very faint brownish yellow coloration in addition to the pervasive colorless, very pale gray and very pale brown varieties. Feldspar is relativety rare. Black mafic minerals are mostly indeterminate, but tend to be dominated by augite-magnetite-hornblende suite, and green colored minerals are also iocatty abundant. The sample from 1500' to 2000' had relatively equal proportions of claystone and sandstone (or sand}, with occasional siltstone and carbonaceous shale. The sands show many of the same characteristics as the disaggregated sand above but consistently are finer in grain size, fine lower to medium lower the dominant fraction, but with rare to scattered very coarse gains #o granules. Nearly all is clay matrix supported, and gradational to very sandy claystone. The sands are 90% angular to subangular and discoidal to subdiscoidal, but mast have a second mode of larger more rounded "floatings sand grains. The finer fraction is mare quartz rich than the coarser disaggregated sand, dominantly in subtithic arenite range. The littric fraction remains diverse but clastic coal and other sedimentary (and meta-sedimentary) rock fragments are nearly absent. The interval from 2000' to 2700' was mostly sand and conglomeratic sand, with some claystone, and minor sitfistone, shale, and coal. Sands were medium t~ht gray to t~ht gray, with predominantly medium upper to fore EPOCH `.. C{~10-~0~71~~f~S 2L-309 BP1 grains, and scattered pebbles to coarse grains to grading conglomeratic sand. The finer fraction was largely subangular to angular, but with again a coarser fraction that was overall subrounded or angular bit impacted fragments. Overall, grains had moderate to occasionally well developed sphericity. The sandswere moderately to occasionally well sorted, with non to very slight siliceous cement, slight loosely attached very hydrophilic day matrix, and dominant grain support with some secondary matrix support in minor lenticular beds. Composition was 70% quartz, and 30% various IithiC fragments including Chert, siliceous mudstones (argillite), greenstones, and minor carboanaceous material. Porosity and permeability was estimated at fair to good. No sample shows were observed, and a peak gas of 683 units, though the highest in the surface hole, included only methane and relatively minor ethane. From 2700' to 3100' was mostly sand, occasionally conglomeratic, and some inrterbedded daystone, and minor siltstone and carbonaceous shale. The sands were almost entirety disaggregated, medium graywith generalty strong tight alive gray to alive gray secondary hues, with local variations in lighfiess value depending on quartz percentage, and a generally °dirty" somewhat coarse salt and pepper appearance. Grains were fine upper to pebble size, but mostly within the medium lower to coarse upper range. The sands appear generally massive. No fining in any direction is discemabte in cuttings, though grain size locally transcends into increasing very coarse lower, but larger conglomeratic grains often appear "floatingA in the finer sands and are an apparent secondary made. Grains are dominantty subangular to angular through the entire size range, but more abundant with finer sands. Subrounded to rounded grains are common to tocalty predominant (occasionally ranging to 60%); and especially many larger conglomeratic oasts are rounded to weH rounded, subspherical to spherical, and often (espedally the dense chert oasts) are highly water poNshed. Composition ranges from lithic arenite to compositional graywacke, the non quartz fraction including chert, chalcedony, and other cryptosilica, argillite and other metalithics, igneous intrusnres, limestone-siderite tithics, silica ark calcite replaced rocks, and hardened sedimentary clasts. Abundant supporting matruc of soluble clays ~ inferrred. Gas peaked at 474 units, including traces of propane, and relative increases in ethane. A trace to slight spotty orange yellow to yellow orange fluorescence was observed throughout this interval, with a fast pale to moderately bright yellow cut. Fluorescence was slightly broader and brighter with cuttings that included supporting clay, and cut included a thin streaming yellow. The interval from 3100' to 3700' included sand, sandstone, conglomeratic sand and conglomerate, with some interbedded claystone and minor coal and silistone. Sands were medium gray with usuatty strong light olive gray secondary hues, and local variations in lightness value and secondary hue`s, the lightness value deperxfirrg on the quartz percentage. Most sand and sandstone had a °dirty" somewhat coarse salt and pepper appearance, fine lower to pebble sized grains, but dominantly medium lower to coarse upper, and moderate to poor sorting. Ail appeared massive, with rare fining upward in massive discreet sandstone sections. Composition, and angularity and rounding variations were similar to the above irrterval. Gas peaked at 442 units, including minor butane and traces of pentane, but a second peak of 352 units had higher percentages of heavier gases. Trace to moderate oil shows near continuous through th~ section, from a sticky dark brown to a light brown stain on supporting clay matrix. Fluorescence was a dull to moderately bright goldfish brown to yellow white on clay supported sands, cutting an instant moderate to bright yellow to yellow white, with rare to common moderately bright streams. The interval from 3700' to 4350' included sand and conglomeratic sand, and interbedded daystone, especially above casing point. Sands were medium light gray to very light gray, coarse upper to fine lower, espedally medium upper to fine lower; and locally conglomeratic, subrounded in medium to fine grains, and subangularto angular bit impacted fragments in coarser grains, low to moderate sphericrty, poor overall sorting, non to very slight siliceous cement, slight soluble clay matrix material toosety attached and pore filling;with dominantgrain support, composed of 70% quartz, 30%chert, igneous, coal fragments and various lithic fragments, and fair overact estimated porosity and permeability. Sample fluorescence was observed from 3800' to 4100', a dull to moderate tight green in 10-40% of the samples, peaking at 3840-60' wtth the high gas for the intenrat of 232 units. Cut was an instant dull light green. DEPTH .GAS units C1 m C2 m C3 m C4 m C5 m 2683 683 134402 36 0 0 0 ~ EPOCH C~i~~lp5 2L-309 f3P1 • 2997 474 94613 148 7 0 0 3219 442 87774 391 18 11 5 3567 352 76120 487 77 23 7 3854 223 36691 99 19 7 2 Casing Point to C80 (K10j 4350' to 4668' MD (-2237' to -2359' TVDSS} Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 386 32.7 225 14 1 9 After initially driQing into sand, from just below casing to the top of the C80 was largely a very uniform claystone, with some interbedded siltstone and sandstone, and little deviation in lithologic content. Thy is also reflected in the drift rate and formation gases. The initial sand was of similar character and composition to overlying sands. The claystone was medium gray to medium light gray with an overall very faint brownish hue, mostlyverysoftto soft due solubility in the mud system, occasionally moderately soft to slightly firm and slightly siliceous, with very slightly to occasionally moderately silty textures, including mostly quartz sifts and slight to trace carbon silts and fines, and non to slightly calcareous with an occasions! calcite streak. fnterb~ded siftstone was medium light gray, moderately to very clayey, soft to friable to moderately consolidated, and often grading to very fine to fine grained sandstone: angular to subangular, matrix and grain supported, and friable to poorly consolidated as overall slightly siliceous, with a trace to slight calcite to occasional moderately consolidated calcareous streaks. Composition was 85% quartz, and 15% mostly carbon sifts and fines and minor greenish chlorite. Overall there was very poor visible porosity and permeabtlit)v, with no fluorescence or oil cuts. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 4625 14 2861 7 0 0 0 AVE 9 1822 4 0 0 0 C80 (K10) to C50 4668' to 6234' MD (-2359' to -3631' TVDSS) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 492 18.7 209 22 2 9 This interval included a minor show in sand and conglomeratic sand in the upper 200 feet, but overall this interval was largely claystone dawn to 5300', grading to mostly siltstane around 5350', and remaining mostly sittstone thereafter. t~thofogy was difficult to differentiate through drill rate, especially as constantly alternating between sliding and rotating. The upper conglomeratic sand, sandstone and sand graded to a silty claystone by 4850'. These sands averaged 20% of the samples, and as high as 40% where the (show) gas peaked. The peak was only 22 units over a 9 unit background, and included methane with only minor ethane. The conglomeratic sand and sand was medium dark gray to medium gray, very fine to very coarse grained, with scattered to common pebble sized fragments (bit impacted) and grains, angular to subrounded, with overall moderate sphericity, and estimated moderately sorted and mostly grain supported. Composition was 50% clear to translucent quartz, and 50% light gray to black to brownish black to white to minor green including charts and other silicates, partially siliceous litlrics, calcite and traces of free pyrite clusters, and common scattered pyrite on mostly non quartz grains. Estimated some fair to good porosity. A show of oil was noted first at 4675' with trace brown oil C~ EPOCH 9 ~: COnOCO~'1t~~i~'S 2L-309 BP1 • stain on clayey fine grained sandstones with a slow blooming poor cut of oil. Samples of conglomeratic sand and sand from 4775' to 4800' displayed 20% dull to moderate yellow to orange yellow fluorescence with slight instant to slow blooming oil. The claystones are medium gray to medium frctht gray and displaying a slk~htly browner hues until 5200', in which the overall color is a light brownish gray to a pale yellowish brown, all are very soft, lumpy to clumpy, clustered to clotted, gelatinous, mushy to pasty, tacky to slimy (showing a wide array of consistency and tenacity), non to very slight cohesiveness and moderate adhesiveness, amorphous fracture, amorphous to massive habit, velvet to satin luster, ashy to colloidal texture, massive gradational beds of clay and interbedded silts, some thin harder siltstone lenticular beds, overall composed of 70% clay, 30°lo silt and various detrital materia{. • Sittstone was medium t"rght gray to light brownish gray with same dark yellowish brawn to brownish gray hues, and poorly to moderately indurated. Interbedded with clay, the upper silts were amorphous to subblocky, with a dull earthy lustec, and silty to gritty textures. The silts become abrasive to sucrosic by 6100', composed overall of 60% silt and 40%ciay, scattered very fine grains and carbonaceous specs, non calcareous overall butwith a trace of shell fragments, and occasionally gradational to very fine grained sand. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 4789 22 4317 19 0 0 0 AVE 9 1662 9 0 0 0 C50 to C40 6234' to 6764' MD t-3631' to X019' TVDSS) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 354 11.1 143 14 2 8 The C50 section was composed of a uniform section of silty shale, elaystone, siftstone and sandstone (all gradational and mostly interbedded)_ The top of the section was distinguished by a change from the C80 siltstone (90%) to an array of shale (30°r6), silts (20%), clays (30%) and sandstones (20%}. The drill rate is erratic between 20 to 80 ft/hr and the background gas is mostly under ten units. The lower section ofthe C50 is marked by an increase of carbonaceous shale with a small increase in gas (7-9 units over background}. Sandstone was medium light gray to brownish gray overall, very fine to fine grained, subangular to angular, moderate to huh sphericity, poorly to moderatety sorted, thinly bedded and laminated in siltstone and silty shale, and variably silty and argillaceaus. Cleaner sandstone was moderatetywetl consolidated with siliceous cement, while argillaceous sandstone was poorly to moderately consolidated and matrix and grain supported with same siliceous and some calcareous cement. Grains were predominantly quartz wrth slight carbon fines and a trace of chlorite. Same occasional carbon flakes on laminations, minor interbedded greasy ash fall tuff, and very poor to poor visible porosity and permeability, with na show of oil fluorescence or oil cut. The shale and elaystones are gradational and dark gray to medium dark gray with brownish hues to brownish gray, moderately soft to firm, soluble to slightly soluble, subblocky to subplaty to flaky with common inapientto visible lamina, earthy to silty texture with softer pieces generally earthy grading to claystone and firmer pieces generally silty grading to siltstone, mostly non calcareous except some grading to sandstone and sittstone, grains generally quartz with slight sifts, fines and flakes of carbonaceous matter, flakes common as partings on lamina, trace chlorite (or glauconite} associated with grairry cuttings, overall mashy interlaminated to interbedded with sittstone and sandstone, slight calcareous debris throughout samples, arxi a trace interbedded greasy ash fall tuff . Shales become dark gray to gray grading to grayish black at 6700', soft to sl~htty firm, subblocicyto subplatyto fissile, smooth to slightly silty texture, often slightly to moderately carbonaceous with carbon matter dorninantiy EPC~C;H 10 C~1+~1~ 2L-309 BP1 weathered to clay and remnant carbonaceous matter as partings on lamina especially fissile shale, some slight disseminated mica flakes in non carbonaceous shale. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 6721 14 2440 69 16 0 0 AVE 8 1410 26 5 0 0 C40 to C37 6764' to 7139' MD (-4019' to -4236' TVDSS) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 401 31.1 228 23 2 11 The C40 is composed of siltstone and claystone and an increase of carbonaceous shale and carbonaceous clays. The increase of carbonaceous material increased the background gas from 8 units at the top of the section (6770') to 15 units at the base {7120'). The drill rate is fairly steady throughout the entire section averaging 228 ft/hr. No shows of oil fluorescence or oil cuts were observed. The carbonaceous shale and carbonaceous clays are brownish black to grayish black mottled black and various hues of all, brittle showing micro planar fracture with a flaky to sub paper habit with some grading to a micro tabular habit, very distinct change in samples, dull earthy occasionally greasy luster, matte to mottled texture, thin to thick beds of very carbonaceous shale and carbonaceous clay mottled with clean silt and clay, trace amounts of calcite crystals and trace amounts of aggregate pyrite. The siltstone is 1`ight brownish gray occasionally laminated black with micro carbonaceous material, poor to moderate induration, slightly seclale, predominantly mushy, non to slight cohesive, slight to moderate adhesive, planar fracture, platy to micro tabular habit, dull earthy luster, silty #o gritty texture, massive gradational beds of silt, carbonaceous shale and general detrital material, overall composed of 60% silt, 30% clay, 10°10 carbonaceous material. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 6858 23 4814 146 41 7 0 AVE 11 1895 59 18 2 0 Top C37 to iceberg Zone 7139' to 7518' MD (-4236' to -4454' TVDSS) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 306 9.9 206 24 4 11 The G37 zone is described here in three different intervals. The top is a continuation of the C40 with 40% carbonaceous shale and clays. The middle is composed of gradational siltstone and claystone, and the bottom is composed of a gradational siltstone and sandstone with a trace cut of oil. Drill rate was fairly uniform averaging 206 ft/hr. The carbonaceous shale and carbonaceous clays are a reflection of the lower G40 with no change in 1'ithiotogic content. The claystones are composed of light brownish grays, very soft, lumpy to clumpy, clustered to clotted, gelatinous, mushy to pasty, very hydrophilic, non to slightly cohesive, slight to moderate adhesive with various consistency and tenacity, amorphous fracture and habit, dull earthy luster, ashy to colloidal textures, composed ~l?~~~ 11 ~„ ~I+~t~ 2L-309 BP1 of a massive bed of gradational clays and silts composed of 80% clay and 20% silt at 7230' grading to a more siltier section at 7300' of 60% clay, 40°!° silt and various detrital material. The siltstones are composed of medium light gray hues, poor to moderate induration, brittle to firm in parts, slightly sectile in clay sections, mushy to pasty with slrclht cohesiveness to slight adhesiveness, planar fracture, platy to micro tabular habit, dull earthy taster, silty to gritty textures, massive gradational beds of silt and clay composed of 70% silt, 30% clay. The lower sandstones from 7405' to 7505' had a distinct "salt and pepper" color. Grains ranged from fine lower to very fine lower grading to sift, and were subrounded with moderate to well developed sphericity, The sandstone was poorly sorted, with a moderate #o very calcareous cement and moderate clay matrix, both matrix and secondary grain support, composed of quartz with minor chert and traces of various lithic fragments, and had poor visible porosity and permeability. A slight oil show was noted in the lower C37 sandstone from 7410' to 7420', with 15% dull even to patchy greenish sample fluorescence, and a very slaw, very poor diffuse cut. No petroleum odor, stain, or visible oil was observed. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7371 24 3955 138 47 18 0 7416 19 2113 70 31 19 0 AVE 11 1888 69 25 9 0 Iceberg Zone to T3.1 7518' to 8572' MD t-4454' to -5040' TVDSS) • Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Ma~amum Minimum Avera e 326 6.1 139 69 4 20 The Iceberg Zone is dominantly sand and sandstone from 7518-7820', with interbedded shale and siltstone. From 7820' to 8380' was roughly 60% shale, some carbonaceous, with interbedded siltstone and sandstone. From 8380' to the T3.1 is dominantly siltstone, with some interbedded claystone, carbonaceous shale and shale, and minor sandstone. The base plate was attached to the trap at 7690' and gas increased coincident with a minor show of 69 units, which included, far the first time in the pilot hole, a full suite of gases methane through pentane. These gases persisted through total depth. Another show of 69 units occurred in a thin sandstone at 8349'. Sand/sandstone to 7820' was medium light gray overall with a slight "salt and pepper" appearance and some very faint olive hues. Grains ranged from medium to very fine upper with slightty scattered coarse to conglomerate, and were subangular to angular with moderate to huh sphericity. Mgt loose grains are medium to fine indicating moderatety well to weft sorted sands. Some sandstone is moderatety welt sorted, grain supported, and poorly consolidated with a slight white clay and catcite cement. Some is poorly sorted with varied grains, to moderately well sorted with a dominant fine faction, mostly grain supported, and moderately well consolidated with calcareous cement and clay matruc. Overall compositions are 75°k clear to #ranslucent quartz, 25% dusky brown to black to gray to minor green and trace red to tan grains including silicates {especially dark mafics}, partially siliceous carbonaceous lithics, minor glauconite (or chlorite) staining, and traces volcanic tuff and pyrite clusters. The tuff is possibly interbedded in parts. Visible porostiy was poor to fair. Background gas increased from 10 units {before adding the base plate) to 69 units and returned again to 12 units. The show gas was briefly subdued by some slow pump rates, but samples cut for approximately 120 feet, displaying a slow weak diffuse green yellow bulk cut with no sample fluorescence. Sandstone below 7820' is medium light gray to medium gray, some with faint brownish hues, fine to very fine • grained, subangutar to angular, moderately to poorly sorted and mostly grain supported ~ sift and clay matruc, ~PC)C;H 12 ~,' ~~~~~~~~ 2L-309 BP1 • moderately well to poorly consolidated with calcareous cement, 75% quartz, and 25% black carbon lithics, tan variably calcareous clasts, and traces of glauconite and pyrite, with some very poor to poor visible porosity. Samples at 8350' with a thin gas spike had a trace of fluorescence and a weak diffuse cut. Siftstone and shale was medium gray to medium fight gray, some with faint brownish hues. Cuttings were moderately soft to moderately firm, subplaty to tabular, same flaky, some subbtocky, and with common incipient fissility to visible lamina. Traces of d~seminated carbon silts and mica persisted throughout, to some grading carbonaceous shale. Cuttings were mostly non calcareous to very slightly calcareous, often exhibiting slight pin point fluorescence from 10% HCL. Samples included traces of a tan aphanfic slightly calcareous tuff, and traces light gray with a greasy luster as possibly grading ash fall tuff. Sittstane below 8380' was pale yellowish brown to dark yellowish brown, poorly indurated, to some moderately indurated on larger fragments, predominantly lumpy to clumpy, clustered to clotted, gelatinous, mushyto pasty with various consistency and tenacity but becoming firmer with depth, especially at the contact of the T3.1 top, amorphous to earthy fracture, subplaty to amorphous habits, very hydrophilic, dull earthy luster, silty to clayey texture; massive gradational beds of silt with interbedded clays and trace carbonaceous material. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7740 69 11488 532 264 147 62 AVE 20 3050 169 99 65 29 T3.1 to T3 (Top Bermuda) 8572' to 8661' MD (-5040' to -5092' TVDSS) • • Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 93 21.5 62.8 43 0 19 This brief interval is dominantly a pale to dark yellowish brown slightly calcareous siltstone, with some grainy texture as occasionally grading to sandstone. With a subplaty to subtabular habit, grades to shale in part. The interval produced some minor gas and a trace of fluorescence and cut. The intervat was control drilled at 50-70 feetthour. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 8653 43 6367 452 311 264 74 AVE 19 2499 163 112 101 45 T3 (Top Bermuda) to T2 (Base Reservoir) 8661' to 8876' MD (-5092' to -5238' TVDSS) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 209 12.4 62.9 2930 39 1184 The T3 sandstone reservoir had medium lower to very fine upper grains, especially fine grains, subangular to subrounded, with moderate to high sphericity. Composition was approximately 80% cleartotranslucentquartz. The remaining 20% were black to dark brown to gray to trace green and pink, occurring as hard grains to firm grainy clasts and flakes. Possible constituents included silicates such as dark mafics, biotite, feldspar, and trace chlorite (or greenstone), and partially siliceous lithics of carbonaceous matter and claystone. The sandstone was well to moderately sorted, predominantly grain supported with an overall slight white to light gray clay matrix, and moderately to well consolidated with a trace to slight persistent calcareous cement, and slight overall siliceous cement more prominent in welt consolidated sandstone. [~ ~P~CH 13 C+Q~'14G1D~'11~~tp5 2L-309 BP1 This section was control drilled to average 50-70 feet/hour, but drill rate was erratic during sliding intervals. The sandstone was generally massive with occasional streaks of slightly sandy calcite, thin beds grading to matrix supported sandstone, and locally some apparent thin beds of gray to brownish gray shale and sittstone. Some minor flaky white ash fall tuff was observed, and the clay matrix in part may have been derived from ash fall tuff. Visible porosity was poor in moderately consolidated sandstone, diminishing to very poor in matroc supported and same dense welt consolidated sandstone. Gas peaked at 2930 units with a 9.7 mud down to 8807', with a significant breakdown of methane through pentane. Mud weight was subsequently increased to a 10.4, with a peak gas of 323 units after. Slight free oil in the upper sand included a greasy dark brown non fluorescent tar. Occasional light brown oil stain was visible on clayey streaks. Sample fluorescence varied from 90% in the upper sandstone diminishing to 60-70% at the base. Fluorescence was bright greenish yellow to moderate yellowish green to dull Irght green, with an instantaneous moderate to slight light blue white cut, slowly diffusing to a br~ht bluish milkywhke. Cuts dried to a slight visible rescue. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 8670 913 102677 10460 5990 977 694 8748 2930 202030 47260 41326 30249 17696 8821 323 7290 931 1621 3042 3040 AVE 1184 83153 14890 13415 10590 6231 T2 {Base Reservoir) to C35 {K3) 8876' to 8905' MD 1-5238' to -5260' TVDSS) CJ • Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 145 18.9 59.6 146 79 130 From the base of the reservoir this section grades into interbedded sitthtone, sandstone, shale and carbonaceous shale. Sample fluorescence decreased sharply from the 60% above the base ofthe reserver, to 30% initially, and dawn to 10-20°x6 at the base of this short interval. The fluorescence was possibly from thin sandstone beds of similar character and composfion of the overlying reservoir, but also included cuttings from the overlying reservoir. Maximum gas was 145 units possibly from sandstone. Control drilling averaging 50 to 70 feet per hour continued, with drill rate erratic through sliding intervals. Siltstane and shale was gray to brownish gray, overall poorly indurated, and subplafy to subblocky, some with gritty textures grading to sandstone, and locally grading to carbonaceous shale. Carbonaceous shales were brownish gray to brownish black, poorly indurated, subplaty to subtabular to flaky, with variably organic clay content, and partings commonly associated with carbon residue or micro laminations of carbonaceous matter. Traces of white flaky ash fall tuff, observed also in overlying reservoir, continued to be carried in samples. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 8890 146 3814 335 512 1070 1457 AVE 130 3176 283 439 946 1288 C35 {K3} to TD 8905' to 9203' MD -5260' to -5516' TVDSS Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 191 5.7 57.8 129 46 76 C~ EPOCH 14 ~~~,~~~ 2L-309 BP1 • This final section is dominated by sand and some sandstone, with some interbedded siltstone and probably shale in the top 20', and locally throughout. Sample quality and especially sample lag is somewhat questionable due in part to slower, less efficient pump rates to reduce ECD, and long sliding intervals with very little rotating. Initial cuttings dominated by carbonaceous shale are probably from the overlying section arm the very top of this section. Sittstone is apparerrtty of similar character to the overlying section. The actual top of the sand, first realized at 8990', may have actually been much hrc~her. Control drilling continued, averaging 50-70 feetJhour, and continued to be erratic during sliding intervals. The sands are light gray #o very light gray, with medium to fine upper, overall subangular grains, of poor to moderate sphericity. The sands are moderately to weft sorted, predominantly grain supported, and loosely consolidated to grading sandstone with slight siliceous cement. Composition ~ dominantly quartz, with minor undifferentiated grains and clasts. Same slight clay and silt matror is interred. Despite a maximum of only 92 units of gas in the apparent main sand body, the show quality is estimated at fair. Porosities are estimated to be fair to good. Dark grayish brown greasy tar is very pervasive on upper sand cuttings diminishing to pin point spots on 50% of grains lower. Fluorescence is a 90°r6 dull light green, with an instant slight hazy bluish green cut, slowly diffusing to a moderate bluish green in the upper sand portion and to a bluish green white lower. Cuts dried to a light grayish brown residue in the upper, and to a medium grayish brown lower. DEPTH GAS units C7 m CZ m C3 m C4 m C5 m 8948 129 2435 184 191 496 855 9110 92 7101 316 147 158 323 AVE 76 2942 258 191 345 491 • • _G~Q\J~ 15 e.-' Ct]f1~0~'11~~fp5 2L-309 BP1 • 3.3 Gas Samples 1 unit = 0.05% Methane Equivalent • • Gas Baas -Surface and Pilot Hole (2L-309PB1 Sam le De th Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1u=0.05% M.E. (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) 1 1500 1 236 2 2000 1 187 3 2565 22 3833 4 2686 600 119316 30 5 2990 260 53584 77 4 6 3000 340 68705 109 5 7 3220 428 $5076 375 18 6 4 2 2 8 3493 204 40293 73 26 2 10 1 4 9 3571 306 66699 409 68 5 16 2 4 10 4032 126 21415 216 28 0 4 1 1 11 4500 8 1525 4 12 5000 10 1897 9 13 5500 7 1036 5 14 6008 8 1375 10 2 15 6500 10 1705 30 4 16 7000 11 1986 56 10 17 7120 62 Connection Gas - GG breakd own not recorded. 18 7375 17 2781 98 33 5 8 0 0 19 7589 10 1903 70 43 22 14 20 8000 24 3948 195 116 21 46 12 17 21 8491 20 2445 188 134 35 101 81 68 22 8652 39 6367 452 311 76 188 33 41 23 8663 64 7115 520 368 80 209 53 79 24 8673 750 Connection Gas - GC breakd own not recorded. 25 8709 626 69968 7958 6001 1041 2791 842 1420 26 8741 2830 194305 41741 36092 7115 19165 7602 7011 27 8850 280 8823 736 985 444 1624 903 1521 28 8990 70 1469 124 153 60 261 185 287 3.4 Connection Gases 1 unit = 0.05% Methane Equivalent Depth(ND) (feet} Gas units/BG Depth(ND) (feet) Gas units/BG Depth(TVD) feet Gas units/BG Depth(T1lD) (feet) Gas units/BG No CG 0-6649' 7309(4485) 4 7967(4853) 35 8623(5220) 25 6744(4158) 9 7404(4540) 5 8061(4905) 38 8716(5277) 2100 6867(4230) 11 7499(4594} 3 8155(4956) 10 8807(5338) 3600 6931(4266) 20 7594(4648) 13 8247(5007) 10 8901(5408) 100 7025(4321) 7 7684(4699) 12 8341(5060 15 8995(5483) 150 7120(4375) 50 7779(4751) 35 8434(5112) 10 9091(5566) 185 7214(4430) 14 7873(4802) 21 8530(5167) 16 9185(5651) 300 ~1 EP+C~~H 16 ~rt31'1'11~~1~S 2L-309 BP1 • 3.5 Sampling Program /Sample Dispatch For Surface and Pilot Hole 121-309PB11 J • Set T e / Pu ose Fre uenc Interval Dis etched to Bayview Warehouse Unwashed Biostratigraphy 50' 1000' - 8350` MD Cono~Phillips Alaska, Inc. ABV 100 A CPAI 10' 8350' -9203' MD $105 Eleusis Drive Anchorage, AK 99502 SNOWS Attn: D. P kUM. McCracken Bayview Warehouse Unwashed Biostratigraphy 50' 1000' - 8350` MD Cono~Phillips Alaska, Inc. ABV 100 B CPAI 10' 8350' -9203' MD $105 Eleusis Drive Anchorage, AK 99502 SNOWS Attn: D. P ~skUM. McCracken Bayview Warehouse Washed, screened & dried 50 1000' - 8350` MD ConocoPhillips Alaska, Inc. ABV 100 C Reference Samples ' 8350' -9203' MD 8105 E~usis Drive CPAI 10 SNOWS Anchorage, AK 99502 Attn: D. P 7M. McCracken Bayview Warehouse Washed, screened 8~ dried 50' 1000' - 8350` MD ConocoPhillips Alaska, Inc. ABV 100 D Reference Samples 10' 8350' -9203' MD $105 Eleusis Drive CPAI Anchorage, AK 99502 SNOWS Attn: D. P ki/M. McCracken Bayview Warehouse Washed, screened & dried 50' 1000' - 8350` MD ConocoPhillips Alaska, Inc. ABV 100 E Reference Samples 10' 8350' -9203' MD $105 Eleusis Drive CPAI Anchorage, AK 99502 SNOWS Attn: D. Przywojski/M. McCracken Bayview Warehouse Washed, screened 8~ dried 50' 1000' - 8350` MD ConocoPhillips Alaska, Inc. ABV 100 F Reference Samples 10' 8350' -9203' MD 8105 Eleusis Drive AOGCC Anchorage, AK 99502 Shows Attn: D. P ki/M. McCracken Gas Bags Routine intervals or 1000' - 9203' MD Isotech Laboratories, Inc. G si nificant eaks above 9 P 500' Show Peaks 1308 Parkland Court Champaign, IL 61821 background ~I?~l.fH 17 Rr'11~~Ip5 2L-309 BP1 • 4 PRESSURE /FORMATION STRENGTH DATA 4.1 Formation Integrity/Leak Qff Tests Equivalent mud weight (EMW) is calculated from rotary table. LOT (Leak Off Test) in bold italics. MD TVDSS FIT t LOT FORMATION (ft) (t{) E 4370' -2244 16.0 pp~_ NA 4.2 Wire line Formation Tests HYDROSTATIC DEPTH TVD TVDSS Before After F Press Mobil" PPG Calc Formation No Data 4.3 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 a well; Background Gas {BG) Trip Gas (TG) Mud Weight (M111~ Resistivity (RES} Corrected D exponent (DXC} Hale Candi6ons (HC) Pressure Test Wire line {PT) Swab Gas (SG) Equivalent Circulating Density {ECD) Quantitative Methods Downtime Gas {DTG) Wiper Gas (WG) Connection Gas {CG) Pore Pressure (PP) The primary indicators used for PP evaluation were gas trends, including BG, CG, TG, WG, DTG, and SG. Wire line testing was not conducted on the pi{ot hole. Epoch was not monitoring RPM, necessary far DXC calculations, and therefore DXC plots were not utilized. Factors such as controlled drill rates, alternate sliding and rotating intervals, variations in angle building, PDC bits, and the absence of clean shale baselines to establish compaction trends, tend to make DXC plots unreliable, anyway. RES plots tend to be reliable in determining a permafrost base, and suggesting compaction trends with depth, although the presence of hydrocarbons skews this data. However, generally, tow RES and low gas indicate shaliness. 4.4 Pore Pressure Evaluation Conclusions 1 }Surface Hole -121/4" {MD:986' to 4350'; TVD: 973' to 2388'} Surface was drilled with a 9.9-10.2 ppg MW. ECD, DXC, and RES data were not acquired, and gas data was utilized to estimate PP. Only one to three units of BG was recorded down to 2300' (1837'TVD}, well below the estimated base of the permafrost @ 1200' (1170TVD}. Without RES data, or apparently any indication from gas data, it is not possible to confirm the estimated top of the permafrost. CG and other DTG were not observed, despite a number of shows after 1900' TVD. Therefore, PP is ~1 EPC~-~;H 18 C~'1OC1O~'11~~fp5 2L-309 BP1 • estimated to have remained well below MW, in the 8.7 to 8.8 ppg range below 1837'TVD, and in the 8.9 to 9.2 range dawn to casing point. 2) 8'/z" pilot hole (MD:4350'to 9203'; TVD: 2388'-5667') Pore pressure first appeared to be approaching mud weight at 6744' (4148'TVD), in the C50 zone just above the C40, where the first CG (see section 3.5) was reported while drilling with a 9.6 to 9.7 mud. Carbonaceous shale, also encountered at this depth, was water soluble and much of the CG appears to have been generated from backreaming before connections. High ECDs from solids washing into the mud in the C50 reduces BG possibty masking increasing PP, as overpressured shales can swell into the borehole. Carbonaceous shales, for instance, drilled between 6180 and 6240' did not release any CG. ECD was dramatically reduced after cleaning the hole with a wiper trip at 6931'. WG, however, was only 24 units, indicating pressures remained less than the 9.6 mud weight. From 6644' to 8623' (see section 3.5), CG persisted, varying from 3 units to as high as 50 units, averaging 10 to 15 units over background, and on average doubling BG. The well flowed slightly at 8714', and flawed again at 8807', while making connections in the Bermuda reservoir. Very high CGs were of short duration, and PP is estimated to be slightly over the 9.7 MW, but well below the ECD_ After raising the MW to 10.4, BG and CG were greatly reduced and the well stopped flowing after connections. CG continued to trend upward, however, and a 32 minute downtime at TD produced 4000 units. Therefore, it is concluded that PP continued to trend upward to TD, and MW was raised to a 10.7 before tripping. Trip gases after TD varied from 453 units to 3110 units. Overall, pore pressure in the pilot hole was estimated to have remained fairty constant between 9.1 and 9.2 ppg down to the C50, to have increased to a 9.5 at the tap of the C40, and to have remained fairly constant again until approaching the Bermuda reservoir. Pore pressure is estimated to have increased sharply to a 9.9 at the top of the reservoir, and gradually to a 10.2 at total depth. The following chart and plots summarize the conclusions for the surface and pilot holes. • • 4.5 Pore pressure evaluation r.,- • CCMt"1~)O~t1~~1p5 2L-309 BP1 ti F Primary Secondary Interval To s Pore Pressure EMW T d Source of on orma Interval Lithology (%) Lithology (%) MD ft TVD ft Min Max Trend ren Indicators Quantitative Estimate Base Permafrost CI st 50% Sd-Ss 40% 1200 1170 8.7 9.2 Sli U BG,TG NONE Casin Point CI st 70% Sltst 20% 4350 2388 9.1 9.2 Flat BG NONE C80 Sltst 60% CI st 30% 4667 2509 9.1 9.2 Flat BG RES C50 Sh-CI st 60% Sltst 25% 6233 3781 9.2 9.5 Sli U BG,CG RES C40 Sh-CI st 60% Sltst 30% 6763 4169 9.4 9.5 Flat BG,CG,TG RES Iceber Zone Sh-CI st 40% Sd-Ss 30% 7517 4454 9.4 9.6 Flat BG,CG RES T3 Bermuda Ss-Sd 70% Sltst 20% 8660 5242 9.9 10.1 U BG,CG,HC RES TD NA NA 9203 5517 10.2 10.2 NA BG,TG RES NOTE: Clyst = Claystone/Clay, Sd =Sand, Sltst = Siltstone, Sh =Shale, Sst =Sandstone EPOCH 20 • COt1000~'11~~I~'y5 2L-309 BP1 MWBGASvsND-121/4" .,,, • ~ • CO~OC0~1~~~IpS 2L-309 BP1 ECD, MW, GAS 8< PPG vs TVD - 8.5" 15 14.5 14 13.5 13 12.5 12 11.5 11 10.5 10 9.5 9 8.5 8 2000 • • ECD (PPG) -~ MW (PPG) f GAS (ME+8) f PP (PPG) ~~ ~POC;H 22 2500 3000 3500 4000 4500 5000 5500 6000 s .• • COt1000~11~~1~35 2L-309 BP1 RES8~GASvsND-8.5" 100 10 0.1 ~ RES ~ ~ GAS (ME+0.1) ~~ EPOCH 23 2000 2500 3000 3500 4000 4500 5000 5500 6000 Co~xx~o~Phillip~ ZL-3os BP1 • 5 DRILLING DATA 5.1 Survey Data C: • Measured Depth (ft) Incl. {°) Azim. {°) True Vertical Depth ft Latitude (ft) Departure (ft) Vertical Section (ft) Dogleg Rate (°t100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE-IN 34.3 0 0 34.3 a a 0 0 115 0.57 131.39 115 -0.27 0.3 0.4 0.71 172 1.17 133.03 171.99 -0.85 0.94 1.26 1.05 262 1.22 137.41 261.97 -2.18 2.26 3.14 0.12 353 1.90 121.46 352.94 -3.68 4.2 5.57 0.88 441 3.05 104.62 440.86 -5.04 7.71 8.98 1.53 477.26 3.76 105.68 477.05 -5.60 9.79 10.83 1.97 567.56 6.22 104.71 567.00 -7.64 17.37 17.57 2.73 658.8 10.60 102.75 657.24 -10.75 30.35 28.83 4.81 752.28 10.98 108.76 749.07 -15.51 47.16 43.95 1.27 845.49 15.53 106.25 839.77 -21.86 67.56 62.70 4.92 939.39 19.63 104.60 929.27 -29.36 94.90 87.10 4.4 1033.45 21.47 104.46 1017.34 -37.64 126.86 115.28 1.96 1127.48 25.46 103.01 1103.58 -46.49 163.23 146.94 4.29 1222.2 26.89 103.14 1188.58 -55.94 203.93 182.04 1.51 1315.99 31.96 103.36 1270.25 -66.51 248.76 220.81 5.41 1397.68 35.34 103.27 1338.24 -76.93 292.81 258.93 4.14 1493.33 39.53 106.37 1414.18 -91.87 348.97 308.72 4.80 1587.9 47.93 105.69 1482.45 -109.87 411.75 365.33 8.90 1682.68 50.28 105.58 1544.50 -129.18 480.74 427.19 2.48 1778.52 54.21 106.33 1603.17 -150.02 553.58 492.82 4.15 1869.69 57.85 106.17 1654.10 -171.17 626.15 558.50 4.00 1963.02 60.32 106.83 1702.05 -193.92 702.92 628.23 2.72 2059.85 62.44 106.34 1748.43 -218.17 784.38 702.32 2.23 2151.12 66.42 107.18 1787.82 -241.92 863.19 774.20 4.44 2249.08 72.26 104.27 1822.37 -266.70 951.38 853.34 6.58 2345.52 74.05 103.64 1850.32 -288.96 1040.96 931.64 1.96 2447.33 74.06 103.25 1878.28 -311.72 1136.17 1014.21 0.37 2529.06 73.99 102.97 1900.78 -329.54 1212.69 1080.24 0.34 2630.53 73.89 102.98 1928.85 -351.44 1307.71 1162.07 0.10 2726.4 72.84 106.59 1956.30 -374.87 1396.51 1240.66 3.77 2820.34 73.51 105.74 1983.49 -399.90 1482.87 1318.72 1.12 2913.01 73.90 104.91 2009.49 X23.41 1568.66 1395.27 0.96 3007.74 75.12 103.86 2034.79 -446.08 1657.08 1473.07 1.67 3101.97 74.97 105.10 2059.11 -468.84 1745.23 1550.73 1.28 3185.18 75.52 105.82 2080.30 -490.29 1822.78 1620.08 1.07 3286.82 75.17 106.01 2106.02 -517.26 1917.35 1705.23 0.39 [~ ~;P~~;H 24 ~..: ~Ort~'00~'11~If~'S 2L-309 BP1 • • • Measured Depth Incl. (o} Azim. (~} True Vertical Depth Latitude (ft) Departure (ft} Vertical Section Dogleg Rate 3378.69 75.32 105.01 2129.42 -541.01 2002.95 1781.84 1.07 3474.86 74.72 103.49 2154.28 -563.88 2092.99 1860.89 1.65 3568.59 74.7 103.88 2178.99 -585.27 2180.83 1937.36 0.4 3661.05 73.16 103.82 2204.59 -606.54 2267.10 2012.64 1.67 3753.31 73.75 103.54 2230.86 -627.46 2353.03 2087.44 0.7 3846.81 73.95 103.63 2256.87 -64$.55 2440.32 2163.31 0.23 3941.22 73.33 105.40 2283.46 -671.25 2528.02 2240.62 1.92 4036.65 72.80 106.11 2311.26 -696.04 2615.88 2319.54 0.9 4131.06 76.02 106.26 2336.63 -721.39 2703.20 2398.48 3.41 4226.57 76.29 106.07 2359.48 -747.20 2792.27 2478.98 0.34 4303.49 76.57 104.99 2377.53 -767.22 2864.31 2543.47 1.41 4364.07 75.97 107.42 2391.91 -783.64 2920.81 2594.57 4.02 4409.66 72.41 109.29 2404.33 -797.45 2962.44 2633.44 8.75 4455.66 69.41 111.26 2419.38 -812.50 3003.21 2672.62 7.68 4504.54 68.09 110.93 2437.09 -828.90 3045.72 2713.96 2.77 4548.48 65.85 111.93 2454.28 -843.67 3083.36 2750.75 5.51 4596.89 62.93 112.93 2475.2 -860.32 3123.70 2790.78 6.31 4641.02 60.70 113.28 2496.05 -875.58 3159.48 2826.63 5.1 4690.60 58.50 112.69 2521.13 -892.28 3198.84 2866.01 4.55 4737.29 56.71 113.13 2546.15 -907.63 3235.16 2902.29 3.92 4786.55 55.15 113.$1 2573.74 -923.87 3272.59 2940.00 3.37 4830.62 53.42 112.59 2599.47 -937.97 3305.47 2973.00 4.52 4879.05 51.28 114.38 2629.05 -953.24 3340.64 3008.43 5.3 4923.90 48.88 114.41 2657.83 -967.45 3371.96 3040.43 5.35 4973.43 46.46 116.16 2691.18 -983.08 3405.07 3074.68 5.54 5018.01 44.60 117.13 2722.41 -997.34 3433.00 3104.71 4.45 5066.63 42.25 119.63 2757.72 -1013,21 3462.91 3136.56 5.99 5113.18 39.62 120.98 2792.89 -1028.59 3489.24 3165.93 5.96 5159.49 37.72 123.43 2829.04 -1044.00 3513.73 3194.03 5.27 5206.58 35.21 126.37 2866.92 -1059.99 3536.69 3221.48 6.49 5256.59 33.49 130.76 2908.21 -1077.55 3558.75 3249.45 6.03 5300.31 32.20 134.82 2944.94 -1093.64 3576.15 3273.11 5.84 5347.05 30.77 140.69 2984.81 -1111.67 3592.57 3297.48 7.23 5393.23 30.22 143.28 3024.6 -1130.13 3607.00 3320.78 3.08 5442.74 29.75 149.03 3067.5 -1150.65 3620.77 3345.11 5.88 5486.89 28.94 152.30 3105.98 -1169.50 3631.38 3366.03 4.07 5535.34 27.71 155.80 3148.63 -1190.16 3641.44 3387.87 4.26 5579.63 26.20 159.58 3188.11 -1208.72 3649.08 3406.52 5.16 5627.65 25.22 164.66 3231.39 -1228.52 3655.48 3425.20 5.02 5673.41 24.16 170.37 3272.97 -1247.16 3659.63 3441.48 5.70 5723.54 24.17 177.77 3318.72 -1267.53 3661.74 3457.59 6.04 5766.09 23.66 181.31 3357.61 -1284.77 3661.89 3470.07 3.58 [~ EPC~~H 25 C~l~~i~S 2L-309 BP1 • • • Measured Depth (ft) Incl. o () Azim. ~ () True Vertical Depth ft Latitude (ft) Departure (ft) Vertical Section (ft) Dogleg Rate (°/100ft) 5814.87 24.16 186.40 3402.21 -1304.48 3660.55 3483.30 4.35 5861.75 23.88 188.72 3445.03 -1323.39 3658.04 3495.15 2.1 5910.55 24.23 194.71 3489.60 -1342.85 3654.00 3506.31 5.05 5955.63 23.61 198.25 3530.81 -1360.37 3648.83 3515.30 3.47 6001.65 23.89 204.75 3572.94 -1377.59 3642.04 3522.95 5.72 6050.59 24.36 211.00 3617.62 -1395.24 3632.69 3529.13 5.31 6098.87 24.62 211.53 3661.55 -1412.35 3622.30 3534.20 0.71 6146.75 25.66 217.01 3704.90 -1429.13 3610.84 3538.29 5.32 6192.31 27.33 224.11 3745.69 -1444.52 3597.62 3540.15 7.85 6241.49 29.74 231.34 3788.90 -1460.25 3580.23 3539.36 8.56 6289.53 32.56 237.33 3830.02 -1474.68 3560.04 3535.68 8.72 6334.49 34.74 239.25 3867.45 -1487.76 3538.84 3530.33 5.39 6382.43 37.26 242.36 3906.23 -1501.48 3514.24 3523.08 6.49 6428.3 39.20 244.92 3942.26 -1514.07 3488.80 3514.44 5.46 6476.04 42.02 247.61 3978.50 -1526.56 3460.36 3503.62 6.95 6523.75 44.29 250.48 4013.31 -1538.21 3429.89 3490.80 6.29 6571.91 46.88 252.31 4047.01 -1549.17 3397.29 3476.00 6.02 6617.06 48.21 255.53 4077.49 -1558.38 3365.28 3460.36 6.03 6664.49 49.88 256.55 4108.58 -1567.02 3330.52 3442.39 3.88 6710.75 51.08 258.16 4138.02 -1574.83 3295.70 3423.78 3.73 6802.07 55.49 258.85 4192.60 -1589.40 3223.98 3384.37 4.87 6895.04 54.90 258.32 4245.67 -1604.51 3149.16 3343.17 0.79 6990.98 54.85 258.38 4300.87 -1620.35 3072.30 3301.11 0.07 7085.67 54.17 258.89 4355.84 -1635.54 2996.72 3259.45 0.84 7179.63 55.10 261.61 4410.23 -1648.51 2921.21 3216.25 2.56 7274.62 54.69 260.95 4464.86 -1660.29 2844.4 3171.29 0.71 7368.98 54.04 261.14 4519.83 -1672.23 276$.65 3127.17 0.71 7463.75 55.97 262.35 4574.18 -1683.36 2691.82 3081.74 2.29 7558.08 55.16 262.49 4627.52 -1693.63 2614.7 3035.47 0.87 7649.01 54.76 261.76 4679.73 -1703.82 2540.95 2991.51 0.79 7744.35 57.58 260.27 4732.81 -1716.21 2462.74 2946.01 3.23 7838.11 57.55 260.65 4783.09 -1729.32 2384.7 2901.15 0.34 7933.06 56.72 260.17 4834.62 -1742.61 2306.06 2856.00 0.97 8027.04 56.5$ 259.61 4886.28 -1756.39 2228.78 2812.15 0.52 8120.84 57.02 261.26 4937.65 -1769.43 2151.39 2767.68 1.54 8213.53 56.58 261.52 4988.40 -1781.04 2074.70 2722.69 0.53 8305.32 55.92 261.28 5039.40 -1792.45 1999.24 2678.40 0.75 8400.25 55.64 261.87 5092.78 -1803.95 1921.59 2632.66 0.59 8495.15 55.27 261.99 5146.60 -1814.92 1844.20 2586.71 0.40 8589.25 54.91 261.15 5200.45 -1826.24 1767.86 2541.75 0.83 8632.68 53.82 261.60 5225.75 -1831.53 1732.97 2521.28 2.65 8680.37 51.74 261.93 5254.60 -1836.97 1695.38 2499.05 4.40 ~1 EP~~H 26 r..' Ci0I1OaQ~'tl~~l~?5 2L-309 BP1 U • • Measured Depth (ft) Incl. (o) Azim. (~) Vert al Depth ft Latitude (ft) Departure (ft) Vertical Section (ft) Dogleg Rate (°/100ft) 8727.56 49.79 263.22 5284.44 -1841.70 1659.14 2477.24 4.64 8773.54 47.1$ 265.43 5314.92 -1845.12 1624.89 2455.87 6.72 8823.02 43.75 265.56 5349.62 -1847.89 1589.74 2433.41 6.93 8867.35 41.77 265.10 5382.16 -1850.33 1559.74 2414.3 4.52 8913.95 38.47 265.17 5417.79 -1852.88 1529.82 2395.33 7.08 8960.97 36.15 265.32 5455.19 -1855.25 1501.42 2377.27 4.94 9009.63 33.60 264.73 5495.11 -1857.65 1473.71 2359.72 5.29 9057.29 29.15 263.19 5535.79 -1860.24 1449.04 2344.43 9.49 9102.92 26.74 261.31 5576.10 -1863.11 1427.85 2331.75 5.62 9151.95 24.12 262.18 5620.37 -1866.14 1407.02 2319.44 5.40 9165.9 23.51 262.18 5633.13 -1866.91 1401.44 2316.11 4.37 PROJECTED SURVEY TO TOTAL DE PTH 9203' 9203 23.51 262.18 5667.15 -1868.92 1386.78 2307.36 0 ~~~`J~ 27 • 5.2 Bit Record ~. • • ~CI~"1t1~f1~]5 2L-309 BP1 Bit Make Type Jets / TFA Depth In MD / TVDSS ft Total Footage Bit Hrs Aug' ROP ft/hr WOB (Klbs) RPM PP lpsi) Wear BHA 12.25" Hole 1 HTC MXL-1 3X15, 1X13 119'/119' 4231 37.99 172 30 na na 2-2-CT-H-E-I-WT-TD 1 8.5" Hole 2 HTC HMC605 5X14 4350'/XX)CX 4853 43:31 163 18 na na 1-2-BT-N-D-I-CT-TD 2 ~PO+CH 28 • ~i • Ct]If10C0~"11~f1~5 2L-309 BP1 5.3 Mud Record Contractor :MI Mud Type :Spud Mud in Surface. LSND from 4370' (after FIT) to TD. Date Depth MW VIS s/ t PV YP Gels FL cc FC Sols % O/W Ratio Sd % MBT pH CI ml/1 Ca ml/I 12 1/4" section 1 /12106 400 9.9 162 58 60 18/50/68 6.6 3/na 7.5 0/92.5 0.25 25 8.0 300 0 1 /13/06 2399 10.2 109 51 43 7/32/57 5.5 3/na 9.5 0/90.5 0.25 25 8.0 400 20 1 /14/06 4330 10.2 90 45 37 7/25/56 4.8 3/na 10.5 0/89.5 0.25 27.5 8.0 300 0 1 /15/06 4350 10.2 86 46 35 8/19/39 4.8 3/na 10.5 0/89.5 0.25 30 8.0 400 0 8'/z" Pilot hole section 1 /16/06 4350 9.7 99 15 28 13!16/19 3.0 1 /na 5.5 0/94.5 0 0 8.5 300 0 1 /17/06 4350 9.65 71 13 28 9111 /14 6.0 1 /1 6.0 0/94 0 0 9.0 300 20 1 /18/06 5806 9.75 50 13 28 11 /18/23 3.1 1 /1 7.0 3/90 0.25 5 8.0 700 40 1 /19/06 6930 9.65 51 13 28 11 /18/24 4.1 2/3.5 8.0 3/89 0.33 17.5 9.0 600 20 1 /20/06 8501 9.7 56 19 31 18/24/32 4.0 2/3 8.0 3/89 Tr 25 9.0 500 60 1 /21 /06 8979 10.4 52 20 27 13/19/23 4.2 1 /3 12.0 3.5/84.5 0.25 26 8.5 400 20 1 /22/06 9203 10.7 53 18 24 12/20/27 4.3 2/3 13.5 3/83.5 0.33 28 9 500 20 1 /23/06 9203 10.8 52 20 24 10/18/24 4.5 2/3 14 3/83 Tr 28 9 500 20 1 /24/06 9203 10.8 51 20 22 11 /17/23 4.5 213 14 3/83 0.12 27 9 500 20 1 /25/06 9203 10.7+ 42 13 16 617/11 5.5 2/4 13.5 2/84.5 Tr 17.5 11 500 120 1 /26/06 9203 10.7 40 14 14 6/7/$ 5.4 2/3 13.5 2/84.5 0.13 20 11 550 80 1 /27/06 9203 9.8 45 10 16 7/15/25 8 2/na 9.0 1 /90 0.30 15 11.5 550 120 1 /28/06 9203 9.7 42 12 15 7/16/24 8 2lna 8.5 1 /90.5 0.33 15 11.5 550 100 Abbreviations MW =Mud Weight Gels =Gel Strength Sd =Sand content WL = Water or Filtrate Loss CI =Chlorides VIS =Funnel Viscosity Ca =Hardness Calcium PV =Plastic Viscosity Sols =Solids YP =Yield Point ECD =Effective Circulating Density FC =Filter Cake O/W =Oil to Water ratio lI~ ~l'O~I~ 29 ~~t~E)C0~11~~~~ 2L-309 BP1 • • MORNING REPORTS ~~~~~ 30 ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB • Report for: Kleibacker • Date: 1/15/06 Time: 12:OOam Current Depth: 4269 Operation: DRILLING Yesterdays Depth: 2400 24 hr Footage: 1869_ r)rillinn Ppramotarc ROP: Current: 53 Max: 334 Tor ue: Current: 0 Max: 0 WOB: Current 27 Max: 47 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 669 Time: 5:15 Circulation: Strokes: 5259 Time: 39 ECD: Current: 0 Max: 0 M~~ri Prnncrtinc MW: 10.2 FV: 109 PV: 51 YP: 43 FL: 5.5 Gels: 7!32/57 Sal: 9.5 pH: 8.0 CI- 400 Ca++ 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 60 Max: 683 Depth: 2683 C~ac Fvantc Trip Gas Depth TG C1 CZ C3 C41 C4N C51 C5N 2399 143 Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N NONE Paakc Depth TG C1 C2 C3 C41 C4N C51 C5N 683 NO 134402 582 96 27 8 3as Sam les No. Depth TG C1 C2 C3 C41 C4N C51 CSN Lithologies: Current: 60% CLAYSTONE, 30% SAND, 10% CONGLOMERATE SAND Last 24 hrs: SAND, SANDSTONE, CONGLOMERATE SAND, CLAYSTONE Opperationat Summary: DRILLING FORMATION Calibrations: YES @ START OF WELL Failures: NONE • ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB U Report for: KLEIBACl4ER Date: 1/16/06 Time: 12 am Current Depth: 4350 Operation: RUN 9 5/8" CSG Yesterdays Depth: 4269 24 hr Footage: 81 r)rillinn Paramaterc ROP: Current: 50 Max: 155 Tor ue: Current: 0 Max: 0 WOB: Current 44 Max: 48 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 669 Time: 5:15 Circulation: Strokes: 5259 Time: 39 ECD: Current: 0 Max: Mud Pro~efies MW: 10.2 FV: 90 PV: 45 YP: 37 FL: 4.8 Gels: 7/25/56 Sol: 10.5 pH: 8.0 CI-~ 300 Ca++ 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 105 Depth: 4328 C.`,ac Fvpntc Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N NONE Connection Gas De th TG C1 C2 C3 C41 C4N C51 CSN NONE PPakc Depth TG C1 C2 C3 C41 C4N C51 CSN 105 NO 20400 42 8 4 0 3as Sam les No. Depth TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 80% CLAYSTONE, 20% SAND Last 24 hrs: CLAYSTONE, SAND DRILL FORMATION TO 4350' CIRCULATE BOTTOMS UP THREE TIMES Opperational Summary: AND PULL OUT OF THE HOLE AND PREP TO RUN 9 5/8n CSG, RIG UP CSG CREW AND BEGIN TO RUN CSG. Calibrations: NO Failures: NONE ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB r~ LJ • Report for. KLEIBACKER Date: 1/17/06 Time: 12 AM Current Depth: Yesterdays Depth: 24 hr Footage: rlrillinn Paramctnrc 4350 Operation: NIPPLE UP TEST BOPE 4350 ROP: Current: 0 Max: 0 Tar ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: Maui PrnnartiPc MW: 10.2 FV: 86 PV: 46 YP: 35 FL: 4.8 Gels: 8/19/39 Sot: 10.5 pH: 8.0 CI- 400 Ca++ 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth: 0 (S~c Fvcntc Trip Gas Depth TG C1 C2 C3 C41 C4N C51 CSN 4350 YES Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N NONE Paakc Depth TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 80% CLAYSTONE, ZO% SAND Last 24 hrs: FINISH RUNNING CSG TO BOTTOM, CIRCULATE OUT 400 UNITS OF Opperational Summary: TRIP GAS, COND1TlON AND PUMP CEMENT, NIPPLE DOWN AND NIPPLE UP BOPE. Calibrations: NO Failures: NONE ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB • U LJ Report for: KLEIt3ACKER Date: 1/18/06 Time: 12 AM Current Depth: 4350 Yesterdays Depth: 4350 24 hr Footage: 0 rlrillinn Paramatars Operation: M/~U BHA P/U DP ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: Mud Properties MW: FV: PV: YP: FL: Gets: Sol: pH: CI- Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth: Gas Events Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N NONE Connection Gas De th TG C1 C2 C3 G41 C4N C51 C5N NONE Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N Gas Sam ples No. Depth TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Opperational Summary Calibrations: YES Failures: NONE FINISH TESTING BOPE, MIU NEW BHA, P/U DP AND PREP RIG TO DRILL OUT CEMENT ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB • C] Report for: KLEIBACKER Date: 1/19/06 Time: 12 AM Current Depth: Yesterdays Depth 24 hr Footage: rlrillinn Poramofiarc ROP:v Current: 272 Max: 388 Tor ue: Current: 0 Max: 0 WOB: Current 13 Max: 75 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 2772 Time: 22 Circulation: Strokes: 7825 Time: 62 ECD: Current: 10.95 Max: M~~ri Prnnnrtipc MW: 9.6+ FV: 71 PV: 13 YP: 28 FL: 6 Gels: 9/11 /14 Sol: 6 H: 9.0 CI- 300 Ca++~ 20 MW Change: Depth: 4350 From: 10.2 To: 9.6+ Reason: CSG Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 6 Max: 75 De h: 4351 r_aa Fvcnfic Tri Gas De th TG C1 C2 C3 C41 G4N C51 C5N 4350 24 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 4350 75 14528 32 6 1 C;ac Samnlac No. Depth TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 80% SILTSTONE, 20°!o CLAYSTONE Last 24 hrs: CLAYSTONE, SILTSTONE, SAND Opperational Summary: TIH TO BOTTOM, CIRCULATE UP 24 UNITS OF TG DRILL AHEAD Calibrations: NO Failures: NONE Operation: DRILL/ SLIDE ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB • C: Report far: VAUGHNBROWN KLEIBACKER Date: 1/20/06 Time: 12 AM Current Depth: 9100 Yesterdays Depth: 8601 24 hr Footage: 499 tlrittinn Rcr~mntcrc Operation: DRILU SLIDE ROP: Current: 52 Max: 209 Tor ue: Current: 0 Max: 0 WOB: Current 6 Max: 134 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4333 Time: 41 Circulation: Strokes: 9771 Time: 89 ECD: Current: 9.88 Max: Mnri Prnnartias MW: 10.4 FV: 52 PV: 20 YP: 27 FL: 4.2 Gels: 13/19/23 Sol: 12 H: 8.5 CI-~ 400 Ca++~ ZO MW Change: Depth: 8800 From: 9.8 To: 10.4 Reason: GAS Mud Loss event: Depth: 8800 Volume: SLIGHT Gas Data Ditch Gas: Current: 75 Max: 2930 Depth: 8748 C~ac FvPntc Wi er Gas De h TG C1 C2 C3 C41 C4N C51 CSN NO Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N YES 9089 185 8994 150 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8748 2930 202030 47260 41326 30249 17759 f~ac Samnlec No. De th TG C1 C2 C3 C41 C4N C51 C5N 24 8709 626 69968 7958 6001 3832 2262 25 8741 2830 194305 41741 36092 7115 19165 7602 7011 26 8850 280 8823 736 985 444 1624 903 1521 27 8990 70 1469 124 153 322 472 Opperational Summary: DRILLING AHEAD Lithologies: Current: 90% SAND, 10% SILT Last 24 hrs: SANDSTONE, SILTSTONE, CARBONACEOUS SHALE & SILT/CLAY DRILL TO 8809 CBU WT UP WELL FLOWING CBU = GCM WT UP 10 4 Calibrations: NO Failures: NONE • ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB • Report for: VAUGHNBROWN KLEIBACKER Date: 1/21/06 Time: 12 AM Current Depth: Yesterdays Depth: 24 hr Footage: 8601 Operation: DRILL/ SLIDE I~rillinn PPramatarc C] ROP:v Current: 51 Max: 326 Tor ue: Current: 0 Max: 0 WOB: Current 1SLIDE Max: 122 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4105 Time: 33 Circulation: Strokes: 6933 Time: 55 ECD: Current: 9.88 Max: Marl Prnnarficac MW: 9.6+ FV: 51 PV: 13 YP: 28 FL: 4.1 Gels: 11J18/24 Sol: 8 H: 9 CI~ 600 Ca++ 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 13 Max: 68 De h: 7740 C~ac FvPntc Tri Gas De th TG C1 C2 C3 C41 C4N C51 CSN NONE Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N YES 8530 16 8436 10 Paakc Depth TG C1 C2 C3 C41 C4N C51 C5N 7740 68 11488 737 411 254 149 C~ac Samnlpc No. De th TG C1 C2 C3 C41 C4N C51 C5N ~, 21 8491 21 2445 188 134 35 101 81 68 20 8000 24 3942 195 116 67 30 19 7589 10 1903 70 43 22 14 18 7375 17 4095 144 49 8 11 Last 24 hrs: Opperational Summary Calibrations: NO Failures: NONE Lithologies: Current: 90% SILTSTONE, 10% SANDSTONE (VERY FINE) DRILLING • ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB I~ • Report for: VAUGHNBROWN KLEIBACKER Date: 1/22/06 Time: 12 AM r)rillinn PPramPtPrc Current Depth: Yesterdays Depth: 24 hr Footage: 9100 Operation: DRILU SLIDE ROP: Current: 52 Max: 209 Tor ue: Current: 0 Max: 0 WOB: Current 6 Max: 134 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4333 Time: 41 Circulation: Strokes: 9771 Time: 89 ECD: Current: 9.88 Max: Mud Properties MW: 10.4 FV: 52 PV: 20 YP: 27 FL: 4.2 Gels: 13/19/23 Sol: 12 H: 8.5 CI- 400 Ca`+~ 20 MW Change: Depth: 8800 From: 9.8 To: 10.4 Reason: GAS Mud Loss event: Depth: 8800 Volume: SLIGHT Gas Data Ditch Gas: Current: 75 Max: 2930 Depth: 8748 C~ac Fvpntc Wi er Gas De th TG C1 C2 C3 C41 C4N C51 C5N NO Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N YES 9089 185 8994 150 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8748 2930 202030 47260 41326 30249 17759 C~aG Samnlas No. De th TG C1 C2 C3 C41 C4N C51 C5N 24 8709 626 69968 7958 6001 3832 2262 25 8741 2830 194305 41741 36092 7115 19165 7602 7011 26 8850 280 8823 736 985 444 1624 903 1521 27 8990 70 1469 124 153 322 472 Opperational Summary: DRILLING AHEAD Lithologies: Current: 90% SAND, 10% SILT Last 24 hrs: SANDSTONE, SILTSTONE, CARBONACEOUS SHALE & SILT/CLAY DRILL TO 8809 CBU WT UP WELL FLOWING CBU = GCM WT UP 10 4 Calibrations: NO Failures: NONE • ConocoPhillips Alaska Inc. Exploration Wet12L-309 PB n U C] Report for: VAUGHN/SROWN KLEBACKER Date: 1123!06 Time: 12 AM Current Depth: 9302 Operation: CIRCULATE MUD ON BOTTOM Yesterdays Depth: 9302 24 hr Footage: 0 Drilling Perameters ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 4381 Time: 41 Circulation: Strokes: 42035 Time: 133 ECD: Current: 9.88 Max: Mud Properties MW: 10.7 FV: 53 PV: 18 YP: 24 FL: 4.3 Gels: 12120127 Sof: 13.5 H: 9 Cl" 500 Ca++ 20 MW Change: Depth: 9203 From: 10.4 To: 10.7 Reason: SWAB GAS Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 50 Max: 92 De h: 9110 Cac Fvents SWAB GAS De th TG C1 C2 C3 C41 C4N C51 C5N YES 9203 4000 229235 84756 74882 15092 36917 8423 10537 WIPER GAS De th TG G1 C2 C3 C41 C4N C51 C5N YES 9203 458 10.4 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 9110 92 7101 450 377 622 1012 Gas Samples No. De th TG C1 C2 C3 C4t C4N C51 C5N 28 8990 70 1469 124 153 60 261 185 287 27 8850 280 8823 736 985 444 4624 903 1521 26 8741 2830 194305 41741 36092 7115 19165 7602 7011 25 8709 626 69968 7958 6001 1041 2791 842 1420 Lithologies: Current: Last 24 hrs: Opperational Calibrations: Failures: 80% sand, 20% siltstone SAND, StLTSTONE Summary: C[RCULATE MUD ON BOTTOM NO NONE ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB . Report for: VAUGHN/BROWN KLEIBACKER Date: 1/24/06 Time: 12 AM Current Depth: 9203 Operation: CIRC ON BOTTOM Yesterdays Depth: 9203 24 hr Footage: 0' Drif6na Perarr~ters • ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4381 Time: 48:00 Circulation: Strokes: 12035 Time: 134 ECD: Current: 9.88 Max: Mud Properties MW: 10.8 FV: 52 PV: 20 YP: 24 FL: 4.5 Gels: 10/18124 Sol: 14 H: 9 Gf 500 Cap+~ 20 MW Change: Depth: 9203' From: 10.7 To: 10.8 Reason: wiper gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Cun-ent: 45 (arc} Max: 73 Circ} De h: 9203' Gas Events De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks WIPER De h TG C1 C2 C3 C41 C4N C51 C5N 15 stands 9203' 3110 191063 29782 19411 3501 8523 1840 2400 Swab Gas De th TG C1 C2 C3 C41 C4N C51 C5N 2 rrrinutes 9203' 65/55i3G Pumps down gas Sam tes No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 90% SAND, 10% CLAY Last 24 hrs: Circ mud, losing PP (250 pst7, 15 std Wiper Trip/Drop carbide, purrs out Opperational Summary: carbide two returns 1) 850 strokes (washout 14th stand off bottom}, TIH Circ out 3110 units, gas cut 10.7 to 9.7, arculate mud incr to 10.8 wait on weather Calibrations: no Failures: none • ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB • • Report far: VAUGHN/BROWN KLEIBACKER Date: 1/25/06 Time: 12 AM Curren# Depth: 9203 Yesterdays Depth: 9203 24 hr Footage: 0' Drilling Perimeters Operation: OUT OF HOLE PREP CEMENT JOB ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4381 Time: 48:00 Circulation: Strokes: 12035 Time: 134 ECD: Current: 11.83 Max: Mud Prooer6es MW: 10.8 FV: 51 PV: 20 YP: 22 FL: 4.5 Gels: 11/17/23 Sol: 14 H: 9 CC' 500 Ca" 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 9 (cite} Max: 65 cite} De h: POOH' Gas Events WIPER De th TG C1 C2 C3 C41 C4N C51 C5N De h TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 90% SAND, 10% CLAY Last 24 hrs: Lost 75 psi PP, drop carbide est. washout @ 3229', purrs out of hole found Opperationaf Summary: washout ~ 3,000', purrs out to 4500'=packir~ off (tight 4700-4500'clays),CBU x2 purrs out to shoe, check flow POOH, UD BHA Run 3.5" tubing. RIH 4340'. Calibrations: YES Failures: none ConocoPhillips Alaska Inc. Exploration Well 2L-309 PB • Report far: VAUGHNBROWN KLEIBACKER • Date: 1/26/06 Time: 12 AM Current Depth: 9203' Operation: Prep to Pump Pill Yesterdays Depth: 9203' 24 hr Footage: 0' Orillina Rerarnefers ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4381 Time: 48:00 Circulation: Strokes: 12035 Time: 134 ECD: Current: 11.83 Max: Mud Properties MW: 10.8 FV: 51 PV: 20 YP: 22 FL: 4.5 Gets: 11/17!23 Sol: 14 H: 9 Cf 500 Ca++~ ZO MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 50 ~«rc) Max: 1 GO Depth: 6650' Gas Events Depth TG C1 C2 C3 C41 C4N C51 C5N 'eaks WIPER De th TG C1 C2 C3 C41 C4N C51 C5N NO TRIP GAS De h TG C1 C2 C3 C41 C4N C51 CSN ~~ YES 9200 X330' 188978 23507 13560 2002 4870 934 1238 YES 6650 1410 161526 31649 25607 4423 11372 2477 3270 No. De th TG C1 C2 C3 C41 C4N C51 CSN 3as Sa les Lithologies: Current: 90°fo SAND, 10% CLAY Last 24 hrs: TIH f/ 4340' wl 3.5 tubing & DP to bottom, cite out 1330 units of TG, pump Opperafional Summary: cement, POOH work Lost Cire TIH to 6500 , cite out 1410 units TG, pump pill. Calibrations: no Failures: none ConocoPhillips Alaska Inc. Explora#ion Well 2L-309 PB • n U U Report for: VAUGHNlBROWN KLEtBACKER Date: 1/27/06 Time: 12 AM Current Depth: 9203 Operation: Suspend 2L-309P8 Yesterdays Depth: 9203 Test BOPE prep for - 24 hr Footage: 0' Drlg out 2L--309 I~riflinn PPramPtarc ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: 0 M~~ri Prnnartiac MW: 10.7 FV: 40 PV: 14 YP: 14 FL: 5.4 Gets: 6/7/8 Sal: 13.5 H: 11 CI- 550 Ca'+~ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: ~~} Depth:4851' 3as Events WIPER De th TG C1 C2 C3 C41 C4N C51 C5N 4630 320 TRIP De th TG C1 C2 C3 C41 C4N C51 C5N 4851 940 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sarr ~les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: POOH to 4340', flow check, pump dry job, POOH R/U ~ run 3.5" tbng, TIH to Opperational Summary: 4851' CBU (940 units TG}, pump forrrra plug & pill POOH to 4200, pump nut pfug, TIH to 4630' CBU (320 units WG), cement kick off plug, POOH to 3692 CBU (240 units WG) & nut plug, POOH to 879' L/D tbng, TEST BOPE. Calibrations: NO Failures: none ConocoPhillips Alaska Inc. Exploration Well 2L-3U9 • C~ Report for: VAUGHNBROWN KLEIBACKER Date: 1/28/06 Time: 12 AM Current Depth: 4530 Operation: Prep to RIH Yesterdays Depth: 4530 24 hr Footage: 0' r)rillinn Perarr~tPrs ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 2242 Time: 25 Circulation: Strokes: Time: ECD: Current: Max: Mud Prooerties MW: 9.8 FV: 45 PV: 10 YP: 18 FL: 8 Gels: 7115125 Sol: 9 H: 11.5 CI-~ 550 Ca+' 120 MW Change: Depth: 4530 From: 10.7 To: 9.8 Reason: aad H2o Mud Lass event: Depth: Uolume: Gas Data Ditch Gas: Current: 0 Max: 60 G De h: 4000' Gas Events WIPER De h TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 CSN Gas Sam les No. De th TG C1 C2 C3 C4i C4N C51 C5N Lithologies: Current: Last 24 hrs: RtD BOP test equipment, M/U BHA, upload to MWD & surface test, TIH t/3700 Opperationat Sumrr~ry: wash t14000 (max gas 60 units} M/U DP wash f/4000~340 W/O orders, pump OOH 4530 to 4300, blow down top drive, observe well, tube rig, pump slug, POOH, stand back BHA, DC UD BHA Calibrations: no Failures: Wane EPOCH Day Rate: $2700.00