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206-190
II Histo File Co~r Pa e Image Project We ry g XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a ~ ~ - 1 ~ Q Well History File Identifier II I I II I III ( VI II II II I II II I O anizin (done) r9 9 Two-Sided III III III II I p Rescan Needed RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: her Items Scannable by a Large Scanner L ~~ ~ ^ Poor Quality Originals: V{~RI 0 ~ S ('({ N s OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date:. ~s~ Project Proofing I II IIIIIIIIII VIII BY: Maria Date: ~ © ~s~ ti P x 30 ~ = ~~~ + ~ =TOTAL PAGES d on repara Scanning _ (Count does not inGude cover sheet) BY: _ Maria Date: (~ / r Q ~~ g ~s~ ~ ' Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover et) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~~ ~ D V ~s~ 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Scanning is complete at this point unless rescanning is required. VIIIIIIIIIIIIIIII ReScanned III 111111 VIII V III BY: Maria Date: /s~ Comments about this file: Quality Checked III 111111 III II'I III 10/6/2005 Well History File Cover Page.doc ~~..' `~ ~' " ~~~, `~"$ ;;r ~, ~ ~~< w -0~~ ~.;• ~~. ~ ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 5127/2009 Permit to Drill 2061900 Well Name/No. INTREPID 2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-023-20036-00-00 MD 3550 TVD 3550 Completion Date 4/23/2007 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION ~ C 2`~ .,.,- Mud g~Ye~~ Samples No Directional Survey t Y DATA INFORMATON ~' Types Electric or Other Logs Run: Dipole sonic / GR /platform express / MSCT Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / i y e mearrrmt numcer Name acme mea~a rvo start stop cn Kecervea comments Log Neutron 2 Col 123 3550 Open 4/13/2007 DGR, CTN, ALD, CNO 12~ Apr-2007 **Large Log** D 15228°lReport: Final Well R Open 6/18/2007 Final Well Report: Table of contents, Equip and Crew, Well Details, Geo Data, Pres Form, Drilling Data, Daily Reports w/Graphics ~~ PDF, TIF ' og 15228 Mud Log 2 Col 117 3550 Open 6/18!2007 Gas Ratio Log ~og 15228 Lithology 2 Col 117 3550 Open 6/18!2007 Lithology Log ~g 15228 Mud Log 2 Col 117 3550 Open 6/18/2007 Formation Log og 15228 Mud Log 2 Col 117 3550 Open 6/18/2007 Drilling Dynamics ~, I og 15228 ~ud Log 2 Col 117 3550 Open 6/18/2007 Pore Pressure Log !, D C Lis 15244/ Induction/Resistivity 151 3550 Open 6/28/2007 LIS Veri, NCNT, NPHI, DRHO, FET, GR, ROP w/Graphics, PDF, TIF, TXT, EFI og 15244 Induction/Resistivity 25 Coi 1 123 3550 Open 6/28/2007 MD DGR, EWR-Phase 4, i ROP 12-Apr-2007 og 15244 Induction/Resistivity 25 Col 1 123 3550 Open 6/28/2007 TVD DGR, EWR-Phase 4, ROP 12-Apr-2007 (.',, 15266 ~onic 5 Col 1300 3530 Open 7/3/2007 DSI, Shear and Compressional Data 12- i Apr-2007 • DATA SUBMITTAL COMPLIANCE REPORT 5/27/2009 Permit to Drill 2061900 Well Name/No. INTREPID 2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-023-20036-00-00 M SDDU I VU J.70U I~ORI~JICIIUII UdIC '//LJ/LUV/ I..VI11f.JICUVII JIGIIUJ ran ~,uncni.~iawa ran Div i~ og 15266 Pressure Col 3124 3160 Open 7/3/2007 Pres and Sample Report 13-Apr-2007 og 15266 See Notes Col 1300 3512 Open 7/3/2007 Platform Express, AIT, TLD, CNL, MCFL, GR 12- Apr-2007 og 15266 See Notes Col 1300 3500 Open 7/3/2007 Mech Sidewall Coring Tool and Core Report 12-Apr- 2007 Rpt Directional Survey 20 3550 Open D ~ 15274`~See Notes 0 0 Open 7/12/2007 Core Anal Report w/Graphics PDF and TIF ED ~ ~~ 15332 °~See Notes 0 0 Open 8/16/2007 Rotary Sidewall Core Analysis Results ~ w/Graphics EXL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~uttings 90 3350 5/3/2007 1189 Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 1/29/2007. j,/ore Chips 3128 3183 5/3/2007 1189 Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 1129/2007. ADDITIONAL INFORMATION Well Cored? Y'/ N Daily History Received? ~/ N Chips Received? f~Y / N Formation Tops gY,/ N Analysis ~Y '' N Received? • Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/27/2009 Permit to Drill 2061900 Well Name/No. INTREPID 2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-023-20036-00-00 MD 3550 TVD 3550 Completion Date 4/23/2007 Completion Status P&A Current Status P&A UIC N ~1 Compliance Reviewed By: _ _ Date: ~ Y ~~ ~~J~ Page 1 of 1 • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Wednesday, September 05, 2007 11:34 AM To: NSK Expl Env Cc: Brasfield, Tom J; Winfree, Mike B Subject: RE: Pictures of CPAI Exploratory Wells ~v~ `~ \,~ I left a voice message with the Environmental Coordinators (659-7217) on 8/31/07 regarding the location clearance inspections at Intrepid #2 and Noatak #1. The photos provided indicate conditions at the Intrepid #2 well location that require additional surface work. Noatak #1 location is acceptable. Please call to discuss, or summarize what CPAI plans to do to complete the surface abandonment at Intrepid #2. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Expl Env [mailto:n1662@conocophiHips.com] Sent: Friday, August 17, 2007 6:15 PM To: Regg, James B (DOA) Cc: Brassfield, Tom J; Winfree, Mike B Subject; Pictures of CPAI Exploratory Wells Jim, I talked to Chuck 5heve yesterday about flying by helicopter to inspect the two exploratory weAs that ConocoPhillips drilled this past winter. Unfortunately, he couldn't make the flight but he said that sending pictures of the locations to you would suffice. Attached are two pictures of the Intrepid #2 location drilled south of Barrow and two pictures of the Noatak #1 location drilled in NE NPRA. If you need more information, let me know. Chris Chris Brown/Bob Lipchak Exploration Environmental Coordinators Office: (907) 659-7217 Fax: (907) 659-7706 Truck Phone: (907) 448-1976 6/2/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 30, 2007 8:07 AM To: Regg, James B (DOA) Subject: RE: Pictures of CPAI Exploratory Wells ~ ~~ -~ I agree that Noatak looks good, shouldn't be a problem giving location clearance there. Intrepid is another matter. I was copied on some recent messages from guys at DNR about location clearance and subsidence/ponding issues. I am surprised to see the extent of disturbance at Intrepid. It might be interesting to see if CPAI has photos from prior to drilling. It would appear that Intrepid may have different "soils" than Noatak. It is the furthest west of any location recently drilled. I think CPAI needs to be notified that the Intrepid site needs some work. Tom _ From: Regg, James B (DOA) Sent: Wednesday, August 29, 2007 2:47 PM To: Maunder, Thomas E (DOA) Subject: FW: Pictures of CPAI Exploratory Wells Pictures from Noatak and Intrepid locations are attached. Noatak is in good shape; mound still intact. I'd be interested in your thoughts about clearing location with subsidence around Intrepid well? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Expl Env [mailto:n1662@conocophillips.com] Sent: Friday, August 17, 2007 6:15 PM To: Regg, James B (DOA) Cc: Brasfield, Tom J; Winfree, Mike B Subject: Pictures of CPAI Exploratory Wells Jim, I talked to Chuck Sheve yesterday about flying by helicopter to inspect the two exploratory wells that ConocoPhillips drilled this past winter. Unfortunately, he couldn't make the flight but he said that sending pictures of the locations to you would suffice. Attached are two pictures of the Intrepid #2 location drilled south of Barrow and two pictures of the Noatak #1 location drilled in NE NPRA. If you need more information, let me know. Chris Chris Brown/Bob Lipchak Exploration Environmental Coordinators Office: (907) 659-7217 Fax: (907) 659-7706 Truck Phone: (907) 448-1976 6/2/2008 ~t)1'ICK~~11~~1 S TRANSMITTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7"' Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Intrepid 2 Permit: 206-190 DATE: 08/14/2007 Hand delive Tr n mitt Intrepid 2 500232003600 Report and CDROM Rotary Sidewall Core Analysis Results; Intrepid #2, Barrow South Field. North Slope, Alaska; CL57111- 107443CP Core Labs, Bakersfield, CA. Please sign, scan signed transmittal, save as .pdf format and e-mail to address below. Or return to CPAI via mail within 48 hours of receipt. To all data reci tents: All data is confidential until State of Alaska desi Hated AOGCC release date CC: Andy ~dre PAI Geologist Receipt: ~ _ Date: ~ ~:~ f ~ GIS-Technical Data Management E ConocoPhillips ~ Anchorage, Alaska ~ Ph: 9©7.265.6947 Sandra.D.Lemkena Conocophi/l~s com ao~ - i9o '~ - S~ t 'j r ,`~ Core La9~ AESERY~IR AP2IMIZA7ION l _~~~ ~~ PETR®L.EUM SERVICES G~~- ~ 9~ - f~~yq~ V' ~ ~ w OPdROENTI COR RESULTS CONOCOPHILLIPS ALASKA, INC. INTREPID 2 WELL BARROW SOUTH FIELD CL FILE 57111-107443CP Performed by: Core Laboratories 3437 Landco Dr. Bakersfield, CA 93308 (661) 392-8600 ~ tqb #-5~ ' ~ ~ Petroleum Services D'evision 3437 Landco Dr. Bakersfield, California 93308 Te1:661-325-5657 ® Fax:661-325-5808 Core Lich www.corelab.com RESERVOIR OP7[MIZAiION Mr. Greg Wilson July 27, 2007 ConocPhillips Alaska Post Office Box 100360 Anchorage; Alaska 99510-0360 Subject: Core Analysis Data Well: Intrepid 2 Field: Barrow-South File No.: 107443CP API No.: 50-023-20036-00 Dear Mr. Wilson; Rotary sidewall cores recovered from the subject well were submitted to our Bakersfield facility for permeability, porosity, and fluid saturation determinations. The results of these measurements are presented in the accompanying report. The saturations were determined by Dean Stark Methods with toluene as the distillation solvent. Following distillation, the samples were extracted of remaining hydrocarbon by soxhlet with methylene chloride/methanol. Prior to measurement of porosity and permeability to air, the samples were dried at 235 degrees Fahrenheit. Grain volumes were determined by Boyle's Law Double-cell Methods with helium as the gaseous medium. Bulk volumes were measured by mercury displacement at ambient conditions. Pore volumes were calculated from bulk volume and grain volume data. Permeability measurements were made with a confining pressure of 400 psig. The analysis procedures are noted on the data pages. The bottle containing sample #3 from 3121' had broken during transit and as a consequence the sidewall core dried out and therefore shows a very low total fluid saturation. We are pleased to have performed this service and hope it is beneficial in the evaluation of this reservoir. ®istribution: 1 original, 4 copies, 5 CDs: Addressee ~~~ ~5~ ,.~,.~~~._T ..ate. _.__ Company: ConocoPhillips Alaska Inc. Location; Sec. 11-19N/20W `r Well: Intrepid 2 ~~_~- ~. ~~~-~ ~~,~, Field: Barrow-South PF.SEIIVOIN IIPTIMIfA'fION Rotary Sidewall Core Analysis Results File No.: 57111-107443 API No.: 50-023-20036 Date: 7\18\2007 Sample Depth Rec Perm. Porosity Fluid Saturation Grain Sample Method Description Number ft in Kair and % Oil % Water % O/W Ratio :Total % Den /cc Wt. 1 3119.0 1.6 0.2 12.9 0.9 82.2 0.01 83.0 2.65 28.4 1 Sst tan vfgr vslty sit strtcs biotrb I sm no vis nor 2 3120.0 1.6 0.5 14.6 4.7 77.0 0.06 81.8 2.65 28.2 1 Sst lbrn vfgr vslty slt strks biotrb m stn gld flor 3 * 3121.0 1.7 0.5 14.2 0.7 25.5 0.03 26.2 2.66 28.7 1 Sst tan vfgr vslty slt strks biotrb 1 stn no vis flor 4 3122.0 1.5 25.2 I8.5 5.0 82.8 0.06 87.8 2.66 26.4 1 Sst lbrn vfgr vslty m stn gld flor 5 3123.0 1.7 39.1 19.5 0.6 94.5 0.01 95.1 2.66 27.8 1 Sst tan of-fgr slty slt strks 1 stn no vis flor t 6 3124.0 1.5 164.0 22.4 0.7 93.2 0:01 93.8 2.65 26.4 1 Sst tan vf--fgr slty 1 stn no vis flor 7 3125.0 1.1 161.9 23.6 0.0 93.3 0.00 93.3 2.65 19.8 1 Sst gry vf--fgr slty no stn no flor 8 3126.0 1.2 148.4 22.5 0.0 97.4 0.00 97.4 2.65 24.6 1 Sst gry vfgr slty no stn no flor 9 3127.0 1.6 29.6 15.4 0.0 93.2 0.00 93.2 2.72 25.9 1 Sst gry vfgr vslty sh lams pyr no stn no flor 10 3128.0 1.6 92.3 22.2 0.0 92.9 0.00 92.9 2.65 26.0 1 Sst gry vf--fgr slty no stn no flor * Low fluid content of this sample can be attributed to the bottle containing this sample having been broken during shipping. For Method Definitions See Procedures Page Company: ConocoPhillips Alaska Inc. ,~ . Well: Intrepid 2 ` Field: Barrow-South Cure Lab ACSEAVAIR OPTIMIZATION File No.: 57111-107443 API No.: 50-023-20036 Date: ?\18\2007 Core Type: Sidewall Cores CORE ANALYSIS PROCEDURES AND CONDITIONS Procedure (1) Procedure (2) Procedure (3) Procedure (4) Sampling. Method Rotary Percussion Percussion Percussion Drill Coolant N/A N/A N/A N/A Jacket Material N/A None N/A None Saturation Method Dean Stark (Toluene) Dean Stark (Toluene) Retort Dean Stark (Toluene) Porosity Method Grain Volume Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Pore Vol Boyle's Law (Helium) Pore Volume Boyle's Law (Helium) Bulk Vol-Grain Vol Summation Of Fluids Bulk Vol-Grain Vol Bulk Volume pore Vol + Grain Vol Mercury Displacement Mercury Displacement Mercury Displacement Permeability Method Air Air Em irical Em irical Common Conditions Sleeved Sample Seating Pressure: N/A Confining Pressure Pore Vol & Permeability: 400 Samples Dried At 235 Degrees Fahrenheit Additional Extraction by Soxhlet with Methylene Chloride/Methanol Oil Density used in Calculation: 0.97g/cc • ~t~r"I+~+C+U~11~~1 S TRANSMITTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7~' Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Intrepid 2 Permit: 206-190 DATE: 07/12/2007 Intrepid 2 500232003600 Core Analysis Results; Intrepid #2, Barrow South Field. North Slope, Alaska; CL57111-107239CP; Care Labs, Bakersfiels, CA. Please sign, scan signed transmittal, save as .pdf format and e-mail to address below, Or rfturn to CPAI via mail within 48 hours of receipt. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: Andy A ou, PAI ogist / I /' Receipt: Date: / ~ ~` e.`~ ~1 U rJ~ '11Pi;Jf ~~+~ GfS-Technical Data Management I ConocoPhi/lips I Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.LemkeCa7Conocop fillips com ~o~ -I}9o ~ ~5a~! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 206-180 ConocoPhitlips Alaska, Inc. Development ^ Exploratory ~ 7. Well Name: Intrepid #2 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-023-20036-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal Q or Continuation ^ or Final ^ 307-131 4/17/2007 Exploration 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 26.5'' 26.5 totals (bbls): 2007 / 2nd 2007 100 0 2107 3 4/15/2007 4/18/2007 Intrepid #2 2007 / 3rd 2007 / 4th 2008 / 1st Total Ending Report is due on the 20th volume 2007 100 26.5 2133.5 3 (bbls): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *annular leak-off tests and correct to the best of my knowledge. I hereby certify that the foregoing is tr ue ~ j \ ''s-~ - ~ D Si t t ~ ~'~ ra 7 - gna ure: a e: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ! • +~a~nc~cilli s ~ ~©~ -i~o TRANSMITTAL ~-~Sa6~ CONF/DENTIAL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`h Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Intrepid 2 Permit: 206-190 DATE: 07/02/2007 Hand dellve Intrepid 2 500232003600 ~CDROM and paper report Halliburton LAS LWD data; LWD digital logs 0-3550' md; final directional surveys. Logging run 4/12/2007. 1 hardcopy directional survey report. Color Log prints Halliburton Dual Gamma/Comp Neutron Porosity/AZ LithoDensity (MD); Halliburton Dual Gamma/EWR-Phase 4/Rate of Penetration (MD) Schlumberger log data CDROM Schlumberger - LDWG OH edits of Wireline data (TIF files)&PDS color images of final edits Field PDS files for MDT-DSI-MSCT; Field DLIS and MDT data; logging date 4/11/2007; Job ref 11628999 Color Log prints Schlumberger- DSI/Shear and Comprssional ;logged 4/12/2007; run 1; 1300-3550' and Schlumberger- MSCT/Core report; logged 4/12/2007; run 1; 1300-3500' and Schlumberger- MDT/Pressure Sample report ;logged 4/13/2007; run 1; 3124-3160' and Schlumberger- PEX: AIT-TLD-CNL; MCFUGR; logged 4/12/2007; run 1; 1300-3512' and Please sign, scan signed transmittal, save as .pdf format and a-mail to address below. Or return to CPAI via mail within 48 hours of i receipt. iTo all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: Andy reou CP logi t Receipt: Date: ~G~~~ V ,~~~. Q ~ 2~~7 GIS-Technical Data Management I ConocoPhillips I A,~I~J;i~~i~~: ~$!~47 Sandra.D.LemkeC~Conocophillips.com Anchorage ~+C~t'1~~~'11~~1 5 ~~ ~~`./~ 2 (9~ ?t g~:'I ,g1aSk,~ ll/j ~ Gas TRANSMITTAL ~®ns ~nchnra0x ~r,ion CDNF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7"' Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Intrepid 2 Permit: 206-190 DATE: 06/27/2007 Hand delive Tr mi d: Intrepid 2 500232003600 CDROM Halliburton LAS LWD data; LWD digital logs 0-3550' md; final directional surveys. Logging run 4/12/2007. Color Log prints Halliburton Dual Gamma/Comp Neutron Porosity/AZ LithoDensity (MD) Halliburton Dual Gamma/EWR-Phase 4/Rate of Penetration (MD) Please check aff each item as received, promptly sign and return the transmittal to address I~elow. To all data reci Tents: Al/data is confidential until State ofA C ' release date CC: Andy Andreou, CPAI Geologist ~uN 2 8 Z007 Receipt: Date: alaska Oil & Gas Cons. Comr~~issicn ~~~~i~~~~. GIS-Technical Data Management (Co~illips I Anchorage, A/aska I Ph: 907,265.6947 Sandra.D,Lemke~Conocophil/i,~s com • ~ ~ C~n~coP~illip~ RECEIVED TRANSMITTAL SUN ~ ~ 2007 CONFIDENT/AL DATA Alaska Qil $ G~5 ions. Cammissiaa FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken Anchorage ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7~' Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Intrepid 2 Permit: 206-190 DATE: 06/18/2007 Hand delive Tr n m' Intrepid 2 500232003600 Report and CDROM Final Well Report, Mudlogging Data, Intrepid #Z; Epoch, report date:4/18/2007. Contents, equipment and crew, well details, geological data, pressure/formation strength data, Drilling data, daily reports, Color log prints: Formation logs MD; LWD lithology MD; gas ratio MD; drilling dynamics MD; Pore pressure MD ~ Dl~ ~ 6 ~ ~/ ~t~~ -,_~ I p~ ~ r5a~~ Please check off each item as received, promptly sign and return the transmittal to address below. To al! data reci ients• A//data is confidentia/until State ofAlaska desi Hated AOGCC release date CC: Andy Andre u CPAI Geologist Receipt: ~~ ,C~ _ Date: ~~ ~~ ~.~ ~~~~~- GIS-Technical Data Management ~ ConocoPhillips ~ Anchorage, Alaska ~ Ph,• 907.165,6947 Sandra.D.LemkeCa)Conoc~hi/lips com FW: Intrepid #2 Cut-off Subject: FW: Intrepid #2 Cut-off From: "Brassfield, Tom J" <TOM.J.Brasfield@conocophillips.com> Date: Tue, 29 May 2007 15:06:01 -0800 To: steve_davies@admin.state.ak.us CC: tom_maunder@admin.state.ak.us, "Alvord, Chip" <Chip.Alvord@conocophillips.com>, "Allsup-Drake, Sharon K" <Sharon.K.AI/sup-Drake@conocophill ips.com> Steve, here are the final reports for the P&A at Intrepid. We started a demob report after releasing the rig at 2400 hrs on 4/18/07! The Rig Supervisor (Donnie ~utrick) sent the attached pictures to Jim on 4/23. Thanks, Tom «4 19 07 Drilling Demob Report.pdf» «4 22 07 Drilling Demob Report.pdf» «4 23 Drilling Demob Report.pdf» -----Original Message----- From: Kuukpik 5 Company man Sent: Monday, April 23, 2007 1:00 PM To: 'jim_regg@admin.state.ak.us' Cc: Brassfield, Tom J Subject: Intrepid #2 Cut-off «Csg Cut-off.JPG» «ID Plate.JPG» «Csg cut-off 1.JPG» .~.,. ~- °~ . ,., ~. o„ ~.~, ~~,~~ a~ ;. ~~ ;:: • U :."'' .~,~ ~ ,~ I of 4 5/29/2007 3: 18 PM ;„ .~ '. ,r , rte.. FW: Intrepid #2 Cut-off ' _ ..-. -~ ~~ ~ .~~ w ..: .: -~- ~_ M ~,~ _. ~ ,~„ ,~ 4 ~ i %' _~~._ ~ .t w. ~ e ~~ -~ h ~ ~ iiw !f ~; y'J x- zy ~..wM1 ~ - y'rly. ~ ~ K ~- '~ '~ . 4,.e ` ~ ~ ""r° S~r, q`tr'. ~: ~r y -. f ~ ~ ~ ~~ ~~ { -`~~ ~' r f ~ ~~;~ ~~. ~r. •I • ~ of 4 ~~ ~".~ F_ ~ry ~~ .._ TI~~ ;~y X00? ;:18 PM FW: Intrepid #2 Cut-off ~ of 4 ~~ .. ~. ~.~ ~~a ..,~*.* ~ a~ti d s~ d ~"r" 5~ ~ i +y.~ ~ ~,aa~ 1 > r , S J' r" ~~ ~ ~NM=.~..~Y Irc • • 5/29/2007 3:18 PM Intrepid #2 Cut-off Content-Description: 4 19 07 Drilling Demob Report.pdf 419 07 Drilling Demob Report.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 4 22 07 Drilling Demob Report.pdf 4 22 07 Drilling Demob Report.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 4 23 Drilling Demob Report.pdf 4 23 Drilling Demob Report.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: Csg Cut-off.JPG Csg Cut-off.JPG Content-Type: image/jpeg Content-Encoding: base64 Content-Description: ID P1ate.JPG ID P1ate.JPG Content-Type: image/jpeg Content-Encoding: base64 Content-Description: Csg cut-off I.JPG Csg cut-off 1.JPG Content-Type: image/jpeg Content-Encoding: base64 • 4 of 4 5/29/2007 3:18 PM ConotoPhillips May 17, LUU7 G. C. Alvord Exploration Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Commissioner ~~'~'~~ State of Alaska Alaska Oil & Gas Conservation Commission i~AY 1 $ 2007 333 West 7th Avenue Suite 100 ~~laslca Oil & Gas Cons. Commission Anchorage, Alaska 99501 Anchorage Subject: Well Completion Report for Intrepid 2 (206-190 / 307-130) Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits this Well Completion Report for the recent work on the exploration well Intrepid 2. The attachments include a summary of the daily drilling operations, a directional survey, an as-built and a memo of formation tops. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~- G. C. Alvord Exploration Team Leader CPAI Drilling GCA/skad 1'S Ct"d C l V C V STATE OF ALASKA ~ MAY ~ S 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ~iaska Oil & Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT AND t~g~ 1a. Well Status: Oil ^ Gas Plugged / Abandoned / Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^ Exploratory ^/ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., n2 ~g!„pp1 orAband.: April((~/ee//y.~, 2007.`6,, 12. Permit to Drill Number: 206-190 / 307-130 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 1, 2007 13. API Number: 50-023-20036-00 4a. Location of Well (Governmental Section): Surface: 2406' FSL, 1750' FEL, Sec. 11, T19N, R20W, UM ` 7. Date TD Reached: April 12, 2007 14. Well Name and Number: Intrepid 2 Top of Productive Horizon: 2406' FSL, 1750' FEL, Sec. 11, T19N, R20W, UM 8. KB (ft above MSL): 57' AMSL Ground (ft MSL): 36' 15. Field/Pool(s): Total Depth: 2406' FSL, 1750' FEL, Sec. 11, T19N, R20W, UM 9. Plug Back Depth (MD + ND): surface Exploration 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface: x- 613138. y- 6221408 • Zone- 6 10. Total Depth (MD + ND): 3550' MD / 3550' TVD 16. Property Designation: NSB 1-2 Gas Lease, ASRC Sw-2 Oil Lease TPI: x- 613138 y- 6221408 Zone- 6 Total Depth: x- 613138 - 6221408 Zone- 6 11. SSSV Depth (MD + ND): none 17. Land Use Perrnit: NSB 07-093 1 S. Directional Survey: Yes 0 No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1000' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Dipole sonic / GR /platform express / MSCT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 63# B 20' 100' 20' 100' 24" 200 sx AS 1 9.625" 40# L-80 20' 1372' 20' 1372' 12.25" 89 bbls AS LITE, 43 bbls AS 1 7" 26# L-80 20' 3516' • 20' 3516' 8.75" 4o bbls Class G 23. Open to production or injection? Yes No Q If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET none none no perforations - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED surface to 300' (surface plug) 73 sx AS 1 surface to 1850' (annulus) 86 bbls ASLite, 43.9 bbls AS 1 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure ~ Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes / ~ No Sidewall Cores Acquired? Yes / ~ No ^ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~~~~r^~T TO BE SENT UNDER SEPARATE COVER ~~t}~Q 4=lEG ~~ MAY ~ ~ 2~~7 _Q_ i Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ORIGINAL ~'' r ~~ .~ s-29.07 .~~~ ~/mil ~ ~, 28. GEOLOGIC MARKERS (List all formations and marker encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No . If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1000' 1000' needed, and submit detailed test information per 20 AAC 25.071. Torok Formation 395' 395' HRZ 2665' 2665' Top Walakpa Sands 3119' 3119' LCU 3164' 3164' Top Miluveach 3164' 3164' Top Jurassic 3258' 3258' N/A Formation at total depth: Jurassic 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, As-Built, memo of formation tops 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brasfield @ 265-6377 Printed Name C ~ Alvord Title: Exploration Team Leader S~ (' d r2 ~ ~ .o 7 Signature • Phone uS-~ f; !Z O Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on ail types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~J ~t~l'1t3C ~'~11~~1 S Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: May 15, 2007 Intrepid 2 Formation Tops Greg Wilson CpNFIDENTIAL Staff Geologist ConocoPhillips Alaska, Inc. 263-4748 Intrepid Operations File The following are formation tops for Intrepid 2 as picked from MWD and wireline logs: Formation, Marker, or Casing Shoe Measured Depth (MD) Nanushuk Formation Formation below surface surficial deposits Base Permafrost (ice-bearing) Estimated 1000' MD (No ice-bearing /resistive intervals) Top Torok 395' MD Top HRZ 2665' MD Top Walakpa Sandstone 3119' MD Lower Cretaceous Unconformity (LCU) 3164' MD Top Miluveach 3164' MD Top Jurassic 3258" MD Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. __ __ Date: 5/3/2007 Time: 13:42:34 i':~~~~: 1 Field: ASP Zone $ Co -ordinate(NE}Reference: WelLtntrepid #2. True Nor th. Sitc: Intrepid Ve rtical('PVD) Re ference: Intrepid #2: 56-9 Well: Intrepid #2 Section (VS) Reference: Well (Q~~ON,C-OO E,346.94Azi) Wellpath: Intrepid #2 __ Su rccg Calculation _ __ 11cfh«t: Minimum Curvat ure Dba Grade ___ Field: ASP Zone 6 NSB 1-2 Gas Lease; ASRC SW-2 Oil Lease I ~ Map System:US State Plane Coordinate System 1927 ~ Geo Datum: NAD27 (Clarke 1866) Map Zone: Coordinate Sy Alaska, Zone 6 stem: Well Centre ~ys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: Intrepid #2 Slot Name: Well Position: +N/-S -7.85 ft Northing: 6221408.20 ft Latitude: 71 0 49.380 N I +E/-W 3.18 ft Fastin g : 613138.30 ft Longitude: 157 3 2.149 W - Position Uncertainty: 0.00 ft - Wellpath: Intrepid #2 Drilled From: Well Ref. Point 500232003600 Tie-on Depth: 20.50 ft Current Datum: Intrepid #2: Height 56.90 ft Above System Datum: Mean Sea Level i Magnetic Data: 3/30/2007 Declination: 19.76 deg t Field Strength: 57403 nT Mag Dip Angl e: 80.57 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ ft ft ft deg 0.00 0.00 0.00 _ 346.94 Survey Program for Definitive Wellpath ~ Date: 12/13/2006 Validated: No V ersion: 3 Actual From To Survey Toolcode Tool Name ft ft J ~, 173.85 3468.47 - Intrepid #2 (173.85-3468.47) _ _ MWD MWD _Standard Survey __ _ _ .. ivID Incl Azim TVD Sys "CVD ~/5 EIW blapN Ntap'E Toal ft deg deg ft ft ft ft ft ft 20.50 0.00 0.00 20.50 -36.40 0.00 0.00 6221408.20 613138.30 • TIE LINE 173.85 0.30 21.20 173.85 116.95 0.37 0.15 6221408.58 613138.44 MWD 296.84 0.59 328.89 296.84 239.94 1.22 -0.07 6221409.42 613138.22 MWD 407.75 0.70 358.33 407.74 350.84 2.38 -0.38 6221410.58 613137.88 MWD 540.56 0.66 4.23 540.54 483.64 3.96 -0.35 6221412.15 613137.89 MWD ~~ 665.46 0.70 341.15 665.43 608.53 5.40 -0.54 6221413.59 613137.67 MWD 788.68 0.46 324.15 788.64 731.74 6.51 -1.07 6221414.69 613137.12 MWD 914.36 0.40 334.09 914.32 857.42 7.31 -1.56 6221415.49 613136.62 MWD 1040.65 0.74 330.83 1040.60 983.70 8.42 -2.15 6221416.59 613136.02 MWD 1166.63 0.79 313.85 1166.57 1109.67 9.73 -3.17 6221417.88 613134.97 MWD 1282.14 0.46 309.13 1282.08 1225.18 10.58 -4.11 6221418.71 613134.03 MWD 1514.33 0.84 291.19 1514.25 1457.35 11.78 -6.42 6221419.88 613131.70 MWD 1662.40 0.75 288.14 1662.31 1605.41 12.48 -8.35 6221420.54 613129.76 MWD 1786.39 0.70 290.24 1786.29 1729.39 12.99 -9.83 6221421.03 613128.27 MWD 1974.02 0.36 306.27 1973.91 1917.01 13.74 -11.38 6221421.75 613126.70 MWD 2098.63 0.14 31.77 2098.52 2041.62 14.10 -11.62 6221422.11 613126.46 MWD I 2226.40 0.45 7.06 2226.29 2169.39 14.73 -11.47 6221422.74 613126.60 MWD 2349.10 0.58 27.19 2348.98 2292.08 15.76 -11.13 6221423.78 613126.92 MWD 2484.76 0.53 22.13 2484.64 2427.74 16.95 -10.58 6221424.98 613127.45 MWD 2609.16 0.62 338.64 2609.03 2552.13 18.11 -10.61 6221426.14 613127.41 MWD 2729.32 0.82 27.37 2729.18 2672.28 19.48 -10.45 6221427.51 613127.55 MWD ~ ~ 2886.73 0.33 358.81 2886.58 , 2829.68 20.93 -9.94 6221428.97 613128.03 MWD ~ 2981.45 0.68 18.61 2981.30 2924.40 21.74 -9.77 6221429.78 613128.19 MWD 3109.13 0.81 14.88 3108.97 3052.07 23.33 -9.30 6221431.38 613128.64 MWD 3295.89 1.05 13.88 3295.70 3238.80 26.26 -8.55 6221434.32 613129.34 MWD 3358.26 1.21 ~ 18.77 3358.06 3301.16 27.44 -8.20 6221435.51 613129.67 MWD ' 3468.47 1.06 14.47 3468.25 3411.35 29.53 -7.57 6221437.61 613130.27 MWD . 3550.00 1.06 14.47 3549.77. 3492.87 30.99 -7.19 6221439.07 613130.62 PROJECTED to TD • Operations Summary INTREPID 2 r / rPrimary Job Type Job Category AFE / RFE I Start Date Spud Date i End Date ,DRILLING ORIGINAL _ DRILLING ', 10148267 3/16/2007 4!1/2007 4/19/2007 ors r. ~i,a inn ~~~~i ~ri;ir~ ~L~~t Date Ph,-+se ~YrfT ~~_ Op C~x:~- ~ipSulr Q,de ~-cnm Fer3n;;n cur lnr) i1~4:6! ffW,6i PR~gmss (tt1 3/2412007 MIRU 00:00 MOVERURD Set rig floor on sub. install outside 24.OOi section of mast. Set drawworks & bold down same. String tuggers. Set pre-mix tanks and hopper buildings. Set in boilers, suction pit, parts house, hopper room, etc. Mechanic worked on hot air heater. Installing motor on mud ' 1 j ;pump #2. Set volume pit & centrifuge ~ ~ ,building. Install monkey board onto derrick. j ' ~ 3/25/2007 MIRU 100:00 MOVE RURD Raise derrick. Put top drive on floor 24.OOi, and raise same. Set shakers, off-driller side doghouse. Set water tank, change ;room, drillers dog house. Set wind ~ ~~ ~~ ~ ~ walls. Finished truck shop. I I ~ '. ~ Finished with Lynden Herc. Released 'from Intrepid airstrip @ approximately ~ 10pm, 03/25. 3/26/2007 MIRU i 00:00 ;MOVE RURD Install lower front wind walls. Too windy', 24.00 'i to put cattle chute/pipe shed together. ~ i Hook up main hydraulic lines, flow it '.lines. Install beaver slide, new ~ centrifuge pit, hook up lines in power ~ ~ I module. Work on mu dpump, install ~ dewater buildings, start stuffing cracks. ~, I, ', Set poor boy degasser, assist hooking ~ III ', up electrical. i ~ 3/26/2007 MIRU 00:00 MOVE ~ ~ ' i 13/27/2007 MIRU 00:00 I MOVE j RU & set cattle chute. Fill hot well & 24.00 i I 1 ~ it start boiler. Finish setting pipe shed. ~ Hook up hyd, elec, & steam lines. Run drawworks. Spot drl line & pull line to ~~ ~~ ~ floor. Offload rolligons. ~I 3/28/2007 MIRU 100:00 ',MOVE RURD String up tuggers and blocks, set water i 6.00 I~ tank, RU mud pits. 3/28/2007 MIRU06:00 ' MOVE !.RURD PU top drive, prep and scope derrick, 6.00 1 set fuel tank, set fuel traansfer house, ~ spot pipe shed and sub heaters. 3/28/2007 MIRU 12:00 I MOVE RURD Hang torque tube, change out hose in 6.001, steam heater, remove top drive stand I from rig floor, hook up pit room lines, ', i plung in power to pipe shed, install !~ I I ;derrick board dog house. I~3/28/2007 MIRU .18:00 MOVE RURD ~RU to drive service loo RD bridle 6.00 p P' I i line, LD herculite and mats under drawworks, continue hooking up pump room lines, start to clean out ODS tool ' ~ ~ house. ~3l29/2007 ~ MIRU 00:00 MOVE RURD I Work on service loop, RU rig floor, RU ' 12.00 ~ i ' !,pits and injection tank, pull electrical ' i ~ lines, work on pump #2, build berms for I i ~ light plants, spot tank farm, hook up I ~ water lines. ~~ 13/29/2007 MIRU 112:00 MOVE RURD Finish rigging up bails and elevators, 4.00 'finish rigging up service loop, RU poor ~ i boy degasser, RU lines to #2 ~I I I !centrifuge, hang rig tongs and pipe i ~ (spinner. Page 1/7 Report Printed: 5/7/2007 • -_ !( ! ~, ~. Operations Summary INTREPID 2 ,it Date ~'hasF suit Tlu~e U;, .ode OpSuh C: <la ComMOperaGon 'lur ~rsl rt!k6? (ftF.Bi P _aress (K) 3/29/2007 MIRU 16:00 MOVE , RURD Set starting head, PU Hydril, set 4.00 diverter spool and knife valve in cellar. 3/29/2007 MIRU 20:00 MOVE ' RURD ! Nipple up diverter. 4.00 il j 3/30/2007 MIRU 00:00 MOVE ! RURD ~ Nippleupdivertertostartinghead. 3.00 l I 3/30/2007 MIRU 03:00 MOVE ~' RURD ~ PU and stand back 60 jts of drill pipe. 3.00 3/30/2007 MIRU ; 06:00 MOVE RURD RU portable HPU to BOP rams, set in 6.00 (! diverter line section, install valve caps '; on mud pumps, ready pits for water. '.3/30/2007 MIRU ~ 12:00 ! MOVE RURD Align diverter system I 3.00' ,3/30/2007 MIRU 1 15:00 (, MOVE RURD i RU mud manifold, RU Mud Line, Test 9.00', I , ' run #2 pump ~ 1, I! '~~ 3/31/2007 ~I MIRU 00:00 MOVE i RURD Continue to work on HPU #2. Build 6.00 I ~ mud volume. Build mud product ~ I~ containment. 3/31/2007 !MIRU 06:00 MOVE ~I RURD ! Change out saver sub and set TD 2.00 ( aorque. 3/31/2007 MIRU 08:00 MOVE RURD '; Continue mixing mud. Run Pason 4.00 wiring. Load pipe shed with HWDP. ! I 'i ( Test HPU #2 and MP #1. Change out I I swab and liner on #2 pump. 1 ,3/31!2007 MIRU 1 12:00 MOVE RURD Work on counter balance system. Test 3.001 ~ ~ mud line to 4000 psi, blow down TD '. ~ ', ~ ~ amd mud line. 1 ',3/31/2007 MIRU 15:00 MOVE ; RURD PU HWDP and stand back in derrick. i 2.00 ~ ~ ,3/31/2007 ~, MIRU 17:00 MOVE ' RURD Function test diverter. AOGCC waived 1.00 ~ I I I I ; witness of test. I I 3/31/2007 !MIRU 18:00 MOVE RURD ; Continue to mix spud mud. Clean rig 3.00 floor. Gather BHA tools. 3/31/2007 ':MIRU 21:00 MOVE RURD MU BHA, Held diverter drill. Fill hole 3.00 SURFAC 4/1/2007 00:00 DRILL DRLG !Rig Accepted @ OO:OOhrs. Check 1.50 93.0 257.01 164.00( ( ~ I ~ (surface equipment. ~ i 4/1/2007SURFAC 01:30 i DRILL DRLG ~ RIH with rotary BHA tag at 93'. Drill . 11.OO f 93.0 257.0 164.00 ' ~ from 93' to 25T. I I 4/1/2007 SURFAC 112:30 DRILL I CIRC Circulate and condition mud. 0.501 93.0 257.0 164.00 4/1/2007 SURFAC 13:00 DRILL TRIP Pump out of hole. 1.00 ~ 93.0 ~ 257.0 164.00 4/1/2007 SURFAC 1 14:00 DRILL I pULD LD rotary BHA 1.00 93.Oj 257.0 164.00 4/1/2007 SURFAC 115:00 DRILL !. PULD PU BHA 7.50 93.01, 257.0 164.00 1.4/1/2007 SURFAC 22:30 DRILL PULD Plug in MWD. Test MWD. j 1.00 93.OI 257.0 164.00 ',4/1/2007 SURFAC 23:30 DRILL PULD ; Break out from top drive and blow ~ 0.50 93.0 257.0 164.00 I ' down same. 14/2/2007 (SURFAC 00:00 DRILL DRLG ! Lubricate rig, tighten swivel packing. 0.50 251.0 1,250.0; 999.00, '14/2/2007 ;SURFAC 00:30 DRILL PULD '(Continue MU BHA. Load sources. 4.50 251.0( 1,250.0; 999.001 4/2/2007 !SURFAC 05:00 DRILL CIRC Circulate and condition mud. RIH to 0.5011 251.0( 1,250.01 999.00( ' I 251'. ( ' 4/2/2007 ~ SURFAC 05:30 i DRILL 1, DRLG Drill from 251' to 580' 6.0011 251.01 1,250.0 999.00 I Up Wt: 46k ~ Dn Wt: 48k 1 Rot Wt: 48k i ~ ( ~ 4/2!2007 SURFAC 11:30 DRILL DRLG Drill from 580'to 1250'. ! 12.00 251.0 1,250.0 999.00 4/3/2007 SURFAC ',00:00 DRILL DRLG (Drill from 1250'to 1389' j 2.50 1,250.0 1,389.0 139.00 4/3/2007 SURFAC I ',.02:30 DRILL CIRC jCondition mud and circulate. ~ 1.00 1,250.0 1,389.0 1 139.00( i 4/3/2007 SURFAC 103:30 DRILL TRIP IPOOHfrom 1389'to 1357. 0.50 1,250.0 1,389.0 1 139.001 ';4/3/2007 ,,SURFAC 04:00 DRILL (TRIP (Pump out of hole from 1357 to 1024'. 2.00 1 1,250.0 1,389.0 139.00 1 ' ( I Packed off. Could not get returns. 1 1 1 '4/3/2007 :SURFAC 06:00 DRILL ;TRIP Pump OOH from 1024'to BHA. 9.50 1 1,250.0 ( 1,389.0 139.00 ,14/3/2007 ..!SURFAC 15:30 (DRILL ;PULD Start toLDBHA. Pulling tight when 8.50 1 1,250.0 1 1,389.0 139.00 1 ' ~ coming out of the hole. PuH sources, j ' 1 download MWD. ', 4/4/2007 SURFAC 00:00 RIGMNT ~OTHR __ Ii Clear floor and lubricate rig _ I 1.00 1 389.0 '1 1,389.0 ', 0.001 _ _ _ Page 2/7 Report Printed: Sl7/20071 • ~ ~ f Operations Summary INTREPID 2 _ a't Cata d/4/2007 4/4/2007 ', 4/4/2007 4/4/2007 i 4/4/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/5/2007 4/6/2007 4/6/2007 4/6/2007 4/6/2007 4/6/2007 4/6/2007 4/6/2007 4/6/2007 Ft+. ~r~ ,tar Trne Cp t ..,de 1p5~ 1~ Code SURFAC ', 01:00 IDRILL i REAM ISURFAC 16:30 IDRILL CIRC SURFAC 18:30 ;DRILL TRIP ISURFAC 20:30 IDRILL PULD SURFAC 23:30 CASING OTHR SURFAC 00:00 CASING RNCS SURFAC 03:00 (CASING . RNCS SURFAC 06:00 CASING , RNCS SURFAC 1 08:30 CASING ' RNCS SURFAC ; 09:00 CASING i CIRC SURFAC ! 10:30 CASING CIRC ISURFAC 1 11:00 CASING OTHR ~~ISURFAC '; 12:30 CASING I OTHR SURFAC 15:30 CASING OTHR .SURFAC 16:30 CASING OTHR SURFAC SURFAC SURFAC SURFAC PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 18:30 19:00 00:00 101:00 02:00 02:30 03:00 06:00 08:00 :12:00 CASING CASING CASING CASING DRILL DRILL DRILL DRILL WELCTL WELCTL WELCTL WELCTL 4/6/2007 PROD1 21:00 4/7/2007 PROD1 00:00 4/7/2007 PROD1 05:00 4/7/2007 iiPROD1 05:30 4/7/2007 PROD1 06:00 4/7/2007 ,PROD1 12:00 4/7/2007 1 PROD 1 ~~ 13:30 WELCTL WELCTL DRILL DRILL DRILL DRILL DRILL OTHR CIRC OTHR OTHR DRLG DRLG DRLG DRLG NUND NUND NUND NUND NUND BOPE DRLG PULD PULD PULD DHEO ".omn [ri alior, Make up BHA, ream to circ and ream to btm Circ hole clean/pump slug. POH to jars Lay Down BHA ~'~Clean floor UD misc handling subs, li UD rig tongs, prepare to run casing. Prep to run casing 'Run 9-5/8" casing to 450' stacked out RU and circulate Cont'd to run casing from 460' to 1379. (wash down jt #11) RD/ GBR & RU to circulate Circ and condition mu for cement RD circ lin RU false rotary MU XO's pup 8~ stab in tools TIH w/ stab-in assembly to 1237 Space out to 1288 RU circ and (cementing equipment PJSM on cement job. test lines to 2300 ipsi, pump 10 bbls CW100, 25 bbls mud ,push, 89 bbls lead, 43 bbls tail, '.displace with 10 bbls. full returns 'throughtjob CIP @ 18:30 hrs RD cmt head, PU 60' screw into TD Circ/ wash out knife valve and diverter/ Blow down. POOH LD stab assy. ~i Finish LD Stab in tool. Back out i landing joint. LD same. Clear and clean rig floor. RD Schlumberger cement line in cellar. Pull mouse hole and rotary table. ',Nipple down surface stack. ', NU starting head and test to 1000 psi i Install Hydril, double gate, mud cross, (single gate and annulus valves. I Continue to hammer up BOP's connect choke and kill line. Install rotary table, (floor plates, PU drilling nipple, install and MU flow line, Turnbuckles, high pressure hoses, rd kill side check iivalves. RU accumulator hoses, panic ,lines. L MU test jt, test plug, attempt to set ',plug, RILDS. I Test BOPE. Set wear bushing. Re-install floor mats. Mouse hole & ~Ielevators. Make up BHA. MU BHA. Up load smart tools and sources to 500' con't MU BHA. PU DC, Jars, DC 1 std HWDP. Surface test MWD @ 450 GPM/1000 ;psi. OK. Blow down TD. ~I Dcuth °larl C~.ir ihrai (RVC6i 15.50 1,389.0 2.OO 1,389.0 2.001 1,389.0 3.00 1,389.0 0.50 1,389.0 3.00 1,388.0 3.00 1,388.0 2.50 1,388.0 0.50 1,388.0 1.50 1,388.0 0.50 1,388.0 1.50 1,388.0 3.00( 1,388.0 1.OOf 1,388.0 2.001 1,388.0 0.50 1.50 3.00 0.50 1.00 1,388 1,388 1,388 1,388 1,388 1.00 0.50 0.50 3.00 2.00 4.00 9.00 3.00! 5.00 0.50 0.50 6.00 1.50 1.501 1,388 1,388 1,388 1,388 1,388 1,388 1,388. 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 I_~-~!!h nd ((tV~B' 1,389.0 1,389.0 1,389.0 1,389.0 1,389.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388.0 1,388 1,388 1,388 1,388 1,388 1,388 1,388 1,388 1,388 1,388 1,388 1,388. 1,388.0 1,520.0 1,520.0 1,520.0 1,520.0 1,520.0 1,520.0 C c:- ~. r _. 0.01 O.Oi O.Oi O.Oi O.Oi O.Oi O.Oi O.Oi O.Oi O.Oi O.Oi O.Oi O.Oi 0.0~ 0.0~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 264.00 264.00 264. Page 3/7 Report Printed: 5/7/20071 • • Operations Summary INTREPID 2 -;?ar Jato Fha>~ Stee Time Op C~x1o ~FSutrCad-- Comm/OPera..:n Dw (ft}~E- (ithRl Prour~ss fft) 4/7/2007 PROD1 '',15:00 DRILL TRIP TIH w/ HWDP from 468'to 1021'. Tag ~ 2.50 1,388.0 1,520.0 264.00 1 I cement at 1243'. CBU. Blow down TD. j ',4/7/2007 PROD1 17:30 DRILL DRLG Test 9-5/8" casing to 2500psi for 30 1.00 1,388.01 1,520.0 264.00 min. OK. Blow down choke/kill lines. 0 ,4/7/2007 PROD1 18:30 DRILL DRLG Drill cement from 1243'-1281'. Tag 1.00 1,388. 1,520.0 264.00 ~ float collar. 14/7/2007 PROD1 19:30 DRILL DRLG Drill out float equipment: 0.50 1,388.01 1,520.0 264.00 WOB 2k 30 RPM ~I 500 GPM ~, ~ 1000 psi ~ '4/7/2007 PROD1 120:00 ~i DRILL ! DRLG Drill cement from 1283' to 1410'. 1.00 1,388.0 1 1,520.01, 264.00; 1 i 1 , Displace mud to 9.2 ppg. i 4/7/2007 ~PROD1 121:00- DRILL ~IFIT 18 ppg EMW FIT. 9.2 ppg @ 640 psi. 0.50 ; 1,388.0 1,520.0 264.00 1 ,4!7/2007 PROD1 ,21:30 i DRILL (DRLG ~ Drillfrom1410'to1520'. 2.00' 1,388.0 1,520.0 264.001 14/8/2007 PROD1 !00:00 ' DRILL DRLG ' Drill from 1520'to2464' 14.00! , 1,520.0 2,647.0 2,254.00 14/8/2007 ! PROD1 14:00 ; DRILL CIRC ( Circulate hole clean. Pump 15 bbl hi 1.001 1,520.0 2,647.0 2,254.00 1 ' 1 vis sweep. 14/8/2007 I PROD1 15:00 1 DRILL TRIP ' Short trip to shoe from 2464'to 1335'. 2.50 1 1,520.0 2,647.0 2,254.00 Some tight spots. 4/8/2007 IPROD1 !,17:30 RIGMNT SVRG Service rig. i 0.50 1,520.01 2,647.0 2,254.00 4/8/2007 IIPROD1 1 18:00 DRILL TRIP TlHfrom1335'to2342' 1.00 1,520.0 2,647.0 2,254.00 4/8/2007 1 IIPROD1 19:00 DRILL REAM Precautionary ream from 2342' to , 1.00 ' 1,520.01 2,647.0 2,254.00 1 2464'. Circulate heavy mud around. 4/8/2007 PROD( 20:00 DRILL DRLG Drill from2464'to264T 4.00 1,520.0; 2,647.01 2,254.00 4/9/2007 PROD1 00:00 DRILL ',DRLG Drill 2647 to 2935' 6.00 2,647.01 1 2,647.0, 0.00; 4/9/2007 PROD1 06:00 DRILL DRLG Dri112935 to 3110 5.00 2,647.0 1 2,647.0. . O.OO 4/9/2007 PROD1 11:00 DRILL 'DRLG '! Time drill at 10'/hr for samples from 5.00 2,647.0 2,647.01 , 0.00; ~ 1 ~ 3110' to 3128' circ up samples (ART= ~ ~ ~ 1 ! 1.3)\ I 1 Up wt: 72k ~ 1 Dn wt: 74k I I 'Rot: 74k 14/9/2007 II 16:00 ~ PROD1 'DRILL DRLG ~ Short trip from 3128' to 1338' 3.50 ~ 2,647.0 2,647.0 0.00 4/9/2007 PROD1 1,19:30 DRILL DRLG ITIHfrom1338'to3045'. Taking 1.00 1 2,647.0 2,647.0 0.00 1 ' ' ~ weight. -15klbs 4/9/2007 ~! PROD1 ' 20:30 I DRILL DRLG Ream from 3045' to 3128' (Circulate ~ 1.00 2,647.0 2,647.0 0.00 1~ ~ ~ thick mud) 1 4/9/2007 'PROD1 ',21:30 !DRILL CIRC Circulate and condition. 1.00 2,647.0 2,647.0 0.00 ;4/9/2007 'pROD1 22:30 !,DRILL TRIP POOH from 3128'to 1715'. No 1.50 2,647.0 2,647.0 0.00 overpull. ~ i ADT: 1.3 hours Up wt: 78k ~ i I Dn wt: 78k ' it I ! Rot: 78k i i I 14/10/2007 PRODI 00:00 DRILL ~ITRIP '.,POOH from 1715'to MWD Nukes @ 2.50 3,128.0' 3,188.0 1 60.00 ~~ ' 77.27. 1 4/10/2007 PROD1 02:30 DRILL IITRIP Pull Nuke sources and download 2.50 3,128.0 3,188.0 60.00 1 SMART tools. 14/10/2007 PROD1 05:00 DRILL TRIP Finish POOH and L/D BHA 2.50 !, 3,128.0 3,188.0 60.00 14/10/2007 PROD1 07:30 (CORING PULD P/U coring assembly and M/U same. ~ 3.50 1, 3,128.0 3,188.0 60.00 114/10/2007 PROD1 11:00 ;CORING TRIP Continue P/U BHA and TIH to 2385'. 4.00 3,128.0 3,188.0 60.00 (Fill pipe @ shoe.) i 4/10/2007 PROD1 15:00 ',CORING OTHR (Service Rig. 0.50 1 3,128.0 3,188.0 60.00': 4/10/2007 PROD1 15:30 ;CORING TRIP Continue TIH f! 2385'to Core point @ ', 1.50 3,128.0 1 3,188.O j 60.00 1 I 1 3128'. ' ~ 14/10/2007 IPROD1 '117:00 (CORING (CIRC Circ and condition hole for coring. 2.00 11 3,128.0 ; 3,188.0 1 60.00 Page an • ~~ Operations Summary INTREPID 2 I~CI,~LH Pll,i_F ~JIJI~, IMP C~7~!~t]~F ~-)~~~t E: :.,. C° ~Ii.'llfll 1:t3~..a 4/10/2007 PROD1 ' 19:00 S CORING OTHR Cut 60' core f/3128' to 3188'. (10K overpull to free core.) 4/10/2007 lPROD1 X23:00 ': CORING CIRC Circ sample up, pump slug and blow down top drive. 4/11/2007 PROD1 100:00 ! CORING TRIP POOH f/ 3188' to coring assembly @ ' !, 61'. (5min per stand) 4/11/2007 IPRODI 105:30 ( CORING PULD Break off bit, UD adjusting head, pull inner core barrels and UD same. 4/11/2007 1PROD1 ~ii06:30 II CORING OTHR Monitor well and W.O.O. 4/11/2007 IPROD1 08:00 1 CORING PULD UD coring assembly. 4/11/2007 '1PROD1 1 09:00 DRILL PULD P/U BHA#6 and R.LH. T/ smart tools. (Up-Load) 4/11/2007 11PROD1 '111:00 DRILL TRIP ',, Continue M/U BHA#6 and TIH to 615'. 4/11/2007 ~~, PROD1 12:00 DRILL DHEO ! Surface test MWD/ 475 gpm @ 1125 ~~ ~ ! psi. (Blow down TD) 14/11/2007 PROD1 12:30 DRILL TRIP ; Continue TIH f/ 615' to 3128'. (Fill pipe @ shoe) :4/11/2007 PROD1 1115:00 DRILL CIRC ', Circulate and condition mud prior to 'I reaming out core hole. 4/11/2007 PROD1 16:00 DRILL I REAM I Ream f/ 3128' to 3188'. 14/11/2007 PROD1 117:00 DRILL !DRLG Drill f/ 3188' to 3507 1'14/12/2007 PROD1 1100:00 11 DRILL I DRLG Drill ahead f/ 3507 to TD @ 3550'. • '14/12/2007 PROD1 101:30 DRILL ',CIRC CIRC and COND mud (MW 9.8 ppg) 4/12/2007 PROD1 ,02:00 ; DRILL STRIP Short trip f/ 3550'to 3065' (12 K overpull f/ 3408' to 3371') RIH back to 1 TD @ 3550'. 4/12/2007 PROD1 '.04:00 DRILL ~iCIRC CIRC hole clean. 4/12/2007 PROD1 1,05:00 'DRILL TRIP POOH f/3550'to collars @ 376'. 4/12/2007 PROD1 '-09:00 ' DRILL OTHR Clean rig floor and PREP to L/D BHA. 4/12/2007 PROD1 09:30 ~ DRILL PULD UD BHA f/ colars @ 376'to MWD l telemetry HOC @ 96' (download smart ; tools) 4/12/2007 ~ PROD1 ',12:30 DRILL PULD UD smart tools, Mud motor and Bit. 4/12/2007 ! PROD1 ' 13:30 EVALFM RURD ' PJSM with SWS, P/U sheaves, R/U i l hogging tools and RIH with wireline run !,#1. 4/12/2007 ! PROD1 15:00 EVALFM OTHR , 1 Run dipole sonic log. 4/12/2007 PROD1 i 18:00 EVALFM RURD ~ MU logging tools for run #2. 4/12/2007 ; PROD1 19:00 EVALFM OTHR Run platform express log. 4/12/2007 i PROD1 i 21:30 i EVALFM i RURD MU logging tools for run#3. 4/12/2007 PROD1 122:30 'EVALFM ~ OTHR POOH for mechanilcal sidewall core tool failure. 4/12/2007 PROD1 23:30 EVALFM !:RURD M/U logging tools for mechanical I sidewall core re-run. 4/13/2007 I PROD1 00:00 ' EVALFM ~OTHR Run wireline log #3 re-run. Mechanical I sidewall cores. 4/13/2007 PROD1 06:00 i EVALFM PULD UD sidewall coring assembly. 14/13/2007 PROD1 07:00 ',EVALFM PULD ~I Monitor Well & M/U MDT to run on DP. 4/13/2007 PROD1 ,.08:30 EVALFM PULD ! PJSM with SWS P/U logging tools, ' ', hang sheaves, tie into tools and test. 14/13/2007 PROD1 ' 10:30 EVALFM DLOG ~ ITIH w/ MDT logging tools to 2900'. (Fill @ shoe & every 500') ':4/13/2007 PROD1 :.15:00 EVALFM 11 DLOG M/U side entry sub, rig up wireline, ~ 1 space out @ 2900'. .4/13/2007 PROD1 16:00 EVALFM I DLOG ~ RIH w/ wireline (latch up run) ',.4/13/2007 ~~ PROD1 ',17:00 EVALFM ' DLOG M/U jewelry for PSI run, TIH w/ DP f/ 2900' to 3240'. D~cl`~ ~l:art D~~:dh Fart Ceu!`~ Dur !nrs7 itKf3; UiKB~ P~gress ,ft! 1.00 ~ 3,128.0 3,188.0 ~ 60.00 I 5.50! 3,188.0 3,507.0 319.00 1.00'; 3,188.0 3,507.01 319.00 1.5011 3,188.0 3,507.01 319.00 1.001 3,188.0 3,507.01 319.00 2.00 3,188.0 3,507.O~I 319.00 1.OOli 3,188.0 3,507.01 319.00 0.501 3,188.0 1 3,507.0 319.00 2.50 3,188.0 3,507.0 319.00 1.00 3,188.0 i 3,507.0 319.00 1.001 3,188.0 3,507.0 319.00 7.00 3,188.0' 1 3,507.0 319.00 1.50; 3,507.0 3,507.0 0.00 0.50 3,507.0 3,507.0 0.00 2.001 3,507.0 3,507.0! 0.00 1.00 3,507.0 3,507.01 0.00 4.001 3,507.0 3,507.0 0.00 0.50 3,507.0 3,507.0 1 0.00 3.00 11 3,507.0 3,507.0 1 0.00 1.00 3,507.0 3,507.0 0.00 1.50 3,507.0 1 3,507.0 i 0.00 3.00 3,507.0 1 3,507.0 0.00 1.00 3,507.0 !, 3,507.0 0.00 2.50 1 3,507.0 ' 3,507.0 0.00 1.00 3,507.0 3,507.0 0.00 1.00 3,507.0 '; 3,507.0 0.00 0.50 3,507.0 , 3,507.0 1 0.00 6.00 ` 3,507.0 3,507.0 0.00 1.00 3,507.0 i 3,507.O~ i 0.00 1.50 3,507.0 3,507.0 0.00 2.00 3,507.0 3,507.0 0.00 4.50 3,507.0 1, 3,507.0 0.00 1.00 3,507.0 3,507.0 0.00 1.00 3,507.0 , 3,507.0 0.00 1.50 , 3,507.0 1 3,507.0 1 0.00 ', Page 5/7 Report Printed: 517/2007 4/13/2007 PROD1 18:30 ! EVALFM 4/13/2007 PROD1 22:00 'i EVALFM 4/13/2007 PROD1 22:30 EVALFM 4/14/2007 PROD1 ' .00:00 EVALFM 4/14/2007 PROD1 1 ' 04:00 . CASING j 4/14/2007 j PROD1 1 06:30 CASING 4/14/2007 PROD1 08:00 . CASING 4/14/2007 PROD1 13:00 !, CASING 4/14/2007 PROD1 1 16:00 CEMENT 4/14/2007 II PROD1 ~I ~!i18:00 I ! CEMENT 14/14/2007 4/14/2007 .4/15/2007 4/15/2007 '; 4/15/2007 4/15/2007 ~', 4/15/2007 i 4/15/2007 4/16/2007 PROD1 20:30 PROD1 23:00 PROD1 00:00 PROD1 02:00 PROD1 ~ 03:00 PROD1 X 03:30 PROD1 , '' 12:00 i PROD1 14:00 PROD1 00:00 '~ PROD1 19:00 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL Operations Summary INTREPID 2 ,_ u;d ,~ „~ ~c~~~h ~~,; ~r,,~~, CiptiuL Code ~'omn pcra~ an ;lur ,hr.1 UtKLi l(th61 F yecs (ft) DLOG i POOH w/ DP for PSI logs @ 3124', t 3133' 3144' 3152' & 3160' Take , , . , Sample @ 3124'. DLOG POOH f/ 3124' to side entry sub @ 2900'. DLOG POOH w/ wireline to side entry sub, UD side entry sub, R/D sheaves & wireline. Monitor well. DLOG POOH f/ 2900' to wireline tools, UD i same and collect samples f/ tools. RURD Change top rams to 7", P/u test jt., pull wear ring and M/U test plug. Shell test to 250 psi low, 2500 psi high for 5 min. ~ UD test plug and test jt. RURD ': R/U to run 7" casing hold PJSM. RNCS L Run 7" casing to 3485'. (82K up WT) ', P/U 9.85 ft pup joint and RIH to 3495'. RNCS i P/U hanger and landing jt. M/U circ ' head and wash down casing f/ 3506 to TD @ 3516.41'. Circ while making up cement head. PLUG PJSM, Pump cement job, 2bbls H2O,/ Test lines to 3000 psi, Drop plug, Pump 20 bbl 12 ppg Mudpush/ 40 bbl ~, 15.7 ppg class "G" CMT, Drop plug / ~ Pump 10 bbl H2O 8~ Displace w/ 118 i bbl mud. Full returns throughout job. i~ RURD ~ Blow lines dwn, R/D cement head, R/D ~ manifold, Backout landing jt./ Wash ! .down rig floor, UD side doors, bale Lexts, P/U Hyd Elev & UD all subs. OTHR I Drain and wash stack, P/U testjt., Pack off, RIH & test to 5000 psi. OTHR ' RIH open ended to 1243'. OTHR RIH f/ 1243' to 3186' & CIRC B/U. OTHR Test 7" casing to 3500 psi for 30 min. (lost 2.5%) LOT Perform LOT on Annulus, UO @ 620 psi. OTHR UD 4" DP & 4" HWDP, clean BOP's, clean rig floor, and start preparing for i ng move. LOT i Perform INJ. test with Schlumberger cement unit, pump 20 bbls UO @ 531 j psi, stabilize @ 462psi. OTHR 'i N/D BOP's and continue preparing rig for move. RURD Continue N/D annular preventer, double gate, remove trolley f/ cellar. R/D pipe shed, and derick board. Clean and wash rotary table. Inspect derrick, OTHR UD topdrive & blocks. ; 19:00 hrs PJSM w/ SWS for injecting fluid/start injecting @ ! , 0.5 bpm/work up to 3 bpm 415 psi. 0.50 1.50 4.00 2.50 3,507.0 3,507.0 3,550.0 3,550.0 3,507.0 3,507.0 3,550.0 3,550.0 1.50 3,550.0!; 3,550.0 0.00 5.00 3,550.0' 3,550.0 0.00 3.00 3,550.0'1 3,550.0 0.00 i~ 2.OO 3,550.01 I 3,550.01 I 0.00 2.501 3,550.0 3,550.01 0.00 2.50 1.00 2.00 1.00 0.50 8.50 2.00 10.00 19.00 3,550.0 it 3,550.0 3,550.0 3,550.0 3,550.01 3,550.01; 3,550.0 j 3,550.0 3,550.0 3,550.0 3,550.0 3,550.0 3,550.0 3,550.0 3,550.0 3,550.0 0.00 0:00 0.00 0.00 0.00 5.00 3,550.0 3,550.0 3,550.0 3,550.0 0.00 Report Printed: 5/7/2007 • ---- ~ Operations Summary INTREPID 2 i I I~ art Oat phase Shit Tnne J ~ r r9e ~y5 1,-Cody Comn =.iliar~ • CrCr Gtsd ~ epih end Depfh Cyr (hc.'I 1'iK6? tt6C6i Progress (ft) '. 4/17/2007 PROD1 00:00 DRILL RURD ;Inject fluids to annulus @ 3 bpm, 400 ~ 24.00 ~ 3,550.0 3,550.0 0.001 psi (1756 bbls total pumped) Clean ~ ' ~ pits, R/D cattle chute, unstring j ~I i drawworks & blocks. R/D beaver slide, j ~ catwalk building tugger hoses & main ~ hyd. hoses. ~ ! i ~ 4/18/2007 PROD1 00:00 jDRILL i ~OTHR ~ICleanpitswhilewntinuingannular ~ 12.OOi 3,550.0 3,550.0 0.00; ~ i injection (350 bbls injected) prep ~ ~ ' ~ derrick to remove drawworks, R/D ~ pump room suction & discharge. Spot ! 5 bbl pill down 7" casing. (total bbls ! i injected to date=2106) ~ t 14/18/2007 PROD1 '',12:00 (DRILL OTHR Pump 15.1 bbl (73 sx) 15.8 ppg II 12.00 3,550.0 3,550.0 0.00. ' Arcticet 1 down 7" casing. Continue to ~ I prepare rig for move. Pump remaining ' 72.5 bbls fluid down annulus followed ~ ', by 126 bbls cement (86 bbls Arcticset f ~ i I II I sill III I, i I ~i L 'i I _ _ Lite and 40 bbls Arcticset 1) --- I i I ~I 1 ~ _. __ . . --- - -- __ _ _- ------ Page 7/7 Report Printed: 5/7/2007 • DATE: 03-21-07 SCALE: 1 " = 200' SHEET: 1 OF 1 ~ cV-~ REV DATE DESCRIPTION REV DATE DESCRIPTION ,``!G `sCi~ BARROW ~ ~\ ~ S~~Q~~ NOTES. ~ ~~! : k s, , , ,:~ ',; J ~ ; 1) COORDINATES SHOWN HEREON ARE ASPC NAD 83, ZONE 6 PROJECT n ,`,~~J Qi G ° ~~'0 a u j .,, AREA oh ~ ;~ Y ~, .~ ~ ~~ ;'~ - 2)ALL DISTANCES ARE IN U.S. SURVEY FEET o; ~ ~~ ~ I ~ ~~~(~ r ~ , ~' r~ I ~ ~ 3) PROTRACTED SECTION LINES HEREON ARE SHOWN FOR „t1~p ~ I ~ ~'_f'J ~?~ ~° PI ~"' ~ J REFERENCE ONLY AND ARE APPROXIMATE v '~juti_ I ~ t(,r o ~` ~; Q o 1 ,"s ~ ~~ ' ~~° 4) DATE OF AS-BUILT SURVEY IS MARCH 15, 2007 a u J ~ ~ ~`,-I" ~ ~ Z ~ C qa 6V,~^~,I~ C n~;' n ~e C ~ ~1~ VICINITY MAP -NOT TO SCALE INTREPID #2 PAD AS-BUILT EXHIBIT INTREPID #2 CONDUCTOR LOCATED WITHIN T. 19 N. R. 20 W., SECTION 11, UMIAT MERIDIAN 3 o_ a a DD v N O i 3 rn Y 6 N N a U V O 0 t!) Z 0 a U O C7 z a 0 NAD 83 LAT: 71°00'47.822" N LONG: 157°03'14.506" W NAD 83 ZONE 6, ASPC, N = 6,221,095.55 E = 1,753,143.44 NAD 27 * LAT: 71°00'49.380" N LONG: 157°03'02.149" W NAD 27 ZONE 6, ASPC N = 6,221,408.2 E = 613,138.3 TOP RIM OF 16" WELL CONDUCTOR CASING ELEVATION GEOID 2006, ALASKA 36.4° (APPROX. MSL) * CONVERTED FROM NAD 83 BY NADCON N ~~•4, ~ ~~ ~~~ N ,~ ,- ~ ~ ,59 ~~ I, \ ~ \ A ~~8 PIT 2a~ 1,,0~ E N ~ ~ zlz ~I~ IV IV ~- ~ O ~ O ~I~ ~~6, R ~~ ~ ~ ~ C <~ m m ~ P~~~NG J' ~ ~ 0 PR ~~No OIo Z z z w _ ~ ~ ~ N ~ A 0 0 o ioo 200 SCALE IN FEET LEGEND RAMPS ® 16" O.D. STEEL CONDUCTOR AREA UNDER ~, _ _ CONSTRUCTION 0 ~~ OF' A`~sll l T 19 N, R 20 W, UM SECTION 11 ~ _ ~ CrJ~P •~'9,~~ 14 /*. QTH ~ ,* T 19 N, R 20 W, UM SECTION SURVEYORS CERTIFICATE / f ~ 3-ZI-0?~ T.~.4----rte" ........ / 1 HEREBY CERTIFY THRT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE ,KENNETH J. PINARD ,~ / STATE OF ALASKA AND THAT THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT ~~I ~ O~ SUPERVISION AND THAT ALL.DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 15, 2007 f Fc~j.. - -. No. 11545 . 'yam i , ~tIF~F~~'ROFESSI NA~.~~'~~~ ~ rws eznwwesunE mo. n"c".acws~ia ConocoPh~Il~ps ~```~'`` an Ukpeagvik Inupiat Corporation Company A~aSka, ~IIC. DRAWN BY: LHH CHECKED BY: KJP W.O. No: 2006-241 INTREPID 2 ___ _. _ __ _ _ -_ Security Level: Intrepid Daily Drilling Report -- __ _ 10148267 10168776 tig: AFE/RFE- ~~ Report Number: 1 KUUKPIK 5 Report Date: 4/19/2007'.. __ ___- _ _..... _____-Network/1D#___... __._- .. _. ------_ __-- TotatAFE+Sup __._ _. 19,730,095.00'. Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Original Hole Exploration ' NPRA TIGHT HOLE 4/1/2007 ' 1.00 ,Daily Mud Cost Cumulative Mud Cost ,Daily Cost Total Cumulative Cost 84,405.12 84,405.12 Last Casing String Next Casing OD (in) Next Casing-Set Depth (ftKB) Production, 3,516.4ftK6 _ Ops and Depth @ Morning Report 24hr Forecast 'Preparing rig for move. Continue preparing rig for move. _. _ _. --- Last24hrSummary Pump 3.5 bbis 15.6 ppg Arcticset1 down annulus pressure up to 1099 psi, bleed pressure back to 0 and pump another 0.4 bbis pressure up to 1039 psi hold 700 psi on annulus for 10 min. Bleed to zero and rig down cementers. Conti nue preparing rig for move. RIG RELEASED 04/18/2007 @ 24:00 hrs. General Remarks !Weather 'Head Count No Accidents or Incidents, No Spills. 'Temp 18 F, Wind 8 mph f E, WC 8 F 45.0 - -- SupenASar ~ Fine Tom Brassfield, Drilling Engineer Drilling Engineer Donnie Lutrick, Rig Supervisor Rig Supervisor ', Dink Heim, Drilling Supervisor Drilling Supervisor '..Brian Hope, Drilling Engineer Drilling Engineer Ted Peter, Tool Pusher 'Tool Pusher Mike Galvin, Construction Sup. Construction Sup. Ttme L _ Stan End i Dur T ~ Tjme Depth StsR Depth End __~ ~- - ~ ~ Trbl Code ,. Trbl Cless. (ftKB) ~ {ftKB) Operation Mme Mme rs Phase Op Code QpSub-Co. -N- ~ 0130 1.50!PROD1 MOVE DMOB P 00.00 _~ ~ Continue preparing rig for move. f; 0.0 0.0 ,02:00 0.50..PROD1 ,CEMENT PLUG P 01:30 _ 0.0 0.0',Pump 3.5 bbis 15.6 ppg Arcticset 1 down annulus ', pressure up to 1099 psi, bleed pressure back to 0 and ', !.pump another 0.4 bbls pressure up to 1039 psi hold 700 I ', ' ', ',psi on annulus for 10 min. Bleed off pressure and rig down cementers. ~ ' -~-- 1_ DMOB P ! 02:00 00:00 22.00 ~ PROD1 MOVE ~ ,L I 0.0, 0 O _T~ --- ----- - - i Preparing rig to move. _ _ ~ Wellbores - - _- - ~ ', Welibore Name ' Welltwre API/UWI ' Original Hole S0-023-20036-00 Sedioh ~~ Size.(irtj ~1- Act Fop (RKBj 1 ~ Ad Btm (ftKB) Start Date -r End Date ~_~_ 'SURFAC 121/4 ', 0.0 1,389.04/1/2007 ~~4/3/2007 I COND1 16', 0.0 80.0,.3/5/2007 ' 3/6/2007 ~,PROD1 83/4' 0.0 5,550.0'4/7/2007 !4/12/2007 - - iLatest BOP Test Data Date --- -- - - --- ...--- Come Page 1/1 Report Printed: 5/29/2007', • __ Security Level: Intrepid Daily Drilling Report INTREPID 2 Report Number: 4 tig: KUUKPIK 5 Report Date: 4/22/2007 ----- _ AFE / RFE -_ _ __ --_ - -. _. ___ _- ___- -tJetwotk/ID # _ -_-- ---. -- Total AFE+Sup------ _..--- '~. _ _ 10148267 -__ -_ _ _. _ - --+- --- - __ _ _ _ - -- --- -- _ _ .__ --__ 19,730,095.00'. 10168776 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftK6) _ _ Depth End (ftK8) 'Depth Progress (ft) Original Hole Exploration NPRA TIGHT HOLE 4/1/2007 4.00 Daily Mud Cost Cumulative Mud Cost ---- Daily Cost Total Cumulative Cost 68,188.04 315,938.48 Last Casing String Next Casi ng OD (in) Next Casing Set Depth (ftKe) Production, 3,516.4ftKB - - ----- Ops and Depth @ Morning Report 24hr Forecast Demobilizing Rig. - Continue Demobilizing Rig . -__ Last 24hr Summary -- Demobilizing Rig. General Remarks Weather Head Count No Accidents or Incidents, No Spi lls. Temp 16 F, Wind 13 mph f NE, WC 2 F 36.0 Supennsoc _ _ _-_~ ~ Tiee Tom Brassfield, Drilling Engineer Drilling Engineer Donnie Lutrick, Rig Supervisor Rig Supervisor Dink Heim, Drilling Supervisor Drilling Supervisor Brian Hope, Drilling Engineer ,Drilling Engineer Ted Peter, Tool Pusher Tool Pusher ', Mike Galvin, Construction Sup. .Construction Sup. Time t-nn Time ~ Time il. fh~) i Phase ! Op Code ~OpSub-Co... P-i`1-Tj TeWCode TrblClas_s 00:00 12:00 ' 12.00 PROD1 MOVE DMOB P 12:00 00:00 12 00~PROD1 ',MOVE DMOB P -- - - 'ran Ready loads for HERC & rolliaon's. 'with misc., tie down same. Pickup herc-lite and scrape pad. Send 2 men to Anchorage & 7 men to " " --- - Wellbores - --- - Wellbore Name - - -- _._....-- _-_- _- __-- _ Wellbore API Original Hole 50-023-20036-00 _-._ Section:- T - Sizetin) - ActTop:(ftK6) I .ActBtm(ftK8) ---- $tartDate End I SURFAC 12 1 /4 0.0' 1, 389.0' 4/1 /2007 ', 4/3/2007 COND 1 16 0.0' 80.0' 3/5/2007 3/6/2007 'PROD 1 ' 8 3/4' 0.0 5,550.0', 4/7/2007 ', 4/12/2007 Latest BOP Test Data Date -" .-..-_----. ___. -_--- Comment Page 1/1 Report Printed: 5/29!2007 Csg cut-off I.JPG (JPEG Image, 640x480 pixels) imap://sfdavies@ancmail I .state.ak.us:993/fetch%3EU I D%3 E/IN$OX%3 E 19820?part=1.7... • I of I ~ ?9 ?OU % ;: I K I'Nl • __ - Security Level: Intrepid Daily Drilling Report INTREPID 2 Report Number: 5 Zig: KUUKPIK 5 Report Date: 4/23/2007: - - -_ _ , _ _ _ _,-.. _AFE / RFE.. __ -.. - -. _. _ - Network/ID # _. _. -- -__. Toial AFE+Sup -_.- 10148267 _- _ _ -_ _ -_ 19,730,095.00 10168776 Wellbore .Well Type Field Name Original-Spud Date DFS (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Original Hole Exploration NPRA TIGHT HOLE 4/1/2007 5.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 66,474.68 382,413.16 Last Casing String Next Casing OD (in) _ - -- - __ _ _ Next Casing Set Depth (ftK6) Production, 3,516.4ftK6 _ ---- Ops and Depth @ Morning Report 24hr Forecast Demobilizing Rig. 8th HERC load sent out @ 4:30 am Continue Demobilizing Rig. --- --- _ Last 24hr Summary Demobilizing Rig. General Remarks Weather Head Count No Accidents or Incidents, No Spills. Temp 19 F, Wind 14 mph f ENE, WC 6 F 36.0 ------- - - - --- -- - -_. -- T Supervisor --_..- -- - - Title -_-'~.. Tom Brassfield, Drilling Engineer Drilling Engineer Donnie Lutrick, Rig Supervisor Rig Supervisor Dink Heim, Drilling Supervisor Drilling Supervisor Brian Hope, Drilling Engineer Drilling Engineer Ted Peter, Tool Pusher Tool Pusher ,Mike Galvin, Construction_Sup. _.-- -- .- - Construction Sup. _. -- ._. _-_-- _.-- -.--- _. __ Time L - - ---- -~ ~ - --- _ _- --- - -- ~ - r Start Dur ~ pth Depth Start e n D ~~ ~ ' ~ , . IP-N T, Time ~: Time hrs i Trbl Class. ( ) Phase Coda ub-Co.. Trbl Code ' ( ) I - d - i ftK6 ftK6 Q~d~ _ ._._ ___ ._--- -- . . _ _ _ __ 00:00 12:00 12.00, PROD1 MOVE ' DMOB P _. .-- - - - 0.0 0.0, Load out HERC skid's and trailers. Clean pad and weld well cap on. 12:00 ,00:00 12.00'PROD1 'MOVE DMOB 'P _- - -- Continue HERC skid load out and chain out. Continue -- 0.0 0.0 ;pad clean & snow removal. Weltbores - - _ - _ - -- - _ _ - - - 'Wellbore Name Wellbore APt/UWI Original Hole ' S0-023-20036-00 Section Sze (in) _ _ Act lop (ftK6) ,- --- ~ Ad Btm (ftK6) -__-.-- Start Date ' ~--~ End Date - I SURFAC 121/4 0.0 1,389.0'4/1/2007 '4!3/2007 COND1 16 0.0 80.0' 3/5/2007 3/6/2007 0.0 5,550.0 4/7/2007 4/12/2007 • • SAMPLE TRANSMITTAL TO: AOGCC 333 WEST 7T" SUITE 100 ANCH. AK. 99501 2791433 OPERATOR: CPAI SAMPLE TYPE: CORE CHIPS & DRIES SAMPLES SENT: INTREPID #2 DATE: May 3, 2007 AIR BILL: FEDX AUTO CPBV: 07-05-03-02 CHARGE CODE: 10148267 NAME: INTREPID #2 NUMBER OF BOXES: 1 BUNDLE (4 Bxs) Core Chips: 3128.1 3131.1` 3134.13135.'~3136.~ 3137.1, 3138.1~3139.1~ 3140.1 3141.1 3142.1 a 3143.1 3144.13145.13146.3 3147.5 3148.3 3149.3 3150.5 3151.5 r . t ~ • ~ c 3152.5 3153.3 3154.3 3155.3 3156.3 3157.3 3158.3 3159.3 3160.5 3161.3 3162.3~3163.3c 3164.4 ~3165.5~ 3166.3` 3167.5` 3169.1 f3170.3r3171.1r 3172.3r 3173.4.3174.4r 3176.1 3177.1 3178.3 3179.4 3180.3 3181.2e 3182.4 3183.4 No core chip samples for the following: 3129 3130 3132.3 3133.1 3168 3175 Dries: 90-3550 SENT BY: M. McCRACKEN UPON RECEIPT OF THESE SAMPLES. PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF_ THIS FORM TO: PHILLIPS BAYVIEW GEOLOGICAL FACILITY 619 EAST SHIP CREEK AVE SUITE 102 ANCHORAGE, AK. 99510 ATTN: DAN PRZYWOJSKI ABV100 RECEIVED: 3 e^'b. J~ oe~ ~i~~~ Intrepid 2, 206-190, Weekly update 4/24 ~ i Subject: hitrepid 2, 206-190, Weekly update 4/24 From: "Hayden, Philip" <Phlp.Hayden c~conocophillips.cotn> Date: Tue, 24 Apr 2007 16.18:3 -0~~)(1 To: Thomas >viaunder <=to~u nlaundei-(u'~admin.state.ak.us=- ~a~-~~ Tom, Sorry for the delay in getting this to you. I was out of the office yesterday and have been playing catch-up. I plan on this being the last update for this well. ND BOPs Set surface cement plug Squeeze cemented 7" x 9 5l8" annulus Prepared rig for move If you have any questions please let me know. Regards Philip 1 of 1 4/25/2007 7:15 AM Intrepid #2 Cut-off Subject: Intrepid #2 Cut-off From: Kuukpik 5 Company man <Kt7C1I~5CM@conoeophillips.co~n> Date: Mon, 23 Apr 2007 12:59:36 -0800 ~~r(`~ To: jimr-e~~~~~r'admin.stat~.ak.us CC: "Brasfield. Tom .l" ~~~TOti~1..1.Brasstield~c~conoco~~hillips.cony=°~ «Csg cut-off 1.JPG» «ID Plate.JPG» «Csg Cut-off.JPG» "~~~ ~~ Content-Description: Csg cut-off l.JPG Csg cut-off l.JPG Content-Type: image/jpeg Content-Encoding: base64 Content-Description: ID P1ate.JPG ' ~ ID P1ate.JPG Content-Type: image/jpeg Content-Encoding: base64 Content-Description: Csg Cut-off.JPG Csg Cut-off.JPG Content-Type: image/jpeg Content-Encoding: base64 I of 1 4/23/2007 1:22 PM Intrepid #2 (PTD 206-190) P&A Photos provided by ConocoPhillips April 23, 2007 -- --~ ' r .h 4 . 4r, a ~4•~ iMT S!ltll1~: ~.. ,~~ • Cement to surface; casing cut-off Cement to surface; casing cut-off Marker plate r~ ~J Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder@admin.state.ak.us] Sent: Tuesday, April 17, 2007 1:41 PM To: Grimaldi, Louis R (DOA) Subject: [Fwd: FW: Intrepid #2 (206-190)-casing pressure test] Attachments: Trnch Casing Pressure Test.pdf 7inch Casing Pressure Test.pdf... Lou, Here is the casing test done at Intrepid. I don't think there is a need to do another. Tom -------- Original Message -------- Subject: FW: Intrepid #2 (206-190)--casing pressure test Date: Tue, 17 Apr 2007 13:37;36 -0800 From: Hayden, Philip <Philip.Hayden@conocophillips.com> To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: Brasfield, Tom J <TOM.J.Brassfield@conocophillips.com> Tom, Attached is the test recorded on the rig's Pason system. If you need anything more please let me know. Regards Philip -----Original Message----- From: Kuukpik 5 Company man Sent: Tuesday, April 17, 2007 1:00 PM To: Hayden, Philip Subject: RE: Intrepid #2 (206-190)--casing pressure test Philip, Here is the Pason chart for the 7" casing pressure test. Tf you need some thing more let us know. B.Hope -----Original Message----- From: Hayden, Philip Sent: Tuesday, April I7, 2007 9:42 AM To: Kuukpik 5 Company man Cc: Brassfield, Tom J Subject: FW: Intrepid #2 (206-190)--casing pressure test We need you to forward us a copy of this chart. Philip -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] 1 • Sent: Tuesday, April 17, 2007 9:31 AM To: Hayden, Philip Cc: Brassfield, Tom J Subject: Re: Intrepid #2 (206-190)--casing pressure test Philip, Could you provide a copy of the chart? One of the Inspectors had asked about the pressure test in conjunction with the P&A. Thanks, Tom Maunder, PE AOGCC Hayden, Philip wrote, On 4/17/2007 9:26 AM: >Tom, > We bumped plugs on the 7" at 18:00 4/14/07. RIH with drillppe and >tested casing to 3500 psi for 30 minutes at 02:00 4/15/07. Instructions >were for it to be recorded. >Philip >-----Original Message----- >From: Thomas Maunder ~mailto:tom maunder@admin.state.ak.us] >Sent: Tuesday, April 17, 2007 9:21 AM >To: Brassfield, Tom J; Hayden, Philip >Subject: Intrepid #2 (206-190)--casing pressure test >Tom and Philip, >When the 7" casing was cemented, was the pressure test accomplished at >that time? If so, what was the pressure test and was it charted? >Thanks in advance for your reply. >Tom Maunder, PE >AOGCC 2 • INTREPIDZ KUUKPIK5 P e11 04115/flT :0.5 :10 :15 :2Q :25 :ifs :3.5 :4Q :45 :50 :55 03:D0 :D5 :i0 ;15 •20 :25 :30 :35 :~ :d5 :50 :55 Intrepid #2 (206-190) Subject: Intrepid #2 (206-190) From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Tue, I7Apr 2(~i17 (i9:19:O9 -0800 Tv: I~om F3rass[icl~l ~-_ f om..i.F3rassiic~~i'u;c~>n~~co~~hillips.cuiT~>. Philih ffa~~clen ~~_r~hilih.haycien~u conocophillir~s.com= CC: Steve Davies <-st<:vr davies~u admin.state.ak.us== Tom and Philip, Sorry I did not get a reply back to you last night. This message acknowledges Tom's call about 1815 regarding the status of the annular disposal sundry submitted earlier in the day. As I related, Steve Davies and I had examined the application and had forwarded it to the Commissioners recommending approval. On the basis of the information submitted and our analysis I did give you verbal approval to begin disposal. we discussed the pumping schedule that had been included in the application and the importance of following it. Also, that disposal should cease if a sudden loss of pressure were experienced. As usual, call or message with any questions. Tom Maunder, PE AOGCC r~~ 1 of 1 ~'~;,- U ~ ~ ~ ~ ~ 4/18/2007 7:42 AM SARAH PALIN, GOVERNOR 0i~[a-7~ OIL ~ ~S7 333 W. 7th AVENUE, SUITE 100 COATSI~iRQ.~TI011T COMMISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Exploration Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Exploration, Intrepid 2 Sundry Number: 307-131 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 Superior Court unless rehearing has been requested. Joh'l~. ~ 7 DATED this ~ T day of April, 200' Encl. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR.. 1 6 2007 ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 Alaska i)a & Gas Cnnc_ I'.nmmiecinn 1. Operator 3. Permit to Drill ARGl10f8ge Name: Number: 206-190 ConocoPhillips Alaska 4. API Number: 50-023-20036-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska Intrepid 2 6. Field: Exploration 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: None Torok formation, primarily shale with a few thin. turbiditic sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers in the lower Torok formation N0112 ~ c) Confinement: The Lower Nanushuk formation provides an upper barrier and the shales of the HRZ formation provide a lower barrier 9. Depth to base of permafrost: - 10. Hydrocarbon zones above waste receiving zone: approximately 1064' M D /TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 1298 PSI 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: ' \ ~ 5,000 bbls. ~` ~~ ~~ " "t (t e Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, domestic waste water, any added water 16-Apr-07 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well ~ , . 17. Attachments: Well Schematic (Include MD and TVD) ~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ~ Other ^ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ -` f~~ Title: Exploration Team Leader Printed Phone Name; Chip Alvord Number. 265-6120 Date: ~ ~ I ~i ~ 2.00 Commission Use Only `` Conditions of approval: ~o~`~n(',~t ~~ ~0 ~~-- ~ LOT review and approval: ~ y "1 Subsequent form required: ~Oe. fL~'a. Approval number. ~~ ~ '~ r{ ~~/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: d 2 I/ // '~~ CTATF (1F DI ACllA -r.-- ~~ y rGR a~ Form 10-403RD Rev. 6/2004 ~ ~ ~ ~~UCTIONS ON RE ~~~ ~ ~ SubmiY in Duplicate ~ ~ ConocoPhillips Alaska, Inc. , Post Office Box 100360 ~ ~, Anchorage, Alaska 99510-0360 ~~~~~~'' Telephone 907-276-1215 J April 16, 2007 IlE~i~~ V E~ Alaska Oil and Gas Conservation Commission APf~ 1 6 207 333 West T1i Avenue, Suite 100 Anchorage, Alaska 99501-3539 Alaska Oii & Gas Cons. Commission Anchorage Re: Application for Sundry Approval for Annular Disposal of DrillinE Waste on Intrepid 2 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that Intrepid 2 (206-190) be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080: It is intended to begin annular disposal operations at Intrepid 2 approximately April 16`h Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job.. 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells-NA 10. List of wells on the Intrepid pad and the lateral distance from the surface casing shoe-NA 11. Additional information regarding wells within'/4 mile radius-NA 12. Copy of previous authorization. for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations- NA The casing shoe test (FIT) was 18.2 ppg EMW. The initial annular LOT was 18.5 ppg EMW. On repeating the test the annular LOT was recalculated at 16.1 ppg. Based on the fact that; (1) the original casing shoe test was a Formation Integrity Test; (2) the subsequent annular tests actually achieved leak-off; (3) the limited volume to be disposed (3000 bbl) and (4) the geology of the confining zones we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT. If you have any questions or require further information, please contact Philip Hayden at 265-6481; Chip Alvord can also be reached by calling 265-6120. Sincerely, ~~ ~ ,~,t, Philip Hayd Drilling Engineer cc: Intrepid 2 Well File Chip Alvord ATO-1570 Sharon Allsup-Drake ATO-1530 Annulus Disposal Transmittal Form -Intrepid 2 A(~GCC; Re~ilatinns_ 20 AAC 25 ~R~ (hl 1 Desi nation of the well or wells to receive drillin wastes: Intre id 2 2 The depth to the base of freshwater aquifers and permafrost, i There are no aquifers .local to the Intrepid area (none below " present. permafrost). Estimated base of Permafrost is about 1000' MD, but because the .formations above and below this depth are dominated by muddy non-reservoir lithologies, this is only a rou h estimation. 3 A stratigraphic description of the interval exposed to the open See attached figure. The figure displays the geology of the annulus and other information sufficient to support a interval open to annular injection and the under-.and commission finding that the waste will be confined and will overlying confining units, Both we111ogs are Intrepid 2, but not come to the surface or contaminate freshwater. displayed at different scales.. Below cement (2600') is about 30' of the impermeable HRZ shales underlain by 400' of "Pebble Shale" - a thick section of impermeable shale with local scatters of floating quartz grains: Above the annular disposal interval and above the surface casing shoe is a hick 01000') section of distal shales of the Nanushuk Formation underlain by Torok Formation shales.. The Nanushuk in this setting contains no reservoir units. The formation open to annular injection is the Torok Formation. It is primarily shale, but contains a few thin turbiditic sandstones. In the Walakpa Gas Field a short distance to the north of Intrepid 2 similar thin sandstones of the Torok Formation are all discontinuous, as attempted correlation between wells (~1 mile inter-well spacing) illustrates. 4 A list of all publicly recorded wells within one-quarter mile N/A and all publicly recorded water wells within one mile of the well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste maybe drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids. associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 5,000 bbls. /~ 6 A description of any waste sought to be determined as drilling Cement rinsate, mud pit rinse fluid generated by rinsing tanks waste under (h)(3) of this section. and equipement after producing drilling/completion fluid. 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 1298 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer. casing is set below the See attached: cementing reports, LOT /.FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. i 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or Intrepid 2 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com Hance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. - • ConocoPhillips Alaska, Inc. i Internal Correspondence Date: April 13, 2007 Subject: Geology of Annular Disposal Interval From/Location: Greg Wilson ATO-1450 Telephone: 263-4748 To/Location: Philip Hayden, Tom Brassfield The following figure displays the geology of the interval open to annular injection (red box) and the under- and overlying confining units. Both well logs are Intrepid 2, but displayed at different scales. The log at right is the entire well, whereas the log at left is from surface casing to TD. Below cement (-2600') is about 30' of the impermeable 400' RZ h l d l i b ~ nt r e p i d 2 es un er a n y H s a of "Pebble Shale" - a thick section of impermeable shale ~~ with local scatters of floating ~ " ; Above the quartz grains ~ Su rface Casin f . ~ __ _ annular disposal interval and ~ "' f ~ _ Nani above the surface casing shoe is a thick (-1000') section of ~ .,~ ~; - ~ Forn distal shales of the Nanushuk -~ `~ Formation underlain by Torok ~~ Formation shales. The ~ h~ C- Nanushuk in this setting ~ ,.., contains no reservoir units. - ~ !'~ . - The formation open to annular - '~ v ~ ~ _ injection is the Torok ~ ; • Torok -- Formation. It is primarily shale, , but contains a few thin ~j m Formation turbiditic sandstones. In the - Walakpa Gas Field a short ~ '"~ ,; #' • distance to the north of Intrepid ,..., 2 similar thin sandstones of the ~ ~ ~ • ~ Torok Formation are all ~ •° :~ _ discontinuous, as attempted ~ G ~ '~ correlation between wells (-1 ~~~~ `t • ~" ~~ mile inter-well spacing) ~ ~ I ' z illustrates. ~ -F +a ~ ...., Well Intre id 2 ENTER VALUES in the YELLOW CELLS Date 4~ 132007 Version 1.0 - Jan'OS CASING/TUBING DESCRIPTION Collapse Bursting Size Wt. Grade PSI PSI Surf. 9.625 40.000 L 80 3090.00 5750.00 Next String 7.000 26.000 L 80 5410.00 7240.00 Tubing 3.SQ0 Fluid in Tubing/Casing Annulus dicel Surface Casin TVD L, 72 ft Drilled Mud Weight 102 ppg Pore Pressure @ Shoe 0.434 psi/ft (suggest fresh water gradient) Shoe FIT/LOT 18.2. ppg Annuluar FIT/LOT 16.1 ppg Pburst @ 85% 4,888 Max Injected MW 12 ppg Max Surface Pressure 1,500 psi Distance from Pump to Well 350 ft Diameter of Pump Line 1.75 inches 2nd Casin Strin TVD 3,550 ft Estimated TOC 2.628 MD ft Estimated TOC 2.628 TVD ft Gas/Fluid Gradient in tubing/casing annulus 0.3952 psi/ft (suggest 0.06 - 0.07 psi/ft) Header Pressure (for wells on gas lift) 0 psi Pcollapse @ 85% 4,599 ~ ~ Well .Intrepid 2 Date 4/13/2007 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) ve~s;°a t:o - z°a~os Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434. psUft Gas/Fluid Gradient in tubing/casing annulus 0.3952 .psi/ft Header Pressure (for wells on gas lift) 0 psi. c~ Maximum Fluid Density to avoid Burst of Surface Casing ~ Pburst85% - PHydrostatic + PApplied - PFormation c 4,888 = ( 1,372 * 0.052 * MWm~ ) + 1500 - (0.4337 * 1,372 N ~' MWmax = 55.8 PPg 1,372 TVD Surface Casing String Size 9.625 in Weight 40 ppf Grade L 80 rburstloo°i° 5,750 pst Pburst85% 4,888 Psi Depth of Shoe 1,372. ft FIT/LOT @ Shoe 18.2 ppg or 1,298 psi FIT/LOT for Annulus 16.1 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 2,628' MD 2,628' TVD ~,.~~Jv~~~~ vE~ ~.~~~.~~~,~~. s~ ~~t •~.~ 1 Maximum Fluid Density avoid Collapse of 2nd Casing String Va`~\\ ~\jE" Pcollapse85% - PHydrostatic + PApplied - PGasGradient - PHeader ~~~! 4,599 =( 2,628 * 0.052 *MWmax )+ 1,500 - (0.3952 * 2,628) - 0 ~~IC~ MWmax = 30.3 PPP 3.5 "Tubing 2nd Casing String Size 7 in 3,550 TVD Weight 26 . ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 2,628 ft Gas Gradient 0.3952 psi/ft Max Surf. Pressure 1,500 " psi Header Press 0 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 1,372 * .052 * 18.2 ) Pmax allowable - 1,298 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". ...Intrepid 2 Surface Inj ection Pressures with .gauge at .disposal wellhead and using. annulus friction of 50 MW ( ) Injection Pressure ( si MW ( ) Injection Pressure ( si MW ) Injection Pressure ( si 6.~ 863 ~.~ 72.1 10.E 578 6.9 856 ~.9 713 10.9 571 7.0 849 9.0 ..706 1 l .0 564 _ 7.1 842 9.1 699 1 1.1 557 7.2 835 9.2 692 1 1.2 549 7. ~ 828 9. ~ 68~ 1.1.3 542 7.4 821 9.4 678 11.4 535 7.5 .813 9.5 671 1 l .~ 528 7.6 806 9.6 664 11.6 521 7.7 799 9.7 656 11.7 .514 7.8 792 9. ~ 649 11. ~ 507 7.9 785 9.9 642 11.9 499 ~.0 778 10.0 635 12.0 492 ~.1 771 10.1 628 12.1 485 8.2 763 10.2 621 1 ?.? 478 8. ~ 756 10.3 614 12. ~ 471 .4 749 1.0.4 606 12.4 464 ~.~ 742 10.E 599 12.5 457 ~.6 735 10.6 592 12.6 450 8.7 728 10.7 585 12.7 442 - - _ _ - - - '~, J Cement Detail Report ~I ~r::~. ~ ~ i~ : INTREPID 2 i i.- ~ _ jj ! ' Surface Casing Cement ~~ ~ .. Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10148267 .3/16/2007 4/1/2007 - - 'Cement Details _ __ Description Cementing Start Date Cementing.End Date VJellbore Name Surface Casing Cement Original Hole Comment. Cement Stages - Stac)e # 1_ -- -- Description Objective - Top (ftKB) ~ Bottom (ftK6) FuI1 Return"? Gmnt Rtrn (... Top Plug? ' Btm PIugY Surface cement Clean pipe ~ta`~~j : No No Q (start) (bbl min} Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft} _ Rotated? Pipe RPM (rpm) 5 3 4 292.0 No IVo Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives - _ --- Fluid _ --_ -- Fluid Type Fluid Descriptiwt Estimated Top (ftK6) Est Btm (ftKB) Amount{sacks) Glass Volume Pumped (bbl) CW 100 OA OA Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additir ves _ 8.57. -- _ Additive Type Concentration Conc Unit label jFlufd r•naia type Fluid Description Estimated Top (itKE) Est 3tm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) Push OA OA .d (ft°/sack) Mix H2O Ratio (gal/sa... Free Water (%} Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr1 (psi) 10.00 Additives Additive Type. Concentration. Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 0.0 900.0 110 e~' ~L 89A Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs} CmprStr 1 (psi)- 4.56 1070 Additives Additive - Type Concentration CondUnitlabel Fluid --_ __ - Fluid Type Fluid Description Estimated Top (ftKB) 'Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) 7aii Cement 900A 1,389.0 273 AS1 45.0 Yield (ft'/sack) - Mix H2O Ratio (gal/sa... Free Water (°I°) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.93 15.70 Additives Additive Type Concentration .Conc Unit label Fluid - -- - - Fluid Type Fluid Description Estimated Top (ftKB) 'Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Displacement 0.0 1,268:0 Yield (ft°/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.20 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/10/2007 i _` - ``;, Casing Detail Report r ~~- . ~_ ~ INTREPID 2 ~ ~~ , ~~:.. ;,~ Surface Casing - - - - - --- __ __ Casing Description Set Depth (ftK8) j Run Date I Set Tension (kips) Surface 1,379.2 ~ 4/5/2007 ~ Centralizers Scratchers _ 5 O Casing Components 1 I Mk up Tq ~ ~ Item Descnptlon. OD (in) ~, Wt Qbslff) Grade Top Thread ~ Jts _ Len (fQ Top (ftKB) ~ (ft_Ibs) ~ _ Btm (rtK6) Class Mix OD (in) ID (in) RKB 9 5/8 22.00 0.0 22.0 9-5/8" Hanger 9 5/8 40.00 L-80 1 3.17 22.0 25.2 _ 8.835 Casing Joints 9 5/8 40.00 L-80 1 1,269.02 25.2 1,294.2 8.835 Float Collar 9 5/8 40.00 L-80 i 1 1.92 1,294.2 1,296.1 8.835 Casing Joints _ 9 5/8 40.00 L-80 1 81.37 1,296.1 1,377.5 8.835 Float shoe 9 5/8 40.00 L-80 1 1.72 1,377.5 1,379.2 8.835 I Page 1/1 Report Printed: 4113/2007 Security Level: Intrepid Daily Drilling Report 1NTREPID 2 - ~• Report Number: 13 Rig: KUUKPIK 5 Report Date: 4/5/2007 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) . Depth End (ftKB) Depth Progress (ft) Original Hole Exploration NPRATIGHT HOLE 4/1/2007 4.93 1,388.0 1,388.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE + Sup Amount 10148267 3, 010.00 19, 910.00 121,677.00 1,598,227.00 19, 730, 095.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 1,379.2ftKB 7 3,600.00 Ops and Depth @ Morning Report 24hr Forecast ND diverter ND/ NU Last 24hr Summary Run and cement casing General Remarks Weather Head Count ,Cement job went well Temp 2 F, Wind 8 mph f/NE, WC -8 F 58.0 e~ ~~~~ - - - _. Tom Brassfield Drilling Engineer. Ray Springer Drilling Supervisor Mike Winfree Sr. Drilling Supervisor Mike Winf~ee Jr. Drilling Engineer , Jerry Otto/Truman Knutson Tool Pusher Mike Galvin Construction Sup. - ~Ttrne Log !r,rt -,, ~ ~~~ _ i~~,~ ~- i -r~ i, 00:00 03:00 3.00 SURFAC CASING RNCS P ~ 0.0 0.0 Prep to run casing 03:00 06:00 3.00 SURFAC CASING ° RNCS P 0.0 450:0 Run 9-5/8" casing to 450' stacked out RU and circulate 06:00 08:30 2.50 SURFAC CASING RNCS P 460.0 1,379.0 ConYd to run casing from 460' to 1379. (wash down jt #11) 08:30 09:00 0.50 SURFAC CASING RNCS P 1,379.0 1,379.0 RD/ GBR & RU to circulate 1. 10:30 1.50 SURFAC CASING CIRC P 1,379.0 1.,379.0 Circ and condition mu for cement ,. .J 11:00 0.50 SURFAC CASING CIRC P 1,379:0 1,379.0 RD circ lin RU false rotary 11:00 12:30 _1.50 SURFAC CASING OTHR P 1,379.0 1,379.0 MU XO's pup & stab in tools 12:30 15:30 3.00 SURFAC CASING OTHR P 1,379.0 1,379.0 TIH w/ stab-in assembly to 1237 15:30 16:30 1.00 SURFAC CASING OTHR P 1,379.0 1,379.0 Space out to 1288 RU Circ and cementing equipment 16:30 18:30 2.00 SURFAC CASING OTHR P 1,379.0 1,379.0 - _ PJSM on cementjob. test lines to 2300 psi, pump 10 bbls CW100, 25 bbls mud push, 89 bbls lead, 43 bbls tail,. displace with 10 bbls. full returns throught job CIP @ 18:30 hrs 18:30 19:00 .0.50 SURFAC CASING OTHR P 1,379.0 1,379.0 RD cmthead, PU ti0' screw into TD 19:00 20:30 1.50 SURFAC CASING CIRC P 1,379.0 1,379.0 Circl wash. out knife valve and diverter/ Blow down. 20:30 23:30 3.00 SURFAC CASING OTHR P 1,379.0 1,379.0 POOH 23:30 00:00 0.50 SURFAC CASING OTHR P 1,379.0 1,379.0 LD stab assy. MUp GIICCK Uata I'r,c: ~ I 1-~,r.~ ~,-..c,,, Ill%11'I Jl ~. i?-~.~t, ,. ~ T,..- Depth (ftKh C i..> I ~ „ ~ _ k ~ _ tr ; ,I, - i t L.-~t ~ f'111 ~Ib/bbll ~~ i -" i ~' ..I I ~ I , Wafer Base 1,389.0- 10.00 ~ 55 ~ 16.0 26.000 11.000 18A00 20.000 12.5 9A 60.0 9.0 Water Base .1,389.0 10.00 50 16.0 24.000 9.000 16.000 20.000 12.5 8.7 55.0 9.0 VNellbores -- _ -- - - _ _ Wellbore Name Wellbore API/UWI Original Hole I 50-023-20036-00 --- -- - _ Section ~ Size (in) Act Top (fCKL; Act Btm (ftKB) ~ Start Daie .End Date rKVU l SURFAC COND1 ;Casing Strings _ Casing Description Surface 8 3/4 12 1/4 16 Run Date 4/5/2007 0.0 1,389.0 4/1/2007 0.0 80.0 3/5/2007 80.0 3/6/2007 _ OD (in) Wt (Ibs/ft) Grade Set Depth (ffKBj ~ 95/8 40.00 L-80 .1,379.2 4/3/2007 - 3/6/2007 Comment ~' Latest BOP Test Data - -- Date ~ __ --, - - - _ -__ __-_ Comment _ _-- Page 1/1 Report Printed: 4/6/2007 ~ .~- ,~z~--- -- Security Level: Intrepid ~ ~' Daily Drilling Report ' ; t ~ , ` ~ INTREPID 2 - - ~ ..r..:::- ~~~`~~~ ,~: s~?_ ~ Report Number: 15 Rig: KU UKPIK 5 Report Dater .4/7/2007 Wellbore Well Type Field Name Spud Date DFS (days) " Depth Start (ftKB): Depth End (ftKB) Depth Progress (ft) Original Hole Exploration NPRA TI GH T HOLE 4/1/2007 6.93 1,388.0 1,388.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost. Daily Cost Total Cummulative Cost Total AFE + Sup Amount .10148267 3,010.00 25,930.00 104,990.00: 1,905,325.00; 19,730,095.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB). Surface, 1,379.2ftKB 7 3,600.00. Ops and'Depth @ Morning Report 24hr Forecast Drilling ahead 1898' - Drill ahead to coring point.'.. Last 24hr Summary Test BODE. PU BHA. Test casing. Drill shoe track +20'. Swap mud; FIT ' General Remarks Weather Head Count Temp 0 F, Wind 14 mph f NNE, WC -19 F 57.0 Turn E3rasstield Drilling Engineer Ray Springer , Drilling Supervisor Mlke Winfree Sr. Drilling Supervisor Mike Winfree Jr. Drilling Engineer. Jerry Otto/Truman Knutson Tool Pusher Mike Galvin ! Construction Sup.' Tinrc Log ,~~, OU:00 05:00 5.U0 PROD1 WELCTL BOPS P - --- 0.0 0.0 Test BOI'E. Set wear bushing. -- 05:00 05:30 0.50 PROD1 DRILL DRLG P 0.0 0.0 Re-install floor mats. Mouse hole & elevators. 05:30 06:00 .0.50 PROD1 DRILL PULD P 0.0 0.0 Make up BHA. 06:00 12:00 6.00 PROD1 DRILL PULD- P 0.0 0.0 MU BHA.' Up load smart tools and sources to 500' `~ ~9 13:30 1.50 PROD1 DRILL PULD P: 0.0 0.0 con't MU BHA. PU DC, Jars, DC 1 std .HWDP. 3 15:00 1.50 PROD1 DRILL DHEQ P 0.0 0.0 Surface test MWD @ 450 GPM/1000 psi. OK. Blow, . down TD. 15:00 17:30 2.50 PROD1 BRILL TRIP P 0.0 1,243.0 TIH w/ HWDP from 468' to 1021'. Tag cement at 1243'. - CBU: Blow down TD: 17:30 18:30 1.00 PROD1 - DRILL DRLG P 1,243:0 1,243.0 Test 9-5/8":casing to2500psi for 30 min. OK. Blow down choke/kill lines. ' 18:30 19:30 1:00 PROD1 DRILL DRLG P 1,243.0 1,281.0 Drill cement from 1243'-1281'. Tag float collar. 19:30 20:00 0.50 PROD1 DRILL DRLG P 1,281.0 1,283.0 Drill out float equipmentx WOB 2k 30 RPM ' 500 GPM : ..1000 psi " 20:90 - 21:00' 1.00 PROD1 DRILL DRLG P 1,283.0 1,410.0. Drill cement from 1283' fo 1410'. Displace mud to 9.2 pp9• 21:00 21:30 0.50 PROD4 DRILL FIT P 1;410.0 1,410.0 18 ppg EMW FIT, 9.2 ppg @ 640 psi.: 21:30 23:30 2.00 PROD1 DRILL DRLG P 1 440.0 1,520.0, Drill from 1410'to 1520'. Mud Check D ata - -- Gel (30t i I ~~ ~ ~ _ Corr. ~,.~.,;. fVUater Base i ____,~ ~ _ 1,410.0 9.25 ~ i 58 1 3.0 1 18.000 6.uuu 1uAUU ~Ibf11000 13.Ou0 - ~_.~ I ~ i ~ 8.8 9.5 60A' 5~.5 . Water Base 1,389.0 9.20 54 1 0.0 17.000 6.000 ~ 9.000 10.000 ~ 7.5 9.0 55.0 6.0 Wellbores f Wellbore N;~me ~~ri~;in ~I H'- section ~ - PROD1 - _ 8 3/4 ~ SURFAC 12 1 /4 COND1 16 W Ilbore /,Plr'UWI <+:Z3-20036-00 - - -- tToo {ftl I Act Bfm ,frKB) -. Start Dafe End Dafe 0.0 1,389:0 4/1/200T 4/3/2007 0.0 80.0 3/5/2007 3/6/2007 80.0 3/6/2007 BOP Test Data Da.z ~_ ------- -I-- Page 1/1 ---- --- ------------ -- --- -- Comman[ Report Printed: 4/8/2007 CASING TEST and FORMATION INTEGRITY TEST Well Name: INTREPID #2 Date: 41712007 Supervisor: Michael Winfree m Initial Casing Shoe Test Reason(s) for test: ^ Formation Adequacy for Annular Injection ^ Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-518" L-80 BTC Casing Setting Depth: 1,372' TMD Hole Depth: 1,410' TMD 1,372' TVD Mud Weight: 9.2 ppg Length of Open Hole Section: 38' EMW = Leak-off Press. + Mud Weight = 640 psi + g.2 ppg 0.052 x TVD o.052 x 1,372 EMW for open hole section = 18.2 ppg ~~~~lte Used cement unit NO Pump output = 0.0838 bps Fluid Pumped = 1.4 bbls Rig pump used # 1 Fluid Bled Back = 0.5 bbls z,eoo p:i i z 7oo , ps 2,600 psi i 2,500 ps 400 i 2, ps 2,300 psi 2,200 psi i 2 100 , ps i 2 000 , ps 7 900 i , ps 1 800 i , ps 1,700 psi i W 1,600 ps l o i ~ so ps 7 4 0 i , ps 0 + 1 300 i ~ 1 , ps i i 1 200 200 , Ps ps , 1 i 1, 00 ps 000 i ps 1, 900 psi i 800 ps i 700 ps 600 psi 500 psi 400 l ps i 300 ps l 200 ps i 100 ps 0 psi 0 1o zo STR~KES 4o so 60 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE -------------------i-------___-_-----_r_____---_ ~ __-----__' -0.0 min 0 o si 1.0 min----I-------6.0-------t------~~-ps -----I 2.0 min-- ~------11.0------~-----360 psi---- ! - 3.0 min ---I------16-~------+-----591- psi---- I 5.0 min i 17.0 i 640 psi ~ ----t--------- °----•-------- ---------° , i I '-------------------E------------------±----------------°--~ I i-------------------; ------------------•--------------------; I ~ I I-------------------I------------------}--------------------! .-------------------f------------------±--------------------I i-------------------t------------------t--------------------I ' -------------°---t------------------i--------------------i i I I i ------------------F------------------}--------------------1 I I j-------------------t------------------±--------------------i ------------------.------------------t--------------------I ' I _____________ ___F ----------_-_- -} ________-_------ -) ' SHUT IN TIME ' I SHUT IN PRESSURE! I•------------------t---- - -- -- O.O min I I 3i, l.isl ; I ---~ ----1.0 min-- ---------------- -----609 psi - I ,-----2.0 min----'------------------~-----604-psi-- --i j-------------------E------------------+--------------------i 3.0 min 595 psi i.__. 4.0-min ----I ------------------i-----591-psi---- I }--------------~--_--I 5.0 min r------------------I 586 sl i-------------------;------------------~----------p ------ 6.0 min 586 psi I ---~ ----7.0 min----j------------------~-----581 psi ~ ' ----------E------------------+--------------------I j 8.0 min i i 581 psi P------------------t---------___------~--------------------i I 9.0 min 577 psi - ---I------------------+--------------r-°-I -- ------------- ' 10.0 mu-: t I---- 572 psl i I-------------------=------------------- ---------° CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r__________________T__-__-__-__----_-_,-_-----_-__________-, 0.0 min 0 stks 0 psi ; ~ 1 0 min i 5 stks { 360 psi i I ~_ ' i----2 0 min ---j ---10 stks---~-----718 psi ---- 3.0 min 1 15 stks 1,077 psi 4 0 min -1 20 stks 1 1,436 psi -~ 5.0 min 25 stks i 1,795 psi i ---~--------------------I - - ---- --------------- 6.0 min ~ 30 stks ~ 2,154 psi t------------------+- , 7 0 min ; 35 stks i 2,513 psi ; i i i i E------------------a------------------}--------------------! frf------------------1------°----------~--------------------~ F------------------i------------------i--------------------I ' I i i ---------°-------i------------------i--------------------t __________________~__-_____-_________i____--------_______-i I ~ ' E---------------'--~----__---_----_---~-----_-___-_----_--- i i --------°--------i------------------i--------------------I ~ ~ i I SHUT IN TIME ,SHU71N PRESSURE; ------ ------------------a______-- ---------i 1.0 min i 2 513 psi I r°------ ------~------------------~----2,509 psi ---I ~---- --- -~-------------°---~----2,504 psi ---, ------i------------------t-------------------- ---- I 1 2,500 psi ~ E------------------+------------------+------------------- 2,499 psi ~------------------;--------------------I ------------------ f 6.~ n1ui ! I 2,495 psi I ___.- ---~------------------~_-__------------"---I 7 O rnui 2,490 psi I ' ------------------~------------------~----2,490 psi ---i ~------------------j------------------i--------------------i - 2,486 psi I --------------~------------------+- - ------i E---- I I 2,486 Psi i ~----.--------------;------------------~- 2,477 psi---! I ------------------i------------------+--------------------! ~ Zu.u n~iin 2,463 psi 2..~ 11~In 1 --------- 2,458 psi ---1-----•--------- --~--------------------I --------------- - ---3C-;; ,;,i i __ 2,449 psi NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scott Reynolds - - TIME LINE ONE MINUTE TICKS - tLEAK-OFF TEST tCASING TEST LOT SHUT IN TIME +CASING TEST SHUT IN TIME +TIME LINE ^~ ~~ , ~ f ~ `~ Casing Detail Report / ` INTREPID 2 .; ;.~ Production Casing Casing Description Set Depth (ftKB) Run Date et Tension (kips) Production 3,516.4 4/14/2007. ~ _ Centralizers Scratchers 2 0 Casing Components _ ~ Mk-up Tq Item Description OD (in) ~ Wt (Ibslft) Grade Top Thread Jts - Len (ft) Top (ftKB) 6tm (ftKB) (H-Ibs) Class Max OD (In) ID (in) RKB 7 1 19.60 0.0 19.6 7" Casing Hanger 7 1 1.56 19.6 21.2 Casing Joints 7 26.00 L-80 1 9.85 21.2 31.0 6.276 Casing Joints 7 26.00 L-80 1 43.43 31.0 74.4 6.276 Casing Joints 7 26.00 L-80 79 3,355.25 74.4 3,429.7 6.276 Float Collar 7 1 1.30 3,429.7 3,431.0 Casing Joints 7 26.00 L-80 2 83.94 3,431.0 3,514.9 6.276 Float Shoe 7 1 1.48 3,514.9 3,516.4 Page 111 Report Printed:. .4/16/2007 '~ ' ~~ `~1 Cement Detail Report INTREPID 2 .Production Casing Cement Primary Job Type DRILLING ORIGIN AL Job Category DRILLING AFE / RFE 10148267 Start Date 3/16/20 07 Spud Date 4/1/2007 End Date - Cement Details - - - - __ Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 4/14/2007 04:50 4/14/200717:00 Original Hole Comment Cement Stages _ - - __ _ _ - i Stye # 1 _ _ _ _ Description Objective Top (ftKBj Bottom (ftK6) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Production Casing Plug off Neocomian 2,680.0 3,516.4 Ye s No No Cement sands on production string. Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement Fluids 8~ Additives -- -- - -- -- - -- - - Fluid _ - --- _ Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) _ _ Class 'Volume Pumped (bbl). Preflush Yield (ft'/sack) . Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gaQ Plastic Viscosity (cp) l'hiekening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label -- Fluid - - _ _ _ - - _ _ - Fluid Type - --- -T Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl). Mudpush Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label - _ Fluid - _ - -- - - __ _ _ ___ Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Production Cement 2,628.0 3,516.4 194 G 40.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.09 Additives Additive Type Concentration Conc Unit label Fluid _ Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) _ Class Volume Pumped (bbQ- Displacement Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening. Time (hrs) CmprStr 1 (psi) Additives _ Additive Type Concentration Conc Unit label Page 1/1 Report Printed:. 4/16/2007 ~ -~- ~~ Security Level: Intrepid ~'~ ~ ~ Daily Drilling Report '~ ~ INTREPID 2 ,, Report Number: 22 Rig: KUUKPIK 5 Report Date: 4/14/2007 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftK8) Depth fnd (ftK8) Depth Progress (ft) Original Hole Exploration NPRA TIGHT HOLE 4/1/2007 13.93 3,550.0 3,550.0 0.00 AFE / RFE /Maint.# Daily Mud Cost C ummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE + Sup Amount 10148267 2,392.50 43,912.50 733,916.32 19,625,853.74 19,730,095.00 Last Casing String N ext Casing OD (in) Next Casing Set Depth (ftK8) Production, 3,516.4ftK6 Ops and Depth @ Morning Report 24hr Forecast. UD 4" DP L/D 4" Dp and 4" HWDP, Cement'top of 7"casing. Last 24hr Summary Run 7" casing to 5416.41' TVD and cement with 40 bbls 15,7 ppg class "G" cement, General Remarks Weather Head Count No Accidents or Incidents, No Spills.. Temp 1 F, Wind 12 mph f SE, WC -15 F 59.0 Supervisor Title Tom Brassfield Drilling Engineer Ray Springer Drilling Supervisor Dink Heim Drilling Supervisor Brian Hope Drilling Engineer Ted Peter Tool Pusher Mike Galvin Construction Sup. 'Time Log _ Start End Dur ~ - - ~ Time ~ 'Depth Start Depth End -- N T ~ - Trbi code Trbi class... _-- aton (ftKg 00:00 04:00 4r00 PROD1 EVALFM DLOG P L/D same and collect. 2900.0 0.0 .POOH f/ 2900' to wirel ne tools samples f/ tools. 04:00 06:30 2.50 PROD1 CASING RURD P 0.0 0:0 Change top rams to 7", P/u test jt., pull wear ring and M/U test plug. Shell test to 250 psi low, 2500 psi high for 5 min. L/D test plug and test jt. 06:30 08:00 1.50 PROD1 CASING RURD P 0.0 0.0 R/U to run 7" casing hold PJSM. 08:00 13:00 5.00 PROD1 CASING RNCS P 0.0 3,495.0 Run 7" casing to 3485'. (82K up WT) P/U 9.85 ft pup joint and RIH to 3495'. 13:00 16:00 3.00 PROD1 CASING RNCS P 3,495.0 3,516.4 P/U hanger and landing jt. M/U circ head and wash down casing f/ 3506 to TD @ 3516.41'. Circ while ~ making up cement head. 16:00 18:00 2.00 PROD1 CEMENT PLUG P 0.0 0.0 PJSM, Pump cement job, 2bbls H2O,/ Test lines to 3000 psi, .Drop plug, Pump 20 bbl 12 ppg Mudpush/ 40 bbl 15.7 ppg class "G" CMT, Drop plug /Pump 10 bbl H2O & Displace w/ 118 bbl mud. Full returns throughout job. 18:00 20:30 2.50 PROD1 CEMENT RURD P 0.0 0.0 Blow lines dwn, R/D cement head, R/D manifold, Backout landing jt./ Wash down rig floor, UD side doors, bale exts, P/U Hyd Elev & UD all subs. 20:30 23:00 2.50 PROD1 DRILL OTHR P 0.0 0.0 Drain and wash stack, P/U test jt., Pack off, RIH & test to 5000 psi. 23:00 00:00 1.00 PROD1 DRILL OTHR P 0.0 1,243.0 RIH open ended to 1243'. Mud Check Data __ _ _ _ Type ~ Depth (ftK8) Dens (Ib/gal) Vis (s/~ PV Ca_Ic (cp) YP Calc Qbfl100ft~) Gel (10s) Gel (10m) (Ibf/100ft~) (Ibf/t00ft~) Gel (30m) ~ Qbf1100ft~) HTHP Fil[ MBT Qblbbl) (mU30min) pH Densty Temp ~ Solids, Corr. ('F) i, (%) KC I/KLAG.. ~ 3,550.0 9.80 76 ~ 21.0 24.000 6.000 7.000 8.000 10.0 9.0 74.0 ~ ~ Wellbores Wellbore Name Wellbore API/UWf Original Hole 50-023-20036-00 _ Section Slze (In) _ --- - Act Top (ftK8) -_. Act Btm (ftK8) Start Date _ End Date '~ - - _.-- ~ T-- - PROD1 8 3/4 SURFAC 12 1/4 0.0 1,389.0 4/1/2007. 4/3/2007 COND1 16 0.0 80.0 3/5/2007. 3/6/2007 Surv~ Data ir;oi (°) Mo ~n Azm (~) rus art) E=w (a) Des (°i~ooft> _ vs eft) Tv~ 0 __ 8 550.00 15. 1.00 ~ 28.15 27.44 -6.29 0 3,549.81 00 Latest BOP Test Data ' Date _ j Comment Page 1/2 Report Printed: 4/16/2007 ~'~~`- ~-~--. Security Level: Intrepid ~ f` ~~~ ``'', J Daily Drilling Report. ,~ r . INTREPID 2 ~ ~~ Report Number:. 22 .. ~,~ •~ Rig: KUUKPIK 5 - _ -- Report Date: 4/14/2007 _ Casco Strm s _ 9 9 __ _ _ _ _ te Casing DescriUGon ~ OD (In Wt ~ Grade Set Depth __- > / (ftKB) Comment 4~14~2007 PrOCIUCtI01l ~ 26 0~ L-80 I 3, 516.4 Cement _ _ _ - - - - Production Casin Cement -Started 4/14/2007 Type Wellbore String CemenYEvaluation Results casing Original Hole Production, 3, 516.4ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Production Casing Cement 2,680.0. 3,516.4 Ruid Class - Amount (sacks) i V (bbl) Density Qblgal) ! - _ - Yield (ft~/sackj ~. Est Top (ftKB) I, Est Btm (ftKB) Preflush Mudpush , Production Cement G 194 40:0 1.16 2,628.0 3,516.4 Dispiacement I Page 2/2 Report Printed:. 4/16/2007 CASING TEST and FORMATION INTEGRITY TEST ~ ~ Well Name: Intrepid #2 Date: 4/15/2007 Supervisor: Brian Hope ^ Initial Casing Shoe Test Reason(s) for test: m Formation Adequacy for Annular Injection ^ Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" L-80 40# X 7" L-80 26# Casing Setting Depth: 1,372' TMD Hole Depth: 1,372' TMD 1,372' TVD Mud Weight: 9.8 ppg Length of Open Hole Section: 0' EMW = Leak-off Press. + Mud Weight = 620 psi + g.g ppg 0.052 X TVD 0.052 x 1,372/' (,t EMW for open hole section = 18.5 ppg v ,~,y~\`~ ~~+ Ewa ,.,.m,..., ....., _ ~~~ ruiup uu~put = v.vaiu ops Fluid Pumped = 5.1 bbls LEAK-OFF DATA CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0.0 min ~ 0 stk~ 0 t,si ----------i------------------i----------°--------I ~ 1.0 min 10 stks 452 psi r------------: --- ------------- ; - --884 si ` 2.0 m;n 20 stks - - - ----1------------------'---------- p-------t 3.0 min 30 stks 1,220 psi }------------------i------------------i--------•-----------I 4.0 min 40 stks ; 2,425 psi - --------- ` 5.0 min 46 stks 3,550 psi , F------------r-----i----------------- i--------------------I 6.0 min ; ; 7.0 min ; ~ E----8 0 min---- -------------------------------------! ----------------- a------------------{--------------------~ 9.0 min ~ ' , ; --------- ---------------------------;--------------------f 10.0 min F------------------i------------------+--------------------I 11.0 min t 12.0 min ; ; I 13.0 min i------------------i--------------------I I 14.0 min---------------------~- 15.0 min i - --------~------------------~--------------°----I 16.0 min 17.0 min ~ ; ; -------------i------------------i--------------------I I 18.0 min I ; 190m1n ; ------------------ , UT INTIME ; SSURE; , SHUT IN PRE ; ('~.~ il~i; ~ -- j t - -___---____--1__________________t--__ --_-__-----__--, -----i------------------f--------------------~ G------------- ; ~ 3,534 psi ' ~ ~ ; 3,530 psi , _ I 3,528 psi ` - - --1------------------ I----~-- --,--- t----3,521---si--- --------------+---- -------p------! ----5 0 min --'---- 3 518 psi j t----°------------~------------------1-----~--------------' 0.0 min 3,515 psi ------------------i------------------i--------------------! ~---? 0 min -- ; 3,511 psi ; 8.0 min i j 3,508 psi ; r---- ----°-----°i------------------f--------------------I 9.0 min ; p ; ~ 3,506 si , 10.0 min ; 3,503 si ~ -----------°-----~------------------~---- -------p------~ 15.0 min ~ 3,492 psi ~------------------~------------------~--------------------I 20.0 min ; 3,482 psi ' ----------------'------------------'---°----°---------f I 25.0 n, in 3,472 psi ~--- ~-------------i------------------j--------------------~ r ; - 3.464 psi NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY • I ~ ~ Moditied bV Sco[Y Reynolds MINUTES FOR LO7 STROKES PRESSURE NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above CASING TEST and FORMATION INTEGRITY TEST .,, Well Name: Intrepid #2 Date: 411 512 0 0 7 Supervisor: Brian Hope ^ Initial Casing Shoe Test Reason(s) for test: m Formation Adequacy for Annular Injection ^ Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" L-80 40# X 7" L-80 26# Casing Setting Depth: 1,372' TMD Hole Depth: 2,628' TMD 1,372' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 1,256' EMW = Leak-off Press. + Mud Weight = 462 psi + g,g ppg 0.052 x TVD o.os2 x 1,372' EMW for open hole section = 16.1 ppg ~/Gli~~{ l Ico Used cement unit yes Pump output = bbls pumped Fluid Pumped = 21.4 bbls Rey N~~~~N ~ - goo i Ps 600 psi 1 ~O `~ ~~~ 500 i TIME LINE - ps ONE MINUTE TICKS i 400 l(~ << E kvJ vl lJJ Ps _--- -~ - tLEAK OFF TEST ~ ` - r7i ~< + ~ «• tCASING TEST w ~ soo LOT SHUT IN TIME p:~ -CASING TEST SHUT IN TIME 200 i +TIME LINE ps t i 00 Ps i 0 Ps o to zo STR~KES ao sc. fio NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE ------------------r_.-______--_----_-1 ___---_-__-i ' 0.0 min ; 0 32 psi i-------------------t-------0.5 ------t-----407-psi-----I i 1.0 min I-----2.0-min ----(-------~ -2-------i-----462-psi----- i 3.0 min 1.6 i 471 si i i-------------------t•------------------4----°---- p -------I ; 4.0 min t 2.0 485 psi ----5.0 min-- ~-------2.4 ------i-----481-psi---- i-------------------+------------------t--------------------I i 6.0 min I 3.1 485 psi 7.0 min 3.5 490 psi i ----5--------------r----t i 8.0 min i 4.2 ; 499 psl I i 9.0 min ; 4.6 494 psi i ' 10.0 min---~-------5.0 ------~-----481 psi j-------------------i------------------}-----aei -- si-----i 11.0 min I 6.1 p 12.0 min j 6.9 481 psi i -------------------r------------------±--------------------i ~ 13.0 min i - 8.8 504 psi 14.0 min 10.3 467 psi 15.0 min---~----- 12.2 ~ 504 psi ~-------------c-----E------------------±-----504-- sl-----I 16.0 min 14.4 p ; 17.0 min 16.3 - 494 psi j ---------t------------------I- p ----( 18.0 min j 18.0 504 si I ----19.0 min---.----- 20.1----- ----458-psi--- I-------------------`------------------.------------------- 20.0 min ~ 21 4 462 psi ; -------------------}---------------°-}--------------------I i_ - 21.0 min----1------------------~- 22.0 min i i-------------------1....................................;....................................... { 23.0 min 1 i t I -SHUT IN TIME --f- ------------}SHUT IN PRESSURE i ---------- ----- --------- 0 0 min t-------------------~------------------t---------- --------p 1.0 min } 362 pst 2.0 min I 352 psl ----- ------°-----F------------------4--------------------I 3.0 min t ----------------I- 348 psi ; I -------------; -- ~ -------------------' i __ 348 psi -------------~------------------t--------------:----- I 343 psl -------------------~------------------t-----343-psi-----' I-------------------t------------------'-------------------- ZO min I 343 psi I i----- ---E------------------+--------------------I ----------- I ~S 0 min I I- 339 psi i I-------------------'_-____------------•- ----------t i J.0 min i ? 339 psi I '---------------•---1------------------1--------------------I I 10.0 min I i 339 si p ; i---------------•----------------------•-------------------° CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0.0 min ; 0 stks i 0 psi ' ------------------i------------------i--------------------1 1.0 min I F-------- --- - -------------- -----°----------- 2.0 min ----3 0 min- ~------------------,--------------------i ~----4 0 min----a------------------j--------------------i 5.0 min ~ ' ~----6 0 min----i------------------i--------------------t 7.0 min ! ' I 8.0 min i i i ---90min i x----10.0 min---a------------------~--------------------~ }------------------i------------------~--------------------I 11.0 min 12.0 min ! i -------------i------------------t------°------------1 ', 13.0 min I t ; 14.0 min ----- 15.0 min I I ~---------°-------i------------------~--------------------I i 16.0 min ; ; -- -- 17.0 min ; ~-------------: ----j------------------~--------------------I 18.0 min i 19.0 min i I I h------------------ i SHUT IN TIME ; ,SHUT IN PRESSURE; (... i~. F------------°----i------------------~--------------------I I I r------------------~---------°-------»--------------------i I ---------------°-i------------------i--------------------1 ------------°----+------------------7------------------- 5.0 min i I ---- ----~------------------'--------------------~ 60 min , ~------------------~--•--------------- j--------------------I Z,: min ~ ~ I I - ---------;--------°--------~--------------------i ~------------------j------------------~--------------------i `~ i - - i' t F--- 1-r---------- ~- -------------- - ------------------ ---1-------- I I I -----a------------------~--------------------! i G'... , i 1 I t--- ~,.------------~------------------~-------------_--_-_-t i ~_ r ! i ; ~------------------~------------------±--------------------I NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ! Modified by Scott Reynolds Intrepid 2 Schematic ~i i~ 9 5/8", 40# L-80, BTCM @1372' MD Cemented to surface 1850' M D ~~ 2040` MD Insignificant sand intervals.. ~ 5 ~ 2160' MD .9 TOC estimated @ 2628' MD 15.8 ppg "G" TD @ 3550' MD 3.128' MD Neocomian Sand 3165' MD 7", 26# L-80, BTCM @ 3516' MD 4/1.6/2007 Intrepid 2, 206-190, Form 10-403RD Subject: hltrepid 2, 206-190, Form 10-403RD From: "Hayden, Philip" <Philip.Hayden@conocophillips.eom> Date: Mon, 16 Apr 2007 14:39:01 -0800 Tv: Thomas Maunder ~_-tom rnaundcr(~r`admin.stat~.ak.us=~° Tom, As per our telephone conversation. please be advised that the wording in the 10-403RD form, block number 15 for the above well should have read as follows: "Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations, and other substances that the commission determines on application are wastes associated with the act of drilling a well permitted under 20AAC25.005." Regards Philip 1 of 1 4/16/2007 3:11 PM • • Note to File Intrepid #2 (206-190...307-131 } Exploration ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface using a DP inner string. No problems were reported. 50 bbls of cement were returned to surface according to the CPAI Engineer. Cementing using the DP allows tight volume control to help reduce waste production at the remote exploration well. According to the spreadsheet, 14% XS cement remained in the well. -- On the initial leak off test, once fluid is compressed, the pressure rises smoothly to 18.2 EMW. Minimal fluid was pumped in. The pressure declined during the observation period to about 17.2 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at a calculated18.5 EMW. Pump in pressure declined to 16.5 EMW.' During the observation period, the pressure declined to 14.2 EMW. A 2nd pump in tests was conducted. Pump in occurs at about 16.1 EMW and ranges as high as 16.5 EMW, essentially in agreement with the initial test. During the 2nd observation period, the pressure declined to 14.3 EMW. Although the initial pump in calculates greater than the initial FIT, it is probable given the uncertainties of the annular fluid column that the EMWs are equal. Once pump in is achieved, the EMW is fairly steady and essentially equal for both pump in tests. The final pressure after the 10-minute observation period is similar for both pump in tests. If the fluids were not confined, the EMWs during pump in and at the end of the observation period for the 2nd test would be lower than first observed. --There are no wells within'/4 mile of Intrepid #2 Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Y V L. Tom Maunder, PE Sr. Petroleum Engineer April 16, 2007 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\070416--Intrepid #2.doc • • Note to File INTREPID 2 (PTD 2061900) April 16, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Exploratory Well Intrepid No. 2 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of Intrepid No. 2 ("Intrepid 2"). Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set at 1,372 feet measured depth ("MD") and about 1,315 true vertical depth subsea ("TVDSS"), within a thick sequence of distal claystone and shale assigned to the Nanushuk and Torok formations that will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the annulus of Intrepid 2 to accept the proposed injected fluids. 3. Shale and claystone of the Torok formation and claystone and shale of the High Radiation Zone ("HRZ") are sufficiently thick and persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular injection activities will be limited to a radius of about 95 feet from the wellbore. Discussion CPAI's application was reviewed along with records from Intrepid 2. The discussion that follows is based on well and mud logs from this well. An index map is provided, below. The proposed injection interval in Intrepid 2 lies in the Torok formation in the southeast portion of Section 11, T19N, R20W, UM. The 9-5/8" surface casing shoe of Intrepid 2 lies at a depth of about 1,315 feet TVDSS within a thick sequence of distal claystone and shale assigned to the Nanuk and Torok formations. This casing string has been cemented to surface. Above the casing shoe, the aggregate thickness of the claystone and shale intervals exceeds 1,000 feet, and these are of sufficient thickness and lateral extent to provide confinement and prevent upward migration of injected waste. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to be at about 2,570 feet TVDSS. The most likely portions of the open annulus that will accept injected waste are four very thin beds of silty sandstone and sandstone that lie between 1,829 and 1,853 feet MD (1,773 and 1,796 feet TVDSS). These beds range in thickness from 1 to 3 feet, have an aggregate thickness of about five feet and an average calculated porosity of about 15%. Two additional sandstone intervals lying between 2,041 and 2,166 feet MD (1,984 and 2,109 feet TVDSS) with an aggregate thickness of four feet may also receive injected • Intrepid No. Note to File • April 16, 2007 Page 2 of 3 wastes. These potential receiving zones are separated and underlain by numerous claystone/ siltstone intervals that will provide lower confinement for any injected wastes. In addition, the carbonaceous claystone and shale of the HRZ, which lies between ?,664 and 2,693 feet MD (2,607 and 2,636 feet TVDSS), are of sufficient thickness and lateral extent provide additional confinement to ensure that none of the injected waste fluids migrate downward. Figure 1. Index Map The operator's application reports the base of permafrost occurs at about 950 feet TVDSS in this area, which is more than 800 feet above the top of the proposed injection intervals. The shallow geologic section in the area surrounding Intrepid 2, including the potential receiving zones, contains methane gas. Mud logging records from Intrepid 2 indicate that traces of methane were first measured at about 160 feet TVDSS. Heavier gasses (C2 through C4) first appear between 4l0 and 640 feet TVDSS. The only porous beds within the shallow section are the very thin turbidite beds of silty sandstone and sandstone. These beds range from only I to 3 feet in thickness and are likely of limited lateral extent. They cannot be considered significant hydrocarbon-bearing intervals having commercial potential. There are no USDW aquifers local to the Intrepid No. 2 area. All sandstone beds present below the permafrost are very thin, silty and gas bearing. They are situated at a depth and location that makes recovery of water for drinking water purposes economically impractical. The following chart provides an estimate of the affected receiving area surrounding the Intrepid 2 wellbore. Assuming a 9-foot thick injection zone with 15% porosity and a maximum of 5,000 barrels of r~ u Intrepid No. 2 Note to File April 16, 2007 Page 3 of 3 injected waste, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of about 95 feet from the wellbore. Injected Fluid vs Affected Distance from Intrepid No. 2 Wellbore (assumes 9-foot thick zone having 15% porosity) 300 250 m m m `0 200 a m 3 __ _ E 0 150 - . d v m 'o m 100 ~ - ---- ~ .~ ~ ... --.- --. °' ~ ~ ~' Q 50 0 J~-_ __ _ _ - - _ - - 0 5,000 10.000 15.000 20.000 25,000 30.000 35.000 Amount of Injected Fluid (barrels) Figure 2. Intrepid No. 2 -Radius of Potentially Affected Injection Zone The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 950 feet of permafrost, and is bounded above and below by continuous layers of claystone and shale. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations. The proposed injection zone is located more than 1,500 feet from any external property lines, so correlative rights will not be a concern. I recommend a oval of this annular disposal project. Steve Davies Senior Petroleum Geologist n u Intrepid 2, 206-190, Weekly update 4/16 Subject: I~it7-epid 2, 2Ofi-190, Weekly update 4/16 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> Date: Mon, 16 Apr 2007 13: X8:47 -0800 To: 1 hom~is ~1~iunder --torn maunder;~t?aclmin.~tate.~~l~.us> Drilled 8 3I4" hole from 2965 to 3128' MD ~~ ~ ~~~ PU coring assembly and RIH. Gored from 3128 to 3188' MD. Drilled 8 314" hole from 3188 to 3550' MD TD. Gampleted data acquisition program with aline and DP canveyed logs. Ran & cemented 7" casing at 3516' MD. RIH with DP and pressure tested 7" casing to 3500 psi far 30 minutes, OK. Perfarm annular injection test with leak off at '18.5 ppg EMW. Repeated injection test with leak off this time at 16.1 ppg EMW. Begin ND BOPS and preparing far rig move If you have any questions please let me know. Regards Philip 1 of 1 4/16/2007 1:40 PM ~~Q~[~ 0~ p~l~~~tG~ / ,.A..M,.~o.~.,. va~L'a~7~ OI~ ~ v0-7 333 W. 7th AVENUE, SUITE 100 CO1~SC' RQATIOIQ COrII~iISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Exploration Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Exploration, Intrepid 2 Sundry Number: 307-130 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of April, 2007 Encl. ~inrPrPl~r ~~ ~//~~ ~ ~ ~ %~ - ~ ~ RECEIVED STATE OF ALASKA ,~,_. ALAS OIL AND GAS CONSERVATION COMMIJ ION . i~yi1e APR 1 6 2001 APPLICATION FOR SUNDRY APPROVALS 20 AAC 2s.2so Alaska Oil & Gas Cons. Commission 1. Type of Request:. Abandon ^~ Suspend ^ Operational shutdown ^ Perforate ^ Waiver nc orage 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 Well Class: 5. Permit to Drill Number: Conoco Phillips Alaska, lnc Development ^ Exploratory ^ ! 206-190 3. Address: Stratigraphic ^ Service ^ 6. API Number. P.O. Box 100360 Anchorage, AK 99510-0360 50-023-20036-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q ~ Intrepid 2 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): NSB 1-2 Gas Lease; ASRC SW-2 Oil Lease , 21 Exploration ' 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3550 3550 3550 3550 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 100' 100' 3280 630 Surface 1359' 9.625" 1379' 1379' 5750 3090 Intermediate - - Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^~ ' ~ Development ^ Service ^ 15. Estimated Date for 4/14/2007 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged Q ~ Abandoned ^~ 17. Verbal Approval: Dat ,w. /1 4/13/2007 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder ~Y~ ~ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Chip Alvord Title Exploration Team Leader Signature Phone 265-6120 ate ~_ 4/13/2007 ~ ~ ~ COMMISSION USE ONLY Conditions of approval: N tify Commission so that a representative may witness Sundry Number: O 1 Plug Integrity ~ .BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ _ r Other:. ~C~"~CA~~ ~V~pfC.~p~ "~ W ~~'~SS ~~1t-O~~ ~~O~~C.~l'~.1~~ CvTCs~~ \Cilt Subsequent Form Required: ~~h ~ ~ ~# ~ ~ ~~~7 APPROVED BY _ //~~~ A roved b COMMISSION Date: / : O MISSIONER THE ~ pp y . % Form 10-403 Revised 06/2006 Submit in Duplicate • ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360. April 13, 2007 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry approval to Plug and Abandon Conoco Phillips Intrepid 2 Surface Location: 2406' FSL, 1750' FEL, Sec. 11, T19N, R20W, UM Target Location: 2406' FSL, 1750' FEL, Sec. 11, T19N, R20W, UM . BHL: 2406' FSL, 1750' FEL, Sec. 11, T19N, R20W, UM CONFIDENTIAL Dear Commissioner: i' ConocoPhillips Alaska, Inc. would like to permanently plug and abandon the Intrepid 2 wellbore. Kuukpik Rig 5 spud this well on 4/1/07 and TD'd the well on 4/12/07. ' The attached Sundry and back-up information describes the P&A procedure for the existing wellbore and has been discussed with AOGCC personnel If you have any questions or require any further information, please contact me at 265-6481 or Chip Alvord at 263-6120. SRRincerely, 1~~ Philip den Drifting Engineer • Intrepid 2 P&A Procedure CONFIDENTIAL Revised 4/13/07 Intrepid 2 Wellbore Status The 9-5/8"surface casing was set at 1379' MD/TVD and cemented back to surface. The Intrepid 2 well was drilled to TD @ 3550 MD/TVD on 4/12/07. The proposed P&A procedures are as follows. 1. Notify AOGCC 48 hours in advance of all well P&A operations. Hold pre-jab meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Rig up casing running equipment. Run the 7" 26# L-80 BTC-M to TD. Casing will be as follows: 7" 26# BTC-M Float Shoe 2 jts. 7" 26# L-80 BTC-M casing 7" 26# BTC-M Float collar 7" 26# L-80 BTC-M casing to surface Run one bowspring centralizer every other joint from TD to TOC, 500' above the Walakpa sands. Centralizers on shoe joints should be installed mid-joint on stop rings. 3. Circulate with mud at the maximum possible rate until returns are clean, monitoring loss rate vs. circulation rate. Circulate 2-3 annular volumes. Reciprocate while conditioning and cementing as hole conditions permit. 4. RU Dowell cementers and ensure the rig-up configuration permits a seamless transition between fluid types. Test cementing lines with water and flush with mud to overflow (slop) tank. DO NOT PUMP WATER AHEAD OF SPACER IF IT CAN BE AVOIDED. 5. Pump the following cement job: 10 bbls water to pressure test the lines 20 bbls MudPUSH II spacer (12.0 ppg) 200 sx (40.1 bbl) 15.8 ppg Class G w/additives (may be revised based on log caliper) ~~oJS~~~ `~ 1.16 ft3/sx yield i ~~.. 6. Kick out the wiper plug and displace cement with 9.8 ppg mud. Displace at 5 - 7 bpm and ~~~~~ ~~~~ position the casing shoe on bottom when spacer reac i~shoe. 7. At 9 bbls prior to calculated plug bump, reduce pump rate to 3 bpm. Pump until plug bumps but do not over displace. 8. WOC 4-8 hours to let cement build adequate compressive strength. 9. RU to pump down the 9-5/8" x 7" annulus. Pump 100 bbls of water to flush annulus and verify infectivity, note rate and pressures. If permission has been granted for annular injection then proceed to dispose of permitted waste fluids down the annulus. After annular disposal is complete proceed to bullhead the annulus with cement. The order of pumping should be as follows: 80 sx ASLite @ 10.7 ppg Remaining sx of Class "G" cement @ 15.8 ppg Remaining sx of AS1 @ 15.7 ppg with a minimum bottom-of-cement at 1065' MD Annulus capacity = 0.0282 bbl/ft (7" x 9-5/8" 40#) 10. Test the production casing to 3500psi for 30 minutes for the AOGCC required integrity test. Record test on a pressure chart for well files and note results on the morning report. Notify Anchorage office if pressure loss is greater than 10% in 30 minutes. Bleed off pressure. Ensure. adequate WOC time has elapsed for compressive strength development. 11. RIH to 561' MD. Spot a 10 bbl high visc pill from 561' MD to 300' MD. Spot a 300' plug (11.5 bbl) of 15.7 ppg Arctic Set I cement plug from 300' to surface in the 7" 26# casing. PH 4/13/07 • Intrepid 2 P&A Procedure CONFIDENTIAL Revised 4/13/07 12. RD and move out rig, 13. Cut off wellhead and all casing. strings at 3 feet below ground level. Verify cement is at surface in all strings. Send casing head with stub to Materials for repair/redressing. 14. Weld %" thick cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top. Drill 1/8" weep hole in cover plate. • Conoco Phillips Alaska, Inc. • .Intrepid 2 • PTD# 206-190 • API# 50-023-20036-00 15. Remove cellar. Back fill cellar with gravel as needed. Clear ice pad location and demob all materials/equipment. Call agencies for final inspection. PH 4./13/07 • Intrepid 2 Proposed P&A Plan 2 ~ l ~w~c,,tc~ ~' ~ ~t c ~ c~ 5~~ Surface cemenf plug (15.7 ppg AS1) from 5' below GL to 300' MD minimum set on Annular cement squeeze after viscous. pill annular disposal of waste fluids (15.7 ppg AS1 / 15.8 ppg „G„) ~~ ~- t1o U~= 15.8 ppg "G" w/50% excess or as indicated by logs 9 5/8", 40# L-80, BTCM @ 1379' MD Cemented to surface 1850' MD 2040' MD Insignificant sand intervals '~ 2160' MD TOC @ 2628' MD 3128' MD Neocomian Sand 3165' MD 7", 26# L-80, BTCM @ TD TD @ 3550' MD 4/12/2007 Subject: Re: [Fwd: Intrepid 2, 206-190 planned P&A] From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Fri, 13 Apr 200715:12:37 -0800 To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> CC: Stephen Davies <steve_davies@admin.state.ak.us> Philip, Thanks for the logs. Steve has examined and concurs with CPAI's assessment. You may proceed with your plans. As discussed on the phone, we will look for a annular disposal sundry early next week. Call or message with any questions. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 4/13/2007 10:33 AM: We have a copy of the mud log and the recorded LWD data on it's way over to you. Part of the density/neutron log over the reservoir is missing but if this is important we can work on getting this information to you as well, it would take a little longer. I am waiting for a reply from our geoscience people for your question on the extent of the sandy intervals as I don't want to put words in their mouths. I will get back to you on this a soon as possible. Regards Philip -----Original Message----- From: Stephen Davies [mailto:steve davies@admin.state.ak.us] Sent: Friday, April 13, 2007 10:21 AM To: Hayden, Philip Cc: Thomas Maunder Subject: Re: [Fwd: Intrepid 2, 206-190 planned P&A] Philip, Tom's right. Could we please get copies of the mud log, resistivity and porosity logs for review prior to making any plugging decisions? Also, what is the basis for the statement that the sand intervals are of no significant extent? For annular disposal, you will need to demonstrate conformance with 20 AAC 25.080. Thanks for your help, Steve Davies AOGCC 793-1224 Thomas Maunder wrote: Philip, I left you a message. This acknowledges receipt of you proposal. Is it possible to look at the mud log and any other logs of these intervals? Tom Maunder, PE • • AOGCC -------- Original Message -------- Subject: Intrepid 2, 206-190 planned P&A Date: Thu, 12 Apr 2007 14:28:98 -0800 From: Hayden, Philip <Philip.Hayden@conocophillips.com> To: Thomas Maunder <tom maunder@admin.state.ak.us> Tom, We are about to begin logging operations on Intrepid 2 but would like to run by you our proposed P&A plan. Attached please find a schematic of that plan. Please note that we plan on running our 7" casing as part of the PEA. Our reason for this is to enable us to use the annulus for liquid disposal should the AOGCC grant us permission after we submit the relevant documentation at a later date. Please note the sand intervals on the schematic above the Neocomian. These have been labeled "insignificant" by our geoscientists. Each is no more than several feet thick and had a corresponding gas show recorded by the mudloggers, the maximum being 500 units. All indications are that these have no overpressure and are of no significant extent. As a result we do not propose covering them with our primary cement job for the 7" casing. After this casing is run & cemented and the waste fluids injected down the annulus the formation (and these sandy intervals) would be isolated from surface by performing an annular squeeze with both AS1 and Class G cement. The schematic shows the squeeze bottom as the uppermost sandy interval. At this point in the operations we would have a limited excess of cement and are planning on over displacing this annular volume with this excess. If you have any questions/comments or would like further information please let me know. Regards Philip «PbA Plan 4-12-07.ppt» • Subject: Re: [Fwd: Intrepid 2, 206-190 planned P&A] From: Stephen Davies <steve_davies@admin.state.ak.us> Date: Fri, 13 Apr 2007 14:00:35 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, My review of the mud log and well logs from Intrepid No. 2 supports ConocoPhillip's contention that it is not necessary to cement the insignificant sands in the upper portion of this well bore. In the Intrepid No. 2 well between 1800 and 2350 MD, there are eight thin beds of sandstone clustered into four groups. These groups are spaced from 120 to 180 vertical feet apart within the well bore. The individual beds of sandstone range in thickness from 1 foot to a maximum of about 3 feet. Total aggregate thickness of all eight beds is about 14 feet. The mud logging geologists describe the sands as being predominantly fine grained, with common to predominant matrix material (some samples were described as being matrix-supported}, and visual porosity that is most commonly described as being poor. There were no oil indicators recorded in association with cuttings samples from any of these beds. Elevated mud gas readings were recorded in association with the drilling of each bed. The geologic section is normally pressured. According to the operator's plan, the 8-1/2 inch diameter borehole will be cased with 7-inch pipe. Cement will be placed across the deeper, thicker Neocomian sand, which was the primary exploration target. The shallow, gas-bearing sandstone beds are thin, silty, and their porosity is likely poor. They cannot be considered to be significant, hydrocarbon-bearing strata. The four shallowest beds will likely be covered by the cement down-squeeze following the proposed annular injection into the annulus between the 7-inch and 9-5/8 inch casing strings. This annulus will be cemented from about 1850 feet MD to the surface, and the 9-5/8 inch casing is cemented from the shoe at 1379' MD to the surface. Please let me know if you have any questions. Thanks, Steve D. Thomas Maunder wrote: Philip, I left you a message. This acknowledges receipt of you proposal. Is it possible to look at the mud log and any other logs of these intervals? Tom Maunder, PE AOGCC -------- Original Message -------- Subject: Intrepid 2, 206-190 planned P&A Date: Thu, 12 Apr 2007 14:28:48 -0800 From: Hayden, Philip <Philip.Hayden@conocophillips.com> To: Thomas Maunder <tom maunder@admin.state.ak.us> Tom, we are about to begin logging operations on Intrepid 2 but would like to run by you our proposed P&A plan. Attached please find a schematic of that plan. Please note that we plan on running our 7" casing as part of the P&A. Our reason for this ', is to enable us to use the annulus for liquid disposal should the AOGCC grant us permission after we submit the relevant documentation at a later date. Please note the sand intervals on the schematic above the Neocomian. These have been labeled "insignificant" by our geoscientists. Each is no more than several feet thick and had a corresponding gas show recorded by the mudloggers, the maximum being 500 units. All indications are that these have no overpressure and are of no significant extent. As a result we do not propose covering them with our primary cement job for the 7" casing. After this casing is run & cemented and the waste fluids injected down the annulus the formation (and these sandy intervals) would be isolated from surface by performing an annular squeeze with both AS1 and Class G cement. The schematic shows the squeeze bottom as the uppermost sandy interval. At this point in the operations we would have a limited excess of cement i • and are planning on over displacing this annular volume with this excess. If you have any questions/comments or would like further information please let me know. Regards Philip «P&A Plan 4-12-07.ppt» __ __ Steve Davies Re: [Fwd: Intrepid 2, 206-190 planned P&A] Subject: Re: [Fwd: Intrepid 2, 206-190 planned P&A] From: Thomas Maunder <tom_rnaunder a,,adminatate.ak.us> Date: Fri, 13 Apr 2007 15:12:37 -0800 "To: "f Iav~icn, Philip" ~ =Philip.Ha~~len~u.conocophillips_con~== CC: Stephen Davies ~ -ste~~e davi~~~~r~aclmin.stale.~ikns=~ Philip, Thanks for the logs. Steve has examined and concurs with CPAI's assessment. You may proceed with your plans. As discussed on the phone, we will look for a annular disposal sundry early next week. Call or message with any questions. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 4/13/2007 10:33 AM: We have a copy of the mud log and the recorded LWD data on it's way over to you. Part of the density/neutron log over the reservoir is missing but if this is important we can work on getting this information to you as well, it would take a little longer. I am waiting for a reply from our geoscience people for your question on the extent of the sandy intervals as I don't want to put words in their mouths. I will get back to you on this a soon as possible. Regards Philip -----Original Message----- From: Stephen Davies [~r:ai.~.to:.steve Sent: Friday, April 13, 2007 10:21 AM To: Hayden, Philip Cc: Thomas Maunder Subject: Re: [Fwd: Intrepid 2, 206-190 planned P&A] Philip, Tom's right. Could we please get copies of the mud log, resistivity and porosity logs for review prior to making any plugging decisions? Also, what is the basis for the statement that the sand intervals are of no significant extent? For annular disposal, you will need to demonstrate conformance with 20 AAC 25.080. Thanks for your help, Steve Davies AOGCC 793-1224 Thomas Maunder wrote: Philip, I left you a message. This acknowledges receipt of you proposal. Is it possible to look at the mud log and any other logs of these davies:~:adm =.:~ .state . ak. usl 1 of 2 4/13/2007 3:12 PM Re: [Fwd: Intrepid 2, 206-190 planned P&A]. Subject: Re: [Fwd: Intrepid 2, 206-190 planned P&A) From: Stephen Davies <steve_davies@admin.state.ak.us> Date: Fri, 13 Apr 2007 14:00:35. -0900 T~: Thomas ~~1aunc~er ~~=tom maunderc~i~admin.state.ak.us== Tom, • My review of the mud log and well logs from Intrepid No. 2 supports ConocoPhillip's contention that it is not necessary to cement the insignificant sands in the upper portion of this well bore. In the Intrepid No. 2 well between 1800 and 2350 MD, there are eight thin beds of sandstone clustered into four groups. These groups are spaced from 120 to 180 vertical feet apart within the well bore. The individual beds of sandstone range in thickness from 1 foot to a maximum of about 3 feet. Total aggregate thickness of all eight beds is about 14 feet. The mud logging geologists describe the sands as being predominantly fine grained, with common to predominant matrix material (some samples were described as being matrix-supported), and visual porosity that is most commonly described as being poor. There were no oil indicators recorded in association with cuttings samples from any of these beds. Elevated mud gas readings were recorded in association with the drilling of each bed. The geologic section is normally pressured. According to the operator's plan, the 8-1/2 inch diameter borehole will be cased with 7-inch pipe. Cement will be placed across the deeper, thicker Neocomian sand, which was the primary exploration target. The shallow, gas-bearing sandstone beds are thin, silty, and their porosity is likely poor. They cannot be considered to be significant, hydrocarbon-bearing strata. The four shallowest beds will likely be covered by the cement down-squeeze following the proposed annular injection into the annulus between the 7-inch and 9-5/8 inch casing strings. This annulus will be cemented from about 1850 feet MD to the surface, and the 9-5/8 inch casing is cemented from the shoe at 1379' MD to the surface. Please let me know if you have any questions. Thanks, Steve D. Thomas Maunder wrote: Philip, I left you a message. This acknowledges receipt of you proposal. Is it possible to look at the mud log and any other logs of these intervals? Tom Maunder, PE AOGCC -------- Original Message -------- Subject: Intrepid 2, 206-190 planned P&A Date: Thu, 12 Apr 2007 14:28:48 -0800 From: Hayden, Philip <Phi.l..ip.I~ayden'~=-con:7ccchill.ips.com> To: Thomas Maunder <tom -~aunder;xadmi~~.st~te.ak.us> Tom, We are about to begin logging operations on Intrepid 2 but would like to run by you our proposed P&A plan. Attached please find a schematic of that plan. Please note that we plan on running our 7" casing as part of the P&A. Our reason for this is to enable us to use the annulus for liquid disposal should the AOGCC grant us permission after we submit the relevant documentation at a later date. Please note the sand intervals on the schematic above the Neocomian. These have been labeled "insignificant" by our geoscientists. Each is no more than several 1 of 2 4/13/2007 3:10 PM Intrepid 2, 206-190 planned P&A • . Subject: Ilrtrepid 2, 206-190 planned P&A From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> Date: Thu, 12 !~hr 2007 14:28:48 -0800 '1'0: ~1 honuls 1\launder <tom maunde..r(~r?admin.state.ak.us~ Tom, We are about to begin logging operations on Intrepid 2 but would like to run by you our proposed P&A plan. Attached please find a schematic of that plan. Please note that we plan on running our 7" casing as part of the P&A. Our reason for this is to enable us to use the annulus for liquid disposal should the AOGCC grant us permission after we submit the relevant documentation at a later date. Please note the sand intervals on the schematic above the Neocomian. These have been labeled "insignificant" by our geoscientists. Each is no more than several feet thick and had a corresponding gas show recorded by the mudloggers, the maximum being 500 units. All indications are that these have no overpressure and are of no significant extent. As a result we do not propose covering them with our primary cement job for the 7" casing. After this casing is run & cemented and the waste fluids injected down the annulus the formation (and these sandy intervals) would be isolated from surface by performing an annular squeeze with both AS1 and Class G cement. The schematic shows the squeeze bottom as the uppermost sandy interval. At this point in the operations we would have a limited excess of cement and are planning on over displacing this annular volume with this excess. If you have any questions/comments or would like further information please let me know. Regards Philip «P&A Plan 4-12-07.ppt» Content-Description: P&A Plan 4-12-07.ppt P&A Plan 4-12-07.ppt Content-Type: application/vnd.ms-powerpoint Content-Encoding: base64 1 of 1 4/13/2007 8:03 AM • i Intrepid 2 Proposed P&A Plan Surface cement plug (15.7 ppg AS1) from 5' below GL to 300' MD minimum set on Annular cement squeeze after viscous pill annular disposal of waste fluids (15.7 ppg AS1 / 15.8 ppg „G„) 9 5/8", 40# L-80, BTCM @ 1379' MD Cemented to surface 1850' MD 2040' MD ~ Insignificant sand intervals 2160' MD TOC @ 2628' MD 3128' MD Neocomian Sand 15.8 ppg "G" w/50% excess 3165' MD or as indicated by logs 7", 26# L-80, BTCM @ TD TD @ 3550' M D 4/12/2007 Intrepid 2, 206-190, Weekly update 4/9 Subject: Intrepid 2, 206-190, Weekly update 4/9 From: "Hayden, Philip" <Philip.Haydenc~conocophillips.com> Dater Mon, 09 Apr ?007 08:55:15 -0800 To: ~f~homas Nlaundcr atom maundcr(u'admin.state.ak.us=- Spudded the well at 01:30 4!1/2007. Drilled 12 1/4" surface hole to 1389' MD with 10 -10.2 ppg KCUKtagard mud. Attempted to POOH but BHA was balled up. Free to rotate, PU and SO but no returns. Unsuccessfully attempted to unball BHA. POOH slowly keeping the hole full and minimising swabbing. Lost approximately 80 bbts of mud when POOH. Stabiliser and bit packed off with clay. Ran clean out assembly to TD and circulated hole clean. Ran 9 5/8" casing to 1379' MD. Had to wash one joint through obstruction at 450' MD. Ran inner string and cemented 9 5/8" casing to surface. Full returns throughout the job. ND diverter. NU BOPs and test. PU 8 3/4" drilling BHA. Pressure tested casing to 2500 psi. Drilled out float equipment and drilled new hole to 1410' MD. Displaced mud to 9.2 ppg KCI/Klagard. Carried out FIT to 18.0 ppg MWE. Drilled 8 3/4" hole to 2464' MD. Carried out wiper trip to previous casing shoe. Drilled to 2965' MD. Current operation -drilling ahead. If you have any questions please let me know. Regards Philip 1 of 1 4/9/2007 9:00 AM Re: BOP Variance--Intrepid #2 • L~ Subject: Re: BOP Variance--Intrepid #2 From: Thomas EMaunder <tarn_maunder@,admin.state.ak.~~s> Date: Sat, 07 Apr 2007 08:04:14 -0800 ~ ©~ ~- ~~ To: Kuukpik. ~ Company i1~an ~_-KUL~K~~'~'1(ccconocophillips.com=:. CC: kuukpik ~ ~[~ool Pushe <KUUK~"I~P4iconi~copllillips.come,".~I~~ord, C`hip~~ ==Chip..<~l~~oT~d~«:c~>>IOCOphillips.com==."I3rassfield, Tom J" ~~-~1Oti~1.J.Brasslicld~crconocophillips.com~'~. -ao~~cc prtiilhoe ba~~~~i.admin.stale..ak.us= Hi Mike, As we discussed on the phone, continuing your operations without making a change to the kill line is acceptable. As you have pointed out the MASP for this well is under 1500 psi and the actual drilling should likely be completed before another BOP test is needed. When operations are complete, it is appropriate for CPAI/Kuukpik to determine a plan for .bringing this particular issue into compliance with the regulations. Good luck with the operations. Call or message with any questions. Tom Maunder, PE AOGCC ----- Original Message ----- From: Kuukpik 5 Company man <KUUKSCMc~co-zocophillips.com> Date: Saturday, April 7, 2007 0:14 am _........._.._._...__.._ ............................_... Subject: BOP Variance To: tom ~;aunde.r.~~La:~.min.state.ak.us Cc: Kuukpik 5 Tool Pushe <KU7K5TPtacox=acohillips.com>, "Alvord, Chip" Chip ._Alvord~?conocophiliips.ccm>, "Brassfield, Tom J" <TO"fi.,~.Brass ield~canacophi_lips.com> Mr. Maunder.... During our most recent inspection it was pointed out that there is a threaded valve installed in the kill line. We would like to request a variance for a threaded connection in the kill line for this well. We currently have surface set at 1372'. Our projected TD is 3600' and our maximum anticipated surface pressure is 1439 psi. Our current schedule shows us to TD by approximately 12 April. Thanks... Mike Kuukpik 5 263-3010 I of I 4/9/2007 7:40 AM Intrepid #2 Well Status As of 4/5/07 Intrepid #2 Began RU of Kuukpik 5 on 3/24/07. Heres released from the Noatak to Intrepid move on 3/25/07. Functioned tested diverter. Accepted rig at OOOOhrs on 4/1/07. Spudded well at 0130 hrs on 4/1/07. Drilled 12-1/4" surface hole to 1389' MD/TVD. Circulated and conditioned mud, pump out of hole from 1357' to 1024'- hole packed off. Pump out of hole and LD BHA. MU clean out BHA and make clean-out run to TD. POOH LD BHA. Run 9-5/8" 40 ppf L-80 casing .Current status is preparing to cement surface casing. Re: Intrepid 2, Weekly update 4/2 ~ ~ Subject: Re: Intrepid 2, Weekly update 4/2 From: Thomas Maunder <tom_maunder cr~admin.state.ak.us> Date: Mon, OZ Apr 2007 08:52 :15 -0800. r~ ~ - ~ To: "Hayden, Philip" ~~-Philip.Ha~~1~ni~r~conocophi11ip5.con1-~- Hi Philip, Glad to hear operations are underway. Yes, sending reports on Monday is fine. Tom Hayden, Philip wrote, On 4/2/2007 8:35 AM: Tom, Just wanted to inform you that we spudded Intrepid 2 early yesterday morning. We are currently drilling the 12 1/4" surface hole at 300 ft. I plan on sending you weekly updates starting from next Monday if that is ok with you? Regards Philip 1 of 1 4/2/2007 9:48 AM Re: Drill Notification • • Subject: Re: Drill Notification From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Thu, 29 Mar 2007 09:31:42 -0800 To: Chi~~ ,~~1~ oral ~ -Chip.Al~ ~~rd(u conocophillfps.con~ ~o ~ ~~ C(': AOGCC' north Slops (~Cficc ~ "ao~~ccpru~lhoe hayrc~:~cli7~ir~.statc.al..us=- ,~ Chip, This confirms your message that the event is not at the Intrepid location, but at Noatak #1. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 3/29/2007 8:57 AM: Chip, This confirms your call that there is a drill in progress on Kuukpik 5 at the Intrepid #2 location. The scenario is that a shallow gas kick has occurred. AlI mud has been blown from the well and the diverter has cut out. One man is down, the rig has been evacuated and preparations are being made to retrieve the missing person. Your man on site is contacting the AOGCC Inspector with the information. Call or message with further information. Tom Maunder, PE AOGCC 1 of 1 4/17/2007 9:09 AM RE: Intrepid #2 update 3/1/2007 Subject: RE: Intrepid #2 update 3/II2007 From: "Hayden, Philip" <Philip.Hayden c~conocophillips.com> Date: Mon, OS Mar 2007 09:15:47 -0900 'To: Thomas ~~'Iaunder <tommauncJcr(~r admin.state.~ik.us-• Tom, ~~ -~ I ~ ~ Cementing vaiumes will be increased if the 7" is run deeper in order to provide adequate shoe coverage and potential hydrocarbon zone isolation consis#ent with the regulations and best practices. Regards Philip -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 02, 2007 8:02 AM To: Hayden, Philip Subject: Re: Intrepid #2 update 3/1/2007 Philip, I have looked at the permit application. It is noted that the original planned 7" depth was for hole stability concerns and possible annular disposal. CPAI has more knowledge of the possible subsurface conditions and the risks/rewards of setting the casing shallower as originally planned. I presume that the cementing volumes might be slightly increase to account for the deeper setting depth? Good luck with the operation. I will place a copy of this message in the well file. Call or message with any questions. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 3/1/2007 3:59 PM: Tom, With reference to the well Intrepid #2, Permit to Drill # 206-190, API # 50-023-20036-00 I would like to highlight some changes we propose to make in our plans: Originally we had intended to seta 7" intermediate casing string on top of the Jurassic target in this well. The purpose of this string was two fold: (1) to isolate the potentially troublesome Miluveach shale from the Jurassic target and (2) to allow for future annular disposal. In the early planning stages of this well our recent experience in the NPRA lead us to the conclusion that isolating the Miluveach shale would maximise the chances of a successful coring and logging program in the target interval below. However, as our other exploration activities this Winter have taken longer than planned thus "squeezing" the time available for this Intrepid well we have reevaluated the need to run this casing string. A review of the Walakpa 2 reference well indicated that no trouble was experienced after drilling through the Miluveach shale which in this area is much thinner than that we have experienced in other parts of the NPRA. We have concluded that there is a much smaller risk of having trouble from this interval than was previously thought. Thus we are proposing to not set this casing string at this point. 1 of 2 3/5/2007 1 l :55 AM RE: Intrepid #2 update 3/1/2007 • If it is decided to complete the well after open hole data acquisition then the 7" casing string would be run and cemented at TD thus also eliminating the previously planned 4 1/2" liner. Alternatively, .regardless of the data acquisition outcome, we may elect to run and cement this string in order to dispose of fluids through annular disposal once the necessary permits were obtained. Please let me know if you require further information or documents to be filed. Regards Philip 2 of 2 3/5/2007 11:55 AM • a ~ I~ r~ ~ ~ n , -~ ~ . -! , _ ~ ~_~ _, Ai.ASSA OIL A11TD GAS C011TSERQA~'I011T COMI~IISSIOIQ Chip Alvord WNS Drilling Team Lead ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510-0360 C7 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 278-7542 Re: Intrepid #2 ConocoPhillips (Alaska), Inc. Permit No: 206-190 Surface Location: 2865' FNL, 17544' FEL, Sec. 11, T19N, R20W, UM Bottomhole Location: 2865' FNL, 17544' FEL, Sec. 11, T19N, R20W, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Please note the following:. 1. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 2. Prior to this well being tested, those plans should be submitted to the Commission via Form 10-403. 3. Drilling below the 7" casing shoe without performing a formation integrity test is acceptable per 20 AAC 25.030 (g). Permit No. 206-190 • • January 26, 2007 Page 2 of 2 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). DATED this~day of January, 2007 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Chairman STATE OF ALASKA RECEIVED ALAr~ OIL AND GAS CONSERVATION COMMON PERIVIIT TO DRILL ~~~ DEC 2 8 2006 20 AAC 25.005 _ 1 a. Type of Work: 1 b. Current Well Class: Exploratory ~ Development Oil ^ 1 c. Specify if we Drill Q Redrill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Aflft'8g6rates ^ Re-entry ^ Multiple Zone ^ Single Zone ^ Shale Gas ^ 2. Operator Name: 5. Bond: Blanket Q Single Well ^ 11. Well Name and Number: ConocoPhillips Alaska, Inc. - Bond No. 59-52-180 Intrepid #2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360, Anchorage, AK 99510-0360 MD: 3600' ~/D~ 3600' ' 4a. Location of Well (Governmental Section): 7. Property Designation: Exploration Surface: 2865' FNL, 1754' FEL, Sec 11, T19N, R20W NSB 1-2 Gas Lease; ASRC SW-2 Oil Lease Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2865' FNL, 1754' FEL, Sec 11, T19N, R20W NSB 07-093 3/1/2007 Total Depth: 9. Acres in Property: 14. Distance to Nearest 2865' FNL, 1754' FEL, Sec 11, T19N, R20W 9600 +/- Property: 2$65' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x-X=613,135. y- 6,221,416 Zone 6 (Height above GL): 20' RKB + 44' MSL Within Pool: 6 1111 t0 Walakpa2 16. Deviated wells: Kickoff depth: 0' ~ feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Strai ht Hole Maximum Hole Angle: degrees Downhole: 1835. Surface: 1439 18. Casing Program: Specifications To p -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 63# B PEB 80' Surf. Surf. 100' 100' 200sxAS1 12.25" 9.625" 40# L-80 BTC 1380' Surf. Surf. 1400' - 1400' - 250 sx ASLite+290 sxAS1 8.5" 7" 26# L-80 BTCM 3324' Surf. Surf. 3344' ~ 3344' sx Class G + additives 6.125" 4.5" 12.6# L-80 IBT-M 356' 3244' 3244' 3600' ~ 3600' 70 sx Class G + additives r0 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) : Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Q BOP Sketch Q Drilling Program Q Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch Q Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Chip Alvord Title Exploration Team Leader ) (- Signatur y ~J Phone Date Commission Use Only Permit to Drill N b ZO~rI ~ API Number: ~~ ~~•v~~rr `~~ 3l ~23~ Permit Approv I D See cover letter for other um er: 50- G.~/v p ate: requirements. Conditions of approval : If ox is checked, well may not be used to explore for, test, or produce Coalbed meth ne, gas hydrates, or gas contained in shales: Other: Samples req'd: Yes[~No^ Mud log req'd: Yes No^ HZS measures: Yes[/~ No^ Directional svy req'd: Yes^ No~ ~OQO ~5 ~ ~.~ ~~, ~~,~. ~3~p ~-cr.5~•- ~'~' ~.~t~~•,~,ow ~u~•~ ~~~t . ,~a ~• 3•d~ APPROVED BY THE COMMISSION DATE: !~' ~ ,COMMISSIONER /•z~/• o? Form 10-401 Revised 12/2005 + /~~ i~4~ u~ Cate ASRC Leases south of Barrow Subject: ASRC Leases south oow From: "Imm, Teresa" <timm@asrc.com> Date: Wed, 24 Jan 200715:29:45 -0900 To: steve_davies@admin.state.ak.us Steve, Zolo-i9o Per your telephone request I am attaching the Exhibit °Area 1 Lease Map" to the Exploration Agreement we entered into with ConocoPhillips and their partners Anadarko and Pioneer. ASRC executed the leases shown in the attachment to ConocoPhillips and partners an July 25, 2006. ASRC SW 002 is the lease that the proposed Intrepid #2 and Intrepid #3 wells are located. If you have any additional questions or require other information please do not hesitate to either call or a-mail. Regards, Teresa Imm Director -Resource Development Arctic Slope Regional Corporation 3900 C St., Suite 801 Anchorage, Alaska 99503 (907) 339-6014 direct (907) 339-6028 fax (907) 230-0227 primary cell (907) 223-2091 alternate cell (rural) timm asrc.com Content-Description: SW Leased Lands_8xl l.pdf SW Leased Lands_8zll.pdf Content-Type: application/octet-stream Content-Encoding: base64 __ 1 of 1 1/24/200'7 4:10 PM • • RE: Intrepid #2 PTD Info • • Subject: RE: Intrepid #2 PTD Info From: "Brassfield, Tom J" <'TOM.J.Brassfield@conocophillips.com> Date: Thu, 18 Jan 2007 08:56:20 -0900 To: Stephen Davies <steve davies@admin.state.ak.us> Steve, thanks! Tom -----0riginal Message----- From: Stephen navies [mailto:steve_davies@admin.state.ak.us) Seat: Thursday, January 18, 2007 8:45 AM To: Brasfield, Tom J Subject: Re: Intrepid #2 PTD Info Tom, As of Wednesday late afternoon, our attorney is still working with your attorney to decide what is needed. I'll let you know when I hear anything. Steve Davies Brassfield, Tom J wrote: Steve, thanks! Tom -----0riginal Message----- From: Stephen Davies [mailto:steve_davies@admin.state.ak.us] Seat: Thursday, January 11, 2007 4:24 PM To: Brasfield, Tom J Subject: Re: Intrepid #2 PTD Info Tom, This helps some. I spoke with our attorney today, and she planned to contact your attorney Barbara Fullmer, to come to mutual agreement on what is acceptable to establish proof of ownership. I'll let you know when I hear anything further. Thanks, Steve Davies Brassfield, Tom J wrote: Steve, in response to your request for Intrepid lease info and AOGCC regulation 20 AAC 25.005 'i; (c) (2} we are submitting the attached plat. Hopefully, this plat will provide the required information to process the Intrepid #2 PTD? i I, Thanks, Tom «Intrepid !-ease PIat.PDF» 1 of 1 1!24/2007 4:10 PM Re: Intrepid #2 PTD Info Subject: Re: Intrepid #2 PTD Info From: Stephen Davies <steve_davies@admin.state.ak.us> Date: Thu, 18 Jan 2007 08:44:58 -0900 To: "Brassfield, Tom J" <'TOM.J.Brassfield@conocophillips.com> Tom, r~ As of Wednesday late afternoon, our attorney is still working with your attorney to decide what is needed. I'll let you know when I hear anything. Steve Davies Brassfield, Tom J wrote: Steve, thanks! Tom -----Original Message----- From: Stephen Davies [mailto:steve davies@admin.state.ak.us] Serrt: Thursday, January 11, 2007 4:24 PM To: Brasfield, Tom J Subject: Re: Intrepid #2 PTD Info Tom, This helps some. I spoke with our attorney today, and she planned to contact your attorney Barbara Fullmer, to come to mutual agreement on what is acceptable to establish proof of ownership. I'll let you know when I hear anything further. Thanks, Steve Davies Brassfield, Tom J wrote: Steve, in response to your request for Intrepid lease info and AOGCC regulation 20 AAC 25.005 (c) (2) we are submitting the attached plat. Hopefully, this plat will provide the required information to process the Intrepid #2 PTD? Thanks, Tom ~ «Intrepid Lease PIat.PDF» Steve Davies 1 of 1 1!24/2007 4:09 PM Subject: Re: Intrepid #2 PTD Info From: Stephen Davies <steve_davies@admin.state.ak.us> Date: Thu, 11 Jan 200716:24:11 -0900 To: "Brasfield, Tom J" ~I'OM.J.Brassfield@conocophillips.com> Tom, This helps some. I spoke with our attorney today, and she planned to contact your attorney Bazbaza Fullmer, to come to mutual agreement on what is acceptable to establish proof of ownership. I'll let you know when I heaz anything further. Thanks, Steve Davies Brasfield, Tom J wrote: Steve, in response to your request for Intrepid lease info and AOGCC regulation 20 AAC 25.005 (c} (2) we are submitting the attached plat. Hopefully, this plat will provide the required information to process the Intrepid #2 ~ PTD? Thanks, Tom '~ «Intrepid Lease PIat.PDF» Steve Davies Intrepid #2 PTD Info Subject: Intrepid #2 PTD Info From: "Brasfield, Tom J" <I'OM.J.Brassfield@conocophillips.com> Date: Thu, 11 Jan 2007 13:41:09 -0900 To: steve_davies@admin.state.ak.us CC: tom_maunder@admin.state.ak.us, "Alvord, Chip" <Chip.Alvord@conocophillips.com> Steve, in response to your request for Intrepid lease info and AOGCC regulation 20 AAC 25.005 (c) (2) we are submitting the attached plat. Hopefully, this plat will provide the required information to process the Intrepid #2 PTD? Thanks, Tom «Intrepid Lease PIat.PDF» Content-Description: Intrepid Lease P1at.PDF Intrepid Lease P1at.PDF 'Content-Type: application/octet-stream Content-Encoding: base64 __ 1 of 1 1/24/2007 4:10 PM • Subject: Shallow salinities in Intrepid area. From: "Campaign, Wayne" <Wayne.Campaign@conocophillips.com> Date: Wed, 10 Jan 2007 14:20:19 -0900 To: steve_davies@admin.state.ak.us CC: "Brassfield, Tom J" <I'OM.J.Brassfield@conocophillips.com>, "Andreou, Andreas C" <Andreas.C.Andreou@conocophillips.com>, "Wilson, Gregory C" <Gregory.C.Wilson@conocophillips.com>, "Mabry, Monte D" <Monte.D.Mabry@conocophillips.com>, "Morgan, Mike R" <Mike.RMorgan@conocophillips.com> «Walakpa2_Sal.pdf» «Bront1 Sal.pdf» «Intrepid_salinity.doc» My take on shallow aquifer potential in the Intrepid area. Basically, there isn't any. We are going to run the porosity logs anyway. Permafrost has been a iffy pick far a while but in the Walakpa presentation, I note the Total Gas curve starts to respond about 140' above where I estimate the permafrost pick. I looked back in several previous year's presentations and noted similar responses. Especially in the wells where there seems to be deeper gas potential. Could this be another indicator of permafrost?? Just an interesting note. Any questions or comments, give me a call. Thanks. Wayne Campaign Petrophysicist ConocoPhillips, Alaska {907) 265-1505 Content-Description: Walakpa2_Sal.pdf Walalkpa2_Sal.pdf Content-Type: application/octet-stream Content-Encoding: base64 __ Content-Description: Brontl_Sal.pdf Brontl_Sal.pdf Content-Type: application/octet-stream Content-Encoding: base64 __ Content-Description: Intrepid_salinity.doc Intrepid_salinity.doc .Content-Type: application/msword Content-Encoding: base64 Shallow salinities in Intrepid area. • • Subject: Shallow salinities in Intrepid area. From: Stephen Davies <steve_davies@admin.state.ak.us> Date: Wed, 10 Jan 200714:42:46 -0900 To: TOM.J.Brassfield@conocophillips,com, Wayne.Campaign@conocophillips.com Wayne, Tom: Thanks for your work on this. Steve Davies AOGCC 793-1224 Steve Davies 1 of 1 1/24/2007 4:12 PM • •~, COt10~0~11~~Ip5 Alaska,lnc;. P. O. BOX 100360, ATO-1454 ANCHORAGE, ALASKA 99510-0360 Telephone 907- 265-1505 Facsimile 907- 263-4966 To: Steve Davies From: Wayne Campaign Petrophysicist Subject: Shallow Salinities in the Intrepid Area Date: January 10, 2007 ,~i~~ i Q ~~~t Aias!ica Qil & Gas Cans. Commission Anchorage This letter will document my analysis of shallow salinity issues for the 2007 NPRA drilling season. Offset wells include Walakpa 2 and Brontosaurus #1. A locator map is included as figure 1, and analyzed well plots as attachments. I may also refer to similar letters produced in previous years. Offset wells have been evaluated for shale volume, total and effective porosity, and apparent water salinity using standard techniques previously documented. Since shales contain excess mineral conductivity, I have highlighted the TDS curves for sands only, and use that for the discussion on water salinity. For this purpose, sand is defined as Vshale < 38%. I will also reference a USGS paper by Lachenbruch (et.aq, °Temperature and Depth of Permafrost on the Arctic Slope of Alaska", 1988 (Ref. 1). Estimates of permafrost depth are taken from reference 1. I interpolate permafrost at 1000' in the Intrepid area from this data. Actual measured depth from the Kuyanak #1 (23 miles ESE of Intrepid) was 330 m (1082. This is the closest well wkh actual stabilized temperature measurements. Walakpa and Brontosaurus do not have good quality sands in the shallow section nor do they not exhibit ice-bearing layers from which to estimate temperature and permafrost depth. Walakpa 2 is analyzed for salinity from surtace to the base HRZ/top Walakpa gas sand. One potential flowable sand appears near the base of Torok (2160'). It has effective porosity of 13%, salinity > 14 Kppm and a gas show. There are no potential fresh water aquifers in the section. Brontosaurus 1 was analyzed from surtace to 2000' and includes Nanushuk and 400' of Torok. Due to hole problems, the next 3800' of the hole has insufficient logs for a quality ananlysis. Four thin sands occur near the base Nanushuk (1400-1600') with effective porosities as high as 14%. Salinities calculate in excess of 15 Kppm. No other sands are present in this section. There are no shallow fresh water sands in the shallow sections of these wells, nor are any expected in the area of Intrepid. If you have any questions or comments, feel free to contact me. Thank you. Wayne Campaign Petrophysicist ConocoPhillips, Alaska (907) 265-1505 1. • Wayne Campaign Page 2 s BaRROw -~ ~~ a I I S BARROW TEST 3CF IK01~ ALAKPA }3~ ~ ~~ # ~~~ ~ WALAKPA ~ ~in:reGi<, ~ItltrepiU 3 KUYANAK ~~ SKULL C F 1~ BRONTO 1 STt¢ ~-~~,. ~ b leer A Fig. 1) Locator map for the prospects and offset wells. Ref.1 Lachenbruch, A.H., Sass, J.H., Lawver, L.A., Brewer, M.C., Marshall, B.V., Munroe, R.J., Kennelly Jr, J.P., Galanis Jr, S.P., Moses Jr, T.H., "Temperature and Depth of Permafrost on the Arctic Slope of Alaska", USGS Professional Paper 1399, Geology and Exploration of the National Petroleum Reserve in Alaska, 1974 to 1982, US. Government Printing Office, Washington DC, 1988, pgs. 645-656. RECEIVED JAN 1 0 2007 Alaska Oil & Gas Cons. Commission Anchorage • • W ALAKPA_2 sooa3aooi9oo ConocoPhillips LOCATION FIELD ST Al llh SPUD DATE IAT: I1.D99693 NATIONPL PETROL E'UM RLSE 1991-Ot-03 ION(:: -t5F.966131 DPILLED DEoTry OF •IA III!ti CDMPLETK)ti JAT= IONL. ASP 4 G360 Sirn~pnl Il iin 1981-02-14 X. 81 M1593.32 _~E 1A'I()NS. KB G_ SA'•t4'tE ; ,IA I.ITr OP6q ATOM Y: 6291026.2 61 H F HUSKY OIL X38_1 ' -_ rn t _ TDS SS_1 - -~ KPPM 2U ~ - RT Z RHOH EDT L KPPM IHSPTH MMM ~~ - 1,56 tE Ff h7 TDS RWA 1 200 300 700 800 900 x N ro ts' tr' Attachment 1 (Shallow Salinities in the Iatrepid Area, Jan 8,2007) d Ezplo lion of US Govt. Printlnp 1988, p9s. 645-I RE: Intrepid #2 • • Subject: RE: Intrepid #2 From: 'Brasfield, Torn J" <TOM.J.Brassfield cr conocophillips.com> Date: Mon, 08 Jan 2007 16:45:12 -0900 To: 7~f~unu~s ~laundcr ~ =tom n~a!u1~1~~!-iu`~ulmin.statc.ak.~!s.- CC: "~tilartin, Michael ~V" ~~~:Michael.~~\'.~1artin~~a.eonoco~~hillips.com=- Tom, sorry- missed the 1000' in the text. Actually, the number should be 500' above the Walakpa Sands at 3184' or TOC should be calculated at 2684' MD! This adds an additional 160' of annulus or a total of 166 cu. Ft or 150 sks (not 120 sks) of cement- my mistake. Hopefully this is right! Tom -----Original Message----- From: Thomas Maunder [mailtc:°.o~ mazr=de r:~ad~,in.state.ak.r.zs] Sent: Monday, January 08, 2007 3:41 PM To: Brassfield, Tom J Subject: Intrepid #2 Tom, I am reviewing your application and have the following in question/comment. In the text it is stated that you plan to cement the 7" casing to 1000' above the shoe, however the SOS cement calculation is based on 500'. Is the 1000' what you intend? Thanks, Tom Maunder, PE AOGCC 1 of 1 1/9/2007 8:03 AM Conoco Phillips Alaska, ~. CAnoco`Phillips Box 100360 Alaska 99510-0360 December 28, 2006 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill Surface Location: Target Location: Bottom Hole Location Dear Commissioner: l ~ lA n ~b.J ~` A/asks ®ir ~ ~~ Zap6 '~~C~® ~9e ~`~~~issipn Intrepid #2 (Exploratory Test) 2865' FNL, 1754' FEL, Sec 11, T19N-R20W X=613,135 & Y=6,221,416 ASP6 NAD27 2865' FNL, 1754' FEL, Sec 11, T19N-R20W 2865' FNL, 1754' FEL, Sec 11, T19N-R20W ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the NSB & ASRC areas South of Barrow, Alaska.. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling 12-1/4" surface hole to 14_00' MD/TVD then running and setting 9-5/8" surface pipe. The surface casing will drilled out with an 8-3/4" bit, drilled to the top of the first objective with a LWD logging suite, core point called, cut approx. 60' of core, drill to the top of the Jurassic, and run a suite of a-line logs. A 7" intermediate casing will be run in order to case off potentially sensitive shales and drilled out with a 6-1/8" bit. Only a minimal amount of hole (<1') will be drilled before POOH to pick-up a 90' coring assembly. At least one 90' core will be cut through the lower objective zone beginning immediately below the 7" shoe. The well will then be drilled to TD and depending on the logs either a 4-1/2" liner will be run and the well completed or the well will be P&A'd. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" intermediate casing, a 4-1/2" production liner and 3-1/2" tubing. There is a strong possibility that CPAI could request authorization for the disposal of drilling waste via the annulus by filing with the AOGCC a 10-403 supplement with additional information as required under 20 AAC 25.080. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2)- straight hole. 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Kuukpik Rig 5) as required by 20 AAC 25.035 (b) ~. • Conoco Phillips Alaska, I~ 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a). 8) ConocoPhillips does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the f standard operating procedure in the Kuparuk River Unit drilling operation. 9) Complete logging, coring, and mud logging operations are planned and descriptions are attached. The following are Conoco Phillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 2) Geologic Data and Logs Heather Perfetta, Geologist (20 AAC 25.071) 265-6374 The anticipated spud date for this well is March 10, 2006. If you have any questions or require further information, please contact Tom Brassfield at (907) 265-6377 or Chip Alvord at (907) 265-6120. Sincerely, .~ ~~ Tom Brassfield Senior Drilling Engi eer cc: CONFIDENTIAL -Intrepid #2 Well File Chip Alvord ATO-1570 Conoco Phillips Alaska, 1~!. Drill and Case Plan for Intrepid #2 General Procedure: 1. MIRU Kuukpik Rig 5 over pre-installed 16" conductor casing with welded landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12 1/4" hole to the surface casing point at 1400' MD/1400' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. - 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. ^ Employ lightweight permafrost cement lead slurry and Dowell ARCTICSET 1 high compressive tail slurry to assure cement returns to the surface in a one-stage stab-in cement job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8-3/4" bit and BHA and RIH to top of float equipment ^ Pressure test casing to 2500 psi for 30 minutes ^ Record results and fax to town 8. Drill float equipment and approximately 20' of new hole ^ Perform LOT (or FIT if gradient reaches 16 ppg equivalent) ^ Record results and fax to town 9. Drill 8-3/4" hole to top of Walakpa Sancta at approx. ±3184' MD/IVD. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Drill to core point, POOH & PU 60' core bbl, core interval as directed by on-site Geologist. POOH, LD core. PU BHA and drill to intermediate casing point at top of Jurassic at approx. 3344' MD/TVD. RU and run a-line logs. Make clean out run as needed. 11. Run 7" intermediate string to isolate potentially sensitive shales located just above the objective (est.@ 3344' MD /TVD). Cement casing to bring cement ±1000' above 7" shoe. 12. Make up 6 1/8" mill tooth bit and BHA and RIH to top of float equipment ^ Pressure test casing to 3000 psi for 30 minutes ^ Record results and fax to town 13. Drill float equipment, circulate & condition mud, TOOH. (LOT is not planned for this casing string - see attached explanation). 14. PU core barrel RIH and core at least one 90' core. TOOH, LD core barrel and PU 6-1/8" bit and drilling assembly and TIH. - 15. Drill 6 1/8" hole to ±3600' MD/TVD. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. ^ Condition hole and mud for a-line logs. 16. Log 6-1/8" wellbore as necessary. 17. Run and cement 4 ~/z" 12.6# L80 IBT-M Liner 18. Make a cleanout run with bit and scrapers ^ Displace to filtered seawater or brine- depending on formation pressure. ^ Pressure test well to 3000 psi for 30 minutes (perform low pressure test on liner lap). ^ Record results and fax to town 19. Run and land 3-1/2" tubing with gas lift completion 20. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. Conoco Phillips Alaska, I~ 21. Secure well, release rig. 22. Upon completion or if the well is not completed, plug and abandon the well, or temporarily shutdown per applicable regulations. Thoroughly clean location and block off further ice road access to location. Conoco Phillips Alaska, ~. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Intrepid #2 Drilling Fluid Properties: Spud to surface casing point Drill Out Production Hole Intermediate hole (Intermediate shoe to TD Density 9.5 - 10.2 ppg 9.5 - 11.3 ppg 9.8 - 10.0 ppg PV 16-26 6-20 15-25 YP 25-35 5-20 14-24 Funnel Vis 50 - 100 35 - 50 50 - 70 Initial Gel 10 - 20 2 - 6 3 - 6 10 Minute Gel 15-40 14-20 3-8 API Filtrate 7 - 15 < 6 <10 pH 9.5-10 9.0-10 9.0-12.0 Solids t 10% < 11% < 8% Drilling Fluid System: Equipment list for Kuukpik Rig #5 is in this package. Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size Casing Settin De th Fracture Gradient Pore Pressure Gradient Pore Pressure MASP Drillin 16" 100' MD / 100' TVD 11.0 8.33 43 NA 9-5/8" 1400' MD / 1400' TVD 12.7 9.0 655 46 si 7" 3344' MD / 3344' TVD ~ 14.8 9.7 1687 771 si 4-1/2"" 3600' MD / 3600' TVD 15 9.8 1835 ~ 1439 si . Expected Maximum Mud Weights: 12-1/4" surface hole to 1400' MD / 1400' TVD: 10.2 ppg 8-3/4"Intermediate hole to 3344' MD / 3344' TVD: 11.3 ppg (for shale stabilization) 6-1/8" Production Hole to 3600' MD / 3600' TVD: 10.0 ppg Conoco Phillips Alaska, Imo. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) - 0.11] x D Where: MASP =Maximum Anticipated Surface Pressure FG =Fracture Gradient at the casing seat in Ib/gal 0.052 =Conversion factor from Ib/gal to psi/ft 0.11 =Gas Gradient in psi/ft (above 10,000' TVD) D =True vertical depth to casing seat in ft from RKB OR 2) MASP =FPP - (0.11 x D) Where: FPP =Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D _ [(11.o x o.052) - o.i1] x loo' = 46 psi OR MASP =FPP - (0.11 x D) = 655 - (0.11 x 1400') = 501 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(12.7 x 0.052) - 0.11] x 1400' MASP = 771 psi OR MASP =FPP - (0.11 x D) = 1687 - (0.11 x 3344') = 1319 psi 3. Drilling below 7"Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(14.8 x 0.052)- 0.11] x 3344' MASP = 2206 psi OR MASP =FPP - (0.11 x D) = 1835 - (0.11 x 3600') = 1439 psi Conoco Phillips Alaska, ~. Casing Design Performance Properties Size Weight Grade Connection Internal Yield Collapse Tensile Strength 16" 63 f B PEB Conductor Casin Joint Body 9-5/8" 40 f L-80 BTC 5750 si 3090 979 M 916 M 7" 26 f L-80 BTC-M 7240 si 5410 667 M 519 M 4-1/2" 12.6 f L-80 IBT-M 8430 si 7500 si 288 M 288 M Casing Setting Depth Rational: 16" @ 100' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8" @ 1400' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8-3/4" hole to top of the J 7" @ 3344' MD RKB ediate a ~ is set s ric to prove a isolation of potentially troublesome shales. The shoe of this casing will be .set immediately into the top of the secondary objective with a planned core to be taken immediately below the 7" shoe if time allows. A LOT would require 20' . of additional hole to be drilled and would jeopardize targeted core recovery. Bottom hole pressures are extrapolated from previous Jurassic penetrations and predicted in the enclosed pore pressure analysis. , Well Proximity Risks: None Drilling Area Risks: Shallow Hazards: See attached report. Drilling Risks: Drilling risks in the Intrepid #2 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached mud weight versus depth graphs for the offset wells listed in the pore pressure analysis report dated 12/11/06. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus. The Intrepid #2 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. ." PAI may request approval to inject or dispose of fluids in the Intrepid #2 9-5/8" x 7"annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 AAC 25.080. Conoco Phillips Alaska, I~ Geolo4v: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (ssj UNCERTAINTY POSSIBLE FLUID TYPE EST. PORE PRESSURE si Permafrost 1000' 200' 434 To Torok 1000' 200' 434 H RZ 2650' 200' 1254 Top Walakpa Sands 3120' 200' Probable Oil and/or Gas 1541 LCU 3150' 200' 1556 Miluveach 3150' 200' 1556 Top Jurassic 3280' 200' Probable Oil and/or Gas 1654 UJU To Kin ak 3360' 200' 1695 TD 3536' 1802 Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 -Surface Casing setting depth) LWD: GR/Res/Density/Neutron 8-3/4" Intermediate Hole (Surface Casing setting depth to Top Jurassic) LWD: GR/Res/Density/Neutron/PWD - Wireline: GR/Res/CMR/MDT/VSP (Contingency: PEX/RSWC/Dipole Sonic) - 6-1/8" Production Hole (7" Shoe to TD) LWD: GR/Res/Density/Neutron/PWD Wireline: GR/Res/CMR/MDT/VSP (Contingency: PEX/RSWC/Dipole Sonic) II. Coring- if time allows Full Diameter 2.5" Core in Upper Jurassic (1-90' cores) Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful II. Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TD. - Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and HZS detection Thirty to sixty-foot (30'-60') wet and dry samples will be collected from surface to surface casing setting depth. Thirty-foot (30') wet and dry samples will be collected from surface casing setting depth to well TD and ten-foot (10') wet and dry samples, or continuous, collected across any hydrocarbon intervals. Conoco Phillips Alaska, III. Flow Testing End of Winter drilling season will not allow enough time to test this year. Conoco Phillips Alaska, . Intrepid #2 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud tem eratures Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted swee s, reduce fluid viscosi ,control ROP. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations Lost Circulation Medium Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled runnin seeds. 8-1 2" ~& 6-1/8" Hole Event Risk Level Miti ation Strate Lost circulation Hiah Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- lanned LCM ills, lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, wei hted swee s. Directional Control Low BHA design, on-sight geologic review and advisement of otential slum blocks. Sloughing Shale, Tight High Increased mud density and fluid Hole composition according to plan, controlled tri seeds, swee s, ECD monitorin . Abnormal Reservoir Low Well control drills, increased mud weight, Pressure contin encies for to set casin strin . Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scaven ers ~~ Intrepid #2 Proposed Completion Schematic 12/28/06 16" 65# H-40 @ +/- 100' MD Depths are based on est rig RKB Surtace csg. 9-5/8" 40.0# L-80 BTC (+/- 1400' MD) 3-1/2" 9.3# L-80 EUE 8rd mod tubing 3-1/2" 9.3# L-80EUE 8rd mod tubing Walakpa Sands 3184' MD Intermediate csg. 7" 26.0# L-80 BTCM (+/- 3344' MD) Alpine Jurassic Sands @ 3344' MD Production Liner 4-1/2" 12.6# L-80 IBT-M (+/- 3600' MD) • Kuukpik Rig 5 RKB to LDS 20.5' 3-1 /2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE 8rd mod pin down w/2.3' pup 1 jt 3-1/2" 9.3# L-80 EUE 8rd mod Tubing 3-1/2" 9.3# L-80 EUE 8rd mod Spaceout Pups as needed 3-1/2" Camco "DS" nipple w/ 2.875" no-go profile @ 500' MD 3-1/2" 9.3# L-80 EUE 8rd mod Tubing 3-1/2" x1-1/2" Camco MMG or MMM GLM w/shear valve @ 2700' MD 3-1/2" 9.3# L-80 EUE 8rd mod tubing 3-1/2" Camco "D" nipple w/ 2.813" no-go profile @ 2970' MD 3-1/2" x1-1/2" Camco MMG or MMM GLM Baker PBR with seal assembly & scoop guide 3-^/i' x 7" Baker S-3 Permanent Packer 3 Y~' Baker "CMU" Sliding Sleeve w/ profile 3-1/2" Camco "D" nipple w/ 2.75" no-go profile Baker locator sub 5" Baker Bullet seal assembly w/ 15' stroke, 4-1/2" L-80 IBT box up Liner Assembly (run on drilloioe~, Baker 7" x 4-1/2"'ZXP' Liner Top Isolation Packer with C-2 profile & 12' PBR Baker 7" x 4-1/2" `FlexLock' Liner Hanger 4-1/2" 12.6# L-80 IBT-M liner as needed 4-1/2" Baker Landing Collar @ 8091' DPM 1 jt4-1/2" 12.6# L-80 IBT-M tubing 4-1 /2" Baker Float Collar 2 jts 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Baker Float Shoe TJB 12/28/06 • ~ Text Box ~ ConOCOPhillips Text Box ROP Rig = AFEDays= #VALUE! 0 Aclual Days = 0.00 0 hours I I I I ' I I I I I I ' I I I I I I I ' ' "YVd - I I I I ' I I I I I I Release = 1 1 I I ' 'I I I 1 I I I I 1 I I I I ' AFE#= \ \I I I 1 I I I 1 AFE $= \~ i i i i i i i Actual Total $_ $0 \\ 1 I I I I I I Intangible $_ $0 ' ~ ~ , , ~ , ~ , Non-Planned $ _ $0 ' n ' I I ' ' ' ' Chafe of Scope $ _ $0 ~ I, I I I I I I I I I I I I 1 I ' Scope "Prouble $_ $0 I\ I ~ I~ I I I I I I I I ' I I ' I I I I I I I ' ' Trouble $= $0 \ I \ I I I I I I Mud $= $0 ~ i I I ' ' ' I I Planned "time = 0 horns \ \ i i i i i i I Non-Phrnned Time = 0 hours 1,000 ----' -'---r---- r----~-----r- ---r---- i-----r-- Scope Change Time= 0.0 hours u ' I I ' ' I ' I Scope Trouble Tiroe = 0.0 hours ' ~ ~ ~ i ~ ~ ~ Trouble Time = 0.0 hours ` \ , , ~ , ~ , ; Total CPF = #lNUM! ' I I ' ' I I I Intan Ible CPF = #Ni.TM! g• It ~ ~ ~ i ~ I i I I I i ~ i Planned CPF = #NL1M! I ~ I I ~ ~ I I 1 I Non-Planned CPF= #NUM! ~ i ~ i ~ i ~ Scope Change CPF = #NUM! ~ , ' ~ , ~ , Scope Trouble CPF = #NIJM! ' I I I I ~ I ~ ~ ' I 1 ' ' 1 I I Trouble CPF = #NUMI I I I' I ~ I ' ' I Mud CPF = #DILJM! ~ i \ ~ i i i i MIItU = 0 hotus ,..~ ; ; \ ~ ~ ; \ ; ~ ; ; Planned Days/IOK #VALUE ~ i ~ i \ ~ ' ~ ; ~ ~ Actual Days/IOK #N[JM! x2,000 u ----i-----i----- r-i - ~- ~ ---~i - , ---T----i-----' -- Planned TD= ft # UM! ft A 1 I I I I I I ~ I I 'I 1 I I I I I N Actual TD = I I 1 I ' ~ I I I Drlg. Foreman = I 1 I I I I I ~ I I 1 I I I I I I Drlg. Engineer = I I I I ~ t 1 1 I I I I 1 I ~ I I I' I I I I I I I I I I I I I I ~ I~ I I 1 t 1 I I I I I I I I I I I ~ I I' I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 1 I I ' I ~ \ I I' I I I I I I I I I I 1 I I I I I I I I I I I •_ I I ~ I I I • `I •`~ `I ` I I I I I I I I I I I I I I I I I I \ ~ I I 1 I I 1 \ I 1 I I I I I I I 1 I I I I I I I ' I t I \ I 1 I I I I I I I I \I I I \ I I I I I I I I I 1 I I I I I I I I I I I I ~ I I \ I I I I I I 3,000 ____,_____I_____ r____y_ ____I__ ___,\___ _I_____r___ ~Y_____I____-r____~_____I_____ 1 I I I I I I I I I I I' I I I I I ' I I I I I I I I I AFE Est. vs. Actual I I I I l I I I \ I I I I \I ` I I ' ' t' I I 1 I I I \ I I\ I I I I 525.000.000 ----- ------ ' I I \ ~ i I I I I\ I I I I I I I I I • a2o,oo0,000 ----- ------ I 1 I I ~ I I I I I I I I I I I I I I \ I 1 I I I I I 1 I 515,000,000 - -- I I I I I I I I I I 1 I I I I I I SIO,000,OOU -- ------ I I I I I I I I I I I I 1 ~ I I I I I 55.000.000 _ _ _ ______ I I I 1 I 1 I I I 1 I I I I I I I I I I I I I I I I Sa I I I I I I I I I I I I I I I I I I AAnned Attaat I I I I I I I I I I I I 1 I I I I I 4,000 a z a F s 10 t2 1S 16 18 20 22 24 26 Davs --0-Actual ` `Low Mean ` `High WELL DETAILS ame +N1-S +E/-W Nortlilng Easting Latitude Longitude Slot lanlntrepid#2 0.00 0.00 6221416.00 ~ 613135.00 71°00'49.457N 157°03'02.245W N/A WELLPATH DETAILS Plan: Irdrepid #2 Rig: Kuukpik 5 Re£ Datum: Plan Intrepid #2 64.OOR V.Section Origin Origin Sfartirg Angle +N/-S +E(-W FranTVD 0.00° 0.00 0.00 0.00 T M Atimuths to Tme North Magnetic North: 19.86° Magnetic Field Strength 57395nT Dip Angle: 80.56° Date: 12/13/2006 Model: bggrn2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 20.00 3600.00 Planned: Wrepid#2wp01 VI MWD 8 b w~.q-yc~K)paoar l a Y 0 1000 voeds~.m~ro.ao°gooow [ PLAN DETAILS Inirepidli2wp01 Verson 1 12(13t2006 Start Point MD Ittc Au TVD +N/-S +FJ-W 20.00 0.00 0.00 20.00 0.00 0.00 t ~s~r.~tc-sua~ronl 9pfarry DAlliny Servkes CanocoPhllips AIBSka REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: Plan itrtrepid #2, True North Vertical (TVD Reference: Plan. Intrepid #2 64.00 Section (VS; Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: Place Inrepid #2 64.00 - Calculation Metitod: Minimum Curvature ~anacaPhillips Alaska, In~ CPAI Report Company: ConocoPhillipsAfaska Ina Date:. 12/13/2006 Time: 14:01:38 Page: 1 Field: ASP Zone 6 Co-ordinate(NE) Reference: Well: Plan: Intrepid #2, True North Site: Intrepid Vertical (TVD) Reference:' Plan: Intrepid #2 64.0 «'ell: Plan: Intrepid #2 Section (VS) Reference: Welf (O.OON,O.OQE,O.QOAzi) ~Vellpath: Plan: Intrepid ~2 Survey CalculationMethodp Minimum Curvature ~ Db: Oracle Plan: [nt€epid#2p01 Date Composed: 12!13/2006 Version: 1 Principe!: Yes Tied-to: From Well Ref. Point F"ceM: ASP Zone 6 NSB 1-2 Gas Lease, ASR( SW-2 Ctif Lease Map Systen,:US State Plane Coo€d'€r~te System 1927 Map Zone: Alaska, Zone 6 Geo Datum: NAp27 (Ckarke 1866) Coordinate System: Well Centre ', Sys Datum: Mean Sea Levee Geomagnetic Model: bggm2006 Site: Intrepid Zone; 6 Site Position: Noethi~: 6221416.00 ft Latitude: 71 0 49.457 N From: Map Fasting: 613135.00 ft Longitude: 157 3 2.245 W Position Tncerts€inty: 0.00 ft North Reference: True Ground. Level: 0.00 ft Grid Convergence: 0.90 deg Well:. Pin: Intrepid #2 Slot Name: Weil Pesitionx +N!-S 0_QO ft Northing: 6221416.00 ft ~ Latitude: 71 0 49.457 N +E/ W 0.00 ft Easti~g : 613135.00 ft Longitude: 157 3 2.245 W Position Uemertehdy: 0.00 ft Weltpath: Pfan_ Intrepid #2 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Curreert Datum: Plan: Intrepkl #2 Height 64.00 ft Above System Datum: Mean Sea Level 1tie Data: 12!13!2006 Declination: 19.86 deg F'udd Ste+ength: 57395 nT Mag Dip Angle: 80.56 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction fl ft ft deg O.EM3 0.00 0.00 0.00 Survey Program f~ Definitive Wefipeth Date: 12/13!2006 Vafuleted: FIo Version: 0 Actual From To Survey Tooicode Tool Name ft ft Ptah Section formation hII) Inc! Haim TVD +N/-S +E1-W DLS Build Turn TFO Target ft deg deg ft ft ft degl1OOft deg/100ft deg/100ft -deg 2o.ao _ o.oo o_cio 2o.a3 0.00 0.00 0.00 0.00 0.00 0.~ 3600.OE3 0.00 0.00 3600.00 0.00 0.00 0.00 0.00 0.00 0.00 Survey :SID ~ ft _- Inc[ deg -- Azire deg T~'D ft Sys TVD ff N/S ft ___. EfiV ft :1IapN ft MapE ft DLS deg/100ft VS Comme ft 20.~ 0.00 0.00 20.00 -44.00 0.00 0.00 6221416.00 613135.00 ~ 0.00 0.00 100.00 0.00 0.00 1Q0.00 36.00 0.00 0.00 6221416.00 613135.00 0.00 O.QO 200.00 0.00 0.(kl 200.00 136.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 300.00 0.00 0.00 300.00 236.80 0.00 0.00 6221416.00 613135.00 0.00 0.00 400.00 O.f70 0.00 400.€ft3 336.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 500.00 0.00 O.QO 500.00 436.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 600.00 0.00 0.00 600.0(? 536.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 700.00 0.00 0.00 700.00 636.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 800.00 0.00 0.00 800.00 736.()0 0.00 0.00 6221416.00 613135.00 0.00 0.00 900.0£3 0.00 0.00 900.00 836.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 1000.00 0.00 0.00 1000.00 936.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 Top Torok 1100.00 0.00 O.dEI 1100.00 1036.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 1200.00 0.00 0.00 1200.00 1136.00 0.(30 0.00 6221416.00 613135.00 0.00 0.00 1300.00 0.00 0.003 1300.00 1236.00 0.00 0.00 6221416.00 613135.00 0.00 0.00 ~onOCOPh' 'p~ kat, In~ eP~ Company: ConocoPhiflips Alaska fnc. -- l 1173'T~'2~16 Time: 14:01:38 Page: 2 loield: ASP Zone 6 Cwswii i-nte(~~aReterence: Well: Plan: Intrepid #2, True North Site: Intrepid ~~esl9rcdl(lQ~4~~Iirferettce: Plan: I ntrepid #2 64.0 Weli: Plan: Intrepid #2 3~rien (d~~fliteilaenrc: Well (O.OON,O.OOE,O.OOAzi) ~i'eltpaHi: Plan: Intrepid #2 S~rf~ i~a~n~ata~w 1-lethod: Minim um Curvature Db: Oracle Survey MD Incl :1zim 'I1'D SysTVD N/S 1';/,~K \IapE DLS VS Commen t, ft deg deg ft R ft % tp ft degl100ft ft 1400.00 0.00 0.00 1400.00 1336.00 0.00 QA.~ 11416.(X1 613135.00 0.00 0.00 9 5/8" 1500.EX1 0.00 0.00 1500.00 1436.00 0.00 m4.~ ~114i16.00 613135.00 0.00 0.00 1600.00 0.001 O.EX} 1600.00 1536.00 0.00 ®..007 X11416.00 613135.00 0.00 0.00 1700.00 O.CXI 0.041 1700.00 1636.00 0.00 ~~ X14116.00 613135.00 0.00 0.00 18410.4X1 0.00 0.€10 18€)0.(10 1736.00 0.00 H~ X14416.00 613135.00 0.00 0.00 1900.00 0.(X3 0.00 1900.(10 1836.(10 0.00 (1!1~ X114416.00 613135.00 0.00 0.00 2000.00 0.(10 0.00 2000.00 1936.00 0.00 0t0ID 6i~1I4416.00 613135.00 0.00 0.00 2100.00 0_(10 O.QO 2100.00 2036.00 0.00 X001 X14416.00 613135.00 0.00 0.00 2200.€10 0.4X3 0.00 2200.00 2136.00 0.00 Oz~ ~114416.0D 613135.00 0.00 0.00 2300.00 O~EX} 000 2300.00 2236.00 0.00 ~~ ~14416.OQ 613135.00 0.00 0.00 244X1.4X1 0.€11,7 0.00 2400.00 2336.00 0.00 Ot~7 (~14416A0 613135.00 0.00 0.00 2500.[10 0.00 O~fXl 2500.00 2436.00 0.00 ®.~ 6i~144416A0 613135.00 0.00 0.00 2600.00 0.00 O~QO 2600.00 2536.00 0.00 ~~ (~1I4i16.410 613135.00 0.00 0.00 274X3.00 O.fX3 0.(10 2700.00 2636.00 0.00 ~t1>m ~tl4kI6.00 613135.00 0.00 0.00 2714.00 0_[10 0.410 2714.0(1 2fi50.00 0.00 ~~ E~114416.00 613135.00 0.00 0.00 HRZ 28EX3.EX3 0.(10 0.00 2800.4X1 2736.00 0.00 mtID01 X14416.00 613135.00 0.00 0.00 2900.00 0.00 0.00 294.00 2836.00 0.00 mlAIOI X114116.00 613135.00 0.00 0.00 3000.00 0.00 0.00 3000.00 2936.00 0.00 ~ll101 X14416.00 613135.00 0.00 0.00 3100.00 0.0(1 0.00 31410.00 3036.00 0.00 Otm07 E~1441613E3 613135.00 0.00 0.00 3184.430 0.00 0.4X1 3184.00 3120.00 0.00 ~~ ft~14416.00 613135.00 0.00 0.00 Top Walakpa S 3200.00 0.00 0.(10 3200.00 3136.00 0.00 (t1k~7 X14416.00 613135.00 0.00 0.00 3214.00 0.€10 0.00 3214.00 3150.00 0.00 ¢A(~ ~i(4416.00 613135.00 0.00 0.00 Miluveach 3300.00 0.00 0.(10 334X}.00 3236.00 0.00 ~t307 X114416.00 613135.00 0.00 0.00 3344.00 O.E10 0.00 3344.00 3280.00 0.00 (tQJ.~ (i~114416.00 613135.00 0.00 0.00 T' 3400.(10 0.00 0.(10 3400_(10 3336.00 0.00 mtOlID E&~114416.00 613135.00 0.00 0.00 3424.00 0.00 0.410 3424.00 3360.00 0.00 (ik41ffi1 E~114416.00 613135.00 0.00 0.00 UJU (Top King k 3500.041 0.00 0.00 35041.041 3436.00 0.00 X007 614416.00 613135.00 0.00 0.00 3564.410 0.041 0.430 3564.00 3500.00 0.00 O1ID03 X14416.00 613135.00 0.00 0.00 TD Upper Kinga 36430.4X1 0.4X1 0.€141 36410.410 3536.00 0.00 Ott X14416.00 613135.00 0.00 0.00 Intrepid#2wp01 1 Targets - ~gxP ~Iap <- -- Latitude ---> 4- Longitude --> Name Description TV'Ih +IY/$ ~%l~i' Lw~etii~ Fasting Deg Vlin Sec lleg Min Sec Dip. Dir. ft tt fft ffi fr Errtrepki#2~1 T1 3600.00 ~ 0.00 191 610 613135.00 71 0 49.457 N 157 3 2.245 W -Circle (Radius: 200} -Plan hit target bID TvD ft ft I 3600.00 3600.00 TD Casio Foiilf$ IVID "P~'D Diameter Hole Size Name ft ft in in _ -- 1400.00 14410.00 9.625 12.250 95/8" 3344.00 3344.00 7.0410 8.54X1 7" 3600.00 3600.4X1 4.500 6.125 41/2" ~onocoPhillips Alaska, In~ CPAI Report Company: ConocoPhiiGp s Alaska Inc.: Date: 12/13/2006 Time: 14:01:38 Page: 3 Field: ASP Zone 6 Co-ordinate(NE) Reference: Well: Plan: Intrepid #2, True North Site: Intrepid Vertical (TVD) Reference: Plan: Intrepid #2 64.0 Nell: Plan: Intrepid #2 Section (VS) Reference: Weil (O.OON,O.OOE,O.OOAzi) ~Vellpath: Plan: Intrepid #2 Survey Calculation Method: Minimum Curvature Db: Oracle Formation s bID TVD Formations Lithology Dip Angle Di p Direction ft ft deg deg. 1000.00 1000.00 Base Permafrost 0.00 0.00 1000.00 1000.00 Top Torok 0.00 0.00 2714.00 2714.00 H RZ 0.00 0.00 3184.00 3184.00 Top Walakpa Sst 0.00 0.00 3214.00 3214.00 LCU 0.00 0.00 3214.00 3214.00 Milweach 0.00 0.00 3344.00 3344.00 Top Alpine (Jur) Equiv Sst 0.00 0.00 3424.00 3424.00 UJU (Top Kingak) 0.00 0.00 3564.00 3564.00 TD Upper Kingak 0.00 0.00 '~`onocoPhillips Alaska, Ln~'~' Anticollision Report Compan}': Conoot>P!~iE#ips Alaska Inc: Dater .12!13/2006 Time: 14:00:44 Pale: 1 Field: ASP Zane 6 Reference ~ tntreptd Co-ordinate(NE) Reference: Well: Plan: Intrepid #2, True North Reference vk'eli: Ptan: lrstr~id #2 Vertical (T4 D) Reference: Plan: Intrepid #2 64.0 Reference V~'ellpath: Plam: krrtrepid #2 Db: Oracle GLOBAL~C'1N ltrIPISEIk,A! wkhin200'+100/100(lof reference Reference: Plan: Intrepid#2wp018~NOTPLANNED Interpolat~w: iYtFD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Ram '20>CI~1 is 3600.00 ft Scan Method: Trav Cylinder North Maximum - ~- ~ Error Sm~': Ellipse ~ Casing Casing Points MD TVD Itt'waneter Hok Size \ame ft fit in in 1400.00 1 ~.OD ~. 12.250 9 5!8" 3344.00 3344..E 9.'t~D 8.500 T' 3600.00 3~C8_DD ~I..~ti0 6.125 41 /2" Plan: ~ tupi04i Date Composed: 92~13/2Ctd6 Version: Principal: ~Pes Tied-to: From U~ Re#. Point Summary <------ Ofl'sc#'R'ellpath ----------> Reference. Offset Ctr-Ctr No-Go Allowable Site R'oH Wellpath MD MD Distance Area Deviation Warning No welh fi fie: ~+or limit. OGRAM 21/4" DIVERTER SCHE~ATIC Kuukpik Rig 5 NPRA Exploration ----- To Accumulator _____ From Accumulator Maintenance & Operation Open 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer/open the valve in the event that an influx of wellbore fluids or gas is detected. DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 21-1/4" Diverter Spool with API 21-1/4" 2000 psi Flanges 5. 21-1/4" x 21-1/4" 2000 psi, Double Studded Adapter Flange (Optional) 6. 21-1/4" Hydril MSP 2000 psi Annular Preventer 7. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 8. 16" Diverter Line TJ B 12/22/06 X11" 5000 psi BOP Sta~ Kuukpik Rig 5 NPRA Exploration Floor Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic 6 fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 5 Kill Line Choke Line Check Hyd Man 4 3 2 Man ~ Hyd 1 Fhr$OP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed back to zero BOP Stack Test psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi for 5 minutes and 5000 psi for 10 minutes. Continue testing all valves, lines, and chokes with a 250 psi low for 5 minutes and 5000 psi high for 10 minutes. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi low for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 10 minutes. 12. Test kelly cocks and inside BOP to 5000 psi for 10 minutes with BOP test pump. 13. Record test information on blowout preventer test form and on pressure chart. Sign and send to drilling engineer. 14. Perform SOPE test a) when initially installed, b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 7 day intervals. Functionally operate BOPE daily. 15. Pit drills are to be conductled weekly for each drilling crew. 1. 16" Starting Head 2. 11" 5000 psi Through Bore System Wellhead 3. 11" 5000 psi Shaffer LWS Gate (pipe rams), 4-1/16" 5000 psi Side Outlets w/ Manual Locks 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves -one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate 2 Kill valves -one 2" 5000 psi Hydraulic gate and one 2" 5000 psi Manual gate 1 Check valve in Kill Line - 5000 psi 5. 11" 5000 psi Shaffer LWS Double Ram (pipe rams on top, blind on bottom), 4-1/16" 5000 psi Side Outlets w/ Manual Locks 6. 11" 5000 psi Hydril GK Annular Preventer, Flange Connection TJB 12/22/06 - • • ~ Schlumherger CemCADE Preliminary Job Design 9 5/8" Surface -Stab-in, V3 Preliminary Job Design based on limitetl input data. For estimate purposes only. Rig: Kuukpik#5 Location: Exploration Client: ConocoPhillips Alaska, Inc. Revision Date: 12/13/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martinl3@slb.com < TOC at Surface Previous Csg. < 16", 65.# casing at 117' MD < Base of Permafrost at 900' MD (900' TVD) < Top of Tail at 900' MD f < 9 5/8", 40.0# casing _;~ in 12 1/4" OH ;~ TD at 1,400' MD (1,400' ND) 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 900' MD. Lead Slurry Minimum pump time: 160 min. (pump time plus 120 min.) ARCTICSET Lite cLD 10.7 ppg - 4.45 ft3/sk 0.7632 ft3/ft x (117') x 1.00 (no excess) = 89.3 ft3 0.3132 ft3/ft x (900' -117') x 4.00 (300% excess) = 980.9 ft3 0.3132 ft3/ft x (900' - 900') x 1.50 (50% excess) = 0 ft3 89.3 ft3 + 980.9 ft3+ 0 ft3 = 1070.2 ft3 1070.2 ft314.43 ft3/sk = 241.6 sks Round up to 250 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary, Tail Slurry Minimum pump time: 130 min. (pump time plus 120 min.) ARCTICSET I @ 15.7 ppg - 0.93 ft3/sk 0.3132 ft3/ft x (1400' - 900') x 1 0.4257 ft3/ft x 80' (Shoe Joint) _ 234.9 ft3 + 34.1 ft3 = 269 ft3/ 0.93 ft3/sk = Round up to 290 sks 50 (50% excess) = 234.9 ft3 34.1 ft3 269 ft3 289.2 sks BHST = 43~, Estimated BHCT = 62`I=. (BHST calculated using a gradient of 2.6/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbD (min) (min) Water 5.0 10.0 2.0 2.0 Pressure Test 0.0 0.0 10.0 12.0 Water 5.0 40.0 8.0 20.0 Wiper Dart 0.0 0.0 0.0 20.0 MUDPUSH II 6.0 50.0 8.3 28.3 ASL III 7.0 190.6 27.2 55.5 AS1 6.0 47.9 8.0 63.5 Displace & shut down 5.0 14.3 2.9 66.4 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, Tv < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" I I, Pv = 17-21, TY ~ 20-25 Centralizers: Recommend 1 per 2 joints throughout column of tail slurry Mark of Schlumberger • • ~ Scbl~mberger CemCADE Preliminary Jab Design 7" Intermediate Casin , V3 Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Kuukpik#5 Location: Exploration Client: ConocoPhillips Alaska, Inc. Revision Date: 12/14/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907} 263-4207 Mobile: (907} 748-6900 email: martin13@slb.com Previous Csg. < 9 5/8", 40.0# casing at 1,400' MD < Top of Tail at 2,844' MD < 7", 26.0# casing in 83!4" OH TD at 3,344' MD (3,280' TVD} Volume Calculations and Cement Systems Volumes are based on 50% excess. Slurry is designed for 500' MD annular length. Tail Slurry Minimum thickening time: 150 min. (Pump time plus 120 min.) 15.8 ppg Class G + 0.2%D46, 0.3°!°D65, 0.02%6155, 0.4% D167 - 1.16 ft3lsk 0.1503 ft3/ft x 500' x 1.50 (50% excess) = 112.7 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 112.7 ft3 + 17.2 ft3 = 129.9 ft3 129.9 ft3/ 1.16 ft3/sk = 112.0 sks ~,~ Round up tom s ~ ~~/^~ ~ ~Q.~-{y~ ,t BHST = 82~, Estimated BHCT = 71~. ~C (BHST calculated using a gradient of 2.2/100 ft. below the permafrost} t PUMP SCHEDULE Stage pump Rate Vo ugme Stage Time Cu~~~ve (bpm) (bbl) (minj (minj Water 5.0 10.0 2.0 2.0 Test lines 8~ drop lu 0.0 0.0 10.0 12 0 MUDPUSH II 5.0 20.0 4.0 16.0 Slurry 5.0 23.1 4.6 20.6 Drop top plug 0.0 0.0 5.0 25.6 Mud 7.0 115.7 16.5 42.1 Slow & bump plug 3.0 9.0 3.0 45.1 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, Ty < 15. As thin and Eight as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. - • • ~ Scblumberger CemCADE Preliminary Job Design 4 1l2" Liner, V2 Preliminary Job Design based on limited input data. For estlmate purposes oroy. Rig: Kuukpik#5 Location: Exploration Client: ConocoPhillips Alaska Revision Date: 12/13/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martinl3@slb.com Top of Tail at < 3,044' MD < Liner Top at 3,244' MD Previous Csg. T', 26.0# casing at 3,344' MD < 4 1/2", 12.61x: casing in 6 1/8" OH TD at 3,600' MD (3,600' TVD} 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: 135 min. (pump time plus 120 min.) 15.8 ppg Class G + 0.4%D167 + 0.3%D65 + 0.03%6155 + 0.2%D46 - 1.16 ft3/Sk Liner Cap: 0.1276 ft3/ft x 200' x 1.00 (no excess) = 25.5 ft3 Liner Lap: 0.1044 ft3/ft x (3344' - 3244') x 1.00 (no excess) = 10.4 ft3 Annular Volume: 0.0942 ft3/ft x (3600' - 3344') x 1.50 (50% excess) = 36.2 ft3 Shoe Volume: 0.0854 ft3/ft x 80' x 1.00 (no excess) = 7.7 ft3 Totals: 25.5 ft3+10.4ft3+36.2ft3+7.7ft3= 79.8 ft3 79.8 ft3/ 1.16 ft3/sk = 68.8 sks Round up to 70 sks BHST = 89`1=, Estimated BHCT = 76`F. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbD (min) (min) CW100 5.0 10.0 2.0 2.0 Test lines 0.0 0.0 10.0 12.0 MUDPUSH II 5.0 15.0 3.0 15.0 Liner Slurry 5.0 12.5 2.5 17.5 Drop dart 0.0 0.0 5.0 22.5 Mud 5.0 33.9 6.8 29.3 Slow & bump plug 2.0 6.0 3.0 32.3 MUD REMOVAL Recommended Mud Properties: 10.0 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH" II, Pv = 19-22, TY ~ 22-29 Centralizers: Recommend 1 per joint from 3224' MD to TD for proper cement placement. Mark of Schiumberger • ~~ To: Andy Andreou Heather Perfetta Kevin Dorrington Tom Brassfield From: Kathy Heinlein Date: December 11, 2006 ATO -1312 ATO -1390 ATO -1318 ATO - 1550 ATO - 1460 • Interoffice Communication subject: Pre-Drill Seismic Pore Pressure Analysis for Proposed Well Locations: Intrepid #1, Intrepid #2, Intrepid #3 CONFIDENTIAL The purpose of this memo is to report and review a seismic velocity based pore pressure estimate for three proposed well locations, Intrepid #1, Intrepid #2, Intrepid #3. Summary Seismic velocity data were used to estimate pore pressure gradients likely to be encountered in three well locations proposed for the 2006-2007 drilling season (Intrepid #1, Intrepid #2, Intrepid #3). Local normal compaction trends and local velocity-to-pore pressure gradient translations were established using control from the Walakpa #1, Walakpa #2 and Brontosaurus #1 / Bronto ST 1 offset wells. Figure #1 shows the location of offset wells, proposed well locations, and 2D seismic data used in this study. To estimate pore pressure gradients, local normal compaction trends and translation functions were established from the control wells and then applied to seismic velocities derived from 2D seismic data. The velocity data indicate no apparent shallow hazards or overpressure at depth at the proposed well locations. _ - _ Seismic Processing: The accuracy of seismic pore pressure analysis depends critically on the accuracy of the input velocity field. The velocities used in this study were generated using ConocoPhillips' proprietary AVEL',2 program, an automated high-resolution velocty analysis program developed by ARCO Exploration and Production Technology. This process produces a seismic velocity field defined at every CDP and every 4 milliseconds. AVEL seismic velocities used in this study were smoothed by averaging over 11 CDPs laterally and within a 60 millisecond time window to minimize velocity field instabilities derived from noise, lack of signal, and variations in CDP fold. 1 Swan, H.W., 2001, Velocities from amplitude variations with offset, Geophysics, v. 66, no. 6, p. 1735-1743. z Kan, T. K., and Swan, H. W., 2001, Geopressure prediction from automatically-derived seismic velocities, Geophysics, v. 66, no. 6, p. 1937-1946. • r Three vintages of 2D seismic data were available for analysis (DNPR, WAK89, BAS94 surveys) Seismic velocities calculated in AVEL were found to be variable when comparing surveys at intersecting locations. Figure 2 shows the difference in Interval Transit Time (ITT) calculated from seismic velocity measured in the four seismic lines that intersect the Walakpa #2 well location (DNPR-13, DNPR-9, WAK89-61, WAK89-79). The ITT functions calculated from DNPR-13 and DNPR-9 are identical from 0 ft to 650 ms and have similar trends but are separated by a small shift from 650 to 2200 ms. The functions differ significantly from 2200 to 3500 ms. The ITT functions calculated for WAK89-61 and WAK89-79 vary significantly from the DNPR-9 and DNPR-13 ITT functions, particularly in the interpretation through the permafrost zone in the near surface (approximately 0 - 900 ft). Variability in seismic velocity functions can be due to a number of factors, including anisotropy, quality of seismic data, low fold in the shallow section, and interpretation of the velocity semblance by the seismic processing geophysicist. AVEL calculations are performed within a window based upon an initial set of time/velocity pairs picked by the seismic processor, therefore interpretation of the initial time/velocity pairs is critical. Prestack seismic data (prior to normal moveout) was reviewed in this area to determine the reason for the differences observed in the calculated AVEL velocities. Seismic gathers from DNPR-13 and DNPR-9 at the Walakpa #2 well location are displayed in Figure 3. Normal moveout curves displayed in red define the velocities calculated by AVEL. Data quality is good and there is adequate fold (# of traces in the gather) to determine velocity with confidence. The AVEL values follow the seismic reflectors throughout most of the section. The exception is the shallow section above 300 ms (approximately 0 - 1200 ft), which includes the near surface permafrost zone (approximately 0 - 900 ft) and the zone at the base of permafrost, where there is the potential for gas hydrate formation. True reflection events should display as a hyperbolic curve; the uppermost hyperbolic event observable on DNPR-13 is at to = 300 ms (1200 ft); the first measurable hyperbolic event on DNPR-9 appears at to = 350 ms (1450 ft). Reflection quality is adequate for velocity analysis as deep as 1800 ms, considerably below anticipated TD of the proposed Intrepid wells. Figures 4-5 show the shallow section of the DNPR-13 and DNPR-9 gathers next to the ITT functions calculated at each location from the AVEL velocities. The ITT curves calculated from AVEL start at approximately 80 microsec/ft (velocity = 12,000 ft/sec) at the surface; ITT rapidly increases (indicating a rapid decrease in velocity) until approximately 1200 ft (300 ms). Although similar velocity relationships with depth are often observed in permafrost areas to the east on the North Slope, there are no seismic reflectors to support the interpretation of ahigh-velocity permafrost zone above 300 ms at this location. Prestack seismic gathers (prior to normal moveout) from lines WAK89-61 and WAK89-79 at the Walakpa #2 well location are displayed in Figure 6. Normal moveout curves, which define the velocities calculated by AVEL, are displayed in red. Data quality is noisier than observed in the DNPR survey and the seismic lines are lower fold, but the velocities calculated by AVEL generate normal moveout curves which follow the seismic reflectors throughout most of the section, including the shallow section. Seismic reflection events are observed as shallow as 250 ms and as deep as 1150 - 1200 ms. Figures 7-8 show the shallow section of the WAK89-61 and WAK89-79 gathers next to the ITT functions calculated at each location from the AVEL velocities. AVEL velocities above 250 ms are extrapolated back to the surface as slowly increasing, which is reflected as a slow decrease in ITT. Figure 9 shows the comparison of Interval Transit Times (ITT) measured by the Walakpa #2 sonic vs ITT calculated from seismic velocity data at the Walakpa #2 offset well location. The DNPR shallow ITT values differ significantly from the sonic trend, but below the HRZ (approximately 2200 ft) the DNPR ITT values fit the sonic better than the WAK89 ITT values. Gathers from DNPR-13 and WAK89-61 at the Walakpa #2 location are displayed side-by-side in Figure 10. Note the differences in data quality from surface to the base of permafrost • • (approximately 230 ms) and below the HRZ (approximately 500 ms). Based upon the ties between seismic velocity function and the Walakpa #2 sonic and the observed differences in data quality, the WAK89 survey is expected to provide the best pressure prediction shallow (surface to HRZ); the DNPR and BAS surveys are expected to provide the best pressure prediction deep (HRZ to TD). Pressure at each proposed well location will be calculated separately for each zone, then merged to form a continuous pressure prediction curve. Seismic velocities are sometimes scaled to match sonic profiles to improve the accuracy of pressure gradient variation prediction. The variability observed in seismic velocity values in the different seismic lines in this area combined with the variable relationship of seismic velocities to sonic at well locations made it difficult to determine a suitable scale factor, therefore seismic velocities were not scaled for the this analysis. Potential for the Presence of Gas Hydrates and Seismic Pressure Prediction It is possible that methane hydrates in or around the base of the permafrost transition zone will exhibit acoustic properties that are not sufficiently different from permafrost to be differentiated seismically. Nevertheless, hydrates can pose a significant drilling risk if proper safeguards are not in place. Gas-charged sands and hydrates within the permafrost zone are thought to have contributed to the blowout at the Cirque #1 well (approximately 10 miles southeast of Oberon #1 and 11 miles east-southeast of Titania #1). A thin zone of over-pressured, gas-charged sands was observed at the base of permafrost in the Cirque #2 well. Previous analysis (Heinlein, 20003) shows that there is no apparent indication of the presence of gas hydrates or free gas within or below the permafrost layer on either 2D or 3D seismic data in the area surrounding the Cirque wells. Pressure Prediction Procedure: ConocoPhillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to estimate pore pressure gradients. Pressure prediction models were developed at offset wells using sonic data. Pressure was predicted at the wells from seismic data using these models and found to be a reasonably good fit. The final models were then applied at the proposed well locations to yield a range of predicted pressure. Procedure 1.) Openhole wireline logs for the control wells were compared to the seismic interval transit time (ITT). 2.) The Normal Compaction Trend Line (NCTL) observed at the Walakpa #1 and Walakpa #2 wells has a logarithmic slope of -6.8e-5. The intercept of the NCTL is 128 from surface to HRZ and 138 for depths below the HRZ. 3.) Normal Compaction Trend Lines (NCTL) were determined from 2D seismic data at both the offset and proposed well locations. The NCTL slope measured at the offset well locations is the same as the slope of the NCTL measured at the offset wells (-6.8e-5). The NCTL intercept values calculated from the seismic data varied slightly between 128 and 138 microseconds/foot. s Heinlein, K. H., 2000, Pre-drill seismic pore prediction for proposed well location: Cirque #3, Phillips Alaska, Inc. • • 4.) The inverse ratio of interval transit times (ITT), recorded by wireline sonic logs (4T) in the existing wells or by seismic velocities in the proposed wells, to interval transit times predicted by downward extensions of the NCTLs were calculated. These values are the interval transit time ratios, ITT~/TTo. 5.) A translation trend model was established by comparing transit time ratios (ITT~/TTo) to mud weights in offset wells. This model calculates pore pressure gradients (PPG) using the Eaton's equation4 for pore pressure. or equivalently VES/VES~ _ (ITT~/TTo)" where: PPG is the pore pressure gradient OBG is the overburden gradient PPGn is the normal (not overpressured) pore pressure gradient (8.65 pgg or 0.45 psi/ft) ITT is the normal (not overpressured) interval transit time ITTo is the observed interval transit time N is the Eaton exponent. VES is the vertical effective stress VEST is the normal (not overpressured) vertical effective stress The appropriate value of N for this area was determined to be 0.9 based upon testing using the driller's mud weights as a constraint. This value is similar to values for the Eaton coefficient observed in other areas of the North Slope. 6.) Fracture gradients were calculated using the Eaton method. Inputs are the bulk density, the calculated pore pressure gradient profile, and Poisson's Ratio. The model used for Poisson's Ratio matches models used in previous North Slope pressure prediction studies. 7.) Overburden Gradient (OBG) represents the pressure at depth of the overlying rocks (lithostatic pressure). It is calculated as the integral of the rock density over depth. Pressure Calibration from Offset Control Wells Data from three offset wells (Walakpa #1, Walakpa #2, Brontosaurus #1 / Bronto ST 1) (Figure 1) were analyzed to calibrate parameters for pre-drill seismic based pore pressure estimates. Data from the Walakpa #1 and Walakpa #2 wells were used to establish local normal compaction trend lines and a local velocity vs. pressure translation model. Data from Brontosaurus #1 was also analyzed and used to compare observed trends. The model follows trends observed in previous pressure prediction models from other pressure studies on the North Slope of Alaska. Walakpa #1 A pressure prediction model was developed at Walakpa #1 using interval transit times derived from sonic measurements. Figure 11 shows the sonic velocity based pore pressure /fracture / a Eaton, Ben A. 1975 The equation for geopressure prediction from well logs, SPE 5544. • ~ overburden gradient analyses of this well plotted with observed mud weights, formation tops, and drilling data. The left track contains the wireline sonic 4T (black curve) with the NCTL (red line). The sonic NCTL has a logarithmic slope of -6.8e-5 and an intercept of 128 microseconds/ft. The right track contains the pore pressure gradient calculation (blue curve), actual mud weights (green curve), the calculated fracture gradient (red curve), and the calculated overburden (black curve). Casing points, drill stem tests, and formation tops are as labeled. Pressure predicted from the sonic data and driller's mud weights indicate low pore pressure gradients throughout the well (< 10 PPG to approximately 2000 ft tvd, < 10.5 ppg from 2000 ft and to 3716 ft md). Pressure predicted from sonic ^T data correlates with mud weight with the exception of a small increase observed from 810 - 890 ft md. An increase in observed pore pressure indicates a decrease in sonic velocity; the decrease in velocity at this depth is due to a lithology effect. The Walakpa #1 well location lies along two seismic lines: BAS94-2 and WAK89-79. BAS94-2 is similar in data quality and seismic velocity interpretation to the DNPR lines. Figure 12 shows the pressure values predicted from 2D seismic line BAS94-2 at the Walakpa #1 well location using the model developed from the sonic. The slope of the NCTL observed in the seismic matched the sonic NCTL slope; the intercept observed on the seismic was slightly higher (~,~4` - i 3 Z ~ ,. 3.°~ microseconds/ft). Predicted pressure is posted in blue; drillers mud weights are posted in green. The predicted pressure curve fits the mud weights with the exception of the zone from 450 ft to 640 ft where pressure is very slightly overpredicted. The predicted increase in ppg in this zone is due to inaccuracies in seismic velocity interpretation rather than reflecting a true increase in pressure. Figure 13 shows the pressure values predicted from 2D seismic line WAK89-79. The slope (-6.8e-5) and intercept (128 microseconds/ft) of the seismic. NCTL match the slope and intercept of the sonic NCTL. The predicted pressure values match driller's mud weights nicely from surface to approximately 2800 ft. Pressures are slightly overpredicted below 2800 ft. The match of predicted pressure in the shallow zone with driller's mud weight, and the slight overprediction below 2800 ft match the observations made in the prestack velocity analysis regarding seismic data quality vs ability to accurately resolve seismic velocity. Walakpa #2 Figure 14 shows the sonic-based pore pressure gradient estimates for Walakpa #2 using the pressure prediction model developed at Walakpa #1. The NCTL fits the sonic data from 0 ft tvd to approximately the HRZ (2203 ft md). Pressures predicted in this interval fit driller's mud weights. Two slight overpredictions in pressure at 1400 ft and and 2000 ft and are due to changes in lithology. Pressures below the HRZ are consistently overestimated by the model. Further analysis of the NCTL shows that although the zone below the HRZ appears to be normally compacted and shares the same NCTL slope, the value of the NCTL intercept changes slightly from 128 microseconds/foot above the HRZ to 138 microseconds/foot below the HRZ. Figure 15 shows the pressures predicted using the deeper compaction trend (138 microseconds/foot intercept). With the exception of a false increase in pressure due to a lithology effect at approximately 2680 ft, pressure gradients predicted using the updated NCTL appear reasonable when compared to driller's mud weights. For the purposes of this analysis, pressure predictions will be run using two models. The "Shallow Section Prediction Model" NCTL will use the intercept observed from surface to HRZ (128 microseconds/ft); the "Deep .Section Prediction Model" will use the NCTL intercept observed below the HRZ (138 microseconds/ft). The WAK seismic survey will be used for the • • surface to HRZ pressure prediction based on the quality of seismic velocity; either the BAS or DNPR surveys will be used for the deep pressure prediction from seismic (based on seismic data quality and location relative to proposed offset well). Figures 16 shows the Shallow Section prediction using seismic line WAK89-79. The slope of the seismic NCTL (-6.8e-5) and intercept (128 microseconds/ft} match the slope and intercept of the sonic NCTL. The predicted pressures fit the driller's mud weights nicely from surface to approximately 3000 ft. Pressures are overpredicted below 3000 ft; this observed increase in pressure is most likely caused by a combination of could inability to resolve seismic velocity at this depth combined with a lithology effect. Figure 17 shows the Deep Section pressure prediction calculated from seismic line DNPR-13. The slope of the seismic NCTL (-6.8e-5) matches the slope of the sonic NCTL; the intercept (132 microseconds/ft) varies slightly. Pressures fit mudweights from approximately 1400 ft to 3400 ft; below 3400 ft pressure is overpredicted by as much as .8 ppg. This false increase in predicted pressure is due to a lithology effect. As expected, seismic velocities appear to be overestimating pressure gradients within and at the base of permafrost (550 ft - 1200 ft). Seismic Pore Pressure Analyses for Proposed Well Locations Pore pressure gradients for the proposed well locations were calculated using the NCTL and Eaton type relationship developed from 2D seismic data at the offset well locations. Intrepid #7 Figures 18 - 20 show the seismic pore pressure, fracture gradient and overburden estimates for the Intrepid #1 well location. The vertical axis is TVD depth. Figure 18 shows the pore pressure estimates made using the Shallow Section Prediction Model and seismic line WAK89-28; Figure 19 shows the pore pressure estimate using the Deep Section Prediction Model and seismic line DNPR-9. Figure 20 shows pressure prediction (black) and fracture gradient (green) curves created by merging the Shallow Section prediction (from WAK89-28) with the Deep Section prediction (from DNPR-9). Figure 21 displays the predicted pressure gradients in cross-section along WAK89-28 calculated using the Shallow Section Model; Figure 22 shows the predicted pressure gradients in cross section along DNPR-9 using the Deep Section Model. Intrepid #2 Figures 23-25 show the seismic pore pressure, fracture gradient and overburden estimates for the Intrepid #2 well location. The vertical axis is TVD. Figure 23 shows the pore pressure estimates made using the Shallow Section Prediction Model and seismic line WAK89-30; Figure 24 shows the pore pressure estimate using the Deep Section Prediction Model and using BAS94-2. Figure 25 shows pressure prediction (black) and fracture gradient (green) curves created by merging the Shallow Section prediction (from WAK89-30) with the Deep Section prediction (from BAS94-2). Figure 26 displays the predicted pressure gradients in cross-section along WAK89-30 calculated using the Shallow Section Model; Figure 27 shows the predicted pressure gradients in cross section along BAS94-2 using the Deep Section Model. • • Intrepid #3 Figures 28-30 show the seismic pore pressure, fracture gradient and overburden estimates for the Intrepid #3 well location. The vertical axis is TVD. Figure 28 shows the pore pressure estimates made using the Shallow Section Prediction Model and seismic line WAK89-32; Figure 29 shows the pore pressure estimate using the Deep Section Prediction Model and using BAS94-2. Figure 30 shows pressure prediction (black) and fracture gradient (green) curves created by merging the Shallow Section prediction (from WAK89-32) with the Deep Section prediction (from BAS94-2). Figure 31 displays the predicted pressure gradients in cross-section along WAK89-32 calculated using the Shallow Section Model; Figure 32 shows the predicted pressure gradients in cross section along BAS94-2 using the Deep Section Model. Conclusions 1.) Seismic velocity data indicate no shallow hazards at the proposed well locations. 2.) Seismic velocity data indicated no zones of increased pressure at depth. 3.) Seismic data quality proved to be inadequate to adequately resolve seismic velocity within the permafrost zone in the near surface (0 - 1000 ft); pressure estimates predicted in this zone may be unreliable. • ~ Intrepid Pressure Prediction -Figure Captions Figure 1. Regional basemap showing location of proposed wells in blue (Intrepid #1, Intrepid #2, Intrepid #3), offset wells in red (Walakpa #1, Walakpa #2, Bronto ST 1) and 2D seismic data in black. Figure 2. Comparison of Interval Transit Time (ITT) calculated from seismic velocity at the Walakpa #2 well location. The left tracks show ITT vs depth for the DNPR-13 (black) and DNPR-9 (green) seismic velocities. Low and increasing ITT values in the shallow section represent seismic velocity interpreted through the permafrost zone; below the permafrost zone ITT gradually decreases with depth. The DNPR velocity functions show similar trends in the shallow section and with increasing depth, but the absolute values diverge with depth. The tracks on the right show ITT values calculated from seismic velocities from WAK89-61 and WAK89-79 (red). The shallow velocity functions for WAK89-61 and WAK89-79 are significantly different than the DNPR shallow velocity trend. The WAK89-61 and WAK89-79 functions also vary significantly from each other from approximately 3200 ft - 4200 ft. Figure 3. Prestack seismic gathers from DNPR-13 (left) and DNPR-9 (right) at Walakpa #2 well location. Normal moveout curves representing the velocities calculated by AVEL are displayed in red. Figure 4. Prestack seismic gather (right) from DNPR-13 at Walakpa #2 location. Velocities calculated by AVEL are displayed in red. Interval transit time (ITT) calculated from AVEL velocities vs depth is displayed on the left; ITT is posted in green. Note that the rapid increase in ITT in the near surface (0 - 1000 ft) occurs in a zone with no interpretable seismic reflections. Figure 5. Prestack seismic gather (right) from DNPR-13 at Walakpa #2 location. Velocities calculated by AVEL are displayed in red. Interval transit time (ITT) calculated from AVEL velocities vs depth (left)is displayed on the left; ITT is posted in green. Note that the rapid increase in ITT in the near surface (0 - 1000 ft) occurs in a zone with no interpretable seismic reflections. Figure 6. Prestack seismic gathers from WAK89-61 (left) and WAK89-79 (right) at Walakpa #2 well location. Normal moveout curves representing the velocities calculated by AVEL are displayed in red. Figure 7. Prestack seismic gather (right) from WAK89-61 at Walakpa #2 location. Velocities calculated by AVEL are displayed in red. Interval transit time (ITT) calculated from AVEL velocities vs depth (left)is displayed on the left; ITT is posted in green. Note that ITT values are gradually decreasing as depth increases. Figure 8. Prestack seismic gather (right) from WAK89-79 at Walakpa #2 location. Velocities calculated by AVEL are displayed in red. Interval transit time (ITT) calculated from AVEL velocities vs depth (left)is displayed on the left; ITT is posted in green. Note that ITT values are gradually decreasing as depth increases. Figure 9. Comparison of Interval Transit Times (ITT) measured by the Walakpa #2 sonic vs ITT calculated from seismic velocity data at the Walakpa #2 offset well location. The DNPR shallow ITT values differ significantly from sonic trend but fit the sonic better than the WAK89 lines below the HRZ (approximately 2200 ft). Figure 10. Comparison of seismic data quality between DNPR vs WAK surveys; data from 2D • • seismic lines DNPR-13 and WAK89-61 is displayed at the Walakpa #2 well location. Figure 11. Best-fit sonic PPFG estimate at the Walakpa #1 offset well. The magnitude of the predicted pressure estimate matches the mud weight nicely everywhere except in the section between 750 and 1000 ft. The low sonic velocity and apparently higher pore pressure gradients are caused by a lithology change in this interval rather than high pore pressures. Figure 12. PPFG estimate from 2D seismic line BAS94-2 at the Walakpa #1 well location. The slope of the NCTL used is the same as observed on the Walakpa #1 sonic (-6.8e-5 microseconds/ft2); the best-fit intercept (134 microseconds/ft) is slightly higher than the sonic intercept (128 microseconds/ft). The magnitude of the predicted pressure matches the mud weight nicely everywhere except for a very slight overprediction of ppg between 450 and 640 ft. Figure 13. PPFG estimate from 2D seismic line WAK89-79 at the Walakpa #1 well location. The slope and intercept of the best-fit seismic NCTL match the best-fit sonic NCTL for Walakpa #1 (- 6.8e-5 microseconds/ft2 slope, 128 microseconds/ft intercept). The magnitude of the predicted pressure matches the mud weight nicely everywhere except for slightly overpredicting ppg below 2800 ft. Figure 14. Sonic PPFG estimate at the Walakpa #2 offset well using the pressure prediction model developed at the Walakpa #1 offset well. The NCTL matches the sonic trend and the magnitude of the predicted pressure estimate matches the mud weight nicely from the surface to approximately 2200 ft. There are two locations where the sonic overpredicts pressure based on actual mud weight values (1290 - 1330 ft and 1950 - 2060 ft); these are caused by lithology changes associated with the presence of sands in these intervals rather than high pore pressures. Below 2200 ft, the predicted pressure exceeds the actual mud weight values, and suggest that the pressure prediction model developed at Walakpa #1 is not applicable in this zone. Figure 15. Sonic PPFG estimate at the Walakpa #2 offset well using a revised NCTL calculated using Vsh data from 2000 - 4300 ft. The slope of this NCTL matches the slope of the NCTL calculated at Walakpa #1 (-6.8e-5 microseconds/ft2), but the intercept has changed from 128 microseconds/ft (Walakpa #1) to 138 microseconds/ft. The magnitude of the predicted pressure estimate appears low from the surface to approximately 2200 ft, which is expected because the new NCTL does not fit the shallow data. Predicted pressure values below 2400 ft appear to match the mud weight nicely. A slight overprediction in pressure occurs from 3580 - 3720 ft; this is due to a lithology change. Figure 16. PPFG estimate from 2D seismic line DNPR-9 at the Walakpa #2 well location using the prediction model developed for the shallow section (model designed for surface to 2000 ft; NCTL slope = 128 microseconds/ft2, NCTL intercept = 128 microseconds/ft). Pressure is overpredicted from approximately 400 - 1300 ft; this over estimation of pressure occurs near the base of permafrost (896 ft). Predicted pressure values from 1300 ft - 3400 ft match the mud weights nicely; below 3400 ft an apparent increase in pressure is attributed to a change in lithology. Figure 17. PPFG estimate from 2D seismic line DNPR-13 at the Walakpa #2 well location using the prediction model developed for the deep section (model designed for 2200 ft and below; NCTL intercept = 138 microseconds/ft). Pressures fit mudweights from approximately 1400 ft to 3400 ft. The false increase in predicted pressure below 3400 ft is due to a lithology effect. Figure 18. Pore pressure and fracture gradient estimation at the Intrepid #1 proposed well • • location using the Shallow Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 128 microseconds/ft intercept). Figure 19. Pore pressure and fracture gradient estimation at the Intrepid #1 proposed well location using the Deep Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 138 microseconds/ft intercept). Figure 20. Pore pressure (black) and fracture gradient estimation (red) at the Intrepid #1 proposed well location. The pore pressure and fracture gradient curves were created by merging the Shallow Section prediction (WAK89-28) with the Deep Section prediction (DNPR- 9). Figure 21. Pore pressure gradients estimated along seismic line WAK89-28 using the Shallow Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 128 microseconds/ft intercept). Vertical axis is in sub-sea depth (ft). Figure 22. Pore pressure gradients estimated along seismic line DNPR-9 using the D Figure 22. Pore pressure gradients estimated along seismic line DNPR-9 using the Deep Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 138 microseconds/ft intercept). Vertical axis in sub-sea depth (ft). Proposed well location Intrepid #1 is located directly on DNPR-9. Predicted Pressure Gradients are similar to pressure gradients predicted at Walakpa #2 offset well with the exception of the zone from approximately 2200 - 2800 ft tvd, where pressure gradients in the proposed well location are higher. Figure 23. Pore pressure and fracture gradient estimation at the Intrepid #2 proposed well location using the Shallow Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 128 microseconds/ft intercept). Figure 24. Pore pressure and fracture gradient estimation at the Intrepid #2 proposed well location using the Deep Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 138 microseconds/ft intercept). Figure 25. Pore pressure (black) and fracture gradient estimation (red) at the Intrepid #2 proposed well location. The pore pressure and fracture gradient curves were created by merging the Shallow Section prediction (WAK89-30) with the Deep Section prediction (BAS94- 2). Figure 26. Pore pressure gradients estimated along seismic line WAK89-30 using the Shallow Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 128 microseconds/ft intercept). Vertical axis in sub-sea depth (ft). Proposed well locations Intrepid #2 and Intrepid #3 are located directly on WAK89-30. Figure 27. Pore pressure gradients estimated along seismic line BAS94-2 using the Deep Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 138 microseconds/ft intercept). Vertical axis in sub-sea depth (ft). Proposed well locations Intrepid #2 and Intrepid #3 are located directly on BAS94-2. Figure 28. Pore pressure and fracture gradient estimation at the Intrepid # 3 proposed well location using the Shallow Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 128 microseconds/ft intercept). Figure 29. Pore pressure and fracture gradient estimation at the Intrepid #3 proposed well • location using the Deep Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 138 microseconds/ft intercept). Figure 30. Pore pressure (black) and fracture gradient estimation (red) at the Intrepid #3 proposed well location. The pore pressure and fracture gradient curves were created by merging the Shallow Section prediction (WAK89-32) with the Deep Section prediction (BAS94- 2). Figure 31. Pore pressure gradients estimated along seismic line BAS94-2 using the Shallow Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 128 microseconds/ft intercept). Vertical axis in sub-sea depth (ft). Proposed well locations Intrepid #2 and Intrepid #3 are located directly on BAS94-2. Figure 32. Pore pressure gradients estimated along seismic line BAS94-2 using the Deep Section Model (NCTL: -6.8e-5 microseconds/ft2 slope, 138 microseconds/ft intercept). Vertical axis in sub-sea depth (ft). Proposed well locations Intrepid #2 and Intrepid #3 are located directly on BAS94-2. COnoCOPhillips Project: Intrepid 2006 Regional Basemap ConocoPhillips Pore Pressure and Fracture Gradient System 12/11!06 K. Heinlein Regional Basemap i r~ li.`J Figure 1 / ~ ConocoPhillips Project: Intrepid 2006 ConocoPhilli 5 Pore Pressure and Fracture Gradient S stem Well: Walakpa #2 p y Seismic Velocity Analysis 12/11/06 K. Heinlein • DNPR-13 DNPR-9 WAK89-61 WAK89-79 Note differences ~ in shallow velocity interpretation Figure 2 Interval Transit Time from Seismic Velocity Functions at Walakpa #2 ~ ConocoPhillips Project: Intrepid 2006 Well: Walakpa 2 ConocoPhillips Pore Pressure and Fracture Gradient System Seismic Velocity Analysis 12/11/06 K. Heinlein DNPR Gathers at Walakpa 2 ies calculatc~l~ in roil. • DNPR-13 DNPR-9 Figure 3 ConocoPhillips Project: Intrepid 2006 ConoeoPh~ll~ 5 Pore Pressure and Fracture Gradient S stem Well: Walakpa 2 p y Seismic Velocity Analysis 12!11/06 K. Heinlein DNPR-13 at Walakpa #2: Interval Transit Time from AVEL Velocity vs Seismic Reflection Data EpTH (Dabim setm RKB, MSL) Interval Transit Time Calculated from AVEL displayed in ~~reen. Normal moveout curves representing the velocities calculated by AVEL are displayed in red. • Figure 4 Seismic gather with no moveout applied Interval Transit Time vs Depth ~ ConocoPhillips Project: Intrepid 2006 Well: Walakpa 2 ConoeoPhillips Pore Pressure and Fracture Gradient System Seismic Velocity Analysis 12/11/06 K. Heinlein DNPR-9 at Walakpa #2: Interval Transit Time from AVEL Velocity vs Seismic Reflection Data • Interval Transit Time Calculated from AVE displayed in ~,reen. curves velocities calculated played in red. Figure 5 Seismic gather with no moveout applied Interval Transit Time vs Depth ConocoPhillips Project: Intrepid 2006 Well: Walakpa 2 ConocoPhillips Pore Pressure and Fracture Gradient System Seismic Velocity Analysis 12/11/06 K. Heinlein WAK89 Gathers at Walakpa 2 • • WAK89-61 1500 1600 oveoutcurves ~g the velocities by AVEL are in red. WAK89-79 Figure 6 ~~ ! ConoCOPhilli s Project: Intrepid 2006 p Well: Walakpa 2 ConoeoPhillips Pore Pressure and Fracture Gradient System Seismic Velocity Analysis 12/11/06 K. Heinlein WAK89-61 at Walakpa #2: Interval Transit Time from AVEL Velocity vs Seismic Reflection Data EPTN lDshim sett RKB,MSL) Interval Transit Timc Calculated from AVCL displayed in ~rcon. MSL 200 - ---- aoo ~ 600 i~ ~. ~ooo ._ , 1200 laoo ~ _r 1600 1800 - i ~` - -- --- 2000 -± r -- 2200 - f i ` 2400 ~ ~ - 2600 y -~ - 2800 ~~ I~ ' 3000 -- r ~, - 3200 sann -~ - Interval Transit Time vs Depth Normal moveout curves i representing the vclocilics calculated by AV~L arc displayed in red, C7 Figure 7 Seismic gather with no moveout applied ,.~' ~ ~ COnOCOPhIIIIpS Project: Intrepid 2006 ConoeoPh~ll~ 5 Pore Pressure and Fracture Gradient S stem Well: Walakpa 2 p Y Seismic Velocity Analysis 12/11/06 K. Heinlein WAK89-79 at Walakpa #2: Interval Transit Time from AVEL Velocity vs Seismic Reflection Data IEPTN (Dabsm setto RKB,MSL) MSl 20 i 40 Interval Transit Time Do Calculated from AVEL e0 displayed in ~~reen. 100 120 140 160 180 200 • 220 240 260 28D 300 320C 340L Interval Transit Time vs Depth Normal moveout curves representing the velocities calculated by AVEL are displayed in red. Figure 8 Seismic gather with no moveout applied ConoCOPhillips Project: Intrepid 2006 1e~ Well: Walakpa 2 ConoeoPhillips Por© Pressuro and Fraeturo Gradient System Seismic Velocity Analysis 12/11/06 K. Heinlein • Sonic Black Sonic Black Sonic Black Sonic Black DNPR-13 Green DNPR-9 Green WAK89-61 Red WAK89-79 Red Figure 9 Walakpa #2 Sonic vs Seismic Interval Transit Time ConocoPhillips Project: Intrepid 2006 ConocoPhilli 5 Pore Pressure and Fracture Gradient S stem Well: Walakpa 2 p Y Seismic Velocity Analysis 12/11/06 K. Heinlein DNPR vs WAK89 Gathers Pre-Moveout at Walakpa #2 • • DNPR-13 WAK89-61 Figure 10 ~ ConocoPhilllps Project: Intrepid 2006 Well: Walakpa #1 ConoeoPhillips Pore Pressure and Fracture Gradient System NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Walakpa #1 Pressure Prediction from Sonic n U Figure 11 LogarNhmie Slope = -ile-IS $- tl-il-1 PPEA ~SOnIe NCTL:1t1-q-S UDEp, Top EoLon Exp -1!) -~-FN1ti-~i-S OBG Cuing Depth % Kick 1 flow ~ k112i-iS-S PGEA (Sonic NCTL: Ili-ir-S_UDEF, Poiaaon Madel: 4lEST CAMERON) + Repeat Formation Test X Drill Shm Test -Mud tMeigMc DRILLING MUD wTt D Production Preasure ~ Leak-o6 Test - ® Lost Circulation cones -Formation Top Stack Pipe Location ti Sidetrack Location % Freetarm ConocoPhillips Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Walakpa #1 Y NCTL: 134, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Walakpa #1 Pressure Prediction from BAS 94-2 • • Figure 12 ~- ~~N~-- ~-- -e-Bt 17l-!! PPC Loguigimie Slope = -l.te-15 _ _ X62 132-f9 FG -Mud Weigh: DRILLING MUD WT! ConoCOPhlllips Project: Intrepid 2006 ~ Well: Walakpa #1 ConocoPhillips Poro Pressure and Fracture Gradient SystQm NCTL: 134, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Walakpa #1 Pressure Prediction from WAK89-79 Figure 13 NCTL Intercept nt GL =12i -0- yy itt iE7 PPG Iblgal Logsrilhmic Slope = -fAe-I! _ _ _ o-W! 12! 7E! FG MuatMeigMcDRILLING MUD Wfl y~ ConocoPhillips Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Walakpa #2 Y NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Walakpa #2 Pressure Prediction from Sonic • • Figure 14 ..s.............r. _ -........-.. -~ PM1211-tiE! OBO _ ~ CasingDeplk * NICk1FI0W -~FN12t-{SE! PGEA(SonicNCTL:XISi-ii-5_UDEF,PoiaoonModei:WEST_CAMERON) + Repeat Pormaltlon Teat x Drill Slam Test -Mud Weigh: WALANPA ! MUDWT! ^ Production Pressure ~ Leak-oBTeet - ® Lost Circulation 2onee -Formation Top Stuck Plpe Location t Sidetrack Location $ Preelorm ~ ~ ConocoPhillips Project: Intrepid 2006 Well: Walakpa #2 ConocoPhillips Pore Pressure and Fracture Gradient System NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Walakpa #2 Pressure Prediction from Sonic -NCTL Intercept = 138 Di • Logaritlimic Slope = -illllie-IS ~- FN171-IIEI PPEA (Sonia NCTL: X131-i1-S I~EF, Top Edon Exp a 1!} -~FN17i-iiE7 OBG \ CaaingDeptii * NicklFlow ~-FN13i-GSEf FGEA(SonicNCTL:DPl3i-ii-5 UDEF,Poiecon ModeI:WEST_CAMERON) + Repeat Formation Test x Drill Stem Teet _ Mud weighf: wALMtPA 7 MUDWT7 o Production Pressure ~ Lesk-off Test - ® Loet Circulation cones -Formation Top ~ SWek Pipe Location ti Sidetrack Location % Freeform Figure 15 ConocoPhillips Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Walakpa #2 Y NCTL: 128, -6.8e-5 ~2r~iios K. Heinlein Modified Eaton Method: e = 0.9 Walakpa #2 Pressure Prediction from WAK89-79 Shallow Section Model • Figure 16 m~gm NCTL Ink~cept art GL = t21 -o-- IMt ttl 7E! PPG Logeffgimie Slope : -ije-11 -9-Wt 121~7E! FG -Mud WeIgM: WALANPA ! MUDWT~ ~.-' ConocoPhillips Project: Intrepid 2006 Well: Walakpa #2 ConocoPhillips Pore Pressure and Fracture Gradient System NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Walakpa #2 Pressure Prediction from DNPR-13 Deep Section Model • Figure 17 NCTL Intercept at GL a 13! ~- Du ~~ PPG Ihlgal LoguRhmie Slope ~ -i.ie-IS _ ~ D IS 13t-t! FG + Re Form~oa Tact X DriN Shm Test -~~~'MALANPA Z hWDNTt D Produelioo Proseure ~ Leak-otl Test ®Lost Circulalion ienes -Formation Top Skick Pipe LosaAioa ~ Sidetask Location 8 Freeform ConocoPhillips Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Intrepid #1 Y NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Intrepid #1 Pressure Prediction from WAK89-28 Shallow Section Model • • Figure 18 Iblgal NCTL Intercept nt GL .1l1 -s- W21 1!t E! PPG Loguilhmic Slope = -i.te-IS t+llt 1!i E! OQG ~ W!i 1!Z Ef FG ~,,-' ConoCOPhillips Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem well: Intrepid #1 Y NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Intrepid #1 Pressure Prediction from DNPR-9 Deep Section Model DEPiN IDffism sett MSL) fEEi • • Figure 19 ~~ NCTL Intercept d GL .13! -~*- ~ ~ E! PPO Loguphmic Slope _ -l1e-16 -~ D! tq E! OBG -s-D! 17! E! FG ConocoPhillips Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Intrepid #1 Y NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 • • Intrepid #1 Merged Pressure Prediction Pressure: Black Fracture Gradient: Red Figure 20 DEPTN (Oaium setm RHB,MSL) ~.-' COnoCOPhillipS Project: Intrepid 2006 Well: Intrepid #1 ConoeoPhillips Pore Pressure and Fracture Gradient System NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Pressure Prediction from WAK89-28 ~ Surface to HRZ wain 1 iNiku i D E P T H IN rr~ 8.0o s 8.50 9.00 9.50 14.50 15.00 15.50 16.00 16.50 17.00 17.50 18.00 18.50 19.00 Figure 21 / COnoCOPhillips Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Intrepid #1 Y NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Pressure Prediction from DNPR-9 ~ HRZ to TD WALAKPA 2 INTRE~PI~D_1 C!LV CDP MSL 0,0 1000,0 ~ooo.o 3000.0 D E P T H (Iq 4000.0 5000.0 caoo.o 7000,0 sooo,o 8.00 8.50 9.00 9.50 16.50 17,00 17,50 18.00 18.50 19.00 Figure 22 ConocoPhillips Project: Intrepid 2006 b~ Well: Intrepid #2 ConocoPhillips Porgy Pressure and Fracture Gradient System NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Intrepid #2 Pressure Prediction from WAK89-30 Shallow Section Model Figure 23 Loguilhmic Slope - -iJe-IS -e-1431 1tiE! PPfi -o- W71 122E! FG `/ ConocoPhillips Project: Intrepid 2006 Well: Intrepid #2 ConocoPhillips Pore Pressure and Fracture Gradient System NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Intrepid #2 Pressure Prediction from BAS94-2 Deers Section Model • • DEPTN (Datum sNto RKB,MSLJ FEET MSL _ 200 200 --- --- --_ __~ ___ __ ___ ~ 400 400 , --- --- I 600 --- -- --- --- ~~- --- -- --- 6~ / ~ 800 -- -- -- --- looo looo - -- --- - -- --- -- --- 1200 12oa --- -- --- -- --- -- --- --- 14Do uoo --- - - --- -- --- 1600 1600 -- - -- --- --- -- --- 1800 1800 --- --- --- - -- -- -- __ 2000 2000 -- -- --- --- --- --- -- - 2200 2200 --- - -- --- --- - 2400 2400 --- --- -- --- -- - --- -- 2600 2600 -- --- --- --- --- -- -- 2600 2800 --- - -- --- --- --- -- 3000 3000 --- --- - --- --- --- --- --- ,.. _ 3200 3200 --- --- - --- --- --- -- -- 3400 -- - --- -- - -- 3400 Bann 3600 7U 6U oU mu ¢u i+u mu iou o i ~ ~ ~~ ~~ ~~ •• •- ~- ~~ ~- -- -- NCTL Intercept at GL =131 Iblgot Logarithmic Slope = -iAe-li - ~- 63 131-1E! PPG -*-OYERCALC13i OBG Figure 24 ~-Bf_13f-tEl FG p~ ~ ~ ConoCOPhilllps Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Intrepid #1 Y NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Intrepid #2 Merged Pressure Prediction • Pressure: Black Fracture Gradient: Red Figure 25 6 8 10 12 14 COnocoPhillips Project: Intrepid 2006 Well: Intrepid #2 ConocoPhillips Pore Pressure and Fracture Gradient System NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Pressure Prediction from WAK89-30 ~ Surface to HRZ Yil_1SiE! PPC INTRE_2 D E P T H h4 ~y~ ,.u~,' ,/D ~, 3.07 8.00 6.50 9.~ 9.50 10.00 10,50 11,00 11.50 12.00 12.50 13 AO 13.50 11.00 11.50 15.00 16.50 16.D0 16.50 17.00 17.50 18.00 Figure 26 ConocoPhillips Project: Intrepid 2006 Well: Intrepid #1 ConocoPhillips Pore Pressure and Fracture Gradient System NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Pressure Prediction from BAS94-2 _ HRZ to TD D E P T H Uq I~~ -~-uis0 ~ ~D 7,3,0 !H 6.50 $~~ i 9.00 9.50 10.00 10.50 11.00 11.50 1z.ao 13.00 13.50 14.00 14.50 15.00 15.50 16.00 16,50 17.00 17.50 18.00 18.50 19.00 • Figure 27 WALAKPA_2 INTREPID 2 INTREPIO_3 COnOCOPhllllpS Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Intrepid #3 Y NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Intrepid #3 Pressure Prediction from WAK89-32 Shallow Section Model Figure 28 Iblgel NCTL IMereept ei GL .1!! ~ W92 121-ft PPG Logerithmlc Slope - -~.te-IS -~ WS! 17t-f1~G / ConocoPhlllips Project: Intrepid 2006 Well: Intrepid #3 ConocoPhillips POrQ Pressuro and Fracture Gradient Systam NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Intrepid #3 Pressure Prediction from BAS94-2 Deep Section Model DEYiN (Debtm satlo RKe,MSL) FEET MJL "" 200 --- -- -- - - _-_ ___ 200 400 - --- --- -- --- - - - 400 600 - --- --- -- - --- -- -- 600 B00 -- - - - --- --- - 800 1000 --- -- - --- -- - - - 1000 1200 -- --- -- -- --- -- 1200 1400 - - -- - --- --- 1400 1600 -- --- -- -- - -- 1600 1800 -- -- --- -- --- -- -- 1800 2000 -- -- -- --- -- -- --- 2000 2200 --- -- -- --- --- -- -- -- 2200 r 2400 --- - ~ -- -- --- --- - -- 2400 }} ~ 2600 --- - -- --- -- - 2600 2800 2800 --- --- --- --- - - 3000 3000 --- -- --- --- -- --- -- 3200 -- - - -- --- --- --- 3200 3400 -- -- - -- -- --- -- --- 3400 r~,r,nri 3;U0 4U 6U tlU lUU 12U l4U 1bU l0U n r o 7 w n is w i• m ,o i~ ~o ,a cu NCTL Inhroept of GL =13t Iblgal LogErrilhmioSlope=-ide-IS -e-B713i-7Ef PPC -~ Bt 13i 7E! OBG ~-B2_131-7Ef fG Figure 29 • s COnOCOPhillipS Project: Intrepid 2006 ConocoPhillips Pore Pressure and Fracture Gradient S stem Well: Intrepid #1 Y NCTL: 138, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 i Intrepid #3 Merged Pressure Prediction Pressure: Black Fracture Gradient: Red 10 12 Figure 30 COnOCOPhllllpS Project: Intrepid 2006 Well: Intrepid #3 ConocoPhillips Pore Pressure and Fracture Gradient System NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 D E P T M Ifll e.oo e,so 9.00 9,50 .00 .50 u Figure 31 Pressure Prediction from WAK89-32 ~ Surface to HRZ ~,~K~~I~, / ConocOPhillipS Project: Intrepid 2006 Well: Intrepid #1 ConocoPhillips Pore Pressure and Fracture Gradient System NCTL: 128, -6.8e-5 12/11/06 K. Heinlein Modified Eaton Method: e = 0.9 Pressure Prediction from BAS94-2 ~ HRZ to TD s • D E P T H Ml 11~ 8,00 8.50 9.00 9.50 10.00 10.50 11.00 11,50 12.00 17.00 17,50 18.00 18.50 19.00 Figure 32 WAL®A_2 M7TR® _2 INTR® _S • Kuukpik Drilling Rig 5 Inventory ConocaPhillips NS Exploration 8f15/06 Rig 5 is a winterized 400,000 pound rated Telescopic Double that is containerized except for the substructure and derrick package. Capacity: • 11,500' rated depth (Capable of standing back 9,500' of 4'/z" drill pipe with 6 ~/z" tool joints plus HW and BHA) or (12,000' of 3 If2"' or 4" with 5 '/a" tool joints plus BHA.) Drawworks: • Tesco Hydraulic Single Drum Drawworks, Lebus grooved for 1 1/8" drill line. The Drawworks is equipped with two 50" disk brakes, two calipers for the working brake. The hydraulic system is used as the dynamic brake. Rig Power (hydraulic): • Two Series DDEC N Detroit Diesel Maximum continuous power 600 kw (800 HP); maximum power 634 kw (850 HP) each. • Each. engine driving 6 Linde HPV130 hydraulic pumps. • Total rig hydraulic power 1,200 kw (1,600 HP). • These units provide power for the Drawworks, top drive and one mud pump. Mast: • Tesco 102' double telescoping, freestanding. • 400,000-pound maximum static hook load, with 8 lines. • Certified and built to API 4H specs. • Winterization around the racking board to include a warm up house for the derrick man. Substructure: • Tesco Swing Up 20' high x 12' wide x 40' long (land use).. • KB (rotary) to ground ZO'6", Usable BOP height is 15'. • Casing capacity 400,000 pounds simultaneous with 200,000 poiu~ids setback. • One set of hydraulic cylinders mounted horizontally under the floor for lifting the BOP stack for setting slips, etc, or for moving the BOPs on or off the BOP dolly. Crown. Black. • Tesco maximum static load 400,000 pounds with 4 sheaves, split block. • • Traveling BIocWHook: • Tesco 400,000 pounds split block. Swivel: • Tesco integrated swivel with top drive. Tap Drive: • Tesco Mode1250 HMI Top Drive (250 ton). • Maximum Torque 20,600 ft-lbs, Maximum Speed 175 rpm. • Includes all standard Tesco pipe handling and safety features. • 3" x 55' rotary hose. Rotary Table: • TSM 17.5" opening -hydraulic driven Pump #1 and Pump #2 • #1 Pump: One each Ellis Williams WH 1000 A Triplex: 6" x 10" stroke. • Powered by a Hagglund Hydraulic motors producing 746 kw (1000 HP). • Equipped with PD 45-5000 pulsation dampener. • Operating Range - 0 spm to 150 spm. • Maximum Allowables: (90% of manufacturer's specifications}. • #2 Pump: One each TSM 1000 HP triplex pump • Powered by one each 1000 hp AC electric drive motor • Equipped with PD 45-5000 pulsation dampener. • Operating range - 0 spm to 120 spm. • Maximum Allowables: (90 % of manufacturer's specifications}. Mud System: • Three tanks, 8' wide x 6'9" high x 20' long: six compartments. • -Active capacity 520 bbls. • -Trip tank 30 bbls. • -Pill tank 30 bbls. • 5 each 7.5 HP agitators. • Mixing room with 3 Mission 5 x 6 centrifugal pumps @ 3600 rpm powered by 2 x 22.5 kw (30HP) and 1 x 30 kw (40HP} electric motors. • Harrisburg mixing hopper. • Two each Demck Flowline Cleaner Shale Shakers. • One each Swaco 518 centrifuge. • One mud mixing building 34' long and 8' wide with two each overhead doors to allow for two pallets of mud at one time. A 2nd shear hopper and mix pump would be located in this building. 2 • • Two each 200 bbl pre mix tanks, (400 bbl total) complete with agitation and upper buildings with heat and lights, located by the mud mix building. The centrifugal pump and shear hopper referenced above would provide mixing capabilities for these tanks as well as transferring fluids to the active system. Cuttings Drying System/ Injection/Vt'aste System: • The cuttings drying system consists of one shaker, two augers, lights, heat, 4 each forklift style cuttings buckets and a 100 bbl underflow tank with pump. The cuttings will come from the rig shakers into an auger that will deposit them on the dewatering shaker. The liquids will fall through the shaker screen into the insulated undetflow tank which then could be disposed of or .pumped back to the active system. The solids will go into a reversible auger to the forklift cuttings buckets. • The injection{waste fluid tank will consist of one each 17S bbl insulated tank with 2 each agitators a vertical transfer pump and line capable of rolling the mud. In the tank enclosure building located above will have heat and lights and house the 2na S 18 centrifuge. Weil Controt System: Accumulator: • Control Technology S Station Accumulator • 17(} gallon reservoir • 12 each 1 S gallon battles • Nitrogen backup system • Complete with pneumatic pumps and electric triplex pump Choke Manifold: • 5,000-psi choke manifold mounted in a separate container located next to the substructure. • one Willis 2" manual choke, one Master Flow 2" Hydraulic Remote Choke. • Choke line valves consist of one manual and one Hydraulic valve. • Kill line valves consist of two each manual valves. • One each 5,000 psi upper Kelly valve. • Two each 5,000 psi lower Kelly /Stab in safety valves. • One each 2 1/16" 5,000 psi rated check valve for kill line. Mud Gas Separator: • (Gas buster) located in a separate building beside the sub/shaker building. 3 • • • 30" diameter x 16' high; 3" inlet; 8" outlet. And 10" vent line. Vacuum Degasser: • One each Derrick vacuum degasser. B.O.P.s: (Rental) • One each 11" 5,000 psi Annular • One each 11" 5,000 psi Double Gate • One each 11" 5,000 psi Single Gate • One each 11" 5,000 psi Mud Cross with 3"outlets • One each 11" 5,000 psi spacer spool 3' long • One each Flow Nipple • Ram Blocks included: a. Two sets 4" b. Two sets 4 '/2" c. One set 7" d. One set 3 '/z" e. Two sets Blinds f. One set 2 7/8" to 5 '/2" VBR's Diverter System: • One each 13 5/8" diverter system complete with a 13 5/8" annular and diverter spool with one each 16" flanged outlet. • One each 16" hydraulic operated knife valve • 100' of 16" diverter line complete with flanges, bolts and gaskets. BOP Test Pump: • One each triplex test pump electrically driven, rated at 4.6 gpm at 5,000 psi • Complete with pressure gauges, hoses, and valuing. Instrumentation: • Weight Indicator -PLC controlled. • Pason Electronic Drilling Recorder • Survey Tool - Totco 7 degree wire line drift indicator. • Sierra Monitor (digital) fixed system gas detector for H2S and Methane gas. 3 station. Sensors located at the rig floor, bell nipple and shakers. • Two each GasTech Genesis portable hand held gas detectors. • Pason (Pit Bull Model) Pit Volume Totalizer Tankage: • 700 bbl of rig water storage consisting of one rented 570 bbl Tankco tank and the existing 150 bbl rig water tank. 4 • • • 1140 bbls of heated water storage consisting of two each rented 570 bbl Tankco tanks with steam coils. • 7,500 gallon fuel day tank • Two each rental 570 bbI (1140 bbl total) Tankco tanks for fuel storage complete with suction standpipes, and a fuel transfer pump. P©rtahle Vacuum System: • One each 85 gallon portable vacuum system • One 8' x 20' spill contained winterized building to house the vacuum system. Light Plant Generators: • Three each 14 L Detroit Diesel Series 60 (600 HP each) generators. • These provide AC for the rig and power the #2 Pump. • The system is designed to be able to operate all three generators at one time, although two generators are able to operate the rig, with one being a backup. Hydraulic jacking systein/VVelding unit: • One each 75 KW generator to power the portable hydraulic unit used to raise/lower the sub and derrick. This generator also is designed to provide power to an electric welding machine mounted in the building. Sailers: • Two each 80 HP Volcano Boilers complete with a hotwell tank and a blow down tank. • Approximately 20 steam heaters located around the rig. Rotary Equipment: • Spinner Hawk hydraulic pipe spinner. • Cavins Air Slips 2 3/8" to 5 '/z" • 2 Sets 4 '/2" Drill Pipe Elevators • 2 Sets hand slips for 4 %2" Drill Pipe • 1 Set 6 '/z" Drill Collar Slips • 1 Drill Collar Clamp • Z Sets of Rig tangs • 2 Sets of 8' Elevator Bails Drill SMing: • 11,000' of 4'/z" drill pipe, Grade TSS 95 • 16.60 #/ft with TCS-8000 or equal hardfacing • NC-46 (4'/z" XH) tool joints 6 3/8" OD x 3 '/a" ID • 600' of 4'/z" Heavy-Wate DP, 41#/ft with NC-46 connections • ~ • 6 3/8" OD x 2 7/8" ID • 12 each 6'h" OD x 2 7/16" ID Drill Collars with 4 %" H90 Connections • Crossovers to be provided: a. Saver subs, 2 each NC-46 Pin down for Top Drive b. HW x DC x-overs, 2 each NC-46 box x 4'/2" H-90 Pin c. Bit subs, 2 each 4 '/s" H-90 Box x 4 '/z" reg Box bored for float d. 2 each upper IBOP (top drive) valves - NC-46 Connections e. 2 each lower IBOP (top drive) valves - NC-46 Connections f 2 each Full Opening floor safety valves - NC-46 Connections g. 1 each Dart Valve with NC-46 Connections h. 6 each Lift Subs for 6 '/z" Drill Collars that fit 4 '/2" Elevators Forklift: • One each 2002 Caterpillar IT62G complete with bucket, forks and material handling stinger. • One each Hyster model no. H360H with 36,000 # of lifting capacity to a height of 21.9'. This unit will be used mainly for rig up of the rig. Casing House: One each casing house consisting of 5 each 9' wide x 56' long buildings. When assembled together, the casing house will be 45' wide x 56' long, capable of holding 10,000' of 7" casing. These 5 buildings can be moved in 6 loads of appx. 40,000# each. Complete with lights and spill containment. One each hydraulic pipe handling machine to move the tubulars from the casing house to the rig floor. One each Scissor lift to index the tubulars from the pipe racks to the catwalk. Rig Shop: The rig shop will consist of 8 buildings that, when assembled, will make a 19' wide x 38' long shop with an 18' high x 14' wide door. This building will be easily assembled with the Hyster loader. In additions to the shop, there will be appx. 3 each 8' x 20' parts house buildings to hold rig parts, etc. Complete with lights and heat. Hot Air Heaters: • Two each diesel fired Hot Air heaters, one for the Casing House, and one far the Substructure. The one for the casing 6 • • house is a Z million BTU and the one for the Substructure is a 1 million BTU. Complete with heat ducting. One each 600,000 BTU portable trailer mounted diesel heater for use during rig up. Portable Light Stands: • 4 each portable generators with light to~~~ers to use around the location during rig up and operating. • Ample lighting around the outside of the rig to provide a lighted area while operating. Rig Mats: • Ample rig mats (appx. 40) to use under-the Rig, shop, fuel and water tanks. Pickups: • Two each Crew Cab pickups 7 • • Mu0 Taea NMk TankCmpaVnems antl Agla[ars 9~eka Task Vobme Tack SucIOM Tark Tr Tail h~csr Tank Ia;,ikc k Cea[iMgaT V'uneT A~.'+~Tar. C~1 ank~~~ .;o a ieoesLS ~ s rs;~, ~L> s il5 1006& _ _ ``d Pre M¢ ank 1...~ ()ntlgrflnw Tank ~ = zn Preto ank1 6'tU BPAS ANew Voluma 79 BBLi TrP Tank 30 ~Le Ptll Tank 400 BBL pra mo- 100 B~ stlGlknv 2W BBL wash Upper Bu/dr9 VfM Sags EW:prnan[ - ~ CharteC9 E~ ~'... 0 O MMrenstaP p5 f ~~ UndeMwv PUmq 5g O MrcR wRfl Rig 5 mud system with modifications Kuukpik Dnging Rg$ MOdaetl Mud Tankage ana SoiCS E~pnanent Dtavn By'. L RO66 oaavi~os • 2" 3" To Shaker 3" Panic To Gasbuster 31/8"~ ~, -•- O - ~ ~ *~ + ~-- 2 1/16" ~' O 2 1/16" T o o + I! 21/16" %~'~ 21/16" .+ - N ~ ~ ~ \~ ~ ~ 3 1 /8" r + + + + o ~ 1 2 1/16" + 2 1/16" 1 Manual Choke ~ ~ Automatic Choke 2 ~/16" Inlet ressure Sensor 3" 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold Drawn By: L Ross Date: 8/1 /04 • • fund k;vel to be 20'6) 1 °o 0 20'6" ~~ Weaterford 11' BOPS 10.5' high Beams to Sub floor is 15" rford 11" BOP stack • • • • r Line Opening 20' DIVERTER KUUKPIK DRILLING RIG 5 t 1!22/06 PERMIT T® DRILL 20 ~~ 25.005 (e) Each well branch requires a separate Permit to Drill. If a previously drilled well is proposed to be redrilled below the structural or conductor casing to a new bottom-hole location, the application fora. Permit to Drill must be accompanied by all items required under (c) of this section. If concurrent multiple well branches are proposed from a single conductor, surface, or production casing, (2) for each other well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that well branch and need not be accompanied by the X100 fee. • • _~ ~ E ~ .~ ~ ~ .~ ,~~ ~: 3 --; .-~ N; ~-.,. SHARON K. ALLSUP-DRAKE 1167 " CONOCOPHILLIPS ATO 1530 700 G ST. ~ ~, ANCHORAGE AK 99501 DaTE .~_ 56-1551/441 PAY TO THE ~~~ l ~t-1~~ ! ./I~ ~l 1 ~,.~y ~~ Q ORDER OF / 1 V` (ij"[, , /' `(.JL~ ,. ~~ J+ %/`y," /Yti 1 C/l/ Lam/ - ~sry-GOB ~ c ~(i~i / ~L..,,_ /COQ ,pq "~627LLARS LJ ~~ o.~~ JPMorganChase ~ j Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH J /~ MEMO ~Z _ i _ ~ ~~~~J - `~ ~:0441~55L1~:5 28 74 7 190 79 2 7u'LL6? ~~ • • TRANSMITTAL LETTER C~IECKLIST WELL NAME ~-~'~'~~~°~ Z' PTD# ~~ ~ ^ l ~d Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT ~ (OPTIONS) APPLIES I TEXT FOR APPROVAL LETTER ~ I MliLTI LATERAL ~ The permit is for a new wellbore segment of existing j I ~ well _ j (If fast two digits in i ,Permit No. , API No. ~0- - - ; API number are ,~ between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs ;acquired for the pilot hole must be clearly differentiated in both ~ i I well name ( PH) and API number j II' (50- - -_, from records, data and logs ~ ~ I acquired for wets I SPACING 'The permit is approved subject to full compliance with 20 AAC ;EXCEPTION ~ 2~.0». Approval to perforate and produce /inject is contingent ~ i ', I upon issuance of a conservation order approving a spacing j ~ ~ ~ exception. assumes the ~ liability of any protest to the spacing exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the Commission must be in i i SAMPLE I no greater than 30' sample intervals from below the permafrost or i I I from where samples are first caught and 10' sample intervals j through target zones. j I ~ , ~ Please note the following special condition of this permit: I ~ Non-Conventional I production or production testing of coal bed methane is not allowed j I Well 'for (name of well) until after (Company Name) has designed and ~ ~ implemented a water well testing program to provide baseline data j ', on water quality and quantity. (Com any Name) must contact the I ~ Commission to obtain advance approval of such water well testing ~ _ ~ program. ~ Rev: 12~i06 C:`jody~transmittal_checklist QUELL ?ERMIT CHECKLIST Field & Pool_ _ _ _ _ _ __-__Well Name: INTREPID 2_ ___ Program EXP__-__^ Well bore seg PTD#:2061900 Company CO~HILLIPS ALASKA INC _ _-___ Initial Classffype EXP 1 PEND___GeoArea 8so _-_,___ Unit ____ On/Off Shore ~-____ Annular Disposal 1 Administration I Permitfee attached_ Yes I 2 Lease number appropriate- . - Yes Lease numbers confirmed with-NSB_ and ASRC, 3 Unique well-name and number________________ Yes_ _____---,---_-___-__-_-------_ I4 Well located in a defined_pogl- No Exploratory well_ located X25 mi SW of Barrow and 6 mi SW-of nearest well_Walakpa No..-2. 15 I Well located proper distance_ from drilling unit_boundary- Yes . Exploratory well, statewide spacing regulations apply, Well is more than_ 1_,500'_ from nearestproperty line, . . j6 Well located proper distance from other wells _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - . Nearest well_is Walakpa No. 2,.which is6 miles to NE. - - - _ _ _ _ _ _ _ _ _ .. - _ _ _ _ _ _ _ _ _ _ _ _ _ ~7 Sufficient acreage available in drilling unit_ Yes , - .. - Exploratory well, statewide spacing regulations apply, - - - !8 If deviated, is_wellbore plat_inclu_ded _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ - - - - - _ _ _ _ _ NA_ Vertical well- - - - . _ _ _ ~9 Operaloronlyaffectedparty________ __________________________- __ Yes_ 110 Operator has_appropriate.bond in force - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit can be issued without conservation order- Yes Appr Date X12 Permitc_an be issued without administrative_approval - - Yes . - - - - SFD 1/24/2007 '13 Can permit be approved before 15-day wait Yes ~14 Well located witftin area and strata authorized by_ InjQCtion Order # (put_10# in-cgmments)_(For. NA. 115 All wells-within 1!4_mile area of review identified (For service well only)- - - - - - - - - - - - - - NA- - - _ _ - - - - - - -- -- - - -- 116 Pre-produced injeetor_ duration.of pre production less than 3 months_ (For service well only) NA- 17 Nonconven. gas conforms to AS31.D5,030(~.1.A),(1.2.A-D) NA C Engineering 118 C_anductor string_provided . - Yes 119 Surface casing-protects all_knpwn USDWs - - Yes Analyses-qf offset wells Brontosaurus.1 and Walakpa 2 demonstrate that there are no USDWs in this area._ SFD _ ~I20 CMT vol_ adequate-to circul_ate_on conductor_ & surf_csg - - - _ . - Yes - ',21 CMT_vol_ adequate_to tie-in long string to surf csg_ No 22 CMTwillcoverallknown-productiyehorizons_______________________ ______ Yes___ ___-.-,.--________ X23 .Casing designs adequate for C,T,B&_pe[mafr_ost- --- --- ------ --- --- -- Yes .- ------- .-- ----- ----- ----- --- 24 Adequate tankage_o_r reserve pit Yes - Rig isequipped with st_eel_pits.. No reserue_pitplanned, Annular disposal_may_berequested, - 25 If a_re-drill, has_a_ 10-403 for abandonment been approved _ _ _ __ _ _ _ _ _ _ _ _ _ _ N_A- _ _ _ I26 Adequate wellbore separation_proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ _ _ - _ _ No wellsp[oximate-in area.- - - - - - . _ . - - 27 If-tliverter required, does it meet regulations- Yes , _ . - - - Appr Date i~28 Drilling fluid_ program schematic & equip list adequate_ Yes - - Maximum expected formation pressu[e 9,8_ EMW.- Planned mud weight_in zone up to-10,0-ppg._ TEM 1/2612007 129 BOPEs,dotheymeetregulation._______----------------- - Yes- . -------- -------------- ------------- -- ------ -------------- -_--_-- a gam, /( 30 BOPS press rating appropriate, test t_o (pu_t psig in comments)_ - _ - - Yes _ _ _ MASP calculated at 1439 psj. 3000-psi appropriate. CPAI usually_test& to 5000_ psi. , 131 Choke-manifold complies wlAPI-RP-53 ~M_ay 84) - Yes . - - ~32 Work wilt occur without operation shutdow_n_ No- . _ . - - - An OSD might be necessa if available time becomes_short. 133 Is presence_ of H2S gas probable - . - - . . - - - - No_ - . - - H2S is unknown in ihe-area, Rig is equippQd with sensors and alarms-- - - - - - - - - - - - - - - - - - ---- - '34 Mechanical-condition of wells within AOR verified (For service well only) NA, Geology X35 Permit can be issued w/o hydrogen_ sulfide measures _ No Exploratory well: H2S measures_ required. - - ~36 Data-presented on_ potential overpressure zones - - - - - . Yes - Expected r_eservoirpressure is 9.8-ppg EMW; will be drilled with 9.8.10.0 ppg_mud, Shallow hazards_analysis - - Appr Date 137 Seismic analysis-of shallow gas-zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - concludes thatlhere is no-evidence of shallow_hazards of overpressure, Gas-hydrated may be encoun_iered _ - SFD 1/3/2D07 1,,38 Seabed condition survey_(if off-shore) NA, - beneath permafrost, mitigation measures-discussed in Drilling Hazards Summary, - ~39 Contact name/phone fo_r weekly-progress reports [exploratory only] - _ - - - Yes - Tom Brasfield 265-6377 Geologic Engineering P I' Commissioner: Date: Commissioner: Date ner Date ~S 126 7 - lTd6~ o~- • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify minding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. PETROLEUM SERVICES Core Lab RESERVOIR OPTIMIZATION f'- " CORE ANALYSIS RESULTS 2~~-iga CONOCOPHILLIPS ALASKA, INC. INTREPID #2 WELL ao(a-l°10 BAR~~OW SOUTH FIELD ~ ~sa~y CL FILE 57111-107239CP Performed by: Core Laboratories 3437 Landco Dr. Bakersfield, CA 93308 (661 j 392-8600 A;~ Care Lab AESERYOIR oPT[Ni2ATI0N Andreas Andreou ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 Subject: Transmittal of Conventional Core Analysis Data Intrepid #2 Well Barrow-South Field CL File No. 57111-107239CP Dear Mr. Andreou: Petroleum Services Division 3437 Landco Dr. Bakersfield, California 93308 Tel: 661-325-5657 Fax:661-325-5808 www.corelab.com June 28, 2007 Core Laboratories field personnel provided core handling services for conventional aluminum inner-barrel cores recovered from the subject well. Recovered core was packaged and shipped to Anchorage Alaska where it was met at the airport by Core Laboratories personnel who transported it to our Anchorage laboratory for initial processing. Upon arrival at the laboratory the core was scanned for natural gamma radiation. The scanned core was removed from the aluminum barrels and slabbed using cone-quarter/three-quarter cut. Afour-tenths of a foot segment from each foot of the three-quarter slabbed section was set aside for plugging. The one- quarterslabs were mounted in slab boxes for photography and description, and the remaining three- quarter sections were preserved by wrapping with Saran Wrap and aluminum foil and then coating with CoreSeal. Horizontal and vertically oriented plug samples were drilled from each of-the set-aside sample segments for routine analysis. Slabbing and plug drilling was performed using Isopar as the coolant. The mounted one-quarter slabbed core was photographed under white light and ultra-violet light for presentation with our Core Viewer. Following core photography all core materials were picked up by personnel from ConocoPhillips' Bayview Geological Facility in Anchorage, Alaska. Thirty-five horizontally oriented samples and twenty-two vertically oriented samples were subsequently forwarded by CPAI to our Bakersfield, California laboratory for routine analysis. The thirty-five horizontally oriented samples were analyzed by Dean-Stark methods with porosity and permeability measurements made using the CMS-300 automated core measurement system. Measurements were made at 800, 1000, 1500, and 2000 psig net stress. Every third vertical plug had been reserved for geochemical testing by ConocoPhillips. These reserved samples were not forwarded to Bakersfield. The remaining vertical plugs were sent to Bakersfield for ' analysis. The vertical samples were cleaned and dried prior to CMS-300 analysis using the same series of applied net stresses as was used for the horizontally oriented samples. ' We appreciate this opportunity to have been of service and look forward to working with you again in the future. All core materials will be returned to CPAI upon completion of analysis. - Rock Properties ' Distribution: 1 Core Book, 5cc report, 6 CDs: addressee CLB iS~ ConocoPhillips Alaska Inc. Location: Sec.11-19N/2OW File No.: 1O7239CP ~k'~. <, Intrepid 2 Well API No.: 50-023-20036 CoreLah Barrow-South Field Date: 6\25\2007 nesrevo~p ornnannax Conventional Core Analysis. Results CMS-300 @ 800 psi Net Stress Sample Depth Perm. Porosity Fluid Saturation Grain Method Description Number ft Kair and % Oil % Water % O/W Ratio Total % Den glcc 1 3128.1 334.64 23.7 27.4 64.1 0.43 91.6 2.65 4 Sst gry of-fgr slty no stn no flor 2 3129.1 378.80 24.4 31.8 54.1 0.59 85.9 2.65 4 Sst gry of-fgr slty no stn no flor 3 3130.1 49.68 19.2 3.8 75.8 0.05 79.6 2.65 4 Sst gry vfgr slty no stn no flor 4 3131.1 321.08 23.7 10.2 70.8 0.14 81.0 2.65 4 Sst gry vfgr slty no stn no flor 5 3132.3 88.58 20.6 6.7 78.3 0.09 85.0 2.65 4 Sst gry vfgr slty no stn no flor 6 3133.1 72.46. 20.7 12.2 70.4 0.17 82.6 2.65 4 Sst gry vfgr slty no stn no flor 7 3134.1 1.68 12.3 4.0 66.0 0.06 69.9 2.76 4 Sltst gry-Ibrn Istrk stn wh flor 8 3135.1 4.26 15.3 3.6 73.6 0.05 77.2 2.65 4 Sst gry vfgr vslty no stn no flor 9 3136.1 4.14 15.6 22.5 59.7 0.38 82.1 2.66 4 Sst gry vfgr vslty no stn no flor 10 3137.1 18.88 18.3 24.7 55.1 0.45 79.8 2.65 4 Sst gry vfgr slty no stn no flor 11 3138.1 8.51 17.1 6.3 73.3 0.09 79.5 2.65 4 Sst gry vfgr vslty no stn no flor 12 3139.1 0.43 12.1 15.0 76.1 0.20 91.1 2.66 4 Sst gry vfgr vslty no stn no flor 13 3140.1 0.94 13.4 17.4 70.4 0.25 87.9 2.65 4 Sst gry vfgr vslty no stn no flor 14 3141.1 11.41 18.0 18.9 69.0 0.27 88.0 2.66 4 Sst gry vfgr slty no stn no flor 15 3142.1 9.05 16.6 19.3 71.7 0.27 91.0 2.67 4 Sst gry-tn vfgr vslty Isptd stn wh flor 16 3143.1 42.04 19.1 15.8 70.8 0.22 86.7 2.65 4 Sst gry-tn vfgr vslty Isptd stn wh flor 17 3144.1 17.36 17.7 18.9 68.8 0.27 87.7 2.65 4 Sst gry vfgr vslty no stn no flor 18 3145.1 3.92 15.5 10.3 68.2 0.15 78.5 2.68 4 Sst gry-tn vfgr vslty Isptd stn wh flor 19 3146.3 0.03 7.7 6.3 93.2 0.07 99.5 2.94 4 Sst gry-tn vfgr vslty Is? lam Isptd stn wh flor 20 3147.5 1.02 13.8 17.0 72.6 0.23 89.5 2.66 4 Sst gry-tn vfgr vslty sh incl Isptd stn wh flor 21 3148.3 1.41 13.7 21.2 75.9 0.28 97.1 2.67 4 Sst gry vfgr vslty sh lams no stn no flor 22 3149.3 8.35 16.5 20.0 73.0 0.27 93.0 2.65 4 Sst gry vfgr vslty no stn no flor 23 3150.5 13.89 18.4 18.3 69.7 0.26 88.0 2.65 4 Sst gry vfgr slty no stn no flor 24 3151.5 7.62 16.8 22.9 69.4 0.33 92.3 2.67 4 Sst gry-Itn vfgr vslty Isptd stn wh flor 25 3152.5 7.50 16.5 21.5 70.6 0.30 92.1 2.68 4 Sst gry-Itn vfgr vslty Isptd stn wh flor For Method Definitions See Procedures Page ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP -,~~~.'~"; Intrepid 2 Well API No.: 50-023-20036 rir;,°;~;d ;.. ~®r~ sae Barrow-South Field Date: 6/25/2007 A£SERVOIP aPTIMIZATION Conventional Core Analysis Results CMS-300 @ 800 psi Net Stress Sample -Depth- Perm. ,Porosity Fluid Saturation Grain Method Description Number ft Kair and % Oil % Water % O/W Ratio Total % Den glcc 26 3153.3 10.62 17.4 192 71.0 0.27 90.2 2.67 4 Sst gry vfgr slty no stn no flor 27 3154.3 28.86 18.9 19.4 70.4 0.28 89.9 2.65 4 Sst gry vfgr slty no stn no flor 28 3155.3 12.07 18.1 11.6 64.9 0.18 76.5 2.65 4 Sst gry-itn vfgr slty Isptd stn wh flor 29 3156.3 15.79 17.4 12.6 69.3 0.18 81.9 2.65 4 Sst gry vfgr slty no stn no flor 30 3157.3 93.50 21.1 17.0 70.7 0.24 87.7 2.64 4 Sst gry-Itn vfgr slty Isptd stn wh flor 31 3158.3 110.79 22.2 16.7 64.5 0.26 81.1 2.66 4 Sst gry-Itn vfgr slty Isptd stn wh flor 32 3159.3 148.18 21.9 19.0 70.3 0.27 89.3 2.65 4 Sst gry vfgr slty no stn no flor 33 3160.5 99.10 21.7 17.0 71.7 0.24 88.7 2.65 4 Sst gry vfgr slty no stn no flor 34 3161.3 6.96 15.1 11.1 71.1 0.16 82.1 2.65 3 Sst gry vfgr vslty no stn no flor 35 3162.3 < 0.001 7.6 1.4 97.7 0.01 99.1 3.18 3 Mdst gry vfgr sdy pyr no stn no flor For Method Definitions See Procedures Page ~`~ <: ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP Intrepid 2 Well API No.: 50-023-20036 Core Lab Barrow-South Field Date: 6/25/2007 RRSERVOIR °PTiPNZATi°N CMS-300 Permeability and Porosity at 800 psi Net Stress Sample Depth Hor. Permeability Vert. Permeability b 'beta alpha Porosity Grain ID ft Kair and Kklink and Kair and Kklink and psi; 1/ft microns % Den g/cc 1 3128.1 335. 323. 1.65E+00 6.52E+06 6.82E+00 23.7 2.65 2 3129.1 379. 365. 1.64E+00 5.89E+06 6.97E+00 24.4 2.65 2V 3129.3 350. 340. 1.40E+00 6.47E+06 7.12E+00 24.1 2.66 3 3130.1 49.7 45.6 4.40E+00 7.43E+07 1.10E+01 19.2 2.65 3V 3130.3 54.9 50.3 4.58E+00 6.62E+07 1.08E+01 19.5 2.64 4 3131.1 321. 310. 1.64E+00 7.51E+06 7.53E+00 23.7 2.65 5 3132.3 88.6 82.8 3.38E+00 3.50E+07 9.38E+00 20.6 2.65 5V 3132.0 114. 107. 3.08E+00 2.48E+07 8.60E+00 21.7 2.66 6 3133.1 72.5 67.4 3.66E+00 4.42E+07 9.64E+00 20.7 2.65 6V 3133.0 65.6 60.4 4.26E+00 5.27E+07 1.03E+01 20.6 2.66 7 3134.1 1.68 1.33 1.60E+01 3.63E+10 1.57E+02 12.3 2.76 8 3135.1 4.26 3.42 1.41E+01 2.91E+09 3.22E+01 15.3 2.65 8V 3135.3 0.269 0.152 5.48E+01 1.41E+12 6.93E+02 13.5 2.66 9 3136.1 4.14 3.35 1.36E+01 4.39E+Og 4.76E+01 15.6 2.66 9V 3136.3 0.544 0.350 3.71 E+01 1.23E+12 1.39E+03 15.2 2.67 10 3137.1 18.9 16.6 7.23E+00 2.24E+08 1.21E+01 18.3 2.65 11 3138.1 8.51 7.16 1.03E+01 7.23E+08 1.68E+01 17.1 2.65 11V 3138.3 3.22 2.49 1.72E+01 1.08E+10 8.75E+01 17.5 2.66 12 3139.1 0.430 0.279 3.64E+01 3.25E+11 2.94E+02 12.1 2.66 12V 3139.3 0.112 0.056 7.65E+01 2.04E+13 3.66E+03 12.7 2.67 13 3140.1 0.945 0.679 2.48E+01 1.37E+11 3.01E+02 13.4 2.65 14 3141.1 11.4 9.80 8.85E+00 4.85E+08 1.54E+01 18.0 2.66 14V 3141.3 0.418 0.237 5.25E+01 6.11E+11 4.69E+02 15.4 2.66 15 3142.1 9.05 7.73 9.29E+00 1.10E+09 2.75E+01 16.6 2.67 15V 3142.0 4.66 3.86 1.19E+01 3.64E+09 4.55E+01 15.4 2.69 For Method Definitions See Procedures Page _ ' ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP Intrepid 2 Well API No.: 50-023-20036 J '.;.i Corte ~~~ Barrow-South Field Date: 6125\2007 11F,SERVQIP OPTIMIZgiiI1N CMS-300 Permeability and Porosity at 800 psi Net Stress Sample Depth Hor. Permeability Ven.. Permeability b ,beta> alpha Porosity Grain iD ft Kar and Kklink and Kair and Kklink and psi 1Ift microns % Den glee 16 3143.1 42.0 38.3 4.79E+00 9.05E+07 1.12E+01 19.1 2.65 17 3144.1 17.4 15.3 7.20E+00 3.36E+08 1.66E+01 17.7 2.65 17V 3144.0 5.84 4.71 1.36E+01 2.62E+09 4.00E+01 17.5 2.66 18 3145.1 3.92 3.18 1.33E+01 5.66E+09 5.84E+01 15.5 2.68 18V 3145.0 35.0 31.7 5.32E+00 1.00E+08 1.03E+01 18.7 2.66 19 3146.3 0.033 0.018 6.43E+01 1.66E+14 9.80E+03 7.7 2.94 20 3147.5 1.02 0.739 2.42E+01 1.26E+11 3.01 E+02 13.8 2.66 20V 3147.5 0.117 0.060 7.16E+01 3.40E+13 6.62E+03 13.0 2.66 21 3148.3 1.41 1.08 1.87E+01 5.86E+10 2.06E+02 13.7 2.67 21 V 3148.2 0.273 0.161 4.86E+01 2.31E+12 1.21E+03 13.8 2.68 22 3149.3 8.35 7.06 9.99E+00 1.03E+09 2.35E+01 16.5 2.65 23 3150.5 13.9 12.1 8.00E+00 5.07E+08 1.98E+01 18.4 2.65 23V 3150.2 1.61 1.07 3.13E+01 1.00E+11 3.48E+02 17.5 2.67 24 3151.5 7.62 6.43 1.02E+01 9.51 E+08 1.98E+01 16.8 2.67 24V 3151.5 1.79 1.19 3.10E+01 5.40E+10 2.08E+02 17.0 2.68 25 3152.5 7.50 6.35 9.98E+00 8.82E+08 1.81E+01 16.5 2.68 26 3153.3 10.6 9.154 8.64E+00 5.29E+08 1.57E+01 17.4 2.67 26V 3153.5 1.10 0.718 3.36E+01 1.36E+11 3.16E+02 15.8 2.67 27 3154.3 28.9 25.8 5.92E+00 1.75E+08 1.46E+01 18.9 2.65 27V 3154.5 11.1 9.46 9.22E+00 6.07E+08 1.86E+01 18.3 2.65 28 3155.3 12.1 10.4 8.44E+00 5.30E+08 1.79E+01 18.1 2.65 29 3156.3 15.8 13.8 7.68E+00 3.78E+08 1.69E+01 17.4 2.65 29V 3156.2 14.8 12.7 8.74E+00 3.88E+08 1.60E+01 18.4 2.66 30 3157.3 93.5 87.4 3.33E+00 3.15E+07 8.91 E+00 21.1 2.64 30V 3157.2 89.6 83.8 3.34E+00 3.27E+07 8.89E+00 21.0 2.66. For Method Definitions See Procedures Page ;~ fi. ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP Intrepid 2 Well API No.: 50-023-20036 "; Barrow-South Field Date: 6\2512007 Cinre L.ab 1lESF.RYIIIR OPTIMI7.ATIRN CMS-300 Permeability and Porosity at 800 psi Net Stress Sample Depth 'Hor. Permeability Vert. Permeability b beta alpha Porosity Grain ID ft Kair and Kklink and Kair and Kklink and psi 1/ft microns % Den glcc 31 3158.3 111. 104. 3.04E+00 2.91E+07 9.82E+00 22.2 2.66 32 3159.3 148. 140. 2.65E+00 1.86E+07 8.42E+00 21.9 2.65 32V 3159.2 143. 136. 2.47E+00 2.06E+07 9.04E+00 22.1 2.65 33 3160.5 99.1 92.6 3.34E+00 2.97E+07 8.90E+00 21.7 2.65 33V 3160.5 69.9 64.5 4.08E+00 4.38E+07 9.16E+00 21.3 2.66 34 3161.3 6.96 5.87 1.03E+01 1.50E+09 2.85E+01 15.1 2.65 '` 35 3162.3 < 0.001 7.6 3.18 35V 3162.6 < 0.001 8.1 3.11 For Method Definitions See Procedures Page ~ ll~ I ~ I ~ ~ lllllllr ~ ~ Ir lll~ ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP ~~~ .~ :: Intrepid 2 Well API No.: 50-023-20036 ='~~"- "` Barrow-South Field Date: 6\2512007 Care Lab R~SLAVOIA IiPTIMI'LA1'tON CMS-300 Permeability and Porosity at 1000 psi Net Stress Sample Depth Mor. Permeability Vert. Permeability b beta alpha Porosity Grain ID ft Kair. and ` Kklink and Kair and Kklink and psi 1/ft microns % Den g/cc 1 3128.1 331. 319. 1.80E+00 6.25E+06 6.45E+00 23.7 2.65 2 3129.1 375. 362. 1.70E+00 5.69E+06 6.66E+00 24.3 2.65 2V 3129.3 347. 336. 1.53E+00 6.20E+06 6.74E+00 24.1 2.66 3 3130.1 49.4 45.3 4.46E+00 7.51 E+07 1.10E+01 19.1 2.65 3V 3130.3 54.6 49.9 4.72E+00 6.61E+07 1.07E+01 19.4 2.64 4 3131.1 318. 307. 1.70E+00 7.32E+06 7.28E+00 23.7 2.65 5 3132.3 88.2 82.2 3.46E+00 3.49E+07 9.29E+00 20.5 2.65 5V 3132.0 113. 106. 3.13E+00 2.50E+07 8.59E+00 21.6 2.66 6 3133.1 72.1 66.9 3.80E+00 4.37E+07 9.46E+00 20.6 2.65 6V 3133.0 65.3 60.1 4.25E+00 5.35E+07 1.04E+01 20.5 2.66 7 3134.1 1.64 1.30 1.62E+01 3.26E+10 1.37E+02 12.2 2.76 8 3135.1 4.21 3.38 1.40E+01 3.20E+09 3.51E+01 15.2 2.65 8V 3135.3 0.252 0.139 5.74E+01 1.09E+12 4.93E+02 13.4 2.66 9 3136.1 4.09 3.30 1.37E+01 4.33E+09 4.63E+01 15.5 2.66 9V 3136.3 0.521 0.331 3.87E+01 1.18E+12 1.26E+03 15.1 2.67 10 3137.1 18.8 16.5 7.29E+00 2.22E+08 1.19E+01 18.3 2.65 11 3138.1 8.45 7.10 1.04E+01 7.01E+08 1.61E+01 17.0 2.65 11 V 3138.3 3.18 2.46 1.72E+01 1.06E+10 8.41E+01 17.4 2.66 12 3139.1 0.417 0.269 3.70E+01 2.74E+11 2.39E+02 12.0 2.66 12V 3139.3 0.101 0.047 8.74E+01 9.62E+12 1.47E+03 12.5 2.67 13 3140.1 0.924 0.662 2.52E+01 1.20E+11 2.56E+02 13.3 2.65 14 3141.1 11.3 9.70 8.90E+00 4.85E+08 1.52E+01 17.9 2.66 14V 3141.3 0.385 0.212 5.67E+01 5.72E+11 3.92E+02 15.3 2.66 15 3142.1 8.97 7.67 9.24E+00 1.13E+09 2.82E+01 16.5 2.67 15V 3142.0 4.63 3.84 1.19E+01 3.62E+09 4.50E+01 15.3 2.69 For Method Definitions See Procedures Page ..~l;' ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP . Intrepid 2 Well API No.: 50-023-20036 [ore Lela Barrow-South Field Date: 6/25/2007 RE5GNVOIR OPTIM/ZATIIIN CMS-300 Permeability and Porosity at 1000 psi Net Stress Sample Depth Har. Permeability Vert. Permeability b ?beta alpha Porosity Grairr iD ft Kai# Kklink rnd and Kair and Kklink and psi 1!ft microns. % Den glcc 16 3143.1 41.8 38.2 4.79E+00 9.17E+07 1.13E+01 19.1 2.65 17 3144.1 17.2 15.2 7.14E+00 3.50E+08 1.72E+01 17.7 2.65 17V 3144.0 5.78 4.67 1.34E+01 2.80E+09 4.24E+01 17.4 2.66 18 3145.1 3.88 3.15 1.33E+01 5.49E+09 5.60E+01 15.4 2.68 18V 3145.0 34.8 31.5 5.38E+00 9.97E+07 1.02E+01 18.6 2.66 19 3146.3 0.027 0.015 7.12E+01 5.68E+13 2.69E+03 7.6 2.94 20 3147.5 1.00 0.725 2.42E+01 1.06E+11 2.49E+02 13.6 2.66 20V 3147.5 0.107 0.053 7.78E+01 3.25E+13 5.57E+03 12.9 2.66 21 3148.3 1.39 1.07 1.87E+01 5.68E+10 1.97E+02 13.6 2.67 21 V 3148.2 0.262 0.154 4.96E+01 2.26E+12 1.13E+03 13.7 2.68 22 3149.3 8.26 6.99 1.00E+01 1.02E+09 2.30E+01 16.5 2.65 23 3150.5 13.8 12.0 8.02E+00 5.14E+08 1.99E+01 18.3 2.65 23V 3150.2 1.54 1.01 3.22E+01 9.59E+10 3.15E+02 17.4 2.67 24 3151.5 7.54 6.35 1.03E+01 9.37E+08 1.93E+01 16.6 2.67 24V 3151.5 1.74 1.16 3.10E+01 5.59E+10 2.10E+02 16.9 2.68 25 3152.5 7.44 6.32 9.81E+00 1.09E+09 2.22E+01 16.4 2.68 26 3153.3 10.5 9.066 8.69E+00 5.19E+08 1.52E+01 17.2 2.67 26V 3153.5 1.07 0.699 3.36E+01 1.44E+11 3.26E+02 15.7 2.67 27 3154.3 28.7 25.7 5.93E+00 1.77E+08 1.47E+01 18.8 2.65 27V 3154.5 11.0 9.39 9.18E+00 6.33E+08 1.92E+01 18.1 2.65 28 3155.3 12.0 10.3 8.49E+00 5.24E+08 1.75E+01 17.8 2.65 29 3156.3 15.6 13.7 7.69E+00 3.86E+08 1.71E+01 17.3 2.65 29V 3156.2 14.7 12.7 8.64E+00 4.13E+08 1.70E+01 18.3 2.66 30 3157.3 93.0 86.8 3.41E+00 3.15E+07 8.86E+00 21.0 2.64 30V 3157.2 89.2 83.4 3.37E+00 3.32E+07 8.96E+00 21.0 2.66 31 3158.3 110. 104. 3.09E+00 2.93E+07 9.84E+00 21.8 2.66 For Method Definitions See Procedures Page k ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP Intrepid 2 Well API No.: 50-023-20036 Barrow-South Field Date: 6/25/2007 Cure Lab AEST.NYOIA OPTIMIZATION CMS-300 Permeability and Porosity at 1000 psi Net Stress Sample Depth Hor. Permeability Vert. Permeability b beta alpha Porosity Grain tD ft Kair and Kklink and Kair and Kklink and psi i/ft microns % Den glcc 32 3159.3 147. 139. 2.70E+00 1.86E+07 8.40E+00 21.9 2.65 32V 3159.2 142. 135. 2.59E+00 2.06E+07 8.97E+00 22.1 2.65 33 3160.5 98.6 92.1 3.37E+00 2.98E+07 8.89E+00 21.6 2.65 33V 3160.5 69.5 64.1 4.14E+00 4.41 E+07 9.16E+00 21.3 2.66 34 3161.3 6.87 5.79 1.03E+01 1.50E+09 2.82E+01 15.0 2.65 35 3162.3 Permeability too low for determination 3.18 " 35V 3162.6 Permeability too low for determination 3.11 For Method Definitions See Procedures Page ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP ~~ - ~``yA Intrepid 2 Well API No.: 50-023-20036 tom,-ewe Barrow-South Field Date: 6\25\2007 nescnvow arm+annox CMS-300 Permeability and Porosity at 1500 psi Net Stress Sample Depth Hor. Permeability Vert. Permeability b beta alpha Porosity Grain ID ft Kair md' Kklink and Kair and Kklink and psi 1/ft microns % Den g/cc 1 3128.1 329. 317. 1.70E+00 6.50E+06 6.67E+00 23.6 2.65 2 3129.1 372. 359. 1.67E+00 5.89E+06 6.84E+00 24.2 2.65 2V 3129.3 344. 332. 1.61E+00 6.24E+06 6.71E+00 23.8 2.66 3 3130.1 48.9 44.8 4.53E+00 7.58E+07 1.10E+01 19.0 2.65 3V 3130.3 54.0 49.3 4.75E+00 6.68E+07 1.07E+01 19.2 2.64 4 3131.1 316. 304. 1.71E+00 7.48E+06 7.36E+00 23.5 2.65 5 3132.3 87.3 81.3 3.52E+00 3.52E+07 9.27E+00 20.5 2.65 5V 3132.0 112. 105. 3.15E+00 2.55E+07 8.69E+00 21.4 2.66 6 3133.1 71.4 66.2 3.79E+00 4.45E+07 9.53E+00 20.5 2.65 6V 3133.0 64.6 59.5 4.31E+00 5.45E+07 1.05E+01 20.3 2.66 7 3134.1 1.58 1.25 1.61 E+01 3.37E+10 1.36E+02 12.0 2.76 8 3135.1 4.11 3.31 1.40E+01 3.38E+09 3.61E+01 15.1 2.65 8V 3135.3 0.228 0.127 5.69E+01 1.65E+12 6.79E+02 13.2 2.66 9 3136.1 4.00 3.23 1.36E+01 3.94E+09 4.13E+01 15.4 2.66 9V 3136.3 0.472 0.286 4.39E+01 5.94E+11 5.51E+02 14.8 2.67 10 3137.1 18.5 16.2 7.33E+00 2.23E+08 1.17E+01 18.1 2.65 11 3138.1 8.19 6.87 1.05E+01 7.61E+08 1.69E+01 16.9 2.65 11 V 3138.3 3.11 2.41 1.71E+01 1.11E+10 8.64E+01 17.1 2.66 12 3139.1 0.397 0.255 3.74E+01 2.22E+11 1.83E+02 12.0 2.66 12V 3139.3 0.090 0.042 8.83E+01 1.45E+13 1.97E+03 12.3 2.67 13 3140.1 0.893 0.642 2.48E+01 1.51 E+11 3.13E+02 13.4 2.65 14 3141.1 11.0 9.42 8.89E+00 5.14E+08 1.57E+01 17.5 2.66 14V 3141.3 0.335 0.181 5.96E+01 9.88E+11 5.78E+02 15.0 2.66 15 3142.1 8.82 7.54 9.25E+00 1.19E+09 2.89E+01 16.5 2.67 15V 3142.0 4.57 3.78 1.19E+01 3.55E+09 4.35E+01 15.1 2.69 For Method Definitions See Procedures Page ~ ! ~ ~ ~ ~ ~ ~ ~ ~ ~ I~ ~ I~ i ~ ~ ~ ~ ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP Intrepid 2 Well API No.: 50-023-20036 >ca~~~,~ Barrow-South Field Date: 6\2512007 nescxvow aennnnnnu CMS-300 Permeability and Porosity at 1500 psi Net Stress Sample Depth Hor. Permeability Vert. Permeability b beta alpha Porosity Grain ID ft Kair and Kklink and Kair and Kklink and psi 1/ft microns % Den g/cc 16 3143.1 41.3 37.7 4.86E+00 9.33E+07 1.14E+01 18.9 2.65 17 3144.1 16.8 14.8 7.38E+00 3.44E+08 1.64E+01 17.7 2.65 17V 3144.0 5.65 4.57 1.34E+01 2.97E+09 4.40E+01 17.2 2.66 18 3145.1 3.81 3.10 1.33E+01 5.56E+09 5.57E+01 15.3 2.68 18V 3145.0 34.5 31.2 5.43E+00 1.02E+08 1.03E+01 18.5 2.66 19 3146.3 0.017 0.009 8.44E+01 8.26E+13 2.34E+03 7.5 2.94 20 3147.5 0.97 0.703 2.40E+01 1.23E+11 2.79E+02 13.5 2.66 20V 3147.5 0.094 0.046 7.99E+01 4.46E+13 6.66E+03 12.7 2.66 21 3148.3 1.36 1.04 1.85E+01 6.14E+10 2.08E+02 13.5 2.67 21 V 3148.2 0.245 0.144 4.94E+01 2.76E+12 1.29E+03 13.5 2.68 22 3149.3 8.10 6.85 1.00E+01 1.06E+09 2.36E+01 16.3 2.65 23 3150.5 13.6 11.8 7.97E+00 5.37E+08 2.05E+01 18.1 2.65 23V 3150.2 1.42 0.94 3.20E+01 1.22E+11 3.71 E+02 17.2 2.67 24 3151.5 7.40 6.24 1.02E+01 9.89E+08 2.00E+01 16.4 2.67 24V 3151.5 1.65 1.10 3.12E+01 6.24E+10 2.23E+02 16.6 2.68 25 3152.5 7.29 6.17 1.00E+01 9.59E+08 1.92E+01 16.2 2.68 26 3153.3 10.4 8.931 8.60E+00 5.77E+08 1.67E+01 17.0 2.67 26V 3153.5 1.01 0.656 3.44E+01 1.42E+11 3.02E+02 15.5 2.67 27 3154.3 28.3 25.3 5.94E+00 1.81E+08 1.49E+01 18.6 2.65 27V 3154.5 10.8 9.23 9.20E+00 6.48E+08 1.94E+01 17.9 2.65 28 3155.3 11.8 10.1 8.50E+00 5.44E+OS 1.79E+01 17.5 2.65 29 3156.3 15.4 13.4 7.73E+00 3.97E+08 1.72E+01 17.1 2.65 29V 3156.2 14.5 12.5 8.66E+00 4.24E+08 1.71E+01 18.0 2.66 30 3157.3 92.0 85.9 3.41E+00 3.25E+07 9.03E+00 20.9 2.64 30V 3157.2 88.2 82.3 3.47E+00 3.33E+07 8.88E+00 20.9 2.66 31 3158.3 109. 102. 3.21E+00 2.96E+07 9.78E+00 21.4 2.66 For Method Definitions See Procedures Page ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP .. ~.e .~ Intrepid 2 Well API No.: 50-023-20036 ~~v Barrow-South Field Date: 6/25/2007 nessnvorn oeamzmnnu CMS-300 Permeability and Porosity at 1500 psi Net Stress Sample Depth Hor. Permeability Vert. Permeability b beta alpha Porosity Grain 1D ft Kar' and Kklink and Kair and Kklink and psi - 1/ft microns % Den g/cc 32 3159.3 146. 138. 2.70E+00 1.90E+07 8.51E+00 21.7 2.65 32V 3159.2 141. 133. 2.62E+00 2.09E+07 9.03E+00 21.9 2.65 33 3160.5 97.5 91.0 3.39E+00 3.05E+07 8.98E+00 21.4 2.65 33V 3160.5 68.6 63.2 4.18E+00 4.50E+07 9.22E+00 21.1 2.66 34 3161.3 6.71 5.66 1.03E+01 1.57E+09 2.87E+01 14.8 2.65 "` 35 3162.3 Permeability too low for determination 3.18 " 35V 3162.6 Permeability too low for determination 3.11 For Method Definitions See Procedures Page ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP ~a~~`~;- Intrepid 2 Well API No.: 50-023-20036 Ca,-e~~ Barrow-South Field Date: 6/25/2007 IIE5EAVOIfl OPTIMIZATION CMS-300 Permeability and Porosity at 2000 psi Net Stress Sample Depth Hor: Permeability Vert. Permeability b beta alpha Porosity Grain ID ft Kair and Kklink and Kair and Kklink and `, psl 1/ft m % Den glcc 1 3128.1 324. 312. 1.81E+00 6.79E+06 6.85E+00 23.5 2.65 2 3129.1 369. 355. 1.82E+00 5.90E+06 6.78E+QO 24.1 2.65 2V 3129.3 341. 329. 1.62E+00 6.29E+06 6.71 E+00 23.6 2.66 3 3130.1 48.6 44.3 4.70E+00 7.49E+07 1.08E+01 18.8 2.65 3V 3130.3 53.5 48.9 4.77E+00 6.79E+07 1.07E+01 19.1 2.64 4 3131.1 312. 300. 1.78E+00 7.61E+06 7.39E+00 23.4 2.65 5 3132.3 86.5 80.5 3.57E+00 3.57E+07 9.30E+00 20.4 2.65 5V 3132.0 111. 104. 3.19E+00 2.56E+07 8.64E+00 21.3 2.66 6 3133.1 70.2 65.0 3.87E+00 4.59E+07 9.66E+00 20.4 2.65 6V 3133.0 64.1 58.9 4.38E+00 5.46E+07 1.04E+01 20.2 2.66 7 3134.1 1.56 1.23 1.64E+01 3.38E+10 1.35E+02 11.9 2.76 8 3135.1 4.02 3.23 1.41E+01 3.41 E+09 3.56E+01 15.1 2.65 8V 3135.3 0.212 0.118 5.68E+01 1.92E+12 7.34E+02 13.0 2.66 9 3136.1 3.94 3.18 1.38E+01 4.56E+09 4.70E+01 15.3 2.66 9V 3136.3 0.448 0.272 4.39E+01 6.58E+11 5.80E+02 14.6 2.67 10 3137.1 18.3 16.0 7.47E+00 2.21E+08 1.14E+01 18.0 2.65 11 3138.1 8.32 7.01 1.03E+01 7.82E+08 1.77E+01 16.9 2.65 11 V 3138.3 3.05 2.37 1.71 E+01 1.13E+10 8.65E+01 17.0 2.66 12 3139.1 0.396 0.256 3.69E+01 2.75E+11 2.28E+02 11.8 2.66 12V 3139.3 0.083 0.039 8.87E+01 2.01E+13 2.52E+03 12.2 2.67 13 3140.1 0.892 0.640 2.51 E+01 1.26E+11 2.61 E+02 13.2 2.65 14 3141.1 10.7 9.20 9.07E+00 4.96E+08 1.48E+01 17.4 2.66 14V 3141.3 0.301 0.160 6.23E+01 1.43E+12 7.38E+02 14.9 2.66 15 3142.1 8.64 7.37 9.44E+00 1.19E+09 2.83E+01 16.4 2.67 15V 3142.0 4.51 3.74 1.19E+01 3.65E+09 4.42E+01 15.0 2.69 For Method Definitions See Procedures Page T. ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP ~~ :~ Intrepid 2 Well API No.: 50-023-20036 C~fe~~, Barrow-South Field Date: 6\2512007 II6FEAYOIA aRTIMI],ATIOH CMS-300 Permeability and Porosity at 2000 psi Net Stress Sample Depth Hor. Permeability Vert. Permeability b beta alpha Porosity Grain ID ft Kair and Kklink and Kair and Kklink and pSi 1/ft m % Den glcc 16 3143.1 40.7 37.0 4.99E+00 9.33E+07 1.12E+01 18.9 2.65 17 3144.1 16.7 14.6 7.38E+00 3.49E+08 1.66E+01 17.6 2.65 17V 3144.0 5.55 4.49 1.34E+01 3.01 E+09 4.38E+01 17.0 2.66 18 3145.1 3.76 3.05 1.34E+01 5.93E+09 5.85E+01 15.3 2.68 18V 3145.0 34.2 30.9 5.45E+00 1.04E+08 1.04E+01 18.4 2.66 19 3146.3 0.015 0.007 9.39E+01 2.36E+15 5.59E+04 7.4 2.94 20 3147.5 0.95 0.690 2.36E+01 1.18E+11 2.65E+02 13.4 2.66 20V 3147.5 0.085 0.041 8.27E+01 5.46E+13 7.24E+03 12.5 2.66 21 3148.3 1.32 1.02 1.82E+01 6.42E+10 2.12E+02 13.3 2.67 21 V 3148.2 0.232 0.137 4.93E+01 3.11E+12 1.38E+03 13.4 2.68 22 3149.3 7.95 6.74 9.87E+00 1.12E+09 2.44E+01 16.2 2.65 23 3150.5 13.4 11.7 7.93E+00 5.38E+08 2.03E+01 18.0 2.65 23V 3150.2 1.33 0.88 3.20E+01 1.43E+11 4.09E+02 17.0 2.67 24 3151.5 7.29 6.15 1.03E+01 9.46E+08 1.88E+01 16.3 2.67 24V 3151.5 1.59 1.06 3.14E+01 6.64E+10 2.27E+02 16.5 2.68 25 3152.5 7.19 6.09 9.99E+00 1.01E+09 1.99E+01 16.1 2.68 26 3153.3 10.2 8.805 8.67E+00 5.68E+08 1.62E+01 16.9 2.67 26V 3153.5 0.97 0.630 3.45E+01 1.54E+11 3.14E+02 15.4 2.67 27 3154.3 28.0 25.1 5.94E+00 1.84E+08 1.49E+01 18.4 2.65 27V 3154.5 10.6 9.11 9.17E+00 6.66E+08 1.96E+01 17.8 2.65 28 3155.3 11.6 10.0 8.46E+00 5.69E+08 1.85E+01 17.3 2.65 29 3156.3 15.2 13.3 7.67E+00 4.15E+08 1.78E+01 17.0 2.65 29V 3156.2 14.3 12.3 8.68E+00 4.29E+08 1.71E+01 17.9 2.66 30 3157.3 91.2 85.1 3.47E+00 3.26E+07 8.98E+00 20.8 2.64 30V 3157.2 87.5 81.6 3.49E+00 3.40E+07 8.98E+00 20.7 2.66 31 3158.3 108. 101. 3.22E+00 3.02E+07 9.89E+00 21.1 2.66 For Method Definitions See Procedures Page ConocoPhillips Alaska Inc. Location: Sec.11-19N/20W File No.: 107239CP ~~ " ~'. Intrepid 2 Well API No.: 50-023-20036 ~~„-~~e Barrow-South Field Date: 6\2512007 ne=Fa~or. ~~r,n~,h1~~,. CMS-300 Permeability and Porosity at 2000 psi Net Stress Sample Depth Hor. Permeability Vert. Permeability b beta alpha Porosity Grain ID ft Kair and Kklink and Kair and Kklink and psi 1/ft ` m % Den glcc 32 3159.3 145. 137. 2.74E+00 1.92E+07 8.50E+00 21.6 2.65 32V 3159.2 140. 132. 2.61E+00 2.12E+07 9.08E+00 21.8 2.65 33 3160.5 96.6 90.0 3.46E+00 3.05E+07 8.91E+00 21.3 2.65 33V 3160.5 67.9 62.6 4.23E+00 4.57E+07 9.26E+00 21.0 2.66 34 3161.3 6.60 5.57 1.03E+01 1.61E+09 2.90E+01 14.7 2.65 35 3162.3 Permeability too low for determination 3.18 '' 35V 3162.6 Permeability too low for determination 3.11 For Method Definitions See Procedures Page ConocoPhillips Alaska In Location: Sec.11-19N/20W File No.: 107239CP ®~ Intrepid 2 Well API No.: 50-023-20036 Core Kati Barrow-South Field Date: 6/25/2007 eesceva~n urnmznrror+ Porosity Histograms 800 psi Net Stress 1 oa T so + U 60 N 40 a zo <10 14- 20- 26- 32- 38- 44- 16 22 28 34 40 46 Porosity % (800 psi) 100 60 ~, sD v 40 a zo 0 <1 D 12- 16- 20- 24- 28- 32- 36- 4D- 44- 14 18 22 26 3D 34 38 42 46 Porosity % (1500 psi) Permeability Histograms 100 so ~ 60 U tL 40 20 0 <.00001 0.0005- 0.01- 0.5.1.0 >10.0 0.001 0.05 Ka (Darcy) 1000 psi Net Stress 100 ,. s0 v 60 a 40 zo 0 <.00001 0.0005- 0.01- D.5-1.0 >10.0 0.001 0.05 Ka (Darcy) 1500 psi Net Stress 100 so ~, so U ~ 40 o_ zo 0 <10 12- 16- 20- 24- 28- 32- 36- 40- 44- 14 18 22 26 30 34 38 d2 46 Porosity 100 so so d0 °- zo 0 <.00001 0.0005- 0.01 0.001 0.05 Ka (Darcy) 2000 psi Net Stress 100 eo ~, so U ~ 40 a 20 0 <.00001 0.0005- 0.01 0.001 0.05 Ka (Darcy) 800 psi Net Stress 1000 psi Net Stress 0.5.1.0 >10.0 0.5-1.0 >10.0 2000 psi Net Stress ConocoPhillips Alaska Inc. ~-~~ Intrepid 2 Well Core Lad Barrow-South Field RESER`lRIR IIPTIHIZATTON Permeability (Kafir) vs Porosity File No.: 107239CP API No.: 50-023-20036 Date: 6/25/2007 800 psi 1000 v ~ 100 10 N 1 ^ E 0 1 ~ . D OI . D 5 10 15 20 25 30 Porosity 30 30 2404 psi 1000 ~ loo = lD- a o.1 ~- ~ 1 0.01 0 5 - 1D 15 20 25 Porosity, 30 ConocoPhillips Alaska Inc. ~.I.l~~ Intrepid 2 Well Core lab Barrow-South Field xesrnvaix orttmzpriow Core Gamma Depth Gamma ft API 3128.00 36 3128.56 29 3129.11 32 3129.67 19 3130.22 26 3130.78 26 3131.33 32 3131.89 37 3132.45 33 3133.00 38 3133.56 42 3134.11 29 3134.67 26 3135.22 31 3135.78 39 3136.34 31 3136.89 22 3137.45 37 3138.00 32 3138.56 41 3139.11 37 3139.67 22 3140.23 29 3140.78 30 3141.34 34 3141.89 27 3142.45 40 3143.00 27 3143.56 38 3144.11 25 3144.67 31 3145.23 30 3145.78 21 3146.34 25 3146.89 35 3147.45 30 3148.00 29 3148.56 22 3149.12 29 3149.67 32 3150.23 32 3150.78 24 File No.: 107239CP API No.: 50-023-20036 Date: 6125\2007 ' ConocoPhillips Alaska Inc. ~`r-~ Intrepid 2 Well ' [ore t..ati Barrow-South Field RESERYRIR RPEfMIZAE[RN Core Gamma Depth Gamma ft API ' 3151.34 32 3151.89 30 3152.45 26 3153.01 38 3153.56 29 3154.12 34 1 3154.67 42 3155.23 27 3155.78 28 3156.34 29 ' 3156.90 30 3157.45 20 3158.01 34 3158.56 36 3159.12 44 3159.67 35 ' 3160.23 41 3160.78 31 3161.34 45 ' 3161.90 40 3162.45 37 3163.01 30 3163.56 30 3164.12 45 3164.67 38 3165.23 47 ' 3165.79 35 3166.34 28 3166.90 53 ' 3167.45 41 3168.01 37 3168.56 41 ', ~ 3169.12 45 3169.68 33 3170.23 39 3170.79 25 ' 3171.34 39 3171.90 38 3172.45 36 3173.01 32 3173.56 35 3174.12 43 File No.: 107239CP API No.: 50-023-20036 Date: 6\2512007 ConocoPhillips Alaska Inc. ~~-~ Intrepid 2 Well core I..ab Barrow-South Field AESEflVOIA flPTIMIZATIflX Core Gamma Depth Gamma ft API 3174.68 26 3175.23 44 3175.79 41 3176.34 34 3176.90 46 3177.45 42 3178.01 30 3178.57 34 3179.12 34 3179.68 37 3180.23 35 3180.79 33 3181.34 32 3181.90 31 3182.46 46 3183.01 39 3183.57 37 3184.12 36 File No.: 107239CP API No.: 50-023-20036 Date: 6125\2007 3120.00 Intrepid 2 Core Gamma 3130.00 3140.00 3150.00 s ... a a~ 3160.00 3170.00 3180.00 3190.00 i 0 50 Gamma (API) 100 ConocoPhillips Alaska Inc. File No.: 107239CP ~~ Intrepid 2 Well API No.: 50-023-20036 ~~ Barrow-South Field Date: 6\25\2007 [ore 1._ati RESERVOIR RPTINIZhTIRN Bulk Core Box Inventory 1 3128.0 - 3131.0 2 3131.0 - 3134.0 3 3134.0 - 3137.0 4 3137.0 - 3140.0 5 3140.0 - 3143.0 6 3143.0 - 3146.0 7 3146.0 - 3149.2 8 3149.2 - 3152.2 9 3152.2 - 3155.2 10 3155.2 - 3158.2 11 3158.2 - 3161.2 12 3161.2 - 3164.2 13 3164.2 - 3167.2 14 3167.2 - 3170.1 15 3170.1 - 3173.2 16 3173.2 - 3176.2 17 3176.2 - 3179.3 18 3179.3 - 3182.2 19 3182.2 - 3184.5 " ~ ConocoPhillips Alaska Inc. File No.: 107239CP i~ Intrepid 2 Well ~ API No.: 50-023-20036 s Core Lab Barrow-South Field RCSERVOIfl OPTIMIZATiflp Date: 6\2512007 Slabbe d Core Box Inventory 1 3128.0 - 3131.0 3131.0 - 3134.0 3134.0 - 3137.0 2 3137.0 - 3140.0 3140.0 - 3143.0 3143.0 - 3146.0 3 3146.0 - 3149.2 3149.2 - 3152.2 3152.2 - 3155.2 4 3155.2 - 3158.2 3158.2 - 3161.2 3161.2 - 3164.2 5 3164.2 - 3167.2 3167.2 - 3170.2 3170.2 - 3173.2 6 3173.2 - 3176.2 3176.2 - 3179.2 3179.2 - 3182.2 7 3182.2 - 3184.5 ~~ ConocoPhillips Alaska Inc. File No.: 107239CP Intrepid 2 Well API No.: 50-023-20036 Core Lab Barrow-South Field Date: 6/25/2007 AESEA`lOIA IIPTIMI2ATIIIN Preserved Core Inventory ** 3128.0 - 3128.3 ** 3154.2 - 3154.5 1 3128.3 - 3129.0 27 3154.5 - 3155.2 "" 3129.0 - 3129.3 '`* 3155.2 - 3155.5 2 3129.3 - 3130.0 28 3155.5 - 3156.2 *" 3130.0 - 3130.3 '"` 3156.2 - 3156.5 3 3130.3 - 3131.0 29 3156.5 - 3157.2 ** 3131.0 - 3131.3 ""` 3157.2 - 3157.5 4 3131.3 - 3132.0 30 3157.5 - 3158.2 "" 3132.0 - 3132.3 "' 3158.2 - 3158.6 5 3132.3 - 3133.0 31 3158.6 - 3159.2 '`* 3133.0 - 3133.3 ** 3159.2 - 3159.5 6 3133.3 - 3134.1 32 3159.5 - 3160.2 *`` 3134.1 - 3134.4 "* 3160.2 - 3160.5 7 3134.4 - 3135.0 33 3160.5 - 3161.2 *" 3135.0 - 3135.3 "* 3161.2 - 3161.5 8 3135.3 - 3136.0 34 3161.5 - 3162.2 "' 3136.0 - 3136.3 '`'' 3162.2 - 3162.6 9 3136.3 - 3137.0 35 3162.6 - 3163.5 ** 3137.0 - 3137.3 36 3163.5 - 3164.2 10 3137.3 - 3138.0 37 3164.2 - 3165.0 "* 3138.0 - 3138.3 38 3165.0 - 3165.5 11 3138.3 - 3139.0 39 3165.5 - 3166.3 *" 3139.0 - 3139.4 40 3166.3 - 3167.2 12 3139.4 - 3140.0 41 3167.2 - 3167.5 ** 3140.0 - 3140.3 42 3167.5 - 3168.3 13 3140.3 - 3141.0 "" 3168.3 - 3168.5 ~" 3141.0 - 3141.3 43 3168.5 - 3169.3 14 3141.3 - 3142.0 44 3169.3 - 3170.1 "" 3142.0 - 3142.3 "* 3170.1 - 3170.3 15 3142.3 - 3142.9 45 3170.3 - 3171.0 '"' 3142.9 - 3143.3 "" 3171.0 - 3171.2 16 3143.3 - 3144.0 46 3171.2 - 3172.2 '"` 3144.0 - 3144.3 '`* 3172.2 - 3172.3 17 3144.3 - 3145.0 47 3172.3 - 3173.2 "~ 3145.0 - 3145.3 ~" 3173.2 - 3173.3 18 3145.3 - 3146.2 48 3173.3 - 3174.2 "* 3146.2 - 3146.5 ** 3174.2 - 3175.2 19 3146.5 - 3147.2 49 3175.2 - 3176.2 *" 3147.2 - 3147.5 50 3176.2 - 3177.2 20 3147.5 - 3148.2 51 3177.2 - 3178.2 *" 3148.2 - 3148.5 ** 3178.2 - 3178.3 21 3148.5 - 3149.2 52 3178.3 - 3179.3 "" 3149.2 - 3149.5 53 3179.3 - 3180.3 22 3149.5 - 3150.2 ''' 3180.3 - 3180.5 "" 3150.2 - 3150.5 54 3180.5 - 3181.2 23 3150.5 - 3151.2 '"` 3181.2 - 3181.3 *" 3151.2 - 3151.5 55 3181.3 - 3182.2 24 3151.5 - 3152.2 "* 3182.2 - 3182.4 '`* 3152.2 - 3152.5 56 3182.4 - 3183.3 25 3152.5 - 3153.2 ** 3183.3 - 3183.9 *" 3153.2 - 3153.5 57 3183.9 - 3184.5 26 3153.5 - 3154.2 ** -Sampled interval, core remnants sealed in zip-lock baggy ~: ConocoPhillips Alaska Inc. File No.: 107239CP ~~~ Intrepid 2 Well API No.: 50-023-20036 core Lab Barrow-South Field Date: 6\25\2007 xeseavoia oenniunox Geochem Sample Inventory 1V 3128.0 4V 3131.0 7V 3134.3 10V 3137.0 13V 3140.0 16V 3143.0 19V 3146.5 22V 3149.2 25V 3152.5 28V 3155.2 31V 3158.7 34V 3161.5 ®.~. Core Lab flESENVOIfl OPTIMIZATION ConocoPhillips Alaska Inc. Intrepid 2 Well Barrow-South Field Routine Sample Inventory Horizontal Samples Vertical Samples 1 H 3128.1 1 V * 3128.0 2H 3129.1 2V 3129.3 3H 3130.1 3V 3130.3 4H 3131.1 4V * 3131.0 5H 3132.3 5V 3132.0 6H 3133.1 6V 3133.0 7H 3134.1 7V * 3134.3 8H 3135.1 8V 3135.3 9H 3136.1 9V 3136.3 10H 3137.1 10V * 3137.0 11 H 3138.1 11 V 3138.3 12H 3139.1 12V 3139.3 13H 3140.1 13V * 3140.0 14H 3141.1 14V 3141.3 15H 3142.1 15V 3142.0 16H 3143.1 16V * 3143.0 17H 3144.1 17V 3144.0 18H 3145.1 18V 3145.0 19H 3146.3 19V * 3146.5 20H 3147.5 20V 3147.5 21 H 3148.3 21 V 3148.2 22H 3149.3 22V * 3149.2 23H 3150.5 23V 3150.2 24H 3151.5 24V 3151.5 25H 3152.5 25V * 3152.5 26H 3153.3 26V 3153.5 27H 3154.3 27V 3154.5 28H 3155.3 28V * 3155.2 29H 3156.3 29V 3156.2 30H 3157.3 30V 3157.2 31H 3158.3 31V* 3158.7 32H 3159.3 32V 3159.2 33H 3160.5 33V 3160.5 34H 3161.3 34V * 3161.5 35H 3162.3 35V 3162.6 File No.: 107239CP API No.: 50-023-20036 Date: 6125\2007 Shale Samples 36C 3163.3 37C 3164.4 38C 3165.5 39C 3166.3 40C 3167.5 41 C 3169.1 42C 3170.3 43C 3171.1 44C 3172.3 45C 3173.4 46C 3174.4 47C 3176.1 48C 3177.1 49C 3178.3 50C 3179.4 51 C 3180.3 52C 3181.3 53C 3182.4 54C 3183.4 * -Taken for geochemical testing ConocoPhiNips Alaska Inc. File No.: 107239CP ~~~ Intrepid 2 Well API No.: 50-023-20036 Core Lab Barrow-South Field Date: 6\25\2007 nescavotn oenn~aanan Sample End-clippings for Thin-Sections Inventory Horizontal Samples Vertical Samples Shale Samples 1 H 3128.1 * 36C 3163.3 2H 3129.1 2V 3129.3 37C 3164.4 3H 3130.1 3V 3130.3 38C 3165.5 4H 3131.1 * 39C 3166.3 5H 3132.3 5V 3132.0 40C 3167.5 6H 3133.1 6V 3133.0 41 C 3169.1 7H 3134.1 * 42C 3170.3 8H 3135.1 8V 3135.3 43C 3171.1 9H 3136.1 9V 3136.3 44C 3172.3 10H 3137.1 45C 3173.4 11 H 3138.1 11 V 3138.3 46C 3174.4 12H 3139.1 12V 3139.3 47C 3176.1 13H 3140.1 * 48C 3177.1 14H 3141.1 14V 3141.3 49C 3178.3 15H 3142.1 15V 3142.0 50C 3179.4 16H 3143.1 51 C 3180.3 17H 3144.1 17V 3144.0 52C 3181.3 18H 3145.1 18V 3145.0 53C 3182.4 19H 3146.3 * 54C 3183.4 20H 3147.5 20V 3147.5 21 H 3148.3 21 V 3148.2 22H 3149.3 * 23H 3150.5 23V 3150.2 24H 3151.5 24V 3151.5 25H 3152.5 26H 3153.3 26V 3153.5 27H 3154.3 27V 3154.5 28H 3155.3 * 29H 3156.3 29V 3156.2 30H 3157.3 30V 3157.2 31H 3158.3 * 32H 3159.3 32V 3159.2 33H 3160.5 33V 3160.5 34H 3161.3 * 35H 3162.3 35V 3162.6 * -Untrimmed samples were taken for geochemical testing. ConocoPhillips Alaska Inc. File No.: 107239CP ~~~ Intrepid 2 Well API No.: 50-023-20036 Core Lab Barrow-South Field Date: 6125\2007 flESEHYfl IR NFTIMIZA'IION End-clippings for State of Alaska Inventory Horizontal Samples Vertical Samples Shale Samples 1 H 3128.1 * 36C 3163.3 2H 3129.1 2V 3129.3 37C 3164.4 3H 3130.1 3V 3130.3 38C 3165.5 4H 3131.1 39C 3166.3 5H 3132.3 5V 3132.0 40C 3167.5 6H 3133.1 6V 3133.0 41 C 3169.1 7H 3134.1 * 42C 3170.3 8H 3135.1 8V 3135.3 43C 3171.1 9H 3136.1 9V 3136.3 44C 3172.3 10H 3137.1 45C 3173.4 11 H 3138.1 11 V 3138.3 46C 3174.4 12H 3139.1 12V 3139.3 47C 3176.1 13H 3140.1 * 48C 3177.1 14H 3141.1 14V 3141.3 49C 3178.3 15H 3142.1 15V 3142.0 50C 3179.4 16H 3143.1 * 51 C 3180.3 17H 3144.1 17V 3144.0 52C 3181.3 18H 3145.1 18V 3145.0 53C 3182.4 19H 3146.3 54C 3183.4 20H 3147.5 20V 3147.5 21H 3148.3 21V 3148.2 22H 3149.3 * 23H 3150.5 23V 3150.2 24H 3151.5 24V 3151.5 25H 3152.5 * 26H 3153.3 26V 3153.5 27H 3154.3 27V 3154.5 28H 3155.3 * 29H 3156.3 29V 3156.2 30H 3157.3 30V 3157.2 31 H 3158.3 * 32H 3159.3 32V 3159.2 33H 3160.5 33V 3160.5 34H 3161.3 * 35H 3162.3 35V 3162.6 * -Untrimmed samples were taken for geochemical testing. ConocoPhillips Alaska, Inc. File No.: 107239CP "~- Intrepid 2 Well API No.: 50-023-20036 Barrow-South Field Date: 6/8/2007 IC®re ILab aesExvore nrriniznriox Core Type: Conv CORE ANALYSIS PROCEDURES AND CONDITIONS Procedure (1) Procedure (2) Procedure (3) Procedure (4) Procedure (5) Sampling Method` Arbor Cut Drilled Drilled Drilled Carved Drill Coolant N/A Liquid Nitrogen Isopar Isopar N/A Jacket Material Lead/Nickel Lead/Nickel None None None Saturation Method Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Porosity Method Grain Volume Boyle's Law (Helium) Boyle's Law (Helium) Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Pore Vol Pore Volume Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Grain Vol CMS-300 Bulk Vol-Grain Vol Bulk Volume. Pore Vol + Grain Vol Pore Vol + Grain Vol Mercury Displacement Pore Vol + Grain Vol Mercury Displacement Permeability Method qjr Air Emprical CMS-300 Emprical Common Conditions Sleeved Sample Seating Pressure: N/A Confining Pressure Pore Vol & Permeability: 800 Samples Dried At 235 Degrees Fahrenheit Additional Extraction by Soxhlet with Methylene Chloride/Methanol Oil Density used in Calculation: 0.97g/cc • r~ .~ ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA INTREPID #2 Provided by: E~ EPOCH Approved by: Compiled by: ~o~ ~~~ ~ ~Saa ~ Brian O'Fallon Patrick Wafker James Kvidera Date: 04/18/07 Distribution: 05/31/2007 Ccmoc~l{ipS A~ska.Inc. Intrepid #2 • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............................................................................................ .. 2 1.1 Equipment Summary .................................................................................................................. .. 2 1.2 Crew ................................................................ ..................... .2 2 WELL DETAILS .................................................................................................................................. . 3 2.1 Well Summary ............................................................................................................................. . 3 2.2 Hole Data ..................................................................................................................................... . 3 3 GEOLOGICAL DATA .......................................................................................................................... . 6 3.1 Lithostratigraphy .......................................................................................................................... .6 3.2 Mudlog Summary ......................................................................................................................... . 7 3.3 GAS(ISOTUBE) Samples (GAS BAG supplement numbered in parenthesis} ............................ 13 3.4 Connection Gases ...................................................................................................................... 14 3.5 Trip {Wiper) Gases ..................................................................................................................... 14 3.6 Sampling Program 1 Sample Dispatch ........................................................................................ 15 4 PRESSURE I FORMATION STRENGTH DATA ................................................................................ 16 4.1 Formation Integrity/Leak Off Tests ............................................................................................. 16 4.2 Wireline Formation Tests ........................................................................................................... 16 4.3 Pore Pressure Evaluation Introduction ....................................................................................... 16 4.4 Pore Pressure Evaluation Conclusions ...................................................................................... 17 4.5 Pore pressure evaluation ........................................................................................................... 21 5 DRILLING DATA ................................................................................................................................ 22 5.1 Survey Data ................................................................................................................................ 22 5.2 Bit Record ................................................................................................................................... 23 5.3 Mud Record ................................................................................................................................ 24 • 6 MORNING REPORTS ....................................................................................................................... 25 Enclosures 2"I100' Formation Log (MD) 2"1100' Drilling Dynamics Log 2"1100' Gas Ratio Log 2"l100' LWD / Lithology Log 2"I100' Pore Pressure Log • ~ EPCJ~H 1 Conoc~hiliips .~. Intrepid #2 1 MUDLUGGING EQUIPMENT ~ CREW 1.1 Equipment Summary • • Parameter Equipment Type f Position Totat Downtime Comments QGM Agitator {Mounted in possum Possum belly be11Y} very small and Ditch gas Flame ionization total gas & d no jet system chromatography. to remove , ; cuttin s. Effective Circulating Density From Sperry-Sun 1389' to TD ~ Calculated in ECD surface hole Hook Load t Weight on bit Pason WITS Feed 2 days Poor data thru surface hole. Mud Flow In Derived from StrokesfMinute and ~ Pum flat ut Mud Flow Out Pason WITS Feed Q Mudlogging unit computer HP Compaq Pentium 4 {X2, DML & a s stem Ri atch Mudlogging unit DAC box In-unit data collectionldistribution g center Pit Volumes, Pit GainfLoss Pason WITS Feed d Pum Pressure Pason WITS Feed 0 Pum stroke counters Pason WITS Feed 0 Pason Wefl Monitoring Pason computer networked in ~ Com onents Mudb in Unit Occasionally Rate of penetration Pason WITS Feed 1 hr during surface hole RPM Pason WITS Feed 0 Tor ue Pason WITS Feed 0 1.2 Crew Mudloggers Years ©ays Sample Catchers Years Days Technician Days Brian O'Fallon 18 12 Tom Novell 1 12 Steve Forrest 0 Patrick Walker 1 7 Dan Lee 1 7 James Kvidera 2 7 Ramon Me is Vidal 1 5 Unit Type Double Unit Number ~ ML ;' Years experience as Mudlogger ~ Days at wellsite between spud and total depth of well ~~~~~ 2 Conoco~Phillips . ~. Intrepid #2 2 WELL DETAILS 2.1 Well Summary • Well: Intrepid #2 APi Index #: 50-023-20036-00 Lat: 71 ° 00' 47.822"N Long: 157° 03' 14.506"W NAD 83 Zane 4 Field: NPRA Surface Co- 801467'W Ordinates: 6269125'N Meridian U SEC 11 T19N R20W 2407' FSL 1751' FEL Borough: North Slope Primary Target Depth: MD: 3118' State: Alaska TD Depth: 3550' MD /3486' TV© SS Rig Name 1 Type: Kuukpik #51 Arctic Double Rig Release Date: 24:00 4118107 Primary Target: Walakpa Sands Region: North Slope Spud Date: 41112007 Pad Elevation: 36.0' MSL Completion Date: 4/14/2007 RT Elevation: 56.9' MSL Completion Sta#us: P&A Secondary Target: Alpine Equivalent ' ' De the MQ 13286 TVD SS 3350 Classification: Exploration TD Date: 411212007 TD Formation: Kingak Shale Days Testing: NONE Days Drilling: 12 2.2 Hole Data H l Maximum Depth Mud i C C Shoe Depth LOT o e TD Dev. or n asingl Section MD TVDSS Formation Weight (°inc) g liner MD TVDSS {ppg} ift} (ft} (ppg} Eft} (ft} Conductor 117 60 Permafrost NA 16" 117 60 NIA 12 114" 1389 1332 Torok 10.2 0,35 NA 9 518" 1379 1311 18.0 8 314" 3550 3493 Kingak 9.8 1.06 7" 3516 3459 NIA 3188 Additional Comments The Intrepid #2 was spudded on April 1, 2007, and reached total depth at 3550' on April 12, 2007. Two hole sections, a 12 %4" surface hole and 8 314" production hole were drilled. All drilling parameters, exclusive of gas, was acquired from Pason through a WITS feed. Epoch provided a WITS gas feed to Pason. Surface hole was drilled to 1389'. Some plugging of the trap occurred until after 590', with clay cu#tings accumulating in the possum belly. Rig hands were instructed to avoid pushing cuttings toward the base of the trap after 590', and from that point were very vigilant in maintaining mud flow at the trap. The rig has very small possum bellies, and does not have a jet system to remove cuttings. Cuttings were removed by shovel • and accumulated rapidly. EPt~CH 3 Ccmo~hillips .~. Intrepid #2 The hookload sensor provided erratic and unusable data to 520', and less erratic but suspect to unusable data for the remainder of the surface hole. While pulling and pumping out of the hole after reaching casing point, at 1024' the rig was unable to circulate due to packing off, The BHA was changed and a cleanup run made before running casing. 9 518" casing was run to 1379'_ The 8 $/~" production hole section was drilled to from 1389' to 3550', without any major difficulties. The Walakpa Sand was cored from 3128' to 318$'. Plans to run wireline through the sand after drilling rathole (and before penetrating unstable Milluveach Shale}, were abandoned due to MWD and core analysis suggesting little potential for oil production. Logs were successfully run, including drill pipe conveyed pressure testing, after Total Depth. • C: ~~~~~ 4 COt1O0OPE'tllltj?S A~slca, lnc. Intrepid #2 • • Daily Activity Summary: Build mud volume; NIU Divertsr; Rig Up Pasan; Test pumps; Test Mud line to 4000psi; Biow 4-1-07 dawn tap drive and mud line; P1U HWDP; Function test Diverter; Continue to build mud volume; PIU BHA; Fill Hole midni ht; RIH; Ta cmt 93'; Drill ahead to 146ft 05:00 Drill 12.25" hole to 257'; Condition Mud and Circ; Pump out of hale; UD BHA; Begin to PIU 4-2-07 SHA; Plug/Load & test MWD; Break out & blow down top drive ~ midnight; Lubricate and tighten swivel packing; Cantinas to P1U BHA & load nuke sources; RIH and prepare to Drill ~ 05:00. 4-3-07 Drill Fram 251' to 1250' @ Midnight; Drilled 1250'-1389'; Circulate and condition holy; Prepare to short tri . Pump out from 1357' to 714'; Pack-Off at 714'; POOH to BHA; Cantinas to pull BHA in tight 4-4-07 hale; Pull Nuke Sources and download MWD; Lay down BHA ~ 12:00; Lubricate rig; Make up BHA; Se in wash and ream to bottom; Ds th 05:00 350' Wash and Ream from 430" to 1389'; Circulate holy clean and pump slug; POOH and lay down 4-5-07 BHA; Glean rig floor, Rig up tangs for casing @ Midnight; Finish rigging up to run casing; Be in Runnin 9 5/8" Casin 03:00. Finish running casing and circufate out @ 12;00; PIU stab-in tool; Pump Cement; Rig down 4-6-07 cement head; POOH; UD stab-in tool ~ 12:00; Rig down cement tine; Begin nipple down cx 03:00 N/U BOP Stack; M/U Flaw fins; R/U Accumulator Hoses; Begin Rigging up for BOP Test; 4-7-07: Attempt to Test BOP{problems getting test plug to seal} @ Midnight; Begin to test BOP; Finish testin BOP 04:30; Bs in MIU mousy holy 05:00 M1U BHA PIU Smart tools and RIH, Surface test tools, TIH W/ HWDP to 1021', Tag cement at 4-8-07 1243', displace mud, Test 9 5l$" casing to 2500psi for'/ HR, Goad Test, Drill out cement, float collar and shoe, Drill ahead to 1410', Displace mud and ship out far storage, Drill ahead to 1520' at re ort time Drill from 1520' TO 2464', Pump Hl VIS sweep to clean holy, TOOH to shoe at 1335', Rig 4-9-07 Service, TIH to 2342', Ream and wash to bottom, Circulate thick mud, Drill ahead to 2650 at re ort time. Drill from 2650' to 3128' Determined core point for Walakpa {Neocomian} sands, Circulate, 4-10-07 Wiper trip to 3128' RTB, Ream dawn from 3029' to bottom, Circulate holy clean, pump slug and POOH. POOH, LID BHA, P/U Caring assembly, TIH to shay, Rig Service, TIH to Bottom, Circulate and 4-11-07: condition mud, Begin coring run, Care 60' from 3128' to 3188' MD, Circulate B1U, Pump slug, POOH with Core #1 POOH with core and coring tools, Break bit, and pull out inner core barrels, LID Core barrels 4-12-07 in pipe shed, LID Coring assembly, P/U Drilling BHA, and RIH, TIH to 615', Surface test MWD, TIH to 3128', Circulate out thick mud, Ream dawn F/ 3128' to 3188', Drill ahead to 3503' at re ort tiros. Drill ahead from 3503' to 3550', Circulate BIU, Short trip to +1- 3128', RTB Circulate and 4-13-07 condition mud, Monitor well, Build and pump slug, POOH, UD BHA' R/U Wire tins tools, RIH w/ Wire line Complete #1 & #2 runs, Toal failure on #3 Run, Re-Run #3 La in Run. 4-14107: POOH w/ Run #3 Lagging Run, Run #4 Wire tins Logging run, Complete #4 Lagging run, RIU Lagging Tools far DP Conveyed Logs, TIH wl Lagging taols,Camplete Logging Run and POOH. C~ ~PC~CH ConocoPhillips . ~. Intrepid #2 i 3 GEOLOGICAL DATA 3.1 Lithostratigraphy C • LWD taps refer to provisional picks provided by the Wellsite Geologist. PROGNOSED LWD PICK FORMATION MD ft} TVDSS (ft} NID {ft} TVDSS (ft) Base Permafrost 1064 1000 N(A NfA Torok 1064 1400 NIA NIA HRZ 2714 2650 2664 2607 Base HRZf Pebble Shale NIP NIP 2694 2637 Kalubik Shale 3139 3075 3071 3014.5 Top Walakpa Sands 3184 3120 3118 3061 LCU {Miluveach Shale) 3214 3150 3164 3107 Jurassic Alpine Equiv Sands 3344 3280 3350 3293 UJU {Tap Kingak} 3424 3360 3420 3363 TD 3564 3500 3550 3493 EPt~CH Cor~oooPhillips ~. Intrepid #2 3.2 Mudlog Summary Surface to *Base of Permafrost First Returns 117' to 1(164" MD (60' to 1007` TVDSS} Drill Rate {ftthr} Total Gas {units } Maximum Minimum Avera a Maximum Minimum Avera e 93 4 68 68 0 27 "`The wellsite geologist was unable to identify the base from available data. The depth used here is from the prognosis. The Permafrost included some minor sand especially below the conductor, but dominantly claystone and some siltstone to sandy siltstone thereafter. Some minor sand below the conductor was light gray, fine to very fine grained, angular to subangular, moderately to well sorted, and loosely consolidated. Composition was 70-80°lo quartz, and 30-20°~ medium to dark gray to black lithics and carbonaceous matter. The sands were apparently thinly bedded and gradational to siltstone. A trace of poorly consolidated sandstone from 690-750', was very fine to fine lower, well sorted, and dominantly quartz. The claystone was medium to dark gray with brownish hues, and mostly hydrated in the samples, soft, and mushy to pasty. Some cuttings were only partially hydrated especially with increasing depth, often exhibiting some shaliness, and moderately soft to slightly firm. These cuttings were subplaty to subblocky, with some flakiness and incipient fissility, a slightly sparkly luster, and earthy to resinous texture. Slight to trace carbon silts and fines, silvery to greenish micro to fine micas, and probable micro pyrite were all pervasive, but overall lessoning toward the base. Overall the clays were non to slightly organic, except occasional subplanar micro partings of organic clay or carbon matter. The claystone {and shale} mostly included slight to traces of silt to very fine lower quartz, except grading to siltstone. siltstone and sandy siltstone was mostly argillaceous and of similar composition to the claystone, except with increasing quartz silts and grains. Samples overall were less silty toward the base of the Permafrost. Gas initially contained only methane, and gradually included ethane and than propane, until at approximately 700 feet when iso butane was first detected, and at 750 feet when both iso and normal butane were detected, and remained through the Permafrost. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 793 68 10829 774 313 58 19 0 0 Base Permafrost {Tarok} to Casing Poiint 1064' to 1389' MD (1007' to 1332' TVDSS) DriN Rate {ftlhr) Total Gas {units ) Maximum Minimum Avera a Maximum Minimum Avera e 96 16 80 131 11 42 The Permafrost probably includes the Torok formation, but a top for the Torok was not identified. This section was presumed to be a continuation of the Torok, and was dominantly claystone, often exhibiting same shaliness, wi#h some siltstone and minor very fine grained sandstone. ~~~~~ ConocoYPliillips .,~. Intrepid #2 The claystone and shale were medium to dark gray, mostly with brownish hues to rare brownish gray, soluble, soft, and mushy to pasty in samples, to moderately soft and slightly firm, subplaty, and with incipient fissility to flaky cu#tings fracture. Trace to slight carbon micro fines, silts and flakes, micro micas, and probably micro pyrite are pervasive throughout. The micro pyrite, while sometimes apparent, is often difficult to distinguish from the mica, and sometimes the sparkle of quartz grains. The flakiness is likely due to same planar orientation of the carbon matter, micas, and pyrite along bedding planes, more than structure. Very thin partings of organic clay or carbon matter are lightly scattered throughout to rare locally common. Cuttings were non calcareous. The shale and claystone often had only traces of quartz silts, and the samples only very slight loose silt to very fine quartz. Some claystone is silty and gradational to siltstone of similar composition, except with increasing silts and very fine grains of dominantly quartz. Minor glauconite was observed in siltstane and sandstone. Siltstone jus# below the base of the Permafrost was slightly calcareous. Pentane first appeared at the base of the Permafrost, and continued throughout this section. Drill gas from a thin zone of apparent slightly calcareous siltstane mare than doubled background gas at 131 units. Peaks • De th TG C1 C2 C3 C41 C4N C51 C5N 1166 131 18269 1721 1065 217 263 99 83 Casing Point to top HRZ 1389' to 2664' MD 1332' to 2607' TVDSS Drill Rate (ftlhr} Total Gas (units } Maximum Minimum Average Maximum Minimum Avera e 277 5 113 570 9 104 The Torok continued, and remained dominantly claystone and shale, but with same occasional interbedded sandstone, same of which are apparently gas bearing. claystone (shale} was massively bedded, or often gradational to and interlaminated to interbedded with siltstone. Overall, the Torok below casing point tended to be sil#ier and sandier than above. claystone and shale were medium to dark gray, with brownish hues, mostly in solution and mushy to pasty in samples, to some generally partially hydrated and moderately soft, subplaty to wedge with slight incipient fissility to rare flaky, and a variably smooth to resinous to silty texture. Trace to slight carbon silts and fines, micas and micro micas, and trace micro pyrite, were pervasive throughout, and appeared disseminated but likely with some planar orientation. Same sparkly luster is due to micas, especially in cuttings with a resinous to silty texture. Cuttings were occasionally slightly calcareous, and occasionally included traces of glaucanite, though these cuttings were typically silty. Clays were slightly to very slightly organic overall, except from 2490-2660', where occasional cuttings, dominantly shale, were grayish brown to brownish black, slightly firm, slightly to moderately organic, trace to slightly silty, and with slight increases in disseminated micro pyrite. Siltstone was medium to dark gray to rare brownish gray, and of similar composition to the claystone and shale, except with increasing silts and some fines of dominantly quartz and minor silicates, and common traces of glauconite, especially when grading to sandstone. Siltstone was mostly moderately to very clayey, and generally firmer with decreasing soluble clays and as often very slightly or slightly calcareous. With increasing coarse silt to fine grains, siltstane occasionally graded to silty, variably argillaceous sandstone. Sand or sandstone, when bedded and excluding the argillaceous sandstone described above, was light C~ EPOCH 8 Conoco`Phillips ~. Intrepid #2 gray to medium gray, fine grained, or very fine to fine grained; subangular to subrounded, moderately well to moderately sorted, poorly to moderately consolidated, and both grain and matrix supported with a clay, silt, and calcite matrix. Grains are dominantly translucent quartz; and same black to gray, minor green, and trace reddish brown grains, including carbonaceous lithics, lithics, and minor silicates. Porosity war estimated as poor to very poor, permeability poor to fair, and no oil indicators. The following peaks were al(from apparent sandstone, and were al12-3 times background. The most significant peak occurred at a depth of 1849', in a fine grained sandstone, where the chromatograph breakdown sugges#s a show more substantial than the 570 units measured. Successive connection gases appeared to lag to this zone. Peaks • De th TG C1 C2 C3 C41 C4N C51 C5N 1651 140 20493 1628 960 143 126 3 4 1714 136 18382 1625 960 12$ 89 16 21 1849 570 195533 22675 11731 1801 2946 1095 1164 2041 363 43979 4808 1641 268 420 163 243 2165 357 47732 5165 2370 396 578 230 250 2591 147 21133 1944 918 160 209 82 79 HRZ to Base HRZ {Top Pebble Shate} 2664' to 2694' MD (2607' to 2637' NDSS) Drip Rate {ftJhr) Total Gas {units } Maximum Minimum Avera a Maximum Minimum Avera e 145 57 97 135 62 96 The HRZ includes hat shales and a trace of greasy fight gray ash fall tuff. Conoco Philips reports these shales were deposited during a major marine transgression. The claystonelshale overall was dark gray to grayish black to brownish black, and ranged firom salt and soluble, with slightly organic clay and moderate to abundant micro partings and minor flakes of carbon matter, to slightly to moderately firm, with mostly organic clay, and irregular to planar fracture with mostly carbon residue on micro partings. The cuttings overall had slight to moderate micro pyrite, especially on partings, a trace to slight disseminated micro micas, were non to slightly silty, and non calcareous. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 2680 135 17659 1308 526 74 113 47 51 Pebbte Shale to K-9 Marker {Kalubik Shate} 2694' to 3070' MD 12637" to 3014' NDSS) Drill Ra#e {ftlhr} Total Gas {units) Maximum Minimum Avera a Maximum Minimum Avera e 168 12 100 124 0 78 The pebble shale was mostly shale and siitstone with some minor interbedded sand. While probably present, no floating pebbles were noted. Claystone/shale was medium light gray to medium gray to occasionally brownish gray; soft and amorphous with soluble clays, to firm with increasing sift or calcareous. Firm to partially hydrated cuttings EP~3CH 9 Conoco`Phillips .~. Intrepid #2 were subblocky with irregular fracture, to subplaty with incipient fissility, to slightly flaky, with earthy to silty textures, trace to slight carbons silts and fines, and micro to fine micas, minor calcite to slightly calcareous, trace, mostly scattered pyrite, and occasional trace glauconite. Some of the lighter shales appeared to be tuffaceous, and focally some light gray to light brownish gray cuttings were very calcareous grading to marl. Siltstone was of similar composition but overall darker than the claystone and shale, medium gray to medium dark gray, with mostly faint brownish hues, and dominan#ly firm as mostly slightly to moderately calcareous. Same siltstone was gritty and graded to argillaceous very fine grained sandstone. Bedded sandstone, especially from 2970 to 3010', was light brownish gray to medium light gray; very fine to fine grained; subrounded to subangular, moderately to poorly sorted; weakly cemented #o friable and unconsolidated, and mostly grain supported, with a slight to moderate clay, silt, and calcite matrix. Grains were 60°~ quartz, and 40°~ light gray to dark gray to black to minor olive black, including carbon and other lithics, silicates, and possible mafics. Visible porosity was estimated at moderate to poor, and no oil indicators. Peaks • De th TG C1 C2 C3 C41 C4N C51 C5N 3006 124 22$07 13$5 555 96 $4 29 20 K-1 Marker {Kalubik Shale) to Walakpa Sands 3070' to 3118' MD (3014' to 3061' TVDSS) Dri11 Rate (ftlhr) Total Gas (units } Maximum Minimum Average Maximum Minimum Avera e 12$ 5 85 120 46 85 This section was dominantly claystone and shale, some silty and gradational to siltstone, and same possible tuffaceous claystone at the marker. The shales are medium dark gray to dark gray with brownish hues, and traces of carbon silts and fines, micro micas, and pyrite, and non to slightly calcareous overall. Peaks Depth TG C1 C2 G3 C41 C4N C51 C5N 30$7 120 20255 1017 349 57 54 39 13 _~ Walakpa Sands to LCU (Miluveach Shale} 3118' to 3164' MD {3061' to 3107' TVDSS} Drill Rate (ftlhr) Total Gas (units } Maximum Minimum Avera a Maximum Minimum Avera e 71 4 19 41 15 27 The sandstone, as observed in cutting samples and examined from core chips, was light gray to medium light gray, very fine to fine lower grained, to same fine to very fine upper grained, well to moderately well sorted, grain supported with a trace to slight (especially finer sandstone} clay matrix, and moderately to moderately well consolidated with a presumed slight siliceous and observed trace calcite cement. Very thin to thin dark gray to black carbonaceouslargillaceous lamina#ions, occurred as spotty to locally common, sub planar depositional features. Grains were 80-85°l° translucent quartz, and 20-15% black to gray, white, brown, dark to light green, and trace rust to tan, including carbonlargillaceous lithics, and altered silicates and silica#es. Micro pyrite occurred throughout in trace amounts replacing carbon matter, ~~~~~ 10 Conoto`Phillips ,~. Intrepid #2 but occasional soft thin carbon lamina or clasts were very pyritic (especially noted at 3149'}. Porosity was estimated at poor to some fair; and permeability fair to good. Care fragments had no visible oil stain, an extremely faint even orangish fluorescence, a trace instant and very slow diffuse bluish white cut, increasing in argillaceous zones (3149'}, and an orangish yellow fluorescent residue, not visible in white light. Gas shows were weak, with gas actually decreasing relative to the overly"sng shales. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 3128 29 4188 375 195 32 32 13 10 3140 30 3900 340 201 37 40 13 10 3150 20 2882 259 149 20 24 6 4 3160 16 2644 194 113 14 20 4 3 LCt1 to top Jurassic Alpine Equivalent Sands 3164' to 3350' MD (3107` to 3293' TVDSS) Drill Rate (ft/hr} Tota! Gas (units } Maximum Minimum Average Maximum Minimum Avera e 148 4 74 184 6 61 The t_CU appeared as an abrupt contact between the overlying light gray Walakpa Sandstone and the massive dark Milluveach shale (and claystone}. Some minor glauconitic sandstone and sand was also present In the Milluveach. The shale is characterized by yellowish brawn hues, initially a dark yellowish brown to dark gray from 3164-3255', and than, associated with higher gas, a darker, dusky yellowish brown. The cuttings overall were firm to slightly firm, and non calcareous, with na fluorescence and a pale weak diffuse cut. The upper shales were slightly firmer overall and had a resinous to smooth texture, subplaty to angular habit, and trace to slight disseminated micro pyrite and mica. The lower shales had a resinous to earthy texture, due perhaps to the clay content being more organic, and a slight increase in micro pyrite. A trace of shell fragments and minor bleeding gas were noted in the lower shales. The sand and sandstone surfaced as approximately 2°~ of the three 10 foot samples from 3250-3280', and could possibly represent thin beds and stringers at the contact between the two shale types. Cuttings were grayish green to greenish gray to very pale green, with grains including quartz, some giauconite, and minor argillaceous matter. The sandstone grains were fine to medium lower, subangular, moderately to well sorted; and moderately consolidated with a very slight siliceous cement, to moderately wel! consolidated with a slight calcareous cement. The sand was very clayey, silty, and possibly ashy, with matrix supported angular to subangular very fine grains. Peaks C De th TG C1 C2 C3 C41 C4N C5l C5N 3323 185 39731 1281 418 53 54 8 11 Jurassic Alpine Equivalent Sands to Total Depth 3350' to 3420' MD !3293' to 3363' TVDSS) Drill Rate (#tlttr} Total Gas (units } Maximum Minimum Avera a Maximum Minimum Avera e 151 6 107 115 66 93 [~ ~P~CH 11 Conoco~Phillips ~. Intrepid #2 • The secondary target, the Jurassic Alpine Equivalent rarely contained some poorly developed sandstone grading from dominantly sittstone. The sittstone was dark yetlowish brown to brownish gray, slightly firm to firm, with a resinous and sHtyJgritty texture, non calcareous, moderately to very clayey to grading shale/claystone; and slightly sandy with very fine grains to occasional thin Laminations to thin beds of variably argittaceaus very fine to fine grained sandstone. Throughout were slight disseminated micro pyrite, mica, and micro mica, very slight carbon silts, fines, and flakes, and trace to locally moderate glauconite. Cuttings had na fluorescence and a pale weak diffuse cut. Pentanes increased relative to total gas, but gas decreased after the overlying shale, and there were no significant peaks or shows. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 3354 115 18334 662 223 42 44 9 7 3444 144 15449 636 244 34 61 23 18 UJU {Kingak Shale) to Total Depth 3424' to 3554' MD (3363' to 3493' TVDSS) Drill Rate {ftlhr) Total Gas units ) Maximum Minimum Avera a Maximum Minimum Avera e 164 11 83 85 27 56 The Kingak includes shale, claystone, and sittstone from dark to dusky yellowish brown to brownish gray, to some pale yellowish brown to medium gray just below the UJU. Cuttings were firm to moderately soft, wedge to subplanar with some incipient fissility, resinous to silty to earthy, with very slight disseminated micro pyrite, trace micas, and trace gtauconite, and non calcareous. Occasionally sittstone graded to very fine grained argiLtaceaus sandstone, with poor visible porosity, no fluorescence, and a weak diffuse cut. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 3449 85 12718 571 222 48 78 21 16 ~T3~~~ 12 Cor~arco~PFn'Ilips . ~. Intrepid #2 3.3 GAS (ISOTUBE} Samples {GAS BAG supplement numbered in parenthesis) 9 unit = Q.Q5°~ Methane Equivalent C] • Sam le De th Units G1 C2 G3 iC4 nC4 iC5 nC5 # (feet) 1u=8.05°!° M.E. {ppm) (ppm} {ppm} {ppm) {ppm} {ppm} {ppm} 1 1000 46 6414 646 338 52 28 0 Q 2 1250 18 2615 270 124 21 27 8 5 3 1500 91 12495 1136 681 87 6Q 10 6 4 1750 80 11185 888 456 57 61 14 18 5 2000 141 16244 1713 786 132 283 89 92 ~ 6 2250 119 14317 1290 493 69 114 50 41 7 250Q 45 5406 547 249 38 54 28 32 8 2750 75 10$55 704 273 43 52 12 16 9 3000 116 19669 865 309 57 48 18 4 ~ 10 3100 77 14574 770 278 43 48 2Q 12 11 3128 29 4188 375 195 32 32 13 10 12 1 3140 30 39Q0 340 2Q1 37 40 13 1Q 13 2 3150 20 2882 259 149 20 24 6 4 14 3 3160 16 2644 194 113 14 20 4 3 15 4 3170 19 3213 215 108 13 19 0 0- 16 3200 21 2943 151 66 8 13 2 2 17 3260 53 8997 278 94 13 16 2 3 18 3282 68 10961 348 122 18 23 3 3 19 3323 185 39731 1281 418 53 54 8 11 ' 20 3350 115 18330 662 223 42 40 9 7 21 3400 1QQ 15409 636 240 3Q 61 23 18 22 3431 71 10313 481 198 43 61 23 17 23 3500 45 6303 343 155 36 55 23 12 24 3510 56 82$2 404 155 34 51 23 24 25 3530 42 5860 324 132 23 47 16 15 26 3540 41 5770 337 154 40 53 3 17 27 3550 26 3384 210 103 27 40 16 8 ~~~~H 13 GonocoyPhillips . ~. Intrepid #2 • 3.4 Connection Gases 1 unit = 0.45°fo Methane Equivalent Depth Gas aver BGG Measured Strokes Battams U {feet units {pum strokes) um strakesj 1895' 71 1944 1860 1958' 71 2019 1961 2021' 60 2036 1905 2083' S1 1924 2066 2146' S8 1913 2171 2209' 65 1963 2234 2272' S$ 1885 2298 2335' 63 2023 2360 2406' 75 1887 2437 2460' 5 1980 2501 2523' 15 1877 2560 2590' 12 1899 2590 2653' 14 1862 2696 2716' 18 1736 2625 2779' 12 2779 2849 2842' 12 2875 2902 3.5 Trip (Wiped Gases 1 unit = 0.05°lo Methane Equivalent De th Tri tv Gas Downtime feet feet units hours 1389' 0 34 33 hrs ream to bottom 1389' 0 41 11 hrs 2464' 1129' 405 6 hrs 3128' 1338' 331 7 hrs 3128' 0 267 19hrs core 3188 0 139 15.5 hrs 3550' 3128' 77 1.5 hrs • ~POC;H ,4 Conoco~f~hilfips . ~. In#repid #2 • 3.6 Sampling Program ! Sample Dispatch Set Type 1 Purpose Frequency Interval Dispatched to Unwashed Biostratigraphy 30' ' 117' - 3000` MD ' ' cPA1 ABV 100 A Set owner: CPAs 10 3000 - 3550 MD 619 East Ship Creek Ave Ste 102 10' SHOWS Anchorage, AK 99502 Attn: D. Przywo'ski Unwashed Biostrati rah g P Y 30' 117' - 3000` MD cPAt Bayview Geologic Facility B Set owner: Pioneer 10' 3000' - 3550' MD 619 East Ship Creek Ave Ste 14 Resources 10' SHOWS Anchorage, AK 99501 ' Attn: D. Pr ski 265-6340 CPAI Unwashed Biostratigraphy 30' ' 11 T - 3000` MD ' ' Bayview Geologic Facility C Set owner: Anadarko 10 3000 MD - 3550 619 East Ship Creek Ave Ste 14 10' SHOWS Anchorage, AK 99501 Attn: D. o'ski 265-6340 CPAI Unwashed Biostratigraphy 30' ' 117' - 3000' MD ' ' 8ayview Geologic Facility D Set owner: Spare 10 3000 - 3550 MD 619 East Ship Creek Ave Ste 14 10' SHOWS Anchorage, AK ss501 Attn: D. Przywojski 265-6340 Unwashed Biostratigraphy 30' ' 117' - 3000` MD ' ' CPAI Bayview Geologic Facility E Set owner Spare 10 300fl - 3550 MD 619 East Ship Creek Ave Ste 14 9 501 . 10' SHOWS Anchorage, AK 9 ' Attn: D. Przywo ski 2fi5-6340 Washed, screened & 30' 117' - 3000` MD CPAI Bayview Geologic Facility F dried Reference Samples 10' 3000' - 3550' MD 6i 9 East Ship Creek Ave Ste 14 Set owner: CPA! 10' SHOWS Anchorage, AK 99501 Attn: D. P -ski 265-634a Washed, screened & 30' 117' - 3000` MD CPAI Bayview Geologic Facility G dried Reference Samples 10' 3000' - 3550' MD 619 East Ship Creek Ave Ste 14 Set owner: Anadarko 10' SHOWS Anchorage, AK 99501 ' ski 265-6340 Attn: D. P o Washed, screened 8~ dried Reference Samples 30' ' 117' - 3000` MD ' ' cpRl Bayview Geologic Facility H Set owner: Pioneer 10 3000 - 3550 MD 619 East Ship Creek Ave Ste 14 10' SHOWS Anchorage, AK 99501 Resources Attn: D. Przywojski 265-6340 Washed, screened & 30' 117' - 3000` MD CPAI Bayview Geologic Facility I dried Reference Samples 10' 3000' - 3550' MD 619 East Ship Creek Ave Ste 14 Set owner: AOGCC 10' SHOWS Anchorage, AK 99501 ' ski 265-6340 Attn: D. P o Isotubes Routine intervals and 250' 1000' - 3000` MD Isotech Laboratories, Inc. J significant peaks above 10'-69' 3000' - 3550' MD 1308 Parkland Court background {Total 27} Champaign, IL 61821 Set owner: CPAI CPAI Cali bond gas bags 3140'-3170' Bayview Geologic Facility K Core #1 10 Total 4 { ~ 619 East Ship Creek Rve Ste i4 Anchorage, RK 99501 Attn: D. Pr o'ski 265340 Corin Fluid Samples g Start 312$' -31 $$' ~aAl yview Geologic Facility J KI Well site TracerlMud 15' 7 Sc'trlT !eS ~ 619 East Ship Creek Ave Ste 14 K 9 501 Set owner: CPAI End Anchorage, A 9 Attn: D. P a'ski 265-6340 . Sample frequency was locally altered according to drill rate constraints and zones of interest. [~ EPOCH 15 ConocoPhillips . ~. Intrepid #2 4 PRESSURE /FORMATION STRENGTH DATA 4.'I Formation lntectritylLeak Off Tests Equivalent mud weight {EMW} is calculated from rotary table. MD TVDSS FIT /LOT FORMATION ft ft EMW 1410 1353 18.0 Torok LOT {Leak Off Test} in bald italics. 4.2 Wireline Formation Tests TVD Pressure Pressure FORMATION {ft Asia) EMW 3124 1188 7.313 Wala a Sandstone 3160 1203.5 7.324 Walak a Sandstone 4.3 Pore Pressure Evaluation Entroduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators far pore pressure trends during the drilling of a well, Background Gas {BG} Resistivity {RES} Hole Conditions {HC} Wiper Gas {WG} • Quantitative Methods Trip Gas {TG} Mud Weight {MW} Connection Gas {CG} Pore Pressure {PP} D exponent {DX} Corrected D exponent {DXG} Equivalent Circulating Density {ECD) The primary indicators used for pare pressure evaluation were gas trends relative to MW and ECD, including increases in BG, appearance and trends of CG, and magni#udes of TG and WG. Regional pore pressure trends from sonic data, provided by CanacoPhil(ips, and surface manifestations of hole conditions were also considered. As a reference, PP is calculated intitiaiiy with a formula provided by Epoch, and than modified using the indicators described above, and DXC and RES data. The formula uses DX, EGD, and BG: PP =ECD - {1-{(A01 *BG)+{0.052*DX}}} The formula has limitations such as it doesn't allow for a PP more than 1 ppg less than ECD, BG must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping establish a PP range, when establishing trends, as with DXC data, with data points in shale intervals. RES data were plotted versus depth far each hole section, and DXC versus depth for the $ 314" hole. A normal trend line was established through shale and claystone intervals on the DXC plot, although DXG data for sandy {including show} intervals is not excluded from the plot. EGD, GAS, and PP were plotted on the RES chart for reference and illustration. RES and EGD data were provided by Sperry Sun, except ECD was not measured on surface hole and was calculated. [~ ~P4~H 16 Conoco~Phillips .~. Intrepid #2 Pare Pressure is evaluated below for each hole section. 4.4 Pore Pressure Evaluation Conclusions 1) SurFace Noie -12.25" {116' to 1388') Pore pressure is estimated to range from 8.7 to 9.2 ppg in the surface hole, and is de#ermined primarily from MW, RES, and gas data, with reference to sonic data estimates. Surface hole was drilled with a 10.0 to 10.2 ppg mud, with ECD calculated at approximately 10.2 to 10.4 ppg. A lack of CG indicates PP remained well below MW and ECD. RES and BG indicate a slight upward trend to about 800 feet, and then remain flat to slightly downward to casing paint. Sonic estimates predicted similar trends, but had indicated pressure to peak as high as 9.6 ppg. It is hard to conclude pressures this high due to the relatively low gas and a lack of CG or significant TG. HC after reaching Total Depth could have suggested same higher pressures, but the rig drilled out from under surface casing with a 9.2 mud without any problems. The base of the permafrost could not be determined from RES, and DXC was nat plotted due to erratic and inaccurate bit weight data. The base of the permafrost, often determined from diminishing resistivity responses in silt and sand, cannot be determined from RES data due to a preponderance of claystone and shale. 2) 8.75" hole (1388' to 3550') Pore pressure is estimated to vary from 8.9 ppg to 9.3 ppg, except 7.3 ppg in the partially depleted • Walakpa Sandstone. MW remained in a tight range from 9.2 to 9.5 ppg while drilling, and PP is estimated from gas trends, including BG, CG, and TG, to be in a tight range also, just below the MW. ECD averaged almost a point higher than MW. BG trended upward from shoe depth until peaking at 537 units at 1849'. Relatively high CG lagged to this zone for several connections white BG decreased. Pore pressure is estimated to have peaked at approximately 9.2 at this depth, just under the MW {9.3), and than to have declined slightly until just above the HRZ. Some minor CG in the Pebble Shale appeared to come from bottom, but connection gas disappeared after 2842' with MW at only 9.2. All TG peaked early, with the zone at 1849' the likeliest contributor, but with a wide duration dropping off slowly until after bottoms up. Pore pressure is estimated to have continued to increase slightly from the HRZ to total depth, relative to increases in MW, peaking at 9.3 at total depth with a 9.5 MW. CJ [~ ~PC~~H 17 ConocoPhillips Aleska,inC. Intrepid #2 DEEP RES and GAS vs DEPTH - 12.25" 100 • • • • • BASE PF.RMAFROST'a; APPRO~ l Od~t' • ~ ~ • • •• s ~.: . . • . •. • • •~ 10 • • • •~ 4518" CA$INGDEPTH (d 1389' • DP • GAS(ME)+1 x ECD ~ PPG 1 + 0 • 200 400 600 800 1000 1200 ~ ~P ,H 1400 1600 18 • ~ O W O O O O N W O O N O O W W O O W O O • ^ ~ v~ ~ x -v n c~ v x n N v m ~ .. _ ~ o~ ~ C. y '~' ~ ~ ~~. N Cif ~ -~ N ConocoPhillips a~~. ~~. Intrepid #2 DEEP RES and GAS vs DEPTH - 8.75" 100 Torok L 1389' ~ : _ • ~ = HRZ (a~ 2664' Walakpa SS 3118-3164' • ~ • _ ; Total Depth Qa 3550' 10 ~ r • .__ ~ 1 -F- 1300 • 1800 2300 2800 ~1 ~P~H 3300 • DP ~-- GAS(ME)+1 x ECD ~ PPG 3800 • 20 ConocoPhillips Alaska, Inc. Intrepid #2 4.5 Pare pressure evaluation F ti Primary Secondary Interval Ta s Pare Pressure (EMW) T d Source of orma on Interval Lithology (°~~ Lithalogy (°~~ MD (ft) TVDSS (,~~ Min (ppJ) Max (Pp9) Trend ren Indicators Quantitative Estimate Permafrost Clyst/Sh 80°~ Sltst/Sst 20°l° Surface Surface 8.7 9.2 U Dn II BG RES, DXC Base Permafrost CI st/Sh 80°~ Sltst/Sst 20% NIA N/A 9.1 9.0 Sli Dn BG,HC,TG RES, DXC Torok Formation Clyst/Sltst 80% Sst 20% NIA N/A 9.2 9.0 U Dn II BG,CG,WG,TG RES, DXC HRZ Sh 90% Ash 1 % 2664 2600 9.0 9.1 Sli U BG,CG,TG RES, DXC To Walak a Sands SS 100°~ None 3118 3054 7.3 7.3 Dn BG,CG RES, DXC LGU Sh/CI st 90% Sst 5% 3164 3100 9.1 9.2 Sli U BG,WG,TG RES, DXC U Jur AI ine E uiv Sltst 60% CI st/Sh 30% 3350 3286 9.2 9.2 Flat BG RES, DXC UJU To Kin ak Sltst 60°I° CI st/Sh 30% 3420 3356 9.2 9.3 Sli U BG RES, DXC Total De th 3550 3486 9.3 9.3 NOTE: Clyst = ClaystonelClay, Sd =Sand, Sltst = Siltstone, Sh =Shale, Sst =Sandstone, Ash =Ash Fall Tuff . [~ EP~H :~ ConocoPt~tlips . ~. Intrepid #2 5 DRILLING DATA 5.1 Sunrev Data C7 • Measured Depth {ftj Incl. ° { } Azirn. ° { } True Vertical De #h (ft) Northings (ft} Eas#ings (ft) Vertical Section ft Dogleg Rate {°110Qft 20.50 0.00 0.00 20.50 0.00 0.00 0.00 O.ao 173.85 0.30 21.20 173.85 0.37 0.15 0.33 0.20 296.84 0.59 32$.89 296.84 1.22 -0.07 1.20 0.38 407.75 0.58 358.33 407.74 2.38 -0.38 2.41 0.31 540.56 0.66 4.23 540.54 3.96 -0.35 3.93 0.06 665.46 0.70 341.15 665.43 5.40 -0.54 5.38 0.22 788.68 0.46 324.15 788.64 6.51 -107 6.58 0.24 914.36 0.40 334.09 914.32 7.31 -1.56 7.48 0.08 1040.65 0.74 330.83 1040.60 8.42 -2.15 8.69 0.27 1166.63 0.79 313.85 1166.57 9.73 -3.17 10.20 0.18 1282.14 0.46 309.13 1282.08 10.58 -4.11 11.23 0.29 1514.33 0.84 291.19 1514.25 11.78 -6.42 12.92 0.18 1662.40 0.75 288.14 1662.31 12.48 -8.35 14.03 0.07 1786.39 0.70 290.24 1786.29 12.99 -9.83 14.86 0.05 1974.02 0.36 306.27 1973.91 13.74 -11.38 15.93 0.20 2098.63 0.14 31.77 2098.52 14.10 -11,62 16.34 0.30 2226.40 0.45 7.06 2226.29 14.73 -11.47 16.92 0.26 2349.10 0.58 27.19 2348.98 15.76 11,13 17.85 0.18 2484,76 0.53 22.13 2484.64 16.95 -10.5$ 18.89 0.05 2609.16 0.62 33$.64 2609.03 18.11 -10.61 20.42 0.35 2729.32 0.82 27.37 2729.18 19.48 -10.45 21.32 0.52 2886.73 0.33 358.81 2886.58 20.93 -9.94 22.62 0.35 2981.45 0.6$ 1$.61 2981.30 21.74 -9.77 23.37 0.41 3109.13 0.81 14.88 3108.97 23.33 -9.30 24.82 0.11 3118.00 0.93 14.38 3117.84 23.46 -9.26 24.94 1.36 3295.89 1.05 13.88 3295.70 26.44 -8.51 27.67 0.07 3358.26 121 18.77 3358. ~ 27.62 -8.16 28.74 0.30 3468.47 1.06 14.47 3468.25 29.71 -7.53 30.64 0.16 PROJ ECTED SURV EY TO TOTAL DEPTH 3550 1.06 14.47 3549.76 31.17 -7.16 31.98 0.00 ~P{JCH 22 ConotoPhillips Alaska, Iris. Intrepid #2 5.2 Bit Record Depth In Avg Bit Make Type / S# lets / MD 1 Total Bit RQP WEB RPM PP Wear BHA TFA TVDSS Footage Hrs (ft/hr} (Kibs) (psi) (ft) 12.25" Hale 1 Hughes MXL 1 / 6054705 1x12, 117 135 9.6 14 NIA 71 201 2-2-NO-A-E-O-NO-TD 1 3x18 2 Hughes MXL 1 ! 6054607 1x12, 251 1137 15.4 74 N/A 77 1217 1-1-NO-A-E-O-NO-TD 2 1x18,2x16 1 rr1 Hughes MXL 1 / 6054705 1x12' 1388 0 0 N/A NIA N/A NIA 2-2-NO-A-E-O-NO-TD 3 3x18 8.75" Hale 3 Hycalog DS70FNPV 6X14 138$ 1739' 22.6 76.9 3.6 77 1816 1-1-CT-A-X-1-ER-CP 4 204795 8.5" Hole (Caring) 1 HTC ARG425C3 / 75 TFA 0 3128 60 4.1 20.3 4.4 51 556 NIA 5 7100484 . 8.75" Hole 3rr1 Hycalog DS70FNPV 6X14 3188 362 6.8 86.6 2.1 77 2136 2-2-CT-A-X-'-ER-TD 6 204795 ~,P ,H 23 ~ ~ Cor~atoPhillips Ate. ~~. Intrepid #2 5.3 Mud Record Gontractor: MI SWAGO Mud Type: KCI / KlaGard Spud Mud Date Depth MW (ppg) ECD (ppg) VIS (s/qt) pV YP' Gels F~- (cc) FC Sols (%) CINV Ratio Sd (%) pH CI (ml/I) Ca (ml/l) 12'/." section 4/1/07 250 10.0 - 101 24 32 8/12/13 6,9 1/- 7.25 0/93 0 8.5 2850D 120 4/2/D7 425 10.0 - 128 18 38 15/28/34 6.4 2/- 8.5 0/91 0.35 9.3 4000 40 4/2/07 1032 10.1 - 66 18 38 11 /29/33 7.0 1 /- 9.0 0/91 0.30 9.5 30000 60 4/3107 1388 10.2 - 80 21 36 13!24/30 6.5 2/- 9.0 -191 0.25 9. D 28000 120 4/3/07 1388 10.2 - 8$ 19 32 9/20/22 5.5 1 /- 10.0 1 /90 0.20 9.0 26500 140 4/4!07 1388 10.2 - 130 29 53 21/38/44 5.3 2/- 9.5 1 /90 D.25 8.9 26000 160 4/4/D7 1388 10.0 - 121 25 50 17/33/37 5.6 1/- 9.0 1190 0.2D 9A 27500 120 4/5/07 1389 10.0 - 50 16 24 9/16/20 7.5 2/- 9.D 1/91 0.25 $.7 25000 120 8 3/4" section 4/5/07 1389 10.0 - 5Q 16 26 11 /18/20 7.1 1 /- 9.0 1 /91 0.20 9.0 25500 120 4/6/07 1388 10.0 - 55 16 26 11 /18/2D 7.1 1 /- 9.0 1191 0.20 9.0 25500 120 4/7/D7 1388 9.3 - 63 18 25 9/7/18 6.7 1 /- 7.5 1 /92 0.20 9.0 23500 86 4/8/07 1410 9.3 - 58 13 18 6/10/13 5.3 1/- 5.5 0/92 D.1D 9.5 29000 100 4/9/07 2039 9.2 - 56 16 22 7/11/16 5.5 2/- 7.0 0/93 0.15 8.8 34000 160 4/9/07 2450 9.2 - 65 26 33 8/17/23 4.8 2/- 8.0 1/92 0.15 9A 32500 120 4/10/07 3049 9.3 - $4 22 33 9/14/20 3,9 2/- $.0 0/92 0.10 9.0 28000 1$D 4/10/07 3128 9.3 - 82 24 27 10/12/17 3.7 2/- 8.0 0/92 0.15 9.5 3050D 160 4/11 /07 3128 9.3 - 56 13 22 7l1 D/13 4.0 2/- 7.D 1 /93 0.05 8.8 26000 140 4/11!07 3135 9.5 - 57 14 18 4/8/10 3.5 2/- 7.5 1 /92 0,15 9.0 24500 120 4/12/07 3188 9.3 - 69 12 1$ 5/8/11 4.2 2/- 7.D 0/93 0.10 9.8 25000 100 4112/07 3255 9.4 - 78 20 26 5/10/13 4.0 2/- 7.5 1/92 0.20 9.9 28000 60 4/13107 3550 9.8 - 90 25 33 8/13/16 2.9 2/- 8.5 1 /91 0.15 9.8 28000 1 DO 4!14/07 3550 9.8 - 68 18 26 8/10/13 3.4 2/- 9.D 1/91 0.15 9.0 27000 100 Abbreviations MW =Mud Weight WI_ =Water or Filtrate Loss Ca =Hardness Calcium YP =Yield Point Gels =Gel Strength Sd =Sand content GI =Chlorides VIS =Funnel Viscosity PV =Plastic Viscosity Sols =Solids ECD =Effective Circulating Density FC =Filter Cake O/W = Oil to Water ratio ~P C;H 24 ~ ~ ConocoPhillips Alaska Inc. • NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Toby Archuleta Date: 4/3/07 Time: 05:00 Current Depth: 1388 Operation: Circulate/Condition Yesterdays Depth: 251 Hole 24 hr Footage: 1137 • Drilling Parameters ROP: Current: 0 Max: 96 Tor ue: Current: 0 Max: 1695 WOB: Current 0 Max: 30 RPM: Current: 0 Max: 92 PP: Current: 352 Max: 1652 La Strokes: 3440 Time: 16min Circulation: Strokes: 3721 Time: 17.3min ECD: Current: 10.2 Max: 10.6 Mud Properties :1032' MW Change: Depth From: MW Change: Depth From: Mud Loss event: Depth Volume: To: Reason: To: Reason: Gas Data Ditch Gas: Current: 59 Max: 131 De the 1166 C;ac Fvantc No. De th TG C1 C2 C3 C41 C4N C51 C5N 1 1000 46 6414 646 338 52 28 2 1250 18 2615 270 124 21 27 8 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N See Gas Sam les Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N n/a Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N n/a Lithologies: Current: Shale 10%, Siltstone 20%, Claystone 70% Last 24 hrs: Shale 20%; Siltstone 30%; Claystone 50%; Trace Sandstone Operational Summary: Drill From 251' to 1250' @ Midnight; Drilled 1250'-1388'; Circulate and condition hole; Prepare to short trip. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: Pason Hook Load Sensor Down 251-530' • ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta Date: 4/4/07 Time: 05:00 Current Depth: 1388' Operation: _ Yesterdays Depth: 1388' 24 hr Footage: 0 C • I~rillina ParamPtPrs Wash and Ream to Bottom. ROP: Current: 0 Max: 0 Tor ue: Current: 7 Max: 14 WOB: Current 0 Max: 0 RPM: Current: 78 Max: 80 PP: Current: 284 Max: 490 La Strokes: 3440 Time: 16min Circulation: Strokes: 3721 Time: 17.3min ECD: Current: 10.4 Max: 10.6 Mud Properties :1388" MW Change: Depth From: To: Reason: MW Change: Depth From: To: Reason: Mud Loss event: Depth _1024' Volume: 80-90bbls Gas Data Ditch Gas: Current: 10 Max: 172 De the Durin tri mac FvPnts No. De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N See Gas Sam les Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N n/a Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N n/a Lithologies: Current: Shale 10%, Siltstone 20%, Claystone 70% Last 24 hrs: Shale 10%, Siltstone 20%, Claystone 70% Pump out from 1357' to 714'; Pack-Off at 714'; POOH to BHA; Continue to pull Operational Summary: BHA in tight hole; Pull Nuke Sources and download MWD; Lay down BHA @ 12:00; Lubricate rig; Make up BHA; Begin wash and ream to bottom; Depth @ 05:00 -350' Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: Pason Hook Load Sensor Down Past 24hrs (can not track depth). C] ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Sprier Toby Archuleta Date: 4/5/07 Time: 05:00 Current Depth: 1388' Operation: Running Casing Yesterdays Depth: 1388' 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: 1000 La Strokes: 1600 Time: 8min Circulation: Strokes: 3524 Time: 17min ECD: Current: Max: Mud P MW Change: MW Change: Mud Loss event: Depth: Depth: Depth: From: To: Reason: From: To: Reason: Volume: Gas Data Ditch Gas: Current: 0 Max: 31 u De the Durin Clean Out Run C;ac FvPnts Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N See Gas Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Shale 10%; Siltstone 20%; Claystone 70% Last 24 hrs: No new formation drilled. Wash and Ream from 430" to 1388'; Circulate hole clean and pump slug; Operational Summary: POOH and lay down BHA; Clean rig floor; Rig up tongs for casing @ Midnight; Finish rigging up to run casing; Begin Running 9 5/8" Casing @ 03:00. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None 1388' (a~ 20:OOhrs • r1 U • ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Tobv Archuleta Date: 4/6/07 Time: 05:00 Current Depth: 1388 Operation: Nipple Down Yesterdays Depth: 1388 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: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: 0 Muni Prnnartiac 1'~RR n 77•nn• MW: 10.0 FV: 55 PV 16 YP: 26 FL: 55 Gels: 01/18/2 Sol: 9 pH: 9.0 CI-~ 25500 Ca+' 120 MW Change: Depth: MW Change: Depth: Mud Loss event: Depth: From: To: Reason: From: To: Reason: Volume: Gas Data Ditch Gas: Current: 0 Max: 41 De the 05:44 C,as Fvantc No. De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N n/a Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N n/a Lithologies: Current: Shale 10%; Siltstone 20%; Claystone 70% Last 24 hrs: No new formation drilled. Finish running casing and circulate out @ 12;00; P/U stab-in tool; Pump Operational Summary: Cement; Rig down cement head; POOH; L/D stab-in tool @ 12:00; Rig down cement line; Begin nipple down @ 03:00 Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None • • • ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta Date: 4/7/07 Time: 05:00 Current Depth: 1388 Operation: _ Yesterdays Depth: 1388 24 hr Footage: 0 f)rillinn Parameters 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: 0 Mud Properties :1388' C~ 22:30 MW Change: Depth: From: To: Reason: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 0 De the Gas Events No. De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N See Gas Sam les Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N n/a Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N n/a Lithologies: Current: Siltstone 20%; Shale 10%; Claystone 70% Last 24 hrs: No new formation drilled. N/U BOP Stack; M/U Flow line; R/U Accumulator Hoses; Begin Rigging up for Operational Summary: BOP Test; Attempt to Test BOP(problems getting test plug to seal) @ Midnight; Begin to test BOP; Finish testing BOP @ 04:30; Begin M/U mouse hole @ 05:00 Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None M/U Mouse Hole • ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta Date: 4/8/07 Time: 05:00 Current Depth: 1520 Operation: Drilling ahead Yesterdays Depth: 1388 24 hr Footage: 132 r~ L~ rlrillinn Paramatarc ROP: Current: 112 Max: 123.4 Tor ue: Current: 189 Max: 420 WOB: Current 3 Max: 13 RPM: Current: 84 Max: 84 PP: Current: 1257 Max: 1570 La Strokes: 1434 Time: 7:25 Circulation: Strokes: 1654 Time: 7:48 ECD: Current: 0 Max: 0 Mud Properties :1410' ~ 21:00 MW Change: Depth: 1389' MW Change: Depth: Mud Loss event: Depth: From: 9.2 To: 9.3 Reason: ~ispiace spud mud From: To: Reason: Volume: Gas Data Ditch Gas: Current: 45 Max: 148 De the 1650' C;ac Fvants No. De th TG C1 C2 C3 C41 C4N C51 C5N 3 1500 91 12495 1136 681 87 60 10 6 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 1650 Gas Sam les Tri Gas. De th TG C1 C2 C3 C41 C4N C51 C5N 1389' 40 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 1590' 108 13719 1334 880 135 89 15 12 Lithologies: Current: Siltstone 40%; Claystone 60% Last 24 hrs: Siltstone 40%; Claystone 50%, Shale 10%, Trace Sand/Sandstone M/U BHA P/U SMART TOOLS, AND RIH, SURFACE TEST TOOLS, TIH W/ HWDP TO 1021', TAG CEMENT AT 1243', DISPLACE MUD, TEST 9 5/8" Operational Summary: CASING TO 2500 FOR''h HR, GOOD TEST DRILL OUT CEMENT FLOAT COLLAR AND SHOE, DRIL LAHEAD TO 1410',DISPLACE MUD AND SHIP OUT FOR STORAGE, DRILL AHEAD TO 1520' AT REPORT TIME Calibrations: None Failures: None Calibrated Total ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta /Dave Date: 4/9/07 Time: 05:00 Current Depth: 2650 Operation: Drilling ahead Yesterdays Depth: 1520 24 hr Footage: 1130 • flrillinn ParamAtarc ROP: Current: 44 Max: 277 Tor ue: Current: 317 Max: 1047 WOB: Current 4 Max: 9 RPM: Current: 78 Max: 85 PP: Current: 2066 Max: 2210 La Strokes: 2671 Time: 12:14 Circulation: Strokes: 3072 Time: 13:42 ECD: Current: 10.601 Max: 10.614 Mud Pro erties :2450' 21:00 MW: 9.2 FV: 65 PV 26 YP: 33 FL: 4.8 Gels: 8/17/23 Sol: 8 H: 9.0 CI- 32500 Ca+' 120 MW Change: Depth: +/- 1389' From: 9.3 To: 9.2 Reason: Per Program Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 62 Max: 570 De the 1849' was Fvants Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 2464' 405 156753 19493 8900 1225 1003 285 296 Connection Gas De th 1860'-2409' 2501'-2590' Regular Avg. 67u* Regular Avg. 13u'` * Reported units above background Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 1651' 140 20493 1628 960 143 126 3 4 1714' 136 18382 1625 960 128 89 16 21 1849' 570 195533 22675 11731 1801 2946 1095 1164 2041' 363 43979 4808 1641 268 420 163 243 2165' 357' 47732 5165 2370 396 578 230 250 2591' 147 21133 1944 918 160 209 82 79 r;ac ~amnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 4 1751 91 12495 1136 681 87 60 10 6 5 2000 141 16244 1713 786 132 280 89 92 6 2250 119 14317 1290 493 69 114 50 41 7 2500 45 5406 547 249 38 54 28 32 8 2750 75 10855 704 273 43 52 12 16 Lithologies: Current: Clay / Claystone60%, Siltstone 30%, Shale 10% Last 24 hrs: Siltstone 40%; Claystone 40%, Sand/Sandstone 10%, Trace Shale DRILL FROM 1520' TO 2464', PUMP HI VIS SWEEP TO CLEAN HOLE, Operational Summary: TOOH TO SHOE @ 1335', RIG SERVICE, TIH TO 2342', REAM AND WASH TO BOTTOM, CIRCULATE THICK MUD, DRILL AHEAD TO 2650 AT REPORT TIME Calibrations: None Failures: Blowing back gas sample line at connections to prevent freeze up issues r'1 LJ ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta /Doug Waters Date: 4/1007 Time: 05:00 Current Depth: 3128 Operation: _ Yesterdays Depth: 2650 24 hr Footage: 478 r~rillinn ParamPtars ROP: Current: 0 Max: 169 Tor ue: Current: 0 Max: 992 WOB: Current 0 Max: 7 RPM: Current: 0 Max: 85 PP: Current: 0 Max: 2394 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 10.2 Max: 10.627 Mud Pro erties :3049' 09:00 MW: 9.3 FV: 84 PV 22 YP: 33 FL: 3.7 Gels: 9/14/20 Sol: 8 H: 9.0 CI- 28000 Ca'+' 180 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 135 De the 2680' Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 3128' 331 Connection Gas De th 2653' 60 7820 617 260 36 59 26 30 2716' 70 9994 694 270 40 51 17 28 2799' 65 9250 644 280 46 51 13 14 2842' 69 9341 773 415 74 71 21 17 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 2680' 135 17659 1308 526 74 113 47 61 2785' 117 16450 1174 529 89 96 25 26 2869' 107 4576 390 215 39 36 11 8 3006' 124 22807 1385 555 96 84 29 20 3087' 120 20255 1017 349 57 54 39 13 Gas SamnlPs No. De th TG C1 C2 C3 C41 C4N C51 C5N 9 3000' 116 20377 1269 515 89 78 26 18 10 3100' 77 14574 770 278 46 48 28 10 11 3128' 29 4188 375 195 32 32 13 10 Lithologies: Current: Clay / Claystone60%, Siltstone 30%, Shale 10% Last 24 hrs: Siltstone 40%; Claystone 40%, Sand/Sandstone 10%, Trace Shale Drill from 2650' to 3128' Determined core point for Walakpa (Neocomian) Operational Summary: sands, Circulate, Wiper trip to 1338' RTB, Ream down from 3029' to bottom, Circulate hole clean, pump slug and POOH. TOOH Calibrations: None Failures: Gas sample line freeze up issues no gas data from 2905'-2925' ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta /Doug Waters Date: 4/1107 Time: 05:00 Current Depth: 3188 Operation: TOOH w/ coring tools Yesterdays Depth: 3128 24 hr Footage: 60 f)rillinn Parameters (Va6~ps in `Current' column are average over core interval 3128'-3188 ROP: Current: 20.3 Max: 71.2 Tor ue: Current: 1.8 Max: 107 WOB: Current 4.4 Max: 22 RPM: Current: 51.3 Max: 76 PP: Current: 556 Max: 1898 La Strokes: 3124 Time: 25.82 Circulation: Strokes: 3526 Time: 29.15 ECD: Current: 0 Max: 10.627 • Mud Pro erties :3135' 19:30 MW: 9.5 FV: 57 PV 14 YP: 18 FL: 3.5 Gels: 4/8/10 Sol: 7.5 H: 9.0 CI- 24500 Ca++ 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Values in `Current:' column are avers a over core interval 3128'-3188 Ditch Gas: Current: 21.5 Max: 34 De the 3129' Gas Events De th TG C1 C2 C3 C41 C4N C51 C5N Peaks Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 3128' 267 Connection Gas De th No. De th TG C1 C2 C3 C41 C4N C51 C5N 11 3128 29 4188 375 195 32 32 13 10 12 3140 30 3900 340 201 37 40 13 10 13 3150 20 2882 259 149 20 24 6 4 14 3160 16 2644 194 113 14 20 4 3 15 3170 19 3213 215 108 13 19 0 0- 3as Sam les Lithologies: Walakpa Sands Current: Shale 70%, Siltstone 20%, Sandstone 10% Last 24 hrs; Sand/Sandstone 80%, Siltstone 20%, Trace Shale POOH, L/D BHA, P/U Coring assembly, TIH to shoe, Rig Service, TIH to Operational Summary: Bottom, Circulate and condition mud, Begin coring run, Core 60' Circulate B/U Pump slug, POOH with Core #1.. Calibrations: None Failures: None • • • • ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta /Doug Waters Date: 4/12/07 Time: 05:00 Current Depth: 3503' Operation: Drlling ahead Yesterdays Depth: 3188' Reached 3550' 24 hr Footage: 315 ro'dA01:304/12/07 Drillina Parameters ROP: Current: 69 Max: 164 Tor ue: Current: 485 Max: 576 WOB: Current 0-2 Max: 4 RPM: Current: 78 Max: 88 PP: Current: 2283 Max: 2555 La Strokes: 3623 Time: 17.72 Circulation: Strokes: 4035 Time: 21.4 ECD: Current: 10.59 Max: 10.627 Mud Pro ernes :3255' 19:00 MW: 9.4 FV: 78 PV 20 YP: 26 FL: 4 Gels: 5/10/13 Sol: 7.5 H: 9.9 CI~ 28000 Ca+' 60 MW Change: Depth: +/-3255 From: 9.3 To: 9.8 Reason: weignt up Mud Loss event: Depth: Volume: Per program Gas Data Ditch Gas: Current: 48 Max: 184 De the 3323' C~as Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 3188' 139 snort trip 3550' 77 Connection Gas De th No. De th TG C1 C2 C3 C41 C4N C51 C5N 16 3200 21 2943 151 66 8 13 2 2 17 3260 53 8997 278 94 13 16 2 3 18 3282 68 10961 348 122 18 23 3 3 19 3323 185 39731 1281 418 53 54 8 11 20 3350 115 18330 662 223 42 40 9 7 21 3400 100 15409 636 240 30 61 23 18 22 3431 71 10313 481 198 43 61 23 17 23 3500 45 6303 343 155 36 55 23 12 24 3510 56 8282 404 155 34 51 23 24 25 3530 42 5860 324 132 23 47 16 15 26 3540 41 5770 337 154 40 53 3 17 27 3550 26 3380 210 103 27 40 16 8 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 3323' 184 39731 1281 418 53 54 8 11 Gas Sam les Lithologies: Current: Siltstone 40%, Shale 30%, Claystone 20%, Sand /Sandstone 10% Last 24 hrs: Siltstone 70%, Claystone /Shale 30%, Trace Sand /Sandstone POOH with core and coring tools, Break bit, and pull out inner core barrels, Operational Summary: L/D Core barrels in pipe shed, L/D Coring assembly, P/U Drilling BHA, and RIH, TIH to 615', Surface test MWD, TIH to 3128', Circulate out thick mud, Ream down F/ 3128' to 3188', Drill ahead to 3503' at report time. Calibrations: None Failures: None ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta /Doug Waters Date: 4/13/07 Time: 05:00 Current Depth: 3550' Operation: Wireline Logging Yesterdays Depth: 3503' Reached 3550' 24 hr Footage: 47 ro'dA01:304/12/07 f~rillinn Paramatarc ROP: Current: 0 Max: 138 Tor ue: Current: 0 Max: 479 WOB: Current 0 Max: 4 RPM: Current: 0 Max: 83 PP: Current: 0 Max: 2555 La Strokes: 3673 Time: 17.66 Circulation: Strokes: 4091 Time: 21.68 ECD: Current: Max: • Mud Pro ernes :3255' 19:00 MW: 9.4 FV: 78 PV 20 YP: 26 FL: 4 Gels: 5/10/13 Sol: 7.5 pH: 9.9 CI-~ 28000 Ca++ 60 MW Change: Depth: +/-3255 From: 9.3 To: 9.8 Reason: weignt up Mud Loss event: Depth: Volume: Per program Gas Data Ditch Gas: Current: 18 Max: 59 De the 3518' Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th No. De th TG C1 C2 C3 C41 C4N C51 C5N 23 3500 45 6303 343 155 36 55 23 12 24 3510 56 8282 404 155 34 51 23 24 25 3530 42 5860 324 132 23 47 16 15 26 3540 41 5770 337 154 40 53 3 17 27 3550 26 3380 210 103 27 40 16 8 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les Operational Summary: gHA' R/U Wireline tools, RIH w/ Wireline Complete #1 & #2 runs, Tool failure on #3 Run, Re-Run #2 Logging Run. Lithologies: Current: Siltstone 70%, Claystone 20%, Sand /Sandstone 10% Last 24 hrs: Siltstone 80%, Claystone /Shale 20%, Trace Sand /Sandstone Drill ahead from 3503' to 3550', Circulate B/U, Short trip to +/- 3128', RTB Circulate and condition mud Monitor well Build and pump slug POOH L/D Calibrations: None Failures: None • ConocoPhillips Alaska Inc. NPRA Exploration Well Intrepid #2 Report for: Mike Winfrey /Ray Springer Toby Archuleta /Doug Waters Date: 4/14/07 Time: 05:00 Current Depth: 3550' Operation: POOH w/ Logging tools Yesterdays Depth: 3550' 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: 4091 Time: 21.68 ECD: Current: Max: U Mud Pro erties :3550' 19:00 MW: 9.8 FV: 68 PV 18 YP 26 FL: 3.4 Gels: 8/10/13 Sol: 9 H: 9.0 CI-~ 27000 Ca+' 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 98 De the +/- 2880' Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th Gas Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: POOH w/ Run #3 Logging Run, Run #4 Wireline Logging run, Complete #4 Operational Summary: Logging run, R/U Logging Tools for DP Conveyed Logs, TIH w/ Logging tools, Complete Logging Run and POOH. Calibrations: None Failures: None ~1 LJ
