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203-196
Ima ge Project Well Histor Cover Pa• 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. 4 -cl3 - t q_ � w ell History File Identifier Organizing wo - sided II I VIII) II �I I II III ❑ Rescan Needed III IIIIII II II III III z in g � done � ❑ RES AN I T L DATA OVERSIZED (Scannable) Color Items: No. ❑ Ma s: �� Geyscale Items: E] Other, No/Type: Other Items Scannable by a Large Scanner �_ O G ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: /s/ ym r Project Proofing II I II �III V III lI III ari BY: Ma Date: �3 �-- /s/ Scanning Preparation �3 _ x 30 = O + 10 =TOTAL PAGES 3 (Count does not include cover sheet) /s/ BY: Maria Date: Production Scanning { II l lI'I II I I III V III Stage 1 Page Count from Scanned File: aag (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date:' ` 3'' 9 /s/ M p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II IIIIII ReScanned II I II V III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III IIII Ill 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 10/13/2011 Permit to Drill 2031960 Well Name /No. CARIBOU 26 -11 1 Operator TOTAL E &P USA INC API No. 50- 279 - 20009 -00-00 MD 9362 TVD 9362 Completion Date 2/25/2004 Completion Status P &A Current Status P &A UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: AIT /DSI /Density Neutron /NGT, CMR/NGS, MDT, MSCT, VSP (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I i meuirrrni IYumuci name J JIVIJ v ...... � D C Las 12490 "Induction /Resistivity 0 9324 Open OH PEX QUAD Combo AIT CMR DSI MDT Logs LAS DLIS Plus PDS Graphics ID C 1249'W Induction /Resistivity 85 9375 Open OH Fm Eval Poro EWR BAT LAS DLIS Plus EMF C 12494 "Mud Log 140 9362 Open CGM TIFF Graphics MudLog Gas Data LAS, Daily Drill reports, Graphics of MudLogs, OH logs CGM EMF PDF TIFF, Various reports in XLS -E'll D Asc 14890 `/Analysis - Misc 0 9076 Open VSP ED C Exc 14891 Analysis - Misc 7202 9157 Open 6/30/2004 Core Analysis Report by Core Labs, Inc. Rotary Side Wall Core DOC XLS and PDF C Wrd � 14892 Analysis - Misc 8800 9100 Open BIOSTRATIGRAPHIC SYNTHESIS by The IRF Group, Inc. DOC XLS PDF .eog Induction /Resistivity 15 Blu 109 9362 Open MD ROP DGR EWR -Log Porosity 15 Blu 109 9362 Open MD DGR CTN SLD ACAL og Sonic 15 Blu 109 9362 Open MD DGR BAT o Log Mud Log 1 Col 106 9362 Open MD Mud Log Log Mud Log 5 Col 106 9362 Open MD Mud Log Show Interval Log • DATA SUBMITTAL COMPLIANCE REPORT 10/13/2011 Permit to Drill 2031960 Well Name /No. CARIBOU 26 -11 1 Operator TOTAL E &P USA INC API No. 50- 279 - 20009 -00 -00 MD 9362 TVD 9362 Completion Date 2/25/2004 Completion Status P &A Current Status P &A UIC N Rpt Analysis - Misc 7202 9157 Open 6/30/2004 Core Analysis Report by Core Labs, Inc. Rotary Side Wall Core DOC XLS and PDF DSN 14891 Rpt Report: Final Well R 109 9362 Open ADT Well Summary Report by Sperry Sun 'Rpt Analysis - Misc 8800 9100 Open 6/30/2004 BIOSTRATIGRAPHIC SYNTHESIS by The IRF Group, Inc. DOC XLS PDF DSN 14892 169 Mud Log 1 Myl 106 9362 Open MD Mud Log -Log Mud Log 5 Myl 106 9362 Open MD Mud Log Show Interval Log .f,og Magnetic Resonance 5 Col 7100 9295 Open 4/1/2004 Magnetic Resonance CMR NGT GR <09 Sonic 15 Col 30 9330 Open 4/1/2004 Dipole Sonic Shear, Compressional GR oo- Log Induction /Resistivity 15 Col 2234 9330 Open 4/1/2004 Quad Combo Platform Express Dipole Sonic 'Log Gamma Ray Spectro 5 Col 6500 9274 Open 4/1/2004 Spectral Gamma Ray Log Formation Tester 5 Col 7615 7849 Open 4/1/2004 Modular Formation Dynamics Tester Tog See Notes 5 Col 7202 9157 Open 4/1/2004 Mechanical Sidewall Coring Tool Log Analysis - Misc 5 Col 900 9250 Open 4/1/2004 Vertical Siesmic Profile - VSP - Dual CSI - Monitor Log -Log Induction /Resistivity 15 Myl 109 9362 Open MD ROP DGR EWR -Cog Porosity 15 Myl 109 9362 Open MD DGR CTN SLD ACAL Log Sonic 15 Myl 109 9362 Open MD DGR BAT Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings 109 9362 1145 • • DATA SUBMITTAL COMPLIANCE REPORT 10113/2011 Permit to Drill 2031960 Well Name /No. CARIBOU 26 -11 1 Operator TOTAL E &P USA INC API No. 50- 279 - 20009 -00 -00 MD 9362 TVD 9362 Completion Date 2/25/2004 Completion Status P &A Current Status P &A UIC N ADDITIONAL INFORMATION Well Cored? 0( N Daily History Received? V N Chips Received? YO 5%&- Wa- k i C,p,rQ 6 h,t—\ Formation Tops � N Analysis lYY N Received? V Comments: Compliance Reviewed By: ._ ___ — Date: v 1, • • 0 *SEAN PARNELL, GOVERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL & GAS CERTIFIED MAIL RETURN RECEIPT REQUESTED September 13, 2011 Mr. Richard Garrard Geoscience Manager FEX L.P. Anchorage Office 9651 Main Tree Drive Anchorage, Alaska 99507 Re: Request for Extended Confidentiality — Caribou 26 -11 No. I Well Dear Mr. Garrard: 550 WEST 7 T " AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501 -3560 PHONE (907) 269 -8800 FAX: (907) 269 -8938 By letter dated May 16, 2006, FEX L.P. (FEX), as operator and on behalf of the working interest owners of the Caribou 26 -11 #1 well, requested extended confidentiality for the reports and information generated from the Caribou 26 -11 #1 well and filed with the Alaska Oil and Gas Conservation Commission (Commission), as required by state law. AS 31.05.035 requires operators to provide the Alaska Oil and Gas Conservation Commission with certain reports and information on wells drilled within the state. The Commission must keep that well information confidential for 24 months following a 30 -day filing period. The data may be held confidential for a longer period " f i]f the commissioner of natural resources finds that the required reports and information contain significant information relating to the valuation of unleased land in the same vicinity ...." Id., see also I 1 AAC 83.153. By letter dated June 28, 2006, the Division granted extended confidentiality through December 31, 2006. The Caribou 26 -11 #1 well was drilled on federal lease AA- 084170 within the NPR -A. The operator also files the reports and information on wells with the Bureau of Land Management. Under the NPR -A lease terms, "during the existence of [the] lease," the information remains confidential in accordance with the federal Freedom of Information Act (FOIA). Federal lease AA- 084170 was relinquished on September 1, 2010 and the well information is no longer protected from disclosure under the federal leases or FOIA. Similarly, under I1 AAC 83.153(b)(1) "[ r]eports or information for which extended confidentiality is requested or has been granted under AS 31.05.035 will not be eligible for extended confidentiality when the lease on which the well is drilled has expired." As a result, the well information for which FEX has sought extended confidentiality is no longer eligible for extended confidentiality under either federal or state law. Thus, these reports and information are now subject to public records disclosure. "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans " Richard Garrard, FEX L.P. • 9/13/2011 Page 2 of 2 A. X By copy of this letter, I am informing the Commission that no basis exists for extended confidentiality of this information. A person affected by this decision may appeal it, in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance " of this decision, as defined in 11 AAC 02.040(c) and (d) and may be mailed or delivered to Daniel S. Sullivan, Commissioner, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1- 907 - 269 -8918, or sent by electronic mail to dnr.appeals @alaska.gov. This decision takes effect immediately. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of I 1 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Sincerely, W.C. Barron Director cc: Dan Seamount, Chairman, AOGCC Julie Houle, Resource Evaluation, DOG Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. 0 Attach this card to the back of the mailpiece, or on the front if space permits, I. Article Addressed to: Mr. Richard Garrard Geoscience Manager FEX L.P. Anchorage office 9551 Main Tree Drive Anchorage, Alaska 99507 • Ret ejvetl NemeJ C. Da a of eiivery } D. is delivery address tlifferent from keen t ? Ye If YES, enter delivery address below: No 3. Se ice "Gyps Certified Mail ❑ ress Mail © Registered Return Receipt for Merchandise ® insured Mail CI C.C.D. 4. Restricted Delivery? {Extra Fee) 13 Yes 2. Article Number (ranter from service lasso 7010 2 7 8 0 00110 6 4 21, 9690 Ps Form $811, February 2004 Domestic Return Receiptµ _'10259502•ra•1540 • • SARAH PALIN, GOVERNOR DEPARTMENT OF NATURAL RESOURCES 550 WEST 7" AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501 -3560 DIVISION OF OIL & GAS PHONE: (907) 269 -8800 FAX (907) 269 -8938 January 7, 2008 " t; Mr. Richard Garrard r ' Geoscience Manager, Alaska FEX L.P. 3601 C Street, Suite 370 Anchorage, Alaska 99503 CERTIFIED MAIL# 7005 1820 0003 7400 3116 RETURN RECEIPT REQUESTED DECISION OF THE DIRECTOR Re: Request for extended confidentiality Caribou 26 -11 #1 well information Dear Mr. Garrard: On February 9, 2006, Dave Dunkley, representing FEX L.P. (FEX), contacted the Division of Oil and Gas (Division) to request extended confidentiality under 11 AAC 83.153 for reports and information required under AS 31.05.035(c) from the Caribou 26 -11 #1 well (Well), located in T10N, R5W, UM, Section 26 on federal lease AA- 084170, a six -mile by three -mile lease that consists of approximately 18 square miles. Total E &P USA, Inc. (Total) purchased the lease in the Bureau of Land Management (BLM) National Petroleum Reserve Alaska (NPR -A) lease sale in June 2002 for $890.00 per acre. Total drilled the Well in the first two months of 2004 to a measured depth of 9,362 feet. The Well was plugged and abandoned on February 26, 2004. FEX had a 30 percent working interest in the Well. Total transferred its interest in the drilled lease and adjoining acreage to FEX along with the drilling operator authority. All the transferred leases were purchased in the BLM June 2002 NPR -A lease sale and will expire in September 2012. The Well data, reports, and information filed with the Alaska Oil and Gas Conservation Commission (AOGCC) were originally scheduled for public release on March 25, 2006, under AS 31.05.035(c). FEX requested that the Division authorize extended confidentiality for this information under 11 AAC 83.153 until 90 days after the next federal NPR -A oil and gas lease sale scheduled for September 2006. 11 AAC 83.153(a) provides, in part, that the commissioner may extend confidentiality for this type of data filed under AS 31.05.035(c), if the owner of the well "makes a sufficient showing that the reports or information contain significant information relating to the valuation of unleased land beyond the three mile radius." The Division temporarily extended the confidentiality of the information until FEX was able to make a presentation in Anchorage. On May 11, 2006, Division staff met with FEX representatives to discuss the relevance of the Well information to the valuation of unleased land more than three miles from the Well. Having considered the geological, geophysical, and engineering information "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " Gold Color Oil & Gas Letterhead 1/7/08 Page 2 of 2 provided by FEX, along with the technical presentation from its geosciences staff, the Division granted FEX's request for extended confidentiality of the information until 30 days following the BLM Northeast NPR -A lease sale of September 2006, but in any event (with or without a lease sale) no later than December 31, 2006. The BLM withdrew approximately 696 tracts comprising about 8,036,485 acres in the northeast planning area, including the lands around the Well, from the BLM NPR -A lease sale that was held on September 27, 2006, for failure to fully consider the cumulative effects of oil and gas development in the northeast planning area. By letter dated October 19, 2006, FEX requested that the information derived from the Well remain confidential until BLM corrected the deficiencies in the EIS for the northeast planning area and another lease sale was conducted. The Division granted an extension of the confidentiality until December 31, 2007. On December 20, 2007, Mr. Richard Garrard, Geoscience manager for FEX, L.P. sent the Division a letter requesting the State extend confidentiality to the information from the Caribou 26 -11 #1 well because there has been no lease sale in the northeast planning area of NPR -A in the vicinity of the Caribou 26 -11 #1 well since June of 2002. The BLM is tentatively planning to issue the Final IAP /EIS in late May 2008 and conduct a lease sale in October, 2008. Because the BLM has still not conducted a lease sale of lands in the Northeast NPR -A planning area, I hereby grant extended confidentiality for the Caribou 26 -11 #1 well information until 30 days following disposal of unleased land in the next BLM Northeast NPR -A lease sale, but in any event (with or without a lease sale) this extension will expire on December 31, 2008. If the lease sale is further delayed beyond December 31, 2008, the Division will consider a written request to extend the confidentiality status of the Caribou 26 -11 #1 well information. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, Commissioner, Department of Natural Resources, 550 W. 7 Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1- 907 - 269 -8918, or sent by electronic mail to dnr appeals@,dnr.state.ak.us This decision takes effect immediately. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Sincerely, Kevin Banks Acting Director Cc: John Norman, Chair, AOGCC Howard Okland, AOGCC Jeff Landry, Department of Law Ken Helmold, Division of Oil and Gas Julie Houle, Division of Oil and Gas 0 0 d O D U SARAH PAL/N, GOVERNOR 555 Cordova Street Anchorage, AK 99501 DEPT. OF ENVIRONMENTAL CONSERVATION PHONE: (907) 269 -3094 DIVISION OF SPILL PREVENTION AND RESPONSE FAX: 269 -7687 http: / /www. w.dec.state.ak.us INDUSTRY PREPAREDNESS PROGRAM Exploration Production & Refineries August 8, 2007 File No: 305.30 (Total) Mr. Lance Martin RECEIVED Sr.HSE &R Representative AUG 1 0 2007 Total E &P USA, Inc. 800 Gessner, Suite 700 Alaska Oil & Gas Cons. Commissi Houston, TX 77024 -4284 A,achotave SUBJECT: Oil Discharge Prevention and Contingency Plan (plan) for Total E &P USA North Slope Exploration Operations: ADEC Plan No. 034 -CP -5102. Plan Rescission Dear Mr. Martin: The Alaska Department of Environmental Conservation (ADEC) completed our review of your August 7, 2007, request to have your plan rescinded. ADEC sent a letter to Total in May this. year, suggesting that a request for plan rescission be submitted to ADEC, since exploration activities have not been conducted under the plan since 2004, and there are no future activities contemplated.. The Alaska Oil & Gas Conservation ( AOGCC) confirmed on July 10, 2007 that the Caribou 26 -1 #1 well was properly plugged and abandoned. according to AOGCC requirements. Therefore, ADEC has determined that the Total plan may be rescinded as of the date of this letter. APPEAL: This is a final agency decision. Aggrieved persons with standing may appeal this decision to the Alaska Superior Court within 30 days as provided by the Alaska Rules of Appellate Procedure. As a reminder, Total must apply to ADEC for a new plan approval and proof of financial responsibility if you intend to conduct exploration or production operations in Alaska at a later date. Please be advised that the rescission of this plan approval does not relieve you of the responsibility for securing and maintaining other state, federal or local approvals or permits, and that you are still required to comply with all other applicable laws. If you have any questions regarding this rescission review process, please contact Laurie Silfven at (907) 269 -7540. Sincerely, Betty Program Manager cc: Lydia Miner, ADEC Laurie Silfven, ADEC Dianne Munson, ADEC Chris Pace, ADEC Tom Maunder, AOGCC 40 Printed on Recycled Pa, : r ALASKA OIL AND GAS CONSERVATION COriMSSION July 10, 2007 Lance T. Martin Sr. HSE &R Representative Total E &P USA, Inc. 800 Gessner, Suite 700 Houston, TX 77024 -4284 Dear Mr. Martin, r� SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 I am responding to your correspondence dated June 28, 2007 in which you request confirmation that the Caribou 26 -1 #1 (PTD 203 -196, API 50- 279 - 20009) was plugged and abandoned according to Alaska Oil and Gas Conservation Commission ( "Commission ") requirements. I confirm that the well was plugged and abandoned according to Commission requirements. Commission records indicate that Total E &P drilled Caribou 26 -11 #1 during January and February 2004. According to our records, this is the only well ever drilled by Total E &P in Alaska. The well was plugged and abandoned on February 25, 2004, with Tim Lawlor, BLM's onsite representative, as a witness to the operations. John Crisp, Commission field inspector, witnessed surface plugging operations on March 11, 2004. Commission records indicate the well has been plugged and abandoned in conformance with Commission regulations. Photographs of the Caribou 26 -11 91 drill site from an over -flight during Summer 2004 provided to the Commission indicate location clearance requirements have been met and the Commission requires no further work on the well or location. The Commission issued a location clearance letter on December 29, 2005, a copy of which is attached. Having satisfactorily complied with the Commission regulatory requirements, Total's performance bond was released December 22, 2005. If there are any questions, please contact Mr. Tom Maunder, PE at (907) 793 -1250. cc: Ms. Lydia Miner, ADEC Mr. Keith M. Boedecker, Total E &P USA �,�� ��+ ALASKA OIL AND GAS CONSERVATION COriMSSION July 10, 2007 Lance T. Martin Sr. HSE &R Representative Total E &P USA, Inc. 800 Gessner, Suite 700 Houston, TX 77024 -4284 Dear Mr. Martin, r� SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 I am responding to your correspondence dated June 28, 2007 in which you request confirmation that the Caribou 26 -1 #1 (PTD 203 -196, API 50- 279 - 20009) was plugged and abandoned according to Alaska Oil and Gas Conservation Commission ( "Commission ") requirements. I confirm that the well was plugged and abandoned according to Commission requirements. Commission records indicate that Total E &P drilled Caribou 26 -11 #1 during January and February 2004. According to our records, this is the only well ever drilled by Total E &P in Alaska. The well was plugged and abandoned on February 25, 2004, with Tim Lawlor, BLM's onsite representative, as a witness to the operations. John Crisp, Commission field inspector, witnessed surface plugging operations on March 11, 2004. Commission records indicate the well has been plugged and abandoned in conformance with Commission regulations. Photographs of the Caribou 26 -11 91 drill site from an over -flight during Summer 2004 provided to the Commission indicate location clearance requirements have been met and the Commission requires no further work on the well or location. The Commission issued a location clearance letter on December 29, 2005, a copy of which is attached. Having satisfactorily complied with the Commission regulatory requirements, Total's performance bond was released December 22, 2005. If there are any questions, please contact Mr. Tom Maunder, PE at (907) 793 -1250. cc: Ms. Lydia Miner, ADEC Mr. Keith M. Boedecker, Total E &P USA ,4 0 A14A RA. OIL AND GAS CONSERVATION COMUSSION December 29, 2005 f FRANK H. MURKOWSK/, GOVERNOR i 1 333 W. n AVENUE, SUITE loo ! ANCHORAGE. ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Gregory B. Moore Vice President Health, Safety, Environment & Regulatory Affairs TOTAL E &P USA, Inc. 800 Gessner, Suite 700 Houston, TX 77024 Re: Location Clearance Caribou 26 -11 # 1 (PTD 203 -196) Dear Mr. Moore: The Alaska Oil and Gas Conservation Commission ( "AOGCC ") has completed its location clearance inspection of the above reference well. The AOGCC inspection shows the location to be in compliance with 20 AAC 2.170, Onshore Location Clearance. The Commission requires no further work on the subject well or location. However, TOTAL E &P USA, Inc. will remain liable if any problems should occur in the future with these wells. Final location clearance is hereby APPROVED for the above listed well. • j -" A14A RA. OIL AND GAS CONSERVATION COMUSSION December 29, 2005 f FRANK H. MURKOWSK/, GOVERNOR i 1 333 W. n AVENUE, SUITE loo ! ANCHORAGE. ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Gregory B. Moore Vice President Health, Safety, Environment & Regulatory Affairs TOTAL E &P USA, Inc. 800 Gessner, Suite 700 Houston, TX 77024 Re: Location Clearance Caribou 26 -11 # 1 (PTD 203 -196) Dear Mr. Moore: The Alaska Oil and Gas Conservation Commission ( "AOGCC ") has completed its location clearance inspection of the above reference well. The AOGCC inspection shows the location to be in compliance with 20 AAC 2.170, Onshore Location Clearance. The Commission requires no further work on the subject well or location. However, TOTAL E &P USA, Inc. will remain liable if any problems should occur in the future with these wells. Final location clearance is hereby APPROVED for the above listed well. 0 - ToTAL E &P USA, INC. June 28, 2007 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: TOTAL E &P USA North Slop Exploration Operations Plugging and Abandonment Confirmation Request Dear Mr. Maunder: • R�CP Alaska L7,� � 1. 0 2 2 007 4 n hor � 9e i on a� 3 - V�lco TOTAL E &P USA, INC. (TEP USA) received a letter dated May 11, 2007 from the State of Alaska Department of Environmental Conservation (ADEC) regarding updated requirements for Oil Discharge Prevention and Contingency Plans. As noted in this letter, TEP USA has not conducted any exploratory activities since 2004 and is not currently proceeding with exploratory or drilling activities. The current approved plan on file with ADEC (Plan Number 034 -CP -5102) is set to expire on December 18, 2008. In the first quarter of 2004, TEP USA drilled an exploratory well in the Caribou Property in Alaska. Well information is as follows: Well Number 26 -11 #1 Permit Number 203 -196 API Number 50- 279 -20009 Upon conclusion of drilling and testing, the well was plugged and abandoned with the Alaska Oil and Gas Conservation Commission ( AOGCC). The May 11, 2007 letter requires that TEP USA request a determination from the AOGCC which meets either of the two criteria: a. Wells must be adequately plugged and abandoned in accordance with Alaska Oil and Gas Conservation Commission ( AOGCC) Regulations. ADEC must receive confirmation, in writing (email is adequate) from the AOGCC that the abandoned well(s) meet their requirements; OR b. You must request a determination from AOGCC that the well has not penetrated a formation capable of flowing oil to the ground surface. AOGCC will send the determination to ADEC. Based on the fact that no drilling or exploratory activities are planned by TEP USA in the Alaska region prior to the expiration date of the existing plan, TEP USA requests a confirmation from AOGCC that the above referenced well has been plugged and abandoned within the requirements of AOGCC. Please provide a copy of the written confirmation to Ms. Lydia Miner of the ADEC. Upon ADEC's receipt of your determination, TEP USA will request the above referenced spill plan be rescinded as allowed and outlined in the May 11, 2007 letter from ADEC. Prior to initiating activities in Alaska, TEP USA will prepare and submit a revised Oil Discharge Prevention and Contingency Plan based upon the current regulations at the time of potential operations. 800 Gessner, Suite 700, Houston, TX 77024 TOTAL Tel: (713) 647 -3000 — Fax: (713) 647 -3003 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission June 28, 2007 If you have any questions regarding this matter, require additional information or would like to speak to me further on the matter, I may be reached at (713) 647 -3489 or via e-mail at lance.martin @total.com Sincerely, Lance T. Martin TOTAL E &P USA, INC. Sr. HSE &R Representative Cc: Ms. Lydia Miner, ADEC Mr. Keith M. Boedecker, TEP USA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL & GAS 0 SARAH PALIN, GOVERNOR 550 WEST 7 AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501 -3560 PHONE: (907) 269 -8800 FAX (907) 269 -8938 December 19, 2006 Mr. Richard Garrard Geoscience Manager, Alaska FEX L.P. 3601 C Street, Suite 370 Anchorage, AK 99503 Certified Mail 7003 2260 0000 6288 3023 Return Receipt Requested RECEIVED DEC 2 2 2006 DECISION OF THE DIRECTOR Re: Request for extended confidentiality Caribou 26 -11 #1 well information Dear Mr. Garrard: Alaska Oil & Gas Cons. Commission Anchorage On February 9, 2006, Dave Dunkley, representing FEX L.P. (FEX), contacted the Division of Oil and Gas (Division) to request extended confidentiality for information derived from the Caribou 26- 11 #1 well (Well), located in T1 ON, RSW, UM, Section 26 on federal lease AA- 084170, a six -mile by three -mile lease that consists of approximately 18 square miles. Total E &P USA, Inc. (Total) purchased the lease in the Bureau of Land Management (BLM) National Petroleum Reserve Alaska (NPR -A) lease sale in June 2002, for $890.00 per acre. Total drilled the Well in the first two months of 2004 to a measured depth of 9,362 feet. The Well was plugged and abandoned on February 26, 2004. FEX had a 30 percent working interest in the Well. Total transferred its interest in the drilled lease and adjoining acreage to FEX along with the drilling operator authority. All the transferred leases were purchased in the BLM June 2002, NPR - A lease sale and expire in September 2012. The Well data, reports, and information were filed with the Alaska Oil and Gas Conservation Commission (AOGCC) and were originally scheduled for public release on March 25, 2006, under AS 31.05.035(c). FEX requested that the Division authorize extended confidentiality for this information under 11 AAC 83.153 until 90 days after the next federal NPR -A oil and gas lease sale scheduled for September 2006. 11 AAC 83.153(a) provides, in part, that the commissioner may extend confidentiality for this type of data filed under AS 31.05.035(c), if the owner of the well "makes a sufficient showing that the reports or information contain significant information relating to the valuation of unleased land beyond the three mile radius." The Division temporarily extended the confidentiality of the information until FEX was able to make a presentation in Anchorage. On May 11, 2006, Division staff met with FEX representatives to discuss the relevance of the Well information to the valuation of unleased land more than three "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " Division of Oil &Gas 12/18/06 Page 2 of 2 miles from the Well. Having considered the geological, geophysical, and engineering information provided by FEX, along with the technical presentation from its geosciences staff, the Division granted FEX's request for extended confidentiality of the information derived from the Well submitted to the AOGCC until 30 days following the BLM Northeast NPR -A lease sale of September 2006, but in any event (with or without a lease sale) the extension of confidentiality would expire on December 31, 2006. The BLM NPR -A lease sale was held on September 27, 2006, but the BLM withdrew approximately 696 tracts comprising about 8,036,485 acres in the northeast planning area, including the lands around the Well. The reason for withdrawing the tracts was a violation of the National Environmental Protection Act for failure to fully consider the cumulative effects of oil and gas development in the northeast planning area. Until a new environmental impact statement (EIS) addressing the cumulative effects in the northeast planning area is issued and approved, no leasing in the area will occur. FEX sent a letter to Bill Van Dyke, acting Division Director, on October 19, 2006, requesting that the information derived from the Well remain confidential until BLM corrects the deficiencies in the EIS for the northeast planning area and another lease sale is conducted. Given that the BLM is currently revising the EIS, resulting in a halt to any lease sale in the Well area, I hereby grant extended confidentiality for the Well information until 30 days following the next BLM Northeast NPR -A lease sale, but in any event (with or without a lease sale) this extension will expire on December 31, 2007. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Marty K. Rutherford, Acting Commissioner, Department of Natural Resources, 550 W. 7 Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1- 907 - 269 -8918, or sent by electronic mail to dnr appeals(a,dnr. state. ak.us This decision takes effect immediately. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. k erel n R. Banks Acting Director cc: John Norman, Chair, AOGCC Howard Okland, AOGCC Jeff Landry, Department of Law Ken Helmold, DO &G Julie Houle, DO &G Subject: RE: Trailblazer A -1 & H -1 bou 26 -11 1 From: Julie Houle < julie houle aadrWte.ak.us> Date: Wed, 24 May 2006 15:53:54 -0800 Tt :.'Toward t kland` howard_akland a adrniii:state.ak us> Hello Howard, • Conoco Phillips Trailblazer well decision appeal is sitting in our commissioner's office. Bill wants to grant extended confidentiality for the Caribou 26 -11 1 well until 30 days after the NPRA lease sale (currently scheduled for September 24 but no later than 12/31/06. 1 have to draft up the letter and get it to you within the next week or so. 1 hope this helps. Just give me a holler if you need more info. Julie Julie Houle Petroleum Geologist (907) 269 -8773 From: Howard Okland [ mailto: howard _okland @admin.state.ak.us] Sent: Wednesday, May 24, 2006 10:41 AM To: julie_houle @dnr.state.ak.us Subject: Trailblazer A -1 & H -1 , Caribou 26 -11 1 Julie, On the 30th of November, 2004, DNR denied ConocoPhillips' request to extend the confidential period of the Trailblazer wells and that the wells would be released 30 days from the date of the decision. The Division of Oil and Gas informed me that ConocoPhillips would be appealing the decision and to keep the wells confidential. ConocoPhillips submitted an appeal, with supporting documentation on the 14th of February, 2005. Jim Cowan then told me that the Div Oil & Gas was working on the exact procedure for handling the appeal. The Trailblazer wells are still being kept confidential. Has a decision been made to keep the wells confidential or are the wells to be released? Now question about Caribou 26-11 1. At Div Oil & Gas' request and as a courtesy to the operator, we have kept Caribou 26 -11 1 confidential past its release date (25 Mar, 2006). The last time you and I talked about releasing Caribou, you mentioned that Total (operator ?) would be making their case for extending the confidentiality while they were in Alaska for the AAPG, GSA, SPE meeting. Has the decision been made to extend the confidentiality of Caribou 26 -11 1 ? understand that these items are probably just a few of the many items on your task list. Any info would be helpful. TNX Howard 163 -Iq6 0 • June 28, 2006 RECEIVED JUN 2 9 2006 Alaska Oil & Gas Cons. Commission t Anchorage Richard Garrard Geoscience Manager, Alaska FEX L.P. 3601 C Street, Suite 370 Anchorage, Alaska 99503 DECISION OF THE DIRECTOR Re: Request for extended confidentiality Caribou 26 -11 #1 well information Dear Mr. Garrard: On February 9, 2006, Dave Dunkley of FEX L.P. (FEX) contacted the Division of Oil and Gas (Division) by telephone to request extended confidentiality for information derived from the Caribou 26 -11 #1 well (Well), located in T10N R5W S 26 on federal lease AA- 084170, a six mile by three mile lease that consists of approximately 18 square miles. The lease was purchased by Total E &P USA, Inc. (Total) in the Bureau of Land Management (BLM) National Petroleum Reserve Alaska (NPR -A) lease sale in June, 2002, for $890.00 per acre. Total drilled the Well in the first two months of 2004 to a measured depth of 9,362 feet. The Well was plugged and abandoned on February 26, 2004. FEX had a 30 percent working interest in the Well. Total transferred its interest in the drilled lease and adjoining acreage to FEX along with the drilling operator authority. All leases in the transferred parcels were purchased in the BLM June, 2002, NPR -A lease sale and expire in September, 2012. FEX requested that the Division authorize extended confidentiality for information derived from the Well until 90 days after the next federal NPR -A oil and gas lease sale, tentatively scheduled for September, 2006. FEX requested extended confidentiality under 11 AAC 83.153 because the well data and information currently protected from disclosure contain significant information related to the valuation of unleased lands. The Well lies greater than three miles from unleased lands. The Well data, reports, and information were filed with the Alaska Oil and Gas Conservation Commission AOGCC. The information was originally scheduled for public release on March 25, 2006. The Division temporarily extended the confidentiality of the information until FEX was able "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." 2C3-1Ci (V 0 . Page 2 of 2 to make a presentation in Anchorage showing that the information is significant for the valuation of unleased land more than three miles from the Well. FEX geoscientists met with Division personnel on May 11, 2006, to discuss its reasons to extend the confidentiality of the information beyond the 24 month confidential period set out in AS 31.05.035(c). 11 AAC 83.153(a) provides that the commissioner may extend confidentiality for this type of well information under the statute, if the owner of the well makes a sufficient showing that the well information contains "significant information relating to the valuation of unleased land beyond the three mile radius." Having considered the geological, geophysical, and engineering information provided by FEX along with its technical presentation from its geosciences staff, the Division hereby grants FEX's request for extended confidentiality of the information derived from the Well submitted to the AOGCC until 30 days following the BLM Northeast NPR -A lease sale, currently scheduled for September, 2006, but in any event (with or without a lease sale) this extension of confidentiality will expire on December 31, 2006. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Mike Menge, Commissioner, Department of Natural Resources, 550 W. 7` Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1- 907 - 269 -8918, or sent by electronic mail to dnr appeals @dnr.state.ak.us This decision takes effect immediately. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Sincerely, " 44 William D. Van Acting Director Cc: John Norman, Chair, AOGCC Howard Okland, AOGCC Jeff Landry, Department of Law Ken Helmold, Division Julie Houle, Division Caribou Subject: Caribou From: Julie Houle <julie h0ule a?dnr. tate.ak.us> Date: Fri, 10 Feb 2006 15:50:15 -0900 Tea ; 3owar& Mand <howard old4nd dm in:state.ak.us= • % Hello Howard, I received a call from Dave Dunkley with regard to the Caribou well that Totel and Fex drilled and completed in February, 2004. They are requesting extended confidentiality, so while the staff is evaluating their request, would ask that you not yet release the well data until we come up with a decision. If you can pass this information along to the right party, I would appreciate it. Julie Julie Houle Petroleum Geologist SOA DNR Div Oil & Gas 550 W 7th Ave Suite 800 Anchorage, Alaska 99501 -3560 (907) 269 -8773 Fax (907) 269 -8942 1 of 1 2/13/2006 1:43 PM i FRANK H. MURKOWSKI, GOVERNOR ALA NA OIL AND GAS CONSERVATION COMMSSION December 29, 2005 Gregory B. Moore Vice President Health, Safety, Environment & Regulatory Affairs TOTAL E &P USA, Inc. 800 Gessner, Suite 700 Houston, TX 77024 Re: Location Clearance Caribou 26 -11 # 1 (PTD 203 -196) Dear Mr. Moore: 333 W. 7 "AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 The Alaska Oil and Gas Conservation Commission ( "AOGCC ") has completed its location clearance inspection of the above reference well. The AOGCC inspection shows the location to be in compliance with 20 AAC 25.170, Onshore Location Clearance. The Commission requires no further work on the subject well or location. However, TOTAL E &P USA, Inc. will remain liable if any problems should occur in the future with these wells. Final location clearance is hereby APPROVED for the above listed well. [Fwd: Caribou 26 -11 #11 Subject: [Fwd: Caribou 26 -11 911 From: James Regg <jim_regg@admin.state.ak.us> Date: Thu, 21 Jul 2005 08:20:46 -0800 To: Steve Davies < steve_davies@admin.state.ak.us> fyi -- - - - - -- Original Message -- - - - - -- Subject: Caribou 26 -11 #1 Date: Ned, 20 Jul 2005 17:27:57 -0800 From: Tim Lawlor @ak.blm.gov To: jim regg @admin.state.ak.us • Jim, Darek Huebner in Fairbanks is the surface contact for the NPRA. His # is 907 - 474 -2312 and his email is: Darek Huebner @blm.gov Photos attached. (See attached file: DCP_1490.JPG)(See attached file: DCP_1492.JPG) Tim Lawlor BLM- Alaska Energy Branch Phone: 907 - 267 -1442 Cell: 907 - 240 -5243 Fax: 907- 267 -1304 1 of 3 12/22/2005 9:05 AM [Fwd: Caribou 26 -11 #1] Jim Regg < iim re &@admen state .A us AOGCC Content -Type: imagelpeg DCP_14911.JPG Content - Encoding: base64 • 2 of 3 12/22/2005 9:05 AM JUL -20 -2005 WED 03;45 PM I NERGY & MINERALS FAX N0. 90767 1304 United States Department of the Interior BUREAU OF LAND MANAGEMENT Northern Field Office 1150 University Avenue Fairbanks, Alaska 99709 -3844 http: / /www.ak.blm.gov Memorandum To: Mineral Law Supervisor (AK940) From: Northern Field Office Manager (AK020) Subject: Total Bond Requirement P. 01 Z,L / `1'6. �l TAK PRIDE' NAM E R I CA AA0841 b 1 -3, AA084170 -2 (AK023) zaay ' Gft Total E&P USA, INC has met the terms and conditions set forth by this office for the surface requirements of their Application for Permit to Drill (APD). Therefore bonds held may be released from the surface management viewpoint. 1 iM • Bob Merril I /AKSO /AK/B LM /DOI 05/19/2005 08:13 AM Thank you! • To Stan Porhola /CTF /AK/BLM /DOI @BL E(,,--', . F', cc Y' L bcc Subject Re: Total's Bond Release[ Bob Merrill, Senior Leasable Minerals Adjudicator Division of Energy & Solid Minerals Bureau of Land Management, Alaska State Office Phone: (907) 271 -4426 Fax: (907) 271 -3933 Internet: blmerril@blm.doi.net Stan Porhola /CTF /AK/BLM /DOI IV Stan Porhola /CTF /AK/BLM/ T Bob Merrill /AKSO /AK/BLM /DOI @BLM DOI 05/19/200512:51 AM cc Subject Re: Total's Bond Release® It's OK to give a copy to AOGCC. Stan Porhola BLM - Alaska Petroleum Engineer 267 -1469 0 • United States Department of the Interior t BUREAU OF LAND MANAGEMENT TAKE PRIDE Campbell Tract Facility IN AMERICA 6881 Abbott Loop Road Anchorage, Alaska 99507 -2599 http: / /www.ak.blm.gov AA- 084170 (941) stp May 2, 2005 Memorandum To: Mineral Law Supervisor From: Stan Porhola, Petroleum Engineer Subject: P +A of well Caribou 26 -11 #1 The TOTAL E &P well Caribou 26 -11 #1 was properly plugged and abandoned and met all downhole requirements. A total of four plugs were set in the well, two in the openhole section, one across the surface casing shoe and one 150' surface plug. The well casing was cut -off at deeper than 3' below ground, a marker plate was installed and the hole backfilled. Petroleum Engineering Tech, Tim Lawlor, was onsite and witnessed the proposed P +A operations in February, 2004. Stan Porhola �i� BLM — AK941 Petroleum Engineer TOTAL Contact Subject: TOTAL Contact From: Bill Penrose <bill @fhirweather.com> Date: Thu, 22 Dec 2005 14;23:42 0900 To: steve memains a admin.state.ak :us . Steve, The best person to whom to send paperwork regarding the TOTAL Caribou #9 -11 well would be: 0 Gregory B. Moore Vice President Health, Safety, Environment & Regulatory Affairs TOTAL E &P USA, Inc. 800 Gessner, Suite 700 Houston, Texas 77024 Phone (713) 647 -3559 Fax (713) 647 -3689 Regards, Bill 1 of 1 ey 12/22/2005 3:32 PM 0 April 19, 2004 Mr. Robert Schneider Field Manger, Northern Field Office US Department of Interior Bureau of Land Management 1150 University Ave. Fairbanks, AK 99709 -3899 Re: 2004 Annual Waste Management Report Dear Mr. Schneider, RECEIVED APR 2 12009, Alaska Oil & Gas Cons. Commission Anchorage TOTAL E &P USA INC. (TOTAL) is pleased to submit its annual waste report as required by the NPR -A stipulations. The report accurately reports the waste management activity conducted by TOTAL in the NPR -A Northeast during the 2003 -2004 winter operation. TOTAL completed its winter exploration season on April 4, 2004, following the earliest recorded spud date of January 29, 2004, since the NPR -A leases sale of 1998. All personnel, equipment and materials have been removed and clean -up has occurred at our operations in the NPR -A in preparation for the summer inspection program by the agencies. TOTAL discovered that waste management in the middle of the NPR -A can be a very costly effort. TOTAL experienced almost a four -fold increase in waste management cost as compared to what was originally planned. The majority of the waste management cost increases resulted from the underestimation of the transportation costs from the well location back to the approved disposal infrastructure at Kuparuk and Prudhoe Bay. TOTAL understands, all too well, that in order to make exploration and development cost - effective we will need to improve our waste management procedures. One of the key areas to improve is the storage and disposal of as much drilling waste as possible back into the well itself. However, the efficient handling of drilling waste has a myriad of issues associated with it. TOTAL has already started planning changes in its operations that will improve drilling waste management for the next NPR -A well. TOTAL experienced seven spills in the NPR -A and four spills on State land which were agency reportable. Three of the NPR -A spills were mud spills into secondary containment at the Nabors' rig, however, due to their size had to be reported to agencies. The other four NPR -A spills were hydraulic fluid spills with volumes in the range of 2 -3 gallons. There were no hydrocarbon spills of significant volume in the NPR -A. One of the hydraulic fluid spills occurred on the Rolligon trail when a leaking Rolligon dripped fluid over a distance of 5.8 miles. This spill required extensive cleanup, by hand, to remove the contaminated snow 4300 B Street, Suite 303, Anchorage, AK 99503 TAL Tel 907 743 0970 - Fax 907 743 0979 • TAL C USA, INC. 0 Mr. Robert Schneider April 19, 2004 Page 2 of 2 and ice. The Rolligon spill site was visited by BLM during the clean -up effort. The BLM inspector found the contractor clean -up efforts to be satisfactory. In addition to the agency reportable spills, TOTAL had sixteen non - agency reportable spills ( <1 gallon and no harm to the environment) in the NPR -A and nine non - agency reportable spills on State land. All the small non - agency reportable spills were cleaned -up immediately. TOTAL's contractors moved over 443,000 gallons of fuel oil from Inigok to the well location without a single reportable spill. Each gallon of fuel that was flown into Inigok had to be handled an average of four times before it was consumed at the well location. This is a record we are proud of considering the severe weather conditions that we operated in this winter. TOTAL performed two C -Plan spill drills, in February 2004, to test our preparedness in the event of a major release at the Caribou well location in the NPR -A. The first drill was conducted in Anchorage with participation by the Alaska Department of Environmental Conservation (ADEC) and the US Environmental Protection Agency (EPA). I have attached the ADEC letter received from Dianne Munson, Environmental Specialist, on the performance of TOTAL and its contractors during the spill drills. We are pleased with effort and expertise shown by all involved in the drills. In addition, we appreciate the agency's opinion of our preparedness as shown in the review. TOTAL learned a great deal about preparedness in the NPR -A by performing the drills and is better prepared to safely operate there. If you have any questions about the information in the waste management report, please contact George Snodgrass at (907) 743 -0970. Respectfully, John E. Bergeron, Jr✓ Alaska Manager Attachments (2) cc: Mike Worley, Bureau of Land Management Don Meares, Bureau of Land Management Greg Noble, Bureau of Land Management, Anchorage Dave Yokel, Bureau of Land Management Sheldon Adams, North Slope Borough — Planning Department George Snodgrass, TOTAL E &P USA, Inc. Tom Maunder, Alaska Oil and Gas Conservation Commission r a ^� 4300 B Street, Suite 303, Anchorage, AK 99503 9 ® TAL Tel 907 743 0970 - Fax 907 743 0979 • • TOTAL NPR -A Waste and Hazardous Materials April 2004 Management Report TOTAL NPR -A WASTE AND HAZARDOUS MATERIALS MANAGEMENT REPORT Aoril 2004 TOTAL developed this Waste and Hazardous Materials Management Report to comply with stipulation numbers 1 and 9 of the Record of Decision, Northeast National Petroleum Reserve — Alaska (NPR -A), Integrated Activity Plan /Environmental Impact Statement (IAP /EIS). This report includes the following information: • Types and quantities of wastes disposed, reused, and recycled (Table 1) • Locations of disposal, reuse and recycling facilities utilized (Table 1) • Status of waste reduction and prevention goals • Any new methods of waste prevention and /or reduction • Any recommended changes to existing waste management procedures TOTAL is committed to pollution prevention and waste reduction practices. Numerous waste management policies and guidelines in place across the North Slope were incorporated that are applicable to management of wastes at exploration operations in NPR -A. 1. Status of Waste Reduction and Prevention Goals Due to the remote nature of drilling in the NPR -A, pollution prevention and waste reduction are required to help minimize environmental impact and to reduce costs. Due to the lack of historical data, TOTAL estimated volumes and types of project wastes to be generated during the development of the waste management plan. Therefore, establishing specific reduction goals by waste stream was not done. Table 1 reports the estimated and actual 2003 -2004 exploration season waste volumes generated. Specific waste reduction goals will be developed prior to any future exploration work based on the data collected in 2003 -2004. TOTAL continually works to reduce waste generation and improve waste management practices. During the 2003 -2004 NPRA exploration project, TOTAL promoted waste reduction through: • Source Reduction – Pre - planning and inventory control to limit the amount of materials and products brought out to and kept on site. • Product Substitution – replaced products with alternatives that are not hazardous wastes when discarded. • Source Control – Proper waste segregation, good housekeeping and spill prevention to minimize waste generation. • Maximum Reuse – Find another use for materials that would otherwise be discarded. Page 1 of 11 • TOTAL NPR -A Waste and Hazardous Materials April 2004 Management Report 2. Waste Tracking Systems TOTAL used the standards outlined in the Alaska Waste Disposal and Reuse Guide Rev. 6, aka "Red Book ", for manifesting and tracking wastes across the North Slope. Manifest forms were required to track all wastes from the point of generation to the final disposal facility. Manifests or other forms of documentation were also required for many recycling activities such as hydrocarbon recovery and enhanced oil recovery (EOR), and for beneficial reuse of many materials. TOTAL contractors have their own waste management plans and policies, which are compatible with TOTAL's waste management policies. However, Table 1 does not include disposal volumes for all of the wastes generated during the 2003 -2004 exploration project. TOTAL contracts require that each service company be responsible for the handling and disposal of wastes resulting from their own activities. A summary of the waste generated by category is provided in Table 2. 3. New Methods of Waste Prevention and /or Reduction When applicable, TOTAL operated in compliance with existing waste management policies and guidelines in place across the North Slope. TOTAL applied for and was authorized to discharge clean snow melt water back onto ice roads and pads under an EPA NPDES general discharge permit. However, TOTAL chose to send this waste stream for water recycling at Kuparuk CPF- 1 rather than discharge the water due to equipment problems affecting water quality. 4. Recommended Changes to Existing Waste Management Procedures TOTAL intends to evaluate the current wastes generated and develop waste reduction goals for future work in the NPR -A. The majority of the costs associated with waste handling are attributed to transportation. Cost estimates for waste handling and disposal provided in the waste plan grossly underestimated transportation from the middle of the NPR -A Northeast. Transportation costs are a significant factor in such a remote exploration project and need improvement. TOTAL will look into alternative disposal options including, disposal of drilling liquids and solids on site, and concentration of the wastes on site to reduce the number of loads that would be required to back haul for disposal. Page 2 of 11 TOTAL NPR -A Waste and Hazardous Materials Management Report TABLE 1 - TOTAL NPR -A EXPLORATION - DRILLING WASTE STREAMS AND MANAGEMENT SUMMARY April 2004 0 Page 3 of 11 2003 -2004 RCRA Estimated Actual Classification Volume Volume Disposal Wastestream * (If Discarded) Per Well Disposed Minimization Opportunities Management Options Facilit Acid - unused Hazardous Waste 10 bbls NA Use on other job Hazardous waste if disposed NA Acid - returned E &P Exempt 200 bbls NA Use on other job if clean enough Class II Disposal Well from downhole NA Aerosol Cans Hazardous Waste 22 cans Service Use contents up entirely, or from SAA , then ACS Techs puncture ( "empty" but not (13003 reactivity) Company outset replace aerosol cans with on -site or ship 55 -gal drum of non - yet punctured) Waste refillable dispensers punctured aerosol cans as HW to TSDF TSDF Aerosol Cans Scrap metal 22 cans Service Recycle scrap metal Scrap metal dumpster (punctured with 2 Company holes) Waste Metal dumpster Aerosol Can Hazardous Waste 1 gallon Service Use contents up entirely, or from SAA, ship as HW to TSDF propellant drained Company outset replace aerosol cans with from puncturing Waste refillable dispensers TSDF Ash- Incinerator Potentially 300 lb 4 55- Gallon Minimize burnable waste Testing required to prove non - Hazardous Drums hazardous before NSB Landfill can accept - sample /test each batch for TCLP metals NSB landfill Batteries - alkaline Non - Hazardous 15 lb Service Use rechargeable batteries Non - burnable dumpster Non - burnable Company dumpster - Waste NSB Batteries - lead- 40 CFR 266.80 2 batteries Service Recyclable- Reclaim Return to supplier and ensure acid Lead Acid Batteries Company supplier reclaims lead acid for Reclamation Waste batteries per 40 CFR 266.80. Recycle 0 Page 3 of 11 TOTAL NPR -A Waste and Hazardous Materials April 2004 • 0 Page 4 of 11 2003 -2004 RCRA Estimated Actual Classification Volume Volume Disposal Wastestream * (If Discarded) Per Well Disposed Minimization Opportunities Management Options Facilit Batteries - Ni -cad, Universal Waste 2 battery Service Send to off -site recycler Recycle as Universal Waste; store mercury, lithium, packs Company in closed and labeled container - silver -oxide Waste accumulate in a UAA TSDF /Rec cler Boiler Blowdown Non - Hazardous 100 bbls 60 bbls Beneficial Reuse (example, rinse If not reused, send to FOR Class Water E &P Exempt material off II -R well equipment) CPF -1 -Water Recycle Brine - unused Non - Hazardous N/A NA Use on other job If not reused, send to FOR Class II -R well NA Brine - returned E &P Exempt 200 bbls NA Use on other job if clean enough Send to Class II Disposal Well or from downhole reuse for FOR Class II -R well NA Carbolite (Frac Non - Hazardous 15K Ibs NA Use on other job NSB Landfill- subject to approval Sand) - unused NA Carbolite (Frac E &P Exempt 20K Ibs NA None Class II Disposal Well Sand) - returned from downhole NA Cement - unused 1000 Ibs NA Use on other job Reuse, or let set up and send to landfill - for liquids, see cement rinsate Solids - NSB Landfill Cement - returned E &P Exempt 100 bbl 45 bbis None Class II Disposal Well - must meet from downhole solids requirements, i.e. <1/8 inch PBU G &I • 0 Page 4 of 11 TOTAL NPR -A Waste and Hazardous Materials Management Report April 2004 Page 5 of 11 2003 -2004 RCRA Estimated Actual Classification Volume Volume Disposal Wastestream * if Discarded) Per Well Disposed Minimization Opportunities Management Options Facilit Cement rinsate - Non - Hazardous 20 bbl 490 bbls Beneficial Reuse (wash up on top Reuse -must meet facility solids from unused (make sure pH for of cement displacement plug for and pH requirements; pH 6 -9, cement aqueous solution >2 all cement jobs) solids content <2 % but <12.5) KRU 1 R -18 Chemicals - Case by Case N/A Returned to Return to vendor for resale. Use Dependent on Chemical; many unused Determination Service on another job. discarded commercial chemical Companies products are listed hazardous waste per 40 CFR 261.33(d). Reuse Completion Fluid - Typically Non -haz, N/A NA Use on other job Reuse unused verify NA Completion Fluid - E &P Exempt 200 bbls NA None Class II Disposal Well returned from downhole NA Crude Oil E &P Exempt 10,000 bbls NA Recycle into a crude production Recycle into a crude production stream, or reinject to producing stream, or reinject to producing formation formation NA Cuttings E &P Exempt 325 cu yd 1721 cu yd None Class II Disposal Well PBU G &I Diesel - unused* Hazardous Waste 2000 NA Find a use /reuse * Cannot be Use or reuse as a fuel only or for gallons recycled into the production other legitimate uses for diesel stream at this time. (e.g., freeze protect, pressure test lines). Do not inject for the purposes of disposal. NA Page 5 of 11 TOTAL NPR -A Waste and Hazardous Materials April 2004 • Page 6 of 11 2003 -2004 RCRA Estimated Actual Classification Volume Volume Disposal Wastestream * (If Discarded ) Per Well Disposed Minimization Opportunities Management Options F acility Diesel -- used as a Hazardous Waste 0 NA Use non - ignitable, non -toxic SAA solvent Stoddard solvents or petroleum naphtha instead NA Diesel - circulated E &P Exempt 200 bbls NA Reuse or recycle in to crude Recycle or leave downhole down -hole production stream, freeze protection NA Drums /Barrels - Potentially 1 drum 3 Use remaining fluids Use completely, see below. not empty Hazardous Return to Warehouse Drums /Barrels - Non - Hazardous 10 drums Service Return to vendor or metal Barrel Crushing Facility PBU- Barrel RCRA empty Company recycling. Purchase in bulk crushing Waste containers. facilit Filters - motor oil Exempt if punctured, 15 lb Service Reuse /recycle free liquids as used Must puncture, hot drain and drained and Company oil regulated under 40 CFR 279. dismantle (crush) in order to dismantled Waste qualify for 40 CFR 261.4(b)(13) exemption. Recycle as scrap metal or add to oily waste bags after crushing. No free flowing Metal liquids allo dum ster Filters - glycol, Non - Hazardous 5 lb Service Reuse /recycle free liquids Bag with Oily Waste -- Dumpster -- diesel, fuel, etc (all Company SA10 Oily waste incinerator. No Oily waste - except used oil ) Waste free liquids. dum ster Frac Fluids - Typically Non -haz, 200 bbls NA Use on other job If not reused, send to FOR Class unused verify II -R well if a high volume water - based fluid. NA Frac Fluids - E &P Exempt 500 bbls NA None Class II Disposal Well returned from downhole NA Garbage /Food Non - Hazardous, 200 lb 22840 lbs No Styrofoam used on location. Incinerate on -site Waste Solid Waste Incinerator Glycol - unused Non - Hazardous N/A NA Reuse If not reused, send to FOR disposal well. Can use for FOR Class II -R if it was mixed into a NA • Page 6 of 11 TOTAL NPR -A Waste and Hazardous Materials April 2004 Management Report 0 0 Page 7 of 11 2003 -2004 RCRA Estimated Actual Classification Volume Volume Disposal Wastestream * If Discarded) Per Well Disposed Minimization Opportunities Management Options Facilit high volume water -based fluid suitable for FOR before the decision to discard it was made - i.e. do not send pure antifreeze straight to EOR. Glycol - from Typically Non- 30 bbls NA Reuse If not reused, send to FOR or vehicles /equipment hazardous, verify max transfer drum to POL Bldg. Can use for FOR Class 11 -R if it was mixed into a high volume water - based fluid suitable for FOR before the decision to discard it was made; i.e. do not send pure antifreeze straight to EOR. NA Light bulbs - Universal Waste 10 lb Service Replace spent lamps prior to UAA - Universal Accumulation fluorescent Company mobilization Area Waste recycle Light bulbs - Universal Waste 10 lb Service Replace spent lamps prior to UAA - Universal Accumulation screw -in type Company mobilization Area Waste recycle Methanol - unused Hazardous Waste None NA Reuse Reuse only, do not dispose NA Methanol - E &P Exempt 25 bbis NA Reuse Class 11 Disposal Well circulated downhole NA Mud - unused Typically Non- N/A NA Reuse Reuse hazardous, verify KRU 1 -H Pit Mud- returned from E &P Exempt 10,000 bbl 80 cu yds None Class 11 Disposal Well PBU G &I downhole 2200 bbls Annulus 3690 bbls KRU 1R-18 Oil /Grease from Non - Hazardous 20 gal See None onsite Incinerator - 5 gallons at Kitchen garbage time Incinerated Oil, Used Used Oil regulated 8 -10 drums Service Reuse in well work through well Reuse in well work. by 40 CFR 279 Company services at PBU. Reuse onsite 0 0 Page 7 of 11 TOTAL NPR -A Waste and Hazardous Materials Management Report April 2004 i • Page 8 of 11 2003 -2004 RCRA Estimated Actual Classification Volume Volume Disposal Wastestream * If Discarded) Per Well Disposed Minimization Opportunities Management Options Facilit Waste Paint/Thinners Hazardous Waste N/A NA Don't paint on location, don't wash Hold in SAA. Ship off -site to brushes, use all paint cans until TSDF. empty NA Paper Products Non- Hazardous 200 lb See Recycle white paper, Incinerate on -site or recycle boxes garbage copier /printer toner cartridges. through Prudhoe Incinerate Rig Wash E &P Exempt 300 bbis Reuse for mud make -up Class II Disposal Well Annulus Rinsate Case by Case 1000 bbl 303 bbis Dedicate trucks to minimize Case by Case Determination; see Determination rinsing needs. Red Book - Class II Pad 3 class I disposal Sewage RCRA Exempt, 4000 bbl 39000 lbs Low flow shower nozzles, low Treat and discharge pursuant to regulated by flush toilets. NPDES requirements. NPDES Permits and Clean Water Act NSB Landfill Snow Case by Case N/A 1505 bbis Melt and reuse in mud system Case by Case Determination; see KRU CPF -1 Determination 200 cu yds Red Book KRU 1 -H. Solvent/Degreaser, Hazardous Waste N/A NA Use material completely. Avoid using citrus -based solvents citrus based depending upon the Minimize maintenance activities whatsoever since they tend to contaminants it on location spontaneously combust more picks up when readily than Stoddard solvents. cleaning /degreasing Hold in SAA then ship of -site to a hazwaste TSDF NA Solvent/Degreaser, Hazardous Waste N/A NA Do not use. Hold in SAA. Ship off -site to Stoddard depending upon the hazardous waste TSDF. contaminants it picks up when cleaning/degreasing NA Solvent/Degreaser, Hazardous Waste N/A NA Do not use, "banned." Do not use. Prohibited onsite chlorinated N/A i • Page 8 of 11 TOTAL NPR -A Waste and Hazardous Materials April 2004 Management Report 0 • Page 9 of 11 2003 -2004 RCRA Estimated Actual Classification Volume Volume Disposal Wastestream * If Discarded) Per Well Disposed Minimization Opportunities Management Options Facilit Sorbents /Rags, Hazardous Waste 40 lb Service Avoid use of solvents Hold in SAA. Ship off -site to contaminated with Company hazardous waste TSDF. solvents Waste TSDF Sorbents /Rags, Non - hazardous 160 lb Service Use rags until completely Bag with Oily Waste -- Dumpster- - contaminated by Company saturated. SA10 Oily waste incinerator. No antifireeze, exempt Waste free liquids. waste, used oil, Oily waste non - hazardous dumpster - waste NSB Landfill Wood Non - Hazardous 2000 lb See Recycle when possible NSB Landfill garbage (- 40,000 Incinerate Ibs) NSB Landfill The following are not listed in the AK Waste Disposal and Reuse Guide i.e. Red Book Refuse- Metal Non - Hazardous 20001b 100,000 Ibs Off -site metal recycler NSB Landfill Metal Dumpster Metal dumpster - NSB Landfill Thread Protectors Potentially N/A NA Send to off -site reclaiming facility Recycle Only hazardous, although there are exemptions for scrap metal in RCRA if recycled Recycle 0 • Page 9 of 11 TOTAL NPR -A Waste and Hazardous Materials Management Report DEFINITIONS RCRA = Resource Conservation and Recovery Act ( Hazardous Waste) April 2004 E &P = Exploration, Development or Production of Crude Oil - waste is exempt from RCRA per 40 CFR 261.4(b)(5) i.e. not regulated as haz waste FOR = Enhanced Oil Recovery - i.e. the injection of fluids to enhance the recovery of oil 0 NPDES = National Pollutant Discharge Elimination System NSB = North Slope Borough SA 10 = Service Area 10, refers to the waste incinerator and the landfill operated by the NSB in Prudhoe Bay SAA = Satellite Accumulation Area (temporary storage of regulated hazardous waste < 55 gallons per 40 CFR 262.34 (c RAA = Recyclable Accumulation Area (temporary storage or recyclables that are not regulated as hazardous waste; e.g. used oil, used antifreeze) UAA = Universal Accumulation Area (similar to an RAA but distinguished to emphasize that a UAA must comply with 40 CFR 273 PBU -POL = The POL building (Petroleum, Oil, Lubricants) in the Western Operating Area of Prudhoe Bay is the BXA hazardous waste storage area. When shipping hazardous waste to Prudhoe, use the North Slope Manifest but cross out the line that says " this is not a hazardous waste ... ". TSDF = Treatment, Storage and Disposal Facility Page 10 of 11 11 • TOTAL NPR -A Waste and Hazardous Materials April 2004 Management Report TABLE 2: 2003- 2004WASTE HANDLING TOTAL NPR -A EXPLORATION DRILLING TRANSPORTATION AND DISPOSAL WASTE GENERATED Drilling Liquid Waste Muds and Cuttings 3690 bbls Cement Rinsate and Mud 793 bbls Drilling Solid Waste Cuttings and Mud 1846 bbls Other Waste Snowmelt Water 1705 bbls Rig Blow Down Water 60 bbls Sewage Solids 39000 Ibs Solid Waste 161000 Ibs Page 11 of 11 L ` DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF SPILL PREVENTION AND RESPONSE INDUSTRY PREPAREDNESS PROGRAM Exploration Production & Refineries March 9, 2004 Mr. George Snodgrass 1-1SE Advisor TOTAL E &P USA, Inc. 4300 B Street, Suite 303 Anchorage, AK 99503 Dear Mr. Snodgrass: FRANK N. MURKOWSK►, GOVERNOR 555 Cordova Street Anchorage, AK 99501 PHONE: (907) 269 -3094 FAX: (907) 269 -7687 httr):// www.state.,ik-.us/de c File No. 305-50.5102 7 .. r MAR 10 2QQ4 Subject: TOTAL E &P USA, Inc., Oil Discharge Prevention and Contingency Flan (plan), ADEC Plan Number 034.03.5102, Spill Response Exercises and Site Inspection. On February 1.0, 2004, the Alaska Department of Environmental Conservation (Department) attended an oil discharge response tabletop exercise at Total E &P USA's Anchorage offices. Mr. George Snodgrass of Total invited us to attend this "in- house" training exercise because we were unable to fly to the actual exploration drill site to conduct a planned inspection due to extreme weather conditions. ADEC's John .Bauer, Tom DeRuyter, Lydia Miner and Dianne Munson observed and participated in the exercise. Carl Lautenberger and Matt Carr of the E.P.A. were also present. Overall, Total and their contractor "The O'Brien's Group" performed very well during this exercise. The O'Brien's Group is contracted to Total to provide trained professionals to staff an Incident Management Team (IMT) in the event of a major oil discharge. Total and The O'Brien's Group worked efficiently and effectively together and clearly demonstrated their ability to implement an Incident Command System (ICS) and 1MT in the event of a major incident. The Department has learned through experience that it is very beneficial to get to know the operators organization and staff prior to a real incident and we thank you for inviting us to this exercise and for the opportunity to get to know your organization and staff better. On February 17, 2004, Dianne Munson, ADEC plan reviewer for Total's exploration operations in Alaska, visited the Caribou 26 -11 # 1 exploration well site in the National Petroleum Reserve of Alaska (NPRA). The purpose of her visit was to get a general overview of Total's exploration operations, to conduct a site inspection and to initiate an un- announced oil discharge response exercise. Alaska Statute 46.04.030(b) requires that an exploration or production facility must be operated in compliance with a contingency plan approved by ADEC.' .. Based on the inspection, the drill site and associated oil storage tanks at the Inigok airstrip appeared to be in compliance with the approved plan, in particular, potential spill sources were placed on liners. Secondary containment areas for regulated tanks appeared to be adequately sized and were free of snow at the time of inspection. All vehicles had secondary catchments (duck ponds) placed under them. Total employs Alaska Clean Seas (ACS) spill technicians to 0 0 Mr. George Snodgrass 2 March 9, 2004 TOTAL E &P USA, Inc. work at the drill site full time. A 90 barrel Lister Snow Melter tank was observed on -site. At the time of this inspection, drilling had been completed for the Caribou #1 well and Schlumberger was working to "log" the well. The ice road between Inigok and Caribou # 1 was in excellent condition. The purpose of the unannounced discharge exercise was to test Total's ability to implement an Incident Management Team (IMT) as identified in their approved plan within an acceptable time -frame of a major incident and to ensure that personnel understood their roles and duties in the event of an oil discharge. Based on our evaluation of the spill exercise forms that were completed by Paul Cooley (on -site HSE supervisor & On -Scene Commander), Gary Truitt (ACS Spill Technician) and Mike Whiteley (Drilling Supervisor) located at the Caribou #1 site, and the numerous Total and O'Brien's staff who participated from Houston, Seattle and Anchorage, the Department concludes that both the on -site and off -site staff understood well whir emergency steps were - to be taTen and who theywere to Contact in he event of a major spill as described in the plan. Also, the forms clearly demonstrated that an IMT and ICS could be mounted within an acceptable time -frame of a major incident. The majority of the positions identified in the plans ICS organization were in place or on site within two to three hours of notification and several other key players (Deputy I.C. and Operations Chief) could have been at Total's Emergency Operations Center (EMOC) by 9:30 pm that same evening (the exercise was initiated at 12:23 p.m.) During both exercises (February 10 and February 17, 2004) the Department observed that Total and their contactors took the exercises very seriously and put a great deal of effort into them. Again, we would like to offer our appreciation to you for us inviting us to the February 10, exercise and for making the necessary arrangements to assist the Department in visiting the exploration operations in NPRA. We would also like to thank Mr. Paul Cooley (HSE onsite supervisor) and Mr. Gary Truitt (ACS Spill Technician) who were prepared to answer questions and assist during the on -site visit. It's been a pleasure to work with you and your staff. If you should have any questions, please contact me at (907) 269- 3080, or Lydia Miner at (907) 269 -7680. Sincerely, Dianne Munson Environmental Specialist cc: Bill Hutmacher, ADEC, IPP Program Manager Lydia Miner, ADEC, EP &R Section Manager Jack Bergeron, Total E &P, Alaska Manager Paul Cooley, Total E &P, IISE Supervisor Tom DeRuyter, ADEC, Fairbanks John Bauer, ADEC, Fairbanks Brad Hahn, ACS Jim Burns, O'Briens Carl Lautenberger, EPA 0 TOTAL ESOP USA, INC. April 5, 2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 2 ao-.3- iq� GS R/ALS K/080 -04 HAND DELIVERY RE: Well Completion Report and Log: TOTAL Caribou 26 -11 #1 Dear Mr. Norman, TOTAL E &P USA, Inc. hereby submits its post- abandonment Well Completion Report and Log (Form 10 -407) for the Caribou 26 -11 #1 well. Enclosed, please find: Form 10 -407 Well Completion or Recompletion Report and Log Daily Operations Summary Post Abandonment Wellbore schematic Abandonment photos Wellbore Directional Survey Required well logs and samples are being submitted under separate cover. For your information, this Well Completion Report is being simultaneously submitted to the U.S. Bureau of Land Management for their approval, also. The AOGCC is requested to keep confidential all information included in this application as information in these documents is drawn from research and data proprietary to TOTAL. If you have any questions or require additional information, please contact me at (907) 743 -0970. Sincerely, TOTAL E &P USA, Jean - Francois Drilling Ma er Enclosures 4300 B Street, Suite 303, Anchorage, AK 99503 TOTAL Tel 907 743 0970 - Fax 907 743 0979 APR _6204 a ORIGINAL STATE OF ALASKA ALASKk L AND GAS CONSERVATION COMMISSO N WELL COMPLETION OR RECOMPLETION REPORT AN L OG 1 a. Well Status: Oil Gas Plugged ❑ Abandoned [2] Suspended ❑ WAG 20AAC 25.105 20nnc 25.110 GINJ ❑ WINJ ❑ WDSPL ❑ No. of Completions Other 1b. Well Class: Development ❑ Exploratory E] Service ❑ Stratigraphic Test❑ 2. Operator Name: TOTAL E &P USA, Inc. 5. Date Comp., Sus or Aband.: L z5 b /S 12. Permit to Drill Number: 203 -196 3. Address: 4300 B Street, Suite 303, Anchorage, Alaska 99503 6. Date Spudded: January 29, 2004 13. API Number: 50- 279 - 20009 -00 4a. Location of Well (Governmental Section): Surface: 1373' FSL, 1589' FWL, Sec. 26, T10N, R5W, UM Top of Productive Horizon: 1373' FSL, 1589' FWL, Sec. 26, T10N, R5W, UM Total Depth: 1373' FSL, 1589' FWL, Sec. 26, T10N, R5W, UM 7. Date TD Reached: February 11, 2004 14. Well Name and Number: Caribou 26 -11 #1 8. KB Elevation (ft): 29' 15. Field /Pool(s): Wildcat 9. Plug Back Depth(MD +TVD): Surface 4b. Location of Well (State Base Plane Coordinates): Surface: x- 613,087.15✓ y- 5,919,404.88 Zone- 5 TPI: x- 613,087.15 y- 5,919,404.88 Zone- 5 Total Depth: x- 6j3,O&7 - " J./3 M9 y- 5,949;404.88 Zone- 5 10. Total Depth (MD + TVD): j 9362' MD/TVD ° 16. Property Designation: AA- 084170 11. Depth Where SSSV Set: N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes Q No ❑ 5,9 r ,ZP 4.6 e,t 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 965' 21. Logs Run: AIT /DSI /Density Neutron /NGT, CMR/NGS, MDT, MSCT, VSP 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 65 H-40 29' 109' 29' 109' 20" Permafrost to surface None 9 -5/8" 40 L -80 29' 2236' 29' 2236' 12 -1/4" G to 1050', PF to surface None 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none "): None 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26, PRODUCTION TEST Date First Production: No production testing performed Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -RbL, 'L p \as C e: IN, sko Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate —� Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none ". Mud log submitted. Briefly, oil shows were encountered in sand members of the Lower Torok Shale and in the Valanginian Sand near TD. Reservoir quality in both intervals was poor. No cores were taken in this well. ORIGINAL t�Ls Form 10 -407 Revised 12/2003 CONTINUED ON REVERSE �9� 28. GEOLOGIC MARKERSaMik 29. MIORMATION TESTS NAME M13 TVD Include and briefly sum.., ize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state Nanushuk Sands 1672 1672 Torok Shale 3121 3121 " None ". Top of "A" Base of Slope Sd. 5939 5939 None Lower Torok Shales 6330 6330 Top of "B" Base of Slope Sd. 7161 7161 HRZ 7887 7887 LCU 8160 8160 Valanginian Sand 8912 8912 BCU 9025 9025 Oxfordian 9239 9239 tl od P QR -. Va l _ 6ag� \ �& p`as p\00 30. List of Attachments: 31. 1 hereby certify that the foregoing is true and correc the best of my knowledge. Contact: Jean -Yves Bellanger 9 Printed Name: Jean -Fro�c is r Title: Drilling Manager Signature: Phone: 907 - 743 -0970 Date: 0 �'J C?� INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for / njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: If no cores taken, indicate "none ". Item 29: List all test information. If none, state "None ". Form 10 -407 Revised 12/2003 0 • TOTAL USA Inc. CARIBOU 26 -11 #1 Well operations summary TOTAL Date Hours Mud weight Marsh viscosity 1/27/2004 01100 - 24h00 MW = 9.1 Test safety equipment, witnessed by State Representative Lou Grimaldi. Function test annular and diverter valve. 49 seconds to close annular and 14 seconds to open the diverter valve. Accumulator pressure dropped from 2700psi to 2000psi. Pressure up accumulator for first 200psi w/h one pump in 35 seconds, then with two pumps. Final pressure 2950psi in accumulator in 2mn and 26seconds. Check nitrogen bottles OK. Check packing leak from top of diverter with water OK. Check PVT system OK. Date Hours Mud weight Marsh viscosity 1/29/2004 Oh00 - 2000 MW = 9.7 MV = 50 sec. Change screens. Spud the well in at 01h00 am. Drilling 12 1/4" hole to 224ft. POOH to P/U new BHA. Log down w /MWD from 147ft to 224ft. Perform diverter drill. Drilling from 224ft to 606ft. Survey at each connection. Date Hours Mud weight Marsh viscosity 1/30/2004 OhOO - 2000 MW = 9.9 MV = 50 sec. Drilling 12 1/4" well section from 606ft to 1397ft taking survey at each connection. Wiper trip to 337 ft while working on dewatering unit and replacing auger gear box. Hole in good condition. RIH to 1397ft. Drilling 12 1/4" hole from 1293ft to 1743ft. Survey at each connection. Date Hours Mud weight Marsh viscosity 1/31/2004 Oh00 - 2000 MW = 9.65 MV = 50 sec. Drilling 12 1/4" hole from 1743ft to 2218ft. Stop drilling for correlation with Inigok #1. Drilling 12 1/4" hole to 9 5/8" casing point. POOH to 1638ft w/h 35 Klbs overpull and swabbing. Get back to bottom and circulate bottoms up. Monitor well OK. POOH and break down BHA. Date Hours Mud weight Marsh viscosity 2/1/2004 Oh00 - 2000 MW = 9.65 MV = 50 sec. Lay down BHA and download LWD data. Lay down mud motor. R/U 9 5/8" caisng equipment. Pre job safety meeting. Run 9 5/8" casing to 2236ft. Port collar at 881 ft. Circulate bottom's up and hook up cement line. Pre job safety meeting and circulate hole while reciprocating string. Date Hours Mud weight Marsh viscosity 2/2/2004 Oh00 - 2000 MW = 9.7 MV = 50 sec. Conditioning mud and circulate. Line up Halliburton line and pressure test to 3000 psi. Cement 9 5/8" casing w/h 50 bbls Alpha spacer + 200 bbls lead slurry 10.6 ppg (Permafrost L) + 65 bbls tail slurry 15.6 ppg (premium cement), Displace w/141 bbls. WOC then lay down casing equipment and landing joint. N/U diverter line and annular preventer. Stab well head + N/U DSA and BOP stack. Pressure test Head seal to 1000 psi for 15 mn. Work on kill and choke lines in progress. Date Hours Mud weight Marsh viscosity 2/3/2004 Oh00 - 2000 MW = 9.35 MV = 50 sec. Continue nippling up BOP, hook up Kill lines 1 & 2. Pressure test annular to 250 and 2500 psi. Pressure test upper PR, lower PR, inside and outside choke valves (HCR and manual), choke manifold to 250 and 5000 psi. Date Hours Mud weight Marsh viscosity 2/4/2004 OhOO - 24hOO MW = 9.35 MV = 50 sec. Pressure test upper and lower IBOP's plus floor vavles to 250 and 5000 psi. Pressure test Koomey Unit. Set wear bushing. Pick up 160 joints of 4" HT38 DP's. Date Hours Mud weight Marsh viscosity 2/5/2004 Oh00 - 2000 MW = 9.5 MV = 50 sec. Continue picking up DP's. Pick up 8 1/2" BHA and RIH to TOC at 2070% DOG from 2070 to 2144ft. Pressure test casing to 2600 psi for 15' OK. DOC from 2144 to 2243ft. Drill 8 1/2" hole from 2243 to 2254ft. Perform LOT #1. EMW= 14.2ppg. Drill ahead from 2254 to 2405ft. • • TOTAL USA Inc. CARIBOU 26 -11 #1 Well operations summary TOTAL Date Hours Mud weight Marsh viscosity 2/6/2004 Oh00 - 24h00 MW = 9.45 MV = 50 sec. Continue drilling 8 1/2" hole from 2405 to 2577ft. Perform LOT #2. EMW= 13.4 ppg. Drill ahead in 8 1/2" from 2577 to 3640ft. Date Hours Mud weight Marsh viscosity 2/7/2004 Oh00 - 2000 MW = 9.35 MV = 50 sec. Shut down due to failure on electrical generator #2. Drill ahead from 3640ft to 4593ft. Circulate bottom's up and trip out to casing shoe. Tight spots 3436 - 3147 then 2856 to 2240ft. Circulate bottom's up at casing shoe. Date Hours Mud weight Marsh viscosity 2/8/2004 Oh00 - 2000 MW = 9.45 MV = 50 sec. RIH from 2240 to 4593ft. Change out hydraulic hose on top drive. Unplug with water jet two flow lines. Drill ahead 8 1/2" hole from 4593ft to 5942 back ream and wash each connection. Average ECD = 10.1 ppg Date Hours Mud weight Marsh viscosity 2/9/2004 Oh00 - 2000 MW = 10.0 MV = 50 sec. Drill ahead from 5942' to 6699'. Wiper trip to 4306' w/o problems. Drill ahead 8 1/2" hole section from 5942" to 7127'. Date Hours Mud weight Marsh viscosity 2/10/2004 Oh00 - 2000 MW = 10.0 MV = 50 sec. Drill 8 1/2" hole section from 7127' to 8889' Average ECD = 10.5 pppg Date Hours Mud weight Marsh viscosity 2/11/2004 Oh00 - 2000 MW = 10.2 MV = 50 sec. Drill from 8889' to 8984'. Circulate bottom's up for sampling. Drill from 8984' to 9004'. Circulate bottom's up for sampling. Drill from 9004' to 9072'. Circulate bottom's up for sampling. Drill from 9072' to 9362'. Circulate bottom's up and trip out to surface. Download LWD and lay down same. Date Hours Mud weight Marsh viscosity 2/12/2004 Oh00 - 24h00 MW = 10.2 MV = 50 sec. Continue laying down BHA.Retrieve wear bushing. ROPE pressure tests to 250 psi and 5000 psi. Hydrill to 3500 psi. Set wear bushing. TIH to 2176'. Ream down to 3320'. TIH to 5920'. Ream 80' to 6100'. Circulate bottom's up. Lot of clay cutting over shakers. TIH to 7789'. P/U top drive. Date Hours Mud weight Marsh viscosity 2/13/2004 Oh00 - 2000 MW = 10.4 MV = 50 sec. Wash and ream from 7789' to TD @ 9362'. Circulate bottom's up. Wiper trip to 6967'. Max overpull 30KIbs @ 8676'. Trip back in hole to TD. Weight up mud to 10.4 ppg. POOH to 2650' in progress. Date Hours Mud weight Marsh viscosity 2/14/2004 Oh00 - 2000 MW = 10.45 MV = 50 sec. POOH BHA to surface. Stand back same in derrick. Rig up Schlumberger for logging. RIH run #1 w/h AIT - DSI - Density - Neutron - NGT. Log open hole from 9317' to 95'. High resolution mode from 9222' to 8780'. RIH run #2 w/h CMR - NGS. Log open hole from 9300' to 8870' and from 8000' to 7000'. Record NGS only from 9300' to 7930' and from 7500' to 6500'. POOH tool in progress. TOTAL USA Inc. CARIBOU 26 -11 #1 Well operations summary TOTAL Date Hours Mud weight Marsh viscosity 2/15/2004 Oh00 - 2000 MW = 10.45 MV = 50 sec. Continue POOH toolstring. 1000lbs overpull @ 3170' (bottom of tool). Log toolstring got stuck. Work on fish w/o success. Prepare for cut and thread fishing. RIH fishing BHA w/ 5 3/4" overhot dressed w/ 3 3/8" grapple. Strip over wire line w /overshot. Circulate bottom's up. Strip over fish. Work pipe to free tool w/ 10KIbs. Work on wire line to latch tool in grapple with 4400 lbs. R/U circulating head. Date Hours Mud weight Marsh viscosity 2/16/2004 Oh00 - 24h00 MW = 10.4 MV = 50 sec. Attempt to shear circulation disc w/o success. Pull on wire w/ T bar. POOH E -line. POOH fishing BHA and lay down fish. M/U clean out BHA and RIH to 3123'. Ream from 3123' to 3410'. RIH to 6010'. Break circulation. RIH to 9242'. Wash down fill to TD @ 9362'. POOH in progress Date Hours Mud weight Marsh viscosity 2/17/2004 Oh00 - 24h00 MW = 10.4 MV = 54 sec. POOH BHA. P/U MDT tool on DP's. Circulate B/U @ casing shoe. Conveyed MDT to 7286'. M/U side entry sub. RIH wireline. Land in wet connector. Perform MDT pressure tests - 17 stations done. POOH to side entry sub. Unlatch wet connector and POOH a -line. POOH w /MDT in progress. Date Hours Mud weight Marsh viscosity 2/18/2004 Oh00 - 24h00 MW = 10.45 MV = 57 sec. POOH MDT to surface. RIH w /BHA. Wash and ream from 3121' to 3410'. RIH and break circulation @ 6100'. RIH and wash and ream from 9148' to 9362'. Circulate bottom's up. Pumped Hi vis sweep aroud. POOH to surface. R/U Rotary Side Wall Coring (MSCT) RIH and perform run #4 as planed. Date Hours Mud weight Marsh viscosity 2/19/2004 Oh00 - 24h00 MW = 10.45 MV = 48 sec. Took 23 samples, recovered 22. RIH w /MSCT on run #5. Took 27 cores from 9157' to 7202'. No recovery, found bent push rod. Replace push rod and run back in hole run #6 w /MSCT. Took 27 samples w /100% recovery. RIH run #7 wNSP /GR to 2000'. Perform test vibroseis and quality check. Date Hours Mud weight Marsh viscosity 2/20/2004 Oh00 - 24h00 MW = 10.45 MV = 47 sec. Perform VSP from 9259' to 5100'. Continue VSP performing check shots from 4900' to 900'. POOH run #7 and lay down wireline equipment. Service top drive, change out hydraulic service loop. R/U tubing equipment. P/U 20 joints 2 7/8" tubing and M/U X -Over. Change handling equipment. Date Hours Mud weight Marsh viscosity 2/21/2004 OhOO - 2000 MW = 10.4 MV = 45 sec. RIH w/h tubing on DP's. Break circulation @ 760' and 3600'. RIH to bottom wash last stand. Circulate bottom's up and rig up cementing lines and pressure test to 2500psi. Mix and pump 10bbls fresh water and 41 bbls 15.8ppg slurry. Displace w/h 2bbls fresh water and 88.5bbls mud. POOH to 8890' and circulate bottom's up (contaminated cement/mud). Pump 66bbls 15.6ppg heavy mud and spot on TOC. POOH 7988' circulate 1.5 bottom's up. Line up cement lines and pressure test to 2500psi. Pump 10 bbls fresh water and 25.5bbls 15.8ppg slurry. Displace w/h 2bbls fresh water and 76.8bbls mud. POOH to 7670'. Circulate while waiting on cement. Line up cement lines and continue to circulate. Date Hours Mud weight Marsh viscosity 2/22/2004 Oh00 - 2000 MW = 10.45 MV = 48 sec. Pump second stage of Cement plug #2. Pumped 10bbls fresh water + 24.2bbls 15.8ppg slurry. Displace w /2bbls fresh water and 73bbls mud. POOH to 7382'. Circulate bottom's up, minor cement returns to surface. POOH to surface. Lay down 2 7/8" tubing. Lay down HWP's + DC's. RIH light BHA to TOC. Found @ 7373'. Weigt test w /20KIbs OK. Circulate hole clean, rack back 24 stands and POOH laying down excess of DP's. • • TOTAL USA Inc. CARIBOU 26 -11 #1 Well operations summary IOTA L Date Hours Mud weight Marsh viscosity 2/23/2004 Oh00 - 2000 MW = 10.45 MV = 47 sec. Continue POOH laying down DP's. M/U and RIH EZ drill Squeeze Packer @ 2181'. Pressure drop measurement: 1 BPM = 75psi, 213PM = 100psi, 3BPM = 150psi, 46PM = 225psi. Pressure test annulus to 1500psi. Perform injectivity test @ 0.513PM. Pressure build to 1020psi then broke to 400psi stabilized. Increse to 1 BPM = 420psi, 1.56PM = 450psi, 213PM = 480psi, 2.513PM = 490psi, 3BPM = 520psi, 3.5BPM = 560psi. Stop pumping pressure stabilized at 320psi. Perform mud injection after getting Authorities green light. Inject mud at 3.5BPM w/h an injecting pressure = 560psi. Pumped in hole 950bbls at 2000 including 50bbls water. Date Hours Mud weight Marsh viscosity 2/24/2004 Oh00 - 24h00 MW = 10.4 MV = 47 sec. Clean out liquid mud storage tanks and continue to inject in hole. Total pumped in hole at 2000 = 1772bbls. Date Hours Mud weight Marsh viscosity 2/25/2004 Oh00 - 2000 N/A N/A Spot cement plug #3 from 2236' to 2362' (126' open hole) + 2236' to 2181' cased hole with 13bbls slurry 15.8ppg. Displace w/h 2bbls of water and 20.8bbls of mud. Pressure increase from 320psi to 520psi when cement in the open hole. Sting out from packer. Pump second stage og cement plug #3 from 2159' to 2036'(123') w/h 9.3bbls slurry 15.8ppg. Displace w/h 2.5bbls water + 17bbls mud. POOH to 1300' circulate 1.5 bottom's up. Lay down tubular. Pressure test 9 5/8" casing to 2000psi for 10' OK. Pull pipes to 184'. Spot surface cement plug #4. 15bbls C permafrost slurry 15.6ppg. Got cement returns to surface.Flush down BOPE. Super suck cement from cellar. Lay down cementing lines Date Hours Mud weight Marsh viscosity 2/26/2004 Oh00 - 2000 N/A N/A N/D BOPE, kill line valves, Hydril, BOP rams, mud cross and drilling spool adapter. N/D wellhead. Remove flex hoses and flow line to shaker. Measure TOC at 3' below ground level (Witnessed by BLM's Representative). End of well operations on the well Caribou 26 -11 #1 at 12h00am on 02/26/04. Start demobilization of the rig to Deadhorse. Date Hours Mud weight Marsh viscosity 3/11/2004 Oh00 - 24h00 N/A N/A Weld on outermost casing marker plate. Operation witnessed by AOGCC representative Mar 11th, 2004 All casing cut off • and marker plate installed at 4' BGL 16 ", 65 #, H -40 Conductor @ 109' MD /TVD Bottom of Cement Plug #4 @ 184' 10.4 ppg Drilling Mud Top of Cement Plug #1 @ 2,036' ti EZSV Cement Retainer @ 2,181' 9 -5/8 ", 40 #, L -80, BTC @ 2,236' MD /TVD Bottom of Cement Plug #3 @ 2,362' 10.4 ppg Drilling Mud Top of Plug #2 @ 7,373' - - - - = _ (Plug #2 Pumped in 2 Stages) - - Bottom of Cement Plug #2 @ 7,988' 15.6 ppg Viscous Mud Pill - - Top of Cement Plug #1 @ 8,890' 10.4 ppg Drilling Bottom of Cement Plug #1 @ 9,355' Mud TD @ 9,362' MD /TVD 0 TOTAL Caribou 26 -11 #1 Wellbore Schematic q� a ' A. • F a�- �R is rte` 0 0 7 17 ti a . � 4 • • Halliburton Sperry -Sun Western North Slope, Total E &P NPRA (Caribou East) Caribou 26 -11 #1 Job No. AKMW2837527, Surveyed: 11 February, 2004 Survey Report 11 March, 2004 Your R,ef API 502792000900 Surface Coordinates: 5919404.88 N, 613087.15 E (70° 11' 19.3962" N, 153° 05' 20.5041" 1" Grid Coordinate System: NAD27 Alaska State Planes, Zone 5 Surface Coordinates relative to Global Coordinates: 6563.12 S, 8010.15 E (Grid) Surface Coordinates relative to Caribou East -Site 1: 0.00 N, 0.00 E (True) Kelly Bushing Elevation: 174.47ft above Mean Sea Level 95pew-viy -so-Lin DRILLING sGRyICGS Survey Reksvy2070 A HaNiburton Company 91 0 Halliburton Sperry -Sun Survey Report for NPRA (Caribou East) - Caribou 26 -11 #1 Your Ref: API 502792000900 Job No. AKMW2837527, Surveyed. 11 February, 2004 Western North Slope, Total E &P Measured True Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ( ° /100ft) 0.00 0.000 0.000 - 174.47 0.00 0.00 N 0.00 E 5919404.88 N 613087.15 E 0.00 MWD Magnetic 171.05 0.990 187.060 -3.43 171.04 1.47S 0.18W 5919403.41 N 613086.99 E 0.579 1.29 358.93 0.980 178.650 184.42 358.89 4.68S 0.34 W 5919400.19 N 613086.88 E 0.077 3.99 450.79 1.000 171.920 276.27 450.74 6.26S 0.21 W 5919398.62 N 613087.03 E 0.128 5.18 543.37 0.840 177.130 368.84 543.31 7.74S 0.06 W 5919397.14 N 613087.20 E 0.195 6.29 637.62 0.750 156.140 463.08 637.55 8.99S 0.22 E 5919395.89 N 613087.50 E 0.321 7.14 728.80 0.510 149.310 554.25 728.72 9.89S 0.67 E 5919395.00 N 613087.97 E 0.275 7.59 822.46 0.610 170.550 647.91 822.38 10.74S 0.96 E 5919394.16 N 613088.27 E 0.244 8.11 916.00 0.760 188.930 741.44 915.91 11.84S 0.95 E 5919393.05 N 613088.28 E 0.282 9.01 1010.02 0.570 177.630 835.46 1009.93 12.93S 0.87 E 5919391.97 N 613088.21 E 0.245 9.93 1101.52 0.660 171.820 926.95 1101.42 13.90S 0.96 E 5919390.99 N 613088.32 E 0.120 10.66 1197.62 0.260 133.170 1023.05 1197.52 14.60S 1.20 E 5919390.30 N 613088.57 E 0.505 11.08 1384.61 0.220 196.520 1210.04 1384.51 15.23S 1.41 E 5919389.67 N 613088.79 E 0.136 11.47 1476.22 0.310 180.030 1301.65 1476.12 15.65S 1.36 E 5919389.25 N 613088.74 E 0.128 11.84 1574.49 0.720 318.360 1399.91 1574.38 15.46S 0.95 E 5919389.44 N 613088.33 E 0.991 11.92 1667.63 0.720 322.010 1493.05 1667.52 14.56S 0.20 E 5919390.33 N 613087.57 E 0.049 11.64 1766.58 0.900 308.040 1591.99 1766.46 13.59S 0.79 W 5919391.28 N 613086.56 E 0.269 11.44 1858.61 1.050 314.440 1684.00 1858.47 12.55S 1.97 W 5919392.30 N 613085.37 E 0.201 11.30 1954.71 1.120 307.740 1780.09 1954.56 11.36S 3.34 W 5919393.47 N 613083.98 E 0.151 11.14 2050.04 1.130 310.250 1875.40 2049.87 10.18S 4.79 W 5919394.63 N 613082.51 E 0.053 11.05 2170.10 1.000 311.780 1995.44 2169.91 8.72S 6.48 W 5919396.06 N 613080.80 E 0.111 10.86 2317.58 1.180 308.230 2142.89 2317.36 6.92S 8.63 W 5919397.83 N 613078.63 E 0.130 10.68 2413.57 1.050 310.650 2238.86 2413.33 5.74S 10.07 W 5919398.99 N 613077.16 E 0.144 10.57 2507.51 1.010 310.060 2332.79 2507.26 4.64S 11.36 W 5919400.07 N 613075.86 E 0.044 10.45 2604.16 1.080 352.650 2429.42 2603.89 3.19S 12.13 W 5919401.51 N 613075.07 E 0.788 9.73 2697.85 0.830 350.050 2523.10 2697.57 1.65S 12.36 W 5919403.05 N 613074.82 E 0.271 8.62 2792.70 0.750 352.020 2617.94 2792.41 0.36S 12.56 W 5919404.33 N 613074.59 E 0.089 7.70 2886.40 0.620 353.190 2711.63 2886.10 0.75 N 12.71 W 5919405.44 N 613074.43 E 0.140 6.88 2981.01 0.750 351.940 2806.24 2980.71 1.87 N 12.86 W 5919406.56 N 613074.27 E 0.138 6.07 3076.17 0.620 349.700 2901.39 3075.86 3.00 N 13.04 W 5919407.68 N 613074.07 E 0.139 5.26 3172.68 0.630 40.970 2997.89 3172.36 3.91 N 12.78 W 5919408.60 N 613074.31 E 0.560 4.38 3267.96 0.980 53.050 3093.16 3267.63 4.80 N 11.79 W 5919409.50 N 613075.29 E 0.406 3.07 3364.40 0.920 51.890 3189.59 3364.06 5.77 N 10.52 W 5919410.49 N 613076.55 E 0.065 1.54 3462.70 0.900 47.420 3287.88 3462.35 6.78 N 9.33 W 5919411.52 N 613077.72 E 0.075 0.02 3559.68 0.800 51.380 3384.85 3559.32 7.72 N 8.24 W 5919412.47 N 613078.80 E 0.120 -1.38 11 March, 2004 - 10:09 Page 2 of 5 DrillQuest 3.03.06.002 Western North Slope, Measured Depth (ft) 3656.85 3752.83 3846.84 3945.98 4042.88 4139.75 4236.39 4332.84 4429.81 4523.03 4619.31 4715.12 4811.23 4906.59 5003.88 5098.92 5195.93 5293.19 5389.37 5484.73 5581.02 5677.85 5776.09 5968.47 6066.00 6158.75 6255.20 6345.24 6440.05 6535.23 6724.63 6818.17 6915.48 7010.32 7105.60 True Incl. Azim. 0.590 119.190 0.700 143.780 0.610 153.080 0.470 164.250 0.310 202.190 0.510 209.280 0.510 227.830 0.590 253.900 0.670 265.430 0.860 262.500 0.720 252.180 0.170 161.050 0.140 78.450 0.250 72.780 0.470 47.890 0.280 23.720 0.480 16.460 0.620 20.210 0.740 9.430 1.270 10.270 1.200 2.730 1.130 4.260 1.080 10.840 0.250 111.140 0.480 164.640 0.620 0.500 0.470 0.570 0.620 0.550 0.280 0.360 0.280 0.310 158.210 141.630 132.770 116.290 102.630 103.650 212.560 228.050 237.770 260.940 Sub -Sea Depth (ft) 3482.01 3577.99 3671.99 3771.13 3868.02 3964.89 4061.53 4157.97 4254.94 4348.15 4444.42 4540.23 4636.34 4731.70 4828.99 4924.02 5021.03 5118.29 5214.46 5309.80 5406.07 5502.88 5601.10 5793.47 5891.00 5983.75 6080.19 6170.23 6265.03 6360.21 6549.60 6643.14 6740.45 6835.29 6930.56 Vertical Depth (ft) 3656.48 3752.46 3846.46 3945.60 4042.49 4139.36 4236.00 4332.44 4429.41 4522.62 4618.89 4714.70 4810.81 4906.17 5003.46 5098.49 5195.50 5292.76 5388.93 5484.27 5580.54 5677.35 5775.57 5967.94 6065.47 6158.22 6254.66 6344.70 6439.50 6534.68 6724.07 6817.61 6914.92 7009.76 7105.03 Halliburton Sperry -Sun Survey Report for NPRA (Caribou East) - Caribou 26 -11 #1 Your Ref. API 502792000900 Job No. AKMW2837527, Surveyed: 11 February, 2004 Local Coordinates Northings Eastings (ft) (ft) 7.90 N 7.27 W 7.18 N 6.49 W 6.27 N 5.93 W 5.41 N 5.58 W 4.79 N 5.57 W 4.17 N 5.88 W 3.50 N 6.41 W 3.08 N 7.20 W 2.89 N 8.25 W 2.76 N 9.49 W 2.48 N 2.16 N 2.05 N 2.14 N 2.47 N 10.78 W 11.30 W 11.14 W 10.83 W 10.33 W 2.94 N 3.55 N 4.43 N 5.53 N 7.18 N 9.24 N 11.20 N 13.08 N 14.71 N 14.24 N 13.40 N 12.58 N 12.02 N 11.55 N 11.23 N 10.79 N 10.49 N 10.08 N 9.76 N 9.60 N 9.95 W 9.74 W 9.44 W 9.16 W 8.87 W 8.63 W 8.51 W 8.27 W 7.53 W 7.23 W 6.94 W 6.48 W 5.97 W 5.26 W 4.33 W 2.45 W 2.14 W 2.49 W 2.91 W 3.36 W Global Coordinates Northings Eastings (ft) (ft) 5919412.67 N 613079.76 E 5919411.97 N 613080.55 E 5919411.06 N 613081.13 E 5919410.21 N 613081.49 E 5919409.58 N 613081.51 E 5919408.96 N 613081.21 E 5919408.29 N 613080.69 E 5919407.85 N 613079.90 E 5919407.65 N 613078.86 E 5919407.50 N 613077.62 E 5919407.20 N 613076.34 E 5919406.87 N 613075.81 E 5919406.76 N 613075.98 E 5919406.85 N 613076.29 E 5919407.19 N 613076.78 E 5919407.67 N 613077.16 E 5919408.28 N 613077.36 E 5919409.17 N 613077.64 E 5919410.27 N 613077.91 E 5919411.93 N 613078.17 E 5919413.99 N 613078.38 E 5919415.95 N 613078.47 E 5919417.83 N 613078.69 E 5919419.47 N 613079.40 E 5919419.01 N 613079.71 E 5919418.17 N 613080.01 E 5919417.36 N 613080.48 E 5919416.81 N 613081.00 E 5919416.35 N 613081.72 E 5919416.04 N 613082.65 E 5919415.63 N -1.57 5919415.34 N -1.08 5919414.93 N -0.58 5919414.60 N 0.10 5919414.43 N 0.95 Total E &P Dogleg Vertical Rate Section Comment plooft) -7.21 0.818 -2.09 0.307 -1.97 0.148 -1.57 0.176 -1.08 0.305 -0.58 0.213 0.10 0.170 0.95 0.270 1.76 0.154 2.53 0.208 3.36 0.207 4.35 0.776 4.92 0.214 4.91 0.117 4.66 0.272 4.10 0.256 3.49 0.212 2.88 0.149 1.99 0.182 0.93 0.556 -0.57 0.184 -2.37 0.079 -4.03 0.139 -5.69 0.598 -7.44 0.397 -7.24 0.165 -6.73 0.208 -6.34 0.090 -6.19 0.189 -6.23 0.158 -6.51 613084.54E 0.037 -7.27 613084.86E 0.741 -7.21 613084.51E 0.120 -6.68 613084.09E 0.102 -6.17 613083.65E 0.128 -5.77 • 0 11 March, 2004 - 10:09 Page 3 of 5 DrlllQuest 3.03.06.002 Halliburton Sperry -Sun Survey Report for NPRA (Caribou East) - Caribou 26 -11 #1 Your Ref. API 502792000900 Job No. AKMW2837527, Surveyed: 11 February, 2004 Western North Slope, Measured Dogleg True Sub -Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) -5.50 5919414.99 N (ft) (ft) (ft) (ft) 7296.41 0.310 316.860 7121.37 7295.84 9.89 N 4.22 W 7390.78 0.250 300.200 7215.74 7390.21 10.18 N 4.58 W 7485.45 0.370 308.200 7310.41 7484.88 10.48 N 5.00 W 7580.60 0.310 327.260 7405.56 7580.03 10.88 N 5.38 W 7678.53 0.350 359.830 7503.49 7677.96 11.40 N 5.52 W 7774.48 0.310 68.010 7599.43 7773.90 11.79 N 5.28 W 7869.46 0.590 109.450 7694.41 7868.88 11.73 N 4.58 W 7964.88 0.450 96.850 7789.83 7964.30 11.52 N 3.75 W 8059.26 0.500 69.160 7884.20 8058.67 11.62 N 2.99 W 8155.10 0.570 66.700 7980.04 8154.51 11.96 N 2.16 W 8249.09 0.170 90.820 8074.03 8248.50 12.14 N 1.60 W 8344.16 0.170 126.480 8169.10 8343.57 12.06 N 1.34 W 8439.10 0.260 94.330 8264.04 8438.51 11.96 N 1.01 W 8534.84 0.250 98.410 8359.78 8534.25 11.91 N 0.59 W 8629.81 0.330 80.720 8454.75 8629.22 11.92 N 0.12 W 8725.06 0.500 65.090 8549.99 8724.46 12.14 N 0.53 E 8820.00 0.660 54.980 8644.93 8819.40 12.63 N 1.36 E 8914.67 0.690 61.820 8739.59 8914.06 13.21 N 2.31 E 9009.27 0.770 58.860 8834.18 9008.65 13.81 N 3.35 E 9103.60 0.720 55.760 8928.51 9102.98 14.47 N 4.38 E 9198.27 0.750 54.770 9023.17 9197.64 15.16 N 5.38 E 9291.82 0.720 52.910 9116.71 9291.18 15.87 N 6.35 E ` 9362.00 0.720 52.910 9186.88 9361.35 16.40 N 7.05 E Global Coordinates Dogleg Vertical Northings Eastings Rate 0.434 (ft) (ft) pi 00ft) 0.189 5919414.71 N 613082.78 E 0.152 -5.50 5919414.99 N 613082.42 E 0.107 -5.53 5919415.28 N 613082.00 E 0.134 -5.52 5919415.68 N 613081.61 E 0.134 -5.62 5919416.20 N 613081.46 E 0.193 -5.96 5919416.59 N 613081.69 E 0.387 -6.41 5919416.54 N 613082.39 E 0.434 -6.77 5919416.34 N 613083.23 E 0.189 -7.09 5919416.46 N 613083.98 E 0.246 -7.62 5919416.80 N 613084.81 E 0.077 -8.38 5919417.00 N 613085.37 E 0.448 -8.87 5919416.91 N 613085.63 E 0.110 -8.95 5919416.82 N 613085.96 E 0.155 -9.06 5919416.78 N 613086.38 E 0.022 -9.27 5919416.80 N 613086.86 E 0.125 -9.56 5919417.03 N 613087.50 E 0.213 -10.12 5919417.53 N 613088.32 E 0.199 -11.00 5919418.13 N 613089.26 E 0.091 -12.03 5919418.74 N 613090.29 E 0.093 -13.13 5919419.42 N 613091.32 E 0.068 -14.27 5919420.12 N 613092.30 E 0.034 -15.42 5919420.84 N 613093.26 E 0.041 -16.56 5919421.39 N 613093.96 E - ' 0.000 -17.41 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. " Vertical depths are relative to RKB@ 174.47' MSL. Northings and Eastings are relative to 1373' FSL, 1589' FWL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 5. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 1373' FSL, 1589' FWL and calculated along an Azimuth of 216.130° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9362.00ft., The Bottom Hole Displacement is 17.86ft., in the Direction of 23.270° (True). Projected Survey Total E &P Section Comment 0 Ol 11 March, 2004 - 10 :09 Page 4 of 5 DrillQuest 3.03.06.002 Halliburton Sperry -Sun Survey Report for NPRA (Caribou East) - Caribou 26 -11 #1 Your Ref: API 502792000900 Job No. AKMW2837527, Surveyed: 11 February, 2004 Western North Slope, Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9362.00 9361.35 16.40 N 7.05 E Projected Survey CoTeMatePs From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 9362.00 9361.35 Survey Tool Description MWD Magnetic Total E &P • i 11 March, 2004 - 10:09 Page 5 of 5 DrillQuest 3.03.06.002 Jan 19 04 09:46a T0& E &P USA, INC TOTAL E &P USA, INC. (9010 743 -0979 GSR/ALSK/022 /04 To AOGCC Name Mr. Tom Maunder Fax Number 907- 276 -7542 Phone Number ............................................................................................... From ............................... TOTAL E &P USA, INC. Name Jim Rose Fax Number (907) 743 -0979 Phone Number (907) 743 -0970 E -Mai! Date 1/19/04 Numberof pages 2 (including cover) .. ... ............... ............................... .......... Sub'ect Caribou 26 -11 # 1 Operationai Report .............................................. ............................... \/\fe.'tk RepA P. i X co RECENE .te TOTAL 4300 B Street, Suite 303, Anchorage, Alaska 99503 Tel: (907) 743 -0970, Fax: (907) 743 -0979 Jan 19 04 09:46a T0# E &P USA, INC [90 743 -0979 p.2 TOTAL E &P USA Inc. Caribou 26 -11 # 1 TOTA.L.. Re ort No 1 Report Date:1 /19104 CONFIDENTIAL Well Information API No: 50- 279 -20009 AOGCC Permit No: 203 -196 Lease SN AA- 084170 Location: Sec 26, Twp 1 ON, Rge 5E, U.M., 3691 FEL, 1373 FSL Mud Wt Depth Date (ppg) (ft) Operation 1/11/2004 Rig camp in place and operating. Rig components starting to arrive. Rig camp in place and operating. Substructure spotted, 2 pit modules in 1/12/2004 place. 1/13/2004 Camp annex is installed and operating. Spot additional rig components. Continue rig construction. String tugger, tong etc lines in derrick. Install 1/14/2004 standpipe in derrick. Pull wires and hook up lines. Continue rig construction. Install crown section, bridal line and blocks. Spot 1/15/2004 remaining pit modules. Start spoting pumps and generators. Spot fuel tank, set up motors, boiler, and hot well. Install wire tray on SCR. 1/16/2004 Warm up pump room. String drilling line and install stabbing board. Prep to raise derrick. Hook up mud lines in pits. Raise derrick and pin to A 1/17/2004 legs. Start installing windwalls 1/18/2004 Install windwalls. Raise and pin substructure. Install topdrive in derrick. Projected Spud Date: 2/25/2004 Fax on Mondays to: Stan Porhola at the BLM @ 907 - 267 -1304 Tom Maunder at the AOGCC @ 907- 276 -7542 Jan 28 04 10:56a TOT(& E &P USA, INC TOTAL E &P USA, INC. To State of Alaska Name Stan Porhola, BLM Tom Maunder, AOGCC Fax Number (907) 267 -1304 (907) 276 -7542 Phone Number (907) 743 -0979 GSRIALSK1029104 ............................................................................................... From ............................... TOTAL E &P USA, INC. Name Jean -Yves Bellanger Fax Number (907) 743 -0979 Phone Number (907) 743 -0970 E -Mai! Jean -yves, bellanger @total.com ............................................................................................... Date ............................... January 28 1h , 2004 Number of pages 2 ............................................................................................... ............................... Subject Caribou 26 -11 #1 weekly report ............................................................................................... ............................... Dear Sirs Please find attached the weekly report nurhbjtwofothe well Caribou 26 -11 #1. Best regards Jean -Yves Bellanger Drilling Engineer Total USA - Alaska P.1 X CT) Li- " JAN 2 8 6b MII RO UGsGong.GmMion mftw , . , TOTAL 4300 B Street, Suite 303, Anchorage, Alaska 99503 Tel: (907) 743 -0970, Fax: (907) 743 -0979 Jan 28 04 10:56a TOS ELLP USA, INC [907743 -0979 p.2 ECEI1/Ep JA t„ • � �. l�Cl�iirNBillpr, TOTAL. E &P USA Inc. ll;� Caribou 26 -11 # 1 TOTAL Re ort No 2 Report Date :1126104 CONFIDENTIAL Well Information API No: 50- 279 -20009 AOGCC Permit No: 203 -196 Lease SN AA- 084170 Location: Sec 26, Twp 1ON, R e 5E, U. M., 3691 FEL, 1373 FSL Mud Wt Depth Date (p ) (ft) Operation Hang off top drive. Set degasser and choke unit. Install windwalls on sub, 1/1912004 front of structure, front of rig floor and back windwall oposite to driller.Set iron roughneck. Hook up cooling lines. Continue to install remaining windwalls. Works on lines in pump room. Rig up floor stair tower. Work on Canrig top drive. Hang Canrig cable rack. Continue 1/20/2004 to rig up mud tanks. Rig up and secure Canrig supply cables. Install BOP platform in sub. Install mud logger and mud engineer units. Continue to work in pits. Hook up steam to rig floor. Set pipe handler. Lay 1/21/2004 down Canrig top drive assy and work on same. Continue to rig up mud tanks and rig supply lines. Install cement silos Install top drive shims on rail. Working in pits. Inatall light on rig floor. Make 11122!2004 up and hang stand pipe. Rig up mud tanks. Install diverter head assy. Work on high pressure line. Istall tugger man ridder on rig floor. Install ladder in derrick. Work on high pressure lines in substructure. Hang kelly hose and 112312004 connect to stand pipe. Hang rig tongs. Hand ans secure cement cement stand pipe. Install casing stabbing board. HOist top drive blower hose to rig floor and warm up. Hook up iron roughneck. Set back BOP in cellar. Rig up cement line on rig 1/24/2004 floor. Rig up BOP platform in substructure. Work on de- watering unit. Spot in Work on rig floor. Hang kelly and blower hoses. Connect to top drive. Install bleed off line. Rig up rig floor equipment. Bring 75 joints of 9 5/8" casing, 96 joints of 4" HT38 DP's and BHA. Center top drive over rotary, Work on top 1/25/2004 drive rotary brake. Change lower IBOP to HT38 connection. Nipple up diverter spool and 21 114" Hydril diverter. Berm liquid mud products area. Projected Spud Date: 1/2812004 Fax on Mondays to: Stan Porhola at the BLM @ 907 - 267 -1304 Tom Maunder at the AOGCC @ 907- 276 -7542 ECEI1/Ep JA t„ • � �. l�Cl�iirNBillpr, Feb 02 04 05:38p TOTO E &P U5fl, INC [9071043 - 0979 P. 1 TOTAL 4E&P USA, INC. GSRIALSK/043104 To State of Alaska Name Stan Porhola, BLM Tom Maunder, AOGCC Fax Number (907) 267 -1304 (907) 276 -7542 Phone Number ........... ............................... ..................................................... ............................... From TOTAL E &P USA, INC. Name Jean -Yves Bellanger Fax Number (907) 743 -0979 Phone Number (907) 743 -0970 X Co E -Mai! Jean- yves.bellanger @total.com .......... ......................... .............................. ............................... .... !` Date . F . e. br . u .. a. ry 2 "d , 2004 Number of pages 2 ............................................................................................... ............................... Subject Caribou 26 -11 #1 weekly report N 0 3 ............................................................................................... ............................... Dear Sirs r Please find attached the weekly repo N °3 ;fhe well Caribou 26 -11 #1. Please note that the well Caribou 2641_41"has been spudded on Thursday January 29`", 2004 at 01 h00arn and the 9 5/8" casing has been set and cemented @ 2236ft. Best regards I r Jean -Yves Bellanger Drilling Engineer Total USA - Alaska 14N_ - ToTAt- 4300 8 Street, Suite 303, Anchorage, Alaska 99503 Tel: (907) 743 -0970, Fax: (907) 743 -0979 RECEIVED FEB 0 3 2004 Atil wQ1&GetGa 1 Aid Feb 02 04 05:38p TOT *E&P USA, INC (907)1643 -0979 p.2 C E I VEE D FEB o 3 ?i}U -. Ad! 1 4 UPWFW TOTAL E &P USA Inc. Caribou 26 -11 # 1 ToT,*Lt-. Re ort No 3 Report Date:?/02104 CONFIDENTIAL Well Informatio API No: 50- 279 -20009 AOGCC Permit No: 203 -196 Lease SN AA- 084170 Location: Sec 26, Twp 10N, R e 5E, U.M., 3691 FEL, 1373 FSL Mud Wt Depth Date ft Operation Continue to install diverter assy and bell nipple. Install diverter lines. Berm 1/26/2004 liquid mud products storage area. R/U safety bell ringer for crown. Hook up gauges and flow line. Hook up fill up line. Berm for mud storage tanks. Install mud storage tanks into berm. Function test diverter OK. Mix spud mud. P/U 4" HT 38 DP's. Work on drawworks oiler pump. Connect and secure 100 ft diverter line. Test safety equipment witnessed by State Representative, 1/27/2004 Took 49 seconds to close in diverter and 14 seconds to open deverter valve. Accumulator pressure dropped from 2700 psi to 2000 psi. Took 2 mn 26 s to pressure up accumulator to 2960 psi. Prepare to P/U BHA Continue mixing mud and install dies on slips. P1U non mag DC and Jar in derrick. P/U bit and one stand HWDP. Work on tong load cell and EZ torque. 1/2812004 M/U assy with TDS. Break circulation and fill up hole wlmud. Pressure test mud line to 4000 psi CK. Shear mud twice 600 bbls. Calibrate MWD and P/U mud motor. Center top drive over the well. Change shaker screens. 1/29/2004 Change screens. Spud the well in at 01 h00 am. Drilli 1 21/4" hale to 224ft POOH to P/U new BHA. Log down w/MWD from 147ft to 224ft. Perform Drilling 12 1/4" well section from 606ft to 1397ft taking survey at each 1/30/2004 connection. Wiper trip to 337 ft while working on dewatering unit and replacing auger gear box. Hole in good condition. RIH to 1397ft. Drilling 12 1/4" hole from 1293ft to 1743ft. Survey at each connection. Drilling 12 114" hole from 1743ft to 2218ft. Stop drilling for correlation with 1/31/2004 Inigok #t1. Drilling 12 1/4" hole to 9 5/8" casing point. POOH to 1638ft w/h 35 Klbs overpull and swabbing. Get back to bottom and circulate bottoms up. Monitor well OK. POOH and break down BHA. Lay down BHA and download LW D data. Lay down mud motor. R/U 9 518" 2/1/2004 caisng equipment. Pre job safety meeting. Run 9 5/8" casing to 2236ft. Port collar at 881 ft. Circulate bottom's up and hook up cement line. Pre job safety meeting and circulate hole while reciprocating string. Main events Spud in date on Thursday 29th, 2004 @ 01 h00 am. 9 5/8" Casing set and cement @ 2236ft. Cemented up to surface Fax on Mondays to: Stan Porhola at the BLM @ 907 - 267 -1304 Tom Maunder at the AOGCC @ 907- 276 -7542 C E I VEE D FEB o 3 ?i}U -. Ad! 1 4 UPWFW Feb 08 04 08:08a TOIL E &P USR, INC (907 #743 -0979 p.1 TOTAL E &P USA, INC. GswALStv050104 To State of Alaska Name Stan Porhola, BLM Tom Maunder, AOGCC CT Fax Number (907) 267 -1304 (907) 276 -7542 Phone Number .................. ............................... ................... ..............................loll ....... I ........ ........ From TOTAL E &P USA, INC. Name Jean -Yves Bellanger {��' _ t Fax Number (907) 743 -0979 Phone Number (907) 743 -0970 E-Ma Jean- yves.bellanger @total.com .............................................................................................................................. Date February 9th, 2004 Number of pages 2 .. .......................... ............................... ................................... ............................... Subiect Caribou 26 -11 #1 weekly report N 0 4 Dear Sirs Please find attached the weekly port N °4 f r the well Caribou 26 -11 #1. After having nippled up and pres re tested uccefully the BOP stack to 250 and 5000 psi , the 8'/2" drilling resume 5 Two LOT's were performed at 2254ft and 2577ft giving respectively 14.2 ppg and 13.4 ppg EMW. Actual rig status at 6h00 am on Feb 9 2004 is drilling 8 %2" hole section at 6405ft. Best regards 1 Jean -Yves Bellanger Drilling Engineer Total USA - Alaska W t RECEIVED FER ftkaucw(,� TOTAL 4300 B Street, Suite 303, Anchorage, Alaska 99503 Tel: (907) 743 -0970, Fax: (907) 743 -0979 Feb 09 04 08:08a T0# E &P USn, INC (907743 -0979 p.2 TOTAL E &P USA Inc. Caribou 26 -11 # 1 TOTAL Report No 4 Report Date:2109104 CONFIDENTIAL We ll information API No: 50.279 -20009 AOGCC Permit No: 203 -196 Lease SN AA- 084170 Location: Sec 26, Twp 1 DN, R e 5E, U.M., 3691 FEL, 1373 FSL Mud Wt Depth Date (ft Operation Conditioning mud and circulate. Line up Halliburton line and pressure test to 3000 psi. Cement 9 518" casing w/h 50 bbls Alpha spacer + 200 bbls lead slurry 10.6 ppg (Permafrost L) + 65 bbls tail slurry 15.6 ppg (premium 2/2/2004 9.7 2243 cement). Displace w /141 bbls. WOC then lay down casing equipment and landing joint. N/U diverter line and annular preventer. Stab well head + N/U DSA and BOP stack. Pressure test Head seal to 1000 psi for 15 mn. Work on kill and choke lines in progress. Continue nippling up BOP, hook up Kill lines 1 & 2. Pressure test annular to 2/3/2004 9.35 2243 250 and 2500 psi. Pressure test upper PR, lower PR, inside and outside choke valves (HCR and manual), choke manifold to 250 and 5000 psi. Pressure test upper and lower ISOP's plus floor vavies to 250 and 5000 psi. 214/2004 9.35 2243 Pressure test Koomey Unit. Set wear bushing. Pick up 160 joints of 4" HT38 DP's. Continue picking up DP's. Pick up 8 112" BHA and RIH to TOC at 2070ft. DOC from 2070 to 2144ft. Pressure test casing to 2600 psi for 160K. DOC from 2/512004 9.5 2405 2144 to 2243ft. Drill 8 112" hole from 2243 to 2254ft. Perform LOT 41. EMW= 14.2ppg. Drill ahead from 2254 to 2405ft. 2/612004 9.45 3640 Continue drilling 8 1/2" hole from 2405 to 2577ft. Perform LOT #2. EMW= 13.4 ppg. Drill ahead in 8112" from 2577 to 3640ft. Shut down due to failure on electrical generator #2. Drill ahead from 3640ft to 2/7/2004 9.3 4593 4593ft. Circulate bottom's up and trip out to casing shoe. Tight spots 3436 - 3147 then 2856 to 2240ft. Circulate bottom's up at casing shoe. RIH from 2240 to 4593ft. Change out hydraulic hose on top drive. Unplug with 2/8/2004 9.4 5942 waterjet two flow lines. Dril I ahead 8 112" hole from 4593ft to 5942 back ream and wash each connection. Average ECD = 10.1 ppg Main events LOT #1 @ 2254 gave EMW =14.2ppg. LOT #2 gave EMW 13.4 ppg. Pressure test the 9 518" casing to 2600 psi. Drilling 8 1/2" hole section from 2243ft to 5942ft. Actual rig status At 6h00 am Monday Feb 9th : Drilling ahead 8 1/2" hole section at 6405ft. Fax on Mondays to: Stan Porhola at the BLM @ 907 - 267 -1304 Tom Maunder at the AOGCC @ 907 - 276 -7542 4 Feb 16 04 08:58a TOTAL E &P USA, INC 0 TOTAL E &P USA, INC. To State of Alaska Name Stan Porhola, BLM Tom Maunder, AOGCC Fax Number (907) 267 -1304 (907) 276 -7542 Phone Number (907) 743 -0979 : C jC / , GSRIALSK1058 /04 P.1 X C� L� ............................................................................................... From ............................... TOTAL E &P USA, INC. Name Jean -Yves Bellanger Fax Number (907) 743 -0979 Phone Number (907) 743 -0970 E -mail Jean- yves.bellanger @total.com ............................................................................................... Date ............................... February 16th, 2004 Number of pages 2 ............................................................................................... ............................... Subiect Caribou 26 -11 #1 weekly report N °5 ............................................................................................... ............................... Dear Sirs Please find attached the weekly r 61t�h200 or the we* Caribou 26-11 #1. TD was reached @ 9362' on Feb (report N14). A ctual rig status at 6h00 am on Feb 16 2004: Prepare to RIiper trip before resuming logging operations. CMR tool that got stuck @ 3170' was successfully fished out. Best regards l � y Jean -Yves Bellanger Drilling Engineer Total USA - Alaska �eFit,� r111 i " 4300 B Street, Suite 303, Anchorage, Alaska 99503 TOTAL. Tel: (907) 743 -0970, Fax: (907) 743 -0979 Feb 16 04 08:58a T6 E&P USR, INC (907) 743 -0979 p.2 4 6 TOTAL E &P USA Inc. Caribou 26 -11 # 1 Report No 5 Report Date:2/16104 CONFIDENTIAL Well Information API No: 50- 279 -20009 AOGCC Permit No: 203 -196 Lease SN AA- 084170 Location: Sec 26, Twp 1 ON, Rge 5E, U.M., 3691 FEL, 1373 FSL Mud Wt Depth Date pg) (ft) Operation 2/912004 10 7127 Drill ahead from 5942' to 6699'. Wiper trip to 4306' w/o problems. Drill ahead 8 1/2" hole section from 5942" to 7127'. 2/10/2004 10 8889 Drill 8 112" hole section from 7127' to 8889' Average ECD = 10.5 pppg Drill from 8889' to 8984'. Circulate bottom's up for sampling. Drill from 8984' to 9004'. Circulate bottom's up for sampling. Drill from 9004' to 9072'. 2111/2004 10.2 9362 Circulate bottom's up for sampling. Drill from 9072' to 9362'. Circulate bottom's up and trip out to surface. Download LWD and lay down same. Continue laying down SHA.Retrieve wear bushing. BOPE pressure tests to 2/1212004 i0.2 9362 250 psi and 5000 psi. Hydrill to 3500 psi. Set wear bushing. TIH to 2176'. Ream down to 3320'. TIH to 5920'. Ream 80 to 6100'. Circulate bottom's up. Lot of clay cutting over shakers. TIH to 7789'. PfU top drive. Wash and ream from 7789' to TD @ 9362'. Circulate bottom's up. Wiper trip 2/13/2004 10.4 9362 to 6967'. Max overpull 30KIbs @ 8676. Trip back in hole to TD. Weight up mud to 10.4 ppg. POOH to 2650' in progress. POOH BHA to surface. Stand back same in derrick. Rig up Schlumberger for 2/1412004 10.45 9362 logging. RIH run #1 w/h AIT - DSI - Density - Neutron - NGT. Log open hole from 9317' to 95'. High resolution mode from 9222' to 8780'. RIH run #2 w/h CMR - NGS. Log open hole from 9300' to 8870' and from 8000' to 7000'. Continue POOH toolstring. 1000lbs overpull @ 3170' (bottom of tool). Log toolstring got stuck. Work on fish w/o success. Prepare for cut and thread 2/15/2004 10.45 9362 fishing. RIH fishing BHA w/ 5 314" overhot dressed w/ 3 3 /8" grapple. Strip over wire line w /overshot. Circulate bottom's up. Strip over fish. Work pipe to free tool w/ 10KIbs. Work on wire line to latch tool in grapple with 4400 lbs. R/U circulating head. Main events Well drilled to TD @ 9362' (report N14). E- Logging in progress. Actual rig status At 6h00 am Monday Feb 16th. Fished out CMR tool. Prepare to run in hole w /BHA for wiper trip. Fax on Mondays to: Stan Porhola at the BLM @ 907 - 267 -1304 Tom Maunder at the AOGCC @ 907 - 275 -7542 Feb 23 04 08:43a TOT E &P USA, INC (90743 -0979 P.1 . y TOTAL E &P USA, INC. GSRIALSK1063 /04 To State of Alaska Name St P ©rhola, BLM Tom Maunder, AOGCC C Fax Number (907) 267 -1304 (907) 276 -7542 Phone Number From TOTAL E &P USA, INC. Name Jean -Yves Bellanger Fax Number (907) 743 -0979 Phone Number (997) 743 - 0970 E - Maid Jean-yves.bellanger@total.com 31 total.com ............................................................................................... Date ............................... February 23rd, 20Q4 Number of pages 2 ................... . o6 .......,........... ............................... Su bi Caribou 26 -11 #1 weekly report N ............................................................................................... ............................... Dear Sirs Please find attached the weekly report 0 6 for4he well Caribou 26 -11 #1 P Main events of the week: Completed logg9 g program ram conveyed ro w/h MDT on DP's Y MSCT (side wall coring) recovered 49 samples, VSP. Started P&A. CP #1 from 9362' to 8890' CP #2 from 7988' to 7670' and from 7670' to 7373' (Tag w /h20 Klbs) Actual rig status at 6h00 am on Feb 23rd, 2004: Setting the 9 518" Cement Retainer Program: Step rate test then injection of mud liquid wastes, complete P &A. Best regards Jean -Yves Bellanger Drilling Engineer Total USA - Alaska TOTAL 4300 B Street, Suite 303, Anchorage, Alaska 99503 Tel: (907) 743 -0970, Fax: (907) 743 -0979 - r~w I ' i rEg v V4 ARs k oii & ;as 0'"3 C : >r 4;'issic�n Feb 23 04 08:43a TOT($ E &P USA, INC (907) 743 -0979 p.2 9 V -, a- 2 S Q r� *0 1P QS -� D O - Z13 *$1 S '�wv S TOTAL E &P USA Inc. Caribou 26 -11 # 1 3Q'TAL Repo No 6 ?SRgrt Date:2nW04 CONFIDENTIAL Well information API No: 50- 279 -20009 AOGCC Permit No: 203 -196 Lease SN AA- 084170 Location: Sac 26, T 10N, R e 5E. U.M., 3691 FEL, 1373 FSL Mud Wt Depth Date Operation Attempt to shear circulation disc w/o Success. Pull on wire w/ T bar, POOH Eaine. POOH fishing BHA and lay down fish. MN clean out BHA and RIH to 2/16/2004 10.4 9362 3123'. Ream from 3123' to 3410'. R)H to 6010'. Break circulation. RIH to 9242'. Wash down fill to TO @ 9362'. POOH in progress POOH BHA. P/U MOT toot on DP's. Circulate BIQ @ casing shoe. Conveyed MDT to 7286'. M/U side entry sub. RIH wireline. Land in wet connector. 2/17/2004 10.4 8362 Perform MDT pressure tests - 17 stations done. POOH to side entry sub. Unlatch wet connector and POOH a -line. POOH w/MOT in progress. POOH MDT to surface. RIH w /BHA. Wash and ream from 3121' to 3410'. RIH and break circulation @ 6100 RIH and wash and ream from 9148' to 211aM004 10.45 9382 9362'. Circulate bottom's up. Pumped Hi vis sweep aroud. POOH to surface. R/U Rotary Side Wall Coring (MSCT) RIH and perform run #4 as planed. Took 23 samples, recovered 22. RIH w /MSCT on run #5. Took 27 cores from 91571 7202'. No recovery, found bent push rod. Replace push rod 2/19!2004 10.45 9362 and run back in hole run #6 w1MSCT. Took 27 samples w1100% recovery. RIH run 07 w/VSP /GR to 2000'. Perform test Abroseis and quality check. Perform VSP from 9269' to 5100'. Continue VSP performing check shots from 4900' to 900'. POOH run #7 and lay down wireline equipment. Service 2120120D4 10.45 9362 top drive, change out hydraulic service loop, RJU tubing equipment. P!U 20 joints 2 VVI tubing and M/U X -Over. Change handling equipment. RIH w/h tubing on DP's. Break circulation @ 760' and 3600'. RIH to bottom wash last stand. Circulate bottom's up and rig up cementing lines and pressure test to 2500psi. Mix and pump 10bbis fresh water and 41 bbls 15.8ppg slurry. Displace w1h 2bbls fresh water and 88.5bbis mud. POOH to 8890' and circulate bottom's up (contaminated cement/mud). Pump 66bbls 2121/20D4 10.4 g362 - fs 6`ppg heavy mud and spot on TOG. POOH 7988' circulate 1.5 bottom's up. Line up cement Imes and pressure test to 2500psi. Pump 10 bbls fresh water and 25.5bbls 15.8ppg slurry. Displace w/h 21bbls fresh water and 76.80bls mud. POOH to 7670'. Circulate while waiting on cement. Line up cement lines and continue to circulate. Pump second stage of Cement plug #2. Pumped 10bbls fresh wa ter + 24.2bbis 15.8ppg slurry. Displace w /2bbis fresh water and 73bbls mud. 2122/2004 10.45 g3g2 POOH to 7382 Circulate bottom's up, minor cement returns to surface. POOH to surface. Lay down 2718" tubing. Lay down HWP's + DC's. RIH tight BHA to TOG. Found @ 7373'. Weigt test wil?Ofts OK. Circulate hole clean, rack back 24 stands - andMOH laying down excess of DP's. Main events Complete logging operations. P&A in progress. Set CP #1 and CP #2. Actual rig status At 6h00 am Monday Feb 23rd. RiH w/h Cement retainer Fax on Mondays to; Stan Porhola at the BLM @ 907 - 267 -1304 Tom Maunder at the AOGCC @ 907 - 276.7542 V -, a- 2 S Q r� *0 1P QS -� D O - Z13 *$1 S '�wv S Mar i 01 04 09:44a TOTAL E &P USR, INC (907) 743 -0979 P,1 .lean -Yves Bellanger Fax Number (907) 743 -0979 t TOTAL E &P USA, INC. (907) 743 -0970 E -Mail Jean- yves.bellanger @total.com GSR/ALSK/067I04 1 2004 .............................................. ............................... To State of Alaska 2 _0 Name Stan Porhola, BLM Tom Maunder, AOGCC Fax Number (907) 267 -1304 (907) 276 -7542 Phone Number ......... .. . ........ . ........ From . ............................................................... . ...... I .............. ........... TOTAL E&P USA, INC. Name .lean -Yves Bellanger Fax Number (907) 743 -0979 Phone Number (907) 743 -0970 E -Mail Jean- yves.bellanger @total.com Date .................... March 1 2004 .............................................. ............................... Number of pages 2 .. Caribou 26 -11 #1 weekly report N°...................•.................... ............................... Su Dear Sirs Please find attached the weekly r ort N °7 f r the well Caribou 26 -11 #1 Main events of the week: Compl ted P &A per approved program. End of well operations on Febr , 2004 at 12h00pm. Cement retainer set @ 2181' CP #3 from 2236'— 2362' in open hole and 2236' — 2036' in cased hole. CP #4 from 184' to 3' below ground level. Actual rig status at 6h00 am on March 1 2004: Continue rigging down and prepare for rig demobilization in Deadhorse. Best regards � , Jean -Yves Bellanger Drilling Engineer Total USA - Alaska ToT^L 4300 8 Street, Suite 303, Anchorage, Alaska 99503 Tel: (907) 743 -0970, Fax: (907) 743 -0979 RECEIVED LIAR 0 � 20104 AI WA QII & Gee G". Wr*jW A"aml* Mar 01 04 09:44a A TOTAL E &P USA, INC (907) 743 -0979 TOTAL. E&P USA Inc. Caribou 26 -11 # 1 T OTAL Report No 7 Report Date :3!01104 CONFIDENTIAL (OAR 0 Well information API No: 50- 279 -20009 AOGCC Permit No: 203 -196 Lease SN AA- 084170 Location: Sec 26, Twp ION, R e 5E U.M., 3691 FEL, 1373 F SL And mud Wt Depth Date ( ft Operation Continue POOH laying down DP's. WU and RIH EZ drill Squeeze Packer @ 2181'. Pressure drop measurement: 18PM = 75psi, 28PM = 100psi, 38PM = 150psi, 4BPM = 225psi. Pressure test annulus to 1500psi, Perform injectivity test @ 0.5BPM. Pressure build to 1020psi then broke to 400psi 2123/2004 10.45 9362 stabilized. Increse to 1 BPM = 420psi, 1.5BPM = 450psi, 2BPM = 480psi, 2.58PM = 490psi, 3BPM = 520psi, 3.5BPM = 560psi. Stop pumping pressure stabilized at 320psi. Perform mud injection after getting Authorities green light. Inject mud at 3.59PM w/h an injecting pressure = 560psi. Pumped in hole 950bbis at 2000 including 50bbls water. 2/2412004 10.4 9362 Clean out liquid mud storage tanks and continue to inject in hole. Total pumped in hole at 2000 = 1772bbis. Spot cement plug #3 from 2236' to 2362' (126' open hole) + 2236' to 2181' cased hole with 13bbls slung 15.8ppg. Displace w/h 2bbls of water and 20.8bbls Of mud. Pressure increase from 320psi to 520psi when cement in the open hole. Sting out from packer. Pump second stage og cement plug #3 2/25/2004 10.4 9362 from 2159' to 2036'(123') w/h 9.3bbls slurry 15.8ppg. Displace w/h 2.5bbis water + 17bbls mud. POOH to 1300' circulate 1.5 bottom's up. Lay down tubular. Pressure test 9 50 casing to 2000psi for 10' OK. Pull pipes to 184'. Spot surface cement plug #4. 15bbis C permafrost slurry 15.6ppg. Got cement returns to surface.FIush down BOPS. Super suck cement from cellar. Lay down cementing lines N/D SOPE, kill line valves, Hydril, BOP rams, mud cross and drilling spool adapter. N/D wellhead. Remove flex hoses and flow line to shaker. Measure TOC at T below ground level (Witnessed by BLM's Representative). End of well operations on the well Caribou 26 -11 #1 at 121100am on 2126/2004 9362 02126/04. Start demobilization of the rig. Rig down stand pipe section, fill up line and hose from cellar. R/D mud pump #2. Remove belt and cover. Cool down boiler #3. Remove chain from rotary table. Lay down kelly hose. Remove liners from pumps. R1D air hoses reel from bridge crane in cellar. R/D bridge crane. Pull liner and swab from pump #1. R/D choke room. Separate Fines between pits 2 &3. Secure derrick for removal of top drive. RID line of Iron Roughneck. Secure top drive and 2/27/2004 disconnect from block. Hang block and slip 120' of line. RID in pits. R/D lines on rig floor, prepare to lay down top drive. Offload 183bbls waste fluids from dewatering unit. R/D floor handling equipment and automatic pick uD and lav down equipment. Slow down steam to Dice shed. Move Section #1. R/D skid 6 section of pipe shed, Remove berm from pipe shed, Transfer 180bbis waste to Rolligons. Install C section support braces in derrick. Clean pits in dewatering unit. Continue to break lines in pit 2128/2004 section. R/D fall arrestors. Slow down brake cooling system. Lay down cooling lines and plug same. Continue cleaning dewatering unit and prepare for moving. R/D second bridge crane. Remove V door. Coil up electric cables from top drive. Secure service loops to top drive. Prepare to lay down C section. Secure dewatering unit for removal. Clean up berms area. Coot down boiler #1. Serviced raising legs for substructure, Prepare BOP scaffolding for transportation. Transfer i80bbls from pits to Rolligons. Remove centrifuge auger. Remove floor plates in choke room and pump room. Remove solids from 212912004 pits #5 and #6. Lay down "C" section, rig down rig floor wind walls. Lay down top drive. Pump excess water from water pits to truck. Remove 4 lights in derrick. Remove centrifuge auger house, poor boy stack and poor boy degasser stairs to injection pits and stair way to floor. Lay over opposite driller side windwall. Main events Complete P &A. Set cement retainer and inject 1772bbis liquid wastes. Set CP #3 and CP #4. End of well operations on February 26th, 2004 at 12h00pm. Actual rig status At 6h00 am Monday March 1st, 2004: continue to rig down rig equipment and move out consumables. Fax on Mondays to: Stan Porhola at the BLM @ 907.267 -1304 Tom Maunder at the AOGCC @ 907.276 -7542 P.2 I. �U61E _Mar 15 04 11:53a TO EaP USFI, INC (907743 -0979 P.1 TOTAL E &P USA, INC. GSRIALSKI073104 To State of Alaska _0 Name Stan Porhola, BLM Tom Maunder, AOGCC Fax Number (907) 267 -1304 (907) 276 -7542 Phone Number ..................... . ................................. From TOTAL E &P USA, INC. .. Name Jean -Yves Bellanger Fax Number (907) 743 -0979 Phone Number (907) 743 -0970 E -Mail Jean- yves.bellanger@a t ............................................................................................... ............................... �J Date March 1 511 2004 Number of pages 2 Subject Caribou 26 -11 ##1 weekly report N °8 Dear Sirs Please find attached the weekly report N 0 8 for the well Caribou 26 -11 #1 Main events of the week: Completed P &A by welding on marker plate. Actual rig status at 6h00 am on March 15 2004: Continue moving out rig equipment to Deadhorse. Best regards Jean -Yves Bellanger Drilling Engineer Total USA - Alaska 1 09 TOTAL 4300 B Street, Suite 303, Anchorage, Alaska 99503 Tel: (907) 743 -0970, Fax: (907) 743 -0979 c� 6�ECEIVED MAR .1.EZD, MiNil Q1&C %ecCw.0 n>worl Slide I.JPG (JPEG Image, 720x540 pixels) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ................... . . . . . . . . . . . . . . . . . . . . . .. . Ao , Pod . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. MUnd.N.W.1' . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . t . . . . . . . . . . . . . CARIBOU 26-11 #1 Well abandonment schematic v • 9 TOTAL HI:' T-TA 1 of 1 3/15/2004 1:59 PM • i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ''`7 DATE: March 11 & 12, 2004 P. I. Supervisor q1+4 FROM: John Crisp, SUBJECT: Surface Plug Petroleum Inspector Total E & P USA Caribou 26 -11 #1 PTD 243 -196 March 11 & 12, 2004: 1 traveled to Total E & P USA 26 -11 #1 Exploratory Drill Site to perform Surface Plug Inspection for well Abandonment. Casing strings were cut off 4' below tundra surface. Conductor & Surface casing has hard cement to surface. The marker plate had all pertinent information bead welded on it before being welded to outermost casing string. I requested all debris such as insulation, cement & wood material be taken out of fill that was used to cover casing strings. In my conversation w/ Drilling Foreman, suggested that ponding on & around casing strings seemed to be more of a problem for Regulatory Agencies as opposed to slight excess of fill on top of casing strings that would subside w/ time. Summary: Surface Plug on Caribou 26 -11 #1 met or exceeded all regulations, report along w/ photos of Location will be forwarded to Supervisor. Attachment: Photos attached for reference. CONFIDENTIAL Surface Plug & Abandonment Caribou 26 -11 #l.doc 0 0 Caribou 26 -11 #1 (Total E &P) Surface Abandonment Inspection Photos from AOGCC Inspector John Crisp March 11 -12, 2004 Casing Cut -off Cement to Surface Marker Plate 0 Caribou 26 -11 #1 Surface P &A Marker Plate Installed Debris in Fill Material Backfill material Caribou 26 -11 #1 Surface P &A 0 Excess material to allow for settlement Mounded MM 12 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 11 : REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic Li Service 6. Permit to Drill Number: 203 -196 7. Well Name: Caribou 26 -11 #1 TOTAL UP USA, Inc. Development ❑ Exploratory ❑✓ 2. Address: 4b. Well Status: Oil Q Gas ❑ WAG ❑ 8. API Number: 4300 B Street, Suite 303, Anchorage, Alaska 99503 GINJ ❑ WINJ ❑ WDSPL ❑ 50- 279 - 20009 -00 3. (Check one box only) 5a. Sundry Number: 5b. Sundry approval date: 9. Field: Initial Dis � or Continuation of Disposal p ❑ E] 304 -005 2/2012004 Wildcat 10 (h)(1) drilling mud, drilling (h)(2) drill rig wash fluids (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids and drill rig domestic waste approved substances (include days Beginning Dates: Ending cement - contaminated drilling water descriptions in block 12) disposal Dates: mud, completion fluids, occurred: formation fluids and any necessary water added. Previous totals 0 0 0 0 0 N/A NIA N/A (bbis): 2004/Q1 1,785 0 0 1,785 2 02/23/04 02/24/04 Caribou 26 -11 #1 YYYY /Q# YYYY /Q# YYYY /Q# T otal E p Re ort is due on the 20th Volume 1,785 0 0 1,785 2 of the month following the final month of the quarter. Ex: (bbis): April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): This well has been plugged and abandoned. No more annular disposal will occur. I hereby certify that the foregoing is true and corre owledge. Signature: Date: L L Printed Jean-Franco! Title: Dril lin g g Mana er Phone 907- 743 -0970 Name: Number: Form 10 -423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate CARIBOU 26 -11 #1 Pre - Injection Step -Rate Test 10 ! Pumped volume ME 3 ME I ME 1 0 F V KINTM 10 n - Mm- Vis : 47 sec 1 BPM 75 psi BPM 150 psi 10 0 CARIBOU 26 -11 #1 is Annular Disposal Injection Record FLOW PRESSURE STROKES TIME DIF TIME Pumped BBL volume total MW ppg Vis REMARKS SPM BPM start finish START STOP INJECTION 02/23/2004 to 02/24/2004 40 3.5 560 510 5000 14:54 17:00 2:06 428 428 10.5 47 Drilling mud 40 3.5 510 510 2340 17:00 200 628 10.3 43 Drilling mud 40 3.5 510 550 832 18:00 71 699 10.2 42 Drilling mud 40 3.5 550 650 320 18:00 27 726 8.3 Rinse Water, 27bbl 40 3.5 600 590 268 18:25 18:42 0:17 23 749 8.3 Rinse Water, 23 bbl 401 3.5 610 510 723 18:46 19:05 0:19 62 811 10 43 Drilling mud 40 3.5 550 550 580 19:09 19:25 0:16 50 861 10 43 Drilling mud 40 3.5 550 550 470 20:25 20:35 0:10 40 901 10 43 Drilling mud 40 3.5 550 550 117 21:08 21:13 0:05 10 911 10 43 Drilling mud 40 3.5 550 550 117 21:43 21:46 0:03 10 921 10 43 Drilling mud 40 3.5 550 550 224 22:16 22:19 0:03 19 940 10 43 Drilling mud 40 3.5 550 550 117 22:51 22:54 0:03 10 950 9.8 381Drilling mud 401 3.5 560 550 117 23:30 23:33 0:03 10 960 9.843 Drilling mud 40 3.5 560 550 117 0:03 0:06 0:03 10 970 9.9 44 Drilling mud 40 3.5 560 550 117 0:30 0:33 0:03 10 980 9.9 44 Drilling mud 40 3.5 570 560 117 1:00 1:03 0:03 10 990 9.9 44 Drilling mud 40 3.5 580 570 117 1:30 1:33 0:03 10 1000 9.9 37 Drilling mud 40 3.5 580 620 235 2:00 2:15 0:15 20 1020 8.3 Water 40 3.5 620 630 117 2:16 2:19 0:03 10 1030 9.9 391 Drilling mud 401 3.5 630 595 117 2:37 2:40 0:03 10 1040 9.9 42 Drilling mud 40 3.5 580 560 117 2:57 3:00 0:03 10 1050 9.9 42 Drilling mud 40 3.5 560 560 117 3:30 3:33 0:03 10 1060 9.9 42 Drilling mud 40 3.5 560 570 117 4:00 4:03 0:03 10 1070 9.9 40 Drilling mud 40 3.5 570 580 117 4:30 4:33 0:03 10 1080 9.9 43 Drilling mud 40 3.5 580 585 117 5:00 5:03 0:03 10 1090 9.9 43 Drilling mud 40 3.5 580 580 117 5:40 5:44 0:04 10 1100 9.9 43 Drilling mud 401 3.5 580 580 117 6:00 6:03 0:03 10 1110 9.9 43 Drilling mud 40 3.5 580 570 117 6:31 6:34 0:03 10 1120 9.9 43 Drilling mud 40 3.5 570 570 117 7:00 7:03 0:03 10 1130 9.9 41 Drilling mud 40 3.5 570 570 117 7:30 7:33 0:03 10 1140 9.9 41 - Drilling mud 40 3.5 570 580 117 8:00 8:03 0:03 10 1150 9.9 37 Drilling mud 40 3.5 570 570 117 8:30 8:35 0:05 10 1160 9.9 39 Drilling mud 40 3.5 570 570 117 9:03 9:06 0:03 10 1170 9.8 42 Drilling mud 401 3.5 570 580 117 9:30 9:33 0:03 10 1180 9.3 37 cement rinseate 40 3.5 5801 600 117 10:00 10:03 0:03 10 1190 9.3 37 cement rinseate 40 3.5 600 625 117 10:34 10:37 0:03 10 1200 9.3 37 cement rinseate 40 3.5 625 625 353 10:55 11:04 0:09 30 1231 9.3 37 cement rinseate 40 3.5 625 625 673 11:30 11:50 0:20 58 1288 9.3 37 cement rinseate 40 3.5 600 650 370 12:00 12:10 0:10 32 1320 8.3 water 28 2.3 650 650 220 12:11 12:20 0:09 19 1339 8.3 water 281 2.3 625 600 1148 12:20 13:04 0:44 98 1437 9.8 37 mud 40 3.5 600 600 235 13:37 13:43 0:06 20 1457 9.8 37 mud 40 3.5 575 117 14:15 14:19 0:04 10 1467 9.8 371 mud 40 3.5 580 590 117 14:50 14:54 0:04 10 1477 9.3 mud 40 3.5 600 600 117 15:25 15:28 0:03 10 1487 9.3 mud 40 3.5 600 590 1075 16:00 16:26 0:26 92 1579 9.3 mud 40 3.5 600 590 117 17:00 17:03 0:03 10 1589 9.3 mud 401 3.5 600 600 117 17:32 17:35 0:03 10 1599 9.3 mud 40 3.5 600 600 117 18:05 18:08 0:03 10 1609 9.3 mud 40 3.5 600 600 117 18:28 18:31 0:03 10 1619 9.3 mud 40 3.5 610 610 117 19:00 19:03 0:03 10 1629 9.3 mud 40 3.5 625 650 117 19:40 19:43 0:03 10 1639 8.9 mud 40 3.5 625 650 117 20:14 20:17 0:03 10 1649 8.9 mud 40 3.5 650 650 141 20:55 21:00 0:05 121 1661 9.4 mud 401 3.5 575 575 286 21:37 21:46 0:09 241 1685 9.4 mud 40 3.5 575 575 618 22:09 22:25 0:16 53 1738 9.4 Imud 40 3.5 575 575 117 22:35 22:38 0:03 10 1748 9.4 mud 40 3.5 575 575 117 23:00 23:03 0:03 10 17581 9.4 mud 40 3.5 5751 5851 176 23:29 23:34 0:05 15 17731 9.4 mud 40 3.5 5751 5501 140124:00:001 0:04 0:04 12 17851 9.4 mud WELL LOG TRANSMITTAL To: AOGCC March 11, 2004 Attn.: Steve Davies 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793 -1224 RE: MWD Formation Evaluation Logs, Mud Logs, End of Well ADT Report for: East Caribou 26 -11 -1 (Site 2), AK- MW- 2837527 API# 50- 279 - 20009 -00 East Caribou 26-11-1 (Site 2): 2" x 5" MD Resistivity & Gamma Ray Logs: -f Blueline Film --- 2" x 5" MD Neutron, Density & Acoustic Caliper Logs: -1 Blueline ✓1 Film ✓ 2" x 5" MD Bimodal Acoustic Logs: - Blueline / 4 Film .� LAS/DLIS formatted Digital LWD Log Data: Quad Combo LAS/DLIS / Logs 1 CD Rom 177 l 11111 ADT Well Summary Report 1 Bound SDL/ML LAS Data, EOWR, ML and Eng. Logs 1 CD Rom - CAD 4f- g.c- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: 3 • �� • ® I Signed: 0 6 DIRECTIONAL SURVEY TRANSMITTAL a 3 - 176 To: AOGCC March 11, 2004 Attn.: Steve Davies 333 West 7` Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793 -1224 RE: Directional Survey Reports: East Caribou 26 -11 -1 (Site 2), AK -MW- 2837527 East Caribou 26 -11 -1 (Site 2) 1 Hard Copy 1 Disk with ptt and pdf files ✓ 50- 279 - 20009 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: 3 / '/. O e Signed: Re: Total Caribou Inspector Reports 40 Subject: Re: Total Caribou Inspector Reports From: Stan Date: Mon, 01 Mar 200411 :04:33 -0900 To: Thomas Maunder <tom_maunder min.state ak us> CC: Tim Lawlor@ak.blm.gov We'll get the info to you as soon as we get it. Tim said the downhole P +A was completed Wednesday and he was not there for the excavation and plate installation, but Mike Whitely will send digital photos of these. As for Umiat, our lead engineer for the project would like to go after Umiat #8, the gas well. I'll give you a call later today after I get all the loose ends wrapped up from my trip to Umiat last week. Stan Porhola BLM - Alaska Petroleum Engineer 267 -1469 I of 1 12/22/2005 12:09 PM Re: Total Caribou Inspector Reports Subject: Re: Total Caribou Inspector Reports From: Thomas Maunder {tom maunder @adin.state.ak.us> Date: Mon, 0l Mar 200410:55:12 -0900 To: Stan Porhoia <Stan ak.bI .gov> BCC: Jim Regg <jiin regg aadin.state,ak,us> Stan, Below is the note I sent last week requesting copies of your Inspectors' reports from the activities at Total's well. By Total's latest report I see that they concluded their well operations at noon last Thursday (2/26) and commenced rig down and move. When Tim's reports are submitted, we would appreciate copies. Please let me know by return message with an estimate of when that might be. Also, after our meeting regarding the P &A of the Total well we discussed potential upcoming P &A work at Umiat. I had sent another message regarding the need for an AOGCC sundry for that work. Could you give us an idea of when that work might start? As I noted last time, it is encouraging that BLM has successfully gotten funding to remove some of those old wells from the work list. Thanks, please call with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote: Stan, Could you please provide copies of the reports that Tim prepared for his witnessing of the plugging activities at Total's Caribou well ?? Since we did not have an Inspector out there, copies of Tim's reports will allow us to close the loop on the abandonment sundry approved by the Commission and provide documentation to verify the final reports Total will ultimately submit. Have all the wellbore activities been completed and the wellhead cutoff ?? If it is possible, digital photos of the cutoff and marker plate would be appreciated. Please call with any questions /comments. Tom Maunder, PE AOGCC vv\ n C mco 1 of 1 12/22/2005 12:09 PM Re: P &A of TOTAL Caribou 26 -11 #1 • Subject: Re: P&A of TOTAL Caribou 26-11 #1 From: Thomas Maunder <torn_rnaunder a@admin.state.ak.us> Date: Fri, 20 Feb 2004 07:33:09 -0900 To: BELLANGER can -Yves < Jean= Yves.BELLANCrER a total,com>, Bilk Penrose <bill(a fairweat er.com> CC: start porhola <Stan_ Pd ha a @ak.blm.gov Jean -Yves and Bill, Everything with the exception of leaving the wellhead section on is the standard procedure that has been employed by all the operators in NPRA as well as elsewhere in the state. With the deep plugs you plan to set including the retainer near the surface shoe, anything in the wellbore should be isolated. I am not aware of any well that has successfully executed a similar P &A program that has had any migration problems that you speak of.Stan, are you aware of any problems ?? Jean -Yves, you do make a correct observation that if the cut off is accomplished now that no one will have to come back next year. It is ultimately Total's call. I expect we will talk later. Tom Maunder, PE AOGCC BELLANGER Jean -Yves wrote: It is much safer to leave the wellhead in place to observe any pressure build up in the future. Should it create some difficulties we may give up that step of the program and cut off the wellhead after the BOPE is nipple down. That makes thing easier for us as we do not have to come back for cutting the wellhad off next year. Regarding the amount of cement we may say caliper plus 20% XS. I understand his stand point for tagging the second plug. Should he does not want to waive that step we will tag the CP #2. It' anyway a good compromise between AOGCC regulations and what we proposed. Let me quickly revise tomorrow morning the final P &A taking into account all comments. Regards JEAN -YVES BELLANGER TOTAL E &P USA, Inc Tel (1) 907 743 0970 Cel (1) 907 317 7850 Fax (1) 907 743 0979 e -mail << jean- yves.bellanger(a7total.com>> 1 of 1 2/20/2004 8:01 AM Re: P &A of TOTAL Caribou 26 -11 #1 • Subject: Re: P &A of TOTAL Caribou 26 -11 #1 From: Thomas Maunder <tom_maunderadin.state.ak.us> Date: Thu, 19 Feb 200417:05:51 -0900 Tv: Bill Penrose bil fir veatlier.coffi> CC: ."Siah l"vncola (Stan 1' ihrala ak,blm.g ©v)" {Stan. Porh+ola@ak:ialm.90V> "Jean -Yves Bellanger (jean. -yves bellanger @total.com)" , <jean, es'be11 to l.cor> : jean Fray col Prose yv �� (Jean francoi t st&tal.cam)" �je`�4i i rc st{a total.dom All, Thank you for the proposed P &A procedure. After a preliminary examination, I have a couple of comments /points. 1. The method of calculating the cement volume will be based on the caliper. I would appreciate your providing some estimate of the cement volume and what XS will be used for each plug. 2. Given that this is a remote exploration well and that a disposal operation will be conducted above the final plug at 7405', the AOGCC is not disposed to waive the tagging of this plug. 3. Since it is planned to leave the wellhead (or some portion of it in place) under AOGCC regulations the well would be considered suspended. Please refer to 20 AAC 25.110 for the suspension criteria. If indeed the intent is to P &A, then the wellhead should be removed and an abandonment marker installed. The procedure as planned is no different from any of the other wells that have been P &Aed in the recent campaign in NPRA other than cutting off the wellhead. 4. We look forward to the opportunity to examine the logs. Please call with any questions. Tom Maunder, PE Sr. Petroleum Engineer AOGCC Bill Penrose wrote: Tom and Stan, TOTAL has decided to plug and abandon the Caribou 26 -11 #1 without running 7" casing. Attached, please find a P&A procedure that also includes a wellbore schematic. Since the rig will be ready to commence P &A procedures sometime 1 of 2 2/20/2004 8:01 AM Re: P &A of TOTAL Caribou 26 -11 #1 tomorrow, it would be appreciated if you would examine the attached procedure while we prepare the remainder of the documentation for you. We anticipate delivering to you early tomorrow the appropriate sundry notice forms, any logs you require for examination to approve the cement plug placement, hardcopies of the attached P&A procedure and transmittal letters for it all. The second well for which you issued drilling permits, Caribou 09 -11 #1, will not be drilled this year. Thank you for having expeditiously processed and approved that project. Please give me a call if you have any questions or comments. Regards, Bill 2 of 2 2/20/2004 8:01 AM Total E &P USA Inc. 0 Caribou 26 -11 # 1 NP - Alaska, 2004 iO TOTAL Caribou 26 -11 # 1 NPR-Alaska Plug and Abandonment Procedure - 1 - Revision No.2 Feb 20th, 2004 Total E &P USA Inc. 0 Caribou 26 -11 # 1 TOTAL E &P USA Inc. Approvals Prepared By: Jean -Yves Bellanger Approved By: Jean - Franco Prost Approved By: NPR = Alaska, 2004 Date: February 20 2004 Date: February 20 2004 Date: Caribou 26 - 11 # 1 P &A Procedure Distribution List Recipient 0 TOTAL Copies TOTAL E &P USA Inc., Houston Office 2 TOTAL E &P USA Inc., Anchorage Office 3 TOTAL DGEP 2 Fortuna Energy 2 Nabor's Alaska Drilling Inc. 1 Halliburton, Anchorage Office, Cementing Division 1 Baroid, Anchorage Office 1 Sperry-Sun Drillin Services, Anchorage Office 1 Schlumber, er, Anchorage Office, Wireline Division 1 Rig Site 3 Fairweather E &P Inc 1 BLM 1 AOGCC 1 -2- Revision No.2 Feb 20th, 2004 Total E &P USA Inc. Introduction r� Caribou 26 -11 # 1 NPR'Alaska, 2004 0 TOTAL The Caribou 26 -11 # 1 was vertically drilled down to 9362' after having recognized the Alpine Sand reservoir between 8993' and 9240' Logs recorded are as follows: AIT — DSI — PEX (Density — Neutron — GR) — CMR — NGS — MDT — SWST — VSP. General Well Information Well Name Prospect Location Well Classification Rig Name Rig Contractor Spud Date Operator AFE Number API Number AOGCC Permit Number Rig Floor Elevation Ground Level Elevation Surface Location Caribou 26 -11 # 1 Caribou Approximately 48 mi West of Nuiqsut Exploration Nabor's 14E Nabor's Alaska Inc. January 29 2004 Total E &P USA Inc. 233262 50- 279 -20009 203 -196 29' 145' AMSL Sec 26, Twp 1 ON, Rge 5W U. M. 3,691' FEL, 1,373' FSL 70 Deg, 11 Min, 19.40 Sec N 153 Deg, 5 Min, 20.40 Sec W X: 613,087', Y: 5,919,405' Bottom Hole Location Actual primary target Target Radius Total Depth Operational Considerations Waste Management Same Alpine Sand @ 8993'TVD 150' 9362' TVD /RT It is planned to inject liquid mud wastes in the well before setting cement plug #3. Liquid mud wastes will be squeezed into the best sand layers located between the 9 5/8" casing shoe and the Torok Shale. Expected volume to be injected into the well is about 4000bbls. Quantity will be adjusted according to remaining mud in pits. A step rate procedure is included in this program. Hazards Stuck pipe could be experienced while plugging back the well with a slick BHA. Influx from the upper part of the Alpine Sands and in the Lower Torok interval is the other major concern. -3- Revision No.2 Feb 20th, 2004 Total E &P USA Inc. ! Caribou 26 -11 # 1 Alaska, 2004 BOPS Test Pressures whenever required during the P &A of the well 0 TOTAL Equipment Descri tion Low (psi) High (psi) Time Annular 250 Max 3500 10 min Rams 250 Max 5000 10 min Choke Mfld 250 Max 5000* 10 min Plug and Abandonment Considerations 1. The Caribou 26 -11 #1 well will be plugged and abandoned in accordance with the rules set up by the Alaska Oil and Gas Conservation Commission ( AOGCC), the Bureau of Land Management (BLM) and Total USA. BLM and /or AOGCC may wish to witness some particular operations. Among them the P&A of any left open potential HC zones, pressure tests, and liquid mud injection. The second cement plug #2 will be weight tested with a BHA to locate its top. For the plugs set in the open hole, volume of slurry to be mixed will be calculated as per the caliper plus a 20% excess BLM requires 24 hr advance notice of the following operations: BLM Contacts: Field Inspectors: Bo Brown - Office 907 - 267 -1440, Cell 907 - 240 -5234, Home 907 - 336 -2882 Tim Lawlor - Office 907 - 267 -1442, Cell 907 - 240 -5243, Home 907 - 563 -1086 Anchorage Office: Stan Porhola - Office 907 - 267 -1469, Cell 907 - 244 -5432, Home 907 - 278 -0430 AOGCC requires 24 hr advance notice of the following operations: AOGCC Contacts: North Slope Inspectors - 907 - 659 -2714, Pgr 907 - 659 -3607 Tom Maunder Anchorage Office - 907 - 279 -1433 2. Clear the rig floor of non - essential personnel while pressure testing and handling explosives if any. 3. Review and implement safe handling and radio silence procedures before handling explosives if any. 4. Perform lockout - tagout, confined space entry, and hot work in accordance with applicable regulations. 5. Calibrate PVT equipment regularly. 6. Hold BOP, H2S, and evacuation drills regularly. Record drills in the IADC book. 7. Have safety meetings regularly and when unfamiliar procedures are being implemented. 8. Use the trip tank on trips and closely monitor breathing, hole fill, and swabbing. 9. Drift all tubulars before they are run in the hole. 10. Caliper all tools before they are run in the hole. 11. Maintain basic fishing equipment on location at all times. 12. Protect the wellhead by installing a wear bushing when possible. 13. Place pipe dope on pins rather than in boxes. 14. Stop and check for flow at the surface casing shoe when tripping. -4- Revision No.2 Feb 20th, 2004 Total E &P USA Inc. Caribou 26 -11 # 1 NPIWaska, 2004 0 TOTAL 15. Check the operability of pressure gauges used during pressure tests. Replace if there is any questions about their accuracy. Caribou 26-11# 1 General P &A Procedure Review AOGCC, BLM and TOTAL USA P &A Procedures and ensure that all operations will be done in accordance with rules stated in documents. Carefully prepare the P &A operations and make sure that premium cement, C Permafrost cement and all necessary cement additives are available at the rig site. Contact BLM and AOGCC representatives on the Slope with sufficient notice for P &A operations they would like witness. P &A principles All depths are MD /TVD (measured depth) and refer to Rotary Table (RT) The well is almost vertical all the way down, the average inclination is less than 0.5 deg and the maximum horizontal displacement is about 15ft away from original target. The Valanginian and Kimmeridgian had some minor gas shows while drilling in the silty interval and should be considered hydrocarbon bearing for P &A purposes over the interval 8993'— 9240'. The whole interval of the Alpine Sands will be sealed off by one cement plug from TD to 1 00f above the top of reservoir. Volume of slurry will be calculated as per caliper plus 20% excess. The Torok can be divided into 2 major intervals. The upper interval is a non - hydrocarbon bearing, but the lower interval is hydrocarbon bearing. Torok — upper interval (7162'— 7436') Non - hydrocarbon bearing Individual sandy units - 7162'-7216' 7237'-7325' 7340'-7436' This interval will not be sealed off as being not HC bearing Torok — lower interval (7505'— 7892') Hydrocarbon bearing. Individual sandy units - 7505'— 7625' 7700'— 7892' This interval will be sealed off with one cement plug set in two stages from 7992' to 7692' and from 7692' to 7405'. After having pumped in the hole enough slurry to seal off the open hole from 7992' to 7692', the well will be circulated twice the thickening time with the stinger at top of theoretical depth. The second stage will be then pumped right above the first stage. Volume of slurry will be as per caliper plus a 20% excess . The cementing assembly will be pulled out and one open jets rock bit will be run to tag the top of the cement plug #2. The well will be circulated while the cement gets enough compressive strength i.e. approximately 500psi before tagging the cement. If cement found not hard enough, WOC till it resists to 20 Klbs weight test. Pull out BHA to surface laying down excess of drill pipes. A cement retainer will then be set between 2136' and 2186'. It will be weight tested with the setting string with at least 20KIbs. All liquid mud wastes will be injected below Frac pressure after having performed a step rate test to determine the best effective injection rate. One cement plug will also be set across the 9 5/8" casing shoe through the cement retainer right after the end of the injection of the liquid mud wastes. Volume of slurry will be as per caliper plus 20% excess for the open hole section only. Internal casing volume will be taken into account between the shoe and the retainer. When the stinger is retrieved from the retainer, one 50 ft minimum cement plug will be set to cap the retainer. -5- Revision No.2 Feb 20th, 2004 Total E &P USA Inc. Caribou 26 -11 # 1 NP OM laska, 2004 0 TOTAL The surface plug will be set 150 ft or even deeper according to quantity of cement available on location, up to the ground level. C permafrost type cement will be used. Nipple down the BOPE and cut off the wellhead. Dress out the top of the 9 5/8" casing to top of the 16" conductor pipe. Install marker. The marker will be a steel plate with the following dimensions. The plate will be at least 18" in diameter and its thickness will be at least' /4 ". Following information must be bead - welded directly to the marker: Name of Operator: TOTAL E &P USA, Inc. AOGCC Number: 203 -19 Name of the well: CARIBOU 26 -11 #1 API number: 50- 279 -20009 Weld the marker onto the 16" conductor. If a post is to be required, it will be at least 4" in diameter and at least 1 Oft long. It will be set in cement inside the casing or firmly welded with supporting fillets to the top of the marker plate secured to the casing stub. Top of post will be 4 to 6' above ground level and closed by one screw cap or welded plate or filled up with cement plug. Detailed operations Plug and abandon of the 8 %" Hole Section While logging the open hole prepare 100bbls of heavy, viscous mud @ 15.6ppg in the pill pit. When the logging program is completed and the decision to P &A the well is taken the following procedure will be implemented: 1. Run in hole with at least 150 ft of 3 EUE tubing to bottom. Circulate one bottom's up to remove any gas from the well. Condition mud if needed. 2. Cement plug #1 from 9362' to 8893': With the tail pipe near bottom of the well, pump one spacer ahead of the slurry then the slurry weighted up to 15.6ppg and displace with a tail spacer and mud. Fresh water will be used for the spacer. Stop pumping leaving 1 00f of slurry in the string above theoretical top of cement. This procedure will allow the setting of good balanced plug. Disconnect surface lines and pull slowly the string. Pull the string wet. Volume of slurry to be mixed = 41 bbls 3. Pull the string just above the TOC and circulate out the long way the spacer to limit the EWD below the shoe. 4. When all the spacer is out spot a viscous, heavy pill form 8893' to 7992'. 5. Pull string to 7992' and circulate out the long way excess of heavy mud as for the cement spacer. 6. Cement plug #2 from 7992' to 7405': This cement plug will be set in two stages. First stage will cover the interval from 7992' to 7692'. With the tail pipe @ 7992', pump one spacer ahead of slurry then the slurry weighted up to 15.6ppg and displace with a tail spacer and mud. Fresh water will be used for the spacer. Stop pumping leaving 1 00f of slurry in the string above theoretical top of cement. Pull slowly to 7692' and circulate the long way. When all spacer is out pull one stand and circulate while the cement sets. Wait twice the thickening time). This will allow to properly setting the slurry of the second stage. Volume of slurry for the first stage of cement plug #2 = 25.5bbls 7. Run back in hole to TOC and proceed to the second stage of cement plug #2. With the tail pipe @ 7692', pump fresh water ahead of slurry then the slurry weighted up to 15.6ppg and displace with a tail spacer and fresh water as tail spacer. Stop pumping leaving 1 00f of slurry in the string above theoretical top of cement. Pull slowly to 7405' and circulate the long way. When all spacer is out pull string to surface. Volume of slurry for the second stage of cement plug #2 = 24.2bbls 8. Tagging of Cement plug #2: RIH w/ BHA to TOC of cement plug #2 and tag it and apply 20KIbs weight down. If cement is not found hard enough WOC until it gets sufficient compressive strength. Re -tag it with 20KIbs then pull out BHA to surface laying down excess of pipe. -6- Revision No.2 Feb 20th, 2004 Total E &P USA Inc. PSI 10 11. 12. 13. 14. 15. 16 17 18 19 20 Caribou 26 -11 # 1 NPFZ"Alaska, 2004 iO TOTAL RIH with EZSV retainer and setting tool on drill pipe to 2186'. Turn string (1 turn per 1000 ft) to the right and lower the string to set the plug. With the stinger still engaged into the retainer, apply 20KIbs down weight on the retainer to make sure it is properly set. Follow Halliburton operator procedure to set the plug. Liquid mud disposal into the well. AOGCC and BLM shall approve the liquid mud wastes disposal permit prior to pumping in the well. This operation will be witnessed by one Agency Representative. A step -rate injection test is to be performed prior to pumping the liquid mud wastes. Step rate procedure: Before placing a P &A cement plug across the shoe of the 9 -5/8" surface casing in this well, the liquid mud in the pits as well as any other liquid mud from this well that is stored on location will we injected into the Lower Nanushuk sands just below the casing shoe. Prior to commencing large -scale injection of mud, a step -rate test must be performed so that the Sate or Federal agency representative on site can determine the maximum injection rate allowable. The following is the procedure for the step -rate test. A minimum of three, and ordinarily a maximum of five, rate - and - pressure -pair points are required. The stabilized rate and pressure are always included as the first point. At least three points are needed to reveal the character of a curve. Five points are usually enough to ensure that a large enough rate change exists between points to emphasize any water hammer effects that might be present. Job Procedure Pressure test surface lines. Establish minimum pump rate and gradually increase it to 0.5bpm and hold until pressure stabilizes. Record first rate and pressure pair. Increase the pump rate in 0.5bpm increments (check for changes in the slope of the pressure curve at stable rates). Plot pair points on a pressure versus rate graph. Determine fracture extension pressure. Reminder: The LOT #1 at 2254' gave 14.2ppg EMW while the LOT #2 at 2577' gave 14.Oppg EMW (when referenced to the 2254' depth). Pumping will be done using the rig mud pumps. Keep a chart of all pumping sequences, i.e. rates and surface pressure, liquid weight and all valuable information. When the injection of all liquid mud wastes is completed, mix and spot cement plug #3. Quantity of cement will be adjusted to fill at least 100 ft of open hole. Pump fresh water ahead of slurry then the slurry weighted up to 15.6ppg and displace with mud and fresh water as tail spacer. Stop pumping when spacer is at retainer. Volume of slurry to be mixed is = 8.5bbls Sting out and reverse circulate the spacer When bottom's up is finished position the stinger right above the retainer. Mix and spot all remaining premium cement with a minimum of 50 ft of slurry above the cement retainer. Pump fresh water ahead of slurry then the slurry weighted up to 15.6ppg and displace with mud and fresh water as tail spacer. Stop pumping leaving 50ft of slurry in the string above the theoretical top of cement. Pull slowly to TOC and reverse circulate. When all spacer is out pull string to 155' laying down excess drill pipe. Lay down all DC's. Volume of slurry to be mixed is = 3.8bbls. Should there is remaining cement available on location mix a larger volume. Verify the integrity of the cement retainer. Pressure test 9 5/8 casing to 1500psi above the pressure to inject the mud in the well less the calculated pressure loss, with a maximum of 4000psi (70% of casing burst) for 10min. Mix and spot 150 ft of C Permafrost cement from about 150ft to right below the ground level. Keep two bbls of cement in mixing tank and re- circulate it while displacing and pulling out string. Pump fresh water spacer and adjust volume in order to get the slurry at surface at the end of the displacement. Pull string out of hole. Slurry level will go down when pulling string out of hole. Position the string at theoretical TOC (± 15 ft) and fill hole with remaining cement to ground level. Check returns through lateral valve of the casing head. Position the stinger below the BOPE and circulate fresh water to clean out all BOP equipment. Lay down remaining drill pipes in the mouse hole if any. Nipple down BOPE, adapter spool 11" 5k x 13 5/8 10K and the 11" 5K tubing spool. Cut off wellhead and install marker. End of operations. -7- Revision No.2 Feb 20th, 2004 Total E &P USA Inc. Caribou 26 -11 # 1 NPR - Alaska, 2004 0 TOTAL NB: For all slurry formulations please revert to main drilling program rev1 dated January 11 2004 Volume of slurry will be calculated according to caliper from open hole logs (Caliper from first run w/h AIT — PEX (Density — Neutron — GR) — DSI. Caliper readings Cement plug #1 From 3962' to 9075' = 8.5" or 0.07020bbl /ft (no readings below 9202' but there is no formation change and it is assume the caliper will be the same. 20% excess of cement will be considered anyway From 9075' to 8904' = 8.75" or 0.07438bbl /ft From 8904' to 8893' = 9.5" or 0.08769bbl /ft Cement plug #2 From 7992' to 7692' = 8.5" or 0.07020bbl /ft From 7692' to 7405' = 8.5" or 0.07020bbl /ft Cement plug #3 From 2236' to 2336' = 8.75" or 0.07438bbl /ft Cement plug #4 and above retainer 9 5/8" 40# internal diameter = 8.8346" or 0.07584bbl /ft -8- Revision No.2 Feb 20th, 2004 Total E &P USA Inc. • Caribou 26 -11 # 1 NPfZ-Alaska, 2004 iO TOTAL � TOTAL E &P USA Inc. l i%AW, Caribou 26 -11 #1 Proposed Plug and Abandonment Schematic TOTAL NPR - Alaska Rig: Nabors Alaska Rig 14E ELEV 145' AMS Sec 26 1 Twp 1 ON Rng 5W Spud: Jan 29th, 2004 RF 1 29' 1 3691' FEL 1373' FSL Note: All referenced depths are MD /TVD RT ;< ::.<_ <::z::::.. C Permafro cement 15 .. 6 .PP.g...:: > > > = 9 5/8 "Lead slurry 10.6 ppg :. :::::< t To o su rface P 16 ", 65 #, H -40, PEB Casing @ +/- 109' 20" Hole cemented to surface o ::::::::::::: :::::::::...........:.:........ o TAM Port Collar @ 881 , 9 5/8" tail slurry 15.6 ppg Mud left in hole 10.4 ppg 7 7 Base Permafrost at +/ -965' Top (n +/- 1050' 12 1/4" Hole of cement g Top plug across retainer na 2136' Premium. cement.15.6opq ... . Surface casing Retainer EZSV Type set @ 2186' 9 -5/8 " 40# L -8U B G set @ 2236' 9 5/8" cemented to surface Premium cement 15.6ppg Base of cement plug across retainer @ 2336' 8 1/2" Hole Mud left in hole 10.4 ppg Torok Lower Interval CP #2 TOC @ 7405' Premium cement 15.6ppg 7505' to 7892' Base of cement plug @ 7992' Viscous mud 15.6 ppg CP #1 TOC @ +/- 8893' [: Valanginian sands Premium cement 15.6ppg ( +/- 100' above the Valanginian Sands) 8993' to 9240' ....... to TD @ 9362' -9- Revision No.2 Feb 20th, 2004 Laboratory Report Prudhoe Bay, Alaska To: Jean -Yves Bellanger Total E & P USA, Inc. Report No: 005 -04 Date: 2/5/2004 Anchorage, Alaska 99503 Submitted by: Rafael Hernandez Rig: Nabors 14E Well: Caribou 26 -11 #lA Job Type:Plug back open hole Cement Plugs #1 &2 Casing Size: - - -- MD: 9583' TVD: 9583' Field: East Caribou Borough: North Slope State: Alaska Hole Size: 8.5 BHST: 220'F OF OF BHCT: 150'F OF OF Stage Stage2 Stage3 Purpose: Field Blend Test Comments: N/A Report prepared by: C. Slight This report was prepared by and is the property of Halliburton Services, a Division of Halliburton Company. The data reported, is intended for the private use of the above named party, is limited to the sample or samples described; accordingly, any user of this report agrees that Halliburton shall not be liable for any loss or damage, regardless of cause, including any act or omission of Halliburton, resulting from the use of the data reported herein; and Halliburton makes no warranties, express or implied, whether of fitness for a particular purpose, merchantability or otherwise, as to the accuracy of the data reported. This report is the property of Halliburton Services and neither it nor any part thereof nor a copy thereof is to be published or disclosed without first securing the express written approval of laboratory management; it may, however, be used in the course of regular business operation by any person or concern and employee thereof receiving such report from Halliburton Services. Cement test accuracy data indicate that an average range of confidence for cement testing is +/- 20 depending on specific well conditions. Although standard API cement testing procedures are followed as closely as possible, deviations from these procedures are made as dictated by specific well parameters. HA'LLIBURThN Stage Number: 1 Slurry Number: 1 Slurry Parameters Water Requirement: 5.04 gal /sk Water Type: Fresh Slurry Volume: 1.16 cu ft /sk Specific Gravity: 1.00 Slurry Density: 15.8 lbs /gal Slurry Composition and Weights Additives % Grams Premium Cement - -- 700 CFR -3 0.25 BWOC 1.75 HALAD -344 0.50 BWOC 3.50 HR -5 0.28 BWOC 1.96 Super CBL 0.25 lbs /sk 1.86 Water 312.48 Slurry Data Slurry Thickening Time ime (Hrs•min) Free Water ( %) Fluid Loss (cc /30 min) 1 3:53 not tested 54 Slurry Rheologv RPM 600 300 200 100 6 3 164 125 78 10 5 Compressive Strength Time Temp(deg F) UCA (psi) Cube(psi) 12 hr 220 949 not tested 24 hr 220 1251 Settling Test Weight 1 Weight 2 W1 /W2 Density (W1/W2 X 8.33). HA?.L1BURTbN Laboratory Report Prudhoe Bay, Alaska To: Jean -Yves Bellanger Report No: 0012 -04 Total E & P USA, Inc. Anchorage, Alaska 99503 Rig: Nabors 14E Well: Caribou 26 -11 #1A Job Type: Plugback CP #3 Csg Sz: 9 5/8" 40# MD: TVD: Purpose: Field Blend Test Comments: Report prepared by: C. Slight Date: 2115/2004 Submitted by: Rafael Hernandez Field: East Caribou Borough: North Slope State: Alaska Hole Size: 8.5" or Caliper BHST: 150 ° F O F O F BHCT: 100'F O F OF Stage Stage2 Stage3 This report was prepared by and is the property of Halliburton Services, a Division of Halliburton Company. The data reported, is intended for the private use of the above named party, is limited to the sample or samples described; accordingly, any user of this report agrees that Halliburton shall not be liable for any loss or damage, regardless of cause, including any act or omission of Halliburton, resulting from the use of the data reported herein; and Halliburton makes no warranties, express or implied, whether of fitness for a particular purpose, merchantability or otherwise, as to the accuracy of the data reported. This report is the property of Halliburton Services and neither it nor any part thereof nor a copy thereof is to be published or disclosed without first securing the express written approval of laboratory management; it may, however, be used in the course of regular business operation by any person or concern and employee thereof receiving such report from Halliburton Services. Cement test accuracy data indicate that an average range of confidence for cement testing is +/- 20 depending on specific well conditions. Although standard API cement testing procedures are followed as closely as possible, deviations from these procedures are made as dictated by specific well parameters. HAt Stage Number: 1 wr=T"%= Slurry Number: 1 Slurry Parameters Water Requirement: 5.6 gal /sk Water Type: Slurry Volume: 1.16 eu ft /sk Specific Gravity: Slurry Density: 15.8 lbs /gal Additives Premium Cement CFR -3 HALAD -344 HR -5 Slurry Composition and Weiahts 0.20 BWOC 0.20 BWOC 0.15 BWOC Water Fresh 1.00 Grams 700 1.40 1.40 1.05 313.74 Slurry Data Slurry Thickening Time (Hrs•min) Free Water ( %) Fluid Loss (cc /30 min) 1 2:57 not tested not tested Slurry Rheology RPM 600 300 200 100 6 3 Compressive StrenEth Time Temp(deg_F) UCA (psi) Cube(psi) 12 hr not tested 24 hr Settling Test Weight 1 Weight 2 W 1 /W2 Density (W 1/W2 X 8.33). HAtLIBURThN Laboratory Report Prudhoe Bay, Alaska To: Jean -Yves Bellanger Report No: 0010 -04 Total E & P USA, Inc. Date: 2/14/2004 Anchorage, Alaska 99503 Submitted by: Rafael Hernandez Rig: Nabors 14E Well: Caribou 26 -11 #1A Job Type: Surface Cement Plug #4 Csg Sz: 9 5/8" MD: TVD:150ft Field: East Caribou Borough: North Slope State: Alaska HoleSz: BHST: 50 F ° F ° F BHCT: 50'F O F O F Stage Stage2 Stage3 Purpose: Field Blend Test Comments: Report prepared by: C. Slight This report was prepared by and is the property of Halliburton Services, a Division of Halliburton Company. The data reported, is intended for the private use of the above named party, is limited to the sample or samples described; accordingly, any user of this report agrees that Halliburton shall not be liable for any loss or damage, regardless of cause, including any act or omission of Halliburton, resulting from the use of the data reported herein; and Halliburton makes no warranties, express or implied, whether of fitness for a particular purpose, merchantability or otherwise, as to the accuracy of the data reported. This report is the property of Halliburton Services and neither it nor any part thereof nor a copy thereof is to be published or disclosed without first securing the express written approval of laboratory management; it may, however, be used in the course of regular business operation by any person or concern and employee thereof receiving such report from Halliburton Services. Cement test accuracy data indicate that an average range of confidence for cement testing is +/- 20 depending on specific well conditions. Although standard API cement testing procedures are followed as closely as possible, deviations from these procedures are made as dictated by specific well parameters. HAtLIBURThN Stage Number: 1 Slurry Number: 1 Slurry Parameters Water Requirement: 3.75 gal /sk Water Type: Fresh Slurry Volume: 0.95 eu ft /sk Specific Gravity: 1.00 Slurry Density: 15.61bs /gal Slurry Composition and Weights Additives % Grams Type "C" Permafrost - -- 800 Sodium Citrate 0.14 lbs /sk Water 312.00 Slurry Data Slurry Thickening Time (Hrs:min) Free Water ( %) Fluid Loss (cc /30 min) 1 2:01 not tested not tested Slurry Rheology RPM 600 300 200 100 6 3 Compressive Strength Time Temp(deg. F) UCA (psi) Cube(psi) TQTAL ESOP USA I1C. USA, February 20, 2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval: Plug and Abandon TOTAL Caribou 26 -11 #1 Dear Mr. Norman, TOTAL E &P USA, Inc. hereby submits an Application for Sundry Approval to plug and abandon the Caribou 26 -11 #1 well. The attached P &A procedure is designed to meet or exceed the requirements of 20 AAC 25.112. Enclosed, please find: Form 10 -403 Application for Sundry Approval Proposed procedure for P &A of Caribou 26 -11 #1 Wellbore schematic of Caribou 26 -11 #1 Logs across the open -hole interval to be cemented For your information, this request for Sundry Approval is being simultaneously submitted to the U.S. Bureau of Land Management for their approval, also. The AOGCC is requested to keep confidential all information included in this application as information in these documents is drawn from research and data proprietary to TOTAL. If you have any questions or require additional information, please contact me at (907) 743 -0970. Sincerely, TOTAL E &P U%" Jean - Francois f Drilling Manage Enclosures 0 1 �� 4300 B Street, Suite 303, Anchorage, AK 99503 TOTAL Tel 907 743 0970 - Fax 907 743 0979 FEB 2 0 2004 Aloft LV A Cm Cons. seaiipn [Fwd: Pump in Test -- Caribou Well] Subject: [Fwd: Pump in Test--Caribou "well] From: Thomas Maunder <tflm maunder admin.state.ak.us> Date: Mon, 23 Feb 2004 14:13:19 -0900 To: Jim Regg <'itn re adrnin,st te.ak.us> Jim, Sorry I meant to copy you. Tom -- - - - - -- Original Message -- - - - - -- Subject: Pump in Test -- Caribou Well Date: Mon, 23 Feb 2004 14:12:49 -0900 From: Thomas Maunder <tom maunder @admin.state.ak.us> Organization: State of Alaska To: Jean -Yves Bellanger < jean- yves.bellangerUtotal.com > Bill Penrose <bill@fairweather.com> Jean -Yves and Bill, Thank you for providing the pump in information on the NPRA well. It appears that the test was conducted satisfactorily and this email is authorization for you to proceed with the waste disposal. The pump in pressure at 0.5 bpm is very similar to the pressure demonstrated with about 250' of open hole. Based on the information provided, it appears that you may conduct your disposal up to 3 bpm. During the disposal, your on site personnel should observe the pressure responses while pumping. Good luck with the operation. Tom Maunder, PE AOGCC 1 of 1 2/23/2004 2:37 PM • Note to File • Caribou 26 -11 #1 (203- 196...304 -005) NPRA Exploration Well TOTAL E &P USA, Inc. TOTAL E &P USA, Inc. made application for annular disposal (AD) on their Caribou NPRA exploration well. The sundry form was originally received January 8, however at that time several necessary pieces of information were not available. On February 11, the additional information was submitted. This document examines the pertinent information for the well and recommends approval of Total's request. - -Total has provided the surface casing cementing record. The surface casing was set about 800' shallower than planned. According to Total, their decision to set casing was based on the formations coming in "high" and that the shoe was set in the targeted formation. -- Surface casing was cemented to surface. No difficulties were reported and 130 barrels of cement was circulated. According to the spreadsheet calculation, gauge plus13% excess was left in the hole. It is indicated that the casing was cemented successfully. - -Prior to drillout, the casing was successfully pressure tested. From the chart, it appears that the pressure declined from 2800 to 2700 psi during the 30- minute test. - -On the initial leak off test, it was possible to pump into the formations exposed below the shoe at 14.2 ppg EMW. The pressure curve shape indicates that some volume was pumped to "fill" the system up. Once that void was filled, the pressure climbs smoothly to the leak off point. It appears that about 1 barrel of mud was pumped into the formation at about the pressure curve break. No pressure bleed off information is provided. With the information provided, it is indicated that the shoe is satisfactorily cemented. - -After drilling an additional 225', Total performed an additional leak off test. Their purpose was to demonstrate that it would be possible to pump into the additionally exposed open hole at an EMW (referenced to the shoe depth) less than the 14.2 EMW determined previously. The calculated EMW leak off for this test was 14.0 ppg, which is lower than the original "Shoe" test. The curve shape is "cleaner" for this test with no "filling volume" needed. About 0.5 barrel was pumped to achieve the leak off. This volume is only slightly greater than that pumped in the "shoe" test. About 0.5 barrel was pumped into the formation and again, there is no pressure bleed off information provided. With the information provided, Total has confirmed that the shoe is satisfactorily cemented. The calculated leak off referenced to the shoe is lower than the original test, although the values are close. - -The production hole has been successfully drilled to TD. No difficulties have been reported drilling this hole section and the actual days involved would support this. - -P &A plans have been approved for the well and the deeper portions of the wellbore will be isolated from the disposed waste. Based on examination of the submitted information, I recommend approval of Total's request to authorize annular disposal for the subject well. Tom Maunder, PE Sr. Petroleum Engineer ��`�`"j February 20, 2004 20 AAC 25.080 ANNULAR DISPOSAL OF DRILLING WASTE (a) A person may not dispose of drilling waste through the annular space of a well unless authorized by the commission under this section. The operator of a well permitted under AS 31.05.090 may request authorization for the disposal of drilling waste through the well's annular space by filing with the commission an Application for Sundry Approvals (Form 10 -403) supplemented with additional information as required under this section. (b) A request for authorization under this section must include the following information or refer to that information if that information is already on file with the commission: DONE ITEM REQUIREMENT SUBMITTAL 1. Form 10 -403 Submitted Received January 8, 2004 2. 1) the annulus to be used for disposal; Below 9 -5/8" casing shoe at 2,236' MD. 3. (2) the depth to the base of freshwater aquifers and Permafrost: Total's application states 600' permafrost, if present; inspection of the DIL suggests —960' MD. Freshwater Aquifers: Disposal injection target interval is sand from 2325' — 2336' MD. Total E &P's consultant calculates salinity of that interval to be 10,800 ppm; AOGCC calculation is 10,400 ppm. The section surrounding the 9 -5/8" casing shoe is sand - poor. AOGCC identified only 8 sand intervals between 1904' MD and 2634' MD for analysis. All of these have calculated salinity levels above 10,400 ppm except a 9 -foot thick sand from 2447 to 2456' MD, which calculates 9600 ppm. The mudlog indicated significant gas in the mud system below 350' MD that may be artificially inflating calculated porosity values, resulting in erroneously low calculated salinities. A change in sonic transit time of 2 microseconds per foot will result in a calculated salinity of 10,100 ppm for the sand from 2447 to 2456' MD. • • • r: 4. (3) a stratigraphic description of the interval exposed to the The receiving zone exposed below the 9 -5/8" casing open annulus and other information sufficient to support a shoe is the bottom 200' + /- of the lower Nanushuk commission finding that the waste will be confined and Topset sands. Upper confinement will be by shales will not come to the surface or, except to the extent within and overlying the Nanushuk sands. Lower allowed under (e)(1) of this section, contaminate confinement will be by several thousand feet of freshwater; massive Torok Shale. 5. (4) a list of all publicly recorded wells within one - quarter None mile, and all publicly recorded water wells within one mile, of the well that will receive drilling waste; 6. (5) the types and maximum volume of waste to be 4000 bbls of 12.0 ppg used drilling fluid disposed of and the estimated density of the waste slurry; • r: DONE ITEM REQUIREMENT SUBMITTAL 7. (6) a description of any waste sought to be determined as Used drilling fluids, minor excess cementing drilling waste under (h)(3) of this section; materials, snow and wash water, minor amounts of arctic grade diesel. 8. (7) an estimate of the maximum anticipated pressure at the 1031 psi; calculations provided. outer casing shoe during disposal operations and calculations showing how this value was determined; 9. (8) details that show that the shoe of the outer casing is set Base permafrost is 960' MD; casing is set at 2236' below the base of permafrost, if present, and any MD, 1276' below base permafrost. freshwater aquifer, other than freshwater excepted under All zones below 1905' MD calculate >10,000 ppm (e)(1) of this section, and except one 9' thick sand having a calculated salinity of 9600 ppm. 25.080 (e)(1)(B) sets criteria of TDS more than 3,000 ppm and not reasonably expected to supply a public water system. Public notice and opportunity for hearing is at commission discretion. 10. (8) details that show that the shoe of the outer casing is The surface casing was cemented with 216% of the adequately cemented to provide zone isolation; the gauge hole volume. 130 bbls were circulated leaving information relied upon and submitted must include 113% in the hole. It is indicated that the casing is (A) cementing records; and adequately cemented. (B) a cement quality log or formation integrity test records; 11. (9) details that show that the inner and outer casing strings Minimal casing is exposed since the pumping will be have sufficient strength in collapse and burst to withstand through a retainer. Initial leakoff occurred at 600 psi the anticipated pressure of disposal operations; surface pressure which is barely 10% of pipe burst. 12. (10) the downhole pressure obtained during a formation Initial leakoff occurred at 14.2 EMW. A subsequent integrity test conducted below the outer casing shoe; LOT was performed with a total of —250' of open hole. Pump in occurred at 14.0 EMW. 13. (11) identification of the hydrocarbon zones, if any, above None in the vicinity of the intended injection zone. the depth to which the inner casing is cemented; Any deeper zones will be abandoned with cement in accordance to AOGCC regulations. 14. (12) the duration of the disposal operation, not to exceed Not anticipated to exceed 10 days. 90 days; • c: DONE 15. (13) whether drilling waste has previously been disposed No, new well. 16. of in the annular space of the well and, if so, a summary of Waste to be disposed was generated during drilling of the dates of the disposal operations, the volumes of waste this same well. 17. disposed of, and the wells where the drilling waste was Operator intends to comply with all limitations. g enerated; minimum specified in 20 AAC DONE ITEM REQUIREMENT SUBMITTAL 16. (14) the well where the drilling waste to be disposed of Waste to be disposed was generated during drilling of was o will be ge nerated; this same well. 17. (15) if the operator proposes not to comply with a Operator intends to comply with all limitations. limitation established in (d) of this section, an explanation minimum specified in 20 AAC of why compliance would be imprudent; 25.080(e)(1)(B), and all but one 9 -thick 18. (16) any additional data required by the commission to Mudlog provided to confirm overlying and underlying confirm containment of drilling waste. clay zones that will confine drilling wastes. (c) The commission will authorize an annular disposal operation described in the Application for Sundry Approvals, as that application has been supplemented under this section, and subject to any modifications prescribed by the commission, if the commission determines that the DONE ITEM REQUIREMENT SUBMITTAL 1. (1) waste will be adequately confined; Yes, sufficient overlying and underlying claystone to confine this amount of injected waste. 2. (2) disposal will not (A) Water in all aquifers is above 3000 ppm (A) contaminate freshwater, except to the extent minimum specified in 20 AAC allowed under (e)(1) of this section; 25.080(e)(1)(B), and all but one 9 -thick (B) cause drilling waste to surface; interval (at 2447' MD) calculate to be greater (C) impair the mechanical integrity of any well; or than 10,000 ppm. None of these aquifers can (D) damage a producing or potentially producing ever reasonably be expected to supply a public formation or impair the recovery of oil or gas from water system. Main injection target zone a pool; and calculates 10,400 ppm (AOGCC) and 10,800 ppm (operator). (B) Successive leakoff tests indicate the subsurface formations should accept the waste at • • • • pressures insufficient to propogate fractures through the confining zones. (C) The mechanical integrity of the well structure will not be threatened. Well will be abandoned after placement of wastes. (D) Not applicable, no potentially producing zones will be affected by this disposal injection program. 3. (3) disposal will not circumvent 20 AAC 25.252 or 20 No. This is a single occurrence annular disposal AAC 25.412. program designed to dispose of wastes generated by drilling of the well. • • (d) Unless the operator demonstrates that compliance with a limitation established in (1) - (4) of this subsection is imprudent, the commission will not authorize disposal of drilling waste DONE ITEM REQUIREMENT SUBMITTAL 1. (1) in a volume greater than 35,000 barrels through the N/A annular space of a single well; 2. (2) for a period longer than one year through the annular N/A space of a single well; Jan 8, 2004. 3. (3) into a hydrocarbon - bearing stratum; or N/A 4. (4) through the annular space of a well not located on the N/A same drill pad or platform as the drilling operation 9 -thick interval (at 2447' MD) calculate to be greater g enerating the drilling waste. than 10,000 ppm. None of these aquifers can ever (e) On a case -by -case basis, and as the commission considers necessary to ensure that the standards in (c) of this section are met, the commission will impose conditions upon an authorization to dispose of drilling waste under this section. In addition, an authorization to dispose of drilling waste under this section is subject to the following conditions: DONE ITEM REQUIREMENT SUBMITTAL 1. (1) drilling waste may not be disposed of into freshwater, unless the 2. (A) freshwater is identified in the Application for Target interval identified in original application dated Sundry Approvals; and Jan 8, 2004. 3. (B) commission finds that the freshwater has a total Water in all aquifers is above 3000 ppm minimum dissolved solids content of more than 3,000 mg/1, specified in 20 AAC 25.080(e)(1)(B), and all but one and is not reasonably expected to supply a public 9 -thick interval (at 2447' MD) calculate to be greater water system; the commission will, in its than 10,000 ppm. None of these aquifers can ever discretion, provide 15 days notice and the reasonably be expected to supply a public water opportunity for a public hearing in accordance with system. Main injection target zone calculates 10,400 20 AAC 25.540 before making that finding; ppm (AOGCC) and 10,800 ppm (operator). Notice not deemed necessary due to amount of injected waste, depth of target injection zone, and very remote location. 4. (2) the downhole disposal pressure may not exceed the As a condition of approval, Total will perform a step • • • downhole pressure obtained during the formation integrity rate test to establish the formation capabilities as test conducted below the outer casing shoe, or a higher pumping rate is increased. The second leak off test pressure specified in the authorization upon the was lower than the initial indicating that there are commission's finding that the higher pressure will not formations deeper than the shoe that should accept the cause drilling waste to migrate above the confining zone; waste at pressures below the initial leak off test. 5. (3) if drilling waste appears above the confining zone, the NA. operator shall immediately cease disposal, notify the commission, and take appropriate remedial action; 6. (4) if the commission notifies the operator that disposal NA. operations pose a threat to well integrity, safety, oil or gas recovery, or freshwater, except to the extent allowed under (1) of this subsection, the operator shall immediately cease disposal and take appropriate remedial action as approved or required by the commission. • —Mar 01 04 09:44a TOTAL ESP LISR, INC (9071 743 -0979 p.2 i • TOTAL E &P USA Inc. Caribou 26 -11 # 1 IOTA{.. Report No 7 Report Date:3/01 /04 CONFIDENTIAL MAR 0 Well Information API No: 50-279-20009 AOGCC Permit No: 203 -196 AWAGUG . Lease SN AA- 084170 Location: Sec 26, Twp ION, R e 5E, U.M., 3691 FEL, 1373 FSL Mud wt Depth Date (ft Operation Q , Continue POOH laying down DP's. M/U and RIH EZ drill Squeeze Packer @ 2181'. Pressure drop measurement: 1BPM = 75pst, 2BPM = 100psi, 38PM = 150psi, 4BPM = 225psi. Pressure test --^� annulus to 1500psi, Perform injectivity test @ 0.5BPM. Pressure build to 1020psi then broke to 400psi 2123/2004 10.45 9362 stabilized. Increse to 1 BPM = 420psi,1.5BPM = 450psi, 2BPM = 480psi, 2.58PM = 490psi, 38PM = 520psi, 3.56PM = 560psi. Stop pumping pressure stabilized at 320psi. Perform mud injection after getting Authorities green light. Inject mud at 3.5BPM w/h an injecting pressure = 560psi. Pumped in hole 950bbls at 2000 including 50bbls water. 2/2412004 10.4 9362 Clean out liquid mud storage tanks and continue to inject in hole. Total pumped in hole at 24h00 = 1772bbis. Spot cement plug #3 from 2236' to 2362' (126' open hole) + 2236' to 2181' cased hole with 13bbls slung 15.8ppg. Displace win 2bbls of water and 20.8bbis of mud. Pressure increase from 320psi to 520psi when cement in the open hole. Sting out from packer. Pump second stage og cement plug #3 2/25/2004 10.4 9362 from 2159' to 2036'(123') w/h 9.3bbls slurry 15.8ppg. Displace w/h 2,5bbis water + 17bbls mud. POOH to 1300' circulate 1.5 bottom's up. Lay down tubular. Pressure test 9 518" casing to 2000psi for 10' OK. Pull pipes to 184'. Spot surface cement plug #4. 15bbts C permafrost slurry 15.6ppg. Got cement returns to surface.Flush down ROPE. Super suck cement from cellar. Lay down cementing lines N/0 BOPE, kill line valves, Hydril, BOP rams, mud cross and drilling spool adapter. WD wellhead. Remove flex hoses and flow line to shaker. Measure TOC at S below ground level (Witnessed by BLM's Representative). End of well operations on the well Caribou 26 -11 #1 at 12h00am on 2/26/2004 9362 02126/04. Start demobilization of the rig. Rig down stand pipe section, fill up line and hose from cellar. R/D mud pump #2. Remove belt and cover. Cool down boiler #3. Remove chain from rotary table. Lay down kelly hose. Remove liners from pumps. R1D air hoses reel from bridge crane in cellar. R/D bridge crane. Pull liner and swab from pump #1. RID choke room. Separate lines between pits 2 U. Secure derrick for removal of top drive. RID line of Iron Roughneck, Secure top drive and 2/2712004 disconnect from block. Hang block and slip 120' of line. R/D in pits. RID lines on rig floor, prepare to lay down top drive. Offload 183bbis waste fluids from dewatering unit. R/D floor handling equipment and automatic pick uo and lay down equipment. Blow down steam to Dige shed. Move Section #1. R/D skid 6 section of pipe shed. Remove berm from pipe shed. Transfer 180bbis waste to Rolligons. Install C section support braces in derrick. Clean pits in dewatering unit. Continue to break lines In pit 2/28/2004 section. RID fall arrestors. Blow down brake cooling system. Lay down cooling lines and plug same. Continue cleaning dewatering unit and prepare for moving. R/D second bridge crane. Remove V door. Coil up electric cables from top drive. Secure service loops to top drive. Prepare to lay down C section. Secure dewatering unit for removal. Clean up berms area. Cool down boiler #1. Serviced raising legs for substructure. Prepare BOP scaffolding for transportation. Transfer 180bbls from pits to Rolligons. Remove centrifuge auger. Remove floor plates in choke room and pump room. Remove solids from 212912004 pits #5 and #6. Lay down "C" section, rig down rig floor wind walls. Lay down top drive. Pump excess water from water pits to truck. Remove 4 lights in derrick. Remove centrifuge auger house, poor boy stack and poor boy degasser stairs to injection pits and stair way to floor. Lay over opposite driller side windwall. Main events Complete P$A. Set cement retainer and inject 1772bbls liquid wastes. Set CP #3 and CP #4. End of well operations on February 26th, 2004 at 12h00pm. Actual rig status At 6h00 am Monday March i st, 2004: continue to rig down rig equipment and move out consumables. Fax on Mondays to: Stan Porhola at the BLM @ 907- 267 -1304 Torn Maunder at the AOGCC @ 907 - 276 -7542 WA 1 200 ARCO J Ni Subject File _ I By _ I Date f► Calculations Chart Gl✓' i I V V 0 V- G 1 0 0 0 v MI IAI IwI ITN()PGINTINn AM11- In.15AP AK M71 -M-AMl a G G c 1 C 1 � p S � � k w G f U� 15A -5A81 0 a G G c 1 C 1 � p S � � k w G f U� 15A -5A81 FEB -23 -2004 01:29 PM TOTAL.CARIBOU 9073391802 P.01 Ta, - rom M mvn; of F.R. rpzm . rn i Kc s +L- IC- ' 0 -&T. C?., z j t V t r ACV C- Z;L Af t FEB 2 3 2004 a teurmoan. , .41 t + r I , mfAl a lk I o wkwi a CASING TEST and FORMATION INTEGRITY TEST Well Name: Total Date: 2/2312004 Supervisor: Whitely ❑ Initial Casing Shoe Test Reason(s) for test: p Formation Adequacy for Annular Injection ❑ Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625 ", L-80,40#, BTCM Casing Setting Depth: 2,236' TMD Hole Depth: 2,236' TMD 2,236' TVD 2,236' TVD Mud Weight: 10.5 ppg Length of Open Hole Section: 0' EMW = Leak -off Press. + Mud Weight = 1,020 psi + 10.5 ppg 0.052 x TVD 0.052 x 2,236` *•- - vrlyauk= Pump output = 0.0833 bps Fluid Pumped = 25.0 bbl / LEAK -OFF DATA MINUTES 3,200 psi FOR LOT STROKES PRESSURE --- --- - -- - - - -r - -- 0 stks -- T - - - - -6 -- — 7 - - - - -; p si ------ - - - - -- - -- -------- - - - - -- L -- ------- 6 stks I 400 psi ---------------- •--------- 12 stks 600 psi - - - - -- - - - - -- 18 stks 700 psi - ------------------- - 24 stks -r -- - 820 psi - - -I> --------------- -- - - -: --------- ;------------------ 1 30 stks 1 F--- -------------t-- - -- -- -- - - -i --- - 1 36 stks 1 3,100 psi 42 stks 400 psi --- - - - 48 stks - - - 400 psi 54 stks 1 400 psi ____ ____ --------- - - - - -- --- 60 stks - --r --- 400 -psi - - -i i 66 stks 1 400 psi i F---- --------- {-- - - -- -- ---- -- - - ------- - iL I 1 78 stks 1 420 psi 1 --------- 90 stks I 420 psi 3,000 psi ------------ 108 stlks 1 450 psi 126 stks 450 psi i 1 172 stks i 480 psi i ------- - - - - -- - F ° - _ --- ' ---- ' -- - --------- 195 stks 1 ----- 480 psi _ J 224 stks 1 490 psi ' - - - - - -s - j_ 2,900 psi 520 psi - -- I ,� r_ 300 stks _T I --- --- i __ I I I I I 1 SHUT IN TIME 1 SHUT IN PRESSURE �__ _______ _L_ 0.0 min ' _ -- - - -- -- ---+ 560 psi - -- , i 1. — in I ---•- - - 325 p si --3 -- 1 2.0 min 1 - -r- 2,800 psi TIME UNE ; r _______________T_________ 325 psi _ 4.0 min I I 325 psi 1 F---------- - :-- -- --- 5.0 min--------------- -- -- - °-- --- -F--- - - -i -- - - °-- - --- - --! 320 psi -_: i 6.0 min ' 1 ________________i____ I I 70 min . ___________.L ----------------- I -L________________ I 2,700 psi 2,600 psi ONE MINVIrs >"ICKffi 1 - - - - -- 9.0 ------- ___ r___ min I ____________T ' - i ______- _________1 I --- - - - - -- - - - - - -- 10 0 min I I 2,500 psi 2,400 psi —®— LEAK -OFF TEST 2,300 psi 2,200 psi —&—CASING TEST 100 psi 2, 000 — LOT SHUT IN TIME 2, psi w 1,900 psi w 1,800 psi —CASING TEST SHUT IN TIME :3 1,700 psi 1,600 psi TIME LINE w 1,500 psi I 1,400 psi [L 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi I 0 psi N I STROKES LEAK -OFF DATA MINUTES FOR LOT STROKES PRESSURE --- --- - -- - - - -r - -- 0 stks -- T - - - - -6 -- — 7 - - - - -; p si ------ - - - - -- - -- -------- - - - - -- L -- ------- 6 stks I 400 psi ---------------- •--------- 12 stks 600 psi - - - - -- - - - - -- 18 stks 700 psi - ------------------- - 24 stks -r -- - 820 psi - - -I> --------------- -- - - -: --------- ;------------------ 1 30 stks 1 F--- -------------t-- - -- -- -- - - -i --- - 1 36 stks 1 950 psi - - - - -- - I 1,020 psi I 42 stks 400 psi --- - - - 48 stks - - - 400 psi 54 stks 1 400 psi ____ ____ --------- - - - - -- --- 60 stks - --r --- 400 -psi - - -i i 66 stks 1 400 psi i F---- --------- {-- - - -- -- ---- -- - - ------- - iL I 1 78 stks 1 420 psi 1 --------- 90 stks I 420 psi ------------ 108 stlks 1 450 psi 126 stks 450 psi i 1 172 stks i 480 psi i ------- - - - - -- - F ° - _ --- ' ---- ' -- - --------- 195 stks 1 ----- 480 psi _ J 224 stks 1 490 psi ' - - - - - -s - j_ 259 stks 520 psi - -- I ,� r_ 300 stks _T I --- --- i __ I I I I I 1 SHUT IN TIME 1 SHUT IN PRESSURE �__ _______ _L_ 0.0 min ' _ -- - - -- -- ---+ 560 psi - -- , i 1. — in I ---•- - - 325 p si --3 -- 1 2.0 min 1 - -r- 1 --------- - - - -T- 325 psi r _______________T_________ 325 psi _ 4.0 min I I 325 psi 1 F---------- - :-- -- --- 5.0 min--------------- -- -- - °-- --- -F--- - - -i -- - - °-- - --- - --! 320 psi -_: i 6.0 min ' 1 ________________i____ I I 70 min . ___________.L ----------------- I -L________________ I --------------------------------- 1 8.0 min 1 F___- i 1 - - - - -- 9.0 ------- ___ r___ min I ____________T ' - i ______- _________1 I --- - - - - -- - - - - - -- 10 0 min I I CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ----------------- i ---- 6 ---- St k - - -- - -- - -- --- I I I I I I I I 1 I :_tee -------- ----------------- ----------- - -- ----------------------------------- 1 I ' I - i---------------- F----------- 1 ' I I 1 I I 1---- ------ - - - - - - ---------- - - - - -; I---------------- i---------------- F----------------- I ---------- - - - - -- - - - - -- ------------------- 1 I 1 ' I 1 1 1 I 1 - --------------- -I --------------- ' -----------------1 I I i 1 I 1 1 ________________ ____ ____________;_________________I 1 I I SHUT IN TIME ; -- SHUT IN PRESSURE ;--- ---�---------- - - - 0.0 min 1 0 psi ; 1 1.0 min 1 1 1 1 2.0 min - -� - - -- - - - -- - - -- ; ---------------- I ---------------- i ---------------- F------------ 3.0 min I I __ ______________ ---------------- ----- - - - -__ ;- 4.0 min i - -- ---- a--- ---- ---- - - -- -; --- ---- -- --- --- --; 5.0 min 1 6.0 min ; 1 - -- - - E-- -- ----------------- ------------ - - - - -1 1 - -- --- rni n -- a---- ----- -------F- ----------- - - - - -1 8.0 I - ------------- i---------------- F ----------------- I 9.0 min ----- ---- ------------ ------ -- ---- 10.0 min ------------�--------------- i ----------------- - -- 15.0 min i 1 " -- ' ----- - " -------- - - ' ---- ' ------ - ------ - -- - 1 1 20_.0 min 1 1 1 1 25 0 min ,--------- - -- - -- ---------------- ' -------- ' -- ---------- - ---I 30.0 E11 -j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME ":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Re: Caribou 26 -11 #1 Step -Rate Test procedure Subject: Re: Caribou 26 -11 #1 Step -Rate Test Procedure From: Thomas Maunder <tom_maunder a@admin.state.ak.us> Date: Fri, 20 Feb 2004 07:34:07 -0900 To: Bill Penrose <bill @fair eather. om:� CC: "jean Prost f jeaj - rancvis.pro t @tp al.com }' < jean:- fraae6is.prost@ cOtal:cora , " an -Yves Bellangpr het- ves.be�an��1:coin" jean- yvves.elaner�atalcorii >, ta'Pirhrla �S� Porhdla @ak.blm gqy b Bill, Jean -Yves and All, The proposed step -rate test procedure is acceptable. Tom Maunder, PE AOGCC Bill Penrose wrote: Tom, Here's the step -rate test procedure to be used prior to commencing annular disposal of waste muds in the subject well. Regards, Bill 1 of 1 2/20/2004 7:34 AM Caribou 26 -11 #1 i Step -Rate Test for Annular Injection Rn A Discussion Before placing a P &A cement plug across the shoe of the 9 -5/8" surface casing in this well, the liquid mud in the pits as well as any other liquid mud from this well that is stored on location will we injected into the Lower Nanushuk sands just below the casing shoe. Prior to commencing large -scale injection of mud, a step -rate test must be performed so that the Sate or Federal agency representative on site can determine the maximum injection rate allowable. The following is the procedure for the step -rate test. Considerations A minimum of three, and ordinarily a maximum of five, rate - and - pressure -pair points are required. The stabilized rate and pressure are always included as the first point. At least three points are needed to reveal the character of a curve. Five points are usually enough to ensure that a large enough rate change exists between points to emphasize any water hammer effects that might be present. Job Procedure 1) Pressure test surface lines. 2) Establish minimum pump rate and gradually increase it to 0.5 bpm and hold until pressure stabilizes. 3) Record first rate and pressure pair. 4) Increase the pump rate in 0.5 bpm increments (check for changes in the slope of the pressure curve at stable rates). 5) Plot pair points on a pressure- versus -rate graph and determine fracture extension pressure. Re: [Fwd: Caribou 26 -11 #1 Step-R 6 Test Procedure] Is Subject: Re: [Fwd: Caribou 26 -11 #1 Step -Rate Test Procedure] From: James Regg < regg r admiin.state.ak.us Date: Thu, 19 Feb 2004 17:58:29 -0900 To: Th©ms launder <to maunder @admin.stateA.us> Looks good to me Thomas Maunder wrote: Just got this, haven't had a chance to examine. Tom -- - - - - -- Original Message -- - - - - -- Subject: Caribou 26 -11 #1 Step -Rate Test Procedure Date: Thu, 19 Feb 2004 16:29:04 -0900 From: Bill Penrose <bill @fairweather.com> To: Tom Maunder ( tom maunder@admin.state.ak.us <tom maunder @admin.state.ak.us> CC: Jean - Francois Prost ( jean- francois.prost@total.com < jean- francois.prost@total.com > Jean -Yves Bellanger ( jean- yves.bellanger @total.com < jean- yves.bellanger@total.com> Tom, Here's the step -rate test procedure to be used prior to commencing annular disposal of waste muds in the subject well. Regards, Bill 1 of 1 2/20/2004 7:35 AM Re: [Fwd: Caribou 26-11 #1 Step-R 6 Test Procedure] Subject: Re: [Fwd: Caribou 26-11 #1 Step-Rate Test Procedure] From: John Hartz <jackLhartz@admin.state.ak.us> Date: Thu, 19 Feb 200417:23:30 -0900 maun state To: Th6mas"Maunder <tom' der@admin, ak.us> CC: hin Regg <jim reggy@admiji; stitte.ak.us>, Tom Maunder <STaunder @aol.com. .... . I think it will do the job. jack Thomas Maunder wrote: Just got this, haven't had a chance to examine. Tom -------- original Message -- - - - - -- Subject: Caribou 26-11 #1 Step-Rate Test Procedure Date: Thu, 19 Feb 2004 16:29:04 -0900 From: Bill Penrose <bill@fairweather.com> To: Tom Maunder (tom maunder@admin.state.ak.us) <tom maunder@admin.state.ak.us> CC: Jean-Francois Prost (jean-francois.prost@total.com) <jean-francois.prost@total.com>, Jean-Yves Bellanger (lean - es.bellang r@total.com) <jean ves.bellanqer@total.com> Tom, Here's the step-rate test procedure to be used prior to commencing annular disposal of waste muds in the subject well. Regards, Bill I of 1 2/20/2004 7:35 AM '��Xa STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR S UNDRY APPROVAL 1. Type of Request: [x] Abandon [ ] Suspend [ ] Plugging [ ] Time Extension [ ] Perforate [ ] Alter Casing [ ] Repair Well [ ] Pull Tubing [ J Variance [ ] Other [ j Change Approved Program [ ] Operation Shutdown [ ] Re- Enter Suspended Well [ J Stimulate 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) TOTAL E &P USA, Inc. [ ] Development 29' RT [X] Exploratory [ ] Stratigraphic 3. Address 7. Unit or Property Name 4300 B Street, Suite 303, Anchorage, Alaska 99503 [ ] Service Caribou 4. Location of well at surface 8. Well Number 3691' FEL, 1373' FSL, Sec 26, T1 ON, R5W, UM 26 -11 #1 At top of productive interval 9. Permit Number 3691' FEL, 1373' FSL, Sec 26, T10N, R5W, UM 203 -196 At effective depth 10. API Number 3691' FEL, 1373' FSL, Sec 26, T1 ON, R5W, UM 50- 279 -20009 At total depth 11. Field and Pool 3691' FEL, 1373' FSL, Sec 26, T10N, R5W, UM Wildcat 12. Present well condition summary Total depth: measured 9,362 feet Plugs (measured) None true vertical 9,362 feet Effective depth: measured 9,362 feet Junk (measured) None true vertical 9,362 feet Casing Length Size Cemented MD TVD Structural 80' 16" To surface 109' 109' Conductor Surface 2,207' 9 -5/8" 200 bbl PF lead + 71 bbl G tail 2,236' 2,236' Intermediate Production Liner Perforation depth: measured N/A O'Scelvej) True vertical N/A FEB 2 Tubing (size, grade and measured depth) N/A ®?QQ� Packers and SSSV (type and measured depth) N/A col ft 13. Attachments [X] Description of Sumary Proposal [ ] Detailed Operations Program [ J BOP Sketch 14. Estimated date for commencing operation 15. Status of well classification as: Exploratory 2/20/2004 [ ] Oil (] Gas [ ] Suspended 16. If proposal was verbally approved Name of approver Date Approved Service Contact Engineer NaTelNumber. Joan -Yves Bellanger 743 -0974 Prepared By Name /Number: Bill Penrose 258 -3446 17. 1 hereby certify t t t fgr�goi Is true and correct to the best of my knowledge Signed es 12p�b� Tj#A Drilling Manager Date VA ommission Use Only Conditions of Ap val: Notif I io so ep ntative may witness Approval No. OLA T PI int city Test Location Clearance On y�atc� ech ical In it est Subsequent form required 10- Z �Q'A , Approved by order of the Commi ion Commissioner Date Form 10 -403 Rev. 06/15/88 VU [' � � / fl .J �:./ t �.� S�bmit/ n TP(plicate j 2004 Total E &P USA Inc. • Caribou 26 -11 # 1 � Caribou 26-111, NPR-Alaska Plug and Abandon Procedure 1 - Revision No. 0 Feb 16th, 2004 Total E &P USA Inc. Caribou 26 -11 # 1 TOTAL E &P USA Inc. Approvals Prepared By: Jean -Yves Bellanger Approved By: Jean- Frangois Prost Approved By: 9 NPR - Alaska, 2004 Date: February 16 2004 Date: February 16 2004 Date: Caribou 26 - 11 # 1 P &A Procedure Distribution List Recipient A Copies TOTAL E &P USA Inc., Houston Office 2 TOTAL E &P USA Inc., Anchorage Office 3 TOTAL DGEP 2 Fortuna Energy 2 Nabor's Alaska Drilling Inc. 1 Halliburton, Anchorage Office, Cementing Division 1 Baroid, Anchorage Office 1 Sperry-Sun Drillin Services, Anchorage Office 1 Schlumber, er, Anchorage Office, Wireline Division 1 Rig Site 3 Fairweather E &P Inc 1 BLM 1 AOGCC 1 -2- Revision No. 0 Feb 16th, 2004 Total E &P USA Inc. Caribou 26 -11 # 1 NPR - Alaska, 2004 �t Introduction The Caribou 26 -11 # 1 was vertically drilled down to 9362' after having recognized the Alpine Sand reservoir between 8993' and 9240' Logs recorded are as follows: AIT — DSI — PEX (Density — Neutron — GR) — CMR — NGS — MDT — SWST — VSP. General Well Information Well Name Prospect Location Well Classification Rig Name Rig Contractor Spud Date Operator AFE Number API Number AOGCC Permit Number Rig Floor Elevation Ground Level Elevation Surface Location Caribou 26 -11 # 1 Caribou Approximately 48 mi West of Nuiqsut Exploration Nabor's 14E Nabor's Alaska Inc. January 29 2004 Total E &P USA Inc. 233262 50- 279 -20009 203 -196 29' 145' AMSL Sec 26, Twp 1ON, Rge 5W U. M. 3,691' FEL, 1,373' FSL 70 Deg, 11 Min, 19.40 Sec N 153 Deg, 5 Min, 20.40 Sec W X: 613,087', Y: 5,919,405' Bottom Hole Location Actual primary target Target Radius Total Depth Operational Considerations Waste Management Same Alpine Sand @ 8993'TVD 150' 9362' TVD /RT It is planned to inject liquid mud wastes in the well before setting cement plug #3. Liquid mud wastes will be squeezed into the best sand layers located between the 9 5/8" casing shoe and the Torok Shale. Expected volume to be injected into the well is about 4000bbis. Quantity will be adjusted according to remaining mud in pits. Hazards Stuck pipe could be experienced while plugging back the well with a slick BHA. Influx from the upper part of the Alpine Sands and in the Lower Torok interval is the other major concern. -3- Revision No. 0 Feb 16th, 2004 Total E &P USA Inc. Caribou 26 -11 # 1 NPR - Alaska, 2004 T TAL BOPE Test Pressures whenever required during the P &A of the well Equipment Descri tion Low (psi) High (psi) Time Annular 250 Max 3500 10 min Rams 250 Max 5000 10 min Choke Mfld 250 Max 5000" 10 min Plug and Abandonment Considerations 1. The Caribou 26 -11 #1 well will be plugged and abandoned in accordance with the rules set up by the Alaska Oil and Gas Conservation Commission ( AOGCC), the Bureau of Land Management (BLM) and Total USA. BLM and /or AOGCC may wish to witness some particular operations. Among them the P&A of any left open potential HC zones, pressure tests, and liquid mud injection. It is proposed not to weight test tops of cement if following procedure is followed. BLM requires 24 hr advance notice of the following operations: BLM Contacts: Field Inspectors: Bo Brown - Office 907 - 267 -1440, Cell 907 - 240 -5234, Home 907 - 336 -2882 Tim Lawlor - Office 907 - 267 -1442, Cell 907 - 240 -5243, Home 907 - 563 -1086 Anchorage Office: Stan Porhola - Office 907 - 267 -1469, Cell 907 - 244 -5432, Home 907 - 278 -0430 AOGCC requires 24 hr advance notice of the following operations: AOGCC Contacts: North Slope Inspectors - 907 - 659 -2714, Pgr 907 - 659 -3607 Tom Maunder Anchorage Office - 907 - 279 -1433 2. Clear the rig floor of non - essential personnel while pressure testing and handling explosives if any. 3. Review and implement safe handling and radio silence procedures before handling explosives if any. 4. Perform lockout - tagout, confined space entry, and hot work in accordance with applicable regulations. 5. Calibrate PVT equipment regularly. 6. Hold BOP, H2S, and evacuation drills regularly. Record drills in the IADC book. 7. Have safety meetings regularly and when unfamiliar procedures are being implemented. 8. Use the trip tank on trips and closely monitor breathing, hole fill, and swabbing. 9. Drift all tubulars before they are run in the hole. 10. Caliper all tools before they are run in the hole. 11. Maintain basic fishing equipment on location at all times. 12. Protect the wellhead by installing a wear bushing when possible. 13. Place pipe dope on pins rather than in boxes. 14. Stop and check for flow at the surface casing shoe when tripping. 15. Check the operability of pressure gauges used during pressure tests. Replace if there is any questions about their accuracy. -4- Revision No. 0 Feb 16th, 2004 Total E &P USA Inc. • Caribou 26 -11 # 1 NPR - Alaska, 2004 TOTAL Caribou 26 -11 # 1 General P &A Procedure Review AOGCC, BLM and TOTAL USA P &A Procedures and ensure that all operations will be done in accordance with rules stated in documents. Carefully prepare the P &A operations and make sure that premium cement, C Permafrost cement and all necessary cement additives are available at the rig site. Contact BLM and AOGCC representatives on the Slope with sufficient notice for P &A operations they would like witness. P &A principles All depths are MD/TVD (measured depth) and refer to Rotary Table (RT) The well is almost vertical all the way down, the average inclination is less than 0.5 deg and the maximum horizontal displacement is about 15ft away from original target. - bra \ t"Z, N"> I, 0-'x The Valanginian and Kimmeridgian had some minor gas shows w ' Z "th� silty interval and should be considered hydrocarbon bearing for P &A purposes over the inte al 8993' — 9240'. he whole interval of the Alpine Sands will be sealed off by one cement plug from TD to 1 bove the of reservoir. The Torok can be divided into 2 major intervals. The upper interval is a non - hydrocarbon bearing, but the lower interval is hydrocarbon bearing. Torok — upper interval (7162'— 7436') Non - hydrocarbon bearing Individual sandy units - 7162'- 7216' 7237'-7325' - 7340'-7436' This interval will not be sealed off as being not HC bearing Torok — lower interval (7505'— 7892') Hydrocarbon bearing. Individual sandy units - 7505'— 7625' a __..._..,, ..._............ 7700'— 7892' . -.... W . This interval will be sealed off with one cement plug sefin'fwo stages from 7992' to 7692' and from 7692' to 7405'. The cementing assembly will be kept in hole and the well urry ets enough cond stage will be then pumped on top of the first stage. I s procedure will allow ensuring a good setting of the second stage cement plug. A cement retainer will then be set between 2136' and 2186'. It will be weight tested with the setting string with at least 20KIbs. All liquid mud wastes will be injected below Frac pressure. CN- c'Y, One cement plug will also be set across the 9 5/8" casing shoe through the cement retainer right after the end H of the injection of the liquid mud wastes. When the stinger is retrieved from the retainer, one 50 ft minimum cement plug will be set to cap the retainer. The surface plug ,Will be set 155' to 5' below the ground level. C permafrost type cement will be used. After having nippled down the BOPS, one adapter spool 11" 5K x 3 1/8 5K will be nippled up onto the wellhead that will be left in place. One 3 1/8" 5K x 3" LP companion flange and one 3" LP x Y2' LP bull plug equipped with one needle valve and one pressure gauge will complete the wellhead. Pressure will be observed for about one year before cutting off the wellhead. This will ease future well re -entry should gas migration be observed over the period. -5- Revision No. 0 Feb 16th, 2004 Total E &P USA Inc. Detailed operations 0 0 Caribou 26 -11 # 1 NPR - Alaska, 2004 Plug and abandon of the 8 %" Hole Section A While logging the open hole prepare 100bbls of heavy, viscous mud @ 15.6ppg in the pill pit. When the logging program is completed and the decision to P &A the well is taken the following procedure will be implemented: 1. Run in hole with at least 150 ft of 3'/2' EUE tubing to bottom. Circulate one bottom's up to remove any gas from the well. Condition mud if needed. 2. Cement plug #1 from 9362' to 8893': With the tail pipe near bottom of the well, pump one spacer ahead of the slurry then the slurry weighted up to 15.6ppg and displace with a tail spacer and mud. Fresh water will be used for the spacer. Stop pumping leaving 1 00f of slurry in the string above theoretical top of cement. This procedure will allow the setting of good balanced plug. Disconnect surface lines and pull slowly the string. Pull the string wet. This plug can be set in two stages. 3. Pull the string just above the TOC and circulate out the long way the spacer to limit the EWD below the shoe. 4. When all the spacer is out spot a viscous, heavy pill form 8893' to 7992'. 5. Pull string to 7992' and circulate out the long way excess of heavy mud as for the cement spacer. 6. Cement plug #2 from 7992' to 7405': This cement plug will be set in two stages. First stage will cover the interval from 7992' to 7692'. With the tail pipe @ 7992', pump one spacer ahead of slurry then the slurry weighted up to 15.6ppg and displace with a tail spacer and mud. Fresh water will be used for the spacer. Stop pumping leaving 1 00f of slurry in the string above theoretical top of cement. Pull slowly to 7692' and circulate the long way. When all spacer is out pull one stand and circulate while the cement sets. Wait until the cement gets a sufficient compressive strength (300 psi) as per laboratory test of the slurry. This will allow to properly set the slurry of the second stage. 7. Run back in hole to TOC and proceed to the second stage of cement plug #2. With the tail pipe @ 7692', pump fresh water ahead of slurry then the slurry weighted up to 15.6ppg and displace with a tail spacer and fresh water as tail spacer. Stop pumping leaving 1 00f of slurry in the string above theoretical top of cement. Pull slowly to 7405' and circulate the long way. When all spacer is out pull string to surface laying down excess drill pipe. 1� 8. It is proposed not to tag the plugs #1 and #2 if the above procedure is strictly followed. 9. RIH with EZSV retainer and setting tool on drill pipe to 2186'. Turn string (1 turn per 1000 ft) to the k `� right and lower the string to set the plug. With the stinger still engaged into the retainer, apply 20KIbs down weight on the retainer to make sure it is properly set. Follow Halliburton operator procedure to set the plug. 10. Liquid mud disposal into the well. AOGCC and BLM shall approve the liquid mud wastes disposal permit prior to pumping in the well. This operation will be witnessed by one Agency Representative. A step -rate injection test will be performed prior to pumping the liquid mud wastes. The injection test Lt will be done with at least three different injection rates followed by a fall off (tentatively 0.5 BPM, 1 °L BPM, 2 BPM), to estimate the pressure drop in the string and to calculate the maximum injection rate keeping the bottom hole pressure at an acceptable level. Reminder: The LOT #1 at 2254' gave 14.2ppg EMW while the LOT #2 at 2577' gave 14.Oppg EMW (when referenced to the 2254' depth). 11. Pumping will be done using the rig mud pumps. Keep a chart of all pumping sequences, i.e. rates and surface pressure, liquid weight and all valuable information. 12. When the injection of all liquid mud wastes is completed, mix and spot cement plug #3. Quantity of cement will be adjusted to fill at least 100 ft of open hole. Pump fresh water ahead of slurry then the slurry weighted up to 15.6ppg and displace with mud and fresh water as tail spacer. Stop pumping when spacer is at retainer. 13. Sting out and reverse circulate the spacer 14. When bottom's up is finished position the stinger right above the retainer. Mix and spot all remaining premium cement with a minimum of 50 ft of slurry above the cement retainer. Pump fresh water ahead of slurry then the slurry weighted up to 15.6ppg and displace with mud and fresh water as tail spacer. Stop pumping leaving 50ft of slurry in the string above the theoretical top of cement. Pull slowly to TOC and reverse circulate. When all spacer is out pull string to 155' laying down excess drill pipe. Lay down all DC's. -6- Revision No. 0 Feb 16th, 2004 Total E &P USA Inc. Caribou 26 -11 # 1 NPR - Alaska, 2004 j rOTAL 15. Verify the integrity of the cement retainer. Pressure t st 9 5/8 casing to 1500psi above the pressure to inject the mud in the well less the calculated presrure loss, with a maximum of 4000psi (70% of casing burst) for 10min. 16. Mix and spot 150 ft of C Permafrost cement from about'f5Oftto right below the ground level. Keep two bbls of cement in mixing tank and re- circulate it while displacing and pulling out string. Pump fresh water spacer and adjust volume in order to get the slurry at surface at the end of the displacement. Pull string out of hole. Slurry level will go down when pulling string out of hole. Position the string at TOC (± 15 ft) and fill hole with remaining cement to ground level. Displace all contaminated mud /water above cement slurry with fresh water to clean out BOPE, then open the 9 5/8 annular valve on the casing head and clean hole 5 ft below the valve with fresh water then displace water to diesel to prevent the wellhead from freezing. When hole is filled up with diesel stop pumping and close the 9 5/8" annular valve. 17. Lay down remaining drill pipes in the mouse hole if any. 18. Nipple down BOPE, adapter spool 11" 5k x 13 5/8 1 O and the 11" 5K tubing spool. 19. Nipple up 11" 5K x 3 1/8" 5K adapter spool onto the casing head housing. Nipple up one 3 1/8" 5K x 3" LP companion flange equipped with one 3" LP x Y2" NPT bull plug. Install two needle valves, one Tee and one 5K pressure gauge onto the bull plu�essure test to 4000psi for 10mn through the test port of the adapter spool. 20. End of operations. (i NB: For all slurry formulations please revert to main drilling program rev1 dated January 11 2004 Volume of slurry will be calculated according to caliper from open hole logs (Caliper from first run w/h AIT — PEX (Density — Neutron — GR) — DSI. - 7 - Revision No. 0 Feb 16th, 2004 Total E &P USA Inc. Caribou 26 -11 # 1 NPOlaska, 2004 C>" TAt Note: All referenced depths are MD /TVD RT 8 1/2" Hole Mud left in hole 10.4 Torok Lower Interval,. :' CP #2 Premium cement 15 6ppg : TOC @ 7405' 7505' to 7892', Base of cement plug @ 7992' NI CP #1 TOC @ +/- 8893' WIN Valanginian sands Premium cement 15.6ppg ; ( +/- 100' above the Valanginian Sands) 8993' to 9240' to TD @ 9362' -8- Revision No. 0 Feb 16th, 2004 15.6 '? 9 5/8 "Lead slurry 10.6 ppg �;::'' Top to surface 16 ", 65 #, H-40, PEB Casing @ +/- 109' cemented to surface y 2yi` ., ° a v 20" Hole TAM Port Collar @ 881' 9 5/8" tail slurry 15.6 ppg :; Mud left in hole 10.4 ppg Base Permafrost at +/ -965' Top @ +/- 1050' S 12 1/4" Hole Top of cement plug across retainer (a. 2136' Premium cement 15.6 R, Surface casing Retainer EZSV Type set @ 2186' 9 - 5/8 " 40# L - 80 BTU set @ 2236' w 9 5/8" cemented to surface z !Premium cement 15.6 Base of cement plug across retainer @ 2336' a 8 1/2" Hole Mud left in hole 10.4 Torok Lower Interval,. :' CP #2 Premium cement 15 6ppg : TOC @ 7405' 7505' to 7892', Base of cement plug @ 7992' NI CP #1 TOC @ +/- 8893' WIN Valanginian sands Premium cement 15.6ppg ; ( +/- 100' above the Valanginian Sands) 8993' to 9240' to TD @ 9362' -8- Revision No. 0 Feb 16th, 2004 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ON AN ULAR DISPOSAL APPLICAT N 20 AAC 25.080 1. Operator Name: TOTAL E &P USA, Inc. 3. Permit to Drill No: 203 -196 4. API Number: 50- 279 -20009 2. Address: 4300 B Street, Suite 303 5. Well Name: Caribou 26 -11 #1 Anchorage, Alaska 99503 6. Field: Wildcat 7. Publicly recorded wells 8. Stratigraphic description: a) Interval exposed to Base Nanushuk Topset Sands, Torok Shale, a) All wells within one- open annulus: Slope "A" Cretaceous Sands, Lower Torok quarter mile: None Shale b) Waste receiving Nanushuk Topset Sands zone: b) water wells within one mile: None c) Confinement: Top: Shales within and overlying Nanushuk Topset Sands Bottom: Torok Shale 9. Depth to base of 10. Hydrocarbon zones permafrost: 600' RT above waste receiving zone: None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: No previous disposal in well 8.5 -12.0 ppg (avg. 11.0 ppg) 2,288 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: Approximately 2,400 bbls Drilling mud and minor amounts of arctic grade diesel used for freeze protection of the annulus receiving injection. RECEIV 16. Estimated start date: Within the first 2 weeks of March, 2004 JAN 0 8 2004 Alaska Oil & Gas Cons. Commission 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ❑ Anchorage FIT Records w/ LOT Graph ❑ Surf. Casing Cementing Data ❑ Other ❑ FIT /LOT and surf csg cementing data to be submitted when available. 18. 1 hereby certify that t77Phone correct best of my knowledge. Signature: Title: Drilling Manager Printed t �Cf ��� b Name: Jean - Francois Prost Number: 907 - 743 -0970 Date: Commission Use Onl Conditions of approval: (7� LOT review and Subseque e red: Approval number: Approv, d BY ORDER OF THE A d COMMISSIONER COMMISSION Date: G� Form 10 -403AD Rev.9 /2003 FINIAL , 1 INSTRUCTIONS ON REVERSE 23 Submi in Dupli e �Y 2� CARIBOU 26 -11 #1 • DISPOSAL OF DRILLING WASTE The following information is provided in support of TOTAL's request for authorization for disposal of waste drilling mud through injection down the 9 -5/8" x 7" annulus or, if 7" casing is not set, below the 9 -5/8" casing in the Caribou 26 -11 #1 well in accordance with AOGCC Regulations in Title 20, Chapter 25, 20 AAC 25.080. 1) Well to receive drilling waste: Caribou 26 -11 #1 (9 -5/8" x 7" annulus or, if 7" casing is not set, below the 9 -5/8" casing. The 9 -5/8" casing will be set at an approximate depth of 3,034'RT.) 2) Depth to base of potable freshwater aquifers: There are no potable fresh water aquifers at or near this location. Permafrost exists from surface to approximately 600' below ground level. 3) The interval exposed below the shoe of the 9 -5/8" casing will be the bottom + 200 feet of the Nanushuk Topset sands, underlain by several thousand feet of the massive Torok Shale which is in turn underlain by the Slope "A" Cretaceous sands and the Lower Torok shale. See the attached stratigraphic column. The top of the 7" cement is planned to be in the middle of the Lower Torok shale. The receiving zone will be the lower Nanushuk Topset sands. Injection into this interval will be bounded at the top by shales within and overlying the Nanushuk sands. It will be bounded at the bottom by the Torok Shale at ±3,234' and the higher pore pressures in the sands that commence more than 2,500' below the top of the Torok shale. 4) There are no publicly recorded wells within one - quarter -mile of this location, nor are there any publicly recorded water wells within 1 mile of this location. 5) The waste to be injected will be used drilling fluid. There may also be a small amount of arctic grade diesel oil injected that is used a freeze protect fluid in the annulus receiving the injection. While the injected drilling fluid will contain formation fines resulting from normal drilling operations, the injectant will not contain cuttings intentionally ground at the surface for disposal. All such rock cuttings will be hauled to the Kuparuk/Prudhoe oilfield infrastructure for grinding and disposal at appropriately permitted facilities there. The estimated volume and maximum density is 2,400 barrels and 12.Oppg. This volume is twice the calculated hole volume at TD plus 500 bbls of active mud system in the surface mud system plus 500 bbls of waste mud stored at the surface. The excess hole volume calculated reflects the possibility of the open Injection Application.doc Page 1 of 4 01/2004 CARIBOU 26 -11 #1 • DISPOSAL OF DRILLING WASTE • hole (if 7" casing is not run) being washed out and significantly larger than gauge. The average slurry density is anticipated to be approximately 11.0 ppg. The maximum volume to be injected under any anticipated circumstances will not exceed 35,000 bbls. 6) Drilling wastes to be injected will be the drilling fluids used for drilling the well and associated rheologic modifiers, minor amounts of excess cementing materials, snow and wash water, and other as allowed under (h)(3) of AOGCC Chapter 25, Regulation 20 AAC 25.080.7). Also, minor amounts of freeze protect arctic grade diesel used specifically as part of this disposal process, will be injected. 7) The maximum anticipated pressure at the 9 -5/8" casing shoe during disposal operations will be at or near the formation fracture pressure of 2,288 psi (14.5 ppg EMW at the casing setting depth of 3,034'RT). The injection pressure during disposal operations may slightly exceed the original fracture pressure at times due to injected fines plugging off established fractures and having to re- fracture or otherwise overcome the tendency of the formation face to sand off. The maximum anticipated surface pressure during disposal operations is calculated as follows: = Fracture Pressure + Friction Pressure Losses - Hydrostatic Pressure _ (3,034') (14.5 ppg) (.052 psi /ft -ppg) + 100 psi - (3,034') (8.6 ppg) (.052 psi /ft- ppg) = 1,031 psi This calculation is for the worst case (highest pressure): the average injection interval depth to be 3034', maximum friction pressure losses to be 100 psi, and fresh water is the least dense fluid to be injected. 8) The 9 -5/8" casing will be set at ±3,034'RT, approximately 2,400' below the base of the permafrost. The cement volume for this casing string will be sufficient to bring it to the surface. A. Cementing records for this casing string will be submitted immediately after the casing is cemented. B. A cement quality log and /or formation integrity test record will be submitted as soon as such logging or testing is completed. 9) Casing Safety Factors during Injection below 9 -5/8" casing. If 7" casing is run, injection of fluids will be down the 7" X 9 -5/8" annulus. This will expose the 9 -5/8" casing to its maximum bursting stress at the casing shoe (surface injection pressure less friction loss plus the difference between the Injection Application.doc Page 2 of 4 01/2004 CARIBOU 26 -11 #1 • DISPOSAL OF DRILLING WASTE hydrostatic pressure of the injectant and the formation pore pressure behind the casing just above the shoe). The 7" casing will be exposed to its maximum collapse pressure at the surface (surface injection pressure with no hydrostatic or backup pressure inside). If 7" casing is not run, injection will be down the 9 -5/8" casing and the maximum bursting stress will remain at the casing shoe. The 9 -5/8" bursting stress and burst safety factor are calculated as follow: Burstinq Stress = Surf. Injection pressure — friction pressure losses + (hydrostatic pressure of injectant at shoe — formation pore pressure at shoe) = 1,031 psi — 100 psi + (3,034' x .052 x (12.0 ppg — 9.0 ppg)) = 1,404 psi Safety Factor = Burst rating of 9 -5/8" casing / Bursting stress = 5,750 psi / 1,404 psi MEHM The 7" collapse stress and collapse safety factor are calculated as follow: Collapse Stress = Surface injection pressure = 1,031 psi Safety Factor = Collapse rating of 7" casing / Collapse stress = 5,410 psi / 1,031 psi = 5.25 10) The downhole pressure obtained during the LOT /FIT at the 9 -5/8" casing shoe will be submitted to the AOGCC and BLM as soon as it is obtained. 11) All hydrocarbon- bearing zones above the 7" casing shoe (if run) will be identified. If 7" casing is not run, all hydrocarbon- bearing zones will be identified and abandoned with cement per AOGCC regulations prior to commencement of disposal operations. Injection Application.doc Page 3 of 4 01/2004 CARIBOU 26 -11 #1 • • DISPOSAL OF DRILLING WASTE 12) The duration of disposal in this well is not anticipated to exceed 30 days. 13) No drilling waste has previously been disposed of in this well. 14) All drilling waste to be disposed of in this well will be generated during the drilling of this well. 15) TOTAL intends to comply with all limitations established in 10 AAC 25.080(d). 16) TOTAL will, to the best of its ability, provide any additional data required by the Commission to confirm containment of the drilling waste. Injection Application.doc Page 4 of 4 01/2004 CARIBOU 26 -11 #1 FORMATION TOPS 10 -17 -03 AGE Aptian ? I W �a W �v 1'i, I U) i PERIOD LITHDFPTr Potential Hazards Formation, Lithology, Depth Colville Group Conglomerate Approx. Base Permafrost . •.; Gravels, Sands, Silts, Clay, 600' is depth of potential high pressure anomaly at and Coal beds Cenomanian ? 1,000 base of Permafrost near at Hunter well location @ Surface Albian ? Nanushuk Topset Sands - 1,484' RT ctiyc -z,000 Potential Gas sands noted in Hunter Well prognosis @ a depth of 2,260' 3 Barremian ? O J Hauteriv Valanginian Kimmeridgian i Oxfordian I Aalenian Torok Shale - 3,234' RT (90% Sh 10% Sd) Base of Slope "A" Cretaceous Sands Lower Torok Shale Base of Slope "B" Cretaceo Sand _HR /Pe bble Sh LCU°6 Valangmian Sh l=u Tian ian Triassic - 5,884' RT - 6,484' RT - 7,334' RT • - 8,046' RT - 8,286' RT -8,831' RT - Primary Objective - 8,981' RT —` "A Sand" Located � - 9,134 'T AI p - 9,334' RT within Channel Fill - 10,724' RT - 11,024' RT Top Overpressure Cell I TOTAL Rig: Nabors Alaska Rig 14E Spud: Estimated Feb 09, 200 16 ", 65 #, H -40, PEB Casing @ +/- 109' Base Permafrost at +/ - 600' 12 1/4" Hole Surface csg. 9 -5/8 " 40# L -80 BTC Casing @ +/- 3034' TOTAL E &P USA Inc. Caribou 26 -11 #1 Proposed Wellbore Schematic NPR - Alaska ELEV 204' AMS S 4 RF 29' Note: All referenced depths MD /TVD RF • SE 26 I Twp 1 ON I Rng 5W 3691' FEL 1 1373' FSL aim Mno a TAM Port Collar @ 850' Top of tail slurry @ +/- 2400' 9 5/8" casing cmtd to surface 8 1/2" Hole TOC @ +/- 6,383' ( +/- 100' above the Lower Torok) Top of tail slurry @ +/- 8681' ( +/- 300' above top of Alpine Sand) 7" 26 # L -80 BTC -M Casing at 9583' TD TD @ 9,583 TVD /MD B'" P° °se 'M�-A TOTAL ESOP USA, INC. January 9, 2004 Ms. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 • RE: Application for Annular Disposal Permit: TOTAL Caribou 26 -11 #1 Dear Ms. Palin, TOTAL E &P USA, Inc. hereby applies for an Annular Disposal Permit to inject used drilling mud into the Caribou 26 -11 #1 exploratory well after drilling operations are complete. Injection is expected to commence in the first half of March, 2004 and last less than 30 days. A 9 -5/8" surface casing will be set at ±3,034'RT and cemented to the surface. An 8-1/2" hole will then be drilled to TD. If the initial evaluation of the wellbore in the target interval is sufficiently encouraging, 7" production casing will be run to TD and disposal of used drilling fluids will be via injection down the 7" X 9 -5/8" casing annulus. However, if the initial well evaluation indicates that an immediate P &A is advisable, all hydrocarbon- bearing intervals will be abandoned per AOGCC regulations, then the waste mud will be injected down the 9 -5/8" casing before continuing to P &A the well per regulations. In both scenarios, the waste receiving zone is the same. Attached find a stratigraphic column and planned wellbore schematic for the Caribou 26 -11 #1 well. Casing cementing data for the 9 -5/8" surface casing and FIT /LOT records obtained at the 9 -5/8" casing shoe will be submitted as they become available. The AOGCC is requested, to the extent possible, to keep confidential all information included in this application as the information in these documents is drawn from research and data proprietary to Total. If you have any questions or require additional information, (907) 743 - 09 Sincerely,_ . Jean - Francois Prost Drilling Manager Alaska Oil at Gas Cons. Commission Enclosures 4300 B Street, Suite 303, Anchorage, AK 99503 TOTAL. Tel 907 743 0970 -Fax 907 743 0979 ORIGINAL please contact me at JAN 0 8 2004 Anchorage Feb 13 04 04:56p TOTAL E &P USA, INC (907) 743 -0979 • TOTAL. E &P USA, INC. To State of Alaska Name Tom Maunder, AOGCC Fax Number (907) 276 -7542 Phone Number GSR/ALSKI057104 ............................................................................................... From ............................... TOTAL E &P USA, INC. Name Jean -Yves Bellanger Fax Number (907) 743 -0979 Phone Number (907) 743 -0970 E -Mail Jean- yves.bellanger @total.com ............................................................................................... Date ............................... February 13th, 2004 Number of pages 2 ............................................................................................... ............................... Subiect Caribou 26 -11 #1 9 5/8" Casing pressure test ............................................................................................... ............................... Dear Sir Please find attached the 9 5/8" casing pressure test chart you required. Please note that the casing pressure test was performed with the HP pump and this made unavailable pumping sequence data. Best regards Jean -Yves Bellanger Drilling Engineer Total USA - Alaska p.1 , I ToTAt- 4300 B Street, Suite 303, Anchorage, Alaska 99503 Tel: (907) 743 -0970, Fax: (907) 743 -0979 FEB x - 200 „ Re: Permafrost 0 0 Subject: Re: Permafrost From: JOHNS John <Jo1m.J0HNS@tota1.com.> Date: Fri, 20 Feb 2004 12:58:46 -0600 To: steve_davies adrnii.state.ak.us Steve, We reviewed the LWD logs and processed sonic data to establish the base of the permafrost. The Geophysicist and I are placing the base at 915' md, based on the sonic and resistivity characteristics. Sperry-sun personnel have reviewed the data and come up with depths between 925' and 960' md. There appears to be a sharp sonic and resistivity contrast at 915'md (hard base) and transition zone down to 960' md. Is this sufficient for your needs? best regards, John W Johns Total E &P ITSA, Inc. Office: (713) 647 -3435 john.johns @total.com Stephen Davies < steve_davies @admin.state.ak.us> To: 02/20/2004 12:24 PM cc: Subject: John, JOHNS John <John.JOHNS @total.com> Permafrost What is your estimated depth to the base of permafrost in the Caribou well? I believe you told me already; unfortuately I don't remember, and I shredded the phone notes I jotted down when we spoke. Thanks, Steve Davies AOGCC 1 of 1 2/20/2004 10:26 AM Re: Caribou 26 -11 #1 Step -Rate Test Procedure • Subject: Re: Caribou 26 -11 #1 Step -Rate Test Procedure From: Thomas Maunder <tom_maunder@a admin.state.ak.us> Date: Fri, 20 Feb 2004 07:34:07 -0900 To: Bill Penrose <hil1 @f'airweatbcr.com CC: "Jean - Francois Prost (dean- franeois.prost�,?a total.com)" <jea - ftancois.prost total.com >, "Joan -Yves Bel anger Ocan- ves.bellan er a total.com)" < jean -yve .bellan er@total:eom >, Stan Porhola <Starl Porhola ak.binLgov> Bill, Jean -Yves and All, The proposed step -rate test procedure is acceptable. Tom Maunder, PE AOGCC Bill Penrose wrote: Tom, Here's the step -rate test procedure to be used prior to commencing annular disposal of waste muds in the subject well. Regards, Bill C P 1 of 1 12/22/2005 12:04 PM Caribou 26 -11 #1 Step -Rate Test for Annular Injection Discussion Before placing a P &A cement plug across the shoe of the 9 -5/8" surface casing in this well, the liquid mud in the pits as well as any other liquid mud from this well that is stored on location will we injected into the Lower Nanushuk sands just below the casing shoe. Prior to commencing large -scale injection of mud, a step -rate test must be performed so that the Sate or Federal agency representative on site can determine the maximum injection rate allowable. The following is the procedure for the step -rate test. Considerations A minimum of three, and ordinarily a maximum of five, rate - and - pressure -pair points are required. The stabilized rate and pressure are always included as the first point. At least three points are needed to reveal the character of a curve. Five points are usually enough to ensure that a large enough rate change exists between points to emphasize any water hammer effects that might be present. Job Procedure 1) Pressure test surface lines. 2) Establish minimum pump rate and gradually increase it to 0.5 bpm and hold until pressure stabilizes. 3) Record first rate and pressure pair. 4) Increase the pump rate in 0.5 bpm increments (check for changes in the slope of the pressure curve at stable rates). 5) Plot pair points on a pressure- versus -rate graph and determine fracture extension pressure. FW: FW: Forward Operations at Caribou Subject: FW: FW: Forward Operations at Caribou From Bill Penrose {bill@£airweather.com> Date: Thu, 19 Feb 2004 07:15:27 -0900 To: "Tom Maunder (tom maunderC"@admin.state.ak.us)" <tom maunder@admin.state.ak us> Tom, FYI 1-111 - - - -- Original Message---- - From: BELLANGER Jean -Yves [mailto :Jean- Yves.BELLANGER @total.com] Sent: Wednesday, February 18, 2004 5:20 PM To: Bill Penrose Subject: Re: FW: Forward Operations at Caribou Bill I'm working on that with Halliburton As soon as we have the procedure set up I will revert to you. Regards JEAN -YVES BELLANGER TOTAL E &P USA, Inc Tel (1) 907 743 0970 Cel (1) 907 317 7850 Fax (1) 907 743 0979 e -mail <<jean- yves.bellanger @total.com>> Bill Penrose <bill @fairweather.com> To: "Jean -Yves Bellanger ( jean- yves.bellanger @total.com)" <Jean -Yves. BELLANGER @total.com> 02/18/2004 10:38 AM cc: "Jean- Francois Prost Qean- francois.prost @total.com)" <Jean- Francois.PROST @total.com> Subject: FW: Forward Operations at Caribou Jean -Yves, See the note below from Tom Maunder. It's very encouraging. In the last line, however, he requests that TOTAL prepare a design for the step -rate test to be conducted at the start of waste mud injection. He says that submission of the step -rate test design will make the injection approval move more quickly. Presently, the test is addressed in Steps 10 and 11 of the P &A procedure. Would you like me to send those steps to him or would you prefer to formalize it and add more detail before submitting it? I suggest the latter. Regards, Bill Nn� C_ 1 of 2 12/22/2005 11:55 AM Forward Operations at Caribou • • Subject: Forward Operations at Caribou From: Thomas Maunder <tom maunder @admin.state.ak.us> Date: Wed, 18 Feb 2404 10:29:12 -0900 To: Bill Penrose <bill@ fairweatler.com> CC: Jim lt.egg <jimn Gregg @adman.sta#e.ak.us >, Steve Davies <steve davies@admn.state.ak.us> Bill, I am writing this note with regard to the possible forward operations at the Total well. This is in particular regard to the proposed annular disposal operations. It appears that we have sufficient information to recommend that the Commissioners approve the proposed activity. The only remaining issue is whether production casing is set. If production casing is set, then operations would be "normal ". If it is elected to P&A the well, some P&A plugs will be set in the open hole before the disposal operation can begin. In either case, a condition of the approval will be perform a step rate test to characterize the open hole performance prior to beginning the full disposal operation. Thus far, the pressure response of the some 250' of open hole has been determined at about 1/2 bpm pumping rate. It is unlikely that the ultimate disposal will be conducted at such a low rate, so the requirement would be to determine the open hole pressure response to increased pumping rates more representative of the potential disposal rate. The goal of the determination would be to demonstrate that the wastes are confined and that an uncontrolled fracture is not initiated at the proposed pumping rates. It is requested that you contact Total and determine a design for such a step rate test. Please call with any questions. Tom Maunder, PE AOGCC 1 of 1 2/18/2004 10:44 AM Re: Caribou Well BOP Subject. Re: Caribou Well BOP From: Thomas Maunder <tom maunder a@admin.state.ak.us> Date: Wed, 18 Feb 2004 09:25:05 -0900 To: James Regg <jim Gregg @admin.state.ak.us> This is news to me. I don't remember anything about only function testing the IBOP. I wonder why this didn't come up as an issue in the initial test when JC was out there ?? I did know they planned the odd kill line that JC mentioned, but our regulations do allow such between the rams. Tom James Regg wrote: Jeff called yesterday about BOP test; he apparently received call from Mike Whiteley (Operator's Rep) at Nabors 14 (Caribou well). From what Jeff explained to me, it sounds very much like the IBOP is similar to what Anadarko was using - no way to pressure test the device. Went back and checked their last BOP test and sure enough, they only function tested the IBOP. Curious if Total has a waiver from requirements of 20 AAC 25.035(e)(9)(B)? Jeff was told by Mr. Whiteley that Total's policy was to not use the IBOP (like that matters). Thoughts? Last BOP test (2/12/03) attached. Jim 1 of 1 12/22/2005 11:54 AM STATE OF ALASKA - 1128/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim re a�,Dadmin.state.ak.us aogc^prudhoe o :vCad:n:n.sta e.ak.0 s bc-b ,:Dadmin.state.ak.us Contractor: Nabors Rig No.: 14 DATE: 2/12/2004 Rig Rep.: Jim Davidson Rig Phone: 339 -1800 Rig Fax: 339 -1802 Operator: Total E &P Op. Phone: Op. Fax: Rep.: Mike Whiteley Field /Unit & Well No.: Caribou 26 -11 #1 PTD # 203 -196 Meridian: U.M. Location: Section: 26 Township: 10N Range: 5W Operation: Drlg: Workover: Explor.: x Test: Initial: Weekly: x Other: Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Quantity Test R Upper Kelly P Lower Kelly P Ball Type P Inside BOP function test Lower Pipe Rams Test Result 31/2-6 Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P 2 3 BOP STACK: Check Valve 1 3 Quantity Size Test Result Annular Preventer 1 13 5/8 5M P Pipe Rams 1 4 P Lower Pipe Rams 1 31/2-6 P Blind Rams 1 P P Choke Ln. Valves 2 4 P HCR Valves 1 4" P Kill Line Valves 2 3 P Check Valve 1 3 P MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: Quantity Test Resu No. Valves 17 P Manual Chokes 1 P Hydraulic Chokes 2 P ACCUMULATOR SYSTEM: Time /Pressure Test Resu System Pressure 2800 P Pressure After Closure 1700 P 200 psi Attained 42 P Full Pressure Attained 3 min P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 2100 Test Results Number of Failures: 0 Test Time: 8 Hours Components tested 32 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: jim regg.�,D dmin.state.a>i.us Remarks: 24 HOUR NOTICE GIVEN YES X NO Date 02/10/04 Time 16:00 Test start 05:30 AM Finish Waived By Jeff Jones Witness BOP Test (for rigs) BFL 1/28/04 2004 -0212 BOP Nabors14 Caribou 26- 11 #1.xls TOTAL ESOP USA AC. February 11, 2004 Mr. John Norman, Chair FEB 11. 2004 Alaska Oil and Gas Conservation Commission AlaOii OW P GaS u'W 333 West 7 Ave., Suite 100 Afv:hofigf Anchorage, Alaska 99501 RE: Supplemental Information Application for Annular Disposal Permit: TOTAL Caribou 26 -11 #1 Dear Mr. Norman, Pursuant to our application for an annular disposal permit submitted on January 9, 2004, TOTAL E &P USA, Inc. hereby submits the remainder of the information required in 20 AAC 25.080. Casing Cementing Records 9 -5/8" surface casing was set at 2,236'RT and cemented to the surface with good returns observed throughout the cementing job. Records generated during the cementing job are enclosed. Leak -Off Tests After setting the 9 -5/8" casing, two leak -off tests were conducted, one at 2,254', just under the casing shoe, and the other at 2,577'. Both yielded substantially the same results: 14.2 ppg EMW and 14.0 ppg EMW, respectively. Leak -off test documentation is enclosed. Formation Water Salinity Determination The salinity of the formation water contained in the 10 -foot sand member immediately below the casing shoe was calculated to be 10,800 ppm chlorides, which correlates moderately well with the more saline offset well North Inigok #1. The formation water salinity determination report is enclosed. Stratigraphic Tie Enclosed is a log section obtained via LWD in the Caribou 26 -11 #1 well. On it are indicated the following points of significance: Top Nanushuk Sands 1,675' 9 -5/8" Casing Depth 2,236' Injectant Receiving Zone 2,325'— 2,335' Top Torok Shale 3,122' 1 4300 B Street, Suite 303, Anchorage, AK 99503 TOTAL Tel 907 743 0970 - Fax 907 743 0979 T®TAL ESP USA 19C. 0 Mr. John Norman February 11, 2004 Page 2 of 2 For comparison, the Nanushuk Sand and Torok Shale tops occur in the offset wells as follows: Nanushuk Sand Inigok #1 1,925 N. Inigok #1 1,610 Torok Shale 3,355' 2,830' It is our understanding that with this submittal, the information requirements of 20 AAC 25.080 have been met. However, TOTAL holds itself available to submit any other information the Commission may need in order to determine that the requested annular disposal permit be issued. The AOGCC is requested, to the extent possible, to keep confidential all information included in this application as the information in these documents is drawn from research and data proprietary to TOTAL. If you have any questions or require additional information, please contact me at (907) 743 -097 ?. Sincerely, Jean- Francois Drilling Manager Enclosures q r: 4300 B Street, Suite 303, Anchorage, AK 99503 TOTAL Tel 907 743 0970 - Fax 907 743 0979 • • Caribou 26AW Casing and Cementing Report NPR-Alaska FEB 1 1 2004; 9 618 Surface Casing 'I ska Oil & Gas Cons, C: Rig Floor to Ice Pad 2927 Casing Set Depth 2236,M Anchorage Rig Floor to GIL TbTAk t- w-I& Depth MD 2243.00 item No. Desert ion Grade Flout Shoe 1 9 5/8" Shoe Jt L-80 2 9 5/8 Shoe Ji L-80 Float Collar 3 9 5/8" Casing L-80 5 9 518" Casing L-80 X.14"Aft-4 WINNOW 7 0 SW Casing L-40 g 5/8" sin L-80 9 W K-M I NAr 9 l-vt vT 11 9 5/8" Casing L-80 13 9 5/8" Cast L-80 W J1�10. &I 15 9 518- Casing L-80 17 9 5/8" Casi L-80 19 9 5/8" Casing L-80 21 Q 518" Cl- L-80 ' MEN 23 0 5/8" Casing L-eo Bill: 25 9 5/8" Casing L-80 27 9 51V' Casing L-80 29 9 5/8" Casing L-80 -410 NOW Mg 31 0 6/8' Casing L-80 33 9 SIB" C!stM_ L40 34 9 518 Casing 36 9 5/8" Casing L-80 Running Conn Le Depth Set DOW Notes BTC 172 1.72 OTC 40.12 41.84 2194.22 Cent i a4d]* & t ,10 1 ) I:f' OTC 38.22 80,08 21 58.00 Centraiii ai" 5 $100 1 OTC 1.21 81.27 2154.79 STC 41,38 122,65 2113.41 Cell SOP -2 OTC x 40.72 201,37 2034.89 OTC 40.44 283.49 y 1962.57 Centfaliza" V BTC 41.52 365.57 1870.49 W 100 BTC T . 0 x 41.67 448.53 1787.53 Centralt iv BTC 41.01 531.14 1704.92 MW& aftPiN10 W BTC 37.90 616,96 1625-18 Cer1A1d13z*'-1- "gig A MW OTC 41 86 0",22 1541. B T C - . 41.63 777.21 1458.85 CerIll'8 14(f w4 OTC - 41.28 880 14 1 375 92 -Al VIC T-1: ski r 10 V OTC 40.89 48 - 1293.50 C"efdvaliier OTC 40.82 1023 . 67 1212,39 P' MIX C 41 Ge 1107.03 1129.03 Centi'alizel N Rig- MMY go W BTC 1 186.97 `104 W-4 w 5 Centralizer OTC 1276.31 965. 41.67 M Y . -21"Aw"t. 8TC; 39.8 1351.39 884.87 NMI l OTC 40.37 1394.73 841.33 N OV M OTC 39.38 V 1475,14 780.92 T 13 1 'A ZORTF-22i06 noqiz!jt1o Wd vv:Ee • • 38 9 518 Casing L -80 BTC 40.87 1557.62 878.44 Gen Iiali v, '.Ta �J X77 Q VN'81t L - 80 ..' i �17�}:17� _ { C!'� •. /�i ,'• ? ,rn�.. .e T r j .' ? 4D 9 518 Casing L -80 BTC 41 43 163 597.21 41 ' . ,( Cb381r1, .. r _yam ^`ttrc,' �7 i,LJ B• sih . ;rt: r dr''.. �� 42 9 5i8' Casing 80 BTC 4048 172 0.28 815.78 Centralize "I. 44 9 518 Caslny L-80 BTC 1802.76 433.30 - . �,. 45 p av t yy q-t _ v �, b! p f' ��t.,, r, N'�� ✓f7f. .� ».., 68 9:5/8 Casing 4- BTC 40A 1864.27 351.79 Centralizer 76 9 516" Gasbag 4.; '. B'CC 40 33 .; ;' 0 l ' 1 601 48 9 518" Casing L-86 BTC 40 333 1964.90 271-18 �c ��� �- X..ae~ �" �yypg p `r 'Y�i "F � b � . � } 73 .4.,10, •,'. :, . yr 9 518" Casing L40 C: iii 06 2045.75 190.31 Centralizer 55 9 5 18" Casin6l' L-80 STO 40.3 2086.14 149.92 58 9 W8" Casing . ; L-�. 38:40' 2124.54 111.52 71 . 9 5/8" Casing L Ql1 1TL 39.50 2164.13 71,93 72 Mao 9 5l$" Casi ' L•0: !l;' 2203.09 32.97 Cementin Inform atlon Hold PJSM. RU cementing equipment and lest lines to 3000 psi. Pump 5 bbl wtr and 45 bbis NSCI spacer w/ 1 gal red dye. Drop bottom plug. Mix and pump 200 bbis of Permafrost L lead cement followed by 71 bbl Premium tail. Drop top plug and displace w/ 25 bbis fresh wtr and 1675 stks mud. Calculated washout based on sweep was 9.3%. Maintain good circulation throughout job. 130 bbls cement to surface which is very close to calculated value. Displace plug with rig pumps. Did not bump plug on time and elected to shut down. Subsequently tag TOC (g 2070 Calculated rig pump efficiency was poor at 89 %. Centralizers and stop rings as noted above .'0'd Z0211S22406 n0al?30�) Wd : ?b: 20 Job Data L sting Totai Surrace Pit Cemwin v1 5 0 . �� Z08Tbz�Z06 n0$I?Jtl�'�tillll wa 0 a ree�- 9e -x3� Total Time Pressure Rate Density Volume 1r► 7:mm:ssp 1ps tn� iolYa: (b ates 1:54:41 Event Star. Job 2:06 2 O. DC 0.00 0.00 2:06:18 Event I Pump Spacer 1 2:07:00 1 0.00 6.41 0.00 2:06:00 13 0.84 9.04 0.42 2:09:00 8 0 0.90 9.03 1.28 2:10 00 97 1.05 9.11 2.29 2:11:00 135 1.95 9.07 4.03 2:12'00 59 0,00 9,11 5,08. 2:12:17 Event Test Lines 213:00 59 coo 8.29 5.06 2:14:00 '60 0.00 &,34 0.00 2:15 :00 gtil2;. 0,04 8:40 0.06 2.16:00 2616 000 8.40 0.06 217:00 28 0.00 8.34 0.06 2 Event Pump Spew 2 2:19:00 32 0.00 8.29 0.00 2:20.00 90- 0.9 8.23 0.75 2 23:00 94 0.84 8.22 139 2:24 :00 as 0.63 8.24 4.20 2.27:00 38 0.00 8.32 5.1 2'28 :00 27 0.00 8.23 3.14 2:31:00 92 C 69 823 687 2 32:00 92 0.63 8.09 7.50 235:00 93 0.69 623 7.84 2.36:00 149 1.85 8.30 8.41 2:37,3+4 Event Pump Spacer .2 2 38:00 316 406 8.37 6.34 2139:00 341 385 10.11 10.49 2AQ:0 1172 4.116 10.25 14.40 2'41:00 480 5.06 9.77 19.16 2 00 480 5 17 971, 2429 243:00 496 5.27 10.20 29.54 2 4 7 5.22• Ip.07 3474 2:45:00 433 6.04 10.12 39,83 246:00 445 4.75 10.10 44.71 Z47:00 396 459 971 49.41 2:47:43 Event Drop bottom Plug 247:50 Event Pump Lead Cement 2:48:00 55 0.00 948 0.00 249:00 50 0.00 9.78 0.00 2:50:00 43 0.00 992 0.00 251:00 44 0.00 10.06 0.00 2:52:00 288 3.69 10.73 184 Z53:00 328 4.38 11.02 5.96 2.54:00 429 4.90 10.95 10.57 2:55= 393 5.27 10.95 16.45 2:56:00 388 523 11.05 21.69 �� Z08Tbz�Z06 n0$I?Jtl�'�tillll wa 0 a ree�- 9e -x3� Job Data Living Total Surface Pip* CemWln v1.5.0 • 0� Z0ET6£�L06 noaI"A LJd TS :c ._. 0 t'0BZ- 90 -£Ta - ?ota� Time Pressure Rata Density Volume (hh:mm:ss) (psi) (bpm) 1b/ al bI bl) 2:57:00 395 5.17 11.18 2688 2 58:00 382 5.17 10.81 3203 . 2:59.00 396 511 10.89 3714 3:OO:QQ 3a2, 5,06 10.76 43.22 3:01;00 412 4.96 %71 4718 302:00 337 506 10.68 52.19 3.03.00 424 506 10.81 57.21 104:00 402 511 10.73 62.36 3:0500 344 5.11 10.68 67.47 3:06:00 378 5.22 10.82 72.53 107:00 439 5.80 10 70 7804 3:08:00 429 5.43 1074 83.68 3; 09'00 397 5.36 10.71 89.12 3.10:00 379 543 1084 94.52 3 427 533 1073 9989 3:12:00 410 5,54 10,55 105.29 3:13:06 425 5,75 10.70 11091 3:1400 396 554 10.73 116.64 3.15:00 387 5.48 10.79 122. 3,18:00 379 $.68 10.60: 1 .27.65 3:171 379 6.89 10.78 13132 3:18.00 346 564 10.76 139.03 3.19.00 392 5.54 10.86 144.70 3:20,00 379 5.80 10,76 150.38 3:21.00 370 5.80 10.65 156.20 3 22 00 372 5.75 1C.79 161 97 3:23:00 352 5.96 10.74 16778 3134,00 363 5:8b 10 .65 : 1`73.68 310:00 384 5:96 °ltJ:68 17956 326:00 436 5.85 10.76 185.39 3:27:00 4 5 9 1056 191.30 3:38:00 407 5,75 10.60 187.13 3 :29:Q41 413 5.75 10.86 202.82 3:30:00 384 580 10.49 208.59 3:31.00 54 3.22 8.89 2142 3:31 37 Event Pump Tail Cement 3:32:00 124 2.43 11 83 0 21 133 00 537 5.48 15.07 407 3'34:00 786 5:64 15.70 10.20 335,{10 38i 6;64: 16.32 15,89 3 36.00 825 5.80 15.32 21.56 3:3700 581 5.75 15.97 27.28 3,38:00 623 5.17 15.85 3278 3:39}00 591 5.01 1562 3789 340:00 584 827 1556 4309 3.41:00 623 5.17 15.81 48.32 342:00 669 5.43 15.41 53.47 3 43:00 720 5.84 'S.96 $9.05 0� Z0ET6£�L06 noaI"A LJd TS :c ._. 0 t'0BZ- 90 -£Ta - • • ng Tctai Surface Pipe CemWin v1.5.0 3 Totai Time pressure Rate Density Volume 3:44:00 939 6.33 16.20 64.85 3:45:00 920 6.33 16.14 71.17 3:45:00 Event brop 'fop Plug 3:49 :00 Event Pump Displacement 3:49:00 115 1.27 11.38 015 3:50:00 118 2.53 91 , 73 2.46 3:64 109 Z '63. 5.19 5.00 3:52:00 414 5.85 8.99 9.07 353:00 75 1.79 8.76 12.36 3:54 !g0 97. 2.37 0,84 14.36 3!65:00 258 4.75 6,53 17.96 3156.00 330 4.96 8.57 22.92 3:57:00 341 5.06 8.42 27.90 3:59:18 Event Rig Pump Displacement 3 02:20 02.40 innipm - - - - – - — Customer: Total UP Inc. WeH Desenpuon: Canbou I A Ralf (bput) C Total Volume (bbl} — C D 26 500 A, !2 400 10 � 18 300 16 14 200 12 lo i-loo 6 0 03:00 0320 03:40 04. Job Date: 02 TiclrA 4: 2871392 Performed for W Jim Rom QMWOVI-1-0 i w4m-0413:46 rl tj bd C G. ri co A B DewitY (lb Wpath 5000 -7= % 2 ; 4000-, 71 3000._ i . 2000-4 4-:; I 3- 1000 2. 0 0 02:20 02.40 innipm - - - - – - — Customer: Total UP Inc. WeH Desenpuon: Canbou I A Ralf (bput) C Total Volume (bbl} — C D 26 500 A, !2 400 10 � 18 300 16 14 200 12 lo i-loo 6 0 03:00 0320 03:40 04. Job Date: 02 TiclrA 4: 2871392 Performed for W Jim Rom QMWOVI-1-0 i w4m-0413:46 rl tj bd C G. ri co Caribou 26 -11 #1 9 5/8" LOT No. 2 0 TOTAL 700 600 500 Leak Off Pressure 540 psi N Q- 400 d to SP 300 a ` 200 Mud Density = 9.4 ppg Hole Depth = 2, .Sr{ LOT =.4 -ppg EMW 100 .o 0 0 0.2 0.4 0.6 0.8 1 1.2 Q (bbis) • • III T�� H IMI I IR E & P SERVICES, INC. Formation Water Salinity Determination Caribou 26 -11 #1 Company Field Well Date Logged Date Processed Reference Number API Number Log Analyst TOTAL Wlldcat Caribou 26 -11 #1 07 February 2004 (First Run Log) 08 February 2004 AOGCC PTD No. 203 -196 50- 279 -20009 Ron Doshier Fairweather E &P Services, Inc. 2000 East 88th Avenue Anchorage, Alaska 99507 (907) 258 -3446 All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and we shall not, except in the case of gross negligence on out part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. • • Fairweather E &P Services, Inc. Log Data: 08 February 2004 Field: Wildcat Well: Caribou 26 -11 #1 Introduction Fairweather E &P Services, Inc was asked to evaluate the salinity formation water for TOTAL on the Caribou 26 -11 #1 exploration well. The interval of interest is from 2,325 ft to 2,337 ft. The data available for this evaluation included LWD Gamma Ray, LWD Borehole Compensated Sonic, LWD Compensated Neutron — LWD Formation Density well logging tools. The reason for this interpretation is to determine if the water salinities of this formation interval and similar intervals just below are saline enough for use for injection. LWD/MWD Many oil and gas companies are currently using Logging - While - Drilling (LWD) or Measurement - While- Drilling (MWD) as compared to conventional wireline logging measurements. With this, a few differences occur between the conventional resistivities and those obtained from LWD/MWD devices. Some of the differences observed between the LWD /MWD and conventional resistivities can be beneficial in helping to locate permeable hydrocarbon zones which have become flushed with mud filtrate and therefore exhibit a difference in resistivity over time. In most cases the LWD /MWD measurements indicate higher resistivity when compared to conventional resistivities due to less mud filtrate invasion at the time of the LWD/MWD measurement. There are certain advantages as well as limitations to each type resistivity device. Of course, expected borehole conditions, deviation angles, and economic considerations are also major factors in deciding which type of logging device is used. Archie Computational Equations Fifty years after it was introduced, the Archie equation remains the keystone of log analysis for the solution of water saturation of potential oil and gas zones: n ,5w (D M R The equation is actually made up of two separate equations. The first describes the relationship of the ratio of the resistivity of a water saturated rock, Ro, to its formation water resistivity, Rw, to the fractional porosity, (D: M This resistivity ratio is also known as the "formation factor ", F. The second equation relates the ratio of the observed formation resistivity, Rt, to its expected resistivity, Ro, if it was completely saturated with water, to the fractional water saturation, Sw: 1R _ 1 The equations are universally applied to reservoir fluid calculations from wireline logs in "clean" (shale -free) formations. Even when specialized equations are applied to clastic reservoirs that are markedly shaley, these same equations are adaptations of the Archie equation that accommodate shale effects. The application of the Archie equations presuppose a knowledge of the parameters, or at least reasonable estimates of them, in order to calculate acceptable water saturations. Formation water resistivity can and is usually established from field measurements and/or log analysis estimations. Evaluation of Water Saturation when either or both the Formation Water Resistivity and Constants of the Archie Equation are Known or Unknown A direct solution for water saturation is predicated on knowledge of both the formation water resistivity and the constants of the Archie equation. There are many occasions when either or both of these quantities are unknown. Both water resistivity and an appropriate form of the Archie equation may be deduced from logs provided that some zones with 100% water saturation occur in the unit of interest. This is not usually a difficult stipulation to meet since many productive units will have a hydrocarbon/water contact separating the reservoir from a lower, water - saturated section. Failing this, an adjacent water - saturated unit of similar lithology and (hopefully) with similar water resistivity may be used as a surrogate for the critical zones. These critical water zones do not have to be recognized initially, but will manifest their presence (or absence) in the methods of analysis. When water resistivity is unknown, but Archie constants are known The reconnaissance water resistivity (R,,, technique is the most widely used method under these conditions. Now, F = a/� ' ( the Archie equation) and F = R./R (by definition) Therefore, R = R. Om /a By analogy, RWa = R Om /a 0 0 Note that for any zone: when S = 1, Rwa = R and when 5,< 1, Rwa > R If the Archie equation constants are known, R values may be calculated from the resistivity and porosity log readings. Within the oil or gas reservoir section, these values will be high and will fluctuate in sympathy with variations in water saturation. Below the hydrocarbon/water contact or in adjacent, similar water -wet units, the values will tend to stabilize at a lower limiting value which corresponds to an estimate of the true formation water resistivity, Rw. Rwa = Rt 0' With this, we can introduce the values for the Caribou 26 -11 #1 Formation Interval Formation Temperature Rt ohm meters (Deep) � Density (2.17 gm/cc) = 2,325' to 2,337' = 78 Degrees F = 4.9 ohm meters = 29.0% Rwa = 4.9 x .29 = 4.9 x .0698/.62 = 4.9 x .112 = .55 Using the attached Chart Gen — 9 in the Schlumberger Chart Book you now convert the Rwa value of .55 to approximately 10,800 ppm NaCl Concentration. Conclusion: The interpretation made was derived from the Archie Equation when no SP can be used in conjunction with mud measurements. This is the case when running LWD/MWD logs. The salinity for the interval calculated is above 10,000 ppm. When correlating this value to the value of 16,000 ppm derived from using the Rwa Method with the SP of the offset log (North Inigok Test Well #1) drilled by Husky Oil/NPRA Operations in 1981 it should be noted that the resistivity and porosity values are almost identical and through this analysis and correlation the Caribou 26 -11 #1 appears to meet the requirements for safe injection. Basic Material Schlumberger Gen • • SGRC 150 0 0 SEDP 20 iso DT -- -------- ---- ----- -- ------------------------------------- api ohmm us f 0 SESP 20 -------- - - - - -- �6o DTCP 60 ^� 0 ohmm ° pf ---- -- --- --- --- --- ---------- -- 0 O CD CD 77 �.. -��i. O O ��• �" ' , ice - r — O — Y �_____ ______________ " -- -� may` ___-______---+.,- 0 0 — ------------------ ±----- .________ O S -------- — .- - - -. -- 1. R� - ------ - - - - -- --- - -_� -. O O 00 O O a --------- -- . -. --- -.� -.. Z �� CD i i O - -- O O O O I i N -- O O w o 0 0 O O 54 O I — o 0 0 O O O O ----- - - - - -- - --_: z..- r� - k_ • s — !Y A — � I f �y y 2 - - - - — - ;..y- -- • S -.ax._ Y. - ....rr_r ------------------ 1+*^ l TOP NANUSHUK 1,675' - - --- -- f c- N) N) CD C) 2,236' CD CD - --------- 4N. O C) OFF rrs C) CD ------------------------ 9-5/8" SHOE O O CD C) INJECTION ZONE rl) 00 O CD ------- 2,325 2,335' N C.0 C) O - --------- CD O C, - --------- OFF rrs ------------------------ 9-5/8" SHOE ------------- INJECTION ZONE ------- 2,325 2,335' - --------- 1, -- ---------- sme 7j - 3,122 w w a N W W O O W -th. O O W U1 O O I' W v O O W co O O W O O O TOP TOR 'S 0 SGRC ISO o o SE DP so 160 DT so api ohmm us f - - - - -- - - - - - -- 20 160 DTCP so N ohmm ----------- --------- ----- ------- --- ---- -- -- o uspf - -- ------ -° RE: Annular Injection at TOTAL's Cari ou 09 -11 #1 19 Tom, To answer your question, the 9 -5/9" casing at Caribou was set 800' higher than originally planned because the formation tops all came in 800' higher than anticipated. The casing setting depth relative to the desired position geologically for annular injection has not changed. The 9 -5/8" was set in a shale near the base of the Nanushuk sand interval and TOTAL anticipates seeing a small amount of additional Nanushuk sand (the planned injectant receiving interval)after drill -out before entering the extensive Torok shale. LWD logs will be run from here on out to provide the data for the stratigraphic and Rwa analyses needed to finish the justification for annular injection authorization. Regards, Bill - - - -- Original Message---- - From: Thomas Maunder [ mailto:tom maunder@admin.state.ak.us Sent: Monday, February 02, 2004 10:32 AM To: Bill Penrose Cc: Steve Davies; Jim Regg Subject: Re: Annular Injection at TOTAL's Caribou 09 -11 #1 Bill, Please refer to 25.080 for the exact listing. I believe you have the mechanical issues correct. The other item I can think of is the logs that would demonstrate that any sands exposed have salinities greater 1 of 2 2/3/2004 3:10 PM Subject: RE: Annular Injection at TOTAIA Caribou 09 -11 #1 From: Bill Penrose <bill @fairweather.com> Date: Tue, 03 Feb 2004 07 :49 :31 -0900 RE: Annular Injection at TOTAL's Caribou 09 -11 #1 than 3000 ppm. If the 7 is not run, then the operational sequence would need to be determined. In the few cases I know of, the deeper plugs were set prior to doing the disposal. I would presume that that would be your plan as well. Is that correct ?? On operational issues, I would expect to get a summary of last weeks activities today. I understand that Winton got a call over the weekend with regard to setting the surface casing shallower than planned. As you and Jim have a chance, I would appreciate some information regarding the need for change. Setting shallower could have an effect on the AD proposal. Call with any questions or information. Tom Maunder, PE AOGCC Bill Penrose wrote: Tom, Just trying to stay on top of things here. As I understand it, the only thing standing between TOTAL and the AOGCC's permission to inject drilling mud at the end of the Caribou well is that they owe the Commission 1) 9 -5/8" surface casing cementing records, 2) the LOT results at the 9 -5/8" shoe and, if they decide not to run 7 casing, 3) an LOT deeper in the 8 -1/2" hole section. Is this how you see it? Regards, Bill 2 of 2 2/3/2004 3:10 PM RE: annular disposal question Subject: RE: annular disposal question From: Bill Penrose <bill a@fairweather.com Date: Thu, 04 Dec 2003 10 :39 :36.0900 Td ttm, imn�rat�ns f �1 x .. ..ic� '.:i:::.. x ".X %x:: 4 �; '_:_..• gym:. "''r;:'`• �����.,,<£ Great! I once again get stuck with all the questions! Actually, it's best if they do get channeled to me. I can answer the technical ones on my own and obtain answers or clarifications to the big issues that involve TOTAL's policies or finances from the appropriate people at TOTAL. S - - - -- Original Message---- - From: Thomas Maunder [ mailto :tom_maunder @admin.state.ak.us] Sent: Thursday, December 04, 2003 10:40 AM To: jimrose @dejazzd.com Cc: Steve Davies; Bill Penrose Subject: Re: annular disposal question Great, I have no problem working with either of you. Just with the exploratory nature of the well, I wanted to be sure no toes were being stepped on. Tom jimrose(a)dejazzd.com wrote: tom yes i did get the letter from steve. thanks. i passed it on to the management here at total. on the contact info, i am not going to be in the office on a regular basis and i expect bill penrose will continue to carry the ball. i am making an effort, however, to identify any potential problems before they occur and pass the info on. thanks for the info. i copied this penrose. i will talk with him and to proceed. somebody will let you these issues will be point forward. thanks information to bill see how we /they intend know who the contact for 1 of 3 2/3/2004 3:12 PM RE: annular disposal question jim From: Thomas Maunder <tom maunder @admin.state.ak.us> Date: 2003/12/04 Thu PM 12:04:35 EST To: jimrose@dejazzd.com CC: Steve Davies <ste _ davies @ ad mi_n .sta _t e.a _k._ us> Subject: Re: annular _ _ disposal question Jim, I suggest you look at those Lone Creek files on the CD. In the event of a dry hole, I believe it is possible to do the disposal. Again, check those files out. If I remember correctly, some amount of plugging must occur. I know the logistics of this project are a little different (with Inigoc storage potential) than others that have been done lately, but even in the dryhole case it may make "economic" sense to run and cement the casing. I don't know what all the logistic abilities are but it may be something to look at. On a related subject, did you get the letter that was faxed ?? I also need to to ask another question. Bill Penrose at Fairweather prepared the 401 application and now you are at Total. Is it possible to get some sort of letter from Total as to who we should be talking to. Is there a transition going on ?? Some guidance would be appreciated. Tom Maunder imrose@delazzd.com wrote: tom, considering the following.... 9 5/8 surface csg set at +/- 3000' 8 1/2 open hole to +/- 10,000' if Total's caribou 26 -11 well is dry and they decide not to run 7 casing, can an annular disposal permit under 20 AAC 25.080 be issued if the other requirements 2 of 3 2/3/2004 3:12 PM RE: annular disposal question 0 0 of the section are met? there is obviously no annulus present in this situation and it would be desirable to dispose of the waste before p &a. please advise. thanks, jim rose 3 of 3 2/3/2004 3:12 PM FRANK H. MURKOWSKI, GOVERNOR L LI e AILA SS�A OIL AND GAS 333 W. 7 AVENUE, SUITE 100 CONSERVA COMUSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Jean Francois Prost Drilling Manager Total E &P USA, Inc. 4300 B Street, Suite 303 Anchorage, AK 99503 RE: Caribou 26 -11 #1 Exploratory Total E &P USA, Inc. Permit No: 203 -196 Sur. Loc. 3691' FEL, 1373' FSL, Sec. 26, T1ON, R5W, UM Btmhole Loc. 3691' FEL, 1373' FSL, Sec. 26, T10N, R5W, UM Dear Mr. Prost: Enclosed is the approved application for permit to drill the above referenced exploration well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10 -403AD prior to the approval of disposal operations. 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. In your application, it is indicated that it may be necessary to stimulate the productive intervals in the well may be tested. When plans are determined, a Sundry Application (Form 403) detailing the planned testing should be submitted for approval. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the diverter function test and BOPE tests must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659 -3607. Sincerely, Sarah Palin Chair BY ORDER OF THE COMMISSION DATED this 'L � . �-- day of December 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 0 STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [X] Drill [ ] Redrill 1b. Type of well [ ] Service [ ] Development Gas [ ] Single Zone [ ] Multiple Zone [ ] Re -Entry [ ] Deepen [X] Exploratory [ ] Stratigraphic Test [ ] Development Oil 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool TOTAL E &P USA, Inc. 29' DF Wildcat 3. Address 6. Property Designation 4300 B Street, Ste. 303, Anchorage, Alaska 99503 AA- 084170 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20AAC25.025) 3691' FEL, 1373' FSL, Sec. 26, T10N, R5W, U.M. Caribou 8. Well Number At top of productive interval Number RLB- 0005671 3691' FEL, 1373' FSL, Sec. 26, T10N, R5W, U.M. 26 -11 #1 9. Approximate spud date At total depth Amount $50,000 3691' FEL, 1373' FSL, Sec. 26, T10N, R5W, U.M. 2/15/04 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 6,653' N of lease line 15 miles north of N. Inigok #1 11,451 9484' TVD, 9484' MD, DF 16. To be completed for deviated wells 17. Anticipated pressure (see 20AAC25.035(e)(2)1 Kick Off Depth: N/A Maximum Hole Angle: Straight Hole Maximum surface 1,932 psig , At total depth (TVD) 5,143 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 65# H -40 PEB 80' 29' 29' 109' 109' Permafrost cement to surface 12 -1/4" 9 -5/8" 40# L -80 BTC 3005' 29' 29' 3034' 3034' 288 sx Permafrost lead, 259 sx Class G tail 8 -1/2" 7" 26# L -80 BTC 9555' 29' 29' 9584' 9584' 125 sx Class G lead, 143 sx Class G tail 19. To be completed for Redrill, Re -entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments [X] Filing Fee [X] Property Plat [X] BOP Sketch [X] Diverter Sketch [X] Drilling Program [ . rilling Fluid Program [X] Time vs Depth Plot [ ] Refraction Analysis [ ] Seabed Report [ ] 20AAC25.050 Req. Contact Engineer ` el : Erw Couzigou 743 -0970 Prepared By NamelNumber: Bill Penrose 258 -3446 21. 1 hereby certify ore g is true and correct to the best of my knowledge Signed Z� 2 I d 3 Title I Drilling Manager Date 1111 Commission Use Only Permit Number �c t� ��� API Number p j G F•, `� / �� °�3 Ap roya l at Z 9 Z See cover letter for other requirements Conditions of Approval: Samples Required: �4 Yes [ ] No Mud Log Required KYes [ ] No Hydrogen Sulfide Measures: [ ] Yes No Directional Survey Req'dWD4 Yes [ ] No Required Working Pressure for BOPE: [ ] 2M, [ ] 3M, [ ] SM, [ ] 10M, [ ] 15M S e t { t Other: C97tjir $z�7 •J '3 rigi�°ai Signed is by order of ; J1y Approved By Y palim Commissioner the commission Date Form 10 -401 Rev. 12 -01 -85 R E C EIV T�ipljir ate DEC - 3 20 03 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA CONND GAS CONSERVATION COMO$ION PERMIT TO DRILL 2n AAC 2s_nns 1 a. Type of work [X] Drill [ ] Redrill 1 b. Type of well [ ] Service [ ] Development Gas [ ] Single Zone [ ] Multiple Zone Re -Ent Deepen X Exploratory Strati ra hic Test Develo ment Oil e of Operator 5. Datum Elevation (DF or KB) 10. Field an71dcat A . E &P USA, Inc. 29' DF 3. Address 6. Property Designation 4300 B Street, Ste. 303, Anchorage, Alaska 99503 AA- 084170 4. Location of well at surface 7. Unit or Property Name 11. Type nd (See 20 AAC 25.025) 3691' FEL, 1373' FSL, Sec. 26, T1 0N, R5W, U.M. Caribou 8. Well Number At top of productive interval Nu ber RLB- 0005671 3691' FEL, 1373' FSL, Sec. 26, T10N, R5W, U.M. 26 -11 #1 9. Approximate spud date At total depth mount $50,000 3691' FEL, 1373' FSL, Sec. 26, T10N, R5W, U.M. 2/15/04 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 5. Proposed depth (MD and TVD) 6,653'N of lease line 15 miles north of N. Ini ok #1 11,451 A 9484' TVD, 9484' MD, DF 16. To be completed for deviated wells 17. Anticipated pressure see 20 AAC 25.035 (e) (2)) Kick Off Depth: N/A Maximum Hole Angle: Straight Hole ' Maximum surface 1, 9 psig , At total depth (ND) 5,143 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Z Quantity of Cement Hole Casing Wei ht Grade Coupling Length MD TVD MD TVD include stage data 20" 16" 65# H -40 PEB 80' 29' 29' 109' 109' ermafrost cement to surface 12 -1/4" 9 -5/8" 40# L -80 BTC 3005' 29' 29' 3034' 3034' 288 sx Permafrost lead, 259 sx Class G tail 8 -1/2" T' 26# L -80 BTC 9555' 29' 29' 9584' 958 125 sx Class G lead, 143 sx Class G tail 19. To be completed for Redrill, Re -entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measure true vertical feet Effective depth: measured feet Junk (measu true vertical feet i` I Ong Length Size Cemented MD TVD Structural '�, Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments [X] Filing Fee ] Property Plat [X] BOP Sketch [X] Diverter Sketch [X] Drilling Program X Drilling Fluid Program [XI Time vs Depth Plot Refraction Analysis Seabed Report 20AAC25.050 Reg. Contact Engineer Name /Number: Erwarlcouzigou 743 -0970 Prepared By Name /Number: Bill Penrose 258 -3446 21. 1 hereby certify that the foregoing is tru and correct to the best of my knowledge Signed Title Drilling Manager Date Commission Use Only Permit Number .�g, AP Number �. .Z �9 , �� 206 0q ^ Approval Date See cover letter for other requirements Conditions of Approval: Samples Required: )<Yes [ ] No Mud Log Required PqrYes [ ] No Hydrogen Sulfide Measures: [ ] Yes ,�No Directional Survey Req'd* ><Yes [ ] No Required Working Pressure for BOPE: [ ] 2M, [ ] 3M, 5M, [ ] 10M, [ ] 15M yrc lt,✓I4101 , OKJ- 6 Other: K03a� �� cs,;�t g n Rc;;C�SSU. stlrV . A by order of A roved By Commissioner the commission Date Form 10 -401 Rev/ 2 -01 -85 Submit In Triplicate ORIGINAL �J • 0 0 Yk WO Application for Permit to Drill CARIBOU 26 -11 #1 November 2003 COPY 0 0 TOTAL Caribou 26 -11 #1 Overview and Timetable J TOTAL E &P USA, Inc. plans to drill an exploratory well, the Caribou 26 -11 #1, in NPRA this winter. Caribou 26 -11 #1 will be located approximately 48 miles west of the village of Nuiqsut. The well will be drilled from a temporary ice pad with spudding estimated to occur approximately February 15, 2004. The well is planned as a straight ✓ hole. The well will be accessible via aircraft to Inigok, then ice road across the frozen tundra and via rolligon from Meltwater 2P Pad. A map showing details of the ice road route and rolligon route as well as the drilling location are enclosed in this application. Ice road and pad construction will begin as soon as the necessary permits and approvals are available and weather conditions allow. Ice road/pad construction equipment will be pre - mobilized via aircraft to the existing Inigok staging area for this purpose. It is planned that the Caribou ice road will extend from Inigok to the drilling location approximately 15 miles to the north. Construction of the ice road and ice pad will occur concurrently. Upon completion of the ice drilling pad, rolligons will be used to transport Nabors' Rig #14 -E to the wellsite. The rig will be supported with personnel and light supplies flown into Inigok and transported to the wellsite via the ice road. Heavy • supplies and equipment will be brought overland via rolligon. Well testing may be performe Current p lans are to plug and aban the well prior to the end of the 2003/2004 winter drilling season; however, the well may be temporarily shut in and secured if well evaluation cannot be completed prior to the closing of tundra travel in the spring of 2004. If the well proves to be a dry hole, it will be plugged and abandoned at the end of this field season. If the well is to be tested, it will be completed, a tree installed and the rig released. If there is time for testing, the well will be tested and, if promising, shut in until a following winter season. If there is insufficient time for testing, the well will be shut in and tested during a subsequent winter season. In either case, if the well test is insufficiently encouraging, the well will be plugged and abandoned without a rig at the conclusion of testing. Operational Considerations Permafrost Based on offset wells, permafrost is assumed to be present from the surface to approximately 600' The permafrost is not expected to present any drilling difficulties as neither thawing nor gas hydrate problems were encountered in any of the offset wells. Surface Casing Shoe Depth The 3,034'RT setting depth for the 9 -5/8" surface casing is located in the bottom 200' of ✓ • the Lower Nanushuk sands, just above the Torok shale. The casing shoe will be set in a 0 0 • competent shale within the Lower Nanushuk in order to yield a strong shoe test, yet leave some of the Nanushuk sand exposed between the casing shoe and the Torok shale for later annular injection of waste drilling fluids. Lost Circulation and Sloughing Shales Some of the offsetting wells encountered sloughing shales below the HRZ and lost circulation in and near their target horizons. The Caribou 26 -11 #1 casing and mud programs have been designed to take these potential problems into account. While the preferred well design presented here calls for a long string of 7" casing to be set at TD, an alternate well design is included in this Application wherein intermediate casing is set just above the target horizon to isolate sloughing shales and the mud weight cut to avoid lost circulation in the target interval. When TD is reached, the target interval will be evaluated as an open hole or, if hole conditions dictate, cased with a production liner. Pressures Anticipated pore pressures are derived primarily from the histories of offsetting wells. These wells, referenced in the Pressure section of this application, were all drilled in the past few years and are well- documented. As shown on the attached pore pressure plot and maximum anticipated surface pressure (MASP) calculations, the highest expected pressure is at 8,600' and is 5,143 psi (11.5 ppg EMW) and will result in a maximum pressure at the surface, with a full column of gas, o 1_._95_ 4 p si (see enclosed Maximum Anticipated Surface Pressure calculations). A 5,000 psi WP BOP and wellhead system • will therefore be used on this well. Abnormally pressured shallow gas is not anticipated. The pore pressure prediction section of this application contains an evaluation of the risk of drilling high- pressure zones as potentially recognized after seismic processing. An abnormal pore pressure gradient starts near the top of the HRZ (7,812' SS) that may explain their tendency to slough. o il '/ " 12-61)� 0- /us D ng_Within Annular Blowout Pre'venter Limitations As shown in the attached pore pressure prediction study, the highest pressure expected I-cyc-, L above the surface casing setting depth (8.9 ppg equivalent mud weight at 3,034' TVD less a 0.11 psi /ft gas gradient) is 1,200 psi which is within the 2,000 psi working pressure rating of the diverter. Below the surface casing, BOPS will be used in lieu of a diverter. Again, the MASP calculations show that all anticipated surface pressures are well below the 5,000 psi working pressure rating of the annular preventer. BOP System and BOPE Testing The BOP system on Nabors Rig #14 -E is rated at 5,000 psi working pressure and is described in the BOPE section of this application. Since the calculated maximum anticipated working pressure (at the surface) in this well is 1,954 psi, it is planned to routinely test all BOPE to 80% of its rated working pressure (i.e., 4,000 psi). • 0 0 The BOP system will be tested initially (before spudding the well) and weekly thereafter • to a low pressure of 200 psi and a high pressure of 4,000 psi (80% of rated working pressure). Straight Hole The Caribou 26 -11 #1 will be drilled as a straight hole. Directional control will be monitored via MWD in all hole sections. H2S None of the offsetting wells encountered measurable amounts of H2S in the intervals to be drilled at Caribou and it is not expected that Caribou 26 -11 #1 will encounter any. However, the drilling rig will be wired with operating sensors, enhanced by additional sensors ti into the mud logging system, to con inuous y monitor for the presence of H2S. Also, the wellhead and tree will be trimmed for H2S service. Drilling Waste Handling -ZA \'�r3 (? t Waste drilling mud from the well will be pumped into subsurface formations at approximately 3,000'DF via the 9 -5/8" surface casing X 7" intermediate casing annulu . Cuttings will be hauled to an approved disposal facility for processing and disposal. Prior to on -site disposal or hauling, mud and cuttings will be temporarily stored in a bermed storage cell on the ice pad or in appropriate containers. Diagrams are included with this application that show the ice pad layouts with the proposed location of the storage cell. Additional Information Additional information on operations such as formation tops, logging, mud logging, etc. can be found on the attached Caribou 26 -11 #1 Well Prognosis. Certified Location Plat An as -built location plat, certified by a Registered Land Surveyor, will be submitted shortly after construction of the drilling location is completed and the conductor set. Contacts The contacts within TOTAL for information are: Reporting and Technical Information Erwan Couzigou (907) 743 -0970 Geological Data and Logs John Johns (713) 647 -3435 0 • TOTAL Caribou 26 -11 #1 Well Prognosis Well Name: TOTAL Caribou 26 -11 #1 0 Surface Loc.: 3691' FEL, 1373' FSL, Sec. 26, T10N, R5W, UM Target Loc.: Same as surface location (straight hole) Bottomhole Loc.: Same as surface location (straight hole) Elevations: Ground Level 205' AMSL s4. Rotary Table (RT) 29' AGL Planned TD: 9,584' TVD, 9,584' MD (RT) Formation Tops: TOPS DEPTHS (SS, TVD) Colville Gp. Conglomerates Surface Nanushuk Sands 1,250' t o C- r cLC cs�L 3 000' Torok Shale "A" Base of Slope Sands , 5,650' . Lower Torok Shale 6,250' "B" Base of Slope Sands 7,100' HRZ 7,812' LCU / Valanginian Shale 8,052' +C;' V� MFS Warm Shale 8,597' Val. Channel Fill / Alpine Sand 8,747' BCU / Kimm Silt 8,900' Oxfordian Shale 9,100 TD 9,350' Cores: Two (2) 90' cores are planned in the target sands. Planned Logs: 12'/4 Surface Hole, 110'- 3,034'RT u1�EV GR only (to be run with logs in 8 -1/2" hole) 8 -1/2" Production Hole, 3,034' — 9,584'RT: LWD: Gr/Resistivity Wireline: GR — Res- Dens/Neutron, Dipole Sonic Optional Rotary SWC is 0 0 Mud Logging: Mud logging will be in operation from the base of the 16 Y conductor to TD. Service will include sample collection, ROP, lithology, show description, hot wire, gas analysis of cuttings, gas chromatography, and drilling parameters. Thirty -foot (30') samples will be collected from the base of the surface casing, and 10 -foot (10') samples will be collected in zones of interest. The wellsite geologist will adjust the interval or sample frequency as required. Planned Sampling 1 set unwashed each: Total 3 sets washed and dried: Total 1 set washed and dried: Partners (2), State of AK, BLM 1 set canned ditch samples for geochemical analysis collected at 30' intervals from base of the conductor casing to TD. 0 l � u • �J l I u ALASKA - NPRA Caribou East Caribou 26 -11 #1 Geologic Prognosis Surface Location: 3691' FEL, 1373' FSL, Sec. 26, T10N, R05W, UM 70 deg. 11 min. 19.40 sec. N 153 deg. 05 min. 20.40 sec W (NAD 27) X = 613,087' Y = 5,919,405' (Alaska State Plane 5) Ground Level: —205 feet %coy r �� Est. Top "Alpine Sand" Primary Reservoir Objective: -8 690' SS TVD Proposed "Alpine Sand" Location: 3691' FEL, 1373' FSL, Sec. 26, T10N, R05W, UM 70 deg. 11 min. 19.40 sec. N 153 deg. 05 min. 20.40 sec W (NAD 27) X = 613,087' Y = 5,919,405' (Alaska State Plane 5) Proposed Total Depth: - 9,250' SS TVD Proposed Total Depth Location: 3691' FEL, 1373' FSL, Sec. 26, T10N, R05W, UM 70 deg. 11 min. 19.40 sec. N 153 deg. 05 min. 20.40 sec W (NAD 27) X = 613,087' Y = 5,919,405' (Alaska State Plane 5) GEOLOGICAL HAZARDS & OBJECTIVES The well will initially be drilled through the Colville Group Conglomerate section starting at or near surface. The base of the permafrost will be reached within the middle of the conglomerate. Pore pressure prediction from seismic (Brilliant Geoscience, Inc., August 2003) indicates a poss anomalous pressure incre below the base of the permafrost (approximately 1000 feet below MSL)."This shallow pressure increase has been noted in the local well control, and drilling mud weights ranged between 10 and 10.5 ppg. Within the Nanushuk topset sands, isolated gas filled sand bodies may be present. Our pore pressure ✓ prediction does not indicate a Nanushuk over - pressured sand at our location, but the possibility cannot be ruled out. The well is expected to be normally - pressured from the Nanushuk to near the top of the HRZ Shale. Our pore pressure prediction indicates an increas in pressure from the top of the HRZ until TD. This over - pressured section should have pressures of approximately 0.52 psi /ft. Being slightly over - pressured, the shale section has a tendency to wash out and shows up on caliper logs throughout the North Slope. In particular, Conoco - Phillips has had severe problems with the MFS shale section, located directly on top of the primary objective. The MFS will potentially cave in and grab drill pipe. Having to set inter mediate pipe within the Valanginian shale is a possibility. TIME Notes FORMATION DEPTH (msec.) LITHOLOGY Colville Group Congl. @ surface Conglomerates Potential Base of permafrost gassands Nanushuk Sands - 1,250' SS Sand Pot. Isolated Gas sands Torok Shale - 3,000' SS 95% Shale Top of "A" Base of - 5,650' SS Sand Stringers Pot O /Gs sands Slope Sands Lower Torok Shale - 6,250' SS Shale /Sand stringers Top of "B" Base of - 7,100' SS Sand Stringers Pot O /Gs sands • • • FORMATION DEPTH TIME (cosec.) LITHOLOGY Notes Slope Sands HRZ - 7,812' SS 1.620 rns Black Shale Top Pressure LCU/ Val. Shale - 8,052' SS 1.667 ms Shale MFS Warm Shale - 8,597' SS Shale Washes out Top Val. Channel Fill / Alpine Sand - 8,747' SS 1.809 ms Sand / Silt Top BCU / Kimm. Silt - 8,900' SS 1.833 ms Silt Top Oxfordian Shale - 9,100' SS Shale TD - 9,350' SS Shale Still in Pressure OPEN HOLE EVALUATION 1. Mudlogging Mudloggers will be rigged up and operational at the spud of the well. They will monitor the well from surface to TD. 2. Conventional Coring Two 90 foot conventional cores are planned to be taken in the "Alpine Sand" (- 8,747' SS TVD), the primary reservoir objective of the well. 3. LWD LWD services (GR/Res) will be utilized on this well in the 8.5" hole section (9.625" casing shoe to TD). Additional equipment may be added if required by the drilling department. 4. Wireline One wireline log job is planned for this well over the 8.5" hole section (from TD to the 9.625" casing shoe). Run 1: NGT- Res - Den /Neu -DSI Run 2: MDT (optional) Run 3: FMI -CMR (optional) Run 4: VSP /Checkshot (optional) Run 5: Rotary Sidewall Cores (optional) 2 • • CARIBOU 26 -11 #1 FORMATION TOPS 10 -17 -03 PERIOD m O. CL :) Cenomanian ? Albian ? I Potential Hazards Formation, Lithology, Depth Colville Group Conglomerate Appi ox. Base Permafrost :.; Gravels, Sands, Silts, Clay, .• .• .• 600' is depth of potential high pressure anomaly at and Coal beds base of Permafrost near at Hunter well location @ Surface Nanushuk Topset Sands - 1,484' RT Potential K3 Gas sands noted in Hunter Well prognosis @ a depth of 2,260' V �I O W L U 3 F.. J W UI U IQ IM Aptian ? Torok Shale (90% Sh 10% Sd) C� - 3,234' RT 6,000 Base of Slope "A" Barremian ? Cretaceous Sands Lower Torok Shale i, Base of Slope "B" Cretaceous Sa nds Hauterivian 6,000 T Overpressure Cell LCU HRZ /P ebble Sh Valanginian Sh Valanginian I - _ MFS Channel W1 en mend yian I ��9.00bo -I BCU KimmFlS H Oxfodian Sh Oxfordian - 5,884' RT - 6,484' RT - 7,334' RT - 8,046' RT - 8,286' RT • -8,831 RT -- _ Primary Objective - 8 ,981 ' RT "Alpine Sand" Located -9,13- within Channel Fill - 9,334' RT Aal enian Sh Triassic 724' R7 - 11,024' RT L—L • N 5a � 9179 0. 0 1 E TOROK - - .•,�,'.• �" - Wit' - '�'� •.1^ � . _ g - �2 S "A" Sands - 5,6' ♦ -�r+�� �`�` - 6,328 -7 120' 1.250 1 500 i Caribou East�,.SP S � 1 1 0,332 Colville Group NEON -. - +�' �- .�. _ ` r fir• ~� • �'t - ...�+�+r1..�- .. 0,500 ■� . • '* 1,762' _. " -►- 1 �' - ��w■r _ �i— • - �. ,. w =-. - �" ----_ _ Nanushuk AW •.. ,r �- _ �,,,;��-- -•. - -- --•- -� - - _ - �"�"''.'w • �"� .fin. �� �`�. 0,750 - y _ dew - 3,208' �.._ -3,192' _ �+ 1,000 ... -7,49 '� BOS "B" Sands � _ ,,,mow■ fir• wk .;t ... I Nom ,- 8,050':. 1.750 � a.1'r''. r � � ■■ ■■ � � 1,750 79' ~ - LCU �. ■■ _ ■■ . on ■ • ■ . ■• .. s wht u c - 8,740' FILLS - 9,092' ■ ■ TVERSE ■ ■ ■ ■ 8,860' TI ■ � - 10,107' BCU - 10,562' OXF i Caribou East�,.SP S � 1 1 0,332 Colville Group NEON -. - +�' �- .�. _ ` r fir• ~� • �'t - ...�+�+r1..�- .. 0,500 ■� . • '* 1,762' _. " -►- 1 �' - ��w■r _ �i— • - �. ,. w =-. - �" ----_ _ Nanushuk AW •.. ,r �- _ �,,,;��-- -•. - -- --•- -� - - _ - �"�"''.'w • �"� .fin. �� �`�. 0,750 - y _ dew - 3,208' �.._ -3,192' _ �+ 1,000 0 INIGOK AGE PERIOD m a Cenomanian ? N O W Q H W V L 3 0 J I i 3 L) Cl) Q a �j Albian ? Aptian ? Barremian ? Hauterivian Valanginian Kimmeridgiar Oxfordian Aalenian L J • 762' SS c: 192' SS 492' SS . 879 SS 092' SS 937' SS ,107' SS 1,562' SS ,737' SS C N S O 100 Gommo Ra y (GR •� Sonic DT Formation Lithology, Depth 25 (GAPI) 150 JTH 1-40 u s f 40 Colville Group Conglomerate Gravels, Sands, Silts, Clay 1,000 _ and Coal beds -_ @ Surface {r? Nanushuk Topset rands 0 r; r - 1,925 DD 1, ,00 r•j rtir -- - - Torok Shale ,000 3,355 DD 3, - (90% Sh 10% Sd) 00 or is S I ,00 7,00 Base of Slope ,00 .- Cretaceous °?rls 7,655 DG 7 Top 1. Overpressure Cell LCU HRZ /Pebble Sh 9.042 D D 8 Valanginian Sh 9,255 DD 9 I 10.00 BCU MFS Sh 9 Kimm Silt 10,270 DD U 11,000 Oxfodian Sh 10,725 DD 11 Objective Not Present - Primary Basal Valanginian "Alpine Sand" - " - -- - _ 12,00 Aalenian Sh 11,900 DD 11 762' SS c: 192' SS 492' SS . 879 SS 092' SS 937' SS ,107' SS 1,562' SS ,737' SS ,7, a 1 — — _ . —. 1 —1 lLL 4J(1 L,' • " • ROLLIGON ROUTE " • ROLLIGON ROUTE PERMITTED 04 -2003 �•�"� ICE ROAD ROUTE PERMITTED DATER SOURCE LAKE TOTAL E &P USA, Inc. NPR -A LEASE TRACT 10500 0 21000 GRAPHIC SCALE 7" =2100n' /wmc:� PER���� E 8 P SERVICES. Ib'C evs e 10 - 28 - 03 cnu AS NOTED TOTAL E &P USA, Inc. FIG, 3 -2 ROLLIGON ROUTES BETWEEN KUPARUK 2P -PAD AND CARIBOU EAST PROSPECT AREA F. Rob TOT - N - A 2 003 - --004 EXPLORATION FIC 3 -2.DWC W - _— ti U T7M! TriN c 2 Ir 2 ti9 _ T10N R4W TK3 POW R2W T1 RIW NO W- RE R2E R3E TI R4E UI JC r R ON R6 ' m N 3 Z 0 VO445 r W .� 8N R3W ' T9N 20 T8N W T8N �yy T9N T8N E 0 A W Z i9P! R2E 4 sr R2E 719N R E TgN " ' A 82 A S1 T9N R5E T9N RISE N R4 1 R � ♦ �� ft T RSE K PAR PA A G G AV 2' P w A V N W T7N w 77N T7N T7N Ra? T7 WE I I I I � IL 3 T T6N F6W T6N I i2W T6N RIW TON R2E LEGEND • POTENTIA T. FYPT nPA 7'rn Ai n TT T 1 1 — — _ . —. 1 —1 lLL 4J(1 L,' • " • ROLLIGON ROUTE " • ROLLIGON ROUTE PERMITTED 04 -2003 �•�"� ICE ROAD ROUTE PERMITTED DATER SOURCE LAKE TOTAL E &P USA, Inc. NPR -A LEASE TRACT 10500 0 21000 GRAPHIC SCALE 7" =2100n' /wmc:� PER���� E 8 P SERVICES. Ib'C evs e 10 - 28 - 03 cnu AS NOTED TOTAL E &P USA, Inc. FIG, 3 -2 ROLLIGON ROUTES BETWEEN KUPARUK 2P -PAD AND CARIBOU EAST PROSPECT AREA F. Rob TOT - N - A 2 003 - --004 EXPLORATION FIC 3 -2.DWC R7W R0329 T10N R6W Caribou 35 -14 ' -- R99Y8 ---- CARIBOU 80334 WEST TOTAL PROSPECT R0325 00 100 • R0327 4f RO 6 ` _ ' so 1* T9N R7W T9N R6W � 80333 80324 80331 R0321 • R0320 R0323 `•� R0322 R0330 R0318 PROSPECT ' Caribou 09-11 No. 1 . H0310E R0314 1 T9N R5W R03 80308 R0309 y 80209 R0307 ! ' R0315 Caribou 35 -0"5** No.1 80306 ` R0304 ` R( R0319 • N. 0 8N R7W T8N R6W 80317 f R0303 �.�T8N R5W R0302 ` R0211 T10N R4W am m m =a& R0312 - Caribou 07 -16 y Caribou 1 No. I 1 No. R0313 T9N R4W L ` R0210 R0301 R0336 TEST WELL No.1 7100027 /_1 NG W 0592 ING GRAVEL PAD 80335 p(13MG AHSTRP T8N R4W to 00 M oft I �4 '01 LEGEND L� I I 00 0 13000 GRAPHIC SCALE 1" = 13000' POTENTIAL EXPLORATION DRILL SITE ROLLICON ROUTE_ ROLLICON ROUTE PERMITTED 04 -2003 ICE ROAD ROUTE PERMITTED WATER SOURCE LAKE TOTAL E &P USA, Inc. NPRA LEASE BOUNDARY T10N R5W Caribou 14 -12 R0316 No. 1 1, i 26 -11 •�� No. 1 TOTAL E &P USA, Inc. FIG. 3 -1 PROPOSED ICE ROAD / ROLLIGON ROUTES F. Robert p AND ES CARIBOU PROSPECT AREA 10 -28 -03 _ BURT TOTAL E &P NPR —A AS NOTED I TOTAL-1 NPR —A 2003 -2004 EXPLORATION FIC 3 -1.DWC T10N R5W Caribou 14 -12 R0316 No. 1 1, i 26 -11 •�� No. 1 0 0 0 CARIBOU 26 -11 #1 DRILLING HAZARDS SUMMARY 12 -1/4" Hole / 9 -5/8" Casing Interval EVENT RISK LEVEL Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low ✓ If observed — control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lost Circulation Moderate Lecithin. Gravel /Sand Sloughing to 500' Moderate Increase mud weight /viscosity, High viscosity Barite Settling Low sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips Low (use of trip sheets), pumping out of hole as needed. Possible thaw bulb /water flow Low Watch return viscosity for signs of thinning. Abnormal Reservoir Pressure Moderate ✓ Increased mud weight /viscosity as needed. Lost Circulation Low Prevent by keeping hole clean. Reduce mud weight if practical. If losses occur — reduce pump rates and mud rheolog , use LCM FAdft Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Shale stability in MFS interval Moderate Control with higher MW and proper drilling below HRZ practices. May be necessary to set 7" casing across shales in order to proceed. Lost Circulation Moderate Monitor hole cleaning. Reduced pump rates, mud rheology, LCM. Barite Settling Low Good drilling practices as documented in well plan. Differential Sticking Low Periodic wiper trips. Do not leave pipe static for extended period of time Abnormal Reservoir Pressure Moderate ✓ Follow mud weight schedule and do not fall behind. Stripping Drills, Shut -in Drills, increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. r� 0 0 0 Caribou 26 -11 #1 Casing Properties and Design Casing Performance Properties Internal Collapse Tensile Strength Size Weight Yield Resistance Joint Body TVD MD Design Safety Factor* fo in. 1( b /ft) Grade Cnxn fiLsi) fp—sil (1,000 lbs ft RT ft RT T B C 9 -5/8 40 L -80 BTC 5,750 3,090 979 916 3,034 3,034 8.97 2.98 2.92 7 26 L -80 BTCM 7,240 5,410 667 604 9,484 9,484 2.97 3.75 1.28 * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factors are calculated using Maximum Anticipated Surface Pressure. Collapse design safety factors are calculated assuming complete evacuation of the casing. Casing Setting etting Depth Rationale 9 -5/8" 3,034' RT, MD Surface casing to provide an anchor for BOP equipment and sufficient fracture gradient until the reservoir is reached. 7" 9,484' RT, MD Production casing to provide hole stability and pressure containment for production testing operations. It also provides an annulus down which to inject waste mud. 0 Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT /LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre - determined equivalent mud weight. • Leak -Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak -off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak -offs. • Open Hole LOTs (OH LOTs)- Leak -off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak -off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. . 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1- minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre - determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowi for or a appropriate amount of kick tolerance m case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak -off. This ensures that future disposal fluids can pumpe away without risk of damage to the surface shoe. If two attempts at establishing leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open -hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre - determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. • Pre -Drill Seismic Pore Pressure Prediction for Location #2 Alaska State Plane 5 X= 613 Y= 5 August 27, 2003 Summary Pore pressures likely to be encountered at the proposed #2 well location are predicted using seismic velocity data. The normal compaction trend and translation model are derived from the Hottman- Johnson methodology and utilize local well control (Hunter A, North Inigok #1, Inigok #1). The compaction trend and translation model were applied to velocities from 3D seismic data to predict pore and fracture pressures. The data show po anomalous pressure ✓ increases at approximately 1200 feet below MSL (below the base of permafrost) and at 7500 feet below MSL, near the top of the HRZ. The shallow anomaly may reflect unreliable seismic velocities at very shallow depths due to low fold but local well control ✓ lends support for the presence of this zone. The HRZ anomaly seems to be consistent with higher pore pressures and accompanying mud weights as seen in the local well control, although the magnitude of the predicted the pore pressure in the wells exceeds the pressure observed in the wells, suggesting that the predicted pore pressures associated with the HRZ might be somewhat exaggerated. Seismic Processing The precision of the pore pressure prediction is directly related to the quality of the seismic velocity field. The velocities used for pressure prediction were generated from Total's proprietary Deltastack software. This software produces an accurate, continuous velocity analysis (every cdp and each time sample) and outputs both VRMS and DIX (interval velocity) sections. The Dix velocities were smoothed to minimize instability in the velocity field which could result from variation in CDP fold or noise. Pressure Prediction Procedure Brilliant Geoscience Inc. of Dallas utilized PPFG software (developed by ARCO Exploration and Production Technology) to calculate the predicted pore pressures and fracture pressures. The Hunter A, North Inigok #1 and Inigok #1 gamma ray and sonic logs were used to ✓ establish a local normal compaction trend in the shale intervals. Second order polynomial functions were used to translate the ADT (difference between seismic ITT and DT from the compaction trend) to pore pressure gradients. Where 0 PPG = C o + C *( o(oT )) + C2* (o(oT)) * * 0 • • In this area, the coefficients are C,, =.465 ; C1 = .0062 ; C2 = 1.34 e -5 • Fracture gradients were calculated using the Eaton methodology. Overburden pressure, calculated pore pressure gradient profiles, and Poisson's Ratio profiles are the inputs. Seismic Pore Pressure Prediction Pore pressure gradients were predicted along a 3D seismic traverse (Fig.l) through Location #2. Pressure gradient prediction displays are provided in depth with the depth stretched seismic wiggle trace overlay (Fig.2). The higher predicted mud weights (pore pressure gradients) are represented by the warmer colors as indicated on the scale on the right hand side of the display. Two potential high - pressure zones were observed. An increase in predicted pore pressure is observed starting at approximately 1200 feet ✓ below MSL (Fig.3). It should be noted that the seismic data also predict an increase in pore pressure in the same interval in the North Inigok #1, Hunter A, and Inigok #1. This zone was drilled with 10 -10.5 lb /gal mud weights in these wells (Figs.4 -6). The 3D seismic data used in this analysis has a low fold in the shallow section above 2000 feet which effectively reduces the reliability of the seismic velocity calculations in this interval. We prefer to use 2D seismic when available because of the higher effective fold but none was available for the pore pressure prediction at this location. An increase in pore pressure is also predicted at approximately 7500 ft below MSL near the top of the HRZ horizon (Fig.3). Mud weights used to drill this zone in the North Inigok #1, Hunter A, and Inigok #1 support this observation, although the magnitude of the predicted pore pressure increase from the seismic data at these wells (in lbs /gal equivalent mud weight) is larger than the mud weights observed in the wells. Conclusions 1. There is an apparent increase in pore pressure at 1200 ft below MSL below the • base of the permafrost. 9 0 2. There are similar anomalies in this zone predicted by the seismic at the North Inigok #l, Hunter A, and Inigok #1 and their presence is supported by the mud weights used in the wells. 3. There is an increase in predicted pore pressure at 7500 ft below MSL, near the top of the HRZ. 4. A moderate increase in pore pressure was seen near the top of the HRZ in the North Inigok, Inigok and Hunter A wells. This zone may have a lithology element in addition to a compaction disequilibrium because the seismic velocities predict a higher pore pressure than was apparently seen in the wells. 5. The normal compaction trend observed in the North Inigok, Inigok, and Hunter A wells is a good match for the seismic derived normal compaction trend. • • 1 �1 0 0 DRILLING PROGRESSION CHART • T dTAL C ARIBOU 26 -11 #1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 • • 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 1nnnn • X 37 • -2 .I A— ICE PAD LIMITS IX CASING BASKETS • i - - 121 ICE PAD 1 '. XTENSION 375-0 / �• e LOGGER'S HUTS PIPE �� \ ,/• BASKETS - 20 -0 THICKENED / - p -0 T ICE PAD - - LIMITS ICE PAD LIMITS NABORS ALASKA RIG 14E RIG PLACEMENT EXPLORATION CONFIGURATION CONCEPTUAL PAD LAYOUT 30' WIDE x 8' HIGH LOADING RAMP • NORTH -`� PR�VP�UNG AND U a ku 13• H PREPARED FOR: TOTAL E &P USA, INC. 0 TbmrAt aom GEI HW SMU W FOOMW A NmW zus c s" " INY99/9x1191ry� k-h- Alalo 90 KW.lm DOW4'L YGO GYP RWP ! G w 907 - wmw m wsmm wo A--rosy LOCO xns W PIACf IW DROMWN C0NFNYp1 nW YIOLD IIICXM ICE PAD AAFA 0Y4CDn W. PAD UYgR 5MMM IAW W WM fiN L1F �� ALSfGN oar® 9r w.aam C am aw Caribou 26 -11 #1 Drillintrogram NPRA Alaska 2003 -2004 Drilling Season TOTAL Caribou 26 -11 #1 Drilling Procedure 1. MIRU Nabors rig 14E over pre - in stalled conductor c asing. Attach landing ring to conductor. 2. Install diverter and function test. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12 -1/4" hole to the surface casing point at 3,034' RT. Run and utilize MWD tools throughout this hole section to monitor hole angle and to ensure hole remains vertical. 4. Condition hole for casing. POOH. 5. Run and cement 9 -5/8 ", 40 #, L -80, BTC casing to surface. Employ a lightweight permafrost cement lead slurry followed by a high strength Class G tail slurry pu mped via drill nine r stabbe int the casing shoe. Pump adequate excess cement to ensure cement reaches the surface. 6. Nipple down diverter and nipple up BOPE. Test B Notify regulatory agencies 48 hours prior to test. 7. Make up an 8 -1/2" drilling BHA and RIH to the top of the 9 -5/8" float equipment. Pressure test the casing to 3,000 psi for 30 minutes. Record the pressure test and fax the results to Anchorage. 8. Drill the float equipment and 20' of new hole. Perform a LOT (or FIT if the gradient exceeds 16 ppg EMW). Record the results and fax to Anchorage. 9. Drill an 8 -1/2" straight hole to the top of the Alpine Sands at + 8,981'RT, looking for core point. Run LWD logging tools in the drill string as required for formation data gathering. 10. At the coring point, POOH and P/U coring assembly. RIH. • 11. Take one 90' core in the Alpine interval. POOH. 12. RIH with the same 8 -1/2" drilling assembly used previously, ream the cored interval, and continue drilling 8 -1/2" hole to TD at +9,584'RT. 13. Condition hole for logging. POOH. 14. Rig up wireline. Run wireline formation evaluation logs per logging program. Rig down wireline. If the decision is made to plug and abandon the well, proceed to Step 23. 15. Make a cleanout run to condition the hole for running casing. POOH. 16. Run and cement 7 ", 26 #, L -80, BTC casing at +9,584'RT TD. Pump sufficient cement to bring_th(.top_t0- . ,+inn' R"T T OC should not be allowed to approach the 9 -5/8" casing shoe because the 7" X 9 -5/8" annulus will be used for annular injection of mud. 17. Make a cleanout run with bit and scraper. 18. Displace well to brine. 19. Run and land 3 -1/2" tubing completion. Pressure test tubing and annulus and freeze protect both. 20. Nipple down BOPE. Nipple up production tree and test to 5,000 psi. 21. Secure well and release rig. 22. MIRU well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be injected back into t he formation. 23. Upon completion of testing or iT ewe 1s not completed, plug and abandon the well per applicable regulations. Thoroughly clean location and access road. • - 1 - 0 0 Caribou 26 -11 #1 Proposed Wellbore Schematic Base Case (All depths measured from rotary table) 16 ", 65 #, H -40, PEB Casing @ +/- 110' lid Surface csg. 9 -5/8 " 40# L -80 BTC Casing @ +/- 3034' 20" Hole Top of tail slurry @ +/- 2400' 12 1/4" Hole 9 5/8" casing cemented to surface • 8 1/2" Hole TOC @ +/- 6900' (Approx. middle of Lower Torok Shale) Top of tail slurry @ +/- 8681' ( +/- 300' above top of Alpine Sand) i s 7" 26 # L -80 BTC Casing at 9584' TD TD @ 9584, TVD /MD TOT^ 4 TOTAL E &P USA Inc. Bill P-,-. 10114 0 0 • TOTAL E &P USA, Inc. Pressure Calculations and Drilling Area Risks Caribou 26 -11 #1 • • Maximum Anticipated Surface Pressure: The maximum anticipated surface pressure (MASP) for this well will be the lesser of the formation pore pressure (less a full gas column to the surface) at TD or the formation fracture pressure at the last casing shoe (less a full gas column to the surface). Based on the attached study " Pre -Drill Seismic Pore Pressure Prediction For Location #2 " the highest formation pressure expected in the final hole section is 5,143 psi at a depth of approximately 8,600' TVD (or 0.598 psi /ft). Documented fracture gradient data for this area indicates that the fracture gradient at 3 034'TVD (the 9 -5/8" su rface casing shoe) is a minimum o 0.754 psi /ft (14.5ppa) . Complete evacuation of the wellbore, except for a 0.11 psi /ft gas gradient, is assumed. 8 -1/2" hole section MASP (pore pressure) _ (8,600 ft)(0.598 — 0.11) = 4,197 psi MASP (fin breakdown) _ (3,034 ft)(0.754 — 0.11) = 1,954 psi Therefore, MASP in the 8 -1/2" open hole section is 1,954 psi and the 5,000 psi BOPE system to be used will be adequate. Well Proximity Risk: The nearest wellbore to that of the Caribou 26 -11 #1 is the Inigok test well located approximately 15 miles to the south. There are therefore no nearby wellbore proximity risks. Drilling Area Risks: See attached Drilling Hazard Summary. Disposal of Muds and Cuttings: Drill cuttings will be stored in bermed holding cells or appropriate containers on the ice pad and hauled to an established processing facility in one of the oil fields to the east at the conclusion of drilling operations at Caribou. Excess drilling mud will be hauled to an existing field to the east for disposal until the 7" casing is set, then the excess mud will be disposed of by being injected down the 9 -5/8" x 7" annulus. NPRAMProposed Well Ates • 0 • Figure 1 Tie to L306 N'[l fyt n at+Yix X11 � 11 { Ulu ! A 11 'qi > 011',(1,, I l k / {i t!': 1k r�f,1�`fi 3D Line Traverse Line CDP44 DEPTH (Datum set to RKB, M8Q FEET MSL 1000 2000 3000 4000 Is �aor 600 8001 900 1000 MSL 1000 2000 3000 4000 5000 6000 7000 8000 9000 • _ 10000 40 60 80 100 120 140160 8 9 10 11 12 13 14 15 16 17 18 19 20 NCTI Interrent. at. III -1T9 Iblgal Figure 3 — - -4i PLIESTOCENE r, �z IN --- - -- -- Locat 2 o PTD 9250' SS *� k - MSL 1000 2000 3000 4000 5000 6000 7000 8000 9000 • _ 10000 40 60 80 100 120 140160 8 9 10 11 12 13 14 15 16 17 18 19 20 NCTI Interrent. at. III -1T9 Iblgal Figure 3 0 0 N. INIGOK_1 Well Seismic Pressure Analysis DEPTH (Datum set to RKB, MR) FEET MSL MSL 1000 1000 1 2000 — 2000 3000 3000 4000 4000 li 1�1 ►1i__ 5000 5000 6000 - -- - -- --- - -- -- 6000 7000 — - - -- - 7000 8000 - -- — — - — 8000 9000 - - C 9000 10000 — - -- FG 1000 11000 - -- 1100 12000 1200 13000 _ -- _ -- -- PPG 1300 14000 -- 1401 15000 1500 40 60 80 100 120 140160 8 9 10 11 12 13 14 15 16 17 18 19 20 NCTL Intercept at ML =129 Iblgal Logarithmic Slope = - 3,30009e -05 -129 -33PLT PPTC (Sonic NCTL:129 -33 NCT, Top Trend Model: PLIESTOCENE) X129 -33PLT FGEA (Sonic NCTL:129 -33 NCT, Poisson Model: WEST CAMERON) Mud Weight: MUD Figure 4 U • • Hunter -A Seismic Pressure Analysis DEPTH (Datum set to RKB, M3L) M5L 100 200 300 400 500 600 70C 80C 90C 1000 110( 120( 1301 1401 15000 40 60 80 100 120 140 160 8 9 10 11 12 13 14 is 16 17 18 19 20 NCTL Intercept at ML = 129.966 Ibigal Logarithmic Slope = - 3.30003e -05 o DD_PPTC (Sonic NCTL 130 -33PLT NCT, Top Trend Model: PLIESTOCENE) o DD FGEA (Sonic NCTL:130- 33PLT_NCT, Poisson Model: PJEST CAMERON) Mud Weight: MUD Figure 5 FEET ........................ . ............. .......................................... i - -- -- - -- x000 - -- -- - 4000 I - -- - — -- - -- -- -•- 1 —� 6000 I - -- - - -- - _ n -- - - 7000 8000 -- -- FG 9000 10000 11000 _ L 12000 p PPG 13000 14000 0 -- -- - I 1500[ 0 0 • 0 INIGOV Well Seismic Pressure Analysis DEPTH (Datum set to RKB, M5L) FEET M5 MSL 100 200 300 0 400 500 0 600 700 800 0 900 1000 1100 1200 1300 400 1500 1600 1700 1800 1900 200 L ........................ . ............... ,.............. ............................... p — —��— 1000 0 —_ 2000 — — - -- - -- — 3000 p 4000 --- — -- — -- 5000 U -- 7000 -- WW 0 -- -- — — — _ -- -- 10000 132 eft — 0 — _ _ — 11000 -- �G 0 — _ _ 12000 0 -- -- — 13000 ° - PPG 14040 15000 0— 16000 0-- —. 17000 0— -- — 1 BOW Nuquiltu du ° P ressure calibration -' - - - 19000 00 20000 40 60 80 100 120 140160 8 9 10 11 12 13 14 15 16 17 18 19 20 NCTL Intercept at ML = 124,996 lhtgal Logarithmic Slope = - 3.2999e -05 --o- 125 -33PLT PPTC (Sonic NCTL:125- 33_UDEF, Top Trend Model: PLIESTOCENE) –x-125 -33PLT FGEA (Sonic NCTL:125- 33_UDEF, Poisson Model: VIEST_CAMEROII) Mud Weight: MUD FiEure 6 40 60 80 100 120 140160 8 9 10 11 12 13 14 15 16 17 18 19 20 NCTL Intercept at ML = 124,996 lhtgal Logarithmic Slope = - 3.2999e -05 --o- 125 -33PLT PPTC (Sonic NCTL:125- 33_UDEF, Top Trend Model: PLIESTOCENE) –x-125 -33PLT FGEA (Sonic NCTL:125- 33_UDEF, Poisson Model: VIEST_CAMEROII) Mud Weight: MUD FiEure 6 • 0 C BOP Control System r� The BOPE control system on Nabors Rig #14 -E is an NL Koomey Model 40200 -3S blowout preventer control unit with a 202 - gallon volume tank. Main energy is provided by a 40 HP electric motor driven triplex plunger pump rated at 20.2 gpm at 3,000 psi. The pump charges twenty (20) eleven - gallon bladder -type separator accumulators. A second energy charging system consists of two Model 31 -00103 air pumps rated at a combined volume of 11.0 gpm at 1,200 psi, or 7.2 gpm at 3,000 psi. The above two energy systems are backed up by six 220 cubic foot nitrogen bottles connected to the manifold system. All of the systems are controlled by a Model SU2KB7 series manifold with seven manual control stations at the unit. 0 0 9 1. MUM AN#M MORKLY 0 0 � v T 'ii i ao h7m MSP W AXIMALOW \ / � \ / ® ANN" amm VM 10 21114- PFM �&%M L i d W. 36 gn JIM FLAP= 16' Of VALVE DIVERTER CONFIGURATION 101 7 ed 16' 10iFE VALVE -gill 412" f#M" AWW C Shr" wo c_ 295l 1 1 A NABORS ALASKA RIG 14E D A OWNWIM INVAM TO W FOWT ALASM MG 14E MN" 2M c PM LNE LAYDIff DIVERTER LINE LAYOUT , =2 B PM 1 16 MUM SMM A PAA JW ALSW I _WW WOU awfimul PAA MANG 004A115 WE Z' I WA 1 A A "I i � I -- ---- 1-1 .. 0 0 0 KILL LINE #1 3" 5k GATE VALVE 3" 5k HCR VALVE 3" 5k CHECK VALVE 3 -1116" 5k FLG x 2' 5k UNIBOLT FITTING REFERENCE KILL LINE 12 FOR ALIGNMENT i 14" OPERATOR E -- 4- 14' OPERATOR 10" OPERATOR -- -- - - -- -- 10' OPERATOR HYDRIL 13 -518" 5k PSI GK ANNULAR BOP SCREW HEAD FLANGED BOTTOM CONNECTION 54 -118" LENGTH HYDRIL 13 -518" 5k PSI HYDRAULIC RAM SINGLE GATE FLANGED CONNECTION 36' LENGTH HYDRIL 13-518"5k PSI HYDRAULIC RAM SINGLE GATE FLANGED CONNECTION 36' LENGTH BLIND SHEARS 4" PIPE RAMS 4" 5k HCR VALVE DRILLING SPOOL 13 -518" 10k BLIND FLANGE Imo^ 4" CHOKE LINE 4 -1116" 5k (CHOKE SIDE) 4' 5k GATE VALVE 10" OPERATOR -- - - -- I - --- -- 10" OPERATOR 3" 5k 017E VALVE 3" 5k GATE VALVE —� KILL LINE #2 2" 5k KILL LINE --r {l -y- BLIND FLANGE 3 -1116" 5k FLG x 2' 5k UNIBOLT FITTING 3" 5k CHECK VALVE HYDRIL 13 -518" 5k PSI HYDRAULIC RAM SINGLE GATE FLANGED CONNECTION 36" LENGTH DRILLING SPOOL 13 -518" 10k 3 -1116" 5k (KILL SIDE) 3.1/2" x 6" VBR's NABORS ALASKA RIG 14E BLOWOUT PREVENTOR STACK CONFIGURATION 0 0 0 Material List Item Description A 3 1/16" 10M Manual Choke B,C 2 9/16" 10M Remote Super Choke 1,2,4,5,7,8,17 -19 Type FC 3 1/16" 10M Gate Valve 15,16 Type FC 4 1/16" 10M Gate Valve 3,6,9 -14 Type DM 3 1/8" 5M Gate Valve Legend a� White Handle Valves Q Normally Open ® Red Handle Valves Normally Closed Date: 10 -13 -00 Rev. 1 12 13 10 w oi w oil 0 0 0 DERRICK 20 CONE DESILIER F c a p s .. S TO p E m y FLOWLINE 75 HP F10CCUIFINT vER17G4< INMECTKIN (J) DERRICK SWACO GALIGHER m SHALE SHAKERS 5 p+E pENCO s m PUMP CRISAFUW MOD. 2000 v oioE Ioso cvM a CENTRI Lan amws TO asf-osv e .W0 GvLON �S FROM WWVpD FAfo a>ANEN _ y a6uKx UM so � � rMS� rEco T A W FLUD MUD GUN 10.0 ro0 mw tr et -feo $ k ffi ' MANIFOLD DECAM JET (UNIIF1aNm PIONM 5RCI6NaR W - TAWS lANX5 o-assw u NFECnaF AW HbPFV?s Aa. a er -nASS amyl CHW e � �� Eaua� urA- MUO U � IJ6.6BH w IJB.7 d� 001 FIT 198.0 E6L IS]I 6BL m I at &5 661. db �b VOLUME p! W0 14&5 1& ccbb MP IMP �W TAW 45 m ® 66L Sw N U50 FUR 006M DESWDER ® ov MUD CHARGE PUMPS . 75 HP GALICHER C GAL)CHER G AUGHER TRP TANK 4X6 GALIGHER 4X6 uuo/wAmt95 rfr 4 X 6 PUMMPP 4z6'S PUMP PUMP 4X6 UNE GAUGHER W HOLE FpL & 75 HP 75 HP 75 HP 75 HP C4SW FILL IMIS 70 0 OR L A- 1700PT MUD PUMPS MUD SUCTION & DISCHARGE TO AUXILWRY TANKS OR VACUUM TRUCKS CENTRIFUGE NJtxii0lN 61ix PUMP LINE MISSION IIX' BLIND 11/2X2 na a • sauFOEnxr omM a roeoa Mmlmclox an usE a C6CM 6 fFWR991E OILY f �WIII01 ®M 6! WBMS NA9Ll NABORS ALASKA RIG 14E Nabor :Almlm �°N z� �ANA9A.9 � °° 26r-°°°° � MUD SYSTEM SCHEMATIC FYn�r NAWRS NAW RIG 14E 1000 BBL ACTIVE SYSTEM IWO c JI A9��F99N.p9� �mF � 9�TU. " MUD SYSTEM SCHEMATIC WITH DEWATERING UNIT 19Nw01 6 m ft1 KCWN FM Nn mm W, 1000 aX_ ACTNE SYSTEM WITH DEWATERING UNIT �m m �. PAA DRAWING 004.0206 20 AN OI A A\ CMMW MW W M0 FMW F1k - C WE W °fir i DOW" N A � N 9NK 2U01 � �" 14E DOW Caribou Drilling PrograTn NPRA Alaska 2003 -2004 Drilling Season 1 * TOTAL Caribou 26 -11 #1 Cementing Program 9 -5/8" Surface Casing (Set at 3,034') Spacer: 50 bbls water Pre - Flush: 50 bbls, density 10.2 ppg Lead Slurry: Top of slurry: Surface Permafrost Cement, density 10.7 ppg Excess: 250% across permafrost interval from surface to 1200' 30% in open hole between 2,400' and base permafrost Yield: 4.15 cu ft/sk Volume (including excess): 213 bbls (288 sx) 0 Tail Slurry: Top of slurry: 2,400' Class G + 2% Calcium Chloride, density 15.8 ppg Excess: 30% in open hole Yield: 1.15 cu ft/sk v Volume (including excess): 53 bbls (259 sx) l � u - 1 - Caribou Drilling Program NPRA Alaska 2003 -2004 Drilling Season TOTAL 7" Production Casing (Set at 9,584' TD) Spacer: 5 bbls water Pre - Flush: 25 bbls, density 10.2 ppg Lead Slurry: Top of slurry: 6,900' (middle of Lower Torok) Class G + 15% light weight extender + 0.2% friction reducer + 0.75% fluid loss additive + 0.05 g/sk anti -foam + retarder as required. Density 12.5 ppg. Excess: 30% in open hole Yield: 2.36 cu ft /sk Volume (including excess): 52.3 bbls (125 sx) Tail Slurry: Top of slurry: 8,681' ( +300' above top of Alpine Sands) • Class G + 0.6% latex polymer + 0.5% friction reducer + 0.05 g/sk anti - foam + retarder as required. Density 15.8 ppg. Excess: 30% in open hole Yield: 1.16 cu ft /sk Volume (including excess): 30 bbls (143 sx) is -2- Caribou Drilling Progrot NPRA Alaska 2003 -2004 Drilling Season is TOTAL Caribou 26 -11 #1 Drilling Fluid Program The TOTAL Caribou 29 -11 #1 will be drilled from surface to TD using a low- solids, non - dispersed, inhibited 6% KCl /polymer mud system. The well will be spudded using a 10.0 ppg high- viscosity spud mud to aid in cleaning the shallow portion of the hole where surficial gravels are anticipated. After setting the 9 -5/8" surface casing at approximately 3,000', the mud system will be treated to lower the density, solids content, viscosity and otherwise adjusted to drill the remainder of the hole with a high quality mud suitable for handling the potential problems of sloughing shales and/or lost circulation. It is not anticipated that any wholesale change -outs of the mud system will be performed at any point because disposal of the old mud system could be problematic. Planned drilling fluid properties are as follow: Interval (RT) MW Vis PV YP API WL Surf — 3000' 10.0 — 10.5 75-95 25-30 35-45 5-15 3000' -7500' 9.5 — 10.5 45-55 15-20 10-20 5-7 7500' -TD' 10.0-12.0 45-55 15-25 15-25 3-5 • Cuttings will be retained in a bermed cell on the ice pad or in appropriate containers and later hauled to one of the established fields to the east for processing and disposal. However, waste drilling fluid will be retained in liquid form on location until the 9 -5/8" x 7" annulus becomes available, whereupon the waste mud will be injected down the annulus. Since the most common and most significant hole problems experienced in the offsetting wells were those of lost circulation and sloughing shales, adequate supplies of LCM and shale inhibitors will kept on location. Also, an adequate barite supply will be maintained to weight up the mud system in response to any need to control unanticipated pressure. Finally, while H2S is not anticipated in this well, the remoteness of the location dictates that a supply of H2S sequestering agents be maintained on location. i s BE • TOTAL. ESOP USA, INC. December 3, 2003 Ms. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 RE: Application for Permit to Drill: Total Caribou 26 -11 #1 Dear Ms. Palin, HAND DELIVERED TOTAL E &P USA, INC. (Total) submitted a Permit Drill package to the Alaska Oil and Gas Conservation Commission (AOGCC) on November 15, 2003 for an onshore exploratory well in the NPRA area of the North Slope. It has come to our attention that Total failed to sign and date the Forms 10 -401 with the signature of the Total Drilling Manager. We regret any inconvenience our oversight may have caused the agency and hope the error will not cause a delay in the processing of the Total permit to drill package. Attached are the signed form 10 -401 Application for Permit to Drill (Public Information) — 1 copy and the signed Form 10 -401 Application for Permit to Drill — 2 copies. If you have any questions or require additional information, please contact me at (907) 743 -0970 Sincerely, Jean-Franc ost Alaska D 'ling Manager Enclosures DEC Alaska Cif & Gas Cons. Commission Anchorage 4300 B Street, Suite 303, Anchorage, AK 99503 TOTAL Tel 907 743 0970 - Fax 907 743 0979 • TOTAL. C&P USA, INC. • November 15, 2003 Ms. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: TOTAL Caribou 26-11 #1 Dear Ms. Palin, TOTAL E &P USA, Inc. hereby applies for a Permit to Drill an onshore exploratory well in the NPRA area of the North Slope. The well, called the Caribou 26 -11 #1, will be located approximately 48 miles west of the village of Nuiqsut and 15 miles north of the Inigok #1 test well. TOTAL plans to spud Caribou 26 -11 #1 approximately February 15, 2004. Ice road/pad construction equipment will be pre - mobilized to the existing Inigok staging site via • aircraft. Then, upon receipt of all necessary permits and approvals (including tundra travel authorization), an ice road will be constructed extending approximately 15 miles north from Inigok to the Caribou 26 -11 #1 drilling location where an ice drilling pad will be built. The drilling rig, Nabors 14 -E, will then be mobilized via rolligon from Meltwater 2P Pad to the drilling location, the well drilled to TD and tested if log results warrant. The rig will be demobilized via rolligon. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill (Public Information) - 1 copy 2) Form 10 -401 Application for Permit to Drill — 2 copies 3) Fee of $100.00 payable to the State of Alaska 4) Well Prognosis and discussion of Operational Considerations 5) Location Plat and Drill Pad Layouts 6) Days vs. Depth Drilling Curve 7) Drilling Procedure 8) Wellbore and Wellhead Schematics 9) Pressure Information including pore pressure, mud weight and fracture gradient curves, offset well mud weight curves, maximum anticipated surface pressure calculations, FIT and LOT procedures, and casing properties and design factors. 10) Dlverter, BOP and choke manifold schematics • 11) Cement Program 12) Drilling Fluid Program 4300 B TOTAL Tel 907 743 0970 - Fax 907 743 0979 Street, Suite 303, Anchorage, AK 995ORIGINAL • 0 TOTAL ESOP USA, INC. Ms. Sarah Palin Page 2 As part of this Application, TOTAL also requests approval for the annular injection of drilling wastes as discussed in the attachments. The AOGCC is requested to keep confidential all information included in the Application for Permit to Drill (except the Public Information copy) as information in these documents is drawn from research and data proprietary to Total. For your information, this permit request is being simultaneously submitted to the U.S. Bureau of Land Management. If you have any questions or require additional information, please contact me at (907) 743- 0970. Sincerely, TOTAL F J�SA, • cois Prost Jea Manager enclosures • E. SIMP30N 1 'r/. D4LTrAl 1 Caribou 26 -11 #1 Proposed Location 12/4/2003 T. FOR I 7F77 1 r 1 P PIK TEST 1 IKPIY•P"JO 1 40CP,RIBG'J 21 -11 1 FISH Gi k 1 FlS GRK TEST 1 SE TOOTH C ENDEZVOUS A RENDEZVOUS 2 Feet 0 5.0,00c 1 i 10,i uj ii Caribou 26 -11 #1 (203 -196) Surface Hole Log ing Program; Sampli... 4R Subject: Caribou 26 -11 #1 (203 -196) Surface Hole Logging Program; Sampling Program From: Stephen Davies <steve davies@admin.state.ak.us> Date: Mon, 08 Dec 2003 14:44:24 -0900 To: john.johns@total.com CC: Tarn Maunder <torn rnaunderCa).admin.state.ak.us> John, The dipole -type sonic is an acceptable substitute for neutron / density porosity logs. So, the surface hole (110' to 3034' MD) logging program must record gamma ray, resistivity and dipole -type sonic information to allow determination of the base of permafrost, distribution of salinity within shallow aquifers, and determination as to whether gas hydrates were penetrated by the well bore. Wet samples are not necessary for this well. Per regulation 20 AAC 25.071(b)(2), Total must provide the Commission with a complete set of washed and dried, legibly identified samples of all drill cuttings, as caught by the operator in accordance with good geological practices, consisting of a minimum of one - quarter cut in volume or three ounces in weight of cuttings for each sample interval. The sample interval for these dried cuttings must be no greater than 30' below permafrost (although, being practical, allowances are made for rapid drilling rates in the shallow geologic section); 10' sample intervals are required through target zones. If you have any further questions, please call me at 907 - 793 -1224. Steve Davies 1 of 1 12/22/2005 11:54 AM Bonding Requirements for Caribou 26 -11 #1 • 0 Subject: Banding Requirements for Caribou 26 -11 #1 From: Stephen Davies <steve_davies admin.state.ak.us> Date: Mon, 08 Dec 2003 13:38:23 0900 To: bill @fairweather.com CC: Tom Maunder <tom maunder a adnrin.state.ak.us> Bill, The bonding information provided on the Permit to Drill application filed for Total's Caribou 26 -11 #1 well is incorrect. The Commission's bonding requirements are outlined in regulation 20 AAC 25.025 (attached below). These requirements are in place to ensure that every operator drills, operates, maintains, and eventually abandons each of its wells in accordance with Commission regulations. Our requirements also ensure that each drill site is properly remediated once the well (or wells) on the site have been abandoned. Please note that the bond must be authorized "...by an authorized insurer under AS 21.09 whose certificate of authority is in good standing... ". You can contact Linda Brunette at the State Division of Insurance (907- 465- 3422)to see if an institution is authorized to transact insurance business in Alaska. Surety Bond form (10- 402A)is available on our web site at: http : / /www.aogcc.alaska.gov/ . Commission regulations, a description of the drilling permit application process, our forms, and other information are also available on our web site. If you have any further questions concerning the Commission's bonding regulations, please call me at 907 - 793 -1224. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission 20 AAC 25.025 BONDING. (a) An operator proposing to drill a well for which a permit is required under 20 AAC 25.005 shall file a bond and, if required under (2) of this subsection, security to ensure that each well is drilled, operated, maintained, repaired, and abandoned and each location is cleared in accordance with this chapter. The bond must be (1) a surety bond issued on Form 10 -402A in favor of the Alaska 1 of 2 12/8/2003 1:42 PM Bonding Requirements for Caribou 26 -11 #1 0 0 Oil and Gas Conservation Commission by an authorized insurer under AS 21.09 whose certificate of authority is in good standing; or (2) a personal bond of the operator on Form 10 -402B accompanied by security guaranteeing the operator's performance; security must be in the form of a certificate of deposit or irrevocable letter of credit issued in the sole favor of the Alaska Oil and Gas Conservation Commission by a bank authorized to do business in the state, or must be in another form that the commission determines to be adequate to ensure payment. (b) A bond and, if required, security must be in the amount of not less than $100,000 to cover a single well or not less than $200,000 for a blanket bond covering all of the operator's wells in the state, except that the commission will allow an amount less than $100,000 to cover a single well if the operator demonstrates to the commission's satisfaction in the application for a Permit'to Drill (Form 10 -401) that the cost of well abandonment and location clearance will be less than $100,000. (c) A bond and, if required, security must remain in effect until the abandonment of all wells covered by them and until the commission approves final clearance of the locations. The commission will then release the bond and security upon written request of the operator. (d) Payment under a surety bond or security does not relieve an operator from the requirements of AS 31.05 and this chapter except to the extent that a default is actually cured, or from any liability under AS 31.05.150. History - Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152 Authority - AS 31.05.030 AS 31.05.150 2 of 2 12/8/2003 1:42 PM ALASKA OIL & GAS CONSERVATION COMMISSION FAX 907- 276 -7542 PHONE 907- 279 -]433 FACSIMILE TRANSMITTAL SHEET . TO: FROM: COMPANY: DATE: LZ FAX NUMBER: TOTAL NO. OF PAGES INCLUDING COVER: PHONE NUMBER SENDER'S REFERENCE NUMBER: RE: YOUR REFERENCE NUMBER: of URGENT ❑ FOR REVIEW ❑ PLEASE COMMENT ❑ PLEASE REPLY ❑ PLEASE RECYCLE NOTES /COMMENTS: AOGCC 333 WEST 77M AVENUE, SUITE 100 " UnVAr -P AK 99501 -3935 I- December 1, 2003 Total E &P USA, Inc. 4300 B Street, Suite 303 Anchorage, AK 99503 Attention: Mr. Jim Rose, Drilling Engineer Dear Mr. Rose: G Total E &P USA, Inc.'s ( "Total ") permit to drill application for the Caribou 26 -11 No. 1 well mentions disposal of waste drilling mud by pumping into subsurface formations at about 3,000' measured depth via the 9 -5/8" by 7" casing annulus. Annular disposal cannot be approved as part of a permit to drill. Total must make a separate request for annular disposal of drilling waste to the Commission. Regulation 20 AAC 25.080 governs annular disposal and lists information that must be provided in support of a request for annular disposal. This regulation and other Commission drilling regulations are available on the Internet at: htlp• / /w state ak us/ local /akpag_es /ADim.1N /ogc /Regulations /artI99 htm A full suite of logs (GR/resistivity /density /neutron) must be obtained from conductor shoe to T.D. of the Caribou 26 -11 #1 well to determine salinity distribution in shallow aquifers and the base of permafrost (as required by 20 AAC 25.080), and to facilitate analysis for gas hydrates. Let me know if you have any additional questions. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) 793 -1224 Fax: (907) 276 -7542 cc: Tom Maunder, AOGCC 89-5 3446 2650 JOHN E. BERGERON, JR. 1252 LESLIE BERGERON 7368854472 25628 BENDILENT CIR. 907-622,2720 Lyi EAGLE RIVER, AK 99577 L Fi K � C (D Wells Fargo Bank Alaska, N.A. Anchorage, Alaska www.welisfargo.com �k'l (1 1 S 2 0 00 S 71:736 [Fwd: TOTAL - BLM Meeting] Subject: [Fwd: TOTAL - BLM Meeting) From: Tom Maunder <tam maunder a@admin.state.ak.us> Date: Tue, 21 Oct 2003 07:47:17 -0800 To: Jim R.egg <jlm regg a ad ln.state.ak.us> Jim, Bill Penrose called me yesterday and then forwarded this message regarding a meeting on Total's planned NPRA well. This Stan Porhola is a new engineer working at BLM. I have not met him. Please have a look at the agenda. There are a couple of topics there of interest. Bill's feeling is that Stan is "gung ho" to make sure all is in order. I think there are some topics that can't really be specified right now. According to Bill, Total is considering annular disposal as the option for whatever waste liquids they have. Of course they have to have an annulus, although Anadarko did dispose of liquids in Lone Creek 2 after setting a cement plug in the open hole. I also am not sure what "• AOGCC - BLM interaction" means. The Total location is likely to be only accessible by air or a long rollagon ride. If things stay true to form, BLM will camp someone out there. At this time, it appears that Total and ConocoPhillips will have at least 1 well out there in the coming season. Let me know your thoughts /preferences. At present, I am planning to go to the meeting. Tom ForwardedMessage.eml Content -Type: message /rfc822 Content - Encoding: 7bit I of 1 12/22/2005 10:18 AM TOTAL -BLM Meeting Subject: TOTAL - BLM Meeting From: Bill Penrose <billfairweather.com> Date: Mon, 20 Oct 2003 14:13:33 -0800 To: Bob Gardner <bob @fairweather.cam >, "Erwwan Couzigou (E-mail)" <erwan.couzigou a tots .com =, "George Snodgrass (E- mail)" <George.SNODG.SRASS total.com >, "Jack Bergeron (E- mail)" <jack.bergero_n@total.com >, "Jean- Francois Prost (E-mail)" < jean- francois.prost(a total.corn >, Jeff Osborne <josborne@fairweather.com.>, fairweather.com. >, "Stan Porhola (E- mail)" <Stan Porhola cr ak.blm.gov>, "Tom Maunder (E- mail)" <tom_maunder @admi n. state. ak. us> CC: "Lianne Hopper (E- mail)" <Lianne.H0PPER total.com >, Bill McLaughlin <billmclaughlin@fairweathi�-r.cor Ladies and Gentlemen, Please see the attached meeting announcement. I can be reached at (907) 258 -3446 with any questions. Stan Porhola, please distribute this message to those attendees within the BLM organization. Thanks! Regards, Bill Penrose TOTAL - BLM Meeting.eml TOTAL -BLM Mtg Memo.doc.DOC 1 of 1 12/22/2005 10:18 AM To: Meeting Attendees (See list below) RE: TOTAL / BLM Meeting A meeting has been arranged between the Bureau of Land Management (BLM), TOTAL E &P USA, Inc., their contractor Fairweather E &P Services, Inc. and the Alaska Oil & Gas Conservation Commission (AOGCC) to address issues concerning the upcoming NPRA winter exploration season. This is seen as an opportunity for everybody to meet and further open the lines of communication in order to improve industry and regulatory interactions. Meeting details are below. Meeting Date, Time and Location Date: October 22, 2003 Time: 2:00 p.m. Location: The offices of TOTAL E &P USA, Inc. 4300 B Street, Suite 303 (at the corner of Tudor Road and C Street) Anchorage, AK 99503 (907) 743 -0970 Agenda (as suggested by BLM) • Inigok Storage • Inigok as a disposal well • ROW Permits • Next winter season • APD, NOS • Future change of plans • Operations timetable • Inspections, camp, flights • Abandonment procedures • Rig removal • Other federal permitting concerns • AOGCC — BLM interaction • Information confidentiality • Exploration partners • NW/NE NPRA EIS • NPRA Staging Area • Setting up future meetings • • Attenrleec Jack Bergeron TOTAL Tom Maunder AOGCC George Snodgrass TOTAL Jean- Francois Prost TOTAL Jeff Osborne Fairweather Erwan Couzigou TOTAL Bob Gardner Fairweather Bill Penrose Fairweather Greg Noble BLM Stan Porhola BLM Beau Brown BLM Don Meers BLM Mike Worley BLM As the length of this attendance list is nearly the capacity of TOTAL's conference room, participants are requested to refrain from inviting additional attendees. Thank you. We look forward to seeing everyone there. Sincerely, FAIRWEATHER E &P SERVICES, INC. 2 Bill Penrose Preliminary Project Description (Executive Summary) TOTALFINAELF E &P USA, INC. 2003 -2004 Winter NPR -A Exploration Drilling Project Prepared for Multi - Agency Pre- Permit Application Conference April 24, 2003 TOTAL FINA ELF J. E. (Jack) Bergeron, Jr., P.E. TotalFinaElf E &P USA, Inc. Alaska Manager 4300 B Street, Suite 303, Anchorage, AK 99503 Tel: 907 743 0970 - Fax: 907 743 0979 Res: 907 222 3974 - Mobile: 907 229 8214 jack.bergeron@us.ep.totalfinaelf.com Jeff Osborne, P.E. Project Manager Y _ E & P SERVICES, INC. 715 L Street #4, Anchorage, AK 99501 (907) 258 -3446 Fax: (907) 258 -5557 By Cell: (907) 441 -6600 E -mail: josborne@fairweather.com Fairweather E &P Services, Inc. Anchorage, Alaska Alpine- Meadowlnc. tEnvir onmental Consulting Services George R. Snodgrass ^ ^. President _ 11043 Tsusena Circle, Eagle River, i Alaska 99577 -8114 ? 1 d phone /fax (907) 694 -7423 t email: grsnodgrass@alpine-meadow.com website: www.alpine - meadow.com • 1.0 Introduction TOTALFINAELF E&P USA, INC. (TotalFinaElf) is a 100% working interest owner in approximately 230,000 acres of oil and gas leases in the Northeast Planning Area of the National Petroleum Reserve - Alaska (NPR -A). This acreage was acquired in 20 tracts selected and awarded in the June 2002 NPR -A oil and gas lease sale. The attached map shows the location of this acreage. TotalFinaElf has carried out extensive geological and geophysical studies in the area, and is now prepared to move into the exploratory drilling phase of what may become a multi -year program aimed at fully exploring and evaluating this acreage. The first well in this program is scheduled for the 2003 -2004 winter drilling season, and permitting activities for this project have been initiated. Geophysical data acquisition activities in the 2002 -2003 winter season have only recently been completed and interpretation of this data will be ongoing for some weeks to follow. It is important to understand that until this work is completed, a final well location will not be selected. TotalFinaElf plans to permit a total of five or six possible well locations within the identified prospect areas (see Section 2.0 b — elo – w - 7 with the objective of drilling only one of these locations in the 2003 -2004 winter season. None of these potential ocatl Lions have been selected as of this date (April 24, 2003), however some information on the operational approach toward this exploratory drilling project is known: • All work will be consistent with the stipulations defined in the Final Integrated Activity Plan/Environmental Impact Statement, and no requests for exceptions to these stipulations are anticipated. • A rollig tr ansportable rig will be used. • An ice exploration drilling pad will be used. • Drilling Operations will be supported by both rolligon and aircraft. A summary project schedule is attached which shows the anticipated dates for rolled - up project components. 2.0 Prospect Areas Three (3) prospect areas have been preliminarily identified by TotalFinaElf. It is anticipated that the five or six drilling locations for which permits will be sought will be within these prospect areas. These preliminary prospect areas are: Caribou East: Situated in the vicinity of Townships 9N., 5W; ION., 5W; and 11N., 6W. Caribou West: Situated in the vicinity of Townships 9N., 7W; and ION., 7W. Fox: Situated in the vicinity of Townships 6N., 6W; and 7N., 5W. • • 3.0 Drillsite Construction An ice drilling pad will be used for the exploration well. The selected drilling locations to be permitted will be surveyed for archaeological significance and unique biological communities during the snow free summer months of 2003. Ice pad design will be finalized once the final drilling location has been selected, and the specific drilling rig to be used is identified. A reserve pit will not be constructed. After drilling operations are completed and the rig, camp and ancillary equipment are demobilized, the pad will be shaved as necessary; the recovered ice chips melted and the resultant water be injected at an approved North Slope facility. 4.0 Drilling Rig A rolligon transportable arctic class land drilling rig will be used for the proposed project. The specific rig has not been identified as of this date (April 24, 2003), as rig negotiations are still ongoing. 5.0 Disposal of Cuttings, Drilling Mud and Waste The management and disposal of waste will be consistent with a project waste management plan which will be prepared as part of the permitting process and as required by the stipulations. Waste mud and drill cuttings will be disposed of by either annular iri ection or by freezin g and backhauling to an approved grind/inject facility in Prud oe Pay. Ballot agreements with the Prudhoe Bay Unit Owners for this activity are Bing negotiated. 6.0 Logistics and Support The exploration well will be supported by both rolligon and aircraft. The existing 5,OOOft. gravel airstrip at Inigok may be used as part of this effort as it is located between the Caribou East a d Fox prospect areas. Support options are currently being evaluated in the context of distance, cost, weather capability and contingency risk. Present plans call for fuel to be delivered by aircraft flying out of Deadhorse either to a purpose built ice strip close to the drilling location, or to a fuel depot which would be installed at Inigok. A project support and logistics plan will be prepared after the various options have been thoroughly evaluated. 7.0 Contingency Planning An Oil Discharge Prevention and Contingency Plan (C -Plan) is required for the proposed operations. The C -Plan will be prepared in accordance with specific format and content requirements as specified by 18 AAC 75. The C -Plan will be designed to cover multiple wells with site - specific information for each drilling location provided as a separate appendix. A current Spill Prevention Control and Countermeasure (SPCC) Plan (as required by 40 CFR 112) for the selected drilling rig will also be contained within the C -Plan. J TotalFinaElf E & P USA, Inc. 2003 -2004 NPR -A Exploration Summary Project Schedule 2004 Task Name Start Finish Mar Apr May Jun Jul Aug Sep! Oct Nov Dec Jan j Feb Mar Apr May Jun Jul 2003 -2004 Exploration - Permitting & Operations Tue 4/1/03 Sat 5/1104 4/1 396 days Initiate Permitting Process Tue 4/1/03 Tue 4/1/03 411 Agency Notifications & Meetings Thu 4/3/03 Sat 5/3/03 30 days Permit Applications & Documents Thu 4/3/03 Tue 9/30/03 180 days Field Data Collection and Route Selection & Clearance Tue 7/1/03 Sat 8/30/03 Ys Permit Submittals Sun 10/5/03 Wed 10/15/03 10 days Permit Reviews by Agencies Fri 10/10/03 Thu 12/4/03 55 days Permit Approvals & Authorizations by Agencies Sun 11/9/03 Wed 12/24/03 days Authorization to Proceed w/ Exploration Season Thu 1/15/04 Thu 1/15/04 1/15 Mobilize Equipment Thu 1/15/04 Mon 1/19/04 4 days Construct Ice Pad & Roads Mon 1/19/04 Wed 2/4/04 16 days Move and Rig Up Rig Wed 1/28/04 Fri 2/27/04 30 days Drill Well Fri 2/27/04 Mon 3/22/04 24 days Test Well Tue 3/23/04 Wed 3/31/04 8 days Plug & Abandon Well Thu 4/1/04 Mon 4/5/04 4 days Demobilize Rig and Equipment Mon 4/5/04 Sat 5/1/04 26 days Exploration Well Operations - Complete Sat 5/1/04 Sat 5/1/04 5/1 Task Rolled Up Task `. External Tasks — -- - -- Project: NPRA Exploration Schedule Progress Rolled Up Milestone 0 Project Summary Date: Thu 4/24/03 Milestone Rolled Up Progress Summary Split Page 1 Thu 4/24/03 J 0 TOTALFINAELF E &P USA, INC. 2003 -2004 WINTER NPRA EXPLORATION DRILLING PROJECT MULTI - AGENCY PRE- PERMIT APPLICATION CONFERENCE APRIL 24, 2003 AGENDA 1. Welcome and Introduction of Guests R.C. Gardner 2. Safety Minute R.C. Gardner 3. Conference Objectives R.C. Gardner 4. Introduction to TOTALFINAELF and Jack Bergeron Project Description 5. Permitting Team R.C. Gardner 6. Questions and Discussion All 7. Wrap Up and Summary of Action Jeff Osborne Items 8. Adjourn Note: A buffet lunch will be served at 11:30am. We intend to continue with questions and discussions through lunch, as necessary to address outstanding issues. Project Manager TotalFinaElf E &P USA, Inc. Bob Gardner Frank Brown Fairweather Project Manager Fairweather Project Advisor ------ Pre - Application Conference Native Issues Plan of operations Coastal Project Questionnaire Subsistence Monitoring Plan ------------- -- - - -� i Jesse Mohrbacher - - - - - -- Houston, TX Liaison ------- - - - - -� Bill Penrose Permits to Drill CJ Duane Vaagen Permits to Drill rar.rulat Iniectior. Approva'. WA / Polar Bear interaction Plan 'T empomy Storage of Drilling Wastes Jeff Osborne, P.E. Sherron Perry Assistant Project Manager IFR Certification Land Use (if necessary) Federal Right of Way NSB Development Permit Title 16 Fish Habitat General Waterway/Waterbody Application Temporary Water Use Notice of Staking Hoefler Consulting Group Bob Britch, P.E. ( I AI Trbovich, CCM DDPCP (Spill Plan) Air Quality Permit by Rule SPCC Plan (if necessary) Reamer & Associates I PSI Environmental and Instrumentation Rick .Reanisr, PI.D Amie Mahler Cultural .esource clearance Waste Management Plan Lake Suneys I I Hazardous Materials Contingency Plan Ber. 6 Associates/ASCG J.V. Surveying Services ERA I Air Logistics Helicopter Services Lee Ann Gardner I I Sandy Hamann T&E Species Environmental Assessment Ecology and Fish Habitat Issues NPR -A Exploration Permitting Project Organizational Chart TOTALFINAELF E & P USA, Inc. (TFE) 2003- 2004Winter NPRA... 0 0 Subject. TOTALFINAELF E & P USA, Inc. ( TFE) 2003- 2004Winter NPRA Explorat ion Drilling Program From: Bob Gardner <bob�,?a fairweather.com> Date: Thu, 10 Apr 2003 1.3:20 :05 -0800 To: " ak:blm.g ©v`" <rnworley ak.bl� .goV >, "'darer huebner a( ak.b m. oV"' <darek_huebi er{ ak.blm.gov >, "'don_meare (ar:blm.goV" <don meares@ak.bina..gov >, "'Grcg noble @blm.gov'" <Greg_noble 3a b1m.gov >, "'rockwell.theodore@epa gov "' <rockwell.tbeodore @epa..gov >, " +leonl@dnr.state.ak.us` <leonl @dnr.state.ak.us > "' Stev'e_sch itz@dnr.swe.ak.u.S " Steve Scl nt 1t @dnr.state.ak us>, "br Gt'_yebb drl. state.ak us'" <bruce_webb dna.state.ak.us>, "'Iydii mi er dec.state.atk ust" <lydieLminer@ded.state ar us>, „r lenn, gray gov.State.ak.us"' •5 eu21 rc y C3v.St�.�,A.115`' , rstk Ugh @j .dEll,gflV <klaughligpo.doi.gov >, tr ott@fishgame.state.a .ust'r l ott@fishg :me.state.ak us>, "'tom maunder u@admm.state.ak.us "r toam maunder@ dmin.state.ak.us>, ttr firt =tt' . i# palriciab dnr.state.ak us <patciciabl�a dnr.state.ak.us>, ,scoff schliebc@fws.gov <Scott schliebe@fws.gov >, + "craig _perham @fWs:gov'" < cram per s;gc v >, • ,,:'' �juliery(c dn�r.state.al .us uli ry@dnr.s�.dk u ; "'Sh ldon.oam rth- lc�pe c�rg'"` ,; m -.Sheldon.adams@ north slope.or ?-$ " *okak€ik.tei earth -sl e.orgt" <okakok.;rex @ric.r&41o� ! ..car ,:`: "T� rc 6net " 4f abrvwfi(i gc net> TJack.berg� {4Vs. ' iaM aelfcc m`tfi <Taclk.bergero u (bus.ep tci lfmaell:com >;:t siiodgmss @c :i�,p:totalfinaelf cc mfi" l�a�r�.Wtlts�(oe���n1E�iL.Ci�,: 13b� er( eski is . oiri. , Jeff Osbon <bfll@fidrweather.com Dear Colleague: F9 °rrr�i ' x On behalf of TFE, I want to extend an invitation to a pre - permit application conference and information exchange covering the above referenced exploration drilling program. This conference is scheduled for 10:00 A.M., Thursday, April 24, 2003 at the Sheraton Anchorage Hotel, 401 E. 6 Avenue, Anchorage Alaska. In the event I have discussed this meeting with you previously, please note the change in meeting location. We were unable to secure space in the Millennium Hotel, as originally intended, and we are now firmly scheduled for the Sheraton Hotel. We anticipate that the meeting may last up to three hours. In order for us to work comfortably through the lunch hour, a buffet lunch will be available at approximately 11:30 A.M. At this meeting we will describe the components of the exploration program to the degree possible at this early date, recognizing that the final well location is contingent on completion of seismic interpretations which are currently underway. Regardless of the final well location selected, the fundamental approach to the project (i.e., ice drilling pad, ice road, rolligon trail, etc.) will be essentially the same, and all proposed activities will be consistent with the stipulations defined in the Final Integrated Activity Plan /Environmental Impact Statement. TFE solicits your agency's input on our approach to this exploration program. We are hopeful of being able to identify and satisfactorily address any agency concerns early in the planning phase of the work, recognizing that this will contribute to a positive working relationship and a more operationally efficient project. We look forward to your participation at the April 24 meeting. If you have any questions, please contact the undersigned or Jeff Osborne at 907 - 258 -3556 at your convenience. Sincerely, R. C. Gardner (for TotalFinaElf) Senior Technical Advisor Fairweather E & P Services, Inc. 715 "L" Street, No. 4 Anchorage, AK 99501 1 of 2 12/22/2005 10:18 AM TOTALFINAELF E & P USA, Inc. (TFE) 2003- 2004Winter NPRA... 9 Telephone: 907 258 3446 Fax: 907 258 5557 Cell: 907 360 3000 E -mail: bob @fairweather.com TOTALFINAELF E & P USA, Inc. (TFE) 2003- 2004Winter NPRA Explorat.eml 2 of 2 12/22/2005 10:18 AM 0 0 TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# �— / 6 CHECK WHAT ADD -ONS "CLUE" APPLIES (OPTIONS MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60 -69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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. Rev: 07/10/02 QodyVemplates 9 Field &Pool WeNome: CARIBOU 26 -11 1 Program EXP Well bore seg El PTD #: 203 -196 Company TOTAL E &P USA, INC. Initial Classlfype EXP / P_IV0' �ZoArea _890 Unit On /Off Shore On Annular Disposal E Administration 1 Permit-fee attached_ - - - - - - - _ - - - - - - - - - - - - - - - - - Yes - _ _ 2 Lease -number appropriate -- ------------------ ------------- -- - - -- Yes--- -- -- -- -------------------------------------------------------- 3 Uniquewell_ nameandnumber ---------------------- --------- - - - - -- Y es----- ----- --- - - - - -- - ----------------------------------------------------- 4 Well-located in_a_ defined -pool ---------------------------------------- o - - - - - - - - Exploratory - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - 5 Well located proper distance from drilling unit _boundary - - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ _ _ - _ Lease encompasses_ entire southern 1/2 of T10N,_R5W _ _ - _ _ - _ _ _ _ _ - _ _ _ - _ _ _ _ - - - - - - - - - - - - _ _ _ 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - - - _ - Nearest well is 15 miles away - _ - - - _ - - - _ 7 Sufficient acreage available in-drilling unit - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ - _ _ _ _ _ - - - - - - - - - - - - - _ _ _ _ _ _ _ - _ _ _ _ - - - - _ - - _ - - _ - - - - - - - - _ - - - - - - - - - - - - _ - - _ - - - _ _ 8 If deviated, is_wellbore plat-included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - _ _ _ _ _ Vertical well_ Inclination-survey required _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ - _ _ _ _ _ _ - _ _ _ - 9 Operatoronly_ affectedparty --------------------------------- - - - - -- Yes --------------------------------------------------------------------------- 10 Operator has_appropriate_ bond inforce - - -- - - - - - - - - - - - - - - - - - - - - - -- - -- - -- Yes - - - - - - - None _filed asof12 -8 -03, Receiv_edBondl2 /22/2003._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -- -- _ - - - - - - _ _ - - 11 Permit_can be issued without conservation order- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - - - - - _ _ _ - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ - - _ - - _ _ _ _ - _ - _ - _ - - - - _ - - - - - Appr Date 12 Permit - - - - - be issued without administrativ_e_appn - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ - _ _ _ - - - - _ _ - _ _ - _ _ - - _ _ - _ _ _ - - - - _ _ _ _ SFD 12/24/2003 13 Can permit be approved before 15 -day wait Yes 14 Well-located within area arid-strata authorized by- lnjWion Order # (put 10# incornments)_ (For NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 15 All wells_within 1 /4_mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ - _ - - - - _ _ _ _ _ _ _ - _ _ - _ - _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre - produced injector: duration-of pre production less than 3 months_ (For_service well only) _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ----------------------------- 17 AC_M_P_Finding of Co ns isten cy-has been issued for this project- - - - - - - - - - - - - - - - - - NA_ - - - - - - Per Kaye Laughlin,_JPO, No Review Required for Total's exploratory_ drilling project._ SFD _ _ _ _ _ _ _ _ _ _ _ - _ - - Engineering 18 Conductor string_provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - _ - - _ - _ _ _ I19 Surface casing-protects all-known USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Likely nO fresh water_present._ Casing set and cemented to su_rface_as_proposed will_protect any possible USDWs._ I20 CMT_vol adequate to circulate-on conductor & surf csg - - - - - - - - - - - - - - - - - - - - - - Yes _ .. - _ - _ _ _ - 21 CMT_vol_ adequate to tie -in long string to surf csg- - - - - - - - - - - - - - - - - - - - - No- _ _ - - - - Annular disposal pl_anned._ - - - _ _ _ _ _ _ _ _ - - _ - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - 22 CMT_will cover all known -productive horizons- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ - - - - - _ _ _ _ _ - - - - - - - - - - _ - - - _ - - - _ _ - - _ - - _ - _ . - _ - _ _ _ . - . - _ - - _ _ - - _ - 23 Casing designs adequate for C,_T, B & permafrost- - - - - - - - - - - - - - - - - - . - - _ _ - . _ Yes 124 Adequate to - -- - - reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - Yes - - - - - - Rig is_equipped with st_eel_pits. -No reserve_ pit planned. Drillingwaste_h ruled or_to approved annulus._ _ _ - _ - - - 25 If_a_re- drill, has_) 1.0 -403 for abandonment been approved - - - - - - - - - - - - - - - - - - - - - N_A_ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ - - _ _ _ - _ _ _ - _ _ _ _ _ _ _ 26 Adequate w e I I b o r e separation _prop 9 s e d - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 27 If diverter required, does it-meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ _ - Appr Date 28 Drilling fluid_ program schematic_& equip -list-adequate - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ _ Maximum expected formation pressure-1 1.4 EMW._ MW planned up-to 12.0 ppg- - - - - - - - - - - - - - - - - - - - - - TEM 12/24/2003 29 BOPEs,_do they meet regulation - _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - - - - - - - - 30 BOPE_ press rat appropriate; test to_(put psig in comments)- - - - - - - - - - - - - - - - _ Yes _ _ _ _ _ _ MASP based on shoe breakdown 1954_psi, based on BHP 4197 psi, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ V TVA 31 Choke _ man ifold complies w /API_ RP -53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ Initial BOP test to_5000 psi. _ Subsequent BOP tests to 4000 psi _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ - - --------------------------------------------------------------------- 33 Is presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No- - - - _ _ - - H2S is unlikely since-the wellis not planning to penetrate the Lisburne. _Rig has sensors-and alarms. - - _ _ - _ - _ 34 Mechanical-con of wells within AOR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - - _ - - - - - - - - - - - - - - - - - - - - - - - _ - _ _ _ _ - _ - - - - - _ - - - - - - _ - - - - - - - - _ Geology 35 Permit_can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ - _ No H2S has-been observed_ in offset exploratory_ wells in this portion of the geologic_section._ - - - _ - - - - _ _ _ _ _ 36 _D_ata_ presented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ - - - - Pre -Drill Sesimic Pore Pressure Prediction_report submitted, Some potential_ for abnormal_pressure beginning _ _ _ Appr Date 37 -Seismic-analysis of shallow gas _zones - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - at X1200' MD._ Higher pore pressure expected_ near top of_HRZ. Mudlogging_will be performed from conductor to _ SFD 12/8/2003 38 Seabed condition surve f off -shore - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ - - - - - - TD. Operator has-seen no indications of gas-in seismic. SFD - - - - _ 39 - Contact name/phone-for-weekly progress_ reports [exploratory only]_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ - - _ - Erwan Couzigou (907)743-0970 - - - - _ - - - - - - _ - - - _ _ - - _ _ _ - _ _ _ _ - _ _ - _ _ - - - - - - - - - - _ _ _ _ - - Geologic Engineering Public Date: Date Date Commissioner: Commissioner: Commissioner L=. 9 0 0 Well History File Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1-1 Biostratigraphic Synthesis of the Total E&P Caribou 26-11 #1 Well North Slope, Alaska (8 - 9,100 ft) April 2004 C� E the irf group, inc. consulting paleontologists 6721 Round Tree Drive Anchorage, AK 99507 907-3464M anchorage • houston • dallas • toronto • halifax I • Biostratigraphic Synthesis of the Total E &P Caribou 26 -11 #1 Well North Slope, Alaska (8,800 - 9,100 ft) Robert L. Ravn, Michael B. Mickey, and David K. Goodman the irf group, inc. March 2004 Synthesis A biostratigraphic profile is developed for a restricted interval in the Total E &P Caribou 26- 11 #1 well, NPR -A, North Slope, Alaska, between 8,800 ft and 9,100 ft based on analysis of palynomorphs, foraminifera, and other miscellaneous microfossils. The interval ranges in age from Early Cretaceous (Valanginian) to Late Jurassic (probable Early Kimmeridgian) in age. Palynological recovery is good although many samples lacked age- diagnostic species. Foraminiferal recovery is generally good throughout the interval, although species diversity is not as high as that of the palynomorphs. • The well section is subdivided as follows: 8,800 to 8,890 ( ?8,910) ft ( ?Early) Valanginian - - - - - -- ?stratal discontinuity -- - - - - -- 8,890 ( ?8,910) to 9,010 ft ?Valanginian to Kimmeridgian - - - - - -- ?stratal discontinuity -- - - - - -- 9,010 to 9,100 ft (bottom sample) ( ?probable Early) Kimmeridgian The goals of the report are to build a chronostratigraphic framework for a restricted stratigraphic interval in the well and to develop a set of general assemblage attributes that can be used for regional correlation models. This report on the Caribouu 26 -11 #1 well will ultimately be integrated into a regional biostratigraphic framework for Total E &P for northwestern NPR -A. Microfossil data acquisition was performed by Michael B. Mickey; palynology data acquisition was performed Robert L. Ravn (the irf group); report integration, statistical analysis, and graphics were completed by David Goodman (the irf group). • 2 • Stratigraphic Summary The well section penetrated is Early Cretaceous (Valanginian) to Late Jurassic (probable Early Kimmeridgian) in age. The samples contain well - preserved and sparse to common populations of calcareous (foraminifera, ostrocods), siliceous (radiolaria) and organic - walled (spores, pollen, fungal spores, dinoflagellates, acritarchs, freshwater algae) microfossils Microfossil recovery was good for most samples examined, with well - preserved populations of both agglutinated and calcareous benthonic foraminifera, as well as other miscellaneous microfossils; palynomorph recovery in the well was good. Figures 2 and 5 each includes a "Similarity Matrix" display, which is a graphic representation of statistically compared population data from sample to sample in the well; an explanation of this method may be found in the Appendix at the end of the report. The Similarity Matrix reveals in a visually intuitive way the potential positions of bounding surfaces in a given section, designated here as "biosequence boundaries." A number of these apparent boundaries are summarized in the discussion of specific biostratigraphic events that follows. The summary below synthesizes pertinent information for the biostratigraphic subdivision of the interval of interest. • Early Cretaceous The ?Earl Valanginian interval (8,800 - 8,890 ft) is dated based on foraminifera. This depositional interval, however, may extend to a depth of 8,920 ft based on palynology. Palynomorphs indicate a Valanginian age between 8,800 ft and 8,850 ft, however the overall assemblage attributes (higher marine percentage abundance and overall marine microfossil abundance) suggests that the base of this interval may be at approximately 8,910/20 ft (Figure 2). The palynology similarity matrix (Figure 2) shows a major break in biofacies at 8,860/70 ft and a minor break at 8,910/20 ft; this may indicate a two -fold subdivision of the Valanginian section in the well; this subdivision is also suggested by the marine palynomprph assemblage parameters. A major foraminiferal biofacies boundary occurs at 8,890/900 ft (Figure 5); note however that a minor break occurs at approximately 8,920 ft, which is close approximation to the palynological biofacies boundary described above. Note that the foram associations below 8,890 ft appear to be more closely associated with the underlying rocks than to the overlying section. Foraminiferal total abundance is higher in the Valanginian section than in underlying intervals (Figure 5); this is principally due to agglutinated benthonic forms, but a similar shift is also seen in hyaline calcareous forms (Figure 5). Reworked Lower Mesozoic palynomorphs are more common in the Valanginian section than in underlying rocks examined in this study. Sediments were deposited in an outer neritic to upper bathyal environment based on • foraminifera (Figure 1). 3 • Early Cretaceous to Late Jurassic The top of the ?Valanginian to Kimmeridgian section (8,890 - 9,010 ft) contains a microfossil assemblage that cannot be dated with complete certainty. The top of this interval can reasonably be extended down to 8,920 ft based on palynology (see discussion above). The foraminifera report suggests a Late Kimmeridgian age for this section (Figure 1), while the palynology report indicates an undifferentiated Kimmeridgian age. The palynological assemblages in this interval contain fewer marine microfossils than the overlying interval. Gochteodinia villosa, Tubotuberella rhombiformis, and Valensiella ovula occur relatively consistently in this section. Other taxa occur in relatively low numbers, and there is strong evidence of reworking throughout the interval. Many of the supposed Kimmeridgian palynomorph taxa which occur sporadically in this interval can therefore be interpreted as representing reworking of Jurassic microfossils during an Early Cretaceous (Valanginian) depositional cycle. The matter is difficult to resolve and the interval is therefore given a somewhat broadened age range of Valanginian to Kimmeridgian to reflect this uncertainty. While not definitive, the foraminiferal similarity matrix (Figure 5) does indicate a poorly defined cluster of samples within this overall interval (possible base at 8,990 ft). The overall pattern of foraminifera abundance (Figure 5) also suggests a separate depositional cycle for this middle part of the well section; the upper boundary appears to be abrupt and may suggest an unconformity. The lower boundary is not as definitive but may represent an unconformable surface as well. The environment of deposition for this interval is interpreted as inner to middle neritic to 0 upper bathyal. Late Jurassic The ( probable Early Kimmeridgian interval (9,010 - 9,100 ft) is based largely on foraminiferal evidence. A foraminiferal biofacies boundary (Figure 5) occurs within this interval at 9,040 ft. Foraminiferal abundance is lower than in the superjacent Valanginian to Kimmeridgian section. Palynomorphs are largely non - diagnostic in this interval, and indicate an undifferentiated Kimmeridgian age. Many of the palynomorphs are unquestionably reworked; this interval has a somewhat higher number of reworked specimens (predominantly Carboniferous) than are present in the superjacent interval. A relatively well - developed palynological biofacies boundary can be observed at approximately 9,020 ft on the similarity matrix in Figure 2; this boundary is in close association with the foraminiferal age break and may support the presence of a stratigraphic event at this depth. The environment of deposition for the interval is interpreted as inner to middle neritic to upper bathyal. Oxfordian sediments were not identified in the interval examined for this study. • n • Display Panels Biostratigraphic results for the well section are illustrated in the following display panels: Figure 1. Well stratigraphic synthesis. Figure 2. Palynology assemblage parameters. Figure 3. Palynology quantitative species distribution. Figure 4. Palynology interval range chart. Figure 5. Foram assemblage parameters. Figure 6. Foram quantitative species distribution. Figure 7. Foram interval range chart. Figure 8. Palynology data acquisition matrix. Figure 9. Foram data acquisition matrix. Appendixes (on CD only) Appendix 1. Species list sorted by major microfossil group. Appendix 2. Sample census data (counts). Appendix 3. Range events: FAD's (First Occurrence Datums, or range bases; LAD's (Last Occurrence Datums, or range tops). Analytical Parameters Samples were evaluated in terms of a quantitative census analysis for the organic - walled, siliceous and calcareous microfossils. Quantitative census data increase the "dimensionality" of the final data set and allow a wide range of numerical and statistical analyses to be performed on the data set, in contrast to either "presence- absence" or "semi- quantitative" (also known as abundance estimates), for which further statistical analyses are either not possible, or produce invalid or misleading results. A complete listing of the 280 taxonomic entities (both species and including more general identified in the well is given in Appendix • 1. 5 • Primary data include the quantitative and stratigraphic distribution of the microfossils. Derivative tracks are used to enhance the primary data and to summarize the geological and biological history of the well section in terms that are more useful than simple range data alone. These tracks can be used to make more detailed interpretations of depositional system architecture, identify possible stratal discontinuities, and to characterize stratigraphic intervals using biological content. The summary tracks recorded for the Caribou 26 -11 #1 section include: Microfossils: • Foraminifera Total Abundance • Foraminifera Diversity • Foraminifera Ratio • Agglutinated Benthonic Foraminifera Total Abundance • Hyaline Calcareous Benthonic Foraminifera Total Abundance • Hyaline Calcareous Planktonic Foraminifera Total Abundance • Agglutinated Benthonic Foraminifera Percentage Abundance • Hyaline Calcareous Benthonic Foraminifera Percentage Abundance • Hyaline Calcareous Planktonic Foraminifera Percentage Abundance • Radiolaria Total Abundance • Ostracod Total Abundance • Pelecypods (internal molds) • • Gastropods (internal molds) • Fish Debris • Inoceramus Prisms • Pelmatozoan Fragments Palynology: • Marine Percentage Abundance • Marine Palynomoph Total Abundance • Marine Species Diversity • Marine Richness Ratio • Dinoflagellate Total Abundance • Acritarch Total Abundance • Microforam Linings Total Abundance • Terrestrial Palynomorph Total Abundance • Terrestrial Species Diversity • Terrestrial Richness Ratio • Bisaccate Pollen Total Abundance • Non - Bisaccate Pollen Total Abundance • Pollen Total Abundance • Spore Total Abundance • • Miscellaneous Freshwater Algae Total Abundance • Reworked Palynomorphs Total Abundance rel • • Reworked Lower Mesozoic Total Abundance . Reworked Carbonicerous Total Abundance • Reworked Devonian Total Abundance Analytical Perspective Our intent is to rp esent the biological data within the context of a dynamic interpretation environment in which all original and derived data sets are documented and displayed in a style that permits evaluation of the results of this study and re- interpretation at any time in the future. These data sets are the result of a complex set of biological and physical parameters, and a suite of reasonable interpretations can be formulated within theconstraints of the acquired data. Thus, we propose our preferred interpretations, but both realize and invite alternate views by other analysts and interpreters. We strongly feel that this dynamic interpretive mode is vastly superior to the more typical (and effectively static) approach of providing an age interpretation over a specified stratigraphic interval with little or no supporting documentation other than listing several range events that occur within the interval. Our fundamental approach to biostratigraphy differs from that utilized by many other consulting groups. We purposely separate the tasks of data acquisition (sample analysis) and interpretation (chronostratigraphic models, statistical analyses, and biofacies calculations). all biological components in the samples based on detailed systematic identification, and (2) attention to detail in collecting census data on all species, or other taxonomic entities, identified. This results in an initial data set for the well which exhibits considerable dimensionality and for which no a priori decisions have been made by the analyst that would exclude taxa with biostratigraphic, chronostratigraphic, or paleoenvironmental significance. The assemblage summary attributes (group total abundances, percentage abundances, selected ratios) and other statistical parameters (similarity coefficients, diversity indexes, principal components scores) derived from the initial data matrix exploit this more complex dimensionality and therefore have enhanced potential for more detailed stratigraphic characterization, subdivision, and correlation than is possible with reduced occurrence data sets. Recommendations The section analyzed covers a very limited stratigraphic interval. Biostratigraphic observations made within such a confined interval are very difficult to interpret within a more comprehensive stratigraphic context. We therefore recommend extending the limits of the biostratigraphic coverage for this well in order to develop a well- constrained model: 1 Extend the interval examined upwards to approximately 100 -150 ft above the • HRZ (High Resistivity Zone). The HRZ is Aptian age and the additional samples would provide an integrated biostratigraphic profile throughout the • entire Lower Cretaceous depositional succession. Analysis could be done either at 10 -ft or 30 -ft intervals. 2 Extend the interval examined downwards to about 100 feet below the top of the Oxfordian section. Doing so would establish the chronostratigraphic calibration of the base of the Kimmeridgian depositional cycle, and it would allow interpretation of the Valanginian to Kimmeridgian section within a more complete understanding of the bounding sections. Analysis could be done either at 10 -ft or 30 -ft intervals. Bidacies Analysis (Similarity Matrix) The matrixes illustrated on Figures 2 and 5 displays similarity coefficients which compare the assemblage composition in each sample with every other sample. The similarity coefficient employs the unweighted pair -group method using binary, or presence- absence data. The coefficients are calculated for all possible combination -pairs of samples, and are expressed as values between -1 (no similarity) and 1 (complete similarity). Species presence is the only measuring criterion; the coefficient as used here ignores negative matches, so that only samples with presences, and not absences, in common appear similar. The advantage of eliminating "negative similarity" makes the index a favorable measure of similarity of content (or species associations). Samples are arranged in stratigraphic order along the vertical axis (and along the horizontal axis as well) of the matrixes (the diagonal line from upper left to lower right indicated "same sample" comparison with a similarity of 1. The similarity coefficients are color keyed for interpretation - solid patterns indicate more closely associated sample pairs. The clusters are interpreted to have inherent biological or depositional significance in response to changing pervasive depositional conditions through time. These clusters, when used in conjunction with relative abundance data and assemblage attribute parameters, permit recognition and characterization of probable genetic biostratigraphic units with potential local or regional correlation utility. These associations might be interpreted as the biological analogs of depositional sequences. Figures 2 and 5 illustrate the integration of the similarity matrix with the results of more traditional chronostratigraphic age interpretation based on range event stratigraphy and overall microfossil assemblages. Similarity matrix boundaries are shown in green. A more complete discussion of the Similarity Matrix is provided in the Addendum at the end of this report. Data Archive (CD) All hardcopy components of this report are included as digital files on the attached CD. The • files are platform- independent files: WORD (.doc), EXCEL (.xls), or PORTABLE DOCUMENT FORMAT (.pdf). The CD files include: • Cbu26ForRept.doc - Report Text Cbu26Apl.doc - Appendix 1: Species List (CD only) Cbu26Ap2.doc - Appendix 2: Sample Census (CD only) Cbu26Ap3.doc - Appendix 3: Range Events (CD only) Cbu26ForTxt.doc - Foram Original Report Cbu26ForData.xls - Foram Original Data Cbu26ForSums.xls - Foram Assemblage Statistics Cbu26Pa1Data.xls - Palynology Original Data Cbu26Pa1Sums.xls - Palynology Assemblage Statistics Cbu26Figl.pdf - Figure 1: Well Stratigraphic Synthesis Cbu26Fig2.pdf - Figure 2: Palynology Assemblage ParametersBiofacies Cbu26Fig3.pdf - Figure 3: Palynology Quantitative Species Distribution Chart Cbu26Fig4.pdf - Figure 4: Palynology Interval Range Chart Cbu26Fig5.pdf - Figure 5: Foram Assemblage ParametersBiofacies Cbu26Fig6.pdf - Figure 6: Foram Quantitative Species Distribution Chart Cbu26Fig7.pdf - Figure 7: Foram Interval Range Chart Cbu26Fig8.pdf - Figure 8: Palynology Data Spreadsheet Cbu26Fig9.pdf - Figure 9: Foram Data Spreadsheet Addendum: Similarity Matrix • Summmary The biostratigraphic content of any rock unit constitutes a "signature" for that unit, much as lithologic or geochemical contents do. They are sedimentary particles of organic origin, and their distribution is subject to stratigraphic, environmental and physical controls. In theory, a particular rock unit (or sedimentary sequence) normally will contain a biostratigraphic population characteristic of it, and differing in measurable ways from the population characteristics of other rock units. Individual samples examined from within a single sedimentary unit should therefore be expected to display a certain degree of similarity to each other; samples from one unit compared to those of another unit should show less similarity overall. This total population similarity /dissimilarity can be assessed using mathematically simple correlation coefficient evaluations. Single -well evaluation The Similarity Matrix display graphically represents such an evaluation for all samples of a given well. The population of every sample in the well (along the X axis) is cross - compared with every other sample in the well (along the Y axis), using an automated spreadsheet correlation coefficient function. The result is a grid of numerical values ranging from —1 (total dissimilarity) to +1 (total similarity or identity). Each sample compared against itself, representing two identical populations, produces a value of +1, for example; two samples having no individual population members in common would produce a value of —1. r� M • The grid of these values is then color -coded in a two -tier system intended to give a visual representation of the areas of greatest similarity, along a diagonal axis of identity produced by the comparison of each sample against itself. This axis is evident as the line of dark squares running from lower left to upper right of the diagram. Along the axis, square areas of darker color indicate intervals of relatively high similarity (probable sedimentary sequences). Points along the axis at which separate square zones connect represent points of dissimilarity (probable unconformities or sedimentary hiatuses); these have been noted on the diagram as "biosequence boundaries." In practice, the signature of these apparent boundaries ranges from striking to subtle, and probably reflects to some degree the overall importance of particular sedimentary surfaces. Comparative two -well evaluation In addition to the similarity evaluation of samples within a single well, samples can be compared between two separate wells.. Such two -well comparison results in a form of "graphic correlation ", a biostratigraphic analysis pioneered by A. B. Shaw of Amoco Production Company and widely used by Amoco for many years. Individual data points such as extinction tops, abundance peaks, and interpreted lines of correlation, can be posted directly on the similarity matrix as well. In practice, the similarity /dissimilarity evaluation often reveals with particular clarity intervals that do not have equivalency between wells. General Comments This similarity analysis is highly objective and independent of • taxonomic opinion. It proceeds fairly directly from observed data, without being heavily filtered by subjective prejudices on the part of the biostratigrapher. The data sets used in this study are, of course, entirely palynological. Should other kinds of population data exist (e.g., other biostratigraphic, geochemical, lithological data), these could be compared using the similarity matrix method. It is to be stressed that these displays are merely a new way of looking at sets of data, and are only one of many pieces of the data puzzle. Like a seismic line display, the matrix represents a graphic display of numerical data, and may be subject to varying interpretations dependent on the individual interpreter. The appearance of a boundary signature on a similarity matrix display is not in itself infallible evidence of the existence of an unconformity. It should be compared with geophysical, electric log, and other available data, and used in conjunction with them to arrive at the most reasonable geologic interpretation. The reliability of the display also depends on the quality of the data on which it is based. Samples containing marginal, or sparse, populations, or samples containing mainly long - ranging taxa of little stratigraphic value, may result in spurious similarity signatures. As one of the major controls on biostratigraphic populations is paleoenvironment, samples of somewhat different ages may have relatively high overall similarities if they record similar environmental conditions and the constituents are dominantly long- ranging forms. This problem may arise especially in palynological samples in which most material is terrestrially - derived and of relatively low diversity. is 10 • Another interpretation difficulty may arise from comparison of core samples to cuttings samples. The latter commonly contain material caved from younger strata, which may be difficult to recognize as such during visual analysis. Caved material, of course, is absent from core samples. This extraneous material therefore tends to exaggerate the dissimilarity between core and cuttings material, and may produce a false appearance of a boundary signature. These interpretation difficulties are generally easy to recognize, however, and the value of the Similarity Matrix as an interpretation tool is considerable. It represents a new means of evaluation data, and may be effectively used to re- evaluate older data sets as well. The data and interpretations presented here are property of the irf group, inc., Anchorage, Alaska, and are hereby licensed for use by Total E &P USA. They are not to be distributed outside this client without the written consent of the irf group, inc. • • Total E &P Caribou 26 -11 #1 Foraminifera Data Acquisition Report Mike Mickey MCI I ter I- C_RO_PAL£O CONSIIL`1'A1V "1'S " FINAL PRELIMINARY FORAM SUMMARY 8800 -8810' Top sample submitted for examination. 8800 -8890' Age. Early Cretaceous Lower (Early) Valanginian Zone. F -13bL Environment. Outer Neritic to Upper Bathyal (Outer Shelf to Upper Slope) 8890 - 9010'? Age. Late Jurassic Upper (Late) Kimmeridgian Zone. F -16au Environment. Inner or Middle Neritic to Upper Bathyal (Inner to Middle Shelf to Upper Slope) 9010? -9100' (Bottom of sampled interval) Age. Zone. Environment. I s MC Job No. 24 -104 Late Jurassic Probable Lower (Early) Kimmeridgian Probable F -16a Inner or Middle Neritic to Upper Bathyal (Inner to Middle Shelf to Upper Slope) 329 Chapalita Drive • Encinitas, California 92024 Total E &P Caribou 26 -11 #1 0 Palynology Data Acquisition Report Robert L. Ravn the irf group, inc. 9 Total E &P Caribou 26 -11 #1 • Appendixes 1 -3 1: Species List 2: Sample Census 3: Range Events U Appendixes 1 -3 are located on the CD on the back inside cover of the report: 1: Species List 2: Sample Census 3: Range Events C7 Total E &P Caribou 26 -11 #1 • Graphics Panels s lm*z • a 2,�, 3 -- )y(, Iii I PETROLEUM SERVICES Core Lab RESERVOIR OPTIRIEATIOR GEOLOGIC EVALUATION ROTARY SIDEWALL CORES LOWER CRETACEOUS 7202 - 9157 FEET TOTAL E &P USA, INC. CARIBOU 26 -11 NO. 1 WELL ALASKA Performed For: Total E &P USA, Inc. Houston, Texas Houston ATC Job File No.: 040187G April, 2004 Performed By: Core Laboratories, Inc. Houston Advanced Technology Center 6316 Windfern Road Houston, Texas 77040 The analytical results, opinions or interpretations contained in this report are based upon information and material supplied by the client for whose exclusive and confidential use this report has been made. The analytical results, opinions or Interpretations expressed represent the best judgment of Core Laboratories. Core Laboratories, however, makes no warranty or representation, express a implied, of any type, and expressly disclaims same as to the productivity, proper operations or profitableness of any oil, gas, coal a other mineral, property, well a sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced, in whoa a in part, without the written approval of Core Laboratories. 1 This geologic report presents the results of thin section petrography performed on forty -nine (49) rotary sidewall cores and X -ray diffraction analysis performed on nine (9) rotary sidewall cores taken from your Caribou 26 -11 No. 1 Well, Alaska. The samples are sandstones, ' siltstones, argillaceous siltstones, and silty shales taken between 7202 — 9157 feet in Lower Cretaceous intervals. The goals of the geologic evaluation are to assess texture, mineralogy, diagenesis, and the effects of minerals on wireline log response. it L r 0 Three (3) copies of this report have been sent to your office in Houston, Texas. If you have any questions, please do not hesitate to call or email. Thank you for choosing Core Laboratories for this project. Sincerely, r S. Kier Senior Project Geologist Core Laboratories Houston, Texas 77040 713- 328 -2575 jerry.kier@corelab.com Brian Nicoud Reservoir Geology Manager Core Laboratories Houston, Texas 77040 713- 328 -2576 brian. nicoud @corelab.com L Petroleum Services Division 6316 Windfern Houston, Texas 77040 USA Tel: 713 - 328 -2673 Fax: 713-328-2170 [pre It.all7 www.corelab.com RESERVOIR OPTIMIZATION April 12, 2004 John Johns and Jim Seefeldt 1 Total E &P USA, Inc. 800 Gessner, Suite 700 Houston, Texas 77024 -4276 Gentlemen: 1 This geologic report presents the results of thin section petrography performed on forty -nine (49) rotary sidewall cores and X -ray diffraction analysis performed on nine (9) rotary sidewall cores taken from your Caribou 26 -11 No. 1 Well, Alaska. The samples are sandstones, ' siltstones, argillaceous siltstones, and silty shales taken between 7202 — 9157 feet in Lower Cretaceous intervals. The goals of the geologic evaluation are to assess texture, mineralogy, diagenesis, and the effects of minerals on wireline log response. it L r 0 Three (3) copies of this report have been sent to your office in Houston, Texas. If you have any questions, please do not hesitate to call or email. Thank you for choosing Core Laboratories for this project. Sincerely, r S. Kier Senior Project Geologist Core Laboratories Houston, Texas 77040 713- 328 -2575 jerry.kier@corelab.com Brian Nicoud Reservoir Geology Manager Core Laboratories Houston, Texas 77040 713- 328 -2576 brian. nicoud @corelab.com L SUMMARY • Forty -nine rotary sidewall cores were examined geologically from the Base of Slope Middle Cretaceous, Base of Slope Middle Cretaceous Sand Sequence 20 — 21.5, Base of Slope Middle Cretaceous Sand Sequence 22A, Valanginian Channel Fill, and Kimmeridgian Silt intervals encountered between 7202 and 9157 feet in the Caribou 26 -11 No. 1 Well. • All the Base of Slope Middle Cretaceous sandstones are very fine - grained and moderately well to well sorted. Sand Sequence 22A is slightly coarser than Sand Sequence 20 — 21.5. The sandstones are composed mainly of quartz, plagioclase, and rock fragments, and they are classified as litharenites to feldspathic litharentites. Most of the intergranular pore volume has been destroyed by physical compaction. Carbonate cements, quartz overgrowths, and authigenic clay fill most of the remaining pores. The clay mineral suite is composed mainly of chlorite, followed by illite /smectite mixed -layer clay and illite. The majority of the pore volume is in the form of micropores. Average porosity is 8.67 %, average air permeability is 0.039 md, and grain density averages 2.71 g /cc. • The Valanginian Channel Fill samples are mainly argillaceous siltstones. They are generally bioturbated. They are composed mainly of quartz, with plagioclase and rock fragments less common than in the Base of Slope sandstones. The sandstones are classified mainly as lithic arkoses, arkoses, and subarkoses. Glauconite grains are concentrated in several samples, suggesting slow sedimentation rates and a possible condensed section. Carbonate cements and pyrite have locally replaced ' detrital clay matrix. Average porosity is 7.81 %, average air permeability is 0.015 md, and average grain density is 2.76 g /cc (median = 2.73 g /cc). • The Kimmeridgian Silt samples are mainly bioturbated argillaceous siltstones that generally are less argillaceous than the overlying Valanginian Channel Fill argillaceous siltstones. They are composed mainly of quartz and less common plagioclase, and they are classified as subarkoses. They are compositionally more similar to the Valanginian Channel Fill samples than the Base of Slope Sand Sequence sandstones. The most common cements are carbonates, pyrite, and quartz overgrowths. Average porosity is 7.52 %, average air permeability is 0.013 md, and average grain density is 2.71 g /cc. • The examined samples contain sufficient dolomite, calcite, and pyrite to elevate average grain densities to 2.71 — 2.76 g /cc. Porosity logs should be calibrated for densities in this range rather than for the typical sandstone matrix of 2.65 g /cc. • The majority of the pore volume in these samples is in form of micropores. This can lead to high immobile water saturations. 11 1 INTRODUCTION Forty -nine (49) rotary sidewall cores were examined (Table 1) by thin section petrography, and nine (9) rotary sidewall cores were examined by X -ray diffraction (XRD) analysis (Table 3. The goals of the geologic evaluation are to assess the texture, mineralogy, diagenesis, and mineral effects on wireline log response. One low- and one high- magnification thin section photomicrograph were taken of each sample and are presented in Plates 1 - 49 at the end of this report. Forty -three (43) of the thin sections were point counted, with the modal analysis data presented in Table 2. The remaining six (6) samples are silty shales and were described qualitatively, with estimated values included with the photomicrographs. Measured rotary sidewall core analysis data are found in Table 4. Grain size measurements were made on one hundred (100) non - deformed grains per sample, and the results are presented in Appendix 1 and on the thin section plates. Table 1 Caribou 26 -11 No. 1 Well Thin Section Samples Examined Depth (ft) Interval Lithology Grain Density (a/cc ) Porosity ( %) Air Permeability (md) 7202 Base of Slope (BOS) Mid. Cret. sandstone 2.72 8.82 0.029 7250 Base of Slope (BOS) Mid. Cret. sandstone 2.73 2.73 0.002 7352 Base of Slope (BOS) Mid. Cret. silty shale 2.73 5.60 0.002 7475 Base of Slope (SOS) Mid. Cret. sandstone 2.71 8.30 0.040 7524 BOS Mid. Cret. Sand 20 - 21.5 shale /sandstone 2.75 6.17 0.022 7547 BOS Mid. Cret. Sand 20 - 21.5 sandstone 2.75 4.60 0.003 7563 BOS Mid. Cret. Sand 20 - 21.5 sandstone 2.71 8.68 0.040 7588 BOS Mid. Cret. Sand 20 - 21.5 sandstone 2.71 10.44 0.050 7613 BOS Mid. Cret. Sand 20 - 21.5 silty shale /sandstone 2.73 8.42 0.146 7615 BOS Mid. Cret. Sand 20 - 21.5 sandstone 2.70 11.99 0.143 7619 BOS Mid. Cret. Sand 20 - 21.5 sandstone 2.70 10.37 0.060 7623 BOS Mid. Cret. Sand 20 - 21.5 sandstone 2.70 11.38 0.095 7704 BOS Mid. Cret. Sand 22A sandstone 2.71 7.52 0.014 7721 BOS Mid. Cret. Sand 22A sandstone 2.71 9.66 0.044 7730 BOS Mid. Cret. Sand 22A sandstone 2.71 10.81 0.053 7742 BOS Mid. Cret. Sand 22A sandstone 2.71 9.29 0.038 7748 BOS Mid. Cret. Sand 22A sandstone 2.72 9.31 0.048 7760 BOS Mid. Cret. Sand 22A sandstone 2.71 10.29 0.051 7769 BOS Mid. Cret. Sand 22A sandstone 2.71 8.67 0.030 7795 BOS Mid. Cret. Sand 22A sandstone 2.71 10.34 0.053 7815 BOS Mid. Cret. Sand 22A sandstone 2.72 9.62 0.046 7825 BOS Mid. Cret. Sand 22A sandstone 2.74 9.85 0.040 7837 BOS Mid. Cret. Sand 22A sandstone 2.70 9.97 0.047 7848 BOS Mid. Cret. Sand 22A sandstone 2.71 10.55 0.046 7859 BOS Mid. Cret. Sand 22A siltstone /sandstone 2.68 7.60 0.035 7884 BOS Mid. Cret. Sand 22A sandstone 2.76 4.40 0.003 8909 Valanginian Channel Fill silty shale NA NA NA 8917 Valanginian Channel Fill argillaceous siltstone 2.71 9.34 0.040 8935 Valanginian Channel Fill silty shale 2.73 7.81 0.020 2 I' Table 1 (continued) Caribou 26 -11 No. 1 Well Thin Section Samples Examined Depth (ft) Interval Lithology Grain Density (g /cc) Porosity ( %) Air Permeability (md) 8939 Valanginian Channel Fill silty shale NA NA NA 8950 Valanginian Channel Fill argillaceous 2.73 7.56 0.016 sandstone 8981 Valanginian Channel Fill argillaceous siltstone 2.72 7.50 0.015 8999 Valanginian Channel Fill argillaceous siltstone 2.71 7.01 0.009 9009 Valanginian Channel Fill argillaceous sandstone 2.73 7.74 0.012 9010 Valanginian Channel Fill argillaceous sandstone 3.04 6.23 0.003 9023 Valanginian Channel Fill argillaceous sandstone 2.74 8.72 0.013 9024 Valanginian Channel Fill argillaceous sandstone 2.74 8.36 0.011 9025 Valanginian Channel Fill argillaceous sandstone 2.73 7.84 0.008 9026 Kimmeridgian Silt argillaceous siltstone 2.74 5.37 0.005 9045 Kimmeridgian Silt argillaceous siltstone 2.71 7.25 0.010 9053 Kimmeridgian Silt argillaceous sandstone 2.71 9.14 0.018 9067 Kimmeridgian Silt argillaceous siltstone 2.70 7.89 0.015 9068 Kimmeridgian Silt argillaceous sandstone 2.70 8.32 0.016 9069 Kimmeridgian Silt argillaceous siltstone 2.72 6.76 0.011 9070 Kimmeridgian Silt argillaceous siltstone 2.72 6.28 0.011 9071 Kimmeridgian Silt argillaceous siltstone 2.72 6.56 0.008 9085 Kimmeridgian Silt argillaceous siltstone 2.71 8.30 0.016 9101 Kimmeridgian Silt argillaceous sandstone 2.70 9.36 0.017 9157 Kimmeridgian Silt argillaceous siltstone NA NA NA DISCUSSION The examined samples encompass five stratigraphic intervals (Table 1). They are discussed separately in the following section of the report. ' Base of Slope Middle Cretaceous Three sandstones and one silty shale (Plates 1 - 4) were examined from the Base of Slope Middle Cretaceous interval. The silty shale sample is laminated. The detrital clay matrix locally contains organic -rich laminae and carbonaceous plant fragments. There are no visible pores in this sample. The sandstones are moderately well to well sorted, with average grain sizes in the very fine sand ranges. Sedimentary structures are not apparent. The framework grain suite is composed mainly of quartz, plagioclase feldspar, and rock fragments. The lithic grains are argillaceous rock fragments, volcanic rock fragments, plutonic /metamorphic rock fragments, dolomite rock fragments, calcite rock fragments, and chert (Table 2). The sandstones are classified as litharenites and feldspathic litharenites (Figure 1). Less common grains include micas and plant fragments. The grains are extensively compacted. Ductile grains, especially argillaceous and volcanic rock fragments, have been deformed and can form 3 pseudomatrix when squeezed into adjacent pores. Most of the grain contacts are long edge and concavo- convex. The most common cements are dolomite, quartz overgrowths, authigenic clay, and pyrite. They fill most remaining intergranular areas and have decreased pore volume. Primary intergranular pores are not well preserved and secondary dissolution pores are not well developed. Pores are poorly interconnected. Average porosity (Table 4) for four samples from this interval is 6.36% (range = 2.73 — 8.82 %) and average air permeability is 0.018 and (range = 0.002 — 0.040 md). Average grain density is 2.72 g /cc (range = 2.71 — 2.73 g /cc) and reflects the abundance of dolomite grains and cements, as well as pyrite and chlorite, in these samples. Base of Slope Middle Cretaceous Sand Sequence 20 — 21.5 Six (6) sandstone samples and two (2) dominantly silty shale samples were examined from the Base of Slope Sand Sequence 20 - 21.5 (Plates 5 — 12). The samples from 7524 and 7613 feet are mainly silty shale. However, thin sandstone laminae are deposited along scoured surfaces and form fining- upward deposits. Plant fragments are prominent in several of the shaly laminae. The sandstone laminae are extensively compacted and compositionally similar to the sandstones examined from this interval. The sandstones are texturally and compositionally similar. Average grain size is in the very fine sand range and grain are well sorted. The framework grain suite is composed mainly of quartz, plagioclase feldspar, and rock fragments. The lithic grains are argillaceous rock fragments, volcanic rock fragments, plutonic /metamorphic rock fragments, and dolomite rock fragments, calcite rock fragments, and chert (Table 2). The sandstones are classified as litharenites and feldspathic litharenites and are compositionally very similar to Base of Slope sandstones previously described (Figure 1). Less common grains include micas and plant fragments. The grains are extensively compacted. Ductile grains, especially argillaceous and volcanic rock fragments, have been deformed and can form pseudomatrix when squeezed into adjacent pores. Most of the grain contacts are long edge and concavo- convex. The most common cements are carbonates, with calcite, ferroan calcite, and dolomite identified. Quartz overgrowths, authigenic clay, and pyrite are generally less common. The clay mineral suite is composed mainly of chlorite followed by illite and illite /smectite mixed - layer clay (Table 3). The cements fill most remaining intergranular areas and have decreased pore volume. Primary intergranular pores are not well preserved and secondary dissolution pores are not well developed. Pores are poorly interconnected. Average porosity (Table 4) for eight samples from this interval is 9.01 % (range = 4.60 — 11.99 %) and average air permeability is 0.070 and (range = 0.003 — 0.146 md). Average grain density is 2.72 g /cc (range = 2.70 — 2.75 g /cc) and reflects the abundance of carbonate grains and cements, as well as pyrite and chlorite, in these samples. Base of Slope Middle Cretaceous Sand Sequence 22A Thirteen (13) sandstone samples and one (1) laminated siltstone /sandstone sample were examined from the Base of Slope Sand Sequence 22A Plates 13 — 26). These samples are slightly coarser grained and compositionally similar to the other Base of Slope Middle Cretaceous sandstones previously discussed. Average grain size is in the very fine sand range. Grain sorting ranges from moderately well to well in the sandstones, with the 4 siltstone well sorted. The framework grain suite is composed mainly of quartz, plagioclase feldspar, and rock fragments. The lithic grains are argillaceous rock fragments, volcanic rock fragments, plutonic /metamorphic rock fragments, and dolomite rock fragments, and chert (Table 2). The sandstones are classified as litharenites and feldspathic litharenites and plot in the same area as the other Base of Slope sandstones on the sandstone ternary diagram (Figure 1). Less common grains include micas and plant fragments. The grains are extensively compacted. Ductile grains, especially argillaceous and volcanic rock fragments, have been deformed and can form pseudomatrix when squeezed into adjacent pores. Most of the grain contacts are long edge and concavo- convex. The most common cements are carbonates, with calcite, ferroan calcite, and dolomite identified, and authigenic clays. The clay mineral suite is very similar to the overlying interval, and is composed mainly of chlorite followed by illite and illite /smectite mixed -layer clay (Table 3). Quartz overgrowths and pyrite are generally less common. The cements fill most remaining intergranular areas and have decreased pore volume. Primary intergranular pores are not well preserved and secondary dissolution pores are not well developed. Pores are poorly interconnected. Average porosity (Table 4) for fourteen (14) samples from this interval is 9.14% (range = 4.40 — 10.81%) and average air permeability is 0.039 and (range = 0.003 — 0.053 md). Average grain density is 2.71 g /cc (range = 2.68 — 2.76 g /cc) and reflects the abundance of carbonate grains and cements, as well as pyrite and chlorite, in these samples. Valanginian Channel Fill Twelve (12) silty shale, argillaceous siltstone and argillaceous sandstone samples were examined from the Valanginian Channel Fill interval (Plates 27 — 38). These argillaceous samples are typically bioturbated and less commonly laminated. Average grain size is typically in the coarse silt to lower very fine sand ranges and sorting is moderately well to well. The framework grain suite is composed mainly of quartz, less common plagioclase, and with local concentrations of glauconite (Plates 36, 37, and 38). Rare arenaceous foraminifers (Plates 29 and 30) are the only observed marine skeletal fragments. Rock fragments are not common. Point count data shows a dramatic difference to the quartz/feldspar /rock fragment ratios between the Valanginian Channel Fill and the overlying Middle Cretaceous sandstones (Table 2 and Figure 1). This is also reflected in the quartz to plagioclase ratio in the XRD data (Table 4). There is no direct evidence that plagioclase and plagioclase -rich grains have been systematically removed by diagenesis. Furthermore, carbonate grains, present in all the Base of Slope Middle Cretaceous intervals are not present in the Valanginian Channel Fill samples. Therefore, it is likely that these argillaceous samples have a different provenance than the overlying sandstones. The samples are classified mainly as lithic arkoses, arkoses, and subarkoses, and less commonly as a feldspathic litharenite. The effects of compaction are masked by the detrital clay matrix common to all of these samples. The concentrations of glauconite grains, generally accepted as forming at the sediment/water interface, suggest very slow sedimentation rates. Therefore, the Valanginian Channel Fill interval may represent a condensed section. Intergranular areas are filled with detrital clay matrix, locally replaced by pyrite, and dolomite cement. The clay mineral suite is composed of illite /smectite mixed -layer clay, illite, and chlorite (Table 3). Visible pores are rare. Average porosity (Table 4) for ten (10) samples from this interval is 7.81 % (range = 6.23 — 9.34 %) and average air permeability is 0.015 and 5 L1 (range = 0.003 — 0.040 md). Average grain density is 2.76 g /cc (range = 2.71 — 3.04 g /cc) and reflects the abundance of pyrite, chlorite, and dolomite, and locally siderite, in these samples. The siderite -rich sample from 9010 feet has a grain density of 3.04 g /cc and skews the average grain density higher. The median grain density of 2.73 g /cc may be more representative of these argillaceous sediments. Kimmeridgian Silt Eleven (11) argillaceous siltstone and argillaceous sandstone samples were examined from the Kimmeridgian Silt interval (Plates 39 — 49). These argillaceous samples are typically bioturbated and less commonly laminated. Grains are well to very well sorted and average grain size is in the coarse silt to lower very fine sand ranges. The framework grain suite is composed mainly of quartz and less common plagioclase. Glauconite is less common than in the Valanginian Channel Fill samples. Rock fragments are minor and are less common than in the overlying Middle Cretaceous sandstones and Valanginian Channel Fill intervals (Table 2 and Figure 1). There is no direct evidence that plagioclase and plagioclase -rich grains have been systematically removed by diagenesis. Furthermore, carbonate grains, present in all the Base of Slope Middle Cretaceous intervals are not present in these argillaceous siltstones. Compositionally, the Kimmeridgian Silt samples are more similar to the Valanginian Channel Fill samples than Middle Cretaceous sand samples, and may have the same provenance as the former. The samples are classified mainly as subarkoses. The effects of compaction are masked by the detrital clay matrix common to all of these samples. Intergranular areas are filled with detrital clay matrix, locally replaced by pyrite, as well as dolomite and quartz overgrowth cements. Clay matrix is less common than in the Valanginian Channel argillaceous siltstones (Tables 2 and 3). The clay mineral suite is mainly illite /smectite mixed -layer clay and illite, with less common chlorite (Table 3). Visible pores are rare. Average porosity (Table 4) for ten (10) samples from this interval is 7.52% (range = 5.37 — 9.36 %) and average air permeability is 0.013 and (range = 0.005 — 0.018 md). Average grain density is 2.71g /cc (range = 2.70 — 2.74 g /cc) and reflects the abundance of pyrite, chlorite, and dolomite in these samples. Mineral Effects on Wireline Log Response The examined samples contain sufficient dolomite, calcite, and pyrite to elevate average grain densities to 2.71 — 2.76 g /cc. Porosity logs should be calibrated for densities in this range rather than for sandstone matrix of 2.65 g /cc. These samples do no contain potassium feldspar. Therefore, most of the gamma ray log response is due to the presence of illitic clays and micas. r The presence of iron -rich chlorite in the clay mineral suite may increase formation conductivity and reduce resistivity. ' The majority of the pore volume in these samples is in form of micropores. This can lead to high immobile water saturations. C: ANALYTICAL PROCEDURES Thin Section Petrography Thin sections were prepared by first impregnating the samples with epoxy to augment cohesion and to prevent loss of material during grinding. Blue dye was added to the epoxy to highlight the pore spaces. Each thinly sliced sample was mounted on a frosted glass slide and then cut and ground in water to an approximate thickness of 30 microns. The thin sections were stained with Alizarin Red -S to differentiate calcite (stains red) from dolomite, potassium ferrocyanide (stains blue or purple) to distinguish ferroan carbonate varieties, and sodium cobaltinitrite, which stains potassium feldspar yellow. The thin sections were analyzed using standard petrographic techniques. A modal analysis of 250 points was made on 43 samples. The data are reported in Table 2. X -ray Diffraction Analysis A sample selected for X -ray diffraction analysis is dried and cleaned of obvious contaminants. The crushed sample is dried, weighed, placed in water, and treated with a sonic cell disrupter. The resultant slurry is centrifuged to fractionate the sample at 4 microns. The suspended < 4 micron fraction is decanted and saved. The > 4 micron fraction is dried and weighed to determine the percent of clay- and silt -sized material. The suspended < 4 micron fraction is suctioned onto a pure silver substrate to orient the clay mineral particles. The < 4 micron sample mount is run in an air -dried state and then treated with ethylene glycol vapor for 24 hours and run again. The > 4 micron fraction is milled and run on a Philips APD 3620 diffractometer. The diffractograms are then analyzed for mineral content using a profile- fitting algorithm. The integrated areas from the profile- fitting algorithm are entered into a spreadsheet that contains correction coefficients for numerous minerals. These coefficients were obtained according to the adiabatic method outlined by Chung (1974). Tabular data are reported in weight percent format in Table 3. REFERENCES Chung, F.H. (1974): A new X -ray diffraction method for quantitative multicomponent analysis. Advances in X -ray Analysis. 17, p. 106 -115. Chung, F.H. (1974): Quantitative interpretation of X -ray diffraction patterns of mixtures. 1. Matrix - flushing method for quantitative multicomponent analysis. Journal of Applied Crystallography, 7, p. 519 -525. Chung, F.H. (1974): Quantitative interpretation of X -ray diffraction patterns of mixtures. II. Adiabatic principle of X -ray diffraction analysis of mixtures. Journal of Applied Crystallography, 7, p. 526 -531. Folk, R.L. (1980) Petrology of Sedimentary Rocks. Hemphill Publishing Company, Austin, Texas, 184p. Houseknecht, David. W. and K. J. Bird (2004): Sequence Stratigraphy of the Kingak Shale (Jurassic — Lower Cretaceous), National Petroleum Reserve in Alaska. AAPG Bulletin, v. 88, No. 3, p. 279 — 302. 7 Figure 1 Ternary Diagram - Sandstone Classification (Folk, 1980) Total Caribou 26 -11 No. 1 Well • Base of Slope Middle Cretaceous • Base of Slope Middle Cretaceous Sand Sequence 20 - 21.5 Base of Slope Middle Cretaceous Sand Sequence 22A Valanginian Channel Fill • Kimmeridgian Silt f Feldspars 3:1 1:1 1:3 Lithics Table 2 Thin Section Modal Analysis Total USA, Inc. Caribou 26 -11 No. 1 Well Alaska Modal Percent C.L. File No: 040187G Sample Depth feet 7202 7250 7475 7547 7563 7588 7615 7619 Sample Number 50 49 22 20 19 18 15 14 Core Porosity 1000 psi % 8.82 2.73 8.3 4.6 8.68 10.44 11.99 10.37 Kair @ 1000 psi and 0.029 0.002 0.040 0.003 0.040 0.050 0.143 0.060 Grain Density /cc 2.72 2.73 2.71 2.75 2.71 2.71 2.70 2.70 . Average Grain Size mm 0.192 0.086 0.134 0.096 0.086 0.096 0.134 0.106 I Sorting poor well mod. well mod. well 1 mod. well 1 mod. well 1 moderate mod. well Interval BOS BOS I BOS I BOS 20 -21.5 BOS 20 -21.5 BOS 20 -21.5 BOS 20 -21.5 BOS 20 -21.5 FRAMEWORK GRAINS Quartz 24.0 21.2 16.8 26.8 23.6 28.4 18.4 22.8 Feldspars K -feldspar Organics Plagioclase 10.0 8.0 12.8 8.4 9.2 12.8 9.6 120 Total 10.0 8.0 12.8 8.4 9.2 12.8 9.6 12.0 Rock Argillaceous R. F. 10.8 10.4 9.6 9.6 9.6 12.0 11.6 11.6 Fragments Volcanic R. F. 6.8 7.6 4.4 12.4 9.6 10.8 8.4 4.4 (Lithics) Plutonic Meta. R.F. 6.4 4.8 4.8 6.4 3.2 2.4 8.4 4.4 Dolomite R.F. 8.8 6.8 8.8 6.0 4.8 3.2 6.8 4.8 Calcite R. F. 0.8 0.8 3.6 3.2 3.2 2.4 0.4 0.4 Chert 3.2 2.8 3.6 4.4 3.2 0.8 2.8 1.6 Total 36.8 33.2 34.8 42.0 33.6 31.6 38.4 27.2 Other Mica 4.4 2.0 2.0 2.0 2.0 2.4 2.4 3.6 Heavy Minerals 0.8 0.4 0.8 0.4 0.4 0.4 Plant Fragments 1.6 0.8 0.4 Glauconite 0.4 Skeletal Fragments Total 6.8 3.2 2.8 2.0 1 3.2 1 2.8 2.8 3.6 IJoJ aka 114 0110 ldVivl 0 h7 IN lnRON F7 Clay Matrix Intergranular 2.4 iuu.0 0.4 0.4 1.2 0.4 3.6 1.2 Authi en. Clay 3.6 4.0 2.8 6.0 4.0 4.8 4.8 5.2 6.8 Non -Clay Quartz O. 4.8 0.4 1.6 1.6 2.4 2.8 4.0 4.0 Cements Feldspar O. 1 52.0% 53.2% trace 54.4% 50.6% 43.4% 0.8 Micropores Calcite 0.4 7.2 6.8 2.4 5.2 5.2 2.0 3.6 6.0 Fe- calcite 3.2 10.0 4.4 3.2 4.0 2.8 0.4 Dolomite 5.2 11.2 7.6 3.6 6.0 6.4 9.2 10.8 Fe- dolomite trace Siderite trace 0.4 0.4 Organics Pyrite / Ti0 2.0 2.8 3.2 2.8 3.2 1.6 1.6 4.0 Total 12.4 31.6 23.6 13.6 21.2 19.2 17.6 22.8 run Inn -aVACt Porosity Intergranular 2.4 iuu.0 0.4 0.4 1.2 0.4 3.6 1.2 Intragranular 3.6 Litharenite 2.8 2.8 3.2 q 33.9% 3.2 2.4 34.7% Moldic 39.0% 27.7% 36.8% f 14.1% 12.8% 19.9% 1.2 1.2 17.6% Fracture 19.4% 1 52.0% 53.2% 54.0% 54.4% 50.6% 43.4% 57.8% Micropores Total 6.0 0.0 3.2 3.2 4.4 0.4 8.0 4.8 iuu.0 iuu.0 iuu.0 iuu.0 wv.0 ivv.0 iuu.0 Iuu.0 Folk (1980) Litharenite Litharenite Feld. lith. Litharenite Litharenite Feld. lith. Litharenite Feld. lith. q 33.9% 34.0% 26.1% 34.7% 35.5% 39.0% 27.7% 36.8% f 14.1% 12.8% 19.9% 10.9% 13.9% 17.6% 14.5% 19.4% 1 52.0% 53.2% 54.0% 54.4% 50.6% 43.4% 57.8% 43.9% Intervals BOS = Base of Slope Middle Cretaceous Val. Ch. Fill = Valanginian Channel Fill Kim. Silt = Kimmeridgian Silt M Table 2 (continued) Thin Section Modal Analysis Total USA, Inc. Caribou 26 -11 No. 1 Well Alaska Mnrial Parrant C.L. File No: 040187G Sample Depth feet 7623 7704 7721 7730 7742 7748 7760 7769 Sample Number 13 11 10 9 8 7 6 5 Core Porosity 1000 psi 11.38 7.52 9.66 10.81 9.29 9.31 10.29 8.67 Kair 1000 psi and 0.095 0.014 0.044 0.530 0.038 0.048 0.051 0.019 Grain Density /cc 2.70 2.71 2.71 2.71 2.71 2.72 2.71 2.71 .Average Grain Size mm 0.115 0.115 0.096 0.096 0.115 0.106 0.211 0.106 Sortin mod. well moderate moderate moderate moderate moderate _ poor moderate Interval BOS 20-21.51 BOS 22A I BOS 22A I BOS 22A I BOS 22A BOS 22A BOS 22A I BOS 22A Quartz Intergranular 19.6 28.0 24.4 24.4 31.6 21.2 21.2 22.4 Feldspars K -feldspar 1.6 6.4 4.8 6.0 7.6 6.4 5.6 6.4 Non -Clay Cements Plagioclase 14.8 13.6 14.4 14.4 10.4 15.2 12.0 18.8 Feldspar O. Total 14.8 13.6 14.4 14.4 10.4 15.2 12.0 18.8 Rock Argillaceous R. F. 12.8 14.8 18.4 20.0 16.0 22.8 16.8 19.2 Fragments (Lithics) Volcanic R. F. 7.6 10.0 8.8 4.4 7.2 6.8 10.4 6.8 Plutonic/ Meta. R.F. 4.4 6.4 1.2 2.8 4.8 3.6 3.2 4.0 Fe- dolomite Dolomite R.F. 5.6 0.8 2.8 1.6 3.2 1.2 2.0 2.8 Siderite Calcite R. F. 1.6 0.8 0.4 0.8 0.8 0.4 0.4 0.4 Chert 1.2 2.8 4.0 5.6 2.4 2.8 6.4 1.6 Total 33.2 35.6 35.2 35.2 34.4 37.6 39.2 34.8 Other Mica 2.4 3.6 1.6 2.0 2.8 2.0 3.2 4.4 Heavy Minerals 0.8 1.2 0.8 0.8 0.8 0.8 0.8 Plant Fragments 0.4 2.0 2.0 0.8 1.6 Glauconite Skeletal Fragments Total 3.6 4.8 1.6 2.8 5.6 4.8 4.8 6.8 Clay Matrix Intergranular 1.6 IUU.V 0.8 0.8 0.4 .vv.v 0.4 Feld. lith. Authi en. Clay 2.8 1.6 6.4 4.8 6.0 7.6 6.4 5.6 6.4 Non -Clay Cements Quartz O. 6.4 1.2 1.6 3.2 1.6 0.8 2.4 0.8 Feldspar O. 0.8 1 49.1% 0.4 47.6% 47.6% 45.0% 50.8% Micro ores 45.8% Calcite 1.2 1.2 1.2 1.2 0.4 2.0 0.8 1.2 6.8 Fe-calcite 4.0 1.2 1.2 1.2 6.4 1.2 0.8 0.4 Dolomite 8.4 4.8 8.0 6.4 3.6 5.6 3.6 4.4 Fe- dolomite Siderite 0.4 0.4 0.8 0.4 0.4 Organics Pyrite/ Ti0 3.6 2.8 2.8 2.4 2.0 3.6 3.2 3.2 Total 11 20.4 11.2 15.6 13.6 8.4 13.6 10.8 10.4 Porosity Intergranular 1.6 IUU.V 0.8 0.8 0.4 .vv.v 0.4 Feld. lith. Intra ranular 2.8 0.4 2.8 2.4 1.6 1.2 4.8 0.4 Moldic 2.4 28.6% 0.4 0.4 f 21.9% 17.6% 1.2 19.5% Fracture 20.5% 16.6% 24.7% 1 49.1% 46.1% 47.6% 47.6% 45.0% 50.8% Micro ores 45.8% Total 6.8 0.4 4.0 3.6 2.0 1.2 6.4 0.4 I UU.0 IUU.0 Ivv.v IUU.V IvU.v Ivv.v IVV.0 .vv.v Folk (1980) Feld. lith. Feld. lith. Feld. lith. Feld. lith. Litharenite Feld. lith. Litharenite Feld. lith. q 29.0% 36.3% 33.0% 33.0% 41.4% 28.6% 29.3% 29.5% f 21.9% 17.6% 19.5% 19.5% 13.6% 20.5% 16.6% 24.7% 1 49.1% 46.1% 47.6% 47.6% 45.0% 50.8% 54.1% 45.8% Intervals BOS = Base of Slope Middle Cretaceous Val. Ch. Fill = Valanginian Channel Fill Kim. Silt = Kimmeridgian Silt 10 Table 2 (continued) Thin Section Modal Analysis Total USA, Inc. Caribou 26 -11 No. 1 Well Alaska Rfi_ h1 93nrrnn4 C.L. File No: 040187G Sample Depth feet 7795 7815 7825 7837 7848 7859 7884 8917 Sample Number 4 3 1 12 1 48 47 45 Core Porosity 1000 psi % 10.34 9.62 9.85 9.97 10.55 7.6 4.4 9.34 Kair @ 1000 psi (md ) 0.053 0.046 0.040 0.047 0.046 0.035 0.003 0.040 Grain Density Icc 2.71 2.72 2.74 2,70 2.71 2.68 2.76 2.71 , Average Grain Size mm 0.144 0.173 0.192 0.144 0.154 0.038 0.125 0.05 I Sorting poor or poor poor moderate well poor I mod. Well Interval BOS 22A BOS 22A BOS 22A BOS 22A BOS 22A BOS 22A I BOS 22A I Val. Ch. Fill Quartz Intergranular 24.0 21.2 21.6 24.4 22.4 23.2 22.0 21.2 Feldspars K -feldspar 3.6 4.0 1.6 3.6 3.6 4.8 1.6 32.3% Non -Clay Plagioclase 11.2 15.2 10.8 13.2 8.4 14.8 12.0 7.2 Cements Total 11.2 15.2 10.8 13.2 8.4 14.8 12.0 7.2 Rock Ar illaceous R. F. 18.8 17.2 13.6 19.6 19.6 32.4 13.6 Fe- calcite Fragments Volcanic R. F. 11.6 10.0 8.4 10.8 13.2 4.4 7.2 2.4 (Lithics) Plutonic Meta. R.F. 6.8 6.0 3.2 2.4 8.0 0.4 2.4 Dolomite R.F. 1.6 3.2 4.8 2.0 2.8 0.8 3.2 0.4 Calcite R. F. 1.6 0.4 1.2 Organics Chart 2.8 4.0 4.8 2.0 4.4 0.4 4.4 7.2 Total 43.2 40.4 35.2 38.0 48.0 38.4 30.8 9.6 Other Mica 2.8 2.0 0.8 3.6 2.8 4.0 2.8 0.8 Heavy Minerals 0.8 0.4 1.2 0.8 0.4 2.8 Plant Fragments 0.4 0.4 1.2 0.4 11 Glauconite 2.4 Skeletal Fragments 0.4 Total 4.0 2.8 2.0 5.6 3.6 8.0 2.8 3.6 Clay Matrix Intergranular 4.4 0.4 1.6 0.8 0.4 Folk (1980) Litharenite 50.0 Authi en. Clay Intragranular 3.6 4.0 1.6 3.6 3.6 4.8 1.6 32.3% Non -Clay Quartz O. 1.2 3.2 1.6 1.2 0.8 17.5% 0.4 19.4% Cements Feldspar 0. 1 55.1% 52.6% 52.1% 50.3% 60.9% 50.3% 47.5% 25.3% Calcite 2.0 0.8 0.8 1.6 0.4 Fe- calcite 0.4 1.6 5.6 0.4 3.6 0.8 2.0 0.0 Dolomite 2.8 5.6 18.0 4.0 6.4 4.8 15.2 2.8 Fe- dolomite 0.4 0.8 11.6 Siderite 0.4 1.2 0.4 0.4 Organics 2.0 Pyrite / T0 2.0 2.0 2.8 2.8 2.4 4.4 1.6 16 Total 8.8 13.6 23.2 11.2 1 10.4 10.0 28.8 874 Porosity Intergranular 4.4 0.4 1.6 0.8 0.4 Folk (1980) Litharenite Feld. lith. Litharenite Intragranular 0.8 1.6 4.0 32 2.4 0.8 1.6 32.3% 28.4% Moldic 34.0% 0.8 f 14.3% 19.8% 0.8 17.5% 0.4 19.4% Fracture 18.9% 1 55.1% 52.6% 52.1% 50.3% 60.9% 50.3% 47.5% 25.3% Micropores Total 5.2 2.8 5.6 4.0 3.6 0.8 2.0 0.0 iuu.0 iuu.v ivv.v w . I.,,,.., Folk (1980) Litharenite Feld. lith. Litharenite Feld. lith. Litharenite Feld. lith. Feld. lith. Feld. lith. q 30.6% 27.6% 32.0% 32.3% 28.4% 30.4% 34.0% 55.8% f 14.3% 19.8% 16.0% 17.5% 103% 19.4% 18.5% 18.9% 1 55.1% 52.6% 52.1% 50.3% 60.9% 50.3% 47.5% 25.3% Intervals BOS = Base of Slope Middle Cretaceous Val. Ch. Fill = Valanginian Channel Fill Kim. Silt = Kimmeridgian Silt 11 Table 2 (continued) Thin Section Modal Analysis Total USA, Inc. Caribou 26 -11 No. 1 Well Alaska Modal Percent C.L. File No: 040187G Sample Depth feet 8950 8981 8999 9009 9010 9023 9024 9025 Sample Number 42 41 40 39 38 37 36 35 Core Porosity 1000 psi % 7.56 7.5 7.01 7.74 6.23 8.72 8.36 7.84 Kair @ 1000 psi and 0.016 0.015 0.009 0.012 0.003 0.013 0.011 0.008 Grain Density /cc 2.73 2.72 2.71 2.73 3.04 2.74 2.74 2.73 , Average Grain Size mm 0.048 0.048 0.048 0.048 0.048 0.048 0.048 0.048 I Sorting well well well I well well mod. well well well Interval Val. Ch. Fill Val. Ch. Fill Val. Ch. Fill I Val. Ch. Fill Val. Ch. Fill Val. Ch. Fill Val. Ch. Fill Val. Ch. Fill r RFi1VIGVVIJRn I�RAl1VJ Quartz Intergranular 21.2 20.8 24.0 25.6 20.0 22.0 25.6 30.0 Feldspars K -feldspar Subarkose Arkose Arkose Subarkose q 61.6% 61.2% 69.8% 73.6% Plagioclase 9.6 9.6 7.2 7.2 4.4 7.6 9.2 6.0 Total 9.6 9.6 7.2 7.2 4.4 7.6 9.2 6.0 Rock Fragments Argillaceous R. F. Micro ores Calcite Volcanic R. F. 3.2 3.6 3.2 1.6 0.8 1.6 1.2 0.8 (Lithics) Plutonic Meta. R.F. Dolomite 7.6 5.2 6.8 0.8 0.4 3.2 Dolomite R.F. 0.4 Fe- dolomite Calcite R. F. Siderite 0.8 0.4 1.2 0.8 40.8 1.2 Chert Organics 1.6 2.0 0.4 2.8 5.2 0.4 1.6 3.6 Total 3.6 3.6 3.2 2.0 0.8 1.6 2.4 1.2 Other Mica 2.0 3.2 1.6 0.4 0.8 0.8 0.4 12.4 Heavy Minerals 0.8 0.4 Plant Fragments 0.4 1..6 0.4 0.4 0.8 0.8 0.8 Glauconite 6.4 2.0 1.6 8.0 5.6 28.0 14.0 13.2 Skeletal Fragments Total 9.2 5.6 3.6 8.8 6.8 29.6 15.2 14.0 1:1�7:��71AAlPIC=�S�L'ti7 Bold aC I F, Clay Matrix Intergranular 42.4 48.2 48.4 40.8 15.2 26.8 33.2 36.4 Authi en. Cla Intragranular Subarkose Arkose Arkose Subarkose q 61.6% 61.2% 69.8% 73.6% Non -Clay Quartz O. 68.8% 80.6% f 27.9% 28.2% 20.9% 20.7% 17.5% 24.4% Cements Feldspar O. 1 10.5% 10.6% 9.3% 5.7% 3.2% 5.1% 6.5% 3.2% Micro ores Calcite Total 0.0 Fe- calcite 0.0 0.0 0.0 0.0 0.0 0.0 Dolomite 7.6 5.2 6.8 5.6 2.8 3.2 4.8 4.0 Fe- dolomite Siderite 0.8 0.4 1.2 0.8 40.8 1.2 Organics 1.6 2.0 0,8 2.8 5.2 2.8 1.6 3.6 Pyrite / Ti0 4.0 4.6 4.8 6.4 4.0 6.4 6.8 4.8 Total 14.0 12.2 13.6 15.6 52.8 12.4 14.4 12.4 NUKt -n P'AL.t Porosity Intergranular IUU.0 IUU.0 IUU.0 IVV.V IVV.V IUU.0 Folk (1980) Lithic arkose Lithic arkose Lithic arkose Intragranular Subarkose Arkose Arkose Subarkose q 61.6% 61.2% 69.8% 73.6% Moldic 70.5% 68.8% 80.6% f 27.9% 28.2% 20.9% 20.7% 17.5% 24.4% Fracture 16.1% 1 10.5% 10.6% 9.3% 5.7% 3.2% 5.1% 6.5% 3.2% Micro ores Total 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 - luu.0 IUU.0 IUU.0 IUU.0 IUU.0 IVV.V IVV.V IUU.0 Folk (1980) Lithic arkose Lithic arkose Lithic arkose Arkose Subarkose Arkose Arkose Subarkose q 61.6% 61.2% 69.8% 73.6% 79.4% 70.5% 68.8% 80.6% f 27.9% 28.2% 20.9% 20.7% 17.5% 24.4% 24.7% 16.1% 1 10.5% 10.6% 9.3% 5.7% 3.2% 5.1% 6.5% 3.2% Intervals BOS = Base of Slope Middle Cretaceous Val. Ch. Fill = Valanginian Channel Fill Kim. Silt = Kimmeridgian Silt 12 Table 2 (continued) Thin Section Modal Analysis Total USA, Inc. Caribou 26 -11 No. 1 Well Alaska Mnrial Parcant C.L. File No: 040187G Sample Depth feet 9026 9045 9053 9067 9068 9069 9070 9071 Sample Number 34 33 32 31 30 29 28 27 Core Porosity 1000 psi % 5.37 7.25 9.14 7.89 8.32 6.76 6.28 6.56 Kair @ 1000 psi and 0.005 0.010 0.018 0.015 0.016 0.011 0.011 0.008 Grain Density /cc 2.74 2.71 2.71 2.70 2.70 2.72 2.72 2.72 Avera a Grain Size mm 0.048 0.048 0.048 0.058 0.058 0.048 0.048 0.048 Sortin well well well well well well well well Interval Kim. Silt Kim. Silt Kim. Silt Kim. Silt I Kim. Silt I Kim. Silt Kim. Silt Kim. Silt FKAIVItVVUKK URAINN Quartz Inter granular 34.2 45.2 43.6 50.4 46.8 49.6 53.6 41.2 Feldspars K -feldspar Subarkose Subarkose 0.4 Subarkose 0.4 3.6 1.6 86.3% Plagioclase 5.8 10.0 8.4 4.4 8.8 4.8 10.4 10.0 Total 5.8 10.0 8.4 4.4 8.8 4.8 10.4 10.0 Rock Argillaceous R. F. Calcite 0.4 Total Fragments Volcanic R. F. 2.0 1 1.2 2.8 2.0 1.2 0.4 0.8 (Lithics) Plutonic/ Meta. R.F. Dolomite 13.6 8.4 0.4 11.6 9.2 9.2 7.2 Dolomite R.F. Fe- dolomite 0.4 0.4 0.8 0.4 Calcite R. F. Siderite 0.4 0.4 Chert 1.2 0.4 0.4 1.6 1.2 0.4 0.8 Total 2.0 0.0 1.2 3.6 2.4 1.6 1.2 1.2 Other Mica 0.4 2.0 1.2 1.2 0.8 1.6 1.6 1.6 Heavy Minerals 0.8 0.4 1.2 0.4 0.4 0.8 1.2 Plant Fragments 3.2 0.8 0.4 2.0 0.8 2.0 1.6 0.8 Glauconite 0.4 1.2 2.4 1.2 2.0 1 1.2 0.4 Skeletal Fragments Total 4.8 4.4 5.2 4.8 4.0 4.8 4.0 4.0 r�rr�c�amra raecicranran�r- �umQVEw� Clay Matrix Inter granular 32.8 25.6 21.2 10.8 13.6 16.0 18.0 26.8 Authi en. Cla Intra ranular Subarkose Subarkose 0.4 Subarkose 0.4 3.6 1.6 86.3% Non -Clay Quartz O. 82.2% 78.6% 5.2 6.8 7.6 1.2 15.2% Fracture Cements Feldspar O. 1 4.8% 0.0% 2.3% 6.2% 4.1% 2.9% Micropores 2.3% Calcite Total 0.0 0.0 0.4 Fe- calcite 0.4 4.8 1.6 0.0 Dolomite 13.6 8.4 9.6 11.6 9.2 9.2 7.2 8.0 Fe- dolomite Siderite 0.4 0.4 Organics 1.2 0.4 0.4 1.6 1.2 0.4 0.8 Pyrite / TiO 5.2 5.6 4.8 5.2 5.6 6.8 3.6 8.0 Total 20.4 14.8 20.0 23.6 24.0 18.4 11.2 16.8 rLjmr- Mrat.r Porosity Inter granular 1UU.0 1UU.0 IUU.0 1UU.0 1UU.0 100.0 Folk (1980) Subarkose Subarkose Subarkose Intra ranular Subarkose Subarkose 0.4 Subarkose 0.4 3.6 1.6 86.3% Moldic 88.6% 82.2% 78.6% 2.4 18.1% 1.2 7.5% 15.2% Fracture 16.0% 19.1% 1 4.8% 0.0% 2.3% 6.2% 4.1% 2.9% Micropores 2.3% Total 0.0 0.0 0.4 2.4 0.4 4.8 1.6 0.0 IUU.0 IUU.0 1UU.0 1UU.0 IUU.0 1UU.0 1UU.0 100.0 Folk (1980) Subarkose Subarkose Subarkose Subarkose Subarkose Subarkose Subarkose Subarkose q 81.4% 81.9% 82.0% 86.3% 80.7% 88.6% 82.2% 78.6% f 13.8% 18.1% 15.8% 7.5% 15.2% 8.6% 16.0% 19.1% 1 4.8% 0.0% 2.3% 6.2% 4.1% 2.9% 1.8% 2.3% Intervals BOS = Base of Slope Middle Cretaceous Val. Ch. Fill = Valanginian Channel Fill Kim. Silt = Kimmeridgian Silt 13 Table 2 (continued) Thin Section Modal Analysis Total USA, Inc. Caribou 26 -11 No. 1 Well Alaska C.L. File No: 040187G Modal Percent Quartz Intergranular 44.8 53.2 32.0 Feldspars K -feldspar 84.7% 80.0% Moldic Plagioclase 9.2 8.0 8.0 Total 9.2 8.0 8.0 Rock Fragments (Lithics) Argillaceous R. F. Total 2.8 Volcanic R. F. 1.6 1.2 Plutonic/ Meta. R.F. 10.8 8.4 8.0 Dolomite R.F. 0.4 0.4 Calcite R. F. 1.6 Chert 1.2 1.2 1.2 Total 2.0 1.6 0.0 Other Mica 0.8 1.2 1.6 Heavy Minerals 1.6 0.4 Plant Fragments 0.8 2.0 Glauconite 0.4 1 0.8 Skeletal Fragments Total 2.8 1 2.8 4.0 1VJM Mal A 11 OLCRU .J e"I11 aac�n Clay Matrix Intergranular 16.4 12.8 38.0 Authi en. Cla 2.8 84.7% 80.0% Moldic Non -Clay Cements Quartz O. 5.6 6.0 0.0% Feldspar O. Micro ores Calcite Total 2.8 Fe- calcite 0.0 Dolomite 10.8 8.4 8.0 Fe dolomite Siderite 1.6 Organics 1.2 1.2 1.2 Pyrite / TiO 4.4 6.0 7.2 Total 22.0 21.6 18.0 11wJC4__0-1JGL"a Porosity Intergranular IUU.0 Folk (1980) Subarkose Subarkose Intragranular 2.8 84.7% 80.0% Moldic 12.7% 20.0% 1 3.6% Fracture 0.0% Micro ores Total 2.8 0.0 0.0 IUU.0 IUU.0 IUU.0 Folk (1980) Subarkose Subarkose Subarkose q 80.0% 84.7% 80.0% f 16.4% 12.7% 20.0% 1 3.6% 2.5% 0.0% Intervals BOS = Base of Slope Middle Cretaceous Val. Ch. Fill = Valanginian Channel Fill Kim. Silt = Kimmeridgian Silt 14 Total E &P USA, Inc. Table 3 File: 040187G Caribou 26 -11 No. 1 Well Mineralogy Determined by X -ray Diffraction * Mixed -Layer Illite / Smectite Contains 20 -25% Smectite Layers (1) Base of Slope Middle Cretaceous Sand Sequence 20 - 21.5 (2) Base of Slope Middle Cretaceous Sand Sequence 22A (3) Valangianian Channel Fill (4) Kimmeridgian Silt 15 Core Lab Petroleum Services Whole Rock Mineralogy (Weight %) Relative Clay Abundance (Normalized to 100 %) Depth Quartz Plagioclase Calcite Dolomite & I Ca/Ma- Siderite Pyrite Total Clay Illite / Illite & Chlorite Fe- Dolomite Siderite I I Smectite * Mica 7615(l) 49 22 2 12 0 trace 1 14 27 33 41 7623(1) 50 21 3 12 0 0 2 13 28 28 44 7760 (2) 50 22 2 7 0 2 1 16 23 29 48 7837 (2) 50 22 2 6 0 2 0 19 25 32 43 9010 (3) 30 5 0 1 20 21 2 21 43 28 29 9023 (3) 53 4 0 3 0 1 3 36 39 26 35 9025 (3) 57 3 0 5 0 trace 4 31 39 33 28 9068 (4) 71 6 1 7 0 trace 3 12 42 31 27 9101 (4) 69 7 1 8 0 trace 3 12 45 33 22 * Mixed -Layer Illite / Smectite Contains 20 -25% Smectite Layers (1) Base of Slope Middle Cretaceous Sand Sequence 20 - 21.5 (2) Base of Slope Middle Cretaceous Sand Sequence 22A (3) Valangianian Channel Fill (4) Kimmeridgian Silt 15 Core Lab Petroleum Services Figure 2 Porosity vs Air Permeability Total Caribou 26 -11 No. 1 Well 1.000 0.100 v E Z , a m d E L d a L Q 0.010 ■ ♦,♦ ♦ ■ j ♦► ■ r •• ♦ 1 ■ ■ 0 2 4 6 8 10 12 14 Porosity ( %) Base of Slope (BOS) ■ BOS 20 - 21.5 ♦ BOS 22A ■ Valanginian Channel Fill Kimmeridgian Silt 16 Table 4 Total E. & P. USA, Inc. Caribou 26 -11 No.1 Well Alaska PCTASECOM SEAVILFS CMS -300 ROTARY CORE ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Number Depth ft Net Confining stress psig Porosity % Permeability Saturation Grain Oil I Water Density % Pore Volume /cm3 Klinkenberg I Kair mD mD 17 Base of Slope Middle Cretaceous 50 7202 1000 8.82 .015 .029 18.4 66.9 2.72 49 7250 1000 2.73 .001 .002 2.0 91.2 2.73 23 7352 Ambient 5.60 .001 .002 0.0 69.0 2.73 22 7475 1000 8.30 .026 .040 17.4 36.0 2.71 average 6.36 0.010 0.018 9.5 65.8 2.72 median 6.95 0.008 0.016 9.7 67.9 2.73 minimum 2.73 0.001 0.002 0.0 36.0 2.71 maximum 8.82 0.026 0.040 18.4 91.2 2.73 Baase of Slope Middle Cretaceous Sand Sequence 20 - 21.5 21 7524 1000 6.17 0.014 0.022 3.6 84.8 2.75 20 7547 1000 4.60 0.001 0.003 12.0 65.0 2.75 19 7563 1000 8.68 0.023 0.040 16.9 42.3 2.71 18 7588 1000 10.44 0.030 0.050 24.5 39.1 2.71 16 7613 1000 8.42 0.101 0.146 17.0 57.4 2.73 15 7615 1000 11.99 0.084 0.143 5.8 64.3 2.70 14 7619 1000 10.37 0.037 0.060 8.0 42.9 2.71 13 7623 1000 11.38 0.054 0.095 17.1 60.2 2.70 average 9.01 0.043 0.070 13.1 57.0 2.72 median 9.52 0.034 0.055 14.5 58.8 2.71 minimum 4.60 0.001 0.003 3.6 39.1 2.70 maximum 11.99 0.101 0.146 24.5 84.8 2.75 Baase of Slope Middle Cretaceous Sand Sequence 22A 11 7704 1000 7.52 0.007 0.014 20.0 45.9 2.71 10 7721 1000 9.66 0.026 0.044 0.9 45.7 2.71 9 7730 1000 10.81 0.032 0.053 3.5 39.3 2.71 8 7742 1000 9.29 0.023 0.038 9.7 40.4 2.71 7 7748 1000 9.31 0.029 0.048 7.3 50.3 2.72 6 7760 1000 10.29 0.031 0.051 3.4 39.4 2.71 5 7769 1000 8.67 0.019 0.030 13.2 46.1 2.71 4 7795 1000 10.34 0.036 0.053 9.4 36.8 2.71 3 7815 1000 9.62 0.030 0.046 5.1 36.3 2.72 2 7825 1000 9.85 0.029 0.040 11.9 36.8 2.74 12 7837 1000 9.97 0.028 0.047 7.3 37.9 2.70 1 7848 1000 10.55 0.027 0.046 14.2 29.3 2.71 48 7859 1000 7.60 0.021 0.035 9.7 58.9 2.68 17 Table 4 Total E. & P. USA, Inc. Caribou 26 -11 No. 1 Well Alaska [are PETROLEUM SERVICES CMS -300 ROTARY CORE ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Number Depth ft Net Confining stress psig Porosity % Permeability Saturation Grain Density g /cm3 Klinkenberg Kair Oil I Water mD mD % Pore Volume 0.024 47 7884 1000 4.40 0.001 0.003 47.3 28.2 2.76 average 9.14 0.024 0.039 11.6 40.8 2.71 median 9.64 0.028 0.045 9.6 39.3 2.71 minimum 4.40 0.001 0.003 0.9 28.2 2.68 maximum 10.81 0.036 0.053 47.3 58.9 2.76 Valanginian Channel Fill 45 8917 1000 9.34 0.029 0.040 1.0 85.4 2.71 44 8935 1000 7.81 0.013 0.020 0.6 95.6 2.73 42 8950 1000 7.56 0.007 0.016 0.9 92.0 2.73 41 8981 1000 7.50 0.007 0.015 0.5 95.2 2.72 40 8999 1000 7.01 0.004 0.009 1.3 84.6 2.71 39 9009 1000 7.74 0.009 0.012 0.7 75.2 2.74 38 9010 1000 6.23 0.001 0.003 7.6 68.8 3.04 37 9023 1000 8.72 0.006 0.013 0.3 93.6 2.74 36 9024 1000 8.36 0.005 0.011 10.1 86.9 2.74 35 9025 1000 7.84 0.004 0.008 1.2 88.4 2.73 average 7.81 0.009 0.015 2.4 86.6 2.76 median 7.77 0.006 0.013 0.9 87.7 2.73 minimum 6.23 0.001 0.003 0.3 68.8 2.71 maximum 9.34 0.029 0.040 10.1 95.6 3.04 Kimmeridgian Silt 34 9026 1000 5.37 0.002 0.005 8.9 70.3 2.74 33 9045 1000 7.25 0.005 0.010 9.2 72.8 2.71 32 9053 1000 9.14 0.009 0.018 15.1 37.3 2.71 31 9067 1000 7.89 0.007 0.015 8.5 52.1 2.70 30 9068 1000 8.32 0.007 0.016 9.5 50.3 2.70 29 9069 1000 6.76 0.005 0.011 4.8 72.4 2.72 28 9070 1000 6.28 0.005 0.011 0.7 92.7 2.72 27 9071 1000 6.56 0.003 0.008 0.4 89.3 2.72 26 9085 1000 8.30 0.007 0.016 12.4 47.1 2.71 25 9101 1000 9.36 0.008 0.017 9.7 53.0 2.70 average 7.52 0.006 0.013 7.9 63.7 2.71 median 7.57 0.006 0.013 9.0 61.6 2.71 minimum 5.37 0.002 0.005 0.4 37.3 2.70 maximum 9.36 0.009 0.018 15.1 92.7 2.74 18 Fl APPENDIX 1 I THIN SECTION GRAIN SIZE ANALYSIS 1 Ll 0 1 � I �� Core Lab RESERVOIR OPTIMIZATION 100 80 25 20 0 j, 15 v c d Er to LL 5 0 n 60 3 c III m 40 u 20 0 0.00 Total Caribou 26 -11 No. 1 Well Depth (ft): 7202 THIN SECTION GRAIN SIZE ANALYSIS 10.00 1.00 0.10 0.01 Particle Diameter (mm) MM inches phi 0.201 0.008 2.315 0.171 0.007 2.548 0.152 0.006 2.722 0.130 0.005 2.943 0.100 0.004 3.322 0.080 0.003 3.644 0.060 0.002 4.059 0.060 0.002 4.059 0.050 0.002 4.322 0.049 0.002 4.352 TRASK* FOLK *' DESCRIPTION 0.100 3.322 Upper Very Fine Sand 0.105 3.367 Upper Very Fine Sand 1.479 0.638 Moderately Well 2.100 -0.016 Nearly Symmetrical 0.225 1.174 Leptokurtic 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 0.0 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM a 0000 0 0 00 5 -2.00 0.1575 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 _ 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 30 0.75 0.0236 0.6000 0.0 0.0 50 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 MED 50 1.75 0.0117 0.2970 2.0 2.0 95 SAND 60 2.00 0.0098 0.2500 3.0 5.0 5.0 70 2.25 0.0083 0.2100 5.0 10.0 80 2.50 0.0070 0.1770 10.0 20.0 FINE 100 2.75 0.0058 0.1490 9.0 29.0 STD DEVIATION (mm) : SAND 120 3.00 0.0049 0.1250 16.0 40.0 45.0 140 3.25 0.0041 0.1050 17.0 62.0 170 3.50 0.0035 0.0880 14.0 76.0 VFINE 200 3.75 0.0029 0.0740 7.0 83.0 STD DEVIATION (inches SAND 230 4.00 0.0024 0.0620 10.0 48.0 93.0 270 4.25 0.0021 0.0530 7.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : SILT 500 5.00 0.0014 0.0310 0.0 7.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 _ FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM a 0000 0 0 00 ,ib Core Lab PESERVIIIP OPTIMIZATION 25 - 20 15 v C Cr T to LL Total Caribou 26 -11 No. 1 Well Depth (ft): 7250 THIN SECTION GRAIN SIZE ANALYSIS 5 0 , 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 d 40 e 20 �0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 I ENNUI 7 -1.50 0.1114 2.8300 I 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 1 1.1900 0.0 0.0 5 0.131 0.005 2.938 11 18 0.00 Milli 1.0000 0.0 0.0 0.0 10 0.111 16 0.110 01 3.171 3.184 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.100 0.004 3.322 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.070 84 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 1.0 1.0 80 2.50 0.0070 0.1770 2.0 3.0 5 0 , 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 d 40 e 20 �0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.131 0.005 2.938 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.111 16 0.110 0.004 0.004 3.171 3.184 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.100 0.004 3.322 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.070 84 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 1.0 1.0 80 2.50 0.0070 0.1770 2.0 3.0 FINE 100 2.75 0.0058 0.1490 3.0 6.0 STD DEVIATION (mm) : 0.025 SAND 120 3.00 0.0049 0.1250 12.0 18.0 18.0 140 3.25 0.0041 0.1050 28.0 46.0 170 3.50 0.0035 0.0880 17.0 63.0 VFINE 200 3.75 0.0029 0.0740 17.0 80.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 13.0 75.0 93.0 270 4.25 0.0021 0.0530 6.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.329 SILT 500 5.00 0.0014 0.0310 0.0 7.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.080 MEAN 0.085 3.644 3.629 Lower Very Fine Sand Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.428 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.125 -0.130 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.294 1.102 Mesokunic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well tta�A Depth (ft): 7475 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 - 0 T 15 U C 2 10 LL 5 0 10.00 1.00 - 0.10 0.01 Particle Diameter (mm) 100 so 0 60 3 v A 40 0 20 �0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.161 0.006 2.639 VC S D 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.141 0.132 0.006 0.005 2.826 2.926 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.120 0.005 3.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.100 0.004 3.322 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.080 0.070 0.003 0.003 3.644 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 3.0 3.0 80 2.50 0.0070 0.1770 7.0 10.0 FINE 100 2.75 0.0058 0.1490 11.0 21.0 STD DEVIATION (mm): 0.031 SAND 120 3.00 0.0049 0.1250 22.0 43.0 43.0 140 3.25 0.0041 0.1050 26.0 69.0 170 3.50 0.0035 0.0880 12.0 81.0 VFINE 200 3.75 0.0029 0.0740 12.0 93.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 6.0 56.0 99.0 270 4.25 0.0021 0.0530 1.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.993 SILT 500 5.00 0.0014 0.0310 0.0 1.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.100 0.100 3.322 3.361 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.443 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 0.006 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.282 0.995 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 - COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 oAa L wA - 4 1 RESERVOIR OPTIMIZATION 25 20 j� 15 v c c a 2 10 LL Total Caribou 26 -11 No. 1 Well Depth (ft): 7547 THIN SECTION GRAIN SIZE ANALYSIS 10.00 1.00 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 3 c m 40 a 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 i 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.160 0.006 2.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.150 16 0.150 0.006 0.006 2.737 2.737 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 I. 0.0 25 0.130 0.005 2.943 30 0.75 0.0236 0.6000 0.0 0.0 50 0.095 0.004 3.396 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.080 84 0.070 0.003 0.003 3.644 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.069 0.003 10.00 1.00 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 3 c m 40 a 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.160 0.006 2.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.150 16 0.150 0.006 0.006 2.737 2.737 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.130 0.005 2.943 30 0.75 0.0236 0.6000 0.0 0.0 50 0.095 0.004 3.396 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.080 84 0.070 0.003 0.003 3.644 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.069 0.003 3.857 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 3.0 3.0 80 2.50 0.0070 0.1770 15.0 18.0 FINE 100 2.75 0.0058 0.1490 9.0 27.0 STD DEVIATION (mm) : 0.033 SAND 120 3.00 0.0049 0.1250 10.0 37.0 37.0 140 3.25 0.0041 0.1050 27.0 64.0 170 3.50 0.0035 0.0880 16.0 80.0 VFINE 200 3.75 0.0029 0.0740 10.0 90.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 7.0 60.0 97.0 270 4.25 0.0021 0.0530 3.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.907 SILT 500 5.00 0.0014 0.0310 0.0 3.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK• FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.095 MEAN 0.105 3.396 3.323 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.489 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.211 -0.202 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.309 0.828 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well Depth (ft): 7563 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 0 T 15 U C 7 Q .d, 10 LL 5 0 10.00 1.00 0.10 0.01 Particle Diameter (mm) A 100 80 n 60 3 iu 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3600 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.140 0.006 2.837 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.120 16 0.110 0.005 0.004 3.059 3.184 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.100 0.004 3.322 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.070 84 0.068 0.003 0.003 3.837 3.870 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 4.0 4.0 FINE 100 2.75 0.0058 0.1490 4.0 8.0 STD DEVIATION (mm) : 0.026 SAND 120 3.00 0.0049 0.1250 16.0 24.0 24.0 140 3.25 0.0041 0.1050 29.0 53.0 170 3.50 0.0035 0.0880 17.0 70.0 VFINE 200 3.75 0.0029 0.0740 14.0 84.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 12.0 72.0 96.0 270 4.25 0.0021 0.0530 3.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.267 SILT 500 5.00 0.0014 0.0310 0.0 4.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.090 MEAN 0.085 3.474 3.509 Upper Very Fine Sand Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.357 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 1.889 0.056 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.250 0.974 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 A Core Lab RESERVOIR OPTIMIZATION 25 20 0 15 v c c 10 It Total Caribou 26 -11 No. 1 Well Depth (ft): 7588 THIN SECTION GRAIN SIZE ANALYSIS 10`00 -� _ 1.00 m. .. T 0.10 0.01 Particle Diameter (mm) 5 0 100 so 0 60 3 d m 40 e 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.131 0.005 2.938 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.120 0.120 0.005 0.005 3.059 3.059 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.070 0.003 0.003 3.837 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 1.0 1.0 80 2,50 0.0070 0.1770 3.0 4.0 FINE 100 2.75 0.0058 0.1490 4.0 8.0 STD DEVIATION (mm) : 0.027 SAND 120 3.00 0.0049 0.1250 19.0 27.0 27.0 140 3.25 0.0041 0.1050 27.0 54.0 170 3.50 0.0035 0.0880 14.0 68.0 VFINE 200 3.75 0.0029 0.0740 18.0 86.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 11.0 70.0 97.0 270 4.25 0.0021 0.0530 2.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.220 SILT 500 5.00 0.0014 0.0310 0.0 3.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.090 0.090 3.474 3.456 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.364 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 -0.012 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.333 0.705 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 ' COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well 44.A'a Depth (ft): 7615 Care Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 T 15 c ru C Cr d 10 LL 5 0 IIEN p l �. --� . . . . . . . . . . . 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 m 40 c 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.200 0.008 2.322 VCRS SO 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.180 0.170 0.007 0.007 2.474 2.556 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.140 0.006 2.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.120 0.005 3.059 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.090 0.090 0.004 0.004 3.474 3.474 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.080 0.003 3.644 IVIED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.070 0.003 3.837 SAND 60 2.00 0.0098 0.2500 4.0 4.0 4.0 70 2.25 0.0083 0.2100 7.9 11.9 80 2.50 0.0070 0.1770 8.9 20.8 FINE 100 2.75 0.0058 0.1490 22.8 43.6 STD DEVIATION (mm) : 0.041 SAND 120 3.00 0.0049 0.1250 16.8 56.4 60.4 140 3.25 0.0041 0.1050 24.8 65.1 170 3.50 0.0035 0.0880 7.9 93.1 VFINE 200 3.75 0.0029 0.0740 4.0 97.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 2.0 38.6 99.0 270 4.25 0.0021 0.0530 1.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.610 SILT 500 5.00 0.0014 0.0310 0.0 1.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.120 0.115 3.059 3.030 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.459 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 1.917 -0.098 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.250 0.974 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 ' COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 - COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well 4t0W& Depth (ft): 7619 Care Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 0 T 15 U C Q T 10 LL 5 0 10.00 u. ., .. .. 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 m N 40 e 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.160 0.006 2.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.140 16 0.122 0.006 0.005 2.837 3.040 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.070 84 0.070 0.003 0.003 3.837 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 I� 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 1.0 1.0 1.0 70 2.25 0.0083 0.2100 2.0 3.0 80 :IIE 0.0070 0.1770 4.0 7.0 FINE 100 2.75 0.0058 0.1490 9.0 10.00 u. ., .. .. 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 m N 40 e 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.160 0.006 2.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.140 16 0.122 0.006 0.005 2.837 3.040 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.070 84 0.070 0.003 0.003 3.837 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 1.0 1.0 1.0 70 2.25 0.0083 0.2100 2.0 3.0 80 2.50 0.0070 0.1770 4.0 7.0 FINE 100 2.75 0.0058 0.1490 9.0 16.0 STD DEVIATION (mm) : 0.032 SAND 120 3.00 0.0049 0.1250 16.0 31.0 32.0 140 3.25 0.0041 0.1050 28.0 60.0 170 3.50 0.0035 0.0880 14.0 74.0 VFINE 200 3.75 0.0029 0.0740 13.0 87.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 9.0 64.0 96.0 270 4.25 0.0021 0.0530 4.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.982 SILT 500 5.00 0.0014 0.0310 0.0 4.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK'* DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.090 MEAN 0.090 3.474 3.450 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.414 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 -0.132 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.250 0.889 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well AtalAa Depth (ft): 7623 Core Lab NOSTNVOIN OPTIMIZATION THIN SECTION G / RAIN SIZE ANALYSIS �V 25 20- 0 T 15 v c a .d. to LL 5 0 10.00 1.00 y 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 m 40 0 -20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.180 0.007 2.474 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.160 0.150 0.006 0.006 2.644 2.737 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.140 0.006 2.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.110 0.004 3.184 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.080 0.080 0.003 0.003 3.644 3.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 1.0 1.0 95 0.070 0.003 3.847 SAND 60 2.00 0.0098 0.2500 1.0 2.0 2.0 70 2.25 0.0083 0.2100 5.0 7.0 80 2.50 0.0070 0.1770 12.0 19.0 FINE 100 2.75 0.0058 0.1490 13.0 32.0 STD DEVIATION (mm) : 0.040 SAND 120 3.00 0.0049 0.1250 23.0 53.0 55.0 140 3.25 0.0041 0.1050 14.0 69.0 170 3.50 0.0035 0.0880 17.0 86.0 VFINE 200 3.75 0.0029 0.0740 9.0 95.0 STD DEVIATION (inches): 0.002 SAND 230 4.00 0.0024 0.0620 4.0 44.0 99.0 270 4.25 0.0021 0.0530 1.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.650 SILT 500 5.00 0.0014 0.0310 0.0 1.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.110 0.110 3.184 3.188 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.435 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 -0.015 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.333 0.697 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 ' COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 A 4 mwA ' 4 Care Lab RESERVOIR OPTIMIZATION 25 20 0 15 v c Cr d 10 LL Total Caribou 26 -11 No. 1 Well Depth (ft): 7704 THIN SECTION GRAIN SIZE ANALYSIS 10.00 1.00 0.10 0.01 Particle Diameter (mm) I 5 0 100 80 O c -60 3 m m 40 0 . 20 +0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 SEEN 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 111101111 PERCENTILES: GRAVEL 1 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.150 0.006 2.737 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.140 0.120 0.006 0.005 2.837 3.059 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 NEI 0.080 0.003 3.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 1.0 1.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 0.0 1.0 1.0 70 2.25 0.0083 0.2100 2.0 3.0 80 2.50 0.0070 0.1770 5.0 8.0 FINE 100 2.75 0.0058 0.1490 7.0 15.0 STD DEVIATION (min): 0.037 SAND 120 10.00 1.00 0.10 0.01 Particle Diameter (mm) I 5 0 100 80 O c -60 3 m m 40 0 . 20 +0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.150 0.006 2.737 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.140 0.120 0.006 0.005 2.837 3.059 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 1.0 1.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 0.0 1.0 1.0 70 2.25 0.0083 0.2100 2.0 3.0 80 2.50 0.0070 0.1770 5.0 8.0 FINE 100 2.75 0.0058 0.1490 7.0 15.0 STD DEVIATION (min): 0.037 SAND 120 3.00 0.0049 0.1250 16.0 30.0 31.0 140 3.25 0.0041 0.1050 15.0 46.0 170 3.50 0.0035 0.0880 21.0 67.0 VFINE 200 3.75 0.0029 0.0740 15.0 82.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 10.0 61.0 92.0 270 4.25 0.0021 0.0530 5.0 97.0 325 4.50 0.0017 0.0440 3.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.762 SILT 500 5.00 0.0014 0.0310 0.0 8.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.080 0.090 3.644 3.587 Lower Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.490 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.250 -0.240 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.250 0.996 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 ' COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well *4,�\ Depth (ft): 7721 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 0 T 15 U C W 7 CT 2! 10 LL 5 0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n r 60 3 c d A 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.150 0.006 2.737 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.130 0.120 0.005 0.005 2.943 3.059 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 50 0.085 0.003 3.556 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.070 0.003 0.003 3.837 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 6.0 6.0 FINE 100 2.75 0.0058 0.1490 6.0 12.0 STD DEVIATION (mm) : 0.027 SAND 120 3.00 0.0049 0.1250 15.0 27.0 27.0 140 3.25 0.0041 0.1050 23.0 50.0 170 3.50 0.0035 0.0880 20.0 70.0 VFINE 200 3.75 0.0029 0.0740 16.0 86.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 8.0 67.0 94.0 270 4.25 0.0021 0.0530 6.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.195 SILT 500 5.00 0.0014 0.0310 0.0 6.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.085 0.090 3.556 3.484 Lower Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.435 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.118 -0.240 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.286 0.996 Mesokunic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 .100.0 Total Caribou 26 -11 No. 1 Well Depth (ft): 7730 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 li T 15 U C >T W 10 EL 5 0 10.00 -� 1.00 „• �• �. p• •� •m 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 c w qp e 20 t0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.150 0.006 2.737 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.131 0.112 0.005 0.004 2.932 3.164 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.100 0.004 3.322 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 - 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 1.0 1.0 1.0 70 2.25 0.0083 0.2100 2.0 3.0 80 2.50 0.0070 0.1770 4.0 7.0 FINE 100 2.75 0.0058 0.1490 6.0 13.0 STD DEVIATION (mm) : 0.032 SAND 120 3.00 0.0049 0.1250 10.0 22.0 23.0 140 3.25 0.0041 0.1050 31.0 54.0 170 3.50 0.0035 0.0880 16.0 70.0 VFINE 200 3.75 0.0029 0.0740 13.0 83.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 15.0 75.0 98.0 270 4.25 0.0021 0.0530 2.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.967 SILT 500 5.00 0.0014 0.0310 0.0 2.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.090 0.085 3.474 3.565 Upper Very Fine Sand Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.424 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 1.889 0.096 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.211 1.053 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 - COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well A " Depth (ft): 7742 Core Lab NESEOVOIA OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 0 � 15 U C d 7 Q 2 10 LL 5 0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 60 3 m N 40 u - 20 .0 0.00 GRAIN SIZE DISTRIBUTION -- wlll�lil SORTING PARAMETERS MESH PHI al MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 11 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.151 0.006 2.732 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.150 0.130 0.006 0.005 2.737 2.943 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.120 0.005 3.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.070 0.003 0.003 3.837 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MEO 50 1.75 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 1.0 1.0 80 2.50 0.0070 0.1770 12.0 13.0 FINE 100 2.75 0.0058 0.1490 8.0 21.0 STD DEVIATION (mm): 0.032 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 60 3 m N 40 u - 20 .0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.151 0.006 2.732 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.150 0.130 0.006 0.005 2.737 2.943 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.120 0.005 3.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.070 0.003 0.003 3.837 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MEO 50 1.75 0.0117 0.2970 0.0 0.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 1.0 1.0 80 2.50 0.0070 0.1770 12.0 13.0 FINE 100 2.75 0.0058 0.1490 8.0 21.0 STD DEVIATION (mm): 0.032 SAND 120 3.00 0.0049 0.1250 15.0 36.0 36.0 140 3.25 0.0041 0.1050 21.0 57.0 170 3.50 0.0035 0.0880 10.0 67.0 VFINE 200 3.75 0.0029 0.0740 22.0 89.0 STD DEVIATION (inches); 0.001 SAND 230 4.00 0.0024 0.0620 8.0 61.0 97.0 270 4.25 0.0021 0.0530 2.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.969 SILT 500 5.00 0.0014 0.0310 0.0 3.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.090 0.095 3.474 3.418 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.424 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.111 -0.153 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.278 0.699 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Core Lab RESERVOIR OPTIMIZATION 25 20 0 T 15 U C d 7 Q d 10 LL Total Caribou 26 -11 No. 1 Well Depth (ft): 7748 THIN SECTION GRAIN SIZE ANALYSIS 10.00 1.00 0.10 0.01 Particle Diameter (mm) 5 0 100 80 0 60 3 c N .40 0 , 20 v 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP 1 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 MM inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.120 0.005 3.059 VCRS SO 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.110 0.100 0.004 0.004 3.184 3.322 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.093 0.004 3.434 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 1.0 1.0 FINE 100 2.75 0.0058 0.1490 3.0 4.0 STD DEVIATION (mm) : 0.021 SAND 120 3.00 0.0049 0.1250 10.0 14.0 14.0 140 3.25 0.0041 0.1050 24.0 38.0 170 3.50 0.0035 0.0880 22.0 60.0 VFINE 200 3.75 0.0029 0.0740 19.0 79.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 14.0 79.0 93.0 270 4.25 0.0021 0.0530 7.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.558 SILT 500 5.00 0.0014 0.0310 0.0 7.0 100.0 5.25 0.0010 0.0260 0.0 100.0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 5 0 100 80 0 60 3 c N .40 0 , 20 v 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 MM inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.120 0.005 3.059 VCRS SO 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.110 0.100 0.004 0.004 3.184 3.322 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.093 0.004 3.434 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 1.0 1.0 FINE 100 2.75 0.0058 0.1490 3.0 4.0 STD DEVIATION (mm) : 0.021 SAND 120 3.00 0.0049 0.1250 10.0 14.0 14.0 140 3.25 0.0041 0.1050 24.0 38.0 170 3.50 0.0035 0.0880 22.0 60.0 VFINE 200 3.75 0.0029 0.0740 19.0 79.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 14.0 79.0 93.0 270 4.25 0.0021 0.0530 7.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.558 SILT 500 5.00 0.0014 0.0310 0.0 7.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.080 0.081 3.644 3.675 Lower Very Fine Sand Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.376 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.031 -0.004 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.225 1.287 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 6.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 44alk Core Lab RESERVOIR OPTIMIZATION 25 - 20 - 15 v c m c Q' d 10 LL Total Caribou 26 -11 No. 1 Well Depth (ft): 7760 THIN SECTION GRAIN SIZE ANALYSIS 10.00 m ri� 1.00 v 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 3 S. m 40 o 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm Inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.250 0.010 2.000 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.200 0.160 0.008 0.006 2.322 2.644 20 0.25 0.0335 0.8500 0.0 0.0 f4 25 0.50 0.0280 INS 0.0 0.0 25 11 0.006 2.811 30 0.75 0.0236 0.6000 0.0 0.0 50 0.110 0.004 3.184 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.088 0.078 0.003 0.003 3.515 3.673 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 2.0 3.0 95 0.070 0.003 3.837 SAND 60 in 0.0098 0.2500 I 7.0 7.0 70 2.25 0.0083 0.2100 6.0 13.0 80 2.50 0.0070 0.1770 12.0 25.0 FINE 100 2.75 0.0058 0.1490 9.0 34.0 STD DEVIATION (mm) : 0.054 SAND 120 3.00 0.0049 0.1250 22.0 49.0 56.0 140 3.25 0.0041 0.1050 19.0 75.0 170 3.50 0.0035 0.0880 9.0 84.0 VFINE 200 3.75 0.0029 0.0740 13.0 97.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 3.0 44.0 100.0 270 4.25 0.0021 0.0530 0.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.207 SILT 500 5.00 0.0014 0.0310 0.0 0.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 10.00 m ri� 1.00 v 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 3 S. m 40 o 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm Inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.250 0.010 2.000 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.200 0.160 0.008 0.006 2.322 2.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.143 0.006 2.811 30 0.75 0.0236 0.6000 0.0 0.0 50 0.110 0.004 3.184 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.088 0.078 0.003 0.003 3.515 3.673 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 2.0 3.0 95 0.070 0.003 3.837 SAND 60 2.00 0.0098 0.2500 4.0 7.0 7.0 70 2.25 0.0083 0.2100 6.0 13.0 80 2.50 0.0070 0.1770 12.0 25.0 FINE 100 2.75 0.0058 0.1490 9.0 34.0 STD DEVIATION (mm) : 0.054 SAND 120 3.00 0.0049 0.1250 22.0 49.0 56.0 140 3.25 0.0041 0.1050 19.0 75.0 170 3.50 0.0035 0.0880 9.0 84.0 VFINE 200 3.75 0.0029 0.0740 13.0 97.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 3.0 44.0 100.0 270 4.25 0.0021 0.0530 0.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.207 SILT 500 5.00 0.0014 0.0310 0.0 0.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK`* DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.110 0.115 3.184 3.167 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.536 Moderately Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.091 -0.170 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.212 1.070 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well Depth (ft): 7769 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 - 20 T 1s U C d 7 Cr d 10 LL 5 0 10.00 .«~ 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 c 60 3 c N 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.131 0.005 2.938 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.121 16 0.110 0.005 0.004 3.047 3.184 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.100 0.004 3.322 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.070 84 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.060 0.002 4.059 IVIED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 1.0 1.0 1.0 70 2.25 0.0083 0.2100 1.0 2.0 80 2.50 0.0070 0.1770 2.0 4.0 FINE 100 2.75 0.0058 0.1490 6.0 10.0 STD DEVIATION (mm): 0.030 SAND 120 3.00 0.0049 0.1250 11.0 20.0 21.0 140 3.25 0.0041 0.1050 24.0 45.0 170 3.50 0.0035 0.0880 16.0 61.0 VFINE 200 3.75 0.0029 0.0740 20.0 81.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 10.0 70.0 91.0 270 4.25 0.0021 0.0530 8.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.071 SILT 500 5.00 0.0014 0.0310 0.0 9.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.080 MEAN 0.085 3.644 3.629 Lower Very Fine Sand Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.428 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.125 -0.130 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.246 1.102 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well �. Depth (ft): 7795 Core Lab RESERVOIR OPTINRATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 - T 15 v c 3 Cr d 10 LL 5 0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n c 60 3 m 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP i CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.210 0.008 2.252 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.170 0.142 0.007 0.006 2.556 2.820 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.120 0.005 3.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.100 0.004 3.322 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.080 0.080 0.003 0.003 3.644 3.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 1.0 2.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 2.0 4.0 4.0 70 2.25 0.0083 0.2100 4.0 8.0 80 2.50 0.0070 0.1770 8.0 16.0 FINE 100 2.75 0.0058 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n c 60 3 m 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.210 0.008 2.252 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.170 0.142 0.007 0.006 2.556 2.820 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.120 0.005 3.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.100 0.004 3.322 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.080 0.080 0.003 0.003 3.644 3.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 1.0 2.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 2.0 4.0 4.0 70 2.25 0.0083 0.2100 4.0 8.0 80 2.50 0.0070 0.1770 8.0 16.0 FINE 100 2.75 0.0058 0.1490 8.0 24.0 STD DEVIATION (mm) : 0.046 SAND 120 3.00 0.0049 0.1250 17.0 37.0 41.0 140 3.25 0.0041 0.1050 31.0 72.0 170 3.50 0.0035 0.0880 13.0 85.0 VFINE 200 3.75 0.0029 0.0740 6.0 91.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 7.0 57.0 98.0 270 4.25 0.0021 0.0530 2.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.434 SILT 500 5.00 0.0014 0.0310 0.0 2.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK "' DESCRIPTION FINE 6.75 0.0003. 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.100 0.100 3.322 3.262 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.480 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 -0.263 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.200 1.266 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well Depth (ft): 7815 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 0 T 15 v c m a d to LL 5 0 10.00 li mp �- __- .._,�,. � 1.00 _ 0.10 0.01 Particle Diameter (mm) t 100 80 n c 60 3 m m 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 1 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.241 0.009 2.056 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.181 0.007 2.466 20 0.25 0.0335 0.8500 0.0 0.0 16 0.170 0.007 2.556 25 0.50 0.0280 0.7100 0.0 0.0 25 0.150 0.006 2.737 30 0.75 0.0236 0.6000 0.0 0.0 50 0.110 0.004 3.184 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.090 0.004 3.474 40 1.25 0.0165 0.4200 0.0 0.0 84 0.080 0.003 3.644 45 1.50 0.0138 0.3500 0.0 0.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 2.0 2.0 95 0.070 0.003 3.837 SAND 60 2.00 0.0098 0.2500 4.0 6.0 6.0 70 2.25 0.0083 0.2100 7.0 13.0 80 2.50 0.0070 0.1770 15.0 28.0 FINE 100 2.75 0.0058 0.1490 12.0 40.0 STD DEVIATION (mm): 0.049 SAND 120 3.00 0.0049 0.1250 17.0 51.0 57.0 140 3.25 0.0041 0.1050 22.0 79.0 170 3.50 0.0035 0.0880 9.0 88.0 VFINE 200 3.75 0.0029 0.0740 8.0 96.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 3.0 42.0 99.0 270 4.25 0.0021 0.0530 1.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.339 SILT 500 5.00 0.0014 0.0310 0.0 1.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.110 3.184 Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 MEAN 0.120 3.128 Upper Very Fine Sand 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.542 Moderately Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.182 -0.211 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.270 0.990 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 P ; t �- __- .._,�,. � 1.00 _ 0.10 0.01 Particle Diameter (mm) t 100 80 n c 60 3 m m 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 1 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.241 0.009 2.056 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.181 0.007 2.466 20 0.25 0.0335 0.8500 0.0 0.0 16 0.170 0.007 2.556 25 0.50 0.0280 0.7100 0.0 0.0 25 0.150 0.006 2.737 30 0.75 0.0236 0.6000 0.0 0.0 50 0.110 0.004 3.184 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.090 0.004 3.474 40 1.25 0.0165 0.4200 0.0 0.0 84 0.080 0.003 3.644 45 1.50 0.0138 0.3500 0.0 0.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 2.0 2.0 95 0.070 0.003 3.837 SAND 60 2.00 0.0098 0.2500 4.0 6.0 6.0 70 2.25 0.0083 0.2100 7.0 13.0 80 2.50 0.0070 0.1770 15.0 28.0 FINE 100 2.75 0.0058 0.1490 12.0 40.0 STD DEVIATION (mm): 0.049 SAND 120 3.00 0.0049 0.1250 17.0 51.0 57.0 140 3.25 0.0041 0.1050 22.0 79.0 170 3.50 0.0035 0.0880 9.0 88.0 VFINE 200 3.75 0.0029 0.0740 8.0 96.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 3.0 42.0 99.0 270 4.25 0.0021 0.0530 1.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.339 SILT 500 5.00 0.0014 0.0310 0.0 1.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.110 3.184 Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 MEAN 0.120 3.128 Upper Very Fine Sand 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.542 Moderately Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.182 -0.211 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.270 0.990 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well Depth (ft): 7825 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 a 15 U C O d 10 LL 5 0 10.00 1.00_ o.lo 0.01 Particle Diameter (mm) 1 100 80 n r - 60 3 U.. ,40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION N SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 Mill 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 MEN 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.191 0.008 2.388 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.170 0.150 0.007 0.006 2.556 2.737 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.140 0.006 10.00 1.00_ o.lo 0.01 Particle Diameter (mm) 1 100 80 n r - 60 3 U.. ,40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.191 0.008 2.388 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.170 0.150 0.007 0.006 2.556 2.737 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.140 0.006 2.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.110 0.004 3.184 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.090 0.080 0.004 0.003 3.474 3.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.080 0.003 3.644 MED 50 1.75 0.0117 0.2970 1.0 2.0 95 0.080 0.003 3.644 SAND 60 2.00 0.0098 0.2500 2.0 4.0 4.0 70 2.25 0.0083 0.2100 4.0 8.0 80 2.50 0.0070 0.1770 13.0 21.0 FINE 100 2.75 0.0058 0.1490 16.0 37.0 STD DEVIATION (mm) : 0.043 SAND 120 3.00 0.0049 0.1250 20.0 53.0 57.0 140 3.25 0.0041 0.1050 26.0 83.0 170 3.50 0.0035 0.0880 14.0 97.0 VFINE 200 3.75 0.0029 0.0740 2.0 99.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 1.0 43.0 100.0 270 4.25 0.0021 0.0530 0.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.547 SILT 500 5.00 0.0014 0.0310 0.0 0.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.110 0.115 3.184 3.188 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.417 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.091 -0.127 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.278 0.807 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well A4.A'4 Depth (ft): 7837 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 T 15 v c s d 10 lL 5 0 SOME GRAIN SIZE DISTRIBUTION I rrA N SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 Mill 0 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches Milill 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 I 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.160 0.006 2.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.150 0.130 0.006 0.005 2.737 2.943 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 Ell 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.078 0.070 0.003 0.003 3.690 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.060 0.002 4.059 VIED 50 1.75 0.0117 0.2970 0.0 1.0 95 0.060 0.002 4.071 SAND 60 2.00 0.0098 0.2500 1.0 2.0 2.0 70 2.25 0.0083 0.2100 2.0 4.0 80 2.50 0.0070 0.1770 9.0 13.0 FINE 100 2.75 0.0058 0.1490 5.0 18.0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 n e0 3 m m -40 u 20 �0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.160 0.006 2.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.150 0.130 0.006 0.005 2.737 2.943 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 50 0.090 0.004 3.474 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.078 0.070 0.003 0.003 3.690 3.837 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.060 0.002 4.059 VIED 50 1.75 0.0117 0.2970 0.0 1.0 95 0.060 0.002 4.071 SAND 60 2.00 0.0098 0.2500 1.0 2.0 2.0 70 2.25 0.0083 0.2100 2.0 4.0 80 2.50 0.0070 0.1770 9.0 13.0 FINE 100 2.75 0.0058 0.1490 5.0 18.0 STD DEVIATION (mm) : 0.040 SAND 120 3.00 0.0049 0.1250 17.0 33.0 35.0 140 3.25 0.0041 0.1050 25.0 60.0 170 3.50 0.0035 0.0880 15.0 75.0 VFINE 200 3.75 0.0029 0.0740 14.0 89.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 6.0 60.0 95.0 270 4.25 0.0021 0.0530 5.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.648 SILT 500 5.00 0.0014 0.0310 0.0 5.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 IVIED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK• FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.090 0.094 3.474 3.418 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.440 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.083 -0.180 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.181 1.158 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 - 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Cnre Lab RESERVOIR OPTIMIZATION zs - 20 0 �, 15 v c c d to LL Total Caribou 26 -11 No. 1 Well Depth (ft): 7848 THIN SECTION GRAIN SIZE ANALYSIS 10.00 .. �. _ _ y .. 1.00 0.10 0.01 Particle Diameter (mm) 5 0 1 100 80 0 60 3 m m -40 c 20 �0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS 1 0 MESH all INCH MM SEP SEP CUM 5 -2.00 I 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.231 0.009 2.114 VCRS SD 18 0.00 w 1.0000 0.0 0.0 0.0 10 16 0.200 0.190 0.008 0.007 2.322 2.396 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.160 0.006 2.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.115 0.005 3.120 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.090 0.080 0.004 0.003 3.474 3.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.080 0.003 3.644 MED 50 1.75 0.0117 0.2970 3.0 4.0 95 0.070 0.003 3.837 SAND 60 2.00 0.0098 0.2500 4.0 8.0 8.0 70 2.25 0.0083 0.2100 12.0 20.0 80 2.50 0.0070 0.1770 11.0 31.0 FINE 100 2.75 0.0058 0.1490 13.0 44.0 STD DEVIATION (mm) : 0.054 SAND 120 3.00 0.0049 0.1250 20.0 56.0 64.0 140 3.25 0.0041 0.1050 19.0 83.0 170 3.50 0.0035 0.0880 8.0 91.0 VFINE 200 3.75 0.0029 0.0740 5.0 96.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 3.0 35.0 99.0 270 4.25 0.0021 0.0530 1.0 100.0 325 4.50 0.0017 0.0440 10.00 .. �. _ _ y .. 1.00 0.10 0.01 Particle Diameter (mm) 5 0 1 100 80 0 60 3 m m -40 c 20 �0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.231 0.009 2.114 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.200 0.190 0.008 0.007 2.322 2.396 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.160 0.006 2.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.115 0.005 3.120 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.090 0.080 0.004 0.003 3.474 3.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.080 0.003 3.644 MED 50 1.75 0.0117 0.2970 3.0 4.0 95 0.070 0.003 3.837 SAND 60 2.00 0.0098 0.2500 4.0 8.0 8.0 70 2.25 0.0083 0.2100 12.0 20.0 80 2.50 0.0070 0.1770 11.0 31.0 FINE 100 2.75 0.0058 0.1490 13.0 44.0 STD DEVIATION (mm) : 0.054 SAND 120 3.00 0.0049 0.1250 20.0 56.0 64.0 140 3.25 0.0041 0.1050 19.0 83.0 170 3.50 0.0035 0.0880 8.0 91.0 VFINE 200 3.75 0.0029 0.0740 5.0 96.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 3.0 35.0 99.0 270 4.25 0.0021 0.0530 1.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.220 SILT 500 5.00 0.0014 0.0310 0.0 1.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.115 0.125 3.120 3.053 Upper Very Fine Sand Lower Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.573 Moderately Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.174 -0.221 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.292 0.850 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 ' COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 � Core Lab AESERV91K NPTINnATINN 25 20 0 T 15 U C rT d 10 LL Total Caribou 26 -11 No. 1 Well Depth (ft): 7859 THIN SECTION GRAIN SIZE ANALYSIS NEI I in 110111111 Ism 10.00 1.00 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 3 m 40- 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.080 0.003 3.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.070 0.070 0.003 0.003 3.837 3.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.060 0.002 4.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.050 0.002 4.322 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.040 0.040 0.002 0.002 4.644 4.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.030 0.001 5.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.014 SAND 120 3.00 0.0049 0.1250 0.0 0.0 0.0 140 3.25 0.0041 0.1050 3.0 3.0 170 3.50 0.0035 0.0880 4.0 7.0 VFINE 200 3.75 0.0029 0.0740 11.0 18.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 23.0 41.0 41.0 270 4.25 0.0021 0.0530 30.0 71.0 325 4.50 0.0017 0.0440 20.0 91.0 CRS 400 4.75 0.0015 0.0370 0.0 91.0 STD DEVIATION (phi) : 6.146 SILT 500 5.00 0.0014 0.0310 9.0 59.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.050 0.050 4.322 4.267 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.416 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 -0.227 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.333 0.991 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well btsmoift Depth (ft): 7884 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 T 15 v c a 2 to LL 5 0 10.00 M ,.. T - w 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 r - 60 3 m m 40 c -20 0 0.00 GRAIN SIZE DISTRIBUTION Ell Milit SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.201 0.008 2.318 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.181 0.160 0.007 0.006 2.466 2.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.140 0.006 2.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.110 0.004 3.184 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.090 0.080 0.004 0.003 3.474 3.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 0.0 1.0 95 0.070 0.003 3.837 SAND 60 2.00 0.0098 0.2500 2.0 3.0 3.0 70 2.25 0.0083 0.2100 9.0 12.0 80 2.50 0.0070 0.1770 12.0 24.0 FINE 100 2.75 0.0058 0.1490 13.0 E 37.0 STD DEVIATION (mm) : 0.046 SAND 120 3.00 0.0049 0.1250 16.0 10.00 M ,.. T - w 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 r - 60 3 m m 40 c -20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.201 0.008 2.318 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.181 0.160 0.007 0.006 2.466 2.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.140 0.006 2.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.110 0.004 3.184 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.090 0.080 0.004 0.003 3.474 3.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.070 0.003 3.837 MED 50 1.75 0.0117 0.2970 0.0 1.0 95 0.070 0.003 3.837 SAND 60 2.00 0.0098 0.2500 2.0 3.0 3.0 70 2.25 0.0083 0.2100 9.0 12.0 80 2.50 0.0070 0.1770 12.0 24.0 FINE 100 2.75 0.0058 0.1490 13.0 37.0 STD DEVIATION (mm) : 0.046 SAND 120 3.00 0.0049 0.1250 16.0 50.0 53.0 140 3.25 0.0041 0.1050 25.0 78.0 170 3.50 0.0035 0.0880 11.0 89.0 VFINE 200 3.75 0.0029 0.0740 9.0 98.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 2.0 47.0 100.0 270 4.25 0.0021 0.0530 0.0 100.0 325 4.50 0.0017 0.0440 0.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.453 SILT 500 5.00 0.0014 0.0310 0.0 0.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.110 0.115 3.184 3.157 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.480 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.091 -0.111 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.225 0.976 Mesokudc 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Core Lab RESERVOIR OPTIMIZATION 25 - 20 - T15- to Total Caribou 26 -11 No. 1 Well Depth (ft): 8950 THIN SECTION GRAIN SIZE ANALYSIS 10.00 1.00 uT A. .•• 0.10 0.01 Particle Diameter (mm) 5 0 4 100 80 n -60 3 40 u -20 _+ 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 E 0.0 IN 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 MEN 2.0000 0.0 0.0 111111 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.120 0.005 3.059 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.100 0.090 0.004 0.004 3.322 3.474 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.083 0.003 3.599 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.060 0.050 0.002 0.002 4.059 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 10.00 1.00 uT A. .•• 0.10 0.01 Particle Diameter (mm) 5 0 4 100 80 n -60 3 40 u -20 _+ 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.120 0.005 3.059 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.100 0.090 0.004 0.004 3.322 3.474 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.083 0.003 3.599 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.060 0.050 0.002 0.002 4.059 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.050 0.002 4.322 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.336 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 3.0 3.0 80 2.50 0.0070 0.1770 1.0 4.0 FINE 100 2.75 0.0058 0.1490 0.0 4.0 STD DEVIATION (mm) : 0.030 SAND 120 3.00 0.0049 0.1250 4.0 8.0 8.0 140 3.25 0.0041 0.1050 17.0 25.0 170 3.50 0.0035 0.0880 10.0 35.0 VFINE 200 3.75 0.0029 0.0740 14.0 49.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 29.0 70.0 78.0 270 4.25 0.0021 0.0530 17.0 95.0 325 4.50 0.0017 0.0440 5.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.072 SILT 500 5.00 0.0014 0.0310 0.0 22.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.060 0.071 4.059 3.952 Coarse Silt Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.406 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.375 -0.478 Very Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.225 1.140 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well A,, Depth (ft): 8999 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 j 15 U C d 7 Q d 10 LL 5 0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 60 n 60 3 E A 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS 9 MESH PHI INCH MM SEP SEP f; 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.101 0.004 3.315 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.090 16 0.080 0.004 0.003 3.474 3.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 Mill 0.0 25 0.070 0.003 3.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.050 84 0.050 0.002 0.002 4.322 4.322 40 1.25 0.0165 0.4200 0.0 0.0 IN 1.50 0.0138 0.3500 0.0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 60 n 60 3 E A 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.101 0.004 3.315 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.090 16 0.080 0.004 0.003 3.474 3.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.070 0.003 3.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.050 84 0.050 0.002 0.002 4.322 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.049 0.002 4.351 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.644 SAND 60 2.00 0.0098 0.2500 0.0 010 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 1.0 1.0 FINE 100 2.75 0.0058 0.1490 1.0 2.0 STD DEVIATION (mm) : 0.020 SAND 120 3.00 0.0049 0.1250 3.0 5.0 5.0 140 3.25 0.0041 0.1050 10.0 15.0 170 3.50 0.0035 0.0880 9.0 24.0 VFINE 200 3.75 0.0029 0.0740 24.0 48.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 23.0 66.0 71.0 270 4.25 0.0021 0.0530 19.0 90.0 325 4.50 0.0017 0.0440 9.0 99.0 CRS 400 4.75 0.0015 0.0370 0.0 99.0 STD DEVIATION (phi) : 5.616 SILT 500 5.00 0.0014 0.0310 1.0 29.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN X0 60 MEAN CO- 4.059 4.008 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 :060 SORTING 79 0.371 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 -0.282 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.244 1.122 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 ' COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 - COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 , Core Lab RESERVOIR OPTIMIZATION 25 20 0 T 15 v c o� 2 10 LL Total Caribou 26 -11 No. 1 Well Depth (ft): 9009 THIN SECTION GRAIN SIZE ANALYSIS 10.00 r ` 1.00 i N. m 0.10 0.01 Particle Diameter (mm) 5 0 4 100 80 n -6o 3 E CD 40 u .20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.110 0.004 3.184 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.100 16 0.100 0.004 0.004 3.322 3.322 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.090 0.004 3.474 30 0.75 0.0236 0.6000 0.0 0.0 50 0.070 0.003 3.837 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.060 84 0.060 0.002 0.002 4.059 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.059 0.002 4.083 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 1.0 1.0 FINE 100 2.75 0.0058 0.1490 0.0 1.0 STD DEVIATION (mm): 0.020 SAND 120 3.00 0.0049 0.1250 5.0 6.0 6.0 140 3.25 0.0041 0.1050 25.0 31.0 170 3.50 0.0035 0.0880 18.0 49.0 VFINE 200 3.75 0.0029 0.0740 20.0 69.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 21.0 84.0 90.0 270 4.25 0.0021 0.0530 9.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.636 SILT 500 5.00 0.0014 0.0310 0.0 10.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.070 MEAN -0.075-- 3.837 3.739 Lower Very Fine Sand Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.357 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.143 -0.376 Very Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.366 0.797 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 ' COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 i Core Lab RESERVOIR OPTIMIZATION 25 20 0 ,, 1s v c a 10 LL Total Caribou 26 -11 No. 1 Well Depth (ft): 9010 THIN SECTION GRAIN SIZE ANALYSIS 10.00 1.00 0.10 0.01 Particle Diameter (mm) s 0 100 80 n 60 3 m 40 u -20 L0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.110 0.004 3.184 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.090 16 0.090 0.004 0.004 3.474 3.474 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.080 0.003 3.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.050 84 0.050 0.002 0.002 4.322 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.050 0.002 4.322 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.644 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 1.0 1.0 FINE 100 2.75 0.0058 0.1490 2.0 3.0 STD DEVIATION (mm) : 0.022 SAND 120 3.00 0.0049 0.1250 3.0 5.9 5.9 140 3.25 0.0041 0.1050 10.9 16.8 170 3.50 0.0035 0.0880 10.9 27.7 VFINE 200 3.75 0.0029 0.0740 19.8 47.5 STD DEVIATION (inches): 0.001 SAND 230 4.00 0.0024 0.0620 24.8 66.3 72.3 270 4.25 0.0021 0.0530 17.8 90.1 325 4.50 0.0017 0.0440 6.9 97.0 CRS 400 4.75 0.0015 0.0370 0.0 97.0 STD DEVIATION (phi) : 5.507 SILT 500 5.00 0.0014 0.0310 3.0 27.7 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK- DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0. MEAN < 0.065 4.059 3.952 Coarse Silt Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.433 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.167 -0.399 Very Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.375 0.882 Platykunic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 4 Core Lab AESENYOIB OPTIMIZATION 25- 20 0 T 15 tr 2 to LL Total Caribou 26 -11 No. 1 Well Depth (ft): 9023 THIN SECTION GRAIN SIZE ANALYSIS 10.00 f 1.00 .. 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 m 40 a 20 0 0.00 GRAIN SIZE DISTRIBUTION or SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 Ell 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 Minn inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 III 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.282 0.011 1.829 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.211 16 0.200 0.008 0.008 2.245 2.322 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.160 0.006 2.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.105 0.004 3.252 CRS SD 35 1.00 0.0197 0.5000 1.0 1.0 1.0 75 0.080 84 0.060 EI 3.644 4.059 40 1.25 0.0165 0.4200 1.0 2.0 45 1.50 0.0138 0.3500 3.0 5.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 -0.2970 2.0 7.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 3.0 9.0 10.0 70 2.25 0.0083 0.2100 10.0 20.0 80 2.50 0.0070 0.1770 7.0 27.0 FINE 100 2.75 0.0058 0.1490 14.0 41.0 STD DEVIATION (mm) : 0.080 SAND 120 3.00 0.0049 0.1250 9.0 40.0 50.0 140 3.25 0.0041 0.1050 18.0 68.0 170 3.50 0.0035 0.0880 8.0 76.0 VFINE 200 3.75 0.0029 0.0740 7.0 83.0 STD DEVIATION (inches) : 0.003 SAND 230 4.00 0.0024 0.0620 13.0 46.0 96.0 270 4.25 0.0021 0.0530 3.0 99.0 325 4.50 10.00 f 1.00 .. 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 m 40 a 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 Minn inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.282 0.011 1.829 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.211 16 0.200 0.008 0.008 2.245 2.322 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.160 0.006 2.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.105 0.004 3.252 CRS SD 35 1.00 0.0197 0.5000 1.0 1.0 1.0 75 0.080 84 0.060 0.003 0.002 3.644 4.059 40 1.25 0.0165 0.4200 1.0 2.0 45 1.50 0.0138 0.3500 3.0 5.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 -0.2970 2.0 7.0 95 0.060 0.002 4.059 SAND 60 2.00 0.0098 0.2500 3.0 9.0 10.0 70 2.25 0.0083 0.2100 10.0 20.0 80 2.50 0.0070 0.1770 7.0 27.0 FINE 100 2.75 0.0058 0.1490 14.0 41.0 STD DEVIATION (mm) : 0.080 SAND 120 3.00 0.0049 0.1250 9.0 40.0 50.0 140 3.25 0.0041 0.1050 18.0 68.0 170 3.50 0.0035 0.0880 8.0 76.0 VFINE 200 3.75 0.0029 0.0740 7.0 83.0 STD DEVIATION (inches) : 0.003 SAND 230 4.00 0.0024 0.0620 13.0 46.0 96.0 270 4.25 0.0021 0.0530 3.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 3.643 SILT 500 5.00 0.0014 0.0310 0.0 4.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.022 0 0.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.105 MEAN 0�0 3.252 3.211 Upper Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.772 Moderate VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.286 -0.173 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.265 0.914 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well h4wAmla Depth (ft): 9024 Core Lab RESERVOIR OPTINIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 0 15 U C 7 Cr d 10 IL 5 0 1000 1.00_ �..� 0.10 0.01 Particle Diameter (mm) 100 80 0 60 3 m N 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3600 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.221 0.009 2.178 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.170 0.130 0.007 0.005 2.556 2.943 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 I 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 2.0 3.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 3.0 6.0 6.0 70 2.25 0.0083 0.2100 2.0 8.0 80 2.50 0.0070 0.1770 5.0 13.0 1000 1.00_ �..� 0.10 0.01 Particle Diameter (mm) 100 80 0 60 3 m N 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3600 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.221 0.009 2.178 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.170 0.130 0.007 0.005 2.556 2.943 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.110 0.004 3.184 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 1.0 1.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 2.0 3.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 3.0 6.0 6.0 70 2.25 0.0083 0.2100 2.0 8.0 80 2.50 0.0070 0.1770 5.0 13.0 FINE 100 2.75 0.0058 0.1490 4.0 17.0 STD DEVIATION (mm) : 0.052 SAND 120 3.00 0.0049 0.1250 9.0 20.0 26.0 140 3.25 0.0041 0.1050 16.0 42.0 170 3.50 0.0035 0.0880 21.0 63.0 VFINE 200 3.75 0.0029 0.0740 19.0 82.0 STD DEVIATION (inches) : 0.002 SAND 230 4.00 0.0024 0.0620 12.0 68.0 94.0 270 4.25 0.0021 0.0530 5.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.263 SILT 500 5.00 0.0014 0.0310 0.0 6.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK' FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.08 _0.090 _' 3.644 3.549 Lower Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.604 Moderately Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.250 -0.373 Very Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.182 1.348 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 A =SA Core Lab RESERVOIR OPTIMIZATION 25 20 j 15 v c P 10 IL Total Caribou 26 -11 No. 1 Well Depth (ft): 9025 THIN SECTION GRAIN SIZE ANALYSIS 10.00 �. 1.00 N m 0.10 0.01 Particle Diameter (mm) i 5 0 '100 60 0 60 3 iu 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 11 8 -1.25 Ell 2.3800 0.0 0.0 I GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 1110111111 0.0 1 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.201 0.008 2.318 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.160 0.140 0.006 0.006 2.644 2.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.120 0.005 3.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 1.0 1.0 45 1.50 0.0138 0.3500 0.0 1.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 1.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 3.0 4.0 4.0 70 2.25 0.0083 0.2100 4.0 8.0 80 2.50 0.0070 0.1770 5.0 13.0 FINE 100 2.75 0.0058 0.1490 8.0 21.0 STD DEVIATION (mm) : 0.051 SAND 120 3.00 0.0049 0.1250 7.0 24.0 28.0 140 3.25 0.0041 0.1050 13.0 41.0 170 3.50 0.0035 0.0880 15.0 56.0 VFINE 200 3.75 0.0029 0.0740 22.0 78.0 10.00 �. 1.00 N m 0.10 0.01 Particle Diameter (mm) i 5 0 '100 60 0 60 3 iu 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.201 0.008 2.318 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.160 0.140 0.006 0.006 2.644 2.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.120 0.005 3.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.080 0.003 3.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.070 0.060 0.003 0.002 3.837 4.059 40 1.25 0.0165 0.4200 1.0 1.0 45 1.50 0.0138 0.3500 0.0 1.0 90 0.060 0.002 4.059 MED 50 1.75 0.0117 0.2970 0.0 1.0 95 0.050 0.002 4.322 SAND 60 2.00 0.0098 0.2500 3.0 4.0 4.0 70 2.25 0.0083 0.2100 4.0 8.0 80 2.50 0.0070 0.1770 5.0 13.0 FINE 100 2.75 0.0058 0.1490 8.0 21.0 STD DEVIATION (mm) : 0.051 SAND 120 3.00 0.0049 0.1250 7.0 24.0 28.0 140 3.25 0.0041 0.1050 13.0 41.0 170 3.50 0.0035 0.0880 15.0 56.0 VFINE 200 3.75 0.0029 0.0740 22.0 78.0 STD DEVIATION (inches): 0.002 SAND 230 4.00 0.0024 0.0620 15.0 65.0 93.0 270 4.25 0.0021 0.0530 6.0 99.0 325 4.50 0.0017 0.0440 1.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 4.288 SILT 500 5.00 0.0014 0.0310 0.0 7.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.08Q 0.095 3.644 3.513 Lower Very Fine Sand Upper Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.609 Moderately Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.375 -0.388 Very Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.250 1.056 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 - COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well bra. Depth (ft): 9026 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 - 20- T 15 v c c d to LL 5 0 10.00 � - - 1.00 Y - 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 c iu 40 0 -20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS M ill MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 ME 0.0 0.0 I I 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.080 0.003 3.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.071 16 0.070 0.003 0.003 3.816 3.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 10.00 � - - 1.00 Y - 0.10 0.01 Particle Diameter (mm) 100 80 n 60 3 c iu 40 0 -20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.080 0.003 3.644 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.071 16 0.070 0.003 0.003 3.816 3.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.070 0.003 3.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.050 84 0.040 0.002 0.002 4.322 4.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.644 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.014 SAND 120 3.00 0.0049 0.1250 0.0 0.0 0.0 140 3.25 0.0041 0.1050 4.0 4.0 170 3.50 0.0035 0.0880 6.0 10.0 VFINE 200 3.75 0.0029 0.0740 18.0 28.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 26.0 54.0 54.0 270 4.25 0.0021 0.0530 26.0 80.0 325 4.50 0.0017 0.0440 20.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 6.190 SILT 500 5.00 0.0014 0.0310 0.0 46.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK• FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 060 MEAN ' 0� 060 ^ � 4.059 4.180 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.353 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 0.310 Very Positively Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.323 0.844 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 ' COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 A Care Lati RESERVOIR OPTIMIZATION Total Caribou 26 -11 No. 1 Well Depth (ft): 9045 THIN SECTION GRAIN SIZE ANALYSIS 25 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 too 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 2 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 so 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.071 ■ 3.826 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.070 16 0.060 0.003 0.002 3.837 4.059 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.060 0.002 4.059 y : 0.75 0.0236 0.6000 0.0 0.0 s0 0.050 0.002 4.322 CRS SD 35 1.00 0.0197 0.5000 15 0.0 0.0 75 0.050 84 0.040 0.002 0.002 4.322 4.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 ■ • 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 60 0.002 4.662 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 d 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.012 SAND 120 3.00 ■ 0.1250 0.0 0.0 0.0 140 3.25 0.0041 0.1050 1.0 1.0 170 3.50 0.0035 0.0880 4.0 C d 10 5.0 VFINE 3.75 0.0029 0.0740 9.0 ■ ■ - SAND 230 4.00 0.0024 0.0620 27.0 41.0 41.0 ao 0 LL 325 4.50 0.0017 0.0440 18.0 95.0 • • 4.75 0.0015 0.0370 0.0 95.0 STD DEVIATION (phi) : 6.383 SILT 500 5.00 0.0014 5 5.0 59.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 ■ ■ ■ 100.0 3 MED 5.75 0.0007 0.0190 0.0 20 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 5P 0.0 0.0 100.0 MEDIAN 0 50 MEAN 0.055: 4.322 4.342 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.273 Very Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.200 -0.054 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.167 0 0 10.00 1.00 0.10 0.01 0.00 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.071 0.003 3.826 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.070 16 0.060 0.003 0.002 3.837 4.059 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.060 0.002 4.059 30 0.75 0.0236 0.6000 0.0 0.0 s0 0.050 0.002 4.322 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.050 84 0.040 0.002 0.002 4.322 4.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.662 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.012 SAND 120 3.00 0.0049 0.1250 0.0 0.0 0.0 140 3.25 0.0041 0.1050 1.0 1.0 170 3.50 0.0035 0.0880 4.0 5.0 VFINE 200 3.75 0.0029 0.0740 9.0 14.0 STD DEVIATION (inches) : 0.000 SAND 230 4.00 0.0024 0.0620 27.0 41.0 41.0 270 4.25 0.0021 0.0530 36.0 77.0 325 4.50 0.0017 0.0440 18.0 95.0 CRS 400 4.75 0.0015 0.0370 0.0 95.0 STD DEVIATION (phi) : 6.383 SILT 500 5.00 0.0014 0.0310 5.0 59.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK" DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0 50 MEAN 0.055: 4.322 4.342 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.273 Very Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.200 -0.054 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.167 1.302 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well �64.A'4 Depth (ft): 9053 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 15 c a 2 10 LL 5 0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 c 60 c m c m 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP - 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 I - 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.090 0.004 3.474 VCRs SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.080 16 0.080 0.003 0.003 3.644 3.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.070 0.003 3.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.060 84 0.050 0.002 0.002 4.059 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.050 0.002 4.322 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.336 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.015 SAND 120 3.00 0.0049 0.1250 2.0 2.0 2.0 140 3.25 0.0041 0.1050 6.0 8.0 170 3.50 0.0035 0.0880 12.0 20.0 VFINE 200 3.75 0.0029 0.0740 21.0 41.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 38.0 77.0 79.0 270 4.25 0.0021 0.0530 16.0 95.0 325 4.50 0.0017 0.0440 4.0 99.0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 c 60 c m c m 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.090 0.004 3.474 VCRs SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.080 16 0.080 0.003 0.003 3.644 3.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.070 0.003 3.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.060 84 0.050 0.002 0.002 4.059 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.050 0.002 4.322 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.050 0.002 4.336 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.015 SAND 120 3.00 0.0049 0.1250 2.0 2.0 2.0 140 3.25 0.0041 0.1050 6.0 8.0 170 3.50 0.0035 0.0880 12.0 20.0 VFINE 200 3.75 0.0029 0.0740 21.0 41.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 38.0 77.0 79.0 270 4.25 0.0021 0.0530 16.0 95.0 325 4.50 0.0017 0.0440 4.0 99.0 CRS 400 4.75 0.0015 0.0370 0.0 99.0 STD DEVIATION (phi) : 6.105 SILT 500 5.00 0.0014 0.0310 1.0 21.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.060 MEAN _ O 5__- 4.059 4.008 Coarse Silt Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.300 Very Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.167 -0.299 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.167 1.589 Very Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 `COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 - COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well 'A Depth (ft): 9061 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 0 15 V c d 3 [T d 10 LL 5 0 10.00 1.00 •,� �• *• �• .�• .� •�• .� 0.70 0.01 Particle Diameter (mm) i 100 80 n 60 3 m m - 40 u -20 l 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL. 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.091 0.004 3.466 VCRS SO 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.090 0.080 0.004 0.003 3.474 3.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.070 0.003 3.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.050 0.050 0.002 0.002 4.322 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.050 0.002 4.322 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 SEE 4.644 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm): 0.016 SAND 120 10.00 1.00 •,� �• *• �• .�• .� •�• .� 0.70 0.01 Particle Diameter (mm) i 100 80 n 60 3 m m - 40 u -20 l 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL. 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.091 0.004 3.466 VCRS SO 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.090 0.080 0.004 0.003 3.474 3.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.070 0.003 3.837 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.050 0.050 0.002 0.002 4.322 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.050 0.002 4.322 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.644 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm): 0.016 SAND 120 3.00 0.0049 0.1250 2.0 2.0 2.0 140 3.25 0.0041 0.1050 11.0 13.0 170 3.50 0.0035 0.0880 11.0 24.0 VFINE 200 3.75 0.0029 0.0740 16.0 40.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 32.0 70.0 72.0 270 4.25 0.0021 0.0530 21.0 93.0 325 4.50 0.0017 0.0440 7.0 100.0 CRS 400 4.75 0.0015 0.0370 0.0 100.0 STD DEVIATION (phi) : 5.934 SILT 500 5.00 0.0014 0.0310 0.0 28.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN -, 0.06 60 4.059 4.008 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.348 Very Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 -0.252 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.250 0.994 Mesokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Core Lab RESERVOIR OPTIMIZATION 25 20 a T 1s v c c 10 LL Total Caribou 26 -11 No. 1 Well Depth (ft): 9068 THIN SECTION GRAIN SIZE ANALYSIS 10.00 w. m .. .. 1.00 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 3 U m 40 u -20 L0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.090 0.004 3.474 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.090 0.080 0.004 0.003 3.474 3.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.080 0.003 3.644 30 0.75 IN 0.6000 0.0 0.0 50 0.065 0.003 3.943 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.060 0.050 oil 4.059 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.050 0.002 10.00 w. m .. .. 1.00 0.10 0.01 Particle Diameter (mm) 5 0 100 80 n 60 3 U m 40 u -20 L0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.090 0.004 3.474 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 16 0.090 0.080 0.004 0.003 3.474 3.644 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.080 0.003 3.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.065 0.003 3.943 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 84 0.060 0.050 0.002 0.002 4.059 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.050 0.002 4.322 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.644 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 2.0 2.0 STD DEVIATION (mm) : 0.018 SAND 120 3.00 0.0049 0.1250 2.0 4.0 4.0 140 3.25 0.0041 0.1050 8.0 12.0 170 3.50 0.0035 0.0880 16.0 28.0 VFINE 200 3.75 0.0029 0.0740 22.0 50.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 29.0 75.0 79.0 270 4.25 0.0021 0.0530 14.0 93.0 325 4.50 0.0017 0.0440 6.0 99.0 CRS 400 4.75 0.0015 0.0370 0.0 99.0 STD DEVIATION (phi) : 5.813 SILT 500 5.00 0.0014 0.0310 1.0 21.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN MEAN 0.065 0.070 3.943 3.970 Lower Very Fine Sand Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.347 Very Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.154 0.019 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.250 1.155 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 - COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well Depth (ft): 9069 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 a T 15 v c c 2 10 IL 5 0 10.00 1.00 0. i 0 0.01 Particle Diameter (mm) 100 80 n 60 3 m m 40 e 20 0 0.00 GRAIN SIZE DISTRIBUTION I Iwo SORTING PARAMETERS i PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 INE1 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 in in 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.090 0.004 3.474 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.070 16 0.070 0.003 0.003 3.837 3.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.060 0.002 4.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.050 0.002 4.322 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 IIN 75 0.040 84 0.040 0.002 0.002 4.644 4.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.662 10.00 1.00 0. i 0 0.01 Particle Diameter (mm) 100 80 n 60 3 m m 40 e 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.090 0.004 3.474 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.070 16 0.070 0.003 0.003 3.837 3.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.060 0.002 4.059 30 0.75 0.0236 0.6000 0.0 0.0 50 0.050 0.002 4.322 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.040 84 0.040 0.002 0.002 4.644 4.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.662 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.016 SAND 120 3.00 0.0049 0.1250 1.0 1.0 1.0 140 3.25 0.0041 0.1050 7.0 8.0 170 3.50 0.0035 0.0880 1.0 9.0 VFINE 200 3.75 0.0029 0.0740 8.0 17.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 14.0 30.0 31.0 270 4.25 0.0021 0.0530 36.0 67.0 325 4.50 0.0017 0.0440 28.0 95.0 CRS 400 4.75 0.0015 0.0370 0.0 95.0 STD DEVIATION (phi) : 5.997 SILT 500 5.00 0.0014 0.0310 5.0 69.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK ** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.050 MEAN 56 - 4.322 4.267 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.382 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.000 -0.323 Very Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.333 0.832 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 **COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 "qtA Core Lab RESERVOIR OPTIMIZATION 25 20 0 15 a m 10 I.L. Total Caribou 26 -11 No. 1 Well Depth (ft): 9070 THIN SECTION GRAIN SIZE ANALYSIS 10.00 1.00 0.10 0.01 Particle Diameter (mm) 5- 0.' ,00 80 n 50 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION MESH PHI INCH MM SEP SEP CUM SORTING PARAMETERS 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.070 0.003 3.837 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.060 16 0.060 0.002 0.002 4.059 4.059 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.050 0.002 4.322 30 0.75 0.0236 0.6000 0.0 0.0 50 0.050 0.002 4.322 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.040 84 0.030 0.002 0.001 4.644 5.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.030 0.001 5.059 IVIED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.030 0.001 5.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm): 0.011 SAND 120 3.00 0.0049 0.1250 0.0 0.0 0.0 140 3.25 0.0041 0.1050 0.0 0.0 170 3.50 0.0035 0.0880 0.0 0.0 VFINE 200 3.75 0.0029 0.0740 7.0 7.0 STD DEVIATION (inches) : 0.000 SAND 230 4.00 0.0024 0.0620 15.0 22.0 22.0 270 4.25 0.0021 0.0530 29.0 51.0 325 4.50 0.0017 0.0440 32.0 83.0 CRS 400 4.75 0.0015 0.0370 0.0 83.0 STD DEVIATION (phi) : 6.451 SILT 500 5.00 0.0014 0.0310 17.0 78.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK- DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.050 MEAN 0.045 4.322 4.480 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.435 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 1.800 0.340 Very Positively Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.167 1.556 Very Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 *COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well A 4 w h'a Depth (ft): 9071 Care Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 �„ 15 v c a T 10 IL 5 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 so n 60 3 m 40 u 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 1 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches p 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.070 0.003 3.837 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.051 16 0.050 0.002 0.002 4.293 4.322 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.040 0.002 4.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.040 0.002 4.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.030 84 0.030 0.001 0.001 5.059 5.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.030 0.001 5.059 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.030 0.001 5.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm): 0.012 SAND 120 3.00 0.0049 0.1250 0.0 0.0 0.0 140 3.25 0.0041 0.1050 0.0 0.0 170 3.50 0.0035 0.0880 4.0 4.0 VFINE 200 3.75 0.0029 0.0740 2.0 6.0 STD DEVIATION (inches) : 0.000 SAND 230 4.00 0.0024 0.0620 4.0 10.0 10.0 270 4.25 0.0021 0.0530 12.0 22.0 325 4.50 0.0017 0.0440 37.0 59.0 CRS 400 4.75 0.0015 0.0370 0.0 59.0 STD DEVIATION (phi) : 6.339 SILT 500 5.00 0.0014 0.0310 41.0 90.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK* FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.040 MEAN 035 - 4.644 4.675 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.369 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 1.750 -0.097 Nearly Symmetrical SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.238 1.207 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 • COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well A40W Depth (ft): 9085 Care Lati RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 0 � 1 c w c d to LL 5 0 I flm I ME SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 ism 0.0 11 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.071 ism 3.826 VCRS SD 18 0.00 I 1.0000 0.0 0.0 0.0 10 0.070 16 0.070 0.003 0.003 3.837 3.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.063 0.002 4.000 30 0.75 0.0236 0.6000 0.0 0.0 50 0.050 0.002 4.322 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.040 84 0.040 0.002 0.002 4.644 4.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.662 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.015 SAND 120 3.00 0.0049 0.1250 1.0 1.0 1.0 140 3.25 0.0041 0.1050 3.0 4.0 170 3.50 0.0035 0.0880 1.0 5.0 VFINE 200 3.75 0.0029 0.0740 20.0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 -80 n 60 3 m m 40 0 20 ,0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.071 0.003 3.826 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.070 16 0.070 0.003 0.003 3.837 3.837 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.063 0.002 4.000 30 0.75 0.0236 0.6000 0.0 0.0 50 0.050 0.002 4.322 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.040 84 0.040 0.002 0.002 4.644 4.644 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.662 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.015 SAND 120 3.00 0.0049 0.1250 1.0 1.0 1.0 140 3.25 0.0041 0.1050 3.0 4.0 170 3.50 0.0035 0.0880 1.0 5.0 VFINE 200 3.75 0.0029 0.0740 20.0 25.0 STD DEVIATION (inches): 0.001 SAND 230 4.00 0.0024 0.0620 22.0 46.0 47.0 270 4.25 0.0021 0.0530 22.0 69.0 325 4.50 0.0017 0.0440 26.0 95.0 CRS 400 4.75 0.0015 0.0370 0.0 95.0 STD DEVIATION (phi) : 6.045 SILT 500 5.00 0.0014 0.0310 5.0 53.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRASK` FOLK** DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.050 MEAN 0.051 4.322 4.267 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.328 Very Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.050 -0.205 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.375 0.532 Very Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well 4t.A4 Depth (ft): 9101 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 o ° T 15 v c v I.L. 10 5- 0 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 60 3 Iv 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION MESH PHI INCH MM SEP SEP CUM SORTING PARAMETERS 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.101 0.004 3.315 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.090 16 0.082 0.004 0.003 3.474 3.615 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.080 0.003 3.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.050 84 0.050 0.002 0.002 4.322 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 I SAND 60 2.00 0.0098 0.2500 1.0 1.0 1.0 70 2.25 0.0083 0.2100 0.0 1.0 �I 2.50 0.0070 0.1770 10.00 1.00 0.10 0.01 Particle Diameter (mm) 100 80 0 60 3 Iv 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION MESH PHI INCH MM SEP SEP CUM SORTING PARAMETERS 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.101 0.004 3.315 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.090 16 0.082 0.004 0.003 3.474 3.615 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.080 0.003 3.644 30 0.75 0.0236 0.6000 0.0 0.0 50 0.060 0.002 4.059 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.050 84 0.050 0.002 0.002 4.322 4.322 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.040 0.002 4.644 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.040 0.002 4.644 SAND 60 2.00 0.0098 0.2500 1.0 1.0 1.0 70 2.25 0.0083 0.2100 0.0 1.0 80 2.50 0.0070 0.1770 0.0 1.0 FINE 100 2.75 0.0058 0.1490 1.0 2.0 STD DEVIATION (mm) : 0.026 SAND 120 3.00 0.0049 0.1250 3.0 4.0 5.0 140 3.25 0.0041 0.1050 11.0 16.0 170 3.50 0.0035 0.0880 10.0 26.0 VFINE 200 3.75 0.0029 0.0740 20.0 46.0 STD DEVIATION (inches) : 0.001 SAND 230 4.00 0.0024 0.0620 23.0 64.0 69.0 270 4.25 0.0021 0.0530 18.0 87.0 325 4.50 0.0017 0.0440 10.0 97.0 CRS 400 4.75 0.0015 0.0370 0.0 97.0 STD DEVIATION (phi) : 5.255 SILT 500 5.00 0.0014 0.0310 3.0 31.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRAS FOLK DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.060 MEAN 0.065 4.059 3.999 Coarse Silt Lower Very Fine Sand 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.378 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.167 -0.188 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.300 0.803 Platykurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 Total Caribou 26 -11 No. 1 Well mtvmh Depth (ft): 9157 Core Lab RESERVOIR OPTIMIZATION THIN SECTION GRAIN SIZE ANALYSIS 25 20 T 15 v c 3 8 2 10 LL 5- 0 10.00 1.00 r � _ � 0.10 0.01 Particle Diameter (mm) 1 100 -80 n -60 3 c w N 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION i SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 I PERCENTILES: MEN GRAVEL 10 -1.00 10 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.071 0.003 3.826 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.060 16 0.050 0.002 0.002 4.059 4.322 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.050 0.002 4.322 30 0.75 0.0236 0.6000 0.0 0.0 50 0.040 0.002 4.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.038 84 0.030 0.001 0.001 4.737 5.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 10.00 1.00 r � _ � 0.10 0.01 Particle Diameter (mm) 1 100 -80 n -60 3 c w N 40 0 20 0 0.00 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.0000 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.0000 0.0 0.0 0.0 mm inches phi 12 -0.75 0.0661 1.6800 0.0 0.0 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.071 0.003 3.826 VCRS SD 18 0.00 0.0394 1.0000 0.0 0.0 0.0 10 0.060 16 0.050 0.002 0.002 4.059 4.322 20 0.25 0.0335 0.8500 0.0 0.0 25 0.50 0.0280 0.7100 0.0 0.0 25 0.050 0.002 4.322 30 0.75 0.0236 0.6000 0.0 0.0 50 0.040 0.002 4.644 CRS SD 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.038 84 0.030 0.001 0.001 4.737 5.059 40 1.25 0.0165 0.4200 0.0 0.0 45 1.50 0.0138 0.3500 0.0 0.0 90 0.030 0.001 5.059 IVIED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.030 0.001 5.059 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 STD DEVIATION (mm) : 0.015 SAND 120 3.00 0.0049 0.1250 1.0 1.0 1.0 140 3.25 0.0041 0.1050 2.0 3.0 170 3.50 0.0035 0.0880 2.0 5.0 VFINE 200 3.75 0.0029 0.0740 2.0 7.0 STD DEVIATION (inches): 0.001 SAND 230 4.00 0.0024 0.0620 7.0 13.0 14.0 270 4.25 0.0021 0.0530 17.0 31.0 325 4.50 0.0017 0.0440 44.0 75.0 CRS 400 4.75 0.0015 0.0370 0.0 75.0 STD DEVIATION (phi) : 6.083 SILT 500 5.00 0.0014 0.0310 25.0 86.0 100.0 5.25 0.0010 0.0260 0.0 100.0 5.50 0.0009 0.0220 0.0 100.0 MED 5.75 0.0007 0.0190 0.0 100.0 SILT 6.00 0.0006 0.0160 0.0 0.0 100.0 6.25 0.0005 0.0130 0.0 100.0 6.50 0.0004 0.0110 0.0 100.0 TRA FOLK DESCRIPTION FINE 6.75 0.0003 0.0093 0.0 100.0 SILT 7.00 0.0003 0.0078 0.0 0.0 100.0 MEDIAN 0.0 MEAN 0.044 ' 4.644 4.675 Coarse Silt Coarse Silt 7.25 0.0002 0.0065 0.0 100.0 7.50 0.0002 0.0055 0.0 100.0 SORTING 1.479 0.371 Well VFINE 7.75 0.0002 0.0046 0.0 100.0 SKEWNESS 2.188 -0.100 Negative Skewed SILT 8.00 0.0001 0.0039 0.0 0.0 100.0 KURTOSIS 0.208 1.217 Leptokurtic 8.25 0.0001 0.0033 0.0 100.0 8.50 0.0001 0.0028 0.0 100.0 8.75 0.0001 0.0023 0.0 100.0 9.00 0.0000 0.0019 0.0 100.0 9.25 0.0000 0.0016 0.0 100.0 COMPUTED USING MILLIMETER VALUES 9.50 0.0000 0.0014 0.0 100.0 "COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.0 100.0 CLAY 10.00 0.0000 0.0010 0.0 0.0 100.0 I THIN SECTION PETROGRAPHY Plate 2A Plate 213 ' Company: Total E & P USA. Inc. Depth (ft) 7250 Minor (1 -5 %) Well: Caribou 26 -11 No. 1 Sample No. 49 RESERVOIR OPTIMIZATION Location: Alaska Porosity ( %) 2.73 2.8 Interval: Base of Slope Middle Cretaceous Kair (md) 0.002 Plant fragments ' Glauconite Grain density (g /cc) 2.73 Plate 2A Plate 213 Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.085 Sorting well Detrital grains Quartz 21.2 ' Trace ( <1 %) Argillaceous rock frag Minor (1 -5 %) Volcanic rock frag Moderate (5 -10 %) Elim Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.085 Sorting well Detrital grains Quartz 21.2 Feldspar 8.0 Argillaceous rock frag 10.4 Volcanic rock frag 7.6 Plutonic /meta rock frag 4.8 Dolomite rock frag 6.8 Calcite rock frag 0.8 Chert 2.8 Mica 2.0 Heavy minerals 0.4 Plant fragments 0.8 Glauconite Skeletal fragments Cements Quartz overgrowths 0.4 Feldspar overgrowths Calcite 7.2 Fe- calcite 10.0 Dolomite 11.2 Fe- dolomite Siderite Authigenic clays 2.8 Organics Pyrite/Ti0 2.8 Clay Matrix Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 2A: Intergranular porosity has been reduced by compaction and carbonate cements. Many of the rock fragments are ductile and easily compacted. Plate 26: Argillaceous rock fragments (arrows) have been deformed by compaction. These rock fragments have been squeezed into adjacent pores (pseudomatrix) reducing pore volume. Note that most of the grain contacts are long edge or concavo- convex. Calcite, stained red, is a prominent cement. Plate 3A Plate 3B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) IL Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type silty shale Classification (Folk) NA Average grain size (mm) NA Sorting NA Detrital grains Quartz abundant Feldspar common Argillaceous rock frag Volcanic rock frag Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica minor Heavy minerals Plant fragments moderate Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite minor Fe- dolomite Siderite minor Authigenic clays Organics moderate Pyrite/Ti0 minor Clay Matrix abundant Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description 0 Plate 3A: This sample is mainly organic -rich silty shale with a few thin silty laminae (arrow). The fractures are not natural. The clay matrix may be locally replaced with siderite. Plate 313: The dark laminae are organics that are locally pyritized. Pyrite is also intermixed with the clay matrix. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7352 Well: Caribou 26 -11 No. 1 Sample No. 23 Location: Alaska Porosity ( %) 5.60 Interval: Base of Slope Middle Cretaceous Kair (md) 0.002 Grain density (g /cc) 233 Plate 3A Plate 3B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) IL Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type silty shale Classification (Folk) NA Average grain size (mm) NA Sorting NA Detrital grains Quartz abundant Feldspar common Argillaceous rock frag Volcanic rock frag Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica minor Heavy minerals Plant fragments moderate Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite minor Fe- dolomite Siderite minor Authigenic clays Organics moderate Pyrite/Ti0 minor Clay Matrix abundant Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description 0 Plate 3A: This sample is mainly organic -rich silty shale with a few thin silty laminae (arrow). The fractures are not natural. The clay matrix may be locally replaced with siderite. Plate 313: The dark laminae are organics that are locally pyritized. Pyrite is also intermixed with the clay matrix. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7475 Well: Caribou 26 -11 No. 1 Sample No. 22 Location: Alaska Porosity ( %) 8.30 Interval: Base of Slope Middle Cretaceous Kair (md) 0.040 Mica 2.0 Grain density (g /cc) 2.71 Plate 4A Plate 46 Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.100 Sorting well Detrital grains Quartz 16.8 Feldspar Trace ( <1 %) Argillaceous rock frag Minor (1 -5 %) Volcanic rock frag Moderate (5 -10 %) ' cam b RESERVOIR OPTIMIZATION Common (10 -20 %) Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.100 Sorting well Detrital grains Quartz 16.8 Feldspar 12.8 Argillaceous rock frag 9.6 Volcanic rock frag 4.4 Plutonic /meta rock frag 4.8 Dolomite rock frag 8.8 Calcite rock frag 3.6 Chert 3.6 Mica 2.0 Heavy minerals 0.8 Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 1.6 Feldspar overgrowths trace Calcite 6.8 Fe- calcite 4.4 Dolomite 7.6 Fe- dolomite Siderite Authigenic clays 6.0 Organics Pyrite/Ti0 3.2 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular 2.8 Secondary Moldic Petrographic description Plate 4A: The white grains are mainly quartz and plagioclase, and most the dark grains are rock fragments. Compaction and carbonate cements have greatly reduced intergranular pore volume. Plate 4131: Identified grains include quartz (Q), plagioclase feldspar (F), chert (Cht), as well as dolomite (DRF), calcite (CRF), argillaceous (ARF), and plutonic (PRF) rock fragments. The grains are extensively compacted. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7524 Well: Caribou 26 -11 No. 1 Sample No. 21 Location: Alaska Porosity ( %) 6.17 Interval: BOS Mid. Cret. Sand Sequence 20 - 21.5 Kair (md) 0.022 Grain density (g /cc) 2.75 Plate 5A Plate 5B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) COQ Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant (>20 %) Job number: 040187G Depositional texture Rock type shale / sandstone Classification (Folk) NA Average grain size (mm) NA Sorting NA Detrital grains Quartz abundant Feldspar moderate Argillaceous rock frag trace Volcanic rock frag trace Plutonic /meta rock frag Dolomite rock frag minor Calcite rock frag trace Chert minor Mica Heavy minerals Plant fragments moderate Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite minor Fe- calcite Dolomite moderate Fe- dolomite Siderite Authigenic clays Organics trace Pyrite/Ti0 minor Clay Matrix abundant Pore types Intergranular trace Secondary intragranular trace Secondary Moldic Petrographic description Plate 5A: This sample is mainly shale with thin, discontinuous sandy laminae (red arrows). These lithologies form fining- upward depositional units (blue arrow). Plate 513: The contact between shale and sandstone is irregular (dashed line). This suggests scouring as the sandstone was deposited. Plate 6A Plate 6B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Clore Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.105 Sorting well Detrital grains Quartz 26.8 Feldspar 8.4 Argillaceous rock frag 9.6 Volcanic rock frag 12.4 Plutonic /meta rock frag 6.4 Dolomite rock frag 6.0 Calcite rock frag 3.2 Chert 4.4 Mica 2.0 Heavy minerals Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 1.6 Feldspar overgrowths Calcite 2.4 Fe- calcite 3.2 Dolomite 3.6 Fe- dolomite Siderite trace Authigenic clays 4.0 Organics Pyrite/Ti0 2.8 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular 2.8 Secondary Moldic Petrographic description Plate 6A: Pores (blue) are mainly secondary and result from the partial dissolution of grains. These pores are not well interconnected, resulting in very low permeability. Plate 66: Pores are mainly secondary intragranular (2). Calcite (red) and dolomite (D) are identified as grains and as cements. Ferroan calcite (purple) is a cement. Grains include chert (Cht), quartz (Q), plagioclase (F), and rock fragments. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7547.0 Well: Caribou 26 -11 No. 1 Sample No. 20.0 Location: Alaska Porosity ( %) 4.60 Interval: BOS Mid. Cret. Sand Sequence 20 - 21.5 Kair (md) 0.003 Grain density (g /cc) 2.75 Plate 6A Plate 6B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Clore Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.105 Sorting well Detrital grains Quartz 26.8 Feldspar 8.4 Argillaceous rock frag 9.6 Volcanic rock frag 12.4 Plutonic /meta rock frag 6.4 Dolomite rock frag 6.0 Calcite rock frag 3.2 Chert 4.4 Mica 2.0 Heavy minerals Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 1.6 Feldspar overgrowths Calcite 2.4 Fe- calcite 3.2 Dolomite 3.6 Fe- dolomite Siderite trace Authigenic clays 4.0 Organics Pyrite/Ti0 2.8 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular 2.8 Secondary Moldic Petrographic description Plate 6A: Pores (blue) are mainly secondary and result from the partial dissolution of grains. These pores are not well interconnected, resulting in very low permeability. Plate 66: Pores are mainly secondary intragranular (2). Calcite (red) and dolomite (D) are identified as grains and as cements. Ferroan calcite (purple) is a cement. Grains include chert (Cht), quartz (Q), plagioclase (F), and rock fragments. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Well: Caribou 26 -11 No. 1 Location: Alaska Interval: BOS Mid. Cret. Sand Sequence 20 - 21.5 Plate 7A Plate 7B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) ICore Liao Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depth (ft) 7563 Sample No. 19 Porosity ( %) 8.68 Kair (md) 0.040 Grain density (g /cc) 2.71 Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.085 Sorting well Detrital grains Quartz 23.6 Feldspar 9.2 Argillaceous rock frag 9.6 Volcanic rock frag 9.6 Plutonic /meta rock frag 3.2 Dolomite rock frag 4.8 Calcite rock frag 3.2 Chert 3.2 Mica 2.0 Heavy minerals 0.4 Plant fragments 0.4 Glauconite 0.4 Skeletal fragments Cements Quartz overgrowths 2.4 Feldspar overgrowths Calcite 5.2 Fe- calcite 4.0 Dolomite 6.0 Fe- dolomite Siderite 0.4 Authigenic clays 4.8 Organics Pyrite/Ti0 3.2 Clay Matrix Pore types Intergranular 1.2 Secondary intragranular 3.2 Secondary Moldic Petrographic description Plate 7A: Grains are extensively compacted, resulting in limited intergranular pore volume, Most of the white grains are quartz and plagioclase and most of the dark grains are rock fragments. Plate 76: Most of the grain contacts are long edge or concavo- convex, the result of extensive compaction. The ductile grains have been deformed and squeezed into adjacent areas to form pseudomatrix. THIN SECTION PETROGRAPHY Company: Well: Location: Interval: Total E & P USA. Inc. Caribou 26 -11 No. 1 Alaska BOS Mid. Cret. Sand Sequence 20 - 21.5 Depth (ft) 7588 Sample No. 18.0 Porosity ( %) 10.44 Kair (md) 0.050 Grain density (g /cc) 2.71 Plate 8A Plate 8B Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.090 Sorting well Detrital grains Quartz 28.4 Feldspar Trace ( <1 %) Argillaceous rock frag Minor (1 -5 %) Volcanic rock frag Moderate (5 -10 %) RESERVOIR OPTIMIZATION Common (10 -20 %) Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.090 Sorting well Detrital grains Quartz 28.4 Feldspar 12.8 Argillaceous rock frag 12.0 Volcanic rock frag 10.8 Plutonic /meta rock frag 2.4 Dolomite rock frag 3.2 Calcite rock frag 2.4 Chert 0.8 Mica 2.4 Heavy minerals 0.4 Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 2.8 Feldspar overgrowths Calcite 5.2 Fe- calcite 2.8 Dolomite 6.4 Fe- dolomite Siderite 0.4 Authigenic clays 4.8 Organics Pyrite/Ti0 1.6 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular Secondary Moldic Petrographic description Plate 8A: Pore volume has been greatly reduced by compaction. The abundance of ductile rock fragments increases the effects of compaction. Plate 813: Calcite (red), ferroan calcite (purple), and dolomite (D) are the most common cements. Most of the white grains are quart and plagioclase and most of the dark grains are rock fragments. Note the deformed argillaceous rock fragments (arrows), dolomite rock fragments (DRF), and volcanic rock fragments (VRF). Plate 9A Plate 9B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type silty shale / sandstone Classification (Folk) NA Average grain size (mm) 0.086 Sorting poor Detrital grains Quartz abundant Feldspar common Argillaceous rock frag trace Volcanic rock frag trace Plutonic /meta rock frag Dolomite rock frag minor Calcite rock frag Chert trace Mica minor Heavy minerals trace Plant fragments minor Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite minor Fe- calcite Dolomite minor Fe- dolomite Siderite Authigenic clays Organics Pyrite/Ti0 minor Clay Matrix abundant Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description 0.086 Plate 9A: This sample is composed of silty shale and sandstone laminae. Sharp contacts separate the different lithologies. Plate 913: The sandstone is extensively compacted, with long edge and concavo- convex grain boundaries recognized. Pores are rare. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7613 Well: Caribou 26 -11 No. 1 Sample No. 16 Location: Alaska Porosity ( %) 8.42 Interval: BOS Mid. Cret. Sand Sequence 20 - 21.5 Kair (md) 0.146 Grain density (g/cc) 2.73 Plate 9A Plate 9B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type silty shale / sandstone Classification (Folk) NA Average grain size (mm) 0.086 Sorting poor Detrital grains Quartz abundant Feldspar common Argillaceous rock frag trace Volcanic rock frag trace Plutonic /meta rock frag Dolomite rock frag minor Calcite rock frag Chert trace Mica minor Heavy minerals trace Plant fragments minor Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite minor Fe- calcite Dolomite minor Fe- dolomite Siderite Authigenic clays Organics Pyrite/Ti0 minor Clay Matrix abundant Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description 0.086 Plate 9A: This sample is composed of silty shale and sandstone laminae. Sharp contacts separate the different lithologies. Plate 913: The sandstone is extensively compacted, with long edge and concavo- convex grain boundaries recognized. Pores are rare. Plate 10A Plate 10B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) COI"e [-Zlb Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.115 Sorting well Detrital grains Quartz 18.4 Feldspar 9.6 Argillaceous rock frag 11.6 Volcanic rock frag 8.4 Plutonic /meta rock frag 8.4 Dolomite rock frag 6.8 Calcite rock frag 0.4 Chert 2.8 Mica 2.4 Heavy minerals 0.4 Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 4.0 Feldspar overgrowths 0.8 Calcite 2.0 Fe- calcite Dolomite 9.2 Fe- dolomite Siderite Authigenic clays 5.2 Organics PyritefTi0 1.6 Clay Matrix Pore types Intergranular 3.6 Secondary intragranular 3.2 Secondary Moldic 1.2 Petrographic description 100.0 Plate 10A: Pores (blue) are a combination of primary intergranular, secondary intragranular, and secondary moldic types. Grain sorting is moderate. Plate 10B: Primary intergranular (1), secondary intragranular (2i), and secondary moldic (2m) pores are distinguished in higher magnification. Pyrite (Py) has replaced an argillaceous rock fragment. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7615 Well: Caribou 26 -11 No. 1 Sample No. 15.0 Location: Alaska Porosity ( %) 11.99 Interval: BOS Mid. Cret. Sand Sequence 20 - 21.5 Kair (md) 0.143 Grain density (g /cc) 2.70 Plate 10A Plate 10B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) COI"e [-Zlb Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.115 Sorting well Detrital grains Quartz 18.4 Feldspar 9.6 Argillaceous rock frag 11.6 Volcanic rock frag 8.4 Plutonic /meta rock frag 8.4 Dolomite rock frag 6.8 Calcite rock frag 0.4 Chert 2.8 Mica 2.4 Heavy minerals 0.4 Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 4.0 Feldspar overgrowths 0.8 Calcite 2.0 Fe- calcite Dolomite 9.2 Fe- dolomite Siderite Authigenic clays 5.2 Organics PyritefTi0 1.6 Clay Matrix Pore types Intergranular 3.6 Secondary intragranular 3.2 Secondary Moldic 1.2 Petrographic description 100.0 Plate 10A: Pores (blue) are a combination of primary intergranular, secondary intragranular, and secondary moldic types. Grain sorting is moderate. Plate 10B: Primary intergranular (1), secondary intragranular (2i), and secondary moldic (2m) pores are distinguished in higher magnification. Pyrite (Py) has replaced an argillaceous rock fragment. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7619 Well: Caribou 26 -11 No. 1 Sample No. 14 Location: Alaska Porosity ( %) 10.37 Interval: BOS Mid. Cret. Sand Sequence 20 - 21.5 Kair (md) 0.060 Grain density (g /cc) 2.70 Plate 11 A Plate 11 B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Eire Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.090 Sorting well Detrital grains Quartz 22.8 Feldspar 12.0 Argillaceous rock frag 11.6 Volcanic rock frag 4.4 Plutonic /meta rock frag 4.4 Dolomite rock frag 4.8 Calcite rock frag 0.4 Chert 1.6 Mica 3.6 Heavy minerals Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 4.0 Feldspar overgrowths Calcite 3.6 Fe- calcite 0.4 Dolomite 10.8 Fe- dolomite Siderite Authigenic clays 6.8 Organics Pyrite/Ti0 4.0 Clay Matrix Pore types Intergranular 1.2 Secondary intragranular 2.4 Secondary Moldic 1.2 Petrographic description Plate 11A: Most of the white grains are quartz and most of the dark grains are rock fragments. Pores (blue) are mainly secondary and are poorly interconnected. Plate 11B: The black mineral is pyrite. It has filled intergranular areas and replaced argillaceous grains. Calcite forms a cement (C) and detrital grains (CRF). Dolomite (D) and quartz overgrowths (0) are other cements. Plate 12A Plate 12B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) Cam [.�ab Common (10 -20 %) RESERVOIR OPTIMISATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.110 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc Depth (ft) 7623 Well: Caribou 26 -11 No. 1 Sample No. 13 Location: Alaska Porosity ( %) 11.38 Interval: BOS Mid. Cret. Sand Sequence 20 - 21.5 Kair (md) 0.095 0.8 Plant fragments Grain density (g /cc) 2.70 Plate 12A Plate 12B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) Cam [.�ab Common (10 -20 %) RESERVOIR OPTIMISATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.110 Sorting well Detrital grains Quartz 19.6 Feldspar 14.8 Argillaceous rock frag 12.8 Volcanic rock frag 7.6 Plutonic /meta rock frag 4.4 Dolomite rock frag 5.6 Calcite rock frag 1.6 Chert 1.2 Mica 2.4 Heavy minerals 0.8 Plant fragments 0.4 Glauconite Skeletal fragments Cements Quartz overgrowths 6.4 Feldspar overgrowths 0.8 Calcite 1.2 Fe- calcite Dolomite 8.4 Fe- dolomite Siderite Authigenic clays 1.6 Organics Pyrite/Ti0 3.6 Clay Matrix Pore types Intergranular 1.6 Secondary intragranular 2.8 Secondary Moldic 2.4 Petrographic description Plate 12A: Most of the white grains are quartz and plagioclase, and most of the dark grains are rock fragments. Calcite (red) is found as grains as a cement. Pores (blue) are mainly secondary dissolution types. Plate 126: Argillaceous grains have been deformed by compaction to form pseudomatrix (arrows). Pores (blue) are not well interconnected. Preliminary Plate 13A Plate 13B Trace ( <1 %) Minor (1 -5 %) Eum I-ab Moderate (5 -10 %) RESERVOIR OPTIMIZATION Common (10 -20 %) Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.090 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 7704 Well: Caribou 26 -11 No. 1 Sample No. 11 Location: Alaska Porosity ( %) 7.52 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.014 2.8 Grain density (g /cc) 2.71 Plate 13A Plate 13B Trace ( <1 %) Minor (1 -5 %) Eum I-ab Moderate (5 -10 %) RESERVOIR OPTIMIZATION Common (10 -20 %) Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.090 Sorting well Detrital grains Quartz 28.0 Feldspar 13.6 Argillaceous rock frag 14.8 Volcanic rock frag 10.0 Plutonic /meta rock frag 6.4 Dolomite rock frag 0.8 Calcite rock frag 0.8 Chert 2.8 Mica 3.6 Heavy minerals 1.2 Plant fragments Glauconite trace Skeletal fragments Cements Quartz overgrowths 1.2 Feldspar overgrowths Calcite 1.2 Fe- calcite 1.2 Dolomite 4.8 Fe- dolomite Siderite Authigenic clays 6.4 Organics Pyrite/Ti0 2.8 Clay Matrix Pore types Intergranular Secondary intragranular 0.4 Secondary Moldic Petrographic description Plate 13A: Compaction has deformed ductile rock fragments and reduced intergranular pore volume. Grain sorting is moderate. Plate 136: Secondary pores have formed in a partially leached, deformed volcanic rock fragment. Other identified grains include glauconite (G), quartz (Q), plagioclase (F), mica (M), chert (Cht), and dolomite (DRF) and argillaceous (ARF) rock fragments. Plate 14A Plate 14B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.090 Sorting well Detrital grains Quartz 24.4 Feldspar 14.4 Argillaceous rock frag 18.4 Volcanic rock frag 8.8 Plutonic /meta rock frag 1.2 Dolomite rock frag 2.8 Calcite rock frag trace Chert 4.0 Mica 1.6 Heavy minerals Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 1.6 Feldspar overgrowths 0.4 Calcite 1.2 Fe- calcite 1.2 Dolomite 8.0 Fe- dolomite Siderite 0.4 Authigenic clays 4.8 Organics Pyrite/Ti0 2.8 Clay Matrix Pore types Intergranular 0.8 Secondary intragranular 2.8 Secondary Moldic 0.4 Petrographic description Plate 14A: This faintly laminated, very fine grained sandstone is moderately sorted. Pores (blue) are not common and are poorly interconnected. Plate 146: A secondary pore (2) has formed in a partially leached argillaceous rock fragment. Calcite (red arrow), ferroan calcite (blue arrow), and dolomite (D) are prominent cements. Note the extensive compaction of the ductile grains. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7721 Well: Caribou 26 -11 No. 1 Sample No. 10 Location: Alaska Porosity ( %) 9.66 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.044 Grain density (g/cc) 2.71 Plate 14A Plate 14B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.090 Sorting well Detrital grains Quartz 24.4 Feldspar 14.4 Argillaceous rock frag 18.4 Volcanic rock frag 8.8 Plutonic /meta rock frag 1.2 Dolomite rock frag 2.8 Calcite rock frag trace Chert 4.0 Mica 1.6 Heavy minerals Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 1.6 Feldspar overgrowths 0.4 Calcite 1.2 Fe- calcite 1.2 Dolomite 8.0 Fe- dolomite Siderite 0.4 Authigenic clays 4.8 Organics Pyrite/Ti0 2.8 Clay Matrix Pore types Intergranular 0.8 Secondary intragranular 2.8 Secondary Moldic 0.4 Petrographic description Plate 14A: This faintly laminated, very fine grained sandstone is moderately sorted. Pores (blue) are not common and are poorly interconnected. Plate 146: A secondary pore (2) has formed in a partially leached argillaceous rock fragment. Calcite (red arrow), ferroan calcite (blue arrow), and dolomite (D) are prominent cements. Note the extensive compaction of the ductile grains. Plate 15A Plate 15B Trace ( <I %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.085 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 7730 Well: Caribou 26 -11 No. 1 Sample No. 9 Location: Alaska Porosity ( %) 10.81 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.053 5.6 Grain density (g /cc) 2.71 Plate 15A Plate 15B Trace ( <I %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.085 Sorting well Detrital grains Quartz 24.4 Feldspar 14.4 Argillaceous rock frag 20.0 Volcanic rock frag 4.4 Plutonic /meta rock frag 2.8 Dolomite rock frag 1.6 Calcite rock frag 0.8 Chert 5.6 Mica 2.0 Heavy minerals 0.8 Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 3.2 Feldspar overgrowths Calcite 1.2 Fe- calcite Dolomite 6.4 Fe- dolomite 0.4 Siderite Authigenic clays 6.0 Organics Pyrite/Ti0 2.4 Clay Matrix Pore types Intergranular 0.8 Secondary intragranular 2.4 Secondary Moldic 0.4 Petrographic description Plate 15A: Size -sorted laminae are prominent in this view. Most of the white grains are quartz and plagioclase and most of the dark grains are rock fragments. Plate 1513: Pores (blue) are mainly secondary and are due to grain dissolution. Chert (Cht), volcanic rock fragments (VRF), and argillaceous rock fragments (ARF) are identified grains. Plate 16A Plate 16B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.095 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 7742 Well: Caribou 26 -11 No. 1 Sample No. 8 Location: Alaska Porosity ( %) 9.29 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.038 2.4 Grain density (g/cc) 2.71 Plate 16A Plate 16B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.095 Sorting well Detrital grains Quartz 31.6 Feldspar 10.4 Argillaceous rock frag 16.0 Volcanic rock frag 7.2 Plutonic /meta rock frag 4.8 Dolomite rock frag 3.2 Calcite rock frag 0.8 Chert 2.4 Mica 2.8 Heavy minerals 0.8 Plant fragments 2.0 Glauconite Skeletal fragments Cements Quartz overgrowths 1.6 Feldspar overgrowths Calcite 0.4 Fe- calcite Dolomite 3.6 Fe- dolomite Siderite 0.8 Authigenic clays 7.6 Organics Pyrite/Ti0 2.0 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular 1.6 Secondary Moldic Petrographic description Plate 16A: Faint size -sorted laminae are visible in this low- magnification view. Compaction has reducing intergranular pore volume. Plate 1613: A large carbonaceous plant fragment (arrows) is highlighted in higher magnification. Physical compaction has resulted in deformed grains, as well as long -edge and concavo- convex grain contacts. Plate 17A Plate 17B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core I-ab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.081 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 7748 Well: Caribou 26 -11 No. 1 Sample No. 7 Location: Alaska Porosity ( %) 9.31 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.048 2.8 Grain density (g /cc) 2.72 Plate 17A Plate 17B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core I-ab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.081 Sorting well Detrital grains Quartz 21.2 Feldspar 15.2 Argillaceous rock frag 22.8 Volcanic rock frag 6.8 Plutonic /meta rock frag 3.6 Dolomite rock frag 1.2 Calcite rock frag 0.4 Chert 2.8 Mica 2.0 Heavy minerals 0.8 Plant fragments 2.0 Glauconite Skeletal fragments Cements Quartz overgrowths 0.8 Feldspar overgrowths Calcite 2.0 Fe- calcite 1.2 Dolomite 5.6 Fe- dolomite Siderite 0.4 Authigenic clays 6.4 Organics Pyrite/Ti0 3.6 Clay Matrix Pore types Intergranular Secondary intragranular 1.2 Secondary Moldic Petrographic description Plate 17A: Size -sorted laminae can create vertical permeability barrier in these sandstones. Pores are not common. Plate 1713: Secondary pores (blue) are isolated by compacted grains. Calcite (red) ferroan calcite (arrow), and dolomite (D) are identified cements. Plate 18A Plate 18B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) E13M llab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.115 Sorting moderately well Detrital grains Quartz 21.2 Feldspar 12.0 Argillaceous rock frag 16.8 Volcanic rock frag 10.4 Plutonic /meta rock frag 3.2 Dolomite rock frag 2.0 Calcite rock frag 0.4 Chert 6.4 Mica 3.2 Heavy minerals 0.8 Plant fragments 0.8 Glauconite Skeletal fragments Cements Quartz overgrowths 2.4 Feldspar overgrowths Calcite 0.8 Fe- calcite 0.8 Dolomite 3.6 Fe- dolomite Siderite Authigenic clays 5.6 Organics Pyrite/Ti0 3.2 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular 4.8 Secondary Moldic 1.2 Petrographic description Plate 18A: Pores (blue) are mainly secondary dissolution types. The dark grains are mainly rock fragments and the white grains are mainly quartz and plagioclase. Plate 18B: Identified grains include quartz (Q), plagioclase (F), chert (Cht), argillaceous rock fragments (ARF), and dolomite (D). Pores are mainly secondary (2). They are partially occluded by pyrite (black) and ferroan calcite (arrow). THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7760 Well: Caribou 26 -11 No. 1 Sample No. 6 Location: Alaska Porosity ( %) 10.29 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.051 Grain density (g /cc) 2.71 Plate 18A Plate 18B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) E13M llab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.115 Sorting moderately well Detrital grains Quartz 21.2 Feldspar 12.0 Argillaceous rock frag 16.8 Volcanic rock frag 10.4 Plutonic /meta rock frag 3.2 Dolomite rock frag 2.0 Calcite rock frag 0.4 Chert 6.4 Mica 3.2 Heavy minerals 0.8 Plant fragments 0.8 Glauconite Skeletal fragments Cements Quartz overgrowths 2.4 Feldspar overgrowths Calcite 0.8 Fe- calcite 0.8 Dolomite 3.6 Fe- dolomite Siderite Authigenic clays 5.6 Organics Pyrite/Ti0 3.2 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular 4.8 Secondary Moldic 1.2 Petrographic description Plate 18A: Pores (blue) are mainly secondary dissolution types. The dark grains are mainly rock fragments and the white grains are mainly quartz and plagioclase. Plate 18B: Identified grains include quartz (Q), plagioclase (F), chert (Cht), argillaceous rock fragments (ARF), and dolomite (D). Pores are mainly secondary (2). They are partially occluded by pyrite (black) and ferroan calcite (arrow). THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7769 Well: Caribou 26 -11 No. 1 Sample No. 5 Location: Alaska Porosity ( %) 8.67 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.030 Grain density (g /cc) 2.71 Plate 19A Plate 19B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Common (10 -20 %) REESSE OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.085 Sorting well Detrital grains Quartz 22.4 Feldspar 18.8 Argillaceous rock frag 19.2 Volcanic rock frag 6.8 Plutonic /meta rock frag 4.0 Dolomite rock frag 2.8 Calcite rock frag 0.4 Chert 1.6 Mica 4.4 Heavy minerals 0.8 Plant fragments 1.6 Glauconite Skeletal fragments Cements Quartz overgrowths 0.8 Feldspar overgrowths Calcite 1.2 Fe- calcite 0.4 Dolomite 4.4 Fe- dolomite Siderite 0.4 Authigenic clays 6.4 Organics Pyrite/Ti0 3.2 Clay Matrix Pore types Intergranular Secondary intragranular 0.4 Secondary Moldic Petrographic description Plate 19A: Grains are moderately sorted in this very fine - grained sandstone. Pores (blue) are rare. Plate 1913: A secondary intragranular pore (2) has formed in a partially leached argillaceous rock fragment. Note the well- compacted and deformed grains. Plate 20A Plate 20B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Common (10 -20 %) re RE OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.100 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 7795 Well: Caribou 26 -11 No. 1 Sample No. 4 Location: Alaska Porosity ( %) 10.34 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.053 2.8 Grain density (g/cc) 2.71 Plate 20A Plate 20B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Common (10 -20 %) re RE OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.100 Sorting well Detrital grains Quartz 24.0 Feldspar 11.2 Argillaceous rock frag 18.8 Volcanic rock frag 11.6 Plutonic /meta rock frag 6.8 Dolomite rock frag 1.6 Calcite rock frag 1.6 Chert 2.8 Mica 2.8 Heavy minerals 0.8 Plant fragments 0.4 Glauconite Skeletal fragments Cements Quartz overgrowths 1.2 Feldspar overgrowths Calcite 2.0 Fe- calcite 0.4 Dolomite 2.8 Fe- dolomite 0.4 Siderite Authigenic clays 3.6 Organics Pyrite/Ti0 2.0 Clay Matrix Pore types Intergranular 4.4 Secondary intragranular 0.8 Secondary Moldic Petrographic description Plate 20A: This fine- grained sandstone is poorly sorted. Extensive compaction has reduced pore volume. Plate 2013: Pores (blue) are mixture of primary intergranular and secondary intragranular types. A deformed argillaceous rock fragment (ARF) has been squeezed into adjacent pores creating pseudomatrix. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7815 Well: Caribou 26 -11 No. 1 Sample No. 3 Location: Alaska Porosity ( %) 9.62 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.046 Grain density (g /cc) 2.72 Plate 21A Plate 21 B Trace (<1%) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.120 Sorting moderately well Detrital grains Quartz 21.2 Feldspar 15.2 Argillaceous rock frag 17.2 Volcanic rock frag 10.0 Plutonic /meta rock frag 6.0 Dolomite rock frag 3.2 Calcite rock frag Chert 4.0 Mica 2.0 Heavy minerals 0.4 Plant fragments 0.4 Glauconite Skeletal fragments Cements Quartz overgrowths 3.2 Feldspar overgrowths Calcite 0.8 Fe- calcite 1.6 Dolomite 5.6 Fe- dolomite Siderite 0.4 Authigenic clays 4.0 Organics Pyrite/Ti0 2.0 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular 1.6 Secondary Moldic 0.8 Petrographic description Plate 21A: Isolated pores (blue) are visible in this poorly sorted, fine grained sandstone. Grains are extensively compacted. Plate 2113: Dolomite (arrow) had partially replaced a microporous volcanic rock fragment. Calcite (red) and ferroan calcite (purple) are identified cements. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7825 Well: Caribou 26 -11 No. 1 Sample No. 2 Location: Alaska Porosity ( %) 9.85 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.040 Mica 0.8 Grain density (g /cc) 2.74 Plate 22A Plate 22B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.115 Sorting well Detrital grains Quartz 21.6 Feldspar 10.8 Argillaceous rock frag 13.6 Volcanic rock frag 8.4 Plutonic /meta rock frag 3.2 Dolomite rock frag 4.8 Calcite rock frag 0.4 Chert 4.8 Mica 0.8 Heavy minerals 1.2 Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths 1.6 Feldspar overgrowths Calcite 0.8 Fe- calcite Dolomite 18.0 Fe- dolomite Siderite Authigenic clays 1.6 Organics Pyrite/Ti0 2.8 Clay Matrix Pore types Intergranular 1.6 Secondary intragranular 4.0 Secondary Moldic Petrographic description Plate 22A: Pores (blue) are not well interconnected. This results in low permeability. Grains are extensively compacted, resulting in a loss of intergranular pore volume. Plate 2213: Note the deformation of ductile grains (arrows). Physical compaction has greatly altered this sandstone. Pyrite (black) has replaced portions of the deformed argillaceous grains. Secondary pores (blue) have been partially filled with dolomite (D). Calcite (red) occurs as grains and as a cement. Plate 23A Plate 23B Trace ( <1 %) Minor (1 -5 %) E13M Lab Moderate (5 -10 %) RESERVOIR OPTIMIZATION Common (10 -20 %) Abundant (>20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.094 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 7837 Well: Caribou 26 -11 No. 1 Sample No. 12 Location: Alaska Porosity ( %) 9.97 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.047 2.0 Grain density (g /cc) 2.70 Plate 23A Plate 23B Trace ( <1 %) Minor (1 -5 %) E13M Lab Moderate (5 -10 %) RESERVOIR OPTIMIZATION Common (10 -20 %) Abundant (>20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.094 Sorting well Detrital grains Quartz 24.4 Feldspar 13.2 Argillaceous rock frag 19.6 Volcanic rock frag 10.8 Plutonic /meta rock frag 2.4 Dolomite rock frag 2.0 Calcite rock frag 1.2 Chert 2.0 Mica 3.6 Heavy minerals 0.8 Plant fragments 1.2 Glauconite Skeletal fragments Cements Quartz overgrowths 1.2 Feldspar overgrowths Calcite 1.6 Fe- calcite 0.4 Dolomite 4.0 Fe- dolomite Siderite 1.2 Authigenic clays 3.6 Organics Pyrite/Ti0 2.8 Clay Matrix Pore types Intergranular 0.8 Secondary intragranular 3.2 Secondary Moldic Petrographic description Plate 23A: This sample is a poorly sorted, fine - grained sandstone. Most of the white grains are quartz and feldspar and most of the dark grains are rock fragments. Plate 2313: Argillaceous rock fragments (ARF) have been deformed by compaction. Quartz (Q) and plagioclase (F) are not ductile and were not deformed. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7848 Well: Caribou 26 -11 No. 1 Sample No. 1 Location: Alaska Porosity ( %) 10.55 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.046 Grain density (g/cc) 2.71 Plate 24A Plate 24B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) litharenite Average grain size (mm) 0.125 Sorting moderately well Detrital grains Quartz 22.4 Feldspar 8.4 Argillaceous rock frag 19.6 Volcanic rock frag 13.2 Plutonic /meta rock frag 8.0 Dolomite rock frag 2.8 Calcite rock frag Chert 4.4 Mica 2.8 Heavy minerals 0.4 Plant fragments 0.4 Glauconite trace Skeletal fragments Cements Quartz overgrowths 0.8 Feldspar overgrowths Calcite Fe- calcite Dolomite 6.4 Fe- dolomite 0.8 Siderite Authigenic clays 3.6 Organics Pyrite/Ti0 2.4 Clay Matrix Pore types Intergranular 0.4 Secondary intragranular 2.4 Secondary Moldic 0.8 Petrographic description Plate 24A: Grains are tightly compacted in this lithic- rich, moderately sorted, fine - grained sandstone. Pores (blue) are not common. Plate 2413: Calcite (red), ferroan calcite (FeD), and dolomite (D) are identified carbonate cements. A large secondary moldic pore (2m) has formed from a leached grain. Grains include quartz, (Q), plagioclase (F), as well are volcanic (VRF) and argillaceous (ARF) rock fragments. Plate 25A Plate 25B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core LC-16 Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type siltstone / sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.050 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 7859 Well: Caribou 26 -11 No. 1 Sample No. 48 Location: Alaska Porosity ( %) 7.60 Interval: BOS Mid. Cret. Sand Sequence 22A Kair (md) 0.035 0.4 Grain density (g /cc) 2.68 Plate 25A Plate 25B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core LC-16 Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type siltstone / sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.050 Sorting well Detrital grains Quartz 23.2 Feldspar 14.8 Argillaceous rock frag 32.4 Volcanic rock frag 4.4 Plutonic /meta rock frag 0.4 Dolomite rock frag 0.8 Calcite rock frag Chert 0.4 Mica 4.0 Heavy minerals 2.8 Plant fragments 1.2 Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite 0.4 Fe- calcite Dolomite 4.8 Fe- dolomite Siderite 0.4 Authigenic clays 4.8 Organics Pyrite/Ti0 4.4 Clay Matrix Pore types Intergranular Secondary intragranular 0.8 Secondary Moldic Petrographic description Plate 25A: This sample is mainly a siltstone, but contains thin very fine sandstone laminae. The siltstone is laminated to rippled. Plate 2513: The dark material is mainly argillaceous rock fragments deformed into pore - filling pseudomatrix. Pore volume to very low. Plate 26A Plate 26B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.115 Sorting well Detrital grains Quartz 22.0 Feldspar 12.0 Argillaceous rock frag 13.6 Volcanic rock frag 7.2 Plutonic /meta rock frag 2.4 Dolomite rock frag 3.2 Calcite rock frag Chert 4.4 Mica 2.8 Heavy minerals Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 15.2 Fe- dolomite 11.6 Siderite 0.4 Authigenic clays 1.6 Organics Pyrite/Ti0 1.6 Clay Matrix Pore types Intergranular 1.6 Secondary intragranular 0.4 Secondary Moldic Petrographic description Plate 26A: This sandstone is well cemented by dolomite and ferroan dolomite. This has resulted in elevated grain density and low porosity. Plate 266: A secondary moldic pore (2m) is isolated in this sample. Ferroan dolomite (arrows) and dolomite (D) cements are common. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 7884 Well: Caribou 26 -11 No. 1 Sample No. 47 Location: Alaska Porosity ( %) 4.40 Interval: BIDS Mid. Cret. Sand Sequence 22A Kair (md) 0.003 Grain density (g/cc) 2.76 Plate 26A Plate 26B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type sandstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.115 Sorting well Detrital grains Quartz 22.0 Feldspar 12.0 Argillaceous rock frag 13.6 Volcanic rock frag 7.2 Plutonic /meta rock frag 2.4 Dolomite rock frag 3.2 Calcite rock frag Chert 4.4 Mica 2.8 Heavy minerals Plant fragments Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 15.2 Fe- dolomite 11.6 Siderite 0.4 Authigenic clays 1.6 Organics Pyrite/Ti0 1.6 Clay Matrix Pore types Intergranular 1.6 Secondary intragranular 0.4 Secondary Moldic Petrographic description Plate 26A: This sandstone is well cemented by dolomite and ferroan dolomite. This has resulted in elevated grain density and low porosity. Plate 266: A secondary moldic pore (2m) is isolated in this sample. Ferroan dolomite (arrows) and dolomite (D) cements are common. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 8909 Well: Caribou 26 -11 No. 1 Sample No. 46 Location: Alaska Porosity ( %) NA Interval: Valanginian Channel Fill Kair (md) NA Grain density (g /cc) NA Plate 27A Plate 27B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant (>20 %) Job number: 040187G Depositional texture Rock type silty shale Classification (Folk) NA Average grain size (mm) NA Sorting NA Detrital grains Quartz abundant Feldspar moderate Argillaceous rock frag Volcanic rock frag trace Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica trace Heavy minerals Plant fragments trace Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite minor Fe- dolomite Siderite Authigenic clays Organics rare Pyrite/Ti0 minor Clay Matrix abundant Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 27A: This faintly laminated silty shale may be slightly bioturbated. Intergranular areas are filled with detrital clay matrix. Plate 2713: The black material intermixed with the clay matrix is pyrite and plant fragments. The white grains are mainly quartz and feldspar. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 8917 Well: Caribou 26 -11 No. 1 Sample No. 45 Location: Alaska Porosity ( %) 9.34 Interval: Valanginian Channel Fill Kair (md) 0.040 Grain density (g /cc) 2.71 Plate 28A Plate 28B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) CUM LaI13 Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) feldspathic litharenite Average grain size (mm) 0.048 Sorting moderately well Detrital grains Quartz 21.2 Feldspar 7.2 Argillaceous rock frag Volcanic rock frag 2.4 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert 7.2 Mica 0.8 Heavy minerals Plant fragments Glauconite 2.4 Skeletal fragments 0.4 Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 2.8 Fe- dolomite Siderite Authigenic clays Organics Pyrite/Ti0 3.6 Clay Matrix 52.0 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 28A: The green rounded grains are glauconite. They are intermixed with silt -size grains and detrital clay matrix. Plate 2813: Pyrite and organics (black) are intermixed with the clay matrix (brown). The glauconite grains are larger than the detrital siliciclastic grains. Plate 29A Plate 29B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Ei3m Lafi Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type silty shale Classification (Folk) NA Average grain size (mm) NA Sorting NA Detrital grains Quartz abundant Feldspar moderate Argillaceous rock frag Volcanic rock frag Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica trace Heavy minerals Plant fragments minor Glauconite trace Skeletal fragments trace Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite minor Fe- dolomite Siderite Authigenic clays Organics trace Pyrite/Ti0 minor Clay Matrix abundant Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 29A: This sample is a bioturbated silty shale. Most of the white grains are quartz and plagioclase. A large arenaceous foram (arrow) is prominent. Plate 2913: The arenaceous foram is composed of size - selected quartz and feldspar grains. Detrital clay matrix is the most abundant component in this sample. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 8935 Well: Caribou 26 -11 No. 1 Sample No. 44 Location: Alaska Porosity ( %) 7.81 Interval: Valanginian Channel Fill Kair (md) 0.020 Grain density (g/cc) 2.73 Plate 29A Plate 29B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Ei3m Lafi Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type silty shale Classification (Folk) NA Average grain size (mm) NA Sorting NA Detrital grains Quartz abundant Feldspar moderate Argillaceous rock frag Volcanic rock frag Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica trace Heavy minerals Plant fragments minor Glauconite trace Skeletal fragments trace Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite minor Fe- dolomite Siderite Authigenic clays Organics trace Pyrite/Ti0 minor Clay Matrix abundant Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 29A: This sample is a bioturbated silty shale. Most of the white grains are quartz and plagioclase. A large arenaceous foram (arrow) is prominent. Plate 2913: The arenaceous foram is composed of size - selected quartz and feldspar grains. Detrital clay matrix is the most abundant component in this sample. t i x ♦1 � •' � � � � per. , r � � : • j am .• :`', �'�`- -�'1 - - -.`` � � .-• .� -� . • :• h . o l , t t i x a - `+t ,. i• ! - 3 � • • . ; tip► . - � ` - •' :� " +.,.. �� � ••- �'. •� _ ` -�•'• .} /I, �Z te r. •• ` �t • ' ,'• +. �� ' _�. fi _ ••1 •� �•'. �• - - ���� ti �� "• > - LN,••. _f r -fi •'.I •:. so Vo Ir J� _t���- � �- ff.`s i '� ' L• '; .•••'� �: ! tr'I ' � •�� 'r ay'+. ; • y �T � :_. •� .- I�. �..:. _ .tea • �' to's ` ,1-k v lip AOO r r f ' J, v - �' i ' - - • 4 1 , A V ap f • -• - - +�� , .1 i` Y• } ` •.1•, • ^wit +tti �� �i .•• j' • • d _,• !•• 5�� .� r .•+ ..•� rte' 'R �'r` . .+ =�� �•• • • .. �„ a . ' A "f . ear �. �� • � 4 � � ♦ : Y Ito - j r 4r low 1 0 z r tt, 17 41b 46 ;Aft. 0 4k 91 AV, _71 l i p I zv OKI Plate 34A Plate 34B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) arkose Average grain size (mm) 0.075 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 9009 Well: Caribou 26 -11 No. 1 Sample No. 39 Location: Alaska Porosity ( %) 7.74 Interval: Valanginian Channel Fill Kair (md) 0.012 0.4 Grain density (g/cc) 2.73 Plate 34A Plate 34B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Core Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) arkose Average grain size (mm) 0.075 Sorting well Detrital grains Quartz 25.6 Feldspar 7.2 Argillaceous rock frag Volcanic rock frag 1.6 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert 0.4 Mica 0.4 Heavy minerals Plant fragments 0.4 Glauconite 8.0 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 5.6 Fe- dolomite Siderite 0.8 Authigenic clays Organics 2.8 Pyrite/Ti0 6.4 Clay Matrix 40.8 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 34A: A burrow is outlined in red. The base of the burrow is filled with pyrite, and the upper portion is filled with silt -sized grains and clay matrix. Plate 3413: This sample has a high concentration of glauconite grains (green). Pyrite in the base of the burrow referenced in Plate A is visible. Plate 35A Plate 35B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) Enm Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.065 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 9010 Well: Caribou 26 -11 No. 1 Sample No. 38 Location: Alaska Porosity ( %) 6.23 Interval: Valanginian Channel Fill Kair (md) 0.003 Grain density (g/cc) 3.04 Plate 35A Plate 35B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) Enm Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.065 Sorting well Detrital grains Quartz 20.0 Feldspar 4.4 Argillaceous rock frag Volcanic rock frag 0.8 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 0.8 Heavy minerals Plant fragments 0.4 Glauconite 5.6 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 2.8 Fe- dolomite Siderite 40.8 Authigenic clays Organics 5.2 Pyrite/Ti0 4.0 Clay Matrix 15.2 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 35A: This argillaceous siltstone is bioturbated. Silt -size grains and clay matrix are intermixed, obscuring primary sedimentary structures. Plate 356: The green grains are glauconite and the white grains are mainly quartz and plagioclase. Pyrite (black) is intermixed with the clay matrix. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 9023 Well: Caribou 26 -11 No. 1 Sample No. 37 Location: Alaska Porosity ( %) 8.72 Interval: Valanginian Channel Fill Kair (md) 0.013 Grain density (g/cc) 2.74 Plate 36A Plate 36B Trace ( <I %) Minor (1 -5 %) Moderate (5 -10 %) EFIFIR LFc1b Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) arkose Average grain size (mm) 0.120 Sorting moderate Detrital grains Quartz 22.0 Feldspar 7.6 Argillaceous rock frag Volcanic rock frag 1.6 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 0.8 Heavy minerals Plant fragments 0.8 Glauconite 28.0 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 3.2 Fe- dolomite Siderite Authigenic clays Organics 2.8 Pyrite/Ti0 6.4 Clay Matrix 26.8 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 36A: This sample is an argillaceous siltstone that contains a concentration of glauconite grains (green). The sample has been extensively bioturbated. Plate 3613: The black intergranular material is mainly organics that are intermixed with the clay matrix. Glauconite grains (green) are concentrated in this sample. Plate 37A Plate 37B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) CUM Il21113 Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) arkose Average grain size (mm) 0.090 Sorting moderately well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 9024 Well: Caribou 26 -11 No. 1 Sample No. 36 Location: Alaska Porosity ( %) 8.36 Interval: Valanginian Channel Fill Kair (md) 0.011 0.4 Grain density (g /cc) 2.74 Plate 37A Plate 37B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) CUM Il21113 Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) arkose Average grain size (mm) 0.090 Sorting moderately well Detrital grains Quartz 25.6 Feldspar 9.2 Argillaceous rock frag Volcanic rock frag 1.2 Plutonic /meta rock frag 0.8 Dolomite rock frag Calcite rock frag Chert 0.4 Mica 0.4 Heavy minerals Plant fragments 0.8 Glauconite 14.0 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 4.8 Fe- dolomite Siderite 1.2 Authigenic clays Organics 1.6 Pyrite/Ti0 6.8 Clay Matrix 33.2 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 37A: This argillaceous siltstone was bioturbated, resulting in an uneven texture. Glauconite grains (green) are concentrated in this sample. Plate 37B: No pores are visible in this matrix -rich siltstone. Glauconite grains (green) are common. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc Depth (ft) 9025 Well: Caribou 26 -11 No. 1 Sample No. 35 Location: Alaska Porosity (pia) 7.84 Interval: Valanginian Channel Fill Kair (md) 0.008 Grain density (g /cc) 2.73 Plate 38A Plate 38B Trace (<1%) Minor (1 -5 %) Moderate (5 -10 %) COI"e �tl Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.095 Sorting moderately well Detrital grains Quartz 30.0 Feldspar 6.0 Argillaceous rock frag Volcanic rock frag 0.8 Plutonic /meta rock frag 0.4 Dolomite rock frag Calcite rock frag Chert Mica Heavy minerals Plant fragments 0.8 Glauconite 13.2 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 4.0 Fe- dolomite Siderite Authigenic clays Organics 3.6 Pyrite/Ti0 4.8 Clay Matrix 36.4 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 38A: The brown intergranular material is detrital clay matrix. The green grains are glauconite and most of the white grains are quartz and plagioclase. Plate 3813: The apparent random orientation of the grains is due to bioturbation. Allochemical glauconite grains (green) are generally larger that the detrital siliciclastic grains. Plate 39A Plate 39B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) EGFIR Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.060 Sorting well Detrital grains Quartz 34.2 Feldspar 5.8 Argillaceous rock frag Volcanic rock frag 2.0 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 0.4 Heavy minerals 0.8 Plant fragments 3.2 Glauconite 0.4 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 13.6 Fe- dolomite Siderite 0.4 Authigenic clays Organics 1.2 Pyrite/Ti0 5.2 Clay Matrix 32.8 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 39A: Bioturbation is evident in this low - magnification view. Note the uneven distribution of silt -size grains and clay matrix. Plate 396: The uneven distribution of clay matrix and silt -size grains is featured in higher magnification. This is a characteristic of samples that have been bioturbated. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 9026 Well: Caribou 26 -11 No. 1 Sample No. 34 Location: Alaska Porosity ( %) 5.37 Interval: Kimmeridgian Silt Kair (md) 0.005 Grain density (g/cc) 2.74 Plate 39A Plate 39B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) EGFIR Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.060 Sorting well Detrital grains Quartz 34.2 Feldspar 5.8 Argillaceous rock frag Volcanic rock frag 2.0 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 0.4 Heavy minerals 0.8 Plant fragments 3.2 Glauconite 0.4 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 13.6 Fe- dolomite Siderite 0.4 Authigenic clays Organics 1.2 Pyrite/Ti0 5.2 Clay Matrix 32.8 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 39A: Bioturbation is evident in this low - magnification view. Note the uneven distribution of silt -size grains and clay matrix. Plate 396: The uneven distribution of clay matrix and silt -size grains is featured in higher magnification. This is a characteristic of samples that have been bioturbated. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 9045 Well: Caribou 26 -11 No. 1 Sample No. 33 Location: Alaska Porosity ( %) 7.25 Interval: Kimmeridgian Silt Kair (md) 0.010 Grain density (g /cc) 2.71 Reservoir quality Plate 40A Plate 40B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) rare Ilab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.055 Sorting very well Detrital grains Quartz 45.2 Feldspar 10.0 Argillaceous rock frag Volcanic rock frag Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 2.0 Heavy minerals 0.4 Plant fragments 0.8 Glauconite 1.2 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 8.4 Fe- dolomite Siderite 0.4 Authigenic clays Organics 0.4 Pyrite/Ti0 5.6 Clay Matrix 25.6 Pore types Intergranular Secondary intragranular Secondary Moldic Petrographic description Plate 40A: This sample is very similar to the bioturbated argillaceous siltstone described in Plate 39. The uneven texture is apparent. Plate 40B: No intergranular pores were preserved in this sample. Intergranular areas are filled with detrital clay matrix. Plate 41 A Plate 41 B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) COI"e Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.065 Sorting very well Detrital grains Quartz 43.6 Feldspar 8.4 Argillaceous rock frag Volcanic rock frag 1.2 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 1.2 Heavy minerals 1.2 Plant fragments 0.4 Glauconite 2.4 Skeletal fragments Cements Quartz overgrowths 5.2 Feldspar overgrowths Calcite Fe- calcite Dolomite 9.6 Fe- dolomite Siderite Authigenic clays Organics 0.4 Pyrite/Ti0 4.8 Clay Matrix 21.2 Pore types Intergranular Secondary intragranular 0.4 Secondary Moldic Petrographic description Plate 41A: This sample is a bioturbated, argillaceous siltstone. Note the uneven texture of the clay matrix and silt -sized grains. Plate 41 B: Small secondary pores (arrows) are discernable in higher magnification. Dolomite (D) cement and pyrite (black) are visible. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 9053 Well: Caribou 26 -11 No. 1 Sample No. 32 Location: Alaska Porosity ( %) 9.14 Interval: Kimmeridgian Silt Kair (md) 0.018 Grain density (g /cc) 2.71 Plate 41 A Plate 41 B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) COI"e Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.065 Sorting very well Detrital grains Quartz 43.6 Feldspar 8.4 Argillaceous rock frag Volcanic rock frag 1.2 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 1.2 Heavy minerals 1.2 Plant fragments 0.4 Glauconite 2.4 Skeletal fragments Cements Quartz overgrowths 5.2 Feldspar overgrowths Calcite Fe- calcite Dolomite 9.6 Fe- dolomite Siderite Authigenic clays Organics 0.4 Pyrite/Ti0 4.8 Clay Matrix 21.2 Pore types Intergranular Secondary intragranular 0.4 Secondary Moldic Petrographic description Plate 41A: This sample is a bioturbated, argillaceous siltstone. Note the uneven texture of the clay matrix and silt -sized grains. Plate 41 B: Small secondary pores (arrows) are discernable in higher magnification. Dolomite (D) cement and pyrite (black) are visible. Plate 42A Plate 42B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Ei3re I -ad Common (10 -20 %) RESERVOIR UPTI14I2ATIDN Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.060 Sorting very well Detrital grains THIN SECTION PETROGRAPHY Quartz Company: Total E & P USA. Inc. Depth (ft) 9067 Well: Caribou 26 -11 No. 1 Sample No. 31 Location: Alaska Porosity ( %) 7.89 Interval: Kimmeridgian Silt Kair (md) 0.015 Grain density (g /cc) 2.70 Plate 42A Plate 42B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Ei3re I -ad Common (10 -20 %) RESERVOIR UPTI14I2ATIDN Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.060 Sorting very well Detrital grains Quartz 50.4 Feldspar 4.4 Argillaceous rock frag Volcanic rock frag 2.8 Plutonic /meta rock frag 0.4 Dolomite rock frag 0.4 Calcite rock frag Chert Mica 1.2 Heavy minerals 0.4 Plant fragments 2.0 Glauconite 1.2 Skeletal fragments Cements Quartz overgrowths 6.8 Feldspar overgrowths Calcite Fe- calcite Dolomite 11.6 Fe- dolomite Siderite Authigenic clays Organics Pyrite/Ti0 5.2 Clay Matrix 10.8 Pore types Intergranular Secondary intragranular 2.4 Secondary Moldic Petrographic description Plate 42A: This argillaceous siltstone is bioturbated. Pores (blue) are minor and not well interconnected. Plate 426: Pores (blue) are mainly secondary intragranular. Detrital clay matrix fills most of the intergranular areas. Plate 43A Plate 43B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Ci3re ILati Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.070 Sorting very well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 9068 Well: Caribou 26 -11 No. 1 Sample No. 30 Location: Alaska Porosity ( %) 8.32 Interval: Kimmeridgian Silt Kair (md) 0.016 Grain density (g /cc) 2.70 Plate 43A Plate 43B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Ci3re ILati Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.070 Sorting very well Detrital grains Quartz 46.8 Feldspar 8.8 Argillaceous rock frag Volcanic rock frag 2.0 Plutonic /meta rock frag Dolomite rock frag 0.4 Calcite rock frag Chert Mica 0.8 Heavy minerals 0.4 Plant fragments 0.8 Glauconite 2.0 Skeletal fragments Cements Quartz overgrowths 7.6 Feldspar overgrowths Calcite Fe- calcite Dolomite 9.2 Fe- dolomite Siderite Authigenic clays Organics 1.6 Pyrite/Ti0 5.6 Clay Matrix 13.6 Pore types Intergranular Secondary intragranular 0.4 Secondary Moldic Petrographic description Plate 43A: The uneven texture in this argillaceous siltstone is due to bioturbation. Detrital clay matrix is intermixed silt -size detrital grains. Plate 43B: Organic material (black) is intermixed with the detrital clay matrix. The green grains are glauconite. Most of the white grains are quartz and plagioclase. Plate 44A Plate 44B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Eiim Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.050 Sorting well Detrital grains Quartz 49.6 Feldspar 4.8 Argillaceous rock frag 0.4 Volcanic rock frag 1.2 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 1.6 Heavy minerals Plant fragments 2.0 Glauconite 1.2 Skeletal fragments Cements Quartz overgrowths 1.2 Feldspar overgrowths Calcite Fe- calcite Dolomite 9.2 Fe- dolomite Siderite Authigenic clays Organics 1.2 Pyrite/Ti0 6.8 Clay Matrix 16.0 Pore types Intergranular Secondary intragranular 3.6 Secondary Moldic 1.2 Petrographic description Plate 44A: Laminae have been partially disrupted by bioturbation. Most of the white grains are quartz and plagioclase. Plate 4413: Pores (blue) are mainly secondary. They are poorly interconnected due to the abundance of detrital clay matrix. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 9069 Well: Caribou 26 -11 No. 1 Sample No. 29 Location: Alaska Porosity ( %) 6.76 Interval: Kimmeridgian Silt Kair (md) 0.011 Grain density (g /cc) 2.72 Plate 44A Plate 44B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Eiim Lab Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.050 Sorting well Detrital grains Quartz 49.6 Feldspar 4.8 Argillaceous rock frag 0.4 Volcanic rock frag 1.2 Plutonic /meta rock frag Dolomite rock frag Calcite rock frag Chert Mica 1.6 Heavy minerals Plant fragments 2.0 Glauconite 1.2 Skeletal fragments Cements Quartz overgrowths 1.2 Feldspar overgrowths Calcite Fe- calcite Dolomite 9.2 Fe- dolomite Siderite Authigenic clays Organics 1.2 Pyrite/Ti0 6.8 Clay Matrix 16.0 Pore types Intergranular Secondary intragranular 3.6 Secondary Moldic 1.2 Petrographic description Plate 44A: Laminae have been partially disrupted by bioturbation. Most of the white grains are quartz and plagioclase. Plate 4413: Pores (blue) are mainly secondary. They are poorly interconnected due to the abundance of detrital clay matrix. Plate 45A Plate 45B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Eum ILaE] Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.045 Sorting well Detrital grains Quartz THIN SECTION PETROGRAPHY Feldspar Company: Total E & P USA. Inc. Depth (ft) 9070 Well: Caribou 26 -11 No. 1 Sample No. 28 Location: Alaska Porosity ( %) 6.28 Interval: Kimmeridgian Silt Kair (md) 0.011 Grain density (g /cc) 2.72 Plate 45A Plate 45B Trace ( <1 %) Minor (1 -5 %) Moderate (5 -10 %) Eum ILaE] Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.045 Sorting well Detrital grains Quartz 53.6 Feldspar 10.4 Argillaceous rock frag Volcanic rock frag 0.4 Plutonic /meta rock frag Dolomite rock frag 0.8 Calcite rock frag Chert Mica 1.6 Heavy minerals 0.8 Plant fragments 1.6 Glauconite Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 7.2 Fe- dolomite Siderite Authigenic clays Organics 0.4 Pyrite/Ti0 3.6 Clay Matrix 18.0 Pore types Intergranular Secondary intragranular 1.6 Secondary Moldic Petrographic description Plate 45A: A pyritized plant fragment (arrow) is prominent. This sample is a bioturbated argillaceous siltstone. Plate 456: The large plant fragment has been replaced by pyrite. The brown intergranular material is detrital clay matrix. Plate 46A Plate 46B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) CUM ilMb Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.035 Sorting well Detrital grains Quartz 41.2 Feldspar 10.0 Argillaceous rock frag Volcanic rock frag 0.8 Plutonic /meta rock frag Dolomite rock frag 0.4 Calcite rock frag Chert Mica 1.6 Heavy minerals 1.2 Plant fragments 0.8 Glauconite 0.4 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 8.0 Fe- dolomite Siderite Authigenic clays Organics 0.8 Pyrite/Ti0 8.0 Clay Matrix 26.8 Pore types Intergranular Secondary intragranular Secondary Moldic 100.0 Petrographic description Plate 46A: Detrital clay matrix is intermixed with silt - sized grains and pyritized plant fragments (arrows). The uneven texture is due to bioturbation. Plate 466: No pores are visible in this matrix -rich siltstone. The elevated grain density is due to the presence of pyrite. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 9071 Well: Caribou 26 -11 No. 1 Sample No. 27 Location: Alaska Porosity ( %) 6.56 Interval: Kimmeridgian Silt Kair (md) 0.008 Grain density (g /cc) 2.72 Plate 46A Plate 46B Trace (<1 %) Minor (1 -5 %) Moderate (5 -10 %) CUM ilMb Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous siltstone Classification (Folk) subarkose Average grain size (mm) 0.035 Sorting well Detrital grains Quartz 41.2 Feldspar 10.0 Argillaceous rock frag Volcanic rock frag 0.8 Plutonic /meta rock frag Dolomite rock frag 0.4 Calcite rock frag Chert Mica 1.6 Heavy minerals 1.2 Plant fragments 0.8 Glauconite 0.4 Skeletal fragments Cements Quartz overgrowths Feldspar overgrowths Calcite Fe- calcite Dolomite 8.0 Fe- dolomite Siderite Authigenic clays Organics 0.8 Pyrite/Ti0 8.0 Clay Matrix 26.8 Pore types Intergranular Secondary intragranular Secondary Moldic 100.0 Petrographic description Plate 46A: Detrital clay matrix is intermixed with silt - sized grains and pyritized plant fragments (arrows). The uneven texture is due to bioturbation. Plate 466: No pores are visible in this matrix -rich siltstone. The elevated grain density is due to the presence of pyrite. Arf LAP `�� �2�ay� .j!j�yr(y'•�1�",r.�y�y�,�u �,�i•��' � �a!(�:r.�j j� 7V - Ak 7-1 • • s v • • �t!'�� f s� . • ��f���i' • 1 �` -- 4 10. wn' mL 41 po A 40 Jw' A47 41 jif ter, 41F " At* fill Plate 48A Plate 48B Trace (<1%) Minor (1 -5 %) Moderate (5 -10 %) Eiim Lafi Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.065 Sorting well Detrital grains Quartz 53.2 Feldspar 8.0 Argillaceous rock frag Volcanic rock frag 1.2 Plutonic /meta rock frag Dolomite rock frag 0.4 Calcite rock frag Chert Mica 1.2 Heavy minerals Plant fragments 0.8 Glauconite 0.8 Skeletal fragments Cements Quartz overgrowths 6.0 Feldspar overgrowths Calcite Fe- calcite Dolomite 8.4 Fe- dolomite Siderite Authigenic clays Organics 1.2 Pyrite/Ti0 6.0 Clay Matrix 12.8 Pore types Intergranular Secondary intragranular trace Secondary Moldic Petrographic description Plate 48A: The uneven texture in this sample is due to bioturbation. Intergranular areas are filled with detrital clay matrix. Plate 48B: A secondary pore (2) formed in a pyritized plant fragment. Dolomite (D) cement is intermixed with the clay matrix. THIN SECTION PETROGRAPHY Company: Total E & P USA. Inc. Depth (ft) 9101 Well: Caribou 26 -11 No. 1 Sample No. 25 Location: Alaska Porosity ( %) 9.36 Interval: Kimmeridgian Silt Kair (md) 0.017 Grain density (g /cc) 2.70 Plate 48A Plate 48B Trace (<1%) Minor (1 -5 %) Moderate (5 -10 %) Eiim Lafi Common (10 -20 %) RESERVOIR OPTIMIZATION Abundant ( >20 %) Job number: 040187G Depositional texture Rock type argillaceous sandstone Classification (Folk) subarkose Average grain size (mm) 0.065 Sorting well Detrital grains Quartz 53.2 Feldspar 8.0 Argillaceous rock frag Volcanic rock frag 1.2 Plutonic /meta rock frag Dolomite rock frag 0.4 Calcite rock frag Chert Mica 1.2 Heavy minerals Plant fragments 0.8 Glauconite 0.8 Skeletal fragments Cements Quartz overgrowths 6.0 Feldspar overgrowths Calcite Fe- calcite Dolomite 8.4 Fe- dolomite Siderite Authigenic clays Organics 1.2 Pyrite/Ti0 6.0 Clay Matrix 12.8 Pore types Intergranular Secondary intragranular trace Secondary Moldic Petrographic description Plate 48A: The uneven texture in this sample is due to bioturbation. Intergranular areas are filled with detrital clay matrix. Plate 48B: A secondary pore (2) formed in a pyritized plant fragment. Dolomite (D) cement is intermixed with the clay matrix. -V oi s �" � ' `�� • �! r 's. ;° + *ie + ,�� rte- V � � ,w "- iw .. •e• * W i" n Y' 1 1 FINAL ADT WELL SUMMARY REPORT Total E &P USA, Inc. Caribou 26 -11 #1 NPR -A North Slope, Alaska. 8 `6 SPERRY -SUN DRILLING SERVICES LOGGING SYSTEMS Anchorage, Alaska. FINAL ADT WELL SUMMARY REPORT Total E &P USA, Inc. Caribou 26 -11 #1 NPR A North Slope, Alaska Final Report Summary February, 2004 PREPARED FOR: Total E &P USA, Inc. PREPARED BY: John Patton Sperry-Sun, Halliburton Energy Services Anchorage, Alaska TABLE OF CONTENTS Introduction............................................................................................... ............................... A WellDiagram ............................................................................................... ..............................B WellSummary By Intervals ........................................................................ ............................... C Conclusions............................................................................................... ............................... D GraphicalAnalysis ..................................................................................... ............................... E 1) Days vs. Depth 2) Pore Pressure — Mud Weight — TVD 3) Condensed Resistivity — Gamma Ray 4) Condensed Sonic 5) MWD Tool Temperature LogPacket .................................................................................................. ............................... F 1) Condensed MWD -TVD Log (250' /inch) BitRecord ................................................................................................. ............................... G DrillingMud Record .................................................................................. ............................... H SurveyRecord ............................................................................................. ............................... I ShowReports .............................................................................................. ............................... J 1 -5) Show Reports - Zones of Interests ADT Morning Reports .................................. ............................... ............. ............................... I INTRODUCTION ' Drilling operations for Caribou #1 were initiated 01- 29 -04, by Total E&P USA, Inc. The well was drilled by Nabors Alaska Drilling Rig 14 -E on an ice pad location in Section 26, Township 10 North, Range 5 West in NPR -A. The well was planned as straight hole to penetrate targeted sands found in the Alpine Formation predicted on this location. Caribou 26 -11 #1 was drilled to a total depth of ' 9,362' on 2- 11 -04. The total number of operating days that was required to reach this depth was 14 days, including the spud -in date. Preparations to plug and abandon the well were initiated on 2- 20 -04, after completing logging operations over the 8 %2" hole section of this well. The following pages of this report are designed to supply specific historical data of the events that occurred on Caribou 26 -11 #1, along with some analysis and recommendations for specific problems that were experienced during different sections of the hole. All of the information compiled in this I report was acquired and recorded by the Sperry -Sun Unit at the wellsite. ' The sensors incorporated in this unit are independent from the rig sensors and may differ slightly from those reported by the rig contractor. In addition, any evaluations in this report regarding formation evaluation, pore pressure estimates, or other geologic interpretations are made entirely by Sperry-Sun personnel from examination of the data collected by the Sperry-Sun Unit and reference material made available by the operator at the rig -site. j� Deep Phase EWR 1 0 0 1K Ray Gamm .p • 75 150 • •• Shall • 10 100 - — 'J■ ■t ■ 1 000 000 3 000 4 000 , , , , , • 9 000 M � - _ ��- -� -__- i.iiiii ■E== iiiiiii ■l� +dill ■■ ■1111 milli ■■ ■�- ■ 111 M ■■ ■YIIII IN■ �wEM �ii�Yiiiii��i'. ■EYilll ■Mill I ■ ■ ■■■ ■■■■ ■■■ 11 ■E■ ■YIIII M■■■YIIII'i MEC��!1 M ■■ ■YIIII M ■■ ■YIIII ■■ MEC__ =�!!� �E■ ■YIIII ■■■ ■YIIII ■■ - ■El�.:���I ME ■ ■Y;1�� ME■ ■YIIII ■■■ - MOM =rte M ■ ■ ■ U ■fY = ■ ■Y�'�I ■� YIIII M ■■ ■YIIII IN ■ ■ ■YIIII ■YIIIIM M ■■ ■■ ■YIIII ■YIIII IN I N ■■ _ M ■■ ■YID � ■■ ■YIIII ■ ■■ ■YIIII ■ ■ ■ ■ ■� M■■■ � . � ■ ■ ■YIIIIM ■■ ■YIIII � ■■ ■YIIII M ■■ ■YIIII :: 1111111111111 ■■ ■YIIII ■■■ ■YIIII ■ ■ ■ ■ ■■ M ■ ■OYIi ■■ ■YIIII ■ ■■ ■YIIII M ■ ■■ M■■OYI ■■ ■YIIII ■Ew ■YIIII ENEM M■■ ■YF,11 ; � M ■■ ■YIIII M■iiililYi�Yi ■■■■ M ■ ■ ■ ■ ■l�aIII M ■ ■= X11 ■ ■■ ■ ■ ■YIIII ■Y111I M ■ ■■ ■■ ■YIIII ■YIIII ■■■■■ __ - ■■■■ — M ■ ■ ■��111 M■■OYIIII M ■■ ■YIIII t ■ii ■E� ■ ■�� ■ ■i�- ■■E- -� ■ ■E= ■ ■ ■�- ■■■ r - — ■ - ■ ■ ME■■Y M■■ ■F, ■■■YIIII ■■■■YIIII ■■ ■YIIII ■■■■YIIII M ■ ■ ■Y ■ ■ ■Y ■ ■ ■Y • • ■■YI - 3 � '°"` , i �' ■■■■ M ■ME. ■■ ■YIIII ■■■■ M■ ■::x'!11 M ■l��illM ■■ ■YIIII M ■■■■ MOM _ ■ ■ ■■ ■■ ■■ ■YIIII ■YIIII ■YIIII■ ■ M■■OY ■■■■ ■ ■ ■ ■ N■■ ■ ■ ■E =l11 M ■■ ■YII :■■ ■ ■ ■YIE �1 ■_ ■■ ■YII - �-�■ '—� -� ■■ Meson �Mmm�1111 ■E ■■■■YI IN MEMO ■■ ■YIIII ■ ■■ °-' ■YI■ ME■ ■YIIII ME■ ■YIIII ME ■ ■YIIII ■■■ ■YIIII WON ME ■ ■YIIII ■■■ ■YIIII -� !�M FPM ■■YIIII ■YIIII ■YIIII ME■ MEM ME ■ ■ ■Y ■Y .. - ■ ■E■ ■■■■ E■ ■YIIII ME■ ■YIIII ME M■ ■M �� l�:�IIII ■ ■YIIII ■Y1111 ME■ MEM ME■OYIIII ■YIIII ■YIIII ME■ ME ME ■■■■ ■�.?' ■■■■ ■ .' C u WELL SUMMARY BY INTERVALS Interval: 109' to 2,243' - 12 1 /4" Hole Days: 6 Average WOB: 5 -25 klb Hole Size: 12.25" Average RPM: 30 (Surface) No. Bits: 1 Average GPM: 450 -550 gpm Rotating Hours: 25.4 Average SPP: 600 -1500 psi Deviation: 0 -1.13 deg Average ROP: 85.1 fllhr Mud Weight: 9.7 -10.0 ppg Mud Type: KCL Poly Nabors Alaska Drilling Rig 14 -E was positioned on location and rigged up prior to the spud in date of 01- 29 -04. Structural 16' conductor had been set to a depth of 109'. After completing the rig up, a surface diverter system was installed and tested. Drilling operations were initiated by drilling out the conductor with Bit No. 1, a conventional milled tooth bit with 1x19, 3x20 jets. This bit was placed behind an 8" slow speed motor and used to drill to a total interval depth of 2,243'. No gravel was seen at the start of this well. The predominate lithology varied between mostly fine grain sand and soft hydrated clay. Minor coal beds were also logged in the surface hole. The mud system for this section of the hole was a KCL PHPA/Poly starting out at 9.7 ppg. This mud reacted as an inhibited system in that most of the clay cuttings stayed reasonably intact and would not easily go into solution with the mud. This increased the volume of clay cuttings at the rig shakers significantly in comparison to other wells drilled with LSND spud mud. With the additional clay coming back, penetration rates for the first bit run were limited to about 100 -125 fph to avoid problems with handling the overall volume of cuttings coming from the hole. Moderate hole problems were found in the surface hole. They were related to the sticky clay formation that resulted in poor cutting transport and bore hole swelling. One pack off situation occurred after making a connection at 1,743'. The BHA appeared to loosen a clay ball on the connection and packed off:, temporarily causing lost returns. The bit was pulled off bottom to establish good returns and to change out shaker screens. Drilling continued without problems after this clean up. Approximately 80 bbl of mud were lost to the hole because of the pack off. Two wiper trips were made in the 12 1 /4 " interval. The first trip was made from 1,293' back to 337' while making repairs to the auger. The second wiper trip was made back to 1,600' from the interval TD. Both trips were pulled with some drag and tried to swab. This appeared to be caused to some extent by borehole swelling and possibly from pulling into another clay ball above the BHA. The hole was then conditioned with additional circulating time in preparation for running surface casing. ' 9 5/8 40 lb /ft casing was run to a shoe depth of 2,236' with good mud returns. The casing was then cemented in place without problems. ' of the well was believed to be no pressured. Low background as s were readings This interval rurally p gr g g ' logged for this section. The maxim drilled gas was 70 units, lagged from 2,120'. No hydrocarbon shows were logged in the surface hole. A gradient of 8.5 ppg was estimated for the Permafrost extending to about 950'. This estimate was increased to 8.7 ppg for the rest of the 12 %a" interval. 1 J 0 I Interval: 2,243' to 9,362'— 8 1 /2 " Hole I� �7 i 0 0 0 The blow out preventer stack was nippled up and tested. The 9 5/8" surface casing set at 2,236' was tested to 2,500 psi for 30 minutes prior to drilling. Bit No. 2, an 8 %2 PDC type bit, was used to drill out of the 9 5/8" surface casing along with 10 feet of new hole to 2,254' on 2- 05 -04. The hole was then circulated while conditioning the 9.3 ppg mud in preparation for running a leak off test. The test yielded a fracture pressure equivalent to 14.0 ppg EMW. Bit No. 2 was run on a directional assembly with a .93 degree bend and a slow speed motor. Drilling was continued after completing the leak off test to 2,577'. The hole was circulated out at this depth and a second leak off test was made to verify potential injection sands. This leak off test yielded a slightly lower fracture gradient of 13.4 ppg EMW. The 8 1 /2" interval was controlled drilled. The rate was maintained at no more than 120 ft/hr to establish optimum data density for the MWD tools. This rate allowed for a data density of one point per foot while drilling. The slower rate was also beneficial for handling the excessive amounts of clay cuttings drilled on the first 3,000' of the 8 %2 interval. The predominant lithology logged at the start of this section was soft, amorphous, hydrated clay that extended to a depth of about 4, 500 - 5,000'. Cuttings became firmer with depth and were much more defined after penetrating 6,500'. The lithology extending from this depth was varied and included claystone, shale, siltstone, and sandstone. Moderate hole problems were noted over this interval and were mainly concern with trips. Few problems were seen with bit balling. Two intermediate wiper trips were made to condition the hole. One was made at 4,593' and the other at 6,699'. Both of these trips pulled with modest drag but there were considerable amounts of sticky clay coming back over the shakers while circulating after getting back to bottom. The clay coming back overloaded the shakers on both occasions and also loaded the de- watering unit with excess material. The maximum trip gas readings from 4,593' and 6,699' were 163 and 310 units respectively. Days: 8 Average WOB: 5 -15 klb ' Hole Size: 8 %2 Average RPM: 90+120(motor) No. Bits: 1 run Average GPM: 450 -480 gpm Rotating Hours: 87.7 Average SPP: 1500 -3400 psi ' Deviation: .17 -1.27 deg Average ROP: 91 ft/hr Mud Weight: 9.2/10.2 ppg Mud Type: KCL Poly Discussion: I� �7 i 0 0 0 The blow out preventer stack was nippled up and tested. The 9 5/8" surface casing set at 2,236' was tested to 2,500 psi for 30 minutes prior to drilling. Bit No. 2, an 8 %2 PDC type bit, was used to drill out of the 9 5/8" surface casing along with 10 feet of new hole to 2,254' on 2- 05 -04. The hole was then circulated while conditioning the 9.3 ppg mud in preparation for running a leak off test. The test yielded a fracture pressure equivalent to 14.0 ppg EMW. Bit No. 2 was run on a directional assembly with a .93 degree bend and a slow speed motor. Drilling was continued after completing the leak off test to 2,577'. The hole was circulated out at this depth and a second leak off test was made to verify potential injection sands. This leak off test yielded a slightly lower fracture gradient of 13.4 ppg EMW. The 8 1 /2" interval was controlled drilled. The rate was maintained at no more than 120 ft/hr to establish optimum data density for the MWD tools. This rate allowed for a data density of one point per foot while drilling. The slower rate was also beneficial for handling the excessive amounts of clay cuttings drilled on the first 3,000' of the 8 %2 interval. The predominant lithology logged at the start of this section was soft, amorphous, hydrated clay that extended to a depth of about 4, 500 - 5,000'. Cuttings became firmer with depth and were much more defined after penetrating 6,500'. The lithology extending from this depth was varied and included claystone, shale, siltstone, and sandstone. Moderate hole problems were noted over this interval and were mainly concern with trips. Few problems were seen with bit balling. Two intermediate wiper trips were made to condition the hole. One was made at 4,593' and the other at 6,699'. Both of these trips pulled with modest drag but there were considerable amounts of sticky clay coming back over the shakers while circulating after getting back to bottom. The clay coming back overloaded the shakers on both occasions and also loaded the de- watering unit with excess material. The maximum trip gas readings from 4,593' and 6,699' were 163 and 310 units respectively. 0 0 0 Low background gas readings were encountered from the shoe extending to about 7,400'. Chromatograph breakdowns of the gas encountered in these sands were mostly methane but contained notable readings of ethane through pentane gases. No significant hydrocarbon shows were logged from sands in this part of the well. High background gas readings were recorded starting from 7,500' while drilling though a sandstone interval from 7,510' to 7,870'. The maximum gas reading from this sand reached 3,050 units at 7,608'. Shows of oil fluorescence and cut were logged in this sandstone. There was also good overall presence of heavier hydrocarbons (C2 — C5) readings from chromatograph breakdown of the total gas. Analysis of the type of observed fluorescence and gas readings indicated that this zone probably contained light gravity oil. The overall quality of the show was rated as poor — the zone appeared tight. A modest pore pressure trend was noted starting at 7,500' using resistivity and sonic data as the primary reference. Please refer to the Condensed Resistivity and Condensed Sonic Plots in the Graphs section of this report. Other drilling parameters were also logged with this trend that support an increase in pore pressure estimates and included some extra torque and modest amounts of shale slough. The pore pressure estimate was raised to 9.5 ppg by 7,900' in the HRZ and to 9.8 ppg by 8,100' in the low resistivity shale located between the HRZ and the LCU to reflect the overall trend analysis. This estimate was lowered to 9.5 ppg by 8,175' and to 9.0 -9.3 by 8,800' before entering the targeted area starting at 9,025'. The mud weight was maintained at 9.3 - 9.6 ppg starting from the shoe and extending to 6,500'. Some additional water (about 15 bbl/hr) was needed while running the centrifuge to keep clay solids under control. The weight was increased to 10.0 ppg by 6,600' and later increased to 10.2 ppg by 9,000'. Connection gas was not logged on this interval indicating that the mud weights used on this well supplied adequate overbalance. Background gas readings were lower after penetrating the zone between 7,510- 7,870' averaging around 400 -700 units. Gas readings over the sandy siltstone interval from 9,025- 9,135' were higher, reaching a maximum value of 1,925 units at 9,100'. Shows of oil fluorescence were much less evident in this zone. There was no initial visual fluorescence, but the sandy siltstone would sometimes faintly cut when dried and crushed. Cl /C2 ratios indicated that the zone contained oil although without any initial fluorescence, any oil within this zone was probably very light. Visual porosity was at times poor to fair; however, there was not enough fine grain sand supported by the sihstone for a better estimate. Resistivity readings over the show interval were low ranging from 4 -7 ohm m. The overall quality of the show was also rated as poor for oil - the zone appeared tight and perhaps gas prone. Gas readings while drilling below the target interval dropped to 300 -400 units. 0 17 0 0 �I The hole was circulated and conditioned after reaching TD — 9,362' at 11:00 hours on 02- 11 -04. The bit was pulled out of the hole to test BOP'S. Extra drag was seen on this trip starting at 4,225' and extending to 2,750'. A wiper trip was made after completing the BOP test. Drag was seen while going back in the hole just below the shoe. The hole was washed and reamed at about 5 min/std to 3,300' and circulated out after reaching 6,050'. The hole unloaded a large of amount of clay and drilled solids lagged from 2500 -3500' on this circulation. The extra material that unloaded appeared to be coming from sections of the hole that were washing out extending about 1,200' below the shoe. The hole was also reamed from 7,750 - 8,000' and from 8,550' to TD to condition tight hole. The maximum trip gas from this trip was 2,020' and lagged back to about 9,200'. Moderate amounts of larger shale cavings approaching one inch in length were also logged on bottoms up from the trip. A short trip was made back to 6,850'. This trip pulled out and ran back in the hole reasonably well without excess drag. The maxim gas from this trip while circulating on bottom reached 200 units. More shale slough was seen on this circulation, however the amount was not excessive. The bit was later pulled out of the hole after circulating additional time to allow for Schlumberger to get on location. The well was then evaluated with wireline logs. Preparations to plug and abandoned the well were initiated on 2- 20 -04. Four show reports were completed for the Lower Torok Sands located just above the HRZ in this section of the hole. One show report was made for the main target area. Please refer to the Show Report Section J for additional analysis. Hole problems for the interval included significant quantities of clay coming back over the shakers from trips that sometimes blinded off the shakers and caused additional problems in handling the excess material at the de- watering unit. The clay appeared to be coming from up hole between the shoe and 3,300'. This was verified on the wiper trip after testing BOP's at TD. 0 I GENERAL: CONCLUSIONS The drilling program for Caribou 26 -11 #1 was designed to drill to an estimated measured depth of ' 9,700'. The primary objective was to evaluate the Valanginian Alpine Sands. Caribou 26 -11 #1 was drilled to 9,362' in 14 days and reached the projected total depth well ahead of the originally estimated ' days to drill this well. The well was plugged abandoned after completing wire line operations to evaluate the 8 1 /2" hole section. Hole problems that were experienced in the 12 %" interval were associated with the clay formation drilled in this section. Problems were encountered in handling sticky, clay cuttings at the shakers. This ' was a partially product of the type of mud system chosen for this section. The mud system was a 9.7- 10.0 ppg — KCL PhPa/Poly. This system was inhibitive in that it did a good job of keeping clay ' cuttings reasonably intact as they were pumped out of the hole. With the considerable volume of sticky clay coming back, the ROP was limited to handle the volume of cuttings at drilling rates of more than ' 100 -125 fph. It was necessary to use this type of mud on this well to limit the quantity of drilled solids and mud that had to be hauled away from this remote location for disposal. ' In addition to limited penetration rates, other problems were related to the clay section of the hole and included poor clay cutting transport out of the hole and swelling clays causing some bore hole under ' gauge. A pack off problem (with no returns) was encountered at 1,743' where a clay ball unloaded from the hole. When this occurred, the bit was pulled back to establish good returns and change out I shaker screens. About 80 barrels of fluid were lost to the hole on this pack off. ' Moderate drag was seen on wiper trips. The tight hole appeared to be caused primarily by dragging a ball ahead of the BHA while pulling through swelling clays. This situation can be serious on the surface hole when there are gas sands drilled in this interval It takes very little drag to cause a significant swab down hole at this shallow depth The average hole size from the drilling caliper data was 13" below the Permafrost in this interval. Given the situation that inhibited mud often delivers a ' close to gauge hole it is recommended to pump out of the hole on surface to prevent the possibility of swabbing in the well. We would also recommend using smaller jets in this section to possibly increase ' the hole size and allow for more clearance for the BHA when tripping. Problems while drilling in the 8 1 /2" interval were also moderate and were mostly experienced on trips. ' Moderate drag, along with lots of clay and drilled solids, were seen coming back from wiper trips. The material appeared to be mostly coming from up hole between the shoe and about 3,300'. This area of ' the hole provided for most of the problems that were encountered on this well later on. The most serious situation for this well happened during wire line operations when one of the tool runs became E L i 1 0 0 stuck in the hole around 3100'. This required extra rig time to fish the stuck tool out of the hole, as well as another wiper trip to clean up and condition the well bore. The area of the hole between the shoe and 3,300' contained poorly consolidated sands and soft clay that appeared to wash out over time. One way to eliminate this problem would have been to set the surface casing deeper. On this well, the casing was set high to verify potential annulus injection sands. Another recommendation would be to run a tapered ghost reaming about 1,600' behind the bit. Running this type of reamer well above the BHA conditions the hole as it is drilled and helps take excess sticky clay out of the hole. Moderate shale slough was seen on this well after penetrating 8,000'. The amount was not serious while drilling or while conditioning the hole for E -Logs. However, it should be noted that caliper data indicated that the average hole diameter deeper in this well was very close to gauge. Given this data, it does not take much in the way for shale slough to cause problems with tripping. There is simply not much room for any excess material to clear the BHA when pulling pipe. - Relatively good penetration rates were logged with the PDC bit. Penetration rates were limited to about 120 ft/hr in the 8 V2" section to get optimum data from the MWD/LWD tools. The average bit weight was maintained at 5 -15 K lbs to hold back the rate. High background gas readings were recorded on this well from 7,500 - 7,870' in the Lower Torok Sand and from 9,025 — 9,135' in the lower target interval. The max gas reading for this well was close to 3,000 units (30 %) from 7,725'. The overall gas signature in both zones was estimated to be derived from very light gravity oil and possibly some gas. This estimate was made using Cl /C2 ratio analysis of chromatograph readings and type of fluorescence and cut from cutting samples. PORE PRESSURE: Pore pressure estimates Caribou 26 -11 #1 were generally made from observing overall mud gas readings relative to the current mud weight in conjunction with analysis of trend data established by resistivity and sonic data. "Dc" Exponent data for this well was inconclusive primarily because of the use of PDC type bits. Caribou 26 -11 -1 appeared to be normally pressured extending from the surface to 7,500' TVD using 8.7 ppg as a normal gradient. In referencing the Condensed Resistivity and Sonic Plots (refer to Section E), pore pressure estimates were steadily increased starting from just above the HRZ. The highest pore pressure estimate (9.8 ppg) was logged in the low resistivity shale around 8,100' located �j ' between the HRZ and the LCU. Larger pieces of shale slough were later lagged back to this zone. The estimate was decreased from this shale to an estimate of 9.0 -9.3 ppg for the target area near TD. ' ZONES OF INTEREST: ' Very little evidence of oil fluorescence was noted in the first 7,000' of this well. The first zone of interest logged was a Lower Cretaceous Torok sandstone that extended from 7,510' to the top of the ' HRZ around 7,785'. Four show reports were filled out for this section. This zone contained bright visible fluorescence and milky crush cut fluorescence. Background gas and chromattograph readings in ' the sand were good over the interval indicating that the zone contained hydrocarbons. In addition, analysis of the fluorescence and the chromattograph ratios indicated that the sand contained light gravity ' oil. However, there was poor visible porosity in the cutting samples. The zone appeared to be tight. The cutting samples contained too much calcareous clay matrix/cement for a good show rating. ' The second zone drilled on this well, the primary target, was generally a siltstone interval located from 9,025- 9,135' above the Kimmeridgian Silts. One show report was filled out for this section. Higher ' gas readings with good chromatograph ratios were also logged in this interval There was no visual fluorescence in the drilling cuttings but some crush cut could be seen from dried samples. This type of ' fluorescence can sometimes be associated with very light gravity oil or condensate. Poor to maybe fair visible porosity was logged in the interval. The siltstone also supported very fine grain sand but ' generally amounted to less than 10% of individual cuttings. Although there were relatively high gas readings indicating the presence of hydrocarbons, this zone was rated as poor show for very light oil. Resistivity values were low (4 -7 ohm-m) and the sandy siltstone appeared to have low porosity. J I • • I■■■■ ■■ 1....... ■■■■■ E■ ■E■ ■■) ►�.. ■... ■■■■.. ■ ■�� ■■ �� ■■ .■■.. ■■■■. M. \ \ ■■iii�ii�ii�. ■. . ■. ■� ■ ■ ■�. ME = �■ ■■ ■��� ■ ■■.. IN ....t ■ ■.►��� �.�■ ■■. ■.■ ■r ■■.r■ ■ ■1 \� �� ■viii ii�ii�i� ■■■ ■■■■ ■ ■■ ■■■ �i ■ ■ \� ■.. ■■ ■ ■■� ■. ..■...■.■ ■■■.■ ■..■ ■..�.■ ■ ■■■ ■■■.■ ■■MINE . ■ ■ ■ ■. ■ ■■.■■ ..■■.■.■■...■ ■■■■■■■■ IEEE :::■■::■■::■: ■■■■i ■. IM - ..■....■....■ ■■■ ■■■■.■.■■.■.■ ■■■■■■■■■■■■■ ■ ■■■■ ■■■■■ ■■■■■ ■■■■■■■. ■ ■■■■ MINIM. .■ ■...■ ■.■.■ ■■■� ■■MINIM■ ■■■■MIME ■. ■....■■...■.. ► ► ► ■■. ■■ ■ ■ ■■■���■.■■ ■ ■..■ ■. ■■■■■■ ■■■■■ ■.■■■ ■■■■■ ■.■■■ ► IMMIMINIMME .. ■■■■■ ■ ■W ■■■■■ ■MINIM■ ■■■■■ . ► ► ► MIMIMMIMMIMMEMIMI J EST. PORE PRESSURE - MUD WEIGHT lbs per gal eq m MOM ! O MI N 1 3 ME M■ ■ MEN! �OE M MINE mmi � � EMEM M INE ��� INN NIEMEN MINE M MM MM mmm MIN mm ME��IIMI� Cam:= �OEM ��� 1 11101 E ll l i mm �� �MC MEN! m m � �� � � _ MME ���������M� G. � � OM m i�� ����� ��C� ��1 =__ T� === 115 =8 M' ------ CM MME�OEM INS MINN m ME mmmmm mom MINE 3=�! OM �.. = = = = 4000 T■ C C .MC �m� NONE MINE MIN ME 11111110 MINES MM INS on EMNI 11111101 OWN MIN ME MEN IME Mol Minims 11110 � 1111101 0 EN ION IMM111I Im mm M MEN :E NE S EEN Il I �Cm �M�� MINE 11111110 _ .. MEMEM mm�m M EN i Ni M' M� � MM MC :C MEN SEEN mmm mmmmo mm C::C ME mm EMEN` IMEEIMEIMM ME IMMEMEMM ME MIN 1ME IMENIM mom. ■m mmm. = M� �� �_�_ �Cm � � �C=E�CG S:I =�� lom ��� ::_I___E __m___�______�_M ■m m �� � I M� m mom mm MCC� EM =M M� _E � _m mm IN MM mm MEN! ME�MMM i �� �..�. M ■ ON ME! mmm mom= 8 000 mm m ME 111101 M mm M INN OE M M C EM �MINE CSM MEN IN MINE E E� MO MEii�.Ti ��� ■�i�mm �� mm E � M � ME ME MOEN MEN! mmmmmm MINE IME MILIMMM =MM mmmmmm ME mom mm 0111111111111111101 mimmimmIJIMMIMOMMEN ME Em mmmmmms 0 t l Gamma Ray api CONDENSED RESISTIVITY 1 10 00 1K Estimate Po re Pressure PPG 8 • 100 20 00 3 000 5000 6 000 9000 1 ► —` ��- ��.. - �F-- �_. rte- - �� . ■ : ON M E: ■■M■■ mom ■�: ME ME 0:11 �ME _M::: ,� — IN I I NE — C — C_..... ::■ WE ME MOM s:s 5 =: x:11: WE m_:: mom �_.... Ell C C::: NONNI moll ' S E:� �■: . . �.� .. =.moon ■.1 .� .1al i .■ l I= :0 ! ' TVD ft 200 1 I 1000 ' 2000 � 1 f a ' 3000 a 4000 5000 6000 7000 1 ' 1 s000 — 1 8000 Estimated CONDENSED SONIC PorePPPGsure 20 8 9 10 11 12 I' ' TVD MWD Tool Temperature 4—i ft 1000 2000 3000 4000 5000 6000 - -- 7000 - - - - 14� 9000 sperry-sun DRILLING SERVICES Bit • • Customer: ,_ 16" inch at 109 ft • Well: CARIBOU 26-11 #1 9 5/8" inch at 2236 ft -. NORTH SLOPE CARIBOU Rig: NABORS DRLG RIG 14E Company: BAROID Job . 111 I i Serial Number ��yac�ril �L� �E��� i�- 1< yl�f�i���������EY3'�S'a�'as'3�� � �� �'d1f� ��:�.Y�I�>• �� �� , . t�yauF: ���fSS ii�i� a � � � t��if•]yad•�:ibYU�a� - IdlslJi!' I� WMIMMLM"ld Rld'�[m�6'��ba ��x��.YVZ� �� umnmsrtr.�cmi� no Ulm lx��MMUMWMIIWI lm�� WMM MI �x ImuiLl l>. m me"m a[�ya`ranz� �kI: 3� �fi' 8�i[ ��i��Ed =��E3���tb'>��g�� ��y�` K�` �■ � �ii' bs ����[����S�EbS��E3���t��i ■�i�', � �� ���.YVar��vz�i�r�>• MMLSRI M M L'SRWM 3■�L'aE7ii7 �f��E3���Eb���E7��I� �Eb'� ���.YV�>.�y�mi�>• �xx•� ��ya`r.YC�z� AIL' b'© i�a ��E3'a L •Jii(�i��Eb���1Eb����7�I���Ed', � �� ���. YV�r :��cv.��r�r���I:I� EMrc�i■ a l ' ° • Imlx= I ° ' ma a: ", I= t �Ya` rauL■ ���iL' a' �i����E� 1���6�Ed���E�������i ■���� � � � � � � � � � ixxrc� HALLIBURTON DIRECTIONAL SURVEY REPORT Total E &P U.S.A, Inc. Caribou 26 -11 #1 Exploration North Slope Borough Alaska USA AK-MW-0002837527 Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg1100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE -IN 171.05 0.99 187.06 171.04 1.46S 0.18 W 1.29 0.58 358.93 0.98 178.65 358.89 4.67S 0.34 W 3.97 0.08 450.79 1.00 171.92 450.74 6.24S 0.21 W 5.16 0.13 543.37 0.84 177.13 543.31 7.71 S 0.06 W 6.27 0.19 637.62 0.75 156.14 637.55 8.96S 0.22 E 7.11 0.32 728.80 0.51 149.31 728.72 9.86S 0.66 E 7.57 0.27 822.46 0.61 170.55 822.38 10.70S 0.96 E 8.08 0.24 916.00 0.76 188.93 915.91 11.81S 0.94 E 8.98 0.28 1010.02 0.57 177.63 1009.93 12.89S 0.87 E 9.90 0.25 1101.52 0.66 171.82 1101.42 13.87 S 0.96 E 10.64 0.12 1197.62 0.26 133.17 1197.52 14.57 S 1.20 E 11.06 0.51 1384.61 0.22 196.52 1384.51 15.21 S 1.41 E 11.46 0.14 1476.22 0.31 180.03 1476.12 15.64S 1.36 E 11.83 0.13 1574.49 0.72 318.36 1574.38 15.44S 0.95 E 11.92 1.00 1667.63 0.72 322.01 1667.52 14.54S 0.20 E 11.63 0.05 1766.58 0.90 308.04 1766.46 13.58S 0.80 W 11.44 0.27 1858.61 1.05 314.44 1858.47 12.64S 1.97 W 11.29 0.20 1954.71 1.12 307.74 1954.56 11.36S 3.34 W 11.14 0.15 2050.04 1.13 310.25 2049.87 10.17S 4.79 W 11.04 0.05 2170.10 1.00 311.78 2169.91 8.71 S 6.48 W 10.85 0.11 2317.58 1.18 308.23 2317.36 6.90 S 8.64 W 10.67 0.13 2413.57 1.05 310.65 2413.33 5.71 S 10.09 W 10.56 0.15 2507.51 1.01 310.06 2507.26 4.62S 11.37 W 10.44 0.04 2604.16 1.08 352.65 2603.89 3.17 S 12.14 W 9.72 0.79 2697.85 0.83 350.05 2697.57 1.63S 12.37 W 8.61 0.27 2792.70 0.75 352.02 2792.41 0.34S 12.58 W 7.69 0.09 2886.40 0.62 353.19 2886.10 0.77 N 12.72 W 6.88 0.15 2981.01 0.75 351.94 2980.71 1.89 N 12.87 W 6.06 0.14 3076.17 0.62 349.70 3075.86 3.02 N 13.05 W 5.26 0.15 3172.68 0.63 40.97 3172.36 3.93 N 12.79 W 4.37 0.56 3267.96 0.98 53.05 3267.64 4.82 N 11.80 W 3.06 0.40 3364.40 0.92 51.89 3364.06 5.79 N 10.54 W 1.54 0.06 3462.70 0.90 47.42 3462.35 6.79 N 9.35 W 0.02 0.07 3559.68 0.80 51.38 3559.32 7.73 N 8.26 W -1.38 0.11 3656.85 0.59 119.19 3656.48 7.92 N 7.29 W -2.09 0.82 3752.83 0.70 143.78 3752.46 7.20 N 6.52 W -1.98 0.31 3846.84 0.61 153.08 3846.46 6.29 N 5.95 W -1.57 0.15 3946.98 0.47 164.25 3945.60 5.43 N 5.60 W -1.09 0.17 4042.88 0.31 202.19 4042.49 4.81 N 5.59 W -0.59 0.30 4139.75 0.51 209.28 4139.36 4.19 N 5.90 W 0.09 0.21 4236.39 0.51 227.83 4236.00 3.53 N 6.43 W 0.94 0.17 4332.84 0.59 253.90 4332.44 3.11 N 7.22 W 1.75 0.27 4429.81 0.67 265.43 4429.41 2.92 N 8.26 W 2.51 0.15 4523.03 0.86 262.50 4522.62 2.79 N 9.49 W 3.34 0.21 4619.31 0.72 252.18 4618.89 2.51 N 10.78 W 4.33 0.20 4715.12 0.17 161.05 4714.70 2.19 N 11.31 W 4.90 0.78 4811.23 0.14 78.45 4810.81 2.07 N 11.15 W 4.90 0.22 4906.59 0.25 72.78 4906.17 2.16 N 10.83 W 4.64 0.12 5003.88 0.47 47.89 5003.46 2.49 N 10.33 W 4.08 0.27 5098.92 0.28 23.72 5098.49 2.96 N 9.95 W 3.47 0.26 5195.93 0.48 16.46 5195.50 3.57 N 9.74 W 2.86 0.22 5293.19 0.62 20.21 5292.76 4.45 N 9.44 W 1.97 0.14 5389.37 0.74 9.43 5388.93 5.55 N 9.16 W 0.92 0.19 5484.73 1.27 10.27 5484.27 7.20 N 8.87 W -0.59 0.55 5581.02 1.20 2.73 5580.54 9.26 N 8.63 W -2.39 0.19 5677.85 1.13 4.26 5677.35 11.22 N 8.51 W -4.04 0.07 5776.09 1.08 10.84 5775.57 13.10 N 8.27 W -5.70 0.14 5968.47 0.25 111.14 5967.94 14.72 N 7.53 W -7.45 0.60 6066.00 0.48 164.64 6065.47 14.25 N 7.22 W -7.25 0.40 6158.75 0.62 158.21 6158.22 13.41 N 6.93 W -6.74 0.16 6255.20 0.50 141.63 6254.66 12.60 N 6.48 W -6.35 0.21 6345.24 0.47 132.77 6344.70 12.04 N 5.97 W -6.21 0.09 6440.05 0.57 116.29 6439.51 11.57 N 5.26 W -6.24 0.19 6535.23 0.62 102.63 6534.68 11.25 N 4.33 W -6.53 0.16 6724.63 0.55 103.65 6724.07 10.81 N 2.45 W -7.29 0.04 6818.17 0.28 212.56 6817.61 10.51 N 2.13 W -7.23 0.74 6915.48 0.36 228.05 6914.92 10.11 N 2.48 W -6.70 0.12 7010.32 0.28 237.77 7009.76 9.79 N 2.90 W -6.20 0.10 7105.60 0.31 260.94 7105.03 9.63 N 3.35 W -5.80 0.13 7296.41 0.31 316.86 7295.84 9.92 N 4.22 W -5.52 0.15 7390.78 0.25 300.20 7390.21 10.21 N 4.57 W -5.55 0.10 7485.45 0.37 308.20 7484.88 10.50 N 5.00 W -5.54 0.13 7580.60 0.31 327.26 7580.03 10.91 N 5.38 W -5.64 0.13 7678.53 0.35 359.83 7677.96 11.43 N 5.52 W -5.98 0.19 7774.48 0.31 68.01 7773.91 11.82 N 5.28 W -6.44 0.39 7869.46 0.59 109.45 7868.88 11.75 N 4.58 W -6.80 0.43 7964.88 0.45 96.86 7964.30 11.56 N 3.75 W -7.12 0.19 8059.26 0.50 69.16 8058.68 11.65 N 3.00 W -7.64 0.24 8155.10 0.57 66.70 8154.51 11.99 N 2.17 W -8.40 0.08 8249.09 0.17 90.82 8248.50 12.17 N 1.60 W -8.89 0.44 8344.16 0.17 126.48 8343.57 12.08 N 1.34 W -8.97 0.11 8439.10 0.26 94.33 8438.51 11.98 N 1.01 W -9.08 0.15 8534.84 0.25 98.41 8534.25 11.93 N 0.58 W -9.30 0.02 8629.81 0.33 80.72 8629.22 11.94 N 0.10 W -9.59 0.12 8725.06 0.50 65.09 8724.46 12.16 N 0.55 E -10.15 0.21 8820.00 0.66 64.98 8819.40 12.65 N 1.37 E -11.02 0.20 8914.67 0.69 61.82 8914.06 13.23 N 2.31 E -12.05 0.09 9009.27 0.77 58.86 9008.65 13.83 N 3.36 E -13.15 0.10 9103.60 0.72 55.76 9102.98 14.49 N 4.40 E -14.29 0.07 9198.27 0.75 54.77 9197.64 15.18 N 5.39 E -15.44 0.04 9291.82 0.72 52.91 9291.18 15.89 N 6.37 E -16.59 0.04 9362.00 0.72 52.91 9361.36 16.42 N 7.07 E -17.43 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 216.13 DEGREES (TRUE) ATOTAL CORRECTION OF 22.96 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 9362.00 FEET IS 17.88 FEET ALONG 23.29 DEGREES (TRUE) 0 7 J 0 SHOW REPORTS This section of the report contains copies of show evaluation reports for Caribou 26 -11 #1. These reports are based on chromatograph evaluations of gas samples from drilling mud and examination of drill cutting sample for fluorescence and cut. The show evaluations did not use a steam still apparatus to extract the gas for analysis and are so noted on the reports. Show reports are not always included in the well report analysis because of restricted information requirements placed on some exploration wells. They do offer some insight of fluid content on potential producing zones of good permeability; ' however, they are often inadequate on tight zones or when mud -gas samples are taken while coring. 11 r2perrV -sun Show Report 1 MUD LOGGING Depth Interval 7510 to 7560 DRILLING SERVICES True Vert. Depth 7510 to 7560 Prepared by J. Patton Operator Total E &P Delivered to Patrice Frere Well Name Caribou 26 -11 #1 Date 2/10/2004 Time 7:00 Location NPR -A North Slope, Alaska ZONE PRODUCTION ❑GAS [I OIL El WATER ONON- PRODUCTIVE HYDROCARBONS ----------------------------------------------------------------------------------------------------------------------------------------------------------------- CONTACT DEPTH Gas /Oil ft Gas/Water ft Oil/Water ft DEPTH 7524 ft GAS 1000 unit CHLOR. 31.5 k - --------------------------------------------------------------------- FLOWLINE - SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C, 64,497- = 64,49 C /C = 7 C 2 8,879 - = 8, C / C3 = 1 C3 5,079- = 5,0 Cl/C4 = 3 4 C4 1,904 - = 1,904 C1 /C5 = 64 C5 1,000 - = 1, ---------------------------------------------------------------------------------- PRODUCTION J J ❑ GAS ❑ OIL El WATER El NON-PROD. ANALYSIS DEPTH 7531 ft GAS 1200 unit CHLOR. 31.5 k ---------------------------------------------------------------------------------- FLOWLINE - SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C, 8 1,890 - = 8 Cl/C2 = 7 C Z 11,261- = 1 1,261 C /C = 11 C 3 7,132 - = 7, C /C4 = 32 C4 2,556 - = 2, C /C = 12 4 C S 663 - = 6 6 3 ---------------------------------------------------------------------------------- PRODUCTION J J ❑ GAS ❑ OIL El WATER El NON-PROD. ANALYSIS LITHOLOGY SANDSTONE -BUFF WHITE, LIGHT GRAY, GRAY, VERY FINE -FINE GRAIN, SUBANGULAR TO SUBROUND, MODERATELY SORTED, QUARTZ, FRIABLE TO SOMETIMES MODERATELY CEMENTED WITH CALCAREOUS CEMENT, OCCASIONAL CARBONACEOUS INCLUSIONS, FRIABLE TO FIRM, NO VISIBLE POROSITY, NO STAIN. GAS RATIOS ARE FROM TRAP - NOT STEAM STILL. SHOW EVALUATION BRIGHT VERY PALE YELLOW FLUORESCENCE COVERING MAJORITY OF SAMPLE. SLOW RESIDUAL MILKY WHITE CRUSH CUT FLUORESCENCE. COLOR CHANGES TO GOLD IN 7560' SAMPLE - NO CUT FLUORESCENCE. REMARKS MWD RESISTIVITY READINGS IN THIS ZONE RANGED FROM 14 -20 OHM - M2/M. HIGH BACKGROUND GAS READINGS. C1 /C2 RATIO ARE WELL WITHIN OIL RANGE. GAS/ VERY LIGHT OIL SHOW. OVERALL SHOW QUALITY IS POOR FOR LIGHT OIL. ZONE APPEARS TIGHT. 100 10 1 1,000 f[fIlm M 1 HYDROCARBON RATIOS C1 /C2 C1 /C3 Cl/C4 C1 /C5 HYDROCARBON RATIOS C1 /C2 C1 /C3 Ci /C4 C1 /C5 5pe1 7572 ft GAS Show Report 2 - --------------------------------------------------------------------- FLOWLINE -SUCTION = SHOW 'rV-su 1 MUD LOGGING Depth Interval 7560 to 7610 DRILLING 5 E RV I C 5 5 True Vert. Depth 7560 to 7610 C /C = 7 C Prepared by J. Patton Operator Total E &P Delivered to Patrice Frere Well Name Caribou 26 -11 #1 Date 2/10/2004 Time 8:00 Location NPR -A North Slope, Alaska 53 3- = 533 ZONE ❑GAS El OIL El WATER ❑� NON - PRODUCTIVE HYDROCARBONS PRODUCTION ----------------------------------------------------------------------------------------------------------------------------------------------------------------- CONTACT DEPTH Gas /Oil ft Gas/Water ft Oil/Water ft -------------------------------- - - - - -_ ------------------------------------------- FLOWLINE - SUCTION - SHOW HYDROCARBON ppm DEPTH 7572 ft GAS 1200 unit CHLOR. 31.5 k - --------------------------------------------------------------------- FLOWLINE -SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C, 74,304- = 7 4, 3 04 C /C = 7 C 10,474- = 10,47 Cl /C3 = 13 C 5, 808 - = 5,80 C /C = 36 C 2,063 - = 2,063 Cl = 1 C 53 3- = 533 ---------------------------------------------------------------------------------- PRODUCTION 21 GAS El OIL El WATER El NON-PROD. ANALYSIS DEPTH 7588 ft GAS 2000 unit CHLOR. 31.5 k -------------------------------- - - - - -_ ------------------------------------------- FLOWLINE - SUCTION - SHOW HYDROCARBON ppm ppm RATIOS C 139,944 - = 139, 944 C /C = 7 C 20, - = 20, 489 C /C = 10 C 14,029- = 1 4, 0 29 Cl /C4 = 26 C 5, 2 9 1 - = 5, 291 Cl /C5 = 95 C 1,470 - = 1, 47 0 ---------------------------------------------------------------------------------- PRODUCTION ❑ GAS ❑ OIL J J El WATER El NON-PROD. ANALYSIS LITHOLOGY SANDSTONE -LIGHT GRAY, GRAY, PREDOMINANTLY VERY FINE GRAINED, SUBANGULAR TO SUBROUND, MODERATELY WELL SORTED, QUARTZ, FRIABLE - MODERATELY CEMENTED WITH CALCAREOUS CEMENT, OCCASIONAL CARBONACEOUS INCLUSIONS, NO VISIBLE POROSITY, NO STAIN. GAS RATIOS ARE FROM TRAP - NOT STEAM STILL. SHOW EVALUATION BRIGHT VERY PALE YELLOW GREEN FLUORESCENCE. SLOW RESIDUAL MILKY WHITE CRUSH CUT FLUORESCENCE. REMARKS MWD RESISTIVITY READINGS IN THIS ZONE RANGED FROM 10 -20 OHM - M2/M. HIGH BACKGROUND GAS READINGS. C1 /C2 RATIO ARE WELL WITHIN OIL RANGE. GAS/ VERY LIGHT OIL SHOW. OVERALL SHOW QUALITY IS POOR FOR VERY LIGHT OIL. ZONE APPEARS TIGHT. HYDROCARBON RATIOS C1 /C2 C1 /C3 C1 /C4 C1 /C5 1,000 100 W! 10 r-n� r—r mmn 1 MI 10 1 HYDROCARBON RATIOS C1 /C2 C1 /C3 C1 /C4 C1 /C5 sperry -sun Show Report 3 HYDROCARBON ppm MUD LOGGING Depth Interval 7610 to 7625 D R I L L I N G 5 E R V I C E 5 True Vert. Depth 7610 to 7625 Cl/C3 = 11 C 1 7,17 6 - = Prepared by J. Patton Operator Total E &P Delivered to Patrice Frere Well Name Caribou 26 -11 #1 Date 2/10/2004 Time 9:00 Location NPR -A North Slope, Alaska ZONE ❑GAS El OIL ❑WATER 2 NON- PRODUCTIVE HYDROCARBONS PRODUCTION ppm ppm RATIOS ----------------------------------------------------------------------------------------------------------------------------------------------------------------- CONTACT DEPTH Gas /Oil ft Gas/Water ft Oil/Water ft 0 C 1 /C 3 = C3 - = DEPTH 7618 ft GAS 2000 unit CHLOR. 31.5 k - --------------------------------------------------------------------- FLOWLINE -SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C, 1 - = 182, 065 C /C = 7 C 27,376 - = 2 7,376 Cl/C3 = 11 C 1 7,17 6 - = 17, C /C = 30 C4 6,094 - = 6,094 Cl/C5 = 1 C5 1,699- = 1,699 --- ---- --- TIW ----------------------------------------------------------- --- - --- PRODUCTION ❑ GAS ❑ OIL J J El WATER El NON-PROD. ANALYSIS DEPTH ft GAS unit CHLOR. k ---------------------------------------------------------------------------------- FLOWLINE -SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C, = Cl/C2 = C 2 = 0 C 1 /C 3 = C3 - = Cl/C4 C = 0 C /C = C 5 = 0 F ----------------------------------- -------------------------------------------- PRODUCTION J J ❑ GAS ❑ OIL El WATER El NON-PROD. ANALYSIS LITHOLOGY SANDSTONE- LIGHT GRAY, LIGHT GRAY BROWN, VERY FINE -FINE GRAIN, SUBROUND- ANGULAR, MODERATELY SORTED, QUARTZ, MODERATELY CEMENTED WITH CALCAREOUS CLAY CEMENT, OCCASIONAL CARBONACEOUS INCLUSIONS, FRIABLE, POOR - NO VISIBLE POROSITY, NO STAIN. ABUNDANT CLAYSTONE IN SAMPLE. GAS RATIOS ARE FROM TRAP - NOT STEAM STILL. SHOW EVALUATION BRIGHT VERY PALE YELLOW FLUORESCENCE. SLOW RESIDUAL MILKY WHITE CRUSH CUT FLUORESCENCE. REMARKS MWD RESISTIVITY READINGS IN THIS ZONE REACHED 25 OHM -M2/M. HIGH BACKGROUND GAS READINGS. C1 /C2 RATIO ARE WELL WITHIN OIL RANGE. GAS/ VERY LIGHT OIL SHOW. OVERALL SHOW QUALITY IS POOR FOR LIGHT OIL. ZONE APPEARS TIGHT. HYDROCARBON RATIOS C1 /C2 C1 /C3 C1 /C4 C1 /C5 1,000 100 10 1 1,000 •. 10 1 HYDROCARBON RATIOS C1/C2 Cl/C3 Cl/C4 C1/C5 sperrV_sun Show Report MU_ D LOGGING Depth Interval DRILLING SERVICES True Vert. Depth Prepared by 7720 to 7720 to J. Patton 7890 7890 Operator Total E &P Delivered to ratrlce rrere Well Name Caribou 26 -11 #1 Date 2/10/2004 Time 11:00 Location NPR -A North Slope, Alaska ZONE El PRODUCTION GAS ❑ OIL ❑ WATER NON- PRODUCTIVE HYDROCARBONS ----------------------------------------------------------------------------------------------------------------------------------------------------------------- CONTACT DEPTH Gas /Oil ft Gas/Water ft Oil/Water ft DEPTH 7725 ft GAS 3000 unit CHLOR. 31.5 k - --------------------------------------------------------------------- FLOWLINE -SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C 175,663 - = 175, 663 C /C = 7 C2 26,885 - = 26,885 C /C = 12 C 1 - = 15, 115 C /C = 3 1 C 5,60 - = 5,600 WC = 108 C 1, - = 1,633 --- ---- --- -- ------------------------------------------------------------------ PRODUCTION NW ❑ GAS ❑ OIL J J El WATER El NON-PROD. ANALYSIS DEPTH 7825 ft GAS 2700 unit CHLOR. 31.5 k ---------------------------------------------------------------------------------- FLOWLINE - SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C 219,540 - = 21 9,540 C /C2 = 7 C 33,300 - = 33,300 C /C3 = 12 C 18,961 - = 18,96 C /C = 31 C 7,016 - = 7,016 C /C = 9 7 C 2, 260 - = 2,260 ---------------------------------------------------------------------------------- PRODUCTION ❑ GAS ❑ OIL J J El WATER El NON-PROD. ANALYSIS LI THOLOGY DSTONE- LIGHT GRAY BROWN, VERY FINE -LOWER MEDIUM GRAIN, NDED - ANGULAR, POORLY SORTED, QUARTZ, MODERATE TO SELY CEMENTED WITH CALCAREOUS CLAY CEMENT, ASIONAL CARBONACEOUS INCLUSIONS, FRIABLE, NONE TO ,E VISIBLE POROSITY, VERY LIGHT BROWN FILM ON CUTTINGS - CHEMICAL STAIN ?. SHOW EVALUATION DULL PALE YELLOW GREEN FLUORESCENCE. SLOW RESIDUAL MILKY WHITE CRUSH CUT FLUORESCENCE. C4 +C5 ARE INCREASING THROUGH THE ZONE FROM RE- CYCLED GAS. REMARKS MWD RESISTIVITY READINGS IN THIS ZONE RANGED FROM 10 -20 OHM - M2/M. HIGH BACKGROUND GAS READINGS. C1 /C2 RATIO ARE WELL WITHIN OIL RANGE. GAS/ VERY LIGHT OIL SHOW. OVERALL SHOW QUALITY IS POOR FOR VERY LIGHT OIL. BETTER SHOW IN LOWER PART OF ZONE. ZONE APPEARS TIGHT. 1,000 100 10 1 1,000 •6 HYDROCARBON RATIOS C1 /C2 C1 /C3 C1 /C4 C1 /C5 HY DROCARBON RATIO Cl/C2 Cl/C3 C1/C4 C1/C5 10 1 WEEMENE fe������'J�� 5pe1"' r IV -sun Show Report 5 MUD LOGGING npnth intarvni pros to 9135 DRILLING SERVICES True Vert. Depth 9025 to 9134 - --------------------------------------------------------------------- FLOWLINE -SUCTION = SHOW HYDROCARBON Prepared by J. Patton Operator Total E &P Delivered to Patrice Frere Well Name Caribou 26 -11 #1 Date 2/11/2004 Time 21:00 Location NPR -A North Slope, Alaska C 2,733 - = ZONE El GAS 0 OIL E:1 WATER ❑� NON - PRODUCTIVE HYDROCARBONS PRODUCTION C /C = 16 2 C 253 - = ----------------------------------------------------------------------------------------------------------------------------------------------------------------- CONTACT DEPTH Gas /Oil ft Gas/Water It Oil/Water It DEPTH 9046 ft GAS 800 unit CHLOR. 31 k - --------------------------------------------------------------------- FLOWLINE -SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C, 41,013- = 41,0 C /C = 6 C 6, 605 - = 6,6 05 Cl/C3 = 15 C 2,733 - = 2,733 Cl/C4 = 45 C 921- = 9 21 C /C = 16 2 C 253 - = 25 3 ---------------------------------------------------------------------------------- PRODUCTION ❑ GAS ❑ OIL El WATER ❑ NON -PROD. ANALYSIS DEPTH 9104 It GAS 1900 unit CHLOR. 31 k ---------------------------------------------------------------------------------- FLOWLINE - SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C, 111,405- = 11 1,405 C /C2 = 6 C 19,767- = 1 9,767 C /C3 = 14 C 8,079 - = 8,0 79 C /C4 = 42 C4 2,633- = 2,633 C /C = 1 C 742- = 7 42 ---------------------------------------------------------------------------------- PRODUCTION ❑ GAS ❑ OIL E:1 WATER ❑ NON -PROD. ANALYSIS LITHOLOGY SILTSTONE- DARK BROWN, BROWN, GRAY BROWN, ROUNDED CUTTING, FRIABLE -VERY FRIABLE, SLIGHTLY CALCAREOUS, GLAUCONITIC IP., PYRITIC IP., TRACE CARB INCLUSIONS. SILTSTONE IS SUPPORTING GENERALLY <10% VERY FINE GRAINED ROUNDED - ANGULAR, QUARTZ, POOR - FAIR VISIBLE POROSITY, BROWN STAIN ON INDIVIDUAL GRAINS. SHOW EVALUATION NO VISIBLE FLUORESCENCE. NO CUT ON WET SAMPLE. MILKY WHITE RESIDUAL CRUSH CUT FROM DRIED SAMPLE. IN THE 9100 SAMPLE - MUCH OF THE SILTSTONE SUPPORTED 10 -20% VERY FINE GRAINED QUARTZ. 9095 -9105' APPEARS TO BE THE BEST PART OF THE ZONE. REMARKS MWD RESISTIVITY READINGS IN THIS ZONE WERE LOW RANGING FROM 3 -7 OHM /METERS. C1 /C2 RATIO ARE WELL WITHIN OIL RANGE. GAS/ VERY LIGHT OIL SHOW. OVERALL SHOW QUALITY IS POOR - FAIR FOR VERY LIGHT OIL. THE RESISITIVITY WAS TOO LOW FOR BETTER RATING. 1,000 100 10 1 1,000 100 10 1 HYDROCARBON RATIOS C1 /C2 Cl/C3 C1 /C4 C1 /C5 HYDROCARBON RATIOS C1 /C2 C1 /C3 C1 /C4 C1 /C5 Type Customer: TOTAL E &P USA, Inc Report No.: 1 s p e r ry -s u n w ell: Caribou 26 -11 #1 Date: 2/6/2004 3:30 Area: NORTH SLOPE, ALASKA Depth 2577 (units) Lease: WILDCAT Footage: 334 DRILLING SERVICES Rig: Job No.: NABORS 14E 2837527 Rig Activity: Report For: DRILLING JIM ROSE Connection ADT Morning Report —T_ Lag Down Pipe 240 Shale Density (gm /cc) — 6/9 Type Avg Max H2S Survey Data 0.06 Deg 3 _ Gas Gas (ppm) Lithology 80% 0% SD Size (inches) 5 1/2X12 (units) (units) Sample Depth 255 Drill ate r 75 -100 Background 40 70 0 Trip Chlorides Corrected "D" Exp. Jets 4x14 - 2x15 Connection U —T_ Lag Down Pipe 240 Shale Density (gm /cc) — 6/9 Trip _ __ T_ Lag Off Bottom 17 00 EWR (res) pH Flowline Temp �� egree Pressure (psi) TI Filt/Cake API 6.2 Footage 334.0 ORMATION PHI: TA PD Surf / DS (psi) 75 HTHP - Avg ft/hr 76.1 Ann / Bit (psi) 70/195 Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 1166 psi 8.7 ppg psi ppg ECD if 2� psi -- TU - 5 — ppg -- f 4� psi _76 p pg psi ppg Type KCL POLY Type FS 2653 3 _ Weight In 9.50 IADC Code �6C71 Size (inches) 5 1/2X12 5 1/2X1 Funnel Vis. 44 Size 5 Capacity (gal /stk) 379Q 3.590 PVNP 17 Jets 4x14 - 2x15 Pump Rate (stks /min) —T_ Gels — 6/9 Depth Out Flow Rate (gal /min) 45C pH 10.00 Rot. Hrs. .4 # Pressure (psi) TI Filt/Cake API 6.2 Footage 334.0 PD Surf / DS (psi) 75 HTHP - Avg ft/hr 76.1 Ann / Bit (psi) 70/195 Pm 0 Grade Jet Velocity (ft/sec) 153 Pf /Mf 8 Cost/ft Jet Impact (Ibs) 330 Chlorides (ppm) 28 RPM Bit HP (hhp) 25 Calcium (ppm) - TO WOB 38 70 HP Ratio/ HPM2 18% Oil/Water/Solids 5.4 Daily /Cum. Cost ANNUL Length (ft) Volume (bbls /ft) Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) D P /CSG 2236 0.0618 178 285 — 6PT0TF 0.0547 183 310 DC /OH 0.0259 375 395 PIPE D Drill String Casing DC HWDP 4" DP COND SURFACE OD (inches) 6.7500 4.0000 4.0000 160 � 0 ID (inches) 2.8757 L5, 0 34 8.9200 Cap (bbls /ft) __ lam �0 f�� �f6� 77 Disp (bbls /ft) U.M 0.0092 •0 Length (ft) - -_ T5_7 �8J$ X4 : — 109 ��— Weight (Ibs /ft) �(- 29.7 15.8 4 TU 0 Customer: TOTAL E &P USA,Inc Report No.: 2 s p e r ry -s r1 Well: Caribou 26 -11 #1 Date: 2/7/2004 4:00 Area: NORTH SLOPE, ALASKA Depth 3905 Lease: WILDCAT Footage: 1328 DRILLING SERVICES Rig: NABORS 14E Rig Activity: DRILLING Job No.: 2837527 Report For: JIM ROSE ADT Morning Report UGGINU DATA Avg Max H2S Survey Data 0.70 Deg Inc. at 3753' Gas Gas (ppm) Lithology 90% 0% SID (units) (units) Sample Depth 3850 Drill ate r 80-1 Background 60 74 0 Trip Chlorides Corrected "D" Exp. — N Connection 0 Lag Down Pipe Shale Density (gm /cc) Trip 0 Lag Off Bottom 1700 EWR (res) 9.00 Flowline Temp 80 eg�ee Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 1767 psi 8.7 ppg psi ppg ECD 120T psi �)� PP9 Psi .4� PP9 Psi PPg g ame - 00 .: .:: ; 1 Pump o Type Type FS 2653 3 _ I: Weight In 9.4+ IADC Code �6G`7 Size (inches) 5 1/2X12 5 1/2X12 Funnel Vis. 45 Size 8.5 r Capacity (gal /stk) 3.5� 759 ?. PV/YP 21 Jets 4x14 2x15 Pump Rate (stks /min) U b Gels 7/12/15 Depth Out Flow Rate (gal /min) 5 pH Rot. Hrs. Pressure (psi) 175 FilUCake API 5. Footage 334.0 PD Surf / DS (psi) 75 37 HTHP Avg it/hr 7 Ann / Bit (psi) 195 Pm Grade Jet Velocity (ft/sec) 5 Pf /Mf .0 Cost/ft Jet Impact (Ibs) 33 Chlorides (ppm) 29000 RPM 100 Bit HP (hhp) 25 Calcium (ppm) 340 WOB 3811 7.0 HP Ratio / HP /in2 177. Oil/Water /Solids f- 0 /6. ii Daily /Cum. Cost Length (ft) Volume (bbls /ft) Velocity (ft/min) Crit -Vel (ft/min) Ann -Vol (bbls) DP /CSG 2236 0.0618 178 305 � 12 0.0547 183 325 DC /OH 0.0259 375 410 Drill String Casing DC HWDP 4" DP COND SURFACE .11 OD (inches) 6.7500 4.0000 4.0000 16.0000 ID (inches) 2.8750 Ott (T 8�J26)� Cap (bbls /ft) X0.0 80 Disp (bbls /ft) 0.0092 �� Length (ft) 257 Lam— — <: Weight (Ibs /ft) 29.7 407 REMARKS AND RECOMMENDATION 475 x:..::. 14 0 11, AUGER OVERFLOW. GAS READINGS INCREASE ROP TO 120 FT/HR MAX FROM 32 MAX ROP ARE NORMAL. NO CHANGE IN PORE PRESSURE PARAMETMTS. FOR OPTIMUM DATA DENSITY FOR LWU I UUL, ADT Representative JOHN PATTON 0 J sperry -s DRILLING SERVICES ADT Morning Report Customer: TOTAL E &P USA,Inc Report No.: 3 Well: Caribou 26 -11 #1 Date: 2/8/2004 4:00 Area: NORTH SLOPE, ALASKA Depth 4593 Lease: WILDCAT Footage: 688 Rig: NABORS 14E Rig Activity: DRILLING Job No.: 2837527 Report For: JIM ROSE Type Avg Max H2S Survey Data 0.86 Deg Inc. at 4523' 3 _ Weight In Gas Gas (ppm) Lithology 90% 10% SD 5 1/2X12 5 1/2X12 - T. - 570 - Funnel Vis. (units) (units) Sample Depth 4590 Drill ate r 80-120 Background 50 76 0 Trip Chlorides Pump Rate (stks /min) Corrected "D" Exp. 65 Connection 0 Depth Out Lag Down Pipe 515 Shale Density (gm /cc) _T6_7_ Trip _ 6_3 -� Lag Off Bottom 2900 EWR (res) __ Flowline Temp 80 deg PD Surf / DS (psi) 75/1370 HTHP - Avg ft/hr 83.6 Ann / Bit (psi) I I 07T00 Pm 0 Grade Jet Velocity (fUsec) 15 Pf /Mf Casing Bottom Hole Open Hole Jet Impact (Ibs) Pore Pressure 1011 psi 8.7 ppg 1767 psi 8.7 ppg psi ppg ECD TT 5_ psi 172 ppg --- 2476" - psi -7 -0 ppg psi ppg Type KCL POLY Type FS 2653 3 _ Weight In 9.30 IADC Code Size (inches) 5 1/2X12 5 1/2X12 - T. - 570 - Funnel Vis. 44 Size .5 Capacity (gal /stk) 3.5J�0 PVNP 8 Jets 4x14 - 2x15 Pump Rate (stks /min) 63 65 Gels 672/17 Depth Out Flow Rate (gal /min) _T6_7_ pH _____9.00 Rot. Hrs. Pressure (psi) 00 Filt/Cake API 5. Footage 2250.0 PD Surf / DS (psi) 75/1370 HTHP - Avg ft/hr 83.6 Ann / Bit (psi) I I 07T00 Pm 0 Grade Jet Velocity (fUsec) 15 Pf /Mf TM.5 Cost/ft _ Jet Impact (Ibs) 330 Chlorides (ppm) ---- TO 0 0 RPM Bit HP (hhp) Calcium (ppm) ��_ WOB 5 HP Ratio/ HP /in2 °o Oil/Water /Solids 0.5/92/5. Daily /Cum. Cost Length (ft) Volume (bbls /ft) Velocity (ft/min) Crit -Vel (ft/min) Ann -Vol (bbls) DP /CSG 2236 0.0618 182 316 D?70TT 1 0 0.0547 200 325 DC /OH 0.0259 385 430 lNl Drill String Casing DC HWDP 4" DP COND SURFACE OD (inches) 6.7500 4.0000 4.0000 16.000 �.6 52 0 ID (inches) 8.8750 �5 Ul7 -- T.7 - 55 8._9 0T Cap (bbls /ft) 0.008U 0064 .0 0 07773 Disp (bbls /ft) 0.0 2 0.0092 U.UU41 7 Length (ft) 5' 7 38 109 Weight (Ibs /ft) TO 29.7 15.8 4 -0-.T- - 1 sperry - sun DRILLING SERVICES ADT Morning Report Customer: TOTAL E &P USA,Inc Report No.: Well: Caribou 26 -11 #1 Date: Area: NORTH SLOPE, ALASKA Depth Lease: WILDCAT Footage: Rig: NABORS 14E Rig Activity: Job No.: 2837527 Report For: 4 2/9/2004 4:00 6225 1632 DRILLING JIM ROSE Type KCL POLY Weight In 9.40 Funnel Vis. _ 4 PVNP 16/19 Gels 6/15/2 pH 9.00 Filt/Cake API HTHP - Pm _ Pf /Mf Chlorides (ppm) 3150 Calcium (ppm) 240 Oil/Water /Solids 6 Daily /Cum. Cost DP /CSG �7Z5F� DC /OH — 5-7 0.0259 403 450 Avg Max H2S Survey Data 0.86 Deg Inc. at 4523' HWDP 4" DP OD (inches) 6.7500 Gas Gas (ppm) Lithology 5 °° - /° 0 ° SD x.5600 3.340 Cap (bbls /ft) (units) (units) Sample Depth 6150 Drill ate r 100 20 0.0092 Background 70 95 0 Trip Chlorides Corrected "D" Exp. Weight (Ibs /ft) Connection �— Lag Down Pipe 695 Shale Density (gm/cc) �A Avg ft/hr 83.6 ;i Trip 163 �— Lag Off Bottom 4300 EWR (res) 7. 0� Jet Velocity (ft/sec) Flowline Temp 93 eg�ree F Jet Impact (Ibs) 345 RPM 100 Bit Hsi (/in2) 1.01 WOB - 15 HP Ratio .,:., :.::..:....::.....:.:...:: ... .................... ........ . ANNULAR UATP Length (ft) Volume (bbls /ft) ::::.:.:.:....:: Ann -Vol (bbls) Casin Bottom Hole Open Hole --- 0.0547 Pore Pressure 1011 psi 8.7 ppg 2816 psi 8.7 ppg psi ppg — 85 psi psi 1 PP9 Psi ��� PP9 Psi PP9 Type KCL POLY Weight In 9.40 Funnel Vis. _ 4 PVNP 16/19 Gels 6/15/2 pH 9.00 Filt/Cake API HTHP - Pm _ Pf /Mf Chlorides (ppm) 3150 Calcium (ppm) 240 Oil/Water /Solids 6 Daily /Cum. Cost DP /CSG �7Z5F� DC /OH — 5-7 0.0259 403 450 Casing COND SURFACE 16.0000 6 5 773 -- TUTT7 — 109 ffgT 4UT Type FS 2653 Drill String DC HWDP 4" DP OD (inches) 6.7500 4.0000 4.0000 ID (inches) — .8� x.5600 3.340 Cap (bbls /ft) 0.0 - 070 - 9'Z — — ET6_ Disp (bbls /ft) Depth Out 0.0092 •0 Length (ft) 99 ___ 567_T_ Weight (Ibs /ft) 29.7 — Casing COND SURFACE 16.0000 6 5 773 -- TUTT7 — 109 ffgT 4UT Type FS 2653 IADC Code Size (inches) 5 1/2X12 5 1/2X12 Size — 8 Capacity (gal /stk) 3.50T 9 Jets 4x14 - 2x15 Pump Rate (stks /min) — ET6_ 68 Depth Out Flow Rate (gal /min) Rot. Hrs. 8.1 Pressure (psi) T 25db Footage 2250.0 PD Surf / DS (psi) ______ 750/225 75/2050 Avg ft/hr 83.6 Ann / Bit (psi) Grade Jet Velocity (ft/sec) 1 Cost/ft Jet Impact (Ibs) 345 RPM 100 Bit Hsi (/in2) 1.01 WOB - 15 HP Ratio 9% ANNULAR UATP Length (ft) Volume (bbls /ft) Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) 2236 0.0618 189 330 --- 0.0547 209 340 Customer: sperry -sun Weil: Area: Lease: DRILLING SERVICES Ri Job No.: ADT Morning Report TOTAL E &P USA,Inc Report No.: Caribou 26 -11 #1 Date: NORTH SLOPE, ALASKA Depth WILDCAT Footage: NABORS 14E Rig Activity: 2837527 Report For: 5 2/10/2004 4:00 7445 1220 DRILLING JIM ROSE Type KCL POLY Avg Max H2S Survey Data 0.31 Deg Inc. at 7296' 4 PVNP 7 Gels Gas Gas (ppm) Lithology 50% 0 °° 0 °° SID 5. HTHP 68 (units) (units) Sample Depth 7350 Drill Rate r 100-120 315 Background 60 3000 na Trip Chlorides Corrected "D" Exp. 75/2505 Avg ft/hr 89.5 Connection lb.d 85 5 Lag Down Pipe 835 Shale Density (gm /cc) 1 63 Trip Jet Impact (lbs) 0 Lag Off Bottom 5200 EWR (res) 9.ou Flowline Temp — egree 8% UAIA Length (ft) Volume (bbls/ft) F MAI ION PRESSURE OR Ann -Vol (bbls) 2236 0.0618 189 308 Casing Bottom Hole Open Hole i Pore Pressure 1011 psi 8.7 ppg 3368 psi 9.3 ppg psi ppg ECD 1�� psi 10.5 ppg >� psi __T6.5__ ppg psi ppg Type KCL POLY Weight In 10.00 Funnel Vis. 4 PVNP 7 Gels 7 pH 9. Filt/Cake API 5. HTHP 68 Pm Flow Rate (gal /min) Pf /Mf .05 Chlorides (ppm) 315 Calcium (ppm) 28 Oil/Water /Solids 0.5/89/8.0 Daily /Cum. Cost 75/2505 fl �1R59 DC /OH Type FS 2653 — � 3 IADC Code Size (inches) 5 1/2X12 5 1/2X12 - Size T5 Capacity (gal /stk) 3.59T T596 _-_ _ Jets 4x14 - 2x15 Pump Rate (stks /min) 3.340 68 Depth Out Flow Rate (gal /min) � �U Rot. Hrs. Pressure (psi) —5F00 Footage 2250.0 PD Surf / DS (psi) __Z 75/2505 Avg ft/hr 89.5 Ann / Bit (psi) lb.d 85 5 Grade Jet Velocity (ft/sec) 1 63 Cost/ft Jet Impact (lbs) 355 RPM Bit Hsi (/in2) 1.06 WOB 5 HP Ratio 8% UAIA Length (ft) Volume (bbls/ft) Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) 2236 0.0618 189 308 52 0.0547 209 316 435 0.0259 403 450 Casing COND SURFACE 16.0000 � 0 0 .077 �0. 127 109 4 — � 1 Drill String DC HWDP 4" DP OD (inches) 6.7500 4.0000 4.0000 ID (inches) — 2 8 X00 3.340 Cap (bbls /ft) U 64 � Disp (bbls /ft) ___TUT6_2 0.0092 Length (ft) -- 5-7 ___T9B __Z Weight (lbs/ft) 29.7 lb.d Casing COND SURFACE 16.0000 � 0 0 .077 �0. 127 109 4 — � 1 N� ��� N�NN�� ��0�p��N N �� m � DRILLING SERVICES ADTMomhmgReport Customer: TOTAL E8PUGA.|no Report No.: Well: Caribou 26-11 #1 Date: Area: NORTH SLOPE, ALASKA Depth Lease: WILDCAT Footage: Rig: NABORS 14E Rig Activity: Job No.: 2837527 Report For: G 2/11/2004 4:00 DRILLING MIKE WHITS Y oP/CxSo Length (ft) -- _T57 -- Volume (bbis/ft) Velocity (ft1nin) Crit-Vel (ft/min) 0.0618 189 315 0.0547 209 321 0.0259 403 445 Typo Avg max DEPTH Survey Data 0.69 Deg Inc. at 8914' OD (inches) e.7500 Weight In 4.0000 --------- Gas Gas u�o Lithology 50% SHALE - 50% SILTSTONE --- 7��D� - punna|vis. 45 Size (units) (units) oo"" """" Sample Depth 8980 Drill Rate (ft/hr) 60-120 ��� Background 250 3000 @7725 Trip Chlorides oo|o Corrected "D" Exp. Depth Out Connection 48u Lag Down Pipe 1037 Shale Density (gm/cc) A .: Trip Fi|vcauoAp| roo�oo Po Surf /oa(psV zmurro Flowline Temp HT*P 9.8 Avnom, 9 Ann /Bit (pui) 215m35 Pm Grade Jet v | i ��oo) �no p«M' Cost/ft Jet Impact uo) noo omonuoo(ppm) Casing Bottom Hole Open Hole ...!i Pore Pressure 1011 psi 8.7 ppg 4401 psi 9.4 ppg psi ppg o.nmo.om.o ECD 16 psi Daily/Cum. Cost ppg oP/CxSo Length (ft) -- _T57 -- Volume (bbis/ft) Velocity (ft1nin) Crit-Vel (ft/min) 0.0618 189 315 0.0547 209 321 0.0259 403 445 Typo uULpuLv Type DC *vvop -_-_- --___---- OD (inches) e.7500 Weight In 4.0000 --------- �m000ua poc/�o/o* u�o ����� 5 1/2X12 Cap (um --- 7��D� - punna|vis. 45 Size 85' Cavauvmumu oo"" """" Length � y� ---57 -- � pv»/P �����1mo� ��� Pump Rate (noms/mm) oo|o Depth Out Flow Rate (gaVmm) 48u pH no,.nm. Pnmou,o(poi) a000 Fi|vcauoAp| roo�oo Po Surf /oa(psV zmurro HT*P 9.8 Avnom, 9 Ann /Bit (pui) 215m35 Pm Grade Jet v | i ��oo) �no p«M' Cost/ft Jet Impact uo) noo omonuoo(ppm) RPM Bit Hsi Nnu> 1.06 Camium(ppm) 300 vvoo HP Ratio om oi|xwamr/oonuv o.nmo.om.o Daily/Cum. Cost oP/CxSo Length (ft) -- _T57 -- Volume (bbis/ft) Velocity (ft1nin) Crit-Vel (ft/min) 0.0618 189 315 0.0547 209 321 0.0259 403 445 Casing oomo aunpAos — �DZ_ff — _9.ZT5T_ ------ TgTo�______ __T97_7T_ _UTTT7_ _109__ 2T3__F_ Ann-Vol (bbls) Drill String DC *vvop 4" DP OD (inches) e.7500 4.0000 4.0000 --------- ID � --- 2�7S0 - --- �5�0 - ---T��T- ---7DJ��- --------- Cap (um --- 7��D� - -- 7D�Z�' oiop(umo/ft) --- 7DUTR% - 0 --- O]�*7 Length � y� ---57 -- � ----7��-- Weight (lbs/ft) 29.7 Casing oomo aunpAos — �DZ_ff — _9.ZT5T_ ------ TgTo�______ __T97_7T_ _UTTT7_ _109__ 2T3__F_ Ann-Vol (bbls) � sperry - sun DRILLING SERVICES Customer: TOTAL E &P USA,Inc Report No.: 7 Well: Caribou 26 -11 #1 Date: 2/12/2004 4:00 Area: NORTH SLOPE, ALASKA Depth 9362 Lease: WILDCAT Footage: 358 Rig: NABORS 14E Rig Activity: DRILLING Job No.: 2837527 Report For: MIKE WHITELY Casing Pore Pressure 1011 psi 8.7 ppg ECD X220 psi 10.5 ppg Type KCL POLY Weight In 10.20 Funnel Vis. ___T8_75 PVNP 18/14 Gels 7/26/28 _ pH 9.00 — Filt/Cake API 5.8 HTHP 10. Pm Capacity (gal /stk) _ Pf /Mf 20/2.8 Chlorides (ppm) 32000 _ — Calcium (ppm) 120 Oil/Water /Solids 0.5/88 Daily /Cum. Cost Flow Rate (gal /min) DP /CSG DC /OH Bottom Hole Open Hole 4381 psi 9.0 ppg psi ppg — i - T2 -- psi 10.5 ppg psi ppg i� 2 DC OD (inches) 6.7500 ID (inches) ___T8_75 Cap (bbls /ft) �0. $7 Disp (bbls /ft) .03 Length (ft) 898 Weight (Ibs /ft) 0 Bottom Hole Open Hole 4381 psi 9.0 ppg psi ppg — i - T2 -- psi 10.5 ppg psi ppg i� 2 HWDP Humps i ct 1 bUU z Ut i nUU Type FS 2653 T74 0.00UT — 3 _ IADC Code _PDC7MU= 898 Size (inches) 5 1/2X12 5 1/2X12 Size 8.5 Capacity (gal /stk) 3.5 T 3�. go Jets 4x14 - 2x15 Pump Rate (stks /min) 66 — T8__ Depth Out 936. Flow Rate (gal /min) �$0 Rot. Hrs. 78.8 Pressure (psi) — '3'0� Footage 7119.0 PD Surf / DS (psi) 75/2775 Avg ft/hr 90.1 Ann / Bit (psi) 5 Grade 3 - - - Jet Velocity (ft/sec) Cost/ft Jet Impact (Ibs) 355 RPM � 0� I Bit Hsi ( /in2) WOB 8-15 HP Ratio 0 Length (ft) Volume (bbls /ft) Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) 2236 0.0618 189 278 69 0.0547 209 291 — 5 0.0259 403 395 Drill String HWDP 4" DP 4.0000 4.0000 .5600 T74 0.00UT . 08 0.0092 898 -- TM7 — 29.7 — 5� Casing COND SURFACE 7=_ Jam. 5(_ T. 2�S _ . 77 T Tf — 27 109 47-0— I� i sperry -sun DRILLING SERVICES ADT Morninq Report Customer: TOTAL E &P USA,Inc Report No.: Well: Caribou 26 -11 #1 Date: Area: NORTH SLOPE, ALASKA Depth Lease: WILDCAT Footage: Rig: NABORS 14E Rig Activity: Job No.: 2837527 Report For: 8 2/13/2004 5:00 9362 0 CONDITION HOLE MIKE WHITELY Survey Data 0.69 Deg Inc. at 8914' Lithology 50% SHALE - 50% SILTSTONE Sample Depth 9360 Drill ate r 0 Trip Chlorides Corrected "D" Exp. Lag Down Pipe 1055 Shale Density (gm /cc) ___17T__ Lag Off Bottom 6400 EWR (res) x.00 Bottom Hole 4381 psi 9.0 ppg psi — 1= ppg Open Hole psi ppg Psi PPg Avg Max DEPTH 68 — Gas Gas s' Weight In 10.20 (units) (units) ID (inches) Background 100 — U_ 2020 F/ TRIP Connection 8.5 Capacity (gal /stk) Trip TO 0 Jets Flowline Temp 97 egg ree F Weight (Ibs /ft) T= Gels 5 Depth Out 9T6'£- Flow Rate (gal /min) Casing Pore Pressure 1011 psi 8.7 ppg ECD f2_20 psi psi — TT_5___ ppg 8 2/13/2004 5:00 9362 0 CONDITION HOLE MIKE WHITELY Survey Data 0.69 Deg Inc. at 8914' Lithology 50% SHALE - 50% SILTSTONE Sample Depth 9360 Drill ate r 0 Trip Chlorides Corrected "D" Exp. Lag Down Pipe 1055 Shale Density (gm /cc) ___17T__ Lag Off Bottom 6400 EWR (res) x.00 Bottom Hole 4381 psi 9.0 ppg psi — 1= ppg Open Hole psi ppg Psi PPg Length (ft) Type Type FS 2653 68 — 0.0547 3 _ s' Weight In 10.20 IADC Code 4.0000 ID (inches) Size (inches) 5 1/2X12 5 1/2X12 400 Funnel Vis. 47 Size 8.5 Capacity (gal /stk) 3.536ls 0.0092 PVNP Jets _ 4x14 2x15 �0- Pump Rate (stks /min) Weight (Ibs /ft) T= Gels 5 Depth Out 9T6'£- Flow Rate (gal /min) P H 9.00 Rot. Hrs. Pressure (psi) _76 !'! Filt/Cake API 4.8 Footage PD Surf / DS (psi) 75/1225 HTHP Avg ft/hr Ann /Bit (psi) 175/125 1 Pm Grade Jet Velocity (ft/sec) 1 i Pf /Mf An Cost/ft Jet Impact (Ibs) 55 Chlorides (ppm) 1 RPM Bit Hsi ( /in2) .6 Calcium (ppm) 320 WOB HP Ratio 8% _ Oil/Water /Solids 0.5/88 Daily /Cum. Cost Length (ft) Volume (bbls/ft) DP /CSG 2236 0.0618 68 — 0.0547 DC /OH 17T__ 0.0259 Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) 138 246 152 254 295 375 Casing COND SURFACE 16.0000 50 X926( - 77 109 — 2� ZZ— Drill String DC HWDP 4" DP OD (inches) 6.7500 4.0000 4.0000 ID (inches) 2.8756 ___ T56U0 _ 400 Cap (bbls /ft) X0080 Disp (bbls /ft)s 0.0092 — 0.6047 Length (ft) —�� �0- -- Weight (Ibs /ft) T= 29.7 15 Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) 138 246 152 254 295 375 Casing COND SURFACE 16.0000 50 X926( - 77 109 — 2� ZZ— 7 sperry -su DRILLING SERVICES ADT Morning Report Customer: TOTAL E &P USA,Inc Report No.: Well: Caribou 26 -11 #1 Date: Area: NORTH SLOPE, ALASKA Depth Lease: WILDCAT Footage: Rig: NABORS 14E Rig Activity: Job No.: 2837527 Report For: 9 2/14/2004 4:00 9362 0 E -LOG MIKE WHITELY Type Avg Max DEPTH Survey Data 0.72 Deg Inc. at 9292' 3 Gas Gas Lithology MODERATE AMOUNTS OF SHALE + (units) (units) Sample Depth ON TRIP Drill ate r Background 80 200 F/ TRIP Trip Chlorides Corrected "D" Exp. —— Connection —� Lag Down Pipe 1055 Shale Density (gm /cc) Trip 277 — � - 8 Lag Off Bottom 6600 EWR (res) Flowline Temp 90 egree 48 _77 pH 9.60 Rot. Hrs. Pressure (psi) ..:..::. 4.6 Footage PD Surf / DS (psi) Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD __TT5_5 psi __TT_8 PPg __92_57T Psi _ PPg Psi PPg Type KUL PULP Type FS 2653 3 _ Weight In 10.40 IADC Code — �.5 Size (inches) 5 1/2X12 5 1/2X12 90 Funnel Vis. 46 Size Capacity (gal /stk) 3.59T . PVNP Jets 4x14 - 2x15 Pump Rate (stks /min) � 68 Gels 5 Depth Out 936 .0 Flow Rate (gal /min) 48 _77 pH 9.60 Rot. Hrs. Pressure (psi) Filt/Cake API 4.6 Footage PD Surf / DS (psi) 75/2195 HTHP 9.4 Avg ft/hr Ann / Bit (psi) 185/245 Pm 0 Grade Jet Velocity (ft/sec) 163 Pf /Mf .05/2.7 Cost/ft Jet Impact (Ibs) 4 Chlorides (ppm) X00 RPM 90 Bit Hsi (/in2) 1.10 Calcium (ppm) — 80 WOB HP Ratio 8% Oil/Water /Solids 0.5/87.5/9. Daily /Cum. Cost ANNULAR UAFAP Length (ft) Volume (bbls /ft) - i Velocity (ft/min) Crit Vel ( ft/m n ) Ann-Vol ( bbls ) DP /CSG 2236 0.0618 189 322 -- M70R — 0.0547 209 338 DC /OH— 0.0259 403 445 ri i MR SATA Drill String Casing DC HWDP 4" DP COND SURFACE OD (inches) 6.7500 4.0000 4.0000 .000 9. 50 ID (inches) 75 2.5 00 .3400 200 Cap (bbls /ft) �5 �00�� 77 — T27 Disp (bbls /ft)03� 0.0092 U 47— 0 Length (ft) __T� 109 727 Weight (Ibs /ft) f Uff. 29.7 1b.d sperry -sun DRILLING SERVICES istomer: TOTAL E &P USA,Inc Report No.: Well: Caribou 26 -11 #1 Date: Area: NORTH SLOPE, ALASKA Depth Lease: WILDCAT Footage: Rig: NABORS 14E Rig Activity: Job No.: 2837527 Report For: 10 2/15/2004 4:00 9362 0 E -LOG MIKE WHITELY ADT Morninq Report Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD � psi X0.8 ppg psi X0.8 ppg Psi ppg l Slr' iii Ime Avg Max DEPTH Survey Data 0.72 Deg Inc. at 9292' Type Gas Gas Lithology MODERATE AMOUNTS OF SHALE + 3 (units) (units) Sample Depth ON TRIP Drill ate r 0 Background 0 0 F/ TRIP Trip Chlorides Corrected "D" Exp. Connection �— 3.5�J(� Lag Down Pipe 1055 Shale Density (gm /cc) NA it Trip - - 0 — 'S.TRIP Lag Off Bottom 6600 EWR (res) Flowline Temp Depth Out egree Flow Rate (gal /min) Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD � psi X0.8 ppg psi X0.8 ppg Psi ppg l Slr' iii Ime 2/ 14/2004 22:00 Bit No. RR2 rumps i Lot 1bUU z ut Ibuv Type KCL POLY Type FS 2653 3 Weight In 10.4+ IADC Code — �6� Size (inches) 5 1/2X12 5 1/2X12 - Funnel Vis. Size — 8 r Capacity (gal /stk) 3.5�J(� PVNP Jets 414 - 2x15 Pump Rate (stks /min) --- Gels _ 5/1N27 Depth Out Flow Rate (gal /min) pH Rot. Hrs. REAMING _ Pressure (psi) Filt/Cake API 4.8 Footage PD Surf / DS (psi) NO CIRCULATION HTHP _ 9.6 Avg ft/hr — 0. Ann / Bit (psi) PAST 24 HIRT Pm Grade _ Jet Velocity (ft/sec) Pf /Mf . 5 Cost/ft Jet Impact (Ibs) Chlorides (ppm) 32000 — RPM Bit Hsi ( /in2) Calcium (ppm) 300 — WOB 0 HP Ratio Oil/Water /Solids 0.5/87.5 Daily /Cum. Cost iii ...:....... �.. Length (ft) Volume (bbls /ft) Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) D P /CSG 2236 0.0618 322 �p7 6— gT 0.0547 338 DC /OH 0.0259 445 .!yiififf� is�! Drill String ! ! Casing DC HWDP 4" DP COND SURFACE OD (inches) 6.7500 4.0000 4.0000 1660 __ L5_17 ID (inches) 2.8750 --- T. - 5 MU 3.3400 Cap (bbls/ft) — 0.0= __ — �g — •077 Disp (bbls /ft) --- Tb36T_ 0.0092 U.Ub41 Length (ft) T7',- ----- 999 -- TTT7 -- 109 Weight (Ibs /ft) ---- TU.T — 29.7 --- � 0 r-, L 1 Customer: TOTAL E &P USA,Inc Report No.: 11 s p e r ry -s u Well: Caribou 26 -11 #1 Date: 2/16/2004 4:0 W. Area: NORTH SLOPE, ALASKA Depth 9362 Lease: WILDCAT Footage: 0 DRILLING SERVICES Rig: NABORS 14E Rig Activity: FISHING Job No.: 2837527 Report For: MIKE WHITELY ADT Morning Report I LOGUINU UA I A Avg Max DEPTH Survey Data 0.72 Deg Inc. at 9292' Gas Gas Lithology MODERATE AMOUNTS OF SHALE + (units) (units) Sample Depth Drill ate r e Background 0 25 F/ 3000' Trip Chlorides Corrected "D" Exp. 1 Connection 0 Lag Down Pipe 1055 Shale Density (gm /cc) Trip 25 Lag Off Bottom 6600 EWR (res) Flowline Temp egree ION PRESSUR Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD " — psi Pp9 psi ppg psi PP9 :!,.. 1 ifi 11:1 I Ime is 5i2U04 22M Lilt NO. !:; i:ir is !!iillill!111 umps 1 Ut 1600 ,.r I! UP ijisl � Type Type FS 2653 1' Weight In 10.4+ IADC Code Size (inches) 5 1/2X12 5 1/2X12 Funnel Vis. _ Size 9 .5 Capacity (gal /stk) 3 �� PV/YP 23 Jets 4x14 - 2x15 Pump —� p Rate ( stks /min ) 75 Gels 7 Depth Out ___9STT0 Flow Rate (gal /min) pH — 9..00 Rot. Hrs. REAMING Pressure (psi) Filt/Cake API — 4.5 Footage PD Surf / DS (psi) `!! HTHP 9.8 Avg ft/hr Ann / Bit (psi) €' Pm 0 Grade Jet Velocity (ft/sec) Pf /Mf .055T $— Cost/ft Jet Impact (Ibs) '1 Chlorides (ppm) 32000 RPM Bit Hsi ( /in2) [! Calcium (ppm) 280 WOB r HP Ratio Oil/Water /Solids 0.5/87.5/9.6 Daily /Cum. Cost : yi ' i fi iif 111 .��.:....:::..........:.., Jiro ......................... ....::..:..:.:......:..: Length (ft) Volume (bbls /ft) .un:1! . r ! ........... ....... .... ::.:....:.».: .�::�::�::�:.:.:............... .r. . . Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) DP /CSG 2236 0.0618 322 , 1T — 86_9 0.0547 338 DC /OH 0.0259 445 •!:!91111:![!11: U.� , .,::11'r��'rs:z: z ; . >.,s �:'::s'::�� ^.. ..:... ::'. ,............ ..I.I1n•, .:�;�:; .......:' ,.::. P IPF DATA ...... Drill String I!I, ..�::.. , :.::,i:i:!:!!i .........:........::.......:... . Casing is DC HWDP 4" DP COND SURFACE ji OD (inches) 6.7500 4.0000 4.0000 16.0000 — 3 - b'T5= 6 j ID (inches) 0� Cap (bbls /ft) �i)7 3� �! Disp (bbls /ft) __76'i 0.0092 Length (ft) 632 — 109 Weight (Ibs /ft) I... 29.7 ...... . I. . ., ::.......... .............. rr.:. .. r..l.:. 475 x r r .,i9:!:e 1111 ! WINE : 1 ! 111 111 !1!!!i • ;1111!:: : �Id HAUI Fi epr esentative JOHN PATTON 1 sperr -sun Customer: TOTAL E &P USA,Inc Report No.: Well: Caribou 26 -11 #1 Date: Area: NORTH SLOPE, ALASKA Depth Lease: WILDCAT Footage: Rig: NABORS 14E Rig Activity: Job No.: 2837527 Report For: 12 2/17/2004 4:00 9362 0 CONDITION HOLE MIKE WHITELY DRILLING SERVICES ADT Morning Report Avg Max DEPTH Survey Data 0.72 Deg Inc. at 9292' Gas Gas Lithology MODERATE AMOUNTS OF SHALE + (units) (units) Sample Depth ON TRIP Drill ate r 0 Background 0 1428 F/ 9362' Trip Chlorides Corrected "D" Exp. Connection 0 Lag Down Pipe 1055 Shale Density (gm /cc) Trip —�— Lag Off Bottom EWR (res)� M Flowline Temp — 1OF egg ree Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD — 7279 — psi -- TT.T — ppg '' S psi -- TT 7 i7 — ppg psi ppg ]me 2/1 b/21J04 22:00 bit No. 3 M M i Fumps I UL 1600 2 UL 160U Type KGL PUL 7 Type MP7303 Weight In 10.40 IADC Code Tv1TCCT _ Size (inches) 5 1/2X12 5 1/2X12 Funnel Vis. 51 Size 5 Capacity (gal /stk) 3.5ZSls53�6 PVNP Jets OPEN Pump Rate (stks /min) 70 Gels 81222 T Depth Out 9362.0 Flow Rate (gal /min) pH .5 Rot. Hrs. �iEA�I11 _ _ Pressure (psi)b Filt/Cake API �� Footage PD Surf / DS (psi) 76/2175 ! HTHP 8.5 Avg ft/hr -__ Ann / Bit (psi) 285IT5 Pm 0 Grade Jet Velocity (ft/sec) 65 Pf /Mf Cost/ft Jet Impact (Ibs) 7 Chlorides (ppm) 31000 RPM 120 Bit Hsi (/in2) 8 Calcium (ppm) 320 WOB HP Ratio a Oil/Water /Solids 0.5/8 7.5/9. 6 Daily /Cum. Cost i vd.. iiilfril .I Length (ft) Volume (bbls /ft) Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) DP /CSG 2236 0.0618 189 370 6960 0.0547 209 380 DC /OH 0.0259 405 540 ,.,. can ! I I ,., Drill String Casing DC HWDP 4" DP COND SURFACE OD (inches) 6.7500 4.0000 4.0000 T j ID (inches) Cap (bbls /ft) --- (T= 17 j Disp (bbls /ft) 0.0092 U.UU47 Length (ft) bti — tom 109 "' Weight (Ibs /ft) � 29.7 8 "i Casing Bottom Hole Open Hole Ilr Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD� psi 1 ppg 5355 psi — ppg psi ppg Type Weight In 10.40 Funnel Vis. PVNP _ 7 Gels - 812UJZi— pH 9.00 Filt/Cake API HTHP Pm Pf /Mf Chlorides (ppm) 315 Calcium (ppm) Oil/Water /Solids .5 Daily /Cum. Cost DP /CSG DC /OH DC OD (inches) 6.7500 ID (inches) Cap (bbls /ft)� Disp (bbls /ft)3�1 Length (ft) --- 7ZT Weight (Ibs /ft) ____T5T Drill String HWDP 4" DP 4.0000 4.0000 0.0092 U.UU47 29.7 1 0.0259 Size (inches) Capacity (gal /stk) Pump Rate (stks /min) Flow Rate (gal /min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (ft/sec) Jet Impact (Ibs) Bit Hsi ( /in2) HP Ratio 51/2X12 51/2X12 3MT 5 _ 75/2195 5 5 0 Velocity (ft/min) Crit -Vel (ft/min) Ann -Vol (bbls) 189 370 209 380 405 540 Casing COND SURFACE 16.0000 7— ___ 7U9_ 40.0 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg ft/hr Grade Cost/ft RPM WOB Length (ft) Volume (bbis /ft) 2236 0.0618 6 96� 0 0.0547 Customer: TOTAL E &P USA,Inc Report No.: 13 MiM sperry -su Well: Caribou 26 -11 #1 Date: 2/18/2004 4:00 Area: NORTH SLOPE, ALASKA Depth 9362 Drill ate r 0 Lease: WILDCAT Footage: 0 DRILLING SERVICES Rig: NABORS 14E Rig Activity: DP CONVEYED LOGS Shale Density (gm /cc) Job No.: 2837527 Report For: MIKE WHITELY ADT Morninq Report Flowline Temp OT egd ree Casing Bottom Hole Open Hole Ilr Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD� psi 1 ppg 5355 psi — ppg psi ppg Type Weight In 10.40 Funnel Vis. PVNP _ 7 Gels - 812UJZi— pH 9.00 Filt/Cake API HTHP Pm Pf /Mf Chlorides (ppm) 315 Calcium (ppm) Oil/Water /Solids .5 Daily /Cum. Cost DP /CSG DC /OH DC OD (inches) 6.7500 ID (inches) Cap (bbls /ft)� Disp (bbls /ft)3�1 Length (ft) --- 7ZT Weight (Ibs /ft) ____T5T Drill String HWDP 4" DP 4.0000 4.0000 0.0092 U.UU47 29.7 1 0.0259 Size (inches) Capacity (gal /stk) Pump Rate (stks /min) Flow Rate (gal /min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (ft/sec) Jet Impact (Ibs) Bit Hsi ( /in2) HP Ratio 51/2X12 51/2X12 3MT 5 _ 75/2195 5 5 0 Velocity (ft/min) Crit -Vel (ft/min) Ann -Vol (bbls) 189 370 209 380 405 540 Casing COND SURFACE 16.0000 7— ___ 7U9_ 40.0 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg ft/hr Grade Cost/ft RPM WOB Length (ft) Volume (bbis /ft) 2236 0.0618 6 96� 0 0.0547 Avg 9 ax DEPTH Survey Data 0.72 De Inc. at 9292' Y 9 Gas Gas Lithology MODERATE AMOONTS OF SHALE + (units) (units) Sample Depth ON TRIP Drill ate r 0 Background 0 20 Trip Chlorides Corrected "D" Exp. Connection — T Lag Down Pipe 1055 Shale Density (gm /cc) Trip NA —� Lag Off Bottom 6600 EWR (res) 2.0 Flowline Temp OT egd ree Casing Bottom Hole Open Hole Ilr Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD� psi 1 ppg 5355 psi — ppg psi ppg Type Weight In 10.40 Funnel Vis. PVNP _ 7 Gels - 812UJZi— pH 9.00 Filt/Cake API HTHP Pm Pf /Mf Chlorides (ppm) 315 Calcium (ppm) Oil/Water /Solids .5 Daily /Cum. Cost DP /CSG DC /OH DC OD (inches) 6.7500 ID (inches) Cap (bbls /ft)� Disp (bbls /ft)3�1 Length (ft) --- 7ZT Weight (Ibs /ft) ____T5T Drill String HWDP 4" DP 4.0000 4.0000 0.0092 U.UU47 29.7 1 0.0259 Size (inches) Capacity (gal /stk) Pump Rate (stks /min) Flow Rate (gal /min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (ft/sec) Jet Impact (Ibs) Bit Hsi ( /in2) HP Ratio 51/2X12 51/2X12 3MT 5 _ 75/2195 5 5 0 Velocity (ft/min) Crit -Vel (ft/min) Ann -Vol (bbls) 189 370 209 380 405 540 Casing COND SURFACE 16.0000 7— ___ 7U9_ 40.0 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg ft/hr Grade Cost/ft RPM WOB Length (ft) Volume (bbis /ft) 2236 0.0618 6 96� 0 0.0547 1 sp erry -sun Customer: TOTAL E &P USA,Inc Report No.: Well: Caribou 26 -11 #1 Date: Area: NORTH SLOPE, ALASKA Depth Lease: WILDCAT Footage: Rig: NABORS 14E Rig Activity: Job No.: 2837527 Report For: 14 2/19/2004 4:00 9362 0 SIDE WALL CORES MIKE WHITELY DRILLING SERVICES ADT Morning Report Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD 1279 ' psi _77.0 ppg 55 psi -- TT.7 — ppg psi ppg Type KCIL POLY Type MP7303 Avg Max DEPTH Survey Data 0.72 Deg Inc. at 9292' Weight In 10.4+ IADC Code _9EET6 Gas Gas Lithology + Funnel Vis. 57 Size — T5 (units) (units) Sample Depth ON TRIP Drill ate r PVNP Background 40 488 F/TRIP Trip Chlorides Corrected "D" Exp. Gels Connection —(� Flow Rate (gal /min) Lag Down Pipe Shale Density (gm /cc) !!ii pH Trip $ __Z_ Lag Off Bottom EWR (res)5 Filt/Cake API Flowline Temo �5 egree Casing Bottom Hole Open Hole Pore Pressure 1011 psi 8.7 ppg 4527 psi 9.3 ppg psi ppg ECD 1279 ' psi _77.0 ppg 55 psi -- TT.7 — ppg psi ppg Type KCIL POLY Type MP7303 3 Weight In 10.4+ IADC Code _9EET6 Size (inches) 5 1/2X12 5 1/2X12 - Funnel Vis. 57 Size — T5 Capacity (gal /stk) 3.5ZW — T - 5 T PVNP 2 97T5 Jets OPEN Pump Rate (stks /min) — Gels 7 Depth Out Flow Rate (gal /min) pH .5 Rot. Hrs. __TiEA1 - V Pressure (psi) -------- 7371595 Filt/Cake API 4.6 Footage PD Surf / DS (psi) HTHP 14.4 Avg ft/hr Ann / Bit (psi) 5 5 Pm 0 Grade Jet Velocity (ft/sec) 5 Pf /Mf Cost/ft Jet Impact (Ibs) 17 Chlorides (ppm) x330 RPM 100 Bit Hsi ( /in2) Calcium (ppm) — 300 WOB HP Ratio 2 Oil/Water /Solids 0.5/8 Daily /Cum. Cost ANNULAR Length (ft) Volume (bbls /ft) I Velocity (ft/min) Crit -Vel ( ft/min) Ann -Vol (bbls) DP /CSG 2236 0.0618 189 370 DT70Ffb 0.0547 209 380 DC /OH 166 0.0259 405 540 Drill String Casing DC HWDP 4" DP COND SURFACE _ OD (inches) 6.7500 4.0000 4.0000 16.0000 (7_ _ ID (inches) 75 �i� — J Cap (bbls /ft) __7Z6 77 _ Disp (bbls /ft) — 3b 0.0092 U.UU47 _ Length (ft) log Weight (Ibs /ft) � — 29.7 — .0 _
