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207-009
TIIL66LSTTTTr AI 01AAV —K—A— GOVERNOR MICHAEL J. DUNLEAVY August 23, 2019 President FEX Limited Partnership 888 3rd Street SW, Suite 3400 Calgary, AB T2P 5C5 Dear Sir or Madam: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.alaska.gov According to AOGCC records, FEX Limited Partnership has four permitted onshore wellheads that have been properly plugged and abandoned, but the well locations have not been cleared in accordance with 20 AAC 25.170 (see enclosed list). Please arrange clearance inspections by submitting an AOGCC Test Witness Notification form before December 1, 2019. This form is available online at the AOGCC website: http://doa.alaska.gov/ogc/forins/TestWitnessNotif html If you have any questions, please contact Ms. Jody Colombie at 907-793-1221 or jody.colombie(&alaska.gov or Mr. Dave Roby at 907-793-1232 or dave.roby(a,alaska.gov . Sincerely, Daniel T. Seamount, Jr. Je�S e L. Chmielowski Commissioner C is Enclosure: List of Permitted Wellheads without Location Clearance Inspections Alaska Oil and Gas Conservation Commission FEX Limited Partnership *EXPLORATORY 112051800 50-279-20014-00-00 ,AKLAQ 2 _ ,2006-04-10 P&A 2011-04-06 Loc Ready For Inspect *EXPLORATORY 2070090 ;50-279-20019-00-00 ;AKLAQ 6 2007-04-23 P&A 2011-03-25 Loc Ready For Inspect LEX�PIRA�®R�616500-279-20018-DODO AKLAQYAAQ1 2007-04-18 P&A2011-03-13 Loc RdFor Inspect 0-279-20017-00-00 �AMAGLIQ 2 2007-03-30 P&A 12007-03-30 ILoc Ready For Inspect Location Clearance 7/26/2019 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 12/17/2012 Permit to Drill 2070090 Well Name /No. AKLAQ 6 Operator FEX LIMITED PARTNERSHIP API No. 50- 279 - 20019 -00 -00 MD 7280 TVD 7280 Completion Date 4/23/2007 Completion Status SUSP Current Status P &A UIC N REQUIRED INFORMATION Mud Lo(1'e Samples --Nt5 �� $ Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: MWD Gamma, Resistivity, Neutron, Density, Sonic (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number ■ ame Scale Media No Start Stop CH Received Comments ED C Wrd 15151 - eport: Final Well R 99 7280 Open 5/24/2007 End of Well Report, Gen Info, Daily Summ, Daily Ops, Morning Rep, Bit Rec, Mu Rep, Show Rep, Survey Rep, Days Vs Dapth, Data CD's w /Graphics PDF, TXT, LAS, Word ED C Pdf 15152ti14ort: Final Well R Open 5/24/2007 ED C Las 15153 "Induction /Resistivity 0 7280 Open 5/24/2007 Electric Log Files, Quad Combo Logs, MD/TVD, ROP DGR CTN SLD ALD BAT MD/TVD, LAS, and Surveys ED C Pdf 15154 Final Well R 5/24/2007 Daily Drilling Reports Digitized ED C Pdf 15155 See Notes 5/24/2007 Surveys in PDF, Signed • / Well Completion Report Log/ Mud Log 2 Col 99 7280 Open 5/24/2007 Combo Surface Data MD Mud Log 14- Apr -2007 Log Induction /Resistivity 25 Col 342 7280 Open 5/24/2007 MD ROP, DGR, EWR, CTN, SLD, ALD, BAT 15- Apr -2007 Log /e. Mud Log 2 Col 99 7280 Open 5/24/2007 Engineering Log with Lithology 14- Apr -2007 Log Induction /Resistivity 25 Col 342 7280 Open 5/24/2007 TVD ROP, DGR, EWR, CTN, SLD, ALD, BAT 15- Apr -2007 DATA SUBMITTAL COMPLIANCE REPORT 12/17/2012 Permit to Drill 2070090 Well Name /No. AKLAQ 6 Operator FEX LIMITED PARTNERSHIP API No. 50- 279 - 20019 -00 -00 MD 7280 TVD 7280 Completion Date 4/23/2007 Completion Status SUSP Current Status P &A UIC N Rpt v Report: Final Well R 0 7280 Open End of Well Report, Ops overview, bitrun info, survey data, aars & svc interrupts Rpt Report: Final Well R 0 7280 Surface Data Logging, End of Well Report ED C ✓- 15386 Analysis - Misc 0 0 Open 9/6/2007 Humble Geochemical Services Report: Source Rock and Fluid • Geochemistry of the Aklaq #6 Well w /Digital Graphics in PDF ED 15387 Sample 0 0 Open 9/6/2007 Digital Imaging w/White UV slabs photography a / w /Graphics in TIF pics. ED �/ 15388 Analysis - Misc 0 0 Open 9/6/2007 Sedimentology of the Kugrua Sandstone from Aklaq #6 w /PDF Graphics Core Analysis Report w /Graphics in TIF EDL 15390 Gas Analysis 1641 6933 Open 9/6/2007 LAS - CCL, GR, Dept, RATO, RBOR, SGFC Log / Gas Analysis 5 Col 2160 6920 Case 9/6/2007 MD Reservoir Performance Monitor, Gasview Mode 22- Apr -2007 Log /~ Cement Bond 5 Col 1700 6928 Case 9/6/2007 Segmented Bond Tool, CCL 21- Apr -2007 • Rpt s" 15386 Analysis - Misc 0 0 Open 9/6/2007 Humble Geochemical Services Report: Source Rock and Fluid Geochemistry of the Aklaq I #6 Well w /Digital Graphics in PDF Rpt &• 15387 Sample 0 0 Open 9/6/2007 Digital Imaging w/White UV slabs photography w /Graphics in TIF pics. Rpt✓ 15388 Analysis - Misc 0 0 Open 9/6/2007 Core Laboratories Report:Core Analysis Report Rpt / 15388 Analysis - Misc 0 0 Open 9/6/2007 Sedimentology of the Kugrua Sandstone from Aklaq #6 DATA SUBMITTAL COMPLIANCE REPORT 12/17/2012 Permit to Drill 2070090 Well Name /No. AKLAQ 6 Operator FEX LIMITED PARTNERSHIP API No. 50- 279 - 20019 -00 -00 MD 7280 TVD 7280 Completion Date 4/23/2007 Completion Status SUSP Current Status P &A UIC N Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings Co-- 80 7280 5/3/2007 1186 Cores and /or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 2/28/2007. Core Chips `�/ 7126 7161 1186 ADDITIONAL INFORMATION Well Cored? V N Daily History Received? N Chips Received? O' / N Formation Tops / N Analysis ID N Received? Comments: Compliance Reviewed By: Date: 1 ��� \'• • Release of the FEX/PCAI Well Infon: Aklaq #2 & Aklaq #6 Page 1 of 2 Okland, Howard D (DOA) From: Decker, Paul L (DNR) Sent: Monday, December 03, 2012 2:53 PM To: Foerster, Catherine P (DOA); Seamount, Dan T (DOA); Norman, John K (DOA) Cc: Barron, William C (DNR); Davies, Stephen F (DOA); Bettis, Patricia K (DOA); Okland, Howard D (DOA); Houle, Julie (DNR) Subject: FW: Release of the FEX/PCAI Well Information: Aklaq #2 & Aklaq #6 Attachments: Aklaq #2 & #6 well data release 1.bmp; Aklaq #2 & #6 well release 2.bmp Dear Commissioners: It has recently been brought to our attention that AOGCC has not yet released the confidential Aklaq #2 and Aklaq #6 well data to public files. The wells were drilled in 2006 and 2007 in NPRA by FEX, who had requested that the Division of Oil and Gas extend their confidentiality period pending further lease sales on nearby unleased acreage. The Division asked AOGCC to keep the wells confidential pending a decision whether or not to extend the confidential status. Earlier this year, FEX and their co- owners withdrew the request for extended confidentiality in a letter to DOG Director Bill Barron (see attached and below). At this point, since a DNR decision is no longer needed, we withdraw our request that you keep the wells confidential. We would appreciate your assistance in making the Aklaq #2 and #6 well information available to the public without further delay. Best Regards, -Paul Paul L. Decker, Petroleum Geologist Resource Evaluation Manager Alaska Division of Oil & Gas 550 W. 7th Ave, Ste. 1100 Anchorage, AK 99501 (907) 269 -8791 paul.decker @alaska.gov CONFIDENTIALITY NOTICE: This e -mail message, including any attachments, contains information from the Department of Natural Resources (DNR), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and /or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e -mail, please delete it, without first saving or forwarding it, and, so that the DNR is aware of the mistake in sending it to you, contact Paul Decker at (907) 269 -8791 or paul.decker @alaska.gov. From: Garrard, Richard [ mailto :RGARRARDAtalismanusa.com] Sent: Tuesday, February 14, 2012 6:36 PM To: Houle, Julie (DNR) Cc: Decker, Paul L (DNR); St. George, Terry; Dunkley, David Subject: Release of the FEX /PCAI Well Information: Aklaq #2 & Aklaq #6 Julie, I am attaching a signed copy of a letter being sent today to the Director of the Division of Oil & Gas concerning the "extended well confidentiality" for the Aklaq #2 and Aklaq #6 well information in Northwest NPR -A. On behalf of both FEX L.P. and our co- owners Petro - Canada Alaska Inc., we now wish to withdraw our request for extended confidentiality. The associated well data has already been provided to the AOGCC and can now be released. We would like to thank the DNR /DOG for allowing us to keep the results from these wells confidential for an extended period of time. As you know both companies are in the process of exiting this part of the North Slope. 12/3/2012 Release of the FEX/PCAI Well Infon: Aklaq #2 & Aklaq #6 Page 2 of 2 Regards Dick Garrard, Geoscience Manager, FEX Anchorage Office. 1 (907) 644 -4429 «Aklaq #2 & #6 well data release 1.bmp» «Aklaq #2 & #6 well release 2.bmp» 12/3/2012 • E E • FEX L.P., Anchorage Office. 9651 Main Tree Drive, Anchorage, Alaska 99507. Email: garrard @talismanusa.com William C. Barron, Director Division of Oil & Gas, 550W. 7 Ave. Suite 1100, Anchorage, Alaska 99501. February 14 2012 Dear Sir, Subject: Release of Aklaq #2 & Aklaq #6 Well Information FEX L.P. in conjunction with Petro -Canada Alaska Inc., (PCAI), drilled the Aklaq #2 and Aklaq #6 exploration wells in the Northwest NPR -A during the winters of 2006 & 2007 respectively. Both wells were initially suspended to allow time if necessary to conduct meaningful testing programs during subsequent winter seasons. In the winter of 2011 FEX L.P. returned to these wells to complete a successful plugging and abandonment operation. The abandoned drillsites are located on leases held under a "suspension of operations provision" through the BLM. Because of ongoing leasing by the BLM and the subsequent acquisition of new proprietary 3 -D seismic by FEX L.P. & PCAI in the immediate vicinity, a request through the DNR Commissioner for "extended well confidentiality" had been filed for Aklaq #2 and Aklaq #6. In addition the 2006 Northeast NPR -A Lease Sale cancellation after bids had been submitted, together with a 10 -year moratorium being placed on the North Teshekpuk Area, increased the sensitivity of this proprietary well information and the desire to maintain well confidentiality. These requests were approved by the DNR Commissioner in 2008 and 2009. Since then both companies have decided to exit this part of the North Slope and as a result the need for extended well confidentiality no longer exists. I have recently received permission from FEX L.P. and PCAI to withdraw our request concerning the extended well confidentiality for Aklaq #2 & Aklaq #6. The associated well data have already been provided to the AOGCC and can now be released at your convenience. The associated cores have already been donated to the GMC in Eagle River. • 1 • • Lastly, we would like to thank the staff of the DNR/DOG for their cooperation and for allowing our well information to be held confidential for an extended period of time. • ur Sincerely, 4 aw , 0-- ovvv- MN • ' etrd (Dick) Garrard Geoscience Manager, Office: 1(907) 644-4429 Cell: 1 (907) 244-1067 Copy to: Paul Decker DOG Anchorage Julie Houle DOG Anchorage Terry St George PCAI Calgary David Dunkley Talisman Energy Inc. Calgary Page 1 of 2 Okland, Howard D (DOA) From: Houle, Julie (DNR) Sent: Thursday, November 29, 2012 5:23 PM To: Okland, Howard D (DOA) Cc: Decker, Paul L (DNR) Subject: RE: Ghost of Wells Past 0 no! here we go again; they did formally request and perhaps the letter never got to you . Will investigate tomorrow. Julie From: Okland, Howard D (DOA) Sent: Thursday, November 29, 2012 3:37 PM To: Houle, Julie (DNR) Subject: RE: Ghost of Wells Past TNX Kind of a rhetorical question, did FEX ever formally request the confidential period to be extended. A formal letter is not in either well history. Hohoho From: Houle, Julie (DNR) Sent: Thursday, November 29, 2012 3:33 PM To: Okland, Howard D (DOA) Cc: Decker, Paul L (DNR) Subject: RE: Ghost of Wells Past Will check with Paul Decker. The fact they don't hold the leases anymore should be enough. We will have to draft a letter I presume. Julie Julie Houle Resource Evaluation Alaska Div of Oil & Gas (907) 269 -8773 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Department of Natural Resources (DNR), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and /or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the DNR is aware of the mistake in sending it to you, contact Julie Houle at julie.houle @alaska.gov or via phone at (907) 269 -8773. From: Okland, Howard D (DOA) Sent: Thursday, November 29, 2012 3:31 PM To: Houle, Julie (DNR) Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Ghost of Wells Past 12/1 0/2012 • • Page2of2 Julie, Here is a blast from the past. When may we release the following wells: Aklaq -2 50 279 20014 00 00 (ptd 205 -180) completed 04/10/2006 (Susp) Aklaq -6 50 279 20019 00 00 (ptd 207 -009) completed 04/23/2007 (Susp) Recall that Div Oil and Gas asked the AOGCC to keep these confidential until a decision was made whether or not to extend the confidential status of these wells. If I remember correctly, FEX no longer holds the leases. TNX Howard 12/10/2012 ;" 0 7 0 o7 • QS ogNT OF p 4 � -- _ ti United States Department of the Interior � a BUREAU OF LAND MANAGEMENT 4 g 0 CH 3 1� A9 Arctic Field Office TN KE PRIDE" AMERICA 1150 University Avenue Fairbanks, Alaska 99709 -3844 http: / /www.blm.gov /ak In reply refer to: OCT O 3 2011 AA085517 3130 (AKF012) Alaska Oil & Gas Conservation Commission EC 1VED c/o Guy Schwartz OCT 5 nil 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 ,gecko Oil & Gas Goes. Ancno�a8e Subject: FEX Abandoned Drillsites: Northeast NPR -A Dear Mr. Schwartz: This letter is in response to your question as to where the BLM stands with FEX's Aklaq 6 (PTD 207 -009) surface conditions. As to date, it has met all but one of our reclamation standards, which is to monitor the site for a minimum of 2 growing (summer) seasons. With the exception of any unforeseen circumstance occuring at the site in the next year, the BLM will approve Aklaq 6 for Final Abandonment Notice in September 2012. The pond that has developed at the site is acceptable to the BLM. If you have any questions please contact Shane Walker of my staff at (907) 474 -2306 or swalker @blm.gov. Sincerely, t Lon Kelly, Manager Arctic Field Office 4 STATE OF ALASKA ALASKA SAND GAS CONSERVATION COMMISSIllt WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned El Suspended ED lb. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: FEX L.P. Aband.: 3/25/2011 207 -009 3. Address: 6. Date Spudded: 13. API Number: 3601 C Street, Suite 370, Anchorage, AK 99503 3/27/2007 50- 279 - 20019 -00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2307' FWL, 2955' FSL, Sec 25, T16N, R11W, UM 4/14/2007 Aklaq #6 Top of Productive Horizon: 8. KB (ft above MSL): 39 15. Field/Pool(s): 2307' FWL, 2955' FSL, Sec 25, T16N, R11W, UM GL (ft above MSL): 44.5 Total Depth: 9. Plug Back Depth(MD +TVD): 2307' FWL, 2955' FSL, Sec 25, T16N, R11W, UM N/A Wildcat 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 426473 y- 6110601.8 Zone- 5 7,280' AA- 085517 TPI: x- 426473 y- 6110601.8 Zone- 5 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 426473 y- 6110601.8 Zone- 5 n/a LAS 25297 18. Directional Survey: Yes ❑ No El 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) n/a (ft MSL) 1,060' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re -drill /Lateral Top Window MD/TVD: Logs were provided with 10 -407 Form dated 05/27/2007 N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 65 H-40 0 80' 0 80' 20" 50bbls Type C cement N/A 9 -5/8" 40 L -80 0 2,072' 0 2,072' 12.25" 0 -2,072 Cement to Surface N/A 7" 26 L -80 0 7,050' 0 7,050' 8.5" 4,500- 7,050' Multi-stage N/A 24. Open to production or injection? Yes El No s If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) N/A 3.5" 1,413' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 0- 4,500' (9 -5/8" annulus) 45 bbls Class G, 35 bbls Permafrost Cement 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A N/A Date of Test Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: N/A N/A Test Period — N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. Packer 24 -Hour Rate ■■ 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No o Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. A core report was submitted with 10-40 Form dated 05/27/2007 RECEi V OAR 3 0 .iiin RBDAAS MAR 3 0 2011 Masks Oil & sa r. Corr ssp� Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE 7 e 1 7• // Submit original only . N • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top Surface Surface needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1,225' 1,190' Nanushuk group 2,791' 2,775' Torok 3,470' 3,446' Torok Sand 1 4,734' 4,688' HRZ 6,605' 6,558' Kuparuk Sandstone Mbr. 6,800' 6,753' LCU 6,880' 6,834' Kugrua Sandstone 7,120' 7,073' Formation at total depth: 31. List of Attachments: Daily Reports 32. I hereby certify that th • . goi g is true and correct to the best of my knowledge. Contact: Alexey Sachivichik 264 -6112 Printed Name: Rich , . G. rar - Title: Geoscience Manager Signature: I Phone: 907 -644 -4429 Date: 3 L_ t (25n I 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. Ite{n 1b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 ' • F E X Aklaq #6 Fri) Final Welibore Schematic ,26-7-06/ 3/25/2011 24" Hole - 16" 65# Conductor @ 80' MD/TVD 3 -1/2" 9.2# Tubing @ 1,380' 12 -1/4" Hole 9 -5/8" Top of Tail Cement @ 1,572' 9 -5/8" 40# L -80 BTC Casing @ 2,070' MD/TVD 8 -1/2" Hole ,Bottom of Remedial 9.8 ppg Mud ,�/ Cement job @ 5,500' Top of Second Stage Production Cement Job @ 5,500' • _Stage Tool, Top of 1 Stage of Production Cement Job @ 6,386' Float Collar @ 7,004' ►�� = , Al" 7" 26# L -80 BTC Casing @ 7,050' MD /TVD TD @ 7,280' MD/TVD • • F E �--- RECEIVED MAR 30 M March 29th, 2011 ska & Fas Cans. Coati Mr. Dan Seamount, Chair tits Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Report of Sundry Plug and Abandon Operation FEX L.P., Aklaq #6 PTD 207 -009 Sundry No. 310 -186 Dear Mr. Seamount, FEX L.P. hereby submits its Report of Sundry Well Operations for the work performed in plugging and abandonment its Aklaq #6 well, located in the Western NPRA. Please find enclosed the following information for your files: 1) Form 10 -407 Well Completion Report 2) Wellbore Schematic 3) Well Operation Reports 4) Well Photographs If you have any questions or require additional information, please contact me at (907)- 644 -4429 or Alexey Sachivichik at 264 -6112. Sincerely, r L.'. , 11 r 1 Richard " arrard Geoscience Manager cc: Alexey Sachivichik Attachments Cc: Alexey Sachivichik - SolstenXP 1 • • SOLSTENXP, INC • _ DAILY REP s,;, - EX, Akla• DAILY ACTIVITY REPORT FEX Project Mngr Bob Nodwell Project Mngr Alexey Sachivichik BLM Site Rep Tom Zelenka Field Supervisor Shane McGeehan WO# FX- 0210 -1001 FEX Site Rep Jim Rickel WEATHER: -18 8MPH 3/19/2011 START SHIFT: 0700hr END SHIFT: 1900hr 0700 -0730 PJSM, Went over hazards for moving to next well 0730 -1130 Move 12 miles to Aklaq #6 1130 -1900 Set up camp. Remove guardrails and cellar box around well. Setup scaffolding. Set Boiler warm up Warm up and start up heaters. Start up and wire in generator. Make up fitting on tree to pump in. Percent of days Percent of days worked Percent of days worked without first 100% without equipment incidents. 100% worked without spills. 100% Total Days on Project 30 aid cases or in'uries. SAFETY INCIDENTS TODAY PROJECT TO DATE First Aid Cases 0 0 Recordable Injuries 0 1 Equipment Incidents 0 0 NOV's 0 Spills 0 2 TOTAL INCIDENTS 0 3 SolstenXP 6 966 Truck Loader 1 _ --_ Marsh Creek LLC 9 Excavator 320 JD 1 FEX 1 D7G Cat Dozer 1 - -_- BLM Generator 1 _ -_ Heaters 2 2 Catco Guzzler Unit & Trailer 1 _ Light Plants 1 -.- _ Spill Response Kit 1 Atigun Boiler Unit, 25bb1 tank 0 1 -_- _ SolstenXP 90 bbls Batch Mixer p 1 0 TOTAL 16 Spill Response Kit 1 1 _ -_ • • DAILY ACTIVITY REPORT FEX Project Mngr Bob Nodwell Project Mngr Alexey Sachivichik BLM Site Rep Tom Zelenka Field Supervisor Shane McGeehan WO# FX- 0210 -1001 FEX Site Rep Jim Rickel WEATHER: -18 8MPH 3/20/2011 START SHIFT: 0700hr END SHIFT: 1900hr 0700 - 0730 PJSM, Slips trips Falls. Assess work area before strarting job 0730 -1200 Warm up cement unite, run equipment. Fill up and run Boiler. Pull BPV 1200 -1900 Check annulus for pressure,0 psi. Rig up block valve with gauge on annulus. Spot two return tanks next to well. Run return line to tanks. Make up pump line to wing valve on tree. Fill mix tanks 40bbls water, heat up water Percent of days worked Percent of days worked Percent of days without first aid cases without equipment worked without spills. 100 ° Total Days on Project 31 or injuries. incidents. SAFETY INCIDENTS TODAY PROJECT TO DATE First Aid Cases 0 0 Recordable I njuries 0 1 Equipment Incidents 0 0 NOV's 0 0 Spills 0 2 TOTAL INCIDENTS 0 3 SolstenXP 5 966 Truck Loader Marsh Creek LLC 9 Excavator 320 JD 1 FEX 1 D7G Cat Dozer 1 BLM Generator Generator 1 Heaters 2 2 -_- -■- Catco Guzzler Unit & Trailer r 1 - Light Plants 0 1 -. . -- Spill Response Kit 0 1 - Atigun Boiler Unit, 25bb1 tank 1 - - SolstenXP 90 bbls Batch Mixe 1 0 0 --- TOTAL 15 Spill Response Kit 1 1 • • • r DAILY REPORT DAILY ACTIVITY REPORT FEX Project Mngr Bob Nodwell Project Mngr Alexey Sachivichik BLM Site Rep Tom Zelenka Field Supervisor Shane McGeehan /Alexey Sachivichik WO# FX- 0210 -1001 FEX Site Rep Jim Rickel WEATHER: -18 8MPH 3/21/2011 START SHIFT: 0700hr END SHIFT: 1900hr 0700 -0730 PJSM: Housekeeping - keep work area clean, check out equipment for leaks. 0730 -1200 Heat up water in batch mixer to 85 deg F. Check all connections. 1200 -1900 Stage two supersacks of salt and seven supersacks of cement next to the well. Percent of ® Percent days worked ® Percent days worked without first t aid aid cases cases without equipment equipment nt inci dents. without spills. spills. To[aI Days on Project 34 or in'uries. SAFETY INCIDENTS TODAY PROJECT TO DATE First Aid Cases 0 0 Recordable Injuries 0 Equipment Incidents 0 C. NOV's 0 Spills 0 2 TOTAL INCIDENTS 0 - SolstenXP 5 966 Truck Loader 1 Marsh Creek LLC 9 Excavator 320 JD 1 -_- - FEX 1 D7G Cat Dozer BLM Generator 1 - -- Heaters 2 2 - - Catco Guzzler Unit & Trailer Light Plants 0 1 - -- - Spill Response Kit 0 1 - -- - Atigun Boiler Unit, 25bb1 tank 0 1 - SolstenXP 90 bbls Batch Mixer 0 1 - 0 0 TOTAL. 15 Spill Response Kit 1 1 • • SOLSTENXP INC DAILY REPORT DAILY ACTIVITY REPORT FEX Project Mngr Bob Nodwell Project Mngr Alexey Sachivichik BLM Site Rep Tom Zelenka Field Supervisor Alexey Sachivichik WO# FX- 0210 -1001 FEX Site Rep Jim Hickel WEATHER: 6 deg F, 3MPH wind 3/22/2011 START SHIFT: 0700hr END SHIFT: 2400hr 0700 -0730 PJSM: General workplace safety: stepping, pinch points, working at height. 0730 -1200 RU to OA. Bleed trapped pressure. PT surf csg to 1,000 psi for 10 min - good. RD from OA, rig back up to wing. Keep brine temp at 80 deg F. Continue making water for cementing and wash -up. 1200 -1800 PT line to 1,000 psi. Pump 30 bbls wtr from Lake M0629, transfer wtr to cmtg unit, heat up same. Pump 42 bbls 9.3 ppg brine down 3.5" tbg, taking diesel returns to waste tank. Pump 10 bbls rinse water followed by 5 bbls fresh water. Fill both tanks of cementing unit with 21 bbls warm water. 1800 -2000 Mix 7 supersacks of 10.7 ppg ASL cement in cementing unit. 2000 -2145 Pump hhlc r•.amant down 3 5" thp taking brine returns to waste fluid tanks. Good returns at surface. Cement in place at 2142 hrs. Shut down pump, line up to waste fluid tank and pump remaining cement. 2145 -2400 Clean out/wash out lines and equipment. Apply heat to waste fluid tank. c Cement job witnessed by BLM's Tom Zelenka and FEX's Jim Hickel. Percent of days worked - ut equipment worked ® ut of days worked without without first t aid cases cases witho without equipmpm ent nt inci dents. without spills. spills. To[al Days on Project 35 or in'uries. SAFETY INCIDENTS TODAY PROJECT TO DATE First Aid Cases 0 0 Recordable Injuries 0 1 Equipment Incidents 0 0 NOV's 0 Spills 0 2 TOTAL INCIDENTS 0 3 • SolstenXP 5 966 Truck Loader 1 Marsh Creek LLC 9 Excavator 320 JD 1 FEX 1 D7G Cat Dozer -- -- BLM Generator Heaters 2 2 - -- _ Catco Guzzler Unit & Trailer 0 1 --- - Light Plants 0 . -_ Spill Response Kit 0 1 _ Atigun Boiler Unit, 25bb1 tank 0 1 - -- SolstenXP 90 bbls Batch Mixer 1 _ TOTAL 15 Spill Response Kit 1 .- 1 • SOLSTENXP INC DAILY REPORT F DAILY ACTIVITY REPORT FEX Project Mngr Bob Nodwell Project Mngr Alexey Sachivichik BLM Site Rep Tom Zelenka Field Supervisor Alexey Sachivichik WO# FX- 0210 -1001 FEX Site Rep Jim Hickel WEATHER: 18 deg F, 3MPH wind 3/23/2011 START SHIFT: 1200hr END SHIFT: 2000hr 0000 -0300 Continue to clean up /wash up cementing unit. Clean up area around well. 1100 -1900 Pull cementing unit out of the way, RD scaffolding, set waste fluid tanks aside. Repair excavator. Load compressor on trailer. 1900 -2200 Dig around well to 4' below tundra level. Broke tip of tooth on excavator. Will repair in the morning. Percent of days worked Percent of days worked Percent of days worked without first aid cases 97% without equipment incidents. 100% without spills. 94% Total Days on Project 36 or in'uries. SAFETY INCIDENTS TODAY PROJECT TO DATE First Aid Cases 0 0 Recordable Injuries 0 Equipment Incidents 0 n NOV•s 0 / Spills 0 TOTAL INCIDENTS 0 - SolstenXP 5 966 Truck Loader 1 Marsh Creek LLC 9 Excavator 320 JD �- -_ -,- FEX 1 D7G Cat Dozer 1 _ - -' -- BLM 1 Generator 1 _ -■- Heaters 2 2 - - -- Catco Guzzler Unit & Trailer 1 Light Plants 1 -�- Spill Response Kit 0 Atigun Boiler Unit, 25bb1 tank 0 1 - _ -- SolstenXP 90 bbls Batch Mixer 0 1 0 TOTAL 16 Spill Response Kit 1 1 • • SOLSTENXP INC . DAILY REPORT EX •. DAILY ACTIVITY REPORT FEX Project Mngr Bob Nodwell Project Mngr Alexey Sachivichik BLM Site Rep Tom Zelenka Field Supervisor Alexey Sachivichik WO# FX- 0210 -1001 FEX Site Rep Jim Rickel WEATHER: 0 deg F, 7MPH wind 3/24/2011 START SHIFT: 0700hr END SHIFT: 1930hr 0700 -1200 Repair broken tip of tooth on excavator, continue dig. Remove remaining cellar and jackhammer concrete. 1200 -1330 Continue jackhammer cellar concrete around wellhead. 1330 -1630 Cut off 16" conductor, 9 -5/8" surface casing, 7" intermediate casing, 3 -1/2" tubing. Put tree aside. Good cement to cut in 16 "x9 -5/8 ", 65" below cut in 9- 5/8 "x7 ", good cement to cut in 7 "x3 -1/2 ", 12" below cut in 3 -1/2" tubing. 1630 -1730 Mix cement, fill annuli and weld marker plate on 16" conductor. 1730 -1930 Dump 5 cu.yards of gravel into excavation and backfill with dirt. Tree cut -off, top cementing job and welding on marker plate witnessed by BLM's Tom Zelenka and FEX's Jim Rickel. Percent of days worked Percent of days worked Percent of days worked without first aid cases 97% without equipment incidents. mo without spills. 94% Total Days on Project 37 or in'uries. SAFETY INCIDENTS TODAY PROJECT TO DATE First Aid Cases 0 0 Recordable Injuries 0 1 Equipment Incidents 0 p NOV's 0 0 Spills 0 2 TOTAL INCIDENTS 0 3 SolstenXP 5 966 Truck Loader 1 Marsh Creek Creek LLC 9 Excavator 320 JD 1 FEX 1 D7G Cat Dozer 1 -_- BLM Generator 1 _ - -__- Heaters 2 2 - - Catco Guzzler Unit & Trailer 1 - -- _ Light Plants 0 1 - _- - Spill Response Kit 0 1 - - Atigun Boiler Unit, 25bb1 tank 0 1 _ SolstenXP 90 bbls Batch Mixer 0 1 - TOTAL 16 Spill Response Kit 1 1 . - • • SOLSTENXPIN DAILY REPORT - -- - _ FEX, Aklaq #6P.&A DAILY ACTIVITY REPORT FEX Project Mngr Bob Nodwell Project Mngr Alexey Sachivichik BLM Site Rep Tom Zelenka Field Supervisor Alexey Sachivichik WO# FX- 0210 -1001 FEX Site Rep Jim Hickel WEATHER: 7 deg F, 2MPH wind 3/25/2011 START SHIFT: 0700hr END SHIFT: 1900hr 0700 -0730 PJSM: Working at heights, pinch points, load /offload, buddy system. 0730 -1200 Clean out work area. Load boiler on trailer, load heaters and light plant. Prepare waste fluid tank with brine for transportation (still wrapped in tarp). Organize tools and materials in connexes. Load metal waste to dumpster. 1200 -1900 Make final walk around, pick up remainning waste, strap all equipment on tralers. Wait for steigers. Percent of days worked Percent of days worked Percent of days worked without first aid cases 97% without equipment incidents. 100% without spills. 95% Total Days on Project 38 or injuries. SAFETY INCIDENTS TODAY PROJECT TO DATE First Aid Cases 0 0 Recordable Injuries 0 1 Equipment Incidents 0 NOV's 0 Spills 0 2 TOTAL INCIDENTS 0 3 SolstenXP 5 966 Truck Loader 1 Marsh Creek LLC 9 Excavator 320 JD 1 FEX 1 D7G Cat Dozer 1 BLM 1 Generator 1 Heaters 2 2 Catco Guzzler Unit & Trailer p 1 Light Plants 1 Spill Response Kit 0 1 Atigun Boiler Unit, 25bb1 tank 0 1 SolstenXP 90 bbls Batch Mixer 0 1 0 0 TOTAL 16 Spill Response Kit 1 1 • • • SOLSTENXP INC DAILY REPORT FEX, Aklaq #6 P&A DAILY ACTIVITY REPORT FEX Project Mngr Bob Nodwell Project Mngr Alexey Sachivichik BLM Site Rep Tom Zelenka Field Supervisor Lloyde Gentry WO# FX- 0210 -1001 FEX Site Rep Jim Rickel WEATHER: 7 deg F, 2MPH wind 3/26/2011 START SHIFT: 0700hr END SHIFT: 1900hr 0700 -0200 Wait for Steigers w/ re- supply train. 1200 -1500 Load cementing unit, three connexes and two heaters to complete loading and assembly of cat train. 1500 -1900 Move camp and equipment to Aklaq #2. Percent of days worked Percent of days worked Percent of days without first aid cases without equipment incidents. worked without 95% Total Days on Project 39 or injuries. spills. SAFETY INCIDENTS TODAY PROJECT TO DATE First Aid Cases 0 0 Recordable Injuries ti 1 Equipment Incidents 0 0 NOV's 0 Spills 0 2 TOTAL INCIDENTS 0 3 SolstenXP 5 966 Truck Loader 1 Marsh Creek LLC 9 Excavator 320 JD 1 FEX 1 D7G Cat Dozer 1 BLM 1 Generator 1 Heaters 2 2 Catco Guzzler Unit & Trailer • 1 Light Plants 1 Spill Response Kit 0 1 Atigun Boiler Unit, 25bb1 tank 0 1 SolstenXP 90 bbls Batch Mixer 0 1 TOTAL 16 Spill Response Kit 1 1 :`; 1 I 1 ' J ✓ • i , 4 tat I. • f . I. y % t , 1 L t p _ , t. nip. it A„,i • R . 4 .4. 4,: 100k ' • r ' - S *. . -tec". 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I ........,..., .., . , . .. .A,..... . ..., .... . ... ..,....,.. • ._,..., .. ..... _ .- , . , . ..._ . . . •• _ . „. , • . i 1 % • , • , •, • . , .4. _. ..... . ......, . „ ' • rage 1 or � tj k Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Sunday, March 13, 2011 10:59 AM pro Z o 7 - 001 To: Bill Penrose 7D Zo5 - g0 Cc: RGARRARD @talismanusa.com; Alexey Sachivichik P Z a L - /105 Subject: Re: FEX P &A's Bill, I don't see any regulatory issues with that minor change to the procedure. The plan was to check for pressure and then circulate out the freeze protect fluid before cementing. As long as no pressure is encountered that seems to be a reasonable equipment change that doesn't impact safety. A sundry change will not be required. The email notification is sufficient. Regards, Guy Sent from my iPhone On Mar 12, 2011, at 9:19 AM, "Bill Penrose" <bill @solstenxp.com> wrote: Guy, We'd like to make a minor modification to the procedures being used to P &A the FEX Aklagyaaq #1, Aklaq #2 and Aklaq #6 wells.. Specifically, the proposed change is as follows: FEX L.P. proposes the modification of Steps 2 and 3 in the plug and abandonment procedures contained in the Sundry Applications previously approved for work on these wells. Since use of a choke manifold to check for and contain potential pressures has proven to be problematic due to its complexity, size and propensity for freezing, the following is proposed as the alternative: Instead of using a choke manifold, an additional block valve will be installed outboard of the existing valve on the annulus from which returns are to be taken. The valve will contain a needle valve and pressure gauge. The pressure gauge will be used to check for initial pressure, if any, and the block valve will be used to contain pressure, if any, while taking returns. Recall that the perforations in these wells have previously been isolated and pressure is not expected nor has it been encountered to date. 3/14/2011 Page 'L of "l - • This procedural change has been discussed with and verbally approved by the BLM's onsite rep Tom Zelenka. A couple of questions; First, can we get your verbal approval to proceed with this modification? Second, do we need to submit Sundry Applications for this or is this note sufficient for the Commission's files? Thanks and regards, Pe woe Vice President / Drilling Manager <image002.jpg> 310 K Street, Suite 700 Anchorage, Alaska 99501 Main 907 - 279 -6900 Direct 907 - 264 -6114 Cell 907 - 250 -3113 3/14/2011 Page 1 of 4 Schwartz, Guy L (DOA) From: Bill Penrose [bill @solstenxp.com] ,a 1 O 0q Sent: Wednesday, March 02, 2011 4:21 PM " ! " l To: Tom Zelenka Cc: Schwartz, Guy L (DOA); BNODWELL @talisman - energy.com; Alexey Sachivichik Subject: RE: Morning P &A Report Tom, Thanks for your response. As a typical engineer, I'll respond to your note in bullet -point fashion: - First, I have had a talk with my staff about their not having the freedom to modify a previously approved plan unless the modification is highly desirable or necessary. Even in those cases, the proper channels must be followed. - We appreciate your (and the AOGCC's and Operator's) willingness to agree to the modified cement volume for the 9 -5/8" x 13 -3/8" annulus and the proper paperwork has been submitted. - The brine volume change for displacing the diesel out of the tubing and inner annulus in Aklaqyaaq #1 is necessitated by volume limitations at the surface. Recall that the plan was to completely displace all the diesel out with brine before displacing the brine with cement. However, instead of the planned three sleighs with waste liquid storage containers being delivered to location, only two are present. This leaves us just a little short of being able to hold the anticipated amount of waste liquid coming from the well and from equipment clean -up. (There's insufficient time to mobilize additional equipment before the job is due to occur.) What we propose is this: Instead of, as originally planned, displacing all of the diesel from the tubing and inner annulus with brine before cementing, we plan to just displace a little more than the tubing volume with brine then go to cement. This plan 1) reduces the ultimate amount of waste brine we have to handle, 2) ensures that we have a clear circulation path before pumping cement and, 3) retains the intended separation between the diesel and cement. - The operator (FEX) was the entity that dictated well returns be taken through a choke manifold to ensure such returns can be controlled should there be pressure behind them. The crew in the field suggested that the choke manifold is so large, unwieldy and complicated that it makes cleaning up after cementing though it difficult and problematic. They asked that perhaps another way could be found to take returns while maintaining control. The Operator suggested that if the crew has a reliable 2" valve that can be bolted onto the tree outboard of the existing valve(s) on the wing, that that would be an acceptable way of shutting off flow without endangering the primary valves. As the crew does have a 2" valve on site, this is what we plan to do. We hope you agree. Please let me know if I have left out any explanations or approval steps. Thanks and regards, Eck Peoltade Vice President / Drilling Manager 3/2/2011 Page2of4 4 1 0 310 K Street, Suite 700 Anchorage, Alaska 99501 Main 907 - 279 -6900 Direct 907 - 264 -6114 CeII 907 - 250 -3113 From: Tom Zelenka [mailto:tjzelenka @usa.net] Sent: Wednesday, March 02, 2011 11:14 AM To: Bill Penrose Cc: Jhickel @talisman - dc.com; bdiel @blm.gov Subject: RE: Morning P&A Report Any changes to previously approved Sundry Notices (i.e. the Sundry Notice (5N) - Notice of Intent (NOI) to P &A the Aklaqyaaq #1 well) must get prior approval by the BLM (I am also sure you must get that same approval by the AO&CC). The change of cement volume on the 9 -5/8" x 13 -3/8" annulus from 273 bbls of cement to 140 bbls of cement (Step 6 in the originally approved SN -NOI) required a SN -NOI noting this change. I granted verbal approval with an email to Alexei and any verbal approvals must followed up with a written request on the BLM Form 3160 -5, Sundry Notice and it must be the NOI and note the change. If you are changing the volume of brine 9.4 ppg NaCI water in Step 9 of the P &A Procedure (BLM approved) from 85 bbls to 50 bbls then you will have to request that change from me by email or phone (both considered verbal but I prefer by email so I have a record for the file) and then you would follow up with a Form 3160 -5 sent to the BLM Alaska State Office to my attention (222 W. 7th Avenue, #13, Anchorage, AK 99513). Step 10 cannot be achieved due to this change, you will get clean returns before the cement is pumped. It is difficult to the verify testing of pump lines to 3500 psi without a chart recorder (Step 4). You would be self certifying that this was performed without an inspector being present. These steps for changes apply to all the wells that have previously been approved for P &A, i.e. Aklaq #6, Aklaq #2, and Puviac #1. I am the Petroleum Engineer for the BLM for the State of Alaska. I approve the downhole changes of previously approved well work. I hope I have made it clear what I need to see regarding changes in procedures or volumes of any fluids that were initially approved for the P &A of these wells for both FEX L.P. and CPAI which I understand Solsten XP will also be responsible for. This will also apply to any previously approved changes in P &A procedures on the Umiat #9 well. I was surprised to see that my approved SN was different than the procedure that was provided to the Solsten and FEX reps here, that reduction in cement volume from 273 3/2/2011 Page 3 of 4 bbls to 140 bbls. Let me know if you need a further clarification from me on what I expect when changes are proposed in the P &A procedure. The original P &A that was presenting to me by FEX L.P. (Paul Mazzinlini) is what I expect to see performed unless the appropriate change request is performed. I noticed that you also changed the use of a test manifold with two adjustable chokes in Step 2 without prior verbal or written approval. I would like to see that included in your change of brine volumes (85 bbls to 50 bbls). I am verifying that these wells are plug and abandoned in accordance with previously reviewed and approved procedures provided to both the BLM and the AOGCC by the operator, FEX L.P. in the case of the first three wells and CPIA in the case of the Puviac #1 well. I am assuming that the operator is fully aware of changes being made to these procedures and that they are in complete agreement. I am working through the operator's representative, Mr. James Rickel, here on location regarding the changes proposed by the operator. I hope that I am clear on what is required for modifying any changes to previously approved P &A procedures. Thomas Zelenka, BLM Petrolem Engineer and Compliance Inspector Original Message Received: Wed, 02 Mar 2011 10:22:27 AM AKST From: Bill Penrose <bill @solstenxp.com> To: Tom Zelenka <tjzelenka @usa.net> Subject: RE: Morning P &A Report Thanks, Tom. I'll use this one for conversing with you in the field. I've heard from FEX that you need some information on volumes of brine to be pumped soon. Can you fill me in on what you'd like to know? Regards, Epee Pepe Vice President / Drilling Manager 310 K Street, Suite 700 Anchorage, Alaska 99501 Main 907 -279 -6900 Direct 907 - 264 -6114 3/2/2011 Page 4 of 4 Cell 907 - 250 -3113 From: Tom Zelenka [mailto:tjzelenka @usa.net] Sent: Wednesday, March 02, 2011 10:15 AM To: Bill Penrose Subject: Re: Morning P&A Report Bill, this is my personal email address: TJZelenka @usa.net, which you have been using for the morning report. Tom 3/2/2011 TEX to plug and abandon NPR -A Its - October 17, 2010 - Petroleum Neill Page 1 of D NOW READ OUR ARTICLES IN 40 DIFFERENT LANGUAGES. Select Language Powered by Go Sic Translate I i e trO l e ll ACCESS n s �v s FREE FULL SU BS(RIPTIONi omne"""" AcIverti5Ing Subscript[ons Publications k El h Direct Ownership, Horizontal Wells 30+ Years Experience www.oiigasventures.com/ Wellbore Iplete Drilling Solutions For You For More Information Visit Us Now! www.weatherford.com /FishingS Strengthening Stabilize Wellbores : Integrated web based EHS compliance Asset & Compliance Tracking System. www.Ecocion.c While Drilling I -BOSS from M -I SWACO www.deepwaterequipped.com V Week of October 17, 2010 BP coverage of Alaska and northern Canada's oil and gas industry Info about the Gulf of . - Mexico Spill Learn More about How BP is r and abandon NPR -A ® bIBR Helping. www.BP.com /GuIfOfMexicoRe • • V111J Kristen Nelson Petroleum News , rte, As it moves to sell its acreage in the National Petroleum Reserve - Alaska, FEX LP is permitting a plug and abandonment plan for three NPR -A exploration wells it drilled in 2005 -06 and 2006 -07. The company said in applications filed with the State of Alaska that the three wells are on Bureau of Land Management land in Northwest NPR -A with a proposed access route partially on NPR -A and State of Alaska lands. FEX, a subsidiary of Canada -based Talisman Energy, has three wells in suspended status near the Ikpikpuk River southeast of Barrow — Aklaqyaaq 1, I Aklaq 2 and Akla 6. A fourth well, Amaguq 2, was plugged and abandoned in 2006. DC) `1—OOC FEX said the P &A program will occur in two phases, the first in the winter of ! 2010 -11 consisting of permanent plugging and abandonment of the wells and the second in the summer of 2011 including final site cleanup and agency inspections for site clearance. FEX said it plans to revisit the former well sites in 2012 to retrieve any material not previously detected. Mobilization from Deadhorse FEX said it would mobilize the camp and P &A equipment from Deadhorse to Oliktok by truck to a staging area on sea ice at Oliktok Point. From Oliktok, off- , vehicles will pull the camp and skid sleighs with support equipment, with http:// www. petroleumnews .com /pnads /648742412.shtml 10/15/2010 -FEX to plug and abandon NPR -AIls - October 17, 2010 - Petroleum Nee Page 2 of 6� mobilization to begin in early January and continue until complete by April. P &A activities are estimated to take 10 to 14 days at each well. The wells were suspended, and FEX said the planned work will permanently P &A the wells, which are lined with cement casing plugged with cement and filled with kill- weight fluid. The kill- weight fluid will be removed and replaced with cement surface plugs. The Aklaq 2 well, suspended as a Class II injection well, will be used as a disposal well for liquid P &A well wastes before final plugging. Reclamation activities in the summer will consist of placing clean gravel in a mound at the wellhead to allow for subsidence and to avoid thermokarsting (localized thawing of ice -rich soil which would create a depression and eventual erosion). Soil in the reclaimed area will be left loose to allow for natural seeding and revegetation as recommended by BLM. Wells found pay Talisman Energy said in a March securities filing that it was putting its leases in NPR -A and in the foothills of the Brooks Range up for sale, ending what appeared to have been a successful initial exploration program. FEX drilled in NPR -A and parent company Talisman said in May 2007 that three of its NPR -A exploration wells encountered hydrocarbon - bearing sandstones in several formations. Wells drilled in 2006 -07 included the Aldaqyaaq, Amaguq 2 and Aklaq 6; Aklaq 2 was drilled in the winter of 2005 -06. Of the three, one was deemed "subcommercial given current infrastructure," the company said at the time. The initial estimate for the other two wells was a resource of 300 -400 million barrels net to FEX, which had a 60 -80 percent working interest in the wells, with Petro- Canada's Alaska subsidiary (now Suncor Energy) holding the remaining I working interest. Talisman's 2007 announcement was based on log analysis, the company said, and "strong gas and oil shows, including oil staining and free oil in the drilling mud in one of the wells." Did you find this article interesting? Tweet it Di.. it digg Submit it to another favorite Social Site or Article Directory. Ea RI la IE ©®®o El I R ti Email it to an associate. Print this story http:// www. petroleumnews .com /pnads /648742412.shtml 10/15/2010 • c- a, � ems? -� fi" Lti) E€� SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM?M1SSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 August 5, 2010 Ms. Betty Schorr 6 9 (� 1 O 1 Program Manager, Industry Preparedness Program �-/ Division of Spill Prevention and Response Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 -2617 Re: Permanent Abandonment of FEX L.P. operated wells Aklaqyaaq 1, Aklaq 2, and Aklaq 6 Dear Ms. Schorr: On July 1, 2010, the Alaska Oil and Gas Conservation Commission (Commission) provided a letter to the Alaska Department of Environmental Conservation (ADEC) regarding the spill risk of proposed abandonment operations for the suspended Aklaqyaaq 1, Aklaq 2, and Aklaq 6 exploratory wells. This letter stated: "...in the Commission's opinion, it is highly unlikely that abandonment operations could result in an unassisted flow of hydrocarbon to the ground surface, provided installed plugs are not disturbed and casings are not perforated." The Commission understands that the ADEC may be uneasy with this non - absolute determination, but nothing is 100% certain. Further explanation may help. Aklaqyaaq 1, Aklaq 2, and Aklaq 6 are all classified by the Commission as suspended wells. These wells are lined with properly- cemented casing, plugged with cement, and filled with kill - weight fluid, so the Commission does not believe they are capable of flowing. Regulation 20 AAC 25.110 establishes criteria that must be met in order for a well to be classified as suspended. This regulation requires, among other things, that the well: • is mechanically sound, • will not allow the migration of fluids, and • is secure, safe, and not a threat to public health. Plugging of both suspended and permanently abandoned wells is governed by Commission regulation 20 AAC 25.112. The only difference between a suspended well and a permanently I . ' Permanent Abandonment • August 5, 2010 Page 2 of 2 abandoned well is that a surface plug is not required for a suspended well. The plugging requirements of 20 AAC 25.112 also stipulate that plugging of "...a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are confined to their respective indigenous strata and are prevented from migrating into other strata or to the surface." This regulation also requires that every plug set in a wellbore, except for surface plugs, be tested for integrity by either placing sufficient weight on the plug or pressurizing the wellbore to confirm that the plug has set and is competent. See 20 AAC 25.112(g). Based on Commission inspections and review of records for the subject wells at the time the plugging operations took place, the Commission determined that they all could properly be classified as suspended, which means they are incapable of flowing. The only way these wells could have a possibility of flowing would be if FEX L.P. were to remove the existing plugs and/or perforate the casing. Neither of these activities is part of FEX L.P.'s proposed abandonment activities. Accordingly, if ADEC requires a revised SRPS for FEX L.P. to conduct abandonment operations on these properly- suspended wells (or any properly - suspended well), the Commission recommends that it be set at zero barrels per day. Copies of 20 AAC 25.110 and 25.112 are enclosed for your reference. Should you have any questions please contact Commissioner Cathy Foerster at 793 -1221. Sincerely, ag z Cathy P oerster Commissioner cc: Dick Garrard, FEX L.P. Paul Mazzolini, FEX L.P. • • sifty jr[E o[jF A[LAs[r, SEAN PARNELL, GOVERNOR `�-+ ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Paul Mazzolini D&C Engineering Manager FEX L.P. 3601 C Street, Suite 370 Anchorage, AK 99503 (q47r 007 Re: Wildcat Field, Wildcat Pool, AKLAQ #6 Sundry Number: 310 -186 Dear Mr. Mazzolini: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely i K. Nor an Com .' ' sioner DATED this Zaday of July, 2010. Encl. 0 RECEIVED '1 STATE OF ALASKA JUN 1 h 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALSkiaska Oil & Gas C0113. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon 0 ' Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver ❑ Other ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: FEX L.P. Development ❑ Exploratory o • 207 -009 ° 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 3601 C Street, Suite 370, Anchorage, Alaska 99503 50- 279 - 20019 -0000 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: N/A Spacing Exception Required? Yes ❑ No ❑ AKLAQ #6 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): AA- 085517 - 39' Wildcat 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7280' . 7280' , KB KB 7004' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16' 80' 80' 1640 630 Surface 2072' 9.625" 2072' 2072' 5750 3090 Intermediate 7050' 7" 7050' 7050' 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3.5" L -80 1380' Packers and SSSV Type: N/A Packers and SSSV MD (ft): N/A 13. Attachments: Description Summary of Proposal ❑ 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑_ Exploratory 0 • Development ❑ Service ❑ 15. Estimated Date for February,20f0 ( � /C 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alexey Sachivichik (907) 264 -6112 Printed Name Paul Mazzolini Title D &C Engineering Manager Signature ,---7� Q \ Phone O Ea C t�C (724) 814 -6399 ' 14 /Zp / b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/6 gcc.br,MU' 26 /I Plug Integrity ❑ BOP Test 111 n Mechanical Integrity Test 111 Location Clearance /) Other: - Se x r� D/ o�S a }- 1 c.,...4-0 1- f Pr ior � e ' c� - t'ter ��1�Lo+t` P /v6-F- C f o�.n.zssr•w - t - o w� 5'ccr4:Lc p I�� s' s: k O C/a'- Subsequent Form Required: / * Approved by: COMMISSIONER THE COMMON Date: 9 "2 4$ f Form 1RB 06i 10 I V 0 R 1 G 1 N A L A 7 - Lo C � Submit in Duplicate ' ,. r. • • RECEIVED JUN aaa 1 C ?010 F Alaska Oi! & Cor Corrmtissiar� Anchfrape June 14, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application to Plug and Abandon FEX L.P., Aklaq #6 (PTD 207 -009) Dear Mr. Seamount, FEX proposes to plug and abandon its Aklaq #6 well, located in the western NPRA, during the winter of 2010 -11. Submitted here is the Sundry Application for the work. The abandonment of Aklaq #6 will be accomplished as indicated in the attached Form 10 -403, P &A procedure and accompanying wellbore diagrams. The abandonment procedure and targeted final well configuration have been informally reviewed with the AOGCC's technical staff. If you have any questions or require additional information, please contact me at (724) 814 -6399 or Alexey Sachivichik at (907) 264 -6112. Sincerely, FEX L.P. �Le r►1 Paul Mazzolini D & C Engineering Manager cc: Alexey Sachivichik Attachments ill • RECEIVED JUN 1 6 2010 F E X Alaska MI & Gat Cans. Commission Anchorage Aklaq #6 Proposed Wellbore Schematic 5/19/2010 IV 24" Hole ,17t... a,„ • r, * as , 16" 65# Conductor @ 80' MD /TVD ` 3 -1/2" 9.2# Tubing @ 1,380' v µ 12 -1/4" Hole i 1 fi ; S/4--- 9 -5/8" Top of Tail Cement @ 1,572' 9 -5/8" 40# L -80 BTC ill 1. Casing @ 2,070' MD /TVD f are 8 -1/2" Hole Bottom of Remedial 4 9.8 ppg Mud Cement job @ 5,500' 4/ fi, , \Top of Second Stage Production i , Cement Job @ 5,500' c —Sta Tool, Top of 1 Stage of Production Cement Job @ 6,386' ' 4 ' Y.1 vi Float Collar @ 7,004' l ," �� 7" 26# L -80 BTC Casing @ 7,050' MD /TVD TD @ 7,280' MD /TVD F c - - .'446-'-': ' • • RECEIVED JUL 0 2 2010 P &A Procedure: Aklaq #6 Alaska Oil & Cu Cons. Commission Anchorage 1. MIRU camp and equipment. Do not commence well operations until camp operations have been established, personnel are settled in and all equipment and materials required for this job are onsite. 2. Rig up a testing manifold containing two adjustable chokes arranged in parallel. All bleeding off of well pressures and returns taken while pumping should be taken from the well, through the manifold and into appropriate tanks for the liquid being flowed. 3. Check all annuli for pressure. If any is found, document pressure and attempt to bleed off ., through the choke manifold. If it does not bleed off or if it re- builds, contact Anchorage office for plans to deal with it. 4. Rig up pump and lines to pump down 3 -1/2" tubing and take returns from the 3 -1/2" x 7" annulus. Pressure test lines to 1,000 psi. 5. Heat water and mix 55 bbls of 9.4 ppg NaC1 brine. 6. Pump brine down 3 -1/2" tubing until all diesel is displaced from the well and returns are clean brine (calculated diesel volume in well is 49 bbls). 7. Mix 55 bbls of permafrost cement as: Density 10.70 ppg Yield 4.51 cu ft/sk Mix Water 21.316 gal /sk Pump a 5 bbl fresh water spacer down the 3 -1/2" tubing followed by the cement, taking returns out the 3 -1/2" x 7" annulus. Continue pumping cement until uncontaminated cement returns are observed at the surface. 8. When the pump is shut down, immediately shut the annulus and tubing valves (to inhibit falling of the cement column) and disconnect lines. 9. Clear and clean lines and cementing equipment. 10. WOC at least 12 hours. 11. Meanwhile, rig down all mixing, pumping and related equipment and prepare them for moving to the Aklaq #2 location. wjp 5/18/10 • • 12. Using excavator, excavate around the wellhead to a depth of five feet below tundra level. 13. After WOC period is finished and using a cutting torch and hydraulic jack hammer (for cement), cut all casing and tubing strings off to leave well severed 4' — 5' below tundra . level. 14. Remove original guardrail, cellar, wellhead and severed casing/tubing and prepare for , transport to Prudhoe Bay. 15. Top off all annuli and tubing in well with cement if necessary. BLM or AOGCC ' representative to witness. 16. Photographically document the condition of the top of the well before welding on the ' marker plate. 17. Weld a 1/4" thick, 16" diameter steel marker plate over the top of the cut -off well casings. BLM or AOGCC representative to witness. Marker plate to have the following information bead - welded onto it: FEX GP, Inc. Aklaq #6 API #50- 279 - 20019 -00 PTD #207 -009 18. Photographically document the welded -on marker plate. / 19. Back -fill excavation with original soil. Top excavation with five yards of clean gravel brought out from Prudhoe Bay, mounding it over the well to compensate for settling as soil thaws. 20. Clean location, obtain site clearance approval from BLM or AOGCC representative on location and transport all personnel, equipment and materials to Aklaq #2. wjp 5/18/10 • • F E X Aklaq #6 Current Configuration 6/1/2010 24" Hole • 55 bbls of Diesel Freeze Protection • ' 16" 65# Conductor @ 80' MD /TVD 3 -1/2" 9.2# Tubing @ 1,380' • ` 12 -1/4" Hole 4 9 -5/8" Top of Tail Cement @ 1,572' 9 -5/8" 40# L -80 BTC Casing @ 2,070' MD /TVD 8 -1/2" Hole Bottom of Remedial 9.8 ppg Mud Cement job @ 5,500' Top of Second Stage Production Cement Job @ 5,500' 4Stage Tool, Top of 1 Stage of Production Cement Job @ 6,386' Float Collar @ 7,004' 7" 26# L -80 BTC Casing @ 7,050' MD /TVD TD @ 7,280' MD /TVD • . F E X Aklaq #6 Proposed Abandonment 6/1/2010 24" Hole 16" 65# Conductor @ 80' MD /TVD 3 -1/2" 9.2# Tubing @ 1,380' 12 -1/4" Hole ■• 9 -5/8" Top of Tail Cement @ 1,572' 9 -5/8" 40# L -80 BTC Casing @ 2,070' MD /TVD 8 -1/2" Hole Bottom of Remedial 9.8 ppg Mud (Cement job @ 5,500' Top of Second Stage Production Cement Job @ 5,500' 4Stage Tool, Top of 1 Stage of Production Cement Job @ 6,386' Float Collar @ 7,004' ►� _ T 7" 26# L -80 BTC Casing @ 7,050' MD /TVD TD @ 7,280' MD /TVD ... • • RECEIVED JUN 1 6 2010 F E Alaska 011 & Gat . Commission Anchorage COMBINED P &A PROCEDURE Aklagyaaq #1 Aklaq #6 Aklaq #2 Mobilization Site access will be accomplished through the use of off -road vehicles - Steigers, pulling at Cat Camp. The figure below depicts a typical "two string" configuration. Imo ts. .41t 6 *tit lirejaA Cat Camp dual string on trail 1. Mobilize all support equipment, fuel, camp and materials (list will be provided at a later date) from Deadhorse to Oliktok on trucks using road system to a designated staging area. wjp 5/18/10 • • 2. From the staging area load camp components, P &A equipment, materials and fuel on sleighs, and move with Steigers to job site. The figure below shows preliminary 1 mobilization set-up. p Mob Metlr. L*,vUdIN : — `� 2man NNell 061o�3M�1 `';. ,�. � , : °�,.�.r 11010•• Mat 11, �,,. -.� _ D7 1 I ma gi cal SoO Fuel Ste . mop I „ -4.8110 1 ran NOM Ow © -� I F8n 1101111 Pil duo o r r 2040 Feet StS. \, HBO i r Ex zoo 1 , Jill tom' 3. Set up camp in close proximity to Aklaqyaaq #1 well. Set up equipment around the well according to the equipment setup diagram. Preliminary diagram is available. 4. Move two open top tanks and Triplex pump to Aklaq 2 well. Prepare Aklaq 2 well for waste disposal by checking valves, recording pressures and making required adjustments. Rig up tanks and lines to 9 -5/8" x 7" annulus. 5. Send two Steigers back to Oliktok for re- supply and the rest of equipment. 6. Rotate two Steigers between the job site and Oliktok for food, water and fuel re- supply. Prepare Aklap #2 for Annular Disposal of Wastes Discussion: Prior to commencing injection of Class II wastes, the AOGCC must re- activate the original Annular Disposal Permit issued for this well as the primary term of the permit has expired. As a prerequisite for re- activation of the permit, a step -rate injectivity test must be performed so that the State or Federal agency representative on site can determine the maximum injection rate allowable. The following is the procedure for the step -rate test. wjp 5/18/10 • • 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. Procedure: 1. R/U diesel tank and pumping equipment to pump down the 7" x 9 -5/8" annulus. 2. Pressure test surface lines to 2,000 psi. 3. Pumping diesel, conduct a four -point injectivity test down the annulus as follows: a) Establish minimum pump rate and gradually increase it to 0.5 bpm and hold until pressure stabilizes. b) Record first rate and pressure pair. c) Increase the pump rate in 0.5 bpm increments (check for changes in the slope of the pressure curve at stable rates). d) Plot pair points on a pressure- versus -rate graph and determine fracture extension pressure. 4. Forward the data to the Anchorage office for discussion with AOGCC representatives in town if one is not available on site. P &A Aklagvaao #1 1. MIRU camp and equipment. Do not commence well operations until camp operations have been established, personnel are settled in and all equipment and materials required for this job are onsite. 2. Rig up a testing manifold containing two adjustable chokes arranged in parallel. All bleeding off of well pressures and returns taken while pumping should be taken from the well, through the manifold and into appropriate tanks for the liquid being flowed. 3. Check all annuli for pressure. If any is found, document pressure and attempt to bleed off through the choke manifold. If it does not bleed off or if it re- builds, contact Anchorage office for plans to deal with it. 4. Rig up pump and lines to bullhead down the 9 -5/8" x 13 -3/8" annulus. Pressure test lines to 3,500 psi. 5. Heat water and mix 25 bbls of 9.4 ppg NaC1 brine. Pumping down the 9 -5/8" x 13 -3/8" annulus, establish a breakdown pressure and injection rate at a pressure not exceeding 3,500 psi (70% of the burst rating of the 13 -3/8" casing). wjp 5/18/10 • • 6. Mix 273 bbls of permafrost cement as: Density 10.70 ppg Yield 4.51 cu ft /sk Mix Water 21.316 gal /sk Pump a 5 bbl fresh water spacer down the 9 -5/8" x 7" annulus followed by the cement at a rate and pressure not exceeding those established in Step 5 above. This cement will displace the diesel in the annulus ahead of it and the cement volume is sufficient to fill the 9 -5/8" x 13 -3/8" annulus and the 9 -5/8" x 12 -1/4" annulus down to the top of the primary cement job ( +4,500'). 7. When the pump is shut down, immediately shut the annulus valve (to inhibit falling of the cement column) and disconnect cementing line. 8. Clear and clean lines and cementing equipment. 9. Heat water and mix 85 bbls of 9.4 ppg NaC1 brine. Line up to pump down 3 -1/2" tubing and take returns from the 3 -1/2" x 7" annulus (calculated diesel volume in well is 89 bbls). 10. Pump brine down 3-1/2" tubing until all diesel is displaced from the well and returns are clean brine. 11. Mix 85 bbls of permafrost cement as: Density 10.70 ppg Yield 4.51 cu ft/sk Mix Water 21.316 gal /sk Pump a 5 bbl fresh water spacer down the 3 -1/2" tubing followed by the cement, taking returns out the 3 -1/2" x 7" annulus. Continue pumping cement until uncontaminated cement returns are observed at the surface. 12. When the pump is shut down, immediately shut the annulus and tubing valves (to inhibit falling of the cement column) and disconnect lines. 13. Clear and clean lines and cementing equipment. 14. WOC at least 12 hours. 15. Meanwhile, rig down all mixing, pumping and related equipment and prepare them for moving to the Aklaq #6 location. 16. Using excavator, excavate around the wellhead to a depth of five feet below tundra level. wjp 5/18/10 • • 17. After WOC period is finished and using a cutting torch and hydraulic jack hammer (for cement), cut all casing and tubing strings off to leave well severed 4' — 5' below tundra level. 18. Remove original guardrail, cellar, wellhead and severed casing /tubing and prepare for transport to Prudhoe Bay. 19. Top off all annuli and tubing in well with cement if necessary. BLM or AOGCC representative to witness. 20. Photographically document the condition of the top of the well before welding on the marker plate. 21. Weld a '/" thick, 34" diameter steel marker plate over the top of the cut -off well casings. BLM or AOGCC representative to witness. Marker plate to have the following information bead - welded onto it: FEX GP, Inc. Aklaqyaaq #1 API #50- 279 - 20018 -00 PTD #206 -165 22. Photographically document the welded -on marker plate. 23. Back -fill excavation with original soil. Top excavation with five yards of clean gravel brought out from Prudhoe Bay, mounding it over the well to compensate for settling as soil thaws. 24. Clean location, obtain site clearance approval from BLM or AOGCC representative on location and transport all personnel, equipment and materials to Aklaq #6. P &A Aklan #6 1. MIRU camp and equipment. Do not commence well operations until camp operations have been established, personnel are settled in and all equipment and materials required for this job are onsite. 2. Rig up a testing manifold containing two adjustable chokes arranged in parallel. All bleeding off of well pressures and returns taken while pumping should be taken from the well, through the manifold and into appropriate tanks for the liquid being flowed. wjp 5/18/10 _ 1 • • I I 3. Check all annuli for ressure. If any is found, document pressure and attempt to bleed off p Y p p through the choke manifold. If it does not bleed off or if it re- builds, contact Anchorage office for plans to deal with it. 4. Rig up pump and lines to pump down 3-1/2" tubing and take returns from the 3-1/2" x 7" annulus. Pressure test lines to 1,000 psi. 5. Heat water and mix 55 bbls of 9.4 ppg NaC1 brine. 6. Pump brine down 3 -1/2" tubing until all diesel is displaced from the well and returns are clean brine (calculated diesel volume in well is 49 bbls). 7. Mix 55 bbls of permafrost cement as: Density 10.70 ppg Yield 4.51 cu ft/sk Mix Water 21.316 gal /sk Pump a 5 bbl fresh water spacer down the 3 -1/2" tubing followed by the cement, taking returns out the 3 -1/2" x 7" annulus. Continue pumping cement until uncontaminated cement returns are observed at the surface. 8. When the pump is shut down, immediately shut the annulus and tubing valves (to inhibit falling of the cement column) and disconnect lines. 9. Clear and clean lines and cementing equipment. 10. WOC at least 12 hours. 11. Meanwhile, rig down all mixing, pumping and related equipment and prepare them for moving to the Aklaq #2 location. 12. Using excavator, excavate around the wellhead to a depth of five feet below tundra level. 13. After WOC period is finished and using a cutting torch and hydraulic jack hammer (for cement), cut all casing and tubing strings off to leave well severed 4' — 5' below tundra level. 14. Remove original guardrail, cellar, wellhead and severed casing /tubing and prepare for transport to Prudhoe Bay. 15. Top off all annuli and tubing in well with cement if necessary. BLM or AOGCC representative to witness. wjp 5/18/10 . • 16. Photographically document the condition of the top of the well before welding on the marker plate. 17. Weld a '/" thick, 16" diameter steel marker plate over the top of the cut -off well casings. BLM or AOGCC representative to witness. Marker plate to have the following information bead - welded onto it: FEX GP, Inc. Aklaq #6 API #50- 279 - 20019 -00 PTD #207 -009 18. Photographically document the welded -on marker plate. 19. Back -fill excavation with original soil. Top excavation with five yards of clean gravel brought out from Prudhoe Bay, mounding it over the well to compensate for settling as soil thaws. 20. Clean location, obtain site clearance approval from BLM or AOGCC representative on location and transport all personnel, equipment and materials to Aklaq #2. P &A Aklan #2 1. MIRU camp and equipment. Do not commence well operations until camp operations have been established, personnel are settled in and all equipment and materials required for this job are onsite. 2. Rig up a testing manifold containing two adjustable chokes arranged in parallel. All bleeding off of well pressures and returns taken while pumping should be taken from the well, through the manifold and into appropriate tanks for the liquid being flowed. 3. Check all annuli for pressure. If any is found, document pressure and attempt to bleed off through the choke manifold. If it does not bleed off or if it re- builds, contact Anchorage office for plans to deal with it. 4. Rig up pump and lines to pump down 3 -1/2" tubing and take returns from the 3 -1/2" x 7" annulus. Pressure test lines to 1,000 psi. 5. Heat water and mix 60 bbls of 9.4 ppg NaC1 brine. 6. Pump brine down 3 -1/2" tubing until all diesel is displaced from the well and returns are clean brine (calculated volume of diesel in well is 110 bbls). wjp 5/18/10 • • 7. Mix 60 bbls of permafrost cement as: Density 10.70 ppg Yield 4.51 cu ft/sk Mix Water 21.316 gal /sk Pump a 5 bbl fresh water spacer down the 3 -1/2" tubing followed by cement, taking returns out the 3 -1/2" x 7" annulus. Continue pumping cement until uncontaminated cement returns are observed at the surface. 8. When the pump is shut down, immediately shut the annulus and tubing valves (to inhibit falling of the cement column) and disconnect lines. 9. Rig up pump and lines to bullhead down the 7" x 9 -5/8" annulus. Pressure test lines to 3,800 psi. 10. Heat water and mix 25 bbls of 9.4 ppg NaC1 brine. Pumping down the 7" x 9 -5/8" annulus, establish a breakdown pressure and injection rate at a pressure not exceeding 3,800 psi (70% of the collapse rating of the 7" casing). 11. Mix 120 bbls of permafrost cement as: Density 10.70 ppg Yield 4.51 cu ft/sk Mix Water 21.316 gal /sk Pump a 5 bbl fresh water spacer down the 7" x 9 -5/8" annulus followed by the cement at a rate and pressure not exceeding those established in Step 10 above. This cement will displace the diesel in the annulus ahead of it and the cement volume is sufficient to fill the 7" x 9 -5/8" annulus and the 7" x 8 -1/2" annulus down to the top of the primary cement job ( +4,500'). 12. When the pump is shut down, immediately shut the annulus valve (to inhibit falling of the cement column) and disconnect cementing line. 13. Clear and clean lines and cementing equipment. 14. WOC at least 12 hours. 15. Meanwhile, rig down all mixing, pumping and related equipment and prepare them for moving to the Aklaq #2 location. 16. Using excavator, excavate around the wellhead to a depth of five feet below tundra level. wjp 5/18/10 y � • • 17. After WOC period is finished and using a cutting torch and hydraulic jack hammer (for cement), cut all casing and tubing strings off to leave well severed 4' — 5' below tundra level. 18. Remove original guardrail, cellar, wellhead and severed casing /tubing and prepare for transport to Prudhoe Bay. 19. Top off all annuli and tubing in well with cement if necessary. BLM or AOGCC representative to witness. 20. Photographically document the condition of the top of the well before welding on the marker plate. 21. Weld a '/" thick, 16" diameter steel marker plate over the top of the cut -off well casings. BLM or AOGCC representative to witness. Marker plate to have the following information bead - welded onto it: FEX GP, Inc. Aklaq #2 API #50- 279 - 20014 -00 PTD #205 -180 22. Photographically document the welded -on marker plate. 23. Back -fill excavation with original soil. Top excavation with five yards of clean gravel brought out from Prudhoe Bay, mounding it over the well to compensate for settling as soil thaws. 24. Clean location, obtain site clearance approval from BLM or AOGCC representative on location and prepare all personnel, equipment and materials for demobilization. Demobilization 1. Load camp, P &A equipment on sleighs and move to staging area in Oliktok. Have trucks available to pick up equipment at Oliktok. 2. Send trains back to job site to pick the rest of equipment. wjp 5/18/10 • • Aklaq No. 6 2070090 (Confidential) Current Status Suspended Spud March 27, 2007 TD reached April 14, 2007 Suspended April 23, 2007 P &A KB 37.4' Base Permafrost 1225' MD / 1190' TVD / (- 1153' TVDss) TD 7280' MD / 7233' TVD / (- 7196' TVDss) Producing Intervals None Perforated Intervals None Summary Initial permit to drill approved by AOGCC on Feb. 27, 2007. The well was spudded on March 27, 2007 and reached total depth of 7280' MD on April 14, 2007. Sundry 307 -138 approved suspension of the well on April 20, 2007. The well was suspended on April 23, 2007. By letter received May 21, 2009, FEX requested extended confidentiality from the DNR. By letter received May 22, 2009, AOGCC has been instructed by DNR to withhold the release of Aklaq 6 pending DNR's decision. Common gas shows in the Torok Formation and gas shows in the main target interval, the Jurassic -aged Kugrua siltstone and sandstone. Kuparuk sandstone is well developed, glauconitic, displays 17 ohm -m resistivity, and is associated with a gas spike, but has no reported oil staining, fluorescence or cut. Kugrua siltstone and sandstone, display low resistivity (8 ohm -m or less) and lack oil stain, fluorescence or cuts. Conventional core obtained from the Kugrua interval consist of sandstone that is very fine - grained and dolomitic with porosity ranging from 1 -19% (average is 8.5 %) and permeability ranging from 0.01 -0.17 and (average is 0.08 md). An email from Mike Quick, ASRC, to Tom Maunder, AOGCC, dated April 11, 2007 states that a small amount of gas was percolating inside the cellar that the operator believes is "swamp gas" released by melting of the permafrost. This gas was sampled and found to be 100% methane at concentrations below the explosive limit. Mitigation plan stated at the time was to install gas detectors in the cellar and monitor them continually for increasing levels. I did not run across any further discussion. • • Aklaq No. 6 Confidential Well Data Description Form March 8, 2010; Rev. June 22, 2010 Page 2 The target Kugrua sediments were deposited in the distal lower shoreface and shelf; expected coarser - grained fades were not encountered. A single reported "black oil" show from the well was subsequently determined, through geochemical analysis, to be the consequence of drilling additives; it does represent an indigenous oil show. The reservoir rock has not received a significant migrated hydrocarbon charge nor much contribution from adjacent source rocks currently in the peak oil window.' January 14, 2008, FEX applied to DNR for extended confidentiality for Aklaq 6. The DNR has not yet rendered a decision. Formation Tops Formation / Marker Top MD Top TVD Top Subsea Source Permafrost 1225 1190 -1153 Operator Nanushuk 2791 2775 -2738 Operator Torok 3470 3446 -3409 Operator HRZ 6605 6558 -6521 Operator Kuparuk 6800 6753 -6716 Operator CCU 6880 6834 -6797 Operator Kugrua 7120 7073 -7036 Operator Test Results DSTs None Production Tests None Mud Log Gas Occurrences Type MD (ft) Mud Wt (ppg) First significant C1 in mud 510 9.8 First C2 3860 9.6 First C3 3325 9.6 1 Ruble, T.E. Jarvie, B.M. and Jarvie, D.M., 2007, Source Rock and Fluid Geochemistry of the Aklaq #6 Well, Alaska, Humber Geochemical Services, in AOGCC Well History file 2070090, p. 30. AOGCC • • • Aklaq No. 6 Confidential Well Data Description Form March 8, 2010; Rev. June 22, 2010 Page 3 First C4 3410 9.6 First C5 34 9.6 First C5+ AOGCC • • Aklaq No. 6 Confidential Well Data Description Form March 8, 2010; Rev. June 22, 2010 Page 4 Shows MD Sam le SoIv Resid Assoc. Mud Formation Rated Lith Stain p UV Cut Wt (ft) Fluor Cut Stain Gases (PPg) 3408- Nanushuk Gas Sdst - - - - C1 -05 9.6 3440 (2500 max) 4855- Torok Gas Sdst - - - V sli dull CI -CS 9.6 4930 pale yellow (1100 yel max) Torok Gas Sdst - - - - - CI -CS 9.6 5675- (942 5700 max) Torok Gas Sdst - try pale bri CI -CS 9.6 5800- slow yel pale (900 5845 yel yel max) strrng ring 6010- Torok Gas Sdst - - - - - CI -CS 10 6155 (900 max) 6180- Torok Gas Sdst - - - - - CI -05 10 6200 (600 max) 6315- Torok Gas Sdst - yellow - CI -CS 10 6460 (1690 max) Kugrua Gas Sdst - - - - - CI -CS 10 7120- (4450 7125 max) I 7190- Kugrua Gas Sdst - - - - - CI -CS 10 (1120 7225 max) AOGCC • . • Aklaq No. 6 Confidential Well Data Description Form March 8, 2010; Rev. June 22, 2010 Page 5 Cores Conventional Cores MD Range (ft) Cut Recovered Description 7125 - 7163 38 36.4 Fine to very fine - grained, clay -rich sandstone. Conventional Core Analysis MD Poro , Oil Formation Perm Sat Wate Description (ft) ( %) ! (md) (/) Sat ( %) -- — —. 1 -19 ! 0.01— Y Sandstone, very fine- to fine 7126 Kugrua Avg 0.17 grained, dolomitic, Avg glauconitis, siderite lamina 8.5 0.08 are very common Sidewall Cores None MD , Poro Perm Oil Water (ft) Formation (/) (md) Sat S at ( °�) ! Description Intervals with best permeability None Mean MD Range (ft) " Formation Perm Perm Range Description ' (md) Well File Notes Initial permit to drill approved by AOGCC on Feb. 27, 2007. The well was spudded on March 27, 2007 and reached total depth of 7280' MD on April 14, 2007. Sundry 307 -138 approved suspension of the well on April 20, 2007. The well was suspended on April 23, 2007. By letter received May 21, 2009, FEX requested extended confidentiality from the DNR. By letter received May 22, 2009, AOGCC has been instructed by DNR to withhold the release of Aklaq 6 pending DNR's decision. AOGCC r • Aklaq No. 6 Confidential Well Data Description Form March 8, 2010; Rev. June 22, 2010 Page 6 Note in file dated April 11, 2007 stating that a small amount of gas was percolating inside the cellar that the operator believes is "swamp gas" released by melting of the permafrost. This gas was sampled and found to be 100% methane at concentrations below the explosive limit. Mitigation plan stated at the time was to install gas detectors in the cellar and monitor them continually for increasing levels. I did not run across any further discussion. The target Kugrua sediments were deposited in the distal lower shoreface and shelf; expected coarser - grained facies were not encountered. No fluorescence or staining are visible in the conventional core. A single reported "black oil" show from the well was subsequently determined, through geochemical analysis, to be "the consequence of the addition of two drilling additives (Drill -N -Slide and Barablok) and do not represent an indigenous oil show." A reservoir sample from 7125.6' MD was analyzed and found to contain indigenous hydrocarbons with no contamination from drilling additives, however, the very low hydrocarbon recovery implies that the reservoir rock has not received a significant migrated hydrocarbon charge nor much contribution from adjacent source rocks currently in the peak oil window. " Conductor pipe was set to 80 feet and cemented to surface. The 9 -5/8 inch pipe was set from surface to 2072 feet and cemented to surface. The 7 -inch casing was set from surface to 7050 feet and cemented in multiple stages. The daily operations report dated 4/20/2007 has a description of "Remedial Casing Cement" associated with the comment "Annular top fill — Cement Job Went Well ". The operator's well completion diagram March 10, 2010 indicates cement reached the surface. This completion diagram does not indicate any cement or bridge plugs isolate the formations below the casing shoe from 7050 feet to total depth at 7280 feet. However, after review of the operations summary, Tom Maunder's opinion is that there is some cement in the open hole portion of the wellbore, and that the casing pressure test to 3500 psi for 30 minutes conducted on April 21, 2007 proves that the open hole section in the Kugrua Sandstone below the casing shoe is isolated by cement. The well status is suspended, and based on drilling results it is highly unlikely that petroleum fluids could flow to surface during plugging and abandonment operations. Production Records None - 2 - ic} 2 Ruble, T.E. Jarvie, B.M. and Jarvie, D.M., 2007, Source Rock and Fluid Geochemistry of the Aklaq #6 Well, Alaska, Humber Geochemical Services, in AOGCC Well History file 2070090, p. 30. s FEX L.P., 2007, DDR Detail, Date: 4/20/2007, Report: 30.0, DFS: 24.47, page 2/3, in well history file no. 207 -009 (Extended Confidential) AOGCC • • FEX L.P. - Schematic - Basic Page 111 Well Name: AKLAQ #6 I PBTD Depth (fti(B): lEditi Surface Legal Location Asset Branch State /Province License No Current Well Status I ZIIr' I ELReee FBI, Sec25, T,611. R „W, ,.. International Alaska Drilling Original KB Elevation (ft) Ground Elevation (ft) Casing Flange Elevation (ft) KB- Ground Distance (ft) KB- Casing Flange Distance (ft) 37.10 18.20 18.90 Oriq Confiq Typ: Vertical - Original Hole, 3/11/2010 12:41:58 PM ftKB Incl (ND) Actual ftKB (MD) Schematic - .Actual Cr Prf Stm -63 0.0 0 0 ( ) 0.1 19 19 iii::. ""''''111' - ., „,,,, l 0.1 22 22 ; r 0.1 24 24 0 0 0.3 99 99 # 1 II :16in,Des:ConducrnrPipe,Bm(MDj:99ftKB, 0 0 ■ Wt.:65.001bs /ft ID:15. 248in 0 / Conductor Casing, 19 -99 ftKB 0.3 99 99 0 0 0 d Tubing, 0 fIKB 2.8 1,350 1,350 • / $ $ / 0 ; Des:Tieback Liner, Btm (MD):1 350 ftKB 3.1 1,380 1 ,380 / i 1 7 c. AL / 3 ' M n 6.5 1,571 1,572 0 0 0 r , LEAD, 22 -1572 ftKB . � t 11.7 2,019 2,027 % 0 0 % O f} e e�••e 4 ./X 1- 35 44,44 0 0 % y /zo /o 7 L t 11.7 2,022 2,029 0 j _Q 12.1 2,063 0 / �"`- 2,071 0 OD:9 5/8in, Des:Surface Casing, Btm (MD):2,072 0 0 40 / ftKB, Wt.:40.001bs /ft, ID:8.835in 12.1 2,064 2,072 % TAIL, 1 ,572 -2,072 ftKB 12.4 2,093 2,101 I 0 / 0 1.7 5,454 5,500 Remedial Casing Cement, 22 -5500 ftKB 1.4 6,339 6,386 1 ;) Production Casing, 5,500 -6,386 ftKB 1.4 6,342 6,389 1.1 6,915 6,962 S 1.1 6,916 6,963 1.1 6,957 7,004 1.1 6,958 7,005 I 1.2 7,000 7,047 ii Production Casing, 6,386 -7,050 ftKB 1 / OD:7in, Des:Production Casing, D 7,050 1.2 7,003 7,050 ftKB, Wt.:26.001bsift g Btm ( } 7,280 Report Printed: 3/11/2010 • • FEX Aklaq #6 Post Drill Stick Deviated Hole °4� - 2107 . Or4k 41.1,g GEE . rtion C n.nw.1 NT t i i P jrca Wild Cri EApbrribn CDNFIDENTIAI ' ....omn... W. •mow row. L �u.a.wm KS.: lea n 5.2.202,2.110 146u11400,400 022.22.2. moomosaf 6516 50001 a.wir Though 00. wellhead 0612. fah* 0 ........„ 0.61' 02 WmuIK w... rr i° o..wa ..... • wu 1266 n r 1s • a 9311•sr 34 3.1/2 w 2003 era };wr. Sudka - 4 44_4.. 4444.__. 434 4 93 u i 9 :' r,.r 020 1022 20 u7 O4 . ' 840 10 _ ..r.. - _, � Dese P4mkhwl _ _ _ _ _44__4_4. .._!a+ uo. o __ . . . "a F r�.e.a.m wi..✓.w... 479.7. .__ WO k.. 6470.. ✓4444 wu .. 4 1# 112 • _ilm.w .22.wi✓.WI r,...rt anart, tr 15 43 922 lOd ler. '. : thnuNUk ytWQ 1......... 11.2 44 ( ._ `.'6'a.m^'rm 66161 ...- '° 2791 2276 . 2747 1270 94 Oj 344 as Bbl.wi .W.mw.r.M 3 .47944/1 bpptfM.1 I l 4. 4.�� ^ � 4...4, tr a 27 4412 e. as O.6 9.44 1A r r.. u > 1 ea.mowi a.1.rto W2MNili OP., 661 2 _.._.___..�_._ ._. ___ 4 4 4 4 • _ x _ _ _ 1 "4 _4_44 ..620 rlsar.....aw.rim4 Orr i ii 1 . 2078 142 4091 I # ( 95 01 j a« 066 • Turuk s.m.. .4.61 mr.ma4 1 . 1 ..a.n ..72179 • 1 a . _ ...l..rr.. km* r.m ___ nto-wr , ....er.n. r wa.rma.r 4ar•m ......40 401 �oa.rWlop 4720 Me ( 4461 1 MC 100 <y6 1.61 166 Torok Sand I' tam. a...... 1.91.4361. -,-_. ..o.wi40 •rwr.s.mrr .a.r.r•1176 Torok Sand 2 "'040 OPr..aaaar ....a. 613 420 MO +71Y 246 f 121 Oa 9.61 00 ....m rrwilral MOM . r.rr I .44 . O -h. S.M. a 1 Mr aW I 400 201 I w, 41 am 586 Torok !and 3° aaaaa ma 4.61. nlW30 __. ? 2424 r•.r...rmrr Torok SW 1• .m p.a., iii. .2424.. 02.1.0. 77 Me 1 00 I 4616 102 1 w 1 4745 3435 9 as ..__ ..- nro-m _._.. _._ + 444 . .-7- ._ .....2.2.1.1060.11.611....1•112 ...rM 1 - 09 05 ✓1..,.avoo.raN. P.. rm.. 00 . 4747 1 4212 BM 6407 406 6.66 10 r r j Torok Sold S' _ �.. __ . .- SM. xr .�. -_ !✓. - f- warm ammo! le lowill or. .0.00.. ..r..w•1M .6717 110 1ka I 466 ' 494 .. Pm*m.o. w mran•tar 1 M. 40 10 !Torok Seed ' r ... .2+. m nto• Om. _..7, ..r....maa m.m.ma.....a.r ........1746 .. r+r.ar r oar* ..4..40.•127 M4I 00 .40 324 111.11 OA C A0 0 Torok Sand e ...> nro•nark , • wi . r �rr•an _ . t .._._ 1 _ _ n10i u4 Mg 1, ilia { 4.4� I 9.0 10 .m40wimwi40 a mam a . . t r •1Y NM 6632 4 1 Torok Sand/ ra atmkne knew. UT. Hoar r O.....Paun s ...aaa..sa..mM 1 MM.. . , 017 1111 4521 314 aka I 4.0 F k0 b 3i'KN.P MOrw..a..'.n 112.1,..2 HRZ r1.4mw.uwawm..mrnwrmd , aw 10•MOW S 1 _ 444_4 - 4444._. 4.0. ' -_ , 11.10• MOW* 1 40 -1 81...0.44.4.h40.k41,0.m ar.6.11 1 201 00 4716 3620 00 00 I k0 00 1NuparukC ••• r�4....a.ralm.rr�.4al uram.am.lr Mull h a.ra _ 1 **am 22113.710204 79194 )oY2 � • : LCU 45'9 1 r 016 ; -00 301 I 1L1 i 40 I 294 ... 10 1 ' MssiMe. r.rr4014..1 /� rr.rl.9w.ra..... -a..r 1 00 OM ; 1211 NM 1 1 140 0.66 1 1161 ; 216 �ecu m } .___- }..._ / h ■ 0614 I' j «.. MD 120 I 417,11 MI +N 1 4.61 w I .as t I"�"°°"" "'2679. .r.. . w. n o*..mam.. ..rrf n. ...m. ( ' Upper Kin9ak `_ .1761 2772 s..laM.40.a0.wrr 720 201 ' '2 .202 307 •'•• • 111 ' 4j6 wad 696 I..awia....a..r..rr...r.m.r. Kulprua sfltsta4 14040..or __ g261±±4 i raw ma tea I ' • room. aia. . rl.9 w a a.r rmamm ' er rasa mot i 710. 701 4706 4476 i aka 40 1 k0 I 1.96 m w O•rrnar. 4menesm r. 6421 . I Y Lower Ku/rw arldaOna rrrwarr+. 1 11.71.6•106 1 ..._ ._. 4444 • .......... ,71.'..ro:m \ ..7.710 .al TM 720 MN 270 1 120 Oe III %CO 2 See. ma. CMOS MOMS ro .. I*Wa i t 4"_4_44 �._'_ ._' -- ! - . _ _� -- .__ 1 ! 1 I UMW"' OP 0.1.110 PIKKISMIlla r) dead PY prom 0YUCbr ada park GOM M. 0N. 2)1,43904 in Doyen ArcOC W01 born AOO9u0 2 b24607 Rip up aver Ma cana6*. mad 041161110 mtluctar plan. 3) aced UP good m4 60 m,d and dead sufaca hob b 2101 h Deviation became an awe an surface hats ark oar da4l let 01120 •. C4014030 sa al 2077 n a good sham - 4)k41Og up WK. prem. 005004 and 7901.0 re9ubmry apsrcws 0 horns prom eel. ....154 ma000600e10o.6k 041.1 hT rM m Ooaamain.42.479 a sorer4bbLWD road canon to dog me dear. nolo bad, an 12 947 1 WNe doing 4164846440161.004 sight.. 06101 in 914 Tan Sans. ca.ou m earbd0ato and no loam*. aama4op LCM as ..gwad 15 awe 400000 DNm aneaa to cae pant e17125 h Canrwa to b9w towslara 10p30p0e1 Te Tara Sanc, men losses ware camp 2792 coed ham m 7163 O. liar 29..792 WS... caring et 7133 h.. Ran m.1m 61.A 0.400 buns m. TOW to 71) . Performed • 4944 2.94 to clean hole 00 .5.9 WNW foaming at 6905 6 0018 tare of slow Plat ratter 202465 prove. m be a 61,9402000 0 aN a.. 1440 and aa,pnauemas 5) B 2 of hb o caeam 792 tyre ns aM 09 004 4798 Me 1 1 a not performeperformed a p N performed o41 vas nor 1201.11. 1201.11. pa la m. / .15..4 cups 0)14a200 de u2 p 24609.2. m stn fondue 4202224044 422244 ' Tosco 2790 ue ungs. osco Ca aura. mot 3633 6 h wake awmam and established lass ram a 90 69411. A17037 M 4.94 O...101.... ..,.a 43:46 24140k pump. vat: partial rahons Cut could not romte woe. Worked 094010 70506 and 79400791.4 005.0 d0 50ap1A 7)Ran cased woe bps and suspanaed 800..m 138011 90 08010, ....0 of. awl ...1.10,1 L ....1. 194.[6 07 0`04 0 f.61 ...Iwo 0 W1 1040m..7.•.am.1 .tmay.l Lvov.,✓ M m is m q a 4 6 070 , 216 4_444.. _. 444. 44 44.. wo-w., erne � # � t i 1 AM 2740 � 300 1 . �"' _44.. • 44_40 7791711.947 ' . tmm. .......r. ....Ire mw am r T M n T 11m7 4 I .40A 1.40 area orom KO K w .1279 6 wizen ..wm,wi.... 2,00 01 .. .. iwo _'_{_ : '�-� -. I .. _ . -.. I.Ora.nW Two wow. 91 261.47 I W .....1.13. I.2)90 a.1m.1I ....4 1207.4I2261".1 r.,......., ...2....14 ma ' 1006 i fw 179 ■ 2.621 rt i okra ■ _. 4444.. -... n... 00. Kv r.wiM.. 020 1 - a.* flee ■ en #9 use 1 E ANM 1 ! ♦ ♦♦ � M r. ow 61 a a Ktl:C.rw.w6•A! 3.0.441 y_ 207.4 W4 4020 m 1107 awe i 11 awn news 0 4444. _ 4.,.026114 - -- KCt.C.r....r0�_ , _.W 094 We 1 fm4l If19 1 1f0 K3 j 42 L _ -_ 1wm /140aOawl6raYYWnm. 6napm0lberw a.m.0w.aoc<e.*4 ,, _ . 1ry J boo* . Ku et 4ra.r.r.mn 1v 474.. 19 u4141er4r) Yad,e1400..4140161 _- - 1 t F aw...FLR„•. 41 wn.a.anl40 awi40.R�2Y.maw rlr 11 c - � _._a_ ___. _. -}00. ru .. w. 1 Y . °I .. "n_ _4 444. �-1 I 61k OR mm e.r0.........,..........-7,-,........, --,.. 4 6�IW rP k.maanM - - 100 pi _ IraY .ka.saparwp�..atsnm• •94701114 ...._.�_ ; _. TMa�.m��..- .�•�.or, .ro a40.r ` ww.. r ..r. w...... .,.1r.rrm 040...1.• """• 40204017.0.epr..r>o. 4*4s aw0rw.mn.• eox...r..rwi .wi mane Aau4ae.ra __ . ...40a..40aaw• awi40.�. ......,,.«.a.. w ru__ ✓. 4044. w..wmaNww40..wiim�..a ........wean 40. 0.✓,..n...r.+.....0r..4 .s a..awm.,.,.,..6 900 •mer..040010anaarw. mar.:. mree 702797 a 1.1e1o..1 0.41.... 6,.70..010 14rW 2174 11410 la 100.99.0. YO.. 450.1....140 4..4•0.0'0 PO 4761 mw 0..1 , m .rtawi OO..rt b m 0 sun.:... .nMMla�r -t allI M _ ld .mwY ._._ # 1�aa mtx ow .._ ___.. 44_4 ' yysy rr��' M.m„arO.1R4WwCmr. #tor 11.4 0.Y 01 1 2121.0 2227 _.� _ -- 4.....___.. e ea m..20 w Ik10m.,ar0• 111,14.040.a. A.W1Ha•a210 eaa. 010 i #0 ' 0i 4 v. .uw.,0 1 14 nw..m 00.42 ,15 40.2. 2107! a •ko4s4u • 79 ..797.2401 v2...✓- 2.......40T- 0010g61?Ck (... aw• 6161 .. K.... 7...g. ama _ Post Drill Sept . sly . -_. PreparedbPSceep.V0k- /OM&A)O7- -_. - ._4444 Page • F E FEX L.P. 3601 C STREET, SUITE 370 ANCHORAGE, ALASKA 99503 June 15, 2010 TEL (907) 644 -4429 FAX (907) 644 -4892 Stephen Davies, Petroleum Geologist, t) State of Alaska, Oil & Gas Conservation Commission, JUN 1 5 2010 333 W. 7 Avenue, Ste. 100, Anchorage, Alaska 99501 ; ak( & ett Comihigil Apthtr t Subject: Release of Confidential FEX Well Information to the ADEC Dear Steve, In 2011 FEX L.P., is planning to return to the Northwest NPR -A to abandon three suspended exploration wells drilled during the winters of 2006 and 2007. These wells include Aklaqyaaq #1, Aklaq #2, and Aklaq #6. The abandonment operation is scheduled to commence in mid - February and be completed by mid -April. The well information from Aklaqyaaq #1 has been released by the AOGCC, but the data from both Aklaq #2 and Aklaq #6 is restricted because of an extended confidentiality provision requested by FEX. On June 14 we conducted an informal meeting with the Alaska Division of Spill Prevention and Response to discuss the proposed abandonment operation and the necessary compliance requirements. All three wells have been cased and cement plugs placed in the deeper sections of the wells. During our discussions Laura Silfven (Environmental Program Specialist) she stated the AOGCC was unable to provide the Alaska Department of Environmental Conservation (ADEC) with critical information from Aklaq #2 and Aklaq #6 because of the extended confidentiality provision. On behalf of FEX L.P., I would be grateful if you could provide the ADEC with the appropriate information they require from these two confidential wells. The AOGCC has our full approval to ensure all critical data necessary for spill prevention and response be made available to ADEC. Please let me know immediately if this request might present any problems. At ?Tb 3T1--00 9 • s ,A si cerely is are arrard, Geoscience manager, FEX L.P. 1(907) 644 -4429 a Delaware Limited Partnership with Registered Office c/o CT Corporation 1209 Orange Street, Wilmington, DE, 19801 • 1 T -c Za -009 • 3. •141.34CZ 4 G Webote Job Date anron:a Hnh J I <no ,ot> Jr I <rcw> � ► 11 H4 N K .+1 r Ong Config Typ Vertical • Drone' Hide, 711872007 430 51 P+.1 tq� (A) Ira Scnemetic - Actual i t -63 19 0.1 . .. .., = 22 0.1 24 0.1 Original Hole, Conductor, 24n, 99 *03 il 99 03 ICorduccr Pioe,16n, 65 CCbs tt, H -40, 99 11<B / ' 93 0.3 Cmrt, Conductor Case g,19.39 ttKB ' 0 Original Hole, Surface, 12 t i4n, 2,101 td<B 1,350 2 8 Tieback Liner 1 350 5KB 0 0 I t • 1 572 6 5 Cmrt, LEAD, 22 -1,572 11KB I • 0 II • 2,027 11.7 0 • I r I 2,029 11_7 '� I �' rr 2,071 12.1 {I . P 1 Surface Casing, 9 5,8n, 40.CCbsttt, L -80, 2,072 1tKB 0 t: ' 2,072 12.1 Cmrt, TAIL, 1,572.2,072 t1KB 2,101 12.4 i Original Hole, Production, 8 1 /2n, 7,280 Rl<B — 5,500 1 7 Cmrt, Remedial Casing Cemert, 22 -5,500 1tKB 6,386 1 .4 Cmnt, Production Casing, 5,500- 6?8611KB 6,389 1.4 I 6,362 1.1 1 I 6,963 1 1 7,004 1.1 1 7,005 1 7 7,047 12 Cmrt, Production Casing, 6,386 -7,050 11KB , 7,050 1 2 'Production Casing, Tn, 26 CObsttt, L -80, 7,050 ttKBJ 7,280 1 SARAH PALIN, GOVERNOR DEPARTMENT OF NATURAL RESOURCES 550 WEST 7 AVENUE, SUITE 1100 ANCHORAGE, ALASKA 99501 -3560 DIVISION OF OIL & GAS PHONE: (907) 269 - 8800 FAX: (907) 269 -8938 CERTIFIED MAIL P \ :�* f: RETURN RECEIPT REQUESTED ' " MAY 2 2 400 May 21, 2009 Alaska Oil & Gas Cons, Ctnr €., < „ , :.. Richard Garrard Anchorage Geoscience Manager FEX L.P. 3601 C St., Suite 370 Anchorage, AK 99503 Subject: Request for Extended Confidentiality - Aklaq No. 6 Dear Mr. Garrard: The Department of Natural Resources, Division of Oil and Gas (Division) received your May 20, 2009, request under 11 AAC 83.153 to extended the confidentiality of reports and information required under AS 38.05.035(a) for the Aklaq No. 6 well. The Aklaq No. 6 well is located in the National Petroleum Reserve — Alaska more than three miles from unleased acreage. By copy of this letter I am advising the Alaska Oil and Gas Conservation Commission (Commission) that the Division has received your request to extend confidentiality and ask that the Commission withhold the release of Aklaa No. 6 well reports and information pending the Division's decision. If you have any questions, you may contact Julie Houle at 269 -8773 or by e-mail at julie.houle @alaska.gov or, in her absence, Don Krouskop at 269 -8766 or by e-mail at don.krouskop@alaska.gov. Sincerely, Kevin Banks Director cc: D. Seamount, Commissioner, AOGCC J. Norman, Commissioner, AOGCC C. Foerster, Commissioner, AOGCC J. Houle, DOG "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans.” • SARAH PALIN, GOVERNOR DEPARTMENT OF NATURAL RESOURCES 550 WEST 7TH AVENUE, SUITE 1100 ANCHORAGE, ALASKA 99501 -3560 DIVISION OF OIL & GA PHONE: (907) 269 -8800 FAX: (907) 269 -8938 CERTIFIED MAIL RETURN RECEIPT REQUESTED May 21, 2009 RECEIVED Richard Garrard MAY c 2 1 2009 Geoscience Manager Alaska O i (;� Cons, FEX L.P. Anchorage s ons. Co m m ission, 3601 C St., Suite 370 Anchorage, AK 99503 Subject: Request for Extended Confidentiality - Aldaq No. 6 Dear Mr. Garrard: The Department of Natural Resources, Division of Oil and Gas (Division) received your May 20, 2009, request under 11 AAC 83.153 to extended the confidentiality of reports and information required under AS 38.05.035(a) for the Aklaq No. 6 well. The Aklaq No. 6 well is located in the National Petroleum Reserve - Alaska more than three miles from unleased acreage. By copy of this letter I am advising the Alaska Oil and Gas Conservation Commission (Commission) that the Division has received your request to extend confidentiality and ask that the Commission withhold the release of Aklaq No. 6 well reports and information pending the Division's decision. If you have any questions, you may contact Julie Houle at 269 -8773 or by e-mail at iulie.houle@alaska.gov or, in her absence, Don Krouskop at 269 -8766 or by e-mail at don.krouskop(?a,alaska.gov. Sincerely, N'Ud Kevin Banks &I Director cc: D. Seamount, Commissioner, AOGCC J. Norman, Commissioner, AOGCC C. Foerster, Commissioner, AOGCC J. Houle, DOG "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." a, d ?- u d 01 F i . • r F E X F EX I.. P. ie ul t STREET. SI - 1 1 I. 3 ?r7 AN( F10ltAtil., :ALASKA A 9950.3 FI1. 1007) 644 -442 t907 1 644.4892 Ms. Julie Houle Section Chief— Resource Evaluation Department of Natural Resources Division of Oil and Gas 550 West Seventh Avenue, Suite 800 Anchorage. AK 99501 Subject: Alaska NPR -A, Aklaq #6. Request for Extended Confidentiality Dear Julie, In 2007 FEX L.P., in conjunction with Petro - Canada (Alaska) Inc., drilled the Aklaq #6 in the Northwest NPR -A. The exploration well was spudded on March 27 and reached an ultimate TD of 7,200" MD on April 14 Because of lost circulation problems this operation proved to be a very difficult. time consuming, and expensive, although the geological and engineering information gathered is considered to be of significant value. As insufficient time at the end of the winter operating season prevented from further evaluation being undertaken, the well was temporarily abandoned. We note that the latest AOGCC "Well Records to be Released" lists the Aklaq #6 well data as being scheduled for release into the public domain on May 23 2008. Because of the importance of this information in our ongoing exploration evaluation of the NPR -A region we would like to request an extension to the existing confidentiality provision for the Aklaq #6. The justification for this request is as follows. 1) FEX is intending to return to the Aklaq #6 well and perform a stimulated testing operation during the primary term of the lease. At present no tests of this nature have yet been undertaken on the North Slope in a remote location under the current regulations. Conducting a meaningful and commercially viable test will be both difficult and costly. 2) In 2008 in conjunction with Petro- Canada FEX acquired a large 3 -D seismic program covering the Aklaq #6 and the adjacent onshore and offshore areas. These data are being evaluated in an attempt to better understand the reservoir distribution, estimate the resource potential, and determine additional potential drill sites. Technical, engineering and commercial studies are still actively taking place. 3) Approximately eight miles to the north of Aklaq #6 is a small area of open acreage on BLM lands separating our State Leases offshore in Smith Bay and our a 11t•'.st,ale L inule+1 Pertncr,ilip t.ith I1egist.`md ()Hike . n t 'l C.,rporanon I20 tlt.rnge \treet, \Ytltmli tors. OL. 16801 • .-• • t • onshore Leases in the Northwest NPR -A. This area was not made available for bidding during the 2008 BLM Lease Sale. At present we are unclear when the BLM will hold a new lease sale covering this area. Our main concern might be an opportunity for unwanted land speculation eventually taking place based upon the Aklaq #6 well information. 4) To the northeast of Aklaq #6 is the prospective North Teshekpuk Lake region that was deferred from leasing in 2008 by the BLM for 10 years. FEX submitted bids for certain key tracts in this area during the 2006 Lease Sale that was eventually cancelled. There are geological trends extending in to this area from Aklaq #6 that are now covered by our proprietary and speculative 3 -D seismic data. In addition, all of the allocated leases between the Ikpikpuk River and Teshekpuk Lake are scheduled for relinquishment on August 31 2009. 5) To the northwest lies additional open acreage in the vicinity of Cape Simpson, the Dease Inlet and the Meade River drainage. No leases were offered for tender in this area by the BLM during the 2008 Lease Sale. The BLM has also implemented a no surface occupancy provision on all new leases ( "The Barrow Triangle "). The status of this geologically similar area under the current administration is at present not understood. 6) Six miles due east of the Aklaq #6 lies ConocoPhillips suspended Puviaq #1. This well drilled in 2003 is still under extended confidentiality although it does not appear on the AOGCC list of "Alaska Wells with Extended Confidentiality ". FEX would feel some what uncomfortable if Aklaq #6 was released while ConocoPhillips can keep Puviaq #1 confidential. To our knowledge ConocoPhillips has made no plans over the last six years to return to this well and continue operations. We would appreciate your cooperation regarding our request for extended confidentiality and look forward to hearing from at your earliest convenience, u h. sincerely. di „ • .. .. :'rrard Geoscience Manager FEX L.P. CC. Dave Mithen Kevin Ramage Dan Seamount Cathy Foerster • • .207 - Mr. Tom Maunder AOGCC 333 W 7 Ave, Suite 100 Anchorage, AK 99501 -3539 Re: Request for Verification of Suspended and Shut In Wells Dear Mr. Maunder: The list of Suspended and Shut In Wells for FEX LP has been reviewed and is complete. There is a slight difference in the Aklaq #6 location as recorded on the aforementioned list. The location documented by the AOGCC for Aklaq #6 is the "As Staked" and not the "As Built ". The difference is as follows: As Staked 2955 FSL 2307 FWL Sec 25 T 16N R 11W J As Built 2982 FSL 2298 FWL Sec 25 T 16N R 11W The appropriate Sundry Notice will be submitted to AOGCC to officially correct the Aklaq #6 surface location. FEX appreciates the effort of AOGCC to inform the Operator of revisions to the Alaska Oil and Gas Regulations. Sincerely, e- / Paul Mazzolini Operations Manager ROOMS BFL. APR 1 0 2009 FW: • Page 1 of 2 Maunder, Thomas E (DOA) From: Mazzolini, Paul PMAZZOLINI talisman -ener com Do \-ooh Sent: Monday, April 13, 2009 1:16 PM To: Maunder, Thomas E (DOA) Cc: Erickson, Laura Subject: RE: Attachments: 06242 AKLAQ6 AS- BUILT.pdf Tom, Please see the attached "as built" survey from Aklaq 6. Let me know if you require additional info. Regards Mazz From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, April 13, 2009 11:34 AM To: Mazzolini, Paul Cc: Erickson, Laura Subject: RE: Mazz, Regarding the differences in surface location on Aklaq 6, could you provide the ASP (NAD 27) coordinates? Thanks in advance. Tom Maunder, PE AOGCC From: Mazzolini, Paul [mailto:PMAZZOLINI @talisman - energy.com] Sent: Thursday, April 09, 2009 3:56 PM To: Maunder, Thomas E (DOA) Cc: Erickson, Laura Subject: FW: Tom, Good speaking with you today. Please see the attached memo below that was sent concerning the difference of the Aklaq 6 location as staked" and "as built" locations. The AOGCC has the "as staked" location on file vs the more correct "as built ". After you have the opportunity to review with Steve Davies let me know if additional efforts are required to correct this oversight on the part of FEX. Thanks in advance for your assistance. Regards 4/13/2009 • 410 aC)`' 000 DATE: 03 -22 -07 I SCALE: 1" = 2001 SHEET: 1 OF 1 Barrow REV DATE DESa+wnar REV DATE DESCRIPTION PROJECT SITE NOTES: Kaktovik 1. COORDINATES SHOWN HEREON ARE ASPC NAD -83, ZONE 5 :. P' r' —* I� r z at 2. ALL DISTANCES AND ELEVATIONS ARE IN U.S. SURVEY FEET , , , , . ,, ., . 1 3. FIELD SURVEY CONDUCTED MARCH 18, 2007 it " ... . ' _r_ I i IL x - -- ' . " 3 ' g ':. 4. PROTRACTED SECTION LINES HEREON ARE SHOWN FOR • REFERENCE ONLY AND ARE APPDXIMATE t ' µ 1 ' _ ' r r 41 VICINITY MAP - NOT TO SCALE AS -BUILT OF AKLAQ #6 PAD ----VA— 2298' —I Pp AKLAQ #6 co N N -0 . �� CONDUCTOR LOCATED WITHIN PROTRACTED SECTION 25, Li w T. 16 N. R. 11 W., UMIAT MERIDIAN O� 011‘ ACCESS RAND HAD 83 LAY DOWN LAT: 70 °42'43.229" N AREA LONG: 154 °36'39.748" W NAD 83 ZONE 5, ASPC, SURVEY FEET N = 6,110,316.1 0 Z� E = 1,566,489.3 I D . AKLAQ #6 NAD 27 * 0 . CONDUCTOR LAT: 70 °42'44.662" N a LONG: 154 °36'27.778" W 0 z I S HAD 27 ZONE 5, ASPC O - 4 N = 6,110,601.8y �"'— a \NO Q�t \ PROPOSED E = 426,473.1 )C, / �� a � c. \ ACCESS TOP RIM OF 16 WELL I k \ \ CONDUCTOR CASING W N \ GEOID 2006, ALASKA E 1 ELEV = 20.2' (N I TEMPORARY . Q (APPROX. MSL ELEVATION) I l i o ACCESS 30' ICE ROAD * CONVERTED FROM NAD 83 BY NADCON a 3 LEGEND 0 100 200 0 _ O a• "" FEET j * 16" O.D. SCALE 200' rr CONDUCTOR 1 f!! l ° SEC. 25, T. 16 N., R. 11 W. 'c ! O A`"qs`� if- LJ SEC. 36, T. 16 N., R. 1 1 W. / � ® � � P ' � - l 9 �� A A% 3 , * /\ •. * / W � I._ SU CERTIFICATE LL / N I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE �� • , • , • • ; v STATE OF ALASKA AND THAT THIS ASBUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT i 0 0 � S UPERVISION AND THAT AU. DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 18, 2007 • KENNETH J. PINARD . . No. 11545 • r � 4 I.,. • • Z r r, , • . ,., I..cM 11 ffSSpNAI � z P r r , FE L.P. e n Mimi &InuplRtCDrPOratbnCuRgany �NL‘N,,,�-%-461.. o 2307 (DRAWN BY: LHH I CHECKED BY: KHE I W.O. No: 2006 -242 Humble Geochemical Services Division of Humble Instruments & Services, Inc. rn ` 218 Higgins Street Humble, Texas 77338 P.O. Box 789 Humble, Texas 77347 Telephone: 281 - 540 -6050 Fax: 281 - 540 -2864 SCANNED MAY 2 8 2013 Source Rock and Fluid Geochemistry of the Aklaq #6 Well, Alaska Prepared for Talisman Energy Prepared by T.E. Ruble, B. M. Jarvie and D.M. Jarvie Project 07 -4547 Humble Geochemical Services Division RECEIVED SEP062007 June, 2007 Alaska Oil & Gas Cons. Commission Anchorage 06 ai_ t(''' cae& Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division • • Drilling . Project Transmittal 2007 d, +r Qom R eserve Alaska To: State of Alaska Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 September 6, 2007 Attn: Steve Davies From: FEX L.P. RECEIVED 3601 C Street, Suite 370 Anchorage, Alaska 99503 S E P 0 6 2007 RE: Aklaq #6 Alaska Oil & Gas Cons. Commission Anchorage 1. 1 print copy of Baker Hughes RCI - Gasview Mode 2. 1 print copy of Baker Hughes SBT /CCL 3. 1 print copy and CD of Baker Hughes META, LAS 4. 1 print copy and CD of Corelab Conventional Core White Light / UV Photography 5. 1 print copy and CD of Conventional Core Analysis 6. 1 print copy and CD of FEX/Talisman Sedimentology of the Kugrua Sandstone from Aklaq #6 7. 1 print copy and CD of Humble Geochem Services, Source Rock and Fluid Geochemistry Delivered by Date t 161 266 Y Received by \ Date ` - (o - U 7 iS'3/5 /S /s 9 41 3 o� � /5319 1 5 -390 Drilling Transmittal Project 4 2007 -c "4 • e fr To: State of Alaska June 15, 2007 % °'^ ReSe A,aska Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 Attn: Steve Davies From: FEX L.P. 3601 C Street, Suite 370 Anchorage, Alaska 99503 RE: Aklaq #6 1. 1 box of Core Chips for Aklaq #6 Depth listing - 7126 7127 7128 7129 7130 7131 7132 7133 7134 7135 7136 7137 7138 7139 7140 7141 7142 7143 7144 7145 7146 7147 (31 7148 • • Aklaq #6 Core Chips 7149 7150 7151 7152 7153 7154 7155 7156 7157 7158 7159 7160 7161 7161.4 Delivered by .Livi Date 6 Received by _ � 1: 4- Date 4/S -O,7 RECEIVED STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM► SION JUN 0 7 2007 WELL COMPLETION OR RECOMPLETION REPORT LOG la. Well Status: Oil El Gas Plugged ❑ Abandoned ❑ Suspended 0 l b. We 8as�: t ads Gins. t.ammis ;ion 20MC 25.105 20AAC 25.110 Development ❑ A ncf aso eatory 1511 ' GINJ❑ WINJ❑ WDSPL❑ WAG Other No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: An., FEX L.P. Aband.: April 23, 2007 207 -009 �' Q�f' -- / ? - £ 7 3. Address: 6. Date Spudded: 13. API Number: 3601 C Street, Suite 370 Anchorage AK 99503 March 27, 2007 50- 279 - 20019 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2307'FWL,2955' FSL. Sec. 25, T16N, R11 W. UM April 14, 2007 Aklaq #6 - Top of Productive Horizon: 8. KB (ft above MSL): 37.4 15. Field /Pool(s): 2307 'FWL,2955'FSL.Sec.25,T16N,R11 W.UM Ground (ft MSL 16.4 Total Depth: 9. Plug Back Depth(MD +TVD): Wildcat 2307'FWL,2955' FSL. Sec. 25, T16N, R11W. UM NA 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 426473 y- 6110601.8 Zone- 5 7280 AA- 085517 - TPI: x- 426473 y- 6110601.8 Zone- 5 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 426473 y- 6110601.8 Zone- 5 NA LAS 25297 18. Directional Survey: Yes El No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) 1060 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD Gamma,Resistivity, Neutron,Density,Sonic 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 65# H -40 0 80 0 80 20" 50 bbls Type C cement NA 9 -5/8" 40# L -80 0 2072 0 2072 12.25" 0 -2072 Cement to surface NA 7" 26# L -80 0 7050 0 7050 8.5" 4500 -7050 Multi-stage NA 23. Open to production or injection? Yes ❑ Noel If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) NA - 3.5# 1413 N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 0 -4500 (9 5/8 annulus) 45 bbls Class G, 35 bbls Permafrost Cement 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NA Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period -O. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate •-■ 27. CORE DATA Conventional Core(s) Acquired? Yes El No ❑ - Sidewall Cores Acquired? Yes ❑ No El - If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. A core was taken on this well from 7127 -7163 MD. A full detailed report will be submitted with this report. COMPLETION A comprehensive summary of the geology on this well will be submitted with this report. ,t ® G>� Full detailed reports of mud logs and MWD logs will be submitted with this report. No wireline logging was performed on this well. ��]��yy��Q�+ BFL q ,, �tataJArlm7 ®F� JUL 6 200 4 ��' Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE I ( �/h 6- �. 07 O RIGINAL . /0T /f7 . • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes El No 0 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Base Permafrost 1225 1190 No well tests performed on this well Nanushuk group 2791 2775 Torok 3470 3446 Torok sand 1 t 4734 4688 HRZ 6605 6558 Kuparuk Sandstone 6800 6753 LCU 6880 6834 Kugrua Sandstone 7120 7073 Cored 7127 to 7163 Formation at total depth: 7280 7233 - Kingak 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Paul Mazzolini Title: Operations Manager Signature:. / ' / Phone: 907 771 1923 Date: 5/31/2007 / 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 la: 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 and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 NOTES: Barrow 1. COORDINATES SHOWN HEREON, BASED UPON STATIC GPS PROJECT OBSERVATIONS SITE 2. VERTICAL DATUM: MSL (GEOID 2006, ALASKA) - A' -- Kaktovik 3. ALL DISTANCES AND ELEVATIONS ARE IN SURVEY FEET Nuiqsut 4. 0.5' CONTOUR INTERVALS BASED UPON FIELD SURVEY CONDUCTED 08 -24 -06 5. PROTRACTED SECTION LINES SHOWN HEREON ARE ! l ' } � f `'11 APPROXIMATE AND FOR REFERENCE ONLY -e. � . T • - L l■SEASTUAVE"UESOREIID,N. MOW. an Ukpeagvik Inupiat Corporation Company VICINITY MAP V ► , \- 2307' - N N 16 / 0 U U // 2 w w cn to 5 = /15 4 � � oar re 0 0 0, 9 0 - 6 1 `E r *. F z c0. NOS 00 e / - SCALE: 1" = 200' 1y / AKLAQ #6 WELL a A � LOCATED WITHIN 1c� 0 p, ° Ag1 • � 1 �' PROTRACTED SECTION 25, ' T. 16 N. R. 11 W., UMIAT MERIDIAN 6_0.o 6 AKLAQ �' 7.06 NAD 83 #6 R P AKLAQ #6 LAT: 70 °42'43.229" N WELL LONG: 154 °36'39.378" W 6 NAD 83 ZONE 5, ASPC, ° /\ SURVEY FEET 7 rn 's N = 6,110,316.13 I \ O \ E = 1,566,489.64 o �O. 0 E id o N6 :0 NAD 27 LAT: 70 °42'44.662" N N LONG: 154 °36'27.769" W ° I NAD 27 ZONE 5, ASPC * p, N = 6,110,601.780 v E = 426,473.428 vi J J 3 MSL ELEVATION (GEOID 2006, ALASKA) Lti SEC.26 SEC. 25, T. 16 N., R. 11 W. _ 16.4' — — N SEC.35 SEC. 34, T. 1 6 N W. o * CONVERTED FROM NAD 83 c ° v BY NADCON iil s a z o AKLAQ #6 EXPLORATION a FEX y 4 WELL SITE AND PAD LAYOUT E Drilling . NPR —A, ALASKA 0 Project -. F EX L P a 2007 _ . DATE: 9 -19 -06 DRAWN BY: LHH SHEET: 1 OF 1 _ S SCALE: 1" = 200' CHECKED BY: KHE W.O. No: 2006224 a , 1 • Halliburton Company • Survey Report �i - ��� 4 ,,,e _ � ,c - , D ate a. 15 0 Q � ranee 08 ;53 45 • ` a a e r 2 . ''Fie A N 20 e 5 f " y . -fit ' 7 , i Co " o g in y a y te &E ' 'eferen - -,. a f��epp q 6 rue h ` ' . : .. x .: 3`F * 6 _.� M � "4 , ? t\ i l e r Rtak 5 '; _ , '� '' $� ,, Y y " 4 S ec on ttree r 1Wei i a0 I O0E29' tAzt - ' h' 4.��� a �� e .. �%i r Yrs' � e .x ! ��` T 5} } 3 ?5. L `R 3. ' 1~ llpath a • . F ,,:y 1 S ti utv ey ctu 1atio} t 1i 1 Cu i t D $*- O ra d e a .3 ��4����p t_ a r .. t . -.'XI 'h � ` .. .R �t�, ..„„a u.x . s .r , -... ,... r n. !c ,,,L .,.. *` 9' _4 aw,u - . ,. . s 4 Survey Sri 1 #Tack } '; P ,.'TV ;'`'L s-t D N(S ' FJW� $1,:": MapN: tap ° # aoi' 4 ? 4 rd . , deg ,: t t H . . . : ' ... ... r' , , •V g•a " . ' i ,. -- ` 2944.15 3.51 105.74 2927.36 2831.46 -25.49 - 180.68 6110578.12 426292.19 MWD 2999.32 4.50 79.32 2982.40 2886.50 -25.55 - 176.92 6110578.03 426295.95 MWD 3068.73 6.38 55.85 3051.50 2955.60 -22.88 - 171.05 6110580.64 426301.84 MWD 3130.71 7.43 45.78 3113.03 3017.13 -18.15 - 165.33 6110585.31 426307.61 MWD 3186.24 10.79 42.98 3167.86 3071.96 -11.84 - 159.21 6110591.56 426313.80 MWD 3255.80 12.13 49.57 3236.03 3140.13 -2.33 - 149.20 6110600.96 426323.89 MWD 3319.68 12.43 53.38 3298.45 3202.55 6.12 - 138.58 6110609.31 426334.61 MWD 3379.03 12.83 56.28 3356.36 3260.46 13.59 - 127.97 6110616.67 426345.29 MWD 3442.67 14.19 59.11 3418.24 3322.34 21.52 - 115.39 6110624.47 426357.94 MWD 3505.14 12.92 60.74 3478.97 3383.07 28.86 - 102.73 6110631.69 426370.68 MWD 3563.29 12.97 66.14 3535.64 3439.74 34.68 -91.09 6110637.39 426382.37 MWD 3631.28 13.29 76.24 3601.87 3505.97 39.63 -76.52 6110642.19 426396.99 MWD 3691.59 14.78 83.08 3660.38 3564.48 42.20 -62.14 6110644.62 426411.39 MWD 3753.91 16.25 92.60 3720.43 3624.53 42.77 -45.54 6110645.02 426428.00 MWD 3816.47 17.20 102.96 3780.36 3684.46 40.29 -27.77 6110642.37 426445.73 MWD 3878.61 16.59 109.43 3839.82 3743.92 35.28 -10.45 6110637.18 426463.00 MWD 3941.46 13.85 114.58 3900.46 3804.56 29.17 4.86 6110630.91 426478.25 MWD 4002.87 11.19 119.79 3960.41 3864.51 23.15 16.72 6110624.78 426490.05 MWD 4066.52 9.70 119.64 4023.00 3927.10 17.43 26.74 6110618.96 426500.01 MWD 4127.27 7.01 130.05 4083.11 3987.21 12.51 34.02 6110613.97 426507.24 MWD 4192.30 4.94 148.28 4147.79 4051.89 7.58 38.53 6110608.99 426511.70 MWD 4256.10 4.60 186.68 4211.38 4115.48 2.70 39.68 6110604.10 426512.80 MWD I 5.07 202.87 4269.82 4173.92 -2.02 38.40 6110599.39 426511.47 MWD 4378.25 4.76 208.82 4333.09 4237.19 -6.92 36.04 6110594.52 426509.06 MWD 4440.34 3.41 230.26 4395.03 4299.13 -10.35 33.38 6110591.12 426506.37 MWD 4503.08 3.45 276.70 4457.67 4361.77 -11.32 30.07 6110590.18 426503.05 MW D 4565.18 3.62 297.12 4519.65 4423.75 -10.21 26.47 6110591.32 426499.46 MWD 4629.17 3.33 298.41 4583.52 4487.62 -8.41 23.04 6110593.16 426496.05 MWD 4687.61 3.17 296.53 4641.87 4545.97 -6.88 20.10 6110594.72 426493.13 MWD 4751.47 3.10 297.70 4705.63 4609.73 -5.29 16.99 6110596.34 426490.03 MWD 4813.76 3.03 297.55 4767.83 4671.93 -3.75 14.04 6110597.91 426487.10 MWD 4875.78 2.93 296.24 4829.77 4733.87 -2.29 11.16 6110599.40 426484.24 MWD 4938.94 2.82 298.82 4892.85 4796.95 -0.82 8.36 6110600.89 426481.45 MWD 5001.16 2.76 297.24 4955.00 4859.10 0.60 5.69 6110602.34 426478.79 MWD 5064.08 2.57 _ 300.12 5017.85 ____ 4921.95 2.00 3.12 6110603.77_ 426476.24 MWD 5126.76 1.93 285.14 5080.48 4984.58 2.98 0.89 6110604.77 426474.02 MWD 5187.76 1.82 285.89 5141.45 5045.55 3.51 -1.03 6110605.32 426472.10 MWD 5252.81 1.74 281.17 5206.47 5110.57 3.99 -3.00 6110605.81 426470.14 MWD 5315.13 1.75 285.31 5268.76 5172.86 4.42 -4.85 6110606.27 426468.30 MWD 5376.45 1.97 282.87 5330.05 5234.15 4.90 -6.78 6110606.77 426466.37 MWD 5435.66 1.96 282.54 5389.22 5293.32 5.35 -8.76 6110607.24 426464.39 MWD 5500.91 1.67 283.79 5454.44 5358.54 5.82 -10.77 6110607.73 426462.39 MWD 5626.74 1.33 289.67 5580.23 5484.33 6.75 -13.92 6110608.68 426459.25 MWD 5814.88 1.41 293.95 5768.31 5672.41 8.42 -18.09 6110610.40 426455.10 MWD 5999.28 1.42 297.89 5952.66 5856.76 10.40 -22.17 6110612.42 426451.04 MWD 6187.37 1.46 292.14 6140.69 6044.79 12.40 -26.45 6110614.46 426446.77 MWD 6374.61 1.36 295.66 6327.87 6231.97 14.26 -30.67 6110616.36 426442.58 MWD 6561.62 1.40 295.99 6514.83 6418.93 16.22 -34.72 6110618.37 426438.54 MWD 6750.80 1.29 301.04 6703.95 6608.05 18.34 -38.64 6110620.53 426434.65 MWD 1 6873.26 1.18 311.87 6826.38 6730.48 19.90 -40.77 6110622.10 426432.54 MWD I 6998.65 1.08 306.80 6951.75 6855.85 21.47 -42.68 6110623.69 426430.64 MWD 7120.65 1.44 299.57 7073.72 6977.82 22.91 -44.92 6110625.16 426428.41 MWD I I 1 •Halliburton Company • P Y Survey Report E :: a � s � �� S a la • e _ °°' -- 3r > tlQl[)$$} .a- ik ,P E }' !. Date " ' �. Qt}7 ` Time � - ,... JJ' 3 4 . 6 F y ( :' � - -" / i t - rr e d ' zo e 5j { a " � C r, , # t :! It efer'en�ee E �„ 6 ; T`r u ort ` " � ." P arm . x ga s# � +` Z.1 ' ` � ' yy f . _1 ► Re a enc t 6 38 `3- ' � 7* .,. ', �t� & N q ` : on : -. 1 yen e a �€ 7A W 0 ESE 0 OGE 97 - 03 ,- 1 e1 a th �`' '- — a §n - .;� , . . ` a� ... 0 14l etil Od t �M � ! . ,. � D t�Cc Survey t'e,` a +a ' - ' - 3' - •r'-,a tic- ;,�, u , v .. ,.. ` ru s ,,.'rte � N J i � c �, 4 T [/D _ N/ Eiv p p . _ . r* ' ` a� °. 9 -48.40 6110627. 6 jr }t 3 " . ,z�, - �t ' -d *` '''- 'ft '-**'r e ,w - Ea/Lt re ? 7280.00 1.44 29.57 7233.02 7137.12 24.88 r 1 7 426424. PROJECTED to TD • 2 • FORMATION TOPS Aklaq 6 K.B.(ft): 37.10 G.L.(ft): 18.20 PROGNOSIS SAMPLE & MWD LWD FORMATION MD(m) TVD(m) SS(m) MD(m) TVD(m) SS(m) MD(m) TVD(m) SS(m) Base Permafrost 1022 1022 -985 1020 1020 -983 Nanushuk Gp. 1062 1062 -1025 912 912 -875 Nanushuk topset 1 2716 2716 -2679 2791 2774 -2737 Nanushuk topset 2 3414 3414 -3377 3388 3369 -3332 Torok 3580 3580 -3543 3470 3449 -3411 Torok sand 1 4675 4675 -4638 4734 4688 -4651 Torok sand 2 4783 4783 -4746 4852 4806 -4769 Torok sand 3 5042 5042 -5005 5090 _ 5044 -5007 Torok sand 4 5560 5560 -5523 5630 5583 -5546 Torok sand 5 5698 5698 -5661 5798 5751 -5714 Torok sand 6 5911 5911 -5874 6008 5961 -5924 Torok sand 7 6212 6212 -6175 6313 6265 -6228 Torok sand 8 6501 6501 -6464 6568 6521 -6484 HRZ 6529 6529 -6492 6605 6558 -6521 _ Kuparuk C 6710 6710 -6673 6800 6753 -6716 LCU 6717 6717 -6680 6880 6833 -6796 BCU 6717 6717 -6680 6880 6833 -6796 Upper Kingak 6718 6718 -6681 6880 6833 -6796 Kugrua siltstone 6939 6939 -6902 7066 7019 -6982 Kugrua sandstone 6974 6974 -6937 7120 7073 -7036 Kugrua ironstone 7024 7024 -6987 - - - Pliensbachian J2 7475 7475 -7438 - - - TD 7675 7675 -7638 7280 7233 -7196 • • Drilling t F E Pro 2007 e 4 x a. T R eserve mast. FEX L.P. 2006 -2007 Drilling Season Aklaq #6 Daily Drilling Reports 0o - -d r —I) FEX L.P. DDR Detail , ''i �I'' Page 1/2 Well Name: AKLAQ �, '4 1t,���k : , ( Q � � Mkt '< � n y i'EU:�fii�. �€ y �� '�' . 4 " d �. -r "F�-- ii� ,o-v ) .� = I`� 'G �. ''j Job Type: Drilling - Original Date: 3122!2007, Report: 1.0, DFS: -4.53 . Job Spud Date - - -- Rig Release Date - - Ground - Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/200 "2:45 I Y na 18.20 37.10 18.90 AF62034 22,574,244.00 22574,244.00 I Safety „i;:, u Target Depth (ttKB) Target Formation 1 l+e.= , Type 1 Date .., .«•a t' ..:.. Comment , r #, vixlti4 , l,'i '` ilil4e lll'll&llrIS Daly Cost Total Cum Cost To Date Daily Su ix t: : 5,269,048.00 5,269,048.00 Y r ' Dal Weather Lease / Conditions Wellbore Condit Over ( +) /Under ( -)AFE ( +l -) Var Days y Mud Cost Mud Cum To Date Light Wind Good Conductor Set 80' Depth Start (ftKB) Depth End (ftKB) Ope @ 06:00 _. __. ............ _.. ......... ____. ) ' RIG UP ON AKLAQ This — —. --- epth Progress ...... -- --- - - -.._.. Operations This Report Period g ess (ft) Drilling Hours (hrs) I Rig Down & Load Out / Derrick Down Q 10:00 Hrs / Sub Loaded & Moving © 16:00 Hrs 1 Operations Next Report Period ' i "°,14.,:'. 1 !Rig Up a c' , .. ,i ime Start Dur Ops Scheduled ' ° r � ' "�'x "` " �' Rigs: Doyon, Arctic Wolf Time (hrs) Cat Type Phase Major Op Operation Trou (ftK8) Comment Rig supervisor .. -1 ...... 1 J , Bill Lupton, Rig Manager Mui cks: Mud Pumps: 1 Gardner - Denver, PZ -9 Di ensity (lb/gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) No. p Pwr (hp) 'Rod Diameter (In) , Vis (s /qt) Filtrate (mU3Omin) Filter Cake (132 ") Pm (mLJmL) Potassium (mg/L) Percent 011 ( %) Mud Lost (Surf) (bb 1 liner Slur (In) St o (In) Vol /Stk OR (bbl /s... 1 9.02 PV Over (cp) Gel (10s) (lbfl100f... Sand ( %) MBT (Ib/bbl) Lime (Ib/bbI) 011 Water Ratio Mud Vol (Act) (bbl) i , Pum Checks YP Over (Ibf110... Gel (10m) (14/100... Solids ( %) LOS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) ,�, i' i �' 1 Strokes ,r r _ r 14 Slow Spd (spm) Eff ( %) Type Ge1(30m) (Ibf /100... T (tl) (°F) Chlorides (mg/L) HTHP Alt (mU30... Alkalin (mUmL) Whole Mud Add (bbl) ! NO I Silicate (%) Electric Stab (V) Comment No. Pwr (hp) Rod Diameter (in) 1 2 900.0 N TM ' ? va tsr % 1 '•, •• Liner Size (In) Stroke (in) Vol/Stk OR (bblis... il Description Make tModel 9 Dryer Derrick €_•� HG D Pump Checks Shaker Screens � IiF It lp '° € Wa a Deck No. " sc reen No. • Scr Sz X ( " "'' -- `' " Scr Sz Y (ln) Pres (psi) q' ii, K , h)6j< o it4 :4 �,hh 1 1 120.000 No k . . _. 2 1 120.000 Shak( 6 "x ..aU° 3 1 120.000 Make Model ' Shaker Checks , P Dens UF (4/gal) ' ' "& '",' P , '`. ,k, ,1 ' 8lt,,, 4 a 4 " t Shaker Screens 1 Description Make Model a Scr Sz Y in ill HG Dryer Derrick 1 Shaker Screens Shaker Checks ( ' r 'ra h Screen No. Scr Sz X In Scr Sz `r i ` " ° i � �_�, �_: _ - '. Hrs (hrs) r; ( 1 ( � i t . a. 1 1 120.000 2 1 120.000 Make ' Model ` a ) i I 3 1 120.000 • . " Shaker Checks Dens UF (Ib /gal) 1 lira (h k � Centrifuge /Cyclone Checks Density overflow (lb/gal) Overflow Rate (gpm) cf i; Description Make Model HG Dryer Derrick :Dens UF (lb/gal) Underflow Rate (gpm) rg Shaker Screens Hours (hrs) 1011 Under Fl (%) !bens FD (lb/gaq 6 ry` 1 1 120.000 j , a 4 �s . :; . 2 1 120.000 r:0 ldn - t CRne ,'. Dall Cost L',';,.1 . I 3 1 120.000 1 ll 6 Shaker Checks Pr Dens UF (Ib /gal) Hrs (hrs) .w.;i' �" ._ r' ,: G 4 l 1 l 1 , =, l _ . e 4. ■ Arc , II ! 77 d� i �ry� ;3.,:::'::.1;;:',,,,,i":' a �d ' j����� Bit Run Make Blt Inventory Blt Type Item Cost 1 � ` . _ ,. 1 T#et IADC Bit Dull TFA (Incl Noz) (In') BHA ROP (ft/hr) Nozzles (132 ") IADC Codes i ,, i lit : ::). Ill Formatlons n P Base Perma 1,019.0 Nanushuk Group 1,020.0 1 r e ' ( at i bra F EX L P Dt e " Well Name: AKLAQ . 4"i4, ; fi r= �: a �n 31221200 R „ , Job Type: Drill - Original Da e: 7, r eport': 1.0, DFS: '4.53 --- Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (11) on uctor Pipe.,,98.8ftKB 18.20 37.10 18.90 Cs g Run Date OD (In) Grade Wt (Ibs /ft) , 3/19/2007 16 H-40 65.00 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) 'TFO Reference Rot HL (10001... Max. Hook Load WOO (10001bf) Interval ROP (f /hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over -Pull (lbf) Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hr.) Off Bottom Torque Torque Units SO HL (10001bf) Hydraulic Calculations Drill Strin • Corn • onents �� �i�i Top Btm Bend i E Item I �' 1 Density'.' Drift Conn Sz Conn Sz Btm Angie .its - Description Len (ft) OD (in) ' (Ibs /ft) Grade ID (in) (In) (in) . Top Thrd (in) Thrd Cum Len (ft) () th'"'"e* pw . (� iq, 'tt , E_ � �ww � � i t ,�I ;. � ¢ 3 Wellbore Name VS Dir ( *) Kick Off Depth (ftKB) s _ Original Hole 0.00 I ' `?i I II �I A & u .. ,,. , FEX L.P. - DDR Detail P 1/2 Well Name: AKLAQ #6 Job Type: Drilling -_Ori Original Date: 3/23/2007, Report: 2.0 Yp 9 9 2.0, DFS: -3.53 P . Job Spud Date Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.0 Safety Target Depth (ftKB) Target Formation Type Date Comment Daily Cost Total Cum Cost To Data Daily Summary 194,061.00 5,463,109.00 Weather l Lease ! Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( + / -) Var Days Daily Mud Cost Mud Cum To Date Light wind ',Good Conductor Set 80' - - Operations @ 08:00 -.. -......_.._.... — _ --____ -- - - - -- -- - -- - - -' Depth Start (ftKB) Depth End (ftKB) Rig up on Aklaq #6 Operations This Report Period Depth Progress (ft) Drilling Hours (hrs) ! Raise Derrick, Fire Boilers, Rig up top drive. Operations Next Report Period Nipple up, P/U DP &BHA Daily Foreman Contact ( F Job Contact Cell Phone Start Dur Ops ..Scheduled Depth End Time..... (hrs) Cat Type Phase Major. Op Operation Trouble (ftKB) Comment -_ - -= Rig Su , i pervisor Doyon, Arctic Wolf 00:00 12.00 Drl Planned Rig Move/Up Rig Rig Move No Trbl 60 0' g g p g g Skid rig on Pony's, ' P Skid Bill Lupton, Rig Manager ii O Move /... Mud Pumps: 1, Gardner- Denver, PZ -9 derrick,drawroks No. Pwr (hp) Rod Diameter (m) onto sub base, 1 900.0 ;scope and raise ILIner Size ( In) 'Stroke (in) - VoustkOR(bbi/s... derrick 9.02 12:00 12.00, Drlg Planned Rig Move /Up Rig Rig Move No Trbl 60.0 Rig up complexes, pump Checks ii Op Move/ , Strokes Mud Checks: 1 �� ' ` * l; Pres (psi) Slow Spd (spm) Eff ( %) 0 Density (Ibigal) pH CEC for Cuttings IPf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (YYI) NO I [ M ud Pumps: 21 .t t „ ,® ° , r, PZ -9 via (slat) Filtrate (mL/30min) Filter Cake (/32") Pm (mUmL) Potassium (mglL) Percent Oil(%) Mud Lost (Surf) (bbl) No. Pwr (hp) Rod Diameter (in) 2 I 900.0 PV Over (cp) Gel (10s) (Ibf /1001.. Sand ( %) MBT (1b/bbl) Lime (1b/bbl) 011 Water Ratio Mud Vol (Act) (bbl) j Liner Size (in) Stroke (In) Vol /Stk OR (bbl/s... 9.02 YP Over (Ibf/10... Gel (10m) (Ibf /100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Pump Checks Strokes Type Gel (30m) (Ibf /100... T (fl) ('F) Chlorides (mg/L) HTHP Flit (mU30... Alkalin (mUmL) Whole Mud Add (bbl) I Ares (psi) Slow Spd (spm) Eff ( %) No Silicate (%) Electric Stab (V) Comment ii ( iii ��i ��i�i,�ji�ij�bescrlptlon . > j Make Model Dat " , N.i, , 't . iffil :: : lam Description Make Model Shaker S - ........ HG Dryer Derrick S Screens Screen Shaker Screens Deck No, No. Scr Sz X (in) Scr Sz Y (in) , Deck No. Screen No. Scr Sz X (in) Scr Sc Y (in) 1 1 120.000 ' Shaker Checks 2 1 120.000 Dens OF (Ib /gal) Dens UF (lb /gal) Hrs (hrs) 3 1 120.000 Shaker Checks I, ' "it t i 31111 e Dens OF (113/gel 'i Hrs (hrs) Make Model 1 Description Make lb Model � Centrifu e/C lone Checks HG Dryer Derrick :D ensity Ove low (lb/gal) Overflow Rate (gpm) „ Shaker Screens ' Deck No a ' _ ` ` , Scr Sz X ( in 1 � ,' - , Scr Sz Y (in) Dens UF (Ib/gal) Underfloor Rate (gpm) ate a 1 1 120.000 i 2 1 120.000 'Hours (hrs) Oil Under Fl (%) Dens FD (lb/gal) .. n 3 1 120.000 0 rirrrItin Tr Shaker Checks Dens UF (lb/gal) Hrs (hrs) De§cr tion ConS... Dail Cast it Vendor 1 Descrlptlon Make Model if4 t =" ' Dryer Derrick I 144 li - ` .f, 631, ' `Vp i. �' l t„ .. Date Type wa . Shaker Screens ph v , -, " ` r < , ., Screen No, Scr Sz X (in) Scr Sz Y (in) _ „. � s ,, i 1 1 120.000 . int ® I g° ;i E 14G s"; estrry)re'h;i .d, g 2 1 120.000 3 1 120.000 Formations Shaker Checks Sample Top ; .... _ _ D4ns OF (Iblgai) ._aW..,_ . - Hrs � rs (hrs) _ Formation Name MD (ftKB) I BasePermafrost 1,019.0 ,Nanushuk Group 1,020.0 i i. I ' 1 d ' _' :; i tinted: 4/2/2007 , FEX L.P. - DDR De �, , ,, , ' k�i G ` r e ll Na me AKLAQ #6 - 4�4 gp 3 a � ` 004 d p 777'7176''''''D' ' t 1 :U .t M y , , ti`G hl�Ii E. • •�d > ® ' 'I�! 'ng - Original 'i �'' ' �c ' a` - I i .a % a" x 1? �y ® g ' ! 's' 2 � 01 ®m Ji t f ' ' � �.� �• 7 . ,w 4 -- — — Ground Elevat (ft) Orig KB Elev (ft) KB G roun d Di stance (ft) On ) i : n _ .,(a. , .. 1820 37.10 18.90 Csg Run Date OD (in) Grade Wt (lbs/ft) Bi _I ` °°" ^ Nl i 3/19/2007 16 H-40 65. t Run Make Bit invento Bit Type Item C ry ost Cem Cm D � Co , IADC Bit Dull TFA (Inc/ Noz) (In') BHA ROP (ft/hr) Nozzles (132 ") IADC Codes 3 , lI �"k 1 i ,l.ii � e . t HL ( xs =i I Lo lll ll BHA No. Cum Depth (ft) SPP (psl) Flow Rate (gpm) TFO • Reference Rot HL (10001... Max. Hook Load oho WOB (1000Ibf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (70001bf) Max. Over -Pull (Ibf) Motor RPM ) (hrs) (rpm) (rpm) Cum Drill Time (hra) Off Bottom Torque Torque Units HL (t0001bf) Hydraulic Calculations AV DP ( ftlmin) AV DC (ft/m -- Err 1 Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle:‘,''',11,.,.1,1',.4i-,,I,,I, Jts Description Len (ft) OD (in) (Ibs / ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (1 i I � w ; ' � � m'. � ,1 iarld • n i i j4 ''' i O rD H , ih � aa . Wellbore Name Qrlglna) HOIe VS Dir ( ° ) �� K lck Off Dep (ftKB) ' P I x illi i II h Bit RPM p 1 it i I iiii fe i ll f■ Afi rit 4. ' f , ■ ■ Otr ! m. 9 ni �x � �0it Printe /2/2004 ° .a., . a . a �Lalt „�o-s ..mM, ,f' . a � , 1 14" ' i i , C � , I � ...i . _ <Cm � 1Io FEX L.P. - DDR Detail Page 1/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/24/2007, Report: 3.0, DFS: -2.53 Job Spud 3/27/2007 12:45 Rig Release Date Ground .118 2o (ft) orig 37 (ft) ; KB- Groun18 Distance ( A AF62034 22 244 00 22,574 244 00 Safefy x "' "1111PI t "'hNFr " ' t " " "` ", i 'r ,p i 117 t 'lrY Target Depth (ftKB) Target Formation Type Date 1 'A {I,wsx ,/•, Comment Daily Cost Total Cum Cost To Date Daily,Sumrn• 194,061.00 5,657,170.00 o di i D aily Mud Cost Mud Cum To Date Weather Lease / Road Conditions Wellbore Condition Over + / Under -) AFE (+/ -) Var Days Light Wind -30 C Good Conductor Set 80' I L. I Operation, 08:00 0 .. Depth Start (ftKB) Depth End (f1KB) ` R/U top drive _ -- Operations This Report Period —_. -. D e pth Progress (ft) Drilling Hours (hrs) ` Raise DerrickRig up top drive, Operations Next Report Period Nipple up diverter Build mud I r e _' ''''OP S cheduled Dep End ' Rigs: Doyon, Arcti _ ,; . i 'i. ,., A* i fl me (hr s) Cat Type Phase Major Op Operation Trouble (ftKB) Comment Rig Supervisor 00:00 12.00 Drlg Planned Rig Move /Up Rig Rig Move No Trbl 60.0 Rig up top drive Bill Lupton, Rig Manager Op Move /:.. loop for top drive Mud Pumps: ° m ° ° 12:00 12.00 Drl Op Move /... Planned Rig Move/Up Rig Rig Move No Trbl 60.0 Work on service p t j" 9 g p 9 9 No. Pwr (hp) Rod Diameter (in) y p p p 1 900.0 L,II ". Mud - i '' ,ir4 ' t+ Liner Size (In) Stroke (in) Vol /Stk OR (bbl /s... ltiit � . a te . , � Density ( pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) 9.02 Pum Checks Viss 01gt) Filtrate (mU30min) Filter Cake (132 ") Pm (mUmL) Potassium (mg/L) Percent Oil ( %) Mud Lost (Surf) (bbl) mg/L) , 4 m - i ran s . . /'° r e (gpm ) 1 E �4 PV Over (cp) Gel (10s) (lbf/100f... Sand ( %) MBT (Ib/bbi) Lime (1b/bbl) 011 Water Ratio Mud Vol (Act) (obi) No r d j YP Over (Ibf/10.. Gel (10m) (Ibf/100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) No. Gel (30m) (Ibf/100... T (fl) (°F) Chlorides Pwr (hp) R 900.0 Diameter (in) y t l Type HTHP Flit mL130... Alkalin mL/mL) Whole Mud Add (bbl) 2 ( ( ( diner Size (In) Stroke (in) Vol/Stk OR (bbl/s. ..._.._._.._ 6 9.02 0.070 Silicate ( %) Electric Stab (V) Comment i Pump Checks 410 , . -aka t�, . �a'_'. I , . • a 1• • t,1. ti,:,: 7 Strokes Pros (psi) Stow S pd Elf 1%1 Description Make Model No HG Dryer Derrick Shaker Screens Shakers. <Description?> No. Screen No. Scr Sz X (In) ''� : ;, _� �'a Make Model i � 1 1 120.000 — 2 1 120.000 Shaker Screens Screen 3 1 120.000 t`"""�'"'l' Deck No. No. Scr Sz X (in) Scr Sz Y (In) Shaker Checks � ..xi�,(t;� n Dens OF Ibl al - a°.'.` h !t a:.� +v .. $.t.:r - ___ - ...... -___ • H t e) �' � �, �s4 • I� . u�,�'�r�s. , .� ' ~:.� . ,. . . � Sha Checks Dens OF (Ibigal) Dens UF (lb /gal) Hrs (hrs) Description Make -- — Model HG Dryer Der — Shaker Screens Make Model _ F` �����. " + r a � - ,tsa,�'t" ' �"�'� '' ScrSzX(in) 3crSzY(in) i � � 1 1 120.000 Centrifuge clone Ch 4. 2 3 1 1 120.000 I , Density O (Ib/gal) Overflow Rate (gpm) 120.000 ' Shaker Checks Dens UF (113/gal) Underflow Rate (gpm) ' Dens OF (lb /gal) 35" 1"f; x'a t ititt'.'' Hrs (hrs) Hours (hrs) 1011 Under Fl (%) Dens FD (lb/gal) ' Description Make Model '' HG Dryer Derrick , 7 1' ,.< ; . Shaker Screens Sz X (in) Scr Sz Y Screens ' Descri. n Cons.. Dally Cost . , Vendor D eck No, Scree$ l +le .. " , :' (in) `° ' V 1 1 120.000 r . h F 1 i 2 1 120.000 *,IiSi = s� I. 3 1 120.000 Date Type i 4 ! Shaker Checks ' „iii r , F- * � a � r. -�� .s it Hrs (hrs) . ..... Dens OF ,gal) ._. ... -.._ ..... -.. Test Date * -Test Type " Drill Strings: t Formations 1 Bit Run 'Make Bit Inventory Bit Type Hem Cost Sample Top .{. Formation Name MD,(ftKB) IADC Bit Dull TM (Ind Noz) (In') BHA ROP (ft/hr) Nozzles (/32") IADC Codes Base Permafrost 1,019.0 —_ -- INanushuk Group 1,020.0 Report Printed: 4/2/2007 t , tit �5 p 1V"*Ei�i'�s. m,ra �:. 4 ,a ti ,.d x, .t ,N, iw'��i (, 24 re,�. � .iA ai: I; . . � a !f.. .ate. = , : r� a� ` , d , rv.rr g x a�H,6r ut ..,, ..,.ra 3� ,�,'�I ------.---- F -7- E) --- C L.P. - DDR Detail Page 2/2 Well Name: AKLAQ #6'` "na"' Job Type: Drilling - Orig Date: 3/2412007, Report: 3.0, DFS: -2.53 0 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Conductor Pipe, 98.8ftKB 18.20 37.10 18.90 csg Run Date OD (in) Grade Wt (Ibs /ft) AI I �a pm) 3/19/2007 nt 16 H -40 65.00 BHA No. 'Cum Depth (fl) SPP (psi) Flow Rate (g TPO Reference Rot HL (10001... Max. Hook Load (Ibf) j Ceme Cmnt Des Commen WOB (10001bf) Interval ROP (ftlhr) Total ROP (TUhr) Drilling Time (hrs) Drilling Torque PU HL(t0001bf) Max. Over -Pull (lbf) 1 , Bit RPM (rpm) Motor RPM (rpm) , Cum Drill Time (hrs) Off Bottom Torque Torque Unite SO HI. (1000Ibf) ' I Hydraulic Calculations AV DP (ft111t , , i ce , ", 'L $ 2� 1H ,,' ai ° .p .a k..�,',aaa.: y x Drill String Corm orients iw ' .: i Ili, 4r , Top Btm Bend 1 It . m Density Drift Conn Sz Conn Sz g ;m Angle Att. Jts Descripti L iq) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) c) We i .. r :. Wet lbore Name VS Mr (°) Kick Off Depth (ftK8) Original Hole 0.00 I j 1 al �� I fi I I ■ 1 11 I I ; ( , I , � l I ■ ■ ■ a :; 1 Pi x 1 i' 0 ij .... , .... a�i . ^°:��re� - R �� .. �. .r � ,. � %.— .. �- . < f. ��, � .. � ■ ,a e � a "» „ ,... �t, x �. F u �. �wuoc � --410 FEX L.P. - DDR Detail 1 11 1 Page 1/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/25/2007, Report: 4.0, DFS: -1.53 �I • Job Spud Date Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB -Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12 18.20 :: ',10 18.9 AF62034 22,574,244.00 22,574,244.00 Safety 1, „ - Target Depth (ftKB) Target Formation Type Date Comment p 'j 7 aF ,m Safety Highlight 3 /25/2007 Pad is very Slippery, wear slip protection whenever possible. Daily Cost Total Cum Cost To Date '' Daily Summary 230,062.95 5,887,232.95 Weather Lease / Road Conditions Wellbore Condition Over ( +) I Under ( -) AFE (+/ -) Var Days Dally Mud Cost Mud Cum To Date 15 mph wind Good Conductor Set 80' 1 20,378.95 20,378.95 i Operations @ 06 :00 - - - . - Depth Start (ftKB) Depth End (ftKB) Nipple up diverter ,,, ---- _ - ---'- 'Depth Progress (ft) Drilling Operations This Report Period ( 0 Hours hrs) ! Finished R/U top drive, Mount service loop for top drive, build mud Operations Next Report Period Daily Foreman Contact P/U Drillpipe prepare to spud Y -- -- - - -- - -- - -- - -- -- Job Contact Cell Phone Time Log Gregg Fischer, Dr (306) 577 -8455 Start Dur Ops Scheduled Depth End Foreman Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment 00:00 24.00 Drlg Planned Rig Move /Up Rig Rig Move No Trbl 60.0 Work on service i s s ' ` aI Arctic Vii { ' - W 10p Move /... loop for top drive, Ri g Supervisor I' build mud Bill Lupton, Rig Manager 'P `c .. .•' ve lePi9 M' , 0.0ftKB, 3/25/2007 22 :00 N No. Pwr(hp) Rod Diameter (in) , i. Density (lb /gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) 'Mud Lost (Hole) (bbl) 1 900.0 I 9.40 9.0 Liner Size (in) Stroke (in) Vol/Stk OR (bbi/s... Vis (s /qt) Filtrate (mL/30min) Filter Cake (132 ") Pm (mUmL) Potassium (mg /L) Percent 011(%) Mud Lost (Surf) (bbi) 6 9.02 0.070 45 _ 8.6 PV Over (op) Gel (10s) (Ibf /100f... Sand ( %) MBT (lb/bbi) Lime (Ib/bbl) Oil Water Ratio Mud Vol (Act) (bbl) Pump Checks roi 10.0 2.000 _ a „ , _ ‘ i Slo Strokes YP Over (Ibf /10... Gel (10m) (Ibf/100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) ' N Eff (%) 28.000 6.000 2.9 Type Gel (30m) (Ibf/100... T (fl) (°F) Chlorides (mg/L) HTHP Flit (mU30... Alkalin (mUmL► Whole Mud Add 1 :. ° . , , t ,, ;,? i 1 9 : ° t ., .. r ► I " Potassium No. Pwr (hp) Rod Diam ( In) Salt Base 2 900.0 II Silicate (%) Electric Stab (V) Comment --- - , Liner Size (in) 'Stroke (in) Vol /Stk OR (bbl /s... 1 ' 0 1 6 I 9.02 0.070 Mud Checks: 0.OftKB, 3/26/200 410 ; ,v,-- , ,, „ Pump Checks Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) ' Stro 1 9.0 Pres (psi) Slow Spd (spm) Eff ( %) 1 Vis (s /qt) Filtrate (mL/30min) Filter Cake ( /32 ") Pm (mUmL) Potassium (mg/L) Percent Oil (%) Mud Lost (Surf) (bbl) I NO 47 9.8 _ ? .". » '' PV Over (cp) Gel (10s) (Ibfl100f :.. Sand ( %) MBT (Iblbbl) Lime (lb/bbl) Oil Water Ratio Mud Vol (Act) (bbl) Make Model 8.0 2.000 ' _ YP Over (Ibf /10... Gel (tom) (Ibf /100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Shaker Screens 26.000 4.000 5.4 so�i� ' 11,x: , No S (1n , • Type Gel (30m) (Ibf /100... T (fl) ( °F) Chlorides (mg/L) HTHP Flit (mU30... Alkalin (mUmL) Whole Mud Add (bbl) y k k,N , , , „ . ' �, e S ode i(It Sz Y cr l Potassium Salt Base Shaker Checks Silicate (%) Electric Slab (V) Comment is +. i := . . ° M• .r gal) )l.. 14 Mud Checks: o.oftKB,'S ;� . m iff:00 q1'I! �, 1 ., r 4 ` 3 ; x, , : ' ,'. 1 1 � : ) g' ti x' t Density (lb /gall pH CEC for Cuttings Pf (m Calcium (mg/L) % Water ( %) Mud Lost (Hole) (bbi) M ake Model 9.80 9.7 V is (s /qt) Filtrate (mU30min) Filter Cake (/32 ") Pm (mUmL) Potassium (mg/L) Percent Oil ( %) Mud Lost (Surf) (bbl) Centrifuge /Cyclone Chec 4 5 3.5 , Density Overflow (Ib/gal) Overflow Rate (gpm) gi PV Over (cp) Gel (105) (Ibf/100f... Sand (%) MBT (Ib/bbl) Lima (Ib/bbl) 011 Water Ratio Mud Vol (Act) (bbl) 9.0 7.000 Dens OF (lb/gal) Underflow Rate (gpm) i l YP Over (Ibf /10... Gel (10m) (Ibf /100... Solids ( %) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbi) 1 ilifl 19.000 10.000 5.2 'Hours (hrs) 011 Under Fl ( %) ;Dens FD ( Type Gel (30m) (lbf /100... T (fl) (°F) Chlorides (mg/L) HTHP Flit (mU30... Alkalin (mUmL) Whole Mud Add (bbl) , Potassium,; , .., „I` Salt Base ,' Description Cons... Daily Cost Vendor Silicate 09 Electric Stab (V) Comment Potassium 258.0 4,200.24 1 Chloride D a!'a: ., 6 : 1 , tt „�z 4 v >, ,' ` t : r ' t �. A $ I , ° ' . Baroid . . 495.0 ,5,063.$5 '' Description Make 1Model CLAYSEAL 1 3.01 2,379.39 HG Dryer t� . ........ � Barazan D+ 22.0 3,491.62 ° k Shaker Screens ; Deck No. Screen No. Scr Sz x (In) Scr Sz Y (In) DEXTRID 38.01 2,368.92 1, LT 1 1 120.000 O. 2 1 120.000 DRIL-N-S... 2.0 1,549.56 3 1 120.000 Baracor 700 3.0 434.13 Shaker Checks 7 Potassium 3.0 179.07 Dens OF (lb /gal) Hrs (hrs) y Hydroxide 1 , 1 � ,i 1 Report Printed 4/2/2,0 ■ ,. I a,1 . n (iv . t �t ,' d•= w.., , .. , . , ..I : „ .,.e, ■ ,. '0,q,, , . , '.., .. I „ .y ,I, a1 1 c Deta 1.141j!iiiiilleiect:11 . 1 PP Page2/2 FEX L.P. - DDR Detail Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3125/2007, Report: 4.0, DFS: -1.53 ; Ground Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (B) Mud Additive Amounts ' 18.20 ; 37.10 18.90 Description Cons... Daily Cost Vendor Drying s.hogr.Pat? ,,j11:;: -.. '..,--: , „„„ ,_, Baradefoam 3.0 329.55 Description Make Model I MP HG Dryer Derrick _1Barascav D 6.0 382.62 ■:■1 Shaker Screens Mud 4.0 Deck No. Screen No. Sor Sz X (in) Scr Sz Y (in) Engineer 1 1 120.000 2 1 120.000 Last Casing Check 3 1 120.000 Date Type Shaker Checks Dens OF (lb/gal) Hrs (hrs) Last BOP Check Test Date Test Type Description Make Model HG Dryer Derrick Formations Sample Top -Iliiki pfral,, T s ien Screen No. ... Scr Sz X (in) g67g y (in) Formation Name MD (ftKB) 1 1 120.000 Base Permafrost I 1,019.0 2 1 120.000 Nanushuk Group 1,020.0 1 1q,h, 3 1 120.000 1 kConductord,p0e 1 :17, 111, i 1 ,: , , , y 1 . , :! , ; i iii:,111,!4,7,51iiii1,011 10 1.0470 Shaker Checks Csg Run Date OD (in) Grade Wt (lbsift) 1 3/19/2007 16 H-40 65.00 Dens OF (lb/gal) Hrs (hrs) r i n , i. 4 b1 1 .111. 1 A0,01e.st item Cost Bit Run Make Bit inventory Bit Type 11,1 IADC Bit Dull TFA (incl Noz) (in') 1 BHA ROP (ft/hr) Nozzles (/32”) IADC Codes Ili ilZ 151:11 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (113f) 1 4 1 11 WOB (1000Ibf) interval ROP (ft/hr) Total ROP (ftihr) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) Max. Over-Pull (tbf) Pli Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units ]S0 HL (10001bn Fitt ii _l_ty_clraullc Calculations 5 7. , :,31 11, :.4 11 1 , %: 0 4 1 ' It1 AV DP (ftImIrt) AV DC (ft/min) ,, .„, . ,,,, ,! _ ,,, . „ Err Drill String Components Mtr 1 Top gtm Bend I Item Density Drift Conn Sz Angle Conn Sz Btm ,its Description Len (ft) OD (in) (lbs/ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (°) , 01(IJt19M)4S'iTiq'ePO.!10!I'!'4',1VPlgliPiL)"F*,Yii)i)v).,)) Kick 'ddil— Wellbore Name ' ) ■1 Original Hole 0.00 4 [„,.. f 4 [ M5 !Pi 1 01111.... ,.; tt t Ft t it if, l' , 1 444 I rh [ 4 1111: :[1:14L „, ' ' .14 ,5;illigitlf '':1144 11F4'f:iii: 1: 4 [ 1 .,P,,, °[ „[Iffig i l l !iirP4 : 4/212007 II FEX L.P. - DDR ____________. ,,, ,,, Detail t �,1II , Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/26/2007, Report: 5.0, DFS: -0.53 ill Job Spud Date - Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. - -- Total AFE Amount Total AFE +Sup 3)27/2007 12:45 18.20 37.10 18 AF62034 22,574,244.00 22,574,24 Safety Target Depth (ftKB) Target Formation TYpe Date Comment ittt s "' rw,�,i .,: 4t , I'll All Safety Highlight13 /26/2007 Discuss frost bite protection Daily Cost Total Cum Cost To Date Daily;,$urpmay 218,486.30 6,105,719.25 Weather Lease 1 Road Conditions Welibore Condition Over (4)! Under (•) AFE ( +1•) Var Days Daily Mud Cost Mud Cum To Date i.'f Srong wind,Phase Plowing snow drifts Conductor Set 80 14,512.30 34,891 3 visability ePii, Start (ttKB) Depth End (ttKB Operations x.00:00 Depth Progress (ft) Drilling Hours (hrs) P/U mud motor/bit Operations This Report Period ig Change seals on starter head. P/U HWDP,Nipple up stack I s ' : Operations Next Report Period ,r n; ..1 i 0 a + , Spud well, P/U BHAIDrill ahead Job contact Cell Phone Fit (liBt�aj)�"'H' €. Gregg he , Drilling (306) 577 -8455 r t - ' I � e ll 1, a � � ' Foreman Fis c D Ops Sc heduled Type De 'E .y { yr ' l" 4Ml r = rs Cat pe Ma or Op Tro uble (ft Comment Rlt ) � �.0 �_ 06..-60 � ) y :...___..__ ) �Op ) Rlg Supervisor 8.00 Drig Planned Rig Move /Up Rig R Move NoT Trbl 60.0 I Attempt to test Bill Lupton n Op Move /... starter head, no test, change seals - g.,l i - . PZ -9 re test No. Pwr Rig Maager (hp) Rod D (in) 1 900.0 08:00 5.00 tanned Rig Move /Up R Rig Up No Trbl 60.0 P/U 18 jts heavywt' Llner Stroke(In) voUStkOR(bbua gd drill i e 6 9.02 0.070 Op Move /. .. p p i g g Op Rig p g g p t 13:00 8.00 Dri Planned Ri Move/Up Move /... Ri U No Trbl 60.01 head Re -sea w/ new starter seals, Pump Checks Strokes rlu spool and Hydril, l Pres (psi) Slow Sp (spm) Eff ( %) t est head to 1000 No ps i. Oumps:, 2, Gardngr DenverD , iameter PZ - (in 9 ) 21:00 3.00 DrIg Planned Rig Move/Up Rig Rig Up No Trbl 60.0 R/U diverter, R/U No. Pwr (hp) R od Move /t flow line and mud 2 1 _ 900.0 � ,'' Eta t�t,�t °, } to �l °,' °) can 6 1 9.02 0.070 Liner Size (In) Stroke (in) - -- Vol/Stk OR (bbi/s... 1 ° '� - ±=ks: Pump Ch Strokes �qq Density (Iblgal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) p Pres (psi) Slow Spd (spm) Eff (%) , Via (8/qt) Filtrate (mL/30min) Filter Cake (/32 ") Pm (mUmL) Potassium (m(1ll) Percent Oil ( %) Mud Lost (Surf) (bbl) NO (= PV Over (cp) Gel (10s) (Ibf /100f... Sand (%) MST (lb/bbl) Lime (lb/bbl) Oil Water Ratio Mud Vol (Act) (bbl) iii Shakers <Desc a i ` ° € ^ Make M od e l ' YP Over (lbf/10... Cie/ (10m) (IbfI100.,. Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Shak @r Screens � it Type Gel (30m) (Ibfl100... T (fl) (°F) Chlorides (mg /L) HTHP Filt (mLl30... Alkalin (mUmL) Whole Mud Add (bbl) Screa a " ' "" ° ' { . k Deck No. No Sz Y (tn) r¶ Sillcate ( %) Electric Stab (V) Comment 1 (iI r Shaker Checks (l� il r tl ! ` P .,.r,.atp vi r•r'e . . , a:i.A,r & S,t. " °a "l�;t mn+� a. _.,- TF', `. •' a Dens OF (ibigal) Ht ' (rs) _ 9 ) Description Make Model °��" v HG Dryer Derrick < °$ Make Model Shaker Sre "a.. a ° cens Green No. 'ga,P,' z la ,. j . €: 11 centrifuge/cyclone Checks Rate 1 120 000 Density Overflow (Ib/gal) Overflow Rat (gpm) � �� _ 3 1 120.000 Dens OF (113/001) Underflow Rate (gpm Ar Shaker Checks Dens OF (I6 /gal) Hrs (hes) " , a Hours (hrs Oil Under Fl ( %) Dens FD (Ib/gal) A Description HG Dryer Derrick Model Description Co ?,.,gy Co s vendor Shaker Screens MUD LAB 5.0 225.00 Deck No Screen No. : Scr Sc X (in) Scr Sc Y (in) Mud 2.0 1 1 120.000 Engineer 2 1 120.000 Baroid 705.0 7,212.15 3 1 120.00 CBLAYiSEAL 1.0 793.13 Shaker Checks Barazan D+ 25.01 3,967.75 Dens OF (Iblgal) Hrs (hrs) - l . 1Chloride - -- Potassium 72.0 1,172.16 1 ,i,I, ` Description Make Model *ascription Derrick Derrick PAC - R 3.01 463.95 Shaker Screens Baradefoam 4.0 439.40 ii Deck No. Screen No. Scr Sz X (In) Scr Sc Y (in) H P i H�l � I�h 11 1 120.000 y. l it �, k !11 Report Prmtect; 14 a t der ui '' , "1 % : a.� " ','$ I11:ei vl,Ai' h iaiv, .s ,_. =,'I'I,m1411,,,, , ,. ,,,I i., i�r,'16'° ". 440,I °I61 a . - - - - - -- -- - -- FEX L.P. - DDR Detail Page 212 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/26/2007, Report: 5.0, DFS: -0.53 ' Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Mud Additive Amounts 18.20 37.10 i 18.90 Description Cons... Daily Cost Vendor Shaker Screens Potassium 4.0, 238.76 Deck No. Screen No. ' Scr Sz X (In) Scr Sz Y (in) Hydroxide '.. 1 120.000 2 3[ 1l 120.000 Last Casing Check 'll Up' Shaker Checks Date Type Dens OF (lb /gal) Hrs (hrs) ..... Last BOP Che . ) �is r .._. —. -.. .___ ....__... ......_. - Test Date h Test Type i, 1 r big ■10 n *i. ' �I�i�fall'uliiw',fir ' '' Bit Type Item Cost ,, Bit Run Make Bit Inventory .. I, I Formations � IADC Bit Dull TFA (Intl Nos) (In') !BHA ROP (1t/hr) Nozzles (132 ") IADC Codes Top Formation Name MD (ftKB) Base Permafrost 1,019.0 f'a lloi ii � I ian Nanushuk Group ,0 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) p Conductor Pipe,,98.8ftki 1i1,j ;Nl' iii WOB (100011H) Interval ROP Ht/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bt) Max. Over -Pull (Ibt) Csg Run 3/19/2007 Date OD (in) Grade H -40 i Wt (I /ft) 1 65.0 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units `SO HL (1000lbf) Cement n � , i N i • ( Cmnt Des C i —..- (; Hydraulic Calculations AV DP (ft/min) AV DC (ft/min) Err Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle Jts ... Description Len (ft) OD (in) (Ibslft) Grade ID (in) (In) (in) :Top Thrd (In) Thrd Cum Len (ft) I') Wells �' h 1 `( Pyl '' 6 _ ',',' t it l Wellbore Name VS Dir (°) Kick Off Depth (ftKB) Original Hole 0.00 1 IP A li 'i 0, I LI r i iA , idi AA s i (I R ti: 41212007 ,. r v . ,.': l- ���I�ilit�iiik�k FbgII��II�iIIiIIItp. gnu... ....I II As�I ,r x, b {?u§ �n. }Hfi�I IIIi a -�i`� � ,. _....4�dgw°.0 ea..,,fs..i BdI) ..� ,.. !gad FEX L.P. - DDR Detail • Page 1111 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3127/2007, Report: 6.0, DFS: 0.47 . Job Spud Date Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (ft) AFE No. Total AFE Amount 'Total AFE+Sup 3/27/2007 12:45 18.20 I 37.10 1 18.90 AF62034 22,574 244.00 22,574,244.00 rt i lii . .. , ,I;:„;. , 4 4 :00010,01400000,000110000,10n0000710 Target Depth (ftKB) Target Formation ■ A ,, Type Date Comment Safety Highlight 3/27/2007 Phase 3 conditions Daily Cost Total Cum Cost To Date i 240,056.22 6,345,775.47 If II Weather Lease / Road Conditions Wellbore Condition Over (4)1 Under (-) AFE (0-) Var Days Daily Mud 4,7 Cost Mud Cum To D , Light winds Opening roads from Conductor Set 80' .22 39,682.47 1 1' phase 3 ' Depth Start (ftKB) Depth End (ftKB) 1 1___ 98'0 400.0 1 Operations @ 06:00 Drilling ahead ;Depth Progress (ft) Drilling Hours (hrs) 302.00 1.00 Operations This Report Period ((P/U Drillpipe, Repair flow line Nipple, R/U mud pumps, Drill 300',POOH P/U MWD BHA . • ' ''' ' , .; :J ,1 11. ,, 1;• ' - iii :1111 1 1 1; , ' ,I l'i: 11 :4000,1000;;; Operations Next Report Period Job Contact „ III Drill ahead in Surface hole Gregg Fischer, Drilling (306) 577-8455 0 . I m ihj'I, ';:j!lq,'"IIIIII',I , , . Foreman Start ' Dur Ops Scheduled ' ep End Rigs: Doyon, Arctic 11 4 Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment Rig Supervisor 00:00 5.00 DrIg I Planned Rig Move/Up , Rig Rig Up No Trbl 60.0 P/U 60 stds of Bill Lupton, Rig Manager Op Move/... drillpipe "Mud Pumps:4 r(rir'n 05:00 1.00 DrIg Planned Rig Move/Up BOP / Rig Up No Trbl 60.0 Gramaldi with No. Pwr (hp Rod Diameter (in) . .i . ; '; Op WH / AOGCC waived 1 900.0 II, Drillout witnessing of Liner size (in) Stroke (in) VoUStk OR (bblis... 11 I , .. diverter test, 6 9.02 0.070 function test 1 .4 diverter Pump Checks Strokes : 66:06 1.00 Drlg :Planned Rig Move/Up , Rig Safety Meeting No Trbl , 60.0 Clean floor, prejob Pres (psi) Slow Spd (spm) ES (%) Op Move/... , , safety meeting prior No ; , 1 , 1 I to p/u BHA Mud Pumps: 2, Gardner-Denver, PZ-9 1 ' 1 No. IPwr (hp) Rod Diameter (in) 07:00 3.00 'DrIg Planned Rig Move/Up BOP / Rig Repair / Rig 60.0 Repair seal on bell 2 900.0 Op WH / Service Repair nipple Liner Size (in) Stroke lin) Vol/Stk OR (bblis... Drillout 6 9.02 ' 0.070 I' 100 10:00 1.00 DrIg Planned Rig Move/Up Drilling Handle Tools No Trbl 60.0 P/U mud motor and : Op I Pump Checks . . BHA for 300' drillout ■ Strokes ,....b I 11:00 2.00 DrIg Trbl 3rd Rig Move/Up Rig Rig Repair / Rig 60.0 Wire and bring mud Pres (psi) Slow Spd (spm) ES (%) 4 Party Move/... Service Repair pumps online to I No pump. Shakers: <Description?› 1 '1,N01;00.000.1100 13:00 0.50 DrIg Planned Rig Move/Up ; Rig Rig Up No Trbl 60.0 Prime mud lines, Make Model ...100 Op 1Move/... 'pressure up to 1 1 ; 3500psi Shaker Screens Screen A.. 13:30 4.50 DrIg Planned DrIg Surf Drilling Drill - Motor Dir No Trbl 342.0 Spud @ 12:45 Drill Deck No, No. Scr Sz X (in) Scr SE Y (in) Op ahead F/80' to/342' j i I 18:00 1.00' Drlg Planned DrIg Surf Drilling Trip Out No Trbl 342.0 Blow down kelly, Shaker Checks Op POOH 5 stands Dens OF (11a/gal) Dens UF (Ib/gal) Hrs (hrs) 19:00 0.50 DrIg Planned Drlg Surf Drilling Safety Meeting No Trbl 342.0 PJSM ,,,• Op ' ' ' .1q1I Wikr " ' ■eld:P0A.10 , "1 ,,,';:A.:"... ,, il, ; 1q . ,[4: 19:30 3.50 Drlg Planned DrIg Surf Drilling Handle Tools No Trbl 342.0 P/U MWD BHA, Op Load source, load Make Model ■ :.4 mwd tools Centrifuge/Cyclone Checks Density Overflow (lb/gal) Overflow Rate (gpm) '`..'A 23:00 0.50 Drlg Planned Drlg Surf Drilling Trip In No Trbl 342.0 Install Corrosion Op ring in string, trip in Dens UF (lb/gal) PS: Underflow Rate (gpm) *A hole 00 00 23:30 0.50 DrIg Planned DrIg Surf Drilling I Drill - Motor Dir No Trbl , 400.0 Drill ahead to 400' Hours (hrs) Oil Under Fl (%) Dens FD (lb/gal) 1 Op Mud Checks: zsp.pftkB, 3/27/2007 12:00 , ; :,,,,,,;4 , ',....,,, , „;, , .',,', .;:.: y Amounts 1 ,IV''''';',...Ai.1,./ i .,,,,., -.,.....,;, Density (lb/gal) pH CEC for Cuttings I Pt (ml/mL) Calcium (mg/L) % Water (%) Mud Lost (Hole) (bbl) DescrIpt1011 i Cons... Daily Cost Vendor 1 10.00 9.7 0.200 91.8 ' MUD LAB I 1.01 45.00 VW (s/qt) Filtrate (mL/30min) Filter Cake (/32") Pm (mL/mL) Potassium (mgIL) Percent Oil (%) Mud Lost (Surf) (labl) Potassium 1.0 59.69 51 4.0 1 0.600 58.0 Hydroxide PV Over (cp) Gel (108)(1W/100f... Sand (%) MBT (1b/bbl) Lime (ibibbl) Oil Water Ratio Mud Vol (Act) (bbl) CON DET 1.0 433.801 10.0 8.000 0.0 3.0 PLAYSEAL 1.0 793.13 VP Over (lbf/10... Gel (10m) (lbf/100... Solids (%) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) ' DEXTRID 1 1.01 62.34 17.000 10.000 6.0 1.6 LT Type . Potassium , Base Gel (3107.)0(10b10/10 27,999.999 0.000 0... T (fl) (°F) Chlorides (mg/L) HTHP Flit (mLJ30... Alkalin (mLimL) Whole Mud Add (bbl) ,,, , 1 ■ Silicate (%) Electric Stab (V) Comment Barascav D 2.0 127.54 Fine tuning mud system for drilling: adjusting KCI content, pH level, and Mud 2.0 Engineer /l lE , PAC-R 2.0 309.30 rheology for hole cleaning. _ EZ MUD DP , 2.0 117.14 Report rt Printed' - 4/2/2007 4.10:1■1::alailiiiiHahrillr!!: , ...;,4 ,.''''.``ot,'..' , voiv,..4 ,.''' '4 . - ' , ,..Atoo _ FEX L.P. - DDR Detail Page 2/3 Well Name: AKLAQ #6 Job Type: Drilling - Original _< x.4, 9 - :j 3/2712007, Report: 6.0, DFS: 0.47 and E1 on (ft) O ig KB E 10 (ft) KB Groun (ft) ' Mud Additive Amounts:,, ii ,' :11 , , Description Cons... Daily Cost Vendor ' Mud Checks: 342.0ft ,l ' 27/2007 19:00 Vi ,( ' ,1;: Baracor 700 2.0 289.42 r Density (1b/gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) Ciric Acid 3.0 324.24 9.90 10.5 0.100 92.0 WALL - NUT ! 4.0 105.20 , Vis (s /qt) Filtrate (mLI30min) Filter Cake (132") Pm (mUmL) Potassium (mg/L) Percent Oil (%) Mud Lost (Surf) (bbl) I M 48 6.5 1 0.270 r , ±, }„ 1 PV Over (cp) Gel (1os) (Ibf /�o0f.. Sand (%) MBT pbtbbl) Lime (Iblbbl) 011 Water Ratio Mud Vol (Act) (bbl) A araza I Li 6.0 90 9.0 7.000 2.5 Potassium 72.0 1,172.16 YP Over gbf /10... Gel (10m) (IbN100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Chloride 18.000 10.000 5.8 1.9 Type Gel (30m) (Ibf1100... T (B) ('F) Chlorides (mg/L) HTHP Flit (miJ30... Alkalin (mUmL) Whole Mud Add (bbl) 4 a - I ..° . 71'. %, , Potassium 10.000 54.0 27,999.999 0.000 Date Type lirll Salt Base ' I ° '' silicate Electric Stab (V) Comment , eC Test Date Test Type Description Make Model Formations HG Dryer Derrick � Sample Top ', Formation Name MD (ftKB) Shaker Screens Base Permafrost 1,019.0 '' l kr`r'et+ft 3'17 :, - . 11114'7 a :.: ` ) ', 4 t° Scr SzX(In) Scr SzY(In) 1 1 120.000 Nanushuk Group 1,020.0 il Conductor P = ' 2 1 120.000 Csg Run Date OD (in) Grade IWI (Ibs /ft) 3 1 120.000 3/19/2007 16 H -40 65.00 of Shaker Checks Cement I ',...,..4.'t _ Dens UF (lb /gal) Hrs (hrs) Cmnt Des C 4 I I in Description Make Model HG Dryer Derrick Shaker Screens 5cr SzY(In) ia 1 1 120.000 2 1 120.000 3 1 120.000 "! "Shaker Checks 1 DescrI if on Dens OF (Ib /gal) Hrs(hrs) Make Model HG Dryer Derrick Shaker Screens Deck No. Screen No. Scr Sz X (In) Scr Sz Y (In) I ( 1 1 120.000 2 1 120.000 f 3 1 120.000 ' Shaker Checks ..... _.-.. . ` Dens OF (Ib /gal) .._.. ---- - - -- ........ .....__ .s..�. Hrs (hrs) ..,..... 1 yyam�:. . " , w Bit Run Make Bit Inventory Bit Type item Cost 1 Hughes 12 1 /4in, MX -1 , 510623 Mill Tooth IADC Bit Dull TFA (lncl Noz) (in') BHA ROP (ft/hr) Nozzles (/32 ") IADC Codes li 1- 1-WT- A- 2- 1 -NO -TD 0.67 43.1 16/10/16/16 1 -1 -5 -W + 5:;,:i.. t t ,n "n i.i* .«...�u " . `>s .ate ,+"' BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001. Max. Hook Load (Ibf) 1 302.00 900.0 480 5 WOB (10001bf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Driling Torque PU HL (100011d) Max. Over - Pull (Ibf) 10 302.0 302.0 1.00 1,500.0 15 10,000 .0 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units 80 HL (10001W) 220 120 1.00 1,500.0 10 . Hydraulic Calculations � AV DP (ft/min) AV DC (ft /min) Err 9I 21.0, 136.7 Unable to calculate drill string volume because at least one component is il missing an inner diameter Drill String Components Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle .. Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (") Drill Pipe 1,311.... p 4 17.53 TS... 2.5831 5 1/2 NC 40 5 1/2 NC ' 2,102.45 40 HWDP 248.88 4 27.20 2.750 791.45 ilull IP „ p z f /2/2007 � • FEX L.P. - DDR Detai ii ' werlimmentorin: � I n � � � h _ , i - t 9 �(i. - ; , , Date: 3/27/2007, at ®. r a t k S� Ii ( ", 1�1 L h `: . h q yyNi�E i t P t� I') 3 ', ; It' I a Ground Elevation (ft) Orig KB Elev (ft) KB- Ground D ( )�' ei 18.20 37.10 I 18.90 '* Drill String Components Mtr i Top Bhtt Bend '' Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (in) (Ibslft) Grade ID (in) (in) (in) Top Thrd (in) Thrd - Cum Len (ft) ( °) Drilling 31.96 8 2.250 542.57 Jars - Hydraulic ,_ KV HWDP 311.11 4 27.20 2.750 510.61 5 ., IXO Sub 2.61 8 154.58 2.560 199.50 Drill Collar 30.98 8 149.85 2.813 196.89 Drill Collar I 30.99 81149.85 2.813 1 165.91 , l MWD (Dir 83.73 8 161.44 1.920 134.92 il, Of & Logging) XO Sub 2.02 8 154.58 1 2.560 51.19 Drill Collar 15.30 8 147.00 5.000 49.17 - Pony Float Sub 2.22 8 154.00 33.87 Motor with 30.65 8 104.39 a 31.65 .44 l Stabile - m 6 hi,b1 iltN.rNl"'.14 W ' '' '' ' '' 3 ' '4 l -t'i 6 � a � ?iST I''L � � at Wellbores c, ar. .. _ , ,. . 1, Wellborn Name VS ph. ( °) Kick OM Depth mks) Original Hole I 0.00 Directional Surveys Date Description 3/27/2007 MWD Surveys �? Survey Data MD (ftKB) Incl ( °) Azm ( °) ND (ftKB) NS (ft) EW (ft) VS (ft) DLS ( °/100ft) Survey Company Ai ,y( 0.001 0.00 0.00 0.00 0.00 0.001 0.00 0.001HALLIBURTON S1 321.30 1.12 267.69 321.28 -0.13 -3.14 -0.13 0.35 HALLIBURTON " r i 0. w'„ r' 1 t II ■ '} IIJ, '..' 1 i Cn qI g Re ort Printed • 4/2/2007' w .V�t ruwix..i� *sr ! . h i � t .f ae Iix#..i.ti.r..U.... -no, e„,11 I re , +ii�7e :iia �.�. x Rr -x i�hH� ' �16iioul€ FEX L.P. - DDR Detail Page 1/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/28/2007, Reg , 6) , , DFS 1.47 u 7 . 41111 , Job Spud Date Rig Release Date Ground Elevation (ft) OrIg KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574244.00 151 Safety ' lrl' " [ l'Illli r ° ' I)i ,, ° I i ,I Target Depth (ftKB) Target Formation Al Type Date Comment _ �F . Safety Highlight 3/28/2007 Discuss hand injuries, pinch points Daily Cost Total Cum Cost To Date r . s 239,916.36 6,585,691.83 L o f t ` i ° "` Dal Mud Cost Mud Cum To Date ,0 Weather Leased Road Conditions Wellbore Condition Over ( +) /Under ( -) AFE ( + /.) Var Days ty Sunny, 5 degrees Good Good condition 14,608.36 54,290.83 Operations 0 06:00 , Depth Start (ttKB) Depth End (MKB) RS I DRILL 12 1/4" HOLE / DEPTH 1800' KB 400.0 1,540.0 , Depth Progress (1*) Drilling Hours (hrs) . 1 Operations This Report Period Drill ahead to 1540' 1,140.00 24 00 ll Operations Next Report Period L)r y4� F It ( ws q Drill ahead to casing point, short trip �-,uhi oren* r , t - ;,'il1111 X ir '1': �('Ilut l')Iiri ,t ,j� � . 'T°' ° ,�, '' " . " .. i ; iJi9 @9im ' Fischer, ° cher, Dt Cell 577-8455 Phone -,�. �� ` " ' = I' j + i ' ii 1 Gregg Fischer, Drilling (306) 577-8455 e ° Scheduled Depth End Foreman m a (hr- ° , [ tai Type Phase Major Op Operation Trouble (ftKB) Comment Ernie Natte,`Drilling (519 )427 -7406 g O g g 00:00 12.001 DrIg Planned Drl Surf Drilling Drill - Motor Dir No Trbl 981.0 Drill ahead in Foreman surface aole l 12:00 12.00 DrIg Planned brig Surf Drilling Drill Motor Dir No Trbl 1,540.0 Drill ahead in 'Rigs: Doyon, Arctic Wolf „ „. `fir. ` Op surface hole Rig Supervisor BiII Lupton Rig Manager ' OF Mud Checks: 918.0ftKB, 3/28/2007 10:00 ,,)jG I" ;' !!1 ; ' ' w . I)! Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) No. Pwr (hp) Rod Diameter (In) 10.00 10.0 0.150 91.5 I 1 900.0 ilti Vis (s /qt) Filtrate (mU30min) Filter Cake (/32 ") Pm (mL/mL) Potassium (mg/L) Percent Oh (%) Mud Lost (Surf) (bbl) ! Liner Size (In) Stroke (In) Voi$tk OR (bbl/s... 50 4.0 1 0.900 27,500.000 184.0 6 9.02 0.070 M ' " PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MBT (1b/bbl) Lime (lb/bbl) 011 Water Ratio Mud Vol (Act) (bbl) 12.0 11.000 0.2 6.0 : lki Pump Checks YP Over (lbf /10... Gel (10m) (ibf /100... Solids (%) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Strokes=' „ ': ` . 27.000 6.2 2.1 Pres (psi) Slow Spd (spm) Eff ( %) 1,200.01 No 87 95 Type Gl (30m) (Ibf 1100... T VI) (°F) Chlorides (mg/L) HTHP Flit (mU30... Alkalin (mUmL) Whole Mud Add (bbl) 0. Potassium 0.000 i mps i� 0000010° t{ l .. Salt Base I No. rc Pwr(hp) (Rod Diameter (In) Silicate (%) Electric Stab (V) Comment - 2 900.0 Adjusting mud properties as needed for hole cleaning & stabilization. Adding KCI user Size (in) Stroke (In) VollStk OR (bb1h... iii as needed for 32000ppm. Adding CLAYSEAL for shale stabilization. Adding 6 9.02 0.070 fa 6 -.. - - ' EZ -MUD (PHPA) to activate system at rate of 1 pail per 2 hrs. Adding water at Pump Checks rate of 1.5 -2 gal /min. strokes iy. -__ _._ ..._ ..... _._._ -- Pres (psi) Slow Spd (spm) Eff (f) ,, t 200718:00 = a, ( 1,300.0 No 87 95 l 0 Vis (slqt) Density (Ib/gal) CEC for Cuttings Pf (mL/ml) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) bakers t ption ?> it 10.00 Filtrate (mU3Omin) Filter Cake (132 ") Pm (m mL9 Potassium (mg Perce 01 %) Mud Lost (Surf) (bbl) ' Model qt) t 45 6.6 1 0.210 -. H! PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MBT (Ib /bbl) Lime (lb/bbl) 011 Water Ratio Mud Vol (Act) (bbl) Shaker Screens 11.0 10.000 0.3 5.0 Screen YP Over (ibf /10... Gel (10m) (Ibf 1100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) LDeck No. No. 1 Scr Sz X (in) Scr Sz Y (in) 26.000 18.000 7.5 4.9 � - 1 Type Gel (30m) (Ibf /100... T (fl) (°F) Chlorides (mglL) HTHP FM (mL/30... Alkalin (mUmL) Whole Mud Add (bbl) [Dens Shaker ( ks 1. Den UF(Ib /gal) Hrs (hrs) a er Checks Potassium 19.000 80.0 0.000 Salt Base Silicate (%) Electric Stab (V) Comment ; . Make Model Drying Shaker 0. u l r' Description Make Model Centrifuge /Cyclone Checks HG Dryer 'Derrick Density Overflow (lb/gal) Overflow Rate (gpm) qiiiTi Shaker Screens Dens OF (lb/gal) Underflow Rate (gpm) pp . Deck No. Screen No. Scr Sz X (in) SG! Sz Y (in) , N),01..1. i, ° . .. ( 1 1 120.0001 2 1 120.000 Hours (hrs) 011 Under Fl (%) i Dens FD (Ib/gal) 3 1 120.0001 r 4 ' u` ' t� Shaker Checks r) = 1. rl, , o 5... Dail IS 'is.' vend ' ;1,;, DensuF.(tblgal) ,G'„:''° :� �:s . a �li ..... w 1 Hrs(hrs) -.I, �ilr�IMu ... 1 J 2. _ Engineer !' Description Make Model HG Dryer Derrick MUD LAB 1.0 45.00 Shaker Screens - - Barazan D+ 24.0 3,809.04 „ aik Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) CLAYSEAL 4.0 3,172.52 IIIP 1 1 120.000 Potassium 120.0 1,953.60 2 1 120.000 Chloride l'Illil 3 1 120.000 lBaroid 186.0 1,902.78' Baracor 700 5.0 723.55 Aldacide G 4.0 663.72 „p 41 , u j , . Re ort Printed 4/2/2007, k ... ,� it „� +l"' Cil,x�"r"":N� to' ilmliw> „.�.�° vPrrvliiGu� „ !� ��»'�"sw% � � °ate „i,„ , , � i , „ i IiLII I a���,.,.... �tm ,�#illill"Ih��`!�6at� tir u .. 7),F ,A,„air,: ; , FEX L.P. - DDR Detail • Page 212 Well Name: AKLAQ #6 Job Type: Drilling- Original Date: 3/28/2007, Report: 7.0, DFS: 1.47 II. Ground Elevation (ft) Orig KB Elev (ft) I KB- Grround Distance (ft) M ud Additive Amounts 18.20 I 37.10 18.90 Description Cons... Daily Cost Vendor Shaker Checks EZ MUD DP 11.0 644.27 Dens UF (Ib/gal) Hrs (hrs) Baradefoam 3.0 329.55 HP a 1 i PAC -R 2.01 309.30 Description Make Model Potassium 5.0 298.45 HG Dryer Derrick Hydroxide Shaker Screens Barascav D 4.01 255.08 Deck No. . ' t „ i it , Screen No. Scr Sz X (in) Scr Sz Y (in) 4.01 1 1 120.0001 WALL -NUT 8.0 206.40 2 1 120.000 F 3 11 120.000; DEXTRID 3.0 187.02 1 Shaker Checks LT Shaker Dens OF (Ibigal) Hrs (hrs) Ciric Acid 1.0 108.08 I rill Strings: BHA #1, Motor `' ; .� `l " ' ''T' "�G '` � Last Casing Check tl " . r ilrm t { � i 1 Date Type Bit Run Make Bit Inventory Bit Type Item Cost 1 Hughes 12 1 /4in, MX -1 , 510623 Mill Tooth 1 !ADC Bit Dull TFA (incl Noz) (In') TBHA ROP (ft/hr) !Nozzles (/32 ") IADC Codes 1 Last BOP Check Type 1-1-WT-A-2-1-NO-TD 0.67 43.1 16/10/16/16 1-1-5-W T est Date Test T y I 0 - w`t ■ __ _.. _. - ! BHA No. Cum Depth (ft) SPP (psi) FIow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) Formations II 1 1,442.00 1,200.0 480 5 Sample Top WOB (100011:4) Interval ROP (R/hr) Total ROP (Rlhr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over-Pull OM) Formation Name MD (ftKB) 12 47.5 57.7 24.00 1,500 .0 15 12,000.0 Base Permafrost 1,019.0 Nanushuk Group 1,020.0 Bit RPM (rpm) Motor RPM (rpm) !Cum Drill Time (hrs) Off Bottom Torque Torque Units ISO HL (1000Ibf) 220 120 25.00 I 1,500.0 10 Csg Run Date n Grade s Hydraulic Calculations m 771 n , 3/19/2007 16 H-40 65.00 Av)3P (1Hmi 2, 0 AV DC (ftrm 1 36.7 Una ble to calculate rill string volume because at � d g t least one component is �_ - _ �,:, � � v missing an inner diameter Cnint Des Coat ent r 1 Drill StringComponents - -.. -. _- __._...____ ....... r Mtr ;, i 0 Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angie s Jts Descrition Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) 0) Drill Pipe 1,311.... 4, 17.53 TS... 2.583 5 1 /2l NC 40 5 1/2 NC 2,102.45 ) 40 HWDP i 248.88 4 27.20 2.750 791.45 Drilling 31.96 8 2.250 542.57 Jars - Hydraulic HWDP 311.11 4 27.20 2.750 3(lt ., l f.' 510.61 1X0 Sub 2.611 8 154.58 12.560 199.50 Drill Collar 30.98 8 149.85 2.813 196.89 I 'Drill Collar 30.991 8 149.85 2.813 165.91 MWD (Dir 83.73 8 161.44 1.920 134.92 &Logging) XO Sub 2.02 8 154.58 2.560 51.19 Drill Collar 15.30 8 147.00 5.000 49.17 , - Pony Float Sub 2.22 8 154.00 1 33.87 1 Mote '.l ri 30.65 8 104.39 31.65 1 ■ w ¢s-, Iii'" 4 fit, ,0#. r .'f; i 'x B O rigin sl , Wellbore Name VS Dir C) Kick Off Depth (ftKB) t al Hole 0.00 M1M1 L. Directional Surveys Date Description 3/27/2007 1 MWD Surveys Description Survey Data i MD (ftKB) Inc' ( °) Azm ( °) TVD (ftKB) NS (ft) EW (ft) VS. (ft) DLS ( °1100ft) Survey Company 0.001 0.001 O.00L 0.001 0.00 LHALLIBURTON ■ ii d i I ' -------A110-- F'X L P DD ,�I � ,. � '1 Page 1/3 Well Name. AKLAQ #6 ; : „1 1 „,,,,,„,„,,,,, , , , A li' , ,„ li I�I , • il 1,4'4'11" Job Type: Drilling - Original Date 3/29/2007,'Re• i .', DFP1 � j 1 • Job Spud Date Rig Release Date 'Ground Elevation (ft) T Orig KB Elev (ft) 'KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup .t, 3/27/2007 12:45 J 18.20 37.10 18.90 1 AF62034 22,574,244.00 22,574,244 00 Safety TargetDepth(ftKB) Tar Formation ii Type - -- Date -... Comment -.- - -- i,'. Safety Highlight 3/29/2007 Discuss warming temps and slippery areas Daily Cost Total Cum Cost To Date ; 238,072.49 6,823,764.32 .: t 1' i n a ball Mud Coat Mud Cum To Date Weather Lease / Road Conditions Wellbore Condition Over ( +) /Under ( -) AF AFE ( +/.) Var Days y Cloudy 25 degrees Good Pulling tight on short trip 14,014.49 68,305.32 Operations 08:00 Depth Start (ftKB) Depth End (ftKB) On bottom circulating B/U 1,540.0 2,101.0 1 -- ----- - -- Depth Progress (ft) Drilling Hours (hrs) Operations This Report Period Drill ahead to TD © 2101. POOH on Short trip. 561.00 21.50 Operations Next Report Period N_ ,,� I Short trip, POOH run casing Daily ): ore ' 7 e . l'v Job Contact ` Cell Phone Time Log Ernie Natte, Drilling (519) 427 -7406 Start Dur Ops Scheduled Depth End Foreman Time. (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment 0 00:00 14.501DrIg Planned',Drlg Surf Drilling "'; Dr - Rotary No Trbl 1,977.0 DRILL 12 1/4" Rigs: Doyon, Arctlblf Op HO LE F/ 1540' - Rig Supervisor Bill Lupton Rig Manager 14:30 0.50 DrIg Planned DrIg Surf Drilling Rig Repair / No Trbl 1,977.0 rt Peri RIG & Mud Pumps: , • PZ -9 No. Pwr (hp) Rod Diameter (in) Op Service TOP DRIVE 1 900.0 15:00 7.00 Drlg Planned Drlg Surf Drilling 'Drill - Rotary No Trbl 2,101.0 DRILL 12 1/4" utter size (In) Stroke(in) Vol/Stk OR (bbl/s... Op HOLE F/ 2101' 6 9. 0.070 22:00 1.50 DrIg Planned flat Surf Drilling Circ & Cond No Trbl 2,101.0 Circulate and clean Pump Checks Op Mud hole Strokes 23:30 0.50' DrIg Planned Flat Surf Drilling Trip Out No Trbl 2,101.0', Blow down POOH Pres (psi) slow spd lsem) Eff (%) Op on short trip No Mud Checks ; ,1$56 0ftKB�.31 912007, 10k _ , Mud'. r, Gardner - Denver, PZ -9 Density (1b/ al N O. Pwr ( hp) 1 2 Rod Diameter (in) g ) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % (%) Mud Lost (Hole) (bbl 900.0 5 10.20 10.0 0.200 90.4 -- - - - - -- brier Size (In) Stroke (in) Vol!Stk OR (bbl/s... @ ', Vis (s /qt) Filtrate (mL/30min) Filter Cake (132 ") Pm (mUmL) Potassium (mg!L) Percent 011 (%) Mud Lost (Surf) (bbl) 1 6 9.02 0.070 51 6.8 1 0.450 210.0 PV Over (cp) Gel (105) (Ibf /100f... Sand ( %) MBT (Ibibbl) Lime (lb/bbl) 011 Water Ratio Mud Vol (Act) (bbl) Pump Checks 11.0 11.000 8.0 a Strokes YP Over (Ibf /10... Gel (10m) (Ibf/100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (WI) Pres (psi) Slow Spd (spm) Eff (/) , _ 26.000 18.000 7.2 2.7 1722.0 No 87 951 111 Type Gel (30m) (lbf/100... T (tl) ( °F) Chlorides (mg /L) HTHP Filt (mL/30... Alkalin (mUmL) Whole Mud Add (bbl) (Shakers: <Description ?> Potassium 21.000 31,000.000 0.000 Make Model Salt Base Silicate (%) Electric Stab (V) Comment Shaker Screens Adding EZ -MUD for shale inhibition and lubrication. Adding BARAZAN for screen viscosity and a mixture of PAC -R, PAC-L, and DEXTRID for filtration control. Deck N o. No .Scr Sz X (in) Scr Sz Y (in) Adding KOH for alkalinity. Using centrifuge to decrease mud weight. Centrifuge temporarily down when cuttings plugged up and froze. Shaker Checks - - -- - - -- - -- ° °- Dens OF (lb /gal) Dens UF (lb /gal) ° Hrs (hrs) Mud Checks: 2,026.OftKB, 3/29/2007 18:00 h, ,. P Density (lb/gal) pH CEC for Cuttings Pf (mUmL) 'Calcium (mg!L) % Water ( %) Mud Lost (Hole) (YYI) a r, •:M, i s g tk I 10.30 8.8 0.100 90 , . -- - - - ......... -- �, :,,.v .... -. -._- 90.0 n , �., Percent Make Model l' Vis (8/qt) Filtrate f. PV Over p) GeliO 6.ibf/100L,. Sand ( %) a (/32") Pm (mUmL) MBT (Iblb LlmespWbbl) 1fIL) Oil Wate�Ratio Mud Lost (Act; fl (bbl) ntrifuge /Cyclone Checks 14.0 11.000 0.3 5.0 Density Overflow (Ibigal) Overflow Rate (gpm) CI: YP Over (Ibf /10... Gel (10m) (Ibf /100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 26.000 26.000 7.3 2.4 Dens UF (lb/gal) Underflow Rate (gpm) Type Gel (30m) (lbf1100... T (fl) (°F) Chlorides (mg!L) HTHP Flit (mL/30.. Alkalin (mUmL) Whole Mud Add (bbl) Potassium 29.000 93.0 35,000.000 0.000 Hours (hrs OII Under Fl (%) Dens FD (lb/gal) Salt Base Silicate (%) Electric Stab (V) Comment A ,, $ : r'f 1111012= on Cons... Daily Cost Vendor ` ^ ^r ii k e , i, ;9 "III'iiIl I�i'y i'` - „ , ( MUD LAB 1.0 45.00 Drying S haker b ata Description Make Model IGON DET 1.0 433.80 HG Dryer ' Derrick Aldacide G 2.0 331.86 Shaker Screens Mud 2.0 Deck No. Screen No. Scr Sz X (In) Scr Sz Y (in) Engineer 1 1 120.000 PAC -R 2.0 309.30 2 1 120.000 Potassium 3.0 179.07 0 3 1 120.000 Hydroxide Shaker Checks CLAYSEAL 3.0 2,379.39 Dens UF (1b /gal) `; ' +' Hrs (hrs) Baracor 700 4.0 578.84 PAC -L 4.0 633.60 Barascav D 6.0 382.62 Report Printed: 4/2/2007 li: :;,0', ., FEX L.P. - DDR Detail Page 2/3 ' � I ' ® >I 1 ° i Ir r � 8 . 0 , 3/29/2007 Report: 8.0 DFS: 2.47 0 -2 "' ' ' ' - ' ' (ft) Ori y s x �Id �' ` ... �€ . i I n , Ground Elevation ft g KB Elev (ft) KB- Ground Distance (ft) 1 M ud AdditlVe AMt74 nt5 '4 ;i ` � 18.20 37.10 18.90 I Description Cons... Daily Cost Vendor � 1g St 1,' r DEXTRID 8.0' 498.72 I i dr 6.aa i * ",', ? ' Description ption DatQ lJ loli(d iI'�'G,Ii, Make Model LT , ' 1 HG Dryer Derrick WALL -NUT 16.0 420.80 EZ MUD DP 9.0 527.13 ,Z.1,1 L a Shaker Screens „4) __. Deck. No. Screen No. Scr Sz X (in) Scr Sz Y (In) M ( ' 1' 1 120000, , ' Barazan D+ 20.0 3,174.20 " ; It ■ kik. 2 1 120.000 Potassium 52.0 846.56 I;' 1 I '_ . 3 1 120.000 { Chloride ' Shaker Checks I Baroid 320.0 3,273.60 I' Defr4'U' tb`t°iii ` 'fl Hrs Nr$ A. Description 1Make IMOdeI Date ng Ch C' Type HG Dryer Derrick Shaker Screens r I '," �I 1,I; { BOP Chec 11'1, 1 Deck No. Screen No. Scr Sz X (in) Sz Y (in) 1 1 120.000 Test Date Test type 2 1, 120.000 - 1 3 11 120.000 Formations iittii '461 TOp Shaker Checks ' Formation Name' 1 44 4 : 4 4:: MD (ftKB) ''' J.a,„ •a1) Hrs (hrs) Base Permafrost , 019.0., Nanushuk Group 1,020.0 �� Drill-Strings: 1 cilia BHA #1,M I cal "��I�i „ia m „���PIRa�I��l� �m rc r ,,, Bit Run I Make Bit Inventory Bit Type Item Cost Csg Run Date OD (in) (Grade I Wt (Ibs /ft) 1 'Hughes 12 1 /4in, MX -1 , 510623 Mill Tooth i _ 3/19/2007 16 H -40 65.00 it IADC Bit Dull TFA (loci Noz) (in) 'BHA ROP (ft/hr) Nozzles (132 ") IADC Codes e . . 1-1-WT-A-2-1-NO-TD 0.67 43.1 16/10/16/16 1 1 chi 2 ti ! � , 5 W Conh �l t91� 1 2 01,44.4#0 r 1 IHIIII1IIIII1�I 1 "Al ll ' � , r i i ' IlI Iu111 (II h 'S INII[ ru :n Ggi , ` '' s ,V 3 L , 1 m �' � ,,, : X 1 5 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) T Reference Rot HL (10001... Max. Hook Load (Ibf) r 1 2,003.00 1,400.0 525 11 , ( WOB (1000Ibf) Interval ROP (fUhr) Total ROP (fUhr) Drilling Time (hrs) Drilling Torque PU HL (1000lbf) Max. Over -Pull (Ibf) '...... `�; ', 12 26.1 43.1 21.50 1,500.0 12 15,000.0 0 r ill Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (10001b1) I 240 120 46.50 1,500.0 10 Hydraulic Calculations lilifo AV DP (ft/min) AV DC ( ft/min). -"- Err riftki 23.0, 149.5 Unable to calculate annular pressure drop because pressure drop data i s ,, missing from AV talc Drill String Components Mtr 'p Top Btm Bend 'AV? Item Density Drift Conn Sz Conn Sz Btm Angle jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (In) Top Thrd (in) Thrd Cum Len (ft) ( °) rC Drill Pipe 1,311.... 4 17.53 TS... 2.583 5 1/2 NC 40 5 1/2 NC 1 2,102.45 40 HWDP 248.88 4 27.20 2.750 791.4 ' Drilling 31.96 8 2.25 542.57 �, Jars ` Hydraulic HWDP 311.11 4 27.20 2.750 510.61 i XO Sub 2.61 81 154.58 2.560 1 199.50 s,' Drill Collar 30.98 8 149.85 2.813 196.89 I Drill Collar 1 30.99 8I 149.85 2.813 L 1 165.911 MWD (Dir 83.73 8 161.44 1.920 134.92 ii & Logging) 4 XO Sub 2.02 8 154.58 2.5601 1 I 51.19 ;,, ' Drill Collar 15.30 8 147.00 5.000 49.17 - Pony Float Sub 2.22 8 154.00 I 33.871 k M with 30.65 8 104.39 31.65 Stabilizer Iii , � r u� „ ,,,:�� "'"1' 414," �.� Wellbore Name VS Dir ( °) Kick Off Depth ( ftK B ) g 44* Original Hole 0.00 1{, = Directional Surveys . Date Description " ' 3/27/2007 MWD Surveys/ . � i... � . v .. (i FEX L.P. - DDR Detail -a 3 Well Name: AKLAQ #6 "u', � ' �. i I ( Job Type: Drilling - Origina , Date: /29007, 12eport: 8.0, DFS: 2.47 0 , I Ground Elevation (ft) Orlg KB Elev (ft) KB- Ground Distance (ft) 18.20 37.10 18.90 ' .,' y. J ___ Survey Data 1 ' MD (ftKB) Inc! ( °) Azm ( °) TVD (ftKB) NS (ft) EW (ft) VS (ft) DLS ( °It00ft) Survey Company . 417.941 1.37 203.11, 417.90 -1.231 -4.53 -1.23 1.39IHALLIBURTON 475.47 0.94 202.15 475.42 -2.30 -4.98 -2.30 0.75 HALLIBURTON kl 604.93 0.511 173.86 604.871 -3.85 - 5.321 -3.85 0.421HALLIBURTON 666.98 1.18 289.72 666.91 -3.91 -5.89 -3.91 2.38 HALLIBURTON 729.49 0.87 201.27 729.42 -4.14 -6.67 -4.14 2.31 HALLIBURTON I, i l i 792.90 0.63 180.96 792.82 -4.93 -6.85 -4.93 0.56 HALLIBURTON 111 854.711 1.18 289.28 854.631 -5.06 - 7.461 -5.06 2.431HALLIBURTON 917.30 1.43 230.25 917.20 -5.35 -8.67 -5.35 2.08 HALLIBURTON . . 979.441 1.12 299.00 979.331 -5.55 -9.791 -5.551 2.35 HALLIBURTON ;t 1,166.43 0.87 181.14 1,166.31 -6.09 -11.42 -6.09 0.91 HALLIBURTON .,, 1,416.231 3.47 194.43' 1,415.91 -15.301 13.341 -15.30 1.05 1, 1,605.57 7.18 250.25 1,604.50 -24.86 -25.92 -24.86 3.15 HALLIBURTON 1,667.19 7.871 268.68 1,665.60 -26.26 -33.76 -26.26 4.051HALLIBURTON 1 , 1,730.43 8.01 212.36 1,728.32 - 30.09 -40.46 -30.09 11.82 HALLIBURTON 1,793.24 9.551 271.80, 1,790.511 -33.63 - 48.021 -33.63 13.98 HALLIBURTON ,, 1,854.49 6.93_ 303.00 1,851.15 -31.45 -56.21 -31.45 8.31 HALLIBURTON 1,979.711 2.8 316.291 1,975.90 -25.10 -64.681 -25.10 3.37 HALLIBURTON ' 1 ' IL 1 yy 1 f , A I 1 (: . , io it , , ,,,,,, ,,, , , „ ' TM� � i ,, � i °Ante °/2/2007 l/ �: ` �'' � r � , , -1� Ii ail 's ���� k , y[fi �kr,�U. i � 1 w I d �, ; u r 7s qt � n , . FEX L.P. - DDR Detail II Page 1/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/30/2007, Report: 9.0, DFS: 3.47 il l Job Spud Date - - - -- Rig Release Date - - -- l Ground Elevation (ft) 0rig KB Elev (ft) KB- Ground Distance (ft) AFE No. - - -- Total AFE Amount Total AFE +Sup l l „ 3/27/2007 12:45 8 18 20 0 18 0 AF62034 22,574,244.00 22,574,244 00 ` � l � i ��'k . , l �(� iii afi����i�� (j' "' z . , ! l. : ,' ,,,, r "`ww.,E�,;#r"x' 37 r ! �I 9 '' "�'l� � " �� g t Depth (ttKB) Target Formation ., � . r 1 r� Tar e 'Ipe _ Date . Comment u,d, PMV, ,; ,, - 1 1 ¢ Sa fety Highlight 3/30/2007 Moving camp / eye contact w/ equipment operators Daily Cost Total Cum Cost To Date 224,514.76 7,048,279.08 D 1� G� *I pally Mud Cost Mud Cum To Date Weather Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( +l -) Var Days F cloudy 10 degrees Good Casing set at 2072 456.76 68,762.08 " Operations @ 08:00 Depth Start (ftKB) Depth End (ftKB) 1 i RUN IN W/ 4 112" CMT STRING 2,101.0 2,101.0 -- ---- -- -- -- �— Depth Progress (ft) Drilling Hours (hrs) ll Operations This Report Period POOH,L /D 8" BHA,RIH w/ 9 5/8" casing 0.00 'I Operations Next Report Period "1 $ I ` � 4 , f � Cement 9 5/8" casing, Nipple down Nipple up pi f F gr r - w -, r J- Con " o 4444411 ,i0,44,;'44'4,4 1 II ' X 1 �` "' - 4 .- 444 �� � �`�' ` Ernie Natte, Drilling 519 427 -7406 g „tl�I . ; 9 ( ) i 1 � start 1 Dur ,, Opa Scheduled Dealt - �, i �. Fore r. Time ' Oral , Cat Type Phase Major Op Operation Trouble (ftKB) Comment 1,181111 (, l = • 00:00 4.00 Drlg 'Planned 'Flat Surf Drilling Short No Trbl 2,101.0 SHORT TRIP / g l ; I: ��,llrcti ; . t �1 . a Op 1 9 Trip BACKREAM F/ 1477 - 1296' &F / RI Supervisor Lupton Rig Manager ' __ -_ 1172' - 1044' KB Mud . ' x °. .; .. n er -De ,, x,” 111 . ti No. Pwr (hp) !Rod Diameter (in) 04:00 0.50 Drlg Planned'riat Surf' Drilling 'Rig Repair / No Trbl 2,101.0 SERVICE RIG & 1 900. Service TOP DRIVE Liner Size Stroke (in) I iVol/StkOR(bblls ( , r O p g Trip in hole 6 9.02 I 0.070 lill 04:30 1.50' Drl g Planned Flat Surf � Drillin Tri p In No Trbl 2,101.0 I Op Pump Checks 06:00 1.00 Drlg Planned Flat Surf Drilling Circ & fond No Trbl 2,101.0 Circulate sweep, Strokes , ' Op Mud condition mud ores (psi) Slowspd (spm) Eff ( %) 07:00 0.50 DrIg Planned I Flat Surf i Drilling Rig Repair / No Trbl 2,101.0 Monitor well,Blow No Op i ;Service d own all lines [1L ,Pttmps: 2, Gardner -penver, PZ -9 07 :30 4.50 Drlg Planned Flat Surf Drilling Trip Out No Trbl 2,101.0 POOH, LAD jars N °' Pwr (hp) Rod Diameter (In) i, Op 2 900.0 ,'1,11, Liner Slze (in) Stroke (in) Vol /Stk OR (bbl/s... ,I 12:00 1.25 Dr(g Planned Flat Surf Drilling Handle Tools No Trbl ' 2,101.0 Stand back 5 jt 6 j 9.02 0.070 I,/ Op HWDP, L/D 2 NM drill collars Pump Checks I ,,, , 1 1.1rek!i °. 13:15 4.75 Drlg Planned Flat Surf Drilling Handle Tools No Trbl 2,101.0 Remove Nuke Pros (psl) Slow Spd (spm) 6 0,('O dai Op source, download l No ;111 a MWD, L/D BHA Shakers: <Descript(vn ? >'i' ", jII! /# Ja`l1 18:00 3.001 Drlg Planned Flat Surf 'Case & Handle Tools No Trbl 2,101.0; Rig up casing Make Model kill Op Cmnt running tools, and . �;; II landing jt, clean Shaker Screens floor 1 Screen Deck No. No. :, Scr,Sz/L n) 21:00 3.00 Drlg Planned Flat Surf Case & , Trip In No Trbl 2,101.0 RIH with casing to „ Op Cmnt 1700' Shaker Checks Mud Checks: ; 1,856.0ftKB, 3/2 10 :00 Dens OF (ibigal) Dens OF (101951) Hrs (hrs) Density (1b )gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) 10.20 10.0 „ I I II(Illi���ij a r °�. 1 l a rt "rq Hi i r ' if al Ht# VIS (s /qt) Filtrate (m1J30mIn) Filter Cake (132 ") Pm (mUmL) Potassium (mgIL) Percent Oil ( %) Mud Lost (Surf) (bbl) Make Model 51 6.8 _ I PV Over (cp) Gel (10s) (Ibf /100f . Sand ( %) MBT (lb/bbl) Lime (ib /bbl) Oil Water Ratio Mud Vol (Act) (bbl) - - - - Centrifuge /Cyclone Checks ( 11.0 11.000 Density Overflow (11:1/gal) Overflow Rate (gpm) '06 I � ( iYP Over (Ibf/10 .. Gel (10m) (Ibf /100 (Res) ( %) LOS (%) Polymer (ppm) LCM Mud Vol (s) (bbl) 26 000 18.000 7.2 liens OF (1b/gall Underflow Rate (gpm) Type Gel (30m) (Ibf /100... T (fl) ( °F) Chlorides (mg /L) HTHP Flit (mL130... Alkalin (mUmL) ,Whole Mud Add (bbl) Potassium Hours (hrs) Oil Under Fl (/°) Dens FD (lb/gal) Salt Base 1 Silicate ( %) Electric Stab (V) Comment ) ii iIt w Ala Isq 7 Il l ' Description C, rhs.` Daily Cost Vengbr _0 2.0 289.42 Ibarecor 700 .. .ir . :d0 63.773 ._. EZ MUD DP 1.0 58.571 , Mud Ili i ? Engineer id ili l . p ..F e a s ...T t v -.. r ee s °I , 'k� . v. ,,....�11 ywk �U II „aIH�� birt � .. .a i „, Suoa� v :a. ;« . ...w ,_,.. m,„ c.a_I� . _ . w »,N ,.� ,. ., I hak+S'nfi0H . ,,,,f ai t iGlr . a r;.. .1, , , , - AD FEX L.P. - DDR Detail Page 2/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/30/2007, Report: 9.0, DFS: 3.47 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Formations 18.20 37.10 18.90 sample Top I 14 m 2,026.OftKB, 3l29/2007 18:00 uai � - - Formation Name MD (ftKB) Density (1b/gal) pH CEC for Cuttings Pf (mL /mL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) Base Permafrost 1,019.01 10.30 8.8 Nanushuk Group 1,020.0 d Vis (s /qt) Filtrate (mU30min) Filter Cake (132") Pm (mLanL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbl) : ; : 4 46 6.4 Csg Run Date OD (in) Grade Wt (Ibslft) PV Over (cp) Gal (10s) (lbf/100t... Sand ( %) MBT (lb/bbl) Lime (1b/bbl) 011 Water Ratio Mud Vol (Act) (bbl) 3/19/2007 16 H-40 65.00 1 YP 14.0 11.000 Over (Ibfl10... Gel (10m) (1b0100... Solids (%) LOS ( %) Polymer (ppm) LCM Mud Vol (R ( bbl ) '-"3' ?f , �.. m o r "'(i ,a Ewa n ' .I fi ; 26.000 26.000 7.3 1 F Type Gel (30m) (Ibf /100... T (ti) (°F) Chlorides (mg/L) HTHP F111(mU30... Alkalin (mL/mL) Whole Mud Add (bbl) Potassium Salt Base ri Silicate ( %) Electric Stab (V) Comment Mud Checks: 2,101.OftKB, 3/30/2007 09:00 °Mi), I G �° ., Jw.��illli I � Density (lb/gal) pH CEC for Cuttings Pf (mL /mL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) 10.00 9.2 0.150 91.0 Vis (slgt) Filtrate (mL/30mIn) Filter Cake (/32 ") Pm (mL/mL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbl) 47 6.4 1 0.500 80.0 PV Over (cp) Gel (10s) (Ibf /1001... Sand ( %) MBT (1b/bbl) Ume (lb/bbl) Oil Water Ratio Mud Vol (Act) (bbl) 10.0 10.000 6.0 YP Over (Ibf /10... Gel (10m) (Ibf1100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) � 25.000 15.000 6.4 2.4 i i Type Gel (30m) (Ibf/100... T (fl) (°F) Chlorides (mg/L) HTHP Flit (mL/30... Malin (mUmL) Whole Mud Add (bbl) I 1+„ Potassium 19.000 33,000.000 0.000 1 Salt Base Silicate (%) Electric Slab (V) Comment Running centrifuge to decrease mud weight to 9.3 ppg. Mud treated and ready 1 ill for logging operations Mud Checks: 2,101,Q: -4,1% 047,4 ,.,, ii, 44464444 Density (lb/gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) 9.90 8.0 0.000 90.0 0 Vis (s /qt) Filtrate (mU3omin) Filter Cake (/32") Pm (mL/mL) Potassium (mg /L) Percent 011 ( %) Mud Lost (Surf) (bbl) 43 6.4 1 0.000 0.5 PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MBT (Ib/bbl) Ume (Ib/bbI) 011 Water Ratio Mud Vol (Act) (bbl) 11.0 9.000 0.5 6.0 0.6/99.4 YP Over b010... Gel (10m) `1bf/100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 23.000 17.000 7.3 5.4 Type Gel (30m) Ibf1100... T (fl) (°F) Chlorides (mg/L) HTHP Filt (mU30... Alkalin (mUmL) Whole Mud Add (bbl ) a Potassium 22.000 83.0 35,000.000 0.000 i Salt Base _ ;( ■ Silicate ( %) tr Electric Stab (V) Comment -- _1_ D.�s RA " ., IPL,P00,A4 . . 6�i'�ii�,�:';, ' hs, �tlaW�aa ,Lhiewl�aala Description Make Model HG Dryer 'Derrick Shaker Screens Deck No. Screen No. 4 Scr Sz X in 7 Y 1K 1 1 120.000 " 2 1 120.000 itil 3 1 120.000 Shaker Checks Dens UF (lb/gal) Hrs (hrs) Make I Model l Description i HG Dryer Derrick ,:, Shaker Screens a Deck No Screen No. : `', Scr Sz X (in) Scr Sz Y (in) lC , ) 1 1 120.000 € 2 1 120.000 3 1 120.000 ,r„r Shaker Checks Dens UF (lb/gal) Hrs (hrs) f Description Make Model HG Dryer " ' Der r ick Shaker Screens Vri .' ° , 4,T ` Screen No. Scr Sz X (in) Scr Sz Y (in) (, 1 1 120.0001 Ili/ Ili i . 2 1 120.000 �I li - --- - - - - -- - III- ill FEX L.P. - DDR Detail Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3 /30/2007, Report: 9.0, DFS: 3.47 .Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance ( 18.20 I 37.10 j 18.90 Shaker Screens ! Deck No . Screen No. Scr Si X (In) Scr Sz Y (In) f 3; 1i 120.0001 , Shaker Checks Dens OF (Ib /gal) Hrs (hrs) a = + ° l Drill Strings: f ui, Bit Run ;Make Bit Inventory Bit Type ' Item Cost IADC Bit Dull TFA (Intl Noz) (in') BHA ROP (ft/hr) Nozzles (132") IADC Codes BHA No. ,Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) lii lti" WOB (10001bf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over -Pull (Ibf) Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000Ibf) I Hydraulic Calculations 1 AV DP (ftlmin) , „ DC (ft/min) Err ii�i I8 Drill String Components,. ,r •.-- . aM, .. M Mtr Top Btm " Bend illi Item Density Drift Conn Sz Conn Sz Btm Angle , Jts. Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (') Wellbore Name VS Dir ( °) Kick Off Depth (ftKB) Original Hole 0 .00 I Directional Surveys ill Date Description 3/27/2007 MWD Surveys j I9 ''r. 1 1 1 pI iii , I i 3 � , . „,,y,;: ort Printed: 4 /2 /2 S!t 1 '1 € � � � '`a” � � I L � I, xj L3 " y i6a, �4'�� F.,, >�rtl(w � h . u,a �r�.�, =lf rs.�� _.. `hI1� i��.i ��� �.6 '� - e7li FE L.P. DDR Detail Page 1/3 -- ID Well Name: AKLAQ #6; Job Type: Drilling - Original Date: 313112007, Report: 10.0, DFS: 4.47 • Job Spud Date - - -- Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (Ft) AFE No. T Total AFE Amount Total AFE +Sup 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 Safety Target Depth (ftKB) Target Formation Type Date Comment ,,.,_,,,; x. ,,,;, ; ,, ,;. p k� Safety Highlight 3/31/2007 Cementing / pressure lines & communication DaiyCost Total Cum Cost To Date Daily Summary ;a; tPl : h, : l 't a' >,rt i, 216614.18 7,,893.26 Weather Lease / Road Conditions Wel ibor e Condi tion Over ( +) I Under (•) AFE ( +1•) Var ; pays Daly Mud Cost Mud Cum 264 T o Date Li cloudy 16 degrees Good Casing set at 2072' 8, 389.68 77,151.76 kii Operations @ 06:00 - i Depth Start (ftKB) Depth End (ftKB) /1 ill 2,101.0 2,101.0 ilk Nipple up BOP pressure test Depth P ro ress (ft) g (hrs) Operations This Report Period - - - - - 9 O Drillin Hours hrs Cement 9 518" casing, Nipple down 0.00 Operations Next Report Period Pressure test BOPE, pressure test casing, pick up pipe, make up BHA, drill floats, LOT /FIT Job Contact Cell Phone 7 bI l�'' Ernie Natt Dnllin (519)427-7406 Start our e s „- - £ De pth End Foreman Time (hrs) at T ype Phase Major Op Operation Trouble (ftKB) Comment tit o 00:00 1.50 Drlg 'Planned Flat Surf Case & Run Casing No Trbl 2,101.0 Run i n hole with 9 ; Rlg Supery i sor Ri gs: Doy On Pplii Cmnt 5/8 "casing Op Bill Lupton, Rig Manager 01:30 2.50 Drlg Planned Flat Surf Case & Circ Casing No Trbl 2,101.0 Circulate casing " . Op Cmnt N O, (h perdner - Rod n Dimeter (In) I '; 04:00 1.00 Drlg Planned Flat Surf 1 Case & Circ Casing No Trbl 2,101.0 Rig down casing 1 1 900.0 Op Cmnt running tools and Liner Size (In) Stroke (In) Vollstk oR(bblls... iiiiiti I blow down 6. - -- 9.02 0.070 1)5 :00 2.06:Dri "g Planned Flat Surf Case & Circ Casing No Trbl 2,101.0 rig up to run. in hole Pump Checks _ _,' Op Cmnt w dp for inner stroke , string job Pres (psi) slow . Spd ' (spm) Eff ( /) 1 R No 09:00 1.50 Dr1 Planned Flat Surf Casing Case & I Run Casing Other 2,101,OIP gOp No. Pwr (hp) R casing to space-out out Mud Pumps: 2(Gardner -R Rod Diam PZ eter (in) � Op Cmnt g . d Diam Drlg g Rig up ' Op Cmnt equipment and run 2 900.0 J Liner Size (In) Stroke (in) VollStk OR (bblis... two joints to 6 9.02 0.070 iii re -space r Pump Checks 10:30 2.00 Drlg Planned Flat Surf ; Case & ,Circ Casing Other 2,101.0' :Circulate casing, - strokes Op Cmnt ��Rig down casing Pres (psi) Slow Spa ( SP m) EFf(i) I 'tools, blow down No 12:30 1.00 Drlg Planned Flat Surf Case & Trip In No Trbl 2,101.0 Run drill pipe for Shakers: <Description ?> Op Cmnt inner string job Make Model 1 Rig 13:30 1.00 Drlg Planned Flat Surf Case & Circ Casing No Trbl ' 2,101.0 1 4 up cement Op Cmnt head and break Shaker Screens _ circulation Screen 1 €, . Deck No. No. Scr SzX (in) Scr Sz Y (in) 14:30 2.50 Drlg Planned Flat Surf Case & Cmnt Casing No Trbl 2,101.0 pump 5 bbl water I I Op Cmnt @ 15:25 pressure Shaker Checks 41111444144714141 h' r ".I ° I , j , t u r�004444 � 4 ' test. to 2500 psi @ Dens OF (lbl al Dons OF ib/ al Hrs hrs 444; 4 'S YY 15:30 pump 5 bbl g ) ' ( g ) ( 1 • I;I .. ., -.4,, , l, .,, -. 1 , ,,C , 1, water and 20 bbl of e � .0 .. vial > 1 � w rli I,ip 10# alpha spacer. o ` ,;� ;t 144144414111414444144444444044 r Make Model �n I , �h ' i .: q ( , 11l Start to pump 136 r{ ' 3 6 ;i A ,,l Ili , 1 , ( "r f % t , ,f 42 ti I, t i I,k ,. w i ft.t, r € 1I ,n t F-11 t ir9:1' p t tiltf1 . � �. € :, i bbl of lead at 4 -5 _ - _..__. ........._. _ Centrifu elC clone C hecks f i ' € „ „I�I '��I{�� , b @15:40 g -_ �,' . ' ifii,t '' , ` {`' r' ; id,,,.' ,1,4,, € I' I" , Pu mp 41 bbls of tail Density Overflow (Ib /gal) Overflow Rate (gpm) t n ' € � � ,I�r � y- . PIr l l , { � l r ' , a ,! i, l , { I', „liy, :hl r, `' at4bpm @16:36, a. - s Fl p i �It i, 1 „fix Dens OF (Ibugal) Underflow Rate lgF ) e , l hl.' wI ,,. . I 1 " I i i tll ll ! i" , € ' ° # , 1 % ' ` 4' , N I'! , @ 16:36 drop plug yyyy P9;� I ',hyl�Iyj, g s,„a l�'I'' ' ' 9 �',' J i' I �I i I{ s ,,c e " _ ,, fir �= 1 and begin cit Hours (tire) Oil Under Fl (%) Dens FD (Ibtgal) I , ° ,I � I rI ft � , � r ' displace with 20.6 Ih' , , € illy N,f bbl starting at3bpr>1 ,Il i, Ot liv 2 t , y1ex ,Ali 1,i,jj and slowin to �t " •S I,, •. 1i! N II "4 tf4 ,'' {' �' ` lbpm afte pumping ' Description Co s ... Daily Cost Vendor , ; ,jy l' ! € ,�F j 17bbl. Plu bum Mud 2.0 t t " ( @ and floats' Engineer iE J, held. Potassium 194.0 3,158.32' V ," € tr € .'.. .1 y 3t a , ,t (' ''t/nf Chloride PAC L 6.0 950.40 1 7:00 1.00 Drlg y Planned ��Flat Surf C ase & ' I C mnt Casing No Trbl 2,101.0'r down cement CLAYS 1.0 793.13 Op Cmnt head DEXTRID 12.0 748.08, "18:00 2.00 Drlg Planned Flat Surf Case & Trip Out No Trbl 2,101.0' pull out of hole with LT Op Cmnt inner string WALL -NUT 28.0 736.40 20:00 1.00 Drlg Planned P Flat Surf Case & Wellhead No Trbl 2,101.0 Back out landing M O l Cmnt 1 ljoint PAC -R 3.0 463.95 Baroid 35.0 358.05 . i � p . '. Report Printed: 4/2/2007 str t e .r J , ,,. r' L; t ' sJ;U, 4" „ Mtn , , 6 . . .. i.u6l k ,CI �s= ...,.. -.. .. e.I N ,�u, Ih „ �,4 � �, . 4 FEX L.P. - DDR Detail 0 Page 2/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/31/2007, Report: 10.0, DFS: 4.47 0 - - ----- -- ---- Ground Elevation (k) Orig KB Elev (ft) - KB-Ground Distance (ft) Mud Additive Amounts 37.10 18.90 Description Cons... Daily Cost Vendor Time Log Ciric Acid 3.0 324.2 Start Dur ops Scheduled Depth E nd Baracor 700 2.0 289.42 ( ) Yp Phase Major Op Operation Trouble Trbl (ftKB) Comment - - - me hrs Cat T e Aldacide G 1.0 165.93 21:00 Ti 3.00 Drlg Planned Flat Surf BOP / BOP No 2,101.0 Nipple down Barascav D 2.0 127.54 Op W1-1•11 / diverter out Bicarbonate 4.0 110.96 of Soda Mud Checks: 2,101.0ftKB, 3/31/2007 12:00 �l ' pota ssium 1.0 59.69 Density (lb/gal) pH CEC f or Cuttings PE (mUmL) Calcium (mg /L) % Water 91.0 16.0 r (x) Mud Lost (Hole) (bbl) 10.00 0.100 Hydroxide `' u'i' l' "` 9.0 Vis (3/qt) Filtrate ( min) Filter Cake (132 ") Pm (mUmL) Potassium (mg /L) Percent 011 (%) Mud Lost (Surf) (bbl) EZ MUD DP 1.01 58.57 46 6.5 1 0 .550 160.0 MUD LAB 1.0 45. t s i m u iid . PV Over 10 0) Gel (110.000001... Sand (O 6 ) MST (Ib /bb10 Ume (lb/bbl) 011 Water Ratio Mud Vol (Act) (bbl) Last Casing Check' YP Over (lbf /1O... Gel (10m) (Ibf /100... Solids (%) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) Date Type 25. 17.000 6.3 2.7 1 Type Gel (30m) (Ib11100... TT 01) (°F) Chlorides (mg / _ ) HTHP Flit (m1./30... Alkalis (mUmL Whole Mud Add (bbl) ' aSt BOP Check'' ii' Potassium 20.000 33,999.998 0.000 Test Date Test T ype Salt Base silicate (x) Electric Stab (V) Comment Formations „ Cleane a ll Its Runnin centnfu a to cut mud wei ht to 9.3 in re aration for „ ry irk * I. = ample Top 9 mu tr eatment of CaCo3 and fluid loss chemicals. Formation Name „ D (ftKB) Base Permafrost 1,019.0 Mud Checks: 1.0ftKB 3/31/2007 19:00 Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) _Mud Lost (Hole) (bbl) I Group 1,020.0 9.50 8.6 0.070 91.0 Conductor Pipe, 98.8ftKB Vis (s /qt) Filtrate (mLl30min) Filter Cake (/32 ") Pm (mUmL) Potassium (m101.) Perc ent 011(x) Mud Lost (Suri) (bbl) Cs g Run Date OD (in) Grade Wt (Ibs /k) 51 6.8 2 _ 3/19/2007 16 j H -40 65.00 _ PV Over (cp) Gel (10s) (111f/1001... Sand (x) MBT (Ib/bbI) Lime (Iblbbl) 011 Water Redo Mud Vol (Act) (bbl) � u rf a c e Casing2,072.1 ftKf . 1 ,,, al' ,' 13.0 10.000 0 . 3 6.0 cs Run Date OD (in) Grade cwt Ps/k) YP Over (Ibfl10... Gel (1 Om) (Ibf /100... Solids (x) LGS (x) Polymer (ppm) LCM Mud Vol (Res) (bbl) 3/31/2007 9 5/8 L -80 40.00 24.000 25.000 6.3 6.5 ' ' :: `. :. 1111 il enfii; f ., r, 'N'i/ iI''I 0 'dn Type Gel (30m) (Ibf /100... T (fl) ( "F) Chlorides (mg /L) HTHP Flit (mL/30... AIkaIM (mUmL) Whole Mud Add (bbl) �, = Cm Des Commen Potassium 26.000 63.0 33,999.998 0.000 Surface Casi 1 , Salt Base Silicate (x) Electric Stab (V) Comment - _ ,',;' Drying Shaker Date 4 ' ` Description Make Model HG Dryer Derrick Shaker Screens Deck No. Screen No, Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 2 1 120.000 3 1 120 000 Shaker Checks Dens OF (1b/gal) Hrs (hrs) Description - - -- Make Model HG Dryer Derrick 1 Shaker Screens Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 . 1 120.000 3 1 120.000 Shaker Checks , Dens UF(Ib /gall .. e- " 'l r " ■ ' gr,u(� IIIC Description . - . -.. ........... Make ............... Model ' HG Dryer Derrick Shaker Screens 1 Deck No.' Screen N Scr Sz X (In) if 1 Scr Sz Y (in) _ . _; ) 120.000 2 1 120.000 3 1 120.000 Shaker Checks Dens OF (lb/gal) 1101: , tii i i ti. .r i frOp 'I ri ` t :.gyp q dill/ c, ..,,,, .'� ? , li Ili PAL'r' "` 1 n : - ,. n ,.,s.,. ,, 'I �fi��w1'itt . , x �,, 6 ., c. 8 --O------ F EX L.P. DDR Detail Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 3/31/2007, Report: 10.0,;DFS: 4.47 0 ', I Ground Elevation (ft) Orlg KB Elev (ft) KB- Ground Distance (ft) 18.20 37.10 18.90 Drill Strin s: Blt Run Make Blt Inventory Bit Type Item Cost 'ADC Bit Dull TFA (Inc] Noz) (in') BHA ROP (ft/hr) Nozzles (132") - IADC Codes I i BHA No. Cum Depth 04,1' ft) SPP (psi) Plow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) WOB (1000Ibf) Interval ROP (ftlhr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000lbf) Max. Over -Pull (lbf) I, Bit RPM (rpm) Motor RPM (rpm) 1Cum Drill Time (hrs) Off Bottom Torque Torque Units 30 HL (1000Ibf) ° H draulic Calculations IA AV DP (fflmin)'': 'AV DC (ft/min) —... .. _.... Err , z r N l4r, ;'„ III; I Drill Strin Corn onents i p -- Mtr it }Its a , r i ", >r° ri. Top Btrn Bend Item Density Drift Conn Sz Conn Sz Btm ` Angle Jts Description Len (ft) OD (in) (lbs/ft) Grade ID (in) (In) (In) Top Thrd (in) Thrd Cum Len (ft) (°) r! Wellbore Name Original VS Dlr ( °) �Klck Off Depth (ftKB) � Directional Surveys Hole 0.00 Date Description t 3/27/2007 MWD Surveys 6 i G Y { , j ' it If 1 Ir ,, I 4. :„br,,,li,,,, 4 . six ' ` virile ,T v % . ''''41:::' t i i� _• I �, ;� �' . � I �. ,..., . �:. 4 ' Ia. � w l' *Y , :... : ": Pa e1 /2 �� � FEX L P . - DDR D 'R' „ " p „���a 9 �„ I ,,, Ali Well Name: AKLAQ #6 t s „s a 6� , , rv< � 1,rat'!h3 6; i 6, , I , 6666,666666:16666: 1 1 i w { ' s `.= ° � _ � `' ob,Type: ` Drill - Or " ' Date: 4/1/200 Report 11.0 D 5.47 . . Jo b Spud Date Rig Release Date Ground Elevation (ft) 10rig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup , 3!27/200712:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 n I'� Target Depth (MB) Target Formation ' I ) � , >.;' f;I ,I I,. ,-K e ,`k° 4 x" ; I, t f �, e, p, I r .ra ej A Dally Cost Total Cum Cost To Date 213,552.79 7,478,446.05 l ` Daily Mud Cost Mud Cum To Date - Weat her Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( +l -) Var Days 5,328.29 82,480.05 cloudy 16 degrees Good Casing set at 2072 Operations @ 08:00 Depth Start (ftKB) Depth End (ftKB) Pick up drill pipe 2,101.0 2,101.0 Operations This Report Period - - Depth Progress (ft) Drilling Hours (hrs) i l Nipple up and pressure test BOP 0.00 Operations Next Report Period L , , • ' „ ` Pick up dell pipe, drill out and FIT _ =µ e »r -. Ernie Natte Cell , Drilling (519)427-7406 IR� 0 0.0 0 Foreman ', , I� ;dr T y1ta Phase Major Op Operation Trouble ( t 12.00 DrI Planned Flat Surf BOP / BOP No Trbl D 21 0', Nipple Comment down Rigs: Doyon, w .t ��l ll8 " • 9 Rig Supervisor Op WH / diverter some t Drillout trouble cleanning Bill Lupton, Rig Manager Alt up cement in Mud Pumps: 1, ardner -` , - 9 '�'r diverter, Nipple up No. Pwr (hp) Rod Diameter (in) FMC spool and test 1 900.0 to 1000psi for 10 Liner Size (in) Stroke (In) Vol /Stk OR (bbl /s.. ill min, Nipple up 6 9.02 0.070 BOP, Change pump Checks liners to 5 1/2 Strokes i ' Pres(psi) Slow Spd (spm) Eff(/) M , 12:00 4.00 Drlg Planned Flat Surf BOP / BOP No Trbl 2,101.0 Continue to nipple No Op WH / up, install kill line Mud Pumps: 2, Gardner - Denver, P s ° Drillout and choke line, No. Pwr (hp) Rod Diameter (in) function test BOP 2 900.0 Liner Size (In) Stroke (in) VollStk OR (bbl/s... 16:00 5.50 Drlg P !Flat Surf BOP / / BOP BOP/WH 2,101.0 Rig up test plug and 6 9.02 1 0.070 p fill stack, blind ram Drillout door leak, drain I Pum Checks hi i stack and replace strdkes seals test to 2500 ` 1=. spd (spm) Eft ( %) doors held No , a }ion . „.. , ;621:30 2.50 Drlg Planned Fiat Surf BOP / BOP a No Trbl 2,101.0 Test ROPE first test Make Mo i ;; „ OP WH / annular 250 psi low, 1 « E ; ( I CI, Drillout , , t ` "' 2 500 • psi high, #2 Shaker Screens ''''''''F , i ,, . z _ =' a,( * of .top rams TIW valve :. screen r.. ' '', , xr *r, manual valve Dec kNo. I No. I 'Sar$, ((� 1 ScrSzY(in) 1 rh iy r,a' ; ( : +' a , choke, ang kill 250 n" N t W b A y e* I( N ,, 4,ynb { yli ! }lT H, s a i�" r ; I ,„ i psi low 5000 psi, #3 Shaker Checks a � '' e �'''' 1 - '' ` ,j ', 'a # "1""'',,,,r,,,-;,-," S Top. rams D art Dens OF (lb/gal) Dens OF (lb/gal) Hrs (hrs) 1 6 4 q,� ''''''',4 6 % � , 5 g ,� b i t �f � r , ! _. .. a n INr ey a 1' y ,�` Y #. , ,, a "; va lve, HCR choke �" , . & kIII VaIVeS 250 "i� G �y �i ' +:�i `4° 4 .. ^t. . IOW 5000 drive high, Make Model ��`7 ��',� � * a #4 Top drive low i L . _, 1 6 rn { 66:66 r. , valve 250 low Centrifuge /Cyclone Checks a x = � , 5000psl high. ail Density overflow(Ih/gal) OverflowRate (gpm) „ +w � � test he y �'a t Id 10 min �,�, ; ( t� , §t t .ii „i c 1 r r ' ) i. . , a. ,,, [ Dens OF ( Underflow Rate (gprn) , z Lid Checks: 2,101.OftKB, 4/1/2007 18 :00 Hours (hrs) Oil Under Fl (%) Dens FD (Ib/gal) Density (lb/gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) 1% Water ( %) Mud Lost (Hole) (bbl) 9.30 8.8 0.100 140.000 94.5 tg O�s Via (s /qt) Filtrate (mtJ30min) Filter Cake (/32 ..) Pm (mL/mL) Potassium (mg /L) Percent Oil ( %) Mud Lost (Surf) (bbl) Descrlpt o ,(w;„t,,,'!' Cost Vendor 51 6.4 1 0.500 MUD LAB : 1 .0 45.00 . PV Over (cp) Gs 1(10s) (Ibf /100L. Sand ( %) MBT (Ib/bbI) Lime (Ib/bbl) 011 Water Ratio Mud Vol (Act) (bbl) I PA -R 1.0 154.65 ift 10.000 0.2 6.0 687.3 BA. DM 2.0 1,575.00 fli YP Over (1bf/10... Gel (10m) (Ibf /100... Solids (%) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) Tech Ik 23.000 2.9 1.1 I Service /L... Type 001 (30m) (Ibf 1100... T (fl) ( °F) Chlorides (mg/L) HTHP Flit (mL130... Alkalln (mUmL) Whole Mud Add (bbl) Polymer 25.000 54.0 31,000.000 'Barascav D 2.0 127.54 silicate ( %) Electric stab (V) Comment Baracor 700 6.0 868.26 i PAC -L 6.0 r u r f r', ;l/ t E". eying Shaker Data DEXTRID i 10.0 623.40 Description Make Model L T HG Dryer Derrick - Potassium 11.0 179.08 _ . Chloride , } 8 !! Report Printed: 4/2/2007 FEX L.P. - DDR Detail • Page 2/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/112007, Report: 11.0, DES: 5.47 0 Ground Elevation (ft) Orlg KB Elev (ft) KB- Ground Distance (ft} Mud Additive Amounts 18.20 I 37.10 1 18.90 Description Cons... Daily Cost Vendor Shaker Screens _ Baracarb 50 ` 20.0 376.40 , ck No.. Screen No Scr Sz X (In) Scr Sz Y (In). Baracarb 25 22.0 428.56 1 1 120.000 2 1 120.000 Last Casing Check 3 1 120.000 Date Type Shaker Checks Dens OF pb /gal) Hrs (hrs) Last BOP Check Test Date 1 U ) ' D Iri ® * fi g ,4 () i. r a t1 Description Make !Mod For mations __ itel HG Dryer Derrick Sample Ton Al G - -- Fo Name MD (ftKB) ) Shaker Screens Base Permafrost 1 1,019.01',1; 6 0- '':,.:2: , ; ® 86 O.rr `r � i`; ' 'r 1( "NO. - -.. .......... Scr Sz X(in� ._.... Scr SzV6n1 �,,,N,_':_.._._ Nanushuk Group 1,020.0 ! t �° 1 1 120.000 2 1 120.000 Conductor Pipe, 98.8ftKB Csg Run Date 'OD (in) Grade Wt (Ibslft) i 3 1 120.000 3/19/2007 16 H -40 65.00 � Shaker Checks Surface Casing, 2,072 . Elp Dens OF (Ib /gal) _ Hrs (hrs) ,;I eo" Csg Run Date OD (in) Grade Wt (Ibslft) 3/31/2007 9 5/8 L -80 1 40.00 Description Make Model , „,r HG Dryer Derric t � Cmnti r es ! Wes ,, Cer i nMen t Shaker Screens Deck No. Screen No. Scr Sz X (in) Sar Y „(in) „_. r I 1 1 120.000 2 1 120.000 3 1 120.000 Shaker Checks ;S u �) Dens OF fb/ al �; , e 7 ,,i411,r. 1„ ;Id .. .. til Fair . . Hrs (hrs) ,: °rill” fi : ;�4 ,5 t Bit it R Run Dull Make Bit Inventory �Blt Type 'Item Cost 0 tD TFA (Intl Noz) (In') BHA ROP fUlrr) 1Nozdes (132 ") 11ADG Codas BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) WOB (10001bf) Interval ROP (Whr) Total ROP (fUhr) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) Max. Over -Pull (lbf) `'' Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000lbf) Hydraulic Calculations AV DP (ft/min) AV DC (ft/min) - -- - Err -- ; 'ii! Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Still Angie Jts Description Len (ft) 'OD (in) (Ibslft) Grade ID (in) (In) (in) Top Thrd (in) Thrd Cum Len (ft) ( °) WGllbbres " "who 9r"�tos. Welibore Name VS Dir ( °) Kick Off Depth (ftKB) ; Original Hole 0.00 Directional Surveys Date Description 3/27/2007 MWD Surveys li s , , `i �.;f, '0'4111, rte .. f 5 , ,� X007' . . 'le '' d � s .a . � L� a 'sd. k, _ 1 1,.. 11 :: 1 ;1,4 , -110 FEX LP. - DDR Detail 1,-- - - Page 1/l Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/212007, Report: 12.0, DFS: , S Job Spud Date - - -- Rig Release Date Ground Elevation (ft) i Orig KB Elev (ft) 7KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12 45 .8.20 37 10 I 18.90 AF62034 22,574,244.00 22,574,244.00 . _ Safet il llpll i l 11°,1: ' I) T;` r¶ t I : Wpq Target Depth (ftKB) Target Formation r Type Date Comment i .4 : i il tt'06, . SafetyHighlighttj 4 /2/2007 WILD LIFE / REPORT ALL SIGHTINGS Daly Cost Total Cum Cost To Date W h 1 e : ' s- Leas e l Road Conditions weliboree 218,673.58 C, Cum To D to " O ( Dally M ud Cost Mud Cum To Date 1. Condition Over (+ /Under -AFE +/ -) Var Days 10,449.08 92,929.13 t it sun /clouds 20 degrees Good Casin set at 2072' Operations @ 06:00 _. - Oepth Start (ftKB) Depth End (ftKB) Loading sources and t i nto ho 2,101 A 2 101.0 Operations This Report Period - - -- - - - - -- Depth Progress (ft) Drilling Hours (hrs) Pick up drill pipe and BHA 0.00 Operations Next Report Period J , is 11+ Run in hole, FIT, Drill a a .€, : ar .. ., 7 Job Conte) `'! 9 519 ) - („ iii �..' 'g' ' 4114111111411111 " 4 " 0 . 41 011 11 111T Pi o ` i� ' : it t a 'it 7:77,, „ i3- ' t "V , .x " . a, i 6'� C a , nd Ernie Natte, Drilling t 427 -7406 ' ll:10l�8 $ heddeied 4 £ � w p Depth ' Foreman ' 3. y ,, a Major rO O p eration Trouble (ftKB Comment 00 :00 6.00 brig ;Planned Flat Surf BOP / BOP No Trbi 2,101.0 BOP test #4 Choke Rigs: Doyon, Arctic Wo Op WH/ valves 1,5,9,14 RlgSupervlsor L Bill Lupton, Rig Manager Drillout manual IBOP, 250 - low 5000 high 10 I I d ° , ,,L'. 1 1'1, Gardner- Denver, PZ 9 , min, Test #5 choke No. Pwr (hp) Rod Diameter (in) i ., valves 4,8,12,13, 1 900.0 Hydraulic IBOP 250 tuner size (In) Stroke (in) Vol/Stk OR (bbl /s r low, 5000psi high 5 1/2 9.02 0.066 +; 10 min, Test #6 pump Checks Top Rams Choke ; . 5. Valves 3 7 11 250 Pres (psi) Slo ',' = _ ,',,„g# , (%) , ` : low 5000high 10 No min, Test #7 bottom ud Pumps ) a ® ix�q;1 rf rams 250 low 5000 iNo. Pwr (hp) Rod Diameter (in) r i. high 10 min, Test 1 2 1 900.0 f #9 blind rams 250 Tuner size tin) Stroke (in) VoIIStk OR (bblls low 5000 high 10 1 5 1/2 9.0 0.066 h , , III min. Koomy test, pit allarm test, flow Pum Checks alarm test, gas S ( pme rn) alarm check. Pres (psi) Slow Eff(i) No s h akers: <De: : = k. ; .�_, . i liti Make Model 06:00 2.00 Drlg Planned Flat Surf BOP / BOP No Trbl 2,101.0 Blow down test Op WH / equipment and Shaker Screens I Drillout choke manifold, Screen „i i � � i Deck No. No• 1 Scr Sz X lin) i Scr Sz Y (in) , 1 08 :00 4.00 brig Planned Flat Surf BOP / Handle Tools No Trbl 2,101.0,Pick up pipe Op WH / - Shaker Checks 0 Drillout I Dens OF (Ibtgal) Dens UF (lb/gal) Hrs (hrs) 12:00 0.50' prig Planned Flat Surf BOP / Rig Repair / No Trbl 2,101.0 rig servieellube 1 ° 1 ' Op WH / Service � Drillout Make Model 12:301 6.50 Drig I Planned Flat Surf BOP / I Handle Tools No Trbl 2,101.0 Pick up and rabbit ,. Op WH / pipe 'Centrifuge /Cyclone Checks Drillout Density Overflow (1b/gal) Overflow Rate (gpm) 19:00 ' 1.75 Drig Planned Ffat "Burf ' BOP / Handle Tools No Trbl 2,101.0 Pressure test - Dens OF (Ib /gap Underfiow Rate (gpm) Op WH / casing 2600 psi Drillout held 10 ruin, blow Hours (hrs) Oil Under Fl ( %) Dens FD (lb/gal) down 20:45 1.251 Drlg ', Planned Flat Surf BOP / Handle Tools No Trbl 2,101.0 Pull out of hole Mud Ad % � \t ' i`n . i lj l, �31�1 o,I�' Op WH / Description Cons... Daily Cost V end o r MUD LAB 1.0 45.00 Drillout �� 22:00 2.00 Drig Planned Flat Surf BOP / Handle Tools No Trbl 2,101.0 Pick up BHA and IfOl EZ MUD DP 1.0 58.57 : Op WH / set motor to 1.22 CLAYSEAL 1 1.01 793.13 Drillout bend A(dacide G 2.0 331.86 h E 'iy Potassium 2.0 119.38 Pr , g. Hydroxide hh, 5 'BA. DM 2.0 1,575.00 Tech - Service /L... II Barascav D 2.0 127.54 c pp PAC -R 2.0 309.30 .` ' t Baracor 7001 2.01 289.42 -- - ,,..3.1.4 ,'p 9 � ` " �� • .- FEX L.P. - DDR Detail Pag� Well Name: AKLAQ #6 R� Job Type: Drilling - Original Date: 4/2/2007, Report: 12.0, DFS: § d r 0 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Mud Additive Amounts ' ' 18 20 37.10 18.90 Description Cons... Dally Cost Vendor A Mud Checks: 2,101.0ftKB, 4/2/2007 10 :00, PAC -L 2.0 316.80 Density (lb/gal) pH 'CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) LBarazan D+ 6.0 952.26 9.60 9.0 0.150 120.000 93.0 WALL -NUT ': 10.0 258.00 Vis (s /qt) Filtrate (mU30min) Filter Cake (/32 ") Pm (mUmL) Potassium (mg/L) Percent OII ( %) Mud Lost (Surf) (bbl) , F C _ 55 6.2 1 0.600 PV Over (cp) Gol (108) (lbf /100f... Sand (%) MBT (1b/bbl) Lime (IWbbl) 011 Water Ratio Mud Vol (Act) (bbl) L T XTf 20.0 G r 246.80 9.000 6.0 YP Over (Ibf /1o... Gel (10m) (Ibf /100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Baracarb 50 35.0 658.70 16.000 4.0 1.4 I Baroid 100.0 1,023.00 Type Gel (30m) (1b0100... T (fl) ('F) Chlorides (mg/L) HTHP Flit (mL/30... Alkalin (mUmL) Whole Mud Add (bbl) Potassium 144.0 2,344.32; Polymer 17.000 37,000.001 Chloride Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas (%) Avg Conn Gas ( %) Max Trip Gas (%) Avg Trip Gas (%) Silicate % Electric Stab Comment IIIIIIIIIIIIIIIIIIIIIIIIIII D � (1b/gal) pH t /2 O CEC for Cuttings gs Pf (mUmL) Calcium (mg/L) % Water ( %) • Mud Lost (Hole) (bbl) a5 - ° i. . i ., ; , es 1. : 9.60 9.0 0.000 440.000 93.0 1 Vis (s /qt) Filtrate (mL/30m1n) Filter Cake (/32 ") Pm (mUmL) Potassium (mg /L) Percent 011 (%) Mud Lost (Surf) (bbl) Formations 55 6.3 1 m Sample Top PV Over (cp) Gel (108) (Ibf/100f... Sand ( %) MBT (Ib/bbl) Limo (Ib /bbl) 011 Water Ratio Mud Vol (Act) (bbl) Formation Na a MD (ftKB) 9.000 6.3 818.0 Base Permafrost 1,019.0 YP Over (Ibf/10... Gel (10m) (Ibf100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Rs$) (bbl) Nan US huk Grou ( 1,020.0 21.000 3.6 0.9 dnductor' Qipe, 98.8ftiiii 'r'1IllAik, Type Gel (30m) (1bf1100... T (fl) (°F) Chlorides (mg/L) HTHP Flit (mU30... Alkalin (mUmL) Whole Mud Add (bbl) I Run Date OD (In) Grade Wt (Ibs /ft) Polymer 28.000 42,000.000 13 Max Back Gas ( %) Avg Back Gas (%) Max Conn Gas ( %) Avg Conn Gas (%) Max Trip as (%) Avg Trip Gas % 3/19/2007 16 H -40 65.00 P ( ) 9 P ( ) casing, 2,072 iii ,P"' Silicate (%) Electric Stab (V) Comment -- Csg Run Date OD (In) Grade Wt (Ibs /ft) 3/31/2007 9 5/8 L -80 40.00 1 '' ��j1 �� a d i. "ii . +.. 6 ,4 t1 , , its"`,i,.:,, a � j 3 ° I III � I c, t .. , �•, �. u m w - Comment Description Make Mo �- -- .- _. - `�°" C ill HG Dryer Derrick , j Shaker Screens Deck No, Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 2 1 120.000 3 1 120.000 I Shaker Checks Dens OF (lb/gal) Hrs (hrs) -I Description Make !Model HG Dryer Derrick `j' Shaker Screens Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) a , 1 1 120.000 b 2 1 120.000 s �' 3 1 120.000 r to Shaker Checks Dens OF (lb/gal) - Hrs (hrs) Description Make Model HG Dryer Derrick 1 Shaker Screens s ck No. Screen No. Scr Sz X (in) Scr Sz Y (in) a 1 1 120.000 s. 2 1 120.000 Flu, 3 1 120.000 I a Shaker Checks ti "a Dens OF (lb/gal) Hrs (hrs) , '. ' Drill Strings: � li' � ''; s �� Bit Run Make Bit inventory Blt T hem Cost IADC Bit Dull [TFA ( Intl Noz) (in) JBHA ROP (ft/hr) 'Nozzles (/32) I IADC Codes 1 411 , R � �� '' 1� " , Report Printed 4 007 V I � : :7 psda y : ' ) �,� w'.,,m '41, 11/1 . .�r6: a . .w, i.iogidii n ' : - gibil ut aaw, u .,). s.� i (6�IC�!NI �aI IIgiga .als,w.. !un u�,m6„,,a . ' r u a_, ,, m. _ a a iuu i n ,-, a° r 4 I I , - - - - FEX L.P. - DDR Detail 4 11 Il# gtlill Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/2/2007, Report: 12.0, DFS: 6.47 0 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) � J 18.20 3710 18.90 BHA No. Cum Depth (ft) SPP (psi) Flow R ate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (ibf) WOB (10001bt) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over -Pull (Ibf) Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HI. (1000Ibf) Hydraulic Calculations AV DP (ftlmfn) AV DC (ft/min) Drill String Components Mtr Top Btm Bend Rem.' Density Drift Conn Sz ConnSz Btm Angle Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) r) lii v 4 Wellbore Name VS DIr (°) Kick Off Depth (ftKB) 1 ',,; Original Hole 316.00 Directional Surveys +` Date Description 3/27/2007 MWD Surveys ' S 't Ilill. } WI vi ra ' I A Ip o,,, L F i I � 4 .4 1f °" 11lr t, �� t `y 'rinted� 4 t; I fiii i . . � it$sb's '," ., _ .... .a a „,�. �..... , . .. �i,� i� �w iah G. x"'oJ ._ '�: �.. - F . �z� 41° FEX L.P. - DDR Detail 4111)- ----- - Page 1/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/3/2007, Report: 13.0, DFS: 7.47 ID Job Spud Date Rig Release Date Ground Elevation (ft) prig KB EIev (ft) KB Ground Distance (ft) AFE No. 7 Total AFE Amount Total AFE +Sup 3/27/200712:45 _ 18.20 37.10 18.90 AF62034 22,574,244.00 22,574244.00 Safety Target Depth (ftKB) Target Formation Type Date Comment Safety Highlight1413 /2007 1FALL PROTECTION ON AND OFF THE RIG Daily Cost Total Cum Cost To Date - � 219,642.18 7,916,761.81 Dili I U U ° ' $ ' . Dail Mud C Mud Cum To Date Weather Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( + / -) Var Days sun /cloud -5 deg Good Casing set at 2072' i 11,417.68 104,346.81 Operations fa 06:00 Depth Start (ttKB) Depth End (ftKB) - Drill ahead directionaly at 2800' 1 2,101.0 2,101.0 -- --- - -- "' ' - - De 1 p th Progress ( ress ft Drilling rs Operations This Report Period 0.00 (ft) g Hours (hrs) Drill out shoe, FIT, drill 8.5" hole Operations Next Report Period - -- . -_ Drill ahead directionaly Job Contact Cell Phone Time Log ', d , I' - r ' ;' j Ernie Natte, Drilling (519) 427 -7406 Start Dar is Schedul s ... ; : "a „. t. ., r �, .. ,. fi ... Depth End Foreman Time (hrs) Cat Type ` ° [ MN. • •eragon Trouble (ftKB) Comment 00:00 7.50 Drlg Planned ( Flat Surf 1Drilling Handle Tools No Trbl 2,101.0 MAKE UP MWD Rigs: Dgyon, Arctic Wolf Op BHA / LOAD Rig Supervisor TOOLS & TEST Bill Lupton Rig Manager Mud Pumps ,a1i ®enver, PZ -9 07:30 0.50 Drlg Planned Flat Surf Drilling Rig Repair / No Trbl 2,101.0 SERVICE RIG & No. Pwr(hp) Rod Diameter (in) Op Service TOP DRIVE 1 900.0 08:00 1.00 Drlg Planned Flat Surf Drilling Trip In No Trbl 2,101.0 RUN IN HOLE Liner Size (In) Stroke(in) Vol/StkOR(bblls... Op L 51/2 9.02 0.066 1 09:00 3.00 Drlg Planned Flat Surf BOP / Drill - Cmnt No Trbl 2,101.0 DRILL OUT 7" Pump Checks g FLOAT, CMT & strokes Op Dritout SHOE Pres (psi) Slow Spd (spm) Eff ( %) 12:00 0.50 Drlg Planned Flat Surf Drilling Drill - Motor No Trbl 2,102.0 DRILL OUT TO No L Op Vert 2102' Mudi�, °,:Gardner - Denver, PZ -9 12:30 1.00 DrIg Planned Flat Surf Drilling OT No Trbl 2,102.0 PERFORM F.I.T. NO. Pw r (hp) Rod Diameter (in) 9 Op 9 700PSI SURFACE 2 900.0 ' ' HELD 10 MIN unerSize / 2n) Stroke 9.02 VoVSt0.066 1/s Op Drill -Motor Dir No Trbl 2,602.0 DRILL AHEAD Drlg Flat Surf Drilling ! IDIRECTIONALY Pum Checks 13:30 10.50 Drl Planned Strokes TO 2602 Pres (psi) Slow Spd (spm) Eff ( %) M. . -1 . ,• - ' ,. " ., 13/20045 c h ex �l ll , x : NO (ib /gal) pH CEC for 7 Cuttings 13 : pt (mL/mL calcium viva.) /. Water ( %) Mud Lost (Hole I1 (bbl) ? � " ' 9> Density ) ) 5 : 9.55 9.2 0.120 520.000 93.0 Make (Model Vis (s /qt) Filtrate (mU30min) Filter Cake (/32") Pm (mUmL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbl) Shaker Screens I 52 6.8 1 0.100 37,000.001 PV Over (cp) Gel (10s) (Ibf1100f... Sand ( %) MBT (Ib/bbl) Lime (Ib/bbi) 011 Water Ratio Mud Vol (Act) (bbl) i ;!. 7.000 0.0 6.5 IN: , ' , , ;Scr Sz x (In) . Scr Sz Y (in) YP Over (Ibf /10... Gel (10m) (Ibf1100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) L 18.000 4.2 2.0 Shaker Checks Type Gel (30m) (lbf/100... T (fl) (°F) Chlorides (mg/L) HTHP Alt (mU30... Alkslin (mL/mL) Whole Mud Add (bbi) Lpens OF (11a/gal) Dens OF (lb/gal) Hrs (hrs) Polymer 24.000 33,999.998 Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas ( %) Avg Trip Gas (A) ^, r VAN - - Make 1 re Model i Silicate (%) Electric Stab (V) Comment iii l[ r .., Centrifuge /Cyclone Checks 441 ° i e a 1 *00 I I , Density Overflow (Ib/gai) Overflow Rate (gpm) Density (Ib/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) 9.60 9.4 0.150 520.000 93.0 Dens OF (Ib /gal) Undorflow Rate (gpm) ' Vis (s /qt) Filtrate (mL/3OmIn) Filter Cake (132 ") Pm (mUmL) Potassium (mg1L) Percent Oil (%) Mud Lost (Surf) (bbl) 49 6.6 1 0.100 35,000.000 135 ( .0 _ Hours (hrs) Oil Under FA ( %) Dens FD (1b/gait PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MBT (1b/bbl) Lime (lb/bbi) Oil Water Ratio Mud Vol (Act) (bbl) 1 01 7.000 0.0 6.3 851.0 d- YP Over (Ibf /10... Gel (10m) (Ibf /100... Solids (%) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl ,. , ..� : r i Amoytnt e. n 18.000 4.0 1.4 ',MUD � Mptlon Co ns... Dally Cost Vendor lik Type Gel (30m) (ibf/100... T (11)1°F) g... LAB 1.0 45.00 ( ) (F �) Chlorides (m/L) HTHP Alt mL/30 Alkalin mL/mL) Whole Mud Add (bbl) ( ( ) 1 d =T 1.0 4 33.80 . ' Max Back Gas %) Avg Back Gas (%) Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) Polymer 24.000 37,000.001 ( g Bicarbonate ' 1.0 27.74 of Soda Silicate (%) Electric Stab (V) Comment Barasd r6am 1.0 109.85 HP ..._ F -. :, x'`)' a 11aat�o�a::z �.. Potassium 2.0 119.3$ ill Description Make Model Hydroxide 1 HG Dryer Derrick BA. DM 2.0 1,575.00 Shaker Screens Tech Deck No. : Screen No. Scr Sz X (in) Scr Sz Y (in) Service /L... 11 1 120.000 PAC -R 1 2.01 309.30 11 i " '• Report Printed' 4/4/2007 w�,"'r >' , ,... i, .�i�lIii ,I , , A�t,�� : a,11„, „ . ;,IIII4yr11,„„ . ,. ._„,,h4.4 uNJ.„1. II,4 !. ir k . �4aa,`L'. . �4 S:�k �' - �dAII Ii ^„, 4 - - - - - -- - - - - -- ---- - - - - -- FEX L.P. - DDR Detail Page 2/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/312007,, Report: 13 DFS: 7.47 Ground Elevation (ft) OrIg KB Elev (ft) KB- Ground Distance (ft) 1111 u Additive Amounts 18.20 37.10 18.90 Description Cons... Daily Cost Vendor Shaker Screens Baracor 700 2.0 289.42 Deck No. Screen No. Scr Sz X (In) Scr Sz Y (in) PAC - 2.0 316.80 2 1 120.000 CLAYSEAL 2.01 1,586.26 3 1 120.000 Ciric Acid 4.0 432.32 Shaker Checks EZ MUD DP 6.01 351.42 hens uF (Ibtgap Hrs (hrs) 77777:' DEXTRID 6.0 374.04 Dryini 1,,,,$ ' a llyll��l��l!,i F m. ._..... - ' 7 4463 LT ^' A „ �,..,,e.,�..., „�. Barascav D .01 446.39 Description Make Model HG Dryer Derrick Barazan D+ 12.0 1,904.52 ,: ,,x, Shaker Screens Chl Deck No. Screen No. Scr Sz X (in) Scr Sz Y (i n) 1 Potassium 43.0 700.04 1 1 120.000 1Baracarb 25 60.0 1,168.80 2 1 120.000 Baroid ;120.0 1,227.60 3 1 120.000 . ..., Shaker Checks Date ' Type Dens OF (Ib /gal)' _ :" u• . �, . a. _." k§ci +>5�i:a.: ," Description - -- Make Model r " itStl � HG Dryer Derrick Shaker Screens ( Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) " Formations Top 1 2 1 120.000 Base Permafrost Name SMO 1 k 019.0 1 1 120.000 3 1 120.000 Nanushuk Group 1,020.0 Shaker Checks i _r , ,, , ° r • pe, 98.8ftKB Dens OF(Ib /gap „�.(,, t�-a ,,t Hrs(h'is)i .1 i ' Csg Run Date 'OD (in) Grade 'WI (Ibs /ft) 3/19/2007 , 16 H -40 65.00 Drill Strings: , _ Id���,... ; - , .i & Ita , i; ) ,:: 4..?a a� a.a ,.' ).; t : :, ; ing, 2 ftKB Bit Run 'Make Bit Inventory Bit Type Item Cost Csg Run Date OD (in) Grade Wt (Ibslft) i p, IADC Bit Dull TFA (loci Noz) (In) BHA ROP (ftlhr) Nozzles (132") IADC Codes 3/31/2007 9 518 L-80 40.00 , , r3! I . '.na , BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference 'Rot HL (10001... Max. Hook Load (Ibf) -- ------- i WOB (1000Ibf) Interval ROP (fllhr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) Max. Over -Pull (Ibf) 1 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (10001bf) Hydraulic Calculations _ AV DP (ft/min) AV DC (ft /min) :':. a 4`d : i t�4 .t a+!' -? - rid as 5_ .h :. 4 -' . .')1 z `.,..k A 1 Drill Strin Com . onents Item 'Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (in) (ibslft) Grade ID (in) (in) (in) Top Thrd . (in) Thrd Cum Len )ft) (') L� Welibores Al- Wel /bore Name VS Dlr ( °) Ki Off Depth (ftKB) Original Hole 316.00 Directional Surveys Date Description 3/27/2007 MWD Surveys Survey Data MD (ftKB) Inc/ ( °) Azm (°) " TVD (ftKB) NS (ft) EW (ft) VS (ft) DLS (°I100ft) Survey Company 2,130.87 12.66 264.25 2,121.80; -35.69 - 113.121 52.91 1.01 IHALLIBURTON 2,195.00 12.69 263.76 2,184.37 -37.16 - 127.12 61.57 0.17 HALLIBURTON 2,250.331 12.061 265.201 2,238.41 - 38.301 - 138.92 68.95 1.271HALLIBURTON 2,319.81 10.61 266.70 2,306.53 -39.28 -152.54 77.71 2.13 HALLIBURTON 2,373.88 9.90 269.00. 2,359.74 - 39.64 - 162.15 84.12 1.52 HALLIBURTON , 2,443.24 - 8.24 274.53 2,428.23 -39.36 -173.07 91.92 2.70 HALLIBURTON 2,506.30 6.93 284.611 2,490.741 -38.04 - 181.261 98.55 2.951HALLIBURTON 2,568.99 5.87 299.81 2,553.04 -35.49 - 187.70 104.86 3.17 HALLIBURTON 2,630.441 4.38 332.78 2,614.26 31.84 -191.50 110.12 5.27 HALLIBURTON 2,693.21 4.19 10.45 2,676.87 - 27.45 -192.18 113.75 4.41 HALLIBURTON 2,755.86 3.63 40.67 2,739.38 -23.70 - 190.47 115.27 3.36 HALLIBURTON i 2,818.14 3.20 81.21 2,801.56 -21.94 - 187.47 114.45 3.85 HALLIBURTON i Report Printed: 4 /4/2007 Jis.`„' . ,. i4 3 ,,.-,., _.,, d1) s4,adVa, _.,,,..is.olgilii11'',:, . e,1 ora.airdai, N , amk.w.ra,.. t40l11,1e 'Jadi ____------- - 4 FEX L.P. - DDR Detail Page 1/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/4/2007, Report: 14.0, DFS: 8.47 III Job Spud Date Rig Release Date Ground Elevation (ft) 0rig KB Elev (ft) KB- Ground Distance (ft) AFE No. 7 Total AFE Amount Total AFE +Sup 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 i Safety Target Depth 011(13) Target r ype Date Comment 7,262.0 Safety Highlight 4/4/2007 SPILL REPORTING & PPE Daly Coat Total cum cost To Date 254,940.33 8,502,879.99 Weather '' Summa i Over Daily Mud Cost Mud Cum To Date Wea Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE (N -) Var pays 1 15,158.08 119,504.89 „ sun /cloud -10 deg Good Casing set at 2072' 0 - - ----- Depth Start (ftKB) Depth End ( Operations 2,602.0 3,662.0 Short trip operations This Report Period -- - - -` -- -- rib ' Depth Progress (ft) Drilling H ours (hrs) Drill ahead directionaly 1 06 00 23.50 r ' Operations Next Report Period i drill target sands . tl ' ICRntact yal, Ceti ' ii I„ ;, 4;Con �itPhone ' g t : - . ' �S �'�'c kw .. � , "'"fs 4 ,, , � '�r 't'y� Ernie : Natte, Drlllln 907 771 -0536 1 (r) �� � . „ a:" Major p Depth Foreman rt ur taps Scheduled De grid w Time hra Cat T i i � r, Ma or O Operati Trouble (ftKB) Cbmmerit -- ■ g g Drilling DIRECTIONAL Rig D Arctic Wolf 00:00 8.00 Drl Planned ' DrIg Prod Drillin Drill - Motor Dir No Trbl 2,911.0 Rlg S upe rvi sor Op DRILL 8 1/2" HOLE Bob Lupton, Rig Manager 1 / SLIDE 206' / Mud Pu F/ 2602' - 2911' KB ..... m ps 113 . : / enver, PZ -9 ® ROTATE 101' No. Pwr (hp) Rod Fo Diameter mation (In) 1 900.0 , 08:00 0.5 'Drlg Planned Drlg Prod Drilling Rig Repair/ No Trbl 2,911.0 SERVICE RIG & Liner Size (In) stroke (In) 1.VoUStcOR(bbus . Op Service TOP DRIVE 5 1/2 9 02 I 0.066 08:30 3.50 Drlg Planned Drlg Prod 'Drilling 1 Drill - Motor Dir No Trbl 3,038.0 DIRECTIONAL I pump Checks Op DRILL 8 1/2" HOLE , Sirekes I F/ 2911' to 3038 / t Pres (psi) Slow Spd (spur) Eff (A, slide 80' 245.0 Yes 55 95 12:00 12.00 Drlg Planned DrIg Prod Drilling Drill Motor Dir No Trbl 3,662.0 DIRECTIONAL 00 0 No 55 95 Op DRILL 8 1/2 " N m , ' � i i :� ' � wr ' I � ; enver, PZ-9 HOLE FI 3038' TO N o. P (hp) Rod Diameter (in) 3662/ SLIDE 348/ 2 900.0 e IMud Lost Liner Size (In) Stroke (In) YoUStk OR (bbl /s... .../..." 0 Mud Checks: 2 930 .0ftKB 4/4/2007 23 :30 , 5 1/2 9.02 0.066 Density (lb/gal) pH CEC for Cuttings Pf (mUmL Calcium (mg /L) % Water ( %) (Hole) (bbl) 9.60 8.5 0.050 520.000 92.0 I Pum . Checks Vis (s /qt) Filtrate (ml/3omin) Filter Cake p32 " ") Pm (mUmL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) ( bbl) , 51 5.5 1 37,999.999 245.0 Yes r 55 95 il PV Over (cp) Gel (tOs) (Ibf /1001... Sand (%) MBT (Ib/bbI) Lime (IWbbl) 011 Water Ratio Mud Vol (Act) (bbl) t t f M ° 1 „ r 7.000 0.0 6.5 �, t i i� ' YP Over (Ibf /10... Gel (10m) (Ibfl100... Solids (%) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) `e �D ,� 17.000 5.1 3.5 Make Model )Typo Gel (30m) (Ibf /100... T (fl) ( °F) Chlorides (mg/L) HTHP FM (m1J30... Alkalin (mLlmL) Whole Mud Add (bbl) � Polymer 24.000 35,999.999 Shaker Screens K Max Back Gas (%) Avg Back Gas ( %) I Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) Screen , ° � . t Deck No No. Scr Sz X (in) 1 Scr Sz Y (in) ',Silicate (%) Electric Stab (V) Comment _ ...i..... Shaker Checks Mud Checks: 3,473.OftKB, 4/4/4/ 2007 23:30 "''`" Dens OF (lb/gal) Dens OF (Iblgal) Hrs (hrs) 2 Density (lb/gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) % Water (%) Mud Lost (Hole) (bbl) 1 pi 9.60 9.0 0.150 420.000 91.0 40.0 1,i111� {I ti) Vis (s /qt) Filtrate (mLl30min) Filter Cake (132 ") Pm (mUmL) Potassium (mg/L) Percent al (%) Mud Lost (Burl) (bbl) Make Model " 56 4.6 1 35,000.000 220.0 � PV Over (cp) Gel (1os) (IbO10oL.. Sand ( %) MBT (Ib/bbl) Lime (Ib/bbl) 011 Water Ratio Mud Vol (Aet) (bbl) Centrifu s e/C clone Checks ' r 7.00 0.0 7.0 _ 863.0 Density Overflow (lb/gal) Overflow Rate Ram) YP Over (Ibf /10... Gel (1Om) (Ibf/100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) _ 18.000 6.2 5.6 Dens OF (Iblgal) Underfltwr Rate (gpm) r Type Gel (30m) (Ibf / 100... T (fl) (°F) Chlorides (mg /L) HTHP Filt (mU30... Alkalin (mUmL) Whole Mud Add (bbl) ' Polymer 26.000 35,000.000 Hours (hrs) 011 Under FI (%) Dens FD (Iblgal) - ~a ll Max Back Gas ( %) Avg Back Gas (%) Max Conn Gas ( %) Avg Conn Gas (Y. Max Trip Gas ( %) Avg Trip Gas ( %) 1 . x Silicate ( %) Electric Stab (V) Comment MUD LAB I 1.01 45.0 De r1 C ', ® ' I ost ' a 0 1 Drying l bNi., ,rllrwa!Ixi:)4 CON DET 1.0 433.80 /s Description Make Model ' Baradefoam : 1.0 109.85 HG Dryer Derrick HP Shaker Screens Deck No. Screen No. ScrSzX (in) ScrSz (In) CLAYSEAL 1.0 793.13 ServDCe /L... 2.0 1,575.00 1 1 120.000 Tech 2 1 120.000 3 1 120.000 Bicarbonate 4.0 110.96 of Soda wl " I ■' k Report Pr1nt� x5/3/2007 f " *m r ii II x / rI a iI I r) . ..: . , : , �i .,�"s�• � ��,�h..4. U..�� a,...,ti,:��IH�,..'�..! �- �ii i�Vl:iuIl�f�oNi�. , 161 I�IIr, - FEX L.P. - DDR Deta Page 2/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/4/2007 Report: 14.0, DFS: 8.47 0 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) lytkiFLAddjtive Amounts 18.20 1 37.10 18.90 .,r,,, :0Ift,rt Cons... Daily Cost vendor 1 Shaker Checks 'Barascav D . 5.01 318.85 Dens OF (Ib/gai) Hrs (hrs) DEXTRID 5.0 311.70 T ` °' frig S hake', Barazan D+ 7.01 1,110.97 Description Make Model Baracor 700 7.0 1,012.97 `i" HG Dryer Derrick Potassium 1 10.0 596.90 Shaker Screens '= Deck No Screen No Scr Sz X (in) Scr Sz Y (in) Hydroxide 111 1 1 120.000 WALL -NUT 10.0 258.00 2 1 120.000 F 3 1 120.000 PAC -L 22.0' 3,484.80 Shaker Checks Shaker MUD DP 27.0 1,581.39 <; a rm 1(1 14',;. Den OF ( lb/ gall H rs (hr Barofibre 28.0 704.481 Potassium 51.0 830.28 Description Make Model Chloride HG Dryer Derrick Baroid 60.0 613.80 rir Shaker Screens Baracarb'25 65.0 1,266.20 It •' , .j r ` Screen No. Ser Sz X (in) .., ...- Scr Sz Y (in) '' II I II�I� ! t 1,1 IIrI i''1' 1'�'I II Ii Ii j'ija 1 1 120.000 1 Last Casing C � iS1 � �Ir444illh� it II ,1 I , 2 1 120.000 Date Type 3 1 120.000 Shaker Checks Lash' 64P check Dens UF�IbI I) - Hrs (hrs) Test D a t e Test Type 1 Drill Strings: BHA #2, Steerable 7 1hi 141 Formations Bit Run Make Bit Inventory Bit Type item Cost Sample Top 2 'Hughes 8 1l2in, HCM605Z, 7106613 PDC 22,833.00 Formation Name MD (ftKB) , IIADC Bit Dull TFA (Inc' Noz) (in) 'BHA ROP (ft/hr) Nozzles (/32 ") IADC Codes NanushUk Group 912.0 14/14/13/14/13 M-3-2-3 Base Permafrost 1,020.0 0 1 NO A X -0 NO CP 0.71 35.8 i ��. ! I' �i I - la 0 ny 1 t I) ( I' f 3^ III ,;, [,, i :FAR (I '� 1v -__ 0 r T , .`.'r11!1IIiII:1 'r} 11 �I) `` 'c,1,1i!i,1 ��,a14110i1 ;11aai' -; ° a "i '!1��11,, qo �, 1, q� F Nanushuk topset sst. 2,795.0 i'i'i /� „ '� " ( I�H�I.i6� � qI, IIwF!�i � � I BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TF Reference Rot HL (10001... Max. Hook Load (Ibf) Nanushuk topset sst. 3,388.0 1 2 1,561.00 1,900.0 560 135 152 Torok 3,470.0 1' WOB (10001b9 Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) M ax Over -Pull (Ibf) Torok sand 1 4,734.0 i r I' 10 45.1 45.9 23.50 4,000.0 152 12,000 0 Torok sand 2 4,852.0' Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000Ibf) P Torok sand 3 5,090.0 _ 290 200 34.00 1,500k Fttbs 125 1 l'''' k - - Torok sand 4 5,630.0 ' 'I `'I Hydraulic Calculations AV DP (wm'n) ' AV DC (ft/m'n) Err Torok sand 5 5,798.0 Torok sand 6 6,008.0 i A casing component contains a null value in ID Torok sand 7 6,313.0 Drill String Components Mt`r Torok sand 8 6,568.0 Top Btm Bend HRZ 6,605.0 Item Density Drift Conn Sz Conn Sz Btm Angie K aruk Sandstone Mbr 6,800.0 �.I Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (') • 208 Drill Pipe 2,868....1 4 14.00 X95 3.3401 4 FH 4 FH 3,662.30 LCU (lower Cret. 6,880.0 8 HWDP 248.59 4 27.20 2.750 4 FH 4 FH 793.99 Unconformity) 1 Drilling 36.02 4 2.000 4 FH 4 FH 545.40 BCU (Base Cret. 6,880 0 Jars Unconformity) f Hydraulic Upper Kingak (Miluveach) 6,880 0 ''. 10 HWDP 311.40 4 27.20 2.750 4 FH 4 FH 509.38 Kugrua siltstone 7,066.0 11X0 Sub 2.021 6.28 2.5001 4 FH 4 1/2 IF 197.98 Kugrua sandstone 7,120.0 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 Kugrua ironstone D.C. Kingak Fm pp�� 1 NM FLEX 31.08 6 3/4 2.880 4 1/2�IF 4 1/2 IF 165.13 Cpt�` I ��!�iP�1��•� rLtr"t'i�Bi��Pi'�i1'� D.C. Csg Run Date r13 (in) Grade Wt (Ws/ft) it , II 1 $t?bt�l�z , !'r ' ir`8 3/4 2.810 41/2 IF 41/2 IF 134.05 3/19/2007 16 �, H40 11NN 6500 .._ j .�'?ltli i U? D II te $ , • D (I y ) '' Gra WI (Ibs /ft) B1 �I �:! �, mr ', 99 g) IF 128.59 Csg Run a Onde 1 & Lo Dir 22.42 6.71 4.6301 4 1/2 IF 4 1/2 3/31/2007 9 5/8 L -80 40.00 '1 BAT i ICeme'rt' 'der r /11ir; 1 MWD (Dir 9 $9 6.76 4.880 4 1/2 IF 4 1/2 IF 106.17 GmntD la ment - 1 � 1 & Logg in g ) 9 ATM '4'� i I *A011,1' i k, A ''^ uiMi,M , 4 '' ' '4 " + � - . 4, s I h.' N -- 2 ,' : M • N 7r j ' a i � •„ - -. - 1 MWD (Dir 9.21 6.79 4.560 4 1/2 IF 4 1/2 IF 96.28 Iii! & L zit, 1 MWD (Dir 30.20 6.73 4.630 4 1/2 IF 4 1/2 IF 87.07 �� & Log "S �� �rl'NUKE , 141,11 -I1444,4„..4-4"..4., x°? -1:414'444,::::: { t. "..*,1.', ' H • r t 4' „ ort Pri 1 d: 5/312007 4 1 I) ty,I /'11 1.1 -:1 N Re . ,Ia� N lrt fNlh 1; .1� _____4) FEX L.P. - DDR Detail Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/4/2007, Report: 14 0, INS: 8 47,t III _ ___. ____. 7 _. ..,E Ii "'; t .I„„ ; .„ „ : „„ s. "�:,, � h I „II ,, w N., 1,Ih1; I�hdd „ I' ir 11111 Ground - Elevation (ft) Orig K Elev (ft) KB- Ground Distance (ft) - im 18.20 37.10 18.90 Drill String Components , 1;, Mtr� --- - - - - -- Top Btm Bend ��� Item Density Drift Conn Sz Conn Sz Btm Angle i „$ 1 MWD do 28.14 OD 7 ID(in) (in) (in) Top (in) Thrd Cum Len(ft) (°) Jts Description Len (ft) OD i n (Ibslft) Grade ' , ,4.630 ; 41/2 IF 41/2 IF 56.87 , ,u & Logging) ,Lo. 99 9) FE i s 1 Float Sub 2.50 6.8 2.750 4 1/2 IF 4 1/2 IF 28.73 1IMud Motor 25.23 7 1.500 4 1/2 IF 4 1/2 IF 26.23 1.221 �.,�" ` )` C I We)i�yo i x Wellbore Name VS DV Kick Off Depth (RKB) Original Hole 258.00 Directional Surveys Date Description 3/27/2007 1MWD Surveys i Survey Data MD (ftKB) Inc! ( °) Azm ( °) TVD (ftKB) NS (ft) EW (ft) VS (ft) DLS (`1100ft) Survey Company i d 2,630.44 4.38 332.79; 2,614.26 -31.841 - 191.50 193.94 5.27 HALLIBURTON 0 2,693.21 4.19 10.45 2,676.87 -27.45 - 192.18 193.69 4.41 HALLIBURTON 1 2,755.86 3.63 40.67' 2,739.38 -23.70 - 190.47 191.24 3.36 HALLIBURTON 2,818.14 3.20 81.21 2,801.56 -21.94 -187.47 187.93 3.85 HALLIBURTON 2,880.641 3.39 133.17 2,863.971 -22.93 - 184.40 185.14 4.621HALLIBURTON 2,944.15 3.51 105.74 2,927.36 -24.75 -181.16 182.34 2.58 HALLIBURTON 2,999.321 4.501 79.32, 2,982.40 -24.80 - 177.40 178.68 3.75 HALLIBURTON 3,068.73 6.38 55.85 3,051.51 -22.13 - 171.54 172.39 4.14 HALLIBURTON 3,130.71 7.431 45.78' 3,113.04 -17.41 - 165.81 165.81 2.58 HALLIBURTON 3,186.24 10.79 42.98 3,167.86 -11.10 - 159.70 158.51 6.10 HALLIBURTON 411 1„, 1 F, ICI ,,. I I %I Vat r f .. i' iK FEX L.P. - DDR Detail Page 1/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/5/2007, Report: 15.0, DFS: 9.47 Job Spud Dater ' ' P k ; « Rig RNaase Date Ground Elevation (ft) Orig KB Elev (ft) 7KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE + 1 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 r a , Target Depth (SKB) Target Formation µ, Type Date Comment 7,262.0 Safety Highlight 4/5/2007 COLD AND FLU PREVENTION Daily Cost Total Cure Cost To Date N „ 258,818.56 8,761,698.55 " tr sl 11 ` ' Daly Mud Cos Mud Cum To Date Weather Lease / Road Conditions We C on d ition Over ( +) / Under (•) AFE ( + / -) Var Days sun /cloud -5 deg Good Fluid Losses 0 17,736.31 137,241.20 - .. ]Depth Start (ftKB Depth End ftKB Operations @ 06:00 ......... -- .. - ) ( ) Drill ahead directionaly at 4540 I. 3,662 0 4,286.0 r Depth Progress (ft) Short to dril directions L��� 4 00 Drilling Hours ( rip, Operations This Report Period 1850 b i � Operations Next Report Period ` i Drill directionaly Dally ' t', , r , � I r y 1 � , ��- Job Contact Cell Phone 11; l h s 0•1i ga #IIiII: °< i'. Ernie Natte, Drilling 1(907) 771 -0536 toit, i Dur t + Scheduled Depth End Foreman ' Time ( hr(Z l 'r , l'' .. i � il .Type Phase Major Op Operation Trouble (ftKB) Comment 00:00 8.00 Drlg Planned Drlg Prod Dr Dr - Motor No Trbl 3,912.0 DIRECTIONAL Rigs: Do Arctic wolf 0 Op I Vert DRILL 81/2 " HOLE Rig Supervisor F/ 3662' - 3912' KB Bob Lupton Rig M anager 08:00 0.50 Drl Planned Drlg Prod Drilling Circ & Cond No Trbl 3,912.0 CIRCULATE & Mud Pumpsw i rdn`- , `' i m (I 9 9 9 No. Pwr (hp) Rod Di (in) Op Mud CLEAN HOLE 1 900.0 08:30 2.50 Drlg Planned Drlg Prod Drilling Short Trip No Trbl 3,912.0 SHORT TRIP TO Liner size (in) Stroke Voustt OR(bbus Op 2072' (9 5/8" CSG 5 1/2 9.02 0.066 : SHOE) Pump Checks 11:00 0.25 DrIg Planned Drlg Prod Drilling Other No Trbl 3,912.0 FLOW CHECK / Strokes Op CLEAN RIG Pres (psi) Slow Spd (spm) Eff ( %) FLOOR 282.0 Yes 55 95 11:15 0.75 Drlg ,Planned Drlg Prod Drilling Rig Repair / No Trbl 3,912.0 SERVICE RIG & 1,800.0 No 88 95 p 'TOP DRIVE / Mud Pumps: grIOt PZ-9 O Service I CHANGE OUT No. Pwr (hp) R Diameter ( in) SAVER SUB 2 900.0 l it Liner Size (in) Stroke (In) Vol/Stk OR (bbl /s... AI 12:00 1.50 DrIg Fla" 'llrig Prod ' Drilling Short Trip No Trbl 3,912.0 RUN BACK IN 5 1/2 9.02 0.066 Ale Op HOLE (8' FILL) Planned . Prod Drilling Drill - Motor No Trbl 3,912.0 DIRECTIONAL Pump Checks 9 [ Drlg 9 Strokes �s� 13:30 10.50' Drlg Op Vert DRILL 8 1/2" HOLE pres (psi) Slow Spd (spm) Eff. F/ 3912' TO 4286'/ 278.0 No I 55 95 1 SLIDE 238' 1,800.0 No 88 95 i I Y �, .,Ii�s fi :,l Mud Checks: 3,909.0ftKB, 4/5/2007 0 8:45 ) i'hakers <De i iG " "l A.. �' ,:' Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mglL) % Water (%) i Mud Lost (Hole) (bbl) :. M Model 9.60 9.0 0.150 240.000 91.0 ' Vis (s /qt) Filtrate (mU3Omin) Filter Cake (/32 ") Pm (mUmL) Potassium (mglt) Percent 011 (%) Mud Lost (Surf) (bbl) r Shaker Screens 49 5.4 1 0.150 32,000.002 Screen , PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MBT (Ib/bbl) Lime (lb/bbl) 011 Water Ratio Mud Vol (Act) (bbl) Deck No. No. Scr Sz X (in) Scr Sz Y (in) 1 ` 5.000 0.1 6.5 1. -. - - 1 - _... i .... YP Over (ibf/10... Gel (10m) (Ibf/100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Shaker Checks 13.000 6.5 6.0 FDens OF (Ib/gal) bens`UF (Ibfgal) Firs (hrs) E " 'I Type Gel (30m) (IbN100... T (S) CF) Chlorides (mglL) HTHP Alt (mU30... Alkailn (mLhnL) Whole Mud Add (bbl) �" Polymer 19.000 31,000.000 I I "fi 1 Max Back Gas (%) Avg Back Gas (%) Max Conn Gas ( %) Avg Conn Gas Ck) Max Trip Gas (%) Avg Trip Gas ( %) Make Model t. Silicate (%) Electric Stab (V) Comment Centrifu • e/C clone Checks = � � ( i Density Overflow (Iblgaq Overflow Rate (gpm) i : m, , +#, ., ba,,..,h CEC 2`. O7F2O ' „ � ! 'i rC�o i�IG (,d 1i1 -.;,;.: 1 ! i Density (Ib/gal) pH for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) Dens OF (lb/gal) Underflow Rate (gpm) 9.6 9.2 0.150 200.000 91.0 Via (s /qt) Filtrate (mU30min) Filter Cake (132 ") Pm (mUmL) Potassium (mglL) Percent Oil (Y.) Mud Lost (Surf) (bbl) ,Hours (hrs) 011 Under Fl (%) IDene FD (Ib/gal) 50 6.0 1 0.300 27,000.001 90.6 PV Over (cp) - Gel (105) (1bf,1000.. Sand (%) MBT (Ib!bb1) Lime (Ib/bbi) Oil Water Ratio Mud Vol (Act) (bbl) T ,, .11.ilitive1 K1,,- 1 '! '1 5.000 0.1 7.0 926.8 Description Cons... Daily Cos ,- YP Over (Ibf /10... Gel (10m) (Ibf1100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) M LAB 1.0 45.00 10.000 6.6 6.1 Baradefoam 1.0 109:85 '� Ty pe Gel (30m) (Ibf/100... T (f1) (°F) Chlorides (mglL) HTHP Flit (mL/30... Alkailn (mUmL) Whole Mud Add (bbl) HP Polymer 16.000 2 Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas (%) Avg Conn Gas ( %) Max Trip Gas ( %) Avg Trip Gas ( %) • LT DEXTRID I 1.0 62.34 It Silicate(%) Electric Stab (V) Comment I Barazan D+ 2.0 317.42 BA. DM 2.0 1,575.00 ._: _ ,..' : n.�i.. Tech De escription Make Model Service /L... -,HG Dryer Derrick CON DET 2.0 867.60 R ort Printed 5/3 /2 002 t�;i1 , r ,A s '. . .a4 t 4. �,moM.. ' oaM'" , Li mi t lr $ 1 '1 p om; i to r. 4111 FEX L.P. - DDR Detail • Page 213 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/5/2007, Report: 15.0, DFS: 9.47 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) ' ,.. Mud Additive Amounts 18.20 37.10 j 18.90 1 Description Cons... Dally Cost vendor III! Shaker Screens WALL -NUT 2.0 51.60 ... : Deck No. '._._.._. '' . . ... s ,, IiIII( R niNO {4 { ,.W tit.u•`- "')c sr SzX(I n) ScrSzY(in) F 1 1 120.000 Baracor 700 2.0 289.42 ' 2 1 120.000 Barascav D 4.0 255.08 3 . ' a 1 120.000 �CLAYSEAL 4.0 3,172.52 : <a , ' Shaker Checks " Dens UF pb /gal) Hrs (hrs) Aldacide G 5.0 829.65 De PAC-L Potassium 7.0 113 9 P 6.0 950.40 i Description Make Model 0 II'I ii i'=0 1, , i � ! , . •'11 '� I 0 "':1111.:.1..1?',... n , o Chloride m 1 6 61 HG Dryer Derrick 1 Baracarb 1L1 {94,$ , ■ Shaker Screens Potassium l 14.1 835.66 Dick No Screen No - Scr Sz X (in) Scr Sz Y (in) Hydroxide 1 1 120.000 ( Barofibre 20.0 503 1 2 1 120.000 EZ MUD DP' 21.0 1,229.971 , 3 1 120.000 .13aranex 40.0 3,095.60 Shaker Checks Baro -Trot 1 40.0 2,541.601 ka, , Dens OF (lb/gal) _. Hrs (hrs) Plus , __ Baroid 68.0 695,64 Description Make Model i i� (tgi1 a +, • ° 1 1 1' H HG Dryer Derrick 1P ®', 1 t , , V Shaker Screens Data y i r ' Type , ' I' ) 4 ' Screen No. Stit X (in) Scr Sz Y in 1 j c/t No 1 1 120.0001 F Cas B.i S '. I ' 2 1 120.000 I TestO to FaalcrtI, ill;. 'F1'pe 3 1 120 000 [ Shaker Checks ' Formations r a �� e , , ','r 1Y'� '". • •= '' r a' ' ' ', .' �'�.�it , ' 'r 5,4 .sr a 3 111 . 14 1 ,, ' �1 . ,'ampleTep y t : ry Formati �l (1 ' i{ I�II jx u MD (ftK�) " �� )T��;3trti� s ` HA, •I � 1 N anus h uk Group 9 12 0 ° 4. , Base Permafrost 1,020 0 i1 Bit R un Make BIt Inventory •� , �� ��� - B i t T Item Cost a `r 2 1 Hughes 8 1 /tin HCM605Z, 7106613 PD C 2.2,833. Nanushuk topset sst. 2,795 0 l l IADC Bit Dull TFA (loci Noz) (in') BHA ROP (ftlhr) Nozzles (132 ") ADC Codes Nanushuk topset sst. 3,388 0 , 0 1 -NO A -X -O NO CP 0.71 35.8 14/14/13/14/13 M 3 2 3 ,Torok 3,470 0 ',1 , , � n a SPtiIi� II.N III II!�P� 7 IB1!k p' S.,�I'M !i ' ItAt �ri�a #L. uI 'U,h`I 1. .,, • , ' r 3,�� �� ?� ��HI���t� I I � � � � II�Ca �, � ��� � n � 1 a Torok sand 1 4,734 0 BHA No. (Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibt) Torok sand 2 4,852 0 a 2 2,185.00 1,800.0 560 148 168 Torok sand 3 5,090 0 WOB (10001bf) I lnterval ROP (ftlhr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over -Pull (Ibf) +kn 10 1 33.7 41.6 18.50 5,000.0 168 20,000.0 Torok sand 4 5,630.0 ° ' Torok sand 5 5,798.0 Bit RPM (rpm) -a Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000Ibf) 325 200 52.50 1 2 000.0 Ftlbs 135 Torok sand 6 6,008 0 4y,1 Hydraulic Calculations - Torok sand 7 6,313 0 ; U AV DP'(ftlmin) AV DC (ftlmin) --- ........ Err ' , - ' r Torok sand 8 6,568.0 "i "''...... A casing component contains a null value in ID HRZ 6,605.0, D It rill String Components Kuparuk Sandstone Mbr 6,800.0: - Mtr LCU (lower Cret. 6,880.0 Top B1111 : B Unconformity) Item Density Drift Conn Sz Conn Sz Btm • i Angie OD(in) (Ibs /ft) Grade ID(in) (in) (in) 'TopThrd (in) Thrd :CumLen(ft); (' BCU(BaseCret. 6,8800 , p n 2081 Dr 1 ll Pipe 2 O 868 ... I 4 14.00 X95 3.3401 4 FH 4 FH 1 3,662.301 Unconformity) "Igiilii 8 HWDP 248.59 4' 27.20 2.750' 4 FH 4 FH 793.99 ' Upper Kingak (Miluveach) 6,880.0 ;. 1 Drilling 36.02 4 2.000 4 FH 4 FH 545.40 Kugrua siltstone 7,066.0 Jars Kugrua sandstone 7,120.0 Hydraulic Kugrua ironstone 10 HWDP 311.40 4 27.20 2.750 4 FH 4 FH 509.38 Kingak Fm. 1IXOSub 1 6.28 2.021 2.5001 4 FH 41/2 IF 197.98 CondUCt� ` �,e )r .t, Af, � - P, ■■ .I �� 1 NM FLEX 30.83 6.68 2.880 4 1 /2 I F 4 1 /2 IF 195.96 Csg Run Date O o (in) Gr Wt (Ibs /ft) i. D.C. 3/19/2007 16 H-40 ; 65 00 1 NM FLEX 31.08 6 3/4 2.880 4 1/2 IF 4 1/2'', IF 165.13 IS4� y ",1 ", ;F)n s ' t (; i'. K y 1(1 01 1 11.1' D.C. Csg Run Date OD (In) ,Grade Wt (ibsfft) 3/31/2007 9 5/8 ' L -80 1 40 00 1 Stabilizer 5.46 6 3/4 2.810 4 1/2 1F 4 1/2 1F 134.05 I ,.. ,° „ 6 I , t=' ' a , 1 MWD D ir i 22.42 6.71 . 4.630' 41/2 IF 41/2 IF 128.59 )i ( tl., & Lo gg g) In Cmn Des Co ent , BAT 1 Iwii 1 1 MWD (Dir 9.89 6.76 4.880 4 1/2 IF 4 1/2 IF 106.17 & Logging) �r , TM �, . a. , . , 0 , ...t., _ . 'r' :u�.. , . . ,I 1: i � " ,- sn sl I,4 tu4 ' ! �' �1. , .. : '4,,= __________ __ 11111____ 0 FEX L.P. - DDR Detail Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/5/2007, Report: 15.0, DFS: 9.47 - • Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) 1 , .t „r, 18.20 37.10 18.90 Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (In) (Ibs(ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (°) , i hli 1 MWD (Dir 9.21 6.79 4.560 4 1/2 IF 4 1/2 IF 96.28 & Logging) PM3 I 1 MWD (Dir 30.20 6.73 4.630 4 1/2 IF 4 1/2 IF 87.07 1i & Logging) i 0 . NUKE _ w 114401,„ ,1t 4 € ,. 1a r kh i a 7 as , 11 1 '. Y Rat t .. r , . ��4 1 l 1 MWD (Dir 28.14 6.76 14.630 4 1/2 IF 4 1/2 IF 56.87 & Logging) 11 -0 FE 1 Float Sub 2.50 6.8 .4 2.750 4 1/2 IF 4 1/2'1F 28.73 ,, 1 Mud Motor 25.23 7 1.500 4 1/2 IF ' 4 1/2 IF 26.23 1.22 „0 1 0,e Wellbore Name VS Dir (°) Kick Off Depth (ftKB) i Original Hole 258.00 `, Directional Surveys Date Description 3/27/2007 MWD Surveys Survey Data MD (ftKB) Inc' ( °) Azm ( °) TVD (ftKB) NS (ft) EW (ft) '" VS (ft) DLS ( °/1001) Survey Company 0.001 0.001 0.00 0.00 0.00 HALLIBURTON 1 3,255.80 12.13 49.57 3,236.03 -1.59 - 149.69 146.75 2.69 HALLIBURTON 3,319.68 12.431 53.38 3,298.45 6.86 - 139.07 134.60 1.35 HALLIBURTON 1' 3,379.03 12.83 56.28 3,356.37 14.33 - 128.46 122.67 1.26 HALLIBURTON 3,442.67 14.19 59.111 3,418.25 22.26 - 115.89 108.731 2.38 HALLIBURTON 3,505.14 12.92 60.74 3,478.98 29.60 - 103.22 94.81' 2.12 HALLIBURTON 3,563.291 12.97 66.14 3,535.65 35.42 -91.58 82.221 2.081HALLIBURTON _. 3,631.28 13.29 76.24 3,601.87 40.36 -77.01 66.94 3.40 HALLIBURTON ' 1 3,691.59 14.781 83.08 3,660.38 42.94 -62.64 52.34 3.69 HALLIBURTON 3,753.91 16.25 92.60 - 3,720.44 43.50 -46.03 35.98 4.71 HALLIBURTONi,I l 77 17.20 102.961 3 6 3,780.37 41.03 - 28.271 19.12' 4.99 HALLIBURTON 3,878.61 16.59 109.43 3,839.83 36.02 -10.95 3.22 3.18 HALLIBURTON 3,941.46 13.85 114.58 1 3,900.471 29.901 4.36 -10.48 4.861HALLIBURTON 1 .0 4,002.87 11.19 119.79 3,960.42 23.88 16.21 -20.82 4.70 HALLIBURTON 4,066.52 9.70 119.64' 4,023.01 18.16 26.23 -29.44 2.34 HALLIBURTON ,' 4,127.27 7.01 130.05 " 4,083.12 13.25 33.52 -35.54 5.06 HALLIBURTON 4,192.30 4.941 148.28 4,147.79 8.31 38.03 - 38.931 4.28 HALLIBURTON ' 4,256.10 4.60 186.68 4,211.39 3.43 39.18 -39.04 4.94 HALLIBURTON 1 4,314.74 5.07 202.87 4,269.821 -1.291 37.90 -36.80 2.45 HALLIBURTON 4,378.25 4.76 208.82 4,333.10 -6.19 35.54 - 33.47 0.94 HALLIBURTON 4,440.34 3.41 230.26 4,395.03 -9.62 32.88 -30.16 3.25 HALLIBURTON 4,503.08 3.45 276.70 4,457.67 -10.60 29.57 -26.72 4.31 HALLIBURTON 4,565.18 3.62 297.12 4,519.66 -9.49 25.961 -23.43 2.03 HALLIBURTON 4,629.17 3.33 298.41 4,583.53 -7.68 22.53 -20.44 0.47 HALLIBURTON 4,687.611 3.17 296.53 4,641.881 -6.15 19.59 -17.89 0.33 HALLIBURTON 4,751.47 3.10 297.70 4,705.64 -4.56 16.48 -15.18 0.15 HALLIBURTON 4,813.76 3.031 297.55 4,767.84 -3.02 13.53 -12.61 0.11 HALLIBURTON 4,875.78 2.93 296.24 4,829.78 -1.56 10.66 -10.10 0.20 HALLIBURTON 4,938.941 2.82 298.82 4,892.861 -0. 7.851 -7.66 0.271HALLIBURTON i 1 1 1 5,001.16 2.76 297.24 4,955.00 1.33 5.18 -5.34 0.16 HALLIBURTON ,' , 5,064.08'1 2.571 300.12, 5,017.86 2.73 2.611 -3.12 0.37 HALLIBURTON 5,126.70 1.93 285.14 5,080.43 3.71 0.38 -1.14 1.38 HALLIBURTON , 5,187.76 1.82 285.891 5,141.46 4.25 -1.55 0.63 0.18 HALLIBURTON 5,252.81 1.74 281.17 5,206.47 4.72 -3.51 2.45 0.26 HALLIBURTON 1 5,315.13 1.751 285.31: 5,268.77 5.15 -5.36 4.17 0.20 HALLIBURTON # 5,376.45 1.97 282.87 5,330.05 5.64 7.29 5.96 0.38 HALLIBURTON Ak , 11 il 1 1 Li } (i i p /3/2007 � C �s h: F x a . IIa, +.�. r, II, y1» t 1 i10 . , Oe Q l r ® l ■ FEX L.P. - DDRII II' i I'''i al l' � P , I 1 I'� ' W I Well Name: AKLAQ #6 „ Job Type: Drilling - Original Date: 4/612007, Report: 16.0, DFS: 10.47 ___ _ _ •' :. ua: >edII iIII ii „ a,dln 0 Job Spud Date Rig Release Date !Ground Elevation (ft) Orig KB Elev , (ft) KB-Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 1 3/27/2007 12:45 4/23/2007 16:00 , I 18.20 .7.10 18.90 AF62034 22,574,244.00 22,574,244.00 Safety Target Depth (ftKB) Target Formation Type Date Comment 7,262.0 Safety Highlight 4/6/2007 RABIES IDENTIFICATION AND AWARENESS Daly Cost Total Cum Cost To Date Daily Summary , 274,341.07 9,036,039.62 Weather Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( + / -) Var Days Daily Mud Cost Mud Cum To Date , cloudy 4 deg Good Fluid losses 0 34,558.82 171,800.02 Operations @ 06:00 Depth Start (ftKB) Depth End (ftKB) ' ee .0 5 285 0 Hole depth is 5530' wiper tripping to 3900' 4,286 6 . Operations This Report Period Depth Progress (ft) Drilling Hours (hrs) Drill 8 1/2" hole derectionaly 999.00 23.50 Operations Next Report Period Daily Foreman Contact Short trip and drill 8 1/2" hole y - -- -- - - -- - -- - - -- - -- -- - - -- Job Contact Cell Phone Time Log Ernie Natte, Drilling (907) 771 -0536 Start Dur Ops Scheduled Depth End Foreman i Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment - 1 00:00 10.50 DrIg 'Planned DrIg Prod Drilling Drill - Motor No Trbl 4,723.01DIRECTIONAL Rigs Doyon, Arct Wolf Op Vert DRILL 8 1/2" HOLE Rig Supervisor F/ 4286' - 4723' KB/ ,Bob Lupton, Rig Manager SLIDE 200' Mud Pumps: 1, Gardner- Denve,i° °.' No. Pwr (hp) Rod Diameter (In) 10:30 0.50 DrIg Planned Drlg Prod Drilling Rig Repair / No Trbl 4,723.0 SERVICE RIG & 1 900.0 O kit p Service TOP DRIVE / Liner Size (In) Stroke(In) VOUStkOR(bb1 /s... alp ADJUST 51/2 9.02 0.066 DRAWWORKS - - i i, BRAKES Pump Checks .. Strokes 11:00 1.00 Drlg Planned DrIg Prod Drilling Drill - Motor No Trbl 4,785.0 DIRECTOINAL Pres (psi) Slow Spd (spm) Eff ( %) Op I I Vert DRILL 8 1/2" HOLE 237.0 Yes 44 95 F/ 4723' to 4785' 1 1 0 No 55 95 nG ,'' 12:00 12.00 Drlg Planned DrIg Prod " Drilling Drill - Motor No Trbl 5,285.0 DRILL 8 1/2" HOLE M ud ° .1 • Gardner- Denve#ml l� `` Op Vert F/ 4785' -5285' /, N o. Pwr ( bpi Rod Diameter (In) SLIDE 15' 2 900.0 4' Liner Sim (In) Stroke (in) VOUStk OR (bbl /s... 0 Mud Checks: 4,655.0ftKB, 4/6/2007 08:45 '' :$. 5 1/2 9.02 0.066 Density (lb /gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg/L) % Water ( %) Mud Lost (Hole) (bbl) 9.65 9.0 0.150 160.000 91.0 Pump Checks Vis (s /qt) Filtrate (mtJ30min) Filter Cake (132 ") Pm (mUmL) Potassium (mg /L) Percent 011 ( %) Mud Lost (Surf) (bbl) Strokes 53 4.8 1 0.300 28,999.999 Pres (psi) Slow Spd (spm) Eff ( %) PV Over (cp) Gel (10s) (Ibf /100L.. Sand ( %) MBT (113/bbl) Lime (113/13b1) 011 Water Ratio Mud Vol (Act) (bbl) 237.0 No 44 95, 5.000 0.0 5.0 360.0 No 55 95 hakers YP Over (Ibf /10... Gel (10m) (ibf /100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) t <Description?> P 13.000 6.3 53 I Make Model Type Gel (30m) (Ibf /100... T (fl) (°F) Chlorides (mg/L) HTHP Flit (mL/30... Alkalin (mUmL) Whole Mud Add (bbl) L. -_ Polymer 20.000 33,999.998 15.2 Shaker Screens ,„ , 1 Max Back Gas ( %) Avg Back Gas ( %) 'Max Conn Gas ( %) Avg Conn Gas ( %) Max Trip Gas ( %) Avg Trip Gas ( %) Screen Deck No No I Scr Sz X (in) Scr Sz Y (in) Silicate (%) L ) Electric Stab (V) Comment I .......... I 114' Shaker Checks 'i:° c - Dens OF (Ib /gal) Dens..UF (lb /gal) Hrs (hrs) M ' Checks: 5,022.0'ftitii, 4 /Gi/0 ., "� „ .. ,ii,T s Ir, , „ a l li: I V' Ilk; Rili Density (Ib /gal) pH 'CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) 9.60 8.4 0.100 200.000 91.0 j: ,,, $$ Vis (s /qt) Filtrate (mU3Omin) Filter Cake (/32 ") Pm (mL/mL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbl) Make Model ' 60 4.0 1 27,000.001 178.5 , I PV Over (cp) Gel (10s) (Ibf /loot.. Sand ( %) MOT (lb/bbl) Lime (Iblbbl) Oil Water Ratio Mud Vol (Act) (bbl) I Centrifuge /Cyclone Checks i 4.000 0.0 7.0 1008.5 Density Overflow (Ib/gal) Overflow Rate (gpm) g ,, YP Over (Ibf/1O... Gel (10m) (Ibf1100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) ' fl ' 13.000 6.8 6.2 'Dens OF (Ib/gal) Underflow Rate (gpm) t: i Type Gel (30m) (Ibf /100... T (fl) CF) Chlorides (mg/L) HTHP Filt (mU30... Alkalin (mUmL) Whole Mud Add (bbl) Polymer 20.000 27,999.999 14.8 Hours (hrs) 011 Under Fl (%) Dens FD (Ib/gal) Max Back Gas (%) Avg Back Gas ( %) .Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas (%) - - -- Avg Trip Gas (%) - Silicate ( %) Electric Stab (V) Comment ,n ® rf, lbb 1' ® Cost i MUD LAB ' 1.01 45.00 01.$ , a, r ry .• y„ i+ ( •u,� r'i�. a J„ ' ® ,t - ® � "�t:� �� , , . �w v��, ,-� ,.. �; 4 BA. DM' 2.0 1,575.00 I I Description Make l Model ' Tech HG Dryer Derrick Service /L... Shaker Screens 2.0 Deck No Screen o. Scr Sz X (In) Scr Sz Y (in) CLAYSEAL 2 1 1 1 120.000 WALL -NUT 4.0 103.20 2 1 120.000 F ' 1a 3 1 120.000 Barascav D 5.01 318.85 t ilq Baracor 700 5.0 723.55 ,I. llii i ii v 447 I7, s *P<r 10( ' ' �' .. a ,, ' Re pa .. 9 t , t a qtr+, l ti . , < �„ , „ .. t, : i�„ "�� . f , .fl i � , „ ,IVo,IIR Rig ,,�fi�l,, t z, . . is:i ' 41° FEX L.P. - DDR Detail Page 2/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 416/2007, Report: `16.0, DES: 10.47 • - Ground Elevation (k) p KB Elev (ft) KB- Ground Distance (k) Mud Additive Amounts 18.20 37.10 18.90 Description Cons... Daily Cost Vendor Shaker Checks Potassium 6.0, 358.14' Dens OF (lb/gal) Hrs (hrs) Hydroxide 1 � . � m oil mllmr r - - ; arazan. 0+ 8.0 1 =r ° ' , l t 6 .; j ` a410. EZMUDDP 13.0 761.41 Description HG Dryer Derrick Make Model Baracarb 50 14.0 263.48 PAC -L 20.0 3,168.00 Shaker Screens ' N -DRIL H ' 21.0 1,995.84 1 £. > , Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 Barofibre 44.0 1,107.04 2 1 120.000 Baranex 117.0 9,054. ;5 ,, `' 3 1 120.000 Baro -Trot 153.0 9,721.62 Shaker Checks Plus bens OF (lb/gal) Hrs (hrs) Potassium 154 0 2,507.12 Chloride 'k HG Make Model 1111',!''':111i::; 1 1 , HG Dryer Derrick Last Casing Cllegk' pl ,, . Shaker Screens Date Type 00)110, Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 Ch 6iI' 1 „o 'iiIIIIII'' ,,, , , ;!r, H 1 2 1 120.000 Test BOP D Test Type I 3 1 120.000 I Shaker Checks Formations I, Dens OF (1b/gall Hrs (hrs) , „# _. + Sam le Top ii ._. _... _� _ ", Formation Name MD (ftli Nanushuk Group 912.0 ■ i�(� }�ifl Strings: BHA #2, Steerable 1'11 % 1 ., 1 " 41 ',# ,1 Base Permafrost 1,020.0 Bit Run Make Bit Inventory Bit Type Item Cost Nanushuk topset sst. 2,795.0 2 IHughes 8 1 /2in, HCM605Z, 7106613 IPDC 22,8 IADC Bit Dull TFA m ci Noz In' BHA ROP (ft/hr) Nozzles (/32") IADC codes - Nanushuk topset sst. 3,470 388 0 4 ( 1( I ( 1 0 1 -NO A X -0 NO CP 0.71 35.8 14/14/13/14/13 m_3_2_3 Torok 3, O F _� �4, 6, - 5,2 0 f t K Biill i Iu � �o lil i l C I ��i l ' - .... 1 111 11 '011": ' � r i � � i Torok sand 1 4,734 0 BHA N Cum Depth (ft) SP P (psi) Flow Rate (gpm) T FO Re Rot HL (10001... Max. H o o k Load (Ibf) Torok sand 2 4,852.0 il 2 3,184.00 2,300.0 560 178 202 Torok sand 3 5,090.00 ,fit WOB (1000Ibf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000lbf) Max. Over -Pull (Ibf) Torok sand 4 5,630.0 8 42 5 41.9 23.50 7 202 24,000.0 L - -- - -.__ -- Torok sand 5 5,798 0 ; Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000Ibf) Torok sand 6 6,008.0 320 200 76.00 4,000.0 Ftlbs 160 Torok sand 7 6,313.0 Hydraulic Calculations Torok sand 8 6,568.0 1I AV DP (ftlmin) 1 AV DC (ftlmin) Err A casing comp onent contains a null value in ID HRZ 6,605 0 , ii Drill String Components g p Kuparuk Sandstone Mbr 6,800 0 „ Mtr LCU (lower Cret. 6,880.0 a µ' Top Btm Bend Unconformity) :!!'! 1 §,_, Item " r, Dens Drift Conn Sz Conn Sz Btm Angle ,j Description Len (ft) OD (in) (lbslft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) 1 ° BCU (Base Cret. 6,880.0 208 Drill Pipe 2,868.... 41 14.00 X95 3.340 4 FH 4 FH 3,662.30 Unconformity) 8 HWDP 248.59 4 27.20 2.750 4 FH 4 FH 7 Upper Kingak (Miluveach) 6,880.0 1 Drilling 36.02 4 1 2.000 4 FH 4 FH 545.40 Kugrua siltstone sandstone 7,066.01'4 Jars - Kugrua 7,120 0 0,",,, , Hydraulic ',Kugrua ironstone 10 HWDP 311.40 4 27 20 2.750 4 FH 4 FH 5091973 .98 '1;0 ) , Kingak Fm 1 NM FLEX 30.83 8 2.500 41FH 4 . �tcrPt�. =�lla1ii''is 11)(0 Sub 2021 62 a a Csg Run Date OD (In) 11211E Grade Wt (lbs `: 2.880 4 1/2 IF 4 1/2 IF 195.96 D.C. ! 3/19/2007 16 m 0I H-40 65.00 ( y 1 NM FLEX 31.08 6 3/4 2.880 4 1/2 IF 4 1/2 IF 165.13 ISU� Ii in � k6 ll u lh ii,,, D.C. Csg Run Date OD (in) Grade !Wt (lbs 3/31/2007 9 5/8 I L -80 1 40.00 1 Stabilizer 5.46 6 3/4 t � kY , 1 I 2 . 8 10 4 112 IF 4 1/2 IF 134.05 i )7II = ii i" , ~1 z . i 1 MWD (Dir i 22.42 6.71 4.630 41/2 IF 4 1/2, IF 128.59 Cement,,,{ 1,: ,'„ �ul 1 , � Cmnt Des Comment & Logging) �.. ���, 1 i'u BAT 1 'MWD (Dir 989 6.76 ' 4.880 4 1/2 IF 4 1/2 IF 106.17 , H'I' & Logging) 1 MWD (Dir 9.21 6.79 4.560 4 1/2 IF 4 1/2 IF 96.28] ill & Logging) y PM3 1 1 MWD (Dir 30 20 6 73 $ £ rit 1 , s t t � & Logging) k r NUKE , .,. sr; r ' , T'111 ea t4 ..'- z� r IIV �,,,i i'P / ,1„ t '1' ,I H , `4 . { 1' 1" r ��... �' 's .,,. " °;: �' ' , '') I„ �a .'II �F fi %� . �, ,�I ,x la�Yorf �1`7427: p° /��Q' s� ° ».. d`- : x I,' .. ti„ . ' (, a.�xr . ' ,, , .vaa t Iii ,fit , � �w Fu BI "�sd' °. 1 _ID FEX L.P. - DDR Detail Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/6/2007, Report: 16.0, DFS: 10.47 0 . - -- stance (ft) 1GroundElevation (ft) Or1g KB Elev (ft) KB- Ground Di i 18.20 j 37.10 18.90 Drill String Components 1 Mir Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (in) (Ibslft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) ( ) 1 MWD (Dir 28.14 6.76 4.630 4 1/2 IF 4 1/2' IF 56.87 & Logging) FE 1 I, 1 Float Sub 2.50 6.8 2.750 4 1/2 IF 4 1/2 IF 28.73 l' 1 Mud Motor 25.23 7 ' 1.500 4 1/2 IF 4 1/2 IF 26.23 1.22 weHbore Name VS Dir (°) Kick Off Depth (ftKB) Original Hole 258.00 4. 1 Directional Surveys Date Description 3/27/2007 MWD Surveys k ,.' I.. I t; 1 J 1 1 1 1 I i` lir p. I a ■ I N. Pt 1 00 I r Pri" ,;; rt , , ,,, Ib ,� , y 'y�. l� a -m, - •� � iC ;3 a t 4 'cii'l e. 3 , .,. a. =f.' '∎ .: - a,: 1 A, ate t om . ---- -- -- - -- --- - - ------ ------ - - II ill- FEX L.P. - DDR Detail n 0, age 1/3 1 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/7/2007, Repo ,..., :L. (1, DFS: 11.47 1 .' 4 :::::::;;Vhil, , • Job Spud Date Rig Release Date '_., ., :::i:::14.4g:,.. ,_ Ground Elevation (ft) Orig KB Elev (ft) KB Distance (ft) AF No. Total AFE Amount Total AFE+Sup 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 '41 1 Safety Target Depth (ftKB) Target Fonnation Type Date Comment 7,262.0 , Safety Highlight14/7/2007 COMMUNICATION IS THE KEY TO A SAFE WORK ENVIRIMENT Daily Cost Total Cum Cost To Date )111 , : ,' .,, , ;5:1 nkii .. 268,167.31 9,304,206.93 Weather Lease/ Road Conditions Wellbore Condition Over (+) / Under (-) AFE (+1-) Var Days DaIly M C os t Mud Cum To Date sun/cloud 1 deg Good Fluid Losses j 0 27,085.06 198,885.08 Operations @ 06:00 ----------- - - Depth Start (ftKB) Depth End (ftKB) i DRILL 8 1/2" HOLE / DEPTH 6280' KB 5,285.0 6,033.0 ;. Operations Thls Report Period Depth Progress (ft) Drilling Hours (hrs) Wiper trip to 3900 and drill ahead 748.00 17.50 Operations Next Report Period . (i Drill 8 1/2" hole to core point AilYForernatJAPRI114,9tAmikanah, , „, ..,.....,,,,.., Job c,0014101):%trnniji.0,i hon ...,",- , -' -,',. , , ,:',-, ' . - ' - Emie fstatfe,filrilling (907)771-0536 al qi,IP: t ' l'k T'e'■ 7 '' ' ild , '' 141* ■ 6 ' Scheduled Depth End Foreman ' ,., 1.!.."i.... , , ' ' ..'..,-1 Type Phase Major Op Operation Trouble (ftKB) Comment 00:00 6.00 Drlg Planned Drlg Prod Drilling ; Drill - Motor No Trbl 5,534.0 DRILL 8 1/2" HOLE Rigs: Doyon, Arctic Wolf ig ;RI Supervisor Op , Vert F/ 5285' - 5534' KB g , ■ Bob Lupton, Rig Manager ' 7 1.56. DrIg Planned DrIg Prod Drilling Circ & Cond No Trbl 5,534.0 PUMP / PUMP - - O Mud PILL / FLOW No. Mud Pumps: 1, Gardner-Derwessrhz.-e 1 Pwr (hp) Rod Diameter (In) CHECK 1 900.0 07:30 4.50 DrIg 'Planned DrIg Prod Drilling Short Trip No Trbl 5,534.0 WIPER TRIP TO uner Size (In) Stroke (In) Vol/Stk OR (bbl/s Op 1 3900' KB! RUN TO 5 1/2 9.02 0.066 i 1 1 ; BTM (5 FILL) ' Pump Checks 12:00 8.25 DrIg Planned DrIg Prod Drilling Drill - Motor No Trbl 5,906.0 DRILL 8 1/2" HOLE strokes Op Vert F/ 5534. Pres (psi) Slow Spd (spm) Eff (%) 20:15 0.501DrIg Planned DrIg Prod Drilling Rig Repair / No Trbl 1 5,906.0 LUBRICATE RIG 278.0 Yes 44 95 Op Service , 380.0 No 55 95 ipardner-Denver, PZ-9 :i , 20:45 3.25 DrIg Planned Drlg Prod Drilling Drill - Motor No Trbl 6,033.0 DRILL 8 1/2" HOLE No Pwr Pumps., (hp) Rod Diameter (in) Op Vert F/ 5906' - 6033' ' 2 z 900.0 M1 4, 4 12:30 Liner Size (In) Stroke (in) Vol/Stk OR (bbl/s... *),.. Density (Ib/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg/L) % Water (%) Mud Lost (Hole) (WI) 5 1/2 9.02 1; 6 0.066 ;4.6 6,. 9.95 1 8.8 0.080 160.000 89.0 ; - '. 46 Ws (s/qt) Filtrate (mL/30min) Filter Cake (/32") Pm (mUmL) Potassium (mgIL) Percent 011 (%) Mud Lost (Surf) (bbl) Pum • Checks .. ,, ... .. 52 1 4.8 1 0.050 31,000.000 0.0 LP Over (cp) Gel (10s) (1b1/1001... Sand (%) MBT (Ibibbl) Lime (Ib/bbl) 011 Water Ratio Mud Vol (Act) (bbl) A 5.000 0.0 7.0 0.1/99.9 ; 278.0 Yes 95 • tYP Over (1b010... Gel (10m) (Ibf/100... Solids (%) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) Lak4 ,a4'.$$ 431, 7 :i'' ' !r: 10.000 8.6 7.3 Type Gel (30m) (1b0100... T (11) eF) Chlorides (mg/L) HTHP Fitt (mt./30... Alkalin (mUmL) Whole Mud Add (bbl) Make Model Polymer 19.000 29,999.999 14.8 ! , 14 1" Max Back Gas (%) Avg Back Gas (%) Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas (%) Shaker Screens 'A 1 Screen . Silicate (.4) Electric Stab (V) Comment ' Deck No. No. Scr Sz X (in) Scr Sz Y (in) 1 1 1 i t e: :% Joh .t...,..:,4,§,900.0ftKB, 4/7/2007 20:30 Shaker Checks Density (Ib/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg/L) % Water (%) Mud Lost (Hole) (bbl) 1Dens OF (Ib/gal) Dens UF (lbfgal) Hrs (hrs) '.1: 9.95 9.0 0.100 240.000 89.0 !VW (s/qt) Filtrate (mL/30min) Filter Cake (/32") Pm (mL/mL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbi) 54 3.6 1 24,000.000 0.1 116.6 Make Model PV Over (cp) Gel (10s) (1b01001... Sand (%) MBT (lb/bbl) Lime (lb/bbl 011 Water Ratio Mud Vol (Act) (bbl) 6.000 0.0 8.7 0.1/99.9 1068.4 _ _ Centrifuge/Cyclone Checks 4 YP Over (lbf/10... Gel (10m) (/bf/100... Solids (%) LGS (%) Polymer (ppm) LCM Mud VoF(kes) (bbil Density Overflow (lb/gal) Overflow Rate (gpm) 7.1! 6 18.000 8.6 7.4 ; Type Gel (30m) (1b1/100... T 09 ("F) Chlorides (mg/L) HTHP Alt (mU30... Alkalln (mUmL) Whole Mud Add (bbl) Dens UF (lb/gal) Underflow Rate (gpm) Polymer 25.000 28,999.999 15.6 Max Back Gas (%) Avg Back Gas %) I Max Conn Gas (%) 1Avg Conn Gas (y.) 1,:lax Trip Gas (%) 'Avg Trip Gas (%) -- Hours (hrs) Oil Linder Fl (%) Dens FD (Ib/gal) 'It Silicate (%) Electric Stab (V) Comment IVI U0' :1.'1.! ' '',,,,, . ., . viti Description Cons_ ' 'al ": ' ' ' , M 1 40:4 1 1. 11 M, 1 11 1 , '.i..!,' MUD LAB 1 45.00 .... Description Make Model 1Baradefoam 1.0 109.85 HG Dryer Derrick 'HP , Shaker Screens BA. DM 2.01 1,575.00 Deck No. Screen No. Scr Sz X (in) Scr Sz Y (In) Tech 1 1 120.000 Service/L... 2 1 120.000 CON DET 2.0 867.60 3 120.000 Shaker Checks EZ MUD DP , 3.01 175.71 ill ' Dens UF (lb/gal) Hrs (hrs) WALL 4.0 103.20 F 4. dl 'e 1 1" : ' 11 Ri !'l Pgi l6 6464:6'466,4616,1614'1:6664,,,,,,66466'66411064'6,6664661'. .6646,46 , ..ao,k!:theil` Ji . „ Ah* ' „,,Lo k ..,..0..K.-:,, . . ,...,.:........,...,4. . .. FEX L.P. - DDR Detail Page 2/3 ' Name: AKLAQ #6 : Type: Drilling - Original Date: 4/7/2007, Report: ' 17.0, DFS: 11.47 i Ground Elevation (ft) 1 0rIg KB Elev (ft) KB- Ground Distance (ft) Mud Additive Amo unts 18.20 37.10 18.90 Description Con Daily Cost vendor e ! tt ! , 7 ,. iIIII'di 111' IIGI") IIIi111ilillllrll�Iiiii ii ` BGIiIIGIiii,u' ii , : hn ` CLAYSEAL 4.0 3,172.52 iw iDescrIptIon Make IModel X 207 6.0 721.68 !; HG Dryer _ Derrick Baranex 10.01 773.90 Shaker Screens Aldacide G 10.0 1,659.30 Deck No. Screen No. Scr Sz X (in) Scr Sz Y (In) Baro - Trot 10.0 635.40 1 1 120.000 Plus , ,,11 2 1 120.000 3 1 120.000 Potassium 10.0 596.90 Hydroxide Shaker Checks " r - ps OF (lb /gal) Hrs (hrs) Barazan D+ 14.0 2,221 PAC -L 15.0 2,376.00 Description Make - -- Model N - DRIL HT+ 29.01 2,756.16 - HG Dryer Derrick Baracarb 25 124.0 2,415.52 Shaker Screens Baroid 150.0 1,534.50 Deck No. Screen No. . Scr Sz X (in) Scr Sz Y (in) Baracarb 50 284.0 5,344.88 1 1 120.000 2 1 120.000 Last Casing Check 3 1 120.000 Date Type Shaker Checks Dens OF (lb/gal) Hrs (hrs) Last BOP Check ... ...... Test Date Test Type i Drill Strings: BHA #2, Steerable I k, Bit Run ,Make Bit inventory Bit Type Bern Cost Formations 11 Hughes I 8 1/21n, HCM605Z, 7106613 PDC 22,833.00 Sample Top �r L .._ 1._._._. _..._.. _.... -- - -- - -- - -- - - -- -- -- _ Formation Name MD (ftKB) i IADC Bit Dull TFA (loci Noz) (In') ,BHA ROP (ft/hr) Nozzles (132 ") IADC Codes 0 1 -NO A X -0 NO -CP 0.71 35.8 14/14/13/14/13 M-3-2-3 Nanushuk Group 912.0 • II , ��, ! i r L , ! fii f, -, t om = -6 ,, lhii'8 ) ri rx � „6 66.66166 � .. -,:6,66.6066-2.6. 'fin J 'gI!a ll ,, t . 6s'rri I11IIII I h Base Permafrost 1,020.0 9,28 , b I -a l3 a Igo Nanushuk topset sst. 2,795.0 ,Ie BHA No Cum Depth (ft) SPP (psi) Flow Ra (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) , i , l 2 3,932.00 2,500.0 510 190 212 Nanushuk topset sst. 3,388.0 '. WOB (10001bf) 1lnterval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over -Pull (Ibf) Torok 3,470.0 " 10 I 42.7 42.1 17.50 7,000.0 212 22,000.0 Torok sand 1 4,734.01 06Bit RPM (rpm) . Motor RPM (hrs) (rpm) ,Cum Time hrs Off Bottom Torque Torque Units SO HL ( Torok sand 2 4,852.0 1000lbt) - Torok sand 3 4,852.0 L Hydraulic Calculations 200 93.50 4,000.0 Ftlbs 172 Av DP fttC AV DC fflmin Err ' Torok sand 4 5,630.0 ( ) ( ) Torok sand 5 5,798.0 A casing component contains a null value in ID Torok sand 6 6,008.0 i�H Drill Strin�Components m „ Torok sand 7 6,313.0 ' Top Btm Bend Torok sand 8 6,568.0 1 ' Ite r Drift Conn Sz Conn Sz Btm Angle HRZ 6,605.0 Jts P ( Density OD Top Thrd (in) Thrd Cum Len (ft) (1 Kuparuk Sandstone Mbr 6,800.0' ,, 208 Drill Pipe i I 2 86 (' 4 (1 Grade (in) (in) I 14.00 X95 3 3 4 FH 3,662.30 3.340 4 FH LCU (lower Cret. 6,880.0 8 HWDP ' 248.59 4 27.20 2.750 4 FH 4 FH 793.99 Unconformity) 1 Drilling 36.02 4 2.000 4 FH 4 545.40 Jars - BCU (Base Cret. 6,880.0 Hydraulic Unconformity) 10 HWDP 311.40' 4 27.20 2.750 4 FH 4 FH 509.38 Upper Kingak (M1luveach) 6,880.0 1 XO Sub 2.021 6.28 2.5001 4 FH 4 1/2 IF 197.98 Kugrua siltstone 7,066.0 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 Kugrua sandstone 7,120.0 D.C. Kugrua ironstone !; Kingak Fm 1 NM FLEX 31.08 6 3/4 2.880 4 1/2 IF 4 1/2 IF 165.13 Condudt Pipe, 9 8.8ftKB , „ i. D.0 Csg Run Date OD (in) Grade Wt (Ibs/ft) U 1 Stabilizer 5.46 63/4 116 2.810 41/2 IF 41/2 IF 134.05 r .. 3/19/2007 16 I H 1 65.00 IF 12859 ( . 4 S urface Casi 2 i & Lo 1 MWD Dir 22.42 6.71 . 630 4 1/2 IF 4 1!2 Logging) Csg Run Date OD (in) Grade Wt (Ibs/ft) r BAT 3/31/2007 9 5/8 , L -80 40.00 I, I�, 1 MWD (Dir 9.89 6.76 4.880 4 112 IF 4 1/2 IF 106.17 t • "! TM 1, , ') ti a r 1 ' ' <r ''1 a ; ' � ' " � t# , I a ' 0 im',4 at�, ; I m T fkmnt Da#i 1 Comment � ' � �� i '' #� Man ,u� s + ,� ( - I ' 1 MWD (Dir 9.21 6.79 4.560 4 1/2 IF 4 1/2 IF 96.28 & Logging) PM3 'i 1 MWD (Dir 30.20 6.73 4.630 �( 41 u3' 4 ,, (� 2( ,,- & Logging) A' a * .# ,1 rj " r r! Ili NUKE ski, y / T, r' J ■ 1 MWD (Dir 28.14 6.76∎ 4.6 0 4 1/2 IF 4 1/2 IF 56.87 & Logging) ' FE x,.a G, (l e *di , :: � ; ; I�Griva ,,., :M,;. r _r ro 1-,tv§a rr.e.. .-. _ . � G,,,,_ , irr;, ,: r r ,.. . , „, :u Ar 7. � a rt . .I . .,,1 ___________411) 4110- FEX L.P. - DDR Detail P 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/712007, Report: 17.0, DFS k 1 - Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) 18.20 j 37.10 18.90 Drill String Components �,'' Mtr I' Top Btm Bend Item . Density Drift - Conn Sz Conn Sz Btm Angle I� Jts ! Description Len (ft) ' OD (in) (lbslft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) ( ") r. 1 Float Sub 2.50 6.8 2.750 4 1/21IF 4 1/2 IF 28.731 , ,1 1 Mu d Motor 25.23 7 1 500 4 1/2 IF 4 1/2 IF 2 1 22 ,: IN ellbore N V$ Dir (°) Kick Off Depth (ftKB) Original Hole 258.00 Directional Surveys I I Date Description I 3/27/2007 MWD Surveys oor Y Surve Data ' MD (ftKB) Ind () Azm ( °) T (ftKB) NS (ft) EW (ft) VS (ft) DLS ( °/100ft) Survey Company ,k 5,435.66 1.96 282.54 5, 6.081 -9.27 7.80 0.03 HALLIBURTON 1 5,500.91 1.67 283.79 5,454.45 6.55 -11.28 9.67 0.45 HALLIBURTON N 5,626.74 1.331 289.67 5,580.23 7.48 -14.44 12.56 0.30 HALLIBURTON 5,814.88 1.41, , : ;95 5,768.32 9.15 ' -18.61 16.30 0.07 HALLIBURTON 5,999.281 1.421 297.89 5,952.661 11.141 - 22.701 19.891 0.0511-IALLIBURT0N i 1 iggg 1 11 glgg gg NA R I ii � k 4Pf 66 t, r,..1, l i '11. 11 1 ,I . 10 lik li ro b* 1 .. � < . s wr 1 ».i' M,x's . ,� l � , ' �N i;i � � _. FEX L P - DDR Detail • ''I Page 1/3 Well Name: AKLAQ #6 , � ^ 7� w ;, ` « 1,w , , . i " j I , I � �' �, ' ' : ,, l„ r fir, . r - . ) q II, , i r l .t' ..' � Job Type: Drilling - Original Date: 4/812007, Report: 18.0, DFS: 12.47 Job Spud Date - - -- Rig Release Date - -- Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No Total AFE Amount Total AFE +Sup 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22,574 244.00 , Safety A Target Depth (ftKB rm ) Target Foation Type Date comment _ 7,262.0 Safety Highlight 4/8/2007 'MITIGATE TRIPPING HAZZARDS, NOTE THAT ICE IS WIND BLOWN AND Daly Cost Total Cum CostTeDate � SLICK. I 270,393.42 9,574,600.35 Da �' 1 3, iii ° .. . q . Daily Mud Cost Mud Cum To Date I , nary . i kikk, '' ,l a ir 1. 29,311.17 228,196.25 Weather Lease / Road Cond WNlbexs Condition O ( +)1 Under ( -) AF E ( +1.) Var D ays Depth Start (ftKB) Depth End (ftKB) cloudy -9 deg Good Fluid Losses 0 Operations i 06:00 6,033.0 6,782.0 Drilling at 7001' 12 bbl/hr losses FDepth Prog (ft) Drilling Hours (hrs) , Operations This Report Period 749.Q0 21.00 Drill 8 1/2" hole OpentionsNext Report PeNod Ernie Natte, Dr Lin® . Wiper trip I ' i tp to core, and core Job contact 9 cell p a u °��I� 71me Lo „io, < , „i 9 Foreman � (907) 771 -0536 , 9 1 u 1 , Ops Scheduled Depth End Rig s :'DOyon, Arct WDIf c e li 8.501Drlg Planned �'krne; i(Nrs) Cat Type Phase Major.Op Operation Trouble (ftKB) Comment Rig Supervisor 00:00 Drlg Prod Drilling Drill - Motor No Trbl 6,405.01 DRILL 8 1/2" HOLE Bob Lupton, Rig Manager Op Vert F/ 6033' - 6405' KB Mud Pumps: 1, ardner- Denver,'P ,` 08:30 0.50 Drlg Planned Drlg Prod Drilling Rig Repair / No Trbl 6,405.0 SERVICE RIG & No. Pwr (hp) Rod Diameter (In) Op Service TOP DRIVE 1 900.0 09:00 5.00 Drlg Planned Drlg Prod Drilling Drill - Motor No Trbl 6,529.0 DRILL 1/2" HOLE unersizepn) Stroke (In) VoustkOR(bbus... Op Vert F/ 6405 ' 6529' KB 51/2 9.02 0.066 / WELL TOOK Pump Checks 75BBL FLUID @ 6490 / 1700 UNITS Pres (psi) Slow Spd Stroke (sprit) i' _ .' ; , GAS @ 6430' / 260.0 No I 44 95; BACKGROUND 00 330.0 No 50 (i�" 14:00 0.50 Drlg Trbl Drlg Prod Drilling BOP We ll 6 = 2, Ga., ' ' r Rod D a ' _ ,,, g g g WELL FLOWING / ; No. Pwr (hp) Rod Di (In) 2 900.0 Well Control SHUT IN & VERIFY Liner size (ln) Stroke (In) lVol/StkOR(bbl/s... , k. ' - Irg ii� h,, ' H a m L ,.. �,, 4:1 i,ii, aft' . 0 SICP &OATH 5 1/2 9.02 0.06 BREATHING , i *lie). ' tl „rx �u DOW / BLOW Pump Checks ■ 14II )r i I 'I 1 ' i 1, � 41, ,' ' 1 t r DOWN Stroke ' i ,k ,'9 , $ ",- ( I,I I �t , r 111 H q r ,� I ) �(, ,,: �c + I� .. 4+ %� ' I, t. ( �I t t ,r - . Pres (psi) Slow Spd (s pm) Eff Ir r , 3hS , ° 11 W / AIR (p . p (° ) 11 1 ',, i ' &1 ',, D' ,t h 4G 264.0 No 40 95 1 30 X 0.50 rl Planned Drag Prod Drilling D rill Motor No Trbl 6,554.0' R 1 /2" O Op Vert F( D 6529 8, ' 6554 KB LE Shakers: 320.0 <Descr No ption ?> 50 95 / LOSING MUD @ ; Make Model 17088E /HR 15 :00 1.50 Drlg Trbl DrIg Prod Dri C irc & Cond Lost Circ 6,554.0 BUILD & SPOT ' Shaker Screens Well Mud 5OBBL LCM PILL Screen 1 I Deck No. ° No. Scr Sz X (in) Scr Sz Y (in) 16:30 1.00 Drlg Trbl Drlg Prod Drilling Short Trip Lost Circ 6,554.0 HOIST OUT OF Well PILL 2 STANDS / WASH BACK TO Shaker Checks BTM Dens OF (I Dens O (Ib /gal) Hrs (hrs) V. 1,417:30 6.50 Drlg Planned Drlg Prod Drilling Drill - Motor No Trbl 6,782.0 DRILL 8 1/2" HOLE Make Model Op Vert F/ 6554 -6782' LOSSES SLOWED TO 30 BPH, Centrifuge /Cyclone Checks TOTAL MUD Density Overflow (lb/gal) Overflow Rate (gpm) LOSSES =728 BBL Dens (F (uVgaq UnderFlow Rate (gpm) ' i .,; 6,405.OftKB, i .g07 08 :3 Mud L ost (Hole) / .. Density (lb/gal) pH CEC for Cuttings Pf mUmL) Calcium (mg /L) % Water ( %) ) (bbl) Hours (hrs) Oil Under Fl (%) Dens FD (lb/gal) 10.00 9.0 0.150 160.000 89.0 G� Vis (a /qt) Filtrate (mU30min) Filter Cake (/32") Pm (mUmL) Potassium (mg /L) Percent Oil ( %) Mud Lost (Surf) (bbl) g ) " , r 50 4.4 1 0.100 31,000.000 .g Cdr vendor ! �€ :' PV Over (cp) Gel (10s) (Ibf /10of... Sand ( %) MBT (1b/bbl) Ume (1b/bbl) 011 Water Ratio Mud Vol (Act) (bbl) MUD LAB 1.0 45.00 5.000 0.0 8 . 0 CON DET 1.0 433.80 YP Over (Ibf /10... Gel (10m) (Ibfi100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) BA. DM 2.0 1,575.00 20.000 8.7 7.1 Tech Type Gel (30m) (Ibf/100... T (ft) ( "F) Chlorides (mg /L) HTHP Flit (mU30... Alkalin (mUmL) Whole Mud Add (bbl) Service /L... Polymer 29.000 29,999.999 13.8 `, Max Back Gas ( %) Avg Back Gas ( %) I Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas ( %) Avg Trip Gas ( %) C LAYS EAL 2.0 1, s X Cide 207 6.0 721.68 Silicate (%) 'Electric Stab (V) Comment PAC L 8.0 1,267.20 1 - -- - N D RIL HT+ 10.0 950.40 ;'l r� d , , fi� p .i" � .' i o ��, r 007 „gg 'rAv . " � 0 ' � k , i , � a�„ � . . . �, , q - y. ,4'n. .:' N''�" F k l ��.)i r � e - =.. _a � . s �I,au Page 2/3 FEX L.P. - DDR Detail Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/8/2007, Report: 18.0, DFS: 12.47 • t o jGround Elevation (ft) Orlg KB Elev (ft) Kg-G Distance (k} ) Mud Additive Amounts 18.20 37.10 18.90 . Description Cons... Daily Cost Vendor Mud ' r h9,9,kP: 6,766,Pft <B.4/814 23 :20 Potassium 16.0 955.04 Density (lb/gal) pH GEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) Hydroxide 1 9.95 8.0 0.100 280.000 89.0 750.0 I" arofibre 24.0 603.84 Vis (slgt) Filtrate (mIJ3Omin) Filter Cake (/32 ") Pm (mL/mL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbl) E Z MUD DP 24.0 ' 1 ,405.68 54 8.2 1 29,999.999 181.0 PV Over (cp) Gel (105) (Ibf/100f... Sand (%) MBT (Ib/bbf) Lime (lb/bbl) 011 Water Ratio Mud Vol (Act) (bbt) 1 UVAL L -NUT 25.0 645.00 8.000 0.2 8.5 958.0 F YP Over (Ibf /10... Gel (tom) (Ibf/100... Solids (%) LOS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Barazan D+ 29.0 4,602.59 19.000 8.5 7.5 200.0 Baro -Trol x,;. 38.0 2,414.52 Type Ge1 (30m) (Ibf/100... T (11) ( °F) Chlorides (mg/L) HTHP Alt (mIJ30... Alkalin (mUmL) Whole Mud Add (bbl) Plus Polymer 21.000 29,999.999 495.0 Baracarb 50 48.0 903.36 Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) Baranex 70.0 5,417.30 Baracarb 25 70.0 Silicate ( %) Electric Stab (V) Comment 1,363.60 Baroid 90.0 920.70 Drying Shaker Data ° "' " ' Potassium 215.0 3,500.20 Description Make Model Chl oride HG Dryer Derrick Shaker Screens 'Last Casing Check _.- ... --- -.... Date f Type Deck No. Screen No. Scr Sz X (i Scr Sz Y (in) .,,.,.. ®_ - - ■ 1 1 120.000 Lat 2 1 120.000 s 3 1 120.000 Te t Date Test Type 1 Shaker Checks Formations Dens OF {Ib /gal) Hrs (hrs) �''' Sample Top I� .__ Formation Name MD (ftKB) I Description Make Model Nanushuk Group 912.01p HG Dryer Derrick _Base Permafrost 1 ,020.0 Shaker Screens Nanushuk . 2,795.0 Deck No. Screen No Sc Sz X (in) Scr Sz Y (in 1 e _._._ 1 w 120.000 Nanushuk topset topset sst 3,388.0 2 1 120.000 Torok sand 1 Torok 3,470.0 4,734.01 3 - - 1 120.000 Torok sand 2 4,852.0 Shaker Checks .:h Dens uFil §al) Hrs (hrs) Torok sand 3 5,090.0 . - ' Torok sand 4 5,630.0 Description Make -Model Torok sand 5 5,798.01 HG Dryer 1 Derrick ; Torok sand 6 6,008.0 Shaker Screens Torok sand 7 6,313.0 Deck No. Screen No. Scr Sz X (In) Scr Sz Y (in) Torok sand 8 6,568.0 1 1 120.000 HRZ 6,605.01' 2 1 120.000 Kuparuk Sandstone Mbr 6,800.0 3 1 120.000 LCU (lower Cret. 6,880.01 Shaker Checks Unconformity) ' Dons L)F (Ib /gal) Hrs (hrs) BCU (Base Cret. 6,880.0 Drill Strings:, BHA #2, Steerable Unconformity) Bit Run Make Bit Inventory Bit Type Item Cost Upper Kingak (Miluveach) 6,880.0 2 Hughes 8 1 /2in, HCM605Z, 7106613 PDC I 22,833.00 Kugrua siltstone 7,066.0 IADC Bit Dull TFA (Intl Noz) (In') !BHA ROP (ttlhr) Nozzles ( /32 ") IADC codes Kugrua sandstone ' 7,120 :0 i 0- 1- NO -A -X- 0NO -CP 0.71 35.8 I 14!14/13/14/13 M 3 2 3 Kugrua ironstone 6,033.0 . 6,78 a « 1 . �:,'( , r' , Kingak Fm. 1 o,! BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) ,.. & . Q :` 2 4,681.00 3,200.0 510 202 245 Csg Run Date OD (in) Grade Wt (ibs/ft) WOB (1000lbf) Interval ROP (ft/hr) Total ROP (fUhr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over -Pull (Ibf) 3/19/2007 16 H -40 65.00 8 35.7 40.9 21.00 8,00 0.0 245 43,000.0 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000Ibf) kk i ` " ' d `. 290 200 114.50 4,000.0 Ftlbs 180 osg Run Dat OD (i G rade lwt (lbs/ft) - -- - -. - 3/31/2007 9 5/8 L -80 � 40.00 Hydraulic Calculations` AV DP (ft/min) AV DC (ft/min) _...,..e _,.,..., Err ... -- , = x ,41 m . ; i.r . , . "( A casing component conta a null value in ID Drill String Components �` Mtr Top Btm Bend .,...[«, Item Density Drift Conn Sz Conn Sz Btm Angle (ft) OD (in) (Ibs /ft) Grade ID On) (In) (in) Top Thrd (in) Thrd Cum Len (ft) l') Jts Description ill 208 Drill Pipe Len e 2,868.... 41 14.00 X95 3.340 I 4 FH 4 FH 3,662.30 8 HWDP 248.59 4 27.20 2.750 4 FH 4 FH 793.99 k � ; i ILI dilllo x? , HI1mk w !P , " oti,.,d .l w . ILu,. ,?IOLA" . 1. 1 41, a �: '44'4., , ;`. , r ^s . ?, � r ;ALA 0 • , !' EX L.P. - DDR Detail Page 3/3 Well Name: i ,' ' ,,, ' „ r (� , ' i i ,- U ' „ * i II I 1 4 'R,u:'� i ` ':' ( k t 4 ` Pi x .I r', 'i `` ,. i i l ' i tF ,4 y illli 11; i 1 i'�I � 2 i �� IbIll� �� 141,0110ri , 1T 1,00, Jr w nP� ,, b0'''e r. 1 hw „ :,., i 1 Im I� �' ( ( II i- h.,� ' :r d „r (( ! ,:� 11111 H I,,,. ;., , #„i 1 a.p„ ,i b is :I (I Xt I „rd Job Type: Drilling - Or Date: ' 418/20x`7 , Report: ` ''!18.0, D i" ,( -- - -- -- - Ground Elevation (ft) (trig KB Elev (ft) KB- Ground Distance (ft) IF 410 18.20 1 37.10 18.90 ' Drill String Components -_ log I logl Mtr Top Btm Bend Item. :.Density Drift Conn Sz Conn Sz Btm. Angle. , , Jts Description Len (ft) OD (in) (Ibslft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (�) t "11 1 Drilling 36.02 4 2.000 4 FH 4', FH 545.40' 11111 Jars - Hydraulic 10 HWDP 311.40 4 27.20 2.750 'it 4 FH 4 FH 509.38 1 1 11 =: 1 XO Sub 2.02 6.28 2.5001 4 FH 4 1/2 IF 197.98 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 I` ,D.C. 11NM FLEX 31.08 6 3/41 12.880 4 1/2 IF 4 1/211F 165.13 4 1 1D.C. i 1 Stabilizer 5.46 6 3/4 ) „ 2.810 4 1/2 IF 4 1/2 IF 134.05 y4 , 1 MWD (Dir 22.42 6.71 I 4.630 4 1/2 IF 4 1/2 IF 128.59 ry & Logging) I BAT ' 1 MWD (Dir 9.89 6.76 4.880 4 1/2 IF 4 1/2 IF 106.17 & Logging) G; M (Dir 11P 3D Dir 9.21 6.79 4.560 4 1/2 IF 4 1/2 IF 96 ; I & Logging) 1 MWD (Dir 30.20 6.73 4.630 4 1/2 IF 4 1/2 IF 87.07 1 & Logging) , NUKE 0 1 MWD (Dir 28.14 6.76 '4.630 41/2'IF 41/2'IF 56.87 & Logging) . 1 Float Sub 2.50 6.8 2.750 41/2 IF 41/2 IF 28.73 1 Mud Motor 25.231 7 1.500 4 1/2 IF 1 4 1/2 IF 26.23 1.22 W lbores 1�II��I�I Jj e 4 '"r''1!;-',..'..; ( , 1 � 4" o,y_ J / n t=',, -, i r ', J 6 f q,,,,., 4 *.f , p h KB) Wellbore Name VS Dir ( °) Kick Off Dept (ft Original Hole 258.00 ___1 Directional Surveys _ Date Description 3/27/2007 MWD Surveys Survey Data - MD (FtKB) Incl ( °) Azm ( °) TVD (ftKB) NS (ft) EW (k) VS (ft) DLS (1100ft) Survey Company 6,187.37 1.46 292.1411 6,140.69 13.14 -26.98 23.66 0.08 HALLIBURTON Ii1 6,374.61 1.36 295.66 6,327.88 15.00 -31.19 27.39 0.07 HALLIBURTON 1 I 1 i , i litt lo .° ..,;:!: ....: 0 ,,„ : : , .,,,,, I . a l'ii: a ...a ( ar `.' +..,.,. r .littg ." , -,,, . , 4,,,,4,..,1g14:1,,,,",,, . I 1„1:44 ' Oar ..,,, ,, „r,A,G . �N * 1 * 0 0 � Page 1/3 Talisman Energy Canada - DDR Detail Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/9/2007, Report: 19.0, DFS: 13.47 ill v nd Distance (ft) AFE No. Total AFE Amou ii it' -Job Spud Dat Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB- Grount Total AFE +Sup 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244 00 ,' Safety Target Depth (ftKB) Target Formation 1 ■111 Type Date Comment rl Safety Highlight 4/9/2007 REFLECTIVE GEAR AND TRAFIC AWARNESS Daily Cost Total Cum Cost To Date 'i��i 258,267.56 9,736,017.51 �''1 De th mry , u Le mai /1 I�i/6I a 1a�I61I) II •1 n Gr,iioil Da ily Mu Co st Mud Cum To Date - Weather Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( + / -) Var Days cloudy - 11 deg Good Casing set at 2072' 0 18,485.31 246,681.56 1, Operations @ 06:00 Depth Start (ftKB) Depth End (ftKB) 411j Trip out to BOP test 6,782.0 7,125.0 Progress (ft) Drilling Hours (hrs) ; a'i H Operations This Report Period 343.00 12.00 ,11j Drill to core point, wiper trip, trip for core 4� awMq Operations Next Report Period ' ! � rt - Bop test and core Pk Forema►, ont�ac ' I'�� ilii" , "t1 1 an,y "ni 1171 @111�1I ipi2@1I111117iiI1"r49ii17111, 'viii" Job Contact Cell Phone Time Log Ernie Natte, Drilling (519) 427 - 7406 Start our Ops Scheduled Depth End Foreman Time (hrs) '.. Cat Type - Phase Major Op Operation Trouble (ftKB) ..Comment 00:00 12.00 Drlg Planned Drlg Prod Drilling Drill - Motor No Trbl 7,125.0 DRILL 8 1/2" HOLE Rigs: Doyon, Arctic wolf Op Vert F/ 6782' - 7125' KB Rig Supervisor Bill Lupton, Rig Manager 12:00 1.00 Drlg Planned Drlg Prod Drilling Circ & Cond No Trbl 7,125.0 CIRCULATE AND Mud Pumps: 1, Gardner-Denver, PZ -9 Op Mud CONDITION MUD, No. Pwr (hp) Rod Diameter (in) MONITOR WELL 1 900.0 13:00 1.00 Drlg Planned Drlg Prod Drilling Circ & Cond No Trbl 7,125.0 PULL UP 5 STDS Liner Size (in) Stroke (in) Vol /Stk OR (bbllstk) Op Mud AND PUMP SLUG, 5 1/2 9.02 0.066 MONITOR WELL Pump Checks 14:00 2.50 Drlg Planned Drlg Prod Cond Short Trip No Trbl 7,125.0 SHORT TRIP TO Strokes Op Trip 5500', MONITOR Pres(psi) Slow Spd (spm) Ef(A) WELL 320.0 No 44 95 16:30 1.00 DrIg Planned Drlg Prod Cond Short Trip No Trbl 7,125.0 RUN BACK TO 398.0 No 55 95 Op Trip BOTTOM AT Mud Pumps: 2, Gardner - Denver, PZ -9 CONTROLED No. Pwr (hp) Rod Diameter (in) ,, SPEED, MONITOR 2 900.0 4111 WELL Liner Size (in) Stroke (in) Vol /Stk OR (bbl /stk) 5 1 /2 9.02 0.066 1 7:30 4.00 Drlg Planned Drlg Prod Cond Circ &Cond No Trbl 7,125.0 BREAK Op Trip Mud CIRCULATION, Pump Cheeks Strokes REAM TO Pres (psi) Slow Spd (spm) Eft ('/ BOTTOM, 315.0 No 44 95 REDUCE PUMP 398.0 No 55 95 RATE AND MONITOR WELL, Shakers: <Description ?> SPOT LCM PILL Make Model 21:30 2.50 DrIg Planned DrIg Prod Drilling Trip Out No Trbl 7,125.0 PULL 5 STDS, Shaker Screens PUMP 30 BBL Screen Op Deck No. No. Scr Sz X (in) Scr Sz Y (in) Iiii SLUG, MONITOR WELL (STATIC), BLOW DOWN , Shaker Checks TRIP 30 STDS Dens OF (lb/gal) Dens OF (Iblgal) Hrs (tars) OUT. Mud Checks: 7,12 .163 Date ?' !4,44.14,4,4;„ rf. Make 04 Model Density (lb/gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) %Water (%d Mud Lost (Hole) (bbl) 9.95 9.5 0.250 80.000 89.0 Centrifuge /Cyclone Checks Vis (s /qt) Filtrate (m)..l30min) Filter Cake (/32 ") Pm (mL/mL) Potassium (mg /L) Percent 011 (% ) Mud Lost (Surf) (bbl) Density Overflow (lb/gal) Overflow Rate (gpm) 59 5.8 1 0.600 27, 000.000 PV Over (cp) Gel (10s) (Ibf /100ft') Sand (%,) MBT (1b /bbl) Llme (1b /bbl) 011 Water Ratio Mud Vol (Act) (bbl) Density Underflow (lb/gal) Underflow Rate (gpm) 7.000 0.1 7.5 YP Over (lbf/10... Gel (10m) (lbf /100... Solids ( %) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) Hours (hrs) 1 Under Fl (%) 1 Dens FD (lb/gal) _ 20.000 9.0 7.8 Type Gel (30m) (Ibr/100... T (fl) ( °F) Chlorides (mg/L) HTHP Filt (mL/30... Alkalin (mLlmL) Whole Mud Add (bbl) Mud Additiv iii m ount s ', ,,, � 4411°' Polymer 24.000 26,000.000 16.6 Description Cons... Daily Cost Vendor Silicate (%a Electric Stab (V) Comment MUD LAB 1.0 45.00 Barazan D+ 1.0 158.71 BA. DM 2.0 1,575.00 Tech Service /La... • N -DRIL HT+ 2.0 190.08 EZ MUD DP 2.0 117.14 Potassium 6.0 358.14 Hydroxide Aldacide G 8.0 1,327.44 Report Printed: 4/10/2007 P F created with pdfFactory tr vers www.pdffactory.com Talisman Energy Canada - DDR D= "ai Ii' 'i ;, ` 3 m Well Name: AKLAQ #6 n i 11 i H i , , ry z , � ,� I l �i Job Type: Drilling - Original Date: 4/9/2007, Report: 19.0, DFS: 13.47 0 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) M Additive An10U mounts ".' 18.20 37.10 18.90 Description Cons... Daily Cost Vendor Mud Checks :'7,125.0ftKB, <Date ?> CON DET 8.0 3,470.40 Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) %Water (I ) Mud Lost (Hole) (bbl) Baro -Troi ' 12.0 762.48 9.95 8.5 0.200 80.000 89.0 63.0 Plus Vis (slgt) Filtrate (mL/30min) Filter Cake (/32 ") Pm (mUmL) Potassium (mg/L) Percent Oil ( %) Mud Lost (Surf) (bbl) Barabiok 12.0 433.44 59 4.5 1 28,000.000 25.8 Baracarb 5 15.0 284.55 PV Over (cp) Gel (10s) (Ibf /100ft') Sand ( %) MBT (lb /bbl) Llme (Ib /bbl) 011 Water Ratio Mud Vol (Act) (bbl) 7.000 0.1 7.5 1130.9 PAC - L 15.0 2,376.00 YP Over (Ibf /10... Gel (10m) (Ibf /100... Solids (%a LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Baracarb 50 15.0 282.30 20.000 9.0 200.0 Baranex 22.0 1,702.58 Type Gel (30m) (Ibf /100... T (n) (F) Chlorides (mg /L) HTHP Filt (mU30... Alkalin (mUmL) Whole Mud Add (bbl) Baracarb 25 50.0 974.00 Polymer 24.000 27,000.000 13.8 100.0 Barofibre 55.0 1,383.80 Silicate ( %d Electric Stab (V) Comment Potassium 72.0 1,172.16 Chloride Drying Shaker Data Description Make Model ; Baroid 183.0 1,872.09 HG Dryer Derrick Last sing Check Shaker Screens Date Type Deck No. Screen No. Scr Sz X (in) Scr Sz Y (In) 1 1 120.000 2 1 120.000 Last BOP Check Test Date Test Type 3 1 120.000 Shaker Checks Formations Dens UF (Ib /gal) Hrs (hrs) Sample Top MD Formation Name (ftKB) Description Make Model Nanushuk Group 912.0 HG Dryer Derrick Base Permafrost 1,020.0 Shaker Screens Nanushuk topset sst. 2,795.0 Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) Nanushuk topset sst. 3,388.0 1 1 120.000 Torok 3,470.0 2 1 120.000 Torok sand 1 4,738.0 3 1 120.000 Conductor Pipe, 98.8ftKB Shaker Checks Csg Run Date OD (in) Grade (Wt (Ibs /ft) Dens OF (lb/gal) Hrs (hrs) 3/19/2007 16 H - 1 65.00 Description Make Model Surface Casing, 2,072.2ftKB HG Dryer Derrick Csg Run Date 0D (in) Grade 1 Wt pbs/ft) 3/31/2007 9 5/8 , L -80 40.00 Shaker Screens Deck No. Screen No. Scr Sz X (In) Scr Sz Y (in) Cement 1 1 120.000 Cmnt Des Comment 2 1 120.000 3 1 120.000 Shaker Checks Dens UF (lb/gal) Hrs (hrs) Drill Strincs: BHA #2 Steerable Bit Run Make Inventory Bit Type Item Cost 2 Hughes iBit 81/2in, HCM605Z, 7106643 PDC 22,833.00 IADC Bit Dull TFA (Inc! Noz) (in') BHA ROP (ft/hr) Nozzles (/32 ") IADC Codes 0.71 39.7 14/13/13/14/14 M -3 -2 -3 6,782.0 - 7,1253 it l ,B Ors!It oli C� BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) 2 5,024.00 2,300.0 440 209 250 WOB (10001bf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) Max. Over - Pull (lbf) 10 28.6 39.7 12.00 8,000.0 250 41,000.0 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000Ibf) 290 200 126.50 4,000.0 Ftlbs 180 Hydraulic Calculations AV DP (ft/min) AV DC (ft/min) Err 19.3 463.8 Unable to calculate annular pressure drop because pressure drop data is missing from AV calc Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm ' Angle Jts Description Len (ft) OD (in) (Ibs /ft)' Grade ID (In) (in) (in) Top Thrd tin) Thrd Cum Len (ft) r) 0 192 Drill Pipe 2,868.31 4 14.00 X95 3.340 4 FH 4 FH 3,662.30 8 HWDP 248.59 4 27.20 2.750 4 FH 4 FH 793.99 1 Drilling 36.02 4 2.000 4 FH 4 FH 545.40 Jars - 1 Hydraulic Report Printed: 4/10/2007 PDF created with pdfFaciory trial version www.pdffactory.com Talisman Energy Canada - DDR Detail Page 3/3 Well Name:, AKLAQ #6 Job Type: Drilling - Original Date: 4/9/2007, Report: 19.0, DFS: 13.47 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) 18.20 37.10 18.90 Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (In) (Ibs /ft) Grade ID (In) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (1 I 10 HWDP 311.40 4 27.20 2.750 4 FH 4 FH 509.38 1 XO Sub 2.02 6.28 2.500 4 FH 4 1/2 IF 197.98 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 D.C. 1 NM FLEX 31.08 63/4 2.880 41/2 IF 41/2 IF 165.13 D.C. 1 Stabilizer 5.46 6 3/4 2.810 4 1/2 IF 4 1/2 IF 134.05 1 MWD (Dir 22.42 6.71 4.630 4 1/2 IF 4 1/2 IF 128.59 & Logging) BAT 1 MWD (Dir 9.89 6.76 4.880 4 1/2 IF 4 1/2 IF 106.17 & Logging) TM 1 MWD (Dir 9.21 6.79 4.560 4 1/2 IF 4 1/2 IF 96.28 & Logging) PM3 1 MWD (Dir 30.20 6.73 4.630 4 1/2 IF 4 1/2 IF 87.07 & Logging) NUKE 1 MWD (Dir 28.14 6.76 4.630 4 1/2 IF 4 1/2 IF 56.87 & Logging) FE 1 Float Sub 2.50 6.8 2.750 4 1/2 IF 4 1/2 IF 28.73 1 Mud Motor 25.23 7 1.500 4 1/2 IF 4 1/2 IF 26.23 1.22 ill Wellbores Welibore Name VS Dir ( °) Kick Off Depth (ftKB) Original Hole 258.00 Directional Surveys Date Description 3/27/2007 MWD Surveys Survey Data MD (ftKB) Inc! ( °) Azm ( °) TVD (ftKB) NS (ft) EW (ft) VS (ft) DLS (°/100ft) Survey Company 6,750.80 1.30 301.04 6,703.96 19.13 -38.87 34.04 0.04 HALLIBURTON 6,873.26 1.18 311.87 - 6,826.40 20.69 -41.00 35.80 0.21 HALLIBURTON ' (i 41111 , _____i Report Printed: 4/10/2007 P F cr e ated with pdfFactory trial version www.- pdffactorv.com FEX L.P. - DDR "Detail - Page 1/ - „, Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/10/2007, Report: 20.0, DFS: 14.47 '' Job Spud Date - - -- - Rig Release Date Ground Elevation (ft) Orlg KB Elev (ft) KB- Ground Distance (k) AFE No. Total A F E Amount Total AFE +Sup 18 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 ,,;, 3/27/200712:45 4/23/200716:00 Safety Target Depth (ftKB) Target Formation g i i Type Date Comment 7,262.0 Safety Highlight 4/10/2007 NO SMOKING ANYWHERE BUT THE SMOKE SHACK, GAS DETECTION IN Dairy Cost Total Cum Cost To Date ' CELLAR 251,038.16 10,083,906.07 r., l Daily Mud Cost Mud Cum To Date II ° ' t � � t . d.�'� ti 1, 8,755.91 _ 255,437.47 Weather Lea /Road Conditions We l i bore C Over ( +) I Under ( -) AFE ( +1_) Var Days Depth Start (ftKB) Depth End MIL Clear + 3 Deg. Good Fluid Losses 0 Operations © 06:00 t , TRIP IN CORE BBLS - 7,125.0 7 125 0 p a Depth Progress (ft) Drilling Hours (hrs) il 0.00 Operations Thls Report Period Trip out to Smart Tools /Down Load Info / Rack Back Tools (Slip & Cut Drill Line /Press. Test Bops As Per t • t� „ „ AOAGCC/ JIM REGG Waved Wlttness to BOP TEST Job Contact f'h i 1 Operations Next Report Period Ernie Natte, Drilling (907) 771 -0536 t ki T est BOP'S / Make Up Core BBLs / RIH & Core 60' / Hoist to Recover Same , Ti e ' oc� ' 1 1r,� .. Rigs:- „ > 11 ' l g 1g .t) g ii> .. I ,' li u • - +8 v =w• w . ...e . i "" , - ., -` 00:00 7 50 Eval Planned Drlg Prod , " --- Bob Trip Out No Trbl 7,125.0 1, PULL OUT O " Op HOLE SLOW TO No. , purr) • � i Gardner-D d Diame (in) TT NOT SWAB 1 900.0 07:30 0.50 Eval Planned DrIg Prod Coring Trip Out No Trbl 7,125.0 FLOW CHECK AT LinerSize(in) Stroke(in) VoIIStkOR(bbIIs... 1 Op THE SHOE 5 1/2 9.02 0 066 08:00 2.50 Eval Planned Drlg Prod Coring Trip Out No Trbl 7,125.0 PULL OUT OF Pump Checks Op HOLE CLEAN StrokBg CLAY OFF BHA Pres (i: slow' =,,It ttr".9 . * (i - aff,(%) 10:30 0.50 Eval Planned Drlg Prod Coring ( Trip Out No Trbl 7,125.0 L /D'JARS AND No Op CROSS OVERS Mud Pumps: 2, p , r `i'r ..r, PZ -9 11:00 1.00 Eval Planned Drlg Prod Coring Trip Out No Trbl 7,125.0 LAY DOWN BHA No. 2 P (900.0 Rod Diameter (in) I Op AND CLEAN OFF Liner Size (In) Stroke (In) VollStk OR (bblls... iti (CLAY 51/2 i 9.02 0.066 fg i 12:00 1.00 Eval Planned Drlg Prod Coring Trip Out No Trbl 7,125.0 PULL NUKES pum • Checks Op UNLOAD strokes SOURCES Pres (psi) Slow Spd (spm) Eff ( /) ,; 13:00 2.50 Eval IPianned Drlg Prod Coring Trip No it Tri Out No Trbl 7,125.0 DOWNLOAD MWD Op INFO er lescription ? >.. I„ 15:30 1.50 Eval Planned Drlg Prod Coring Trip Out No Trbl 7,125.0 LAY DOWN MWD, Make M odel Op DC, MOTOR AND BIT. Shaker Screens 1 7:00 1.50 Eval Planned Prod Coring R Re air! No 7, 125.O Screen g 9 g p Deck No . No . Scr Sz X (in) Scr Sc Y (in) Op Service 120' OF DRILL LINE Shaker Checks 18:30 1.50 Eval Planned Drlg Coring Rig Repair / No Trbl 7,125.0 SERVICE TOP Dens of (ib /gap Dens UP pb/gal) _ Op Service DRIVE AND ADJUST TORQUE i' k) �; TUBE Make yF Model 20:00 1.50 Eval Planned Drlg Prod BOP / BOP No Trbl 7,125.0 PULL WEAR . - -_ -..- Op WH / BUSHING AND Centrifuge /Cyclone Checks Dr1110Uf INSTALL TEST Density Overflow (Ib/gal) Overflow Rate (gpm PLUG Dens OF (lb/gal) Undernow Rate (gpm) `_ 21:30 2.50 Eval Planned DrIg Prod BOP / BOP No Trbl 7,125.0 TEST BOP Op WH / TEST #1 ANNULAR Hours (hrs) IOII Under Fl (%) Dens FD (lb/gal) Drillout 250 LOW, 2500 HIGH 10 MIN, �' ,, * e li , e Ii .*mounts TEST, ALL OTHER Description Cons... Daily C Vendor IH C L 6 0 50 40 TEST ARE 250 PA 9 F O R TEN MI IGH MUD LAB 1.0 45.00 FOR TEN MIN. #2 UPPER PIPE B A . DM 2.0 1,575.00 r " 6'' ;fr 1 11, i Te „I u" a, 1 + RAMS ON FLOOR y 1 � ,1 * i i Service /L... i� j ,1 1 mil r , ' & ' r r ' } BALL AND r t "' "I �'' : MANUAL CHOKE, Barazan D+ 3.0 476.13 i1+ a 1 �1r , �I GI ; TEST #3 UPPER ,:, fib Fx ��, ,iia � ;,,,(({,Iti , � y, � 7 ' Baracor 700 5.0 723.55 ,I y „ 1,' I, „ti �i (, ,,,� w ' PIPE ON DART, : * p: ;ic , E CHOKE AND KILL Potassium 6 0 358.14 i , -k. t, l'I ,� � II o �G �1' r C ' a k HCR'S Hydroxide g I,C ;,,1; r( (',1'' ' ' " � y Baracarb 25 22.0 428.56 �„ s B f r vIi "„ 'rk��� , �31ru �.? G, ,� „.ra1 ; „I , Baroid 22.0 225.06 • ,1 1 .....,,1 ...� . -... .. . .. - - - -- -- :Baranex 23.0 1,779.97 ,r. %�, t ` a �, e II :,�I Ih. = Re ort Printe% t' 6 d .fi ,� : 4 . , r �'ti 5 I� (I ,41,,,,,,,,,„„,,,,,„,i, ,_ P.) q xII c^ il� a�ItHli 4kw ,61, ri11,I'.,,a, Ilt,i'.... wit a! i! w a- a, ," >,,,, ,�,I,p,��«v- *,I:II1kur, o k �t� „.!..,� �e.. *tlrtm GT it T 6,n FEX L.P. - DDR Detail Pa ge�h ,�, � Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/1012007, Report: ''20.0, DFS: 14.47 0 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Mud Additive Amount = `f ,, , > , � .44 18 37.10 18.90 Description Cons... Daily Cost Vendor j [1 1 ks: „ Baracarb 50 37.01 696.34 Denslty (Ib/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg/L) % Water ( %) Mud Lost (Hole) (bbl) Potassium 92.0 1,497.76 , Chloride ` °" Vis (s /qt) Filtrate (mU30min) Filter Cake (132") Pm (mUmL) Potassium (mgIL) Percent 011 (%) Mud Lost (Surf) (bbl) „ Last Casing Check PV Over (cp) Gel (105) (Ibf /loot... Sand ( %) MBT (1b/bbl) Lime (Ib(bbl) 011 Water Ratio Mud Vol (Act) (bbl) Date Type YP Over (Ibf /10... Gel (10m) (Ibf /100... Solids (%) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) I Last BOP Check 1 , 1 , t' " „ �, Test Date Test Type Type Gel (30m) (Ibf/100... T (f1) ("F) Chlorides (mg/L) HTHP Filt (mJ30... Alkaitn (mUmL) Whole Mud Add (bbl) % Avg Back Gas (%) Max Conn Gas Formations Max Back Gas l ) 9 t 1 (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) Sample'TOp Formation Name MD (ftKB) Silicate %) Electric Stab (V) Comm Nanushuk Group 912.0 llil - 1 ! r' l ` " Nanushuk topset sst. 2,795.0 Base Permafrost 1,020.0 - � -- Descriptlon Make Model Nanushuk topset sst. 3,388.01 HG Dryer Derrick Torok 3,470.0 Shaker Non Screen No. Scr Sz X (In);. Scr Sz Y (in) Torok sand 1 4,734.01 1 1 120.000 Torok sand 2 4,852.0 2 1, 120.000 Torok sand 3 5,090.0 ti I 3 1 120.000 [Torok sand 4 5,630.0 Shaker Checks Torok sand 5 5,798.0 Dens OF (lb/gal) Hrs (hrs) Torok sand 6 6,008.0 T oro k san 7 6,313.0 Description Make Model Torok sand 8 6,568.0 HG Dryer Dernck . HRZ 6,605.0 Shaker Screens _ _ Kuparuk Sandstone Mbr 6,800.0 Deck No Screen No Scr Sz X;(in) S S z Y (in) - LCU (lower Cret. 6,880.0 iii 1 2 1 1 120.000 120.000 Unconformity) BCU (Base Cret. 6,880.0 _ 3 1 120.000 Unconformity) Shaker Checks Dens uF (1b/gal) Hrs (hrs) Upper Kingak (Miluveach) 6,880.0 Kugrua siltstone 7,066.0 Description Make Model Kugrua sandstone 7,120.0 HG Dryer jDerrick Kugrua ironstone Shaker Screens Kingak Fm. Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) U „ ° , dUctor Pipe, 98 ftKB 1 1 120.000 loss Run Date (OD (In) Grade [Wt (Ibslft) 2 1 120.000 3/19/2007 1 16 H -40 1 65.00 1 3 1 120.000 , dr . Surface Ca ` - , Shaker Checks Csg Run Date OD (In) Grade Wt (Ibslft) Dens uF (IbfgaI) Hrs (hrs) 3/31/2007 9 5/8 L -80 40.00 Cement 4 ,Ii,� p - I °.p„ Cmnt Des Comment 5tnngs:' BHA #2, Steerabl ,, ' Blt Run Make Bit inventory Blt Type item Cost 2 1 Hughes 8 1 /2in, HCM605Z, 7106613 PDC I 22,833.00 IADC Bit Dull ITFA (lncl Noz) (In') 1 BHA ROP (f /hr) Nozzles (132 " ) IADC Codes 0- 1- NO- A- X- 0 -NO -CP 1 0.71 35.8 14/14/13/14/13 M -3 -2 -3 1 -47,125.0 - 7,125,0 ftKB .— BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... 'Max. Hook Load (Ibf) 2 5,0 209 250 WOB (10001bf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over-Pull (lbf) 39.7 0.00 8,000.0 250 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units ISO HL (1000Ibf) 0 126.50 4,000.0 Ftlbs 180 H draulic Calculations ,„ 6 — AV DC ft/min Err A casing component contains a null value in ID ■ Drill String Components Mtr Top Btm Bend , Item Density Drift Conn Sz Conn Sz Btm Angle = - Jts Description. Len (ft) OD (in) (Ibslft) Grade ID (in) (In) (In) . Top Thrd . (in) Thrd Cum Len (ft) (1 208 'D 2 Drill WDP Pipe 1 2 68.... 41 14.00 X95 � 3.340 4 FH 4 FH 3,662.30 4 27.20 2.750 4 FH 4 FH 793.99 1 1i r Report Printed: 5/3/2007 0 0 FEX L.P. - DDR Detail Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/1012007, Report: 20.0, DFS: 14.47 0 Ground Elevation (ft) OrIgK6 Elev (ft) KB-Ground Distance (ft) 18.20 1 37.10 1 18.90 Drill String Components Mir Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle , Jts Description Len (ft) OD (in) (lbs/ft) ; Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (`) 1 Drilling 36.02 4 2.000 4 FH 4 FH 545.40 i Jars - 1 Hydraulic 1 1 10 !HWDP 311.40 4 27.20 I 2.750 4 FH 4 FH 509.38 1 XO Sub 2.02 6.28 2.5001 4 FH 4 1/2 IF 197.981 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 D.C. ,j `4 1 NM FLEX 31.08 6 3/4 I 2.880 4 1/2 IF 4 1/2 IF 165.13 D.C. 1 Stabilizer 5.46 6 3/4 2.810 4 1/2 IF 4 1/2 IF 134.05 , 1 MWD (Dir 1 22.421 6.71 i 4.630 4 1/2 IF 4 1/2 IF 128.59 & Logging) i lI BAT 1 1 MWD (Dir 9.89 6.76 _" °t r ; �+ 4 1/2 IF 106 _ & L ogg in g) ' OT, 1 MWD 9.21 6.79 Dir ( 4.560 4 1/2 IF 41/2'IIF 96.28 I i ll & Logging) PM3 I 1. 1 MWD (Dir 30.20 6.73 n " 4 630 4 1/2 IF i ; 4 1/2 IF 87,07; U, & Logging) 1 ire` 4 °', t. Iu .4,i:w ew :;:t>s" ° tt ` °te � ( (Dir NUKE - " ', 1 MWD Dir 28.14 6.76 4.630 41/2 IF 41/2 IF 56.87 & Logging) �tl FE ,, 1 Float Sub 2.50 6.8 2.750 4 1/2 IF 4 1/2 IF 28.73 1 Mud Motor 25.23 7 1 .500 41/2 IF 4 1/2 IF 26.23 1.221 $ #. ..4 az a . � ... . lm - j " f thi Wellborn Name VS Dir (°) Kick Off Depth (SKB) Ig , Original Hole 258.00 I II if Directional Surve s : , Date Description , ,I .-1. 3/2712007 MWD Surveys iI Surve Data _T ;, 6,99 8.65 s " , P7:7 ;= o p CI (° 1.081 306.80 - Azm ( °) TVD (ftKB) NS (ft) 6,951.761 22.261 EW (ft)': -42.911 37.34 0.11 HALLIBURTON VS (ft) DLS ( °1100ft) Survey Company "I I _ I ti IS lill i , i s ICI ill , ,>. f r t sa , f. ,tl qu 11�'„ ( , . Report Printed 007 kkgti 444,544k., . a ' 4 mi' I . ,I . € aC� + �N . , 4.,,t1 , ihi,, 4 10 -411) FEX L.P. - DDR Detail Page 1/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 411112007, Report: 21.0, DFS: 15.47 ill Job Spud Date Rig Release Date (Ground Elevation. (ft) Orig KB Elev (ft) 1KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup I11 3/27/2007 12 :45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244 00 ., Safety Target Depth (ttKB) Target Formation Type Date Comment 7,262.0 Safety Highlight 4/11/2007 THERE WILL BE ALOT OF TRAFFIC WITH UP COMMING DEMOBE STAY Daly Cost Total Cum Cost To Date .. ALERT AND THERE WILL BE ALOT OF TRAFFIC WITH UP COMMING 252,522.73 10,336,428.80 DEMOBE. STAY ALERT AND TRY TO WALK OUTSIDE OF MAIN TRAFIC ,Daly Mud Cost Mud Cum To Date AREAS 1 12,690.48 268,127.95 rt Depth Start (ftK Depth End (ftKB) Weather Lease ` ^ I 7,125.0 7,125.0 Daily Summary , fl , ry$ Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( + / -) Var Days pth Pr . e ___.._ snow -10 deg Good Fluid Losses .5 Depth Pro 0O (ft) Drilling Hours (hrs) Operations © 06:00 , n ii0 l I : , x ` Core at 7134' . )', ,,,,:i.0 Operations This Report Period i Job Contact C ell P hone BOP test and trip in to core Ernie Natte, Drilling I (907) 771 -0536 Operations Next Report Period Foreman Pull out of hole with core make up BHA igs: Doyon, Arctic Wolf = "; I '§ r a? r Rig Supervisor 00:00 4 Eval Planned Depth End Time i , Bob Lupton RIg Manager Start Dur Ops Scheduled Type Phase Major Op Operation Trouble (ftK6} Comment i mud • U :�, er- Denver, PZ -9 anned DrIg Prod BOP / BOP No Trbl 7,125.0 TEST #4 TOP No. Pwr (ho Rod Diameter (m) Op WH / DIVE MANUAL ON 1 900.0 Drillout CHOKE 1,5,9,14. Liner size (in) Stroke (in) VoUStk OR (bbus . I TEST# 5 TOP 5 1/2 9.02 0.066 Iii I DRIVE HYDRAULIC ON Pump Checks CHOKE VALVES 4, Strokes 8, 12, 13. TEST #6 I Pres(psi) slowspd (spm) Err(r> TOP RAMS, No j�l CHOKE VALVES 3, Lid Pumps: 2, Qi enver, PZ -9 7, 11. TEST #7 No. Pwr (hp) Rod Diameter (in) BOTTOM RAMS 1_. 2 900 0 !TEST #8 BLIND [Liner Size (In) tStroke (in) Vot/Stk OR (bbl /s... RAMS. TEST #9 1 5 1/2 9.02 0.066 0 KOOMY TEST. pump Checks I , strokes 1 Pres (psi) Slow Spd (spm) ,�;,,, ',;,,, 04:00 1.00 Eval Planned DrIg Prod BOP / BOP No Trbl , 7,125.0 PULL TEST PLUG No I Op WH / AND RUN WEAR Shakers: < pescription ?> ;" ii Drillout BUSHING. Make [Model - 05:00 3.50 Eval LL Planned DrIg Prod Coring Handle Tools No Trbl 7,125.0 P/U CORE Op BARRLE. SET Shaker Screens INNER BARRLE Screen ' LENGTH I Peek Na , No. , Scr Sz x (in) Scr S= Y (in) ', . , " I 08:30 0.50 Eval Planned DrIg Prod Coring Handle Tools No Trbl 7,125.0 PICK UP JARS Shaker Checks , Op ` Dens OF (lb /gal) Dens UP (lb/gal) Firs (hrs) 09:00 2.00 Eval Planned DrIg Prod Coring Trip In No Trbl 7,125.0 RIH WITH CORE Op iilill [IPir" 11 `` ..., 1 ° ti' l ''l O BARRLE TO 2065' 11:00 1.00 Eval Planned Drlg Prod Coring Circ & Cond No Trbl 7,125.0 CIRCULATE M ake Model 1 Op Mud BOTTOMS UP i110 12:00 0.50j Eval Planned DrIg Prod 1Coring Trip In No Trbl 7,125.01 BLOW DOWN TOP . Centrifuge /Cyclone Checks Op DRIVE Density Overflow(Ib/gal) Overflow Rate (gpm) 0 Fiiii 12:30 2.00 Eval Planned Drl Prod Coring Trip In No Trbl 7,125.0 TRIP IN TO 4286' 9 9 P Dens bF (lb/gal) Underfloor Rate (gpm) F 14:30 1.00 Eval , Planned ,DrIg Prod Coring Trip In No Trbl 7,125.0 FILL PIPE AND Hours (hrs) 1011 Under FI (%.) Dens FD (lb/gal) air. Op BLOW DOWN ' 15:30 3.00 Eval Planned DrIg Prod Coring Trip In Tight 7,125.0 WASH IN HOLE Mud A6I ANO� 1 631 'ti IIII Op d Hole TO 6532' WORK Description Cons... Daily Cost Vendor P . II,7 x 4 T, ''1}i't "" 11 ,[1x TIGHT SPOT AND MUD LAB 1.01 45.00 '1 a, 1:2['",'-'1[314,',1[ ' .'I,1 i[d 4i�I r � r ' n r'b i ' ce ' eSp i 1e PUMP 5OBBL LCM BA. DM 2.0 1,575.00 I na j ' l : .. i , . ; r ' l: " r ` 1 i ; PILL PARTIAL Tech + � ,r :,., il �; l j ltYll: RETURNS Service /L... Barazan D+ Baranex 3.0 476.13 18:30 0.501 Eval Planned Prod Coring Trip In Lost Circ 7,125.01 PUMP 50 BBL an Op LCM PILL WORK 6.0 464.34 PIPE PAC -L I 6.01 950.40 19:00 2.50 Eval Planned Drlg Prod Coring Trip In Tight 7,125.0 PUMP INTO HOLE Potassium 20.0 325.60 Op Hole TO 7025' Chloride Barofibre 26.0 654.16 E Baracarb 5 30.0 569.10 ` STEELSE... 1 34.01 4 . I. err Report Pr • : 5/3/28 s ���pp 5 „ ,eta„& .. .. ,..e... N.. .. � 14 "8 . �n'1" aw..;4 : � w.,,k ; ,,, . / 't ,.. . fs . ,1 f 'f' N`i �I `;, ,. I'�I i up 7 m, 6' . ii l -III FEX L.P. - DDR Detail Page 2/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: ` 4/11/2007, Report: 21.0, DFS: 15.47 II Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) mud Additive Amounts 18.20 37.10 1 18.90 Description Cons... Daily Cost Vendor Time Log Baracarb 501 40.0 752.80 Start Dur Ops Scheduled Depth End Baroid 53.0 542.19 Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment Baracarb 25' 87.0 1,694761 21:30 1.50 Eval (Planned Drlg Prod Coring Trip In Tight 7,125.0! WASH Op Hole FILL /BRIDGE Last Casing Check { F l u ,,, „ FROM 7025 -7045' Date Type Mud Checks: 7,125.0ftKB, 4/11/2007 09:15 Density (1b/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg/I4 % Water ( %) Mud Lost (Hole) (bbl) I Last BOP Ch , , ` ' 4h ;4 � 10.0 9.5 0.250 80.000 89.0 1 Test Date Test Type i1 Vis (s /qt) Filtrate (mL/30m1n) Filter Cake 032 ") Pm (mUmL) Potassium (mg /L) Percent 011 (%) Mud Lost (Sufi) (bbl) 1 l 64 4.0 1 1.000 32,000.00.2 Formations 0 5 1 '' � _ _ PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MBT (1b/bbl) Lime (Iblbbl) 011 Water Ratio - Mud Vol (Act) (bbl) -"- Sample Top ''' 5.000 0.0 6.5 0.6/99.4 ' ' Name MD (rtKB) YP Over (ibf/10... Gel (10m) (Ibt1100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Nanushuk Group 912.0 13.000 7.8 5.3 Base Permafrost 1,020.01' Type Gel (30m) (Ibf /100... T (fl) (°F) Chlorides (mg/L) HTHP Filt (mU30... Alkalin (mUmL) Whole Mud Add (bbl) Nanushuk topset sst. 2,795.01' Polymer 19.000 35,000.000 14.0 Nanushuk topset sst. 3,388.0 Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas ( %) Avg Trip Gas ( %) Torok 3,470.0 Silicate ( %) Electric Stab (V) Comment Torok sand 1 4,734.0 Torok sand 2 4,852.0 of 7,125.0ftKB, 4/11/2007 22:30,.. Torok sand 3 5,090.0 Density (lb/gal) ' pH CEC for Cuttings Pt (mL/mL) 'Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) Torok sand 4 5,630.0 10.00 8.0 0.150 100.000 89.0 310.0 Torok sand 5 5,798.0 Vis (s/qt) Filtrate (m1.130mIn) Filter Cake (132 ") Pm (mUmL) Potassium (mglL) Percent 011 (%) Mud Lost (Surf) (WO Torok sand 6 6,008.0 58 5.8 1 0.250 25,000.000 0.5 25.4 Torok sand 7 6,313.0 PV Over (cp) Gel (10s) (Ibf /1001.. Sand ( %) MBT (lb/bbl) Lime (Iblbbl) 011 Water R atio Mud Vol (Act) (bbl) Torok sand 8 6,568.0 6.000 0.2 7.0 0.6/99.4 1088.4 HRZ 6,605.0 YP Over (lbf /10... Gel (10m) (Ibfl 100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 14.000 8.6 6.5 Kuparuk Sandstone Mbr 6,800.0 Type Gel (30m) (.bf/100... T (f1) (°F) Chlorides (mg /L) HTHP Flit (mU30... Malin (mUmL) Whole Mud Add (bbl) LCU (lower Cret. 6,880.0 Polymer 20.000 25,000.000 120.0 Unconformity) 1 al Max Back Gas ( %) "Avg Back Gas ( %) Max Conn Gas ( %) Avg Conn Gas ('h) Max Trip Gas ( %) Avg Trip Gas ( ° k) gCU (Base Cret. 6,880.0 silicate (%) Electric Stab (V) Comm l Uppei Upper r Kingak (Miluveach) 6,880.0 Kugrua siltstone 7,066.0 1 Drying S haker Data , , ,,,l,i , 1 Descr M Model Ku g l'Ua sandstone 7,120.0 HG Dryer 'Derrick Kugrua Ironstone Shaker Screens Kinga m Deck No, ,Ili Screen No. A. Scr Sz X (in) Scr Sz Y (in) C a ,, w . s F,& .. f4 =' 4 1 il,j 1 1 120.000 Csg Run Date OD (In) Grade Wt (Ibs/ft) 2 1 120.000 3/19/2007 16 H-40 65.00 i 3 1 120.000 V _ i „1 , ! , B : 0 1 ,, Shaker Checks Csg Run Date (JD (In) Grade I Wt pns/ft) ,, . - 3/31 /2007 9 5/8 L -80 40.00 4, ru z _. �i; lyl„ , t , . ,: a .,-, a d .!, ,�- wr B Hrs (hrs) n 7 .. P Ci l � , Description Make Model Cmnt Des Comment HG Dryer Derrick I 1 1 4 , ,. Shaker Screens .,. t i � r Deck No. �� Scre en No. Scr Sz X (In) Scr Sz Y (in) 1 1 i 120.000 ) 2 1 120.000 ■ 3 1 120.000 Shaker Checks Dens OF (lb/gal) ''_` i8 , 1' , .T , : 1'i,,. M a +n ") Hrs hrs ..,.. -- - - - -- - ill /) Description Make Model HG Dryer Derrick Screens . q � I Shaker i)a1 , ��i+�. ��r ' Screen No. Scr Sz X (IH) 'j "' Scr Sz Y (in) „_ .,� 1 1 120.000 2 1 120.000 , 3 1 120.000 Shaker Checks 1 iliii° Dens UF (Ib/gal) ..........._ Hrs (hrs) - .._ - i, i / r t l kilkii ;, a tans ua.�' l0;0 iii 4A, .,a5 ilMlllnl a� ., . .; l llllihl old i!, - -. L 7�.. ,a,42, 1.r. h 1 U�Il.1 = e I � . , ' ,ls B rt `�, �...... It -41 FEX L.P. - DDR Detail Page 3 /:;;%'' '1'") Well Name: AKLAQ #6 47 Job Type: Drilling - Original Date: 4/11/2007, Report: 21.0, DFS: 15. ill, ,.„.: -* ,..„ , Ground Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (ft) 1 18.20 37.10 18.90 • 11.'1, ? 1 ,7 }} 'Y'lti l r ' 'LT;5.14110 :•' * -",' Bit Run Make Bit Inventory Bit Type Item Cost 2 Hughes 8 1/21n, HCM605Z, 7106613 1PDC L 22,833.00 IADC Bit Dull TFA (Inc! N�) (In.) IBHA ROP (ft/hr) Nozzles (i32) mix os .., 0 0.71 35.8 14/14/13/14/13 1 M-3-2-3 7,1250 - 7,125.0 ftKB ht BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (lbf) 2 5,024.00 1,100.0 306 200 225 1 WOB (10001bf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque Pll HL (10001bf) Max. Over-Pull (lbf) 39.7 0.00 6,000.0 225 25,000.0 Bit RPM (rpm) Motor RPM (rpm ) Cum Drill Time (hrs) Off Bottom Torque Torque Units ■80 HL (1000 30 0 126.50 5,000.0 Ftlbs Hydraulic Calculations rgli AV DP (ft/min) AV DC (ft/min) Err A casing component contains a null value in ID Drill String Components Top Btm Bend f 1 Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (in) (Ibs/ft) Grade ID (in) (in) (in) Top Thrd (In) Thrd Cum Len (fft (°) 208 Drill Pipe 2,868.... 4 14.00 X95 3.3401 4 FH 4 FH 3,662.30 8 HWDP 248.59 4 27.20 2.750 4 FH 4 FH 793.99 6 1 I Drilling 36.021 4 2.000 41FH 4 FH 545.40 Jars- Hydraulic 0 .. 10 HWDP 311.40 4 27.20 2.750 4 FH 4 FH 509.38 1 X0 Sub 2.021 6.28 2.500 41FH 4 1/2 IF 197.98 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 D.C. 1 NM FLEX 31.08 63/4 2.880 4 1/2 IF 4 1/2 IF 165.13 D.C. . ill 161, 1 Stabilizer 5.46 6 3/4 2.810 4 11, tik.,A ,111.1],1(2 134.05 1 MWD (Dir 22.42 6.71 4.630 4 1/2 IF 4 1/2 IF 128.59 .1!° & Logging) BAT 1 1 MWD (Dir 9.89 6.76 4.880 4 1/2 IF 4 1/2 IF 106.17 te & Logging) : 11. TM 1 MWD (Dir 9.21 6.79 4.560 4 1/2 IF 1 4 1/2 IF 96.28 & Logging) PM3 i 0 ?;...; 1 MWD (Dir 30.20 6.73 4.630 4 1/2 IF 4 1/2 IF 87.07 ,ryi & Logging) :: 1 1 MWD (Dir 28.14 6.76 ' 4.630 4 1/2 IF T 4 1/2 IF 56.87 :.., & Logging) 1 '-' FE OM ..':.' 1 Float Sub 2 6.8 &I ' • ,, t , :kiforat -- ,,,,,,,,, '., ,. , 1 Mud Motor 25.23 7 ' 1166 41/2 IF 4 1/2 IF 26.23 1.22 ov4 11 /Vegbor°- Wellbore Name VS Dir (*) Kick Off Depth (ftftB) Original Hole 258.00 Directional Surveys i Date 1Description 3/27/2007 MWD Surveys fi ..,:, I ,, iik 1111, 1 f; , iril:1141110 ort P r i nte d : 5/3/2.0 ,, i ,',,'' .:-,... *1 F L.P. - DDR Detail 0 P age 114 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/12/2007, Report: 22.0, DFS: 16.47 0 Job Spud Date - - Rig Release Date -- - 'Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. T otal AFE Amount Total AFE +Sup , I 3/27/2007 12:45 4/23/2007 16:00 1 8.20 37.10 18.90 AF62034 22,574,244 22,574,244.00 Safety Target Depth (ftKB) Target Formation Type Date Comment 7,262.0 Safety Highlight 4/12/2007 SAFE CORING PROCEDURES Daily Cost Total Cum Cost To Date Daily Summq,,it 409 10,745,430.66 ' Dal Mud Cost Mud Cum To Date Weather Lease 1 Road Conditions Wellbore Condition Over (+) / Under ( -) AF ( +1 -) Var D ays y clear 3 deg Good Fluid Losses 1 I 38,883.91 307,011.86 Operations © 06:00 Depth Start (ftKB) Depth End (ftKB) Lay down core 7,125.0 7,163.0 Operations This Report Period — Depth Progress (ft) Drilling Hours (hrs) Core and trip out 38.00 13.50 Operations Next Report Period 1 ' _ . : , i ' I < Run in hole with BHA •, e ' ® P..' _, ' 41 I` �. W -,� Ar�.:. f *maw Jot. Contact Cell Phone &�W� r . �..a( �a i,I ; ,r V . E rnie Natte, Drilling (907) 771-0536 Start Dur Ops Scheduled Depth End Foreman Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment 00:00 2.00' Eval ,Planned ,DrIg Prod Coring '1 Trip In Lost Circ 7,125.0 WASH TO Rigs: Doyon, Arctic Wol Op BOTTOM Rig Supervisor .� FIGHTING Bob Lupton Rig ana Mger LOSSES PUMP U1 tps: s k`® enver, PZ -9 TWO 50 BBL LCM I No. Pwr (hp) Rod Diameter (in) 1 900.0 PILLS ( Liner Size (In) Stroke (In) Vol/Stk OR (bblis... , 02:00 2.00 Eval Planned DrIg Prod Coring Trip In Tight 7,125.0 WASH AND REAM 5 1/2 9.02 0.066 OP Hole CORE BARRLE TO Pump Checks r� „g. BOTTOM. SOME Strokes ' l t ' 1 , -.'& 'lk, TIGHT SPOTS Pres (psi) Slow Spd (spm) Eff(/) ' 1, PUMP3HI -VIS 322.0 No 55 95 I r �I,' SWEEPS TO HELP d, 256.0 Yes 44 95 CLEAN UP HOLE Mud Pumps: 2 , Gardner D enver, PZ -9 ', " ^., ... "+ = �$ �:. No P wr (hp) R od Diameter (in) 04:00 8.00 Eval Planned Drlg Prod Coring Co Lost C irc 7,153.0 BEGIN TO CORE Op AT 74 SPM 510 2 900.0 l PSI BEFORE BALL Liner Size (In) Stroke (In) VOUStk OR (bblfs , 51/2 9.02 0.066 DROP 563 PSI AFTER. START Pump Checks ROP 4 -6 FT /HR Strokes I HIT 14 FT/HR Pres (psi) Slow Spd 1 (spm) Eff (44 ' DRILLING BREAK No I AND BEGAN TO Shakers: 'Description ?> •;: ( LOSE MUD. Make Model TOTAL LOSSES .. NO RETURNS. Shaker Screens LOST 1060 BBLS Screen Deck No. No. 1 Scr Sz X (in) 1 Scr Sz Y (in) LOSSES AND Coring ks 12.00 5.50 Eval Planned Drlg Prod Corin Coring Lost Circ 7,163.0 FOR ��63 FIGHT Dens OF (ielgaq Dens uF (Ibtgal) His (hrs) 9 9 9 Shaker Chec , REGAIN CIRCULATION. Make Model ODERS FROM HEAD OFFICE TO - BREAK AND en ty Oveerno Overfiow (gpm) RETRIVE CORE. INDICATED Dens UF(Ib/gaI) �� UnderflowRate(gpm) , CLEAN BREAK , � ti Hours (hrs) 011 Under Fl (%) (Dens FD (lb/gall , 17:30 4.50 Eval ;Planned DrIg Prod ,Coring Circ & Gond Lost Circ 7,163.0 CONDITION MUD .. "s . 'Op Mud AND BUILD MUD _ - esc _ :"s.k ° y os ". Ve ndor I, WT. TO TRIP OUT MUD LAB 1.01 45.001 re OF THE HOLE 'BA. DM 2.0 1,575.00 Tech RI Bisevice/L... EZ MUD DP 1 2.0 117.14 ;>c 1 Baradefoam 2.0, 219.70 HP A Potassium 4.01 238.76 1 .0 Hydroxide 1PAC -L 7.0 1,108.80 I d. Barascav D 8.01 510 16', 1 x N +� � Report d 5/312007 ' w "� -1 ; ' iN ,> � i ° i9 ,.a.4 ". s < �� . as h ,.- , t � � r s l ItiII � . C [ m4 s" I(( ,n iiHI'i�mwiA'=r S45§ �e # tT ss ■■ �y,j r '�zpY ! a v"aa , 4P - y �� s ��li i M ' � p i., �i a I ,� i , ` pit � ,1eu "< '� r 1 . � �. � _ i - yyy 4' . � 1 � '� f + E '9 kG s t x� '" y s^ I ( I ` t .) } 1 , a , L• o gi o ,:, 0 11 ,,,,I� tt i ( y irP s 3 � + #'I`" iW� `. ,�I i i t a e a d i Y i �„ � in (i I � ° °9��� k'� X z, i � ��-W¢m { � '' �i� i� I �,si I , � �r� i,i�k�4 F e ta �k '. eI �� n :i i � iP: 1 , ,a, 1111, 1 ■ ;. , 6 � �1;':'," .r, o : . r. �' . 1 i ' , I` .. „ '� z. t � ,. i ; Groun Elevation (ft) iOri K B Elev (ft) KB- Ground Distance (ft) o f � � 18.20 37 18.90 Q ° Description Cons.:. aN' ■ 1 . -' . ,,, f '' B a a z a n D 17 2,698.07 .0f D 1,493. Dur Ops Scheduled DepthEnd Baraz D+ 17 y, (hrs) Cat Type Phase MaiorOp Operation Trouble (ftKB) Comment Baracarb 50, 30.0 564.601 22:00 2.00 Eval Planned Drl Prod Coring Accident Other 7,163.O H `aracarb 5 38.0 720.86 Op WAS STUCK AND WITH [...,� 9 I ei HOSE KNOCKING Baracarb 25 72.0 1,402.56 �' i i r HIM DOWN. TEELSE... 112.0 15,288.... ' i 153.0 2,490.8 INCLUDED VISIBLE A INJURIES Chloride CONTUSION AT Barofibre 1 0 4, mo t , ` ) HIS HAIR LINE Q�'' AND A VISIBLY Baroid 57 5 882.25 FRACURDJAW. i,1i1I II,,', iai '¢ MED a , I ising Che 1k ,;� ,¢, , EVACUATION I Date Type PROCEDURES � 1 a WEREPUTIN wat s t l t PLACE AND RIG Test Date ;, ., ±,,i .i' ' a �Ji =° -',YPe t v f WAS MONITORED AN - D Formations OPERATIONS PUT `i�'� I. i ON HOLD UNTIL L' Fcrmatlon 9atine - ' ; FLOOR HAND Nanushuk Group 912.0 , WAS Base Permafrost 1,020.0 i EVACUATED. SEE Nanushuk topset sst. 2,795.0 ` SAFETY Nanushuk topset sst. 3,388.0, INCIDENTS FOR Torok 3,470.0 .y DETAILS. Torok sand 1 4,734.0 Torok sand 2 5,090 0 4,852.0 ` Torok sand 3 . 4 , : , ',, Torok sand 4 5,630.0 i. IY mud O ,Ny�!r.�{ '� I(;,h ( !fir a ":: ��� }, 4 yi III } � « TM ,' (III { j , � i iiq } l I�j(�;i'II Torok sand 5 5,798.0 tud r✓iiTiRY! {IhA�i'!^���� .S�Ii� X4.'�.AS -,., ., ii,i 9�'�x.,VI`.4i��m`�h.w. (� �i'�IIN'�I�,V +T Density (Iblgal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) r % Water (%) Mud Lost (Hole) (bbl) Torok sand 6 6,008.0 9.65 9.5 0.200 100.000 90.0 Torok sand 7 6,313.0 Vis js /qt) Filtrate (mU3Omin) Filter Cake (132 ") Pm (mUmL) Potassium (mg1L) Percent 0 ( %) Mud Lost (Surf) (bbl) Torok sand 8 6,568.0 1 _ 0.600 0 HRZ 6,605.0:$11i PV Over (cp) Gel (10s) (Ibf /100L . Sand (%) MBT (1b/b131) Lime (IbIbbl) Oil Water Ratio Mud Vol (Act) (bbl) 52 4.8 4.000 0.1 7.0 0.6 /99.4 Sandstone Mbr 6,800 0 ,¢ il YP Over (IbfIlO.. Gel (10m) (Ibf(100... Solids ( %) LGS ( %) Polymer (ppm) 1 -Cm Vol (Res) (bbl)! LCU Kuparuk (IOWer Cret. 6,880 0 ( mU30... Alkalin ( m Unconformity) 6.8 P01 mer list (3 19,000 ( °F) hl2orids 99 HTHUmL) Whole Mud Add (bbl) BCU (Base Cr @ t. 6,880.0 14.000 '00... T (fl) 7.3 Y Unconformity) P Flit Max Back Gas (%) Avg Back bas ( %) x Conn Gas ( %) - Avg Conn Gas (%.) 1Max Trip Gas ( %) 'Avg Trip Gas (°h) Upper Kingak (Miluveach) 6, It I I Ku grua siltstone 7,066.0 880 O ' ° Silicate (%) Electric Stab M Comment Kug rua sandstone 7,120.0 " I K ironstone lit,, Ia i , 1I @ OA P e Density (Ib/gal) pH CEC for Collings Pf (mUmL) Calcium (mglL) ro % Water (/o) Mud Lost (Hole) (bbl) Kingak Fm 9 90 9.0 toil 0 0 200 100.000 89 0 1127 7 1'r Vis (s /qt) Filtrate (mU3Omin) Filter Cake (/32 ") Pm (mUmL) 450 Potassium (mg/L) Percen (%) Mud Lost (Surf) (bbl ® � 7 O ( ) Csg R un Date OD (in) Gra Wt (Ibs/ft) 50 7 1 . 0.5 3 16 H -40 de 65 00 PV Over (cp) Gel (10s) (IbfH00f... Sand ( %) MBT (lb/bbl) Lime (Ibibbi) OII Water Ratio Mud Vol (Act) (bbl) ' x- _ ii ii"' " ' 1 I . • 6.000 0.1 7.5 0.6/99.4 1070 4 Su n Date r I a Cs Run Date 79(I5n. ) Grade Wt (Ib . YP Over ohmic, Gel (10m) (Ibf/100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 3/31/2007 /8 L-80 40 00 16.000 8.4 7.1 .,i r .. ,�i Type Gel (30m) (Ibf1100... T (fl) (°F) Chlorides (mg/L) HTHP Flit (mum_ Amon (mUmL) Whole Mu865 d A dd (bbl) ODD P;'„„ Comme „ li Polymer 23.000 27,000.001 ri Max Back Gas ( %) Avg Back Gas (%) Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) I '' ... - _ l Silicate ( %) Electric Staff (V) Comment I a F °vr ) .P pp li P „s iii . ,ilip Is PI IP _ l �` € r . ry +' ik Vim" i 1' .,. 9 ,i0 3" .. 3.., , . ' . .„ ' .,n t w �u .i . �' + .` r * ' e e f -0 FEX L.P. - DDR Detail ,i) n , ' , Page 3/4 Well Name: AKLAQ #6 1 ��ii'I i�jj ���1'iii:iHl ilitttet� 9 b; +tM .� ' !! t t r tf, k d u' , i 1 'pf i � Pit' ��1 , ., � � f . : y ;m. ry �. ( i " , f ��''I��i �' II'�I� 'i �'�'If >wy Job Type: Drilling - Original Date: 4/12/2007, Report: 22.0, DFS: 16.47 0 d (Ground Elevat (ft) Orig KB Elev (ft) KB- Ground Distance (ft) 18.20 37.10 18.90 M ,..` Depth ? >ftKB, 4/17/2007;14:15' Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) 10.00 9.2 0.150 200.000 89.0 228.0 Vis (s/qt) Filtrate (mU30m1n) Filter Cake (132 ") Pm (mUmL) Potassium (mg /L) Percent 011 (%) Mud Lost (Surf) (bbl) 58 3.9 1 0.450 0.5 PV Over (cp) Gel (10s) (lbf /100f... Sand (%) MBT (Iblbbl) Lime (lb/bbl) 011 Water Ratio Mud Vol (Act) (13131) 14.0 6.000 0.3 5.0 0.6/99.4 1277.0 YP Over (ibf /10... Gel (10m) (IbV100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 20.000 12.000 8.2 6.1 kl IV Type Gel (30m) (Ibf/100... T (11) ("F) Chlorides (mg/L) HTHP Filt (mU30... Alkalin (mUmL) Whole Mud Add (bbl) I; Polymer 15.000 28,999.999 13.8 I Max Back Gas ( %) Avg Back Gas ( %) 1 Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) „% Silicate (%) Electric Stab (V) Comment � y t%, . :,.. d tl?. # 059., .a..o � Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg/L) % Water ( %) Mud Lost (Hole) (13131) 10.00 9.5 0.200 200.000 90.0 Vis (slgt) Filtrate (mU3omin) Filter Cake (132 ") Pm (mUmL) Potassium (mg /L) Percent 011 ( %) Mud Lost (Surf) (bbl) 55 4.7 1 0.400 i 4 0 PV Over (cp) Gel (10s) (Ibf/100E.. Sand ( %) MBT (lb/bbl) Ume (1b/bbl) 011 Water Ratio Mud Vol (Act) (bbl) 14.0 6.000 5.0 YP Over (Ibf /10... Gel (10m) (Ibf /100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 16.000 11.000 7.7 5.2 I Type Gel (30m) (Ibf /100... T (fl) ( °F) Chlorides (mg/L) HTHP flit (mL/30... Alkalin (mUmL) Whole Mud Add (bbl) Polymer 12.000 28,999.999 ' Max Back Gas ( %) Avg Back Gas ( %) 1Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) 1 Silicate (%) Electric Stab (V) Comment - ___ - -- 1 LP I Drying Shaker'IData 411 .' s " _ , ' 11' a ..,3,..r... .., '' ','.i..,. Hg,':" 1,' " ° ° 1 Description Make Model lif A Mk HG Dryer Derrick kik Shaker Screens 1 Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 I ., 2 1 120.000 3 1 120.000 � „ Shaker Checks Dens UF (lb/gal) Hrs (hrs) Description Make 'Model i HG Dryer Derrick Shaker Screens il Deck No. Screen No. Scr Sz X (In) Scr Sz Y (in) ,1 1 1 120.000 2 1 120.000 3 1 120.000 Shaker Checks T Dens UF (Ib /gal) Hrs (hrs) ; Description Make Model .c''', HG Dryer Derrick Shaker Screens rI° ( Deck No. , , 1`,, ,: � Screen No. - -. Scr Sz X (in) Scr Sz Y (in) - -- ` 1 1 120.000 2 1 120.000 3 1 120.000 ,,� Shaker Checks *( '&1 Dens UF ( igal) _.. _.. Hrs (hrs) , a ?; b' , — BHA #2, Steerabl Bit Run Make Bit Inventory Bit Type 'Item Cost , � k 2 Hughes 8 1 /2in, HCM605Z, 7106613 PDC 22,8 , (ADC Bit Dull TFA (loci Noz) (in') BHA ROP (ft/hr) Nozzles (132 ") (ADC Codes . , ` ill 0- 1- NO- A- X- 0 -NO -CP 0.71 35.8 l 14/14/13/14/13 M-3-2-3 `t ) F w I �j'll0, a Iy j E t ■ « � � t . . 1 ; ' :' IIIi � II 6 °tw S � I i Ii���i. €! 1 ,,, , NW i- ,Ii' , ,r � i . h ��� � � i __ A 4 �' _ - - - - - - -- FEX L.P. - DDR Detail • Page 4/4 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/12/2007, Report: 22.0, DFS: 16.47 S r - r ound Distance (ft) Ground Elevation (ft) Orig KB Elev (ft) KB-Ground 1 8.20 37.10 18.90 7,125,0 7,163.0 ftKB BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load Pt) 2 5,062.00 774.0 200 213 245 WOB (1000111) Interval ROP (ft/hr) Total ROP (few) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) Max. Over -Pull (lbf) 1 12 2.8 36.2 13.50 8,000.0 245 32,000.0 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hr$) Off Bottom Torque Torque Units ISO HL (10001b1) 55 0 140.00 8,000.0 Ftlbs 190 Hydraulic Calculations I AV DP (ft/min) AV DC (ft/min) Err j A casing component contains a null value in ID Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) : ( °) , 208 I Drill Pipe 12,868....1 4 14.00 X95 3.340 1 4 1 FH 4 FH 3,662.30 8 HWDP 248.59 4 27.20 2.750 4 FH 4 FH 793.99 1 Drilling 36.02 4 2.000 I 41 FH 411 FH 545.401 Jars - 1 Hydraulic 10 HWDP 311.40 4 27.20 2.750 4 FH 4 FH 509.38 11X0 Sub 2.02 6.28 2.5001 4 FH 1 4 1/2 IF 197.98 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 D.C. 1 NM FLEX 31.08 6 3/41 12.880 4 1/2 IF 4 1/21IF 165.13 D.C. 1 Stabilizer 5.46 6 3/4 2.810 4 1/2 IF 4 1/2 IF 134.05 1 MWD (Dir 1 22.42 6.71 4.630 4 1/2 IF 4 1/2 IF 128.59 & Logging) 1 BAT 1 40 1 MWD (Dir 9.89 6.76 4.880 4 1/2 IF 4 1/2 IF 106.17 & Logging) TM 1 MWD (Dir 9.21 6.79 - - -- 4.560 41/2 IF ' 41/2 IF - - - - 96.28 & Logging) 1 PM3 I 1 MWD (Dir 30.20 6.73 4.630 41/2 IF 41/2 IF 87.07 & Logging) NUKE , 1 MWD (Dir 28.14 6.76 4.630 4 1/2 IF 4 1/2 IF 56.87 1 & Logging) FE 1 Float Sub 2.50 6.8 2.750 41/2 IF 41/2 IF 28.73 1 Mud Motor 1 25.231 71 1.500 4 1/2 IF 4 1/2 IF 26.23 1.22 ellbores 1 Wellbore Name t . VS Dir (°) Kick Off Depth (ftKB) , K Original Hole 258.00 Directional Surveys Date Description 3/27/2007 MWD Surveys i M i , I A I 1 1 e �p r il ,,,, '. ;.. .... .. - �' : s ! > , , . 10 ■ a "R ' i` i ? r , „:, ,, . ' «. �' .a t 410 ________ _ _ ________. 10 --- __ ___ __ FEX L.P. - DDR Detail Page 1/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/13/2007, Report: 23.0, DFS: 17.47 0 Job Spud Date - -- Rig Release Date Ground Elevation (ft) Orig KB Elev(ft) KB- Ground Distance (ft) AFE No. 'Total AFE Amount Total AFE +Sup 3/27/2007 12:45 18.20 I 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 Safet Target Depth (ftKB) Target Formation y , e 3 - , Type Date Comment Safety Highlight 4/13/2007 DEBRIEF ON SAFETY INCIDENT Daily Cost Total Cum Cost To Date i ly Weather Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( + / -) Var Days Daly Mud Cost C ost Mud Cum m 3o, To Date ate Da Summary 2s6.88 clear -9 deg l Good j Fluid Losses 1 14,614.43 321,626.29 - - Operations @ 08:00 - - - -- - - - -- Depth Start (ftKB) Depth End (ftKB) 7,163.0 7,163.0 Tripping in with motor and LWD - Deptn Progress (ft) - Drilling Hours (hrs) Operations This Report Period Trip out, 1 0 .00 Lay down core and make up BHA C j Operations Next Report Period I' i ® � Contact Trip out to log - -- - - -- - Job Contact Cel(Phone Time Log , .,;:.,, «_ #,' Ernie Natte, Drilling (519) 427 -7406 Start Dur Ops Scheduled Depth End Foreman I Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment - -- 00:00 13.00 Eval Planned Drlg Prod Coring 'Trip Out No Trbl 7,163.0!POOH WITH Rigs: Doyon, A rctic Wolf Op CORE BARRLE Rig Superv SLOWLY AS PER Bill Lupton, Rig Manager PULL OUT ;,„ - d Pumps: fr :, . eenver, PZ -9 GUIDELINES No. Pwr (hp) ;Rod Diameter (in) TOTAL LOSSES 1 900.0 22BBLS Liner Size (In) Stroke (in) Vol /Stk OR (bbl /s... 5 1/2 9.02 0.066 13:00 2.00 Dial hlahned Drlg Prod Coring Handle Tools No Trbl 7,163.0 LAY DOWN CORE Pump Checks Op 36' RECOVERED Strokes 15:00 1.00 Eval : Planned Drlg Prod Coring I Rig Repair / No Trbl 7,163.0 SERVICE TOP 1 Pr " ( 1 Siow spd (spml Eft ( %) Op Service DRIVE I No 16:00 1.00 Eval Planned DrIg Prod Coring Handle Tools No Trbl 7,163.0 PICK UP MOTOR Mud Pumps 2, Cj, r- D PZ -9 Op AND MWD PLUG No. Pwr(hp) RodDl IN TOOLS 2 900 0 Liner Size (In) Stroke (In) (Vol/Stk OR (bolls... , 17:00 1.00 Eval Planned Drlg Prod Coring Handle Tools No Trbl 7,163.0 LAY DOWN CORE 5 1/2 9.02 1 0.066 qf • Op CARRIER AND CORE BARRELS Pump Checks Strokes 18:00 3.00 Eval ' Planned Drlg Prod Coring Handle Tools No Trbl 7,163.0 PICK UP MWD Pres (psi) Slow Spd (spm) Eff ( %) Op NUKES, COLLAR, No 1 TM COLLAR, Shakers: <Description ?> ORIENT MWD TO Make (Model MOTOR, PLUG IN AND UPLOAD Shaker Screens g 21:00 0.50 Eval ! Planned DrIg Prod Coring Rig Repair No Trbl 1 7,163.0 REPAIR HOSE ON Deck No. Screen " No. ii fi+; (; ,, t. $cr6lt f/f TOPDRIVE 1 21:30 1.00 % O p Service Eva! Planned Drlg Prod Coring Handle Tools No Trbl 7,163.0 SHALLOW PULSE Shaker Checks 1 Op TEST AND BLOW 'D 6 Dens UF (113/gal) Hrs (hrs) DOWN TOPDRIVE /MUD iy r ., ; LINES ,-..,11,, _ v�. Make Model TRIP IN WITH O 22:30 1.50 Eval Planned Drlg Prod Coring Trip In No Trbl 7,163.0 HWDP AND JARS [Centrifuge /Cyclone Checks Density Overflow (Ib/gal) Overflow Rate (gpm) Mud Checks: 7,163.0ftKB, 4/13/2007 23:30 Density (Ib/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg/L) % Water ( %) Mud Lost (Hole) (bbl) .Dens UF (lb/gal) Underflow Rate (gpm) 9.90 8.8 0.150 280.000 89.0 MI Vis (s /qt) Filtrate (mU30min) Filter Cake (/32 ") Pm (mUmL) Potassium (mgIL) Percent Oil (%) Mud Lost (Surf) (bbl) Hours (hrs) 011 Under Fl ( "k) Dens FD (lb/gal) 55 4.5 1 0.400 29,999.999 0.5 PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MBT (Ib/bbl) Lime (Ib/bbl) 011 Water Ratio Mud Vol (Act) (bbl) l r 4.000 0.1 7.5 0.6/99.4 itive Amounts !� ., , VP Over (lbf/10... Gel (10m) (Ibfl100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) Description Cons... Daily Cost Vendor 8.000 8.2 6.8 ( MUD LAB 1.0 45.00 Type Gal (30m) (Ibf /100... T (n) ("F) Chlorides (mg /L) HTHP Filt (mL/30... Alkalin (mlJmL) Whole Mud Add (bbl) 'Potassium 1.0 59.69 Polymer 12.000 29,999.999 14.0 , Hydroxide 2.0 317.42 Max Back Gas (%) Avg Back Gas (%) I Max Conn Gas %) Avg Conn Gas (%) Max Trip Gas (% ( ) Avg Trip Gas %) Barazan D+ BA. DM 2.0 1,575.00 Silicate ( %) Electric Stab (V) Comment - Tech Service /L.., 1 Barascav D 2.0 127.54 IBaradefoam 2.0 219.70 HP CLAYSEAL 2.0 1,586.26 Aldacide G 5.0 ..829.65 Report Printed: 4!16120+ l e a. w .. 02411,,Q „ - ; 7k, s ,, ;,, ,waA491 ,t, ,,',!.., ,, . jai ■ di id, . i d dll dd , , . did ti 4 -it II , 3i ?, ,....,,, IA , • l i' F L p D DR Detail i :a Page 2/3 Well Name: AKLAQ #6 i ��il- ' &,,Nlii Job Type: Drilling - Original Date: '4 1 /2007, Report: ,23.0, DFS: 17.47 0 -.0a -- Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Mud Additive Amounts 18.20 37.10 18.90 Description Cons... Dally Cost Vendor M i n7,163.0ftKB, 4/13/2007 23 :30 Baranex 10.0 773.90 Density (1b/gal) pH CEC for Cuttings IPf (mUmL) 10.00 8.1 0.150 240.000 89.0 69.3 ' Calcium (mg!L) % Water ( %) ,Mud Lost (Hole) (bbl) k13aracor 700 10.0 j'i10 Baro -Trop 13.0 826.02 Vis (slgt) Filtrate (mLI30mIn) Filter Cake (132 ") Pm (mLImL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbl) 'Plus 63 3.8 1 0.200 22,000.000 0.5 Barofibre 15.0 77.40 PV Over (cp) Gel (10s) (1b1/1001... Sand ( %) MBT (IbJbbl) Lime (Ib/bbI) Oil Water Ratio Mud Vol (Act) (bbl) 4.000 0.1 7.5 0 1197.8 STEELSE... 15.0 2,047.50 YP Over (Ibf /10... Gel (10m) (IbH100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) [PAC-51, 16.0 2,534.40 9.000 8.8 6.7 Baracarb 5 30.0 569.10 Gel (30m) (Ibf /100... T (f1) ("9 Chlorides (mg1L) HTHP Filt (mL/30... Alkaiin (mUmL) Whole Mud Add (bbl) Baroid 125.0 1,278.75 Polymer 13.000 22,000.000 13.8 180.0 Max Back Gas ( %) Avg Back Gas ( %) !Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) { Casing Check i:.. D ate Type Silicate ( %) Electric Stab (V) Comment ((i1 mr 1 j I� 1111 i, _) � II�I,�1,,6 x,11 i Test Type iii Des cription 3 Make Mode ' HG Dryer i Derrick 'Formations Shaker Screens i Forman n' o w , r, °MD p (ftKB) p Deck No Screen No. Scr Sz X (in) Scr Sz Y (In) ,,,, 1; ,_w 1 1 120.000 Nanushuk Group 912.0 2 1 120.000 Base Permafrost 1,020.0, 3 1 120.000 INanushuk topset sst. 2,795.0 Shaker Checks , Nanushuk topset sst. 3,388.0 Dens OF pblga(k !Hal Hrs (hrs) F` Torok 3,470.0 1 Torok sand 1 4,734.0, Description Make - -- Model L Torok sand 2 4,852.0 Dryer Derrick Torok sand 3 5,090.0, Shaker Screens .._ �_.. Torok sand 4 5,630.0 Deck No. Screen No. Scr Sz X (in) Scr Sz Y ( in) Torok sand 5 5,798.0 1 1 I 120.0001 2 1 120.000 Torok sand 6 6,008.0 iii' 3 1 120.000 Torok sand 7 6,313.0 Torok sand 8 6,568.0 i Shaker Checks i_ .._.w Dens OF (IblgaO Hrs (hrs) HRZ 6,605.0 Kuparuk Sandstone Mbr 6,800.0 Description Dryer ! Derrick Model LCU o(lower Cret. 6,880.01 HG Shaker Screens BCU (Base Cret. 6,880.0 - - -- Deck No. Screen No. _ - -- Scr Sz X (in) -_ -- Scr Sz Y (in) Unconformity) 1 1 120.000 Upper Kingak (Miluveach) 6 , 880.0 2 1 120.000 Kugrua siltstone 7,066.0 3 1 120.000 Kugrua sandstone 7,120.0, Shaker Checks Kugrua ironstone Dens OF (lb/gal) Hrs (hrs) Kingak Fm. Drill Strings: BHA #2, Steerable csg R Da e r 1 0 g ( i n)j 8 8f G a Wt (Ibs/ft) Bit Run Make Bit inventory Bit Type Item Cost 3/19/2007 16 H -40 65.00 2 (Hughes 8 1 /2in, HCM605Z, 7106613 PDC 22,833.00 IADC Bit Dull TFA (Intl Noz) (in') BHA ROP (ftlhr) Nozzles (132 ") !ADC Codes - Surface Casing, 2,072.1 ftKB 0- 1- NO- A- X- 0 -NO -CP 0.71 35.8 14/14/13/14/13 M -3 -2 -3 Csg Run Date OD (in) Grade Wt (ibs /ft) p , , . .; 3/31/2007 9 5/8 L -80 40.00 7,163.0 - 7,163 0 ftKB ".r. ,,;,' �, _. d emen BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load PO 2 5,062.00 213 245 Cmnt Des comment WOB (10001bf ) Interval ROP (fJhr) Total ROP (ftlhr) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) Max. Over -Pull (Ibf) 36.2 0.00 8,000.0 245 Bit RPM (rpm) !Motor RPM (rpm) ICum Drill Time (hrs) Off Bottom Torque Torque Units 'SO HL (l0001bf) 0 1 140.00 8,000.0 1 Ftlbs 190 Hydraulic Calculations AV DP (ftlmin) AV DC (ft/min) LLv Err _ ... 0.0 0.0 ; Unable to calculate annular pressure drop because pressure drop data is missing from AV talc Drill String Components Mtr Top Btm Bend • Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (') 208IDrill Pipe 1 2,868.... 4 14.00 X95 3.3401 1 4IFH ' 4 FH 1 3,662.30 8 HWDP 248.59 4 27.20 2.750 4 FH 4 FH 793.99 Report Printed: 4/16/2007 0 , ,,, ' tk ■ :jet a.2' FEX L.P. DDR Det , ) tip Well Name: AKLAQ #6 , , t ' . ,nil i i h =' , y .. , , i , ,1 u , = { i ° III ;z' � inl i i ': ,e Job Type: Drilling - Original Date: 4/13/0107, ® e•or t . 23.0, DFS: 1 ip Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) 18.20 I 37.10 18.90 l��l Drill String Components Mtr Top Btm Bend Item : : Density Drift Conn Sz Conn Sz Btm Angle !; 1, Jts Description Len (ft) OD (in) (lbs/ft) Grade ID (in) (in) (in) Tog Thrd (in) Thrd Cum Len (ft) (1 1 Drilling 36.02 4 2.0001 4 FH 4 FH 545.40 '' Jars - Hydraulic 10 HWDP ` 311.40 4 27.20 2.750 4 FH 4 FH 509 .38 • 1 XO Sub I 2.02 6.28 2.500 i 4 FH 4 1/2 IF 197.98 11 i1 , . FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 ClIll D.C. lite 1 NM FLEX 31.08 6 3/4 2.880 4 1/2 IF 4 1/2 IF 165.13 D.C. 1 I ,, 1 Stabilizer 5.46 6 3/4 2.810 4 1/2 IF 4 1/2 IF 134.05 111 f1 f 1 MWD (Dir 22.42 6.71 4.630 4 1/2 IF I 4 1/21IF 128.59 i 1 i,1 r ` & Logging) 1 1 l BAT 1 MWD (Dir 9.89 6.76 4.880 4 1/2 IF 4 1/2 IF 106.17 & Logging) TM 1 MWD (Dir 9.21 6.791 4.560 4 1/2 IF 4 1/2.IF 96.28 i ' & Logging) PM3 1 MWD (Dir 30.20 6.73 4.630 4 1/2 IF 4 1/2 IF 87.07 1111 1 & Logging) t� � i NUKE 1 1 MWD (Dir 28.14 6.76 4.630 4 1/2 IF 41I21IF 56.87 & Logging) �� 410 FE n 1.FIoatSub 2.50 6.8 2.750 4 1/2 IF 4 1/2 IF 28.73 1 Mud Motor 25.23 7 1.500 41/2 IF 4 1/2 IF 26.23 1.22 Welibor '« t�f r I W ellborn N VS Dir ( Kick Off Depth (ftKB) Original Hole 258.00 i Directional Surveys gif Date Description 3/27/2007 MWD Surveys Off Of ff Of ff I Al I � { 'l . YJi 3 Y k k J 4"''" t i , %"Nt:4' : a A",'-,> V' 4o- ■I1', .i. , fi »,- r .. ,, w .,'�' � . -�°it: e >..0 FEX L.P. - DDR Detail Page 1/3 Well. Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/1412007, Report: 24.0, DFS: 18.47 ill ,,, em 6I,IIIIIaII,ii644 = =3 ,:sl',Irfa' #. Job Spud Date - - -- Rig Release Date - - -- Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup ° 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 Safety II) l , I Target Depth (ftKB) Target Formation Type Date Comment Safety Highlight /14 /2007 PROPER CONTAINMENT FOR FLUIDS Daily Cost Total Cum Cost To Date 1' 271,561.10 11,207,368.04 aatY Summary ,MCI, MC_ Daily Mud Cost Mud Cum To Dale Weather Lease / Road C onditions Wellbore Condition Over (+)l Under ( -) AFE ( +l•) Var Days 27, Cost 3 m To Da e clear -10 deg Good Fluid Losses 2 - ... 4 Operations ©06:00 -- .- .. -.. -- -- --- --- --- - - -- -- -- Depth Start (ftKB) Depth End (ftKB) ,, Tripping out of the hole to log 7,163.0 7,280.0 Operations This Report Period -------- • ,Depth Progress (ft) Drilling Hours (hrs) Trip in drill to TD and trip out 117 4 Operations Next Report Period Log upper hole to confirm DST packer placement €I .... :Ali, { Y .' .. 1 l 1. , ' 1t Job Contact Ce it id ) tw° tea ` � r . ,� Ernie Natte, Drilling 519 427 - 7406 Start Dur Ops Scheduled Depth End Forema u Time Operation Trouble (ftKB) Comment 00:00 (hrs) 100 Eval Planned Prod Cor Op Coring ;Trip In No Trbl 7,163.0ITRIP IN TO THE Rigs: Doyon, Arctic Wolf Op Drlg Prod Coring Trip In Tool 7,163.0 SHOE Rig Supervisor ton, 0 Bill Lupt on, Rig Manager .CIRCULATE AND _.., _ -.. � � _ = 01:00 3.00 Eval Planned _ III ' , I p Failure SURGE PUMPS Mud Pumps: 1, Gardner- Denver, PZ,y TO TRY' TO GET No. Pwr (hp) Rod Diamete ( 1 900.0 MWD TOOLS TO PULSE, SURGES Liner SIze (In) Stroke (in) VousfltOR( bbl /s... CLEARED TOOLS -- 5 1/2 9.02 0.066 1 - - - , Pump Checks 04:00 4.00 Eval Planned DrIg Prod Coring Trip In No Trbl 7,163.0 RUN IN HOLE TO Strokes Op 7110 Pres (psi) Slow Spd (spm) Eff ( %) 08 :00 2.50 Eval Planned DrIg Prod Coring Trip In Tight 7,163.0 CLEAN AND REAM 350.01 Yes 44, 95 Op Hole TO BOTTOM 480.0 No 55 95 Mud Pu m .I - ' , . P (•. , e Denver, P r 10:30 1.50 Drlg Planned DrIg Prod Drilling Drill - Motor Lost Circ 7,184.0 DRILL F No. Pwr(hp) 1Rod Diameter (In) Op Vert 7162 -7184' 2 900.0 12:00 3.00 DrIg Planned DrIg Prod Drilling Drill - Motor Lost Circ 7,280.0 DRILL F 7184 liner Size (In) Stroke (In) Vousntolipious.: Op Vert 9.02 0.066 • 15:00 3.00 Drlg Planned Flat Prod Drilling Circ & Cond Lost Circ 7,280.0 CONDITION HOLE 51/2 �Op Mud AND CURE Pahiecks I LOSSES :: Stroke g W; I �I,l �i rrr 18:00 0.50 DrIg Planned Flat Prod Drilling Circ & Cond Lost Circ 7,280.0 SPOT LCM PILL IN 480.O slow spd (spin) No I 55 Ef ( %) 5 j 951 Op Mud OPEN HOLE 350.0 Nt , 44 95 18:30 1.00 DrIg Planned Flat Prod Drilling Trip Out Tight 7,280.0' PUMP AND I hakers: <Des '' ,y> Op ' Hole ROTATE 1.5 Make Model STANDS OUT OF HOLE WELL Shaker Screens I DRAGGING Screen I I Desk No.. No. Scr Sz X (in) 5cr Sz Y lie) 19:30 4.50 Drlg Planned Flat Prod Drilling Trip Out Tight 7,280.0 MADD PASS Op Hole LOGGING WHILE �,.. PUMPING AND Shaker Checks Dens OF (lb/gal) Dens OF (lb /gal) Hrs (hrs) ROTATING OUT WELL DRAGGING - - 1 ' 1 4111 1 ' ah Mud Checks :'7,162.0ftKB, 4/14/2007c10:30 . p . Make Model Ni Density (lb /gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) I% Water ( %) '.. Los (Hole) (bbl) 10.00 _ 9.0 0.200 320.000 88.0 Centrifuge /Cyclone Checks " Vis (s /qt) Filtrate (mL/30min) Filter Cake (/32") Pm (mL/mL) Potassium (mglL) Percent Oil (%) Mud Lost (Surf) (bbl) !Density Overflow (lb/gal) Overflow Rate Wpm) 57 4.5 1 0.350 27,000.001 0.5 j PV Over (cp) Gel (106) (Ibf/100f... Sand ( %) MBT (1b/bbl) Lime (1b/bbl) Oil Water Ratio Mud Vol (Act) (bbl) Dens OF (lb/gal) Underflow Rate (gpm) •I, 4.000 0.1 0.6/99.4 YP Over (Ibf/10... Gel (10m) (lbf/100... Solids (%) LOS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 'Hours (hrs) 011 Under Fl (%) IDens FD (lb/gal) 11.000 9.4 8.3 IA 6 Type Gel (30m) (Ibf /100... T (11) (°F) Chlorides (mglL) HTHP FIIt (mL130... Alkalin (mUmL) Whole Mud Add (bbl) r 6 ■ q " i r; L ' Polymer 18.000 27,999.999 14.0 Description Cons... Daily Cost Vendor Max Back Gas ( %) Avg Back Gas ( %) I Max Conn Gas ( %) Avg Conn Gas ( %) Max Trip Gas ( %) Avg Trip Gas ( %) MUD LAB 1.01 45.00 Baradefoam 1.0 109.85 ' ' '` Silicate (%) Elechic Stab (V) Comment - HP - '. BA. DM 2.0 1,575.00' Tech Service /L... EZMUDDP 3.0 175.71 a K k iii,ii PAC -L 1 7.01 1,108.80 Barazan D+ 9.0 1,428.39 Aldacide G 10.01 1,659.30 �„ . *zs r ; .1n ° s , a wt.. - ,t:-,,. : z ` ?, , r Report Printed: 4116/2007 Page 2/3 111°- FEX L.P. - DDR Detail Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/14/2007, Report: 24.0, DFS: 18.47 4110 Ground Elevation (ft) prig KB Elev (ft) KB-Ground Distance (ft) 18.20 37.10 ! 18.90 Mud Additi Am Description Cons... Daily Cost Vendor Mr ' I ks: 0.0ftKB, 4114/2007 19:15 Pt (mum Potassium 10.0 596.90 Density (lb/gal) pH L) Calcium (mg/L) % Water (%) Mud Lost (Hole) (bbl) Hydroxide 1 0.00 8.1 0.100 320.000 88.0 479.0 Baroid 24.0 245.52 Vis (skit) Filtrate (mL/30tnin) Filter Cake (/32") Pm (m 00 Potassium (mg/L) Percent Oil (%) Mud Lost (Surf) (bbl) Baracarb 50 30.0 564.60 50 5.5 1 28,999.999 0.5 1 Baracarb 25 60.0 1,168.80 PV Over (cp) Gel (10s) gbf/100f... Sand (%) MET (HAM) Lime (Ib/bbl) Oil Water Ratio Mud Vol (Act) (bbl) 4.000 0.1 0.6/99.4 1071.1 Barofibre 8101,49683'12! YP Over gbf/10... Gel (10m) gbf/100... Solids (%) LOS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) !JEELSE... 90.0111 5 .... 16.000 9.3 8.2 Potassium 1125.0 2,035.0 0 ,O) Type Gel (30m) (lbf/100... T (II) ("F) Chlorides (mg/L) HTHP Filt (mL/30... Alkalin (mi.JmL) Whole Mud Add ( Chloride bbi) Polymer 21.000 28,999.999 30 5.0 'CBahrarcidae 5 rb 5 138.0 I Max Back Gas (%) Avg Back Gas (%) I Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas (%) I ' IIIMVIIIIriir,l,VOiriMirr A■i.' iiii 1 ] Last Casing Check Silicate (%) Electric Stab (V) Comment Date Type , ),1(941r4iii„riviV ' Last, BOP Check „ Drying Shaker Data '.!R'''' Description Make Model . ' ' Test Date Test Type HG Dryer Derrick 1. Shaker Formations _ _., Screen No Scr SZ X OM Scr Sx Y (in) li SV161:11;2 Top p( ' 1 1 120.000 Formation Name : 1' ( Key 2 1 120.000 Nanushuk Group 912.0 3 1 120.000 Base Permafrost 1,020.0 Shaker Checks Nanushuk topset sst. 2,795.0 -,' 1 '1 OEMs UF libigni) Hrs (hrs) _.... ...._ Nanushuk topset sst. 3,388.0 J --- Torok 3,470.0 Description Dryer ' IModel Torok sand 1 4,734.0 Deck Torok sand 2 4,852.0 .,,., Shaker D S e CFee o n Screens Torok sand 3 5,090.0 Deck N 1/ Screen No. Scr Sz )5 ftn) Scr Sz Y (lilt 5,630.0 Torok sand 4 !I , 120.000 !!!,- 1 1 20.000 im 0 Shaker Torok sand 5 5,798.0 2 1 120 '', ... .000 ..... .....- ecks 3 1 120.000 Torok sand 6 Torok sand 7 6,008.0 W 6,313.0, haker vn ,. Dens LW libigal) Hrs (hrs) Torok sand 8 6,568.0 _ HRZ 6,605.01 Description Make Model Kuparuk Sandstone Mbr 6,800.0 HG Dryer Derrick LCU (lower Cret. 6,880.0 Shaker Screens Unconformity) Deck No. screen No _ ,, ,,„ Scr ,sz x (In) Scr Sz Y ( 6,880.01 IT 1 11 L 120.000 BCU (Base Cret. Unconformity) 1 2 120.000 Upper Kingak (Miluveach) 6,880.01 3 120.000 Kugrua siltstone 7,066.0! Shaker Checks r. ,,, . Kugrua sandstone 7,120.0, Dens UF (lb/gal) 1 34414**12414 Kugrua ironstone 1 1 Drill Strings: BHA #2, Steerable I IC .!, . 98.8ftKB Bit Run Make Bit Inventory Bit Type Item Coat 2 Hughes 8 1/2in, HCM605Z, 7106613 PDC 22,833.00 Csg Run Date OD (In) Grade Wt (lbs/ft) IADC Bit Dull ITFA (Inc! Nor) (in') (BHA ROP (ft/hr) Nozzle IADC Codes 3/19/2007 16 H-40 65.00 0-1-NO-A-X-0-NO-CP , 0.71 35.8 1 1s /32. 4 4/13/14/13 M-3-2-3 . , - 7,163,0,. - :p,o ftmoi , ° F , /, 2,072.1ftKB Csg Run bate JOD (in) Grade Wt (lbs/ft) BHA No. ICum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) 3/31/2007 9 5/8 L-80 40.00 5,179.00 213 245 Intermedfata 7,280.0ftKB WOB (100 Interval ROP (fUhr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL Max. Over-Pull (Ibf) Csg Run Date OD (In) Grade Wt (lbs/ft) 4 26.0 35.8 4.50 8,000.0 4/15/2007 7 L-80 26.00 , ta Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque e Units 'SO HL (1000Ibf) .. ''***' ' 0 144.50 8,000.0 Ftlbs 190 Cmnt Des 8, , 44 Hydraulic Calculations AV DP ( (ft/mm) AV DC (ftinnin) Err 0.0 0.0 Unable to calculate annular pressure drop because pressure drop data is 1 missing from AV talc , Drill Strin! Corn . orients . . , 1 Mtr *4 '''• '''''''''' ' . ; ' , ' .,. .1 ., , (..,. ' Top Btrn Bend : ' I ': ','' '", 7 i* D t %.,;',' 1 ni , ,,- '- ,' '-- ■ ' ,' et - Drift Conn Sz Conn Sz Btm Angle il l Jts Description Len (ft) OD (in) (lbs/ft) Grade ID (in) (in) f (in) Top Thrd (in) Thrd Cum Len (ft) C) 208 Drill Pipe 12,868.... 4 14.00 X95 3.340! 4 FH 1 4 FH I 3,662.30 8 HWDP 248.59 4 27.20 2.750 4 FH 4 FH 793.99 I ' 4 1 --- - - - - - - -- -- - - - - -- -- - - - - -- • FEX L.P. - DDR Detail - Page 313 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/14/2007, Report: ' 24.0, DFS: 18.47 0 . J uo + t t 't r d ..•ii La I Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) 18.20 1 37.10 18.90 Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (in) (Ibs /ft). Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum L` (°) 1 Drilling 36.02 4 2.000 4 FH 4 FH 545.40 Jars - Hydraulic 1 1 10 HWDP 311.40 4 27.20 2.750 4 FH 4 FH 509.38 ' 11 XO Sub 2.02 6.281 2.500 4I FH 4 1/2 197.98 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 D.C. - , a 1 NM FLEX 31.08 63/4 2.880 4 1/2 IF 41/2 165.13 D.C. 1 1 1 Stabilizer 5:41, • 3/4 2.810 4 1/2 IF 4 1/2 IF 134.05 1 MWD (Dir 22.42 6.71 14.630 41/2 IF 4 1/2 IF 128.59 Logging) BAT I 1 MWD (Dir 9.89 6.76 4.880 4 1/2 IF 4 1/2 IF 106.17 & Logging) TM 1 MWD (Dir 9.21 6.79 14.560 4 1/2 IF 4 1/2 IF 96.28 '' & Logging) 1 1 PM3 1 MWD (Dir 30.20 6.73 4.630 4 1/2 IF 4 1/2 IF 87.07 & Logging) NUKE 1 MWD (Dir 28.14 6.76 4.630; 41/2 IF 4 1/2 IF 56.87 & Logging) iiii „, FE I 1 Float Sub 2.50 6.8 2.750 41/2 IF 41/2 IF 28.73 k 1 1 Mud Motor 25.23 7 1.500 4 1/21 IF 4 1/2 IF 26.23 1.22 i °; 1 .I ti ' PIS Welibore Name VS Dir (°) ; Kick Off Depth (ftKB) Original Hole 258.00 Directional Surveys Description 3/27/2007 MWD Surveys '`' Survee.LData MD (ftKB) Ind(*) Aim (°) TVD (ftKB) NS (ft) EW (ft) VS (ft) DLS ( °1100ft) urvey Company 7,120.651 1.441 299.571 7,073.731 23.711 - 45.161 39.251 0.321HALLIBURTON 1 4 1 i t , I ' IE 'Ill i Re port Pnrlted: 4/16/2007 �,11�1 a � � niux ' 1 :I' . 1 w 4): ,. _: 77,o.,171;777- , . .. I6 Ai k .K „,,,711 7 ;,,, Ii,dJnl i��ii0 u r EX L.P. - DDR_Detail Page 1/3 Well Name: AKLAQ #6 '',*11:1, a , : , Job Type: Drilling - Original Date: 4/ Report: 25.0, DFS: 197 • Job Spud Date - - -- Rig Release Date Ground Elevation (ft) Orig KB Bev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/200712:45 18.20 37.10 18.90 AF62034 22,574, 22, 574,244.00 Safet Target Depth (ftKB) Target Format Type Date Comment d '''I+r �,Halx „F (ry Safety Highlight! /15/ 2007, SAYING ALERT AS THE PROJECT COMES TO AN END Daly Cost Total Cum Cost To Date Dail 'Summar 258,949.82 11,466,317.86 y y Da Mud Cost M u d Cum T o Date 4' Weather Lease ) Road Conditions Wellbore Condition Over ( +) /Under ( -) AFE ( +l•) Var Days Light Snow 10 deg. / Good Fluid Losses 1 2 15,067.57 3 64,32.71 Operations , 06:00 h Start (ttKB) Depth End (ftKB) Running in hole for clean out t 7,280 0 7,280.0 x Operations This Report Period - _.. -- -- Depth th Pro (ft) Drilling Hours (hrs) Trip out Slow from 6923' - 6835 Mad Pass/ Pump out Due to Tight Hole/ Pump Sweeps Spot Pill / Pump & 0.00 $ Back Ream out to 6780' / Pump Slug & Continue Out till 3750' Pulled Tight & Had to Back Ream out Pumpin Sweeps & Mixing Mud to Maintain Properties to Keep Up with Loses , Back Ream Out to 2970' / Hoist to 2590' ° i & Pump High Vis Sweep / Slug Pipe & Pooh & Lay Down Sperry Smart Tools K Job Contact Cell phone , Drilling (519) 427 -7406 Operations Nex llltoo t Report Period Foreman Ernie Natte Makeup Mth Bit & RIH Kleen Out Trip Rig Supervisor 7i igs Doyott Arctic Wolf �: L, l ,, , m $� d # F' G "' Depth End Bill Lupton Rig Manager lti. OO 1.00 Eval Trbl p 3rd Flat Prod Lo Or in O ther er Lion troub (ftK Commen y Y ) by OP ya N .�4 =, , ,1 , Gardner- Denve0' m: gg' g BHA 7,280.0 Had to MAD Pass NO pan (hp) Rod Diameter (In) r Party Failure Log Tools Over 1 900.0 ' Section Of Hole All Liner Size (In) Stroke (in) Vol /Slk OR (bblls... pi ■ l Ready Drilled Due 5 1/2 9.02 0.066 Of To Tools Lost Data on Previous Run Pump Checks_ - ___ ! Strokes ; 01:00 2.50 Drig Trbi Flat Prod Cond Other , Hole 7,280.0 Had to Back Ream Pres (psi) Slow spd (sp Elf ( %) Well Trip Stability Out to 6780' from No 0#' kiii0'? i 7300' / Sloughing Mud Pumps: 2, Gardner - Denver, PZ -9 I '..... 03:30 5.00 DrIg Planned Flat Prod Shales No. Pwr (hp) Rod Diameter (in) iii.1 2 900.0 0 ., Pump Slug & Hoist ` Liner Size (In) - Stroke (in) Vol /stk OR (bbl/s... { i , p Trip � Cond Tri p Out No 7,280.0 Out to 3750' 5 1 /2 9.02 0.066 08:30 3.50 Drlg Planned Flat Prod Cond Trip 9 Out Tight 7,280.0 Wash and ream Pump Checks iii p p from 3748 -3400 Strokes " tight at 3750, 3680, Ares (psi) Slow Spd (sprit) Elf 1 % 3571,3447 N 12:00 3.50 Drlg Planned Flat Prod Cond Trip Out Tight 7,280.0 Back ream from �Cers: <Description ? ! Op Trip j Hole 3400 -2590 Make Model ii"15 :30 1.50 DrIg Planned Flat Prod Cond Trip Out Tight 7,280.0 Circulate a high vis 001 Op Trip Hole s weep, pump slug Shaker Screen and blow down top Screen i II drive Deck No. No. Scr Sc X (in) Scr Sc Y (in) x ,( 17:00 3.00 DrIg Planned, Flat Prod Cond Tri Out Tight 7,280.0 Continue to pull out I �_ p g P Shaker Checks It 9 Op ;Trip Hole of hole to BHA 1 Dens OF (ibrgal) Dens u (lbrgaq Hrs (hre) 20:00 0.50 Drl PPl Flat Prod Cond Handle Tools Tight 7,280.0 Lay down NMF .. Trip Hole DC's & NMSTB l l 20:30 : 1.50 Drlg Planned Flat Prod Cond Handle Tools Tight 7,280.0 Remove sources Make Model I 22:00 2.00,IOrt ° Planned Flat Prod Cond Handle Tools THole ht 7,280.0 Re download tool Op 'p g g Remove _Cen cycl Op Trip Hole lay down smart puller and iron Dens Overflow (Iblgaone l) Checks OvefiowRate (gpm) r'hecks: 7,279.OftKB, 4/15/2007 14:00 e I , „ De tins F (Iblgal) Undefiow Rate (gpm) =Density (lb /gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) it 10.10 9.0 0.120 320.000 89.0 Hours (hrs) Oil Under Ft (%) !Dens FD (ib/gai) rti At Via (skit) Filtrate (mU30min) Filter Cake (/32 ") Pm (mUmL) Potassium (mg/L) Percent Oil ( %) Mud Lost (Surf) (bbl) 53 4.9 1 MBT (Ib/bbl) 0.100 Lime 28,9 0.5 t , ; p) Gel (10sbf /100f... Sand ( %) /b) Oil Water Ratio Mud Vol (Act) (bbl) 4.000 0 .1 7.0 _ 0.6/99.4 Desert by cost ven PV Over (c ) (I YP Over Qbf /10... Gel (10m) (Ibf/100... Solids ( %) LGS (%) 5.6 Polymer (ppm) LCM M ud Vol (Res) (bbl) 1.0 45.00 15.000 8.5 Aldacide G 1. k 165.93 MUD LAB Tech BA. DM 2.0 1,575.00, Type Gel (30m) (Ibf /100... T (fl) ( °F) Chlorides (mg/L) 14 P Flit (mU30... Alkalin (mUmL) Whole Mud Add (bbl) Polymer 21.000 26,000.001 14. Max Ba Gas ( %) Avg Back Gas (%) Max / Conn Gas (%) Avg Conn Gas (%) M ax Trip Gss (°h) [Avg Trip Gas ( %) ` Service /L.. Silicate (%) Electric Stab (V) Comment I Baro -T of P 5.0 317.70' lel Pius 6aranex 6.0' 464.340 PAC -L 6.0 950.40, k potassium 8 477.52 Hydroxide �2eport Printed 4,1161172 1 l .� "k .. .�- M:uk � r .. ,� III "i ., I �il�I�'I IIiII�li }e. .. "#(116 ,�a i -110 FEX "L.P. - DDR Detail lIl ''i Page 2/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/15/2007, Report: 25.0, DFS: 19.47 S r - . y Ground Elevation (ft) ()rig KB Ele v (ft) KB-Ground Distance {ft) f �U Amounts d Additive Amounts 18.20 37.10 18.90 Description Cons... Daily Cost Vendor Mud Checks: 0.0ftKB, 4 /15/2007 21:00 Barazan D+ 16.0 2,539.36 Density (Ib/gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mgIL) % Water ( %) Mud Lost (Hole) (bbl) Potassium 20.0 325.60 10.05 9.4 0.120 240.000 89.0 190.0 Chloride Vis (s /qt) Filtrate (mL/30min) Filter Cake (/32 ") Pm (mLJmL) Potassium (mg/L) Percent oil ( %) Mud i oat (s (b STEELSE... 20.01 2,730.00 50 5.5 1 0.300 23,000.000 0 .5 10.2 8arofibre 30.0 754.80 PV Over (cp) Gel (105) (lbf/100f... Sand ( %) MBT (Ib/bbl) Lime (lb/bbl) Oil Water Ratio Mud Vol (Act) (bbi) y .t 6.000 0.1 6.5 0.6/99.4 1214.5 Baracarb 50 30.0 564.60 VP Over (lbf/10... Gel (10m) (Ibf1100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) ' Baracarb 25 32.0 623.36 14.000 8.7 6.2 Baroid 334.0 3,416.82 Type Gel (30m) (Ibf/100... T (fl) ('F) Chlorides (mg/L) HTHP Filt (mlJ30... Alkalin (mLlmL) Whole Mud Add (bbi) z Polymer 19.000 23,000.000 225.0 Max Back Gas ( %) Avg Back Gas ( %) i Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (3) Avg Trip Gas ( %) 7 Silicate ( %) Electric Stab (V) Comment r Drying Shaker Data Description Ma ke Model Formations , HG Dryer i Derrick Sample Top Shaker Screens Formation Name MD (ftKB) Deck Na. Screen No. Scr Sz X (in) Scr Sz Y (in) � Nanushuk Group 912.0 1 1 { 120.000 Base Permafrost 1,020.0 2 1 120.000 Nanushuk topset sst. 2,795.0 3 1 120.0 !Nanushuk topset sst. 3,388.0 Shaker Checks Torok 3,470.0, Dens uF (Ib /sap Hrs (bra) Torok sand 1 4,734.01 1 Torok sand 2 4,852.0 Description Make Modal Torok sand 3 5,090.0 HG Dryer 'Make i Torok sand 4 5,630.0 Shaker Screens Torok sand 5 5,798.0 Deck No. 1, 'a , keen No. Scr Sz ?5,0 Scr Sz Y (in) _ 1 120.000 I Torok sand 6 6,008.0 2 1 120.000 Torok sand 7 6,313.0 3 1 120.000 Torok sand 8 6,568.0 - 1 HRZ 6,605.0 .1 Shaker Checks - w D OF ib/gai) , . w � Hrs (hrs) Kuparuk Sandstone Mbr 6,800.0 T LCU (lower Cret. 6,880.0 Description Make Model Unconformity) HG Dryer Derrick BCU (Base Cret. 6,880.0 '' r Shaker Screens Unconformity) Deck No. Screen No. Scr Sz X (in)_ Scr Sz Y (In) Upper Kingak (Miluveach) 6,880.0 r 1 1 120.000 Kugrua siltstone 7,066.0 1 zji 2 1 120.000 . a 3 1 120.000 Kugrua sandstone 7,120 0 ,; Kugrua ironstone Shaker Checks � Kingak Fm Dens OF (lb /gal) - 1, -., t. „�,, Hrs (hrs) r • • i. a, p, ponducto Pi * ' 4. 1. �' i, � x r�� I Csg Run Date OD (in) (Grade Wt (lbs/ft) i , Drill Strings: BHA #2, Steerable 3/19/2007 16 1 H -40 I 65.00 Bit Run Make Bit Inventory Bit Type Item Cost 2 Hu h I 8 1 /2in, HCM605Z, 7106613 PDC 22,833.00 Surface Casing, 2,072.1' es 9 (ADC Bit Dull TFA (Intl Non) (in') 'BHA ROP (ft/hr) Nozzles (/32 ") IADC Codes Csg Run Date OD (in) Grade Wt (Ibslft) 0- 1- NO- A- X- 0 -NO -CP 0.71 35.8 14/14/13/14/13 M -3 -2 -3 3/31/2007 9 5/8 L -80 40.00 7,280.0 - 7,280.0 ftKB Intermediate Casing, 7,280.0fIKOP BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (lbf) Csg Run Date OD (in) Grade Wt (Ibs /k) 2 5,179.00 213 245 4/15/2007 7 L -80 26.00 WOB (10001bf) Interval ROP (ftlhr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over-Pull (lbf) ' 35.8 0.00 8,000.0 24 5 Cmnt Des Comment Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (t000lbf) __... -J 0 144.50 8,000.0 Ftlbs 190 Hydraulic Calculations ' i :; AV DP (ft/min) AV DC (ft/min) _ _ - -- - -- Err 0.0 0.0 Unable to calculate annular pressure drop because pressure drop data is missing from AV calc Drill String Components c� ICgn ' 'w,a ( ;1 /' , A l x " Y Mtr 41I'i "'v. :- ' .d '' °be % 1 . _ � T op B t m B end is Item Density Dr Conn S z Conn Sz Btm Angle 0 Jts Description Len (ft) OD (in) (Ibslft) Grade ID (in) (in) (In ) Top Thrd (I ^) Thrd Cum Len (ft) (') {' 208 Drill Pipe 2,868.... 41 14.00 X95 13.340 4 FH 4 FH 1 3,662.30 8 HWDP, ;'. 248.59 4 27.20 2.750 4 FH 4 FH 793.99 ii I i ii N , ,e9 .114'',.Nax. w , , , ,t a lHOlgi ,,r , d,+ ` *- - M ix* � ." ,, , a i'w ms !).d Ip1 r� da ar k , 1I�.. • FEX L.P. - DDR Detail 4111 Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/15/2007, Report: ' 25.0, DFS: 19.47 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (Ft) 18.20 37.10 18.90 Drill String Components Mtr Top Btm Bend ■ Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (1 1 Drilling 36.02 4 2.000 41FH 4 FH 545.40 Jars - . Hydraulic 1 i 10 HWDP 311.40 4 27.20 2.750 4 FH 4 FH 509.38 1 XO Sub 2.021 6.28 12.500 4'.FH 4 1/2 IF 197.98 1 NM FLEX 30.83 6.68 2.880 4 1/2 IF 4 1/2 IF 195.96 D.C. ..: 1 NM FLEX 31.08 6 3/4 2.880 4 1/2 IF 4 1/2' IF 165.13 D.C. 1 Stabilizer 5.46 6 3/4 2.810 4 1/2 IF 4 1/2 IF 134.05 1 MWD (Dir 22.42 6.71 4.630 4 1/2 IF 4 1/2 IF 128.59 SV & Logging) 1 BAT : 1111;11''lll;1'1' ' 111: 1 MWD (Dir 9.89 6.76 , 4 880 4 1/2 IF r u 4 1/2 IF 106.17 " & Logging) Ft' t y 't� '(`Et # '�k`� , •� A n , i TM �s P. 1 MWD (Dir 9.21 6.79 4.560 4 1/2 IF 4 1/2 IF 96.28 4; i & Logging) PM3 1 1 1 MWD (Dir 30.20 6.73 4.630 4 1/2 IF 4 1/2 IF 87.07 Iii ' & Logging) NUKE 1 MWD (Dir 28.14 6.76 14.630 4 1/2 IF 4 1/2 IF 56.87 X91 1 11 & Logging) FE r 11, 1 Float Sub 2.50 6.8 2.750 4 1/2 IF 4 1/2 IF 28.73 eik 1 Mud Motor 25.23 7 1.5001 4 1/2 IF 4 1/2 IF 26. 4,,,,,,14! , Wellbore;k $ , Wellbore Name VS Dir (°) Kick Off Depth (ftKB) Vi Original Hole 258.00 Directional Surveys Date Description li 3/27/2007 MWD Surveys I l i 140' '� kt IMI Pwl air 4' 1 is! 1 ' I N I - - - - - - - - - S . Page 1 / 3 FEX L.P. - DDR Detail Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/16/2007, Report: 26.0, DFS: 20.47 0 Job Spud Date Rig Release Date Ground Elevation (ft) Orig Kb Eiev (ft) KB-Ground Distance (ft) AFE No. Total AFE Amount Total AFE+Sup 3/27/2007 12:45 18.20 37,10 18.90 AF62034 22,574,244.00 22,574,244 00 Safety d10s,d, . ', . , , 4, Target Depth (f1KB) Target Formation Type Date Comment ' , ,,1 4 ' , ,' ;._..4 s',. '...,:'-' 7,262.0 Safety Highlight 4/16/2007 1WALK AROUND EQUIPMENT Daily Cost Total Cum Cost To Date Daily Summar - 276,131.91 11,730,199.77 Weather Lease / Road Conditions Wellb Condition Over (+) / Under (-) ar AFE (+/-)V Days Mud Cost r oa on ons ore o n i ,i clear 7 deg Good Fluid Losses 1.5 34,699.66 399,072.37 id, ',,.. Operations *06:00 - - - - Depth Start (ItKB) Depth End (ftKB) PC lift -'•• Tripping out of the hole 1 7,280.0 7,280.0 Pit IV --- --- ' Operations This Report Period - - ----- Depth Progress (ft) Drilling Hours (hrs) !pit Wiper trip to run casing! Loosing Fluid to Formaton took @ 600 bbls on whiper trip/reaming & back reaming in 0.00 i..,..ii & part way out to 6800' • Operado iii- ... .i.'. 0 .,0 .,, --- - - - , . emaMntac ' ,,,.., ns Next Report Period . [ ' Job Contact Cell Vfftrst tl'ill'i; Install casing rams and pick up running tool, run casing Ernie Natte, Drilling (907) 771-0536 Foreman ... „ . ... . ... ... . - 1:, 11 -1,, L ::, 6:fieduled Depth End R Doyon, Arctic Wolf Ri ; Mr, 'i,r,, -,;:.„,=. , 7,, t.,/,,Type Phase Major Op Operation Trouble (ftKS) Comment Rig Supervisor 00:00 2.00 Drlg Planned Flat Prod Cond Trip In Rig 7,280.0 Replace IBOP , Bob Lupton, Rig Manager 1 ' Op Trip Repair hydraulic seals an , - 901, , , , ,,,Ria„•*5,1 1 .-1 - 1 lube rig. k , ...,,P um ps : I", _ _ 1 No. Pwr (hp) Rod Diameter (in) 62:06 0.50 DrIg Planned Flat Prod Cond Trip In Tight 7,280.0 Pick up BHA 1 900.0 Op Trip Hole Liner Size (In) Stroke (In) Vol/Stk OR (bbIls... 02:30 1.00 DrIg Planned Flat Prod Cond Trip In Lost Circ 7,280.0 RIH to 2034' 5 1/2 9.02 0.066 Op , 1Trip i Pump Checks 03:30 1.00 DrIg Planned Flat Prod Cond Trip In Tight 7,280.0 Circulate bottoms Strokes Op Trip Hole up and ream from Pres (ps) Slow Spd (spm) Eff (%) 3300-3330 No 1 1 I 04:30 3.50 Drlg Planned Flat Prod Cond Trip In No Trbl 7,280.0 RIH to 6803 Mud Pumps: 2 , Gardner-Denver, PZ 10p 1 Trip 1 No. Pwr (hp) Rod Diameter (in) , 2 900.0 08:00 4.00 Drlg Planned Flat Prod Cond Trip In Lost Circ 7,280.0 Wash and ram from un „ size (ln) Stroke (In) Vol/Stk OR (bbl/s... Op Trip 6803-6962 well took 5 1/2 9.02 0.066 165 bbls 1 Pump Checks III 12:00 3.50 DrIg Planned Flat Prod Cond Trip In Tight 7,280.0 Wash and ream Str okes Op Trip Hole from 6962-7270 1 Pres (psi) Slow Spd (sPrn) Eff (%) ' 7 15:30 0.50 Drlg Planned Flat Prod Cond Trip In Tight 7,280.0 Flow check and No 1 Op Trip Hole attempted to pull Shakers: <Description?> with out pump Make Model would not pull ,.. Shaker Screens 16:00 0.50 Drlg 'Planned Flat Prod 1Cond Trip In Tight 7,280.0 wash and ream j ..., 1 Screen Op Trip Hole from 7270-7280 Deck No, No. Scr Sc X (in) Scr Sr Y (in) 16:30 3.00 DrIg Planned Flat Prod Cond Trip In Lost Circ 7,280.0 Circ Hi-Vis sweeps I 1 Op Trip and spot LCM pill Shaker Checks 19:30 3.00 Drlg Planned Flat Prod Cond Trip Out Tight 7,280.0, Back ream from Dens OF (lb/gall Dens OF (lb/gal) Hrs (hrs) Op 1Trip Hole 7280-7127 with no , • pump from Milt' „,,1:11,k'ir';c.4;4,-,V1,1;:',.•;;`,:±;:l' l ila ,,,_ ,,",1,461b 7127-6423 with Make 4" . ' . Model • pump and rotary , 1 pipe pulling free at Centrifuge/Cyclone Checks 6570' Density Overflow (1b/gal) Overflow Rate (gpm) . ,.., 22:30 0.50 DrIg Planned Flat Prod Cond Trip Out Lost Circ 7,280.0 Spot LCM pill in Dens UF (1b/gal) Underflow Rate (gpm) Op Trip open hole . 23:00 1.00 DrIg Planned Flat Prod Cond Trip Out Tight 7,280.0 POOH wet and Hours (hrs) 011Under Fl (%) Dens FD (lb/gal) lOp Trip 1 Hole pump trip slug ,7 Fi ;i1 ' P ,., ■:' , Mud checks: '41iiibi 09:00 Mud 4.0., .0:000 ___„, Density (lb/gal) pH CEC for Cuttings ■Pt (mLimL) Calcium (mg/L) .% Water (%) Mud Lost (Hole) (bbl) Description D;;;;;,:top Ity Cost Vendor ■ 10.05 8.8 0.120 320.000 88.0 BA. DM 1 2.0 1,575.00 Sr Vie (skit) Filtrate (mL/30min) Filter Cake (/32") Pm (m1JmL) Potassium (mg/L) Percent Oil (%) Mud Lost (Surf) (bbl) Tech 1 1 1 62 4.1 1 25,000.000 0.5 Service/L... PV Over (cp) Gel (108) (lbf/100f... Sand (%) MBT (Ib/bbl) Lime (lb/bbl) 011 Water Ratio Mud Vol (Act) (bbl) r MU LAB 1.0 45.00 1 4.000 0.1 7.5 0.6/99.4 PAC-R 3.0 463.95 YP Over (lbf/10... Gel (10m) (lbf/100... Solids cm LOS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) ' 14.000 9.5 8.0 EZ MUD DP 3.0 175.71 I Type Gel (30m) (lbf/100... T NI) (°F) Chlorides (mg/L) HTHP Flit (mtJ30... Alkalin (mL/mL) Whole Mud Add (bbi) Da ra b lok 5.0 180.601 olymer 19.000 26.000.001 14.2 Potassium 6.0 358.14 4110ax Back Gas (% Avg Back Gas (%) Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas (%) Hydroxide 1 . j DRIL-N-S... 8.0 6,198.24 Silicate (%) 'Electric Stab (V) 1Comment Barazan D+ 9.0 1,428.39 • Aldacide G I 13.0 2157.09 Repo ' °- 4/23/2007 • 41) FEX L.P. - DDR Detail *: fi. 7 icili l iji,: , 41 INNAINigliNINNNorN; N N NN Well Name: AKLAQ #6 '1•1441:01Viril..wy NAlF;i1.4.-,'''',:;,•$:,-;,,..,•'..,,,,',,' .....-1 , - , frpsplY , ! , '•:; ,': :.: 1 1 :4 : 7'1'111;:'444611$1411"I'ili!'f144111111}') '11:liW ,1 bate: ''' 1016/2007, Report: ' 26.0, DFS: I • 7 - Job Type: Drilling - Original III Ground Elevation (ft) Orig KB Eley (ft) KB-Ground Distance (ft) 18.20 Mud Additive Amount 8.20 37.10 18.90 Description Cons... Daily Cost Vendor Mud Checks: 7,280.0ftKB, 4/16/2007 17:30 .. PAC 1 13 . 0 1 2 Density (lb/gal) pH CEC for Cuttings Pf (mUmL) C alciu m on g/L) % Water (%) Mud Lost (Hole) (bbi) Baranex 22.0 1,702.58 ' 10.05 8.8 0.100 240.000 88.0 520.0 STEELSE... 1 45.01 6,142.501 Vis (s/qt) Filtrate (mU3Omin) Filter Cake (/32") Pm (mUmL) Potassium (mg/L) Percent Oil (%) Mud Lost (Surf) (bbl) Barofibre 90.0 2,264.40 28.8 58 4.2 2 29,999.999 0.5 A ...... l Baracarb 25 90.0 1,753.20 1.1t7 PV Over (cp) Gel (10s) (1b1/1001... Sand (%) MST (Ib/bbl) Lime (Ib/bbl) Oil Water Ratio Mud Vol (Act) (bbl) , 5.000 0.1 7.0 0.6/99.4 1120.0 'potassium 286.0 4,656.08 ! ,. .11 1 ' 1 '1 : 11 i1 1 1:: 1 ;1:: , : ; 11 ,„ 1. 1. 4 1, 1, 11 1 VP Over (lbf/10... Gel (10m) (1b1/100... Solids (%) LGS (%) Polymer (ppm) LCM Chloride Mud Vol (Res) (bbl) I 18.000 9.2 7.7 Baroid 1346.01 3,539.58 i Type Gel (30m) (1b0100... T (II) rF) Chlorides (mg/L) HTHP FR (mU30... Alkalin (mUmL) Whole M Polymer 22.000 29,999.999 14.2 Max Back Gas (%) Avg Back Gas (%) 1Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas (%) . . ..... . Silicate (%) Electric Stab (V) Comment Test Date Test Type .. ,, . , Drying Shaker Da,...- 1 Description Make Model I Formations HG Dryer Derrick W0aniple Top * Name MD (ftKE Shaker Screens Nanushuk Group 912.01 Deck No, Screen No. , Scr $z X (in) Scr Sz Y (in) 1 1 120.0001 Base Permafrost 1,020.0, 2 120.000 Nanushuk topset sst. 2,795.0 .., if 31 l 120.000 Nanushuk topset sst. 3,388.0 1. Torok 3,470.0! ,!If Shaker Checks Dens LIF (/bigs!) Hrs (hrs) Torok sand 1 4,734.0 [ Torok sand 2 4,852.01 Description Make ',Model Torok sand 3 5,090.0 4 5 HG Dryer Derrick Torok sand 4 5,630.0 Shaker Screens „,, 'Torok sand 5 5,798.0 . .. - . T - T.' Deck No. , 4 4 4 No. , Scr Sz X (In) ._ Scr Sz Y (i "L - , ''' " ''''' --.''' Torok sand 6 6,008.01 fir! 1 1 120.000 !Torok sand 7 6,313.0 2 1 120.000 11,1!111' Torok sand 8 6,568.0 3 1 120.000 I HRZ 6,605.0 '., Shaker Checks Kuparuk Sandstone Mbr 6,800.0 Hrs (bra) , 1 LCU (lower Cret. 6,880.0 Description Make Model 1U nconformity) G Dryer Derrick BCU (Base Cret. 6,880.0. Shaker Screens 7 Unconformity) Deck No , ,„ Screen No ., Scr Sz X in Scr Sz Y (In) ,i;RiT Upper Kingak (Miluveach) 6,880.0 i 1 120.000 Kugrua siltstone 7,066.0 t 2 1 120.000 Kugrua sandstone 11:1 7,120.0 ki ..:. 3 1 120.000 .Kugrua ironstone '."..., Shaker Checks _ , _ , , ,,- 4e- ST: oiiiii (iiiigaiy Hrs (hrs) Kingak Fm. 41. = 6. ':2'...' 'k!':: ' I C sg Run D ate 100 'T'I! Wt (lbs/ft) 1::0 ril 1 '?* '':;' l :Reaming 3 19/2007 16 H-40 65.00 T :it- Run Make Bit Inventory Bit Type :item Cost lS llrfillf4W 'r'ki":41 0lifli ' ili.re .I 3 Hughes 8 1/2in, MX-1 , 5114219 Mill Tooth 1 - Csg Run Date OD (in) Grade Wt (lbs/ft) 1,.. $.:11ADC Bit Dull TFA (Inc! Noz) (in') [BHA ROP (ft/hr) Nozzles (/32") IADC Codes 3/31/2007 9 5/8 L-80 40.00 ir,:, 0 0.00 0 1-1-5-W „,„ , ,, . Cern9OFIttluir . ! 'A w:4 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10 Max. Hook Load ,'!,:64:-'3-;;:,,vi, ki'''Efiqr.;14';11'::=11r.:4':01:1:0' ---- ' ''' ''''' `1 com ,1 - ; , .:. '' "' $.■'; ':., ' ( lb f) DMPt peti'l 4 3 1,450.0 360 230 280 ttiVOB (1000Ibf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HI- (1000Ibf) Max. Over-Pull (ibf) ...„ . 10 0.00 280 50,000.0 .0 „..r. Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO Ht. (-mama ..f, 0 I 210 ra. Hydraulic Calculations AV DP (fbmin) AV DC (ft/min) _- Err _.,..., -_-.....,.. ■8 A casing component contains a null value in ID ,, '',..: Drill String Components Mir Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle lli Jts Description Len (ft) OD (in) (lbs/ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (*) 101 Drill Pipe 2,868.... 41 14.00 X95 ! 3.340 4 FH 1 4 FH 1 3,463.73 4 HWDP 124.04 4 27.20 2.750 4 FH ; ,, 4 FH 595.33 , !..! 1 X0 Sub 1 2.631 4 1 1 I 41F! 4 FH I 471.291 Report Printed: 4/23/2007 • FEX L.P. - DDR Detail — _ - - Page 313 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/16/2007, Report: 26.0, DFS: 20.47 III '' � Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) 18.20 1 37.10 1 18.90 E , Drill String Components -- -- -- --- - - - - -- Mtr li Top Btm Bend k` Item Density Drift Conn Sz Conn Sz Btm Angle 111 Jts Description Len (ft) OD (in) Ps/ft) Grade ID (In) (In) (in) Top Thrd (in) Thrd Cum Len (ft) r) 1 Drilling 31.98 4 2.000 4 FH 4 FH 468.66 Jars - Hydraulic 1 XO Sub 0.00 4 2.41 4 FH `' 4 FH 436.68 14 HWDP 435.68 41 27.20 12.750 4 FH 4 FH 436.68 I 1 XO Sub 0.00 4 2.02 4 FH 4 FH 1.00 , , 1 Bit Sub 0.00 4 2.20 4 FH 4 FH 1.00 W� either* Name VS Dir ( °) Kick Off Depth (ftKB) Original Hole 258.00 1 'a i i Directional Surveys is Date Description 3/27/2007 j M WD Surveys , ' is MO l fiV 1,,. i 1 11014 ■ L I/1 u a ' 1 jai i ' '' I $1, , • t IC `161 a P Report Prim ° i o ,G s i � il , £Z A, ∎1 1 i101: 11111,1b1i6 NOUN' l,aa, .. '.1YI ,,,,., ,.. ________ _ 4 FEX L.P. - DDR Detail Page 1/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/17/2007, Report: 27.0, DFS: _ 21.47 • Job Spud Date - -- Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,2 Safety Type Date 1Mb' IiH � PR 8711fi �1H'iHHlr Comment ak a a * _ Target Co 7 , 2 62.0 ) Cum Cost Formation 1 Safety Highlight 4/17/2007 WILDLIFE / REPORT ALL SIGHTINGS Daily y� 1 ; r 258,660.95 11,988,860.72 I G Daily Summary ,+; r .i ' ' . ° t •" -- ,, r Weather Lease I Road Conditions Wellborn Condition Over ( +) / Under ( -) AFE ( +l -) Var Days Daily Mud Cost Mud Cum To Date wet snow 6 deg Good Fluid Losses 1.5 17,228.70 416,301.07 _< -- - -- --- .. Depth Start (ftKB) Depth End (ftKB) ..._ - Operations @ 08:00 Running 7" Casing / Loosing Fluid @ 19 bbl / hr _7,280 0 ,ijl��§ 00 ■ Operations This Report Period - -- _- - - - -- - - - - -- - -- - -- - - - -- -- ___ -- Depth Progress (ft) Drilling Hours (hrs) ,'' ! Hoist out to Run 7" Csg. /PRE- JOB Safety MTG./ Rig up Csg, Tool/ Change Pipe Ram Blks to 7 "! Pre- Job jH Safety Mtg. / Pressure Test 7" Pipe Ram blks to 1500 PSI /AOGCC Waved witnessing Test / Pre- Job Safety ' Orientation on Running 7" Csg./ Makeup Reamer Shoe & Run Csg. & Floast Clrs/ Stage Tool / Centrilizers (21) 1� ' � ' ' ` �In,; , in total. Break circ at 3683' establish loss rate of 90BPH when pumping at 115 GPM. Running loss rate Ja can(acli 'phone, consistent at 19 BPH Ernie Natte, Drilling (907) 771 -0536 y Ij Foreman 1111 Operations Next Report Period 0�u' rI" I g xtHil IIjIIjIIIjIN �yl!j casing and pump cement R 9sp e + rg a� ir eS � .. 1 } Run g p p Rlg Supervisor Bob Lupton, Rig Manager T141W j .3 . • RR t at?--- ' r„?;!a :U. . . , .n.!4 t a.- .. ., ... . - -- 70 17 Start'. Dur Opt � Scheduled Depth End Mud Fit !j ¢ ner- Denver, P =9 Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment No. Pwr (h Rod Diameter (in) 00:00 i 6.00 Drlg Planned Flat Prod Cond Trip Out No Trbl 7,280.0 POOH to BHA. 1 900.0 I Op Trip 1 Upper hole in better Liner Size (in) fstroke (In) Vol /StkOR(bblls... shape pull slow not 5 1/2 9 02 j 0.066 to swab. - Pump Checks 06 :00 1.50 Drlg Planned Flat Prod Cond Handle Tools No Trbl 7,280.0 Lay down HWDP, Strokes Op Trip jars and bit. Pres (ps Slow Spd (Spm) ert ( 07:30 1.00 Drlg Planned Flat Prod BOP / Wellhead No Trbl 7,280.0 Pull wear bushing No 1 Op ! WH / and set test plug Filie� 2 , tti ?Z 9 ''... Drillout No. Pwr (hp) Rod Diameter (in) 2 900.0 08:30 1.00 Drlg Planned Flat Prod BOP / BOP No Trbl 7,280.0 PJSM and change Liner size (in) Stroke (in) Vol /Stk OR (bblls... Op WH / top rams 5 1/2 9.02 0.066 0 09:30 1.50 Drl Planned Flat Prod Case & Ha ndle Tools No Trbl 7,280.0 PJSM and fig up Pump Checks Drillout 9 i li g Strokes ", Op Cmnt TESCO running Pres (psi) Slow Spd (sPm) tool No 11:00 0.50 DrIg Planned Flat Prod Case & Handle Tools No Trbl 7,280.0 Clear floor to run Shakers:' <Descrip a . ij! ;a, Op Cmnt casing. Make Mode € II 11:30 2.00 Drlg Planned Flat Prod Case & 'BOP No Trbl 7,280.0 Rig up and test r - I , Op ' Cmnt casing rams to Shaker Screens 1 500 psi f 10 mi Screen rig down and blow L Dec No. 1 No. Scr Sz x (in) Scr Sz, (in) 0 , * down lines. � - I i 1 1 1 Shaker Checks 13:30 1.00 Drlg Planned Flat Prod Case & Run Casing No Trbl 7,280.0 Make up shoe and Dens OF (Iprgaq Dens OF (lb /gal) Firs (hrs) I Op Cmnt shoe trac. Have a , PJSM for casing "H ' r ka � . , �rIG rp running Make Model 14:30 7.50 DrIg Planned Flat Prod Case & 'Run Casing No Trbl 7,280.0 Run casing to 3638' - - , Op Cmnt static loss rate of Centrifuge /Cyclone Checks ,41 j 19 BPH Density Overflow (Iblgal) Overflow Rate (gpm) r`.. t 22:00 1.00 Drlg P Flat Prod Case & Run Casing No Trbl 7,280.0 Break circulation to Dens (b /gal) UnderfiowRate (gpm) 3 ' . ' Cmnt establish loss rate. 't#; losses at 90 BPH Hours (hrs) 1011 Under Fl (%) Dens FD (lb /gal) returns = 50% at 44spm= 115gpm• i y, l pump for 20 min. R Ilil ( t � of t . , i ; d Descript Cons... Dally Cost Vend 23:00 1.00 Drlg Planned Flat Prod Case & 'Run Casing No Trbl ' 7,280.0 Run casing to MUD LAB 1.0 45.00 'Op ' Cmnt i 4165'. Running i Baradefoam 1.0 109.85 the hole with 19 HP I bph loss rate. Potassium 2.0 119.38 Hydroxide BA. DM 2.0 1,575.00 Tech III Service /L... PAC -L 12.0 1,900.80 Barazan D+ 18.0 2,856.78 Baranex 1 36.0 2,786.04 • tl: . :gip � Y 3/2007 i� il�Ili� .ar I r 4 , , •' . 4 3 E Y4,:, - ti k - FEX LP. - DDR Detail Well Name: AKLAQ #6 ,adtfiitli„titri t Job Type: Drilling - Original Date: 4/17/2007, Report: 27.0, DFS: 21.47 1 1 • Ground Elevation (ft) Orig KB Eiev (ft) KB-Ground Distance (ft) lifilft Mud Additive Amounts 18.20 37.10 18.90 Description Cons... Daily Cost Vendor f Mud Checks: 7,280.Q,ftKB, 44);"; s 07 14:15 Potassium 1 120.0 1,953.60 Density (lb/gal) 1pH CEC for Cuttings Pt (mUmL) Calcium (mg/L) % Water (%) Mud Lost (Hole) (bbl) Chloride 10.00 9.0 200.000 89.0 , 228.0 Baroid 575.0 882.25 4..i. Vis (s/qt) Filtrate (mL/30min) Filter Cake (/32") Pm (mL/mL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbi) 58 3.9 1 32,000.002 0.5 PV Over (cp) Gel (10s) (lbf/100f... Sand (%) MBT (Iblbbl) Lime (1b/bbl) Oil Water Ratio Mud Vol (Act) (bbi) lo .' ,Ii',.,, '-- r_.... 6.000 0.3 5.0 0.6/99.4 1018.0 IP YP Over Obf/10... Gel (10ni) (lbf/100... Solids (%) LGS (%) Polymer (ppm) LCM Mud Vol Masi (bbl) ' ," '' ' ' I .' d ' 't ''t.' . "!'' V 12.000 8.2 6.1 Test TY,P. Type Gel (30m) (lbf/100... T (fl) ("F) Chlorides (mg/L) HTHP Flit (mL/30... Alkalin (mIJmL) Whole Mud Add (bbl) Polymer 15.000 28,999.999 13.8 156.0 'Formations 'It; Max Back Gas (%) Avg Back Gas (%) Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas (%) - sirii3Temp 1 Formation Name MD (ftKB) Silicate (%) Electric Stab (V) Comment Nanushuk Group 912.0 Base Permafrost 1,020.0 Drying Shaker Da , Model Nanushuk topset sst. 2,795.0 Description Make Nanushuk topset sst. 3,388.0 HG Dryer Derrick Torok 3,470.0 Shaker Screens Deck No, Screen No. Scr Sz X (in) Scr Sz Y (in) Torok sand 1 1 1 1 1 120.000 Torok sand 2 44:783542..00 2 120.000 Torok sand 3 5,090.01 3 1 120.000 Torok sand 4 5,630.0 Torok sand 5 5,798.0 Shaker Checks (hrs) Torok sand 6 6,008.0 - - - 1 1 Torok sand 7 6,313.0 Description - rake Model Torok sand 8 6,568.0 HG Dryer Derrick 1 HRZ 6,605.0 III Shaker Screens Kuparuk Sandstone Mbr 6,800.0 i ' 1 screen No I t S4r Sz X (I'll Scr Sz V °n) " LCU (lower Cret. 6,880.0 ; 120.0091- Unconformity) 2 1 120.000 BCU (Base Cret. 6,880.0 3 1 120.000 Unconformity) Shaker Checks Dens UF (lb/gal) H I ., ( ) Upper Kingak (Miluveach) 6,880.0 Kugrua siltstone 1 7,066.0 Description 1Make 1 - TModel Kugrua sandstone 7,120.0 HG Dryer Derrick Kugrua ironstone Shaker Screens Kingak Fm. 1 Deck No, Screen No. .., Scr Sz X (in) Ser Sz Y (In) C 1 I 1 120.000 I V P, 8.8n9)ftkGraBde Wt (lbstft) 2 1 120.000 3/19/2007 16 H-40 , 65.00 , 3 1 120.000 :::!' tel' Shaker Checks Csg Run Date OD (In) Grade Wt (lbs/ft) Dens UF (lb/gal) 11 ' Hrs (hrs) 3/31/2007 9 5/8 1 L-80 40.00 10 Production Casing, 7,050.0ftKB Drill Strings: BHA #3, Reaming, olL4,464 „,„.,,,,,, Csg Run Date OD (in) Grade Wt (lbs/ft) 1 Bit Run Make Bit Inventory Bit Type Item Cost 4/17/2007 7 L-80 26.00 1 3 lHughes 8 1/2in, MX-1 , 5114219 Mill Tooth i Cemdi '.,' - . ' ''.' IADC Bit Dull ITFA (incl Noz) (In') IBHA ROP (ft/hr) Nozzles (132") IADC Codes Cmnt Des Comment 0-1-NO-A-E-0-WT-TD 1 0.00 1 0 1-1-5-W [ i lk 7,280.0 - <End?> ftKB kyili, BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (lbf) filli 3 230 280 1 I wos (10001bt) - Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over-Pull (ibf) 'di 1 1 VI 0.00 280 III; 0.1 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units ISO HL (1000 0 rl .. it' Hydraulic Calculations ilk AV DP (ft/mm) H , AV DC (ft/min) A casing component contains a null value in ID 41 Drill String Components IP . , Mtr Top Btm Bend .. Item Density Drift Conn Sz Conn Sr Btm Angle '111.2 1 '0 ( 1 1 Jts Description Len (ft) OD (in) (lbs/ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) il 14k'I 0 101 Drill Pipe 2,868.... 4 14.00 X95 3.3401 4 FH 4 FH 3,463.73 4 HWDP 124.04 4 27.20 2.750 4 4 FH 4 FH 595.33 -0 11X0 Sub 1 2.631 41 1 1 1 4 FH 4 FH 1 471.29L__ I 111 ill! 110 111 ' '4 ilt .;;Af A ' .P171 t'ir lit eliy - r , t,,,Vtli, ; , Report Prii .,..: 4/23/24,t; ;'. 4, ,bm„,441 142 o„,ghwir.i. k --- -- - _AV__ _ii• FEX L.P. DDR Detail Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/1712007, Report: ' 27.0, DFS: 21.47 Ground Elevation (ft) Ong KB Elev (ftj KB-Ground Distance (ft) 18.20 37.10 18.90 Drill String Components Mtr Top Btm Bend Item Density Drift Conn Sz Conn Sz Btm Angle Jts Description Len (ft) 00 (in). (Ibslft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) ` I') 1 Drilling 31.98 4 2.000 4 FH 4 FH 468.66 Jars - Hydraulic j 1 XO Sub 0.00 4 2.41 4 FH 4 FH 436.68 ■ 14 HWDP 435.68 4 27.20 2.750 4 FH 4 FH 436.68 1 XO Sub 0.00 4 2.02 4 FH 4 FH 1.00 1 Bit Sub 0.00 4 2.20 4 FH 4 FH 1.00 � tc §� tk r VJellbore Name VS Dir (°) Kick Off Depth ( Original Hole 258.00 Directional Surveys Date Description 3/27/2007 j MWD Surveys i II 17, r a; ti l iii 4 iri 41 10 l I k; i fi� i 1' ,''k Report Printed: 41212:01:1;:k:::71'''';'1'''''' 12 72 0 0 7! ,� „ . -.e bsx Ii :w d!4a��a 46, I �� §4tl.v o-n, u ,. .,6„,14-, : .., ;,t, t. , . �. . , ... . §. ilr. � u , x. er , . s. -- - — ------41)----- FEX L.P. - DDR Detail � k ` , 5 , a�r�1� n �� " r ,�I ,' ,, I Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/19/2007, Report: 29.0, DFS: 23.47 41 Job Spud Date - Rig Release Date GroundElevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 1 3/27/2007 _ 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 Safety Target Depth (ftKB) Target Formation Type Date Comment 7,262.0 Safety Highlight 4/19 /2007 Phase II Blow ! Convoy Travel Only Daily Cost Total Cum Cost To Date 1 Dailysu(nmaty ' 222,136.69 12,477,793.23E Weather Lease I Road Conditions Wellbore Condition Over +) / Under ( -) AFE ( +/ -) Var Days Daily Mud Cost Mud Cum To Date Phase II Blow 19 F snow Fluid Losses 12 19,160.69 460,825.3 Operations @06:00 y — Depth Slitit (ftKB) Depth End (ftKB) Lay down Tesco CRS Operations This Report Period __ — — - -- - -- - — --- Depth Progress (ft) Drilling Hours (hrs) . „: Safety Mtg. w/ Cementers /Rig up Cement Head 35' in Derrick Due to Stuck Pipe / Per Job Cement Procedures I Circ. Out Gas * * ** 4200+ Units * * * ** /Cement 1st Stage Displace with Rig Pumps / Bump & Open Stage tool r m. I,( g s # . 1. With Cementer/ Tool Opened Q 3300 psi / Circulation handed over to Rig to Circ. out Contaminated Cement ° i ® a� , i i 1 C on,, above Stage Tool / Lost Complete Circulation after 30 bbls over Excess of 30% Annular Volume 1 Stopped ,' '� J. C ontact ' P0oda Pumps & Hole it Gave Back 12 bbls in 1 hr/ then tapered off to nothing / Safety Mtg. & Procedures /Rig to & Gregg Fischer, Drilling (907) 771 -0536 a Pump 2nd Stage Total Losses for First 75 bbls Pumped / Only receive Back 30 % of Volume Pumped /Cement Foreman Top Can Only be no higher than 5500' with calulated losses planned to be Q 4500' ! after bumping plug HES Kim Parenteau, Drilling (907) 771 -0536 pumper took over and closed stage tool by pressuring up to 1755 psi ! blow down both HES and rig pumps / )lpreman a Rig down cement head and X/O / W/O cold cutter to cut casing / Lift BOPs / set C21 manual slips (set with 4 0k iR,ppy Arctic Wolf t over) / install cutter and cut 7" in preparation for installing pack -off assembly - Rig Supervisor Bob Lupton, Rig Manager Operations Next Report Period Ud Pumps: 1, Gardner-Denver, p Set Manual Slips & Seal/ Press. Test Bop Equip. Makeup Bit & RIH to Drill Out Float & Shoe No . Pwr (hp) Rod Diameter (in) 1 900.0 1 ,l at Type Phase Major Op Operation Trouble �`' Liner Size (!n) Stroke (i VoUStk 066 0 p0 i � i ® y - ed De nKB rid m. , �cmmed 5 112 9 . 00:00 2.00 brig ' Planned Flat Prod Case & Rig Up No Trbl 7,280.0 Rig up cement Pump Checks Op head /lines ( -35' in Strokes , O Cmnt i air due to hole Pres (psi) Slow Spd (spm) ES ( %) conditions) No 02:00 3.00 Drlg Planned Flat Prod Case & Circ Casing No Trbl 7,280.0 Pre -job safety Mud Pumps: 2, Gardner -De' 1yi,: Op Cmnt meeting on cement No. Pwr (hp) Rod Diameter (In) procedures / 2 900.0 1 0 Circulate out gas Liner Size (in) Str oke (in) VoUStk OR (bbl /s... - (4200+ units) _5 9.02 � _._. 0.066 g Op Flat Prod Case & Cmnt Casing No Trbl 7,280.0 Pump 5 bbls water, Pump Checks 05:00 2.00' Drl Planned Stokes Cmnt pressure test lines Pres (psi) Slow Spd ( sp m ) E ft( / ; to 3500psi. No Continue to pump 5 . De . , } _ "' °� blls water followed ° � " by 20 bbls of 11.5 #1 Ma ks Model s — — — 15. cement 23 bbis (1st of Shaker Screens stage). Drop plug , • Screen and chase with y Qeck No. No. Scr Sz X (in) Scr Sc Y (in) 5bbls water. Rig r- L 1 pumped Shaker Checks displacement of 1 Dens OF (Iblga'f)' Dens UF (lb /gal) Hrs (hrs) 260 bbls mud --„,„:„ before HES took .,.., _ over for last 6.25 I Make Model bbls. Bump plug and pressure to Centrifu, e/C clone Checks 3200 psi to open Density Overflow (lb/gal) Overflow Rate (gpm) stage tool with 1 cementer. Dens UF (1b/gal) Undernow Rate (gpm) Hours (hrs) Oil Under Fl (%) i Dens FD (lb/gal) x�. ; Cons... Daily C. ,,, P " �` MUD LAB 1 1.0 45.00,,''` Baranex 19.0 1,470.41 STEELSE... 12.0 1,638.001 Barazan D+ 10.0 1,587.10 N -DRIL HT+ 17.0 1,615.68 r 0 I Baradefoam 11.0 1,208.35 HP CiricAcid 14.0; 1,513.12', ir Baracarb 48.0 1,188.96 ill 150 Report Printed: 4/23/2007 - 0 — FEX L.P. - DDR Detail Page 2/4 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/19/2007, Report: 29.0, DFS: 23.47 • Ground Elevation (ft) OrIg KB Elev (ft) KB- Ground Distance (ft) Mud Additive Amounts 18.20 37.10 18.90 j Description Cons... Daily Cost Vendor Time Log i l° , Potassium 12.0 716.28 Start Dur Ops Scheduled Depth End Hydroxide Time (hrs) Cat Type : Phase Major Op Operation Trouble (ftKB) Comment Barofibre 15.0 377.40 ' 07:00 8.00 DrIg Planned Flat Prod Case & Circ Casing No Tr bl 7,280.0 Rig circulated Bicarbonate 17.0 471.58 Op Cmnt 1 through stage tool ,1 I while WOC. Lost of Soda complete circulation'Baracarb 50 20.0 376.40 , initially. Stopped X -Cide 207 1.01 120.28 pumps & hole BA. DM 2.0 1,575.00 I returned 12 bbls in Tech 1 hr, then tapered Service /L... off to nothing. Continue to Baracor 700 13.0 1,881.23, circulate hole by Baroid 330.0 3,375.90 pumping 17 stks i "' every 15 minutes. 1 h�igai �tnt Check Dote, Type 1.00 Drlg Planned Flat Prod ( Case & Circ Casing No Trbl 7,280.0 Slug pipe to stop lI � e Cheo �l ' I,;i N a , ':Ili Op Cmnt u -tube effect. Load Test Date Test Type 1 P 2nd stage plug into I if' 01 1� i 3,r? '� 3 ' 2 • cement head. Formations ali ,. Continue circulating sample Top a lb t ,, 4 : ? k t ` casing with rig Formation Name MD (ftKB) ' p ,� " l , �� � a pump with 100% Nanushuk Group 912.01 myra p I t, �j x Ptn ," losses Base Permafrost 1,020.0 �t L '' ' "," , 6 y r,i y ,. Nanushuk topset sst. 2,795.0 16:00 2.00 D rIg Planned Flat Prod Case & Cmnt Casing No Trbl 7,280.0 Cement safety Nanushuk topset sst. 3,388.0 ' ■ Op Cmnt meeting. Rig to & Torok 3,470.0 pump 2nd stage. 10 Torok sand 1 4,734.01 1 bbls water, 20 bbls Torok sand 2 4,852.0 spacer, 60 bbls cement. After Torok sand 3 5,090.0 droppping plug Torok sand 4 5,630.0 il i followed with 5 bbls Torok sand 5 5,798.0 water by HES Torok sand 6 6,008.0 followed by rig Torok sand 7 6,313.0 pumping 240 bbls Torok sand 8 6,568.0 mud. Bumped HRZ 6,605.0 before HES took over to increase Kuparuk Sandstone Mbr 6,800.0 p lit ressure to 1755 LCU (lower Cret. 6,880.0m. psi to close cement Unconformity) I tool. Encured total BCU (Base Cret. 6,880.0 r losses for the 1st Unconformity) 75 bbls pumped Upper Kingak (Miluveach) , 6880.0 followed by -30% i ' returns . Believe Kugrua siltstone 7,066.0 0,0 cement top to be - : Kugrua sandstone 7,120.0 a,` 5500' ( planned @ Kugrua ironstone Ii 4500') Kingak Fm gg'�' I . G D ate D (In) S Grade Wt (I 3/19/2007 16 ' H-40 65.00 00 .. 18:00 1.00DrIg Planned Flat Prod Case & Rig Down No Trbl 7,280.0 Blow down both Surfac I , ' p + 'I a (� , ,, € , Op Cmnt HES and rig csg Run Date OD (In) Grade Wt (rosrft) pumps. Rig down 3/31/2007 9 5/8 L -80 40.00 cement head and Production Caafn'gl .050.0: iCijl „r9 I I X/0 Csg Run Date OD (In) Grade 1Wt (Ibs /ft) 4/17/2007 7 L -80 I 26.00 19:00 3.00 DrIg Planned Flat Prod 'Case & Wait on Other No Trbl 7,280.0 W.O. cold cutter to �ont 00 ' ,ilu�igl Op Cmnt cut casing. Cmnt Des Comment ■ Continue to monitor I 0 i well status for flow iii -- 0 - - - 10 FEX L.P. - DDR Detail Page 3/4 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/19 /2007, Report: 29.0, DFS: 23.47 - Ground Elevation (ft) ?Orlg KB Elev Elev (ft) KB- Ground Distance (ft) 18.20 1 37.10 1890 "M � x � sY *4 � H. 1,'' H y ' , H H' , , �, 'ui6 l d��� ,• 1( �Time't_Og 11 � '.b �i�l���r� �� "'I � ,; , i � n .'"'d, ,�-'� , � _� ;11 i I k'� � t l.F r +fir ihi��� " -) � �` Start Dur Ops Scheduled Depth End Time (hrs) Cat Type Phase Major Op... Operation Trouble (ftKB) Comment 22:00 2.00 Drig ' Planned Flat Prod Case & Wellhead No Trbl 7,280.0 Lift BOPs and pull Op Cmnt to 190 kips. Set C -21 manual slips (set in tension with , -40k over string , weight). Install cold cutter assembly II and cut 7" in preparation for a' install of pack -off 1 !, assembly. :b ikB 4/19%200`7 13 :00 ' Mud Che " ,, �.... II Density (1b/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) 9.80 8.8 0.050 200.000 91.0 374.0 Vis (s /qt) Filtrate (mL/30min) Filter Cake (/32 ") Pm (mUmL) Potassium (mg /L) Percent Oil ( %) Mud Lost (Surf) (bbl) 53 4.3 1 0.150 4 PV Over (cp) Gel (10s) (lbf/100f... Sand (( %) MBT (Ib/bbi) Ume (Ib/bbl) Oil Water Ratio Mud Vol (Act) (bbl) 11.0 4.000 5.0 610.0 YP Over (lbf /10... Gel (10m) (lbf /100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 15.000 11.000 6.6 4.6 Type Gel (30m) (Ibf /100... T (B) ( "F) Chlorides (mg/L) HTHP Flit (mLt30... Alkalin (mUmL) Whole Mud Add (bbl) ii io Potassium 13.000 29,999.999 13.5 383.0 Salt Base Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas ( %) Avg Conn Gas ( %) Max Trip Gas (%) Avg Trip Gas ( %) Ve Silicate (%) Electric Stab (V) Comment tri ft Mud Checks: 7,279.0ft , . X3119/2007 23:00 b . ill Density (lb/gal) pH CEC for Cuttings 1Pf (mUmL) Calcium (mg /L) % Water ( %) - -,Mud Lost (Hole) (bbl) 9.80 11.2 0.350 340.000 91.0 Vis (s /qt) Filtrate (mU30min) Filter Cake (132 ") Pm (mUmL) Potassium (mg/L) Percent Oil (%) Mud Lost (Surf) (bbl) I 53 4.7 1 1.000 PV Over (cp) Gel (10s) (lbf/100f... Sand ( %) MBT (Ib/bb1) Urn* (lb/bbl) Oil Water Ratio Mud Vol (Act) (bbl) k i. 11.0 3.000 5.5 1 b 1 , Gt YP Over (IbfMO... Gel (10m) (ibf /100... Solids ( %) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) j ;11 14.000 12.000 7.0 5.0 _ t Type Gel (30m) (Ibfl100... T (B) ('F) Chlorides (mg /L) HTHP Flit (mU30... Aikalin (mUmL) Whole Mud Add (bbl) 44 Potassium 17.000 25,000.000 Salt Base Max Back Gas ( %) Avg Back Gas ( %) IMax Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas ( %) Avg Trip Gas ( %) flit i 1' Silicate ( %) Electric Stab (V) Comment i'll. Cm r,. .h I s Description Make Model 14, HG Dryer Derrick Shaker Screens Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 2 1 120.000 MI 3 1 120.000 1 1 Shaker Checks l i l lii Dens OF (lb /gal) Hrs (hrs) ,,.. ; cS R; 1 Description Make Model 1. HG Dryer Derrick Shaker Screens Ilii Deck No. Screen No. Scr Sz X(in) Scr Sz Y (in) 1 1 120.000 'El Li 2 1 120.000 3 1 120.000 ill Shaker Checks 1 " Dens OF (iblgal) Hrs (hrs) ., Description Make Model 1,1'''';' HG Dryer f Derrick ` . �ri` I tar r t, " ) 'j. 'e �., nr.. _` -. t x, via 'r , k = i , 7t p l „tit ! � . t i t ', p ! i 110- 0 FEX L.P. - DDR Detail Page 4/4 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/19/2007, Report: 29.0, DFS: 23.47 • _, B (iotmd Olsfrr'Lr n d Dis �' _.. Ground Elevation (ft) Orig KB Elev (ft) K- ance (ft) 18.20 37.10 18.90 Shaker Screens .., 3,ii imp : �IIII / °. r. -r a. (in) ScrSz . 1 1 120.000 vl. 2 1 120.000 I Fi 3 1 120.000 Shaker Checks l; Dens OF (lb /gal) Hrs (hrs) i - r i �l ?' r;� ; i rat i:8111)i t ? kNki a ate ts . v k dz t r * rt_ F t :R r . <a "' Bit Run Make Bit Inventory Bit Type Item Cost IADC Bit Dull TFA (Intl Noz) (In') BHA ROP (Itlhr) Nozzles (132 -) IADC Codes BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot F112'00001... Max. Hook Load (lbf) WOB (1000lbf) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000lbf) Max. Over-Pull (Ibf) Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (10001W) Hydraulic Calculations AV DP (ft/min) AV DC (f /min) Err Drill String ,- Com . onents i�Ii x* Mtr Top Btm Bend ' Item Density Drift Conn Sz Conn Sz Btm Angle it Jts Description Len (ft) OD (in) (Ibslft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (°) I li Weilbores ,..� r €' ' ter= ' -rya Wellbore Name VS Dir ( °) Kickoff Depth (ftKB) Original Hole I 258.00 ilk Directional Surveys Date Description t 3/27/2007 MWD Surveys i ik , I I 3 3431 �r 1�I 4i I ;4 "a' 0 i Report Printe 4123/2007 - r a FEX L.P. - DDR Detail Pa 1/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/20/2007, Report: 30.0, DFS: 24.47 I) Job Spud Date Rig Release Date TGround Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (ft) AFE No. Total AFE Amount Total AFE+Sup 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574244.00 Air, Safety Irri1rp 4/F. riR111p1MANA' Target Depth (ftKB) Target Formation h , Type Date Comment 7,262.0 Nil, Safety Highlight 4/20/2007 (Warm Temp. Changing things fast /Water on Surface of Pad /Timeline Daily Cost Total Cum Cost To Date I; INC. Daily Summary 557,182.12 13,034,975.35 I Weather Lease I Road Conditions Welibore Condition Over (+) I Under (-) AFE 1 (44-) Var Days Dally Mud Cost Mud Cum To Date cool 20 deg Good 'Fluid Losses 2 1 3,729.62 _ 464,554.95 Operations @ 06:00 - - - -- - -- 'Depth Start (ftKB) Depth End (MB) , DrIg on Stage Tool Operations This Report Period - - - -- --------- - ----- ---- - -- -- rDepth Progress (ft) Drilling Hours (hrs) Finish cutting 7" production casing, Install pack-off, nipple up stack and pressure test to 5000 psi, change rams from 7" back to 4", RID Tesco CRS, Pressure test BOPs and function test accumulator. M/U bit and start to 11,', #oremar i' i l o iliilillpiilli ik l i . il i l i ti i Plii5,..1,! .i. , i ,c' 1 "i i h,: i , i ,, iiii RIH to pressure test lower pipe rams/drill out stage tool and pressure test casing. Abandon 9-5/8" surface casing by 7" production casing annulus: - pump 50 bbls mud to determine feedrate (avg pressure of 300 psi at J C T. ,,.,, i , • .1.1111446 ri; 3 bbl/min) followed with cement. Pumped 48 bbls of 15.8 ppg class G (starting pressure of 350 psi dropped to Gregg Fischer, Drilling (907) 771-0536 30 psi at end) and 35 bbls of 10.7 ppg premafrost type L (-30 psi throughout). Upon closure of annular casing Foreman valve observed wellbore annulus to be on vaccuum. Kim Parenteau, Drilling (907) 771-0536 Foreman , Operations Next Report Period 'Rigs: Doyon, Arctic Wolf Finish pressure test lower rams, slip and cut, drill out stage tool, pressure test casing. POOH and UD DP on Rig SupervIsor way out in preparation of cased hole logging run Bob Lupton, Rig Manager iii .1(1 Nlud Pumps: 1, Gardner-Denver, PZ-9 Time Log Ni Pwr i Rod Diameter (in) Start Dur Ops Scheduled Depth End 1 %, ."., o. ,„, Time (hrs) Cat Type Phase Major Op Operation Trouble (ft/KB) CommerNY 1 900.0 _ . .....,... .... 00:00 1.00 DrIg Planned Flat Prod Case & Wellhead No Trbl 7,280.0 Finish cutting 7" Liner Size (In) Stroke (In) Vol/Stk OR (bbl/s... Op Cmnt , production casing. 1 5 1/2 9.02 0.066 LID joint #174 and Pump 13.57 ft or joint 173 • "' Strokes — T dii, viff 01:00 2.00 DrIg Planned Flat Prod BOP / Wellhead No Trbl 7,280.0 Safety meeting, Pres (psi) Slow Spd (spm) Eff (%) ((( ((N (( ( (.. ( Op WH / install pack off Drillout assembly, lower fol(It Ii.... 111 - 70 enver, PZ-9 BOP stack and No. Pwr (hp) Rod Diameter (in) 110 nipple back up. 2 900.0 1.:. Pressure test pack Liner Size (in) 'Stroke (in) Vol/86c OR (b1 off to 5000 psi. 5 1/2 _j 9.02 0.066 p., Pump Checks 1 03:00 2.00 Drlg Planned Flat Prod BOP / BOP No Trbl 7,280.0 Change ranms 7777 Strokes il q lf. Op WH I back to 4" from 7". Preis (psi) Slow Spd (spm) Eff (%) Drillout 1 Re-Install Katch No I 1 Kan S1 ., ' ,, ".?,./... i' ' -2 '„i',,tion9> 05:00 1.00 Drlg 'Planned Flat Prod BOP / Rig Down No Trbl 7,280.0 Safety meeting and d make Model Op WI-I / rig out of Tesco Drillout CRS (( Shaker Screens geav Screen 06:00 3.00 DrIg Planned Flat Prod 'BOP / Rig Up No Trbl 7,280.0 Clean floor, R/U ::Deck No. No. Scr Sc X (in) Scr Sc Y (in) Op WH / bails and elevators ---1 I 1 Drillout on top drive . Shaker Checks [Dens OF (lb/gal) Dens UF (Ibigal) Hrs (hrs) i i 1 Make Model i . 1 Centrifuge/Cyclone Checks ri 1Density Overflow (IbIgal) Overflow Rate (gpm) ' Dens UF (lb/gal) Underflow Rate (gpm) rt, Hours (hrs) Oil Under Fl (%) 'Dens FD (Ibigal) A ... ,•Rpons... Daily Cost Vendor BA. DM 2.0 1,575.00 Tech , Service/L... 1 Bcarbonate 2.0 55.48 ill of Soda Baranex 10.01 773.90 (Potassium 72.0 1,172.16 y- II Chloride MUD LAB 1.0 45.00 01 Ciric Acid 1.0 108.08 R ft P ' ted. 4/23/2007 ill ;'''' ' :!1°Yivi,i;;:,:Aiii1,,ii„,',a,'.0.,1.11 ,,,,,I,,O,, ,N14„4 ,, ,,,,, , '01,111104 ne , ,■ „ 4 I bak- , ,1,, , ,,,,, • FEX L.P. DDR Detail Page 2/3 Well Name: AKLAQ #6 . , . ® Original Date: 4/20/2007, Report: 30.0, DFS: 24.47 , Ground nd Elevation (ft) Ori g KB Elev G rou Orig Ele (ft) KB- Ground Distance (ft) Last C asing Check ' al AoiIIIiIMu Aklil 18.20 37.10 18.90 1 ype 'WA 0, Da te T li !, Start Dur Ops Scheduled Depth End l'-' ' �i Time (hrs) Cat Type Last BOP Check �I •� ( ) : YP Phase Major Op Operation Trouble (ftKB) Comment Test Date , , Test Type 09:00 1 12.00 Drlg Planned Flat Prod BOP / BOP No Trbl 7,280.0 Safety meeting, Op 1WH / ' Pressure test BOPs .. - Formations Drillout as per AOGCC. I Sample Top Small leak on Formation Na el ,' (ftKB) choke line flange Nanushuk Group 912.0 ; repaired w/o issue. Base Permafrost 1,020.0 Function test accumulator as Nanushuk topset sst. 2,795.0 l' well. Unable to test Nanushuk topset sst. 3,388.0 lower rams - Torok 3,470.0 casing cut off Torok sand 1 4,734.0 appears to be Torok sand 2 4,852.0 hindering the ( sand 3 5,090.0 landing of the test Torok sand 4 5,630.0 low enough to get a Torok sand 5 5,798.0 seal on the pipe Torok sand 6 6,008.0 rams over the DP Torok sand 7 6,313.0 body. Received 'Torok sand 8 6,568.0 verbal approval HRZ 6,605.0 from Tom Maunder AOGCC to test with ' Kuparuk Sandstone Mbr 6,800.0 l I DP to 3500 psi ' LCU (lower Cret. 6,880.0 j I while RIH. Rig Unconformity) down BOP test BCU (Base Cret. 6,880.0 equipment. Unconformity) (Upper Kingak (Miluveach) 6,880.0 Kugrua siltstone 7,066.0 ;Kugrua sandstone 7,120.0 I k , ii• 21:00 3.00 Drlg Planned Flat Prod BOP / Handle Tools No Trbl 7,280.0 M/U 6 -1/8" bit, bit' Kugrua ironstone Op WH / sub, X/O and Kingak Fm Drillout HWDP and start to Conductor Pipe, 98.8ftKB RIH. Csg Run Date OD (in) Grade Wt (Ibs /ft) 3/19/2007 16 H -40 65.00 Mud Checks: 7,280.0ftKB, 4/20/2007 13:00 Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) /o Water (/) ',Mud Lost (Hole) (bbl) Surface Casing, 2,072.1 ftKB 9.80 9.5 0.10 200.0 91.0 3/31/2007 Csg Run Date OD (in) Grade Wt (Ibs /ft) Via (s /qt) Filtrate (mU30min) Filter Cake (l32 ") Pm (mUmL) Potassium (mg/L) Percent Oil (%) Mud Lost (Surf) (bbl) 9 5/8 L-80 40.00 55 4.1 1 0.200 mroduction Casing, 7,050.OftKB PV Over (cp) Gel (10s) (Ibf /1001... Sand ( %) MBT (Ib/bbl) Lime (ibibbl) Oil Water Ratio Mud Vol (Act) (bbl) Csg Run Date OD (in) Grade 11/VI (Ibs /ft) 11.0 4.000 5.5 810.0 4/17/2007 7 L -80 26.00 YP Over (Ibf /10... Gel (10m) (Ibf1100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) to q '' (i I 14.000 8.000 6.7 4.6 , t T Des comment " Type Gel (30m) (Ibf /i00... T (fi) ("F) Chlorides (mg1L) HTHP Flit (mU30... Alkalln (mUmL) Whole Mud Add (bbl) Remedial Casing Annular top fill - !: Potassium 13.000 28,999.999 Cement Cement Job Went 1, Salt Base , Well Max Back Gas ( %) Avg Back Gas ( %) !Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) tk, Silicate ( %) Electric Stab (V) Comment 1° hecks: 7,280.0ftKB, 4/20/200,4 p lit Density (Ib/gai) pH CEC for Cuttings Pf (mUmL) Calcium (mg/i.) % Water (%) Mud Lost (Hole) (bbl) 9.80 9.5 0.100 200.000 91.0 Vis (s /qt) Filtrate (mU30min) Filter Cake (/32 ") Pm (mL/mL) Potassium (mall.) Percent Oil (%) Mud Lost (Surf) (bbl) A 55 4.1 1 0.20 PV Over (cp) Gel (105) (Ibf /100f.. Sand ( %) MBT (1b/bbl) Lime (lb/bbl) 011 Water Ratio Mud Vol (Act) (bbl). 4.000 5.5 5 1 ' YP Over (Ibf/10... Gel (10m)) (lbf /100... Solids (%) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) i 14.000 9.000 6.7 4.6 Type Gel (30m) (ibfl100_ T (fl) ( "F) Chlorides (mg/L) HTHP Flit (mt./30... Alkalln (mUmL) Whole Mud Add (bbl) Potassium 12.000 28,999.999 I Salt Base 1 Max Back Gas ( %) Avg Back Gas (%) Max Conn Gas ( %) 'Avg Conn Gas (%) Max Trip Gas (%) f Avg Trip Gas (%) 1. __ Silicate (%) Electric Stab (V) Comment Description Make Mode Pill HG Dryer Derrick ,k' fit,. 1 ' (! t F, -, ,.° i '4 7'0` b :: I' ' ;, . " . 01. s . €!' - ) ! :, ','�1� '4 � 1 ww § 4 c° , �a t �T 41° FEX L.P. DDR Detail Page 3/3 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/20/2007, Report: 30.0, DFS: 24.47 • , 2,..,. , iii, .I .,J1t Ground Elevation (ft) Orlg KB Elev (ft) KB- Ground Distance (ft) 18.20 37.10 l 18.90 l� i Shaker Screens Deck . No. Screen No. - Scr Sz X (In) Scr Sz Y (In) 1 1 120.000 2 1 120.000 :1,1 1. 3 1 120.000 ' Shaker Checks I �ti Dens UF (lb/gal) Hrs (hrs) 1 . D%9itrg, §h D a.tROIlil!Ilililll8�� Description Make Model , i„ ' n ; HG Dryer Derrick a„ Shaker Screens Deck No. Screen No. Scr Sz X (in) Scr Sz Y (In) Wi' . ." illiliiiilti 1 1 120.000 2 1 120.000 3 1 120.000 Shaker Checks Dens OF (Ib /gal) Hrs (hrs) ... o h Description Make Model HG Dryer Derr Shaker Screens Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.0001 2 1 120.000! 3 1 120.000 Shaker Checks Or Dens UF Ib/ al) Hrs (hrs) .�.� ( 9 , k' z. a . Iix Drill Strings Blt Run Make 1 Bit Inventory Bit Type 'Item Cost 0 I IADC Bit Dull — L (Incl Noz) (In') BHA ROP (ftihr) Nozzles (/32 ") IADC Coda § i Fx .s: i, ..ir ,r1 !1TFA �I P4H'r!�:nnnn,. ,, °: ilgiiii11 ; ' BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load Obi) l WOB (10001bf) Interval HOP (ft/hr) Total HOP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000lbf) Max. Over -Pull (Ibf) iii Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000Ibf) ii . Hyraulic Calculations AV DP (ft/min) AV DC (ft/min) ° Err Drill String Components Mtr Top Btm Bend i 4 Item Density Drift Conn Sz Conn Sz Btm Angle . Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) ( °) 6' W !C ore ,a'ol.• I)11) . . mw .s ti h ,. .61a Welibore Name VS DIr (') ,Kick Off Depth (ftKB) Original Hole 258.00 [ Directional Surveys Date Description 1 ' 3/27/2007 MWD Surveys Ilitig 1111 11 1": ( � tt1t i 1 :;- �4}Ni�:r� I s aix �kC.,�;t s :., , n .,C �1 �,r.�... . �,r, iiii , , ti,e , ": ° .. .. FEItt. P. - DDR Detail,;e4,41401:30,:,,I,,,,:,,„,:, Page 1/3 Well Name: AKLAQ #6 , IrRf'f - T:::lNiAt ''';': POI -*;;;', ' ' ,- , Job Type: Drilling Original Date: 4 - /21/2007, Repo III) Job Spud Date Rig Release Date 'Ground Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (ft) AFE No. Total AFE Amount Total AFE+Sup ;. 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 I , Safety --- Target Depth (ftKB) Target Formation Type Date Comment 7,262.0 ,I 1 Safety Highlight 4/21/2007 Rig down, rig move meeting with Cruz. Peak, and rig personnel 1 C 3 os 3 t 7 T 8 o ,2 Da 8 tr 2 , . 3 DallY Cost Total 343,307.28 Cum DW,ti1401'r111'''')Y 4111! ' Daily Cost _ .,. Weather ' ' Lease 1 Road Conditions Wellbore Condition Over (4)/ Under (-) AFE (+/-) Var Days Da y M u d C " Mud Cum To Date overcast, 30F fair Fluid Losses 2 1 1,620.00 466,174.95 1 1.1 ,r1 Operations @ 06:00 Depth Start (ftKB) Depth End (ftKB) Cased hole logging -- - --- - ---- - -- -- - - --- Operations This Report Period --- - - ------- - .- Depth Progress (ft) - Drilling Hours (hrs) - 0, il RIH, slip and cut, drill out stage tool and clean with hi-visc sweep, RIH and tag up on baffle plate at 6962 ftKB, pressure test lower pipe rams, unscrew from to drive, POOH and L/D DP, repair pipe skate, begin cased hole logging program at 21:30 hrs. , „ ontact 1 ,4_ Job Contact Cell Phone 1 Operations Next Report Period Gregg Fischer, Drilling 1(907) 771-0536 , Complete cased hole logs, run 3-1/2" kill string w/ TWC and pressure test same, N/D stack, N/U christmas tree, Foreman if,4 retrieve TWC, pump diesel freeze protect to 1350 ft, install BPV, start rig down 1 Kim Parenteau, Drilling (907) 771-0536 1:1111 Foreman , II■ ' 6 Val iIIIF , 7' 11 F i'i 0111k !I , - orPH - Start Dur Ops Scheduled Depth End Rigs: Doyen, Arctic WiDIf Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment Rig Supervisor 00:00 1.50 Drlg Planned Flat Prod BOP / Trip In No Trbl 7,280.0 RIH to pressure test Bob Lupton, Rig Manager Op WH / casing and lower 1 M P umps : ii...,r, :,, ;,. '.;,; '.„ : ., ' , , i. ,,, , Drillout pipe rams No. Pwr (hp) Rod Diameter (In) % 01:30 1.00 Drlg Planned Flat Prod Drilling Rig Repair / No Trbl 7,280.0 Shp and cut 120 ft 1 900.0 114ii Op Service of drilling line Liner Size (In) Stroke (in) Vol/Stk OR (bbl/s... 02:30 3.00 DrIg Planned Flat Prod BOP / Trip In No Trbl 7,280.0 Continue RIH 5 1/2 9.02 0.066 1 Op WH / 1 , Pump Checks 1 Drillout '' ' - i sfreikiii' 05:30 0.50 Drlg Planned Flat Prod Drilling Rig Repair / No Trbl 7,280.0 Rig service Pres (psi) Slow 06:00 Spd (spm) Eff (Y.) 06:00 1.00 Drlg Planned Flat Prod , :.: :: l ' BOP / Drill - Other No Trbl 1 7,280.0 Drill stage tool ki No. . % el i:w1 iff {hp) Rod PZ-9 Rod Diameter (in) Op , WH / 1 A n k , 1 1 2 900.0 L Drillout 1 1 1 1 Liner Size (1n) Stroke (in) Vol/Stk OR (bbl/s... lip 07:00 1.00 DrIg Planned Flat Prod BOP / Circ & Cond No Trbl 7,280.0 Circulate a hi-visc 5 1/2 9.02 0.066 Op WH / Mud sweep to clean hole Drillout of stage tool debris Pump Checks Strokes 08:00 2.00 Drlg 'Planned Flat Prod BOP / Trip In No Trbl 7,280.0 RIH, tag up on Pres (psi) Slow Spd (spm) Eff (%) Op WH / baffle plate at 6962 No Drillout ft as planned. e rs: ,, , . ,. , 0?> Circulate one Make Model bottom's up 10:00 1.00 DrIg Planned Flat Prod BOP / Wellhead No Trbl 7,214p' Pressure test lower Shaker Screens Screen Op WH / 1 pipe rams 250 psi Deck No, No. Sr Sz X (in) Scr Sz Y (In) Drillout , :`,:',",';',''' To.). .,:. -„:.,:-. - - ' ,.:-'., ,...: .,,,,. ....„,::..,:: ,,.,.. low, 3500 psi high I 1 Pressure test Shaker Checks i casing to 3500 psi Dens OF (lb/g Dens UF (lbfgal) Hrs (hrs) for 30 min , 11:00 6.00 Eval Planned Flat Prod Logging Trip Out Op No Trbl 7,280.0 Unscrew from top Make Model drive, start out of i ' hole sideways (L/D I Centrifu t e/C clone Checks , I 1 DP) I DensIty Overflow (lb/gal) Overflow Rate (gprn) . ' 17:00 0.50 Eval Planned Flat Prod Logging Rig Repair / No Trbl 7,280.0 Rig service Dens UF (lb/gal) Underflow Rate (gpm) Op Service 17:30 0.50' Eval 'Trbl 3rd Flat Prod Logging Rig Repair / Rig 7,280.0 Repair pipe skate Hours (hrs) Oil Under Ft (%) lDens FD (lb/gal) Party Service Repair 18:00 3.00 Eval Planned Flat Prod Logging Trip Out No Trbl 7,280.0 Continue out of Mud Addltiva Amountiii-'! Op hole and L/D DP Description Cons... Daily Cost Vendor 1 1 , 21:00 3.00 Eval Planned Prod Logging Log No Trbl 7,280.0 Hold safety meeting MUD LAB 1.0 45.00 Op and begin cased BA. DM 2.0 1,575.00 runs Io ry - 2 Tech s p Service/L... iitti:?i,;, ', "n■':INI4r. = , ,kili • Ti.:::"1 t : .' ; =, = ■Plkiii:0 __9i ' !' .' '' IL '"tylie . 0434: ii:iiiklilgt:',iiIttliiii,;:i.iiittfl' III:0411:ft: !iz 7 '' 'Pate i1 1 . • FEX LP. DDR Detail Page 2/3 Well Name: AKLAQ #6 Job Type: Drilling Original Date: 4/21/2007, Report: 31.0, DFS: 25.47 S Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Formations 18.20 37.10 18.90 Sample Top Mud Checks: 7,280.0ftKB, 4/21/2007 00:00 = Formation Name MD (ftKB) Density (lb/gal) pH CEC for Cuttings Pf (mL /mL) Calcium (mg /L) h., Water (r) Mud Lost (Hole) (bbl) N anushuk Group 912.0 9.80 9.5 0.050 200.000 91.0 Base Permafrost 1,020.0 Vis (s /qt) Filtrate (mLi30min) Filter Cake (132 ") Pm (mL/mL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbl) , Nanushuk topset sst. 2,795.0': 55 4.5 1 0.100 i Nanushuk topset sst. 3,388.0 PV Over (cp) Gel (10s) (Ibf /1001... Sand ( %) MBT (1b/bbl) Lime (Ib/bbl) 011 Water Ratio Mud Vol (Act) (bbl) Torok 3,470.0 11.0 4.000 5.5 0.0 YP Over (Ibf /10... Gel (10m) (Ibf /100.. Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl T' 14.000 9.000 6.7 4.6 Torok sand 2 4,852.0 Type Gel (30m) (Ibf1100... T (ft) ( "F) Chlorides (mg /L) HTHP Fill (mIJ30... Aikalin (mL/mL) Whole Mud Add (bbl) i Torok sand 3 5,090.0 Potassium 12.000 28,999.999 ; Torok sand 4 5,630.0 Salt Base 'Torok sand 5 5,798.0, Max Back Gas ( %) Avg Back Gas ( %) [Max Conn Gas (%) Avg Conn Gas ( %) Max Trip Gas (%) Avg Trip Gas ( %) Torok sand 6 6,008.0 Torok sand 7 6,313.0 Silicate ( %) Electric Stab (V) Comment Torok sand 8 6,568.0 [ ' ��. 1, H I ,' ` 7 „ ;`�� HRZ 6,605.0 D a :K ��,; ����I�l.1ll iu ii .;.r�u Kuparuk Sandstone Mbr 6,800.0 Description Make Model HG Dryer Derrick LCU (lower Cret. 6,880.0 —a� Unconformity) Shaker Screens Deck No Screen No. Scr Sz X (In) Scr Sz Y (In) BCU (Base Cret. 6,880.0, 1 1 120.000 1 Unconformity) 2 1 120.000 Upper Kingak (Miluveach) 6,880.0' 3 1 120.000 J Kugrua siltstone 7,066.0 Shaker Checks Kugrua sandstone 7,120.0 Dens UF (lb/gal) s° e, ' " * :-, , ;;!..77:.:1' His (fits/ , a 1' /. ; Kugrua ironstone Kingak Fm. Description Make Model HG Dryer — _ D errick I Csg Run Date OD (In) Grade Wt (lbs /ft) Shaker Screens I _ 3/19/2007 16 H-40 65.00 Deck No t4 c; /d a e^R 7 7 n`".' , A -1 174%4W '"74f i1 t r 0 1 1 120.000 �.� et .. 7 .� 't 2 1 120.000 Csg Run Date OD (In) G rade Wt (Ibs /ft) 3 !3 1 12007 9 5/8 L -80 40.00 3 1 120.000 ■ n . 50 Shaker Checks Csg Run Date OD (In) Grade Wt (Ibsen) gee Dens UF (lb/gal) Hrs (hrs) '" u h h ' e 4/17/2007 7 L -80 26.00 Cenien llIT ''-',./", Description Make Model HG Dryer Derrick CmntDes .,�i rig g i.a ,y �� Shaker Screens Deck No. "` Scre No. Scr Sz X (in) Scr Sz Y (in) h 1 1 120.000 2 1 120.000 l 3 1 120.000 Shaker Checks i Dens UF (lb/gal) Hrs (hrs) ; i Drill Strings: S 4,Ct Bit Run ..Make Bit Inventory Bit Type Item Cost IADC Bit Dull TFA (Inca Noz) (In') (BHA ROP (fVhr) Nozzles (/32") IADC Codes j ,. BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... (Max. Hook Load (Ibf) WOB (10001b0 Interval ROP (ft/hr) Total ROP (fUhr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over -Pull (Ibf) (rpm) I (pm) ` ` 30 HL (1000Ibf) ; Bit RPM ( Motor RPM r Cum Drill Time (hrs) ( Off Bottom Torque ( Torque Units Hydraulic Calculations AV DP (ft/min) AV DC (ft/min) AT tiotr : `,; : 7 ° ° Err , h e^ - , 1 e/ Drill String Components , ! e Y .v k l. Mtr Top Btrn Bend Item Density Drift Conn Sz Conn Sz Btm Angle • Jts Description Len (ft) OD (in) (Ibs /ft). Grade ID (in) (in) (In) Top Thrd On) Thrd Cum Len (ft) ('1 1 '' ' 1 L l - - -- I l 1 1 I — I I I F Report Printed: 4/23/2007 FEX L.P. - DDR Detail ,� ( (h; , , (in /3 � � I �� L Well Name: AKLAQ #6 q� I II r I l lk Job Type: Drilling - Original Date: 4121 /2007, Report: 31.0;' ® FS:' 25.47 Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) � 18.20 37.10 18.90 Wellbore Name VS Dir (°) Kick Off Depth (ftKB) Original Hole 258.00 Directional Surveys Date Description 3/27/2007 IMWD Surveys l � I t I r I n)I ' 4Q I aaa • t; I T p � I r li , "R ., ? Report Pfl. ....<LI > Lµ 3/2007 ______410 Pa e 1/2 ---- ----II/ FEX L.P. - DDR Detail g Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/22/2007, Report: 32.0, DFS: 26.47 14; , ■ ■ „IP ,;p ,'■ I ,,;,,,,' , ,4 41) Job Spud Date Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (ft) AFE No. Total AFE Amount Total AFE+Sup 3/27/2007 12:45 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 86etY ------ '' 1'1.'1 1 -1 Target Depth (f1KB) Target Formation Type Date Com ment ,, ,!(:. ' , :'74 4 ' 7,262.0 Safety Highlight 4/22/2007 Lease traffic due to move Daily Cost Total 1 Cum Cost To Date DailYi SitimMit . 229,198.80 13,607,481.43 Weather Lease / Road Conditions Wellbore Condition Over (+) / Under (-) AFE (+/-) Var Days Daily Mud Cost Mud 2 C4u6m8To22D8at.e75 20?F light wind dark spots Cased 1 2,053.80 Operations @ 06:00 ---- - Depth Start (ftKB) Depth End (ftKB) N/D BOPs for storage Operations This Re -- - ------ ---- 'bepth Progress (ft) Drilling Hours (hrs) port Period Finish logging, pull wear bushing, run 3-1/2" tubing (47 jts to 1380 ftKB), land tubing hanger, N/D BOPs for : 4 , summer storage Operatio N/D BOPs rt x_ni ' st• 7 ":" I nt''' v,' ,,,k Cell Phone as tree, pull TWC, pump diesel freeze protect, install BPV. Release rig and rig Gregg Fischer, Drilling (907) 771-0536 down to move Foreman ;iiiiiiiNiviirii- - 1'1 r■ 1 Kim Parenteau, Drilling (907) 771-0536 Time Log Ops S cheduled Depth End Foreman Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment _ gs: Ri Doyon, 00:00 14.50 Eval Planned Flat Prod Logging :Log No Trbl 7,280.0 Cased hole logging Arctic Wolf OP 1 (STB, GR, RPM). Rig Supervisor Bob Lupton, Rig Manager 14:30 1.00 DrIg Planned Flat Prod 1111 BOP / Wellhead 4., No Trbl 7,280.0 Pull wear bushing Mud Pumps: 1, Gardner-Denver, PZ-9 Op WH / i ii';',i No. Pwr (hp) Rod Diameter (In) Drillout 1„ '''. ' '.:01i'•:- ) -'':-".-ff-A,F41,4,,:,` 1 900.0 15:30 5.00 Drig Planned Flat Prod Case & Run Casing 11- No Trbl 1 7,280.0 Rig to and run Liner Size (In) Stroke (in) Vol/Stk - Op Cmnt 3-1/2" 9.2# tubing : 5 1/2 , 9.02 0 and hanger w/ Pump r Checks Stkes associated TWC , : valve with Doyon Pres (psi) Slow Spd (spm) Eff (%) casing crew. Rig 1 : No out casing crew. :Mud Pumps: 2, Gardner-Denver, PZ-9 No. Pwr (hp) Rod Diameter (in) 20:30 3.50 Drig Planned Flat Prod BOP / BOP No Trbl 7,280.0 N/D BrOPsse all rn BOPs. Clean 2 900.0 0 Op WH / a a g ea Liner Size (in) Stroke (In) i : n) Vol/Stk OR (bblis ... bodies - prep for 5 1/2 9.02 0.066 Drillout summer storage Pump Checks , Mud Checks: Strokes Density (Ib/gal) pH CEC for Cuttings PT (mL/mL) Calcium (mg/L) % Water (%) Mud Lost (Hole) (bbl) Pres (ps,) Slow Spd (spm) Eff (%) No vie (s/qt) Filtrate (mL/30min) Filter Cake 0321 Pm (mL/mL) Potassium (mglL) Percent 011 (%) Mud Lost (Surf) (bbl) [ Shakers: ‹Description?> Make Model PV Over (cp) Gel (10s) (lbf/100f... Sand (%) MBT (lb/bbl) Lime (1b/bbl) 011 Water Ratio Mud Vol (Act) (bbl) YP Over ObT/10... Gel (10m) (lbff100... Solids (%) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) Shaker Screens Screen Deck No. No. Scr Sz X (in) Scr Sc Y (in) ., Type Gel (30m) (IbT/100... T (f1) (°F) Chlorides (mglL) HTHP Alt (mtJ30... Alkalin (mL/mL) Whole Mud Add (bbl) I 1 1 ■ - Shaker Checks Max Back Gas (%) Avg Back Gas (%) — Wax Conn Gas (A,) 'Avg Conn Gas (%) 'Max Trip Gas (%) Avg Trip Gas (%) 1 Dens OF (Iblgal) Dens UF (lb/gal) Hrs (hrs) Silicate (Yv) rleckic Stab (V) Comment Make Model . Drying gi citle';'! ' '14111 vAih., Description Make , Centrifuge/Cyclone Checks HG Dryer Derrick :Density Overflow (iblgal) Overflow Rate (gpm) Shaker Screens Deck No. 1 120.000 Screen No. Scr Sz X (in) Scr Sz Y (in) Dens UF (Ib/gal) Underflow Rate (gpm) 1 2 1 120.000 Hours (hrs) 011 Under Fl (%) !Dens FD (Ib/gal) 3 1 120.000 Shaker Checks ' Mud Additive Amounts Dens UF (lb/gal) Hrs (hrs) i Description Cons.. Daily Cost Vendor BA. DM 2.0 1,575.00 i. Descripdon Make Model 1 Tech HG Dryer Derrick , Service/L... ii,i_ ti Shaker Screens ' CON DET 1.0 433.80 illiiit in Deck No. Screen No. 1 Scr Sz X (In) Scr Sz Y (iriL MUD LAB 1.01 45.00 ig 1 120.000 il 2 1 120.000 Last Dnte Casing Check 7, yp,,, i 1 3 1 120.000 Shaker Checks 'F Dens UF (Ib/gal) Hrs (hrs) I'liltt:%",IV:4-(iiZ:'414:4M(01111;!IgrOi':' Report Printed: 4/23/2007 dl �� � (' IiIF I �i'ux' I 1 I i �,�,, ., ,: � v ii i i r r�� ,J a C wi H t r Nx �I ,, xi I" /I a I„Illi r I hI ���� ��i � �� i e i r %Fil i�. 4e +,"� �F,�I Y P n ` i i� : I l i ■ �l� 4,,, A , � d 7 I d � ' ! ( ! �fi l kJ 5 of k: i �r r 11:! : r O ,1 111..:', ,4. ,- i 'u limo (� a =f `iNril ;7r r rh,l ,'i'll ! " ik l a �i ':R i`lf" A;.;� pI IIi�'�'Ia1 i!' =iiia�Iii ' l �iIII G, 3xa i � Ix " ��i�7'�'i'�i li "� € F 9 i I� • � 1 �� 1 ��i[7 ;�i� � i7l i ,n "` s ' , ni % a a : l'II O A,ir, � r a � I� , .'_' c ;c ) G' I ryiilGii �4ii 1 a ' li / V, i x,1,1, ` t, ,, , 1 , :,„! , Hilo agi i) iI ., :,ri :'i 'I^ a i '',:�, r " x:. y x , I x„ x �1 p€1 I Iki' a i ( ¢ ; , 4 i; ,);, Pa ej III4 px,ii r Sr''. f ��,� f anti i ," q � I j " f �( ( � t t r ., r ii,A i llir � a�I ( i i i�:ri= a„ mr ax „1.0, 'a: uiix�G 4 al l l ' 'r n iI II l l ' i 7'I i ; i , r I i �„a.MW�::i�:I Iw'e.; :.. k �� � II I . i}�� irv..::eni�o �#'n.r III t�'�. J :I , ". t =k` .' .: (', � �.; N �71I� J � II� ( I � i t : S. i i t( � I � ' i � . Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft)4 .,°„T .i ) b ` ea , 1820 37.10 18 ! . 1,:, 90 T a rest Type 1'111 „I, ='r1 I ! 1 a1iki i.' ,a4 x c,rt, ri:"b ,• ' ,, D io 411011 ' )+I l.:t ����r��Aa#�u �� I , x. �3 +} "�,�as��9�r# +.. :� ,� C.i" r N"wE rY. -t tai!' _ _ Description Mak Model Formations " ' C — — I HG Dryer Derrick -" - "-""-' -" '' Sampts Top I c { ry Ki Shaker Screens Formatioit Nam§ ,1 MD (ft ) I Deck No. ( ___.. Nanushu Group 912 0 �, - : .:...,„ $.greenNo. ScrSzX (In) iT-- - - - � -- ScrSzY(in) „I r i ' 1 1 0 Base Permafrost 120.00 1,020 Ot 2 1 120.000 Nanushuk topset sst. 2,795.0 3 1 120.000 ,Nanushuk topset sst. 3,388.0 Shaker Checks Torok 3 li��i „;° Dens UF (iblgal) Hrs (hrs) Torok sand 1 4,734.0 Torok sand 2 4,852.0 I i; D�INIti Torok sand 3 5,090 0 ii��,, Bit Run [ Make Bit Inventory Bit Type hem cos( Torok sand 4 5,630.0 IADC Bit Dull TFA (Intl Noz) (in') [BHA ROP (ft/hr) Nozzles (!32 ") [ADC Codes - Torok sand 5 5,798.0 Torok sand 6 6,008.0 i , Torok sand 7 6,313.0 id! BHA No. Cum Depth (ft) SPP (P81) !!!,.,!!.. Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) Torok S and 8 6,568.0 800 l'':1 HRZ 6 , 605 0 WOB (1000Ibf Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (t000Ibf) Max. Over -Pull (I bf) KUparu Sandstone Mbr 6, 0 LCU (lower Cret. 6,880.01A ( Bit RPM (rpm) [Motor RPM (rpm) Cum Drill Time (hrs) [Off Bottom Torque 'Torque Units 'SO HL (1000Ibf) Uf1orty) ' 11 I ` 1 _ BCU COnf (Base ml Cret. 6,880.00 Hydraulic Calculations m Unconformity) AV DP (ft/min) AV DC (ft/min) Err Upper Kingak (Miluveach) 6,8 0 ii Drill String Components Kugrua siltstone 7,066 0 Mir Kugrua sandstone 7,120.0 i;, Top Btm Bend Kugrua ironstone Item Density Drift Conn Sz Conn Sz Btm Angle �) O ) • ) Top � ) Kin ak Fm Jts Description Len ft OD in (Ibs /ft Grade ID m (in) (in) To Thrd (in Thrd Cum Len ft O g �l 1 ::;Y r ,:r ;I x ii1;;iIPJ')uenn; °i at iiii ,� I' Ili '' un Csg R Date OD (in) Grade I Wt (Ibs /ft) , . , �(,�.'t `ra�s `�, 3 /19/2007 16 , H -40 650 IRV Wellbore Name VS Dir (°) Kick Off Depth (ftKB) ti } rt rc Ff , 1' . ii' Original Hole 258.00 Cs g Run Y d�P iii ,x< r OD (In) Grade Wt (Ibs /ft) Directional Surveys 4/22/2007 Date , Date Description -- .. 3/27/2007 MWD Surveys Csg OD , . w Wt . &n '' 3/31/20 9 5/ 8 g L - 80 p 4 p 0 00 #", ve . e ” 1 ' / , " Y � !, �� � a Csg Run Date OD (in) Grade Wt (Ibs /ft) 4/17/2007 7 L -80 2 !..,.?? Id '� N i � al tw a,� 0 l lit Pall PI I Y it pii ofic , I it 5. „' ' tt j _l t 5 '. `a•-� 7 P 1 b #� tx I (1r ° fi b ' II , 1; 4�" i g / _ : a t , .:�:; d,e� $:' `i.m: .a _ o l,t, ^5 ,,� ..af'41iiil^e,aia Swxr.1 a . e�:.... .. P. < „r #�., F, _,. -41/ FEX L.P. - DDR Detail • Page 1/2 Well Name: AKLAQ #6 Date: 4/23/2007, Report: 33.0, DFS: 27.47 Job Type: trilling - Original ..,..a.v= c..ti'I�J�ww.ww�u. d . = i, n ., I.. 7 , iia 1j ni` G ':: , Job Spud Date Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22574,244.00 Target Depth (ftKB) Target Formation LIM Type Date Gomme 7,262.0 Safety Highlight 4/23 /2007 Diesel freeze protect Daly Cost Total Cum Cost To Date . 734,829.00 14,500,204.53 Weather Lease /Road Conditions Daily Mud Cost Mud Cum To Date tions Wellbore Condition Over ( +) I Under ( -)AFE ( +J -) Var Days 4 High of 30 ?F dark spots Suspended 2 468,228.75 Operations @ 06:00 —.. _ .... Depth Start (ftKB) Depth End (rtKB) " a A Prepare rig for move to Cape Simpson Operations This Report Period Depth Progress (ft) Drilling Hours (hrs) Clean BOP stack, N/U adapter fl ange and test to 5000 psi, N/U X-mas tree and test to 5000 psi against TWC „_, a. , :„ v alve, pull TWC and pump 10 bbls water followed by 60 bbls diesel freeze protect (5 bbls diesel to surface), 1 .r lean derrick/wind walls/ mud pumps /pits /choke manifold /shop/ top drive. Release rig at 16:00 04/23/2007. ' ' `$ t ",`" ° ", Job Contacts ' a IG''O perations Next Report Period Gregg Fischer, Drilling ', (907) 771 -0536 I,= Continue rig cleaning/prep for move Foreman E , T)' Kim Parenteau, Drilling (907) 771 -0536 S rt a Depth End Foreman ) ` .:. ration Trouble (ftKB) Comment '' 00:00 10.00 Drl Planned Flat Prod BOP / BOP No Trbl 7,280.01 Clean flow line, Rigs: Rayon, Arctic Wolf ' R. Op WH / bl eed down koomey Rig Supervisor Bob Lupton, Rig Manager Drillout unit, open ram ®� a Gt bodies /wash /grea... I .. / 1.! 1, Gardner -D , 16, break down BOPs Flat Prod BOP / Wellhead No Trbl 7,280.0 No. Pwr (hp) Rod Diameter (In) ". 10:00 * 6.00 DrI Planned 1 900.0 — — g N/U adapter flange u ser size (In) Stroke (In) V ol /Stk OR (bbUS . O Dr (lout psi, N/U tree, ee, ... Pump plChecks 9.02 tirokes 0.066 1 p s with Halliburton to Pres (psi) Slow Spd (spm) Eff (i) 5000 psi, pump 10 No bbl water and 600 " bll diesel freeze Mud Pumps v 2,,Gafdner D. ° r protect. 5 bblS No Pwr (hp) Rod enver Diameter PZ -9 (in) diesel return is 2 900.0 to 4111/ surface. Install Liner Size (In) Stroke (in) Voi /Stk OR (bbl/s... BPV. Rig out 5 1/2 ... 9.02 0.066 Halliburton Pump Checks ` :u 1l a i.. Strokes ., Pres (psi) Slow Spd (spm) Eff (%) 16:00 8.00 Drlg Planned Rig Down Rig Rig Down No Trbl 7,280.0 Clean rig, clean No 1 ■ 11 Op Down derrick /wind walls/ IShakers: <Des j 0, ,,,; mud Make Mode . pumps /pits /choke _ ill manifold /shop/ top Shaker Screens .I drive. Release rig Screen ',. at 16:00 Deck No. No. Scr Sz X (in) Scr Sz Y (in) 04/23/2007. 1 I Shaker Checks �, a . , f . i .. rt s Dens OF (Iblgal) Dens UF(Iblgal) Hrs(hrs) benslty l (Iblgal) pH CE for Cuttings Pf (mUmL) ' C ' alcium (mgIL) % Water ( %) Mud Lost (Hole) (bbl) ' Vis (s /qt) Filtrate (mU3Omin) Filter Cake (/32") Pm (mUmL) Potassium (mg/L) Percent 011 (%) Mud Lost (Surf) (bbl) Make Model i PV over (ep) 0.1(10s) (Ibf /100f... Sand ( %) MBT (1b/bbl) Lime (Iblbbl) 011 Water Ratio Mud Vol (Act) (bbl) Centrifuge /Cyclone Checks f Density Overflow (lb/gal) Overflow Rate (gpm) YP Over (Ibf /10... Gel (10m) (Ibf1100... Solids ( %) LOS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) , Dens OF (Ib/gaf) Underflow Rate (gpm) Type Gel (30m) (Ibf/100... T (ft) (°F) Chlorides (mgIL) HTHP Filt (mU30... Alkalln (mU 'Whole Whole Mud Add (bbl) Hours (hrs) 1011 Under FI ( %) 'Dens FD (Ib /gal) Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas (%) ' Avg Trip Gas (%) - Mud Additive Silicate ( %) Electric Stab (V) Comment Description C ; §i (.� • I _� ,. .i Ind � +' ,,. ; ... .. ... J1fg Shat' 0 Descrlptlon Make Model s � ey � t-'� L r . HG Dryer Derrick , ' ! I .. , d`(a' � Shaker Screens Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) . '1,' " . r { �,� 1 1 120.000 i1�.,3 °I � ' . � , �� 2 1 120.000' 3 1 120.000 � i P h E �. , a } . t " ,i x ' 9..a,. � ly , `.i t �i, ", u') 4 ,- ,k4r i.a . .: _5 * `I ,� iii` „h!: ., I ii L, „ ,t "� ,"i;! i � $ �`` NIIii :i ; ii!I" N�! III I III NI i ` r } � , .,i :N„ ti t x"11' �{Imilf NIii1 „I� ,i „ b lNi : � y ( ,ai l , p . I p „i ; P I Ir� I sill, ,„ F i i t t , FS N' ilY Ili .y i11,. ; u it G ,,:N., I, 1, i la Ml1' N1, Ii Iii „, idi x X ` .' P . .DDR Detail_ :iN Iii, . Gr,i i II r i h , ,I iIi �f , ,.i ? . /1 1 —f d '. i ll /k iii if , Ri ai ii �I� � 'v ` , „ I I iI � , rt!i ii lr < , 1 � f '1I ,.. I , i.' ,�I xFI ii "1, A . l 1 , 0 , t Ni:: 011 it ='i lli • t Iw k Y" a , � , y . ,: i, ,� r i i 1 I, , pi,IN tli llia, „' n ;� �' " ` 'l w . } l l ' Ii � e '' ` , , T , g I i m t i n i & r,F i 2 : ' , l�ii i (il l II y( I(ii i i, iii� • , " , ' f y I III) i +x a (111 i r ill I III,! �i�Ii ii tr, ■ il , r,t d "tr i.7'4.i, 1 , filiilli ti / ' i li s i i ' `"i) ( VN . 4 lif ' i i o � ' T yp e: D - OW A dr lg l nal D9f7 4/23/2007 Re po 4444)1:10 l , '• �i � � car 11;1141111131111111111 t r , 1, s . , i t l yll li ' r ,41Iii11 I i l i l p� yu II�'I�N 1 b µ aI I I I I II) ll Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Formations ti 18.20 37.10 1 18.90 ; SampleTop' Shaker Checks Formation Name MD (ftK6) Dens OF (lb/gal) Hrs (hrs) '' ' Nanushuk Group 912.0 tai Base Permafrost 1,020 0 ; "' i . ._ _ , zit wGri i Description Dry,i .2 ..,! - a w� . Ntlt .ff'' i , � k, ? aihi' ? , 4h :: Nanushuk topset sst. 2,795.0' Make Model 3,388.0 HG Dryer [Derrick Torok 3,470.0 r'' Shaker Screens Torok sand 1 4,734 0 , 017 ° 4+ 1 '"; `a: :A �,, . ,, W Is�x' Scr Sz X (In ( v ) -:+ . " t " Nanushuk topset sst. 1 1 120.000 Torok sand 2 4,852.0 '.. 2 1 120.000 Torok sand 3 5,090.0 . 3 1 120.000 Torok sand 4 5,630 0 Torok sand 5 5,798.0 I;, t Shaker Checks _ Torok sand 6 6,008.0 ,;. /if: aena uF pb/gal) Hrs (hrs) Torok sand 7 6,313.0 s, Description Make Model Torok sand 8 6,568.0 1: Iiir HG Dryer Derrick HRZ 6,605.0 � Shakerb Deck No. Screen r Screen No Scr Sz X (in) - scr Sz Y (in) CU (lower Cret. ne Mbr 6,880 0 „ 'i 1 1 120.000 Unconformity) 2 1 120.000. ,i BCU (Base Cret. 6,880.0 3 1 120.000 Unconformity) Shaker Checks f Uppe Kingak (Miluveach) 6,880 0 .afu I(/ga1) H rs ( .,.,"1ii5 Kugrua siltstone 7,066.0 pip �i , 1t,,, a� I,I N 'Kugruasandstone 7,120.0 ' �ii'lli fligL„f; „rINdlliifift,f,, 1 , ' l i1 '1 : " n�1' 1,, �I ii 'f” °,t'tne, K ugrua ironstone I Bit Run ( Make Bit Inventory Bit Type I tem Cost Kin ak Fm 'I (I -- _ _.. i g s °7011,14.01111644,:.. , I 'ADC Blt Dull TFA (Inc! Noz) (in) /BHA ROP (ft/hr) Nozzles (/32 ") 'ADC Codes s� �,C�qr PI p �, ' „'. ¶f"r' . 9 .t1 I Csg Run Date OD (In) 'Grade Wt (Ibslft) I „I ' ” 3/19/2007 16 I �H -40 65.00 Itil BHA No. Cum Depth (ft) SPP (psi) 'Flow Rate (gpm) TFO Reference Rot HL (10001... Max. , Hook Load (Ibf) lS I , � Q k �� „ ( t Ili, Csg Run Date lOD (In) Grade IWt (Ibs/fl) WOB (1000Ibf) Ilntervai (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) Max Over Pull (Ibf) 4/22/2007 1 4 �i i III i„ , I, �i .i � t i V'� {ly i i � �I'�idl� .. IH”, Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (10001bf) Csg Run Date OD 072.1 .',. i, �� II61i �dii i (in) Grade 1W1 (Ibs /ft) ;t? 3/31/2007 9 5/8 L -80 I 40.00 .. —..-- - ..._ iii , ia9 r "IIII i ' „° + }. I f; Hydraulic Calculations ti Ca a `Iliift 7 !'''' , a x i , AV DP ( ft/min) AV DC (ft/min) Err Csg Run Date OD (in) Grade Wt (I /ft) 4/17/2007 7 L -80 ; 26.00 ∎Drill String Components x 9 pt i, III i il� Mtr ..,! �.N, i'II!nt D ', t i of)nment 'Ili, �� If Top Btm Bend v Item : „ ' `' Density Drift Conn Sz Conn Sz Btm Angle - - -- -- - ) �r , Jts 1' Des ' Len (ft) OD (in) . (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) ( ") Wellbore Name VS Dir C) Kick Off Depth (ftKB) 41. li Original Hole 258.00 P Direct Surveys Rai Date Description ( N. i 3/27/2007 MWD Surveys k ;If ilgil ' E tg It ! i111 1 1111 0 i i Li .11101. 1 ,r,Iiiii 1 11471 , 4 1 111 1011 N t�t m. ry { � '+�. " I , y1 , a }i; i " ii ?g 4 • ! 4 ;; • Age 1/2 De t a il FEX L.P. - DDR ' ,nl'iiiiiiil Well Name: AKLAQ #6 '..F -7,--':'7:::'-'''‘'''-';';':',.--', it ie .,, , , , I l ' . .'eport: 34 " ' 1 Job Type: Drilling - Origina .. , i p Job Spud Date Rig Release Date Ground Elevation (ft) Orlg KB Elev (ft) KB-Ground Distance (ft) AFE No TC.■•, AFE+Sup 1 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 , Targ AF et 7 e O ph 4 (ItKB 2 ) 2,5 74 ..f . :: 0 T( F - J onv 22 a , t 5 10 7 n 4244.00 [ , Safety Date ill i , , 1 comment 7 262.0 Daily Cost Total Cum Cost To Date Safety Highlight 4/24/2007 SLIPPERY CONDITIONS 0.00 14,500,204.53 OP, a a Mud Cum To Date Lease / Road Conditions IWellbore Condition 468,228.75 IV': PP Weather Over er (4) i Under (4 APE(;/:) Var Days Daily Mud Cost CLEAR dark spots I Suspended 12 -- Operations © 06:00 :1Depth Start (ftKB) Depth End (ftK13) ■ 1 .: RIG DOWN operations This Report Period Depth Progress (ft) Drilling Hours (hrs) ■ , ,i , 11: RIG DOWN TOP DRIVE / CLEAN RIG / PREP SHOP F/ MOVE [ , Operations Next Report Period hone MOVE RIG SHOP TO CAPE SIMPSON / CLEAN & TEAR OUT RIG "Til:r r , ,...T4,,,A111& '1 , ' ,. .-:'ih,;?? , ,,f4'1(.;...:',......7 ! T, 7: „, , , , . „ - ,, , ' ' ' ' ;',;:),' ' '..':', ,!'",'./,,.." 7 .4‘ 4 c, . Gregg Fischer. Drilling (907)771-0636 Sta rt 19 — OU r''''' Scheduled . Depth Kim Parentebu,' Drilling 11 007)771-0536 Foreman 11 Time (hrs) Cat .. Type Phase Major Op , Op Trouble (ftKB) Comment 00:00 ' 24.00 Drlg li"janned Rig Down R Dicgwn Rig D own No Trbl 7,281.0 O RI U G T D T O D W P N DR / T Foreman 36 CLEAN RIG / IltP , Ernie Natte, Drilling (907)771 - 05 PREP SHOP F/ MOVE Foreman l'Rigs: Do [Mud Purn yon, [ J . , ,,, , ,,,,, -,,, , TriellipailvamiIr ,,r' ' ' - Rig Manager 1, ,,...„...„,,, Density (Ib/gal) pH CEC for Cutt mrdm PMEitrorr$'0,116117147,1111127411b11;1":*9 1 :!7.4:4'''' ' ' ' '. ' ' pf ( ' Calcium (mg/L) % Water (A) Mud Lost (Hole) (bbl) . 1 Gardrinra[Denve• 1 No. i l * Pwr ' (hp) 900.0 11 :Rod Diameter (In) Vis (slat) Filtrate (mU3Omin) Filter Cake (/32") Pm (mUmL) Potassium (mg/L) Percent 011 (%) Mud L o st (Suri)(bbl) 1 .. Liner Size (In) Stroke (In) Vol/Stk OR (bbl/s. PV Over (cp) Gel (10s) (lbf/100f... Sand (%) MBT obibbg Lime (Ib/bbl) 011 Water Ratio Mud Vol (Act) (bbi) 9. 5 1/2 0.066 Polymer (ppm) LCM Mud Vol (Res) MN) Pump Checks YP Over (lbf/10... Gel (10m) (lbf/100... Solids (%) Les(%) ; ejliTiol' 2: THP Flit (mL/30... lkalin (m AUmL) Whole Mud Add (bbl) : dli ' 41°' l;11' ' ''''''''' in '11 No. Type Gel (30m) (lbf/100... T (0) rF) Chlorides (mg/L) H No „![[ r[ 11 , [ 4 ,, a Avg Trip Gas ( LI,: : 4 ...: 11 ::',." : 1 Pwr .'1,;,' ie.., (In) silt ( .71,1!1 Max Sack Gas (% Avg Back Gas %) Max Conn Gas (%) Avg Conn Gas (%) 'Max Trip Gas (%) , 2 I 900.0 Liner S 1, t 1,e v.) Electric Stab (V) Comment 'fit e (1 IStrIgn I i,. Vol/Stk OR (bblis... ' 5 1/2 0.066 „ i'' ' ' Model i:( - Make Description I Pump Strokes 1 Checks HG Dryer Derrick Shaker Screens Pres (psi) Slow Spd (spm) Eff (%) > I I .... ' ` t Deck No. Screen No. Scr Sz X (in) Ur- $z Y (in) No 1 1 120.000' 1Shakers: <Descrip lo mo, , ,i f1 7 el 2 1 120.000 Make 3 1 120.000 Shaker Checks Shaker Screens Dens UF (lb/gal) Screen Hrs (hrs) ttr'l Deck No. No. Scr Sz X (in) Scr Sr Y (in) . 1 Model L 1 I ' Description 141;eakle HG Dryer TiCk . 'Shaker Checks i Shaker Screens „, ,[[ 1DeitS OF (Iblgal) Dens UF (lb/gal) Hrs (hrs) i ? 1 1 II tRIP. , Dec( ■ 41'2'. ,is Screen No. Scr Sz X (in) Scr Sz V (In) r 120.000 2 1 120.000 Make Model 3 1 120.000 -- , ..P' Ov Ov rflow Rate (gpm) icoi Shaker Checks Hrs (hrs) DCeenneitty rflow rifu!e/Cyo cloanoe Checks Dens UF (lb/gal) ; I Dens UF (Ibtal) Undergoes Rate (9Prsi ' I tIf.."01 Description Make Model I HG Dryer Derrick . Hours (hrs) Oil Under Fl (%) 'Dens FD (lb/gal) 1 ,, Deck '.: 1 , Scr Sz Y (in) 77 ” . ” 7 7,11;,::414 ShakerS illil'i' Mud Additiv mounts Screen No. 1 Sz X (in) Scr 120.000 1 2 1 120.000 Description Cons... Daily Cost Vendor 1 3 1 120.000 Shaker Checks Last Casing Check Hrs (hrs) Date Type A i& Dens UF (1b/gal) L ast BTOesPt Date Test Test Type , ,, ', M100:, , , . „r ,, .,„„' !,40,E, „ , , . . ,, %I., ,',iip,':, „,' : ■ ' 1 . 0 FEX L.P.. DDR Det Page 212 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 412412007, Report: '34.0, DFS: 28.47 Ground Elevation (ft) Orig KB Elev (ft) – KB- Ground Distance (ft) Formations 18.20 37.10 18.90 Sample lop Bit Run Make Bit Inventory �„ Bit Type Format Name MD (9K6) Item cos Nanush Group 912.0 Base Permafrost 1,020.0 IADC Bit Dull 7FA (Intl Nez) (In') BHA ROP (ft/hr) Nozzles (132) � IADC Codes Nanushuk topset sst. 2,795.01 ��� ", _ . 3,388.0 j i, II pl � t ,3,T i11 i bnt , ; f' l 'I f , 1, „ &, If: + 1 . , Torok Nanushuk topset sst. 3,470.0 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Ref Rot HL (10001... Max. Hook Load OW) Torok San Sand d 1 4,734.0 WOB (10001bf) Interval ROP (ft/hr) Total ROP (f /hr) Drilling Time (hrs) Drilling Torque PU HL (10001b� Max. Over -Pull (lb!) Torok sand 2 4,852.0 Torok sand 3 5,090.0 Bit RPM (rpm) - -- Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque ITOrque Units 80 HL (1000Ib1) Torok 4 321 5,630.0, Torok sand sand 6 5 5,798.0; Hydraulic Calculations 6,008.0 AV, DP (ftimin) Ay D (iHmin) Err Torok Torok d 7 6,313.0 L — — Torok sand san 8 6,568.0 Drill String Components _ HRZ 6,605.0' Mtr Ku aruk Sandstone Mbr 6,800.01 Top Btm Bend p Item Y Den Drift Conn Sz Conn Sz Btm Angle LCU (lower Cret. 6,880.0 Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft).. ( °) Unconformity) F f ! BCU (Base Cret. 6,880 0 �V1�ellbolxe „ ,,, 1041,I1111I�IIIIIIk, °tI� (7III�IIIIIla 8IIo1dt 4.. `r, , <: $� Unconformity) Wel Name VS Dir ( °) Kick Off Depth ( -- Upper Kingak (Miluveach) 6,880 0 ;) H j 0. , Original Hole 258.00 j Kugrua siltstone 7,066.0 Kugrua sandstone 7,120.0 DirectionalSurveys Date Description – — — Kugrua ironstone 1 "; 3/27/2007 MWD Surveys Kingak Fm .41 I F andual 't ,..,,, %0 `EY�i�s !i.."E' ,,11,11' IIik�il�i Csg Run Date OD (In) Grade Wt (Ibslft) !, 3/19/2007 }} H -40 65 00 141140/5:11001A, 16 J lu T 'Piii :; y1 1 �i tep, Csg Run Date Grade Wt (Ibslft) ' s£ 4/22/2007 OD (in) , urf' �t iie i 11fH #a2,O i B A' 241: Csg Run Date OD (in) Grade Wt (Ibs /ft) 3/31/2007 9 5/8 L-80 40.00 ;w P ,r odu c ttO,f; asing, 7,854 Q ,, „lb t : i) " Csg Run Date OD (in) Grade Wt (Ibs /ft ) 4/17/2007 7 L -80 26 00 �K , , w i 5 , ' �w,, a7,1 , t�hk,. ._ .fit., 9bes Comment 1 1 'ki ii i � 4 ' :t 4,4 i� il {iii i) zd III Zeltyir iiii �5 :� 9 '. m} , � i � , � ` h t x I li: «,' a:` :x iP"n�fti 'd'91e' C e.6r Ii "S �y, t f .. 8Y . 0 F 7�4z . x} .. , ,.. 7.,,o- , „, X .:a .A` tfit. ,- ,( x , ° `i,i, 1 1 ?1V . - Page 1/2 0 P a „I� . / . X L P DDR Detail g Well Name: K 11 i, i a r i: tit „!` '`'P; i a: "eY :* 14 r Job Type: Drilling - Original Date: 4/25/2007, Report: 35.0, DFS: 29.47 0 Job Spud Date Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22,574244.00 i Safety o Target Depth (fIKB) Target Formation Type Date Comment , .,n ,, ah , } � 1 xli „u a °. 7,262.0 Safety Highlight l4 /25/2007 !LOADING & OFFLOADING EQUIPMENT Daly Cost Total Cum Cost To Date Oil s Ip� ai lySummary ������ ® �' , : R 0 14 - Weather Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( + / -) Var Days Daily Mud Cost Mud Cum To Date 468,228.75 1 CLEAR GOOD Suspended 2 Operations @ 06:00 {Depth Start (ftKB) Depth End (ftKB) RIG DOWN f _ Operations This Report Period Depth Progress (ft) Drilling Hours (hrs) I TEAR OUT & MOVE SHOP TO CAPE SIMPSON / RIG DOWN RIG & TOP DRIVE / CLEAN RIG 1 Operations Next Report Period +TEAR OUT RIG / MOVE PIPE SHEDS & RIG ba l a > , I�I�IIII� . „, I , v 7 Job Contact Cell (�( "°" • 1 . �' "` 4111'1'1;111 ""'' I) ' ,. 1 1 �i,1)1 Kim Parenteau, Drilling = (907) 771 -0536 ) 1' Stav 9 Dwr� ; , ° e Scheduled J Depth End Foreman l�! tr ,fhFs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment Ernie Natte Dollin (907) 771 -0536 24.00 Drlg Planned Rig Down Rig Rig Down No Trbl 7,281.0 RIG DOWN & Foreman , Op Down MOVE SHOP /SET ! 00:00 UP SHOP @ CAPE Rigs: Doyon, Arctic W:`�� t� l n SIMPSON /RIG B ob Lu Ri Manager DOWN &CLEAN p to , 9 I I RIG & TOP DRIVE .Mud Pumps: 1, Gardner- Denver, PZ 9 '01t,. " No. Pwr (hp) Rod Diameter (In) ,,i i . ' , 7, r ; . " ,, j 1 900.0 , Density (Ib/gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) % Water ( %) Mud Lost (Hole 4 ) (bbl) Liner Size (In) Stroke (In) VoI/Stk OR (bbl/s... . t ( �) ( ) ( ` 5_1/2 ____ _ 9.02 0.066 Vis s/ Filtrate mL130min Filter Cake /32 ") Pm (mL/mL) Potassium (mg /L) Percent 011 %) Mud Lost (Surf) (bbl) P ump Checks .111 t{rokres - PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MBT (Ib/bbl) Lime (Ib/bbi) 011 Water Ratio Mud Vol (Act) (bbl) Ares (psi) Slow Spd (spm) Eff (%) No G,. YP Over (Ibf /10... Gel (10m) (Ibf1100... Solids ( %) LOS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) k i� Mud Pumps: 2, Gardner- Denver, Type Gel (30m) (Ibfl100.,. T (11) (•F) Chlorides (mg/L) HTHP Flit (mL130... Alkalin (mL/mL) Whole Mud Add (bbl) No. Pwr (hp) Rod Diameter (in) 2 ( 900.0 • Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) Liner Size (In) Stroke (In) VoUStk OR (bbl/s... . 5 1/2 9.02 0.066 ,., Silicate (%) ElacbiCStab (V) Comment _ - -� -- _ —. -------------- - -_..- I PumpChecks Strokes - - - i j , i csii, ii . 'l,,,,,.., "" .,,, = ` . _. ',-. • -:3 H" . : ,1„ , :1 Presjpsi) SIowSPiii- (4 Eff (°/0) Description Make Model No HG Dryer Derrick ;, „_.,l - 1 + . Iii` Shaker Screens Make Model Deck No. Screen No. Scr Sz X (in) Scr Sz Y (m) ........ ________ -. ! 1 1 120.000 Shaker Screens 2 1 120.000 Screen 3 1 120.000 Deck No. No Scr Sz X (in) Scr Sc Y (in) 1 1 _ Shaker Checks . Dens OF (lb/gal) Hrs (hrs) Shaker Checks Dens OF (Ib /gal) Dens OF (Ib /gal) Hrs (hrs) I Description Make Model �I- -;_. -- °° HG Dryer Derrick o' —_ -._.. - -. __. - -- - - ---- -. -- -. - Make ='�. Model Shaker Screens f - Deck No. Screen No. Scr Sz X (in) 120.000 Scr Sz Y (in) 1 11 Centrifuge /Cyclone Checks D ensity Overflow (Ib/gal) Overflow Rate (gpm) 2 1 120.000 3 1 120.000 Dens OF (lb/gal) Underflow Rate (gpm) '>'14. Shaker Checks Dens OF (Ib /gal) - - -° µ °- Hrs (hrs) Hours (hrs) 011 Under Fl ( %) IDena FD (Ib/gal) Description Make (Model 1 ; : nl 1t) HG Dryer Derrick 1 Mud Ad t o Antpu ail „ „v ry Description Cons... Daily Cost Vendor l Shaker Screens Deck No. Screen No. - Scr Sz X (in) Scr,SzY (in) _,° ° , ,, . ,, ,A...' ', q1 11,; � � . ; i� 1 1 120.000 � j `ll 'i r asingl' �ieck:;a3P � • . ilidi ,4 2 1 120.000 Date Type 3 1 120.000 '.. a , I . 40 Shaker Checks X ' e = ' C Dens OF (Ib /gal) w 19, - �_. 10, ''' '3 1 11 ^r 0 9 ^ # `�.a�� ± .n ------.— FEX L.P. - DDR Detail 1)---- Page 2/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/25/2007, Report: 35.0, DFS: 29.47 el __ . Gr Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (k) Formations 18.20 37.10 18.90 Sample Top DriilStrtngs:; ' ,; Formation Name MD (ftKB) Bit Ru r Make Bit Inventory Blt Type Item cost Nanushuk Group 912.0, Base Permafrost 1,020.0' IADC Bit Dull TFA (Inc! Noz) (In') BHA ROP (ft/hr) INozxles (132 ") IADC Codes Nanushuk topset sst. 2,795.0 Nanushuk topset sst. 3,388.0 I Torok 3,470.0 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gum) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) Torok sand 1 2 4,734.0 4,852.0 T orok , WOB (10001b9 Interval ROP (ft/hr) Total ROP (fUhr) Drilling Time (hrs) Drilling Torque PU HL (10001b1) Max. Over -Pull (Ibf) W 'Torok sand 3 5,090.0 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units 90 HL (10001bf) — Torok sand 4 5,630.0 T orok sand 5 5,798.0 Hydraulic Calculations Torok sand 6 6,008.0 G DP (wminj — Av;(ftlmm) Err Torok sand 7 6,313.01, Torok sand 8 6,568.0 i Drill String Components _ HRZ 6,605.0 Mtr Ku aruk Sandstone Mbr 6,800.0 'Id Top Btm ' Bend p Item Density Drift Conn Sz Conn Sz Btm Angle LCU (lower Cret. 6,880.0'... Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd {in) Thrd Cum Len (ft) (`) Unconformity) BCU (Base Cret. 6,880.0' I' ta .,:. Unconformity) Wellbore Name Y S Dlr ( °) Kick Off Depth (ftKB) Upper Kingak (Miluveach) 6,880.0 1 Original Hole 258.00 I i Kugrua siltstone 7,066.0 D irectional Surve s 1 Kugrua sandstone 7,120.0 Date Description ' , 3/27/2007 MWD Surveys Kugrua ironstone IKingak Fm. . t „ ' pe, 98 T :'(data' ,H,,, . ; Cs Run Date OD (In) Grade Wt (Ibs /ft) !,` 3/19/2007 16 H -40 65.00 ' ieback l , _. r, ( € Csg Run Date OD (in) Grade Wt (IbslR) 4/22/2007 1 ' g � a e v i its f e i Iii .i Csg Run Date OD (in) Grade Wt ( Ibs/ft) 3/31/2007 9 5/8 L -80 40.00 ' ' C gig,. sg Run D OD (in) Grade Wt (Ibs /ft) 4/17/2007 7 L -80 26.00 . Gtitntbea .l1 � ' 1 Iu I I', 1 r ' 4 I l fi k I. IS � �(!ljl� t �i lnted 5/3/200 11 s t ; :t; , � , a �'A rte, 331' , • 1 . , , 1 , ti ,,, (, ,. (,... rrm•ur. ` , . " „dX 6Nw,' k!:,,, hMxu„ a , !,I,� _ ,:..� � . >, .. ! ,!s :l! !� "..., ... ,v? w) w" (�I ! -•,+ � ' d .m... !I rrN i! -- - - - - - - 411 FEX L.P.. DDR Detail - Page 1/2 I Well Name: AKLAQ #6 Job Type: Drilling - Original Date: - 4/26/2007, Report: 36.0, DFS: 30.47 il Job Spud Date Rig Release Date (Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244 00 Safety ..,,,al I l Target Depth (ftKB) Target Formation Type 1 Date Comment e ` r y 7,262.0 Safety Highlight 4 /26/2007 ROAD SAFETY ! BUCKLE UP Daily Cost Total Cum Cost To Date ' ipil 1 , . 0.00 14,500,204.53 a 1 ,. It ¢ ) '° , Dal Mud Cost Mud Cum To Date Weather m Lease / Road Conditions Wellbore Condition O ver ( +) / Under (•) AFE ( + /.) Var Day y pe 468,228.75 O.C. GOOD Suspended 2 �_ Operations 06:00 De pth Start (ftKB) Depth End (ftKB) , RIG MOVE . –. ... - -- -- — 1 Operations This Report Period _._ _.. Depth Progress (ft) .._..__ Drilling Hours (hrs) TEAR OUT RIG COMPONENTS & MOVE TO CAPE SIMPSON . Operations Next Report Period : ' ( l – � a t1G.sitfi: . MOVE RIG TO CAPE SIMPSON :�, ",'Y"rem t' ' Poe , ', ,, „ l „ iii, Job Contact Cell Phone Time e ( sj i c Scheduled Depth End Foreman Operation Trouble (KKI3) comment ; , u ,,, ',, .Ernie Natte, Drilling (907) 771 -0536 00 :00 24.00 Drig Planned Rig Down Rig Rig Down No Trbl 7,281.0 TEAR OUT & Foreman' Op Down MOVE RIG TO CAPE SIMPSON / Rigs: Doyon, Arctic Wolf MOVED 2 Rig Supervisor GENSETS, Bob Lupton, Rig Manager TOOLHOUSE, Mud Pumps: 1, Gardner- Denver, PZ -9 BOILER & 2 MUD No. Pwr (hp) 1Rod Diameter (in) ' PUMPS TO CAPE ' 1 900.0 SIMPSON i Liner Size (In) Stroke (In) VOUStk OR (bblls .1 5 1/2 9.02 0.066 Mud Checks: l , , , ,�. Pump Checks Density (Ib /gal) pH CEC for Cuttings Pf (mL/mL) Calcium (mg /L) /° Water ( %) Mud Lost (Hole) (bbl) "'' ' ` Strokes Pres (psi);. 'Slow Spd (spm) Eff ( %) VIs (s /qt) Filtrate (mLl30min) Filter Cake (/32 ") Pm (mL/mL) Potassium (mg /L) Percent 011 (%) Mud Lost (Surf) (bbl) No ,, ��Mud Pumps: 2, Gardner- Denvef' , l PV Over (cp) Gel (10s) (Ibf /100f... Sand ( %) MST (Ib/bbl) Lime (Ib/bbl) 011 Water Ratio Mud Vol (Act) (bbl) No. Pwr (hp) Rod Diameter (In) 2 900.0 III YP Over (IbfMO... Gel (10m) (Ibf/100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl ∎ Liner Size (In) Stroke (In) Vol/Stk OR (bbl /s I 51/2 ____ _ __ 9.02_ _ 0.066 Type Gel (30m) (ibf /1O0... T (fl) ( °F) Chlorides (mg/L) HTHP Flit (mL/3O... Alkalin (mLImL) Whole Mud Add (bbl) 4 t P Checks k 1, ' Max Back Gas (%) Avg Back Gas ( %) !Max Conn Gas ( %) Avg Conn Gas (%) Max Trip Gas ( %) Avg Trip Gas ( %) Pres (psi) Slow Spd S (spm) s Eff ( %) Silicate ( %) Electric Stab (V) Comm No ,,, . • -.; a �f' w,. 1 M ke ke SC ptI Model 4. rs: <De ri Description Make Model 1 — --- HG Dryer Derrick ;Shaker Screens „v Screen Shaker Screens _ __ Deck No.. No. Scr Sz X (in) Scr Sz Y (In) Deck NO =t . screen No. Scr Sz X (in) Scr Sz Y (in) ° - -- 1 - -- 1 i 1 120.000 2 1 120.000 Shaker Checks !Dens OF (lb /gal) Dens UF (Ib /gal) Hrs (hrs) 3 1 120.000 Shaker Checks 11 Nllyli3O,li 14 1 ' atku� t, (. Dens UF (lb /gal) Hrs (hrs) ° Make ° Mode N � 1 I l ea Dryer D L C entrifu e/C clone Checks ' HG Description Make Model , Den sity Overflow (Ib/gal) Overflow Rate (gpm) le Shaker Screens Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) Dens UF (Ib/gal) Underflow Rate (ppm) : /'I 1 1 120.000 l', 2 1 120.000 IHours (hrs) 011 Under Fl (%) Dens FD (Ib/gal) I 144( 3 1 120.000 I – Shaker Checks d Additive Amounts ° Dens UF (Ib /gal) Hrs (hrs) Description Daily Cost Vendor i . Descr; lion Cons... Description - -- Make (Model (. HG Dryer Der i Last Casing Check ,' ^ n `; Date T : ° "7i•; Shaker Screens Deck No. Screen No. Scr Sz X (in). Scr Sz Y (in) - III 1 1 120.000 — Last BOP Check 1� 2 1 120.000 Test Date Test Type 3 1 120.000 �h-- . -- i ,,, Report Printed: 5 • FEX L.P. DDR Detail Page 2/2 Well Name: AKLAQ #6 Job Type: , Drilling - Original " Date: 4/26/2007, Report: 36.0, DFS: 30.47 r Ground Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (ft) Formations ' 18.20 I 37.10 18.90 — Sample Top Shaker Checks Formation Name MD (ItKB) Dens UF(lb/gaI) Hrs (hrs) Nanushuk Group 912.0, Base Permafrost 1,020.0; Drill Strings: • Al ' ' ; i ., '",i.' Nanushuk topset sst. 2,795.01 Bit Run Make jBit Inventory Bit Type item Cost Nanushuk topset sst. 3,388.0 Torok 3,470.0 IADC Bit Dull 1TFA (Intl Noz) (in') !BHA ROP (ft/hr) Nozzles (132 ") IADC Codes Torok sand 1 4,734.0 ,nr Torok sand 2 4,852.0 BHA No. 'Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) Torok sand 3 5,090.0 I Torok sand 4 5,630.0 WOB ( 10001 g ) g Torque PU HL ( Interval ROP fUhr) Total ROP fUhr) Drilling Time hrs Drilling 1000ib Max ( Over -Pull 1 i Torok sand 5 5,798.0] y ( ( ( Torok sand 6 6,008 0111 ��I i Bit RPM (rpm) Motor RPM rpm) Cum Drill Time (hrs) 1 Off Bottom Torque J (Torque Units SO HL (1000Ibf) Torok sand 7 6,313.0 ';' p , __..._._._ —. ( Torok sand 8 6,568.0 Hydraulic Calculations HRZ 6,605.01 AV DP (ft/min) � -- AV DC (ft/min) - __,�,:;;;l_ ta ^" Err Kuparuk Sandstone Mbr 6,800.0 ;i;,1;1... LCU (lower Cret. 6,880.0 Drill String Components Unconformity) Mtr Top Btm Bend BCU (Base Cret. 6,880.0 :No, � Item Density Drift Conn Sz Conn Sz Btm Angle Unconformity) ), Jts Description Len (ft) OD (in) jibs/ft) Grade ID (in) (in) (In) Top Thrd (in) Thrd Cum Len (11) (1 Upper Kingak (Miluveach) 6,880.0 il ' 1 I „ it Kugrua siltstone 7,066.0 Well o,ce io ,.�,I.;� ,,.., ; '7...-.:.:,-. . ;t« Kugrua sandstone 7,120.0 ` .I . Welibore Name VS Dir ( °) Kick Off Depth (ftKB) Kugrua ironstone (lIilr Original Hole 258.00 Kingak Fm „ Directional Surveys w it' x ' Date Description W tli7lr PI e 'x ” r4yl�,.) 10 ,ii 3/27/2007 1MWD Surve s Csg Run Date OD (In) Grade I Wt(Ibs/ft) Ft ^ 1 y 3/19/2007 16 H -40 I 65.00 4 I i , ck itt Iit, ] : Csg Run Date OD (in) Grade Wt (Ibslft) I 4/22/2007 r nn ° °Iilllil'il�' a t lOa . O19�'2 : " X1,6 Ai;( Csg Run Date OD (in) Grade !Wt (Ibslft) 3/31/2007 9 5/8 L -80 I 40.00 1, I r l , 4 `fin C I#9 t , tt:d ' r Csg Run Date OD (in) , W (I /ft) 4/17/2007 7 L-8026.00 , i; ;II . ° 1:4 iii'l'ir 1 Commen(" FA A h' . t iA 1 1 ) It 4 14 t J f { II , , --- r`' ! ., Report Printed 5/3/2007' .,w . e i i 3, ti : 1/� 4,,:li a,..... „4. d, i�1 t s'°r,01,L., :' 1Ur Ci, .�,, .elgaavv , . 'a.,wi i I '4 i; L,,,, ..,. .,': mph. r ,. :r 4,,,, rd 1 FEX L.P. - DDR Detail Page 1/ ,,,,1::,,, Well Name: AKLAQ #6 Job Type: Drilling - Original Date; 4127/2007, Report: 37.0, DFS: 31.47 lik I12l Date Ground Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (ft) AFE No. Total AFE Amount Total AFE*Sup 3/27/2007 12:45 4/23/2007 16:00 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 . ,,... . . , .. ... ..:, *. .,:. ..,,.. :. . ' Target D Target Formation I Id Type Date I CLEA Date Safety Highlight 4/27/2007 PPE / I ATS ,.,1 ,,:,,,,.„.1, Daily Cost Total Cum Cost T 2 Da 04 53 0.00 14,50 , . , n 4 44. „..1 ,44, 4,: .i 0- - , Il me 4 4 Over oil Under (..) AFE 0,14 Var Days Dally Mud Cost Mud Cum To Date O.C. GOOD Suspended l' Weather H" '''' " ' ' ' '' ' Lease / Road Conditions Wellbore Condition ' 2 I , 468,228.75 ' , r - , - '1 0perations (g 06:00 -1 ,Depth Start (ftKB) Depth End (ftKB) kJ iii RIG MOVE ft) Drilling Hours ( hrs) 1 . ' 11 11 I;t Operations This Report Period Depth Progress ( vita 101 h .1 TEAR OUT RIG COMPONENTS & MOVE TO CAPE SIMPSON , - 1 - Operations Next Report Period MOVE RIG TO CAPE SIMPSON Kim Parenteau, Drilling (907)771-0 04 n „. job Contact Cell Phong ,,, ipto. E ' '.. Forema _ el.:,.; ' ' Cfp ' ' ''' Ill ' ' ' ' iftKB Comment ---- - ' D u r , St Scheduled Phase Major �p Operation Trouble, RIG TO F ) Ernie Natte, Drilling (907)771-053o '00"1 Cat Planned Rig Down Rig Rig Move No Trb 7,281.0 MOVE RI 1 00: oreman ALL RIG Rigs: Doyon, Arct Op Down I , c . ., if • CAPE SIMPSON / i vv ,COMPONENTS Rig Supervisor 114 ,.., Bob Lupton, Rig Manager , , ■„,,,,:,,.., REMOVED F/ AROUND mud Pumps:1, ..q e nver p' I P . .. WELLHEAD Rod Diameter (in) .. I 1 ,,,,.,,, e P 1,' L size (In) Pwr , . .........., , , ,.. • - -, , It , 5 1/2 9.0 0.066 ! ., ir- D rill e u ns d ity C ( h ib e ig C a k o s: pH'—'''''' cc for cuttings Pt (mumL) Calcium (mg/L) % Water (%) Mud Lost (Hole) (bbl) Vol/Stk OR (bblis... . „,,, ,„„ Pump Checks • vis (skit) Filtrate (m(J30min) Filter Cake (132”) Pm (mi../mL) Potassium (regIL) Percent Oil (%) Mud Lost (nurf) too./ 1 Strokes o i Pres (psi) Slo (SPIM Eff ( /0) 1 Over (cp) Gel (10s) (lbf/100f... Sand (%) MBT (IbIbbl) Lime (1b/bbl) 011 Water Ratio Mud Vol (Act) (bbl) YP Over (lbf/10... Gel (10m) (lbf/100... Solids (%) LGS (%) Mud Vol (Res) (b131) {Mud PUITIPS 2 ( Polymer (ppm) LCM 2 900.0 ", Type Gel (30m) (lbfl100... T (fl) (. Chlorides (mg/L) HTHP Flit (mU30... Alkalin (mUmL) Whole Mud Add (bbl) , FLiner Vol/Stk :I . Max Back Gas (%) Avg Back Gas (%) Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas (%) pump ck Silicate (%) [Electric Stab (V) Comment Strokss Pres (psi) Slow Spd (spm) Eff ( Description 1; Shakers: <Descrip lo ', .4..4 4 , - ' . 1440: ' ''''' ' ' ' ''''4119 :' 111111, ' • . n ? ) . I Model <Descriptio I ,I4 HG Dryer Derrick I Make Model .... 1 Shaker Screens Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 Shaker Screens ft 2 1 120.000 Deck No. No. Scr Sz X (in) Scr Sz Y (in) 1 1 3 1 120.000 Shaker Checks Shaker Checks I Dens OF (lbfgal) Dens UF (thigal) Hrs (hrs) „I- Dens UF (lb/gal) Hrs (hrs) .., --r--r- ,, V .,,,, 51j1..!''''.1::E, 41 4 '1111 IA. - - ,...,1 • l T Model Make Model 1§,, Description Make HG Dryer Derrick Ovirflow .,,, Dens , entrugeycone sR a te ( gPm ) _ Shaker Screens C if IC l Check — ,;- , - 4 t , i , i4. 44 Z- 11 ,I. 4 .41 1 1VgainareZI;L'4 :14 Density Overflew (lbigal) -- - .. • - ,, . T . V = ''.,' ', ''''' '''''''; ' ,#4.4f1 ' at d ' ', ikhk.' '''' ' .4 C 4,, s - • 1 20.000 ] !ill 2 1 120.000 Dens UF (lb/gal) Underfloor Rate (gpm) 3 1 120.000 r k Shaker Checks I Hours (hrs) 011 Under Fl (%) Dens FD (Iblgal) Hrs (hrs) ' . , Model 1 Description Make Description Cons... Daily Cost Vendor 'Derrick I HG Dryer .,. 4 Shaker screens 744 , „, „ ,, • .. , .. n) SCr Sz Y (In) Las , -s ng 1 1 120.000 • - - , ,,,, , ,,,: 1 4, I4 ' ' - ,,, 2 1 120.000 3 1 120.000 , .t. 0 , , , e .p1.1.:., . Test Date Test Typ Shaker Checks .I Dens UF (lb/gal) 4 ciret:.) iii if 'ie''''1:ri''..0SS, , , . i Hrs (hrs) V i717 , eip iti:iiiiiiNV4 - ii-- Repci''' - r , ,, ;/3/2 81 II 1, 0 410 FEX L.P. - DDR Detail Page 2/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/27/2007, Report: ` 37.0, DFS: 31.47 e ,,,,,,' ohil , H , I Ground Elevation (k) Orig KB Elev (ft) KB- Ground Distance (k) Formations 18.20 37.10 18.90 Sample Top Drill Strings: Formation. ■ Name MD (ftKB) Bit Run Make Bit Inventory Bit Type Item Cost N anushuk G roup 912.0 ' I Base Permafrost 1,020.0 !ADC Bit Dull ITFA (loci Noz) (In') [BHA ROP (ftlhr) Nozzles (132 ") I IADC Codes Nanushuk topset sst. 2,795.0 ` Nanushuk topset sst. 3,388.0 ,, r. r„ Torok 3,470.0 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max Hook Load (Ibf) Torok sand 1 4,734.0 WOB (1000Ibf) IMervai ROP (ftlhr) Total ROP (ft hr) Drilling Time (hrs) Drilling Torque PU HL (10001bf) Max. Over -Pull (Ibf) Torok sand 2 4 ' = M1 Torok sand 3 5,090.0 , , Bit RPM (rpm) !Motor RPM (rpm) !Cum Drill Time (hrs) Off Bottom Torque Torque Unhs SO HL (1000Ibf) 'Torok sand 4 5,630.0 '„ Torok sand 5 5,798.0 Hydraulic Calculations ' Torok sand 6 6,008.04' ' AV DP (ftlmin) AV DC (ft/min) r ; , Err W; , Torok sand 7 6,313.0 1 Torok sand 8 6,568 0 Drill String Components 'HRZ 6,605.0: , Kuparuk Sandstone Mbr 6,800.0 :' Item Density Drift Conn Sz Conn Sz Btm A ie LCU (lower Cret. 6,880.0,4; Jts Description Len (ft) OD (in) (Ibs /ft) Grade ID (in) (in) (in) Top Thrd (In) Thrd Cum Len (ft) ( Unconformity) BCU (Base Cret. 6,880.0' Unconformity) ', kt Wellborn Name VS DIr O Kick Off Depth (ftKB) Upper Kingak (Miluveach) 6,880.0 Original Hole 258.00 Kugrua siltstone 7,066.0' ', Directional Surveys 'Kugrua sandstone 7,120.01 Date Description 3/27/2007 MWD Surveys -� Kingak F Kugrua ironstone Fm. f 4 onductor ' '.,. Ne Csg Run Date O D (In) Grade Wt (Ibsfft) iP 3/19/2007 16 H-40 65.00 Tiebac14 ;" ' t Csg Run Date OD (In) Grade Wt (Ibs/ft) 4/22/2007 Csg Run Date OD (In) Grade Wt (Iba/tt) 3/31/2007 98 L-80 40 00 VP Csg Run Date OD (in) Gra Wt (Ibslft) 0 4/17/2007 7 L -80 26.00 Pli � I I I , 1 _ :. t 4 E 1G7 ,s�G 3yx I I � , „41 1 Des 1 . 1, — „ .v H til , Flift 1111 71P4 I ' rI PO S fi ;Y ,, l h 'i I z 4$ ifft ligg tili I fdi ii i II? "'I iii wl ----A.---- -11 FEX L.P. - DDR Detail P age 1/ Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/28/2007, Report: 38.0, DFS: 32.47 • Job Sp Date - -- Rig Release Date - -- (Ground Elevation (ft) Or KB Elev (ft) KB- Ground Distance (ft) AFE No. Total AFE Amount Total AFE +Sup 3/27/2007 12:45 4/23/2007 16:00 18.20 ; .10 18.90 AF62034 22,574,244.00 22,574,244.00 �afel y Target Depth (ftKB) Target Format Type Date comment 7,262.0 Safety Highlight 4/28/2007 SPILL REPORTING /VEHICLE CONTAINMENT DaiyCost Total Cum Cost To Date 0.00 14,500,204.53 a ( 9 r.,'+',.7:71' x C Dal M u d Cost Operations @ 06:00 Mud Cum To Date Weather ' t l ease 1 Road Con Welibore ondiUoa Over ( +) /Un (-)AFE ( + /•) Yar Days y '1 CLEAR GOOD 'Suspended 2 468,228.75 — — — ---(Depth Start (ftKB) Depth End ( ftKB) RIG MOVE Depth Progress (ft) Drilling Hours (hrs) Operations This Report Period MOVE RIG COMPONENTS & RACK IN CAPE SIMPSON Operations Next Report Period l ¢ TEAR OUT WOLF CAMP & MOVE TO CAPE SIMPSON ;� r ., 1 Job'Contti, „ e Kim Parenteau, Drilling (907)771-0536 Start Dur Ops Scheduled Depth B End - Foreman Time Ahrs) Cat Type , , Phase Major Op Operation Trouble (ftKB) Comment Ernie Natte, Drilling (907) 771 -0536 „ 00:00 24.00 Drlg Planned Rig Move /Up Rig Rig Move No Trbl 7,281.0 MOVE RIG & Foreman 4 Op Move /... RACK RIG @ 'CAPE SIMPSON / IRigs: Doyon, Arctic Wolf DIESEL FREEZE Rig Supervisor PROTECT & Bob Lupton, Rig Manager j SUSPEND MII . .. ®r 4.. ' r''''t::;', Ill OPERATIONS @ N Pwr (hp) Rod Dia ( t , I AKLAQ #2 I 1 900.0 I Liner Size (In) Stroke (In) Vot/Stk OR (bbl/s... 1 - 9' ' 470M1,.',,,,1417,75 u. 5 1/2 9.02 0.066 Mud Checks:: '?s, Density (Ib /gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg/L) % Water (%) Mud Lost (Hole) (bbl) Pump Checks P. Strokes (is (slgt) FIltrate (mL/30min) Filter Cake (132 ") Pm (mUmL) Potassium (mgiL) Percent Oil ( %) Mud Lost (Surf) (bbl) Pres (psi) Slow Spd (spm) Eff ( %) No PV Over (cp) Gel (10s) (Ibf /100L.. Sand ( %) MBT (Iblbbl) Lime (Ib/bbI) — OH Water Ratio Mud Vol (Act) (bbl) ud Pumps: 2, Gardner - Denver, PZ•9 N o. Pwr (hp) Rod Diameter (In) i 1 YP Over (Ibf/10... Gel (10m) (Ibfl100... Solids ( %) LGS ( %) Polymer (ppm) LCM Mud Vol (Res) (bbl) 2 900.0 Liner Size (In) Stroke (In) Vol /Stk OR (bbl /s... Type Gel (30m) (Ib0100... T (fl) ( ° F) Chlorides (mgiL) HTHP Filt (mU30... Alkalin (mUmL) Whole Mud Add (bbl) '', 5 1/2 9.02 0.06 — — — Pump Checks Silicate ( % � s Electric Si (Y►� ommel Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas (%) Avg Trip Gas ( %) P ( /) Avg ( ) it S trokes Ii Comment — - - -- - - -- -- Pres (psi) Slow Spd (spm) Eff ( %) 'I No Drying Shak # Make Model Description Make Mod el HG Dryer Derrick Shaker Screens Shaker Screens - Screen Deck No. Screen No. Scr Sz X (in) �'�, k No. No. Scr Sz X in Scr Sz Y in 1 1 120.000 scr Sz Y (in) 4 l') ` (' ) 2 1 120.000 �.. II 3 1 120.000 'Shaker Checks „Dens OF (Ib /gal) Dens UF (lb /gal) Hrs (hrs) Shaker Checks l Dens UF (Ib Hrs (hrs) Make Model Description er Make Model 1 HG Dry Derrick Centrifuge /Cyclone Che �H Shaker Screens Density Overflow (Ib/gai) Overf Rate ( gp m) Deck No. Screen No. Scr Sz X (in) S Sz Y (in) 1 1 I 120.000 2 1 120.000 Dens pblgal) Uflow Rats (gpm) 31 1 120.000 Hours OF (hrs) Oil Under FI (% Dene FD (Ib /gaq :'. Shaker Checks .'. II . s �.. III Hrs (hrs) IVI � V e t Description Cons... Daily Cost i Ye i Dens UF (lb/gal) H Description HG Dryer Derrick Make Model ' ,1 ' ': . ', ;I,, , : ,i, , :.:,J yfl� ,� ,.1' a ,1, '' Shaker Screens II Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in)(� -' ' - Tyke, 1 1 120.000 I 2 1 120.000 ' 1 t, ,; u IIII! Testb. rest Type 3 1 120.000 ,, i S ha . ker Checks —_.. I G ,., Dens UF (Ib /ga - - -- Hrs (hrs) h, ` 1 ' 4� 4 f c r. k=2 * t'' . a ,2, h, � � ° fwi � i/ "rill ur , _ 0 .' i. "�IB IIi 4.' I � ' , .n .. r� ..._.. fli%, , :. ., .„< tr - �e " 9 a u ., s#�,. rb�ka! �o iii ds ».. I� , 'd'."r .i. o rv'W AO F EX L.P.. DDR De tail' J'1 i-' `'I' age 2/2 g Well Name: AKLAQ #6 4 � a ,� �' 44 L Jobii ; ,`w "E® „ Original Date: 4/28/2007, Report: 38.0, DFs: Ground Elevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) Formations ___ _ _ 18.20 37.10 18.90 sample Top Drill String ' 1' Formation Name ! r MD (ftKB) Bit Run Make Bit Inventory Bit Type Item Cost ,Nanushuk Group 912.0 Base Permafrost 1,020.0 (Inc! ■ )ADC Bit Dull TFA Intl Noz) (In') BHA ROP (t7hr) Nozzles (132") J iaDC coax Nanushuk topset sst. 2,795.0 , I ' Nanushuk topset sst. 3,388.0 3,470.0 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (ibt) Torok sand 1 4,734.0 WOB (10001bt) Interval ROP gt/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000Ibf) Max. Over -Pull (Ibf) Torok sand 2 452.0 'f' Torok sand 3 590.0 Bit RPM (rpm) Motor RPM (rpm) !Cum Drill Time (hrs) Off Bottom Torque Torque Units ISO HL (10001bf) Torok sand 4 530.0 kEr Torok sand 5 5,798.0:7'i H draulic Calculations Torok sand 6 6,808.00 $j .,. r x , 1. 1, ".',!,.1 x .:b i;: ...' ;' a Torok sand 7 6,313.0 i Torok sand 8 6,56$ 0 I Drill Strin, Com • onents HRZ 6,605 0 I , t dIkiwjt 4 L ' Top Btm Bend Kuparuk Sandstone Mbr 6,800 0 Item ' Density Drift Conn Sz Conn Sz Btm Angle LCU (lower Cret. 6,880.0 1 Jts Description Len (ft) OD (in) (lbslft) Grade ID (in) (in) (in) Top Thrd (in) Thrd Cum Len (ft) (") Unconfornlity) t 1 . i e Hii (H I. 1 i ..' H w= � o, ,, — (Base 80 0 Cret. 6 8 ) : W elibo r eNam e , , ,_a , , . c,t '° t.n. . VS oi r (') r, Upper ga ( �� Unconformity) K ) ) ., Directional Surveys Hole 258.00 ( Kick Off Depth (ftKB) _ Kugrua siltstone iluveach 7060 0 1 L Y Kugrua sandstone Date Description . " ' 3/27/2007 MWD Surveys Kugrua Ironstone Illy :Kingak Fm. Of >uctor Pipe, 98.8ftKB '�; ,(, 71 Csg Run Date OD (In) Grade Wt (Ibslft) ,'.i.,. 3/19/2007 16 H -40 65.00 Ai Tieback �I,e 4 1,350.OftKB 'OP Csg Run Date OD (in) Grade Wt (Ibslft) 4/22/2007 y Via. : .. .gg,: 2,072.1ftKB ICsg Run Date OD (in) Grade Wt (Ibslft) .,i, 3/31/2007 9 5/8 L - 80 40.00 ' 1.- a ,• 50 0ftKB ail 1 1 !Csg Run Date OD (in) Grade Wt Ohs/ft) j 4/17/2007 7 L -80 26.00 vi cll ,.1) Ir . .. 03 1 17 .:Ilu,. , i ....qt t #ant i�al F ' 'ilk i AI i d I d s lo q p 1 , t Ii ri ., 4, 1 i+ t I1I, I i Ohl . i1li 4'' - " 1l! i'" a! ' , Rep 'Wrote 13/2007 ..x- a.� , A i 0 II - tip'' .. � ��N� .� ,. tax . rY. e .. . {, k t „ , eaa.w13r . III FEX L.P. - DDR Detail 0#01 I , Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/2912007, Report: 39.0, DFS: 33.47 AC c,11111- . Job Spud Date Rig Release Date TGroundElevation (ft) Orig KB Elev (ft) KB- Ground Distance (ft) jAFE No. Total AFE Amount Total AFE +Sup 3/27/200712:45 4/23/2007 16:00 1 18.20 37.10 18.90 AF62034 22,574,244.00 22,574,244.00 Safety Target Depth (fIKB) Target Formation Type Date Comment ,.=.Wa.a.a.�,....w, ' , 7,262.0 Safety Highlight 4/29/2007 TRUCK SAFETY/ HANDLING SLINGS Daily Cost Total Cum Cost To Date Daily ! Summary AlkL, 0.00 14,500,204.53 Daily Mud Cost Mud Cum To Date ! Weather Lease / Road Conditions Wellbore Condition Over ( +) / Under ( -) AFE ( + / -) Var Days � CLEAR GOOD Suspended 2 1 468,228.75 �" Operations @ 08:00 Depth Start (ftKB) Depth End (ftKB) RIG UP CAMP @CAPE SIMPSON Operations This Report Period - -- - -- __ - -- ___ -- - - -_ - -- __ - -- -- ----- _ - -- - -- [epth Progress (ft) Drilling Hours (hrs) MOVE CAMP TO CAPE SIMPSON Operations Next Report Period x1111 go' • . RIG UP CAMP @ CAPE SIMPSON ® ci ty $o Ft' Wemon Co,D Ct n ull9 „ , � i . 1 to 4 i '( r °�i p � � ' T hlh 1 Job Contact f Cell Phone Time Log ` � , �1� ^; : ,rr . K Parenteau, Drilling 1(907) 771 -0536 Start Dur Ops Scheduled De Foreman Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment Ern Natte, Drilling (907) 771 - 0536 9 I ! 00:00 24.00 Dr P Op 'Rig Move/Up Move /U ` Rig , Rig Move No Trbl 7 TEAR OU T & Foreman . p Move /... MOVE CAMP TO CAPE SIMPSON / Rigs: Doyon, Arctic WQ Ii I REMOVE Rig Supervisor EQUIPMENT F/ f � Bob Lupton, Rig Manager AKLAQ #2 (/4'I� !, l'I (j('ps: 1 Gardner -De I„, !,n No. Pwr (hp) Rod Diameter (In) Mud Checks: 1 900.0 Density (lb/gal) pH CEC for Cuttings Pf (mUmL) Calcium (mg /L) ,% Water ( %) ''Mud Lost (Hole) (bbl) ( Liner Size (In) Stroke (In) VoI/Stk OR (bbl/s... _ 5 1/2 9.02 0.066 fir Vis (s /qt) Filtrate (mU30min) Filter Cake (132 ") Pm (mUmL) Potassium (mg /L) Percent 011 ( %) Mud Lost (Surf) (bbl) Pump Checks PV Over (cp) Gel (10s) (Ibf/100f... Sand ( %) MST (1b/bbl) Lime (Ibibbi) 011 Water Ratio Mud Vol (Act) (bbl) Pres (psi) Slow Spd S (spm) s Eff (%) No YP Over (IbfMO... Gel (10m) (Ibf /100... Solids (%) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) , Pumps: 2, Gardner - Denver, PZ -9 Type Gel (30m) (Ibf/100... T (f1) (•F) Chlorides (mg /L) HTHP Filt (mLr30... Alkalln (mUmL) Whole Mud Add (bbl) No. Pwr (hp) Rod Diameter (In) 0! 2 900.0 Max Back Gas (%) Avg Back Gas ) Max Conn Gas (%) Avg Conn Gas (%) Max Trip Gas %) Avg Trip Gas ( %) Liner Size (In) Stroke (In) 1 VoUStk OR (bbl/s... ( ) 9 (% ( 1 g C) P 5 1/2 9.02 0.066 Silicate ( %) Electric Stab (V) Comment Pump Checks Strokes a , i .' ' ,� 1,,, � In a =i . , e , �:Preg,(P,si)._ slow Spd , r (SPm) Eff %) Drying Shaker Data �.. ��,,,.. _�,a. ,�,a', Description Make Model No HG Dryer Derrick Shaker Screens Make Model Deck No. Screen No. Scr Sz X (in) Scr Sz Y (in) 1 1 120.000 Shaker Screens 2 1 120.000 Screen Deck No. No Scr Sz X (in) Scr Sz Y (In) 3 1 120.000' I I Shaker Checks Shaker CheckS Dens UF (Ib /gal) Hrs (hrs) Dens OF ( Ib /gai) Dens UF (Ib /gal) Hrs (hrs) Description Make Model ' HG Dryer Derrick -- -_- - — --- - ---._ Make Model I I Shaker Screens Eck No. Screen No. Scr Sz x (In) Scr Sz Y (In) , _ .- _ Centrifuge /Cyclone Checks 1 1 120.000 ` Density Overflow (lb/gal) Overflow Rate (gpm) 2 1 120.000 3 1 120.000 1Dens UF (Ib/gal) Underflow Rate (gpm) Shaker Checks Dens OF (Ib /kal) _— Hrs (hrs) Hours (hrs) 011 Under Fl (%) ! FD (Ib/gal) 1 Description Make - Model ~ }'q „ — t) HG Dryer o Derrick _ peg�rt tl' icons. p � .. Daily Cost Vendor Shaker Screens Deck No Screen No Scr Sz X (in) Scr Sz yin) k? 1 1 120.000 ; "i` * a 1 # °° 2 1 120.000 L., _Date ; _w-t ':ibe _..__.._.. 3 1 120.000 i e Shaker Checks ,, , Dens OF (Ib /pal) , a , 9 " 1` , — ''a",�, °.. . °, ; . ) .APB ,., �' .i ' '411111°" 'Tes t ,# s�- — * @a 1 l I 1 ,rye r . -_ - + ,. w.S ,. ',s . �.. -... .�� .< a .;.. ate. ,, 4 : 1:111 ! . Si)a ) i' ij ?rjt , , s +t nl yi { ' * :n . ' n^ 1 n y .. y 'n • w a 6 8 r , " G e a r d w . 1,,, a I q i %" .'ie a'' ( g Well Name: AKLAQ #6 e ' ,i M , ._f i t , 4 �.. �� r ., u , ,, � � ( �I I'I Ii�� ��I�'i�Il�lii��I I�I)�i a, s .' - Job Type: Drilling - Original Date , 4/29/2007, Report " 't ga. ,, '�Ii�ti ga ,9 *v,;Vr, , Ground Elevation (ft) Orig KB Elev (ft) KB-Ground Distance (ft) Formations k 18.20 7.10 18.90 ( yrll f mpleTop Brf " Formation Name ,r I V i t ' ` ,, l' Bit Run Make Bit Inventory BltType ' Item Cost Nanushuk Group 912.0 = . ! Base Permafrost 1,020 0 IADC Bit Dull ITFA (Inc! Noz) (In') BHA ROP (ft/hr) 1oules (132') IADC Codes Nanu topset sst. 2,795 0 Nanushuk topset sst. 3,388 0 u oHl, , `im! @lit!" * , . f . . „�,.. p, g, �iU3 9 'I�I'' !!!Pl, i I I 3,470 0 tEm, „�A.')� 9I T� I�'i' 6u� P�4b`�t "i' �Nj� �') � Ik( Torok , ar BHA No. ; Cum Depth (ff) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL. (10001... Max. Hook Load ( Ibf) Torok sand 1 4,734.0 .0 Torok sand 2 4,852 0 l` i t 1 Torok sand 3 5,090.0 i i Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units ;SO HL (1000ibf) Torok sand 4 5,630.0 i y'.. Ill; Torok sand 5 5,798.0 l �" Hydraulic Calculations Torok sand 6 6,008.0 l i AV DP fUmin)'... AV DC (ft/min) — ...... _.. . -..... ......__T - -._ Err........ Torok sand 7 6,313.0 .. ttilli f..– -- .. -..._ — — ; Torok sand 8 6,568.0 Drill String Components _ _ HRZ 6,605 0 Top' Bon Bead Kuparuk Sandstone Mbr 6,800.0 7 !* t); EEEEl Jts Description Len (ft) .OD (in) a (Ibslft)' Grade ID (!n) (in) (!n) Top Thrd (In) Thrd Cum Len (ft) t ° ) UnC nfo rmity) Item Densl Drift coon Sz coon Sz Btm Angle LCU (lower Cret. 6,880 0 BCU (Base Cret. 6,880 0 al ild 6 i h !!!' wry tt'' (t r : P � ` ;, ,° ' h „ , J! * �.. alibi T Ur1COhforml �) Wellbore N ame V S Dlr ( °) Kl Off D (ftKB) Upper Kingak (Miluveach) 6, El: , Original Hole 258.00 Kugrua siltstone 7,066.0 880 0 „" L' Directional Surveys , Kugrua sandstone 7,120 0 :, Date Description 3/27/2007 f MWD Surveys Kugrua ironstone Kingak Fm. I P o0 u r. ; Csg Run Date OD (in) Grade Wt (Ibs /ft) 3/19/2007 16 H-40 65.00 `' Csg Run Date OD (in) Grade 'Wt (Ibs /ft) 4/22/2007 } y Csg Run Date OD (in) Grade ;Wt (Ibs /ft) w „ 3/31 /2007 9 5/8 1 L -80 40.00 , r 1 1 Csg Run Date OD in) Grade Wt (Ibs /ft) ;/,, 4/17/2007 7 L -80 , 26.00 x?"'' 1 y& �k & t ���1qe. �ay� Cmnt O carn _ k < I 4 illY j'.' l 4 ripe oi mi t ri I GI it . .. . ., . 'a�.n.�, Mall �,a ! L .._. 2 :. a � �!,t5 Y r, .�4., : .,. � h k , m � . , �' Rn� ' ^st ,E.� S '�� � ----410 FEX L.P. - DDR Detail 4 Page 1/2 Well Name: AKLAQ #6 Job Type: Drilling - Original Date: 4/30/2007, Report: 40.0, DFS: 34.47 ill Job Spu 3 /27/2007 12:45 Rig 4/23/2007 1 6:00 Ground El 18 2 (k) Orig 3 7.10 (ft) K6- Ground (k) A AF62034 22 00 22,5 4,244 00 -- - -- - -- — -- - - -- Safety Target Depth (ftKB) Target Formation Type Date Comment 7,262.0 Safety Highlight 4/30/2007 LOADER SIGNALS [Daily Cost Total Cum Cost To Date D t ��� �. ii i!' i' - +, 5,803,503.00 20,303,707.53 Weather Lease / Road Conditions Wellbore Condition Over (4) / Under ( -) AFE (H-) Var Days !Dally Mud Cost Mud Cum To Date CLEAR GOOD Suspended 2 468,228.75 Operations @ 06:00 Dep th Start (ftKB) Depth End (ftKB) RIG DOWN TALKEETNA CAMP 1 _ Operations This Report Period - - - - -- --- - - - - -- - -_- - - -- _--- _.....-- _ — °e pth Progress (ft) Drilling Hours (hrs) MOVE & SET UP WOLF CAMP @ CAPE SIMPSON Operations Next Report Period - - - - RIG DOWN & MOVE TALKEENA CAMP Kim Paren ' Log ' ; Time , 11 ' 1 �"�17 iI �� �k w g 1 teau, Drilling (907) 771 -0536 Start Dur Ops Scheduled Depth End Foreman , Time (hrs) Cat Type Phase Major Op Operation Trouble (ftKB) Comment Ernie Natte, Drilling x (907) 771 -0536 00:00 24.00 Drlg Planned Rig Move /Up Rig Rig Move No Trbl 7,281.0 SET MATS & Foreman Op Move /... SPOT WOLF CAMP @CAPE Rig;3 *'DOyon,Arctic Wolf SIMPSON / BEGIN Rig Supervisor RIG DOWN OF Bob Lupton, Rig Manager TALKEETNA # a CAMP / INSTALL No Pwr (hp) Rod Diameter GUARD AROUND 1 1 900.0 CELLAR & Liner Size (In) Stroke (In) Vol /Stk OR (bolls... SECURE 51/2 9.02 0.066 WELLHEAD @ AKLAK #6 Pump Checks Strokes Pros (psi) Slow S (spm) ks, Eff (% ) No I Mud Checks: )I i - - -. i , w Density (Ib/gal) pH I CEC for Cuttings Pf (mL/mL) Calcium (mg /L) % Water ( %) Mud Lost (Hole) (bbl) t° "u117 2, Gar pd ne ra� es, PZ -9 No. Pwr (hp) Rod Diameter (in) Vie (s /qt) Filtrate (mb/30min) Filter Cake (132 ") Pm (mUmL) Potassium (mg /L) Percent Oil (%) Mud Lost (Surf) (WI) 2 900.0 Liner Size (In) Stroke (In) I VoUStk OR (bbus... PV Over (cp) Gel (10s) (Ibf /1O0f... Sand ( %) MBT (Ib/bbI) Lime (Iblbbl) Oft Water Ratio Mud Vol (Act) (bbl) 5 U2 9.02 0.066 Pump Checks YP Over (Ibf /10... Gel (10m) (Ibf/100... Solids ( %) LGS (%) Polymer (ppm) LCM Mud Vol (Res) (bbl) Strokes Pres (psi) Slow Spd (spm) Eff (%) Type Gel (30m) (Ibt/100... T (fl) ('F) Chlorides m - --- ( gfL) HTHP Flit (mL130... Alkalln (mL/mL) Whole Mud Add (bbl) NO Shakers: <Description ?> Max Back Gas ( %) Avg Back Gas ( %) Max Conn Gas ( %) Avg Conn Gas ( %) Max Trip Gas ( %) Avg Trip Gas (%) Make Model Silicate ( %) Electric Stab (V) Comment 'Shaker Screens Screen P � i i � Deck No. 1 No. Scr Sz X (in) Scr Sc Y (in) Description Make Model HG Dryer Derrick i - Shaker Checks Shaker Screens Dens OF (Id /gal) Dens UF (lbrgai) Hrs (hrs) Deck No. Screen No. Scr Sz X (In) Scr Sz Y (In) 1 1 120.000 2 1 120.000 Make !Model 3 1 120.000 ' Shaker Checks Centrifu t e/C clone Checks I Dens UF (Ib /gal) Hrs (hrs) Density Overflow (Ib/gal) Overflow Rate (gpm) 1 ( Description Make Model Dens UF (Ib/gal) Underflow Rate (gpm) HG Dryer Hours (hrs) 011 Under Fl (%) Dena FD (Ib/gal) Shaker Screens u4. Deck No. Screen No. Scr Sz X (In) Scr Sz V (in) 1 1 120.000 -Mud A ...i. 0 2 1 120.000 Description Cons... Daily Cos Vend 3 1 120.000 Shaker Checks r p Dens UF (Ib/gal) H tS;,dr.r'ax ° ' 1.. " '' / Description Make . _ Model il l, HG Dryer _Derrick' Shaker Screens i 1 1 120.000 ` gg ; 2 1 120.000 _' y,,G 64)a li.HU+,v=x1fi s '� . i� , , '1 t'I�7) ,UIiI.,,.a. '„ (,I '�s'sul .,. _ l''' -'16i: 4 , , h� +, � , al l,A t . am ,, " ��"'"9'I ) , 1 � 1II1Iaarv:Cv. , I I, �r,a RepQ a : 9 � a`:+ r FEX L. - DDR Detail '� - ; �����71[ AKL.AQ KB '''''°43-°614''' i� iI � A: t" '�° i�u� da � ' q I � .,`I- ' "i iI C�. �' I :. �'i ,�. ��I �'M�I �r r ° 7 1K a a n� �� A, �4f ! Ol Ong a ?- D a t e: 413012007, Repo �� I Ground Elevation (k) Orlg KB Elev (ft) KB- Ground Distance (ft) FOrmatlonS it 18.20 37.10 18.90 it . Sample Top Shaker Screens Formation Name MD (ftKB} Deck No': Screen No. Scr Sz X (In) Scr Sz Y (In) Nanushuk Group 912.0 " 3I 1 120.000 B ase Perma 1,020.0 Shaker Checks Nanushuk topset sst. 2,795.0 Dens OF (Ibigal) Hrs (hrs) i $ ., Iri ,,,,, ,„,, Nanushuk topset sst. 3,388.0 1 L Torok 3,470.0 Drill Strings: Torok sand 1 4,734.0 Bit Run I Make Bit Inventory Bit Type Item Cos Torok sand 2 4,852.0 IADC Bit Dull TFA (Inc, Noz) (In') BHA ROP (k/hr) Nozzles (132') IADC Codes TOI Torok sand 3 5,090.0 Torok sand 4 5,630.0 _ __ _ , , 1 — �. ...... — . - -T� _ - Torok sand 5 5,798.0 BHA No. Cum Depth (ft) SPP (psi) Flow Rate (gpm) TFO Reference Rot HL (10001... Max. Hook Load (Ibf) Torok sand 6 6,008.0 ;Torok sand 7 6,313.0 WOB (100011g) Interval ROP (ft/hr) Total ROP (ft/hr) Drilling Time (hrs) Drilling Torque PU HL (1000lbf) Max. Over -Pull (lbf) J Torok sand 8 6,568.0 — — — —. _ HRZ 6,605.0 Bit RPM (rpm) Motor RPM (rpm) Cum Drill Time (hrs) Off Bottom Torque Torque Units SO HL (1000Ibf) Kuparuk Sandstone Mbr 6,800.0 LCU (lower Cret. 6,880.0 Hydraulic Calculations Unconformity) AV DP (ft/min) AV DC (kim Err BCU (Base Cret. 6,880.0 Drill String Components Unconformity) Mtr Upper Kingak (Miluveach) 6,880.0 Top Btm Bend Kugrua siltstone 7,066.0 Item Density Drift Conn Sz Conn Sz Btm Angle Kugrua sandstone 7,120.0, �� °. Jts Description Len (ft) ', OD (in) (Ibs /ft) Grade ID (in) (in) (1n) Top Thrd (in) Thrd Cum Len (ft) (`1 .. Kugrua Ironstone �� Kingak Fm. Welikores, .. ^tip .w . . ,. "1 ° onductor Pie `,98.8ftKB Weilbore Name VS lift ( °) Ki Off Depth (ftKB) - p Original Hole 258.00 l Csg e (In) Gra Wt (Ibs /ft) 3/19/2007 Run Dat OD 16 H - 65.00 Directional Surveys Date Description . 3/27/2007 MWD Surveys - Tielaack Liner, 1,350.OftKB Csg Run Date OD (in) Grade Wt (Ibslft} _ -_ _ - -_ 4/22/2007 I ce Casing, 2,072.1ftKB Csg Run Date OD (in) Grade Wt (Ibs /ft) 3/31/2007 9 5/8 L -80 40.00 Production Casing, 7,050.OftKB Csg Run Date OD (in) Grade Wt (Ibs /ft) 1 4/17/2007 7 L -80 26.00 Cement Cmnt Des Comment j 15y I I 0 F 1,1q.1, t *� , ,, ,1 :. Re ort Prin ted : 007 p 4 4 r r b rt - , . e-! ( Iii_ 1 1 . " iA. � �az�a ,'� � ... , r e f 'e i �ir =& .> r .:, a s? - e , ..,k �4 "3L �IiruG .����I tree ti�i.t- y Fuiii .�4?is?sv RECEIVED • ,/ STATE OF ALASKA ALASI OIL AND GAS CONSERVATION COMMIS 'ION MA Y 2 6 7007 WELL COMPLETION OR RECOMPLETION REPORT D, L ,( G., C mission la. Well Status: Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ Suspended 0 WAG ❑ lb. Well d ss: gt1 20AAC 25.105 20AAC 25.110 Development ❑ An ogt ( iry 0 GINJ ❑ WINJ ❑ WDSPL❑ No. of Completions Other Service ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: FEX L.P. Aband.: April 23, 2007 • 207 -009 3. Address: 6. Date Spudded: 13. API Number: 3601 C Street, Suite 370 Anchorage AK 99503 March 27, 2007 • 50- 279 - 20019 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2307'FWL,2955' FSL. Sec. 25, T16N, R11W. UM April 14, 2007 w Aklaq #6 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field /Pool(s): 2307'FWL,2955' FSL. Sec. 25, T16N, R11W. UM 39 Total Depth: 9. Plug Back Depth(MD +TVD): Wildcat 2307'FWL,2955' FSL. Sec. 25, T16N, R11W. UM NA 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 426473 , y- 6110601.8 ' Zone- 5 7280. AA- 085517 TPI: x- 426473 y- 6110601.8 Zone- 5 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 426473 y- 6110601.8 Zone- 5 N/A LAS 25297 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A feet MS 1060 21. Logs Run: MWD Gamma,Resistivity, Neutron,Density,Sonic 22. CASING, LINER AND CEMENTING ' CORD WT. PER SETTING DEPTH MD SETTING DEPTH 0 AMOUNT CASING GRADE TOP BOTTOM TOP BO OM HOLE SIZE CEMENTING RECORD FT PULLED 16" 65# H -40 0 80 0 80 20" 50 bbls Type C cement NA 9 -5/8" 40# L -80 0 2072 0 072 12.25" 0 -2072 Cement to surface NA 7" 26# L -80 0 7050 0 7050 8.5" 4500 -7050 Multi -stage NA 23. Perforations open to Production (MD + TVD of Top and Botto' 24. TUBING RECORD Interval, Size and Number; if none, state "none "): SIZE DEPTH SET (MD) PACKER SET (MD) N/A 3.5# 1413 N/A A A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ` ` DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 0 r :I; 0 -4500 (9 5/8 annulus) 45 bbls Class G, 35 bbls Permafrost Cement y ,'� 1.1 V • 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A N/A Date of Test: Hours Teste--: Production for Oil-Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period •-► Flow Tubing Casing Press: Calculated Oil -Bbl: 'Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate - 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none ". A core was taken on this well from 7127 -7163 MD. A full detailed report will be submitted with this report. A comprehensive summary of the geology on this well will be submitted with this report. Full detailed reports of mud logs and MWD logs will be submitted with this report. No wireline logging was performed on this well. • Form 10 -407 Revised 12/20030 R 1 G 1 N ACLNTINUED ON REVERSE 28. GEOLOGIC MARKER 29. FORMATION TESTS NAME MO I TVD Include and briefly surflfTfarize test results. List intervals tested, and attach Base Permafrost 1225 1190 detailed supporting data as necessary. If no tests were conducted, state Nanushuk group 2791 2775 "None". Torok 3470 3446 No tests were performed on this well. Torok sand 1 t 4734 4688 HRZ 6605 6558 Kuparuk Sandstone Mbr.t 6800 6753 Kugrua sandstone 7120 7073 30. List of Attachments: Directional surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Paul Mazzolini Title: Operations Manager Signature: > Phone: 907 771 1923 Date: 22- May -07 (((( 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 la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet 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 • Drilling Project Transmittal woos r ro To: State of Alaska e4M R eserve Alas , ±' May /5, 2007 Oil & Gas Conservation Commission 333 W. 7 Ave.. Suite 100 Anchorage, AK 99501 Attn: Steve Davies From: FEX L.P. 3601 C Street, Suite 370 , , , -j, Anchorage, Alaska 99503 RE: Aklaq #6 1. 1 print copy and 1 CD of Daily Drilling Reports A. 1 print copy of Directional Survey (included in end of well report) 3. 1 print copy of TVD and MD DGR Dual Gamma Ray 4. 1 print copy of TVD and MD EWR — Phase 4 Resistivity ;� B 5. 1 print copy of TVD and MD SLD /ALD Density 6. 1 print copy of TVD and MD CTN Compensated Thermal Neutron ,� 7. 1 print copy of TVD and MD BAT Bi -Modal Acoustic / 4 8. 1 print copy of TVD and MD ROP Rate of Penetration / 9. 1 CD copy of TVD and MD DGR Dual Gamma Ray, EWR — Phase 4 Resistivity, SLD /ALD Density, CTN Compensated Thermal Neutron, BAT Bi -Modal Acoustic, ROP Rate of Penetration 10. 1 print copy and 1 CD of MWD/LWD End of Well report 11. 1 print copy and 1 CD of Mud Log & Engineering Log ✓/ 12. 1 print copy and 1 CD of Mud Loggers End of Well Report V 13. 1 print copy of Provisional Formation Tops ;-� 14. 1 hard copy of AOGCC Well Completion Report and Log 7 15. 1 CD copy of AOGCC Well Completion Report and Log Delivered by Date b S J / 03 Received by `1,11, Date 25 d 7 ice• --- =ate 0 a9 -oa9 rsts/ f 3 ( / /- • • W ... Drilling Project Transmittal s 2007 �� �esc.roe Alaska . To: State of Alaska May 3, 2007 Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 Attn: Steve Davies From: FEX L.P. RECEIVED 3601 C Street, Suite 370 MAY 0 3 2007 Anchorage, Alaska 99503 Alaska Oil & Gas Cons. Commission RE: Aklaq #6 Anchorage 1. Washed dried cuttings samples — 6 boxes depth range 100' to 7280'. \\" j Delivered by 4 . : GV r- Date S 3 d Received by ■41► d Date ' — Memo Date: 4/27/2007 To Tom Maunder AOGCC, Anchorage, AK 99501 907 - 793 -1250 Cc: Paul Mazzolini From: Michael Quick RE: Weekly Update for FEX Exploration Project — Aklaq #6, Permit #: 207- 009 CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 20 April 2007 TD: 7280'. Finish 7" casing cut. Install pack off assembly, lower BOP stack and nipple up. Pressure test pack off to 5000psi. Change back to 4" pipe rams. Pressure test BOPE per regulations. Make up 6 -1/8" bit and RIH. Abandon 9 -5/8" x 7" annulus by pumping 50 bbls of mud to establish injection rate (300 psi at 3 bbl /min), 48 bbls of 15.8 ppg Premium Class G (starting pressure 350 psi dropped to 30 psi at end), followed by 35 bbls of 10.7 ppg Permafrost Type L cement. 21 April 2007 TD: 7280'. Slip and cut drill line. Continue to RIH. Drill cementing stage tool, RIH and tag baffle plate at 6962', circulate bottoms up. POOH laying down DP. Rig up for cased hole wireline logging. 22 April 2007 TD: 7280'. Ran cased hole logs (STB, GR, RPM). Rig up and run 1380' of 3 -1/2" 9.2 #/ft tubing. Nipple down BOP stack. 23 April 2007 TD: 7280'. Clean and grease ram bodies in B OP stack. Nipple up production tree and test to 5000 psi. Pump 10 bbls of water and 600 bbls of diesel for freeze protect in 7 "x3 -1/2 ". Clean rig and mud pits. Rig released at 1600 hours on 4/23/2007. 24 April 2007 TD: 7280'. Rigging down. Lay down top drive, clean rig, prepare shop for move. Confidential Page 1 4/27/2007 • • 25 April 2007 TD: 7280'. Rigging down. Move shop to Cape Simpson and set up. Cleaning rig. 26 April 2007 TD: 7280'. Rigging down. Moved out all but 7 rig loads. Both camps still on location. Confidential Page 2 4/27/2007 Ir Coyer letter error • • Subject: Re: Cover letter error From Thomas Maunder <tom_maunder@a admin.state.ak.us> Date: Wed, 25 Apr 2007 14 :59 :14 -0800 To "Flynn, Tim " <Tim.Flynn@7u asrce .com> ©m -o0 Tim, Thanks for the message. You are correct, the name on the letter should be Aklaq #6. There is no issue here. I will make a correction on our copy and place this note in the file. Tom Maunder, PE AOGCC Flynn, Tim wrote, On 4/25/2007 2:55 PM: Tom Don't know if this is an issue or not, but the name of the well on the cover page is Aklaq #5. Our well we drilled was Aklaq #6. Let me know if we need to change anything on this end. The sundry is correct. Thank you Tim Flynn Project Drilling Engineer 3900 C ST Suite 602 Anchorage, AK 99503 Cell 907 317 5504 Office 907 771 -1929 1 of 1 4/25/2007 2:59 PM • • s E[F AsE[A 66 SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mel Knezevich Operations Manager FEX L.P 3601 C. Street, Suite 307 Anchorage, AK 99503 Re: Exploration, Aklaq # ill Sundry Number: 3(57 -138 Dear Mr. Knezevich: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, r 7 ►� o Chairm.. DATED this day of April, 2007 Encl. Qo m / RECEIVED • STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 0 2007 APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cons. Commission 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend Si Operational shutdown ❑ Perforate ❑ Waiver ❑A' "' age other ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program p Pull Tubing p Perforate New Pool p Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: FEX L.P. Development ❑ Exploratory 0 207 -009 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 3601 C Street, Suite 370 Anchorage, AK 99503 50- 279 -20019 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Aklaq #6 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): AA- 085517 16.2 Wildcat 12 . PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7280 7233 7050 7004 NA Casing Length Size MD TVD Burst Collapse • Structural Conductor 80' 16" 111' 111 1640 670 Surface 2072 9 5/8" 2072 2072 5750 3090 Intermediate 7050 7" 7050 7004 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA None Packers and SSSV Type: Packers and SSSV MD (ft): 13. Attachments: Description Summary of Proposal ❑ 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory El Development ❑ Service ❑ 15. Estimated Date for 4/21/2007 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ Plugged Abandoned ❑ � 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WI WDSPL ❑ Commission Representative: ��,� '��S" t�ck � cJ t l/ t ,0 18. I hereby certify that the foregoin• is true and correct to the best of my knowledge. Contact Printed Name s ; -: Title Operations Manager Signature ,/'���'- Phone 907 - 771 -1926 Date 4/20/2007 r/ n COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number: )�•- / 38 Plug Integrity 7.1 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance A Other: C.bcA L� +r�t.> C i � - , "\ Cfi�S\� �E S'T, "- 5:: - OC' 1�C' `A EL W\ ` ` ` 1 <.� \ tc S \N ©� Q `�, E c\cv1/4-- C 4 Subsequent Form Required: L \d RBDMS BFL APR 2 4 2007 APPROVED BY Approved by: Owl COMMISSIONER THE COMMISSION Date: 4-2.0- o lir Form 10 -403 Revised 06/2006 O 1. N , , Submit in Duplicate Re: Lower pipe rams BOP test • • Subject: Re: Louver pipe rams BOP test From Thomas E Maunder <tom maunder@a admin.state.ak.us> Date: Sat, 21 Apr 2007 08 :46:42 -0800 To: Doyon Arctic Wolf <dc yyonaw@to ism n- dc.com.> CC: Tim Flynn <Tim.1yan®asrcenergy. com >,Michael.Quickkasrcen rgy.com, pmazzolini 3talisman- energy.com, "Knezevich, Melt' <mknezevich a isman- energy.com >,aogccc pr dhoe bay@admin.state.akus Kim, *� r � Your message confirms our conversation. d ` Good luck with the operations. Tom Maunder, PE AOGCC Original Message From: Doyon Arctic Wolf <doyonaw@taiisman- dc.com> Date: Friday, April 20, 2007 8:36 pm Subject: Lower pipe rams BOP test To: 'Thomas Maunder' <tom maunder^admin.state.ak.us> Cc: Tim Flynn <Tim.fl nn@asrcener Y - -- - - -- _Y .. -- - -- -- gam.com >, Michael.Quick @asrcenergy.com, pmazzolini@talisman- energy.com, "Knezevich, Mel" <mknezevich @talisman- energy,con> Tom, As per our telephone discussion from 20:00 April 20, 2007 with yourself(Gregg Fischer and Kim Parenteau, FEX and Bob Lupton, Doyon Drilling) we are writing to document your "verbal approval" of our request for approval for a modified BOP pressure test procedure. This request is made because of issues encountered while attempting to pressure test our lower set of BOP rams. In summary, the issue is due to the fact that the 7" production casing was unable to reach TD due to hole problems and subsequently was set -230ft off bottom. The C -21 emergency casing slips were therefore required in lieu of the mandrel hanger as per program. Casing was subsequently cut off and the pack off assembly installed. The casing cut off appears to be hindering the landing of the upper test plug which is to shoulder on the upper load shoulder of the wellhead. This in turn means that we are unable to get low enough to get a seal on the pipe rams over the DP body. We have already tested the blind rams and hence tested the entire body to 5000 psi. We are requesting approval to test the lower pipe rams with a "drill out" BHA in the casing rather than test plug in the wellhead. We are planning a test to 3500 psi rather than 5000 psi as well. The plan will be to finish the accumulator function test and then run in 1 of 2 4/23/2007 7:03 AM Re: Lower pipe rams BOP test • • hole with a bit and DP to subsequently drill out stage tool. After this, a casing pressure test to 3500 psi for 30 minutes will be performed beforecoming out of the hole for a cased hole logging followed by the running of the 3 -1/2" kill string and nipple up of the FMC production tree with back pressure valve. Please respond via email as indicated per our conversation Kim Parenteau I I 2 of 2 4/23/2007 7:03 AM • • F E X FEX L.P. 3601 C STREET, SUITE 370 ANCHORAGE, ALASKA 99503 TEL (907) 644 -4429 FAX (907) 644 -4892 April 20, 2007 RECEMY APR 2, Alaska Oil and Gas Conservation Commission Alaska Oil 333 West 7 Avenue, Suite 100 ; Anchorage, AK 99501 bra* Dear Sir: RE: Sundry to Suspend Well: FEX L.P. Aklaq #6, AOGCC permit 207 -009 FEX L.P. hereby applies for a Sundry approval to suspend this well, Aklaq #6. The AOGCC is requested to keep confidential all information included in the Application, as information in these documents is drawn from research and data proprietary to FEX L.P. Please see the attached form 10 -403 and other pertinent information attached to this application as follows: 1. Form 10 -403 Application for Sundry Approvals 2. Plan to suspend well If you have any questions or require additional information, please contact me at 907- 771 -1926. Sincerely, FEX L.P. Melville Knezevich Operati ' snager / a Delaware Limited Partnership with Registered Office c/o CT Corporation 1209 Orange Street, Wilmington, DE, 19801 • FEX L.P. Aklaq #6 API # 50- 279 - 20019 -00 AOGCC Permit 207 -009 Confidential April 20, 2007 Current Status: The Aklaq #6 well in the NPRA was spudded on 3/27/07 and reached TD on 4/14/07. After drilling to 7280'md, 7" casing was run to 7050'md. Due to tight hole conditions the casing was cemented off bottom. A two stage cement job was performed with the first stage pumping 23 bbls of premium cement below the stage tool at 6386. The stage tool was successfully opened and minimal circulation was done to minimize losses. The second stage pumped 60 bbls of premium cement with calculated TOC of 3730 feet based on limited returns to surface. The basis for suspending the well is based on the following: 1. Further evaluation is required to determine whether the hydrocarbons encountered are of sufficient quantity to be productive in paying quantities. Further evaluation may include an extended flow test that was not possible this season due to time constraints. Other zones may also be tested. 2. The well is a candidate for redrilling. The well may be drilled to a deeper TD, or the current wellbore may be sidetracked in a subsequent season. This drilling rig, Arctic Wolf, will be demobilized immediately for summer storage at Cape Simpson, and current plans are to return to the area next exploration season. Current Well Conditions: Surface Casing: 9 -5/8" 40 #/ft L -80, Cemented in place from surface 2072'md. Intermediate Casing: 7" 26 #/ft L -80, cemented at 7280' with (23 bbls) of 15.8 ppg Premium Class G cement below the stage tool (6386'md) and 60 bbls of 12.5 ppg Microlite Class G cement above the stage tool. There is an 88' shoe track that has yet to be drilled. Production Hole: 8 1/2" open hole from 7050' to 7280'md, due to inability to run casing to TD. szA r.\- L1 6 1 Confidential 4/20/2007 • Plan Forward: 1. Rig up Halliburton cement lines to the 9 5/8" annulus wing valves and test to 4000 psi. Establish breakdown pressure and rates with water or mud before pumping cement. Record pressures. 2. Mix and pump cement per the final program with 44 bbls of 15.8 ppg class G cement followed by 28 bbls of 10.7 ppg Permafrost Type L. TOC will be surface and approximate slurry volume will be 72 bbls. Confirm all the cement and displacement volumes with any data as indicated by caliper logs and as- drilled hole configuration. Displace cement with just enough water to clean out lines 3. RIH with drill pipe to 1700' pressure test casing to 3000 psi for 30 minutes. 4. Spot diesel from 1500- surface ' (66 bbl). 5. RIH to 1350'md with 9.2 # /ft, 3 1/2" kill string 6. Nipple down stack, Nipple up FMC production tree 7. Test tree to 5000 psi for 10 minutes 2 Confidential 4/20/2007 • • Memo Date: 4/20/2007 To Tom Maunder AOGCC, Anchorage, AK 99501 907 - 793 -1250 Cc: Paul Mazzolini From: Michael Quick RE Weekly Update for FEX Exploration Project — Aklaq #6, Permit #: 207- 009 CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 13 April 2007 TD: 7163'; MW: 9.9; Viscosity: 55. POOH with core barrel. 0' Lost 22 bbls of mud on trip out. Lay down core. P/U motor and LWD tools, RIH. 14 April 2007 TD: 7280'; MW: 10.0; Viscosity: 57. RIH to 7110, ream to 117' bottom. Drill to 7280'. POOH mad passing LWD tools over required sections. 15 April 2007 TD: 7280'; MW: 10.1; Viscosity: 53. Continue to POOH, back 0' ream from 7300' to 6780', 3748' to 3400', tight spots 3750', 3680', 3571', 3447', back ream from 3400' to 2590'. POOH, L/D BHA, download LWD. 16 April 2007 TD: 7280'; MW: 10.1; Viscosity: 62. M/U slick clean out BHA and RIH. Ream from 3300' to 3330', 6803' to 6962' — well took 165 bbls of mud. Ream from 6962' to 7280', flow check, could not POOH without pumping. Back ream from 7280' to 7127', pump out from 7127' to 6423', POOH. 17 April 2007 TD: 7280'; MW: 9.9; Viscosity: 55. POOH to BHA, L/D HWDP. Install 7" casing rams and test to 1500 psi. Rig up Tesco casing running tool, M/U shoe track and RIH with a loss rate of 19 bbl/hr. Break circulation at 3638', losses at 90 bbl/hr at 115 gpm. Run Casing to 4165' Confidential Page 1 4/20/2007 • • 18 April 2007 TD: 7280'; MW: 9.8; Viscosity: 53. Run 7" casing to 7041' with mud losses at 19 bbl/hr. Hit bridge at 7037', work pipe up and down but could not rotate. Break circulation with 20% returns to surface. Work pipe down to 7050' in 12 hours. Rig up cement head 35' off floor. 19 April 2007 TD: 7280'; MW: 9.8; Viscosity: 53. Circulate hole and circulate out 4200 units of gas. Rig up cementers, test lines to 3500 psi, pump 5 bbls water, 20 bbls of spacer, pump 1 stage of cement, p �p P � p ,P p g 23 bbls of 15.8 ppg Premium Class G, 5 bbls of water, 266 bbls of mud. Bump plug and pressure to 3200 psi to open stage tool. Circulate through stage tool with no returns. WOC for 8 hours. Prepare to pump 2 stage of cement, circulate casing with 100% losses. Pump 10 bbls of water, 20 bbls of spacer, 60 bbls of 15.8 ppg Premium Class G cement, 5 bbls of water and 240 bbls of mud.. Bump plug and pressure up to 1755 psi to close cementing tool. Incurred total losses for the first 75 bbls pumped, then had 30% returns from the remainder of the job. Rig down cementers. Lift BOP stack, set manual casing slips, install cold cutter and cut 7" in preparation for installing pack off assembly. Confidential Page 2 4/20/2007 RE: Aklaq #6 Sundry to Suspend 410 411 Subject: RE: Aklaq #6 Sundry to Suspend From: "Flynn, Tim" <Tim.Flynn a@asrcenergy.com> Date: Fri, 20 Apr 2007 16 :56:43 -0800 To: Thomas Marauder <tc m maunder@admin.state.ak.us>, Quick, Michael 7." <Michael.Quick a asrcener com >, Paul Mazzolini <PM ZOLIl\TI a talisman -ever y.com > CC: mknezevich@a talisman- encrgy.com, doyonaw@talisman-dc.com Thank you Tom Tim Flynn ryt� \.J — „0/C \ Project Drilling Engineer q ` 3900 C ST Suite 602 Anchorage, AK 99503 Cell 907 317 5504 Office 907 771 -1929 Original Message From: Thomas Maunder [rnailto :tom maunder-- @admi Sent: Friday, April 20, 2007 4:55 PM To: Flynn, Tim; Quick, Michael J.; Paul Mazzolini Subject: Aklaq #6 Sundry to Suspend All, We have completed our review of the sundry to suspend Aklaq #6. I have been advised by Commissioner Seamount that by copy of this message you have "verbal" approval to proceed. Contact the Inspector with regard to witnessing the pressure test of the wellbore. If the Inspector is unable to witness, the pressure test should be charted. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 4/23/2007 7:03 AM • • Memo Date: 4/13/2007 To: Tom Maunder AOGCC, Anchorage, AK 99501 907 - 793 -1250 Cc: Paul Mazzolini From: Michael Quick RE: Weekly Update for FEX Exploration Project — Aklaq #6, Permit #: 207- 009 CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 6 April 2007 TD: 5285'; Mud Weight: 9.6; Viscosity: 53. Drill to 5285', 999' sliding a total of 215' to bring hole to vertical. 7 April 2007 TD: 6033'; Mud Weight: 10.0; Viscosity: 52. Drill to 5534', 748' wiper trip to 3900', hole slick, RIH , 5' of fill on bottom. Drill to 6033'. 8 April 2007 TD: 6782'; Mud Weight: 10.0; Viscosity: 50. Drill to 6529', 749' well took 75 bbls of mud at 6490', with 1700 units of gas, well flowing. Shut in to verify wellbore breathing — 0 psi SICP and 0 psi SIDPP. Drill to 6554' losing mud at 170 bbl /hr. Drill to 6782', mud losses slowed to 30 bbl/hr. Total mud loss 728 bbl. 9 April 2007 TD: 7125'; Mud Weight: 10.0; Viscosity: 57. Drill to 7125'. 343' Circulate and condition mud, monitor well. Wiper trip to 5500', RIH, ream to bottom. Pull 5 stands, pump 30 bbl slug, monitor well — static. POOH. 10 April 2007 TD: 7125'; MW: 10.0; Viscosity: 57. POOH with no tight 0' spots. Flow check at shoe — static. POOH, clean clay off BHA. Down load LWD tools, lay down MWD, DC's and mud motor. Cut and slip drill line. Start BOPE pressure test per regulations — test witness waived by Jim Regg, AOGCC. Confidential Page 1 4/13/2007 • 11 April 2007 TD: 7125'; MW: 10.0; Viscosity: 58. Complete BOPE pressure 0' test. P/U core barrels, RIH to 2065', circulate bottoms up. RIH, was in at 6532' to work tight spot, lost returns. Pump 50 bbl LCM pill, regained partial returns. Pump 50 bbl LCM pill, work pipe. Pump in hole to 7025', wash to 7045'. 12 April 2007 TD: 7163'; MW: 9.6; Viscosity: 52. Wash to bottom fighting 0' losses, pump two 50 bbl LCM pills. Core to 7153', lost total returns. Regain circulation, core to 7163'. Lost a total of 1120 bbls of mud in the past 24 hours. Condition mud and POOH. Confidential Page 2 4/13/2007 Aklaq #6 cellar gas - 207 -009 • Subject: Aklaq #6 cellar gas - 207 -009 From: "Quick, Michael V' <Michael.Quick> asrcenergy.carn> Date: Wed, 11 Apr 2007 14:36:55 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: pmazzolini®talisman- energy.com Tom — Per our phone conversation, similar to last year at Aklaq #2, there has been a small amount of gas percolating between the conductor and the 9 5/8" casing at Aklaq 6. We have been on the well for approximately 12 days and the gas has just begun to show up in the cellar. We believe this gas is caused by the heating effect of circulating the warm mud during drilling operations which has created a thaw bulb in the proximity of the wellbore. Once the drilling operation halted and the bit was tripped out of the hole the gas migration was significantly reduced. The result of our gas sampling is 100% C1. There is no liquid associated with the gas percolating. The surface casing shoe (9 -5/8 ") is at 2082', and held a FIT at 16 ppg. While drilling the surface hole to 2102', no hydrocarbons were encountered. The levels that are being recorded on the gas sniffers are not at combustible levels. Gas monitors in the cellar have been set up and are being monitored on a continual basis for increase levels. Based on last years levels at Aklaq #2, which are similar to this years, we are venting the cellar to the outside of the substructure to minimize the chance for any gas accumulation. Our forward plan is to drill ahead to TD and rig down. Regards, Michael Quick FEX Drilling Engineering Team Lead 907 - 771 -1928 1 of 1 4/16/2007 4:10 PM [Fwd: FEX Aklaq 6 shut in] • i Subject: [Fwd: FEX Aklaq 6 shut in} From: Jeff Jones <jeffjones a@adInin.state.ak.us> Alit p/ Date: Mon, 09 Apr 2007 12:30:28 -0800 'Cw To: James Regg <jim reggga adminsta#e.ak.us CC: Tom Maunder <torn r ,tau der@adiniri.state ak..us Hi Jim, in routine conversation yesterday Ernie mentioned offhandedly that they had shut in the well the day before for "breathing ". I informed him that FEX is required to notify us as soon as possible when the BOPE is used for well control. Thanks, Jeff Content -Type: message /rfc822 FEX Aklaq 6 shut in Content - Encoding: 7bit 1 of 1 4/9/2007 12:45 PM FEX Aklaq 6 shut in . . Subject: FEX Aklaq 6 shut in From: Doyon Arctic Wolf <doyonarw@talisman- dc.com> Date: Sun, 08 Apr 2007 22:05:00 -0800 To: jeffjones@adminin.state.ak,us CC: "Knezevich, Mel" <In z vich@talisrnan- energy:coln? Jeff: At 14:00 hrs. 4/8/07 - Well took 75bb1 fluid @ 6490' / 1700 units gas @ 6430' / background @ 400 units / 6529' well flowing on connection / shut in well & verify well breathing (0 sicp & 0 sidpp) / blow down manifold w/ air & continue drilling. Shut in well with annular thru open H.C.R. Thanks Ernie Natte. Drillin 9 Supervisor. ervisor. 771 -0536 FEX Aklaq 6 shut in 1 of 1 4/9/2007 12:45 PM 1 Memo Date: 4/6/2007 To: Tom Maunder AOGCC, Anchorage, AK 99501 907 - 793 -1250 Cc: Paul Mazzolini From: Michael Quick RE Weekly Update for FEX Exploration Project — Aklaq #6, Permit #: 207- 009 CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 30 March 2007 TD: 2101'; Mud Weight: 10.2; Viscosity: 51. Short trip, tight 0' spots at 1477' to 1296', and 1172' to 1044'. POOH, download LWD, rig up casing tools, run 9 -5/8" casing to 1700'. 31 March 2007 TD: 2101'; Mud Weight: 10.0; Viscosity: 46. Finish RIH with 9 -5/8" to 2072', circulate hole clean, rig down casing tools. RIH with 4" DP for inner string cement job. Sting into cement retainer, rig up cement head. Pump 5 bbl water, 20 bbl spacer, 136 bbl (184 sx) 10.7 ppg Type L Permafrost cement lead, and 38 bbl (187 sx) 15.8 ppg Class G cement tail. Bumped plug, floats held. 40 bbls of good cement returns at surface. POOH with inner string. Nipple down diverter. 1 April 2007 TD: 2101'. Continue nippling down diverter, Nipple up FMC head and test to 1000 psi for 10 minutes. Nipple up BOP stack. Test BOPE per regulations. Test witnesses by Bob Noble — AOGCC, waived by BLM. 2 April 2007 TD: 2101'. Complete BOPE test. Pick up and rabbit DP while RIH, test casing to 2600 psi for 10 minutes. POOH with DP, P/U BHA. 3 April 2007 TD: 2602'; Mud Weight: 9.5; Viscosity: 52. M/U MWD/LWD 501' tools, load tools and test. RIH, drill out 7" float, cement and shoe to 2102'. FIT to 700 psi at surface, held at 16.1 ppg EMW. Drill ahead to 2602', sliding occasionally to bring hole back to vertical. Confidential Page 1 4/6/2007 • • 4 April 2007 TD: 3662'; Mud Weight: 9.6; Viscosity: 51. Drill ahead to 1060' 3662', sliding a total of 634' to bring hole back to vertical. 5 April 2007 TD: 4286'; Mud Weight: 9.6; Viscosity: 49. Drill to 3912', 624' circulate hole clean, short trip to casing shoe at 2072', flow check. RIH, 8' of fill on bottom. Drill to 4286'. Confidential Page 2 4/6/2007 Re: FIT at Aklaq #6 - 207 -009 • • Subject: Re: FIT at Aklaq #6 - 207 -009 From: Thomas Maunder <tom_maunder @admin.state.ak.us> Date: Wed, 04 Apr 2007 15:02:50 -0800 To: "Quick, Michael J." <Michael.Quick@asrcenergy.com> CC: Tim Flynn <Tim Flynn @ASRCennerg .com> Interesting plot, there appear to be 4 separate sections on the curve with "breaks" at 275, 525 and 600 psi. It is indicated that 3.25 bbls were pumped. Is it true that there was no fluid bled back? The pressure does hold steady after pumping was stopped. Look forward to your reply. Tom Maunder, PE AOGCC Quick, Michael J. wrote, On 4/4/2007 2:51 PM: Hello Tom — Per our conversation, the FIT at the 9 -5/8" surface casing shoe on Aklaq #6 was conducted 31 feet below the casing shoe, but only 1 foot of new formation was drilled. The FIT held a 16.1 ppg EMW at 2102' (see attached chart). For reference, our closest well at 14 miles, Aklaq #2's FIT was a 17.0 ppg EMW, and Aklaqyaaq #1's FIT was 14.6 EMW at 26 miles away. This well does not have abnormal pressure based on both our seismic pore pressure prediction and local offset knowledge, and our maximum planned mud weight is 11.2 ppg only for wellbore stability if the Miluveach shale is present. If the Miluveach shale is not present, maximum mud weight will be 9.6 ppg. Please let me know if you have any questions on this matter. Best regards, Michael Quick FEX Drilling Engineering Team Lead 907 - 771 -1928 I I 1 of 1 4/16/2007 4:10 PM LEAK - OFF TEST Well Name & No. Akaq #6 Date: 4/4/2007 CASING: Size: 9 518" Weight: 40# Grade: L -80 Shoe Depth: 2072 Well Depth: 2103 Surface Applied Pressure: 700 Casing Burst: 5,750 psi Mud Weight: 9.6 E.M.W.= Surface Applied Press + M.W. = 16.1 Hydrostatic Pressure At Shoe 1034 Shoe Depth x 0.052 Gradient Of Well Fluid 185 Total Leak Off Press At Shoe 1734 - -- - Leak Off Press Gradient 0.84 Applied Surface Pressure Projected Depth 7262 Depth of Previous Casing 80 Max. BHP Gradient Expected 9.8 • Zone And Depth Encountered All aoo Max Weight of drilling fluid to be used when penetrating Zone 11.2 700 bbls press 0 0 600 0.25 75 11 5 Pump 0.5 190 At --, 0.75 275 $ ' 500 i 1/4 1 325 SO - - -- - Barrel 1.25 385 (o Per 1.5 425 `r 0 0 400 Minute 1.75 485 cv0 '7' 2 525 40 a (1/4 bbl = 3 SPM) 2.25 550 a 300 2.5 575 ----., 2.75 600 .S 3 650 6.3 200 3.25 700 S' 1 min 700 Shut 2 min 700 100 In 3 min 700 Time 4 min 700 Until 5 min 700 0 ' ' i i i { 1 i i ' Stablilized 6 min 700 I 0.25 0.5 0.75 1 1.25 1.5 1.75 2 2.25 2.5 2.75 3 3.25 1 min 2 min 3 min 4 min 5 min 6 min Volume Pumped Volume Bled Back (bbls) : 0.0 bbls Shut In Time • Memo Date: 3/30/2007 To: Tom Maunder AOGCC, Anchorage, AK 99501 907 - 793 -1250 Cc: Paul Mazzolini From: Michael Quick RE: Weekly Update for FEX Exploration Project — Aklaq #6, Permit #: 207- 009 CONFIDENTIAL Date and Footage Drilled as of 24:00 hours. Activity 27 March 2007 TD: 400'; Mud Weight: 10; Viscosity: 51. Diverter test witness 302' waived by AOGCC inspector Lou Gramaldi. Spud well at 13:30, drill 12 -1/4" hole to 342', POOH to P/U BHA #2 with LWD/MWD tools. Drill to 400'. 28 March 2007 TD: 1540'; Mud Weight: 10; Viscosity: 45. Drill to 1540'. 1140' 29 March 2007 TD: 2101'; Mud Weight: 10.3; Viscosity: 46. Drill to 2101', 561' Circulate hole clean. Short trip to 1000' Confidential Page 1 3/30/2007 Aklaq #6 • • Subject: Aklaq #6 From: "Quick, Michael J." <Michael.Quick @asrcenergy.com> Date: Fri, 23 Feb 2007 14:00:49 -0900 To: Thomas Maunder <tom - m,aumder @admin.state.ak.us> CC: "Mazzolini, Paul" <PMAZZOLINI atalisman- energy com >, "Volk, Scotty" <SVolk@talisman- ennergy.com >, "Flynn, Tim" <Tim.F1ynn @asreenergy.com> Tom — Scotty is on time off in Calgary, and Tim has been on the slope for a couple weeks. 1. On the 401, it appears 7638' was not changed to the new prog total depth of 7713'. I believe we submitted a new 401 a week or two ago. 2. a) the 0.11 gradient is a carry over from previous work submitted prior to the new 0.1 gas gradient regulation. We can correct and resubmit this page if necessary. b) we have found through local experience and the pore pressure work verifies that the formations are underpressured. 3. We calculated both the MASP with and without the last casing shoe failure, and used the higher MASP to prove the BOP pressure rating is sufficient. It looks like 2300# was placed in the text instead of the MASP for the formation pressure of 3092# for below the 9 -5/8" surface casing MASP. Both values are under the 5000# BOP rating. 4. We are set up for both cementing options. We do have a cementing tool on site to place in the string, should hole conditions dictate the need for a two stage job. If the hole is not having any issues, and "standard" single stage cement job with appropriate lead and tail slurries will be used. 5. Yes, the 5" contingency volume is short. The calculations were not redone when the TD was deepened. ``' The correct volume is 17 bbl (82 sacks). I can bring an updated cementing prog with the 401. 6. VBR's will not be utilized. We will have 7" and 5" casing rams, and any necessary tubing rams on location. Please give me a call if you want to discuss any of these in more detail. Thanks, Mike From: Mazzolini, Paul [mailto:PMAZZOLINI @talisman - energy.com] Sent: Thursday, February 22, 2007 9:12 AM To: Quick, Michael J. Subject: FW: Aklaq #6 Mike, Can you help with this to keep APD process moving forward. Thanks, Paul From: Thomas Maunder [ mailto :tom_maunder @admin.state.ak.us] Sent: Thursday, February 22, 2007 9:03 AM To: Volk, Scotty Cc: Flynn, Tim; Mazzolini, Paul Subject: Re: Aklaq #6 1 of 2 2/23/2007 2:19 PM Aklaq #6 • . Scott, I'd don't seem to have your phone numbers. I tried to call Tim and his message said he is out until "the 7th ". I presume March 7. Could you look into these questions? I'd like to get the permit moving forward and can't without your reply. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 2/14/2007 12:19 PM: Tim, I am reviewing Aklaq #6 and have some questions, in no particular order. 1. On the 407, the 7" casing depth (7638') does not agree with the depth for the long string scenario (7713') or the contingency scenario (7012'). Would you please reconcile? 2. On the "Operational Considerations" page ... a. A gas gradient of 0.1 psi /ft is specified in the regulations for calculating MASP. Although the 0.11 gradient you use is not much different. Using the 0.1 factor gives a MASP of 3170 psi. b. Although the 7.71 EMW value used as the maximum expected formation pressure in the surface hole is based on the pore pressure analysis, it is interesting that a sub - normal value is used. It would seem that a water gradient would be appropriate. 3. Where MASP is calculated, experiencing a fracture at the last casing shoe during potential well control operations is used to limit the calculation. While it may be operationally valid to consider shoe fracture, the regulations do not consider this event. The value determined using a 0.1 psi /ft gradient helps determine the required BOP pressure rating. 4. Is your 7" cement job planned as a single stage (lead and tail) or a true 2 -stage operation using a cementing tool in the string? 5. The cement volume planned for the 5" liner appears "short". I calculate a gauge volume of about 11 bbls using the depth, hole size, liner size and lengths given. Would you please confirm the liner cement volume. 6. Various tubular sizes will be run into the well after surface casing is set and the BOP installed. There is no mention in the procedural text regarding the necessary ram sizes. Could you provide some information as to what ram sizes are available? Will VBRs be employed? Thanks in advance for your reply. Call or message with any questions. Tom Maunder, PE AOGCC 2 of 2 2/23/2007 2:19 PM • • pTp 207- oo q SARAH PALIN, GOVERNOR �T ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ap ril 5, 2007 Lydia Miner Environmental Program Manager Department of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 -2617 Re: Response Planning Standard Volume For FEX L.P.'s Aldaq #6 Exploration Well in the National Petroleum Reserve — Alaska Dear Ms. Miner, On March 22, 2007, FEX L.P. gave a technical presentation to members of the senior staff of the Alaska Oil and Gas Conservation Commission ( "AOGCC ") related to the Response Planning Standard ( "RPS ") rate for the above referenced well. At the conclusion of this meeting they requested that the AOGCC provide a revised RPS rate to the Alaska Department of Environmental Conservation. Based on the information provided by FEX L.P. and information contained in our files, both publicly available and confidential data, for other wells in and around the National Petroleum Reserve — Alaska the AOGCC has conducted a thorough review of the maximum flow potential from the proposed well. Using a reasonable set of rock and fluid property assumptions for a worst -case scenario the maximum potential un- stimulated flow rate of this well was determined to be 2,000 barrels per day. If you have any questions, please contact me at 793 -1232. Sincer- David S. Ro y Reservoir Engineer Alaska Oil and Gas Conservation Commission cc: Paul Mazzolini Manager Drilling and Completions, Alaska FEX L.P. Richard Garrard Geoscience Manager FEX L.P. 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F1 0 LP GO rl;\ LP 611 Y l 4 ,! r!`0_ } Cell 2( :am \1411 1\1102 1,014 1140 F'EX Ll' 611 f 6• c -./:2('. , y d c PehaC an 010 V1 40 Peh'a( mad1 40 . � , ° p ° ° Petro-ianwda • * . , 0 2 4 8 12 : dam " - rt. .r ; I - Miles 11111'6 FIA11'60�i V � 1 . ! ;' R 1'etl �( ` 1 FS L P (rll 1 ° 1 !aria 1140 Fetlo-( anada 1140 r� ,,d y �*. _ P 41 40 7� ,y a 6 - .4 rirs1�� e.- —•,,, ' 'S. t+ * ,a - .» a *_• Alaska NPR -A• F E Stratigraphic Targets ..._....... Confidential } — , 2007 Drill program x Discovered Macken i• W a ilso IS • Fields =Mk Aklakyaaq 1 I Aklaq 6 ul F— Aklaq 2 Badami ( Amaguq 2 Polaris, West Sak a� hem , Orion Tarn, Tabasco'5Z 14 Muds \o o �\OQ G Wa w o S hale " • Nanushu k H Nan Torok Torok Kuparuk, Pt. McIntyre • Torok ✓ - Palm, Pt. Thomson t� .av�i UP er o t t e - K u p "C" • Kup C Alpine, Fiord * Kup A & B U V ! I (7 '• Alpine • Alpine Q UPPER cA r Kugrua D / Nuiqs . - wN • K ugrua 0 Kugrua Prudhoe Bay,_!. Simpson —0— Milne Pt. 1�( Lower Kinga' - a rrow in Q Sag River • F Prudhoe Bay, Northstar,' Shublik — z- Sag Delta North c _- -J • Ivishak Q Eileen ■ Ivishak • Echooka cc Kavik�� � c ___—___ Lu Lisburne * EchoQka ` 9) �� o Endicott, ._._ m Liberty �� cL Q Hunt F ork Kanayut z Q 2006 Drill Z Producing Fields """"" ^� O c w Oil source rock O Frank!: loan Gas source rock Doyon /Akita Arctic Wolf F E X Operating at Amaguq #2 Feb. 2007 -.....rompow MIN* - 11 . 11110. -- Confidential 0 IF 9{ • 1 l . M'1 #'� ` ef ..., ' - „' t� �91if ti1AS09 4 . �1° s r' I # 1 "_ risionan. €. r- r . , is 1 Aklaq #6• • F E X NE-SW Geo-Seismic Line Confidential Proposed Aklaq #6 sw NE Permafrost ., ''' .4111adglaitiorm _ 0.2.50 • Nanushuk , -‘ - .. ..„; - -- .... ,,5.,),0 - , Predicted _ ,....„,„... _ _ ------""------.... Nanushuk sst. .....,,......, ....„ 5,; ..,... -.... --.........., , ,--....... ..... ....., . . • - 40 . -. ,.... ' s TOr0 • Predicted Torok channel ssts. _.1.,,,0 --- .........„,. Kugrua sst „ ' - *OW ''....howoo, Predicted Torok fan ssts. _1 250 ' . ...... ...4. HRZ . Miluveach .. . . V. _ .. .._ , —....--- 1,500 , - J2 mkr. ....._ Aklaq #6: Well Prognosis F E X ,,. Confidential Age Stage Formation Lith Potential Targets & Hazarc s Discription —1000 - Base Permafrost @ -1250 ft 1250' - 1325' _ _ - —1500- Nanusnukcp @ -13z5n Interbedded sandstone, siltstone and claystone with some coal and marlstone - - - beds. Coal is mostly likely to be high grade lignite or low sub - bituminous. OP Sandstone is friable, well sorted. Siltstone and claystone are soft with low to moderate cohesion. There may be rare small gas kicks max. 200units over Nanushu c - —2000 - —2500 - - Nanushuk topset sandstones @ -2714ft Interbedded sandstone and siltstone. Sandstone is friable and well sorted. There is a probability of gas charged sands approx. 1500 units over —3000- background. _— Nanushuk topset sandstones @ -3412 ft to - = -3500- Secondary target D 3578' N Cenoman an _____ ______ U to - - Albian _-_-_ _ -_ _ N Torok ________ ___ -4500 Medium to dark grey carbonaceous shales, some light to medium gray U Torok channel sandstones @ -4713 ft claystones. Siltstones present throughout the formation. Sandstone intervals • • - - :: -_ Primary target expected to be more abundant and thicker in the lower part of the formation. —5000 Sands expected to be fair to well sorted, sub - angular to angular, carbonaceous _ -_ -_ -_ and silty. Expect poor porosity, with some fluorescence, shows (up to 1500 ?? 1111, units over background), and possibly hydrocarbon charged. -- - -- - - : - H - : - 5500 - _ _ . Torok fan sandstones @ -5736 ft - - - - - - Primary target Berriasia - - - - - _ - : - H - = - 6000 - to = • Hauterivi n - - = — 6500 - BCU -- -_---------- upr. Kingak Shale and claystone, non - fissile, soft shale, possible small amounts of Tithonian/ = = =X7000 K ugrua sandstones @ -7012 ft siderite o 5 Oxfordian _ - - _ _ - Secondary target V. Fine grained sandstone interval consisting of sub - angular grains, poor poro- - -- - -- - - Middle Kingak perm and possibly hydrocarbon charged, expect sample fluorescence. _ -_ -- -__ _ -7500= — T13■ 763$ i Kingak Fm TD@ 7638' Shale and siltstone. Brittle to firm shale, may have a dusk red color - —8000- F E X Aklaq #6: Key Offset Wells Confidential Kuyanak dank ��--" i . '' '.' (1 i if" 71 BAIIIIR q . . do" 4. • ,....4., 1 ...,,,_ • S Simpson . 4PrAip. - Aklaq #6 _./1.111/1 Oa • • Puviaq - - - .,,,,, ' ®" klaab • J= \ Topagoruk Aklaq #2 - • o k�aq # 2 � ,al coverage .. R i - - Akk1- . #1 -. �`� .a' .q -. Jpiem Al 14 111k . _1411111‘11 i 4 ' ' ii4 , ....,:r.'M '''.' . - E. Ikpikpuk .._____ , ,.. .,:. , ,: , t, , , ,,,,, :::, ,:: ME , „, .. 11 Amaguq #2 L .Alik t,,,;k,..-,.-„ ',--.s.::.::::4,1.AK.7..,-Itr,e:Ste7:;4,-:;,,-i • y i p z , �s v� F E Aklaq #6: 1st Primary Objective Confidential Torok (Albian) Turbidites Regional Reservoir Data: • Aklaq #2 (2006) RSWC's 5120' — 6692' (43) + MDT Suspended but not tested • E. Simpson #2 (1980) Conventional Core #2 6056' -6086' Cut 30', Rec. 27.5' • No test • Nanuk Field Analog (2000) Basin floor fan Commenced production 12/2006 Released information by AOGCC Reservoir Quality: Torok Turbidites F E X Aklaq 2 Confidential 10.00 A • 13 A E 1.00 • ♦ Torok 1 • O Kugrua -F .Q Ai ♦ *® ♦ Kugura-S CU ♦ • 0 • Kugrua -P E " 0.10 Nr:r, • e> [ ❑ ❑ a ' AA. „pc) o no oo o 1 o L 4pAir • t> ®' ❑ 0.01 L- to 0 5 10 15 20 25 Porosity ( %) - AKLAQ Northwest N P R A #2 F E X Brookian Reservoir Potential Confidential Lower Nanushuk Sst. 2585' - 2601' (16') Log 018 -25% (40' >12% log) • Middle Torok Sst. 5120' -5142 (20' >12% log 0) Sst #6: RSWC 014.1 - 15.6% Perm. AV. 2.43 MD Lower Torok Ssts. Sst #5: 5822' -5892' (38' >12% log 0) RSWC 012.7 -14.7% Perm Av. 0.44 MD Sst #4: 6160' -6224' (30' >12% log 0) RSWC 07.0 - 14.5% Perm Av. 0.17MD Northwest NPR -A: Aklaq #2 F E X Brookian Reservoir Potential Confidential Lower Torok Ssts - cont. Sst #3: 6274' -6304' (22'>12% log 0) • RSWC 0 11.5 — 13.2% Perm Av. 0.19 MD Sst #2: 6480' -6550' (30' >12% log 0) RSWC 07.1 — 13.4% Perm Av. 0.17MD Sst #1: 6642' -6692' (38'>12% log 0) RSWC 0 9.6 — 12.6% Perm Av. 0.14M D Total Torok: 178' East Simpson #2 F E Torok Turbidite Core Confidential East Simpson 2 well Torok Formation Depth Range: 6,057 to 6,083 ft National Petroleum Reserve-Alaska • I iLl - lip - 2 Cu • E Cu Cu — - a.) .10 • p • % in e o - •11 • • • 0 0.01 10 20 30 40 Porosity (percent) Nanuk #2: March 19-24 F E X Torok Reservoir Only Confidential Inflow Performance Relationship IPR NOneq #2 Nanuq formation only Test Data Flowing Oil Water Total Pressure Rate Rate Rate Reservoir Pressure (PR) 2732.0 psi • Bubble Point Pressure (Pa 2732.0 psi psi bbl/d bblld bbl/d Test Pressure (Pwt) 1800.0 psi 0.0 1023.1 2547.3 3570.5 Oil Test Rate (q 5330 bbVd 200.0 1003.8 2360.8 3364.6 Water Test Rate (q 869 0 bbl/d 400.0 975.6 21744 3150.0 Results 600.0 938.7 1987 9 2926.6 800 0 893.0 1801 4 2694.4 Maximum Oil Rate 1023.1 bbl/d 1000.0 838.6 16149 2453.5 Maximim Water Rate 2547.3 bbl/d 1200.0 775.3 14284 2203.8 Maximum Total Rate 3570.5 bbVd 1400.0 703.3 12420 1945.3 1600.0 622.6 1055 5 1678.0 Note' Test Point 1800.0` 533.0 869 0 1402.0 Stimulated after f ra c Oil IPR Bubble baseed on Vogel's Equation 2000.0 00.0 32 1 327.6 496.0 823 6 case a t skin = -5 (Quadratic Curve Factor -0 2400.0 211.7 309.6 521.3 xanuq #z Liquid IPR 1 IPR 2800 RW.01001.001100, Oil Rate A OH Test Rate - Water Rate Water Teat Rate Total Rate 2400 2200 � \ 2000 � \ 1800 € 1600 \\ taco 1200 s 1000 800 • 800 400 200 0 500 1000 1500 2000 2600 9000 9500 Rate. Ob80 ra g avirnet92�� Yarn r6 "a c r<er.we�awrnw � a n moor Nanuk #2: March 19 -24, 2000 F E X Torok Reservoir Only confidential Summary of Results: 1. Maximum flow rate of oil for a drilling case 0 • 383 bopd • Actual flow rate at surface will be less due to flowing friction. • GOR = 575 scf /bbl • Uncontrolled release rate for spill planning is 2000 bopd which equates to a safety factor of 5.2 2. Basis for calculations is from Nanuk #2 after frac well test in the Nanuq formation. Flow rates and pressures are taken from well completion • records. Nanuk #2: March 19 -24, 2000 F E X Torok Reservoir Only Confidential IPR inputs: 1. Flowing BHP = 1800 psi • 2. Oil rate = 533 bopd 3. Water rate = 869 bwpd 4. Total rate = 1402 bfpd 5. Reservoir pressure = 2732 psi IPR After Frac Results with skin = -5 1. Max oil rate at sandface = 1023 bopd 2. Flow improvement = 2.67 IPR Drilling case of skin = 0 1. Max oil rate at sandface = 383 bopd 2. Flow damage = 1/2.67 = 0.375 Note: Actual flow rate at surface will be much less due to flowing friction. Nanuk #2: March 19 -24 2000 F E X Torok Reservoir Only Confidential • Nanuq #2 a Alaska " IMPS 6 Testing Results Exploration 66 Nanuq -Only PBU Test • Rate 1,400 BFPD Avg., 1,800 PSI Flowing Pae ' • Permeability 5.5 mD Avg (550 mD -Ft) • Skin -5 • Partial Boundary 530' (800' Investigation) • eb S/OO Nanuk #2: March 19 -24 2000 F E X Torok Reservoir Only Confidential STATE OF ALASKA ). ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 11..... o wW CWMkatIon el S4rvloa Wog On 0 G.0 ❑ SupOMed ❑ Abandoned I] Service ❑ 2. Nano ofOpentor 7. Permit Number PhSlpe Alasla, Inc. 200. 030 /300.118 3. Address a. API Minder P.O. Box 100380, Anchorage, AK 99610-0380 50. 103. 20332.00 • 4. Location of area at metope 9. Una or Loan Name 465' FNL, 864' FEL, See 26, TI IN, R4E, UM (ASP: 377335, 5854676) C0NNo Rbar um Al Top Pnd.onp interval 10. Wet Number 1172' FNL, 3718' FEL, SEC 26, T119, 548, UM (ASP: 374470, 6964017) Nanuk 62 AI Tole Paplh 11. FINd and Pool 1172' FNL, 3719 FEL, SEC 25, T11N, R4E UM (ASP: 374770, 6954017) Explo/aeon 5. Elaalflon in faer(Indie0sI(9, OF, .40.) 8. Law Da0I9WSn and Serial No. RKB28 a Pad 11' ADL 364209ALK 4700 - M. lll}}��r!!!mmass . Date Spudded 13. Date TD. Real3ed 14. Data Coop., Sup Wand. . Or and. 15. W0Mr Depm, 6 ug18aC Mooch 24, 2000 Apr21, 2000 5/72000 Abandoned I N/A roast 391 17. Total Depth ND) I6. Plug Back Depth (MD ♦ ND) 19. Directional Survey 20. Dolh where MU awl NO1R N 9117 MD/ 6241'TVD 9024' MD / 6164' TVD YES 0 N ❑ WA I 1.4 N0 Y � I MD 22. Tape ElednI Con ter or sr Logs Run AI8ik2 pi! & G a s GOR 3. C9 Neueon/Denelty /4-phase Re.IoSvkyIGR, PEX/CMR, OS). PAL RFT, USIT/OFt/CCL, CBL r R BM6d1011 23 CASING. LINER AND CEMENTING RECORD AR56gf311B SETTING DEPTH MD CA81408I2E WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD I AMOUNT PULLED IS' 82.68 B Surface 108' 20' Main. 9.625' 53.58 LAO Surface) 2219' 12.26' 097 as AS III LW, 3509x Class 7' 298 L -80 Surface 9106 8.6' 198 as Claw G Lead. 2450C109a0 TM moor& Plug 0 6707 MD 8N 6rkga plug 0 334' RICH 24. Pad0rM.na open to Production AO a TVD of Tap and Bottom and 25, TUBING RECORD 1, interval. We and nwmben SIZE DEPTH SET 740) PACKER SET (MD) 3.6' 6906' 9791' 7048' -7108' MD 6178' -6238' TVD 5 apt • 7948' -7962' MD 7077'-7091' ND 8 apt 26. ACID, FRACTURE, CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT 3 KIND OF MATERIAL USED ' 7046' -7106, 7948'-7887 F55012935608 d 1600 6061045ba YAM 12 pp. on Ierrnstlon. L0124504 prop M wellborn . brkige plug 12.75SEISASI orml001 Peg #1:118 bbk Clam 0 27 PRODUCTION TEST Dale Firs P0000d1011 MAW of 0pentlon (Flowing, gas Ml, etc.) Apd119, 2000 Abandoned One of Test 4.0,0 Tasted Production to OIL -BBL 2A34ACF WATER -SQL CHOKE SIZE 0AS-03. RATIO 4/19-242000 133 Ma Taal POW > 533 306 669 48/64 575 SCF/STB Flow Tubing - Caning Pressure Caksdalad 011 -881 GAS -MCF WATER -BBL OIL GRAVITY • API (con) press, 350 P0) 555 24HOW Ral6> 740 NIA 935 39' 25 CORE DATA Belot description at 0bolagy, porosity, fractures, apparel dip. and pn.mnce d o6. gas or wrier. Was* WO dips. To be sent under separate cover Fpm 10-407 Rem. 7-1.50 CONTINUED ON REVERSE SIDE Submit in duplicate Aklaq #6: 2 Primary Objective F E Confidential Kugrua (Middle Jurassic) Marine Sandstones Regional Reservoir Data: • • Aklaq #2 (2006) Conventional Core #1 7629' -7677' Cut 51', Rec. 48' ST #1: RSWC's 7629' -7674' (16) No Test • S. Simpson #1 (1977) DST but no Conventional Cores • • Peard #1 (1979) Convention Core #7 7837'- 7868.5' Cut 31.5', Rec. 100% No Test NB: No producing analogs currently exist on the North Slope. The "Alpine" represents a younger (Kimmeridgian) Jurassic shoreface sandstone & appears to have better reservoir characteristics Reservoir Quality: Kugrua Ssts .._ Aklaq 2 Confidential 10.00 ---------- _._ __ _ . _ ___ , M f • E 1.00 ♦ ♦ Torok I • • Kugrua -F � � ♦ • Kugura -S ©4 cu 1 ♦ i 7 Kugrua -P L 0.10 ♦ • ° _° o . ♦ o < O 0 0,0 cc> o 0 • d C;, 0.01 - r♦ ♦ ---0 — 0 5 10 15 20 25 Porosity ( %) S. Simpson #1 F E X Kugrua Marine Sandstones Confidential Data: Wireline Logs / Cuttings / SWC's • No conventional cores Only NPR -A test to date of this Formation Depths: 6523' — 6697' Formation: Middle Jurassic shoreface sandstones with complex iron chlorite mineralogy Upper Sst: 35' > 12% (Av 15 %) porosity 0 Av. Sw 32% DST #1 (6522' — 6568') unstimulated 75 MCFG /D (mainly Methane) +1215' of muddy salt water Peard #1 F E X Kugrua Marine Sandstones: Confidential O • O 0.1 O Peard 1 (routine) : 0.01 • Peard 1 (Klinkenberg) E i a • 0.001 0.0001 0 5 10 15 20 25 30 Porosity, Upper Jurassic (Alpine) Reservoir F E X Response to Fracture Stimulation Confidential 3000 • " -- --- Oil Rate 2500 r • __ ► _ _ • i — -a — • Water Rate i ll, li ) 41,. i', 0 r O. 2000 1 , 1 1 �.-- Stabilized Avg , a) 335 STBOPD 1 c CC 1500 s. Stabilized Avg .� 1 , l 2 STBOPD ttT . 1000 -o Fracture • c 9 • CO I l Treatment - 1 I 500 1, mom E k_ Performed 1; r ` '' rill,. ;1 u' , �' mil . 0.0 ( ( P l e - g e 4. 4 .4- 4. 4?' 4\ 4-'6* Aklaq #6: F E X Anticipated Reservoir Performanc Confidential Conclusions & Recommendations • • Based upon regional reservoir information and analog field modeling (Nanuk & Alpine) it is concluded the two primary reservoir objectives in Aklaq #6 will not produce at rates (unstimulated) above 2000 BOPD vs. the RPS default rate of 5500 BOPD • Operational & drilling problems have compressed the timeline to • complete the drilling & evaluation of Aklaq #6. To ensure completion of this work FEX recommends a favorable acceptance of the 2000 BOPD RPS volume which could allow an extension to the end of season drilling date by ADEC past the present April 21, 2007 , Aklaq #6: Formation Evaluation F E X & Reservoir Performance Confidential • The End • OIL • Spill Response Planning Standard Review FEX's Aklaq #6 Well (PTD 207 -009) Confidential Request: On March 22, 2007, Paul Mazzolini and Richard Garrard of FEX visited the Commission's office and requested a reduced spill response planning standard ( "SRPS ") volume for the Aklaq #6 well in NPR -A. They provided information on offset wells they believe support reducing the SRPS volume from the Department of Environmental Conservation's ( "DEC ") default value of 5,500 barrels per day ( "BPD ") to 2,000 BPD. Recommendation: Based on a reasonable set of worst -case scenario assumptions the SRPS rate should be reduced to 2,000 BPD. Discussion: There are four zones that, based on other wells in the area, may potentially flow at Aklaq #6. In increasing depth these are, the Nanushuk, the Middle Torok, the Lower Torok and the Kugrua/Simpson sandstone. The sandstone beds of the Lower Torok formation are the greatest concern for SRPS volume in Aklaq #6 because they appear to have the greatest amount of net pay. Aklaq #2, located approximately 10 miles to the southwest, encountered a combined 158 feet TVD of net pay, which FEX defines as having greater than 12% log porosity. FEX obtained sidewall cores throughout this possible pay zone and calculates an average permeability of less than 0.5 md. The Lower Torok in Aklaq #6 is comprised of 5 separate sand lobes with average permeabilities for the individual lobes ranging from 0.14 to 0.44 md. The core analysis report from the Aklaq #2 well shows that rock properties in the Lower Torok appear to degrade as depth increases. The primary objective of Aklaq #6 is the Lower Torok a turbidite basin floor fan that FEX believes might be analogous to the Nanuk Field. Unfortunately, none of the Northeast NPR -A wells have penetrated Torok reservoirs of this nature with movable hydrocarbons and, as a result, no test data is available for this interval. FEX believes the Nanuk #2 well test is a good analog to use for Aklaq #6. The Nanuk #2 well produced 39° API gravity oil with a GOR of 575 SCF /STB. Combining the formation properties from Aklaq #2, the fluid properties from Nanuk #2, and the depth, wellbore construction and pressure estimate from the Aklaq #6 PTD application an estimated maximum un- stimulated flowrate of approximately 80 BPD is calculated for the Lower Torok sandstones. However, the maximum permeability measured in the Lower Torok sandstone cores from the Aklaq #2 well was approximately 1.5 and (the Middle Torok which is much thinner and approximately 700 feet shallower had permeabilities as high as 3.5 md). If 1.5 and is substituted for the average v permeability in the prior calculation, the estimated maximum flowrate increases to 280 BPD. A review of nearby exploratory wells (including several Simpson wells and the more recent exploratory wells) indicates that the Nanushuk formation, although oil productive at Umiat, has infrequent gas shows in this part of NPR -A. Because the Nanushuk appears to be gas bearing in this region it is not considered in further detail. Although the Middle Torok has better reservoir properties than the Lower Torok it is a much thinner formation, 35 feet versus 158 feet, and therefore has a very low, approximately 80 BPD, expected un- stimulated flow potential. Because it is relatively thin it is also relatively insensitive to possible changes in rock and fluid properties. Since the formation has a low flow potential and low sensitivity to variances in parameters it is not as significant for the purposes of this analysis as the Lower Torok and is therefore not considered in further detail. The deeper Kugrua sandstone (which is also referred to as the Simpson sandstone in earlier exploration wells) was tested by means of a DST in the South Simpson #1 well, approximately 10 miles to the north of Aklaq #6, and resulted in a flowrate of 75 MCFPD and the recovery of 1,215 feet of muddy saltwater. Logs for South Simpson #1 indicate that the reservoir has good porosity, however the well file contains a series of correspondences related to the issue that indicates that the formation likely contains the minerals Daphnite and/or Limonite which are likely affecting the reliability of the logging tools. Core data from Aklaq #2 indicates that the Kugrua is a poor quality reservoir with permeabilities of no more than 0.25 md. The combination of the data discussed above indicates that the Kugrua is a poor quality reservoir and likely gas prone instead of oil prone. A quick calculation of flow potential based on the available data, and assuming the Kugrua does contain oil, shows that the Kugrua would be incapable of un- stimulated production of more than 100 BPD. Therefore, the Kugrua reservoir is not considered in further detail. There appears to be a general trend of API gravity increasing to the west across the North Slope. The Prudhoe and Kuparuk Oil Pools contain crude with gravities of 28° and 24° respectively, the Alpine Oil Pool contains 40° gravity crude, and several exploratory wells in NPR -A have reported liquid hydrocarbon gravities between 55° and 60° with GORs form 10,000 to 20,000 SCF /STB. However, these lighter gravity liquids and high GOR's were tested from Upper Jurassic -aged "Alpine type" reservoirs sandstone of high quality. The tests at Spark (from close to the gas-oil contact) and Lookout (from the oil leg only) were both achieved after a major fracture stimulation. The Carbon and Rendezvous tests were both unstimulated, as they were known to be located within the gas cap of these two -phase accumulations. The very light hydrocarbons (55 to 60 degree API) are condensates associated with the gas caps. The Upper Jurassic section has been removed by the Lower Cretaceous Unconformity at the Aklaq #6 location (D. Garrard, email communication, April 4, 2007). I 1I. i There is no PVT information available for any of the exploratory wells in the vicinity of the Aklaq #6 well that either conclusively confirms or rules out the higher API gravities and /or higher GORs that were encountered elsewhere in NPR -A. The deeper target at Aklaq #6 is the Middle Jurassic -aged Kugrua/Simpson sandstone, and this sandstone does not exist in the area of the Northeast NPR -A discoveries. The only test performed so far on this interval in the NPR -A took place by USGS/Husky at South Simpson #1 (1977 DST #1) and achieved an unstimulated flow rate of 75 MCFPD of dry gas. Where this reservoir has been penetrated elsewhere in the region only very low matrix permeabilities have so far been recorded (D. Garrard, cited above). So, in order to provide a conservative value for the SRPS volume it is appropriate to evaluate the flow potential using the set of conditions that will result in the highest possible SRPS rate. In this instance, the highest rate is achieved assuming the 1.5 and permeability measured in the Lower Torok of the Aklaq #2 well and crude oil properties of 60° API gravity and a GOR of 15,000 SCF /STB reported from the Jurassic of the Rendezvous A exploration well. Based on these assumptions, the calculated maximum potential rate for Aklaq #6 is nearly 2,000 BPD. The sensitivity analysis only looked at permeability and fluid properties and did not consider the possible effects that varying the net pay could have. This assumption is reasonable for the purpose of this analysis because the combination of rock and fluid properties used for the worst -case scenario provides a very conservative estimate of flow potential. Conclusion: Assuming reservoir and fluid properties that could possibly be encountered by the Aklaq #6 well, the worst -case scenario flowrate is expected to be 2,000 BPD or less. Therefore, providing the DEC with a letter supporting FEX's revised SRPS rate request is appropriate. Prepared by: David S. Roby Prepared on: April 5, 2007 Note: This document contains information from other wells that are confidential. RE: tklaq #6 SRPS value • Q fir) 2o7_0o ' Subject: RE: Aklaq #6 SRPS value From: "Garrard, Richard" <RGARRARD @talisman - energy.com> Date: Wed, 04 Apr 2007 12:21:54 -0600 To: Dave Roby <dave roby @admin.state.ak.us> CC: " Mazzolini, Paul " <PMAZZOLINI @talisman- energy.com >, Stephen F Davies < steve _davies@admin.state.ak.us >, Thomas Maunder <tom maunder @admin.state.ak.us> Dave, We all appreciate your understanding and cooperation with respect to the forward drilling plan for Aklaq #6. Hopefully we will not need any extra drilling days beyond April 21, 2007 - but it would be a nice comfort factor to have a few extra days in the event of a delay in reaching our planned TD. At present the well is drilling ahead on schedule and in our current case of a trouble free operation at the Arctic Wolf we should finish all open hole drilling by April 21. Thanks again for your help. Regards DICK Original Message From: Dave Roby [mailto:dave roby @admin.state.ak.us] Sent: Wednesday, April 04, 2007 9:35 AM To: Garrard, Richard Cc: Mazzolini, Paul; Stephen F Davies; Thomas Maunder Subject: Re: Aklaq #6 SRPS value Dick: Thanks for the explanation below and also for the more detailed core analysis information you provided. Based on this new information I was able to revise my set of assumptions for a worst case scenario and have arrived at a SRPS value in line with what you had requested. I am preparing a letter to Lydia Miner with the DEC that should go out today and will copy you and Paul on it. Additionally, please pass on my thanks to Ken Muse (sp ?) for taking time out of his holiday to discuss this issue with me this morning. Regards, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907 - 793 -1232 Garrard, Richard wrote: Dave, Thanks for your note regarding the Aklaq #6 SRPS values presented at our recent meeting with the AOGCC. Both Paul and myself were involved in the operations and testing programs for Arco /Phillips /ConocoPhillips in the Northeast NPR -A between 2000 and 2005. The lighter gravity liquids and high GOR's you refer to were tested from Upper Jurassic "Alpine type" sandstone formations in that area and in most cases came from some high quality reservoirs. The tests at Spark (close to GOC) and Lookout (oil leg only) were both achieved after a major fracture stimulation. The Carbon and Rendezvous tests were both unstimulated as they were known to be located within the 1 of 3 4/5/2007 1:38 PM RE!Ak12 #6 SRPS value gas cap of these two phase accumulations. The very light hydrocarbons (55 to 60 degree API) you refer to are in fact condensates associated with the gas caps. At the Aklaq #6 location the Upper Jurassic section has been removed by the Lower Cretaceous Unconformity and is therefore, not an objective in this well. The primary objective is a Torok turbidite basin floor fan that we believe might be analogous to the Nanuk Field. That is why we are using the Nanuk example in our modeling. None of the Northeast NPR -A wells penetrated Torok reservoirs of this nature and as a result no tests were undertaken on this interval by the Arco /Phillips /COP Group. Our deeper target at Aklaq #6 is the Kugrua /Simpson sandstone of Middle Jurassic age and this formation does not exist in the area of the Northeast NPR -A discoveries. The only test performed so far on this interval in the NPR -A took place by USGS /Husky at South Simpson #1 (1977 DST #1) and achieved an unstimulated flow rate of just 75 MCFPD of dry gas. Where this reservoir has been penetrated elsewhere in the region only very low matrix permeabilities have so far been recorded. Based upon both sets of data we therefore, concluded the default value of 5500 BOPD for Aklaq #6 was too high. Please let us know whether you require any further information or if we need to attend a second meeting. Thank you for your consideration. Regards DICK Original Message From: Dave Roby [mailto:dave roby @admin.state.ak.us] Sent: Tuesday, April 03, 2007 2:55 PM To: Mazzolini, Paul; Garrard, Richard Cc: Stephen F Davies; Thomas Maunder Subject: Aklaq #6 SRPS value Gentlemen, Sorry it has taken me so long to get back to you. I have been working on the Aklaq #6 SRPS issue and trying to find information that will help me narrow the uncertainty that I am dealing with. When I use the anticipated values it is easy to calculate an SRPS rate that is less than the rate you proposed, however when I start conducting a sensitivity analysis to account for the possible differences between the existing wells and the Aklaq #6 location I can quickly come up with rates that exceed your proposed rate and approach the DEC default rate. I have been trying to find information that would support narrowing the range of values that I am using in the sensitivity analysis but have yet to find any data that would support a significant change in the scope. One item that has a particularly profound effect on the results I am getting is the fluid PVT properties. The 39 gravity 575 GOR of the Nanuk #2 well tests appears to be a relatively "dead" crude compared to the gravities and GOR encountered by some of the other exploratory wells in the NPR -A. There have been several announced results with gravities in the 55 to 60 range and GOR from 10,000 to 20,000 scf /stb. Changing the PVT properties alone does not cause my results to exceed your proposed SRPS value. However taken in conjunction with applying some uncertainty to the permeability and /or net pay values to account for possible variations in rock properties between the existing wells and the Aklaq #6 location the calculated results quickly exceed your proposed rate. If you have any information that would help me constrain my sensitivity analysis I would greatly appreciate it. Thanks in advance, 2 of 3 4/5/2007 1:38 PM RE' AklM.q #6 SRPS value • Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907 - 793 -1232 3 of 3 4/5/2007 1:38 PM FROM : ► FAX NO. :907- 644 -4892 •pr. 04 2007 08:19RM P1 FEXL.P. 3601 C STREET, SuITE 370 E ANCHORAGE, AK 99503 PHONE (907) 644 -4429 FAx (907) 644 -4892 T A ' AX TRANSMITTAL ' Iv r TO: Dave Roby FROM: Laura Erickson COMPANY: AOGCC DATE: April 4, 2007 FAX: 276 -7542 JOB NO: PHONE: 793-1232 PAGES: 9 SUBJECT: Information requested Contract: - n m 1 • ° Northwest N PR A AKLAQ #2 F E X Preliminary Reservoir Potential -�- Tv) ,,,e 11,x, 2 L-r-.. Lower Nanushuk Sst 2585' -2601' (16') Log 018 -25% (40' >12 %) -452.a — 75 4 Middle Torok Ssts 5120' -5142 (20' >12 %0) X z Sst #6: RSWC 014.1 - 15.6% ° Perm. AV. 2.43 MD 1 A A 1 Lower Torok Ssts .T2.'2., f --q-2_9f2- A lLI N SSt #5: 5822'-5892' (38' >12% log¢) zesO 2 Vao R 012.7 — 14.7% Perm Av. 0.44 MD 1 I A Sst #4: 6160'6224' (30' >12% fog¢) A R 67.13 - 14.5% 03 Perm Av. 0.17MD 3 N -Il O F E 1 l Lower Torok Ssts cont. -S7Dq- SSt #3: 6274'-6304' (22' >12% log¢) RSWC 011.5 -13.2% • Perm Av. 0.19 MD Sst #4 2 6480'1 50' (30'>12% loge RSWC 07.1 - 13.4% Perm Av. 0.171/0 m 9642- 1-9092/ Sst #1: 964' -9fi92' (38' >12% loge RSWC 09.6 - 12.6% Perm Av. 0.14MD 110 Total Torok 176' N m 0 m CO N 0 3 W FROM : FAX NO. :907- 644 -4992 •pr. 04 2007 08:20AM P4 Petroleum Services Division Coro Leboraroiles Canada, Ltd, 2510 - 12 Street N.E. Calgary. Alberta, Canada T2E 7P7 • , • Tel: (403) 250 -4000 Fax (403) 250-5120 ww ,,coreIab.COm . Care Lib wawa aPt1M1ZATION May 11, 2006 Talisman Energy Inc. 3400, 888 — 3 Street S.W. Calgary, Alberta T2P 5C5 Attention: Ms. Barb Rypien Subject: FEX L. P. AKLAQ #2 (SIDEWALL) Our File Number: 52131 - 06-0151 Rotary sidewall coring equipment and water base mud were used to core the subject well. The samples were labeled at the wellsite and transported to our Calgary laboratory for analysis. I Prior to analysis, the core material was photographed and eight sets of white light, 216 mm X 280 nun photographs and eight compact disks were forwarded to your office. 1. Conventional, Plug Type Analysis Thirty -eight samples (25.4 mm diameter) were cleaned in a vapour phase extractor using toluene and dried in a gravity oven. Analysis includes porosity by Boyle's Law technique using helium as the gaseous medium and horizontal permeability to air. Fluid saturations were determined using the Dean Stark distillation technique. Thank you for the opportunity to be of service. Yours truly, CORE LABORATORIES CANADA, LTD. "� J, Brooks 1 Supervisor, Routine Rock Properties DJBlwz enclosures I • 0 3 - CORE LABORATORIES Company TALISMAN ENERGY INC. Field File No. 52131 -06 -0151 Well FEX L.P.AKLAQ #2 Formaticm Date 2006 -03 -19 Locatiosi Coring Equip ROTARY STDEWALL Analysts J DOB Province ALASKA Coring Fluid WATER BASE NEED Core Dia 1 inch CORE ANALYSIS RESULTS PERMEABILITY POROSITY GRAIN SATURATION SATURATION SAMPLE 1 DEPTH (MAXIMUM) (HELIUM) DENSITY (PORE VOLUME) (PORE VOLUME) DESCRIPTION NUMBER fl Karr OIL WATER mD _ x (c�nlco) x x • D X 1 5125.5 0.67 14.1 2.68 4.3 4.3 ss of f dol z 0 2 5129.5 2.14 15.2 2.68 5.8 2.5 ss off dot M fe- -3 5134.0 3.42 15.4 2.67 3.3 5.4 ss off dal ZiS 4 5140.0 3.48 15.6 2.67 2.0 5.3 as of f dal I 5 5180 -0 0.01 6.4 2.72 0.0 57.2 as vf shy dot lam A 6 5347.0 NA m 7 5775.0 0.06 9.2 2.69 4.3 17 ss vf I carb dot pyr lam 13 R] _8 5837.5 0.17 12.7 2-68 3.3 8.2 ss of t dol lam a 9 5859.0 m y.0 0.18 13.6 2.66 6.9 9.3 ss vt t Garb dot la m '\ 12 5864.0 0.1 12.4 2.69 3.2 13.6 ss vl f dol 10 5860.5 111120 14.7 2.67 4.2 4.8 ss vi t dol IP N 11 5890.5 0.31 14.1 2.67 3.9 5.4 ss vl Idol 13 5918.0 0.02 5.2 2.70 3.9 66 ss vi I cat dol lam m 14 6065.5 0.01 6.0 2.76 0.0 82.1 ss vf 1 vshy dol lam A ro A 15 6169.5 0.35 13.8 2.69 8.9 6.7 ss vl I dol m m 16 6174.0 0.27 14.5 2.67 7.2 10.7 ss vl f dol m 17 6197.0 0.13 12.6 2.68 8.0 11.2 ss of f dol 0o R1 18 6205.0 0.13 12.0 2.68 10.1 8.7 ss off dal m D 19 6221.0 0.13 11.8 2.68 14.8 4.3 ss vt f dot 3 20 6222.0 0.03 7.0 2.66 24.1 17.2 ss off shy dol lam Ol 21 6276.0 025 112 2.68 0.0 15.2 ss off idol Page 1 of 3 MNIMM• =Nam= m 0 3 CORE LABORATORIES Company 1 TALISMAN ENERGY INC. Field I File NO. 52131 -06 -0151 Well - FMK L_P.AQ #2 Formation Date 2006 -03-19 Coring Equip ROTARY SIDEWAL.L Analysts DJB Location - Province A7eASFCIr Coring Fluid WATER BASE HUD Core Die 1 inch CORE ANALYSIS RESULTS SATURATION SATURATION SAMPLE DSPTH PE ttoRMERMEA8 MUM) L1TY POROSITY GRAIN (PORE VOLUME) (PORE VOLUME) l (HELIUM) DENSITY DESCRIPTION OIL WATER NUMB1 R Dr x (gmlcc) % x I I -n D 22 6288.0 0.08 11.5 2.67 3.4 14.6 ss of f cart dol X 23 6293.0 0.14 12.0 2 4.9 12.3 ss of I carb dol z o 24 6297.0 0.38 12.9 2.68 7.1 7.9 ss of Idol 25 6302.0 up- 0.12 321 2.67 12.1 4.3 ss of f dol m 5.4 9.9 ss of I carb dot lam I 26 6367.0 0.09 11 2 2 67 A 27 6474.0 NA A I 28 6499.4 0.13 12.1 2.70 7.4 6.6 ss of f dol CO N.1 29 6497.0 0.29 12.9 2.69 4.6 9.2 ssvffdjol 30 6513.0 0.24 13.4 2.68 10.0 3.6 ss of f dol 31 6547.0 0.01 7.1 2.69 0.0 30 ss of f dol 32 6644.0 0.16 12.3 2.69 9.6 4 ss of f dol 33 6650.5 0.20 12.6 2.69 6.2 7.8 ss off dol 34 5,7 5.7 ss of f dol 6661.5 0.12 12.2 2.69 m 35 6675.0 0.12 17.5 1 2.70 13.2 13.4 2.6 3.6 ss of f dol ss off do) A 0.11 1.6 2. ru 36 6676.0 m m 37 6684.0 0.07 9.6 2.71 14.6 5.2 ss of f dol pyr ,I 6.7 ss m 38 6690.0 0.19 12.0 2.70 9.2 00 NA A m 39 6714.5 N 3 6785.0 40 0 5.4 2.70 2.1 36 ss of f dol 41 6901.5 m 6.0 2 5.2 43 ssvlfmcdofpyr 42 6902.0 010 Page 2 of 3 E S ! m m m a m W m m r m MINN ! - UMW �l 0 CO RE LABORATORIES Company TAF,ISMAZ ENERGY INC. Field File No. 52131 -06 -0151 well FEX L.F.AKLAQ 02 Formation Date 2006 -03 -19 Location Coring Equip ROTARY SIDEWALL Analysts DUB Province ALASKA Coring Fluid WATER SASE MUD Core Dia 1 inch CORE ANALYSIS RESULTS PERMEABILITY POROSITY GRAIN SATURATION SATURATION SAMPLE DEPTH (MAXIMUM) (PORE VOLUME) (PORE VOLUME) (HELIUM) € ENSITY DESCRIPTION NUMBER ft K.* ( /oc) OIL WATER m ` -Il D X 43 6910.0 NA z O w 0 I 01 A A I A CO fU b 0 A R1 0 0 -'I 0 0 0 D 3 Page 3 of 3 .■ =Emma ■ era IMIM. MINEM - - - ti! - EIM EMI i• MEI Mr _ -n O j •c a re Leib CODE KEY - DESCRIPTIONS • ACA = Removed for advanced core analysis m = Medium SPH = Humidity analysis of small plug sample at 60 entry = Anhydrite ml = Mud invaded degrees Celsius and 50 % relative humldty arg = Argiitaceous my = Medium vug SPP = Small plug from preserved section of the core A • ST = Appears similar to NA = Not analyzed by request SPT = Small Plug used for tracer analysts bit = Bitumen NP = No permeability measurement possible due ss = Sandstone 1]k = Break to poor sample quality ssdy = Slightly sandy (<20%) c = Coarse NP = Not received sshy = Slightly shaky ( <20%) caic = Calcite (calcareous) OB = Overburden sample (permeability and sty = Stylotlte (ic) X carb = Carbonaceous porosity measured at net overburden sulf = Sulphur - - Z cal = Cobble stress) sv = Small vug o cgi = Conglomerate ooi = Oolitic TEC = Thermal Extraction Chromatography to cht = Cheri pbl = Pebble determine oil richness w coal = Coat/coat inclusion PFD = Preliminary Full Diameter sample TS = Thin section m coq = Coquina ppv = Pinpoint vug uncons = Unconsolidated to dol = Dolomite PR = Preserved for future studies vc = Very coarse I = Fine PSA = Particle size analysis of = Very fine i FD = Full diameter analysts including three PSP = Preliminary Small Plug sample vireo = Vertical fracture co directional permeabihities, porosity and pyr = Pyrite (pyritic) VIS = Viscosity of oil measured Ni densities pyrbit • Py+robitumen VOB = Vertical overburden sample (vertical foss = Fossil (lossiillerous) ru = Rubble permeability measured at net overburden . frac = Fracture (undifferentiated) SA = Sieve analysis stress) ri = Friable sdy = Sandy vshy = Very shaly ( >40%) glauc = Glauconite (glauconidc) SEM = Scanning electron microscope analysis . VSP = Vertical small plug drilled from whole • grnl = Granule sh = Shale core to measure vertical permeability gyp = Gypsum shy = Moderately shaly (20% - 40%) (and occasionally porosity) hal = Halite (salt) std = Siderite vug = Vuggy (vugg War) A hirac = Horizontal fracture sltst = Siltstone ws = Water sand I = Intercrystalline sity = Silty XRD = X-ray diffraction m iFD = Inner Full Diameter (Ful€ diameter sample SP = Small plug (sample drilled from core in = Data unavailable due to broken core m is drilled lrom the bulk portion of the maxlmum horizontal direction and parallel to 10240 = Permeability >10 Darcies, (maximum m core in the vertical direction for bedding plane where possible) permeability routine permeability measurement) co perrneability and porosity measurements) porosity, and grain density are measured ni Inc! = Inclusions SPA = (Prefix A) Horizontal matrix permeability 3 lam = Laminae (laminated) measured by pressure decay profile Is = Limestone perrneametry through a probe tip due lv = Large vug to sample quality m I FROM : FAX NO. :97-644-4892 •pr. 84 27 8:21PM P9 1 Permeability vs Porosity 1 EEII 1 - 1 I /+ • 0 ____ / Log(Y) = .2203* X -3.3415 1 77Lcorr9Iatio_n Cf. = 0.868 0.01 / / 1 . 0,0 40 80 12.0 16.0 200 24.0 Kellum Porosity: TALISMAN ENERCY INC. - LEGEND - FEX L,P.AKLAQ 2 1 1 Core Laboratories Canada Ltd. 1 1 . .. 1 i e 1 04/02/07 » »> Snap 1.425 7/25/2006 ««< 15:09:00 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 . f ataSet.snp Title : Aklaq 6 - SRPS Review * ** BASE CONDITIONS * ** 3 1 b /9l 1 Rate Intersection Results 10.14 975" G O Pressure Intersection Results : 2337.96 r IPR Data: Tubing Hydraulics Data Ay 24 m Bottomhole Vcif Flow Rate Pressure Flow Rate Pressure (stbfpd) (psia) (stbfpd) (psia) 0 3577 1 2348 1 3428 2 2347 1 2 3279 4 2346 4 3130 7 2341 5 2981 10 2338 6 2832 15 2335 7 2683 29 2321 9 2534 100 2265 10 2385 11 2236 12 2087 13 1938 15 1789 16 1639 17 1490 18 1341 20 1192 21 1043 22 894 23 745 24 596 26 447 27 298 28 149 29 0 r • Aw e 2 04/02/07 » »> Snap 1.425 7/25/2006 « «< 15:09:00 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type Oil Well * ** PVT Properties * ** Oil API gravity 39.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 575 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso r & , A we 3 04/02/07 » »> Snap 1.425 7/25/2006 ««< 15:09:00 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zor'ie Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 U. 3577.0 0.250 35.00 1490.0 0.354 0.000 0.000 g e 4 04/02/07 » »> Snap 1.425 7/25/2006 ««< 15:09:00 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) • 40.0 Wellhead Pressure (psia) • 0.0 Bottomhole temperature • 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Welibore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 61.43 0.00180 Ansari 2 8.500 7000.00 7000.00 0.00 100.00 0.00180 Ansari ICI " • 1 04/02/07 » » > Snap 1.425 7/25/2006 « «< 15:10:59 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby q' U y✓ Dataset : Aklaq 6 DataSet.snp Title : Aklaq 6 - SRPS Review 1 C * ** BASE CONDITIONS * ** o 0 4 (5 000 6 Rate Intersection Results 77.44 � Pressure Intersection Results : 640.73 5 -, ! 7 IPR Data: Tubing Hydraulics Data A C/A ' ,41 1 Bottomhole Flow Rate Pressure Flow Rate Pressure (stbfpd) (psia) (stbfpd) (psia) 0 3577 1 2081 4 3428 6 1946 8 3279 10 1844 12 3130 12 1801 16 2981 24 1541 20 2832 47 1074 24 2683 94 400 28 2534 100 366 31 2385 35 2236 39 2087 43 1938 47 1789 51 1639 55 1490 59 1341 63 1192 67 1043 71 894 75 745 79 596 83 447 86 298 90 149 94 0 + • •ge 2 04/02/07 » »> Snap 1.425 7/25/2006 ««< 15:10:59 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type • Oil Well * ** PVT Properties * ** Oil API gravity 60.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 15000 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso • lige 3 04/02/07 » »> Snap 1.425 7/25/2006 ««< 15:10:59 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 U. 3577.0 0.250 35.00 1490.0 0.354 0.000 0.000 • 110 we 4 04/02/07 » »> Snap 1.425 7/25/2006 « «< 15:10:59 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) ▪ 40.0 Wellhead Pressure (psia) 0.0 Bottomhole temperature ▪ 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 61.43 0.00180 Ansari 2 8.500 7000.00 7000.00 0.00 100.00 0.00180 Ansari Il i II s 1 1 1 e 1 04/02/07 » »> Snap 1.425 7/25/2006 ««< 15:04:52 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** BASE CONDITIONS * ** D War IS, Rate Intersection Results 365.89 Pressure Intersection Results : 69.00 2, IPR Data: Tubing Hydraulics Data O � P P 6o Bottomhole Flow Rate Pressure Flow Rate Pressure 000 V „ (stbfpd) (psia) (stbfpd) (psia) 0 2400 1 1417 16 2300 10 1191 32 2200 24 930 47 2100 47 495 63 2000 94 169 79 1900 100 155 95 1800 188 81 110 1700 377 68 126 1600 142 1500 158 1400 173 1300 189 1200 205 1100 220 1000 236 900 252 800 267 700 283 600 299 500 314 400 330 300 345 200 361 100 377 0 t +Oi e 2 04/02/07 » »> Snap 1.425 7/25/2006 « «< 15:04:52 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type • Oil Well *** PVT Properties * ** Oil API gravity 60.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 15000 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso c mt 0 •e 3 04/02/07 » »> Snap 1.425 7/25/2006 « «< 15:04:52 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 U. 2400.0 2.500 20.00 1490.0 0.354 0.000 0.000 e 4 04/02/07 » »> Snap 1.425 7/25/2006 ««< 15:04:52 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Upper Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) 40.0 Wellhead Pressure (psia) 0.0 Bottomhole temperature 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 71.91 0.00180 Ansari 2 8.500 4700.00 4700.00 0.00 100.00 0.00180 Ansari ge 1 04/02/07 » »> Snap 1.425 7/25/2006 « «< 11:56:51 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review L * ** BASE CONDITIONS * ** 0ppet ror0 k fe f` Rate Intersection Results 82.66 .2 P Pressure Intersection Results : 1866.58 IPR Data: Tubing Hydraulics Data Z.y ,1 Bottomhole 3 ? O (rff Flow Rate Pressure Flow Rate Pressure (stbfpd) (psia) (stbfpd) (psia) 5 75 6 ol( 0 2900 1 1939 10 2779 10 1929 19 2658 14 1926 29 2538 29 1912 39 2417 58 1886 48 2296 100 1853 58 2175 116 1843 68 2054 232 1756 77 1933 87 1813 97 1692 106 1571 116 1450 126 1329 135 1208 145 1088 155 967 164 846 174 725 184 604 193 483 203 363 213 242 222 121 232 0 011ge 2 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:56:51 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type • Oil Well * ** PVT Properties * ** Oil API gravity • 39.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 575 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso 0 Ike 3 04/02/07 » »> Snap 1.425 7/25/2006 « «< 11:56:51 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water if Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 L. 2900.0 0.500 158.00 1490.0 0.354 0.000 0.000 likge 4 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:56:51 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) • 40.0 Wellhead Pressure (psia) 0.0 Bottomhole temperature • 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 66.32 0.00180 Ansari 2 8.500 5700.00 5700.00 0.00 100.00 0.00180 Ansari 411' l ie 1 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:56:51 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** BASE CONDITIONS * ** ' � J E f / Rate Intersection Results 82.66 ft P9 Pressure Intersection Results : 1866.58 ire IPR Data: Tubing Hydraulics Data Y? i/.t Bottomhole 57 6 Flow Rate Pressure Flow Rate Pressure (stbfpd) (psia) (stbfpd) (psia) Co �� 0 2900 1 1939 10 2779 10 1929 19 2658 14 1926 29 2538 29 1912 39 2417 58 1886 48 2296 100 1853 58 2175 116 1843 68 2054 232 1756 77 1933 87 1813 97 1692 106 1571 116 1450 126 1329 135 1208 145 1088 155 967 164 846 174 725 184 604 193 483 203 363 213 242 222 121 232 0 IliVe 2 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:56:51 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type • Oil Well * ** PVT Properties * ** Oil API gravity 39.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 575 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso t _ e 3 04/02/07 » »> Snap 1.425 7/25/2006 « «< 11:56:51 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 L. 2900.0 0.500 158.00 1490.0 0.354 0.000 0.000 • ilt 4 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:56:51 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) 40.0 Wellhead Pressure (psia) • 0.0 Bottomhole temperature • 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 66.32 0.00180 Ansari 2 8.500 5700.00 5700.00 0.00 100.00 0.00180 Ansari e IPIE le e 1 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:51:46 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** BASE CONDITIONS * ** s in , Rate Intersection Results 689.94 net ,- Pressure Intersection Results : 85.03 /.5 IPR Data: Tubing Hydraulics Data G A A 6 Bottomhole ,Q Flow Rate Pressure Flow Rate Pressure /S ®QO c (stbfpd) (psia) (stbfpd) (psia) 0 2900 1 1710 S e. 30 2779 10 1477 59 2658 44 788 89 2538 89 277 119 2417 100 232 148 2296 178 117 178 2175 355 86 208 2054 711 85 237 1933 267 1813 297 1692 326 1571 356 1450 385 1329 415 1208 445 1088 474 967 504 846 533 725 563 604 593 483 622 363 652 242 681 121 711 0 Ape 2 04/02/07 » »> Snap 1.425 7/25/2006 « «< 11:51:46 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type • Oil Well * ** PVT Properties * ** Oil API gravity • 60.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 15000 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso ill i re 3 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:51:46 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 L. 2900.0 0.500 158.00 1490.0 0.354 0.000 0.000 1 ,I ae 4 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:51:46 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) • 40.0 Wellhead Pressure (psia) • 0.0 Bottomhole temperature • 100.0 «< Well Geometry Data »> «< Tubular flow >» Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 66.32 0.00180 Ansari 2 8.500 5700.00 5700.00 0.00 100.00 0.00180 Ansari •ge 1 04/04/07 » »> Snap 1.425 7/25/2006 « «< 09:43:04 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Lower Torok Revised DataSet.snp Title : Aklaq 6 - SRPS Review * ** BASE CONDITIONS * ** ?9 ,0 /9r 9, 2 - Rate Intersection Results 282.62 5-7C G O" Pressure Intersection Results : 1722.02 D 5 7 IPR Data: Tubing Hydraulics Data fr3 ► /4 Bottomhole Flow Rate Pressure Flow Rate Pressure (stbfpd) (psia) (stbfpd) (psia) 0 2900 1 1939 29 2779 10 1929 58 2658 43 1899 87 2538 87 1863 116 2417 100 1853 145 2296 174 1799 174 2175 348 1676 203 2054 696 1459 232 1933 261 1813 290 1692 319 1571 348 1450 377 1329 406 1208 435 1088 464 967 493 846 522 725 551 604 580 483 609 363 638 242 667 121 696 0 1 we 2 04/04/07 » »> Snap 1.425 7/25/2006 ««< 09:43:04 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Lower Torok Revised DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type • Oil Well * ** PVT Properties * ** Oil API gravity 39.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 575 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso 4 1,ge 3 04/04/07 » »> Snap 1.425 7/25/2006 « 09:43:04 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Lower Torok Revised DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 L. 2900.0 1.500 158.00 1490.0 0.354 0.000 0.000 Illage 4 04/04/07 » »> Snap 1.425 7/25/2006 ««< 09:43:04 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Lower Torok Revised DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) • 40.0 Wellhead Pressure (psia) • 0.0 Bottomhole temperature • 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg I 'l l Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 66.30 0.00180 Ansari 2 8.500 5700.00 5700.00 0.00 100.00 0.00180 Ansari �P x. 410 loge 1 04/04/07 » »> Snap 1.425 7/25/2006 ««< 09:26:55 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Lower Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** BASE CONDITIONS * ** Rate Intersection Results 2003.10 Pressure Intersection Results : 166.87 js o oa 60R IPR Data: Tubing Hydraulics Data 'I 5 0'5 Bottomhole '✓✓ � Flow Rate Pressure Flow Rate Pressure / (stbfpd) (psia) (stbfpd) (psia) 0 2900 1 1710 89 2779 10 1477 178 2658 100 232 267 2538 133 157 356 2417 266 92 445 2296 531 83 534 2175 1062 96 622 2054 2125 176 711 1933 800 1813 888 1692 977 1571 1066 1450 1154 1329 1243 1208 1331 1088 1419 967 1508 846 1596 725 1684 604 1772 483 1860 363 1949 242 2037 121 2125 0 „,` l ive 2 04/04/07 » »> Snap 1.425 7/25/2006 ««< 09:26:55 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Lower Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type • Oil Well * ** PVT Properties * ** Oil API gravity 60.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 15000 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso we 3 04/04/07 » »> Snap 1.425 7/25/2006 ««< 09:26:55 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Lower Torok DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 L. 2900.0 1.500 158.00 1490.0 0.354 0.000 0.000 it 410 l ive 4 04/04/07 » »> Snap 1.425 7/25/2006 ««< 09:26:55 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Aklaq 6 Lower Torok DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) • 40.0 Wellhead Pressure (psia) • 0.0 Bottomhole temperature • 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 66.30 0.00180 Ansari 2 8.500 5700.00 5700.00 0.00 100.00 0.00180 Ansari • •ge 1 04/02/07 » » > Snap 1.425 7/25/2006 ««< 11:12:12 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** BASE CONDITIONS * ** Rate Intersection Results 1038.92 Pressure Intersection Results : . IPR Data: Tubing Hydraulics Data C Wee 1 O K 1919c‘ CONOsrlof Bole N d< i. ®rs /wt eI Flow Rate Pressure Flow Rate Pressure N (stbfpd) (psia) (stbfpd) (psia) 0 2900 1 1939 '9' 42/947- .— 77 2779 10 1929 155 2658 100 1853 575-- 600 232 2538 116 1843 309 2417 232 1756 if of /e/f/ 387 2296 463 1600 464 2175 927 1324 541 2054 1854 924 /58 tqf 618 1933 696 1813 773 1692 850 1571 927 1450 1005 1329 1082 1208 1159 1088 1236 967 1314 846 1391 725 1468 604 1545 483 1622 363 1700 242 1777 121 1854 0 d 2 04/02/07 » »> Snap 1.425 7/25/2006 « «< 11:12:12 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type . Oil Well * ** PVT Properties * ** Oil API gravity • 39.000 Gas Specific Gravity (air -1.) 0.700 Reservoir Producing GOR (scf /stb)..: 575 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso II A il lge 3 04/02/07 » »> Snap 1.425 7/25/2006 « «< 11:12:12 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 L. 2900.0 4.000 158.00 1490.0 0.354 0.000 0.000 oge 4 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:12:12 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) ▪ 40.0 Wellhead Pressure (psia) 0.0 Bottomhole temperature ▪ 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 66.32 0.00180 Ansari 2 8.500 5700.00 5700.00 0.00 100.00 0.00180 Ansari w • 1 04/02/07 » »> Snap 1.425 7/25/2006 « «< 11:31:33 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** BASE CONDITIONS * ** Rate Intersection Results 1965.15 0 Pr Pressure Intersection Results : . 3 3q IPR Data: Tubing Hydraulics Data f 000 60, CI le- / Bottomhole 1 fili Flow Rate Pressure Flow Rate Pressure (stbfpd) (psia) (stbfpd) (psia) t 1k 0 2900 1 1938 96 2779 10 1921 192 2658 100 1774 288 2538 144 1715 384 2417 287 1517 480 2296 575 1192 576 2175 1150 695 672 2054 2300 310 767 1933 863 1813 959 1692 1055 1571 1151 1450 1247 1329 1342 1208 1438 1088 1534 967 1630 846 1725 725 1821 604 1917 483 2013 363 2108 242 2204 121 2300 0 IL lige 2 04/02/07 » »> Snap 1.425 7/25/2006 « «< 11:31:33 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** RESERVOIR DATA * ** Well Type • Oil Well * ** PVT Properties * ** Oil API gravity 39.000 Gas Specific Gravity (air -l.) 0.700 Reservoir Producing GOR (scf /stb)..: 1000 Average Water Cut (fraction) 0.000 Water Specific Gravity.(water = 1).: 1.000 Solution Gas Oil Ratio Correlation.:Vazquez and Beggs Formation Volume Factor Correlation:Vazquez and Beggs Oil Viscosity Correlation Glaso ge 3 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:31:33 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review «< Darcy with Turbulence factor »> Zone Zone Ave Effective Formation Drainage Wellbore Skin Water # Name Press Perm Thickness Radius Radius Factor Cut (psia) (md) (ft) (ft) (ft) (frac) 1 L. 2900.0 4.000 158.00 1490.0 0.354 0.000 0.000 •ge 4 04/02/07 » »> Snap 1.425 7/25/2006 ««< 11:31:33 System Nodal Analysis Program C 1992 - 2004 Engineer : Dave Roby Dataset : Snap Default DataSet.snp Title : Aklaq 6 - SRPS Review * ** WELL DATA * ** «< Well Geometry Data Selection »> Wellhead Temperature (F) 40.0 Wellhead Pressure (psia) • 0.0 Bottomhole temperature • 100.0 «< Well Geometry Data »> «< Tubular flow »> Flow Measured True Angle EndSeg Seg I.D. Depth VertDepth Temp Pipe Wellbore Zones Number (in) (ft) (ft) (deg) (F) Rough Correl Connected 1 8.835 2500.00 2500.00 0.00 66.32 0.00180 Ansari 2 8.500 5700.00 5700.00 0.00 100.00 0.00180 Ansari SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 1 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 CONSERVATION PHONE (907) 279 -1433 FAX (907) 276 -7542 Paul Mazzolini Operations Manager FEX L.P. 3601 C Street, Suite 370 Anchorage, AK 99503 Re: Exploration Well, Aklaq No. 6 FEX L.P. Permit No: 207 -009 Surface Location: 2955' FSL, 2307' FWL, SEC. 25, T16N, R 11 W, UM Bottomhole Location: 2955' FSL, 2307' FWL, SEC. 25, T16N, R 11 W, UM Dear Mr. Mazzolini: II Enclosed is the approved application for permit to drill the above referenced exploration well. Please note that this permit authorizes drilling activities in the planned hole section only. A separate permit application must be submitted for any plugged back or redrilled hole sections. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. 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. If it is determined necessary to set the 7" casing above the objective formation, it is acceptable to forgo the LOT/ FIT normally required after drill -out. See 20 AAC 25.030 (g). 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. FEX L.P. • • Aklaq No. 6 Permit: 207 -009 Please note that in addition to the proposed logging program, an openhole sonic or density porosity log must be recorded in the surface hole to enable evaluation of water salinity in shallow aquifers at this remote location. If formation testing is planned, a Sundry Notice (Form 403) must be submitted in advance of the operations. Annular disposal of drilling wastes will be adjudicated separately following submittal of an Annular Disposal Application (Form 10- 403AD) and supporting information as required by 20 AAC 25.252. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely I • Nor : - Commissioner DATED this0day of February, 2007 III cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA* OIL AND GAS CONSERVATION COM AION PERMIT TO DRILL 20 AAC 25.005 ? la --, ) la. Type of Work: lb. Current Well Class: Exploratory Q , Development Oil ❑ lc. Specify if well is proposed for: Drill © Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket d Single Well ❑ 11. Well Name and Number: FEX L.P Bond No. SBGT736907 492•2.1•e7 Aklaq #6 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 3601 C Street, Suite 370 Anchorage AK 99503 MD: 7713 • TVD: 7713 • 4a. Location of Well (Governmental Section): 7. Property Designation: Wildcat . Surface: 2307' FWL, 2955' FSL, Sec. 25, T16N, R11W, UM AA -085517 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2307' FWL, 2955' FSL, Sec. 25, T16N, R11W, UM LAS 25297 3/5/2007 • Total Depth: 9. Acres in Property: 14. Distance to Nearest 2307' FWL, 2955' FSL, Sec. 25, T16N, R11W, UM 11361 Property: 2981' East 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 426473 y- 6110601.8 Zor 5 (Height above GL): 16.4 feet Within Pool: 5 mIS SE PUVIBq 16. Deviated wells: Kickoff depth: N/A feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: N/A degrees Downhole: 3941 • Surface: 3093 • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 16" 65# H-40 BTC 80' 0' 0' 80' 80' Permafrost cement to surface 12 -1/4" 9-5/8" 40# L -80 BTC 2500' 0' 0' 2500' 2500' 219 sx Permafrost Lead, 201 sx C 8 -1/2" 7" 26# L -80 BTC 7638 0' 0' 7638 7638 2 Stg (154 sx/141 sx) Class G cen 6 1/8" 5" 18# L -80 STL 788 6850 6850 7713 7713 Contingency Set Inter. At 7012 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redriil and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD RECCI` , Conductor /Structural C v Surface F Eg 9 Intermediate 2 uu Production Alaska Oil & Gal C Liner t )rr5• toO MMi 5 • Perforation Depth MD (ft): Perforation Depth TVD (ft): Anchorage 20. Attachments: Filing Fee ❑ BOP Sketch 5 Drilling Program 5 Time v. Depth Plot 5 Shallow Hazard Analysis 5 Property Plat ❑ Diverter Sketch 5 Seabed Report 5 Drilling Fluid Program 0 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Paul Mazzolini Title Operations Manager Signature It flar2/34 Phone 907 771 -1923 Date 2/6/2007 Commission Use Only Permit to Drill —'7 API Number: G} Permit Ap See cover letter for other Number: , 1: ! "0�� 50- Z. - 2.0d 1 1 -06 Date: • . � . n � requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:[✓] Other: Samples req'd: Yes[ Non Mud log req'd: YesY Non H measures: Yes[ Non Directional svy req'd: Yes❑ No2/4• 10 Ivicli'42.474, 5a) .--' IJIJ0 Q t ©V 4 c I'�(Lt•`rtd , / 2.20 •a7 DATE: p .1 2 J ORI / // APPROVED BY THE COMMISSION COMMISSIONER Form 10 -401 Revised 12/2005 A L- Submit ' Duplicate — 4 '4 Z•Z•f • C7 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMON i 9 2007 PERMIT TO DRILL 20 AAC 25.005 1 :%'.:(1s. Commission la. Type of Work: Drill pi Redrill ❑ 1b. Current Well Class: Exploratory gg - Development Oil ❑ Multiple Zon Re -entry ❑ Stratigraphic Test 0 Service ❑ Development Gas ❑ Single Zone 1;,.. 2. Operator Name: 5. Bond: Blanket gg Single Well ❑ 11. Well Name and Number: FEX L.P. Bond No. SBGT736907 - Aklaq #6 ' 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 3601 C Street, Suite 370 Anchorage AK 99503 MD: 7713 ' TVD: 7713 ' Wildcat 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 2307' FWL, 2955' FSL, Sec. 25, T16N, R11W, UM AA- 085517 • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2307' FWL, 2955' FSL, Sec. 25, T16N, R11W, UM LAS 25297 3/5/2007 - Total Depth: 9. Acres in Property: 14. Distance to Nearest 2307' FWL, 2955' FSL, Sec. 25, T16N, R11W, UM 11361 Property: 2981' East 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface:x- 426473.43 y- 6110601.78 Zone- 5 (Height above GL): 16.4 feet Within Pool: 4.6 miles SE Puviaq ' 16. Deviated wells: Kickoff depth: N/A feet 17. Maximum Anticipat -: Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: N/A degrees Downhole: 3941 Surface: 3093 18. Casing Program: - etting Depth Quantity of Cement Specifications c.f. or sacks Size Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 16" 65# H-40 BTC 80' 0' 0' 80' 80' Permafrost cement to surface 12 -1/4" 9 -5/8" 40# L -80 BTC 2500' 0' 0' 2500' 2500' 219 sx Permafrost Lead, 201 sx Class G tail 8 -1/2" 7" 26# L -80 BTC 7638 0' 0' 7638 7638 2 Stg (154 sx/141 sx) Class G cement 6 1/8" 5" 18# L -80 STL 788 6:50 6850 7713 7713 Contingency Set Inter. At 7012 19. PRESENT WELL CONDITION SUMMARY o be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (meas -d) :\ Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): / Casing Length n � ` S' e` ' Cement Volume MD TVD Structural Conductor / ` 0 , Surface yJ v v Intermediate , (, o ll Production I IV Liner Liner PN".--/ Perforation Depth MD (ft): b V) (1/ Y , Perforation Depth TVD (ft): 20. Attachments: Filing Fee L] BOP Sketch Lf Drilling Program L Time v. Depth Plot Lf Shallow Hazard Analysis U Property Plat el Diverter Sketch gg Seabed Report 0 Drilling Fluid Program gg 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Repress tative: Date 22. I hereby certify that the foregoing is t e and correct to the best of my knowledge. Contact Printed Name Paull /Maazzzoli Title Operations Manager tAA Signature � / i a a Phone 907 - 771 -1923 Date C)1 / 1 7/ ZOO 7 Commission Use Only Permit to Drill API Number: /\'� Permit Approval See cover letter for other ,7,�(� Number: 7∎V • '7 � 50- 27 L p � - � Date: requirements. Conditions of approval : Sam , les required Yes d No ❑ Mud log required Yes d No LJ Hy. ogen sulfide measures Yes 2/ b No 0 Directional survey re uired Yes No /f Other: tita 4 14.4e l /�- Co 61.e �ol[ • APPROVED BY �f D • �� 24' • Approved by: THE COMMISSION Date: V OGNAL Form 10-401 Revised 06/2004 Submit inDuplicate • • January 17, 2007 REC Mr. John Norman, Chair JA N 1 r: ; ,,, Alaska Oil and Gas Conservation Commission Alaska t1 # , 333 West 7 Avenue, Suite 100 "' ( 'films shin Anchorage, AK 99501 AEUt;P;°:' R. RE: Application for Permit to Drill: FEX L.P. Aklaq #6 Dear Mr. Norman: FEX L.P. hereby applies for a Permit to Drill an onshore exploratory well in the NW NPRA area of the North Slo e. The well, called the Aklaq #6, will be located approximately 63 miles S f the town of Barrow. FEX L.P. plans to spud the Aklaq #6 approximately March 5, 2 0 7. - Ice road/pad construction equipment has been mobilized via barge to the existing Cape Simpson staging area for this purpose. Upon receipt of all necessary permits and approvals (including tundra travel authorization), the ice road equipment will be mobilized from Cape Simpson to near the well location via approved tundra travel equipment. Construction of an ice runway and ice pad will occur concurrently, followed by the construction of ice road(s) connecting the runway to the well locations. Upon completion of the ice runway and ice drilling pad, a combination of approved tundra travel equipment and/or bed trucks(if ice road is complete) will transport Doyon Arctic Wolf from Amaguq 2 location to the wellsite, drill the well to TD and test if applicable. At the completion of the drilling program, the drilling rig will be demobilized to Cape Simpson via approved tundra travel equipment and/or bed trucks(if ice road is complete). Pertinent information attached to this application includes the following: 1. Form 10 -401 Application for Permit to Drill — 2 copies 2. Fee of $100.00 payable to the State of Alaska 3. Well Prognosis and discussion of operational considerations 4. Location Plat and Drill Pad Layouts 5. Days vs. Depth Drilling Curve 6. Drilling Procedure 7. Wellbore and Wellhead Schematics 8. 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. 9. Diverter, BOP and Choke manifold schematics 10. Cement Program 11. Drilling Fluid Program • • Mr. John Norman Page 2 As part of this application, FEX L.P. also requests approval for the annular disposal of 1 drilling wastes as discussed in the attachments. Form 10 -103AD will be completed and submitted at the time the required well information becomes available, if necessary. In the event that the 5" liner contingency is activated, FEX requests a leak off/formation — - integrity test waiver on the intermediate casing shoe. This casing string is designed for shale stability and is not required for pressure or well control. Conducting a pressure test will have a negative impact on our primary target and is detrimental to the well design. The AOGCC is requested to treat as 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 FEX L.P. 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- 771 -1923. Sincerely, "?0_4A...e tyez FEX L.P. Paul Mazzolini Operations Manager TF II January 17, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 RE: Request for FIT waiver: FEX L.P. Aklaq #6 Dear Mr. Norman: FEX L.P. is hereby requesting a waiver to the FIT /Leak Off Test requirements of regulation 20 AAC 25.030(f), as allowed per regulation 20 AAC 25.030(g), for the 7" intermediate casing shoe in the well named Aklaq #6, as noted within the APD previously submitted and currently under review by the AOGCC. This FIT waiver request is due to the fact that the 7" intermediate casing string is designed to mitigate time sensitive shale stability concerns prior to drilling into the primary objective; thereby ensuring that we have adequate time to completely evaluate the primary objective. The 7" casing string is not required for anticipated wellbore pressures or well control, only to secure the time sensitive shale that is directly on top of this objective. Conducting a pressure test on this 7" casing shoe will have a negative impact on our primary target, and will be detrimental to the wells evaluation needs. The AOGCC is requested to keep confidential all information included in this request, as information in these documents is drawn from research and data proprietary to FEX L.P. If you have any questions or require additional information, please contact me at 907- 771 -1923. Sincerely, ?OcA.02-f Paul Mazzolini Operations Manager FEX L.P. • • FEX L.P. Aklaq #6 Overview and Timetable FEX L.P. plans to drill an exploratory well, the Aklaq #6, in the NW NPRA this winter. Aklaq #6 will be located approximately 63 miles south west of Barrow. The well will be drilled from a temporary ice pad with spudding estimated to occur approximately March 5, 2006. The well is planned as a vertical hole. The well will be accessible via aircraft to one of two potential ice runway locations, then via ice road across the frozen tundra and via tundra travel vehicles from the Meltwater 2P Pad. A map showing the details of the runway locations, ice road route, and tundra travel 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 the weather conditions allow. Ice road/pad construction equipment has been pre - mobilized via barge to the existing Cape Simpson staging area for this purpose. It is lanned that the ice road equipment will be mobilized upon tundra travel opening p p P g from Cape Simpson to near the well location via approved tundra travel equipment. Construction of an ice runway and ice pad will occur concurrently, followed by the construction of ice road(s) from the runway to any additional well locations. Upon completion of the ice runway, ice drilling pad and ice roads, Doyon ArcticWolf will be moved from FEX location Amaguq #2 to the wellsite via ice road. The rig will be supported with personnel and supplies flown into the ice runway and transported to the wellsite via ice road. Some heavy supplies and equipment may be brought overland via approved tundra travel equipment. Well testing may be performed. Current plans are to plug and abandon the well prior to the end of the 2006/2007 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 2007. If the well proved to be a dry hole, it will be plugged and abandoned prior to the rig being released from the wellsite. If the well is to be tested, it will be completed, and tested with out the rig on the well after a testing tree is installed. If the well test is promising, the well may be 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 discouraging, the well will be plugged and abandoned at the conclusion of testing. • • Operational Considerations Permafrost Based on offset wells and seismic data, the permafrost is assumed to be present from the surface to approximately 1225'. While drilling through the permafrost there is a slight chance of hydrates and shallow gas pockets. These risks will be mitigated by weighting the mud to 10 ppg and minimizing circulating time to keep hole in gauge. 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 2500' TVD setting depth for the 9 -5/8" surface casing is located in the Nanushuk formation. The casing shoe will be set in competent shale within the Nanushuk in order to yield a strong shoe test, yet leave some of the sands in the Middle Nanushuk exposed between the casing shoe and the Lower Nanushuk for later annular disposal of waste drilling fluids. Lost Circulation and Sloughing Shales Some of the wells in this general region encountered sloughing shales below the HRZ and lost circulation in and near their target horizons. The Aklaq #6 casing and mud programs have been designed to take these potential problems into account. The preferred well design for this well is a long string of 7" casing to be set at TD, a contingency design is included in this application. The contingency design sets intermediate casing just above the target horizon to isolate sloughing shales, and allows for the mud weight to be cut to minimize lost circulation potential within the target zone. When TD is reached, the target interval(s) will be evaluated as an open hole, and if conditions are favorable, cased with a production liner. Pressures Anticipated pore pressures are derived primarily from the histories of offsetting wells in conjunction with a pore pressure analysis completed using seismic velocities. As shown on the attached pore pressure plot and maximum anticipated surface pressure (MASP) calculations, the highest expected pressure is at 7713' feet and is 3941 psi (9.83 ppg EMW) and will result in a maximum pressure at the surface, with a full column of gas, of psi (see included calculations). A 5,000 psi WP BOP and wellhead system will �AA 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. Drilling Within Annular Blowout Preventer Limitations As shown in the included pore pressure prediction study, the highest pressure expected above the surface casing setting depth (7.71 ppg equivalent mud weight at 2500' TVD less a 0.11 psi/ft gas gradient) is 1003 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 the 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 of Doyon ArcticWolf 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 3093 psi, it is planned to routinely test all BOPE to 100% of its rated working pressure (- 5,000 psi) (except the annular BOP which will be tested to 50% of its rated working pressure (2500 psi) . 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 5,000 psi (100% of rated working pressure). Well Deviation The Aklaq #6 will be drilled as a vertical hole. Directional control will be monitored via MWD in all hole sections. Depending on the outcome of the target horizon penetration, at least one wellbore directional sidetrack may take place. ��� ckc) i c o r ovv ■ ® c H2S None of the offsetting wells encountered measurable amounts of H2S in the intervals to be drilled, and it is not expect that drilling the Aklaq #6 well will encounter H2S. However, the drilling rig will be wired with operating sensors, enhanced by additional sensors ties into the mud logging system, to continuously monitor for the presence of H2S. Research of fresh water in shallow formations A review of the water salinities was completed on Aklaq #2 between 2500' and 4500' to determine the possibility of fresh water aquifers. In this interval the formations are mostly shale with no water bearing sands. The induction neutron/density wireline logs were examined and determined sands in Aklaq #2 at 2100ft, 2194ft and 2244ft have Rwa's of 0.789 at 70degF which results in a water salinity of approximately 7250ppm. Given that salinities usually increase with depth we would not expect to encounter sands with salinities lower than this below our planned casing shoe at 2500ft. The research concluded that the likelihood of any water with salinity lower than 3000 ppm in our drilling horizons was highly unlikely. • Drilling Waste Handling t-i0") GAP \c cc►. or ��fc Waste drilling mud from the well will be pumped into subsurface formations at approximately 3500' TVD via the 9 -5/8" surface casing by 7" intermediate casing annulus. Cuttings will be hauled to an approved disposal facility for processing and disposal. Prior to on -site disposal or hauling, the waste drilling mud will be temporarily stored within a betined storage cell in heated tanks; while the drill cuttings will be temporarily stored in bermed storage areas on the ice pad. Diagrams are included with this application that shows the ice pad layouts with the proposed location of the storage cells. Additional Information Additional information on operations such as formation tops, logging, mud logging, etc. can be found on the attached Aklaq #6 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 pipe is set. Contacts The contacts within FEX L.P. for information are: Reporting and Technical Information: Paul Mazzolini 907 - 771 -1923 Tim Flynn 907 - 771 -1929 Scott Volk 907 - 771 -1924 Geological Data and Logs: Sue Love 403 - 693 -2584 • . i 11 , . ... . 4 . . 1,,:' ‘ + ‘. .4 o' , .. j 1 , 1 -''. - IA* ' t , Ai., 11 ..- t i 1 i * % 1 1 * ' 1 t totted o I Z• ‘4.• . 1 ,:ir, 1 '' 1 19 I 19 , .. ti„.„, * tvi ' '., ', --......' - ..-4 Ai ` I 1 T X..t 4DM li • LI I lei • 1 'ill, - ,,t...- t-. r t ; -,Et 7-4 1. I t * ,til.* i-I•114.**W44,4i. , ; l',W-, r ef. ak... __ 4110„i.: ,,,,: ,,,,, ..„ , nopio, ? ,,,1 - i...k ,,.. A, 4 fccr •:' ""', •..,,, . •,• ,,,..-k .,...,..„, 4 , , i A. 1 ,,,, 1 ..... L . - 1 - ; f y . t. . 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Promotion UTN Zone 5 (m) MAO 27 Umiat Menthan infrared (2002) 000 basemap provided by Ma Bureau o Lana Management t (BLM) emillINE• 2005-06 • D ROUTES II Snow-Packed Roads-Perm Drill Sites-Adde (Drilled) EXP -P .— Ice Roads-Permitted 2005-06 2005 06 DRILLING PROGRAM 1 D.-) DFEnnXiiii E emille. _ Ice Runways SCALE SS Il -e s 6 - CONFI DENTAL ; WINTER A Ice Roads-Pr l ed tte 2 d 0 2 0 0 6- 0 0 5- 7 i [ Snow-Packed Roads-Proposed po 2006-07 Runway-Proposed 2006-07 ,i NO NPR- 60 r . °0 f/ �' r � U �� Q �� ROUTE DISTANCES (AKLAO YY) MILES ./'"N0� q ° p DEADHORSE AIRPORT TO MELTWATER , ,,.r' /�"' - y�, (DS2P PAD) 87 — / j .� f : ti c / , = ) ~ ,,,,,. , -., *B.:,,,..___—...... MELTWATER TO AKLAO 103 143 ! % \ � CAMP LONELY TO AKLAO NB 38 / Barrows 4� re CAPE SIMPSON TO AKLAO MO 70 /.oa.Lb __ 4f fr �z. ��--: = P BARROW TO AKLAQ NO 91 ��,�� 1 1 , - 4Y ---�:( RUNWAY Y7 RUNWAY Yt � e J P y T . (MILES) (MILES) AO -- ° � / , (' fl tl °I' d ' 'o ^--° 4 � ."' . A ' l . f ' 6 _0 a .. Cape Simpson AMAGUO 12 19 35 yy - � �/' / -- -- -_,__ AKLAOYMO N7 4 19 Skull CI wary �� A AKUO N2 e e r Y . G7~l� p t# s, pe S41114011 -{T;;--. Pklagyaaq Yt . 44 mi AJd q 82 --„T-,—, A q 5 Capa Simpson 1 r �1 Ama AKLAO 116 21 6 9 Y2 A' � t .� �" " � L R ' i' ° - - - "' Nan Distances are approximate • ` � _ .{ [ Camp Lonely lk iriffit ..e t +■ ` '•� a x rc � b e S r ...•' gn �. �� c.4. A•� ateai'i . M � ► M Lips „I) At , ' i t t :r, I Aklaq #6 I ogfe . �l .SO a r h o 1 '� , 7 v K ` a ay kto_{s41 I {{ � LI W ... 21 , 4 i[ffii 1' ,a ,R!' w° i` Atgasuk R 1-�� I llis i 4 C' 1 YViAISJ F! 1. 7 "' „ l „ r � 1�f'� g a g . ...,..., i . stm t A llii i P. . ,. - .. .., . _ , ...., 0 no , • ... . 11B11 ,.. �:�N N �`lt.r e�wrttu�ll alrawriiN-.-N 1� y „ ; _ y _ _Nu � i t3 .� ala l� l E ,sr ' I t + a O i i Deadhorse Air rt DS2P ° , il hill � - _ .. � ��� � . • ��� p � � 4 - �� ` ,+ � � { "'w iii' ''r+�"raf l = ' (Me �� rF ) - ) t - i , i ,, , * arl ' tati mil • .. , ..,,,,,....it. , 11, i 114 1 1.. . N7i.,, voi,,, dm mil 0 ilm l -- . .a x. ” ...1 � 1r��_ f ��7 � = "'.' F F,X L.P. pk ,, „,,,,,...1...,... 1? ILPBINIIIEIIIgl! Drele Wel Site 1200`+2008) A Former DEW Una Site NORTH SLOPE OPERATOR n EXXON MOBIL /,1r}.i•. 0 ProposodYWl Saes (20062007) — BethYmWnc Contour (m) ® ENI NM FEX s.: v _ ■ Ica Access Routes ( re i National Petroleum Resee-0Alaska L_ .i An in PETRO- CANADA ; , mdi - � � . PoNnhslkeRunwrys VYaaec BROOKS RANGE PETROLEUM GROUP PIONEER NORTHWEST NPR -A EXPLORATION s— SnowAacessRWles —Roads u BP - SHELL DRILLING PROGRAM ... — Ppelines =CHEVRON a TOTAL 1 ' r 9. ,,$ . � CONOCOPMILLIPS _ Xg• DEVON l _ 1 OTHER OPERATORS '1N' me ,., Note: Alaska Albers Equal Area Conic, NAD 83 } x Lease data is accurate as o106 /19/06 SCALE: FIGURE: Lease data and unit boundaries provided 0 10 20 Miles „ r•' A r.. by Mapmakers Alaska Inc. (02001 Mapmakers Alaska) 1 t I Lynx 15047- 407.mxd 10/1706 600 • FEX L.P. Aklaq #6 Well Prognosis Well Name: Alclaq #6 Surface Location: 2307' FEL, 2955' FSL, Sec. 25, T16N, RI 1W, UM Target Location: 2307' FEL, 2955' FSL, Sec. 25, T16N, R1 1W, UM Bottomhole Location: 2307' FEL, 2955' FSL, Sec. 25, T16N, R11W, UM Elevation: Ground Level 16' AMSL Drill Floor (DF) 18' 9" AGL Kelly bushing (KB) 34' 9" AMSL Planned TD: 7713' TVD Drilled Depth Error Bar Tops TVD ft +1- ft TVD Base Permafrost 1225 200 Nanushuk group 1325 250 Nanushuk topset sst. 2714 —ci.$)t. AS S 200 Torok 3578 200 Torok sand 1* 4713 200 Torok sand 2* 5736 200 HRZ 6539 150 LCU (Lower Cret. Unconformity) 6739 150 BCU 6739 150 Uppper Kingak (Miluveach) 6740 150 Kugrua sandstone ** 7012 150 Lower Kingak 7062 150 Pliensbachian (J2 marker) 7513 150 TD (Lower Kingak) 7713 150 * Primary Objective ** Secondary Target • Depths are referenced from the KB • Depth errors reflect uncertainty associated with the depth conversion of the seismic interpretation, plus uncertainty in the seismic picks. • Cores: 60' core planned in the Kugrua Sands /Cie, • / 4. Planned Logs: Surface Hole: 80' to 2500'( + /- 200') � / Lek SZ 4 44 : 11141‘11 LWD only: Gamma Ray / Resistivity .crv, er ,�, Intermediate /Production Hole: 2500' to 7713'( + /- 0') 2.2 t•d7 LWD: Gamma Ray / Resistivity /Neutron/Density /Sonic/Pressure while Drilling Contingency if long string is not achieved Production Hole: 7012' to 7713'( + /- 200') LWD: Gamma Ray / Resistivity /Neutron/Density /Sonic/Pressure while Drilling Depth Log Provider BSC - TD STAR - multi arm dipmeter /borehole imager Baker BSC - TD XMAC - cross dipole sonic with shear Baker (TD -7713' TVD) BSC - TD CDR -C - cont. directional survey w /GPIT combo Baker (TD -7713' TVD) BSC - TD Density /Neutron, Spectral GR, Resistivity Baker (TD -7713' TVD) BSC - TD RCI - for pressure and samples in primary and Baker secondary zones, must have multiple sample chambers and pump out capability BSC - TD MREX - for effective porosity analysis Baker (TD -7713' TVD) BSC - TD Rotary Sidewall Cores (RCOR) - primarily over main Baker (TD -7713' target intervals (-4700' - 7100') TVD) Mud Logging: Mud Logging will be in operation from the base of the conductor casing to well TD. Services will include sample collection; plotting of ROP, lithology, and drilling parameters; show description; gas analysis of cuttings; and gas chromatography. Samples will be collected every 30' from the base of surface casing to TD, and every 10' in zones of interest. The wellsite Geologist will adjust the interval or sampling rates as required. • • Aklaq #6 Drilling Procedure — Base Case 1. Use pre set rig to drill 24" hole to +/- 80', set 16 ", 64 #, H-40 BTC conductor casing. Pump sufficient cement to bring cement returns to surface. 2. Move in and Rig up Doyon Arctic Wolf. 3. Attach landing ring to conductor. Install diverter and function test. Notify regulatory agencies 48 hours prior to test. 4. Drill 12 -1/4" hole to the surface casing point of +/- 2500' MD/TVD find a good shale section to set shoe. Run and utilize MWD and LWD tools throughout this hole section to monitor hole angle and to ensure the hole remains vertical, as well as collect logging data. Run and utilize MWD and LWD tools throughout this hole section to monitor hole angle and to ensure the hole remains vertical, as well as collect logging data. 5. Condition hole for casing. POOH. 6. Run and cement 9 -5/8 ", 40 #, L -80 BTC casing to surface. Surface job is to be cemented with an inner - string job. Employ a lightweight permafrost cement lead slurry followed by a high strength Class G tail slurry. Pump adequate excess cement to ensure cement reaches the surface. 7. Nipple down diverter and nipple up BOPE. Test BOPE. Notify regulatory agencies 48 hours prior to test. 8. Make up 8 -1/2" drilling BHA and RIH to the top of the 9 -5/8" float equipment. Pressure test the casing to 2,500 psi for 30 minutes. Record the pressure test and fax the results to Anchorage office. 9. 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 the Anchorage office. 10. Drill an 8 -1/2" straight hole to core point at +/- 7012' cut 60' of core and continue to TD at +/- 7713' MD/TVD. Run LWD logging tools in the drill string as required for formation data gathering. 11. Condition the hole for logging. POOH. 12. Rig up wireline. Run wireline formation evaluation logs per logging program. Rig down wireline. 13. RIH with 8 -1/2" BHA and condition hole for casing. POOH. 14. Insert torque rings and make up reaming shoe to run and cement 7 ", 26 #, L -80 BTC - Mod casing. Pay close attention to trip and casing running speeds as to not swab or surge the hole. Use Tesco running and circulating tool to ream and circulate the casing as necessary. If hydrocarbons are identified in the upper zones, pump cement 500' and over the hydrocarbon zones. If no hydrocarbon zones are identified, a contingency single stage cement job will be implemented covering a minimum of 1000' above the intermediate shoe. This will be confirmed once log data is available. 15. TOC 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. 16. Abandon or suspend the well per applicable regulations, depending on results. 1 ' - to cx.Q0\coo • • Aklaq #6 Drilling Procedure — Contingency Case 1. Use pre set rig to drill 24" hole to +/- 80', set 16 ", 64 #, H-40 BTC conductor casing. Pump sufficient cement to bring cement returns to surface. 2. Move in and Rig up Doyon Arctic Wolf. 3. Attach landing ring to conductor. Install diverter and function test. Notify regulatory agencies 48 hours prior to test. 4. Drill 12 -1/4" hole to the surface casing point of +/- 2500' MD/TVD find a good shale section to set shoe. Run and utilize MWD and LWD tools throughout this hole section to monitor hole angle and to ensure the hole remains vertical, as well as collect logging data. Run and utilize MWD and LWD tools throughout this hole section to monitor hole angle and to ensure the hole remains vertical, as well as collect logging data. 5. Condition hole for casing. POOH. 6. Run and cement 9 -5/8 ", 40 #, L -80 BTC casing to surface. Surface job is to be cemented with an inner -string job. Employ a lightweight permafrost cement lead slurry followed by a high strength Class G tail slurry. Pump adequate excess cement to ensure cement reaches the surface. 7. Nipple down diverter and nipple up BOPE. Test BOPE. Notify regulatory agencies 48 hours prior to test. 8. Make up 8 -1/2" drilling BHA and RIH to the top of the 9 -5/8" float equipment. Pressure test the casing to 2,500 psi for 30 minutes. Record the pressure test and fax the results to Anchorage office. 9. 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 the Anchorage office. 10. Drill an 8 -1/2" straight hole to the top of the Kugrua sand at +/- 7012' MD/TVD. If it becomes apparent that there is significant risk of shale stability problems stop drilling at the Kugrua top. Use LWD logging tools in the drill string to help identify problem shales. If time or hole conditions permit rig up and run wire line logs. 11. Condition hole for casing. POOH. 12. Insert torque rings and make up reaming shoe to run and cement 7 ", 26 #, L -80 BTC -Mod casing. Pay close attention to trip and casing running speeds as to not swab or surge the hole. Use Tesco running and circulating tool to ream and circulate the casing as necessary. If hydrocarbons are identified in the upper zones, pump cement 500' and over the hydrocarbon zones. If no hydrocarbon zones are identified, a contingency single stage cement job will be implemented covering a minimum of 1000' above the intermediate shoe. This will be confirmed once log data is available. 13. Make up a 6 1/8" drilling BHA and R1H to top of 7" float equipment. Pressure test 7" casing to 2,500 psi for 30 minutes. Record the pressure test and fax the results to Anchorage office. It is our intent to get a formation integrity test waiver for the intermediate string. The intermediate string is not set as a pressure control string but only to get sensitive shale behind casing. A formation integrity test runs a risk of damaging our primary production zone. 14. Drill out shoe and trip for core. Cut 60' of core at the top of the Kugrua sand from +/- 7012' to 7072' MD/TVD, retrieve core, PU Drilling BHA and continue to TD at +/- 7713'. 15. Condition the hole for logging. POOH. 16. Rig up wireline. Run wireline formation evaluation logs per logging program. Rig down wireline. 17. RIH with 6 1/8" BHA and condition hole for casing. POOH • • 18. Run and cement 5 ", 17.83 #, ST -L Flush joint liner. The liner must be run to have a minimum of 150' of overlap. Pump sufficient cement to bring the cement 100' above liner top. 19. Abandon or suspend the well per applicable regulations, depending on results 1' u■e-fr% 'X — NPRA Exploration CONFIDENTIAL Drilling ifl Project Aklaq #6 1. 2007 Welibore Schematic 1 -40-- 24" Hole r ` % , 1 16" 65# Conductor . @ +/ -80' MD / TVD , a i — — 12 -' /a" Hole a I 9 -5/8" Tail cement top 2000' I j I � i % %3 9 -5/8" 40# L -80 BTC Casing @ +/ -2500' MD / TVD 1 1 I 1 i % 1 1 I 1 % 1 1 1 I , 5 1 1 ■ 8 -' /z" Hole ; 1 1 o 1 1 5 , 1 1 I 1 1 5 1 7" Cement top of stage 2 cement job 1 ',' % 1 4500' to be confirmed by logs 1 1 1 o 1 I o 1 1 i 1 1 1 1 5 1 1 % i I 1 ; ; , 7" Cement top of stage 1 cement job 1 % 1 6600' 1 1 1 i % 1 1 % 1 I 4 i I 1 i 1 i i 1 1 $ 1 5 1 % $ 1 i 1 1 1 1 i 1 7" 26# L -80 BTC -Mod Casing o % i 1 @ +/- 7713' MD / TVD 1 TD @ +/- 7713' MD / TVD ** See line #la (Long string) and #12 (Contingency) of drilling procedures for contingency single stage cement job Drilling '. ' eX -- NPRA Exploration 0 CONFIDENTIAL Project : <. Aklaq #6 2007 Wellbore Schematic - Contingency - ' 1 f- 24" Hole ', 16" 65# Conductor i� @ +/ -80' MD /TVD t i i 0 ?• =:: o i 12 -V" Hole o 1 9 -5/8" Tail cement top 2000' 1 9 -5/8" 40# L -80 BTC Casing @ +/ -2500' MD / TVD %i o -♦- — 8 - /Z" Hole o 7" Cement top of stage 2 cement job w 4500' to be confirmed by logs 7" Cement top of stage 1 cement job 6012' estimate g i 5" Liner Cement top 6750' .:_: i 5" Liner top 6850' it ' 7" 26# L -80 BTC -Mod Casing it ii @ +/- 7012' MD / TVD ii it 14- it 1 ii if ft ;, ' 1 'i 6 -1/8" Hole it .41 1 i it 1 II i ',Il 5" 18# L -80 BTM -Mod Liner Top Set @ +/- 7713' MD / TVD TD @ +/- 7713' MD / TVD ** See line #14 (Long string) and #12 (Contingency) of drilling procedures for contingency single stage cement job . --AO • , 0 01- 1 j 1 1 V ' I 1 .■41 ! ammo { . 3 '3.5000. 303 00 33 , 3 '3-500C 4C0 33 , 0'53.9 Am. 0. 33 1..-f 313.2 AAA 9, , 1 030 . w • LA. 8 ,35 11 - 0103 i 330 8 "003 80 ,2' 8 005 , L ,, .. V! . - L 41' ■ e i , . . . . , . . , . .0., ■ I , 1 . , . ,-------4tD-- _„,„,.7. - 0 g \ '449 3 . 3-5000 000 ?0 .3.A . 1 • 3 VA 1 3. 11- 000 8300 20 38 . ! . 1 . 1 i , . 341 3 AIN 7.J1 3 3/3-5000 3-33 1 . , _ - 233 8 047 • r t" —3 - - Ill ..............A: 0 30.0033 32 . , ....,3:13.88_,-, 11,3 t 2==== 1 3.38 ER , / . a . . , ■ 111111 .... itar7-7----s -3000 3 23-34: 23 A 1 11 II 1 •F-7■••- .-,-,■,, e ell, e e efit 1 :0,23 a m,,,, 0363 1 .n3, t a iL 1 . 21 -, .1 I : PR°. lik4i ; .03e 3 3333 :3.3, -'10r31%,"'NZEACC"' 8 .2C4FA RtinmotO 3003 -a: 233239-003 29-330-3°0 . .2-• 3 23 3 2037 —'"......s.' ' 0 000* 0000 22.13• 0 t .4 , r ' 11 " - N I , 1 1 ;1,:;•)41 hi 1, : 1-'. ) , '''T ,E i 1 • ' 010.31 li 1 i • - \ ' A-Ws-500C ZOOEL 80 . ! . 1 , . 1 G . I 1 . 1 I . . ' I ; . 1 , = 0, 3,• I 0 : 1 2, 00 3.33., 3,, 20. 8807232. 00. 323 ' . 33 ,c... rn - •:as 4^. , . 30, 88 0 - 23 1 33 3.32., '002 1 1 98i 00 3. AL A3223.-503 3 ' 00 .3 AG • ' I.1 THROUGH BORE SYSTEM i \ 1 / 1.6 X 9 5/8 X 7X 312 ____\ . 2830 II 8 .118 - ',Mee I DE:Sc ON . ! 1 I 8 1 , 5363 , 1 ,ANCNC 8.. 1 I '....."-• I - 84 13- . ;:.tiS ' 1 2 1 = [ ' 8 ' 1 61083 1 :AS, 3-2.113 ASSE3.39, 1 I tir 1 .,_7 8.8 50 1 3 I - 3.; - , 0 • r 1 ..., .:1 ,.... I . . 1 ; 1 2- 3 3 1 -2.02. 8 33 3 80 88 A3, ! 1 1 8 ,0132-0003 AZARTE8 83, t 75 I 0 3E AS, 1 02 - 3- I AD>. ASS' 33 . SEALS .1 3. ■ 3 38 I 1 1:7 1 ,1 i 8 '24,3- MO I 3 i I ■ 12 - 093- E - : r .L4 nr pa ■ 20... 2.0 1 0 A... .2013.3 1::7.74.7t.:41 . 7 4 1t. "3 r.S.1131 "I ' C '''' . 1 1 21 .. 0 ' 2 '. , . • Aklaq #6 Pressure Calculations and Drilling Risks 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 Offset well study and a "Pre -Drill Seismic Pore Pressure Prediction. The MASP will be calculated using a pressure gradient derived from historical and seismic pore pressure data. From the historical and seismic pore pressure prediction, (See Pore Pressure Study section) the highest formation pressure expected in the final / hole section is 3093 psi at a depth of 7713 TVD (or .511 psi /ft). This line was derived using maximum predicted fracture gradient data for this area based on historical regional data and seismic interpretation. Utilizing this data, at the 7" casing shoe of 7012'TVD the maximum predicted fracture gradient is 1.03 psi/ft or 19.8 PPG EMW. Complete evacuation of the wellbore, except for a 0.11 psi /ft gas gradient, is assumed. Pore Drilling Fracture Pressure below Casing setting Gradient Gradient MASP BOPE Casing size Depth (Seismic) (Seismic) Drilling Rating 16" 80 ft TVD 1.03 psi /ft .511 psi /ft 32 psi 2000 psi 9 -5/8" 2500 ft TVD 1.03 psi /ft .511 psi /ft s 5000 psi 7" 7713 ft TVD 1.03 psi /ft .511 psi /ft 3093 psi 5000 psi ' MASP Calculations Where: MASP = Maximum Anticipated Surface Pressure FG = Facture Gradient at the casing seat in ppg FPP = Formation pressure gradient at next casing seat derived from siesmic in ppg FPP0 = Formation pressure gradient at next casing seat derived from Maximum offset pressure in Hunter A in ppg D = Depth of casing shoe in ft Dn = Depth of next casing shoe in ft 0.052 = Conversion factor from ppg to psi/ft 0.11 = Gas gradient in psi /ft • • Drilling below 16" Conductor MASP (shoe fracture) = [FG - 0.11] x D = [(.511) — 0.11] x 80 ft = 32 psi Or MASP = [FPPS — 0.11] x Dn (formation pressure) = [(.511) — 0.11] x 2500 ft (from seismic) = 1003 psi As shown in the included pore pressure prediction study and the above calculations, the highest pressure expected above the surface casing setting depth (7.7 ppg equivalent mud weight at 2500' TVD less a 0.11 psi /ft gas gradient) is 1003 psi; which is within the 2,000 psi working pressure rating of the diverter. V' Drilling below 9 5/8" Surface MASP (9 5/8 "shoe fracture) = [FG - 0.11] x D = [(1.03) — 0.11] x 2500 ft = 2300 psi Or MASP = [FG - 0.11] x D (7" formation pressure) = [(.511) — 0.11] x 7713 ft = 3092 psi Therefore, MASP in the 8.5" hole section isy0 psi and the 5,000 psi BOPE system to be used will be adequate. If the liner contingency is activated the following calculations would apply: MASP (7" shoe fracture) = [FG - 0.11] x D = [(1.03) — 0.11] x 7012 ft c . o .k N os�' � = 6451 psi Y Or MASP = [FPP — 0.11] x Dn (formation pressure) = [(.511) — 0.11] x 7713 ft (from seismic) = 3093 psi Therefore, MASP in the 6 1/8" hole section is 3093.0 psi and the 5,000 psi BOPE system to be used will be adequate. • • Well Proximity Risk: The nearest wellbore to the planned wellbore of the Aklaq # 6, is the East Puviaq #1 test well located approximately 4.7 miles southeast. Therefore, there are no nearby wellbore proximity risks. Drilling Area Risks: 12 -1/4" Surface Hole — 9 -5/8" Casing Interval EVENT RISK LEVEL Miti • ation Broach of Conductor Low Monitor cellar continuously during drilling interval. Gas Hydrates Low r If observed: control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin. Gravel/Sand Sloughing to Moderate Increase mud weight/viscosity, pump high viscosity +/- 500' sweeps. Monitor fill on connections. Hole Swabbing / Tight hole Moderate Circulate hole clean prior to trip. Proper hole fill on Trips utilizing trip sheets, pumping out of hole as needed. Possible Thaw Bulb / Low Watch return viscosity for signs of thinning. Water Flow Increased mud weight/viscosity as needed. Lost Circulation Low Mitigation by good hole cleaning practices. Reduce mud weight if possible. If losses occur, reduce pump rates and lower mud rheology, use LCM material. 8 -1/2" Production Hole — 7" Casing Interval EVENT RISK LEVEL Miti . ation Shale stability in the Moderate If possible drill within time window of four days and interval below HRZ run casing. Use bridging agents to prevent invasion of mud into the natural fracturing. Once the fractures are sealed maintain mud wt. to hold back shale. Shale is very sensitive to swabbing and surging, control trip speeds and follow proper drilling practices while paying close attention to the on bottom pressure data. Pay close attention to hole cleaning and mud hydraulics. Massive shale sloughing may overload the hole and packoff annulus. See hydraulics program for recommended hydraulics. Lost Circulation Moderate Monitor hole cleaning efficiency. Mitigation by good hole cleaning practices. Reduce mud weight if possible. If losses occur, reduce pump rates and lower mud rheology, use LCM material. Differential Sticking Low Periodic wiper trips as needed for hole conditions. Do not leave pipe static for extended periods. Abnormal Reservoir Low Follow programmed mud weights, monitor well, Pressure increasing mud weights as needed. Ensure adequate kick tolerance prior to drilling pay interval(s). FEX L.P. Aklaq #6 Casing Properties and Design Internal Collapse Tensile Strength Size Weight Grade Connect. Yield Resistance Joint Body TVD MD Design Safety Factors* Oa) (Ib /ft) 1psi) ( psi) (1,000 lbs) 110 u T B C 9 -5/8 40 L -80 BTC 5750 3090 979 916 2500 2500 10.62 2.99 2.64 III 7 26 L -80 BTC -Mod 7240 5410 641 607 7713 7713 3.64 3.77 1.23 5 18 L -80 STL 10140 10500 457 422 7713 7713 3.65 3.28 2.76 T = Tensile design safety factors are calculated using pipe weight less buoyancy. B = Burst design safety factors are calculated using Maximum Anticipated Surface Pressure. C = Collapse design safety factors are calculated assuming complete evacuation of the casing. • 111/ • Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Note that the terms used in these procedures 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 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 support 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. Pull back up into the shoe. 3. Close the BOP (ram or annular). 4. Pump down the drill stem at '/ to 1/2 barrel per minute. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) versus drillpipe pressure until the appropriate surface pressure is achieved for the FIT at the shoe. 6. Shut down at the required surface pressure. Hold for a minimum of 10 minutes or until the pressure stabilizes. Record time versus pressure in one - 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 allowing for an appropriate amount of kick tolerance in case well control measure are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular disposal pumping is planned on a well, the formation below the surface shoe is taken to leak -off • • This ensures that future disposal fluids can be pumped away without risk of damage to the surface shoe. If two attempts at establishing a leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT Limit per above), then an open hole LOT is performed. Annular disposal pumping is planned on this well; the formation below the surface shoe is to be taken to leak-off. This ensures that future disposal fluids can be pumped away without risk of damage to the surface shoe. If two attempts at establishing a leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT Limit per 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 a FIT. Since this project will require the use of annular disposal once an annulus is available, our plan is to perform a LOT at the surface casing shoe, and then perform an OH LOT after drilling through a perspective sand zone below the casing shoe. • Pore Pressure Study A review of the public records of the existing wells drilled in the NPRA and scouting information gathered from other operators indicate that the formations to be drilled are normally pressured. Although not identified at the drill location, care will be taken in case of encountering shallow gas pockets or possible anomalous pressures below the base of the permafrost (approximately 1200' below MSL). This shallow pressure increase has been noted in the local well control and was drilled with mud weights ranging between 10 and 10.5 ppg. There is also a potential for slight over- pressure (10+ppg EMW) from the top of the HRZ shale until TD. An examination of the shallow seismic at the location and comparison with the 2 key wells, Puviaq #1 and Aklaq #2, (Figures 1 and 2), show no observable bright anomalies that may indicate shallow gas or hydrates. The two recent wells in the area; Puviaq #1, (38 miles NE), and Aklaq #2 & 2ST, (24 miles NE), experienced no abnormal pressures during drilling. Puviaq #1 TD'd at a depth of 7,900 ftssmd, with FIT at 1450 ftssmd of 16.2 ppg, and a LOT at 3195 ftssmd of 16.1 ppg. Aklaq #2ST TD'd at a depth of 8,300 ftssmd, with FITs at 2460 ftssmd of 16 ppg and at 7605 ftssmd of 10.5 ppg. A LOT was also performed at 2850 ftssmd of 16 ppg. The Aklaq #6 well is prognosed to TD at a depth of 7713 ftssmd. The logs, pore pressure and overburden interpretations for these 2 key wells are contained in figures 6 & 7, and from this well information, a stability prediction for the Aklaq #6 location was made, (Figure 8). Pressure Prediction Procedure Well Modeling - lkpikpuk #1. S. Simpson #1 1) A local normal compaction trend line (NCTL) was calculated using gamma ray and sonic logs from the Ikpikpuk #1 and S. Simpson #1 wells. The compaction trend was calculated using a semi -log methodology and was consistent in both slope and intercept at each well. 2) The difference in interval transit times (ITT) recorded by the wireline sonic logs and the calculated by the downward projection of the NCTL was measured. These values are the travel time differences, MT. 3) A second -order polynomial translation trend model was developed which translates MT to pore pressure gradients. This model was found to be consistent with other trend models in the area: PP= C2 *MT +C1 *MT +CO where: C2 = 2.57x10 Cl = .119231 CO = 8.94231 4) Interval transit times (ITT) were derived from high - resolution 2D seismic velocities recorded at each well location and compared to the NCTL calculated from gamma ray and sonic logs. The slope of the seismic NCTL was found to be an approximate match for the average NCTL measured in the wells below 1400 ft. • • The seismic NCTLs did not match the NCTL measured in the well above approximately 1400 ft; this is most likely due to low fold in the shallow seismic data. Seismic fold was sufficient and seismic data quality was reliable for pressure prediction below 1400 ft. Figure 9 shows the average NCTL measured from the sonic logs (brown line) plotted against the calculated interval transit times derived from the seismic velocities (green line) at the Ikpikpuk #1 and S. Simpson #1 wells. 5) Pressure gradients were calculated for the Ikpikpuk #1 and S. Simpson #1 using the translation trend model (Step 3 above). The predicted pressures were compared to mud weights and DST test results and found to be reasonable in value (Figure 9). Application of Model at Proposed Well Location 1) A best -fit normal compaction trend line (NCTL) was estimated at the Aklaq #6 proposed well location using the available seismic data. The slope of the best -fit NCTL matched the slope of the average NCTL measured at the Ikpikpuk #1 and S. Simpson #1 wells; the intercepts were slightly but not significantly different. This difference in intercept is frequently observed when comparing seismic velocity data vs sonic log data and is attributed to the difference in the way velocities are measured in seismic data (large horizontal component) vs sonic logs (primarily a vertical measure). Although the seismic velocity data above 1300 ft sstvd matched the NCTL trend, the 2D seismic data is relatively low -fold and has a high uncertainty associated with pressure prediction. 2) The translation trend model developed at the Ikpikpuk #1 and S. Simpson #1 wells was used to estimate pore pressure directly from the NCTL trends measured from seismic data at Aklaq #6 (Figure 3). In addition to the investigation of the surrounding wells, a pre -drill 3D seismic pore pressure prediction at this location was performed. Seismic velocity data was used to predict pore pressures likely to be encountered in the Aklaq #6 well location. A local compaction trend and a local velocity to pressure gradient translation trend model were established using control from the Aklaq #2, (Figure 6), and Puviaq #1 wells (Figure 7). The local compaction trend and the translation trend model were applied to velocities obtained from the recently processed 2006 3D seismic data to predict pore and fracture pressures. This method of prediction was performed at the Aklaq #2 location and shown to be applicable. Seismic based pore pressure attributes were derived using a high density Amplitude - Orientated Kinematic `A -OK' velocity field. This technique uses automated AVO analysis as a residual velocity indicator to fine tune NMO corrections. The Amplitude- Orientated Kinematics, (A -OK), algorithm is based on a concept developed by Herbert Swan (2001). The predictions show no apparent shallow hazards or large pressure anomalies at the proposed Aklaq #6 well location, figures 6, 7 & 8. The accuracy of seismic geopressure analysis is dependent on the accuracy of the input seismic velocity field. The seismic velocities used for pressure prediction in this area were generated from interpretation of velocity semblance plots calculated from 2D seismic data. • Discovery of inaccuracies in seismic derived pore pressure below 6000' MD The following are three justifications to assume the pore pressure for the proposed drilled formations are normally pressured and do not follow the trends defined in the attached model for Aklaq #6. (Fig 3) Regional Empirical Data The closest wells ells drilled have accurate ressure data reported and are represented in the P � eP attached charts (Fig.1 and Fig. 2). If we assumed the highest reported gradient from Puviaq #1, (.509 psi/ft) the following calculations can be made: MASP (Pore pressure) = 8427 TVD (.509 - .11) = 3362.37 PSI MASP (Formation breakdown) = 2300 TVD (1.01 - .11) = 2070.0 PSI The Maximum anticipated surface pressure (MASP) for Aklaq #6 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 casing shoe (less a full gas column to the surface). Therefore, MASP in the 8.5" hole section is 3093 psi and the 5000 psi BOPE system to be used will be adequate. A second justification references a study that encompassed 24 wells drilled in the NPRA. (Fig 4) The data represents reported pressures for each well and the corresponding measured depth. The highest pressure reported in the study was a well drilled approximately 42 miles west of the proposed drill location and followed a pressure gradient of .624 psi /ft. If we use this gradient as a worst case scenario, the following calculation can be done: MASP (Pore pressure) = 7713 TVD (.624 - .11) = 3964 PSI MASP (Formation breakdown) = 2500 TVD (1.01 - .11) = 2250 PSI The Maximum anticipated surface pressure (MASP) for Aklaq #6 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 casing shoe (less a full gas column to the surface). Therefore, MASP (Worst case) in the 8.5" hole section is 3964 psi and the 5000 psi BOPE system to be used will be adequate. GMI Justification A third justification references a rock stability study that was completed in 2006 by GMI (Geo Mechanical International). GMI is an independent Geo - Mechanics consulting company specializing in pore pressure and rock stability studies in all parts of the world. The study incorporated 3 wells in the surrounding area (NPRA) with particular attention on shale stability. Chris Ward, PH.D a director with GMI summarized the following inaccuracy with seismic derived pore pressure along with rationale to what is truly correct. • • • The techniques assume any overpressure is generated by under compaction. For this to be so the sediments need to be continuously loaded (buried), usually in recent geological time. Most under compaction occurs in recent deltaic environments. From what I understand this part of the North Slope has been uplifted and has had a recent ice load melt, and therefore unloaded and under compaction would not apply. • These techniques for estimating pore pressures in shales assume the shale properties are not changing and the response from the logs (sonic, resistivity, density) is from trapped porosity, i.e. under compacted. It is likely here that the shales below the HRZ differ significantly petrologically from the Torok shales above. Some of them are organic -rich which will affect the density, sonic and resistivity, in a way that looks like overpressure (porosity) but is really due to the organic fraction. More significantly for pore pressure calculations from sonic and resistivity, the lower shales are probably (micro- fractured which affects the petrophysical transport properties resulting in anomalously high calculated pore pressures. • Wellbore stability evidence also points to a low pore pressure. A log response that looks like overpressure is seen in the HRZ /LCU at Puviaq but there were no breakouts observed in the image log or calipers. The well was drilled with a 9.5ppg mud weight and if the pore pressure was 16 -18ppg it would have been drilled severely underbalanced. These are weak shales and we would have predicted catastrophic failure for a well drilled some 6 -8ppg underbalanced. Also, the image logs and presence of lost circulation suggest pervasive natural fractures through these formations. If they are permeable enough to lose while drilling then will not be able to trap overpressure over any sort of geological time. Fracture Gradient Prediction Fracture gradients were calculated for the proposed Aklaq #6 location using the Eaton Methodology. Overburden pressure, calculated pore pressure gradient profiles, and Poisson's Ratio profiles are the inputs. The results are derived from the 3D seismic data and are shown in figures 2, 3 & 4. Conclusions 1) Given the local well control and seismic data, we predict there to be no apparent shallow hazards at the proposed Aldaq #6 well location. 2) Given the local well control and seismic data, there appears to be no zones of anomalously high pressure at the depths in the proposed Aklaq #6 well location. • • 3) The surrounding well data is and should be the primary data for pressure prediction. The justifications identifying the inaccuracies of seismic derived pore pressures should be taken into account. The uncertainty in pressure prediction from 2D & 3D seismic data should be borne in mind, however, the pressure prediction provided useable pressure estimates in line with actual occurrences in the surrounding wells. Based on the above justification and data from the pore pressure models, a best fit line was derived to be .511 psi/ft. (See figure 3) The best fit line was derived with a "worse case" factor applied. Aklaq #2 was drilled in 2006 and had a pressure gradient of .498 psi /ft. • Pressures for Aklaq #2 Fig #1 Pressure (psia) 0 0 0 0 0 0 o 0 0 0 0 o 0 0 0 0 O N V J CJ r 0 - 1000 t` 2000 3000 4000 i —Seismic Pore (psi)1 Seismic Frac (psi) a 5000 ` f Hydrostatic (psi) a) (3371,6765) =.498 psYft - Lithostatic (psi) 6000 di Pressure (psia) A • Hydrostatic (psia) • MW (psi) 7000 - Unconformity 8000 9000 10000 0 • Pressures for Puviak #1 Fig #2 Pressure (psia) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 cti cfl 0 0 I t 1000 2000 3000 4000 iw — Seismic Pore (psi) — Seismic Frac (psi) 0. 5000 Hydrostatic (psi) 0 Lithostatic (psi) 6000 Pressure (psia) A� • Hydrostatic (psia) 0 MW (psi) 7000 A - Unconformity 8000 Li L 9000 (4019,7900) = .509 psi/ft j t 10000 • • Estimated Pressures for Aklaq #6 Fig #3 Pressure (psia) 0 o o o o o 0 0 0 0 0 o c.1 .- o o 0 Estimated Frac gradient (2375,2301) = 1.03 psi/ft 1000 2000 3000 4000 � 0 — Seismic Pore (psi) ili md p g (311 si =.511 radient psilft — Seismic Frac (psi) C 5000 CI — — Hydrostatic (psi) a) o — Lithostatic (psi) ' � 6000 Pressure (psis) • Hydrostatic (psia) Ikb■ A NMI (psi) • 7000 - - Unconformity 8000 } _� .1 9000 4.. 10000 ? __._�_______ _______,__ N Drilling Pressure depth • lo Project t 2007 . o "° Figure 4 A .avr✓•AI•W � Pressure Profile From Offset Wells Aklaq Area 0 • Aklaq 2 ;1 JR. • South Simpson ;q. • Caribou ; •°°:.:•:•• • 2000 t x Ikpikpuk .......% • Puviaq °:�'•.,'•.'• I • Hunter A • 4000 E. Simpson 1 ' x E. Simpson 2 x Aklaq 2 MW 6000 • =, •• x South Simpson MW x xx . ,�• Ikpikpuk MW x _�• ti•• 4- Puviaq MW % _s a 8000 L _ x!' w - Topagoruk MW Q I I x Caribou MW DST Shut -in • Pressures ♦ — • Hunter A MW 10000 + Peard 1 MW x- - Kugrua 1 MW x I — S Meade MW • 12000 j x •• I • Kuyanak 1 MW • ■ E Simpson 1 MW Freshwater hydrostatic x gradient (0.433 psi /ft) x i E Simpson 2 MW 14000 x Inigok MW * N Inigok MW x •. • • 20 % 6 ' P ' P9 » PP9 • °•• • i PPg 17 P , P� _ • ° °• 1 BQPg ••• • 1 •PP9 L • Drew Point MW 16000 I 0 N D o � �o 0 0 ' o 'D ' u ' �' OO OO O O O O O O O OO O OO O OO O Pressure (PSIA) Drilling Transit time & pressure calibration plots for Aki_ Project t 2007 Figure 6 Information derived from the 2006 3D Pressures Travel Time Pressure (psia) Travel Time (µs /ft) 0 0 0 0 0 0 0 0 0 0 0 1 00 200 300 0 0 0 0 0 O N r r I • I _ — 1 000 ,. +�,r � ,�.% , ; � r ; - � . . 1000 --? i i 3000 �__ _ ____...._._ _ .__.._._. ..._. - 1 3000 �_.. __ __. —_ _.._.._. _____-- -- -- - - -- ____-- -� • 4000 - 4000 ,. 1— Seismic Pore (psi) . ..,. a Seismic — Seismic Frac (psi) — 5000 r• -� ____ . r — -- _. __ __ -__ _ —Model M w . - I Hydrostatic (psi) 5000 CI. : d o � — Well o I —� Lithostatic (psi) llnconformity" a Pressure (psia) 6000 = A Hydrostatic (psia) • £ ' • MW (psi) 7000 7000 — Unconformity i 8000 �_ 8000 __ ._ -. — . ___ 9000 ,.� _ — -- - -< - i .. IIIIL 1 0000 -. » -•• 10000 J Drilling - A Transit time & pressure calibration plots for Puvia i Project '" 2007 i Figure 7 Information derived from the 2006 3D Pressures Travel Time Pressure (psia) 0 Travel Time (µs /ft) o 0 0 o o 0 0 o N V to CO 0 100 200 300 0 0 1 • 1 1000 ! }t71' gyp , 4!s., d. ' s ..} '. I R 1 u r z £k ` , t 2000 S ■ 2000 a •":''''' _ r • -:-,,- r 3000 z ..,7",--,,.."."•;: ` "• z nl'.,44,, -' fv 3000 A .. t 1 f � ?.. i ' ; � „� 1 � �� �,,<,«�' , �; �, �� � I 4000 1 . c�, - a te ' 4000 ` a' k ti� Seismic Pore (psi) r . i � Seismic Frac si . ,F ' . Seismic (psi) di � $ r { � # 4 I 4 «. 5000 � Model 1 — Hydrostatic (psi) n 5000 a d z #,� I - Lithostati (psi) 0 a —Unconformity] ra fi ” .� -, #* 6000 Pressure (psia) ' 41 6000 4 .1 I .. ' Hydrostatic i g � ` t , + O M s w (Psi) 1 s000 s " - 7000 } „� I! i 1 — Unconformity I i 8000 8000 ;., ii 1 9000 s000 10000 10000 1 Transit time & pressure calibration plots for A r Drilling p _ . Project zoos . Figure 8 Information derived from the 2006 3D kPa = kg /m = lbs/in x 1kg/2.2151bs x (12in /ft x 0.3048ft/m) Travel Time Pressures Travel Time (Oft) • 0 100 200 Pressure (psia) o 0 r o 0 0 0 0 0 i # 0 0 0 0 0 0 N o o m 0+ 1 1000 1 1000 - - - . 2000 , ;w .- e^± at*:'[ .4"i.v.±.'- ....." .. ... !?.��0> i 2000 __ _. __ . _ . -. _ .. - . - • 3000 3000 s i 4000 F s ' — Model 4000 (P s Seismic -, Seismi Pore i) ti I Seismic Frac (psi) 6 5000 a — Well « 5000 - __,._.__..__. [—Hydrostatic (psi) 1 g • Unconformity o 1— Lithostatic(psi) 6000 r I 6000 ._,,.._ p ♦ H drostati c(PSia) II • A MW (psi) 7000 I 7000 — Unconfonnity L.. r t 8000 t 8000 i 9000 - I I ei 10000 .. ____ _ __ _. _ 10000 _. _.._ ____� (1 Pa = 0.000145 psi) 1 I • =In et : :..... der hi ova ....1. .704.......ii4-...... ao...-- igg.----_,-,te...„ :.,- , . Drilling !_, .. L U S uel iveu pvie ple.,,:...,,:.,.,,, , Project . ,.. 2007 .,,,,.. Figure 9 .....,,,......or ' Modeled at Ikpikpuk #1 & South Simpson #1 a , , " ,.,, , . , , , . , 1 — ■-•-•-• _ .\ Norma I Gann nil on -"' Treat Line / 1 i I , t , ' .‘, N • I 1-7 , 2408 I* ' 00 Fracture Gradient Fract e Gradient ' III . , . i Normal Wmpaction l' ' .._...... , \ . i I 41 t i ! L 1 . . Treid bue 1 Interval Transit Time L 1 doe from Seismic Vrine I 1 : 1 i As 1 \ Nedided Pore Pr -... re - 1 I I, , Mud }Vel Orillere e' 1.,,, : I , / ; I . ■ ' , . , .„,_ ..H., . , .. - , , ! , , . , ... ,.. H., . , . _ , ,.. , ! 1 1 I i 1 -- ' c - - --- ---..- ti : Ptidell ' en Firc ' : /1 , , ' 1\ 1 1 T ----- 1),(- iller's Mud Weight . , ' Interval Transit Time ! • ,-- from Sam c Mow ' I , ....._,_ . , . . -.-, .... , __ MO MN 1 I ...,..._ I ° ' v , i * 51 4 4 4 9i 14 !* 241 1.11 Lila ?I 10 4 4 i 4 4 14 zie 24 114 1;4 4 .■s:1 PPG tis(ft PPG • • BOP Control System The BOPE control system on the Arctic Wolf is a T3 -Oilco blowout preventer control unit with a 450 gallon volume tank. Main energy is provided by two (2) 25 HP Bear (Model BX -10) electric triplex pumps rated at 12 gpm / pump and 3000 psi. The pump charges twelve (12) fifteen gallon bladder -type separator accumulators. A second energy charging system consists of two (2) Bear (Model 8 1/2", 40:1) air - powered pumps rated at 4 gpm / pump at 3,000 psi. The above two energy systems are backed up by six 337 cubic foot nitrogen bottles connected to the manifold system. All of the systems are controlled by a manifold with six manual control stations at the unit. VOYON 1 500' DRILLING — — — -- — 1 180'9'4%0 1 MS 1111.111/111111•111111111111111 140 1 DRILLING LTD. \ — .- — )a 141 d __ .._ _.... ..... ..., -- -- w e11 te . e o7e . 1 ARCTIC WOLF __ ooc ■ c owe,o, on. \ t 2 1 : ,. :0, ,:orfokm 14Ortne ''ne 1 1 Almmommommomomi. • 1 i \ --------- " 1 1 WINIVIIIIIIMMIIM■1■.■ ,■•■■■•■■■■• \ ' ' 1 0 • 0 * 0 * ' ' 1 i 0 To 0 ti - Accumulator 1‘i psi 0 401i Fmm Close Diverter 1 I/ Accumulator INNIMMMIMINSIMMI 1 S iN,i\s,4,1.----- 16 ............74,4iii,__g_ : : _ ( - " Hydraulic gate valve Cl°se I I= SUMMOOMM 1 efr 1 „i \\ 16" ANSI 150 Flanges ti t ‘l itie) \‘‘ .5. 21 1/4 API 2000 psi flanges 11 11111111111111111 . \ saflI - 11101 ' ..... —50 • 1 Iii; I l 1 I 0 11111111/1111111111111 I 1 1 — \ \ 15000 00 — _ — — II I 0 r ITEM DESCRIPTION 279 mm 34500 kPc (1 1 " 5K) SHAFFER SPHERICAL 2 279 mm 34500 kPa ( 1 1 " 5K) SHAFFER DOUBLE GATE 3 279 mm 34500 k ?c (1 1 " 5K) DRILLING SPOOL 4 279 mm 34500 kPa (11' 5K) SHAFFER SINGLE GATE IL Ill If 1_,, I lt-------j I 1 ` 4 w E — o D — I I 1 i co I I C0.I��c : --o : l ICI i [ m ilikiviA n I! It d lick-or _ O me. .•,,,,:!/1:1--:4:::!. l I1 X1 C/il ►-: '1 Btu I on4lle 01 li r [ wil fr,-__ I. lior 1 r E 7 The Inforrnatlon contained In this drawing Is 1 s 16-Sep-05 F54 the sole property of AKITA Drilling Ltd. Any a t o T A L I S N I A M ` ers , - reproduction In whole or part without the s _ r e o r Well cross Section w! 1 t' express written consent of AKITA Drilling o, sor. the LTD . w Ltd. Is 7 prohibited. trex rw.. SM Stack 9E >a TO (TSOI %5E700 W. 199:.9 Dot./ r i1-s1 Sm. /.....)) 1 LEDGEND 7 A K/ TA J V ~� White Handle Valves �j ,� Normally Open 4 0 pi Red Handle Valves , 11001 Normally Closed 1 T4 FLARE r `/ r P o S • .. ` • r F Rd M OOP P STAG K 10 di° 11* / / ,,elik _ , ) - y RE � . 9 ' H F RIG di 1 'MdSp • T4 ��R MATERIAL LIST D� Item Description A 3 -1/16" 10M Remote Operated Choke B 3 -1/8" 5M Adjustable Choke ti re 1 -14 3 -1/8" 5M Manual Gate Valve , 4! ►gyp � r� r� ma ARCTIC WOLF LAYERS TOTAL TANK CAPACITY . IHrr NET E. LOW SYS WELL SKIMMER 'PA RETURNS SLIM* PUMP TANK OUR INN PI TROUGH • I L WEIR ROE I S. r CO ii . Ia • Nor 00r M .L.. 4 q q ILWERSLOW it ‘,,,, L----4) T - - j/ ti W m R u ^ t t f tee 1 + a +• ` r � re •e. br' e4 !�' :' /�'�E A■� ),! NR ) 5 NR ?S(1-10 I N. _. R..R*, I be., ew .I 1_ ��� .1. a (•• ms- e I ° e•, - • I J R e . Q \ TALISMAN L 1S M A is ' fd Me Ig PPFR i ' i l-( 2 ' IIILICIankupioun TA I ( r BL i i .107 A n X01i +SSTU0 i ii V CO eKseu a SESKN 1 A *Iva ,..4.4,5,1 I .+' • OW. T OW. the Information contained In � - this drawing I the sole • ?AA, is-NV ^ ry roryary M AKITA Drilling _ - _ Ltd. Any reproduction M 1 ,.. `a - t_ n seems. whets or pert without the �.s'ON ST. a 00: i OQ11 . AK!TA Ddlpng consent d IN prohibited. /� OAL INT OAPLAONER 'w NTS ■ Ci PUMP wR 2 I.SepLeS . .re..* :E. RTF Mud Schematic • 3 .. p• ale M Mud Tank Schematic Aklaq #6 Cementing Program 16" Conductor Casing (set at 80') Lead Slurry: Top of slurry: Surface Permafrost type C cement, 15.6 ppg density 100% excess Yield: 0.95 cu ft/sk Volume: 49.7 bbls (297 sx) including excess 9 -5/8" Surface Casing (set at 2500') The cement program this year is based on what was achieved in Aklaq #2 last year. After the job, we had calculated a 5% excess of cement based on the capacity of the hole. Although we recovered 80 bbls during the job, we feel the cement job went well. A solid shoe was achieved and cement was brought to surface. We are performing an inner string job, so our intent is to achieve similar results as last year. We will have 300bbls of cement on location which equates to 180% excess if the entire batch needs to be pumped. The samples last year reported high levels of clay and very low % of gravel, thus helping to keep the permafrost better in gauge. PreFlush / Spacer: 10 bbl Water, 20 bbl 10.0 ppg Alpha Spacer Lead Slurry: Top of slurry: Surface Permafrost type L cement, 10.7 ppg density 50% excess across Permafrost, 80' to 1300' 25% excess below Permafrost from 1300' to 2000' Yield: 4.15 cu ft/sk Volume: 161.8 bbls (219 sx) including excess Tail Slurry: Top of slurry: 2000' Premium class G + 1% Calcium Chloride, 15.8 ppg density 25% excess for 500' of annulus volume Yield: 1.15 cu ftlsk Volume: 41.3 bbls (201 sx) including excess i • 7" Production Casing (set at 7713') PreFlush / Spacer: 10 bbl Water, 20 bbl 11.5 ppg Alpha Spacer Stage 1: Top of slurry: +/- 6600' Premium class G + 0.65% Halad -413, +0.2% CFR -3 +/- 0.2% HR -5 (retarder) as required, 12.5 ppg density 25% excess Yield: 2.36 cu ftlsk Volume: 31.5 bbls (154 sx) including excess Stage 2: Top of slurry: +/- 4500' Premium class G + 15LB /SK Microlite + 0.65% Halad -413, +0.2% CFR -3 + 0.15% EZ -Flo + 0.7 %Versaset + 0.1% HR -5 as required, 15.8 ppg density 25% excess Yield: 1.15 cu ft/sk Volume: 59.3 bbls (141 sx) including excess In the likelihood that hydrocarbons are reported (MWD /wireline logs and mud samples) in the intermediate section, a second stage cement job is planned. Cement will be brought 500' past the shallowest hydrocarbon bearing formation. If no hydrocarbon zones are identified, a contingency single stage cement job will be implemented. Cement will be brought a minimum of 1000' above the shoe as per regulations. Contingency 5" liner 5" Production Liner (set at 6850') PreFlush / Spacer: 10 bbl Water, 10 bbl 11.5 ppg Alpha Spacer Lead Slurry: Top of slurry: +/- 6500' (100' above top of liner) Premium class G + 0.65% Halad -413, +0.2% CFR -3 +/- 0.4% HR -5 (retarder) as required, 15.8 ppg density 30% excess Yield: 1.16 cu ft/sk Volume bls (3 . sx) including excess Q 41/\ i • Aklaq #6 Mud Program General Discussion This exploration well will be drilled from an ice pad in the NPRA. Due to the extremely remote location, waste management is critical on this well. Storage tanks will be available but waste minimization will be key to a successful drilling operation. The well will be drilled vertically, spudding with a 12 IA" bit, and drilling to a surface hole TD of 2,500' TMD where 9 -5/8" casing will be run and cemented. An 8 I /?" hole will then be drilled to TD at 7,713' where 7" casing will be run and cemented. A contingency casing string may be run at 7,012' if the Miluveach is present. A 6 1/8" production hole would then be drilled to the same TD (7,713'). Spud the well with a 6% KC1/Clayseal mud. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. This spud mud is formulated with two mechanisms to provide effective wellbore stabilization, ionic inhibition (KC1) and anionic bonding (Clayseal). The KC1 /Clayseal mud will be maintained through the production interval. The weight will be adjusted to 9.6 ppg prior to drilling out of the surface casing. This weight will be ( raised to 11.2 ppg prior to drilling the HRZ shale. Special emphasis should be placed on maintaining low ECD's and surge /swab pressures to minimize the potential for shale instability. Should the contingency casing be run, the weight will need reduced to 9.6 ppg to drill the payzone. Special Considerations: i. Maintain a sufficient quantity of Driltreat (lecithin) to accomplish a 2 ppb treatment in the event gas hydrates are noted — not expected this far west on the North Slope. ii. Lime and zinc carbonate should be on location for H2S. iii. Maintain an adequate barite supply (and other necessary products) to increase the mud weight of the current circulating volume by 1.5 ppg at any time ( @2000 sx barite on location at all times). iv. Due to the remote nature of this location, maintain an adequate supply of LCM and other mud additives, which may be required to support this drilling program. v. Reduce the potential for hole erosion/destabilization, hold the jet velocity below 200 fps while achieving pump rates to deliver AV's around the drillpipe in the 140 -150 fpm range. vi. Possible shale instability issues in the Jurassic sequence (tight filtrate control /mud weight). • • Well Specifics: Casing Program MD TVD Footage 12 '/" hole (9 5/8" casing) 2500 2500 2500 8'/" hole (7" casing) 7713 7713 5213 OR 8 %" hole (7" casing) 7012 7012 4512 Possible 6 1/8" production 7713 7713 701 Surface Interval: 12 1/4" to —2,500'; 6% KCUClayseal Mud Properties Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value — Density (ppg) 10.0 10.0 10.0 10.0 Funnel Viscosity 50 -90 45 -75 45 -75 45 -75 (seconds) Yield Point 25 -35 19 -27 19 -27 19 -27 (cP) Plastic Viscostiy 13 -23 13 -23 13 -23 13 -23 (woo si 10 second Gel Strength (lb /loo 7 -12 7 -12 7 -12 7 -12 sf) 10 minute Gel Strength ( lb /100 9 -18 9 -18 9 -18 9 -18 sf) pH 8.5 -9.5 8.5 -9.5 8.5 -9.5 10.0 API Filtrate(cc) 8 -15 6 -8 5 -6 5 -6 Solids ( %) 2 2 -9 2 -9 2 -9 Base Formulation: COLD Water - 0.905 bbl KCl - 20 lbs (30 -32K ppm K +) Clayseal - 0.84 gal (.21 gal/bbl in initial mix) Dextrid - 3 lbs (API filtrate of 8 -15 cc's) Barazan -D - 1 -2 lbs (as required for an initial 35 YP) KOH - 0.1 -.25 lbs (pH = 8.5 -9) Baroid - as needed Baracor - 1 ppb Barascav D - 0.5 ppb (to be added when first circulating) Drill -N -Slide - 1/2% v/v (Shaker screen blinding from clay) Aldacide G - ONLY if required while drilling ahead • • ** Use Barite for any needed weight ups on this well. NOT drill solids. A strong focus on minimizing waste needs to be in place before and while drilling all sections of this well. Do not jeopardize the integrity of the fluid system, however, all efforts need to be made to this end. Allow the pit volume to deplete prior to TD on the surface hole. This will leave more room in the pits for displaced mud when cementing. Ensure all solids control equipment is working properly prior to spudding. Utilize shakers, desanders / desilters, mud cleaners, and centrifuges to reduce solids and reduce dilution. No processes should take place that will lead to a build up of low gravity solids in the mud. On an example well, some of the centrifuge under -flow was returned to the mud system. This led to a fines build up and the resultant required dilution was excessive. The personnel were trying to reduce waste but wound up causing additional waste. Build and maintain the system with COLD water. All attempts to keep the temperature of the mud <75 °F should be made. Normal surface hole viscosities should be adequate for the hole being drilled. Maximum flow rates should be used to ensure good cuttings transport. Target an initial YP in the 30 -35 range then adjust as dictated by the actual hole cleaning requirements of the well (no gravel is anticipated — mostly clays and sand). Reduce viscosity as allowed, previous wells in the area have TD'd the surface with a —20 YP. However, do not hesitate to quickly raise the viscosity if hole - cleaning problems develop. Polymer viscosity in the form of Barazan D additions should be utilized to provide Theological support as needed. Utilize high viscosity or Barolift sweeps to supplement the hole cleaning capabilities of the system in this large bore interval — if sweeps are needed. Spud the well with an 8.7 ppg density mud. Expect the natural progression of the weight as drilling proceeds. Increase the mud weight as dictated by actual hole conditions. If gas hydrates are encountered in the surface interval, special operational conditions will need implemented. To minimize the potential for difficulties due to hydrate occurrence, the following suggestions are offered: • Control drill the interval. This limits the amount of cuttings in the well bore which might contribute hydrates. • Use slower pump rates to minimize the potential for bringing up large volumes of hydrates all at once and overloading with gas cut mud. • A two pound per barrel treatment with Driltreat (Lecithin) could provide some inhibition of the hydrate break -out. • Keep the mud as cool as possible to minimize thawing of the hydrates. Mud up with cold water and dilute with cold water. • Milne Point and Tarn operations have reported benefits from treating with 1% Dril -N- Slide. The mud engineers state that it acts to smooth out the rheology of the fluid which allows the hydrates to break out of the fluid more readily. • • If possible, use 6% KCI brine (COLD) to maintain volume while drilling ahead. Maintain the mud chlorides — 28K — 34K ppm with KCI. Maintain the potassium level between 30K -33K with KC1. Use Dextrid and PAC's for API filtration control. Target 8 -15 cc's initially, dropping the fluid loss to the 6 cc range prior to running casing at the surface hole TD. Hold the pH in the 10.0 range with KOH. Initial Clayseal concentration should be 0.21 gal/bbl. Increase this to the full concentration while drilling ahead. By the amine test, maintain the Clayseal concentration in the 2% by volume range. Keep penetration rates below 150'/hr for controlling clay "chunks" (as have been experienced on other NPRA wells). Should bacteria become a problem, hold a safety meeting and add the desired amount of AIdacide G using all the proper PPE. High levels of corrosion have been seen when running KCI fluids in other areas on the North Slope. Daily sulfite and phosphonate checks will be run. Sulfite levels at 300 -400 ppm and phosphonate levels between 600 -800 ppm will be targeted. Barascav D and Baracor 700 levels will be maintained at programmed levels. Heavy amounts of clay will be present immediately which will require additions of Dril- N -Slide and/or Condet to reduce BHA balling and screen blinding. Sweeping the hole with high viscosity or Barolift sweeps prior to the short trip at TD and again prior to coming out of the hole to run the surface casing is recommended. If possible, reduce the fluids rheology to those recommended in the cementers program after the casing is on bottom. While drilling it is important to exercise caution to minimize the potential for creating a situation of lost circulation. Tripping speeds and casing running speeds should be slowed to reduce the effects of surge pressures on the formation especially with this elevated rheology. Do not attempt to run casing if the well is not in stable condition. Pumps should be "staged" on line slowly to avoid surging the hole and the pipe rotated to break the mud's gels before turning the pumps on. • Production Interval: 8 1" to 7,713'; 6% KCUClayseal Mud Properties Initial Value Final Value Density (ppg) 9.5 — 9.6 11.2 ' Funnel Viscosity 40_65 40 -65 (seconds) Yield Point 15 -25 15 -25 (cP) Plastic Viscostiy 13 -25 14 -35 (lb /100 sfi 10 second gel 4 -8 4 -8 10 minute gel 6 -13 6 -14 pH 10.0 10.0 API filtrate <6 <4 HTHP filtrate <14 <10 Solids % 5 -9 8 -16 Treat the mud with bicarb and citric acid prior to drilling out. After drilling out, maintain the mud as specified above until approximately 400' above the top of the HRZ (6528'). The mud weight should be raised to 11.2 ppg at this depth to help control the shales. Offset wells went into the Miluveach/Kingak with a much lower mud weight which then required extremely high weights once the shale began running. We have also seen this happen in other areas of the slope. Once the shale begins running, a higher mud weight is required than if it had been cut with medium weight to begin with. Achieve this weight up by adding 15 ppb of Baracarb 25, 15 ppb of Baracarb 50, and finishing with Baroid. The Baracarbs will add bridging material to the system to help seal micro fracturing as it occurs. Mud weights in the 12 ppg range have had to be used in this section once the shale started running. * *Please note that these old wells would frequently elevate the yp in order to support the pieces of shale. This allowed them to trip easier even though the welibore was still unstable. If shale problems occur, Baroid wants to discuss this option with FEX. It seems counter intuitive but it helped the old wells get to TD. The HTHP should be lowered to <10 cc prior to drilling the HRZ. Maintain this tight filtration to TD of the well with N -Dril HT/Dextrid, PAC and Baranex. A 8 -10 ppb treatment with Barotrol will be made while drilling after the HTHP has been lowered (at the HRZ). Keep low gravity drilled solids to a minimum ( <6% by volume if possible). Maintain the MBT at <12 ppb through dilution and solids control. Maintain the pH at 10.0 with KOH. Additions of Aldacide G/X -Cide 207 should be made only if tests indicate a bacteria problem. Maintain the potassium level between 30K and 33K with KC1. The chloride level should be kept in the 28 -34K range through additions of KC1. Fresh KCl and KOH will need added after trips to replace the K ion which will deplete during the trip. The Clayseal concentration will be maintained at it's programmed concentration. A 15 -25 YP should be maintained using Barazan D +. • I Aklaq #1 saw losses in the Torok sands. String in 3 -5 ppb of Barofibre and/or Baracarb 50 while drilling these sands. Due to over balance, it may be advisable to have a 25 ppb LCM pill (check with the MWD personnel to maximize the particle size and concentration of this pill) standing by before entering the Kugrua sand. Losses were noted in prior years drilling programs when drilling this zone. Also string in 4 -8 ppb Barofibre as the zone is drilled. Special efforts should be made to keep ECD's and surge /swab pressures to a minimum. This will reduce the chances of lost circulation and also reduce damage to the exposed shales. Production Interval: 6 1/8" (contingency) to 7,713'; 6% KCUClayseal Mud Properties Initial Value Final Value Density (ppg) 9.6 9.6 Funnel Viscosity 40 -65 40 -65 (seconds) Yield Point 15 -25 15 -25 (cP) Plastic Viscostiy 13 -25 14 -25 (lb /100 si) 10 second gel 4 -8 4 -8 10 minute gel 6 -13 6 -14 pH 10.0 10.0 API filtrate <4 <4 HTHP filtrate <10 <10 Solids % 5 -9 5 -9 A 6 1/8" hole may be required if the contingency 7" casing is run. Cut the mud weight to the 9.6 ppg range prior to and while drilling out. Treat the mud with bicarb and citric acid prior to drilling out. Maintain a tight filtration to TD of the well with N -Dril HT/Dextrid, PAC and Baranex. Keep low gravity drilled solids to a minimum ( <6% by volume if possible). Maintain the MBT at <12 ppb through dilution and solids control. Maintain the pH at 10.0 with KOH. Additions of Aldacide G/X -Cide 207 should be made only if tests indicate a bacteria problem. Maintain the potassium level between 30K and 33K with KCI. The chloride level should be kept in the 28 -34K range through additions of KCI. Fresh KCI and KOH will need added after trips to replace the K ion which will deplete during the trip. • • The Clayseal concentration will be maintained at its programmed concentration. A 15 -25 YP should be maintained using Barazan D +. Aklaq #1 saw losses in the Kugrua sands. String in 3 -5 ppb of Barofibre and/or Baracarb 50 while drilling these sands. Due to over balance, it may be advisable to have a 25 ppb LCM pill (check with the MWD personnel to maximize the particle size and concentration of this pill) standing by before entering the Kugrua sand. Losses were noted in prior years drilling programs when drilling this zone. Also string in 4 -8 ppb Barofibre as the zone is drilled. Special efforts should be made to keep ECD's and surge /swab pressures to a minimum. This will reduce the chances of lost circulation and also reduce damage to the exposed shales. Recommended Drilling Parameters: Penetration Rates: Please see the following optimization chart for maximum allowable penetration rates. These rates are set for rotating. Penetration rates may need to be controlled to minimize overloading the annulus with cuttings which can lead to higher ECD's and shale de- stabilization. Close monitoring of PWD data will assist in diagnosing this potential problem and allow real -time remedial actions. Due to the vertical profile of this well, rpm has no effect on hole cleaning. Hydraulics Optimization Chart Actual P rates will need adjusted to how well the surface equipment can handle the flow and cuttings. 12 1/4" Maximum Acceptable ROP in fph at Specified GPM and RPM GPM—+ 500 600 700 60 rpm 133 174 210 80 rpm 133 174 210 8 1 A" Maximum Acceptable ROP in fph at Specified GPM and RPM GPM- -* 350 450 550 60 rpm 169 242 307 80 rpm 169 242 307 • 6 1 /8" Maximum Acceptable ROP in fph at Specified GPM and RPM GPM—. 200 250 300 60 rpm 178 183 193 80 rpm 178 183 193 Hole Cleaning: Maintaining the programmed flow properties is essential to a successful completion of this well. Any indication of a failure to keep the annulus clean of excess cuttings (drag, torque, partial pack off) should be countered by increasing the circulation time on subsequent connections and prior to trips. If high vis sweeps seem ineffective, other types of sweeps (Barolift, weighted, etc.) should be tried. The returns at surface of all sweeps should be monitored at the shakers to gauge their effectiveness. When circulating bottoms up prior to POH, it is advisable to pull one stand every half hour to reduce the hole washout effects of circulating over one short interval. Risks and Contingencies: Lost Circulation: Preventing the initiation of lost returns should be a primary goal of the drilling fluid. To that end the rheology of the system needs to be run as low as possible while still providing ample hole cleaning. Maintaining a low ECD while circulating, and eliminating high pressure spikes while tripping, will both go a long way toward reducing the risk of lost returns. Should lost returns occur check with MWD personnel prior to pumping any pills to ensure that no plugging will occur. Bacteria Control: Run SRB strips daily and report results. Should signs of bacteria in the mud become evident, Aldacide G must be used. Do not add the Aldacide G while adding Barascav D. After adding any Aldacide G, test for its concentration and report daily. Wellbore Instability: The Kingak/Miluveach shales can be problematic. Ensure the mud has the HTHP reduced to less than 10 cc. Should any signs of shale splintering be seen, immediately raise the mud weight a minimum of 0.4 ppg. As much as 12.1 ppg has been needed in other areas of the NPRA. Offset wells have had to raise the viscosity to -30 -35 YP to keep the shale suspended and avoid pack offs. Tripping speeds and casing running speeds should be slowed to reduce the effects of surge pressures on the formation. Pumps should be "staged" on line slowly -ALL THE TIME- to avoid surging the hole and the pipe rotated to break the mud's gels before turning the pumps on. 40 • Stuck pipe: Two forms of stuck pipe are possible. One is from hole pack -off as related to poor hole cleaning. Stuck pipe can occur if the hole isn't clean or if the wellbore exhibits severe instability. The best cure is to pro - actively prevent the occurrence of either scenario, and if they do occur, correct drilling practices must be employed. If pulling up into a tight spot, do not jar up further, but attempt to get below the problem. Backreaming is an invitation to packing off and resulting stuck pipe so backrearning must be done with care and only when necessary. If stuck pipe occurs across a sand and there are indications of differential sticking, there are drilling fluid solutions. If possible, reducing the fluid density by a minimum of 0.5 ppg may provide some relief. Waste Minimization: 1. Solids Control Equipment — for reduced dilution volume. Monitoring shaker screen mesh size and checking for screen damage (holes) is a primary responsibility of both the fluids engineer and rig contractor. The centrifuges must be run as much as possible to reduce dilution throughout all hole sections. 2. Gauge Hole — for reduced cuttings volume. • Inhibitive Mud System — Use of 6 %+ KC1 Polymer system as outlined in the mud program to reduce washout in clay /shale sections • Hydraulics and Rheology as recommended in the mud program to reduce washouts in unconsolidated formations, especially on surface hole. • Use of near freezing water for mud make -up and dilution to reduce thawing of Permafrost. Note: the close proximity of heat generating equipment (power plants) to the mud pits on some rigs can increase the surface mud temperatures by 10 to 15 deg F while drilling surface hole. • Drilling the surface hole and running casing as efficiently as possible to reduce time, thus minimizing thawing and washout of the Permafrost. 3. Re- cycling of Fluid — for reduced mud volume disposal An Inhibitive KC1 Polymer system, as outlined in the mud program, allows for re -use from interval to interval and from well to well (if storage is available). Tracking and Reporting of Waste Streams and Costs: We consider this to be of vital importance. TFM reports will be completed daily. Interval and well summaries will also be done. Lubrication: Due to the vertical nature of this wellbore, lubricants should not be required. If required, 1 -2% of EZ Glide or Torq Trim II and 1 /2% Dril -N -Slide can be added. Corrosion Mitigation Barascav D and Baracor 700 will be run in this fluid system to mitigate the corrosion. Daily sulfite and phosphonate checks will be run to monitor this program. Sulfite levels should be maintained at 200 -300 ppm and phosphonate levels between 600 -800 ppm. Corrosion rings will be run on this well. Two rings should be run on each trip in the hole — one located in/near the saver sub and one just above the BHA. baton aro�p,N'y fp vdos s R ir -- ( ii a,, /, / i / `' ,,;Y'% s 1. r " ____,_?_,_--______- / r��� j ( IL ca �% r'�/ % o 1 T� O O U� / / 4,,,,,,: __,_-_-:-. , ,,,,,,,, , ,,,,, • oaa, �� ;� 1.: %, � , _ ; !¢,ice � � l ` �wvwa�onaro i rnuaswo.� o� s i�a � 0 TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# Development Service Exploratory Stratigraphic Test Non - Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS ! TEXT FOR APPROVAL LETTER WHAT I (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in , I Pe rmit No. , API No. 50- - - API num are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE i In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both ! ! well name ( PH) and API number (50- - - ) from records, data and logs acquired for well . SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ! 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non- Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and ! implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev. 1'25/06 C 'Jody \transmittal_checklist Alt PERMIT CHECKLIST Feld & Pool Well Name: AKLAQ 6 . Program EXP Well bore seg PTD #: 2070090 Company FEX L.P. Initial Class/Type EXP / PEND GeoArea 890 -_ -- Unit On /Off Shore On Annular Disposal Administration 1 Permit fee attached Yes 1 2 Lease number appropriate Yes Per Bob Merrill, BLM, Fed- LeaseAA- 085517 encompasses Sections 19 to 36 of T16N, R11 W, UM. 3 Unique well name and number Yes 4 Well located in a defined pool No Exploratory well '5 Well located proper distance from drilling unit boundary Yes — 2,970' west of lease line. 1 6 Well located proper distance from other wells Yes Nearest well, Puviaq 1, is 4.6 miles away. 17 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included NA Vertical well i9 Operator only affected party Yes 1/25/2007: Notify Paul Mazzolini that: 1) need current 401 form, 2) need Design. of Op form for lease with 110 Operator has_ appropriate bond in force Yes original signatures. 2/9/07: receive app on current 401 form. 2/15/07: receive 411 form, but it is a copy. 11 Permit can be issued without conservation order Yes Phone Mazzolini. 2/16/2007: receive 411 forms with original signatures. Appr Date , 12 Permit can be issued without administrative approval Yes SFD 2/21 /2007 13 Can permit be approved before 15 -day wait Yes • 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (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 Nonconven. gas conforms to AS31.05.030(i.1.A),(j.2.A -D) NA Engineering 18 Conductor string provided Yes 19 Surface casing protects all known USDWs Yes Based on the salinity study provided there do not appear to be any USDWs. 20 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 may be proposed. Hydrocarbon zones will be covered. 122 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes . 124 Adequate tankage or reserve pit - Yes Rig is equipped with steel pits. No reserve pitplanned. Liquid waste to Aklaq #2 for annular disposal. !25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separationproposed Yes No wells proximate. 127 If diverter required, does it meet regulations Yes Appr Date 128 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 9.8 EMW. Planned MW up to 11.2 ppg. TEM 2/23/2007 29 BOPEs, do they meet regulation Yes PlAjfk 30 ROPE press rating appropriate; test to (put psig in comments) Yes MASP w/o shoe breakdown 3170 psi. 5K BOP stack and test pressure planned. 31 Choke manifold complies w /API RP -53 (May 84) Yes ilk 32 Work will occur without operation shutdown Yes If seasonal time runs short, an operational SD may be necessary. 133 Is presence of H2S gas probable No H2S has not been reported in the formations drilled. Rig is equipped with sensors and alarms. 1 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 135 Permit can be issued w/o hydrogen sulfide measures No Remote exploratory well. 36 Data presented on potential overpressure zones Yes Max. expected pressure is 9.8 ppg EMW; will be drilled with mud wt up to 11.2 -ppg to control HRZ shale. Appr Date 37 Seismic analysis of shallow gas zones Yes No apparent shallow hazards from seismic / velocity analysis, May encounter gas hydrates at base of SFD 1/25/2007 138 Seabed condition survey (if off - shore) NA permafrost mitigation discussed in Drilling Area Risks section. '39 Contact name /phone for weekly progress reports [exploratory only] Yes Paul Mazzolini 907 -771 -1923 Geologic Engineering Public Commissioner: Date: Commissioner: Date ' sioner Date 13' i s 2-] 24 1 1 0:4(,4‘ 2-21 -e7 WA 1 " oil ^ .0 - 7-, • • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding 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. M I NM M I 101111111111111111111 — — MI= CORE ANALYSIS REPORT FOR TALISMAN ENERGY INC. - TALISMAN F.E.X. AKLAQ #6 AKLAQ #6 , ALASKA RECEIVED IF tC3 SEP 0 6 2007 a0 Alaska Oil & Gas Cons. Commission Anchorage THESE ANALYSES, OPINIONS OR INTERPRETATIONS ARE BASED ON OBSERVATIONS AND MATERIALS SUPPLIED BY THE CLIENT TO WHOM; AND FOR WHOSE EXCLUSIVE AND CONFIDENTIAL USE; THIS REPORT IS MADE. THE INTERPRETATIONS OR OPINIONS EXPRESSED REPRESENT THE BEST JUDGEMENT OF CORE LABORATORIES (ALL ERRORS AND OMISSIONS EXCEPTED); BUT CORE LABORATORIES AND ITS OFFICERS AND EMPLOYEES, ASSUME NO RESPONSIBILITY AND MAKE NO WARRANTY OR REPRESENTATIONS, AS TO THE PRODUCTIVITY, PROPER OPERATIONS, OR PROFITABLENESS OF ANY OIL, GAS OR MINERAL WELL OR FORMATION IN CONNECTION WITH WHICH SUCH REPORT IS USED OR RELIED UPON. CORE LABORATORIES IS COMMITTED TO CUSTOMER SATISFACTION AND WELCOMES YOUR FEEDBACK. YOU CAN E -MAIL THE GENERAL MANAGER WITH YOUR COMMENTS AT PSCANADA.FEEDBACK @CORELAB.COM ' Petroleum Services Division Core Laboratories Canada, Ltd 2810 - 12 Street N.E. Calgary, Alberta, Canada T2E 7P7 Tel: (403) 250 -4000 ' Fax: (403) 250 -5120 Core Lab www.corelab.com RESERVOIR OPTIMIZATION ' June 11, 2007 Talisman Energy Inc. ' 3400, 888 — r Street S.W. Calgary, Alberta T2P 5C5 Attention: Mr. Jason Lavigne ' Subject: TALISMAN F. E. X. AKLAQ #6 Our File Number: 52131 -07 -0150 Diamond coring equipment and water base mud were used to core the subject well. The core was boxed at the wellsite and transported to our Calgary laboratory. Prior to analysis, spectral gamma ray activity was measured. 1. Conventional, Plug Type Analysis (Humidity Dried) Thirty -six samples (38.1 mm diameter) were drilled from the bulk core using water. The samples were dried in a humidity oven at 60 Celsius and 50% relative humidity. Analysis includes porosity by ' Boyle's Law technique using helium as the gaseous medium and horizontal permeability to air. The results of these analyses are reported in both tabular and graphical form. ' Samples outside the 95% confidence interval (three standard deviations) on the Permeability X Porosity crossplot have been identified and have been checked and re- analyzed to ensure data integrity. ' As a guide to evaluation and correlation with other data, statistics with tabulated cut -off ranges and plots are also presented herein. The 1/3 slabbed portion of the core material was photographed and six sets of white light and ultraviolet light, 216 mm X 280 mm photographs and six compact disks will be forwarded to your office under a separate cover. Thank you for the opportunity to be of service. ' Yours truly, ' CORE LABORATORIES CANADA, LTD. David J. Brooks ' Supervisor, Routine Rock Properties DJB /wz enclosures Ma I NM NM MO MI NM • • MI NM MI Mli MN MN all MO MN ME CORE LABORATORIES Company TALISMAN ENERGY INC. Field AKLAQ #6 File No. 52131 -07 -0150 Well TALISMAN F.E.X. AKLAQ #6 Formation Date 2007 -04 -18 Location Coring Equip DIAMOND Analysts DJB Province ALASKA Coring Fluid WATER BASE MUD Core Dia 4 inch CORE ANALYSIS RESULTS TOP BOTTOM INTVL HUMIDITY CAPACITY HUMIDITY HUMIDITY HUMIDITY CAPACITY SAMPLE DRIED (MAXIMUM) DRIED DRIED DRIED DESCRIPTION DEPTH DEPTH REP PERMEABILITY Kair POROSITY (H oLft M) BULK DENSITY GRAIN DENSITY NUMBER ft ft ft mD and -ft % qm /cc (qm /cc) CORE NO.1 7125.0 - 7161.4 ft (CORE RECEIVED 36.4 ft) (12 BOXES) P 1A 7125.0 7125.5 0.5 PRESERVE 1 P 18 7125.5 7126.0 0.5 PRESERVE 1 SPH 1 7126.0 7127.1 1.1 0.13 0.14 19.0 21.0 2.21 2.73 ss of f dol lam SPH 2 7127.1 7128.0 0.9 0.17 0.15 19.4 17.5 2.19 2.72 ss of f dol lam SPH 3 7128.0 7129.0 1.0 0.17 0.17 19.3 19.3 2.2 2.72 ss of f dol lam SPH 4 7129.0 7130.1 1.1 0.12 0.13 18.2 20.0 2.33 2.85 ss of f dol sid lam SPH 5 7130.1 7130.6 0.5 0.04 0.02 14.0 7.0 2.38 2.77 ss vf f dol sid lam SPH 6 7130.6 7131.0 0.4 <.01 11.5 4.6 2.47 2.79 ss of f dol sid lam SPH 7 7131.0 7132.7 1.7 0.02 0.03 10.0 17.0 2.53 2.81 ss vf f dol glauc lam SPH 8 7132.7 7134.1 1.4 <.01 4.4 6.2 2.67 2.79 ss vf f dol glauc sid lam SPH 9 7134.1 7134.7 0.6 <.01 8.7 5.2 2.57 2.81 ss vf f dol glauc sid lam SPH 10 7134.7 7135.8 1.1 <.01 5.7 6.3 2.68 2.84 ss of f dol glauc sid lam SPH 11 7135.8 7136.4 0.6 <.01 7.9 4.7 2.84 3.08 ss vf f dol glauc sid lam SPH 12 7136.4 7137.1 0.7 <.01 6.5 4.5 2.62 2.80 ss vf f dol glauc sid lam SPH 13 7137.1 7138.9 1.8 <.01 10.9 20.0 2.7 3.03 ss of f dol glauc sid lam SPH 14 7138.9 7140.1 1.2 <.01 6.2 7.4 2.62 2.79 ss of f dol glauc sid lam SPH 15 7140.1 7140.7 0.6 0.01 0.01 8.4 5.0 2.53 2.76 ss of f dol glauc sid lam SPH 16 7140.7 7141.9 4.2 <.01 11.2 13.7 2.57 2.89 ss of f dol glauc sid lam SPH 17 7141.9 7142.1 0.2 <.01 10.0 2.0 2.48 2.76 ss of f dol glauc sid lam Page 1 of 2 MII • MIN OM MIN MI NM MO MIB 11. NM iii/ NM lal NM INN ii. INE MIN CORE LABORATORIES Company TALISMAN ENERGY INC. Field AKLAQ #6 File No. 52131 -07 -0150 Well TALISMAN F.E.X. AKLAQ #6 Formation Date 2007 -04 -18 Location Coring Equip DIAMOND Analysts DJB Province ALASKA Coring Fluid WATER BASE MUD Core Dia 4 inch CORE ANALYSIS RESULTS TOP BOTTOM INTVL HUMIDITY CAPACITY HUMIDITY HUMIDITY HUMIDITY CAPACITY SAMPLE DRIED (MAXIMUM) DRIED DRIED DRIED DESCRIPTION NUMBER DEPTH DEPTH REP PERMEABILITY Kair POROSITY (HELIUM) BULK DENSITY GRAIN DENSITY ft ft ft mD and -ft % 0-ft gm /cc (gm/cc) P 2 7142.1 7143.1 1.0 PRESERVE 2 SPH 18 7143.1 7143.7 0.6 <.01 10.2 6.1 2.45 2.73 ss of f dol glauc sid lam SPH 19 7143.7 7144.9 1.2 <.01 10.4 12.5 2.45 2.74 ss of f dol glauc sid lam SPH 20 7144.9 7145.9 1.0 <.01 9.5 9.5 2.52 2.78 ss of f dol glauc sid lam SPH 21 7145.9 7146.6 0.7 <.01 9.1 6.4 2.58 2.84 ss of f dol glauc sid lam SPH 22 7146.6 7148.1 1.5 <.01 2.9 4.4 3.24 3.34 ss vf f dol glauc sid lam SPH 23 7148.1 7149.0 0.9 <.01 3.7 3.3 2.77 2.88 ss vf f shy glauc sid lam SPH 24 7149.0 7149.8 0.8 <.01 5.0 4.0 2.83 2.98 ss off shy dol glauc sid lam SPH 25 7149.8 7150.8 1.0 <.01 5.5 5.5 2.71 2.87 ss of f dol glauc sid lam SPH 26 7150.8 7151.5 0.7 <.01 7.9 5.5 2.81 3.05 ss of f dol sid lam SPH 27 7151.5 7152.1 0.6 <.01 9.2 5.6 3.05 3.36 ss of f sid lam P 3 7152.1 7153.1 1.0 PRESERVE 3 SPH 28 7153.1 7153.8 0.7 <.01 9.9 7.0 2.97 3.30 ss vf f dol sid lam SPH 29 7153.8 7154.5 0.7 <.01 6.7 5.0 2.75 2.95 ss off shy dol sid lam SPH 30 7154.5 7155.4 0.9 <.01 4.3 3.9 2.99 3.13 ss vf f shy dol sid lam SPH 31 7155.4 7157.1 1.7 <.01 5.8 9.9 2.92 3.10 ss off shy dol sid lam SPH 32 7157.1 7157.9 0.8 0.01 0.01 4.2 3.4 3.31 3.46 ss vf f shy dol sid lam SPH 33 7157.9 7158.5 0.6 0.02 0.01 5.7 3.4 2.59 2.75 ss vf f shy dol glauc sid lam SPH 34 7158.5 7159.2 0.7 <.01 2.7 1.9 2.57 2.64 ss of f v shy dol glauc lam SPH 35 7159.2 7160.1 0.9 <.01 1.2 1.1 2.63 2.66 ss of f v shy dol glauc lam SPH 36 7160.1 7161.4 1.3 <.01 3.7 4.8 2.58 2.68 ss off shy dol glauc lam Page 2 of 2 1 MO MI - NM = • I • M MI E NM I NE NE = um mu am i - 'k'at8 Core Lab CODE KEY - DESCRIPTIONS ACA = Removed for advanced core analysis Is = Limestone SPH = Humidity analysis of small plug sample at 60 anhy = Anhydrite Iv = Large vug degrees Celsius and 50 % relative humidty arg = Argillaceous m = Medium SPP = Small plug from preserved section of the core AST = Appears similar to ml = Mud invaded SPT = Small Plug used for tracer analysis bit = Bitumen my = Medium vug ss = Sandstone bk = Break NA = Not analyzed by request ssdy = Slightly sandy ( <20 %) c = Coarse NR = Not received sshy = Slightly shaly ( <20 %) calc = Calcite (calcareous) OB = Overburden sample (permeability and sty = Stylolite (ic) carb = Carbonaceous porosity measured at net overburden sulf = Sulphur cbl = Cobble stress) sv = Small vug cgl = Conglomerate ool = Oolitic TEC = Thermal Extraction Chromatography to cht = Chert pbl = Pebble determine oil richness coal = Coal /coal Inclusion PFD = Preliminary Full Diameter sample TS = Thin section coq = Coquina ppv = Pinpoint vug uncons = Unconsolidated dol = Dolomite PR = Preserved for future studies vc = Very coarse f = Fine PSA = Particle size analysis of = Very fine fc = Filter cake on suface of core sample PSP = Preliminary Small Plug sample vfrac = Vertical fracture FD = Full diameter analysis including three pyr = Pyrite (pyritic) VIS = Viscosity of oil measured directional permeabilities, porosity and pyrbit = Pyrobitumen VOB = Vertical overburden sample (vertical densities ru = Rubble permeability measured at net overburden foss = Fossil (fossiliferous) SA = Sieve analysis stress) frac = Fracture (undifferentiated) sdy = Sandy vshy = Very shaly ( >40 %) fri = Friable SEM = Scanning electron microscope analysis VSP = Vertical small plug drilled from whole glauc = Glauconite (glauconitic) sh = Shale core to measure vertical permeability grnl = Granule shy = Moderately shaly (20% - 40 %) (and occasionally porosity) gyp = Gypsum sid = Siderite vug = Vuggy (vuggular) hal = Halite (salt) sltst = Siltstone ws = Water sand hfrac = Horizontal fracture sity = Silty XRD = X -ray diffraction I = Intercrystalline SP = Small plug (sample drilled from core in = Data unavailable due to poor sample quality IFD = Inner Full Diameter (Full diameter sample maximum horizontal direction and parallel to 10240 = Permeability >10 Darcies, (maximum is drilled from the bulk portion of the bedding plane where possible) permeability routine permeability measurement) core in the vertical direction for porosity, and grain density are measured permeability and porosity measurements) SPA = (Prefix A) Horizontal matrix permeability incl = Inclusions measured by pressure decay profile lam = Laminae (laminated) permeametry through a probe tip due to sample quality - - - IMIN 11.11 iNII MIN CORE LABORATORIES Company :TALISMAN ENERGY INC. Field :AKLAQ #6 File No :52131 -07 -0150 Well :TALISMAN F.E.X. AKLAQ #6 Formation : Date :2007 -04 -18 TABLE 1 SUMMARY OF CORE DATA ZONE AND CUTOFF DATA CHARACTERISTICS REMAINING AFTER CUTOFFS ZONE: ZONE: HUMIDITY DRIED PERMEABILITY: Identification Number of Samples 36 Top Depth 7125.0 ft Thickness Represented - -- 33.4 ft Flow Capacity 0.7 and -ft Bottom Depth 7161.4 ft Arithmetic Average 0.08 and Number of Samples 40 HUMIDITY DRIED POROSITY: Geometric Average 0.05 and Harmonic Average 0.03 and DATA TYPE: Storage Capacity 283.4 0 -ft Minimum 0.01 and Porosity • (HELIUM) Arithmetic Average •8.5% Maximum 0.17 and Permeability (MAXIMUM) Kair Minimum 1.2% Median 0.04 and Maximum 19.4% Standard Dev. (Geom) -- K*10 ± and CUTOFFS: Median 8.2% Standard Deviation ±4.7% Porosity(Minimum) 0.0 % HETEROGENITY(Permeability): Porosity(Maximum) • 100.0 % Permeability(Minimum) .0.0000 and HUMIDITY DRIED GRAIN DENSITY: Dykstra- Parsons Var. -- 0.612 Permeability(Maximum) 100000 and Lorenz Coefficient 0.251 Water Saturation(Maximum)•- Arithmetic Average •2.90 gm /cc Oil Saturation(Minimum) - Minimum 2.64 gm /cc AVERAGE SATURATION(Pore Volume): Grain Density(Minimum) 2.0 gm /cc Maximum 3.46 gm /cc Grain Density(Maximum) 3.46 gm /cc Median 2.81 gm /cc Oil - Lithology Excludes NONE Standard Deviation ±0.21 gm /cc Water - 1 1 Humidity Dried Permeability vs Humidity Dried Porosity 10 1 Log(Y) = .0885* X - 2.5283 1 Correlation Coef. = 0.949 I 1 __.... _ , _._ I la as I °' a w L 1 '' I CI • * ' + I .' I Z 0.1 ;. . 1 _e 0.01 I ' I 0.0 4.0 8.0 12.0 16.0 20.0 24.0 Humidity Dried Porosity : 1 TALISMAN ENERGY INC. - LEGEND - TALISMAN F.E.X. AKLAQ #6 ' AKLAQ #6 (7125.0 - 7161.4 ft) 1 Core Laboratories Canada Ltd. 1 1 CORE SPECTRAL GAMMA TALISMAN ENERGY INC. TALISMAN F. E. X. AKLAQ #6 (7125.0 - 7161.4 ft) 5 inches - 100 feet Core Laboratories Canada Ltd. CORE GAMMA DEPTH THORIUM URANIUM Total Gamma Thorium Uranium 0 API 150 1:240 0 PPM 40 0 PPM 40 Uranium Free Gamma MD in F Potassium 0 API 150 0 FRAC 0.08 7110 , MI MINIM 7120 NM I ■IIII 7130 il l ■ el 1 ---" \ 7140 7150 - -aaa KII ,, ogii_ , UM MP ••■■••.............. ...mgr_mr Illib dala- iiie"" C- Fr- doi 7160 Ill ,-.....■ 7170 E III MI 7180 Potassium Total Gamma 0 FRAC 0.08 0 API 150 1:240 Uranium Free Gamma MD in F 0 API 150 Thorium Uranium 0 PPM 40 0 PPM 40 CORE GAMMA DEPT I THORIUM URANIUM 1 CORRELATION COREGRAPH TALISMAN ENERGY INC. TALISMAN F. E. X. AKLAQ #6 (7125.0 - 7161.4 ft) 5 inches -100 feet Core Laboratories Canada Ltd. Lithology ��� Limestone rAminis warAmp Dolomite Sandstone - - Shale ® Anhydrite � .p•r; Conglomerate t'' ( Glauconite _ _ _ ShaeySandstone Siltstone Coal .r,r G - -- GAMMA RAY (API) DEPTH HUMIDITY DRIED POROSITY /HUMIDITY DRIED GRAIN DENSITY Total Gamma Helium Porosity 0 API 150 1:240 50.0 % 0.0 Uranium Free Gamma MD in F Core Grain Density 0 API 150 2 GM /CC 3 7110 7120 — - -- --Q .e 7130 , ± _ �_ - — 7150 i — 7160 - -- -- - -- 7170 - -- 7180 Total Gamma Helium Porosity 0 API 150 1:240 50.0 % 0.0 Uranium Free Gamma MD in F Core Grain Density 0 API 150 2 GM /CC 3 GAMMA RAY (API) DEPTH HUMIDITY DRIED POROSITY /HUMIDITY DRIED GRAIN DENSITY CORRELATION CORE GRAPH TALISMAN ENERGY INC. TALISMAN F. E. X. AKLAQ #6 (7125.0 - 7161.4 ft) 5 inches - 100 feet Core Laboratories Canada Ltd. GAMMA RAY (API) DEPTH HUMIDITY DRIED HUMIDITY DRIED PERMEABILITY POROSITY Total Gamma Helium Porosity 0 API 150 0.0 % 50.0 Horizontal Kmax 1:240 • Uranium Free Gamma MD in F 0.001 MD 1 Core Grain Density 0 API 150 2 GM /CC 3 7110 I 7120 ".----"--V. 7130 � 7140 A - - - - - -- - - - -- — - -. 7150 _ ____ ..c., ,_ 7160 — ...___=,____ c 7170 1 7180 - - -- -- - - - - -- -- — Total Gamma Helium Porosity 0 API 150 0.0 % 50.0 Horizontal Kmax 1:240 • Uranium Free Gamma MD in F 0.001 MD 1 Core Grain Density 0 API 150 2 GM /CC 3 GAMMA RAY (API) DEPTH HUMIDITY DRIED HUMIDITY DRIED PERMEABILITY POROSITY Humble Geochemical Services • sit Division of Humble Instruments & Services, Inc. xui+► 218 Higgins Street Humble, Texas 77338 P.O. Box 789 Humble, Texas 77347 Telephone: 281 - 540 -6050 Fax: 281 - 540 -2864 Source Rock and Fluid Geochemistry of the Aklaq #6 Well, Alaska • Prepared for Talisman Energy Prepared by T.E. Ruble, B. M. Jarvie and D.M. Jarvie Project 07 -4547 Humble Geochemical Services Division RECEIVED June, 2007 S E P 0 6 2007 Alaska Oil & Gas Cons. Commission Anchorage • apt. ®D 153V(o Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division • Table of Contents Summary 3 Introduction and Background 4 Materials and Methods 4 Source -Rock Geochemical Results and Discussion 6 Source Rock Quality 6 Source Rock Thermal Maturity 8 Fluid Geochemical Results and Discussion 10 Background Information — "Oil" Show 10 Geochemical Characterization — "Oil Show 14 Geochemical Characterization — Drilling Additives 18 Geochemical Characterization — Additive Mix #1 22 Reservoir Core Extract Geochemical Results and Discussion 25 Interpretative Conclusions 29 References 30 Appendix 1 Methods Appendix 2 Source Quality Data Appendix 3 Optical Kerogen Data Appendix 4 Extract and Fluid Chromatography Data List of Figures Figure 1 Geochemical log for the Aklaq #6 well. 7 Figure 2 Kerogen type plot from Rock -Eval 8 Figure 3 Kerogen type and maturity plots from Cal. %Ro 9 Figure 4 Photos of "black oil" on Aklaq #6 shale shaker 11 • Figure 5 Photo of "black oil" recovered from Aklaq #6 "possum belly" mud 13 Figure 6 Photo of amber aqueous brine fluid recovered from Aklaq # 6 mud at 7170' 13 Figure 7 Photo of "black oil" and mud from Aklaq #6 examined in the field 14 Figure 8 Photo of "black oil" recovered from Aklaq #6 mud after centrifuge separation 15 Figure 9 Whole oil GC fingerprint of black "oil" recovered from Aklaq #6 16 Figure 10 Saturated biomarker GC -MS traces of black "oil" recovered from Aklaq #6 17 Figure 11 Photos of Dril -N -Slide and Barablok drilling additives . 18 Figure 12 Whole oil GC fingerprint of Dril -N -Slide additive 19 Figure 13 Whole oil GC fingerprint of Barablok additive 20 Figure 14 Saturated biomarker GC -MS traces of Barablok additive. 21 Figure 15 Photos of drilling additive Mix #1. 22 Figure 16 Photos of Dril -N -Slide and additive Mix #1 taken under UV light 23 Figure 17 Whole oil GC fingerprint of drilling additive Mix #1 24 Figure 18 Saturated biomarker GC -MS traces of drilling additive Mix #1 . 26 Figure 19 Whole oil GC fingerprint of 7125.6' Aklaq #6 core extract 27 Figure 20 Saturated biomarker GC -MS traces of 7125.6' Aklaq #6 core extract 28 List of Tables Table 1 List of samples and analyses 5 Table 2 Summary of source, kerogen type, maturity and generation assessment 10 Table 3 Partial summary of drilling history and additives 12 Table 4 Summary of select geochemical data from Alaskan oils 29 • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 2 Humble Geochemical Services Division Summary Rock and fluid geochemical analyses of samples recovered from the Aklaq #6 well located in Alaska's National Petroleum Reserve have been used to assess hydrocarbon prospectivity. In particular, one of the main objectives of the current study is to conclusively document the occurrence of "black oil" shows reported from this well. These "oil" shows have been found to be a consequence of the addition of two drilling additives (Dril -N -Slide and Barablok) and do not represent an indigenous oil show. Geochemical analyses of cuttings and core chip samples from depths between 3230 -7163' in the Aklaq #6 well show good to excellent organic richness, with TOC values that range from 1.2% to 4.7% and reach a maximum at a depth of 6590- 6620'. Interpreted organic matter type throughout most of the source interval is predominantly gas -prone Type III kerogen with the most prospective horizon containing a mixed oil /gas -prone Type II /III kerogen. Thermal maturity based on Rock -Eval parameters and measured vitrinite reflectance values of 0.95% Ro place this source interval in the peak oil window. These analyses offer insights into the origin of recovered fluid samples in the Aklaq #6 well. Potential source rocks appear to consist primarily of gas -prone terrestrial dominated kerogen with marginal oil generative. The in -situ products generated from these humic source rocks at peak oil window maturity are likely to be minor amounts of wet gas and associated aromatic type oils. One source interval with higher TOC has a probable mixed oil /gas -prone kerogen that could generate moderate amounts of both wet gas and oil. Importantly, each of • these potential source facies has a significant gas -prone component in their kerogen mix. Consequently, naturally occurring hydrocarbon shows in Aklaq #6 should correlate with elevated mud gas concentrations and any shows without such would be considered suspect. The "black oil" show recovered from the Aklaq #6 well is composed of predominantly polars and asphaltenes with only a minor amount of saturate and aromatic hydrocarbons (< 5 %). This feature is highly unusual for a naturally occurring crude oil. Detailed molecular GC and GC -MS fingerprinting reveal that the `oil" is composed predominantly of a series of 06 to 0 18 fatty acid esters that originated from the 440 gal. of Dril -N -Slide additive placed down the well on the day the "oil" show was recovered. In addition, biomarker analyses show that the predominant immature, lacustrine signature present in the recovered "oil" originated from Barablok, a gilsonite additive that was also added to the well. Laboratory tests confirm that Dril -N -Slide and Barablok can solubilize to form a black liquid that has all the physical and chemical features observed in the recovered "oil" show. A reservoir core sample recovered from the Aklaq #6 well at 7125.6' was analyzed and found to contain an apparently indigenous hydrocarbon signature with no drilling additive contamination. However, only a very low hydrocarbon recovery was obtained (413 ppm) implying that the reservoir has not received a significant migrated hydrocarbon charge nor much contribution from adjacent source -rocks currently in the peak oil window. This could be due to insufficient organic richness in the source facies, a predominance of gas -prone organic matter and /or poor reservoir quality. The GC fingerprint of the core extract is dominated by light hydrocarbons maximizing at C14 and has the appearance of high API gravity oil associated with mature source rocks in the peak to late oil window. Other biomarker evidence is less diagnostic and no conclusive oil -oil or oil- source rock correlation • could be obtained. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 3 Humble Geochemical Services Division Introduction and Background Cuttings, core and fluid samples along with various drilling additives from the Aklaq #6 well drilled in Alaska's National Petroleum Reserve were submitted by Talisman Energy in order to assess hydrocarbon prospectivity and to examine the origin of apparent hydrocarbon "shows ". Potential source rocks samples were evaluated for source quality, thermal maturity and various other geochemical parameters, as described in the Material and Methods section below. A reservoir core sample recovered from this well was solvent extracted and the products were analyzed to assess their indigenous origin. Fluid samples recovered at various times during drilling were also evaluated using a variety of detailed molecular geochemical techniques to assess their origin, thermal maturity and oil- source correlation. As a consequence of these analyses, a variety of drilling additives and combinations of additives were also evaluated in a similar manner to provide potential correlation with recovered "oil" shows. The source rock geochemical results from the Aklaq #6 well will be presented first in this report, followed by fluid geochemical results, reservoir core extract geochemical results and an integrated geochemical interpretation. Relevant figures accompany the text, while the complete data set is documented in the Appendices. Materials and Methods • A complete list of samples and the analyses performed on each is given in Table 1. Methods are discussed in detail and the analytical procedures are presented in Appendix 1. In total, 11 cuttings and core chip samples from the Aklaq #6 well were analyzed for a combination of TOC (total organic carbon), Rock -Eval analyses, and select vitrinite reflectance and visual kerogen assessment. Three (3) samples of "oils" recovered from drilling mud were selectively analyzed by API gravity, liquid chromatography (LC), gas chromatography (GC) and gas chromatography mass spectrometry (GC -MS). Also, a set of five (5) drilling additives were analyzed in a similar manner. An additive mixture was prepared from a combination of two of the drilling additives and it too was analyzed in the same manner as the recovered "oil" samples. Finally, a reservoir core sample taken from an interior location in a recovered core at a depth of 7125.6' was extracted and the core extract was analyzed by GC and GC -MS to attempt to obtain an indigenous oil fingerprint. • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 4 Humble Geochemical Services Division • I 0 Table 1. List of related Aklaq # 6 samples and anal ses. Type API Ext. Ext. Whole Whole S/A HGS Depth Vitrinite Rock Eval Solvent LC GC GC -MS Oil Oil GC -MS No. (ft.) RoWR LTOC Extraction GC GC -MS 07- 4547 - 194092 cuttings 3230 -3260 X 07- 4547- 194093 cuttings 4670 -4700 X 07- 4547 - 194094 cuttings 5390 -5420 X 07- 4547 - 194095 cuttings 6260 -6290 X 07- 4547 - 194096 cuttings 6590 -6620 X 07- 4547- 194097 cuttings 6680 -6710 X . 07- 4547 - 194098 cuttings 6750 -6760 X 07- 4547 - 194099 cuttings 6840 -6850 X 07- 4547 - 194030 core 7131.75 X 07- 4547 - 194031 core 7146.5 X 07- 4547 - 194100 cuttings 7160 -7163 X 07- 4547 - 191107 `oil" in mud 6830 X X X "rock washer" 07- 4547 - 194028 `oil" in mud 6830 X "possum belly" 07- 4547 - 197803 "oil" in mud 7170 X 07- 4547 - 194031 SteelSeal X X 07- 4547 - 194032 Baro -trol Plus X X X X 07- 4547- 194033 Gilsonite X X X X 07- 4547 - 194034 Barablok X X X X 07- 4547 - 195894 Dril -N -Slide X X X X 07- 4547 - 195895 Additive Mix #1 Dril -N -Slide + X X X X Barablok (68 mg /ml) 07- 4547 - 198186 core 7125.6 X X X Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 5 Humble Geochemical Services Division • Source -Rock Geochemical Results and Discussion Source rock quality and thermal maturity data are documented in Appendices 2 and 3 for the Aklaq #6 well. Figure 1 is a geochemical log of the source rock richness, quality and maturity data, which are also illustrated individually in Figures 2 & 3. A summary of interpreted source rock richness, kerogen type, thermal maturity and generation assessment is provided at the end of this section in Table 2. Source - Rock Quality A total of nine (9) hand picked cuttings samples and two (2) coal core samples from depths between 3230 -7163' in the Aklaq #6 well were examined in this study for geochemical and petrographic analyses, respectively. Organic richness varies from good to excellent, with TOC values that range from 1.2% to 4.7% and reach a maximum in the cuttings samples analyzed at a depth of 6590- 6620'. Very thin (mm sized) coal stringers and chips picked from core at 7131.75' & 7146.5' were not analyzed for TOC or Rock -Eval, but undoubtedly these preserved terrestrial coal samples would have very elevated organic richness. Remaining hydrocarbon generative potential of cuttings from the Aklaq #6 well as measured by Rock -Eval S2 of -1 -12 mg HC /g rock is poor to very good. Most samples are in the poor to fair range and only the zone of most elevated TOC at 6590 -6620' has significant remaining generation potential. Oil content measured by the Rock -Eval 81 for these samples is poor to good and varies from 0.3 -1.7 mg HC /g rock. However, normalized • S1/TOC values are all < 40 and suggest low in -situ oil saturation. Furthermore, most of the samples analyzed by Rock -Eval show evident low temperature S2 shoulders (noted ItS2sh in the tabular data) and this observation combined with the documented addition of various additives (Baratol Plus and Barablock) could indicate potential contamination artifacts in the Rock -Eval data. Thus, even geochemical data from hand picked samples should be used with a certain degree of caution. The organic matter type for most of the Aklaq #6 cuttings samples is currently gas -prone Type III kerogen (Fig. 3) with Hydrogen Index (HI) values <200 mg HC /g TOC and low S2 /S3 ratios. These values have likely been lowered somewhat from their original values due to thermal maturity. However, elevated Oxygen Index (01) values up to 81 mg CO /g TOC suggest deposition of predominantly terrestrial organic matter in an oxic /sub -oxic deltaic or proximal marine setting. Visual kerogen analysis of core chips from 7131.75' & 7146.5' confirm the presence of thin stringers of vitrinite -rich coals and support a Type III kerogen classification for most of these source rocks. The elevated TOC sample from 6590 -6620' has an HI of 266 mg HC /g TOC and would be classified as a mixed oil /gas -prone Type 11/111 kerogen. The lower 01 and higher S2 /S3 ratio for this sample along with its elevated TOC suggest that this particular source rock interval was likely deposited in a more distal anoxic marine setting. Further confirmation of source rock organic matter type will require supplemental petrographic examination of hand - picked cuttings to confirm the proportions of terrestrial organic matter (Type 111) in comparison to oil -prone marine algal (Type II) and inert oxidized marine (Type IV). • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 6 Humble Geochemical Services Division • i • ,, Figure 1. Geochemical log for the Aklaq #6 well. LOG 1: ORGANIC LOG 2: HYDROCARBON LOG 3: ORGANIC MATTER LOG 4: NORMALIZED OIL LOG 5: CALCULATED LOG 6: MEASURED RICHNESS POTENTIAL TYPE CONTENT MATURITY MATURITY 0 Organic Excellent Gas Mix Oil Oil (Isar.. (lac.) 11 y e e C v N N tp ° 2 v o c @ 1000 - N U U z @ f, W F a e a 2000 • S.7 3000 - • ♦ A • + i 4000 - 0 O • • A • + 5000 - • • A I + 6000 - ■ O A P + • ill • 0 8 0 2 ° • +# 7000 - • ® A • + • 8000 0 0 5A 10.0 0 5 la 15 20 0 500 1000 0 50 100 150 200 02 07 1.2 17 2.2 02 0.7 1.2 1.7 2.2 IOC (wt.%) OIL PO TENTTAL (52) HYDROGEN INDEX(HI) NORMALIZED OIL C ORIENT CALCULATED VRo VITRNITEREFLEC TANG m ,...21e Oaooneracal ,erv.rAc Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 7 Humble Geochemical Services Division • Figure 2. Kerogen type plot from Rock -Eval. 1000 900 - Typel Oil Prone 800 - 700 - U - O H - O 600 - U - S E Type 11 (usu. marine) Oil Prone 500 - x - w z z 400 - O _ tY O _ } Mixed Type 11 /111 300 - Oil / Gas Prone • 200 " : • Type Ill Gas Prone • 100 - • • • • Type IV Gas Prone 0 0 20 40 60 80 100 120 140 160 180 200 OXYGEN INDEX (01, mg CO2 /g TOC) Source Rock Thermal Maturity Most Rock -Eval thermal maturity indicators suggest that the source interval intersected in the Aklaq #6 well is currently in the main oil generation window. Rock -Eval derived Tmax values vary between 432 - 443 °C, which corresponds with the early oil window. Calculated reflectance values derived from Tmax generally increase with depth (Fig. 1) and vary between 0.62% and 0.81% Calc. Ro (Fig. 3), indicating a slightly higher maturity level within the main oil generation window. This calculation is based upon a formula developed using Barnett Shale samples from the Fort Worth Basin (Jarvie et al., 2001) and may not be directly comparable to the somewhat different mineralogy of the samples examined in the present study. Production index (PI) values for cuttings samples from the Aklaq #6 well vary from 0.14 to 0.27, consistent with an early oil window maturity. In general, normalized oil saturation levels within these cuttings samples are low, which is probably more a consequence of predominant gas -prone organic matter type rather than lack of sufficient thermal maturity for potential oil generation. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 8 Humble Geochemical Services Division S In comparison, actual measured vitrinite reflectance (Ro) measurements on two coal chips recovered from Aklaq #6 core samples at 7131.75' & 7146.5' give somewhat higher maturity readings of 0.95% & 0.96% Ro, respectively (Fig. 1). These measured vitrinite reflectance reading are indicative of a peak to late oil window thermal maturity. No kerogen or maceral fluorescence colors could be measured on the coal samples analyzed, but the dominant vitrinite groundmass gives good confidence levels in the measured Ro data acquired. It is also of interest to note that the petrologist recognized abundant pyrite and marcasite in one of the coal samples examined. If this pyrite is framboidal in form, it may be indicative of a marine influenced depositional setting. Sulfate reducing bacteria activity on organic matter in marine deposits reportedly can result in this type of pyrite. It is normally most common in hydrogen rich (reducing) marine source rocks. Further mineralogy and petrology analyses of a more complete suite of core samples from the Aklaq #6 well would be required to evaluate the source rock depositional setting. Figure 3. Kerogen type and maturity plot (Cal. %Ro). 1000 - 0.55 %V Ro - - ,h dow Type l oil ". 900 - Oil Prone (usu. lacustrine) 800 - • 700- U O - ~ 600 - ?) Type II Oil Prone - E - marine) x 500 - w O - z w • - O • 400 - • - - 300 - Mixed Type / nl Oil / Gas Prone 200 - - 1.00% Conden Gas "1ndo Type III 0 o sate Gas Prone 0 100 - 00 0 0 11..40%VRo pCY G8 Wd1d0 - Type IV 0 4 , 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00 2.20 Calculated Vitrinite Reflectance Equivalent (Cal.VReq.) © Hunble Geocherrical Services • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 9 Humble Geochemical Services Division Geochemical and petrographic analyses of a limited suite of cuttings and core chip samples recovered from the Aklaq #6 well offer some useful insights into the likely origin of recovered fluid samples in this well, which will be discussed further in the following section of this report. Potential source rocks appear to be present throughout the sampled interval from 3230' to 7163'. Most of the interval appears to consist of gas -prone terrestrial dominated Type III kerogen with marginal oil generative capacity that presently has a thermal maturity within the early to peak oil widow. The in -situ products generated from these humic source rocks are likely to be minor amounts of wet gas and associated aromatic type oils. Source rocks in the interval from 6590 -6620' appear slightly more prospective, with higher TOC and a probable mix of oil /gas -prone Type II /III kerogen that would be expected to generate moderate amounts of both wet gas and oil at the current level of thermal maturity. Importantly, each of the potential source facies examined appear to have a significant gas -prone component in their kerogen mix. Consequently, all naturally occurring hydrocarbon shows recovered from the Aklaq #6 drill -hole would be expected to correlate well with elevated mud gas concentrations and any shows without a significant accompanying gas signal would be considered very suspect. Table 2. Summary of source, kerogen type, maturi and generation assessment. Well Source Rock Kerogen Thermal Generation Name Richness Type Maturity Assessment Aklaq #6 good — excellent Type Ill & peak oil minor /moderate wet gas & oil Type II /III window S Fluid Geochemical Results and Discussion Fluid geochemical analyses results are fully documented in Appendix 4 for the various samples from the Aklaq #6 well examined in this study. Representative photos, chromatograms and ratio plots are illustrated in the text to assist in developing the geochemical interpretations that have been reached regarding the composition and origin of occurrence of the recovered fluids from this well. Background Information — "Oil" Show Drilling fluid samples, including several recovered mud samples from the Aklaq #6 well were submitted for geochemical analyses to determine the origin of apparent "oil" shows. According to information supplied by the client, mud samples were collected on multiple occasions when "petroliferous odor" in the mud and "black oil" on the shakers was observed. These oils were analyzed in the field under UV light and showed yellow -green fluorescence, suggesting that they were indigenous oil shows. Figure 4 documents photographs taken on 4 -16 -07 at the time when the "black oil" was seen on the shale shakers. Two different submitted samples of this mud with "black oil" were analyzed during the course of the current investigation (Table 1 & 3). In addition, according to the client, this well apparently encountered a difficult drilling history with several episodes of lost mud circulation that necessitated the use of a variety of mud additives and even some "recycled" mud used for an adjacent well. A partial summary of drilling history related to additives, operational comments and samples analyzed in this study is presented in Table 3. • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 10 Humble Geochemical Services Division • m 0 4014 II f # ° i . 1 ' ..q tr 4 40 , ii t • , ` l4∎4 a . N EA T 0 Figure 4. Photos of "black oil" on Aklaq #6 shale shaker. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 11 Humble Geochemical Services Division Table 3. Partial summar of Akla• #6 drillin• histo and additives. Date Additive Quantity Sample Operational Comments 4 -5 -07 Baro -trol Plus 2000 lbs. Torok claystones 4 -6 -07 Baro -trol Plus 7650 lbs. 4 -7 -07 Baro -trol Plus 500 lbs. Torok sand 6 4 -8 -07 Baro -trol Plus 1900 lbs. 750 bbls losses 4-9-07 Baro -trol Plus 600 lbs. Pumped pill before coring Baraklok 600 lbs. 63 bbls losses 4 -10 -07 90 bbls losses, POOH, test BOP's 4 -11 -07 310 bbls losses, RIH w /core barrel 4 -12 -07 1128 bbls losses, cut core 4-13-07 Bara -trol Plus 650 lbs. 7170' mud 69 bbls losses, POOH w /core 07- 4547 - 197803 4 -14 -07 Bara -trol Plus 1250 lbs. 479 bbls losses, RIH drill to TD, POOH 4 -15 -07 Baro -trol Plus 250 lbs. 190 bbls losses, POOH Barablok 250 lbs 6830' muds 520 bbls losses, sticky hole on wiper trip Dril -N -Slide 440 gal. 07-4547-191107 "black oil" w /no gas seen on shakers 4 -16 -07 rock washer when hole heavily swabbed 07- 4547 - 194028 "possum belly" SteelSeal 07- 4547 - 194031 Baro -trol Plus 07- 4547 - 194032 G i lson ite 07- 4547 - 194033 Barablok 07-4547-194034 Dril -N -Slide 07-4547-195894 • Additive Mix #1 07- 4547 - 195895 DriI -N -Slide + Barablok (68 mg /ml) From the mud samples collected at the time of the "black oil" shows, two different samples were obtained and analyzed. These two samples were separated from the mud by use of a centrifuge, then recovered with a glass pipette and placed in small 2 ml sample vials for geochemical analyses (see photo in Fig. 5). The original samples came from the Aklaq #6 "rock washer" and from the "possum belly" and differed somewhat in their physical characteristics, with the former being a bit thicker and having a higher apparent viscosity /gravity. Too little sample material from these "black oils" was recovered for determination of API gravity and /or viscosity. However, liquid chromatography (LC) and both gas- chromatography (GC) and gas- chromatography /mass spectrometry (GC -MS) were completed on select samples and will be discussed later. The "black oil" samples were recovered on 4- 16 -07, but another potential hydrocarbon "show" was encountered prior to collection of these samples. On 4 -12 -07 coring was begun at a depth of 7130' in the Aklaq #6 well and during the course of the next few days, strong "petroliferous odors" were noted in the drilling mud all the way until the well reached TD at 7280' on 4- 14 -07. During this time, a sample of mud from 7170' was collected and submitted for geochemical analyses. An amber colored liquid separated from the mud and was collected with a pipette to be analyzed (Fig. 6). API gravity determination was performed on this sample, which smelled strongly of hydrogen sulfide. Based upon these results (specific gravity of 1.05) and qualitative solubility tests, this recovered drilling fluid was determined to simply be brine water associated with the drilling mud. The amber color is apparently caused by another drilling additive called "Baranex ", which is a polymerized lignin powder (D. Higbie, per. comm.). As a consequence of these determinations, no further geochemical tests were conducted to assess the origin of the "petroliferous odor" in these mud samples. • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 12 Humble Geochemical Services Division • Possum Beihi vOGC :0•5 Notarstair Figure 5. Photo of "black oil" recovered from centrifuge of Aklaq #6 "possum belly" mud (HGS #07- 4547 - 194028). • Aklaq #6 7170' Figure 6. Photo of amber aqueous brine fluid recovered from Aklaq #6 mud at a depth 40 of 7170' (HGS #07- 4547 - 197803). Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 13 Humble Geochemical Services Division • Geochemical Characterization - "Oil" Show Despite the apparent volumes of "black oil" observed on the shale shaker and other drilling apparatus (Fig. 4), recovery and isolation of discrete "oil" from the mud samples collected proved surprisingly difficult. Field samples (Fig. 7) show how the "oil" and mud commingle and mix to form a composite sample that would be unsuitable for direct geochemical analyses. Samples shipped in plastic bags and neoflon bottles to the laboratory for analyses did not contain a separated "oil" and mud layer, but had globules of what appeared to be heavy /viscous and dispersed "oil" floating about in the water based drilling mud. The most obvious methodology for separating the drilling mud from the "oil" in these samples was by using differences in density and a centrifuge to separate a heavier mineral phase (containing barite etc.) from an predominantly aqueous phase and then (in principle) a lighter "oil" layer on top of the water. However, when this was attempted on an aliquot (-10 ml) of the mud, no discrete aqueous layer formed and only a very minor black "oil" layer (< 0.25 ml) was observed on top of the predominantly brown mud. To recover sufficient amounts of "oil" to attempt a determination of API gravity, liquid chromatography and other geochemical analyses, multiple mud centrifuge separations were required and the combined recovered "oil" was collected in a single centrifuge vial ( -5 ml). At this point in the collection process, it was determined that a prudent approach would be to ensure that no mud remained in the combined aliquots of "oil" that had been pipette transferred to the centrifuge tube. Thus, a final centrifuge separation was performed on the combined "oil" sample. The results of this sample clean up attempt are shown in Fig. 8. „ gy m. 144477 ://////§ / / it 4 1k sk1 • k .f ' 3 r • Figure 7. Photo of "black oil" and mud recovered from Aklaq #6 examined in the field. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 14 Humble Geochemical Services Division • Figure 8. Photo of "black oil" recovered from Aklaq #6 mud • after centrifuge separation. Only a very small "oil" layer formed after secondary centrifuge separation. Once the combined "oil" aliquot was centrifuged, an abundant solid residual fraction formed and only a very minor amount of liquid layer formed (< 0.25 ml). In hindsight, it is now apparent that the cause of this occurrence is due to the differences "oil" between recovered "oil" in solution versus recovered "oil" in suspension. The majority of the "oil" obtained from centrifuge separation of the Aklaq #6 drilling mud appears to be suspended particulate material and very little actual liquid "oil" in solution was recovered. However, the recovered black, semi - solid, suspended residual material in the "oil" could not be completely separated using the centrifuge and was still quite "wet ". This heterogeneous behavior is highly unusual for a typical oil sample. While some DST oils are know to contain suspended and /or particulate mineral matter, the in -situ suspension of organic constituents (e.g. asphaltenes) in an oil could likely only result from a mixing of two different oils (one heavily asphaltic and the other dominated by light aliphatic hydrocarbon components). As noted, insufficient amounts of the isolated "oil" were recovered to enable an API gravity • determination. However, there was sufficient material to undertake liquid chromatography (LC) separation and to perform gas chromatography. The fractional composition of the recovered "oil" is dominated by resins (46 %) and asphaltenes (45 %), with only minor abundances of saturated hydrocarbons (2 %) and aromatics (3 %). Based on this composition the oil would be classified as an "aromatic asphaltic" crude oil (Tissot and Welte, 1978). Naturally occurring examples of these types of nondegraded oils are very rare and include the heavy oils from Venezuela and the South Aquitaine basin (France). Most oils in this group are degraded oils resulting from alteration of aromatic - intermediate (particularly high sulfur) crude oils, for example most degraded tar sands from Western Canada fall in this class. Thus, from a bulk fractional composition the "oil" recovered in the Aklaq #6 well is highly unusual and this result along with the abnormal proportion of suspended particulates in the "oil" raises serious questions regarding its indigenous origin. A gas chromatographic fingerprint of the recovered Aklaq #6 "oil" sample was obtained on two different mud samples collected at the "rock washer" and the "possum belly ". Both of these fingerprints are identical and consequently, all further discussion will pertain to data from the "rock washer" sample (HGS #07-4547-191107) where sufficient amounts of material were obtained to also enable LC and GC -MS analyses. The GC fingerprint of the recovered "oil" sample is highly unusual and is dominated by a simple pattern of peaks that have been confirmed via full -scan GC -MS to be a series of C6 to C18 fatty acid esters (Fig. 9). Such peaks are clearly not related to an indigenous oil sample and could only originate from a drilling additive. A closer examination of a much enhanced GC trace (Fig. 9) shows that there are indeed minor peaks present in the "oil" in addition to the series of fatty acid esters. These peaks correspond in general with typical patterns of isoprenoids, steranes, hopanes and 3- carotane that have been previously reported from solvent extracts of gilsonite (Ruble, 1990; Ruble and Philp, 1991). Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 15 Humble Geochemical Services Division FID1 A, (G \1 \DATA \TALISMAN \07 -4547 \01911078 D) pA- 012 Aklaq #6 "Oil" 1600 - 1400- 1200- Fatty acid esters 1000- C14 800 - 600- C10 400- C 200- 016 C6 note carbon # refers to acid chain not total 0 018 20 30 40 50 60 70 80 90 miR FID1 A, (G 11 \DATA \TALISMAN \07 -4547101911078 D) pA S 9 6- carotane hopane 8 - I 6- 5- 20 30 40 50 60 70 80 90 mu Figure 9. Whole oil GC fingerprint of black "oil" recovered from Aklaq #6 showing distribution of C6 to C18 fatty acid esters (top) and enhanced to show minor abundances of other peaks corresponding to various biomarkers (bottom). Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 16 Humble Geochemical Services Division 14000 m /z217 :Steranes Aklaq #6 "Oil" 12000 - 10000 - e , v 8000 - c St N 6000 - 4000 - rc 1 2000 - + y w Qv 44 48 52 5 6 60 64 68 Retention Time (min.) 60000 m/z 191: Tri-, tetra- and pentacyclic Terpanes 50000 - 40000 - U � U . 30000 - 4 i C7 20000 - 40 rE u — - e u 0 n 10000 - � U ry f5 a n N W m U U n .1 U u U U .6 U U f 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) Figure 10. Saturated biomarker GC -MS traces of black "oil" recovered from Aklaq #6 showing distribution of steranes (top) and hopanes (bottom) that have typical immature signatures and diagnostic lacustrine biomarkers like gammacerane typically found in gilsonite and related products. Gas chromatography mass spectrometry biomarker analyses were performed on both the saturate and aromatic fractions of the "oil" recovered from the Aklaq #6 well. The complete results of these analyses are reported in Appendix 4. Steranes distributions in the m/z 217 mass chromatogram (Fig. 10) are dominated by the C28 regular sterane series, with relatively low abundances of the diasteranes. The 029 regular steranes are also present in high abundance in comparison to the 027 steranes. This pattern is fairly typical of Uinta Basin gilsonite extracts previously reported (Ruble, 1990; Ruble and Philp, 1991), although variations in different vein deposits can result in almost equal proportions of the C28 and 029 steranes in some instances. Uinta Basin gilsonite is thought to originate as a low maturity expulsion product from lacustrine oil shales in the Green River Formation (Ruble et al., 2001). All of the measured sterane maturity ratios in the Aklaq #6 "oil ", such as the C29 20S /(S +R), are well below their thermal endpoint values of -0.5, suggesting a pre -oil window maturity. In general, the overall pattern within the sterane mass chromatogram is consistent • with an immature bitumen fingerprint derived from gilsonite and /or related drilling additives. Source Rock and Fluid Geochemistry of the Aklaq #6 Well - Talisman Energy 17 Humble Geochemical Services Division • Such a pattern could definitely not be found in a thermally mature natural crude oil and is inconsistent with the peak oil window maturity of the adjacent Aklaq #6 source rocks (see previous section). Hopane distributions in the m/z 191 mass chromatogram (Fig. 10) show relatively low abundances of tricyclic terpanes and elevated concentrations pentacyclic hopanes in the Aklaq #6 "oil ". The hopanes are dominated by C30 hopane, with lesser amounts of the 029 norhopane. Moretane (the (3a configuration of C30 hopane) is also present in very high abundance in this "oil ", a most unusual occurrence due to its relatively low thermal stability. The biomarker gammacerane is present in this "oil" sample, which is used to infer anoxic depositional conditions and is commonly found in lacustrine source rocks, such as the Green River Formation (Hills et al., 1966). Similar abundances of gammacerane have been reported in gilsonite (Ruble, 1990; Ruble and Philp, 1991). The Ts/Tm hopane maturity ratio shows very abundant Tm indicating a low thermal maturity. This assessment is corroborated by a high moretane /hopane ratio that characteristic of immature bitumens. Only the 0 32 S /(S +R) terpane ratio appears to have reached its thermal endpoint, however, since this occurs pre -oil window it does not signify elevated maturity. All hopane maturity ratios are similar to previously reported data from gilsonite (Ruble, 1990; Ruble and Philp, 1991) and clearly point to this additive as the origin since the adjacent source rocks have peak oil window maturity. Geochemical Characterization — Drilling Additives • A variety of drilling additives were analyzed as part of the current investigation into the origin of the "oil" recovered in the Aklaq #6 well. Complete results from these various analyses are reported in Appendix 4. In particular, the two main additives, DriI -N -Slide and Barablok, which were added down the well on 4 -16 -07 just prior to the occurrence of "black oil" in the mud, have been fully characterized. Photos of these two drilling additives are shown in Fig. 11. The DriI -N -Slide is a clear liquid with a measured API gravity of 32.6 and a specific gravity of 0.86 that is used as a drilling lubricant. The Barablok is a very fine dark brown to black colored powder with a reported bulk density of 30 Ibs /ft and a specific gravity of 1.05 that is used as a drilling fluid loss additive. Both products are trade names of Halliburton. Dril -N -Slide Barablok Figure 11. Photos of drilling additives placed into the Aklaq #6 mud system just prior to the occurrence of "black oil ". Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 18 Humble Geochemical Services Division FID1 A, (G:\11DATA \07 -4547 \0195894A D) C12 pA - DriI -N -Slide 5000 - 4000- Fatty acid esters 3000- 014 2000- I C C10 8 1000- 0 16 0 6 note carbon # refers to acid chain not total C18 20 30 40 50 11 _ 60 70 80 90 m FID1 A, (G: \1 \DATA\074547 \0195894A.D) pA 45- . 40 35- 30- 25- 1 20 15 I 10 5 20 30 40 50 60 70 80 90 mir Figure 12. Whole oil GC fingerprint of DriI -N -Slide mud additive showing distribution of C6 to C18 fatty acid esters (top) and enhanced to show minor abundances of other peaks and absence of biomarkers (bottom). • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 19 Humble Geochemical Services Division A gas chromatographic fingerprint of the DriI -N -Slide additive (HGS #07- 4547 - 195894) is shown in Fig. 12. The distribution of components is dominated by the same pattern of peaks that have been confirmed via full -scan GC -MS to be a series of 06 to 018 fatty acid esters. These peaks have a fingerprint, with the 012 fatty acid ester as the predominant component, which is identical to that of the Aklaq #6 "oil ". This is unequivocal confirmation that the origin of this "oil" is at least partially derived from the DriI -N -Slide additive. A closer examination of a much enhanced DriI -N -Slide GC trace (Fig. 12) shows that there are also minor peaks present, but that the characteristic biomarkes found in the "oil" are missing. These peaks correspond in general with typical patterns of isoprenoids, steranes, hopanes and (3- carotane that have been previously reported from solvent extracts of gilsonite (Ruble, 1990; Ruble and Philp, 1991). The absence of these components from the DriI -N -Slide implies that their origin in the Aklaq #6 "oil" must be attributable to a secondary additive. Obviously, this is also implied by difference in physical characteristics like color that have been documented for the recovered "oil" and the DriI- N- Slide. FID1 A, (G \1 \DATA 107 -4547 \E194034A D) pA 22 5- Barablok 20- 175- 15- steranes • 125= p a hopanes p- carotane 7 5- U Q o � s - I 2 5- 20 30 40 50 60 70 80 90 mil Figure 13. Whole oil GC fingerprint of Barablok mud additive showing distribution of C to C20 n- alkanes and other peaks corresponding to various biomarkers. Knowing that the drilling additive Barablok had been put down the Aklaq #6 well at the same time as the DriI -N -Slide lubricant, a gas chromatographic fingerprint of this material was necessary to evaluate whether it also contributed to the recovered "black oil ". Barablok (HGS # 07- 4547 - 194034) is essentially completely soluble (96 %) in organic solvents and its fractional composition is dominated by asphaltenes (66 %) and resins (26 %). The GC fingerprint of Barablok shows a series of C to C20 n- alkanes as the dominant peaks with subordinate amounts of isoprenoids like pristane and phytane. Obvious biomarkers in the sterane and hopane region are also present and these are discussed further in regard to the GC -MS analysis of this sample. The characteristic algal isoprenoid biomarker 3- carotane is present in elevated concentrations, although its peak height is not reflected accurately on the chromatogram relative to peak area due to the temperature program of the GC. The basic pattern of peaks present in the Barablok are very similar, if not identical, to the distribution of • minor peaks in the expanded GC trace of the Aklaq #6 "oil" shown in Fig. 9. These peaks Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 20 Humble Geochemical Services Division • correspond in general with typical patterns of isoprenoids, steranes, hopanes and R- carotane that have been previously reported from solvent extracts of gilsonite (Ruble, 1990; Ruble and Philp, 1991) and it is concluded that Barablok is simply a trade name for the asphaltic bitumen gilsonite. The only major exception between the GC trace of Barablok and that reported previously for gilsonite is the unusually high relative abundance of n- alkanes in the C to 020 region. However, a sample of actual gilsonite supplied for this study by the client (see Appendix 4) also shows similar abundances of n- alkanes. In fact, the GC traces between Barablok, Baro -trol Plus and gilsonite are virtually identical and these are obviously related products. The Baro -trol Plus has a much lower solubility (only about 31 %) and it is reported to be a modified asphalt containing additional sulfur cross linkages that apparently reduce its solubility. 50000 m/z 217: Steranes 45000 - Barablok 40000 - 35000 - 0 a • 30000 - 6 a 0 c 25000 - K g 20000 - U • 15000 - 10000 - 5000 - i I1 JUL • 0 � utJLnl 44 48 52 56 60 64 68 Retention Time (min.) 160000 m/z 191: Tri-, tetra -and pentacyclicTerpanes 140000 - 120000 - ro • 100000 - m . 80000 - 4 Vr • 60000 - CM1 40000 - 6 iG u 20000 - 6 }.� U 6 UN n U U U U U U U U U U h 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) Figure 14. Saturated biomarker GC -MS traces of Barablok extract showing distribution of steranes (top) and hopanes (bottom) that have typical immature signatures and diagnostic lacustrine biomarkers like gammacerane typically found in gilsonite and related products. Compare to Fig. 10 to see similarity between biomarkers in Barablok and the "oil" recovered from the Aklaq #6 well. • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 21 Humble Geochemical Services Division • Gas chromatography mass spectrometry biomarker analyses were performed on both the saturate and aromatic fractions of the Barablok extract. The complete results of these analyses are reported in Appendix 4. Steranes distributions in the m/z 217 mass chromatogram (Fig. 14) are dominated by the C28 and 029 regular steranes, with relatively low abundances of the diasteranes. Hopane distributions in the m/z 191 mass chromatogram (Fig. 14) show low abundances of tricyclic terpanes and elevated concentrations pentacyclic hopanes, including moretane and gammacerane. These patterns are identical to that previously shown for the Aklaq #6 "oil" sample (Fig. 10) and also correspond with gilsonite (see Appendix 4). Almost all of the measured sterane and hopane maturity ratios in the Barablok extract are well below their thermal endpoint values, consistent with a pre -oil window maturity and an origin from gilsonite (Ruble, 1990; Ruble and Philp, 1991). Geochcmical Characterization — Additive Mix #1 Geochemical characterization of the individual drilling mud additives strongly implicate both the DriI -N -Slide and Barablok as the two major contributors to the composition of the "oil" recovered from the Aklaq #6 well. To further document and confirm that this "oil" is indeed simply a combination of these two additives, an experimental mixture was prepared in the lab to attempt to simulate the additive mix. Knowing that 440 gallons of DriI -N -Slide and 250 lbs. of Barablok had been added to the well on 4- 16 -07, a conversion was made to place this concentration in proper units for mixing in the lab. Thus, additive Mix #1 (Fig. 15) was prepared at a concentration of 68 mg /ml in order to replicate the concentration of additives put into the well on 4- 16 -07. However, a significant amount of Baro -trol Plus and some Barablok had also been placed in the well in the proceeding days of drilling to attempt to reduce lost circulation. It is impossible to account for the exact amount of additives that might have been present at the time of addition of the DriI -N- Slide, since most of the lost mud would not be in potential contact with the lubricant added to the well. The approach taken with Mix #1 is the most conservative and it is possible that a considerably larger amount of Baro -trol Plus could have also been included in the recovered "oil" additive mixture. LOIIV DriI -N -Slide Barablok DriI - N -Slide 68 mg/ml Barablok 68 mg /ml Figure 15. Photos of drilling additive Mix #1 prepared in the lab to simulate the "black oil" recovered in the Aklaq #6 well. Photo on left shows total mixture. Upon centrifuge separation the recovered suspended material and solubilized "oil" are shown in the right photo. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 22 Humble Geochemical Services Division • The Dril -N -Slide + Barablok Mix #1 looks very similar to the recovered Aklaq #6 "oil ". It is black in color and apparently consists of both a suspended and dissolved component. The mixture was allowed to equilibrate at room temperature for a period of 72 hours and then centrifuged. A significant fraction of finely suspended Barablok (and /or asphaltene components thereof) was recovered along with some residual liquid Dril -N -Slide that could not be separated. The other fraction consists of primarily dissolved material and has an API gravity of 32.3, with a specific gravity of 0.86. The gravity of this mix is virtually identical to the pure DriI -N -Slide additive. Because it is impossible to "dry" the centrifuge recovered portion from the residual DriI -N- Slide, no estimation could be made as to the percent solubility of Barablok in DriI -N- Slide. It is likely to be rather low, but in the actual mud system could be potentially much higher accounting for residual trace hydrocarbons present (recall that Barablok is 96% soluble in hydrocarbon solvents) and elevated downhole temperature conditions. The fractional composition of the centrifuge separated Mix #1 "oil" is dominated by the resin fraction (62 %) with subordinate aromatics (36 %) and saturates (< 2 %). The pure DriI -N -Slide additive is also dominated by the resin fraction (71 %) where the fatty acid esters apparently occur. Interestingly, asphaltenes make up only 0.1% of the fractional composition of Mix #1 and it is apparent that they are essentially insoluble in DriI -N- Slide. That the recovered "oil" from Aklaq #6 contains significant proportions of asphaltenes as well as resins suggest that the Barablok additive was still present in suspension and /or greater solubilized in the recovered "oil" sample analyzed. The client noted that the recovered "oil" from Aklaq #6 showed strong yellow -green fluorescence color. To establish that this fluorescence property could be replicated by the Dril -N -Slide + Barablok Mix #1, it was examined under UV light. Photos document that the pure additive DriI -N -Slide exhibits no distinct fluorescence color (Fig. 16), but the Mix #1 shows a strong yellow -green fluorescence associated with aromatic hydrocarbon and other polar constituents solubilized from the Barablok (ie. gilsonite). Amminso Figure 16. Photos of Dril -N -Slide (left) and drilling additive Mix #1 (right) taken under UV light to document fluorescence characteristics. Additive Mix #1 shows strong yellow -green fluorescence that was also observed from the "black oil" recovered in the Aklaq #6 well. • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 23 Humble Geochemical Services Division FID1 A, (G:111DATA107 -05471F195895A D) 6000- 5000- 4000- 3000- 2000- 1000- 20 30 • C, 2 pA DriI -N -Slide + Barabiok Mix #1 (68 mg /ml) Fatty acid esters 0+ 14 C C10 8 0 16 06 note carbon # refers to acid chain not total 0 16 40 50 60 70 80 90 mi, FID1 A, (G'111DATA107 -45471F195895A.D) p 50- 40- 30 - 20- 70- • 60- - i 10 20 30 40 50 60 70 80 90 mir Figure 17. Whole oil GC fingerprint of DriI -N -Slide + Barablok Mix #1 mud additives showing distribution of C6 to C18 fatty acid esters (top) and enhanced to show minor abundances of other peaks and apparent absence of biomarkers. • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 24 Humble Geochemical Services Division • A gas chromatographic fingerprint of DriI -N -Slide + Barablok Mix #1 (HGS #07- 4547 - 195895) is shown in Fig. 17. The distribution of components in this mixture is dominated by the same pattern of C6 to C18 fatty acid ester peaks. These peaks have a fingerprint, with the C12 fatty acid ester as the predominant component, which is identical to that of the Aklaq #6 "oil". This provides further confirmation that the recovered "oil" is partially derived from the DriI -N -Slide additive. The much enhanced Mix #1 GC trace (Fig. 17) shows additional minor peaks present, but the characteristic biomarkes found in the "oil" appear to be missing. These peaks correspond with biomarkers through to be derived from the Barablok additive and their absence in the Mix #1 fingerprint is somewhat unexpected. As will be seen later, these compounds are actually present in the Mix #1 as analyzed by the more sensitive GC -MS, but they are not in sufficient concentrations relative to the acid esters to be visible in the GC trace. Gas chromatography mass spectrometry biomarker analyses were performed on both the saturate and aromatic fractions of the DriI -N -Slide + Barablok Mix #1. The complete results of these analyses are reported in Appendix 4. Steranes distributions in the m/z 217 mass chromatogram (Fig. 18) are dominated by the C28 and C29 regular steranes, with very low abundances of all other compounds. The internal standard peak shown in the chromatogram is actually the largest peak and illustrates the depleted concentration of biomarkers in this sample compared to the recovered "oil" from the Aklaq #6 well (see Fig. 10). Hopane distributions in the m/z 191 mass chromatogram (Fig. 18) of the Mix #1 sample are also very depleted as can be seen by the rising baseline of the mass chromatogram. However, despite lower concentrations, the pattern of compound peaks is similar to the recovered "oil" with dominant hopane, moretanes and gammacerane. The sterane and hopane maturity ratios that could be measured in Mix #1 are also well below their thermal endpoint values, consistent with a pre -oil window maturity and an origin from the Barablok additive. While the additive Mix #1 may not be a perfect match for the exact proportions of DriI -N -Slide and Barablok present in the recovered "oil" from Aklaq #6, it does clearly establish that the origin of the "oil" is unequivocally from some mix of predominantly these additives. Chemical fingerprints of the major component fatty acid esters derived from the DriI -N -Slide dominate the `oil ", but it also contains a contribution of solubilized and /or suspended Barablok that gives it a black color and its diagnostic immature Iacustrine biomarker signature. Reservoir Core Extract Geochemical Results and Discussion After completion of the fluid geochemical results, a single reservoir core sample recovered from a depth of 7125.6' in the Aklaq #6 well was submitted for follow -up geochemical analyses in an attempt to obtain a potential indigenous hydrocarbon signature. A relatively large sample (8.9 g), taken from an interior portion of the core, was initially crushed to a 60 mesh grain size to enhance extraction efficiency. This sample was then solvent extracted and the recovered products were quantified. Only a very low hydrocarbon recovery was obtained (3.7 mg), amounting to a total of 413 ppm. Such a low level of extractable hydrocarbon saturation in this reservoir rock implies that it has not received a significant migrated hydrocarbon charge nor much contribution from the adjacent source -rocks currently in the peak oil window. This could be due to insufficient organic richness in the underlying source facies, a predominance of gas -prone organic matter and /or poor reservoir quality. Further, the low recovery prevented fractional assessment by liquid chromatography and all • subsequent GC and GC -MS analyses were performed using the whole extract. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 25 Humble Geochemical Services Division • 1000 _5 "'/i217: steranes 900 - a DriI -N -Slide 800 - + 700 - Barablok • 600 - Mix #1 (68 mg /ml) s 500 - 2 400 - i rc U " • 300 - J 200 - 0 100 - w+V'"e 0 44 48 52 56 6 0 64 68 Retention Time (min.) 1600 m/z 191: Tri-, tetra- and pentacyclic Terpanes 1400 - 1200 - . = 1000 - E • 800 - r �I 1 e "� u 600 _ r Aft!" 400 - • 200 - 0 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) Figure 18. Saturated biomarker GC -MS traces of DriI -N -Slide + Barablok Mix #1 showing distribution of steranes (top) and hopanes (bottom) that have typical immature signatures and diagnostic Iacustrine biomarkers previously noted in the "oil" recovered from the Aklaq #6 well (compare to Fig. 10). A whole extract GC fingerprint of the Aklaq #6 core sample from 7125.6' is shown in Fig. 19. This GC trace shows a unimodal distribution of predominant n- alkanes extending from C9 to - C30 and maximizing at C14. Minor amounts of branched chain isoprenoids were also detected along with several major unidentified peaks eluting between the alkane series. Based on relative retention times, the likely origin of these unidentified peaks is due to plasticizer contaminants in the phthalate series of compounds. The core sample sent by the client for geochemical analysis was wrapped in a light plastic wrap that was then covered in aluminum foil. It appears probable that plasticizers from this material have slightly contaminated the core sample prior to solvent extraction. This artifact was compounded by the extremely low recovery of hydrocarbons in the core extract. However, despite this minor plasticizer contamination, there does not appear to be any significant contamination from known drilling additives such as Barablok or Dril -N- Slide. The Aklaq #6 core was recovered prior to the addition of DriI -N -Slide additive (see Table 3), but there was concern that some mobile additives could have been present in the system as a consequence of the use of recycled drilling mud. The low hydrocarbon recovery and GC fingerprint of the 7125.6' core • extract clearly show that it does not contain any contamination from these drilling additives. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 26 Humble Geochemical Services Division • pA FID1 A. (G \1 \DATA \07 4547F \E198186A D) 120- 0 U I I 100 - 80 - V t 60- U t r 40- 20- t 2 V t ` t`A to R f 2 2 � t L LI , Jai , 4i i ..,1. I t t t . ° 20 30 40 50 60 70 80 90 mi Figure 19. Whole extract GC fingerprint of a core sample recovered from a depth of 7125.6' in the Aklaq #6 well. This 7125.6' core extract GC trace is dominated by light hydrocarbons maximizing at C14 and has the appearance of high API gravity oil associated with mature source rocks in the peak to late oil window. The relatively low abundance of isoprenoids relative to alkanes (Pr /C = • 0.22 and Ph /C = 0.36) is consistent with this interpretation and suggests that the oil fingerprint could be associated with hydrocarbons derived from the adjacent source rocks (0.95% Ro). The elevated thermal maturity is also manifest in a general lack of any visible carbon number predominance in the alkanes. There is minimal diagnostic geochemical information available from the core extract GC trace for oil- source correlation. All potential gasoline range molecular parameters have been lost during solvent evaporation. One of the few diagnostic indicators present is the pristane /phytane ratio (Pr /Ph) that is calculated to be 1.3 (Table 4). This ratio is within the range of previously reported data (Masterson, 2001) from Triassic aged source rock extracts in the calcareous Shublik facies (avg. Pr /Ph = 1.2), but it is far from definitive and also overlaps with Prudhoe Bay oils located in Ivishak reservoirs (avg. Pr /Ph = 1.3) that have been interpreted to have a mixed Kingak (Jurassic), Shublik (Triassic) and HRZ (Cretaceous) source (Masterson, 2001). Saturate biomarker data from GC -MS analyses of the 7125.6' Aklaq #6 core extract is fully documented in Appendix 4 and select mass chromatograms are illustrated in Fig. 20 for comparison purposes. The sterane and hopane biomarker traces show very low signal response consistent with depleted concentrations and may contain some spurious data as a consequence of running the whole extract. These data should be used with caution and will require further testing of duplicate samples for validation. The resolvable sterane peaks in the m/z 217 mass chromatogram are dominated by the more thermally stable diasteranes, with the C27 diasteranes in slightly greater abundance relative to the C29 and C28. This distribution also appears to hold for the a(3(3- steranes as measured in the m/z 218 mass chromatogram, where the C27 steranes are 42% of the total steranes as measured by peak area. Relatively high abundances of the C27 steranes and diasteranes could suggest a marine source rock (Peters and Moldowan, 1993), but these patterns may also reflect relative thermal stability differences and may not be useful for oil- source correlations. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 27 Humble Geochemical Services Division • 12000 m!z 217: Steranes Aklaq #6 Core Extract 10000 - 7125.6' • 8000 - u a 2 • 6000 - y °o 2 rc rc try 4000 - ¢ y rc 2000 - 46, i imvv\tot �'��vi�J^`^''"`Nl'+ 0 44 48 52 56 60 64 68 Retention Time (min.) 7000 m 91: Tri-, tetra- and pentacyclic Terpanes 6000 5000 v 4000 c 1 u 3000 .. u 2000 1000 0 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.{ Figure 20. Saturated biomarker GC -MS traces of the Aklaq #6 core extract from 7125.6' showing distribution of steranes (top) and hopanes (bottom). The terpanes appear to be dominated by the C29 norhopane (Table 4), with lesser amounts of the C30 hopane and extended homohopanes. Such distributions could originate from organic -rich evaporate- carbonate source rocks, but many petroleums from source rocks rich in terrestrial organic matter also have high C29 hopanes (Peters and Moldowan, 1993). In general, the high signal to noise ratio and presence of spurious peaks in the data preclude its usefulness for oil- source correlation. Aromatic biomarker data from this oil can be used with greater confidence because these compounds appear to be present in higher concentrations relative to the saturated biomarkers. This is potentially a consequence of this core extract fingerprint being derived from adjacent source rocks containing a relatively high proportion of humic terrestrial organic matter. The dibenzothiophene /phenanthrene ratio (DBT /P) has been used to help distinguish Alaskan oil families (Masterson, 2001) and the value of 0.34 for the Aklaq #6 core extract shows no obvious correlation with previously defined source groups (Table 4). This observation is consistent with other GC /GC -MS evidence and yield data that suggest no significant migrated oil signal in the Aklaq #6 core sample analyzed from 7125.6' and a probable local origin for the minor hydrocarbon staining recovered during solvent extraction. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 28 Humble Geochemical Services Division • Table 4. Summa of selected •eochemical data from Alaska oils Masterson, 2001 . Shublik Source Kingak Source HRZ Source Aklaq #6 (Triassic) (Jurassic) (Cretaceous) 7125.6' S (wt. %) 1.6 0.3 0.2 - °API 23 37 37 - Pr/Ph 1.9 2.2 1.8 1.3 DBT /Phen 0.67 0.17 0.11 0.34 C Hopane 0.86 0.43 0.42 1.22* C23 Tri /C Hopane 0.62 0.12 0.11 - C Hopane 1.2 0.6 0.8 - Ts/Tm 1.22 0.51 0.73 0.99* NDR 0.14 0.14 0.48 - VR MPI 0.8 0.8 0.7 0.6 *hopane data may be unreliable due to high signal noise Interpretative Conclusions Source -rock geochemical analyses have been combined with molecular geochemical data for fluid samples recovered from the Aklaq #6 well and a reservoir core extract to assess hydrocarbon prospectivity. In particular, one of the main objectives of the current study is to conclusively document the occurrence of "black oil" shows reported from this well located in Alaska's National Petroleum Reserve. These "oil" shows have been found to be a consequence of the addition of two drilling additives (DriI -N -Slide and Barablok) and do not • represent an indigenous oil show. Geochemical analyses of cuttings and core chip samples from depths between 3230 -7163' in the Aklaq #6 well were examined in this study for geochemical and petrographic analyses, respectively. Organic richness varies from good to excellent, with TOC values that range from 1.2% to 4.7% and reach a maximum in the cuttings samples analyzed at a depth of 6590 - 6620'. Interpreted organic matter type based on Rock -Eval HI and 01 values along with the occurrence of coal stringers suggest that the majority of the source interval contains predominantly gas -prone Type III kerogen. Only the most organic rich horizon is thought to have a mix of oil /gas -prone Type 11/111 kerogen. Thermal maturity based on Rock -Eval parameters and measured vitrinite reflectance values of 0.95% Ro place this source interval in the peak oil window. These analyses offer some useful insights into the likely origin of recovered fluid samples in the Aklaq #6 well. While potential source rocks appear to be present throughout the sampled interval, they primarily consist of gas -prone terrestrial dominated kerogen with marginal oil generative. The in -situ products generated from these humic source rocks at peak oil window maturity are likely to be minor amounts of wet gas and associated aromatic type oils. Source rocks in the 6590 -6620' interval have higher TOC and a mixed oil /gas -prone kerogen that could generate moderate amounts of both wet gas and oil. Importantly, each of the potential source facies examined appear to have a significant gas -prone component in their kerogen mix. Consequently, any naturally occurring hydrocarbon shows in Aklaq #6 should correlate well with elevated mud gas concentrations and any shows without a significant accompanying gas signal would be considered very suspect. The "black oil" show recovered along with mud on 4 -16 -07 has been analyzed and was found to be composed of predominantly polar and asphaltene components with only a minor Source Rock and Fluid Geochemistry of the Aklaq #6 Well - Talisman Energy 29 Humble Geochemical Services Division • amount of saturate and aromatic hydrocarbons (< 5 %). This feature is highly unusual for a naturally occurring crude oil. Detailed molecular GC and GC -MS fingerprinting show that the "oil" is composed predominantly of a series of C6 to C18 fatty acid esters that originated from the 440 gal. of DriI -N -Slide additive placed down the well on the same day the "oil" show was recovered. In addition, biomarker analyses reveal that the predominant immature, Iacustrine signature present in the recovered "oil" originated from Barablok, a gilsonite type additive that was also added to the well on the same day of "oil" recovery. Testing in the laboratory confirm that a mixture of DriI -N -Slide and Barablok will solubilize to form a liquid product that is black in color, exhibits yellow -green fluorescence and can have quite variable viscosity /gravity depending upon the amount of fine particulates suspended in the mix. All of these features correspond with observations made regarding the "oil" show recovered in the Aklaq #6 well. A reservoir core sample recovered from a depth of 7125.6' in the Aklaq #6 well was analyzed and found to contain an apparently indigenous hydrocarbon signature with no contamination from drilling additives. However, only a very low hydrocarbon recovery was obtained that amounted to a total of 413 ppm. Such a low level of extractable hydrocarbon saturation in this reservoir rock implies that it has not received a significant migrated hydrocarbon charge nor much contribution from the adjacent source -rocks currently in the peak oil window. This could be due to insufficient organic richness in the underlying source facies, a predominance of gas -prone organic matter and /or poor reservoir quality. The GC fingerprint of the core extract is dominated by Tight hydrocarbons maximizing at C14 and has the appearance of high API gravity oil associated with mature source rocks in the peak to late oil window. Other biomarker evidence is less diagnostic and no conclusive oil -oil or oil- source rock correlation • could be obtained. References Hills, I.R., E.V. Whitehead, D.E. Anders, J.J. Cummins and W.E. Robinson, 1966, An optically active triterpane, gammacerane, in Green River, Colorado, oil shale bitumen. Journal of Chemical Society Chemical Communications, 752 -754. Jarvie, D.M., B.L. Claxton, F. Henk and J.T. Breyer, 2001, Oil and shale gas from the Barnett Shale, Ft. Worth basin, Texas. AAPG Bulletin, 85, A100. Materson, W.D, 2001, Petroleum filling history of central Alaskan North Slope fields, Ph.D Dissertation, University of Texas at Dallas. Peters, K.E. and J.M. Moldowan, 1993, The biomarker guide, Prentice -Hall, Englewoods Cliffs, New Jersey, 363 p. Ruble, T.E., 1990, Organic geochemical investigation of native bitumens from the Uinta basin, Utah, U.S.A., M.S. Thesis, University of Oklahoma, Norman, Oklahoma, 155 p. Ruble, T.E. and R.P. Philp, 1991, Geochemical investigation of native bitumens from the Uinta basin, Utah, U.S.A. The Compass, 68, 135 -150. Ruble, T.E., M.D. Lewan and R.P. Philp, 2001, New insights on the Green River petroleum system in the Uinta basin from hydrous pyrolysis experiments. AAPG Bulletin, 85, 1333 -1371. Tissot, B. and D.H. Welte, 1978, Petroleum formation and occurrence — a new approach to oil and gas exploration, Springer Verlag, New York, 538 p. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy 30 Humble Geochemical Services Division • Appendix 1 Methods 410 Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division • Sample Preparation Samples for TOC and Rock -Eval analysis were ground, and material passing through a 60 mesh (250 micron) sieve was used for analysis. Samples were not high - graded prior to grinding. Total Organic Carbon Approximately 0.10 g of ground rock is accurately weighed and then treated with concentrated Hydrochloric Acid to remove carbonates. Sample weight may be varied depending on sample richness. The samples are left in acid for a minimum of two hours. The acid is removed from the sample with a filtration apparatus fitted with a glass microfiber filter. The filter is placed in a LECO crucible and dried at 110° C for a minimum of one hour. After drying the sample is analyzed with a LECO 600 Carbon Analyzer. Rock - Eval Total organic carbon (TOC) and Rock -Eval pyrolysis were performed to assess source rock quality and thermal maturity (e.g., Peters, 1986; Peters and Casa, 1994). In Rock -Eval pyrolysis, ground samples are heated in an inert environment to measure the yield three groups of compounds (S1, S2, and S3), measured as three peaks on a pyrogram. Sample heating at 300 °C for 3 min. produces the S1 peak by vaporizing the free (unbound) hydrocarbons. High S1 values indicate either large amounts of kerogen- derived bitumen (as in an active source rock) or the presence of migrated hydrocarbons. The oven then • increases in temperature by 25 °C /minute to 600 °C, and the S2 and S3 peaks are measured from the pyrolytic degradation of the kerogen in the sample. The S2 peak is proportional to the amount of hydrogen -rich kerogen in the rock, and the S3 peak measures the carbon dioxide released (to 390 ° C) providing an assessment of the oxygen content of the rock. The temperature at which the S2 peak reaches a maximum, "Tmax ", is a measure of the source rock maturity. Accuracy of Tmax is 1 -3 °C, depending on the instrument, program rate and sample size. Tmax also varies by organic matter type. Tmax values for samples with S2 peaks Tess than 0.2 mg HC /g rock are often inaccurate and should be rejected unless a definitive kerogen peak is noted from the pyrogram. A summary of operating conditions and analytical results from Rock -Eval pyrolysis follows. Operating Conditions S1: 300 ° C for 3 minutes S2: 300 ° C to 600 ° C at 25 ° C /min; held at 600 ° C for 1 minute S3: trapped between 300 to 390 S4: oxidation at 580 for 12 minutes Results S1: free oil content (mg hydrocarbons per gram of rock) S2: remaining hydrocarbon potential (mg hydrocarbons per gram of rock) S3: organic carbon dioxide (mg CO2 per gram of rock) TOC: total organic carbon content (wt. %) Tmax: temperature at maximum evolution of S2 hydrocarbons Cal. %Ro: calculated vitrinite reflectance based on Tmax Ratios: hydrogen index (HI), oxygen index (01), production index (PI), S2 /S3, and S1/TOC Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division • Vitrinite Reflectance and Visual Kerogen Assessment Visual kerogen assessments complement chemical assessments by recording information from the discrete particles (macerals) that make up the sedimentary organic matter. Vitrinite macerals are particles of sedimentary organic matter derived from wood, and their reflectance of incident light under oil immersion is used to assess the thermal maturity of a sample. Vitrinite reflectance ( %R increases with increased depth of burial (i.e., increased thermal exposure), and is an indication of the maximum temperature to which these particles have been exposed. The reflectance microscope measures the amount of reflected light relative to the incident light and expresses this ratio as a percentage. Vitrinite reflectance values range from about 0.25% (immature) to a high of about 5 or 6% (very mature). A population of vitrinite particles is found in almost all rock samples of Devonian or younger age (older samples pre -date the evolution of land plants, the source of vitrinite). Selecting the appropriate vitrinite population for subsequent reflectance measurements is a somewhat subjective process. The in situ population must be identified, and must exclude vitrinite derived from cavings and reworked organic matter. Reworked vitrinite that was redeposited in the sediments may have higher reflectance that will skew the measurements towards higher R values if not recognized and removed from the average. In cuttings samples, cavings from overlying less mature sediments may skew the average towards lower values. Generally, when cavings are excluded, the lowest reflecting population is found to be indicative of the indigenous population, but this evaluation is made in combination with visual kerogen assessments, Rock -Eval Tmax measurements, and data for the extent of kerogen conversion. 40 Vitrinite reflectance values are divided into the following stages of thermal maturity: Stage Reflectance Range Immature 0.2% to 0.6% Oil window maturity 0.6% to 1.1% Condensate or wet -gas window 1.1% to 1.4% Dry gas window 1.40% plus Thermal alteration indices (TAI) are determined from the color of organic matter when viewed under transmitted light through a strewn slide mount of kerogen. Lighter colored organic matter is indicative of low maturity, whereas darker material is indicative of higher thermal maturity. Maceral composition is an assessment of the percentages of various organic particles found in kerogen samples. These particles are related to the oil and gas potential of the organic matter and are generally described as amorphous, exinitic, vitrinitic, inertinitic, or solid bitumen percentages. The former two macerals are primarily oil -prone particulate matter, whereas vitrinitic particles are indicative of gas -prone organic matter. Inertinitic matter is very hydrogen -poor and has no potential for generation of commercial quantities of hydrocarbons. The presence of solid bitumen is indicative of in situ generated hydrocarbons, migrated hydrocarbons, or contamination. Other observations from visual kerogen assessment include the quality of the organic matter (oxidized, well preserved), and the presence of palynomorphs (which can reveal key aspects of the depositional environment). 40 Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division Whole Fluid Chromatography Gas chromatography may be completed on whole extract or oil samples as well as on the saturate or aromatic fractions. Samples to be analyzed are diluted with 100 pl of carbon disulfide solvent and an internal standard (1- hexene) is added directly into the sample for quantitation. Gas chromatography is performed using HP 6890 Series GC System with high - resolution column (50 m, PONA phase, 0.2 mm i.d., 0.5 pm film). A 2 pl aliquot of diluted sample is injected into the 300 °C split inlet set at a 50/1 split ratio. The GC is temperature programmed from 35 °C (20 min. hold) to 300 °C at 8 °C /min. and then to 325 °C at 0.5 °C /min. with a final hold time of 30 min. Light hydrocarbons, isoprenoids and normal paraffins are identified when they are present in the sample. Biomarkers Samples are prepared by performing liquid chromatography (LC) on oil or extracts samples to isolate saturate and aromatic fractions. Saturate fractions are diluted with 5 pl and aromatic fractions /whole extracts /whole oils with 10 pl of carbon disulfide per mg of fraction. 13- cholane and o- terphenyl -d14 are used as saturate and aromatic internal standards, respectively. Samples are analyzed on an HP6890GC / 5973MSD system equipped with a high - resolution column (60 m, DB -1 phase, 0.2 mm i.d., 0.2 pm film). The GC is temperature programmed from 80 °C (2 min. hold) to 320 °C at 3.5 °C /min. with a final hold time of 20 min. There is a 7.5 min. solvent delay on acquisition and selected ion monitoring (SIM) is the standard method for analysis. Reports of peaks and standard geochemical parameters are 411 included for both the saturate and aromatic fractions. Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division Appendix 2 Source Quality Data • Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division • • • TOC and ROCK -EVAL DATA REPORT Talisman Energy, AK Thy • X Il 88896 an 1lnMa Notes tiCdB Depth Depth Sample ' Sample TOC ' "'. °° St 82 • 82 ' leapt ;. Cats. Maas, Hl < - 01 S : S1ltOC PI Cbebks Pytogram • NM, . t 4 P1 is pe , {°G), %Ktif %RO 07- 4547 - 194092 ASRC Energy Services Aklaq #6 3230 3260 3245 picked cuttings 1.35 0.34 1.15 0.83 434 0.65 85 61 1 25 0.23 n;ItS2sh -- - ---- --- - ----- __ 07 -4547- 194093 ASRC Energy Services Aklaq #6 4670 4700 4685 picked cuttings 1.75 0.44 1.48 1.36 432 0.62 85 78 1 25 0.23 n;ItS2sh 07-4547-194094 ASRC Energy Services Aklaq #6 5390 5420 5405 picked cuttings 1.79 0.39 2.45 0.46 435 0.67 137 26 5 22 0.14 n;ItS2sh 07 -4547- 194095 ASRC Energy Services Aklaq #6 6260 6290 6275 picked cuttings 1.42 0.42 1.12 0.46 . 443 0.81 79 32 2 30 0.27 n;ItS2sh 07- 4547 - 194096 ASRC Energy Services Aklaq #6 6590 6620 6605 picked cuttings 4.69 _ 1.74 12.49 0.45 440 0.76 266 10 28 37 0.12 lc n 07- 4547 - 194097 ASRC Energy Services Aklaq #6 6680 6710 6695 picked cuttings 3.18 1.04 4.19 0.44 443 0.81 132 14 10 33 0.20 n;ItS2sh 07- 4547 - 194098 ASRC Energy Services Aklaq #6 6750 6760 6755 picked cuttings _ . 3.04 1.03 4.46 0.52 442 0.80 147 17 9 34 0.19 n;ItS2sh 07- 4547 - 194099 ASRC Enema Services Aklaq #6 6640 6850 6845 picked cuttings 1.18 0.31 1.32 0.95 440 0.76 112 81 1 26 0.19 n,ItS2sh - - --- -- - -- - 07- 4547 - 194029 ASRC Energy Services Aklaq #6 7131.75 7131.75 picked coal 0.95 07- 4547 - 194030 ASRC Energy Services Aklaq #6 7146.5 7146.5 picked coal ._, 0.96 07 -4547- 194100 ASRC Energy Services Aklaq #6 7160 7163 7161.5 picked cuttings 1.47 _ 0.26 0.95 0.44 442 0.80 65 30 2 18 0.21 n Note' " -1" indicates not measured or meaningless ratio Notes: c = Rock -Eval analysis checked and confirmed * Tmax data not reliable due to poor S2 peak lc = Leco TOC analysis checked and confirmed HI = hydrogen index = S2 x 100 / TOC TOC = weight percent organic carbon in rock 01= oxygen index = S3 x 100 / TOC Pyrogram. 51, S2 = mg hydrocarbons per gram of rock S1/TOC = normalized oil content = S1 x 100 / TOC n= normal S3 = mg carbon dioxide per gram of rock PI = production index = 51 / (S1 +S2) ItS2sh = low temperature S2 shoulder Calculcated % VRo = 0.0180 x Tmax - 7.16 (Jarvie et al., 2001) ItS2p = low temperature S2 peak Tmax = °C Measured %Ro = measured vitrinite reflectance htS2p = high temperature S2 peak f = flat S2 peak na = printer malfunction pyrogram not available Humble Genehemlcal Services Division # 0 • Geochemical Log Talisman Energy, AK LOG 1: ORGANIC LOG 2: HYDROCARBON LOG 3: ORGANIC LOG 4: NORMALIZED OIL LOG 5: CALCULATED LOG 6: MEASURED RICHNESS POTENTIAL MATTER TYPE CONTENT MATURITY MATURITY 0 I I Organic v x m c o e Rich Excellent Gas 1 1 Mix Oil I Oil d E o E m L c o 0...) (lac.) " y r u c N N E N N `m N d o n c n E C w E O a o C U O 1000 - E E c o = v o L - J W Li f o a I 2000 - 3000 - • 4 A • + x 4 0 0 0 - • A • + 5000 - 1 I 111 • A • + 1 1 1 6000 - 1 • • A • + I gi 7000 - 1 • • A • + • 9000 I 0.0 5 -0 10.0 0 5 10 15 20 0 500 1000 0 50 100 150 200 0 -2 07 1.2 1.7 2.2 0.2 0.7 12 1.7 2 -2 TOC (ot. %) OIL POTENTIAL (S2) HYDROGEN INDEX (HI) NORMALIZED OIL CONTENT CALCULATED %Ro VITRNITE REFLECTANCE 0 Humble Geochemical Service. 0 Humble Geochemiml Services 0 Humble Geocherrical Services 0 Humble Geochenicel Services 0 Humble Geocherrtical Service 0 Humble Geocherncal Services Figure 1. Geochemical log of TOC, remaining potential (S2), kerogen type (HI), normalized oil content, and calculated and measured vitrinite reflectance. Humble Geochemical Services Division 41, • • KEROGEN QUALITY Talisman Energy, AK 60 - Type I Oil Prone TYPE 11 Oil Prone usu. lacustrine (usu. marine) a) 50 - U 2 a) E Q 40 Mixed Type I1 / 111 z Oil /Gas Prone w I— O Z 30 O m 0 0 0 20 Type Ill _ Gas Prone Organic A Lean 10 2 no Dry A -- Gas Prone 0 0 2 4 6 8 10 12 14 16 TOTAL ORGANIC CARBON (TOC, wt. %) © Humble Geochemical Service: Figure 2. Kerogen Quality Humble Geochemical Services Division • KEROGEN TYPE Talisman Energy, AK 1000 - ..., _._._._. 900 Type l Oil Prone 800 - 700 - 0 O H 600 - U 2 Type 11 (usu. marine) Oil Prone 500 • X w Z _ w C7 400 - O ❑ 2 Mixed Type II / 111 300 - Oil / Gas Prone 200 - 0 0 O Type 111 Gas Prone 100 0 0 • 0 Type IV Gas Prone 0 0 20 40 60 80 100 120 140 160 180 200 OXYGEN INDEX (01, mg CO /g TOC) © Humble Geochemical Services • Figure 3. Kerogen type Humble Geochemical Services Division KEROGEN TYPE and MATURITY • Talisman Energy, AK 1000 -0.55% Ro 1N Type 1 ' W�n 900 Oil Prone 0� (usu. lacustrine) 1 800 - il 700 U O 07 600 - J O Type l! Oil Prone X 500 (usu. marine) • O Z I, Z W ° 400 I 300 - Mixed Type 11/ 111 Oil / Gas Prone • 200 - Type 111 O °O 1.00 %Ro a W Ga5 1N;VtdoW Gas Prone ° Cood sat 100 - en Q - 01.40% Ro pr y Gas window 0 330 380 430 480 530 580 Tmax ( ° C) • © Humble Geochemical Services Figure 4a. Kerogen Type and Maturity (Tmax) Humble Geochemical Services Division KEROGEN TYPE and MATURITY • Talisman Energy, AK 1 000 0.55 %VRO Type I O• N1 1�d0� 900 - Oil Prone (usu. lacustrine) 800 - 700 U 600 ype II J Prone usu. E - arine) w 500 - • o - z z w 0 400 x - 300 xed Type II / III it / Gas • Prone 200 - o 1 .00 %VRo e we Go Ol °W Type III © 0 COndellSa as Prone 0 100 ®® 0 40 1.%VRO d w O Dr y Gas ° win Type IV 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00 2.20 Calculated Vitrinite Reflectance Equivalent (Cal.VReq.) © Humble Geochemical Services • Figure 4b. Kerogen Type and Maturity (Tmax calculated %VRo) Humble Geochemical Services Division • • • Talisman Energy, AK 1.00 as Immature Oil Zone Dry Gas Zone 0.90 y d 0.80 O V — 0.70 X w 0.60 z Z Stained or 0 0.50 Contaminated U 0 0.40 0 a 0.30 • • ak 0.20 eV High Level Conversion - Expulsion •• 0.10 Low Level Conversion 0.00 380 430 480 530 580 MATURITY (based on Tmax ( © Humble Geochemical Services Figure 5a. Kerogen conversion and maturity (based on Tmax). Humble Geochemical Services Division • • I Talisman Energy, AK 1.00 - Immature Oil Zone Condensate - Dry Gas Zone Wet Gas 0.90 Zone 0.80 - 0.70 a X W 0.60 - Stained or Z Contaminated O Z 0.50 H U 0 0.40 0 n - 0.30 O 00 0.20 08) High Level Conversion - Expulsion 0 0.10 L ow Level Conversion 0.00 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00 2.20 MATURITY (calculated vitrinite reflectance from Tmax) © Humble Geochemical Services Figure 5b. Kerogen conversion and maturity (calculated %VRo from Tmax). Humble Geochemical Services Division 0 Appendix 3 Optical Kerogen Data 0 0 Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division • 0 • Talisman Energy ASRC Energy Services, Aklaq #6 Well : Depth ; Depth State a Reflectance : Uv 'luorescence . Gommenle ID. Name Units. R.o,Ave. No. Conf. Form Content Color . I 07 -4547- 194029 ASRC Energy Services Aklaq #6 7131.75 ft AK 0.95 20 C - - - Coal. Rich in pyrite & marcasite 07 -4547- 194030 ASRC Energy Services Aklaq #6 7146.5 ft AK 0.96 20 B - - - Coal Petrologist: M. Jones Conf. = Confident Color A = Very High DO Dark Orange B = High LO Light Orange C = Fair MO Medium Orange D = Poor Y Yellow E = Very Poor N.D.P = no determination possible Humble Geochemical Services Division • • ! 41) Talisman Energy ASRC Energy Services, Aklaq #6 1.038 Operator Well -;Depth' .1: ' . Anvil*. Bitumen w ition ( %) ., 1.1). Name . .. Units init l iptinite Vitt. Inert) Comments r Content Algae Spores Cuticle Resin Reworked 07 -4547- 194029 ASRC Energy Services Aklaq #6 7131.75 ft AK - - Total - - - - 100 - Coal 07 -4547- 194030 ASRC Energy Services Aklaq #6 7146.5 ft AK - - Total - - - - 100 - Coal Humble Geochemical Services Division • • ( Sample ID 1194029 RO Frequency 0.05 Individual Readings 0.10 0.84 0.80 0.85 0.90 0.15 0.98 0.97 0.99 1.01 0.20 0.98 0.87 1.08 0.92 0.25 1.03 0.80 1.00 1.05 0.30 0.84 1.00 1.06 1.01 0.35 0.40 R.o aver 0.95 (20) C 0.45 0.50 0.55 0.60 Talisman Energy, ASRC Energy Services, Aklaq #6 0.65 0.70 0.75 Vitrinite Reflectance 7131.75 (ft) 0.80 4 0.85 2 0.90 2 9 - 0.95 4 8 _ 1.00 8 1.10 7 1.20 (n 6 1.30 a) 5 1.40 E 1.50 al 4 1.60 a) cL 3 1.70 1.80 2 - 1 .00 1 2.00 Z.00 2.50 0 3.00 0.70 0.75 0.80 0.85 0.90 0.95 1.00 1.10 1.20 3.50 4.00 Vitrinite Reflectance ( %) 4.50 5.00 5.50 6.00 6.50 Humble Geochemical Services Division • (Sample ID 1194030 RO Frequency 0.05 Individual Readings 0.10 0.84 0.90 0.89 0.89 0.15 0.91 0.86 1.14 0.83 0.20 0.90 1.31 1.00 0.93 0.25 1.04 0.90 0.92 0.98 0.30 1.15 0.95 0.94 0.93 0.35 0.40 R.o aver 0.96 (20) B 0.45 0.50 0.55 0.60 Talisman Energy, ASRC Energy Services, Aklaq #6 0.65 0.70 0.75 Vitrinite Reflectance 7146.5 (ft) 0.80 2 f . 0.85 3 0.90 8 9 0.95 2 8 1.00 2 1.10 2 7 1.20 to 6 1.30 1 8) 1.40 = 5 1.50 N 4 1.60 l 3 _1 1.70 1.80 2 - 1.90 1 2.00 2.50 0 3.00 0.70 0.75 0.80 0.85 0.90 0.95 1.00 1.10 1.20 1.30 1.40 1.50 3.50 4.00 Vitrinite Reflectance ( %) 4.50 5.00 5.50 6.00 6.50 Humble Geochemical Services Division Appendix 4 Extract and Fluid Chromatography Data Source Rock and Fluid Geochemistry of the Aklaq #6 Well — Talisman Energy Humble Geochemical Services Division S S • Oil Topping and Liquid Chromatography Report � l Humble Geochemical Services 218 Higgins Street Humble, TX 77338 M ao P. O. Box 789 Humble, TX 77347 ii: 7,44 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 - DEPTH I OIL T t ' EV ' LAC SA , .. . ,_ AROMA"" 1T ", k4w.. . r sty . f* ` . :. ' N _, Type ( WT. (mg) OIL WT. (mg) R 4 WI', ', ( s)' WT Ng) . ', % ; ' WT. ( ) % . ,WT. (mg t . °din WTI {mg " £ °/e ' In 07- 4547- 191107 Aklaq #6 "oil" in mud 6830 72 4 72.4 100 72.4 1.7 2.3% 1.9 2.6% 33.5 46.3% 32.8 45.3% 96.5% 07- 4547- 195894 Aklaq #6 Dril -N -Slide 93.7 93.7 100 93.7 1 3 1.4% 21.3 22.7% 66.4 70.9% 0.0 0.0% 95.0% 07- 4547- 195895 Aklaq#6 Mix #1* 101.7 101.7 100 101.7 1.6 1.6% 36.3 35.7% 62.8 61.8% 0.1 0.1% 991% * soluble "oil" after centrifuge separation Humble Geochemical Services Division 6/19 /2007 IIII • • Sovlent Extraction and Fractionation Results for Rock Extracts , -T Humble Geochemical Services 218 Higgins Street Humble, TX 77338 , ,, P. O. Box 789 Humble, TX 77347 y Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 . . T s lat�erq WELL TOTAL EXTRACT TOC EXTRACT LC SATURATES TES. AROMATICS RESINS ' ASPITAALTENES RECOVERY M Name TO t WT (g3 WT. ( (%e) /gTQC PPM , WT. (mg) WT. (mg) % ; WT. (mg) % WT,.(rag) ' % WT. (mg) . % IN 07- 4547- 194032 Aklaq #6 Baro -trol Plus 0.1095 34.5 315068 34.5 1.8 5.2% 1.5 4.3% 10.5 30.4% 20.6 59.7% 99.7% 07- 4547- 194033 Aklaq #6 Gilsonite 0.1209 110.8 916460 110.8 3.2 2 9% 2.8 2.5% 25 5 23.0% 73.1 66.0% 94.4% 07- 4547- 194034 Aklaq #6 Barablok 0.1101 106.0 962761 106.0 2.8 2.6% 3.2 3.0% 27.4 25.8% 69.6 65.7% 97.2% 07- 4547- 198186 Aklaq #6 7125.6' core 8.9540 3.7 413 Humble Geochemcial Services Division 6/19/2007 . S • "Oil" from 6830' drilling mud FID1 A, (G: \1\ DATA \TALISMAN \07 - 4547 \0191107B.D) PA i I 1600; 1400, I I 1200 100s 801 600- , 40 200 - 0 20 30 40 50 60 70 80 90 mir • rillin mud it from 6830 d O FID1 A, (G: \1\ DATA \TALISMAN \07 - 4547 \O191107B.D) pA I _ i 9- 1 I 8- 8 7 6 �► 5 -- 20 30 40 50 60 70 80 90 mir, ": Humble Geochemical Services P. Higgins Street Humble, TX 773 • „� P P. O. Box 789 Humble, TX 77347 7 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 Client: Talisman Energy Client ID: Rock Washer Saturate Biomarker Interpretive Ratios HGS ID: 07 -4547- 191107 Well: Aklaq #6 Interpretive By By Depth: 6830(ft) Ratios Area Height Field: Lease Terpanes (m /z 191) Formation: C19t/C23t 0.23 0.23 Basin: C22t/C21t 0.09 0.09 County,State: AK C22t/C24t 0.40 0.43 Country: C24t/C23t 0.49 0.48 C26t/C25t 1.68 1.64 Bulk Properties C24Tet/C23t 1.15 1.08 C24Tet/C26t 1.84 1.81 C23t/C3OH 0.03 0.03 API ( °) C24Tet/C3OH 0.03 0.03 S ( %) C28BNH /C3OH 0.02 0.01 Saturate ( %) 25- Nor /C3OH 0.01 0.01 Aromatics ( %) C29H /C3OH 0.59 0.56 Resin ( %) C30DiaH /C3OH 0.00 0.00 Asphaltene ( %) Ole /C3OH 0.01 0.01 S' Sat ( %o) C30Ts /C3OH 0.01 0.01 8 Aro ( %°) Gam /C3OH 0.20 0.18 8 Res ( %°) Gam /C31HR 1.41 1.29 8 Asp ( %o) C35HS /C34HS 0.69 0.69 S "C Oil ( %o) C35 Homohopane Index 0.05 0.04 0.07 0.05 Whole Oil /Extract GC Ts /(Ts +Tm) C29Ts /(C29Ts +C29H) 0.03 0.03 Mor /C3OH 0.32 0.31 CPI C32 S /(S +R) 0.56 0.54 Pristane /n -C17 Phytane /n -C18 Steranes (m /z 217) Pristane /Phytane % C27 aaa 20R 8.7 11.7 % C28 aaa 20R 62.0 53.5 % C29 aaa 20R 29.3 34.8 C27 -C28 -C 29 C27 Dia /(Dia +Reg) 0.07 0.07 al3[3 Steranes (C21 +C22)/(C27 +C28 +C29) 0.01 0.01 co ® C29 a(313 /(aaa +a1313) 0.21 0.18 C29 aaa 20S /20R 0.32 0.27 C29 aaa 20S /(S +R) 0.24 0.21 E a113- Steranes (m /z 218) % C27 a(3(3 20(R +S) 12.3 12.4 % C28 4(3 20(R +S) 51.2 53.0 C29 a(3(3 20(R +S) 36.5 34.6 Tricyc C29/C27 a(3(3 Sterane Ratio 2.97 2.78 El z kr Tricyclic/Pentacyclic Terpanes 0.10 0.10 Steranes /Terpanes 0.27 0.21 Tricyclic, % Tricyclic Terpanes 6.9 7.6 Pentacyc Pentacyclic % Pentacyclic Terpanes 72.0 75.2 Terpanes & % Steranes 21.1 17.1 Steranes Humble Geochemical Services Division Humble Geochemical Services 218 Higgins Street Humble, TX 77338 Telephone: 281 -540 6050 Fax: 281 -540 2864 o • M p # � P. O. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Client: Talisman Energy Basin: Client ID: Rock Washer County,State: AK HGS ID: 07- 4547 - 191107 Country: Well: Aklaq #6 Depth: 6830(ft) Field: Lease Formation: Saturate Biomarker Integration Results (Steranes) Ion Peak 217 :S21 Compound R.Time Peak ppm Peak ppm Label Name (min.) Area (A.) Height (Ht.) 47.14 C 21 sterane : 383 8.1 8.7 217 S22 'C22 sterane 49.90 454 9.6 164 9.7 217 ; 27DbaS ;C27 ba 20S diacholestane 57.08 618 13.0: 171 10.1 217 :27DbaR 1C27 ba 20R diacholestane 57.83 311 6.5' 147 126 7.5 4.9 217 28DbaSA 'C28 ba 20S diasterane a 58.88 383 8.1 84: 217 28DbaSB 1C28 ba 20S diasterane b 58 99 333 59 71 .0 - 110 6.5 II 7 217 .28DbaRA C28 ba 20R diasterane a 135 56 217 28DbaRB C28 ba 20R diasterane b 59.77 433 9.1 82 .6 . 143 8.5 217 '27aaS C27 as 20S cholestane 60.36 60.67 3923 1082 64.0 3.3 217 '27bbR C27 bb 20R cholestane 60.51 ' 1860 39.2 425 25.1 14.7 217 27bbS 1C27 bb 20S cholestane 217 27aaR 750 2.8 15.8 249 aaR + ch I C27 as 20R cholestane 61.16 62.26 8012 168.7 2620 155.1 217 28aaS , C28 as 20S ergostane 5487 115.6 2319: 137.2 2922 172.9 982 58.1 57358 1208.0: 11987: 709.5 8723 217 28bbR C28 bb 20R ergostane 62.51 8235 173.4 217 •28bbS 1C28 bb 20S ergostane 62.66 2898 61.0 217 '28aaR C28 as 20R ergostane 63.27 217 '29aaS C29 as 20S stigmastane 63.84 183.7 2070 122.5 217 :29bbR C29 bb 20R stigmastane 64.14 2391 50 . 4 ; 805: 47.7 217 29bbS C29 bb 20S stigmastane 64.20 7036 148.2 1360 80.5 217 .29aaR 'C29 as 20R stigmastane 64.98 27094 570.6 7784 460.8 218 :27bbR C27 bb 20R cholestane 60.52 1783 37.5 482 28.5 218 ' 27bbS 'C27 bb 20S cholestane 60.67 985 20.8 312 18.5 218 :28bbR C28 bb 20R ergostane 62.51 7462 157.1: 2012 119.1 218 28bbS C28 bb 20S ergostane 62.66 4093 86.2. 1373 81.3 - - - - - - -- -- - - - - -- - - - -- - - -- 218 ; 29bbR C29 bb 20R stigmastane 64.14 3858 81.2 1038 61.5 218 29bbS ,C29 bb 20S stigmastane 64.24 4369 92.0; 1169 69.2 259 .27DbaS C27 ba 20S diacholestane 57.08 391 8.2 114 6.8 259 27DbaR IC27 ba 20R diacholestane 57.84 265 5.6 98 5.8 259 :28DbaSA ;C28 ba 20S diaergostane a 58.89 425 8.9 1221 7.2 259 28DbaSB IC28 ba 20S diaergostane b 58.98 289 6.1: 75 4.5 259 28DbaRA !C28 ba 20R diaergostane a 59.70 81 1.7 49: 2.9 259 28DbaRB C28 ba 20R diaergostane b 59.76 63 1.3 43: 2.6 259 '29DbaS ;C29 ba 20S diastigmastane 60.50 386 660 8.1 118' 7.0 259 29DbaR C29 ba 20R diastigmastane 61.74 13.9 176 10.4 259 30TP1 C30 Terpane 65.84 1365 28.8: 411 24.3 259 '30TP2 C30 Terpane 65.92 1036 21.8^ 351 20.8 2516 148.9 1185 148.9 217 b- Cholane 5b cholane (inter. STD) 54.24 7072 148.9: 218 b- Cholane 5b- cholane (inter. STD) 54.24 3213 148.9: Humble Geochemical Services Division 1: ;f Humble Geochemical Services P. Higgins Street Humble,TX773 P. O. Box 789 Humble, TX 77347 • : Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: Rock Washer County,State: AK HGS ID: 07- 4547- 191107 Country: Well: Aklaq #6 Depth: 6830(ft) Field: Lease Formation: Saturate Biomarker Integration Results (Terpanes) Ion Peak ( Compound R.Time Peak ppm ( Peak ppm Label Name (min.) Area (A.) Height (Ht.) 125 BCRT ,b- ,b 1 191 I C19t C19 tricyclic diterpane 40.15 1 984' 20.7 355 1 21.0 191 , C20t C20 tricyclic diterpane 42 43 118711 250.0' 4334 256.6 Y p 191 ; C21t •C21 tricyclicditerpane 44.76 9089 + 191.4 33461 198.1 191 1 C22t [C22 tricyclic terpane : 46.89 ' 830; 17.5 314; 18.6 191 j C23t C23 tricyclic terpane 49.31 4250 89.5. 551 3 92.0 191 ;C24t C24tricyclicterpane • 50.63 2066, 43.5: 739 43.7 191 C25tS C25 tricyclic terpane (S) 53.19 757 15.9: 277 16.4 191 C25tR C25 tricyclic terpane (R) 53.26 8241 17 4 292 I 17.3 191 C24T C24 tetracyclic terpane (TET) 54.79 ( 49071 103.3' 16821 99.6 191 C26tS C26 tricyclic terpane (S) 55.07 1367 ' 4 28.8. 4321 25.6 191 [C26tR C26 tricyclic terpane (R) 55.23 1295: 27.3` 4991 29.5 191 C28tS C28 extended tricyclic terpane (S) 59.20 13131 27 6 264 15.6 • - - 191 C28tR C28 extended tricyclic terpane (R) 59 52 6501 13 7: 260 15.4 191 ' C29tS C29 extended tricyclic terpane (S) 60 42 543' 11.4' 225 13.3 1 ( 191 1 C29tR , C29 extended tricyclic terpane (R) • 60.78 : 862 i 18.1 ' 216 12.8 191 1C3OtS C30 extended tricyclic terpane (S) ' 62.66 862 I 18.2: 247 14.6 191 C30tR C30 extended tricyclic terpane (R) 62.99 ( 2162 45 5 , 787 46.6 191 ITs Ts 18a(H)- trisnorhopane 61.58 1' 2114' 44.5 5411 32.0 191 1Tm :Tm 17a H - trisnorho ane 62.32 28411 ` 598.3: 10093) 597.4 191 I C28BNH :C28 17a18a21b(H)-bisnorhopane ; 64.16 2739 57.7 587 34.7 C29Tm17a(H)21b(H)- norhopane 64.98 17a( -_.n. rho 4 351 20.8 191 C29H H C29 Nor-25-hopane 105 25. p 64.61 j.. ........ .._ .. _.... .. 91405 1925.0: 29784 1763.0 - - - - -- - -- - - -- 191 , C29Ts C29 Ts 18a H - norneoho ane ' 65.05 2984; 62.8. 858 50.8 191 1C30DiaH C30 17a(H)- diahopane 65.40 ; 4951 10.4' 256; 15.2 191 'Normor C29 normoretane 65.85 142711 300.6' 4416' 261.4 191 a -Ole a- oleanane 66.34 14791 31.1 450; 26.7 191 b -Ole b- oleanane 66.41 j 5831 12.3: 249 14.7 191 1 IC30H C30 17a(H)- hopane 66.58 ' 15 3245.2 535861 3171.9 191 C30Ts 17a(H) -30- nor -29- homohopane 66.91 1471 31 0 3671 21.7 191 1 Mor 'C30 moretane 67.25 499901 1052.8 16382 1 969.7 191 [C31 HS C31 22S 17a(H) homohopane 68.38 26229 552.4'' 87251 516.5 191 ,C31HR ' C31 22R 17a(H) _p homohopane 68.59 , 22124; 465.9' 7649 452.8 191 ;Gam •gammacerane 68.79 31089 i 654.7: 9903 586.2 191 1C32HS :C32 22S 17a(H) bishomohopane 6979 I 9397 197.9' 3300 195.3 191 ! C32HR C32 22R 17a(H) bishomoho ane 70.09 : 7437 i 156.6. . 27691 163.9 191 1C33HS C33 22S 17a(H) trishomohopane : 71.45 ( 51211 107.8: 1886; 111.7 191 IC33HR :C33 22R 17a(H) trishomohopane ' 71.89 -_ 44621 _ 94.0 1362: 80.6 191 'C34HS C34 22S 17a(H) extended hopane • 73.38 3421' 72 .0, 962 56.9 1 _ 9 1 1, C34HR i C34 22R 17a(H) extended hopane ' 73.99 . 2523 53 1 661 39.1 191 C35HS : C35 22S 17a(H) extended hopane 75.56 23571 49.6: ; 667; 39.5 191 C35HR C35 22R 17a(H) extended hopane 76.42 1836 f 38.7 5241 31.0 . . 1 ---- , II Humble Geochemical Services Division • - Humble Geochemical Services 218 Higgins Street Humble, TX 77338 P. 0. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Rock Washer Key Saturate GC -MS HGS ID: 07 -4547- 191107 Ion Chromatoarams 14000 m/z 217: Steranes 12000 10000 - u 12 m n c 8000 - cn 6000 - u U m • 4000 9 2000 - N I 44 48 52 56 60 64 68 Retention Time (min.) 7000 m/z 218: Steranes 6000 - 5000 - • m 2 • 4000 o • 3000 - 5 CD 2000 - 1000 - 44 48 52 56 60 64 68 Retention Time (min.) 1400 m/z 259: Diasteranes 1200 - 1000- .3 u c m c 800 - w 600 - 0 U 400 - I 200 - X J[ 4 0 44 48 52 56 60 64 68 Retention Time (min.) 411 Humble Geochemical Services Division •- Humble Geochemical Services 218 Higgins Street Humble, TX 77338 e ll ,„ &w : P. 0. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Rock Washer Key Saturate GC -MS HGS ID: 074547491107 Ion Chromatograms 60000 m/z 191: Tri -, tetra- and pentacyclic Terpanes 50000 - u 40000 - e m i c � 2 30000 - a N 2 0 20000 - a x E 10000 - s U i x A U K m v a m n U V p U U 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 14000 m/z 177: Norhopanes 12000 - 10000 - • u e c 8000 a n 6000 - U 4000 - 2000 - 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 4500 m/z 205 4000 - 3500 - u 3000 - e m c 2500 - m 2000 - CD 1500 - 1000- 500 - 0 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 1 Humble Geochemical Services Division • 218 Higgins Street Humble, TX 77338 f Humble Geochemical Services P. O. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: Rock Washer County,State: AK HGS ID: 07 -4547- 191107 Country: Well: Aklaq #6 Depth: 6830(ft) Field: Lease: Formation: Aromatic Biomarker Interpretive Ratios Interpretive By By Ratios Area Height Naphthalenes DNR- 1= (2,6 +2, 7)/(1,5) DMN 1.62 1.39 DNR- 2 =(2,6 +2,7)/(1,4 +2,3)DMN 1.22 1.02 TNR1= (2,3,6)/(1,4,6 +1,3,5)TMN 0.68 0.71 TDE -1= 1,2,5 -TMN /1,2,4 -TMN 3.25 2.95 TDE -1 =1, 2, 7 -TMN /1,2,6 -TMN 0.23 0.34 Phenanthrenes MPI- 2= 3(2MP) /(PHEN +1 MP +9MP) 0.60 0.53 MPI- 1= 1.5(2MP +3MP) /(PHEN +1 MP +9MP) 0.56 0.53 • Rc(a)= 0.6(MPI -1) +0.37 (for Ro <1.3) 0.71 0.69 Rc(b)= 0.6(MPI- 1) +2.3 (for Ro >1.3) 2.64 2.62 MDR= 4MDBT /1MDBT 3.38 2.13 Rm= 0. 40+ 0. 30(MDR)- 0.094(MDR) +0.011(MDR) 0.76 0.72 MDR23= 23MDBT /DBT 0.54 0.37 MDR1 =IMDBT /DBT 0.27 0.27 DBT /Phenanthrene 0.17 0.17 Triaromatic Steroids TAS 20 +21/all TAS 0.00 0.00 TAS 20/20 +27 0.00 0.00 TAS 21/21 +28 0.00 0.00 TAS C28/C26 20S #DIV /01 #DIV /0! TAS C28/C27 20R 0.88 1.16 % 26 TAS 0.0 0.0 % 27 TAS 61.4 55.7 % 28 TAS 38.6 44.3 % 29 TAS 0.0 0.0 Monoaromatic Steroids MAS Dia /Reg C27 0.58 0.40 MAS 21 +22/all MAS 0.08 0.10 °A)27MA 16.1 24.2 °A)28MA 45.5 41.3 % 29 MA 38.3 34.4 TAS /(TAS +MAS) 0.32 0.29 TAS28 /(TA28 +MA29) 0.51 0.52 • Humble Geochemical Services Division 0 , 218 Higgins Street Humble, TX 77338 Il fr . 1 Humble Geochemical Services P. O. Box 789 Humble, TX 77347 it Division of Humble Instruments & Services, Inc. Telephone: 281 6050 Fax: 281 2864 Client: Talisman Energy Basin: Client ID: Rock Washer County,State: AK HGS ID: 07-4647-191107 Country: Well: Aklaq #6 Depth: 6830(ft) Field: Lease: Formation: Aromatic Biomarker Integration Results (Naphthenes, Dibenzothiophene, Phenanthrenes) Ion Peak Compound R.Time I Peak I ppm I Peak ppm Label Name (min.) Area (A.) Height (Ht.) 1 128 NAPH ;Naphthalene 0.00 o 0.01 0. 0.0 142 2MN 12-Methylnaphthalene 0.00 0 0.0! 0: 0.0 --, 142 1MN :1-Methylnaphthalene 0.00 0 4-- 0.0; 0' 0.0 156 2EN 12-Ethylnaphthalene 21.95 359 4.1; 79: 24 156 1EN 1-Eth Ina. hthalene 22.02 91 1.01 41: 1.2 156 -26DMN 2,6-Dimethylnaphthalene 22.32 869 10.0 215 6.5 156 ,27DMN 2,7-Dimethylnaphthalene 22.39 955 11.0 301 9.0 156 13+17DMN 1,3 & 1,7-Dimethylnaphthalenes 22.82 ' 3622; 41.7 1063 31.9 156 16DMN 11,6-Dimethylnaphthalene 22.94 3160; 36.4 776 23.3 4 - , 156 23DMN 42,3-Dimethylnaphthalene 23.45 639; 7.4; 212 - 6.4 156 14DMN ;1,4-Dimethylnaphthalene 23.51 851; 9.8; 294' 8.8 - --, 156 15DMN 11,5-Dimethylnaphthalene 23.57 11271 13.0; 371; 11.2 • 156 12DMN 11,2-Dimethylnaphthalene 170 .BBEMN Ethyl-methyl-Naphthalene 25.83 1764 20.3 431. 12.9 170 AB EMN Eth I-methyl-Naphthalene 23.99 8.9; 26.38 ' 7711 1059 12.2 221' 6.6 290 8.7 170 137TMN 1,3,7-Trimethylnaphthalene 26.56 3917 45.1 1261 37.9 170 136TMN ,1,3,6-Trimethylnaphthalene 26.74 55111 63.5 1802 54.1 170 146+135T ;(1,4,6+1,3,5)-Trimethylnaphthalenes ; 27.23 52951 61 , 1537' 46.2 170 236TMN 12,3,6-Trimethylnaphthalene 27.38 3625; 41.8; 1090. 32.8 170 127TMN 11,2,7-Trimethylnaphthalene ; 27.73 11661 13.4; 346. , 10.4 , 170 167+126T 1(1,6,7+1,2,61-Trimethylnaphthalenes f, 27.82 50851 58.61 1022: 30.7 170 124TMN 1,2,4-Trimethylnaphthalene 28.30 689 7.9 , 235 170 125TMN 1,2,5-Trimethylnaphthalene 28.54 . 2238 25.8 693' 20.8 184 1357 1,3,5,7-Tetramethylna•hthalene 30.65 . 1775 20.5 387' 11.6 184 1367 1,3,6,7-Tetramethylnaphthalene 31.37 1805 20.8 5607 16.8 184 1247 ;(1,2,4,7+1,2,4,6+1,4,6,7)-Tetr 31.83 1665 19.2 536 16.1 1 184 1257 11,2,5,7-Tetramethylnaphthalene 31.95 1042 12.0; 302: 9.1 184 2367 12,3,6,7-Tetramethylnaphthalene 32.20 351 4.01 104: 3.1 184 1267 11,2,6,7-Tetramethylnaphthalene 32.46 660 7.6: 202' 6.1 184 1237 11,Z3,7-Tetramethylnaphthalene 32.60 306 3.5; 80: 2.4 184 1236 1,2,3,6-Tetramethylnaphthalene 32.77 698 8.01 202. 6.1 184 1256 1,2,5,6-Tetramethylnaphthalene 33.24 ' 1200 13.8 338: 10.1 184 D, 33.47 134715.5: 360, , 10.8 198 4MDBT 14 Methyl Dibenzothiophene 36.58 1206, 13.9; 208 6.3 198 2+3MDBT 1 2 & 3 Methyl Dibenzothiophenes T 37.14 732; - 4741 135: 4.1 , 198 1MDBT ;1 Methyl Dibenzothiophene 37.74 357; 471 98 2.9 , ; 1 , - 154 BP ',Biphenyl 0.00 0 0.01 0' 0.0 168 2MBP __2-Methylbiphenyl 22.01 104 1.21 39, 1.2 , 168 DPM Diphenylmethane 23.04 167 1.9] 44. 1.3 168 3MBP 3-Methylbiphenyl 24.99 1850 21.31 451 13.6 , 168 4MBP , 4-Methylbiphenyl 25.30 6861 7.9; 183 5.5 1 168 ;DBF 1Dibenzofuran 26.05 645 4 7.4T 134' 4.0 1 1 1 I 178 PHEN ,IPhenanthrene 34.31 ' 8101 93.31 2076 62.4 192 3MP ,3-Methylphenanthrene 37.77 2852; 32791 699: 21.0 192 2MP 12-Methyprienanthrene 37.92 3236i 37.3T 697' 20.9 192 9MP ,9-Methylphenanthrene 38.43 4704 i 54.21 1104' 332 • 192 1MP 11-Methylphenanthrene , 38.57 35021 40.31 796' 23.9 Humble Geochemical Services Division • 218 I P. M;-f Humble Geochemical Services Higgins Street Humble, TX773 P. O. Box 789 Humble, TX 77344 7 Il Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: Rock Washer County,State: AK HGS ID: 07- 4547 - 191107 Country: 0 Well: Aklaq #6 Depth: 6830(ft) Field: Lease: Formation: Aromatic Biomarker Integration Results (Dimethyl - Phenanthrenes, Benzohopanes, Triaromatic Steroids, Monoaromatic Steroids) Ion I Peak I Compound R.Time Peak ppm Peak ppm Label Name (min.) Area (A.) Height (Ht.) 206 26DMP 2,6- Dimethylphenanthrene Y P 41.20 f 85 4 9 . 8 155 4.7 221, 6.6 206 27DMP 2,7-Dimethylphenanthrene ene 41.. 30 ! 604 7.0 15858 1 4.7 206 39DMP (3,9 +3,10 +2,10 +1,3)- DimethI henanthrenes 41.67 3836 44.2 910 27.3 206 29DMP ( 2, 9 +1,6)- Dimethylphenanthrenes 41.84 2200] 25.31 347 _ 10.4 206 17DMP 1,7- Dimethylphenanthrene 41.97 15531 17.9! 359'], 10.8 206 23DMP 2,3- Dimethylphenanthrene 42.18 6591 7. 6! 169; 5.1 206 19DMP 1,9- Dimethylphenanthrene 42.27 1 1060: 12.21 256 7.7 • 206 18DMP 1,8- Dimeth Y I henanthrene 42.62 488 f l 5.6 115 P - -- � 206 12DMP 1,2- Dimethylphenanthrene 43.03 312 3.6 92! 3.5 2.8 191 BH32 C32 Benzohopane 0.00 0, 0.0 0 0.0 191 BH33 C33 Benzohopane 0.00 01 0.01 01 0.0 191 . BH34 C34 Benzohopane 0.00 J - 01 0.01 0 0.0 191 BH35 C35 Benzohopane - 0.00 0 0 0 0.0 231 1TA20 C20 Triaromatic Steroid 1 0.00 0 0.0 0! 0.0 231 2TA21 C21 Triaromatic 0.00 0 0.0 0 0.0 231 .3TA26 C26 20S Triaromatic 0.00 1 0 0.0 ! 0 0.0 231 4TA26 +27 C27 20S & C26 20R Triaromatic 63.10 1 8451 9.7 225 6.7__ 231 .5TA28 C28 20S Triaromatic 64 28 66.19 535J 6.2 158 3.9 n- ro I) 1 ' 231 6TA27 C27 20R Triaromatic 64.81 6111 7.01 136 4.1 231 7TA28 C28 20R Triaromatic 4.7 231 8TA29 C29 20R Triaromatic (24 ( P PY I 0.00 0 � 0.0 7 i 0.0! 0 253 1MA21 C21 Ring -C Monoaromatic Steroid 45.03 200 2._3 _ 68 2.0 2 53 2MA22 C22 Monoaromatic steroid 1 47.07 I 204 2.3 86 2.6 253 3MA27 .C27 Reg 5b(H),10b(CH3) 20S r 55.52 I 2451 2.81 111 3.3 253 ,4MA27 'C27 Dia 10b(H),5b(CH3) 20S 55.61 1411 1.6 44 1.3 253 5MA27 C27 Dial0bH,5bCH3 20R +Reg5bH,10bCH3 20R 57.00 1 1621 1.9 73 2.2 253 6MA27 C27 Reg 5a(H),10b(CH3) 20S 57.13 t 109; 1.3, 701 2.1 253 7MA28 C28 Dia 10aH,5aCH3 20s +Reg5bH,10bCH3 20S 57.44 } 462! 5.3' 113 3.4 253 8MA27 C27 Reg 5a(H),10b(CH3) 20R 58.62 1091 1.3 53 1.6 253 9MA28 C28 Reg 5a(H),10b(CH3) 20S 58.72 505 i 5.8 161 1 4.8 253 10MA28 C28 Dia 10aH 5aCH3 20R +Reg5bH,10bCH3 20R 59.00 } 478 6.0! 156 4.5 253 11MA29 C29 Dia 10bH,5bCH3 20S +Re 5bH,10bCH3 20S 4.7 253 12MA29 C29 Reg 5a(H),10b(CH3) 20S 1 60.10 483 5.6; 139, 4.2 253 13MA28 C28 Reg 5a(H),10b(CH3) 20R 60.38 716 8.3 176 5.3 253 14MA29 C29 Dia 10bH ,5bCH320R +Reg5bH,10bCH320R j 60.50 , 41 8{ 4.8! 83, 2.5 253 15MA29 C29 Reg 5a(H),10b(CH3) 20R 61.89 3951 4.6! 1211 3.6 ! • 230 OTP Ortho- terphenyl (Inter. STD) 37.49 I 15504', 178.6 5944 178.6 Humble Geochemical Services Division 218 Higgins Street Humble, TX 77338 �µ ^ I. - " Humble Geochemical Services P. 0 Box 789 Humble, TX 77347 Telephone: 281 -540 6050 Fax 281 -540 2864 Division of Humble Instruments & Services, Inc. Client: Talisman Energy Client ID: Rock Washer Key Aromatic GC -MS I HGS ID: 07-4547- 191107 I Ion Chromatoarams 1200 o m/z 156: Dimethylnaphthalenes 1000 - 800 600 - N i • 400- 2 r 9 1 ( f W 200' IIV • 20 0 3 36 Retention Time (min.) 40 24 28 2000 f L, m/z 170: Trimethylnaphthalenes 1800 1600- IA K 1400 - ry e 1200 - a 1000 - ! u 800 - o 600 m a 2 i k a ID 400 - 200 - ,,,„ ■ 0 20 32 36 Retention Time (min.) 40 24 28 700 m/z 184: Tetramethylnaphthalenes 600 - 500 - rvo Q 400 - i f 300- u N V 1 1 � ^ I ^ �1 ^` a 41 ' 200- rU1. Ajk �N 100 ' 0 20 3 36 Retention Time (min.) 40 24 28 r. 300 m/z 198: Pentamethylnaphthalenes o zsa - 200 - \\ 4 Q 150 - (7 100 - 1 \\ i \ , i ;+ 1 \ V% \ \ V \ )1\ 4 0 - 20 32 36 Retention Time (min.) 40 24 28 • Humble Geochemical Services Division Humble Geochemical Services 218 Higgins Street Humble, TX 77338 0. 10.'4 P. 0. Box 789 Humble, TX 77347 1110 Division of Humble Instruments & Services, Inc. Telephone: 281-540 6050 Fax: 281-540 2864 Client: Talisman Energy Client ID: Rock Washer Key Aromatic GC-MS HGS ID: 074547-191107 ion Chromatoarams 7000 m/z 230: Ortho-Terphenyl (Inter. Std) 6000 - 0 5000 - 1 4000 - .2 e 3000 - r.7 2000 - 1000 - 0 • • • 32 34 36 38 40 42 Retention Time (min.) 300 m/z 154: Biphenyl • 250 - 200 - I .12 150 - 50 - 0 18 20 22 24 26 28 Retention Time (min.) 600 m/z 168: Methylbiphenyls (MBP) 2° 500 - 12 400 .12 300 - 2 8.) ° 200 - 03 2 100 - 18 20 22 24 26 28 Retention Time (min.) • Humble Geochemical Services Division • - Humble Geochemical Services 218 Higgins Street Humble, TX 77338 i «„„,. P. 0. Box 789 Humble, TX 77347 le- .- Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Rock Washer Key Aromatic GC -MS HGS ID: 07 -4547- 191107 Ion Chromatoarams 2500 m/z 178: Phenanthrene 2000 - 1500 - 9 • 1000 - (7 500 - 1 p I (� n i �M ✓ �^,/rvhr�1'M" "�^V"`' 'M1"'M"'� `�4J1^ '1h 0 31 33 35 37 39 41 43 45 Retention Time (min.) 1200 m/z 192: Methylphenanthrenes 1000 - 800 - g I c I m 2 600- (6 N U (5 400 - • 1 • 200 - 31 33 35 37 39 41 43 45 Retention Time (min.) 1200 m/z 206: Dimethylphenanthrenes loon - I m 600 - c 2 600 La 2 o° (7 400 - o • 0 200 m V 1\ r o o 31 33 35 37 39 41 43 45 Retention Time (min.) • Humble Geochemical Services Division •-- -11 Humble Geochemical Services 218 Higgins Street Humble, TX 77338 ,,„ P. 0. Box 789 Humble, TX 77347 `1 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Rock Washer Key Aromatic GC -MS HGS ID: 07 -4547- 191107 Ion Chromatoarams 1600 m/z 191: Benzohopanes 1400- )4''' 1200- v 9� 1 1,YR�, /' i\.k '1i, *1\i'fvf'f,,,,ti\A`pl ' '^ V ' V lu' \ \\ ` III VVV w 1 � ,006 - - 800 - N O • 600 400 - 200 - 70 72 74 76 78 80 Retention Time (min.) 600 m/z 231: Triaromatic Steranes 500 - 10 i 400 - v 5 a 300 - c N a I' N U • 200 - !OlV4h140 100 -� 1 0 . 48 52 56 60 64 68 Retention Time (min.) 450 m/z 253: Monoaromatic Steranes 400 - 350 - 5' w 300 - O i c 250 - 5' m R 1 11 f s a y 200 - § U ¢ ry - § f \1 ? 41'1 * • , • ' 'I 50 42 46 50 54 58 62 Retention Time (min.) II Humble Geochemical Services Division • • • • SteelSeal Extract __-- FID1 A, (G: \1 \DATA \07- 4547\E pA 400 1 co 1 5 I 1 c 350 I I I 1 I 300— in 250 5 N 5 I 200H 1 co I 1 5 C 150] I 1 5 r _ c Lo 5 I 100 - c ao a) 5 c m c 0 5 0 5 O C I L . U N N N N to r rn - i t c &o000,1 & . .900 c I C C c i — 0 H — T T I 40 50 60 80 90 mir 20 30 • • • Baro-trol Pius Extract FID1 A, (G: \1 \DATA \07 - 4547 \E194032A.D) pA c 1 6 - 1 4 - 5 1 2 c 1 0 - ' 4- 2- i 20 30 40 50 60 70 80 90 mir H umble Geochemical Services 218 Higgins Street Humble, TX 77338 • Division of Humble Instruments & Services, Inc. P. O. Box 789 Humble, TX 77347 Telephone: 281 -540 6050 Fax: 281 -540 Client: Talisman Energy Client ID: Saturate Biomarker Interpretive Ratios HGS ID: 07- 4547 - 194032 Well: Aklaq #6 Interpretive By By Depth: Ratios Area Height Field: Lease Terpanes (m /z 191) Formation: C19t/C23t 0.29 0.24 Basin: C22t/C21t 0.09 0.10 County,State: AK C22t/C24t 0.52 0.57 Country: C24t/C23t 0.48 0.44 C26t/C25t 1.60 1.92 Bulk Properties C24Tet/C23t 1.18 1.13 p C24Tet/C26t 1.79 1.82 C23t/C3OH 0.02 0.02 API ( °) C24Tet/C30H 0.03 0.03 S ( %) C28BNH /C3OH 0.02 0.01 Saturate ( %) 25- Nor /C3OH 0.00 0.00 Aromatics ( %) C29H /C3OH 0.54 0.55 Resin ( %) C30DiaH /C3OH 0.00 0.00 Asphaltene ( %) Ole /C3OH 0.01 0.01 6' Sat ( %o) C30Ts /C3OH 0.01 0.01 S Aro ( %o) Gam /C3OH 0.20 0.18 6 Res ( %o) Gam/C31HR 1.54 1.44 6 Asp ( %o) C35HS /C34HS 0.00 0.00 • S "C Oil ( %o) C35 Homohopane Index 0.00 0.00 0.03 0.03 Whole Oil /Extract GC Ts /(Ts +Tm) C29Ts /(C29Ts +C29H) 0.01 0.01 Mor /C3OH 0.33 0.31 CPI C32 S /(S +R) 0.53 0.52 Pristane /n -C17 Phytane /n -C18 Steranes (m /z 217) Pristane /Phytane % C27 aaa 20R 7.7 10.0 % C28 aaa 20R 63.9 56.3 C29 aaa 20R 28.4 33.7 C 27- c28 -c29 C27 Dia /(Dia +Reg) 0.00 0.00 al3l3 Steranes (C21 +C22)/(C27 +C28 +C29) 0.00 0.01 C29 ® C29 a(3(3 /(aaa +4113) 0.18 0.15 C29 aaa 20S /20R 0.29 0.26 C29 aaa 20S /(S +R) 0.22 0.20 c28 a(3(3- Steranes (m /z 218) C27 a(3(3 20(R +S) 11.7 10.2 % C28 a(3(3 20(R +S) 63.1 62.8 % C29 O(3 20(R +S) 25.2 27.1 Tricyc' C29/C27 a(3(3 Sterane Ratio 2.14 2.67 st. Tricyclic /Pentacyclic Terpanes 0.09 0.09 Steranes /Terpanes 0.27 0.20 Tricyclic, % Tricyclic Terpanes 6.4 7.1 Pentacyc Pentacyclic % Pentacyclic Terpanes 72.6 75.9 Terpanes & % Steranes 21.1 17.0 Steranes • Humble Geochemical Services Division - -4 1 Humble Geochemical Services 218 Higgins Street Humble, TX 77338 P. O. Box 789 Humble, TX 77347 • , 00 0`, IV -111 Division of Humble Instruments & Services, Inc. Telephone: 281-540 6050 Fax: 281-540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07-4547-194032 Country: Well: Aklaq #6 Depth: Field: Lease Formation: Saturate Biomarker Integration Results (Steranes) Ion I Peak I Compound I R.Time I Peak I ppm I Peak I ppm I Label Name I (min.) I Area I (A.) I Height I (Ht.) . • . . . . 217 S21 C21 sterane 47.01 : 102 9.7 33' 9.4 217 :S22 IC22 sterane 49.78 27.6 loll 28.2 ,.. 290 217 27DbaS ;C27 ba 20S diacholestane ' 0.00 ' 0 0.0: 0: 0.0 217727DbaR C27 ba 20R diacholestane 0.00 0: 0.0, 0 0.0 217 128DbaSA 1C28 ba 20S diasterane a . 0 00 , . . . 0 0.0' 0: 0.0 217 28DbaSB 1C28 ba 20S diasterane b - 0.000 0.0 0: 0.0 217 28DbaRA 1C28 ba 20R diasterane a , 0.00 , 0 0.0 0 0.0 217 :28DbaRB i- C28 ba 2OR diasterane b . 0.00 : o' 0.0 o i0 : 217 27aaS IC27 aa 20S cholestane I 60.25 2473 235.6: 717 200.7 : 217 :27bbR IC27 bb 20R cholestane - 60.40 : 849' 80.91 2071 58.0 217 :27bbS 'C27 bb 20S cholestane ; 60.56 : 357 34.0: 91: 25.4 • 217 :27aaR C27 aa 20R cholestane : 61.04 . 5545 528.2: 1812 507.5 217 I28aaS 4C 28 aa 20S ergostane : 62.14 5029 479.1: 1534: 429.5 . 217 28bbR :C28 bb 2OR ergostane I 62.38 . 6120: 583.0, 1936 542.2 217 28bbS :C28 bb 20S ergostane . . 62.54 ' 1895' 180.6 630 176.5 217 ;28aaR C28 aa 20R ergostane , 63 16 , 46349 4415.3' 10166' 2846.9 . . 217 .29aaS C29 aa 20S stigmastane : 63.72 5945 566.3: 1565. 438.3 217 ;29bbR ,C29 bb 2OR stigmastane • 64 : 1230 117.2 430 120.4 217 29bbS 1C29 bb 20S stigmastane 64.08 I 4563' 434.7' 919 257.5 217 :29aaR 'C29 aa 20R stigmastane . 64.85 20584, 1960.9 6080: 1702.7 218 I27bbR C27 bb 2OR cholestane 60.41 : 896. 85.4, 239 66.9 218 .27bbS C27 bb 20S cholestane I 60.56 363 34.6 120: 33.7 218 :28bbR :C28 bb 2OR ergostane ' 62.39 : 4249: 404.8 1321. . 370.0 218 .28bbS 'C28 bb 20S ergostane : 62.54 ' 2527 240.7 . • 898 251.6 218 29bbR C29 bb 2OR stigmastane 64.01 : 1551 147.71 4941 138.2 218 :29bbS iC29 bb 20S stigmastane ; 64.07 1149 109.5; 465 130.1 : 259 :27DbaS__ j 27 ba 20S diacholestane • 0.00 : 0 0.0, 0 0.0 259 . 27DbaR C27 ba 20R diacholestane I 0.00 : 0 o.o; o 0.0 259 .28DbaSA I C28 ba 20S diaergostane a • 0.00 0 0.0 0, 0.0 259 :28DbaSB .C28 ba 20S diaergostane b • 0.00 . 0 0.0 0 0.0 259 :28DbaRA 1C28 ba 20R diaergostane a ' 0.00 • 0 0.0 0 0.0 259 28DbaRB . 1C28 ba 20R diaergostane b 0.00 : 0 0.0 . o' 0.0 259 29DbaS 1C29 ba 20S diastigmastane 60.42 : 173 16.4' 51, 14.4 259 :29DbaR C29 ba 20R diastigmastane ' 61.63 ; 332 31.6 121: 33.9 259 .30TP1 IC30 Terpane . 6571 772 73.5 253 70.9 259 30TP2 C30 Terpane . 65.80 • 752' 71.7 236 , . . . • . : . • . . . • • • . . . , .. 217 :b-Cholane 5b-cholane (inter. STD) 54.12 , 1688 160 8 574: 160.8 . , 218 b-Cholane 5b-cholane (inter. STD) . 54 12 ; . 751. 160.8 264 160.8 , 4 . . . : . • . I . , • Humble Geochemical Services Division 218 Higgins Street Humble, TX 77338 Humble Geochemical Services P. O. Box 789 Humble, TX 77347 UM 41110 �-.-� Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07 -4547- 194032 Country: Well: Aklaq #6 Depth: Field: Lease Formation: Saturate Biomarker Integration Results (Terpanes) Ion 1 Peak mpound R.Time Peak ppm Peak ppm Label I Co Name I (min.) Area (A.) I Height (Ht.) 125 I BCRT ; b- carotane ! a 191 C19t C19 tricyclic diterpane 40.03 779;, 74.2. 2451 68.7 191 , C20t C20 tricyclic diterpane 42.31 97991 933.5: 3 614 t 1012.0 191 1C21t C21 tricyclic diterpane 44.64 6933 660.5 11 733.3 191 1C22t 'C22 tricyclic terpane 46.77 656; 62.5: 254 71.3 191 C23t C23 tricyclic terpane , : 49.19 + 2655 252.9' 1005: 281.5 191 C24t ;C24 tricyclic terpane 50.51 ! 1268 120.8 444 124.5 191 C25tS !C25 tricyclic terpane (S) 53.08 559 53.3: 139 39.0 191 C25tR ,C25 tricyclic terpane (R) 53 15 533 50 8 186 52.0 191 +C24T C24 tetracyclrc terpane (TET) • 54 67 31331 298.5 11351 317.9 191 C26tS C26 tricyclic terpane (S) • 54.95 933; 88.9. 306 85.6 191 1 C26tR C26 tricyclic terpane (R) 55.12 815 77.7 317 88.7 P 191 , C28tS C28 extended tricyclic terpane (S) 59.11 9011 85.9' 1751 49.1 • 191 1 C28tR : C28 extended tricyclic terpane (R) 59.40 5071 48.3' 118 33.1 1 191 C29tS :C29 extended tricyclic terpane (S) 60.38 1341 12.7 661 18.6 191 C29tR C29 extended tricyclic terpane (R) 60 66 ! 305 29.1 ' 117 32.9 191 C30tS C30 extended tricyclic terpane (S) 62.55 4371 41.6! 171 48.0 191 1 C30tR C30 extended tricyclic terpane (R) : 62.97 2101 20 1151 32.2 191 1Ts Ts 18a(H)- trisnorhopane 61.46 624 59.4. 2071 58.0 191 Tm Tm 17a(H)-trisnorhopane : 62.20 . 20320 1935 8: 70911 1985.9 191 C28BNH :C2817a18a21b(H)- bisnorhopane ' 64.04 1922: 183.1' 447 125.3 191 !Nor25H C29Nor -25- hopane 64.41 413 39.4' 169 47.3 191 1 C29H C29 Tm 17a(H)21 b(H)- norhopane . 64.86 662671 6312.8 231701 6488.7 191 1 C29Ts 1C29 Ts 18a(H)- norneohopane 64.92 754 71.8' 321 89.9 191 'C30DiaH . C30 17a(H)- diahopane 65.30 233 222! 731 20.4 191 Normor C29 normoretane • 65.73 11818! 1125.8: 38521 1078.6 191 a -Ole : a- oleanane 66.22 i 12211 116.3 340; • 95.1 191 :b-Ole : b- oleanane _ 66.28 j 4731 _ 45.11 200 55.9 191 1C30H C3017a(H)- hopane 66.45 123038 11720.9. 42482 11897.0 191 +C30Ts 17a(H) -30 -nor 29- homohopane 66.78 1014 96.6 218 61.0 191 Mar C30 moretane . 67 13 40098 3819.8 13165' 3686.8 191 C31HS C31 22S 17a(H) homohopane ' 68.25 177011 1686.2 5606: 1570.0 191 C31HR C31 22R 17a(H) homohopane , 68 160281 1526.8: 5439 t 1523.2 191 Gam igammacerane . 68.66 24647 2348.0; 7823 2190.8 191 1 C32HS C32 22S 17a(H) bishomohopane 69.66 4 6106' 581.6 1934 541.7 191 1C32HR C32 22R 17a(H) bishomohopane 69.96 53531 509.9 1778 497.8 191 C33HS . C33 22S 17a(H) trishomohopane 71.32 35301 336.3' 1036' 290.2 191 C33HR :C33 22R 17a(H) trishomohopane 71 75 ; 33361 317 8: 947 265.2 19 C34HS , C34 22S 17a(H) extended hopane , 73.21 1 2283' 217.5' 5371 150.4 191 ! C34HR C34 22R 17a(H) extended hopane 73.83 1551 147.8: 464T 130.0 191 1 C35HS :C35 22S 17a(H) extended hopane _ 0.00 I 0 0.0. 01 0.0 191 1C35HR • C35 22R 17a(H) extended hopane 0.00 I 0! 0.0. 01 0.0 r 1 . • • Humble Geochemical Services Division • Humble Geochemical Services 218 Higgins Street Humble, TX 77338 M P. 0. Box 789 Humble, TX 77347 7 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Saturate GC -MS HGS ID: 07 -4547- 194032 Ion Chromatoarams 12000 m/z 217: Steranes l0000 - 8000 - c A a 6000 - W (.9 4000 - 2000 - o 1 0 44 48 52 56 60 64 68 Retention Time (min.) 6000 m/z 218: Steranes 5000 - • u 4000 - c c a 3000 - en 2 C9 2000 - m I� 1 000 - 11 I 44 48 52 56 60 64 68 Retention Time (min.) 1000 m/z 259: Diasteranes 900 - 800 - d 700 - u a 600 - a 500 - en 400 - t 300 - 200 N i 100 k 0 44 48 52 56 60 64 68 Retention Time (min.) 4 10 Humble Geochemical Services Division • Humble Geochemical Services 218 Higgins Street Humble, TX 77338 P. 0. Box 789 Humble, TX 77347 it" . Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Saturate GC -MS HGS ID: 07 -4547- 194032 Ion Chromatoarams 45000 40000 - m/z 191: Tri -, tetra- and pentacyclic Terpanes 35000 - 30000 - e m c 25000 - 0 a w 20000 - • 15000 - E 1 0000 - r i x K U 2 5000 ° U N m I o e I I a �.A�L_ I U 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 10000 m/z 177: Norhopanes 9000 - 8000 - 7000 - • -o 6000 a • 5000 - a g 4000 - C) CD 3000 - 2000 - 1000 - 0 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 3500 m/z 205 3000 - 2500 - d - 15 2000 - to 1500 - CD CD 1000 - 500 Jl 1wA1,.11AlY 0 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) Humble Geochemical Services Division • 218 Higgins Street Humble, TX 77338 Humble Geochemical Services a�M'Ai O. BOX 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07- 4547 - 194032 Country: Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker Interpretive Ratios Interpretive By By Ratios Area Height Naphthalenes DNR- 1= (2,6 +2,7)/(1,5)DMN 1.98 2.00 DNR- 2 =(2,6 +2,7)/(1,4 +2,3)DMN 1.60 1.88 TNR1= (2,3,6)/(1,4,6 +1,3,5)TMN 0.83 0.79 TDE -1= 1,2,5 -TMN /1,2,4 -TMN 2.67 2.06 TDE -1= 1,2,7 -TMN /1,2,6 -TMN 0.61 0.44 Phenanthrenes MPI- 2= 3(2MP) /(PHEN +1MP +9MP) 1.24 1.19 MPI- 1= 1.5(2MP +3MP) /(PHEN +1MP +9MP) 0.98 0.97 S Rc(a)= 0.6(MPI -1) +0.37 (for Ro <1.3) 0.96 0.95 Rc(b)= 0.6(MPI- 1) +2.3 (for Ro >1.3) 2.89 2.88 MDR=4MDBT/1MDBT 1.29 1.34 Rm= 0. 40+ 0. 30(MDR)- 0.094(MDR) +0.011(MDR) 0.65 0.66 MDR23= 23MDBT /DBT 1.10 1.13 MDR1 =1MDBT /DBT 0.77 1.00 DBT /Phenanthrene 0.16 0.16 Triaromatic Steroids TAS 20 +21/all TAS 0.11 0.14 TAS 20/20 +27 0.04 0.05 TAS 21/21 +28 0.26 0.33 TAS C28/C26 20S 5.88 4.54 TAS C28/C27 20R 0.63 0.92 % 26 TAS 3.5 4.0 % 27 TAS 50.4 52.3 % 28 TAS 37.0 36.1 % 29 TAS 9.1 7.6 Monoaromatic Steroids MAS Dia/Reg C27 #DIV /0! #DIV /0! MAS 21 +22/all MAS 1.00 1.00 % 27 MA #DIV /0! #DIV /0! % 28 MA #DIV /0! #DIV /0! 29 MA #DIV /0! #DIV /0! TAS /(TAS +MAS) 0.93 0.91 TAS28 /(TA28 +MA29) 1.00 1.00 S Humble Geochemical Services Division • L 218 Higgins Street Humble, TX 77338 T 1, Humble Geochemical Services P. O. Box 789 Humble, TX 77347 4 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax. 281 - 540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07 -4547- 194032 Country: Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker Integration Results (Naphthenes, Dibenzothiophene, Phenanthrenes) Ion ( Peak 1 Compound R.Time I Peak I ppm I Peak I ppm i Label Name (min.) Area (A.) Height (Ht.) 128 NAPH !Naphthalene 0.00 : 01 0.0: 0: 0.0 142 2MN 12_Methylnaphthalene 18.37 397! 0.7� 78• 0.4 142 1MN 11- Methylnaphthalene + 18.89 244T 0.5; 87 0.4 156 2EN I2- Ethylnaphthalene I 0.00 01 _ _ 0.0; 0 0.0 156 1EN 11- Ethylnaphthalene 0.00 01 0.0 0. 0.0 156 26DMN 2,6- Dimethylnaphthalene 22.31 193 0.4 65 0.3 156 27DMN !2,7- Dimethylnaphthalene 22.36 210 _ 0.4 841 0.4 156 13 +17DMN 11,3 & 1,7- Dimethylnaphthalenes 22.80 757; 1.4 182, 0.9 156 16DMN _ 11,6- Dimethylnaphthalene 22.92 460 _ 0.& 126, 0.6 156 23DMN 2,3- Dimethylnaphthalene 7 23.42 82 j 0.21 26 0.1 156 -14DMN 1,4- Dimethylnaphthalene 1 23.47 170; 0.31 53. 0.3 156 15DMN 11_5- Dimethylnaphthalene _ 23.54 2041 _ 0.4! 74• 0.4 • 156 12DMN 04 170 AB EMN E t D I ! meth I- Naphthalene 26.34 147: _ 0.3; y I 23.96 158 170 BB EMN Ethyl - methyl- N�hthalene 25.81 304; _ 0.6 47, 66 0.2 _ 0.3 y y 0.3 43 0.2 170 137TMN 1,3,7 - Trimethylnaphthalene 26.53 577 1.11 162 _ 0.8 170 136TMN 11,3,6- Trimethylnaphthalene 26.72 858 1.61 232: 1.2 170 146 +135T 1(1,4,6 +1,3,5)- Trimethylnaphthalenes _' 27.20 8461 1.61 211, 1.1 170 236TMN 12,3,6- Trimethylnaphthalene 27.37 6981 _ 1.31 _ 167, 0.8 170 127TMN 11,2,7- Trimethylnaphthalene _27.70 2841 0.51 65 _ 0.3 170 167 +126T i( 1, 6.7 +1,2,6)_Trimethylnaphthalenes 27.78 4651 0.91 148 0.7 170 124TMN 11,2,4 - Trimethylnaphthalene 28.26 129' 0.21 _ 46 _ 0.2 170 125TMN 1,2,5- Trimethylnaphthalene 28.51 346 0.61 95 0.5 184 1357 1,3,5,7- Tetramet ylnaphthalene 30.61 8521 1.6 277 1.4 184 1367 1,3,6,7 - Tetramethylnaphtalene 31.33 7031 13 213. 1.1 184 1247 _ ;(1, 2,4,7 +1,2,4,6 +1,4,6,7)- TetraMNs 31.79 2 11 21 3.9 677. 3.4 184 1257 11,2,5,7- Tetramethylnaphthalene 1 31.91 1091' 2.0� 323 1.6 184 2367 12,3,6,7- Tetramethylnaphthalene 32.17 210' 0.41 61. 0.3 184 1267 _ _ 11,2,6,7 - Tetramethylnaphthalene 32.43 483 0.9 179' 0.9 184 1237 11,2,3,7- Tetramethylnaphthalene I 32.55 295 0.5 115 0.6 184 1236 11,2,3,6- Tetramethylnaphthalene 32.74 2267. 4.2 631 3.2 184 1256 11,2,5,6 - Tetramethylnaphtalene 33.20 1141 2.1 351. 1.8 ! 1 , 184 DBT Dibenzothiophene 33.44 2254 4.21 505 2.5 198 4MDBT 14 Methyl Dibenzothiophene _ 36.49 _ 2235 4.11 676' 3.4 198 2 +3MDBT 0 _ 2486 4.6i _ __572. 2 & 3 Methyl Dibenzothiophenes 37.1 2.9 198 1MDBT 1 1 Methyl Dibenzothiophene __ I 37.62 17301 3.21 506 _ 2.5 1 154 BP ;Biphenyl 0.00 _ _ 0 _0.01 0 _ 0 168 2MBP '2- Methylbiphenyl 22.01 75 0.1' 29' 0.1 168 DPM Diphenylmethane _ 22.88 66; 0.1 33 0.2 ' 168 3MBP 3- Methylbiphenyl 24.97 629 1.24 114 0.6 168 4MBP ;4- Methylbiphenyl _- a 25.30 28 0.5! 56' 0.3 168 DBF 1Dibenzofuran 1 26.03 129; 0.2 _ 33 0.2 178 PHEN IPhenanthrene 7 34.28 13894 25.6! 3246 16.2 192 3MP 13- Methylphenanthrene ! 37.75 _ 54571 10.1; 1295 _ _ 6.5 192 2MP 2- Methylphenanthrene 1 37.90 9204' 17.0 2037 10.2 192 9MP i 9- Methylphenanthrene _ 38.40 4588 8.5 969• 4.8 ' • 192 IMP i1- Methylphenanthrene 1 38.54 3846 7.1, 930 4.6 Humble Geochemical Services Division • 218 Higgins Street Humble, TX 77338 Iji" 01. 1 Humble Geochemical Services P. O. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07- 4547 - 194032 Country: 0 Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker Integration Results (Dimethyl - Phenanthrenes, Benzohopanes, Triaromatic Steroids, Monoaromatic Steroids) Ion Peak I Compound R.Time Peak ppm Peak ppm Label Name (min.) Area (A.) Height (Ht.) 22 09; - 206 36DMP 3,6- Dimethylphenanthrene 40.96 I 4.1 694' 3 5 206 .26DMP 2,6-Dimethylphenanthrene 1 41.17 3466 6.4 . , 1062 5.3 206 27DMP 2,7- Dimethylphenanthrene 41.27 3173 5.9 815 4.1 206 a 39DMP (3,9 +3,10+ 2,10 +1,3) - Dimethylphenanthrenes 41.65 _ 14443 26.6! 4127' 20.6 206 29DMP (2,9 +1,6)- Dimethylphenanthrenes 41.80 L 4601' 8.5 1091 5.4 206 17DMP 1,7- Dimethylphenanthrene 41.99 14083' 2 32581 - 16.3 206 23DMP 2,3- Dimethylphenanthrene a 42.15 2869 5.3. 6671 3.3 206 19DMP 1,9- Dimethylphenanthrene 42.29 J_ 3564 6.6: 875' 4.4 • 206 18DMP 1,8- Dimethylphenanthrene 42.63 1816 3.3 470 2.3 206 12DMP 1,2- Dimethylphenanthrene 43.03 1833' 3.4 525' 2.6 191 BH32 C32 Benzohopane 24045: 22.2 75.95 237071 43.7 45 5 33 191 BH33 C33 Benzohopane 74.59 24045: 44.3 5188 25.9 191 .BH34 C34 Benzohopane � i � 22.6 I 191 BH35 C35 Benzohopane 77.60 3001 5.51 530 1 2 6 231 1TA20 1 C20 Triaromatic Steroid 51.58 12031 2.2, 410 2.0 231 ' 2TA21 C21 Triaromatic 53.12 66081 12.2 1 9.0 231 3TA26 C26 20S Triaromatic 61.75 22791 4.2 563 2.8 231 . 4TA26 +27 : C27 20S & C26 20R Triaromatic 63.11 160901 29.7' 4616': 23.1 231 5TA28 C28 20S Triaromatic . 64.26 134021 24.7 2555 12.8 231 .6TA27 C27 20R Triaromatic 64.81 16386 ( 30.2 2776 13.9 231 7TA28 C28 20R Triaromatic 66.21 ] 104001 19.21 - 2544 12.7 P PY { . 1073 5 4 231 8TA29 C29 20R Triaromatic 24 n- ro I) 67 84 5844 1 253 ' 1MA21 C21 Ri -C Monoaromatic Steroid 47.06 4242 7.8 .8: 13861 6.9 253 2MA22 C22 Monoaromatic steroid I - - 0 253 3MA27 C27 Reg 5b(H),10b(CH3) 20S 0.00 OF 0.0 0' 0.0 253 .4MA27 ,C27 Dia 10b(H),5b(CH3) 20S y 0.00 E 0] 0.01 0. 0.0 253 1 5MA27 C27 Dia10bH,5bCH3 20R +Reg5bH,10bCH3 20R 0.00 0 0.0 0', 0.0 -- - - --- -- - -- - -- -- -- -- - - - - -- - 253 8MA27 C27 Reg 5a(H),10b(CH3) 20R 0.00 O 0.0: 0 253 6MA27 C27 Reg 5a(H),10b(CH3) 20S 0.00 0 0.0 0 0.0 1 253 7MA28 C28 Dia 10aH { ,5aCH3 20s +Reg5bH,10bCH3 20S 0.00 0 0.0 0' 0.0 0.0 253 : 9MA28 C28 Reg 5a(H),10b(CH3) 20S 0.00 0 0.0 0 0.0 253 10MA28 C28 Dia 10aH,5aCH3 20R +Reg5bH,10bCH3 20R 0.00 0, 0.01 _ 0 0.0 253 11MA29 C29 Dia 10bH,5bCH3 20S +Reg5bH,10bCH3 20S � 0.00 i OF 0.0; 0 0.0 253 12MA29 C29 Reg 5a(H),10b(CH3) 20S 0.00 01 0.0: 0' 0.0 253 13MA28 C28 Reg 5a(H),10b(CH3) 20R 0.00 I 01 0.0' 0 0.0 253 14MA29 C29 Dia 10bH,5bCH3 20R +Reg5bH,10bCH3 20R j 0.00 0 0.0; 01, 0.0 253 a15MA29 C29 Reg 5a(H),10b(CH3) 20R 0.00 0 0.0 0 0.0 230 OTP Ortho- terphenyl (Inter. STD) i 37.47 ; 102128 188.4 r 37712! 188.4 Humble Geochemical Services Division • Humble Geochemical Services 218 Higgins Street Humble, TX 77338 NUM ,. P. 0. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 194032 Ion Chromatoarams 1200 m/z 156: Dimethylnaphthalenes 1000 - tj 800 - a 600 - I I I 1 f 400 - I jbA, ) 1 1 +n�`'� ry' 11W� 1 4 1 f \'' 200 - U"' 0 r r r m Retenton Time in. 20 24 28 32 36 (Min.) 40 4000 m/z 170: Trimethylnaphthalenes 3500- 3000 - 8 2500 - R 2000 - H 1500 - t 1000 - �+ 1 • gp! a a � � p 500 - a te' N . v 0 w 20 24 28 32 36 Retention Time (min.) 40 900 m/z 184: Tetramethylnaphthalenes 800 800 - m 700 - I o 3 600 - 500 - ti 5' G 400 - 1 1 I \i\j' c 200 - , I ��'IuIM� fin`, 'f 200 - t N ,A q1 ^ 1 ^� V1' tl' 1 0 20 24 28 32 36 Retention Time (min.) 40 1200 m/z 198: Pentamethylnaphthalenes 1000- 800 - I 1 rA 1 a 600 - 1 m M I n 466 - 200- , ^ A,h J „ I , 0 � �fl �, � ,t,� ,yWW• �.✓ ' "' WII, UJ}��JU 4h'1 IJ��NU 20 24 28 32 36 Retention Time (min.) 40 0 Humble Geochemical Services Division --� Humble Geochemical Services 218 Higgins Street Humble, TX 77338 P. O. Box 789 Humble, TX 77347 ' " Telephone: 281 -540 6050 Fax: 281 -540 2864 ii --.� D ivi s ion of Humble Instruments & Services, Inc. Client: Talisman Energy Client ID: Key Aromatic GC -MS I HGS ID: 07-4547494032 I Ion Chromatoarams 40000 a m/z 230: Ortho- Terphenyl (Inter. Std) 35000 - I 30000 - c 25000 - a 2 20000 - 5 8 15000 - 10000 - 5000 - 42 0 32 34 36 38 40 Retention Time (min.) 100 m/z 154: Biphenyl' s0- 1 I BO - I 1 I 70- I I � V I �A I` 11 \(k 1 � • m 60- V n I L r 4 'l I V� \1 ' M 2 50 N 40- to CD 30 - 20 - 10- 28 0 18 20 22 24 26 Retention Time (min.) 180 A /z 168: Methylbiphenyls (MBP) 1 160 - 140 - 20 - d o - LL S- 1 \ \i), c 100- � o L N w 60 i V I 1 , 2 A\ IV,VI'f U 8 60- 40 - 20 - 28 0 18 PO 22 24 26 Retention Time (min.) Humble Geochemical Services Division • I '"- 1 Humble Geochemical Services 218 Higgins Street Humble, TX 77338 { v-srA P. 0. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 194032 Ion Chromatograms 35000 m/z 178: Phenanthrene 30000 - 25000 - w c . 20000 - a f 15000 - o 0 10000 - 5000 - a p p I L 31 33 35 37 39 41 43 45 Retention Time (min.) 12000 m/z 192: Methylphenanthrenes 10000 - • 6000 - c a 6000 - a Co U (7 4000 - 2000 pp m� V 31 33 35 37 39 41 43 45 Retention Time (min.) 35000 m/z 206: Dimethylphenanthrenes 30000 - 25000 - c 20000 - c a 1 15000 - U 10000 - a D g 5000 - a n 31 33 35 37 39 41 43 45 Retention Time (min.) Humble Geochemical Services Division Humble Geochemical Services 218 Higgins Street Humble, TX 77338 i „uMa. P. O. Box 789 Humble, TX 77347 11V,Abil Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07- 4547 - 194032 Ion Chromatoarams 10000 m/z 191: Benzohopanes 9000 - 8000 - 7000 - 6000 w 9 a 5000 - a U 4000 - f7 � 3000 - 2000 - „ /� , /'\ n., '^� ° 1000 - 0 70 72 74 76 78 80 Retention Time (min.) 30000 m/z 231: Triaromatic Steranes 25000 - • 20000 2 15000 - a N U (0 10000 - 5000 - � N a 48 52 56 60 64 68 Retention Time (min.) 6000 m/z 253: Monoaromatic Steranes 5000 4000 2 3000 N 2000 AAA IIq� ^ , 1N 1000 f a I 4 �' '` "s V ✓' W 0 42 46 50 54 58 Retention Time (min.) Humble Geochemical Services Division • • G Extract FID1 A, (G: \1 \DATA )07 - 4547 \E194033A.D) pA 14- 12- c U r- 10 - 5 U N - 8 - U U w d c 6 5 I ' ih ,l,p,i Il'11huVJUii 4 2- 2 30 40 50 60 70 80 ll 0 90 mi H umble Geochemical 218 cal Services Higgins eet Humble, TX 77338 • P. O. Box 789 Str Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 Client: Talisman Energy Client ID: Saturate Biomarker Interpretive Ratios HGS ID: 07- 4547 - 194033 Well: Aklaq #6 Interpretive By By Depth: Ratios Area Height Field: Lease Terpanes (m /z 191) Formation: C19t/C23t 0.23 0.22 Basin: C22t/C21t 0.09 0.09 County,State: AK C22t/C24t 0.41 0.43 Country: C24t/C23t 0.45 0.43 C26t/C25t 1.51 1.41 Bulk Properties C24Tet/C23t 0.91 0.87 P C24Tet/C26t 1.68 1.76 C23t/C3OH 0.03 0.03 API ( °) C24Tet/C3OH 0.03 0.03 S ( %) C28BNH /C3OH 0.02 0.01 Saturate ( %) 25- Nor /C3OH 0.00 0.00 Aromatics ( %) C29H /C30H 0.62 0.63 Resin ( %) C30DiaH /C3OH 0.00 0.00 Asphaltene ( %) Ole /C3OH 0.01 0.01 a' Sat ( %o) C30Ts /C30H 0.01 0.01 S Aro ( %o) Gam /C30H 0.25 0.27 513C Res ( %o) Gam /C31 H R 2.39 2.30 S' Asp ( %o) C35HS /C34HS 0.62 0.48 0 ti"C Oil ( %o) C35 Homohopane Index Ts /(Ts +Tm) 0.06 0.03 Whole Oil /Extract GC C29T 0.02 0.02 s /(C29Ts +C29H) 0.01 0.01 Mor /C3OH 0.26 0.25 CPI C32 S /(S +R) 0.55 0.56 Pristane /n -C17 Phytane /n -C18 Steranes (m /z 217) Pristane /Phytane % C27 aaa 20R 6.5 8.8 % C28 aaa 20R 55.8 49.8 % C29 aaa 20R 37.6 41.4 C 27 -C 28 -C 29 C27 Dia /(Dia +Reg) 0.00 0.00 x1313 Steranes (C21 +C22)/(C27 +C28 +C29) 0.00 0.00 c29 I c27 C29 aR13 /(aaa +aR13) 0.20 0.18 C29 aaa 20S /20R 0.37 0.31 C29 aaa 20S /(S +R) 0.27 0.24 c28 aiiii- Steranes (m /z 218) C27 app 20(R +S) 7.3 7.9 % C28 433 20(R +S) 52.0 52.5 % C29 x4313 20(R +S) 40.8 39.6 Tricyc C29/C27 413 Sterane Ratio 5.62 5.05 St. Tricyclic /Pentacyclic Terpanes 0.09 0.10 Steranes /Terpanes 0.26 0.21 Tricyclic, % Tricyclic Terpanes 6.5 7.7 Pentacyc Pentacyclic /° ° Terpanes & % Pentacyclic Terpanes 72.8 74.7 Steranes Steranes 20.6 17.7 • Humble Geochemical Services Division • ►° Humble Geochemical Servi 21 8 Higgins Street Humble, TX 77338 • P. O. Box 789 Humble, TX 77347 Mu hae` � Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07 -4547- 194033 Country: Saturate Biomarker Integration Well: Aklaq #6 Depth: Field: Lease Formation: R esults (Steranes) • Ion I Peak Compound R.Time Peak ppm Peak ppm L abel 1 Name (min.) I Area ( (A.) I Height I (Ht.) L - 217 'S21 1C21 sterane 47.03 703 54.1 248' 48.9 -- -- - -- - -- - - -- -- - - - - - 217 :S22 C22 sterane 49.75 375 28.9; 13T 27.0 217 !27DbaS �C27 ba 20S diacholestane 0.00 0: 0.0' 0 0.0 217 :27DbaR C27 ba 20R diacholestane 0.00 0 0.0; 0 0.0 217 128DbaSA 1C28 ba 20S diasterane a 0.00 0 0.0: 0 0 217 :28DbaSB iC28 ba 20S diasterane b 0.00 0 0.0 0 0.0 217 .28DbaRA C28 ba 20R diasterane a 0.00 0 0.0 0 0.0 217 28DbaRB ;C28 ba 20R diasterane b 0.00 0 0.0, 0 0.0 217 :27aaS ;C27 aa 20S cholestane 60.26 7567 582.7 24121 475.6 217 27bbR 1C27 bb 20R cholestane 60.41 2906 223.8' 790, 155.8 217 :27bbS 1C27 bb 20S cholestane 60.56 1626: 125.2: 547 107.8 217 27aaR C27 as 20R cholestane 61.07 15118 1164.2 5272: 1039.5 217 :28aaS 1C28 aa 20S ergostane 62.16 17080' 1315.3' 5797: 1143.0 .............. _... 217 :28bbR iC28 bb 20R ergostane 62.41 22027 1696.3 6638 1308.9 217 28bbS 'C28 bb 20S ergostane 62.56 11006 847.5 4096: 807.5 217 •28aaR C28 aa 20R ergostane 63.19 128991 9933.31 29812 5878.0 217 29aaS ,C29 aa 20S stigmastane 63.74 32371 2492.8 7637; 1505.8 217 29bbR C29 bb 20R stigmastane 64.05 11658 897.7 2998 591.1 217 1 29bbS C29 bb 20S stigmastane 64.14 18933 1458.0: 3938 776.4 -- - -- - - -- - -- - - -- - - -- --- - - -- - - -- 217 29aaR ,C29 aa 20R stigmastane 64.89 86982 6698.3 24758 4881.5 218 .27bbR , C27 bb 20R cholestane 60.41 3475: 267.6' 984' 194.0 218 ; 27bbS 1 C27 bb 20S cholestane 60.56 1683 129.6 699': 137.9 218 I28bbR ;C28 bb 20R ergostane 62.42 21995 1693.8: 5913; 1165.9 218 .28bbS 1 C28 bb 20S ergostane 62.56 14952 1151.5 5347: 1054.2 218 29bbR 1C29 bb 20R stigmastane 64.05 14659 1128.9` 3860 761.1 218 129bbS 1C29 bb 20S stigmastane 64.15 14315' 1102.4; 4638' 914.4 259 •27DbaS 1C27 ba 20S diacholestane 0.00 0: 0.0: 0' 0.0 259 27DbaR IC27 ba 20R diacholestane 0.00 0 0.0 0', 0.0 259 .28DbaSA 1C28 ba 20S diaergostane a 0.00 0 0.0 0 0.0 259 28DbaSB C28 ba 20S diaergostane b 0.00 0 0.0 0: 0.0 259 28DbaRA 1C28 ba 20R diaergostane a 0.00 0 0.0 0 0.0 259 28DbaRB 1C28 ba 20R diaergostane b 0.00 0 0.0: 0 0.0 259 29DbaS C29 ba 20S diastigmastane 60.42 844 65 0. 208 41.1 259 :29DbaR ,C29 ba 20R diastigmastane 61.64 1200 92.4 380 75.0 259 30TP1 1C30 Terpane 65.74 3622 278.9 1083 213.5 259 :30TP2 IC30 Terpane 65.82 2887, 222 3! 937 184.7 217 b-Cholane 5b cholane (inter. STD) ' 54.13 1308 100.8 511: 100.8 218 :b- Cholane 15b cholane (inter. STD) ; 54.13 642 100.8 230 100.8 Humble Geochemical Services Division 218 Higgins Street Humble, TX 77338 Humble Geochemical Services P. O. Box 789 Humble, TX 77347 • k......s'i lit Division of Humble Instruments & Services, Inc. Telephone: 281-540 6050 Fax: 281-540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07-4547-194033 Country: Well: Aklaq #6 Depth: Field: Lease Formation: Saturate Biomarker Integration Results (Terpanes) Ion I Peak I Compound I R.Time Peak I ppm I Peak 1 ppm Label Name I (min.) Area I, (A.) I Height (Ht.) . , 125 1BCRT b-carotane 191 C19t :C19 tricyclic diterpane : 40.05 28291 217.9 . 10271 202.4 191 I C20t . C20 tricyclic diterpane : 42.33 325781 2508.7 12310_ 2427.2 . 191 1 :C21 tricyclic diterpane ' : 44.66 24242 1866.8 93041 1834.4 191 I C22t 'C22 tricyclic terpane . 46.79 2302, 177.3 8621 169.9 191 1C23t :C23 tricyclic terpane 49.20 _ 12461 959.6 46821 923.1 : I 191 !C24t :C24 tricyclic terpane 50.52 55481 427.2 20101 396.3 . 191 C25tS ;C25 tricyclic terpane (S) 53.09 20561 158.3! 7 145.0 191 ,C25tR ,C25 tricyclic terpane (R) ' 53.16 2407, 185.4. 8961 176.8 191 1C24T 'C24 tetracyclic terpane (TET) 54.68 112971 : 4060 800.4 869.9 1 191 1C26tS :C26 tricyclic terpane (S) 54.96 3503! 269.8 1118t 220.5 191 C26tR :C26 tricyclic terpane (R) 55.13 3223 248.2 118 233.8 ! - . • 191 C28tS ,C28 extended tricyclic terpane (S) , 59.11 3042 191 1C28tR C28 extended tricyclic terpane (R) 59.41 191 1C29tS ,C29 extended tricyclic terpane (S) ' 60.32 1672 128.7: 638 125.9 11841 234.2' 91.2! 6221 398 122.7 78.4 191 IC29tR !C29 extended tricyclic terpane (R) 60.68 1576 121.3 - 3 - - - 8 - 4 - - 1 75.7 .4 191 1 C3OtS - C30 extended tricyclic terpane (S) ' 62.56 1 2083: 634! 125A 191 1C30tR : C30 extended tricyclic terpane (R) 1 62.92 1109 85.41 476 93.8 191 1Ts Ts 18a(H)-trisnorhopane . 61.48 1422; 109.5 463 91.3 191 1Tm :Tm 17a(H)-trisnorhopane : 62.22 738711 5688.6: 26168 5159.4 4 191 'C28BNH . C28 17a18a21b(H)-bisnorhoPane 64.06 7048 . 542.7! 17751 349.9 191 Nor25H !C29 Nor-25-hopane ' 64.42 j 15191 117.0' 507 100.0 191 Lc29H ,C29 Tm 17a(H)21b(H)-norhopane . 64.90 272151: 20957.7' 85387, 1 - 16835.5 191 1C29Ts 'C29 Ts 18a(H)-norneohopane 1 64.9 2299 . 177.1 9391 185.1 . , : 191 'C30DiaH C30 17a(H)-diahopane 1 ' 65.30 9541 73.5, 288 56.9 191 iNormor C29 normoretane 65.75 32722 . 1 2519 9 108141 2132.1 ; 191 la-Ole , a-oleanane . 66.24 3477, 9791 267.7, 193.0 191 lb-Ole . b-oleanane : 66.31 13441 103.5 ---- ife§i 92.5 191 . C30H 'C30 17a(H)-hopane ! 66.50 438642_1 33778.8! 136103 26835.0 1911C30Ts :17a(H)-30-nor-29-homohopane : 66.81 2894 I 222.9: 723, 142.6 191 I Mor :C30 moretane 1 67.16 112476 , 8661.5: 346941 6840.4 191 1C31HS C31 22S 17a(H) homohopane • 68.28 601101 4628.9 ' 203801 4018.3 191 IC31HR C31 22R 17a(H) homohopane ' 68.50 461581 3554.5 16031: 3160.8 191 : 68.70 . am :gammacerane • 68 110358! 8498.4 368371 7263.0 191 C32HS C32225 17a(H) bishomohopane : 69.68 223881 1724.1 7934 I 1564.4 191 C32HR 'C32 22R 17a(H) bishomohopane : 69.98 18044 1389.5: 63611 1254.2 . . 191 C33HS ,C33 22S 17a(H) trishomohopane , 71.33 1 150741 1160.8' 5111 1007.7 191 1C33HR !C33 22R 17a(H) trishomohopane 71.77 12305' 9476: 38771 764.3 • : 191_C34HS .C34 22S 17a(H) extended hopane . 73.24 T 8282 637.7 22851 450.6 191 1C34HR :C34 22R 17a(H) extended hopane • 73.85 6413 493.9' 16821 331.7 : 191 1C35HS 'C35 22S 17a(H) extended hopane ' 75.40 5150 396.6 11031 217.6 _ 191 ,C35HR C35 22R 17a(H) extended hopane 76.27 6814 524.8: 12051 237.6 1 ' . 1 I • ' . • 1 • Humble Geochemical Services Division • HHumble Geochemical Services 218 Higgins Street Humble, TX 77338 1WM P. 0. Box 789 Humble, TX 77347 or" Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Saturate GC -MS HGS ID: 07 -4547- 194033 Ion Chromatograms 35000 m/z 217: Steranes N 30000 - i 2 m V c 5000 m c 20000 - a a to 15000 - 0 0 10000 - "' 1 5000 - - 4 I 0 44 48 52 56 60 64 68 Retention Time (min.) 18000 m/z 218: Steranes 16000 - 14000 - • g 12000 - m c 10000 - 0 a y 8000 - 0 0 6000 - i 4000 - R 2000 - 2 o - ,,k , ,, , • - — --A...AA-AU I .A....,.,.____,_—__A_____ 44 48 52 56 60 64 68 Retention Time (min.) 3000 m/z 259: Diasteranes 2500 - g 2000 - iii a c I 1 5 0 0 - 1 0 0 0 - 4 8 co 52 56 60 64 68 Retention Time (min.) il Humble Geochemical Services Division • 11 Humble Geochemical Services 218 Higgins Street Humble, TX 77338 P. 0. Box 789 Humble, TX 77347 ■ff Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Saturate GC -MS HGS ID: 07 -4547- 194033 Ion Chromatoarams 160000 m/z 191: Tri -, tetra- and pentacyclic Terpanes 140000 - 120000 d • 100000 - a a • 80000 - 0, V 60000 - C7 40000 - E _ 20000 - s N m F m U U U U 0 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 40000 m/z 177: Norhopanes 35000 - 30000 - • 25000 - c 2 20000 - N V 15000 - 0 10000 - 5000 - o ^ ). a _ w 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 14000 m/z 205 12000 - 10000 - V c m c 8000 to 6000 - 4000 - 2000 - lil 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) • Humble Geochemical Services Division 0 218 Higgins Street Humble, TX 77338 "" Humble Geochemical Services P. O. Box 789 Humble, TX 77347 '11 , I Telephone: 281 -540 6050 Fax: 281 -540 2864 R' Division of Humble Instruments & Services, Inc. Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07- 4547- 194033 Country: Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker Interpretive Ratios Interpretive By By Ratios Area Height Naphthalenes DNR- 1 =(2,6 +2,7)/(1,5)DMN 2.96 1.77 DNR- 2 =(2,6 +2,7)/(1,4 +2,3)DMN 0.84 0.75 TNR1= (2,3,6)/(1,4,6 +1, 3,5)TMN 0.39 0.38 TDE -1= 1,2,5 -TMN /1,2,4 -TMN 7.70 7.42 TDE -1= 1,2,7 -TMN /1,2,6 -TMN 0.38 0.51 Phenanthrenes MPI- 2= 3(2MP) /(PHEN +1 MP +9MP) 1.34 1.59 MPI- 1= 1.5(2MP +3MP) /(PHEN +1 MP +9MP) 0.93 1.07 III Rc(a)= 0.6(MPI -1) +0.37 (for Ro <1.3) 0.93 1.01 Rc(b)= 0.6(MPI- 1) +2.3 (for Ro >1.3) 2.86 2.94 MDR= 4MDBT /1MDBT 0.98 1.00 Rm= 0. 40+ 0. 30(MDR)- 0.094(MDR) +0.011(MDR) 0.61 0.62 MDR23= 23MDBT /DBT 2.56 2.55 MDR1 =IMDBT /DBT 1.83 2.45 DBT /Phenanthrene 0.14 0.15 Triaromatic Steroids TAS 20 +21/all TAS 0.04 0.05 TAS 20/20 +27 0.05 0.06 TAS 21/21 +28 0.03 0.05 TAS C28/C26 20S 9.92 6.52 TAS C28/C27 20R 1.32 1.54 % 26 TAS 2.7 3.4 % 27 TAS 42.2 46.4 % 28 TAS 51.4 46.8 % 29 TAS 3.6 3.3 Monoaromatic Steroids MAS Dia /Reg C27 0.68 0.92 MAS 21 +22/all MAS 0.04 0.04 % 27 MA 9.2 8.5 % 28 MA 34.1 38.0 % 29 MA 56.7 53.5 TAS /(TAS +MAS) 0.80 0.78 TAS28 /(TA28 +MA29) 0.89 0.87 III Humble Geochemical Services Division s • 218 Higgins Street Humble, TX 77338 Humble Geochemical Services P. O. Box 789 Humble, TX 77347 Ir Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07- 4547 - 194033 Country: Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker Integration Results (Naphthenes, Dibenzothiophene, Phenanthrenes) Ion I Peak I Compound I R.Time I Peak I ppm I Peak ppm Label Name (min.) Area (A.) Height (Ht.) 128 NAPH ( Naphthalene 0.00 0 0.01 0' 0.0 142 2MN ,2- Methylnaphthalene 18.38 679 0.61 121 0.3 142 1MN !1- Methylnaphthalene 18.91 561 0.5; 165 0.4 156 2EN 2- Ethylnaphthalene 21.89 3341 0.31 97 0.2 156 -1EN 1-Ethylnaphthalene 21.96 _ 234 0.2 101 0.2 156 26DMN 2,6- Dimethylnaphthalene 22.31 9522 8.1 2697 6.1 156 27DMN 12,7- Dimethylnaphthalene 22.36 4377 3.7 1886 4.3 156 13 +17DMN 11,3 & 1,7- Dimethylnaphthalenes 22.81 9671 8.2 3201 7.3 156 16DMN 11,6- Dimethylnaphthalene 22.93 47683; 40.4 14737 33.5 156 23DMN 12,3- Dimethylnaphthalene 23.47 30481 2.6 1181 _ _ 2.7 156 14DMN i1,4_Dimethylnaphthalene 23.50 135961 11.5 4958 11.3 156 15DMN 1 1,5 - Dimethylnaphthalene 23.54 46891 _ 4.01 2592 5.9 • 156 12DMN 11,2- Dimethylnaphthalene 23.98 5630 _ 4.81 1784 4.1 170 BB EMN Ethyl - methyl - Naphthalene 25.82 55461 4.7 1402 3.2 170 AB_EMN Eth I- methyl - Naphthalene 26.36 4203 3.6 1400 3.2 170 137TMN 1,3,7- Trimeth Ina.hthalene 26.55 1 34346 29.11 12779 29.0 170 136TMN 1,3,6 - Trimethylnaphthalene 26.74 153150, _ 129.71 56197 127.7 170 146+135T 1,4,6 +1,3,5)- Trimethylnaphthalenes 27.24 1187941 100.6 41835 _ 95.1 170 236TMN 12,3,6- Trimethylnaphthalene j 27.37 46427 39.3: 15809' 35.9 170 127TMN 11,2,7- Trimethylnaphthalene 1 27.73 331881 28.11 10744 24.4 170 167 +126T x(1,6,7 +1,2,6)- Trimethylnaphthalenes 2T84 87548] 74.21 20961 _ 47.6 170 124TMN 1,2,4- Trimethylnaphthalene 28.29 4545 - 3.9] 1674. 3.8 170 125TMN ,1,2,5- Trimethylnaphthalene 28.53 34988 29.6 12421' 28.2 184 1357 1,3,5,7- Tetramethylnaphthalene 30.65 ' 30078, 25.5 6643. 15.1 184 •1367 1,3,6,7- Tetramethylnaphthalene 31.37 307611 26.1 10257. 23.3 184 1247 1(1 ,2,4,7 +1,2,4,6 +1,4,6,7) - TetraMNs 31.84 _ 681131 57.7 22685: _ 51.5 184 1257 11,2,5,7- Tetramethylnaphthalene 31.96 390211 33.1 13428; 30.5 184 2367 12,3,6,7- Tetramethylnaphthalene 1 32.20 6901; 5.8 2252 5.1 184 1267 11,2,6,7- Tetramethylnaphthalene 1 32.48 204271 17.3 _ 7097. 16.1 184 1237 1,2,3,7- Tetramethylnaphthalene 1 32.60 15736 13.31 5208: 11.8 184 1236 1,2,3,6- Tetramethylnaphthalene 32.80 150090 _ 127.1 47769. _ 108.5 184 1256 _1,2,5,6- Tetramethylnaphthalene 33.25 29208 24.7 10482• 23.8 184 DBT Dibenzothiophene 33.49 6025 5.1 1593, 3.6 198 4MDBT 4 Methyl Dibenzothiophene _ 36.40 108411 9.21 3904 8.9 198 .2 +3MDBT 2 & 3 Methyl Dibenzothiophenes 1 37.14 154321 13.1 4059_ 9.2 198 1MDBT ,1 Methyl Dibenzothiophene 7 37.76 _ 110341 1 3902' 8.9 1 9.31 154 .BP 'Biphenyl 21.26 561 _ 0.5 131 _ 0.3 168 2MBP 2 -Meth (biphenyl 0.00 0 0.0 0' 0.0 168 DPM Di henylmethane 0.00 0 0.01 0' 0.0 168 3MBP 3- Methylbiphenyl 24.98 2323 2.0 529 1.2 168 4MBP 4- Methylbiphenyl 7 25.30 1002; 0.8 213. 0.5 168 DBF _ 1Dibenzofuran _ 26.03 910+ 0.8 164: 0.4 1 178 PHEN 1 Phenanthrene 34.32 44047] 37.31 10854 24.7 192 3MP 1 3- Methylphenanthrene _ 37.81 19676 _ 16.7 5087, _ 11.6 y Iphenanthrene 37.96 50499 42.8 14776' 33.6 192 2MP 2 -Meth 6 192 9MP ( 9- Methylphenanthrene 38.47 44159 37.4- 10552 24.0 • 192 -1MP 1- Methylphenanthrene 38.61 24768. 21.01 6556. 14.9 Humble Geochemical Services Division • , 218 Higgins Street Humble, TX 77338 IMp Humble Geochemical Services P. O. Box 789 Humble, TX 77347 is Telephone: 281 -540 6050 Fax: 281 -540 2864 Division of Humble Instruments & Services, Inc. Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07- 4547 - 194033 Country: 0 Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker Integration Results (Dimethyl- Phenanthrenes, Benzohopanes, Triaromatic Steroids, Monoaromatic Steroids) Ion I Peak I Compound R.Time I Peak ppm Peak I ppm Label Name (min.) Area (A.) Height (Ht.) 206 36DMP 3,6- Dimethylphenanthrene 41.03 20985 17.81 62291 14.2 206 26DMP 2,6- Dimethylphenanthrene ( 41.24 17668 15.0 5399 12.3 206 270MP •2,7- Dimethylphenanthrene _ 11 41.35 23699 20.1 6490 14.7 206 39DMP (3,9 +3,10+ 2,10 +1,3) - Dimethylphenanthrenes 1 41.73 167170 141.6 44061' _ 100.1 206 29DMP (2,9 +1,6)- Dimethylphenanthrenes _ _ 41.85 481671 40.84 146721 33.3 206 17DMP 1,7- Dimethylphenanthrene 1 42.03 1085931 92.0 32673 74.2 206.23DMP a 2,3- Dimethylphenanthrene a 42.25 ' 143121 12.11 32161 7.3 206 19DMP 1,9- Dimethylphenanthrene _ 42.34 t 2383 20.2! 5026 11.4 III 206 I8DMP 1,8- Dimethylphenanthrene i 42.68 10431 ! 8.8' 3262. 7.4 206 12DMP 1,2- Dimethylphenanthrene 43.10 ( 12778 10.8 3166 7.2 191 BH32 C32 Benzohopane 73.14 66923 56.7 161261 36.6 191 BH33 C33 Benzohopane 1 74.74 1 905291 76.7; 17605; 40.0 191 BH34 .C34 Benzohopane 76.11 1 1043491 88.41 172631 39.2 77.86 17424 14.8 1722 191 BH35 C35 Benzohopane 1 3:9 i 231 1TA20 -C20 Triaromatic Steroid 51.67 I 16722' 14.21 52441 11.9 231 2TA21 C21 Triaromatic 53.82 14558 12.3 4269: 9.7 231 3TA26 C26 20S Triaromatic 61.86 22612 19.2 65171 14.8 231 4TA26 +27 027 20S & C26 20R Triaromatic 63.23 1970071 166.91 58283! 132.4 231 5TA28 C28 20S Triaromatic 64.38 2242861 190.01 42477, 96.5 231 6TA27 C27 20R Triaromatic 1 64.93 E 1504151 127.4 303961 69.1 231 7TA28 C28 20R Triaromatic 66.34 I 1991161 168.7! 46908 106.6 231 253 8 ` 129 R ng C Mono a l omat c Ste oid 44.98 'r 2986 2 5 63541 670 14.4 1 1.5 253 2MA22 C22 Monoaromatic steroid 47.05 55601 4.71 1722 3.9 253 3MA27 C27 Reg 5b(H),10b(CH3) 20S 55.85 1 38141 3.21 750 1.7 57 1 2353% 2.01 253 4MA27 C27 Dia 10b(H),5b(CH3) 20S _ 55.68 2587' 2.21 692' 1.6 253.5MA27 C27 Dial ObH ,5bCH320R +Reg5bH,10bCH320R 56.93 41071 3.5: 857' 1.9 253 6MA27 C27 Reg 5a(H),10b(CH3) 20S 1 1.4 253 7MA28 C28 Dia 10aH,5aCH3 20s +Reg5bH,10bCH3 20S 1 57.53 162461 614 13.8! 2892' 6.6 253 48MA27 a C27 _Reg 5a(H),10b(CH3) 20R a a 58.69 5647; 4.8 1612 3.7 253 9MA28 C28 Reg 5a(H),10b(CH3) 20S a 58.80 24076 20.4 8700 19.8 253 10MA28 C28 Dia 10aH,5aCH3 20R +Reg5bH,10bCH3 20R 59.07 12612] 10.7 1 3741 8.5 253 11MA29 C29 Dia 10bH,5bCH3 20S +Reg5bH,10bCH3 20S { 58.97 1 11319. 9.6 31301 7.1 4 253 12MA29 C29 Reg 5a(H),10b(CH3) 20S 60.19 I 339051 28.7; 8491: 19.3 253 13MA28 C28 Reg 5a(H),10b(CH3) 201:2 60.56 t 152851 12.91 49141 11.2 253 14MA29 C29 Dia 10bH,5bCH3 20R +Reg5bH,10bCH3 20R j 60.46 t 47388; 40.11 121761 27.7 253 . 15MA29 . C29 Reg 5a(H),10b(CH3) 20R _1 62.01 208581 17.74 4716 107 • 230 OTP Ortho- terphenyl (Inter. STD) 1 37.51 1331351 112.8 49634, 112.8 Humble Geochemical Services Division • 1i Humble Geochemical Services 218 Higgins Street Humble, TX 77338 4 N0µ , A . P. 0. Box 789 Humble, TX 77347 '!IIII Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 194033 Ion Chromatoarams 16000 o m/z 156: Dimethylnaphthalenes 14000 - 12000 - 10000 - C 6000 - I . in z F, 5 6000 - o i 1 1 1 0 z 4000 - % . ", \,,k �:� . , I 2000 - 6. 20 24 28 32 36 Retention Time (min.) 40 60000 m/z 170: Trimethylnaphthalenes Ft 50000 - g 40000 - 30000 - ' N f tl 20000 - v g{ " I 1 1 • 10000_ NI i n . � ^ 0 ¢ 1 J l.. L MJ �LJI!� ti. Jl.- JVV�`+� .,,11 ,J `^n^, - `^' 20 24 28 32 36 Retention Time (min.) 40 50000 - m/z 184: Tetramethylnaphthalenes 45000 - 40000 - • 35000 - v 30000 - R 25000 - N ✓ 20000 - I 17 15000 - I I 10000 - I — 5000 - 0 20 24 28 28 32 36 Retention Time (min.) 40 14000 m/z 198: Pentamethylnarhthalenes 12000 - 10000 - ee 6000 - o N 6000 v 0 N t an 4000 - ( ^ y 11 }�I�i � ! I 2000 - J 'A N U v i n ce' \ ' )1'✓ \-.A. 0 20 24 28 32 36 Retention Time (mm.) 40 1 10 Humble Geochemical Services Division - -� Humble Geochemical Services 218 Higgins Street Humble, TX 77338 NU M , . ,F P. 0. Box 789 Humble, TX 77347 1 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 074547- 194033 Ion Chromatoarams 50000 P m/z 230: Ortho- Terphenyl (Inter. Std) 45000 - 40000 - 35000 - m 30000 - a • 25000- ¢ 0 U 20000 - (0 15000 - 10000 - s0o0 - 32 34 36 38 40 42 Retention Time (min.) 7000 m/z 1 Biphenyl 6000 - 1 • 5000 - p 4000 - c a 3000 - U (7 2000 - 1000 - A /• f-A v �✓ �, `� �. 0 18 20 22 24 26 28 Retention Time (min.) 800 m/z 168: Methylbiphenyls (MBP) 700 - 600 - c 500 - a 400 - N 8 :::i 0 1 J 100 - 0 18 20 22 24 26 28 Retention Time (min.) Humble Geochemical Services Division 0 -P Humble Geochemical Services 218 Higgins Street Humble, TX 77338 T P. 0. Box 789 Humble, TX 77347 = Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 194033 Ion Chromatoarams 90000 m/z 178: Phenanthrene 80000 - 70000 - d 60000 - i 50000 - .0 1 N 40000 - 2 U U 30000 - 20000 - u � i 0000 - ^� ^ J 0 -A 11 , i V "`� �- vim . 31 33 35 37 39 41 43 45 Retention Time (min.) 30000 m/z 192: Methylphenanthrenes 25000 • . 20000 I � 2 15000 a W F m 8 U 10000 5000 I ..___ i i _ 31 33 35 37 39 41 43 45 Retention Time (min.) 140000 m/z 206: Dimethylphenanthrenes 120000 - I 100000 - d c c $ 80000 - c 1n 60000 - 2 a 0 15 5 0. 40000 - 1 � 20000 - o I o o 0 . - . . , . Jl _., _ 31 33 35 37 39 41 43 Retention Time (min. 5 to Humble Geochemical Services Division Ma. • Pr" Humble Geochemical Services 218 Higgins Street Humble, TX 77338 Si iii.L.040-.it, P. 0. Box 789 Humble, TX 77347 All Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 074547- 194033 Ion Chromatoarams 30000 m/z 191: Benzohopanes 25000 - 20000 - C S a 15000 - a N m 0 (7 10000 - I (y m 5000 - 70 72 74 76 78 80 Retention Time (min.) 70000 m/z 231: Triaromatic Steranes 60000 - • c 50000 - c - 40000 - c P a I 30000 - 20000 - ^� p ' 1 � d ^ I n l o r 10000 - I n "A ' `W �. J - \: i A✓ A . 48 52 56 60 64 68 Retention Time (min.) 20000 m/z 253: Monoaromatic Steranes 18000 - 16000 - 14000 - c 12000 -I 1 v ` 1 - 10000 - a V N 2 8000 - 13 6000 - .3 4000 - a a n - 0 2000 -JL UUUNNN...... V 1 42 46 50 54 58 62 Retention Time (min.) • Humble Geochemical Services Division • . • Barablok Extract FID1 A, (G: \1 \DATA \07 - 4547 \E194034A.D) pA - 22.5 U c 20 M 17.5 -- U 15— U c 12.5— co U d 10— co co co 7.5— u: U U c ,c2)- tAr,ALLJ a 11 c U 2.5— 0' 20 30 40 50 60 70 80 90 mir 'f Humble Geochemical Services 218 Higgins Street Humble, TX 77338 • ,001 P. O. Box 789 Humble, TX 77347 Division of Humble Instruments &Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 Client: Talisman Energy Client ID: Saturate Biomarker Interpretive Ratios HGS ID: 07 -4547- 194034 Well: Aklaq #6 Interpretive By By Depth: Ratios Area Height Field: Lease Terpanes (m /z 191) Formation: C19t/C23t 0.27 0.25 Basin: C22t/C21t 0.07 0.07 County,State: AK C22t/C24t 0.40 0.39 Country: C24t/C23t 0.47 0.48 C26t/C25t 1.98 1.91 Bulk Properties C24Tet/C23t 1.16 1.11 C24Tet/C26t 1.95 1.96 C23t/C3OH 0.02 0.02 API ( °) C24Tet/C3OH 0.02 0.03 S ( %) C28BNH /C3OH 0.01 0.01 Saturate ( %) 25- Nor /C3OH 0.00 0.00 Aromatics ( %) C29H /C3OH 0.55 0.63 Resin ( %) C30DiaH /C3OH 0.00 0.00 Asphaltene ( %) Ole /C3OH 0.01 0.01 S Sat ( %o) C30Ts /C3OH 0.00 0.00 S' Aro ( %o) Gam /C3OH 0.19 0.21 8 Res ( %°) Gam/C31HR 1.72 1.58 S Asp ( %o) C35HS /C34HS 0.52 0.52 • S "C Oil ( %°) C35 Homohopane Index 0.04 0.03 Whole Oil /Extract GC Ts /(Ts +Tm) 0.02 0.02 C29Ts /(C29Ts +C29H) 0.01 0.01 Mor /C3OH 0.32 0.34 CPI C32 S /(S +R) 0.52 0.51 Pristane /n -C17 Phytane /n -C18 Steranes (m /z 217) Pristane /Phytane % C27 aaa 20R 18.5 9.8 % C28 aaa 20R 0.0 53.6 % C29 aaa 20R 81.5 36.7 C27- C28-C29 C27 Dia /(Dia +Reg) 0.00 0.00 a!3!3 Steranes (C21 +C22)/(C27 +C28 +C29) 0.00 0.00 C29 a(3(3 /(aaa +ai3I3) 0.16 0.14 C29 aaa 20S /20R 0.24 0.21 C29 aaa 20S /(S +R) 0.20 0.18 EMI aRl3- Steranes (m /z 218) % C27 aI3(3 20(R +S) 8.9 7.9 % C28 OP 20(R +S) 62.5 62.7 121 t ir % C29 a133 20(R +S) 28.7 29.4 rricyc C29/C27 a(3(3 Sterane Ratio 3.23 3.72 T ricyclic/Pentacyclic Terpanes 0.07 0.09 Steranes /Terpanes 0.14 0.21 Tricyclic, % Tricyclic Terpanes 6.0 6.8 Pentacyc Pentacyclic % Pentacyclic Terpanes 81.6 75.9 Terpanes & % Steranes 12.3 17.3 Steranes 40 Humble Geochemical Services Division Tele 281-540 6 H 05 u o mble F , a T x X : 2 7 8 7 1 3 -5 3 4 8 fl � * Humble Geochemical Services P. O. Box 789 Humble, TX 77347 • :1111P' All Division of Humble Instruments & Services, Inc. 0 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07-4547-194034 Country: Well: Aklaq #6 Depth: Field: Lease Formation: Saturate Biomarker Integration Results (Steranes) Ion I Peak Compound I R.Time I Peak I ppm I Peak ppm I Label Name (min.) I Area (A.) I Height (Ht.) . I• • . • 217 1 S21 C21 sterane . 47.02 1 361 23.8 129 22.3 217 S22 1: b22 sterane 49.74 : 259 17.1: 103 17.8 217 : 27DbaS C27 ba 20S diacholestane 0.00 : 0 0.0' 0, 0.0 217 ;27DbaR 1C27 ba 20R diacholestane 0.00 . 0 0.0 0 0.0 217 28DbaSA 1628 ba 20S diasterane a • 0.00 : 0 0 O. 0' 0.0 . . 217 28DbaSB :C28 ba 20S diasterane b 1 0.00 . 0 0.0 0 0.0 217 28DbaRA C28 ba 20R diasterane a , 0.00 : 0 0.0 0 0.0 217 !28DbaRB LC28 ba 20R diasterane b : 0.00 1 O• 0.01 217 :27aaS 1C27 aa 20S cholestane 1 60.24 . 8250, 543.6, 2605' 449.1 . . 217127bbR !C27 bb 20R cholestane 1 60.40 1 2339: 154 . 1 561: 96.8 217 :27bbS .C27 bb 20S cholestane 1 60.55 i 846' 55.8 303 52.3 410 217 ,27aaR : C27 aa 20R cholestane 61.05 20032 1320.0: . 6807: 1173.3 5957 217 :28aaS 1C28 aa 20S ergostane : 62.14 18310 1206 ' 5 5957: 1026.7 ; 217 28bbR 1C28 bb 20R ergostane ; 62.39 1 21507 1417.2' 8373 . 1443.2 217 ;28bbS I C28 bb 20S ergostane I 62.54 1 6495 428.0 2215; 381.9 217 728aaR C28 aa 20R ergostane : 63.16 . 0 0.0: 37243. 6419.7 217 129aaS 1C29 aa 20S stigmastane : 63.72 ' 21570. 1421.3 , 5426 935.3 217 ;29bbR 1C29 bb 20R stigmastane • 64.04 . 4910 323.6; 1612; 277.8 217 '29bbS C29 bb 20S stigmastane • 64.09' 16232 1069.6, 3471 598.4 217 ;29aaR ,C29 aa 2OR stigmastane 64.87 88126 5807.0 25494. 4394.5 218 27bbR C27 bb 20R cholestane 60.41 : 2837 187.0 706; 121.7 . 218 :27bbS C27 bb 20S cholestane 1 60.55 , 1011 66.6 389: 67.0 218 28bbR C28 bb 20R ergostane : 62.39 . 17749' 1169.5 5527. 952.7 218 ;28bbS C28 bb 20S ergostane ; 62.54 1 9357: 616.6 3148' 542.6 218 ;29bbR C29 bb 20R stigmastane 64.03 ' 6022: 396.8' 1815 312.8 218 ;29bbS C29 bb 20S stigmastane . 64.13 ; 6407' , 422.2. 2254 388.5 259 27DbaS C27 ba 20S diacholestane 0.00 . 0 0.01 0 0.0 259 127DbaR 1C27 ba 20R diacholestane i 0.00 • 0 . 0 1 . 0 , 0: 0.0 259 28DbaSA ;C28 ba 20S diaergostane a ' 0 00 0 0.01 0. 0.0 • : 259 '28DbaSB 1C28 ba 20S diaergostane b 1 0.00 : 0 0.0: 0' 0.0 259 :28DbaRA ba 2OR diaergostane a • 0.00 I O 0.0: 0; 0.0 259 28DbaRB C28 ba 20R diaergostane b . 0.00 • 0. 0 0' . , 0 0.0 . 259 ;29DbaS C29 ba 20S diastigmastane ; 60.41 1 791 52.1 162 27.8 259 129DbaR 1C29 ba 20R diastigmastane ; 61.63 1200 79.1 405 69.7 . , : 259 1 30TP1 iC30 Terpane 1 65.72 . 3331 219.5' 1086. 187.2 259 ,30TP2 IC30 Terpane ; 65.80 1 2626 173.0: 808 139.3 1 . ' . . . . . . ' . • . . • • , . ; . . : . 217 ib-Cholane 5b (inter. STD) : 54.12 : 1698' 111.9 649. 111.9 . 218 b-Cholane 5b (inter. STD) , 54.12 , 853 111.9 315. 111.9 4111/ : . • . • . : Humble Geochemical Services Division 218 Higgins Street Humble, TX 77338 uw. Humble Geochemical Services P. O. Box 789 Humble, TX 77347 iiii 410 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07-4547-194034 Country: Well: Aklaq #6 Depth: Field: Lease Formation: Saturate Biomarker Integration Results (Terpanes) lon Peak Compound I R.Time Peak ppm I Peak II ppm Label I Name 1 (min.) Area (A.) 1 Height I (Ht.) 125 BCRT ;b- carotane 191 IC19t •C19 tricyclic diterpane 40.03 25581 168.6 911 157.1 191 I C20t C20 tricyclic diterpane 42.32 34876 2298.1 132461 2283.2 191 C21t C21 tricyclic diterpane , 44.64 245821 1619.8 92551 1595.3 191 1C22t 1C22 tricyclic terpane 46.77 18051 118.9 6851 118.1 191 1C23t C23 tricyclic terpane 49.19 94371 621.8, 3641' 627.6 191 ; C24t • C24 tricyclic terpane 50.51 4470: 294.5, 1741; 300.1 - -- -- - - - -- -- 191 IC25tS •C25 tricyclic terpane (S) 53.07 ! 1268j 83.6 464{ 80.0 191 1 C25tR C25 tricyclic terpane (R) 53 1576 103.8' 612 105.6 191 1C24T C24 tetracyclic terpane (TET) 54 66 . 10955 721.8 4049 697.9 191 1C26tS •C26 tricyclic terpane (S) • 54.95 29851 1961 1083' 186.6 191 1C26tR ;C26 tricyclic terpane (R) 55.11 2644' 174.2: 979 168.8 • 191 C28tS C28 extended tricyclic terpane (S) 59.09 1006 66.3 4 29' 73.9 191 IC28tR C28 extended tricyclic terpane (R) 59.40 j 837 55.2 370 63.7 191 1 C29tS C29 extended tricyclic terpane (S) 60.31 677' 44.6 270 46.5 191 C29tR _ C29 extended tricyclic terpane (R) 60.65 931 61.4 � 302 52.1 191 C30tS C30 extended tricyclic terpane (S) I 62.54 4 12111 79.8 4901 84.5 191 1C30tR :C30 extended tricyclic terpane (R) 62.89 j 603. 39.7 685; 118.2 191 ITs Ts 18a(H)- trisnorhopane : 61.47 t 1829' 120 569' 98.2 191 ITm Tm 17a(H)-trisnorhopane 62.21 81208 5351.1 289421 4988.8 191 C28BNH :C2817a18a21b(H)- bisnorhopane . 64.05 6879 453.3_ 1527 263.3 191 Nor25H C29 Nor -25- hopane : 64.41 1759 115.9 438, 75.6 191 C29H 'C29 Tm 17a(H)21b(H)- norhopane 64.88 2791201 18392.4; 93029 16035.6 191 jC29Ts ;C29 Ts 18a(H)- norneohopane 64.95 I 1660 109.4 822j 141.7 191 1C30DiaH ,C30 17a(H)- diahopan a 65.29 915 60.3; 3211 55.3 191 ' Normor C29 normoretane 65.73 45391; 2991.0 15517 2674.7 191 a -Ole Ia- oleanane 66.22 2964 195.3 805 1 b- oleanane 66.27 1094 72.1 ' 368; 63.5 191 b -Ole 191 'C30H .C3017a(H)- hopane 66.49 I 504200 33223.9, 147817 25479.5 191 IC30Ts 17a(H) -30- nor -29- homohopane 66.81 i 2269 149.5 .. 504 112.0 191 Mor C30 moretane 67.14 1595521 10513.6 498301 8589.2 191 C31 HS :C31 22S 17a(H) homohopane 68.27 66984; 4413.8 ' 23220 r 4002.5 191 ,C31HR ; C31 22R 17a(H) homohopane : 68.48 55644, 3666.6 19370' 3338.8 191 'Gam ;gammacerane 68.68 955371, 6295.3, 30521 5261.0 191 C32HS C32 22S 17a(H) bishomohopane • 69.67 197721 1302.9, 69111 1191.3 191 LC32HR C32 22R 17a(H) bishomohopane • 69.96 . 18160 1196.6' 65981 1137.3 191 IC33HS C33 22S 17a(H) trishomohopane . 71.32 4 10719 706.3' 3443 I 593.4 I 191 C33HR ;C33 22R 17a(H) trishomohopane 71.75 98241 647.3' 3044 524.8 191 C34HS :C34 22S 17a(H) extended hopane ; 73.22 5920 390.11 16751 288.8 191 C34HR ; C34 22R 17a(H) extended hopane . 73.83 d 5060 333.4 1403 241.9 191 C35HS :C35 22S 17a(H) extended hopane 75.37 1 30951 203.9: 865' 149.1 - - - -- -- - -- 191 1, C35HR C35 22R 17a(H) extended hopane 76.24 1 4313 284.2 11101 191.3 Humble Geochemical Services Division 410 ilfr- --T Humble Geochemical Services 218 Higgins Street Humble, TX 77338 NOM. P. 0. Box 789 Humble, TX 77347 -. -V Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Saturate GC -MS HGS ID: 07 -4547- 194034 Ion Chromatoarams 50000 m/z 217: Steranes 45000 - 40000 - 35000 - c+ I 30000 - a A 2 25000 - a g 20000- 0 LI 15000 - 10000 - o m 5000 - } o a 0 44 48 52 56 60 64 68 Retention Time (min.) 25000 m/z 218: Steranes 20000 - • N a 15000 - c s' ' a 2 10000 - 0 5000 - h 44 48 52 56 60 64 68 Retention Time (min.) 3500 m/z 259: Diasteranes 3000 - 2500 - N v c m - a 2000 - a' a w 1500 - 2 U t7 1000 - 6 1 500 - , 0 44 48 52 56 60 64 68 Retention Time (min.) • Humble Geochemical Services Division ilk II Humble Geochemical Services 218 Higgins Street Humble, TX 77338 6 E P. 0. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Saturate GC -MS HGS ID: 074547- 194034 Ion Chromatoarams 160000 m/z 191: Tri -, tetra- and pentacyclic Terpanes 140000 - 120000 - d 100000 - a a 80000- ¢ w O • 60000 - c� 40000 - E E �U' S ~ U 20000 - U m x i i S U U I U 1 U U U U U 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 40000 m/z 177: Norhopanes 35000 - 30000 - • 25000 - c • 20000- ¢ w V 15000 - 10000 - 5000 - 0 r " r i , 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 14000 m/z 205 12000- 10000 - N c 8000 a to ▪ 6000 - 0 1! 4000- 2000 - 0 ^ A —r nu 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 411 Humble Geochemical Services Division • 218 Higgins Street Humble, TX 77338 T µ� Humble Geochemical Services P. O. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07 -4547- 194034 Country: Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker Interpretive Ratios Interpretive By By Ratios Area Height Naphthalenes DNR- 1= (2,6 +2,7)/(1,5)DMN 3.12 2.17 DNR- 2= (2,6 +2, 7)/(1,4 +2,3) DMN 2.61 1.71 TNR1= (2,3,6)/(1,4,6 +1,3,5)TMN 0.56 0.48 TDE- 1 =1,2, 5 -TMN /1,2,4 -TMN 4.19 2.95 TDE -1= 1,2,7 -TMN /1,2,6 -TMN 0.35 0.52 Phenanthrenes MPI- 2= 3(2MP) /(PHEN +1 MP +9MP) 0.45 0.53 MPI- 1= 1.5(2MP +3MP) /(PHEN +1 MP +9MP) 0.32 0.35 • Rc(a)= 0.6(MPI -1) +0.37 (for Ro <1.3) 0.56 0.58 Rc(b)= 0.6(MPI- 1) +2.3 (for Ro >1.3) 2.49 2.51 MDR= 4MDBT /1 MDBT 1.24 1.24 Rm= 0. 40+ 0. 30(MDR)- 0.094(MDR) +0.011(MDR) 0.65 0.65 MDR23= 23MDBT /DBT 0.49 0.63 MDR1 =1MDBT /DBT 0.63 0.86 DBT /Phenanthrene 0.19 0.20 Triaromatic Steroids TAS 20 +21/all TAS 0.10 0.11 TAS 20/20 +27 0.11 0.12 TAS 21/21 +28 0.12 0.14 TAS C28/C26 20S 6.55 4.70 TAS C28/C27 20R 0.80 0.94 °A) 26 TAS 3.1 3.8 % 27 TAS 49.3 52.2 % 28 TAS 40.1 36.3 % 29 TAS 7.5 7.7 Monoaromatic Steroids MAS Dia /Reg C27 1.45 1.35 MAS 21 +22/all MAS 0.07 0.07 %27 MA 6.8 7.3 % 28 MA 55.9 56.9 % 29 MA 37.3 35.8 TAS /(TAS +MAS) 0.52 0.48 TAS28 /(TA28 +MA29) 0.59 0.57 • Humble Geochemical Services Division • 218 Higgins Street Humble, TX 77338 Humble Geochemical Services P. 0. Box 789 Humble, TX 77347 it' ill Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07 -4647- 194034 Country: Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker Integration Results (Naphthenes, Dibenzothiophene, Phenanthrenes) ton I Peak Compound I R.Time Peak 1 ppm 1 Peak ppm Label Name _ (min.) Area (A.) Height (Ht.) 128 NAPH ; Naphthalene _ 0.00 0; 0.0 0. 0.0 142 2MN 2- Methylnaphthalene 18.36 847 0.71 191' 0.4 142 1MN ,1- Methylnaphthalene 18.89 1033 0.9! 241 0 .5 156 2EN 12- Ethylnaphthalene 0.00 0 0.0; 0. _ _ _ 0.0 156 1 EN 1 -Eth (naphthalene T 0.00 0! 0.0 0. 0.0 156 74 26DMN 2,6- Dimethylnaphthalene 22.30 1331 1.1 262. _ 0.6 156 27DMN 2,7- Dimethylnaphthalene 22.37 96 4' 0.8 250 0.6 156 13 +17DMN 1,3 &1,7- Dimethylnaphthalenes 22.80 2287 1.9 660' 1.5 156 16DMN !1,6- Dimethylnaphthalene 4 _ 22.92 1864 1.6 489' 1.1 156 23DMN 12,3- Dimethylnaphthalene 23.46 , 3961 0.3 125, 0.3 156 14DMN X 1,4- Dimethylnaphthalene 23.50 485 0.4 174' 0.4 156 15DMN +1,5- Dimethylnaphthalene 23.54 735 0.61 235 0.5 IP 156 12DMN 1,2- Dimethylnaphthalene 23.97 538 0.3 170 BB EMN Ethyl- methyl - Naphthalene 25.81 1077 0.5; 0.9L 151 228 0.5 170 AB_EMN Eth I- methyl - Naphthalene 26.34 555 0.5 1261 0.3 170 137TMN ,1,3,7- Trimethylnaphthalene ! 26.53 1324 1.1 443. 1.0 170 '136TMN '1,3,6 - Trimethylnaphthalene 26.71 2279 1.9 677' 1.5 170 146 +135T x(1,4,6 +1,3,5)- Trimethylnaphthalenes_; 27.21 3021; 2.5 867' 1.9 170 236TMN 2,3,6 - Trimethylnaphthalene 27.36 1690 1. 4 418. 0.9 170 127TMN 11,2,7- Trimethylnaphthalene 27.71 _ 8401 _ 0.7; 256. 0.6 170 167 +126T 1(1,6,7 +1,2,6 )-Trimethylnaphthalenes 27.78 2410 2.0; _ _ 492: 1.1 170 124TMN '1,2,4- Trimethylnaphthalene 28.27 393 0.3' 156' 0.3 170 125TMN 1,2,5 - Trimethylnaphthalene 28.50 1645 1.4 462. 1.0 184'1357 1,3,5,7 - Tetramethylnaphthalene 30.62 5077 4.3 1573 3.5 184 1367 1,3,6,7- Tetramethyln phthalene j 31.34 2791 2.3 _ 887 2 .0 184 1247 1(1,2,4,7 +1,2,4,6 +1,4,6,7)- TetraMNs 31.81 1 10.9; 4342' 9.7 184 1257 11,2,5,7 - Tetramethylnaphthalene 31.92 57611 4.8 1780, 4.0 184 2367 12,3,6,7 - Tetramethylnaphthalene 32.16 9301 0.81 308, 0.7 184 1267 _ _ 41,2,6,7- Tetramethylnaphthalene , 32.44 2767! 2.31 1004' 2.2 184 1237 11,2,3,7 - Tetramethylnaphthalene 32.57 23171 1.91 828' 1.8 184 1236 1,2,3,6- Tetramethylnaphthalene 32.76 22441 18.8 6418 14.3 184 1256 11 ,2,5,6 - Tetramethylnaphthalene 33.22 , 6362 5.3 1983' 4.4 184 DBT 1Dibenzothiophene 33.45 11246, 9AI 2991 6.6 _ 198 4MDBT 1 4 Methyl Dibenzothiophene 36.52 8788; 7.4 3176' 7 .1 198 -2 +3MDBT 12 & 3 Methyl Dibenzothiophenes 37.10 5500; 4.61 1898' 4.2 198 1MDBT 1 Methyl Dibenzothiophene 37.64 7065r 5.91 2558; 5.7 154 BP !Biphenyl 21.26 49 1 _ 0.4; 86_ 0.2 168 2MBP _4 2- Methylbiphenyl 22.01 149 0.1 44' 0.1 168 DPM Di henylmethane 23.00 37 0.0 24. 0.1 168 '3MBP 3- Methylbiphenyl 24.96 ' 13641 _ 1.1 321 0 .7 168 4MBP _ 44- Methylbiphenyl _ 25.28 617; 0.51 133 0.3 168 DBF ;Dibenzofuran 1 26.04 388; 0.3 81 0 .2 178 PHEN 1 Phenanthrene 34.29 580471 48.6 14607: 32.5 192 3MP 13- Methylphenanthrene T 37.77 4968 4.21 1107, _ 2.5 192 2MP i2- Methylphenanthrene 37.94 12161 10.2 3340; _ 7.4 192 9MP 9- Methylphenanthrene 38.42 15612 13.1 2839 _ 6.3 • 192 IMP 1- Methylphenanthrene 1 38.57 66140 5.5 1379. 3.1 Humble Geochemical Services Division • Humble Geochemical Services 218 Higgins Street Humble, TX 77338 1, . P. O. Box 789 Humble, TX 773447 N Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 ' Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07 -4547- 194034 Country: 0 Well: Aklaq #6 Depth: Field: Lease: Formation: Aromatic Biomarker integration Results (Dimethyl- Phenanthrenes, Benzohopanes, Triaromatic Steroids, Monoaromatic Steroids) Ion I Peak Compound R.Time I Peak ppm Peak I ppm Label I Name (min.) Area (A.) Height 1 (Ht.) _206 36DMP 3,6- Dimethylphenanthrene 41.00 41111 7502 6.3' 2372 5.3 206 26DMP 2,6- Dimethylphenanthrene 41.21 5983 5.0 1827 4.1 206 27DMP 2,7- Dimethylphenanthrene 41.31 5230 4.4 13541 3.0 t 206 39DMP (3,9 +3,10+ 2,10 +1,3) - Dimethylphenanthrenes _ 41.69 66162 55.4; 18572 4 206 29DMP (2,9 +1,6)- Dimethylphenanthrenes 41.84 261771 21.9 4106 _ 9.1 206 17DMP 1,7- Dimethylphenanthrene 41.98 38233! 32.0 8698 19.3 206.23DMP 2,3- Dimethylphenanthrene 42.29 65911 5.5 1683 3.7 • 206 19DMP 1,9- Dimethylphenanthrene 42.34 106151 8.9 3472 7.7 - -- - -- - - -- 206 18DMP 1,8- Dimethylphenanthrene 42.67 7504) 6.3 2209 4.9 206 12DMP 1,2- Dimethylphenanthrene 43.07 74761 6.31 16741 3.7 191 BH32 C32 Benzohopane 73.08 53164 44.5 12861 28.6 191 BH33 C33 Benzohopane : 74.69 77696 65.1 14550: 32.3 191 . BH34 C34 Benzohopane 76.09 I 861901 72.2 13694 30.4 191 BH35 C35 Benzohopane 77.84 10780{ 9.0; 1624 3.6 1 1 231 - 1TA20 . C20 Triaromatic Steroid 51.41 135481 11.3; 3425 7.6 231 2TA21 C21 Triaromatic 53.69 127631 10.7' 2939 6.5 231 3TA26 C26 20S Triaromatic a 61.82 70174, 5.9 1899, 4.2 231 '4TA26 +27 C27 20S & C26 20R Triaromatic � - 63.18 555881 46.61 16305' 36.2 231 5TA28 C28 20S Triaromatic 1 64.35 45926 38.5; 8918 19.8 231 6TA27 C27 20R Triaromatic 64.89 t 57496 48.21 9986, 22.2 231 7TA28 C28 20R Triaromatic 1 66.28 45951 38.5 ; 9349 20.8 p pY) ¢ -- 9 - 1 -_ 1 - 231 8TA29 C29 20R Triaromatic (24 n- ro I 67.92 17277 1 14.51 3901 8.7 253 , 1 MA21 * C21 Ring -C Monoaromatic Steroid 44.55 10745 9.0 2397 i 5.3 253 ' 2MA22 .C22 Monoaromatic steroid 47.11 5877 4.9 1739 3.9 253 3MA27 C27 Reg 5b(H),10b(CH3) 20S i 55.65 21391 1.81 549 1.2 253 4MA27 C27 Dia g { 56.97 2322 1.91 7591 1.7 1.7 253 5MA27 C27 Dial 0bH 5 20R +Re 5bH,10bCH3 20R 55.82 3099 2 6 743 253 6MA27 C27 Reg 5a(H),10b(CH3) 20S 57.11 1967 1.6; 525: 1.2 253 7MA28 C28 Dia 10aH,5aCH3 20s +Reg5bH,10bCH3 20S 57.47 183151 15.3, 3062 6.8 253 8MA27 C27 Reg 5a(H),10b(CH3) 20R 58.65 5007! 4.21 1705 3.8 253 9MA28 C28 Reg 5a(H),10b(CH3) 20S i 58.76 29772' 24.9 10609, 23.6 253 10MA28 C28 Dia 10aH,5aCH3 20R +Reg5bH,10bCH3 20R 58.94 133131 11.2 47061 10.5 253 11MA29 C29 Dia 10bH,5bCH3 20S +Reg5bH,10bCH3 20S j 59.05 10757 9.01 3627' 8.1 253 12MA29 C29 Reg 5a(H),10b(CH3) 20S 1 60.15 387631 32.51 82864 18.4 253 13MA28 C28 Reg 5a(H),10b(CH3) 20R 60.43 587081 49.21 14812 32.9 253 14MA29 C29 Dia 10bH,5bCH3 20R +Reg5bH,10bCH3 20R 1 60.50 61961 5.2 3255 ' 7.2 1 253 15MA29 C29 Reg 5a(H),10b(CH3) 20R f 61.97 24416! 20.51 5711 ' 12.7 i 411 230 :OTP Ortho- terphenyl (Inter. STD) 37.48 1 1181261 98.9 445141 141 98.9 Humble Geochemical Services Division •` Humbl Geochemical Services 218 Higgins Street Humble, TX 77338 P. 0. Box 789 Humble, TX 77347 I ` l! ° 41 Division Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS I HGS ID: 07- 4547494034 I Ion Chromatoarams 12000 II m/z 156: Dimethylnaphthalenes 10000 - g 8000 - a 6000 - I I in M I l 0 4000 - 2000. ® R f V 0 __ o 2 3 36 Retention Time (min.) 40 20 24 16000 m/z 170: Trimethylnaphthalenes 14000 - 12000 - 10000 - Q 8000 - N chi 6000 - CD I1 I I 4000 - IP 2000 - W � ai n - ° - I r .ri Al --An " �" 4 ' J ` . N . ` m . 0 26 32 36 Retention Time (mm.) 40 20 24 `.Q ,000 i m/z 184: Tetramethylnaphthalenes 6000 - 5000 - il 4000 - a i N 3000 - 1 U c. tl Lr.' ^�A �� 2000 - � l vt , . ,000 - VN 0 -- • - ' r ` - ,_ 8 - 32 36 Retention Time (min.) 40 20 24 7000 m/z 198: Pentamethylnaphthalenes 6000 - 5000 - v 4000 - r N 3000 - U tl 2000 ) 1000- i _ '�� II,„ J� 0 - �J( ° ° 3222 ' 36 Retention Time (min.) 40 20 24 28 • Humble Geochemical Services Division • - Humble Geochemical Services 218 Higgins Street Humble, TX 77338 M,F>ap P. 0. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 074547- 194034 Ion Chromatoarams 45000 m/z 230: Ortho - Terphenyl (Inter. Std) 40000 - 35000 - w 30000 - • 25000 - 2 a N • 20000 - C9 • 15000 - 10000 - 5000- 0 32 34 34 36 38 40 42 Retention Time (min.) 500 m/z 154: Biphenyl 450 - I 400 - • 350 - 300 - c C 2 250- ¢ N U 200- ^^ y r �h L7 V 150 - \ i Al 100 - ' CAP' A V' 50 - 0 18 20 22 24 26 28 Retention Time (min.) 400 g m/ 168: Methylbiphenyls (MBP) 350 - 300 - 250 - i 9 a a 200 - e ) N 8 • 150 - 100 - 3 50 - 0 18 20 22 24 26 28 Retention Time (min.) • Humble Geochemical Services Division •- - Humble Geochemical Services 218 Higgins Street Humble, TX 77338 { P. 0. Box 789 Humble, TX 77347 Division of Humble Instruments & Services Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 194034 Ion Chromatoarams 100000 m/z 178: Phenanthrene 90000 - 80000 - I 70000 - m 60000 - v c .o 50000 - V 40000 U 30000 - 20000 - 10000 - n w� N JWti 31 33 35 37 39 41 43 45 Retention Time (min.) 30000 m/z 192: Methylphenanthrenes 25000 - 20000 - 2 15000 - 1 '. a co E 45 10000 - 1 5000 0 31 33 35 37 39 41 43 45 Retention Time (min.) 120000 m/z 206: Dimethylphenanthrenes 100000 - d 80000 - as 2 80000 - N U (7 40000 - 5 20000 - o � WI 0 - . - ^ A 31 33 35 37 39 41 43 Retention Time (min.) 5 • Humble Geochemical Services Division 1 --� Humble Geochemical Services 218 Higgins Street Humble, TX 77338 1 „M � � 1 P. 0. Box 789 Humble, TX 77347 IG "i Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 194034 Ion Chromatoarams 20000 e000 - m m/z 191: Benzohopanes 16000 - 14000 - u F, 12000 0 c 2 10000 - U • 8000 - o PI 8000 - / 4000 n /1 �. + \ 1 y 2000 2000 - �"v �- 70 72 74 76 78 80 Retention Time (min.) 30000 m/z 231: Triaromatic Steranes 25000 - • u 20000 - F sr a 15000 - u 0 ,0000_ i t 1 . I i .° ■ 5000 - ��` ^ l'�J 6 �/"' � / VV 1;,J'i^' l �+ "�' '� `., 1 lUV1(VV�'' ,k... w v p 48 52 56 60 64 68 Retention Time (min.) 35000 m/z 253: Monoaromatic Steranes 30000 - 25000 - d c p 20000 - c i Q 2 • 15000 - i U 0) 10000 - I ' Z' n N 1 5000 - § ` ( i 0 42 46 50 54 58 62 Retention Time (min.) • Humble Geochemical Services Division I • • • DriI -N -Slide FID1 A, (G: \1 \DATA \07 - 4547 \0195894A.D) pA 500 4000, 3000; 200 100 20 30 40 50 60 70 80 90 - mil • • • Mix #1 DriI -N -Slide and Barablok FID1 A, (G: \1 \DATA \07 - 4547 \F195895A.D) pA 600 500 400 300 200 I 100 20 30 40 50 60 70 80 90 mil • 110 DriI-N-Slide FID1 A, (G: \1 \DATA \07 - 4547 \O195894A.D) pA_ 45- 40- 35- 30- 2 21 15- 1 0 5 20 30 40 50 60 70 80 90 Humble Geochemical Services H • P. 218 O. Box iggins 789 Street Humble, TX 77338 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 Client: Talisman Energy Client ID: 68mg /ml Saturate Biomarker Interpretive Ratios HGS ID: 07- 4547 - 195895 Well: Aklaq #6 Interpretive By By Depth: Ratios Area Height Field: Lease Terpanes (m /z 191) Formation: C19t/C23t #DIV /0! #DIV /0! Basin: C22t/C21t #DIV /0! #DIV /0! County,State: AK C22t/C24t #DIV /0! #DIV/0! Country: C24t/C23t #DIV /0! #DIV /0! C26t/C25t #DIV /0! #DIV /0! Bulk Properties C24Tet/C23t #DIV /0! #DIV /0! C24Tet/C26t #DIV /0! #DIV /0! C23t/C3OH 0.00 0.00 API ( °) C24Tet/C3OH 0.00 0.00 S ( %) C28BNH /C3OH 0.00 0.00 Saturate ( %) 25- Nor /C3OH 0.00 0.00 Aromatics ( %) C29H /C3OH 0.56 0.54 Resin ( %) C30DiaH /C3OH 0.00 0.00 Asphaltene ( %) Ole /C3OH 0.00 0.00 6 Sat ( %o) C30Ts /C3OH 0.00 0.00 8 Aro ( %o) Gam /C3OH 0.26 0.26 S Res ( %o) Gam /C31 HR 1.97 1.42 6 Asp ( %o) C35HS /C34HS #DIV /0! #DIV /0! • S "C Oil ( %o) C35 Homohopane Index 0.00 0.00 Whole Oil /Extract GC Ts /(Ts +Tm) 0.00 0.00 C29Ts /(C29Ts +C29H) 0.08 0.12 Mor /C30H 0.41 0.37 CPI C32 S /(S +R) #DIV /0! #DIV /0! Pristane /n -C17 Phytane /n -C18 Steranes (m /z 217) Pristane / Phytane % C27 aaa 20R 10.3 14.2 % C28 aaa 20R 57.7 51.6 C29 aaa 20R 32.0 34.2 C 27 c 28 c 29 C27 Dia /(Dia +Reg) 0.00 0.00 al313 Steranes (C21 +C22)1(C27 +C28 +C29) 0.00 0.00 C29 C27 C29 a(3(3 /(aaa +a(3(3) 0.23 0.24 C29 cum 20S /20R 0.30 0.36 C29 aaa 20S /(S +R) 0.23 0.26 g a88- Steranes (m /z 218) - % C27 a(3(3 20(R +S) 0.0 0.0 % C28 a(3(3 20(R +S) 63.2 59.4 C29 4(3 20(R +S) 36.8 40.6 Tricyc C29/C27 413 Sterane Ratio #DIV /0! #DIV /0! I st. I Tricyclic /Pentacyclic Terpanes 0.00 0.00 Tricyclic, % 0.38 0.32 Pentacyc Pentacyclic /o Tricyclic Terpanes 0.0 0.0 Terpanes & % Pentacyclic Terpanes 72.5 75.9 Steranes % Steranes 27.5 24.1 • Humble Geochemical Services Division ' - 1 1 Humble Geochemical Services 789 218 Higgins Street Humble, TX 77338 P. O. Box Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 6050 Fax: 281 2864 Client: Talisman Energy Basin: Client ID: 68mg/m1 County,State: AK HGS ID: 074647-196895 Country: Well: Aklaq #6 Depth: Field: Lease Formation: Saturate Biomarker Integration Results (Steranes) • Ion I Peak Compound I R.Time I Peak I ppm I Peak I ppm Label Name I (min.) I Area (A.) I Height (Ht.) • . : 217 S21 C21 sterane 0.00 . 0 0.01 0 : 0.0 217 :S22 - TC22 sterane . 0.00 , 0' 0.0, 0 ., 0.0 217 27DbaS 4C27 ba 20S diacholestane , 0.00 : 0 0.67 0 0.0 217 27DbaR 1 C27 ba 20R diacholestane • 0.00 . 0 0.0 0: 0.0 217 '28DbaSA IC28 ba 20S diasterane a 0 00 : 0' 0 & 0 0.0 . . . . . - . 217 28DbaSB 1C28 ba 20S diasterane b : 0.00 ' 0 0.0, 0: 0.0 217 28DbaRA 1C28 ba 20R diasterane a • 0.00 ' 0 0.0. 0 . 0.0 217 28DbaRB IC28 ba 2OR diasterane b . 0.00 0 0.0! 0 0.0 217 .27aaS iC27 aa 20S cholestane : 0.00 : 0 0.0 0 0.0 217 27bbR 1C27 bb 2OR cholestane : ' 0 00 0 0.0 0 : 0.0 217 27bbS 1C27 bb 20S cholestane 0.00 • 0: 0.0' III 217 ;27aaR C27 aa 20R cholestane 60.98 287 20.5: 100. 217 28aaS 1C28 aa 20S ergostane 1 . : 8 . 231 16.5: 90 20.8 62.0 18.6 217 .28bbR C28 bb 20R ergostane 62.27 . 254 18.1 82 17.1 217 28bbS 1C28 bb 20S ergostane 62.34 1 284 20.2 93 . 19.4 217 ! 28aaR 1C28 aa 2OR ergostane : 63.07 : 1612. 114.9 363 75.5 217 .29aaS 1C29 aa 20S stigmastane 63.65 , 268 19.1 86, 17.9 217 29bbR 1C29 bb 20R stigmastane . 63.94 . 140 10.0 41. 8.4 . .. 217 129bbS C29 bb 20S stigmastane : 64.02 1 199' 14.2 62: 12.9 , 217 :29aaR 1C29 aa 2OR stigmastane , 64.79 ! 893 63.7, 240 50.0 218 27bbR IC27 bb 20R cholestane . 0.00 : 0 0.0 . 0 0.0 218 :27bbS C27 bb 20S cholestane ' 0.00 0, 0.0' 0' 0.0 218 :28bbR C28 bb 20R ergostane . 62.28 105 : 7.5! 49 10.1 218 :28bbS 1C28 bb 20S ergostane • 62.34 : 256 18.2 72: 15.0 218 :29bbR IC29 bb 2OR stigmastane ' 63.96 . 112: 8.0 31 ' 6.4 . 218 29bbS C29 bb 20S stigmastane : 64.05 : 98. 7.0, 51 10.7 259 127DbaS C27 ba 20S diacholestane - 0.00 : 0 0.0' 0 0.0 ..._ 259 :27DbaR C27 ba 2OR diacholestane 0.00 0' 0.0 0: 0.0 259 28DbaSA 1C28 ba 20S diaergostane a ' 0.00 . 0 0.0. 0: 0.0 259 28DbaSB :C28 ba 20S diaergostane b ' 0.00 ' 0 0.01 0: 0.0 259 ,28DbaRA 1C28 ba 2OR diaergostane a ' 0.00 0 0.0- 01 0.0 259 ,28DbaRB 1C28 ba 2OR diaergostane b : , 0.00 : 0 0.0' 0: 0.0 . 259 '29DbaS I C29 ba 20S diastigmastane 0.00 0, 0.01 0 0.0 . 259 :29DbaR 1C29 ba 20R diastigmastane 1 0.00 , 0 : 0.0: 0 0.0 259 :30TP1 1C30 Terpane : 0.00 : 0 0.0: - 0: 0.0 . 259 :30TP2 1 Terpane _. 0.00 0 0.0 0: 0.0 ' , • • . . --- -,- - , 1 . : . : . , . . . • 217 .b-Cholane 5b-cholane (inter. STD) : 54.07 : 2440 174.0. 837' 174.0 .. . 218 'b-Cholane :5b-cholane (inter. STD) 54.07 1 1121 174.0: 392: 174.0 • • • . 1 . . . . . .:. Humble Geochemical Services Division 218 Higgins Street Humble, TX 77338 • q e Humble Geochemical Services P. 0. Box 789 Humble, TX 77347 111 ' IP ill Division of Humble Instruments & Services, Inc. Telephone: 281-540 6050 Fax: 281-540 2864 Client: Talisman Energy Basin: Client ID: 68mg/m1 County,State: AK HGS ID: 07-4547-195895 Country: Well: Aklaq #6 Depth: Field: Lease Formation: Saturate Biomarker Integration Results (Terpanes) Ion ! Peak I Compound I R.Time Peak ppm I Peak I ppm Label I Name I (min.) Area (A.) I Height I (Ht.) • • . , . : L 125 1BCRT • b-carotane 1 ' 191 IC19t ;C19 tricyclic diterpane 0.00 01 0.0: 0 0.0 191 I C20t C20 tricyclic diterpane ' 0.00 01 0.0 0 0.0 191 C21t 'C21 tricyclic diterpane 0.00 01 0.0, 01 0.0 191 C22t 1C22 tricyclic terpane : 0.00 01 0.0: 0 0.0 191 iC23t 'C23 tricyclic terpane 0.00 01 0.0, 01, 0.0 191 IC24t • C24 tricyclic terpane . 0.00 0, 01 0.0: a 0.0 191 1C25tS :C25 tricyclic terpane (S) 0.00 1 0' 0.0' 01 0.0 191 ,C25tR :C25 tricyclic terpane (R) : 0.00 ' 0 0.0. 01 0.0 . 191 1C24T 'C24 tetracyclic terpane (TET) 0.00 01 0 : .0, 01 0.0 191 1 C26tS :C26 tricyclic terpane (S) : 0.00 0 0.0 01 0.0 --I-- . 191 IC26tR ' C26 tricyclic terpane (R) 0.00 . , oi 0 0' 01 0.0 . ID 191 I C28tS , C28 extended tricyclic terpane (S) : 0.00 191 1C28tR :C28 extended tricyclic terpane (R) : 0.00 0.0 07 0.0 191 I C29tS • C29 extended tricyclic terpane (S) ' 0.00 0, (1) 01 0.0: 0.0: 01 0.0 0, 0.0 1 191 1C29tR :C29 extended tricyclic terpane (R) : 0.00 0 i i 0.0 01 0.0 191 I C3OtS 'C30 extended tricyclic terpane (S) ' 0.00 0 0.0' T- O 0.0 191 tC30tR C30 extended tricyclic terpane (R) 0.00 o' 0.0: 0 0.0 191 I Ts 'Ts 18a(H)-trisnorhopane 0.00 0 0.0. 0 0.0 191 1Tm : Tm 17a(H)-trisnorhopane • 62 14 . 8871 63.2 : 285 59.2 191 I C28BNH C28 17a18a21b(H)-bisnorhoPane • 0.00 0 0.0. 0 0.0 1911Nor25H 'C29 Nor-25-hopane 0.00 _ bi 0.0' 0-1 - 1 0.0 191 C29H . , C29 649 Tm 17a(H)21b(H)-norhopane 64.78 2027, 144.5 135.0 191 1C29Ts ;C29 Ts 18a(H)-norneohopane : 64.86 1 1781 12.7 90 18.8 19LC30DiaH .C30 17a(H)-diahopane . 0.00 o 1 o 0.0 0.0 191 Normor 'C29 normoretane 1 65.64 - 5891 42.0: 1901 39.6 191 1a-Ole • a-oleanane . 0.00 0. 0.0: . 0, 0.0 191 i b-Ole : b-oleanane : 0.00 01 0.0: - 0 0.0 191 1C30H :C30 17a(H)-hopane 66.37 3594 256.2 , 12011 249.8 191 1C30Ts 117a(H)-30-nor-29-homohopane : 0.00 t 0 0.0 0 1 0.0 , 191 I Mor C30 moretane • 67.05 1 14641 104.4 : 445 i 92.5 191 1C31HS .C31 22S 17a(H) homohopane : 68.19 -1- 57.9: 2541 52.8 -I- 191 i C31HR C31 22R 17a(H) homohopane ' 68.39 I 4821 34.4 219 45.6 . . 19 • gammacerane : 68.59 . 949 67.7: 311 64.8 191 I C32HS ' C32 22S 17a(H) bishomohopane ' 0.00 0, 0.0' 0 0.0 --f-- . 191 C32HR , C32 22R 17a(H) bishomohopane : 0 0 1 .00 0.0 01 0.0 191 C33HS C33 22S 17a(H) trishomohopane ' 0.00 0 I 0.0, a 01 0.0 191 1 C33HR 1C33 22R 17a(H) trishomohopane • 0.00 or 0.0. _._)---- 0.0 191 1C34HS 1C34 22S 17a(H) extended hopane , 0.00 0: 0.0' 0 0.0 i 191 C34HR :C34 22R 17a(H) extended hopane : 0.00 01 0.0' 01 0.0 191 C35HS :C35 22S 17a(H) extended hopane ' 0.00 I 0 0.0 0 0.0 191 C35HR C35 22R 17a(H) extended hopane ' 0.00 01 0.0, OI •f-- 0.0 I . 1 1 • , - . 1 II Humble Geochemical Services Division • - , Humble Geochemical Services 218 Higgins Street Humble, TX 77338 M ��� , , P. 0. Box 789 Humble, TX 77347 IV --4 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: 68mg /m1 Key Saturate GC -MS HGS ID: 07 -4547- 195895 Ion Chromatoarams 1000 C m/z 217: Steranes v 900 - 800 - d 700 - v 600 - c a 500 - Q cn m 400 - i N 0 300 200 - r n 100 - �k r b, N 4,m04146 , 44.04 0 44 48 52 56 60 64 68 Retention Time (min.) 450 ie m/z 218: Steranes 1 400 - 350 - • u 300 - . = 250- I N 200 - I � 150- 100 - I 4 1 * . I ,. o 50 ��ff 0 44 48 52 56 60 64 68 Retention Time (min.) 140 m/z 259: Diasteranes 120 - i , 100 - 11! i i y l r ii co 1 3 80 - i 1 \Ifi , 4 *** 4ei6 40 - 20 - 0 44 48 52 56 60 64 68 Retention Time (min.) • Humble Geochemical Services Division 9 11 Humble Geochemical Services 218 Higgins Street Humble, TX 77338 00.'1, P. 0. Box 789 Humble, TX 77347 r Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: 68mg /m1 Key Saturate GC -MS HGS ID: 07- 4547 - 195895 Ion Chromatograms 1600 R m/z 191: Tri -, tetra- and pentacyclic Terpanes 1400 1200 d IC 1000 I y s .o 800 a co v 600 C7 400 200 0 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 450 m/z 177: Norhopanes 400 i 350 - • u 300 - e o c 250 - a N 200 - 2 CD 150 - `` 100- 'r 50 0 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 400 m/z 205 350 - 300 - i , StOi d f A 250 1 2 a i 0 R 200 cn v 150 - C IH 100 50- 0 . . 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) • Humble Geochemical Services Division • • • F 218 Higgins Street Humble, TX 77338 ' Humble Geochemical Services P. O. Box 789 Humble, TX 77347 1 ... , Telephone: 281 -540 6050 Fax: 281 -540 2864 , ► Division of Humble Instruments & Services, Inc. Client: Talisman Energy Formation: API: Client ID: Basin: HGS ID: 07- 4547 - 198186 Country: Type: core County,State: AK Well: Aklaq #6 Lease Depth: 7125.6(ft) Field: FID1 A, (G: \1 \DATA \07- 4547F\E198186A.D) pA 120 - U M = U 100 - 80 - N N U U c � 60 - 0 U c n U _ 40 - U 0 U c <:,,‘„ I- v F, 5 U c V U N fr �n 20- ° , �U U U 0 r c or.. Q m (, - U i - C U U L N M � ., N (h , 1 I. a C C U U U M M N rn ._ c c c c U U U _ C 0 C II A C C U V U C .'. � ... ��. i C 0 - - 10 20 30 40 50 60 70 80 90 min -- - - - -- - - - - - - - - - - - Humble Geochemical Services Division • S • Humble Geochemical Services Higgins Street Humble, TX 77338 P. P. O. Box 789 Humble, TX 773447 Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Formation: API: Client ID: Basin: HGS ID: 07- 4547 - 198186 Country: Type: core County,State: AK Well: Aklaq #6 Lease Depth: 7125.6(ft) Field: 180 Histogram Based on Area s ka 160 — — _.. Cycloalkane • Aromatics • Internal Standard 140 — 1211— 100 —__. ea H 40— II 20 I I 2 2 N c' " ° o m r 6 E 6 h �' n • A n &a", h N 9 h 9 w w i1 n 24 n 2 24 > m w • i m __° `' 3 A A r o v w w o N w> o, o v w Y w m m e o ti w m s � m Humble Geochemical Services Division 218 Higgins Street Humble, TX 77338 - 111 0 Humble Geochemical Services P 0 Box 789 Humble, TX 77347 vo■01.. Telephone 281-540 8050 Fax, 281-540 2864 Division of Humble Instruments & Services, Inc. Client: Talisman Enemy Client ID: API: HGS ID: 074547-198188 County,State: AK Type: core Lease Well: Aklaq #8 Depth: 7125.8(ft) Field: Formation: Basin: Country: Gas Chromatography Integration Results Peak Compound R.Time 1 Peak 1 Peak - 1 - I Label Bente (mini_ _ Hem' ht - Area - I I _ T r--- , , ,-- 114 IS L o-b -1 utane 0 00 1 01 , 01 , n-C4 [butane j000 . 04 q 1 0-05 -h-pentane --1 000 cji C'1 h _ - pentane 000 I 01 01 122-OMB 2,2-dimethylbutane 000 ol ol I IcP oa,pentane 000 .. 6I- 1 423-DMB _42,3_-dimettylbutane 0 00 1 or 0 —r- 1 12-MP 12-methylpentane -- 1 0 00 ol 43-MP 13-methylpentane 0 00 I 01 001 41-Std . 1 Internal Standard 000 I-- 01 0[ 1 _4n-C6 hexane 0.00 4 01 PI- !- 122-DMP 2,2-climethylpentane 0 00 1 0 0 ]MCP jaettylcyclopentane 000 1 0 0 F 124-DMP Imettcyclopentane 000 1 0 4 al- --1- n , IE, 3-TMB 2 3-trimeth_ylbu III F 0 00 -r I H f--.`--L-- -- Oh '-t- IBz .benzene 0 00 _ o i 33-DMP 3,3-dimethylpentane 00 1 0 O - L 4CH icyclohexane 0 00 I-- 01 0[ 4 12 12-me thy 0 00 _1_ 01 01 m p 2 ntone 0 00 1 0 01 711-DMCP 11; 1 000 I 01 01 -t 1 3-MH 13-meth_thexane -- 0 00 - r V Er —I _ r or I _ip,13-DMCP cis im : 13-dethylcyclopentene 000 ,3r —,- --r- t-13-DMCP Itrans-13-dimethylcyclopentane I 000 1 01 01 t -- 3-EP 3-ethylpentane 1 0 00 1 01 IDA 4t Itrans-1,2-dimethilpyclopentane 1 0 00 4 . 01 0,1 1 -C7 tip th ne 1 12 02 _L n h 111 1 i -L k- • MCH IECP _4Tol Trnethylcyclohexane lethylcyclo_p_entane toluene octane i 13 63 1 i - 1 1 4- r 23 34 ja_ 01 2 1 01 181 - t - 1 7 ,24 21 r- r-- IE-Bz iethylbenzene a ir 0 00 1 01 Oi r im-xylene peta-xylene 1 0 00 01 (43 1-- . ip-xene ip8ra 0 00 1 '4 0 1- 1 - 1 o-xylene lojto-xylene 000 1 04 0 _ 1n-C9 lnonane 28 44 I 31 t 1 -- IC3-Bz .ro. lbenzene 000 I 01 01 1 I decane 31 56 81 r . its,_ 1 _n-C11 iundecane F 3386 1 311 531 I - In-C12 _Idoec dane 1 36 01 1 61 r 94 --r- i-C13 IC13 isoprenold 36 32 _1_ -- 1 1-C14 C14 iso_prenoid 1 37 43 L 91 214 1- n-C13 tridecane 3T86 4 991 1534_ 1-- 1-C15 farnesane (C15 isoprenoid) 1 3523 ] - 9i - 151 I_ - In-C14 tetradecane 1 3956 I - 1061 1581 F_ 11-C16 rC16 Isoprenoid 1 40 60 --- ,01 20r -- E ,prentadecane 1 41 15 I aol itir r- - , --,- ,,6 lhexadecane --- 1 42 65 4, 4.1-- 97 r 1 1-C18 Lonstane (C16 isperenofdl 1 43 40 1 ---1- - in-C17 iheptadecane 1 44 06 [ I 674 IPr _pristan5_(C19 iso_prenoid)_, 1 44 21 4_, 81 151 in octadecane 1 45 41 1 191 311 IPhy _12hytane (C20 iso_prenoica_ i 45.61 I 51 111 r- 1 -, In-C19 Inonadecane 1 46.70 T 12 2 ___4n-C20 Emosane 1_24_ 171 !— I 4 47 g H_ 171 ■ in-C21 iheneicosane 12 k In-C22 idocosane I 50 21 t I '11 161 I in-C23 itncosane t 51 28 la 4 14 1 n-C24 etracosane 4 52 32 1 74_ 111 1 n-C25 I pentacosane 1 53 31 I 71 1 n-C26 I hexacosane I 54 35 _i_ 51 91 1 n-C27 lileptacosane 5 50 51 .1 1 _, ----,- f r - _411-C28 toctacosane _l___ 56 79 1 91_ 3 In-C29 inonacosane I 58 25 1 8 1 H - n-C30 tnacontane 4 59.93 4 21 84 n-C31 hentnacontane 1 61 85 I, 21 61 -4- ! In-C32 dotnacontane 4_ 64 07 4 11 41 _4_ In-C33 - Tt a ntriacontane _A__ 66 62 1 11 61 tetratnacontane 69 69 I _in 01 pentatnacontane 0 00 7 0 Ell 1 rn-C36 4hexatnecontane , 1 0 -1- 01 r--- -,— r --r- V-C37 [heptatnacontane 0 00 01 0 1 n-C38 loctatnacontane 0 00 at ___ 0 1 -1- ki --F I -C39 Inonatnacontene 1_ 0 00 04, . 01_ 1 4n-C40 _Itetracontane 4_ 0 00 J 01 04 I -- _4n-C41 Ihenetetracontane 1 000 1 01 01 1n L 0 oo i 01 Di I t d r o a t e e tr t r In-C43 1 000 1 0 b-CAROTANE beta-carotene 1 0 00 q 1 0 _ ,— --,— l- or , n-C44 itetratetracontene 0 00 'r , 01 _ I - _ _ • 1n-C45 In-C46 pentatetracontane ihexatetracontane 0 00 0 or 0, 0, Humble Geochemical Services Division • Humble Geochemical Services 218 Higgins Street Humble, TX 77338 ����.,� P. O. Box 789 Humble, TX 77347 Alm Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Client ID: API: HGS ID: 07 -4547- 198186 County,State: AK Type: core Lease Well: Aklaq #6 Depth: 7125.6(ft) Field: Formation: Basin: Country: Gas Chromatography interpretive Ratios Interpretive Interpretive Ratios Ratios Ratios by Area Mango Ratios Pristane / Phytane 1.31 P1 not available Pristane / nC17 0.22 P2 not available Phytane / nC18 0.36 P3 not available nC18 / (nC18 + nC19) 0.60 5N1 not available nC17 / (nC17 + nC27) 0.88 6N1 not available Carbon Preference Index 1.11 N2 not available • Totals by Weight % Invariant Ratios Normal Alkanes not available K1 not available Isoalkanes not available K2 not available Branched Alkanes not available Cycloalkanes not available Ring Preference Ratios Aromatics not available 5N1 / 6N1 not available P3 / N2 not available Halpern Ratios' Tr1 #DIV /0! Thompson Ratios Tr2 #DIV /0! Bz / nC6 #DIV /0! Tr3 #DIV /0! Tol / nC7 236.09 Tr4 #DIV /0! (nC6 + nC7) / (CH + MCH) 0.33 Tr5 #DIV /0! Isoheptane Value #DIV /0! Tr6 not available nC7 / MCH 0.33 Tr7 #DIV /0! CH / MCP #DIV /0! Tr8 #DIV /0! nC7 / 2 -MH #DIV /0! C1 #DIV /0! nC6 / 2,2 -DMB #DIV /0! C2 #DIV /0! Heptane Value 24.83 C3 #DIV /0! C4 #DIV /0! C5 #DIV /0! 1 Halpem, H.1., 1995. APPG Bull.: v.79, p801 -815 2 Mango, F.D., 1994. GCS: V.58, p.895 -901 3 Thompson, K.F.M., 1983. GCA: v.47, p303 -316 • Humble Geochemical Services Division H Geochemical Services 218 Higgins Street Humble, TX 77338 �. • kill- P. O. Box 789 Humble, TX 77347 Division of Humble Instruments &Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 Client: Talisman Energy Client ID: Saturate Biomarker Interpretive Ratios HGS ID: 07 -4547- 198186 Well: Aklaq #6 Interpretive By By Depth: 7125.6(ft) Ratios Area Height Field: Lease Terpanes (m /z 191) Formation: C19t/C23t #DIV /0! #DIV /0! Basin: C22t/C21t #DIV /0! #DIV /0! County,State: AK C22t/C24t #DIV /0! #DIV /0! Country: C24t/C23t #DIV /0! #DIV /0! C26t/C25t #DIV /0! #DIV /0! Bulk Properties C24Tet/C26t #DIV /0! #DIV/0! C23t/C3OH 0.00 0.00 API ( °) C24Tet/C3OH 0.00 0.00 S ( %) C28BNH /C3OH 0.00 0.00 Saturate ( %) 25- Nor /C3OH 0.00 0.00 Aromatics ( %) C29H /C3OH 1.22 1.11 Resin ( %) C30DiaH /C3OH 0.76 0.64 Asphaltene ( %) Ole /C3OH 0.17 0.42 S Sat ( %o) C30Ts /C3OH 0.10 0.17 8 Aro ( %o) Gam /C3OH 0.13 0.14 6 Res ( %) Gam /C31 HR 0.28 0.30 S Asp ( %o) C35HS /C34HS #DIV /0! #DIV /0! • S "C Oil ( %o) C35 Homohopane Index 0.00 0.00 Whole Oil /Extract GC Ts /(Ts +Tm) 0.66 0.57 C29Ts /(C29Ts +C29H) 0.26 0.25 Mor /C3OH 0.11 0.18 CPI C32 S /(S +R) 0.65 0.54 Pristane /n -C17 Phytane /n -C18 Steranes (m /z 217) Pristane /Phytane % C27 aaa 20R 43.5 32.6 C28 aaa 20R 18.1 28.0 % C29 aaa 20R 38.4 39.4 C 27 -C 28-c 29 C27 Dia /(Dia +Reg) 0.61 0.66 a13Q Steranes (C21 +C22)/(C27 +C28 +C29) 0.19 0.21 ® C29 a(3(3 /(aaa +a(V) 0.47 0.50 C29 aaa 20S /20R 0.37 0.70 C29 aaa 20S /(S +R) 0.27 0.41 MI a66- Steranes (m /z 218) % C27 413 20(R +S) 41.8 36.8 % C28 a(3(3 20(R +S) 23.6 25.5 C29 a(3(3 20(R +S) 34.6 37.6 Tricyc C29/C27 4(3 Sterane Ratio 0.83 1.02 Tricyclic/Pentacyclic Terpanes 0.04 0.05 Steranes/Terpanes 0.73 0.71 Tricyclic, % Tricyclic Terpanes 2.4 2.8 Pentacyc Pentacyclic % Pentacyclic Terpanes 55.6 55.9 Terpanes & % Steranes 42.1 41.4 Steranes • Humble Geochemical Services Division Hum Geochemical Services 218 Higgins Street Humble, TX 77338 R fr - P. O. Box 789 Humble, TX 77347 • nu re ] Division of Humble Instruments & Services, Inc. Telephone: 281 - 540 6050 Fax: 281 - 540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07- 4547 - 198186 Country: Well: Aklaq #6 Depth: 7125.6(ft) Field: Lease Formation: Saturate Biomarker Integration Results (Steranes) ton Peak I Compound R.Time Peak ppm I Peak ppm Label Name I (min.) Area I (A.) I Height (Ht.) I 217 S21 IC21 sterane . 47.15 1 1717 4.61 5211 4.2 - - -- - -- --- --- 217 S22 C22 sterane 49.83 I 2059 5.5 6891 5.5 ..... ..... 217 27DbaS C27 ba 20S diacholestane 57A1 3890 10.5 12201 9.7 . ,. 217 127DbaR C27 ba 20R diacholestane • 57.87 2454 6.61 834 6.7 --- --- - -- - 217-128DbaSA C28 ba 20S diasterane a 58.91 2966 8.0 724, 5.8 217 128DbaSB 1 C28 ba 20S diasterane b 59.02 } 1980 5.3 647. 5.2 217 128DbaRA I C28 ba 20R diasterane a 59/3 2049 5.5 4821 3.8 217 128DbaRB IC28 ba 20R diasterane b 59.80 1368 3.7, 505 1 4.0 217 127aaS !C27 aa 20S cholestane 60.41 2409 6.5; 6281 5.0 217 27bbR 1 C27 bb 20R cholestane 60.51 ' 4265 11.5' 9981 8.0 217 27bbS C27 bb 20S cholestane 60.71 2309 6.2 532 4.3 410 1 ._... 217 127aaR 1C27 aa 20R cholestane 61.20 1710 4.6 434 3.5 217 '28aaS 'C28 aa 20S ergostane 62.36 427 1.1 243' 1.9 217 128bbR _IC28 bb 20R ergostane 62.56 1 1080 2.9, . 2871 2.3 217 128bbS IC28 bb 20S ergostane 62.70 ! 2576 6.91 5421 4.3 217 28aaR C28 as 20R ergostane 63.35 . 711 1. 9' 3731 3.0 217 129aaS IC29 aa 20S stigmastane • 63.88 j 551 1.51 369 2.9 217 f 29bbR C29 bb 20R stigmastane • 64.18 902 2.41 4681 3.7 217 29bbS C29 bb 20S stigmastane 64.25 ! 916 2.5, 4211 3.4 217 129aaR C29 as 29R stigmastane 65.01 1506 4.1 525: 4.2 218 '27bbR C27 bb 20R cholestane 60.54 2754 7.4 6271 5.0 218 27bbS C27 bb 20S cholestane 60.71 2114 5.71 492 3.9 218 I28bbR IC28 bb 20R ergostane I 62.54 j 931 2.5' 318 2.5 218 128bbS } C28 bb 20S ergostane 62 1815 4.9 4581 3.7 218 29bbR a 1C29 bb 20R stigmastane . 64.16 a. 2179 5.9 508 _ 4.1 218 29bbS IC29 bb 20S stigmastane . 64.27 ; 1846 5.01 635 5.1 259 27DbaS ,C27 ba 20S diacholestane 57.12 L 3128 8.4; 855; 6.8 259 27DbaR 1C27 ba 20R diacholestane 57.86 j 1877 5.01 ....... 619 . ..... 4.9 259 28DbaS. C28 ba 20S diaergostane a 58.92 3511 9.41 724 5.8 259 28DbaSB C28 ba 20S diaergostane b 59.01 2229 6.0 7 5.9 259 28DbaRA I C28 ba 20R diaergostane a a a , 59.75 I _ 1160 3.1 615; 4.9 a.a 259 28DbaRB C28 ba 20R diaergostane b • 59.82 2086 5.6 698 5.6 259 29DbaS C29 ba 20S diastigmastane 60.52 4118 11.1 749, 6.0 259 29DbaR C29 ba 20R diastigmastane 61.76 j 1301 3.5 481' 3.8 259 '30TP1 1C30 Terpane 65.84 1142 3.1 534 4.3 -- - - - - --- - - - - - -- 259 30TP2 1 C30 Terpane 65.88 1 1898 5.1 I 6211 5.0 t 217 b- Cholane 5b- cholane (inter. STD) _ 54.28 1 26992 72.6 9089 72.6 218 b- Cholane j 5b - cholane (inter. STD) . 54.28 13746 72.6 4279 72.6 • 1 1 Humble Geochemical Services Division 218 Higgins Street Humble, TX 77338 lir Humble Geochemical Services P. 0. Box 789 Humble, TX 77347 • ei000", MP ili Division of Humble Instruments & Services, Inc. Telephone: 281-540 6050 Fax: 281-540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07-4547-198186 Country: Well: Aklaq #6 Depth: 7125.6(ft) Field: Lease Formation: _ -------- T:9T - rate Biomarker integration Results (Terpanes) , , ton I Peak I Compound I R.Time Peak ppm I Peak I ppm Label I Name I (min.) Area (A.) I Height I (Ht.) ' 12 - 1 - 1 - D- - carotane 191 1C19t !C19 tricyclic diterpane ' 0.00 01 0.0 0 0.0 ; 191 C2Ot 1C20 tricyclic 0 diterpane : 0.00 0.0 0 0.0 191 1 ._ 1 1 C21t C21 tricyclic diterpane 0.00 0.0 0 0.0 1 - - 0 , - 191 1C22t ,C22 tricyclic terpane . 0.00 01 0.0 0 0.0 191 1C23t 'C23 tricyclic terpane . 1 0.00 . 01 . 0.01 . . .0 0.0 ... . ... . .... , 191 ,C24t C24 tricyclic terpane ,.. 0.00 01 'o.0 E o 0.0 191 TOY5iS 1C25 tricyclic terpane (S) 0.00 OT 0.0 0 0.0 191 1C25tR 1C25 tricyclic terpane (R) ' 0.00 01 0.0: 0; 0.0 191 1 C24T C24 tetracyclic terpane (TET) 0.00 . 0 0.0. 0 0.0 191 IC26t5 C26 tricyclic terpane (S) 0.00 01 . . .. 0 _. . 0 . . .. . 0.0 ._,. . _.. . . . ..... i . 0 . 191 1C26tR 1C26 tricyclic terpane (R) : 0.00 01 0.0 . 0: 0.0 • 191 1C28tS 1C28 extended tricyclic terpane (S) ' 0.00 01 0.0 0' 0.0 191 1C28tR • ' C28'extended tricyclic terpane (R) ' 0.00 ' 01 0.0 c 0.0 191 C29tS C29 extended tricyclic terpane (S) : 0.00 0 0.0. 0: 0.0 191 C29tR 1C29 extended tricyclic terpane (R) ' 0.00 01 4-- 0.0 0' 0.0 191 1C3OtS !C30 extended tricyclic terpane (S) . 6_2_,.70 15341 4.1: 453 3.6 191 1C30tR C30 extended tricyclic terpane (R) 63.05[ 587 1.6 312. 2.5 . 191 1Ts . .. 1Ts 18a(H)-trisnorhopane_ . . , _61.61 _ . . 39431 10.6 1052 8.4 191 1Tm 1Tm 17a(H)-trisnorhopane i 62.27 ■ 20451 5.5: 803- 6.4 . . 191 ' C28BNH C28 17a18a21b(H)-bisnorhopane : 0.00 1 0 0.0 0. 0.0 1 191 1Nor25H , C29 Nor-25-hopane ' 0.00 01 i- 0.0 0. 0.0 '- , 191 C29H iC29 Tm 17a(H)21b(H)-norhopane : 65.00 74931 20.1' 2111. 16.9 191 ;C29Ts 1C29 Ts 18a(H)-norneohopane . 65.11 2578 i 6.91 7151 5.7 191 1C30DiaH 1C30 17a(H)-diahopane - 65.44 4680 12.6 1224 9.8 191 INormor 1C29 normoretane 65.89 60301 16.2 1357 10.8 191 i a-Ole !a-oleanane 66.38 371' 1.0 431: 3.4 _.. . .. . . _. . . ..,. ... .. . . ._ . . _ . .. ... 191 lb-Ole lb-oleanane 66.42 6501 1.7' 371 • 3.0 I 191 C3OH C30 17a(H)-hopane 66.59 .-4- 6143 16.5 1905 15.2 191 C30T5 !17a(H)-30-nor-29-homohopane 66.88 638 1- 1.7: 327. 2.6 ■ . _ 676 191 Mor C30 moretane ' 67.28 1.8: 345. 2.8 191 C31HS C31 22S 17a(H) homohopane . 68.40 4765 12.8 1232: 9.8 191 C31HR C31 22R 17a(H) homohopane 68.61 2916, 7.8: 890 7.1 .,.. 191 . iGam 1gammacerane ' 68.83 8261 2.2: 270- 2.2 --, _ . 191 1C32HS , C32 22S 17a(H) bishomohopane : 69.82 24461 6.6 843 6.7 1 1 191 C32 22R 17a(H) bishomohopane 70.11 13421 3.6' 7207 5.8 191 C33HS 1C33 22S 17a(H) trishomohopane . 71.48 14611 3.9' 436' 3.5 191 C33HR 1C33 22R 17a(H) trishomohopane . 71.90 _l__ 10301 2.8: 409 3.3 _ , .191 C34H5 . . i C34 . 22S 17a(H) extended .. . 0.00 .. . . . o . . 0.Q, . . 0 0.0 191 C34HR 'C34 22R 17a(H) extended hopane , 0.00_1_ 01 0.0 0. ' 0 191 C35HS C35 22S 17a(H) extended hopane ; 0.00 1 - ell - 0.0: 0 0.0 191 C35HR 1C35 22R 17a(H) extended hopane 0.00 ; ' 0.0: 0' 0.0 . 0 1 1 ----- -- I • • 411 Humble Geochemical Services Division • - Humble Geochemical Services 218 Higgins Street Humble, TX 77338 4 «��.. P. 0. Box 789 Humble, TX 77347 i Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Saturate GC -MS HGS ID: 07- 4547 - 198186 Ion Chromatoarams 12000 1 m/z 217: Steranes `v 10000 - 8000 - c c a 6000 - rn o 2 4000 - $ 1 I o 2000 1 N s " 0 44 48 52 56 60 64 68 Retention Time (min.) 6000 hi /z 218: Steranes 2 5000 - u 4000 - a c a 3000 - 27, w + ( 2000 - ^■ 1000 - ��aa NAA ,A1A4 ` 0 44 48 52 56 60 64 68 Retention Time (min.) 4000 m/z 259: Diasteranes 3000 - 0 d u I� ! ‘11j\IA: C 2000 - 1000 - 0 44 48 52 56 60 64 68 Retention Time (min.) Humble Geochemical Services Division • Humble Geochemical Services 218 Higgins Street Humble, TX 77338 4 .ur. P. 0. Box 789 Humble, TX 77347 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Saturate GC -MS HGS ID: 074547- 198186 Ion Chromatoarams 7000 m 191: Tri -, tetra- and pentacyclic Terpanes 6000 - 5000 - v i I i 4000 � � � � M V� r#44 E U 3000 CD 2000 -1 1000 p 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 3500 m/z 177: Norhopanes 3000 - 2500 - I I ii4 , c 2000 2 a y � U, 1500 - y` 4'� T ) rN i, d I ( 0 CI i1 1000 - 500 0 , , r , . 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) 10000 m/z 205 9000 - 8000 - d 7000 - - 6000 - c 2 5000 - 2 4000 - 3000 , 2000 - p I , 1000 - IV`�JIV 0 . , 1 40 44 48 52 56 60 64 68 72 76 80 Retention Time (min.) Humble Geochemical Services Division • 218 Higgins Street Humble, TX 77338 Humble Geochemical Services 1 nL •` Te l O e p hone:281 -540 050 Fax X281- 5402864 � +C !' Division of Humble Instruments & Services, Inc. Client: Talisman Energy Basin: Client ID: County,State: AK FIGS ID: 07- 4547 - 198186 Country: Well: Aklaq #6 Depth: 7125.6(ft) Field: Lease: Formation: Aromatic Biomarker interpretive Ratios Interpretive By By Ratios Area Height Naphthalenes 3 79 DNR- 1= (2,6 +2,7) /(l,5)DMN 5.29 DNR- 2 =(2,6 +2,7)/(1,4 +2,3)DMN 2.68 1.80 TNR1= (2,3,6)/(1,4,6 +1,3,5)TMN 0.92 1.02 2.33 TDE -1= 1,2,5 -TMN /1,2,4 -TMN 2.34 0.32 TDE -1= 1,2,7 -TMN /1,2,6 -TMN 0.28 Phenanthrenes 0.47 MPI- 2= 3(2MP) /(PHEN +1 MP +9MP) 0.45 MPI- 1= 1.5(2MP +3MP) /(PHEN +1 MP +9MP) 0.44 0.43 • Rc(a)= 0.6(MPI -1) +0.37 (for Ro <1.3) 0.63 0.63 Rc(b)= 0.6(MPI- 1) +2.3 (for Ro >1.3) 2.56 2.56 MDR= 4MDBT /1 MDBT 3.28 3.90 Rm= 0.40 +0.30(MDR)- 0.094(MDR) 2 +0.011(MDR) 0.76 0.79 MDR23= 23MDBT /DBT 0.18 0.19 MDR1 =1MDBT /DBT 0.08 0.07 DBT /Phenanthrene 0.34 0.37 Triaromatic Steroids TAS 20 +21/all TAS #DIV /0! #DIV /0! TAS 20/20 +27 #DIV /0! #DIV /0! TAS 21/21 +28 #DIV /01 #DIV /0! TAS C28/C26 20S #DIV /0! #DIV /0! TAS C28/C27 20R #DIV /0! #DIV /0! 26 TAS #DIV /0! #DIV /0! % 27 TAS #DIV /0! #DIV /0! % 28 TAS #DIV /0! #DIV /0! % 29 TAS #DIV /0! #DIV /0! Monoaromatic Steroids #DIV /0! MAS Dia /Reg C27 #DIV /0. i MAS 21 +22/all MAS #DIV /01 #DIV /0! 27 MA #DIV /0! #DIV /0! % 28 MA #DIV /0! #DIV /0! % 29 MA #DIV /0! #DIV /0! TAS /(TAS +MAS) #DIV /0! #DIV /0! TAS28 /(TA28 +MA29) #DIV /0! #DIV /0! I Humble Geochemical Services Division 218 Higgins Street Humble, TX 77338 I. 11 11 .1: Humble Geochemical Services Tel 281 -540 6050 Humble, x: 2 1 2864 Di o f Humble Instr & Services, Inc Client: Talisman Energy Basin: County,State: AK Client ID: HGS ID: 07.4547- 198186 Country: Well: Aklaq #6 Depth: 7126.6(ft) Field: Lease: Formation: Aromatic Biomarker Integration Results 1 1 (Naphthenes, Dibenzothiophene, Phenanthrenes) 1 Comppund R.Time Peak ppm 1 Peak Peak 1 ppm I Ion Label Name (min.) Area (A.) Height (Ht.) ___ 19.6; 9415' -- 15.7 Naphthalene 14.37 _ 34987; - 146.2 _ 128 NAPH_ - --1 18.34 290805 -- 87386. __ 142 2MN -_- ?-Methylnaphthalene 18 88 2218981 162.7; 124 21 61356: 102.6 142 1MN ;1-Metlnaphthalene_-- :1 N -- 12- Ethylnaphthalene __ - -_ 21.92 64171 35.91 18484' 30.9 156 1EN 11-Ethyllnaphthalene __ - - -- 21.94 49970 28.0T 18692_ 4 31.3 156 260MN 72,6 - Dimethylnaphthalene 22.34 283608 158.7 70214• 7488 117.5 22.39 252705' _ 141.4 9 125.3 156 27DMN 2,7- Dimethylnaphthalene - 22 85 621315 347.6, 149071: 249.4 1 13 +17DMN 1 1. 3 & 1,7- Dimet�lnaphthalenes I 156 16DMN T,6- Dimethylnaphthalene j 22.97 540409 _ 302.41 148712' 248.8 23.50 1078501 60.3 ; 32673. 547 156 23DMN 2,3- Dimethylnaphthalene - 101407; _..- 1_56 14DMN 1 1,4- Dimethylnaphthalene 23.53 921571 51. 1 47881' 80.1 64.0 80.1 56.71 38278: 156 15DMN 11,5 - Dimethylnaphthalene 23.55 156.12DMN 11,2 - Dimethylnaphthalene 24.01 72168! • 170 86 EMN Eth I -meth I -Na hthalene__ 25.87 145614 25547 40.41 81.5 34342. 170 EMN � Eth I -meth I- Naphthalene 26.40 60629 33.9 19235' 42.7 57.4 170 137TMN_ 1,3,7 - Trimethylnaphthalene 26.61 305025 170.7 83141 • 139.1 170.136TMN 1,3,6 - Trimethylnaphthalene 26.80 359794 201.3 115544' 193.3 170 .146 +135T 1( 1,4,6 +1,3, ),Trimethylnaphthalenes 2� 30 27867 _ 143.0 69387 116.8 170 236TMN 2,3,6- Trimethylnaphthalene -__ 1 127TMN 11,2,7- Trimethylnaphthalene 1 27_79 ' 768371 43.0 18856. -31 170 167 +126T 16,7_ +1,2,6)- Trimethyllnaphthale 1 27.88 271895; 152.1 58443: 97.8 = 170 124TMN 1 4- Trimethylnaphthalene - 28.34 - 31486 17.6 =- _10047' 16.8 170 125TMN 1,2,5- Trimeth Ina•hthalene - 28.58 73579 41.2 23415._ 39.2 184 1357 1,3,5,7- Tetramethylnaphthalene 30.72 112437 62.9 23302: 39.0 184 1367 1,3,6,7- Tetramethylnaphthalene 31.44 1379501 77.2 44784' 74.9 184 1247 -111(1,2,4,7+1,2,4,6+1,4,6,7)-TetraMNs i 31.90 ' 951941 53.31 28273 47.3 184 1257 -__ 11,2,5,7- Tetramethylnaphthale 4-- 32.02 54140 30.31 16956 28.4 184_ 2367 2,3,6,7- Tetramethylnaphthalene 1 32.27 - -- 22132 12.41 7982 - -- 13.4 184 1267 1,2,6,7- Tetramethylnaphthalene ! 32.54 37481 21.01 11979 20.0 184 1237 1,2,3,7- Tetramethylnaphthalene 1 32.65 23838 13.31 7221 12.1 184 1236 1 ,2,3,6- TetramethylnaRhthalene- _ 32.84 _3 3821 .- 18.91 -- 11625_ - 19A 184 1256 1,2,5,6 - Tetramethylnaphthalene 33.32 - 60459 33.88 16353: _- 27.4 33.53 341388 191.01 - 93214: 155.9 184 DBT '4 Menzothiophene _ 36.66 84879 47.5; 25249• -- 42 198 4MDBT j4 Methyl Dibenzothio hene 30.4 37.21 62831 35.21 1815 _ 198 2 +3MDBT ,2 & 3 Methyl Dibenzothiophenes 37.80 258491 14.5; 6480. 10.8 198 1MDBT �1 Methyl Dibenzothiophene_ - - - -, _ 1 --- - 21.23_' 399918' 223.7 115861 193.8 154 BP_ T 2 - Meth - 22.02 14805 8.3 4503 __ - 7.5 168 •2MBP 2 -Meth !biphenyl 168 DPM Diphenylmethane __ 1 23.03 60339 33.8 15118 25.3 . 25.01 538318 301.2 184071. _ 307.9 168 3MBP 3- Methylbiphenyl DBF 1 IDib 25.31 160045 _ 89.5; 49822' 83.3 168 BF 168 iben zofuefU ran - 26.05 27427811 153.5! 73122, 122.3 - -_, 1 , 178 PHEN _ _ TPhenanthn ne - T 34.41 100 559.54 248706: 416.0 192 3MP 3 - _Methylphenanthrene 37.87 2280901 127.61 55680 : __ - 9 192 2MP � - Methylphena nth re ne _ 1 38_02 2434951 136.2 66512: - 111.3 192 9MP 9- Methylphenanthrene 1 38.55 339881 190.2 91069• - 152.3 • 192 IMP 11- Methylphenanthrene 1 38.69 ' 276405 154.71 82906 138.7 Humble Geochemical Services Division ■ • , 218 Higgins Street Humble, TX 77338 `'- M' Humble Geochemical Services P. O. Box 789 Humble, TX 77347 I Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Basin: Client ID: County,State: AK HGS ID: 07 -4547- 198186 Country: 0 Well: Aklaq #6 Depth: 7125.6(ft) Field: Lease: Formation: Aromatic Biomarker Integration Results (Dimethyl- Phenanthrenes, Benzohopanes, Triaromatic Steroids, Monoaromatic Steroids) Ion I Peak I Compound R.Time Peak ppm Peak ppm • Label Name (min.) Area (A.) Height (Ht.) 1 206 26DMP - 2,6- Dimethylphenanthrene 41.31 54247 1 1 30.4 16078 206 36DMP 3,6- Dimeth 1 henanthrene 41.10 27903' 15.6' 8064 13.5 26.9 206 27DMP 2,7- Dimethylphenanthrene 41.41 37830 21.2 117221 19.6 206 '39DMP (3,9 +3,10+ 2,10 +1,3) - Dimethylphenanthrenes 41.81 320710 179.4 761531 127.4 206 29DMP (2,9 +1,6)- Dimethylphenanthrenes 41.98 96745 54.1 22143y 37.0 206 17DMP 1,7- Dimethylphenanthrene 42.10 834871 46.71 267411 44.7 206 23DMP 2,3- Dimethylphenanthrene 42.30 471511 26.4 13692 22.9 • 206 19DMP 1,9- Dimethylphenanthrene 42.39 657381 36.8 201791 33.8 206 18DMP 1,8- Dimethylphenanthrene 42.73 j 295091 16.5 8626 14.4 206 ,12DMP 1,2- Dimethylphenanthrene 43.14 25223 14.1 7323 12.2 . , . t 0 BH33 C33 Benzohopane 0 00 0 0.01 � P.O 191 BH32 C32 Benzohopane 0.00 0 0.01 0, 0.0 191 01 191 BH34 C34 Benzohopane 0.00 0 OA O 0.0 191 BH35 C35 Benzohopane 0.00 0 0.01 1 0 0.0 231 1TA20 C20 Triaromatic Steroid � 0.00 C 0 0.0' 0 0.0 231 2TA21 .C21 Triaromatic 0.00 0; 0.0 0 0.0 231 3TA26 C26 20S Triaromatic 0.00 0 0.0 0 0.0 231 '4TA26 +27 C27 20S & C26 20R Triaromatic + 0.00 _ 01 0.01 0 _ 0.0 i C 1 1 1 _ 0.0 231 5TA28 C2 20S Triaromatic 0.00 01 0A 01 0.0 231 6TA27 C27 20R Triaromatic _0.00 0� 0.0, 0 231 7TA28 C28 20R Triaromatic 0.00 0 1 0.01 0 0.0 231 8TA29 C29 20R Triaromatic (24 n- propyl) 0.00 01 0.0' OF 0.0 253 1MA21 C21 Ring -C Monoaromatic Steroid 0.00 0 • 0.0 01 0.0 253 2MA22 C22 0.0 253 4MA27 C27 Dia n 10b(H),5b(CH3) 20S j 0.00 1 01 0.0' 0 253 3MA27 C27 Reg 5b(H),10b(CH3) 20S 0.00 I 0 0.01 0 0.0 0.0 253 5MA27 C27 DialObH,5bCH3 20R +Reg5bH,10bCH3 20R 0.00 O 0.0 01 0.0 253 6MA27 - 1C28Da eg5bH,10bCH320S 0. 0 0 o! 0.0 11 253 78 _ 0.0 253 8MA27 C27 Reg 5a(H),10b(CH3) 20R 0.00 0 0.0 01 0.0 253 9MA28 C28 Reg 5a(H),10b(CH3) 20S 0.00 0 0.0' 01 0.0 253 '1OMA28 - C28 Dia 10aH,5aCH3 20R +Reg5bH,10bCH3 20R I 0.00 } of 0.OI 01 0.0 253 11MA29 C29 Dia 10bH,5bCH3 20S +Reg5bH,10bCH3 20S { 0 0 0.01 0 0.0 E 1 01 253 12MA29 C29 Reg 5a(H),10b(CH3) 20S 0.00 0 0.01 0, 0.0 253 13MA28 `C28 Reg 5a(H),10b(CH3) 20R 0.00 0 0.01 0I, 0.0 253 14MA29 C29 Dia 10bH,5bC H 3 20R +Re g 5bH 10bCH3 20R 0.00 0.0 0 0.0 h n 253 15MA29 C29 Reg 5a(H),10b(CH3) 20R 0.00 0 0.0 0' 0.0 • 230 OTP Ortho terp e y 1 (Inter. STD) 3 7.57 1 115558 64.7: 38652 64.7 Humble Geochemical Services Division • -- Humble Geochemical Services 218 Higgins Street Humble, TX 77338 4 ,,, P. 0. Box 789 Humble, TX 77347 MIP" - 11111 Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 198186 ion Chromatoarams 160000 m m/z 156: Dimethylnaphthalenes 140000- 120000 - ,00000 - R 80000 - f 2 V 6 0000 - d Z 5 40000 - std CAY 20000 - 20 24 28 32 36 Retention Time (min.) 40 120000 i ` m/z 170: Trimethylnaphthalenes z 100000- 5 h $ 80000 - c a 60000 - I N w in I I O 40000 - m 5 z 5 i `i • 20000 - w 1 20 24 28 32 36 Retention Time (min.) 40 100000 s0000 mYr 184: Tetramethylnaphthalenes 80000 - 70000 - 60000 - Q 50000 - N N f 40000 - C9 1,i4 I T U 30000 - n, ,I ^`p t p11�� �,, . ' 20000 - , i g ^I^ �` + ,0606 - M h\fiL ( \, 20 24 28 32 36 Retention Time (min.) 40 35000 30000 - f m/z 198: Pentamethylnaphthalenes m m 25000 - E M 20000 - ry a 5 15000 - F CS I o 10000 - 2 i p�� °W �).i' N Y�� saoo- °° U " "V �wU A,`.,,o 0 ? . 20 24 28 32 36 Retention Time (min.) 40 ID Humble Geochemical Services Division • • e Humble Geochemical Services 218 Higgins Street Humble, TX 77338 P. Box 789 Humble, TX 77347 i MUM Telephone: 281 -540 6050 Fax: 281 -540 2864 lE — - -- Division of Humble Instruments & Services, Inc. Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 198186 Ion Chromatoarams 1 40000 � m/z 230: Ortho- Terphenyl (Inter. Std) 35000 - 30000 - 25000 - w a 20000 - 4 N g 15000 - 10000 - 5000 - 40 42 0 36 3 8 Retention Time (min.) 32 120000 O m/z 154: Biphenyl S 100000 - • d 80000 - I c 2 80000 - 4 N 2 U (0 40000 - 20000 - 0 _ _ - - 24 26 28 18 20 22 Retention Time (min.) 200000 1l► /z 168: Methylbiphenyls (MBP) 180000 - 160000 - 140000 1 v 120000 - c a 100000 - 4 0 N `z 80000 - 0 a 60000 - 40000 - 2 20000 - n n / �n r �/`� M �� - A� Jl 28 0 20 22 24 26 Retention Time (min.) 18 ID Humble Geochemical Services Division _ 218 Higgins Street Humble, TX 77338 • - Humble Geochemical Services P. 0. Box 789 Humble, TX 77347 >.Mb`` Telephone: 281 -540 6050 Fax: 281 -540 2864 ,. R Division of Humble Instruments & Services, Inc. Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 198186 I Ion Chromatoarams 300000 m/z 178: Phenanthrene 250000 - m 200000 - v c 2 150000 - Q N 2 U C� 100000 - 50000 - .,-n rs /--- ',--.- ,_' ,., 41 43 45 31 33 35 37 39 Retention Time (min.) 100000 1 m/z 192: Methylphenanthrenes 90000 - I I 80000 - E 70000 - c 00000 - I i c a 50000 - Q N `i 40000 U 0 30000 - 20000 - U-- 10000 - 0 -- 3 3 3 3 39 41 43 45 Retention Time (min.) 31 80000 g m/z 206: Dimethylphenanthrenes 70000 - 60000 c 50000 -41 c 2 40000 - o a g N .. gIi m U 30000 - 20000 - o N m 10000 - �� f 45 31 33 35 37 3 9 41 43 Retention Time (min.) III Humble Geochemical Services Division • - - Humble Geochemical Services 218 Higgins Street Humble, TX 77338 M � M „` 1 ,) , , P. 0. Box 789 Humble, TX 77347 "l Division of Humble Instruments & Services, Inc. Telephone: 281 -540 6050 Fax: 281 -540 2864 Client: Talisman Energy Client ID: Key Aromatic GC -MS HGS ID: 07 -4547- 198186 Ion Chromatoarams 6000 m/z 191: Benzohopanes 5000 - 4000 - c e c a 3000 - 4 0 � ^ U Y' U 2000 - 1000 - 70 72 74 76 78 80 Retention Time (min.) 9000 m/z 231: Triaromatic Steranes 8000 - 7000 - • d 6000 - c .e 5000 - i I I c I 11 5 4000 I „d I^ 1 r W �j ti "i I V U 1J MM CO J 3000 - ,I^ r f � 4 2000 - 1 1000- 0 . . . 48 52 56 60 64 68 Retention Time (min.) 35000 m/z 253: Monoaromatic Steranes 30000 - 25000 - ■ c i 20000 - 4 &, 15000 - 0 10000 - 5000 - , j) \JJ'IL- j' ''' \,,,, 1 0 42 46 50 54 58 62 Retention Time (min.) • Humble Geochemical Services Division Sedimentology of the Kugrua Sandstone from the AKLAQ #6 Well, North Slope, Alaska Jason Lavigne April 2007 RECEIVED s =., 0 6 2007 aez -ow /531CS Alaska Oil & Anchorage Gas Cons. Commission I u E ow N mo mum Introduction The Aklaq#6 conventional core was recovered from 7125.0 to 7161.4ft (Md). Like the Aklaq #2 Conventional core (cut in 2006), this core recovered primarily fine to very fine - grained clay -rich sandstone. The sandstones are bioturbated with a suite of Thalassinoides with an overprint of Phycosiphon burrows. There are sparse wave - generated sedimentary structures and some coalified plant material. The sandstones are interbedded with numerous thin, greenish mudstone units which contain starved wave ripples. The base of the core is predominantly mudstone with starved ripples and may correlate to the condensed interval directly beneath the Kugrua sandstone (and separated by an unconformity) in the Puviaq area. The cored interval is interpreted to represent deposition in a distal lower shoreface or shelfal setting of comparable bathymetry. The mudstone interbeds demarcate the feather edge of an isolated shelf sand body. Despite being in the most landward position of the Puviaq seismic anomaly, shallower water, coarser grained facies were not encountered. This was the predicted outcome based on the facies observed in the Aklaq #2 core. mmm.....immommimmil.....mmommimi WELL: Aklaq #6 LITHOLOGY CORE ANALYSIS '2 c . 2 v z zi 1 (7) 4) K DEPOSITIONAL 1 mudstone I i I T I E I - re I 30 % 0101 mD 2D THIN-SECTIONS PHOTOS SETTING STRAT 7125ft 1.--.4 preserved 1 i i - :Tin:T.1 N.. "r" coalified wood - 1 - - Th. 4 . • —' ..." — phosphate? "— ;OD ./.. : 4 K . Thalassinoides - 2 _ --.... _ sid? -- .As,.,iiIi -.1.: th Phycosiphon 7 -3 71 0 ..--ji t......7%..-*:...„ coalified wood c ....• _ • T.' P . e: • • a monets '—' 4 ,.. -4. -• z.14: ,-- Ci) U) wave npples 4v k.c Hekninthopsis f — I R:21VM N- • . - 5 rw4. = rt. CD .--- ■••• 1 """' • * — .-_ _ ' - •ified wood — (D 0 — IISIsmianisdanc wave ripples " o r - __ ......... o — ........,...::_ * . _, ... starved ripples M 3 * _ - - _ - mpefickwifi Hehninthopsis 0. . a) _ _ .s:„ Teichichnus greenish (CD a .,-.. , . r•.;_r. ; ripples a) -, " - , , : • s ■ Theleslinoides - C -,--- CalOSSI surfaoe s o ta) 0 C - --I, C7 M"' 7140ft — 7 -..,:: Teichichnus 0 _ - *Ar itiVtt large Diplocratenen cn — . 4., 77ralassinoides 0 CO CD X — — preserved — • CD (1) CO — .1., -: . V7 . • Phycosiphon 7.; • - 8 .-e. ‚-4. 0 C - Thelessinoides CD =`' CD — • ...'.7 ..t.h (coarse fill) Q. "< — ._ ,...„ coa ed wood Write - 9 kir al CO - l starved ripples - npples --- - CD ...7, — Th alessinoides cakito - 10 CD — — 1 heated frIK _ starved ripples Cn 41•14; — ,-..,,;:- • .... • Thalassinoides CD 0 — -- - - - preserved = -IIN r: '. Theiassinoides CL _ _ .....- 7155ft — mcf212, Th greenish — - - arg= - - coalified wood pyrite - 11 - - '. soft sediment deformation \-- — _ - 12 ___ -. chi wave chnus ripples Sh - Ter elf .1 _.., ri - _ r ...:a6, -IC .A1 1 a , HCS starv "Poes 13 14 (Restricted) _ .„,,..7N,.....--.,,, : 7161.4ft — ' ' '' - - — - T Teichichnus 1 1 1 -- ma NE mis LEGEND TO ACCOMPANY COLUMNAR DESCRIPTIONS Lithology / Accessories Trace Fossils _ ' = mudstone sandstone NM coal clast th Chondrites phy Phycosiphon mudstone clast cv Cylindrichnus p Planolites granules / pebbles diplo Diplocraterion t Teichichnus organics oph Ophiomorpha th Thalassinoides pa Palaeophycus Sedimentary Structures Diagenetic Features ..� low angle cross bedding pv pyrite hummocky cross stratification sid siderite wavy beds r° fracture (with dip) --� ripples wave ripples - starved ripples -u load casts T syneresis crack m om me Ns NE No E No me am NE No NIN AKLAQ #6 pa —.a • _t 1 2 7126.5ft 7127.5ft Photo 1 Heavily bioturbated, very fine- grained, clay -rich sandstone. The unit is bioturbated with a pervasive fabric of Thalassinoides (th) with an overprint of Phycosiphon burrows. Note the sideritic (or phosphatic) concretionary cement (arrowed). Photo 2 Burrow - mottled, very fine- grained, clay -rich sandstone. The unit is heavily burrowed with Thalassinoides, Phycosiphon and Palaeophycus (pa). Note the coalified organic grain (arrowed) and the patchy siderite cement (orange). The numerous white specs in the cemented portion are small pellets (probably fecal in origin). They outline an Ophiomorpha -like burrow wall (oph). NIN mu EN =I No am Nom — — — — — INN =I um =I me AKLAQ #6 x 0 co 1 • -8 • • ; - ---- 1 -0 t•••"*"... 3 4 7129.0ft 7130.0ft Photos 3 & 4 Heavily cemented (siderite?), very-fine-grained, clay-rich sandstone. The numerous white specs are pellets (probably fecal in origin). Note the fractures (arrowed) in this denser portion of the unit. The fracture in Photo 4 would appear to have been open at depth. = EN -- I I ow - - — we I= e— No I NIN AKLAQ #6 4 4 wave ri • • les \t phy` 5 6 7132.0ft 7132.5ft Photos 5 & 6 Interbedded, very fine - grained, clay -rich sandstone and mudstone (dark grey). Much of the sandstone has a greenish tinge which is the result of chloritic clay (possibly after glaucony). The unit appears to be contain low angle lamination (wave - ripples) and is lightly bioturbated by Thalassinoides and Phycosiphon (phy) burrows. Note the fracture plane (arrowed) in Photo 6. iime NE am I ii. ow um EN I = ow = am me i N No No AKLAQ #6 tw pby._ t phy ' T .,. rz } �� diplo -6 e.,. ®. ' th i I k , 7 8 7140.5ft 7144.0ft Photo 7 Long Diplocraterion burrow (diplo) in a very fine - grained, clay -rich sandstone. The darker portion at the upper part of the photo is a cement phase, likely siderite. Photo 8 Heavily bioturbated, clay -rich sandstone. The main bioturbate fabric consists of subtle large Thalassinoides (th) with an overprint of Phycosiphon (phy). In the upper part of the photo, there is an overprinting of a tier of coarser, sand - filled burrows, including Rhizocorallium (rz). EN NE No u im AKLAQ #6 F 4 t F 9 10 7147.0ft 7150.0ft Photo 9 Concentration of conspicuous Chondrites -like burrows (ch) in a very fine- grained sandstone. Other diffuse burrows also appear present. The green color is likely the result of chloritic clays. Note the coaly wood fragment (arrowed) at the top of the photo. Photo 10 Calcite- healed, en echelon fractures (arrowed) in a very fine - grained sandstone. Note the sharp based nature of the sand where it sits erosively on organic mudstones at the base of the photo. AKLAQ #6 I s 4 -4 11 12 7157.0ft 7158.2ft Photo 11 Fine to very fine - grained sandstone with drapes of lighter colored mudstone. Photo 12 Well laminated very fine - grained sandstone and mudstone. The sandstone component is wave - rippled and is greenish due to chloritic clays. Some of the muddier portions are heavily bioturbated (left of scale). elot = me Ns — im N = I= I= um am me = l= AKLAQ #6 0. Sync' I t ch pI . - _ I 1 4 I -s Syn wave ripple 6 13 14 7160.0ft 7160.25ft Photo 13 Lenticular bedded, very fine - grained sandstone in a dark mudstone. Note the well defined wave ripple lamination (arrowed). There is minor soft sediment deformation (load casts) as well as some small Chondrites- like burrows associated with the bases of some of the sandier units. Photo 14 Biogenically reworked very fine - grained sandstone and interbedded mudstone. The burrows include larger Thalassino -like forms (th) as well as smaller Planolites (p1) and Chondrites (ch). There are also several small features resembling syneresis cracks. Note the load - casted ripple (Ic), evidence of soft sediment deformation. The greenish color of the sands at the base of the photo are the result of clays, likely chlorite. S me um N = m AKLAQ #6 4- pl =,G w ave ripple 15 7160.9ft Photo 15 Lenticular beds of wave - rippled, very fine - grained sandstone in darker mudstone. The interval to the left of the scale is almost entirely bioturbated with a suite of Planolites (pl), Teichichnus (te) and Chondrites (ch). Note the greenish color of the burrowed sands, likely the result of chloritic clays. • DIGITAL IMAGING I TALISMAN ENERGY INC. I TALISMAN F.E.X. AKLAQ #6 White Light & Ultra Violet (Slabs) Photography 2007 -05 -18 52139 -07 -4397 1 RECEIVED 00'4. - oo °1 SEP 0 6 2007 153`6- Alaska Oil & Gas Cons. Commission Anchorage Core Laboratories 1 TALISMAN ENERGY INC. 52139 - 074397 07 -05 -12 _ - ALISMAN F.E.X. 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II►II.AA HALLIBURTON Sperry-Bun Surface Data Logging END OF WELL REPORT FEX, L.P. Aklaq #6 HALLIBURTON Sperry Drilling Services I Surface Data Logging END OF WELL REPORT FEX, L.P. Aklaq #6 I 1 Drilling Project � z 2007 f ib/ e4jh R eserve Alaska I TABLE OF CONTENTS 1 1. General Information ' 2. Daily Summary ' 3. Daily Operations (I.A.D.C.) 4. Morning Reports ' 5. Bit Record 6. Mud Reports 7. Show Reports 8. Survey Report 9. Days vs Depth 10. Well Diagram 11. Data CD 12. Formation Evaluation Logs 13. Engineering Log I I HALLIBURTON r Drilling y g Services I I 1 1 GENERAL WELL INFORMATION I Company: FEX, L.P. Rig: Doyon Arctic Wolf Well: Aklaq #6 I Field: Exploration Borough: Barrow State: Alaska I Country: United States API Number: 50- 279 - 20019 -00 Sperry -Sun Job Number: AK -AM- 0004986881 1 Spud Date: 27 Mar, 2007 12:30 hrs Total Depth Date: 14 Apr, 2007 15:00 hrs Rig Release Date: 23 Apr, 2007 14:00 hrs 1 Total Depth: 7280' MD; 7233' TVD North Reference: True Declination: 21.048° 1 Dip Angle: 80.588° Total Field Strength: 57455 nT Date Of Magnetic Data: 25 Mar, 2007 I Wellhead Coordinates N: North 70° 42' 44.66" Wellhead Coordinates W: West 154° 36' 27.78" Drill Floor Elevation: 95.90' I Ground Elevation: 76.70' SDL Engineers: Eugene Payne; Larry Lynch, Chuck Stringer, Kerry Garner I Company Geologist: Jaque Ledbetter; Zenon Kotelko P Y 9 q 1 1 SSDS Unit Number: 115 1 1 1 1 HALLIBURTON 1 Sperry Drilling Services 1 DAILY SUMMARY FEX AKLAQ #6 2_ DAIL Y SUMMARY 26 Mar 2007 Attempt to test starter head, test failed, change seals and re -test to 1000 psi. Pick up 18 joints of heavy weight drill pipe. Pick up diverter, flow lines and mud can. 27 Mar 2007 Pick up 60 stands of drill pipe. Pick up mud motor and BHA for 300' drill out. Bring mud pump online. Prime mud lines and pressure up to 3500 psi. Spud at 12:45 and drill ahead from 80' to 342'. Blow down Kelly and trip out 5 stands. Pick up MWD BHA, Toad sources and load MWD 1 tools. Install corrosion ring and trip in hole. Drill 12 hole from 342 to 400'. 28 Mar 2007 1 Drill 12 hole from 400' to 1541'. 29 Mar 2007 Drill 121/4" hole from 1540' to 1977'. Service rig and top drive. Drill to 2101'. Circulate and clean hole. Wiper trip. 30 Mar 2007 Short trip and back ream from 1477' to 1296' and from 1172' to 1044'. Service top drive. Trip in hole. Pump, circulate sweep and condition mud. Trip out and lay down jars. Stand back 5 joints heavy weight and lay down two nonmagnetic drill collars. Remove nuke sources, download MWD and lay down BHA. Rig up casing running tools and landing joint. Run in hole with casing to 1700'. 31 Mar 2007 Continue running 9 5/8" casing to 2072'. Circulate casing. Rig down casing tools. Rig up and run inner string. Pull out of hole to space out casing. Rig up and run 2 joints to respace casing. Circulate the casing, Rig down casing tools and blow down. Run drill pipe for inner string job. Rig 1 up cement head and break circulation. Pump spacer and cement and chase cement until plug bumped and floats held. Rig down cement head. Pull out of hole with inner string. Back out landing joint and nipple down diverter. 01 Apr 2007 Continue nippelling down diverter, with some trouble cleaning up the cement in the diverter. Nipple up FMC spools and test them to 1000 psi for 10 mins. Nipple up BOP. Change rig pump liners to 5W. Continue to nipple up, install kill line and choke line, function test BOP. Rig up test plug and fill stack. Blind ram door leaking. Drain stack and replace seals and test to 2500 psi. Doors held. Finish testing BOP's. 02 Apr 2007 Finish testing BOP's. Pick up drill pipe. Pick up and rabbit drill pipe. Pressure test the casing to 2600 psi. Pull out of hole. Pick up BHA and set motor to 1.22 bend. 1 03 Apr 2007 Continued to pick up BHA. Run in hole and drill out shoe at 2072'. Drill out cement to 2101'. Circulate hole and perform FIT test. Test yielded 16.0 ppg EMW. 1 1 DAILY SUMMARY FEX AKLAQ #6 1 04 Apr 2007 Directional drill 8'/2" hole from 2602' to 2911'. Slide 206' and rotate 101'. Encountered a gas show of 2500 units between 3408 to 3440'. Service rig and top drive. Directional drill 81/2 " hole from 2911' to 3038'. Slide 80'. Directional drill 8'/2" hole from 3038' to 3662'. Slide at total of 348'. 1 05 Apr 2007 Directional drill 8Y2 " hole from 3662' to 3912'. Circulate and clean the hole. Short trip up to 2072' - 9 5/8" casing shoe. Flow check and clean rig floor. Service rig and top drive and change out saver sub. Run back in hole encounter 8 feet of fill on bottom. Directional drill hole from 3912' to 4286' - slide 286'. 1 06 Apr 2007 Drill 8'/2" hole from 4286' to 4723' - slide 200'. Passed through a gas zone between 4856 to 4930' with a maximum peak of 1170 units. Service rig and top drive and adjust draw works brakes. Drill from 4723' to 5285' - slide 15'. 07 Apr 2007 Drill from 5285' to 5534'. Pump pill, flow check and wiper trip to 3900'. Run back to bottom and encounter 5' of fill on bottom. Drill from 5534' to 6405'. 1 08 Apr 2007 Circulate and continue drilling 81/2" hole from 6405' to 6470'. Began losing mud at a rate of 180 bph. Well flowing back. Shut well in and monitor with no pressure build up. Drill from 6500' to 6554'. Losing mud at 180 bph. Reduce pump rate to 112 spm. Spot LCM pill and short trip 2 stands. Drill ahead at 350 gpm with losses at 80 bph. Pump second LCM pill. Continue drilling ahead and increase pump rate to 478 gpm with losses of 75 bph. Losses slowed to 75 bph with total loss of 750 barrels. 1 09 Apr 2007 Drill from 6782' to 7125'. Circulate and condition mud. Monitor well. Pull 5 stands and pump slug. Short trip to 5500'. Monitor well. Run back to bottom at controlled speed. Monitor well. Break 1 circulation and ream to bottom. Reduce pump rate due to mud loss and monitor well. Spot LCM pill. Pull 5 stands and pump a 30- barrel slug. Monitor well. Well static. Trip 30 stands out of hole. 10 Apr 2007 Continue trip out slowly to prevent swabbing. Flow check at the shoe. Clean clay off BHA and lay down jars and crossovers. Lay down Nukes and download MWD. Test BOP's. 1 11 Apr 2007 Test BOP's. Pull test plug and run wear bushing. Pick up core assembly and trip in hole to 2065'. Circulate bottoms up. Trip in to 4286' and fill pipe. Wash in hole from 4286 to 6532'. Work through tight spot and pump 50 barrel LCM pill with partial returns. Pump another 50 barrel LCM pill. Pump into hole to 7025'. Wash through fill and bridge from 7025 to 7045'. 1 r 2 DAILY SUMMARY FEX AKLAQ #6 1 12 Apr 2007 Continue washing to bottom, 5 ft. of fill accumulated on bottom. Circulate high vis sweep. Start coring at 7125'. Cut core from 7125' to 7163'. Total loss of returns. Pump LCM pill. Continue coring while building volume in active pits with water and waiting on vacuum trucks. Pump HiVis sweep. Continue coring and start regaining returns. Losses slowed to 7 bph. Pump LCM pill. Continue coring to 7163' and regain full returns. Build LCM pill and spot on bottom after coring. Weight up suction pit and hole to 10 ppg. Monitor well with 4 bph static mud losses. Start pulling out of hole. Total mud losses 1127 barrels. 13 Apr 2007 Pull out of hole with core. Monitor well at shoe with 4 bph static losses. Lost 22 barrels on trip. Recovered 36.4 feet of core out of 38 feet cored for a recovery of 96 %. Pick up MWD and BHA, start trip in the hole. 14 Apr 2007 Completed running into the hole to top of cored section. Reamed through core section with mud losses ranging from 12 to 98 bph. Drill 8'/2" hole to a total depth of 7280'. Hydrocarbon shows ranging from 200 -430 units above a background of 90 units occurred at 7125', 7128', 7143' and 7147'. Began to trip out of the hole with an LWD "mad pass" from 7170' to 6835'. 15 Apr 2007 Pull out of hole. The hole was tight at 3748' and required back reaming to 2970'. Complete the trip and began to lay down bottom hole assembly. 16 Apr 2007 Pick up a bottom hole dumb iron assembly and began to run into the hole. Wash and ream from j 3000' to 3330', 6802' to 6962' and 7270' to 7280', four feet of fill in hole. Abundant heavy /emulsified oil mixed in with the mud at shakers beginning about 6830'. Maximum trip gas 500 units. Began to pull out of the hole to run casing. 17 Apr 2007 Completed tripping out of the hole. Conducted a BOP test. Rigged up and began to run 7 ", 26 lb/ft. casing into the borehole. 18 Apr 2007 Continue to run in 7" casing. Casing tight at 7050 ft. Reciprocate casing while pumping to make progress. Mud range from losses 90 to 150 bbls per hour. Cease pumping and well flows back from 5 to 21 barrels per hour. 19 Apr 2007 Complete casing run at 7050 ft. Casing joint stick up is above drill floor. Cement the casing in two 1 stages. First, 23 bbls through open stage collar, circulate through the stage collar. Hole began taking mud, waited on cement for 8 hrs. Rig and run 2 cement stage. Used 60 bbls 12.5 ppg cement, 30% returns at end of displacement. Lift BOP's and set emergency slips. Rig up to cut 1 casing. 1 3 1 DAILY SUMMARY FEX AKLAQ #6 1 20 Apr 2007 Cut off 7" casing and lower the BOP's into place. Bolt them up and test. Pick up 6 1/8" bit and bottom hole assembly and begin to trip into the hole to drill out the upper cement staging collar located at 6386.0'. 21 Apr 2007 Drill out cement staging tool, conduct casing pressure test and pull out of hole laying down drill pipe. Sperry MudLoggers released from rig. 1 I 1 t r 1 1 1 t 1 1 t 1 4 1 i DAILY ACTIVITY (LA.D.C.) FEX - AKLAQ #6 I 3.. DAILY ACTIVITY (I A - D_C - Time Elapsed Operations Breakdown i (hrs) Time 03 -26 -2007 00:00 -08:00 8.00 Attempt to test starter head, no test, change seals & re -test. I 08:00 -13:00 5.00 13:00 -21:00 8.00 Pick up 18 Joints of HWDP. Re -seat starter head with new seals, rig up spool & Hydril, test head to 1000 psi. 21:00 -24:00 3.00 Rig up diverter, flow line & mud can. I 03 -27 -2007 00:00 -05:00 5.00 Pick up 60 stands of DP. 05:00 -06:00 1.00 Gramaldi with AOGCC waived witnessing of diverter test, function test diverter. I 06:00 -07:00 1.00 Clean floor, pre job safety meeting prior to pick up BHA. 07:00 -10:00 3.00 Repair seal on bell nipple. 10:00 -11:00 1.00 Pick up mud motor & BHA for 300' drillout. 11:00 -13:00 2.00 Wire & bring mud pumps online to pump. I 13:00 -13:30 0.50 Prime mud lines, pressure up to 3500 psi. 13:30 -18:00 4.50 Spud @ 12:45, drill ahead from 80' to 342'. 18:00 -19:00 1.00 Blow down Kelly, POOH 5 stands. 19:00 -19:30 0.50 Pre job safety meeting. 19:30 -23:00 3.50 Pick up MWD BHA, load source, load MWD tools. I 23:00 -23:30 0.50 Install corrosion ring in string, trip in hole. 23:30 -24:00 0.50 Drill 12 1 /4" hole from 342 to 400'. 03 -28 -2007 I 00:00 -12:00 12.00 Drill 12 'A" hole from 400 to 981'. 12:00 -24:00 0.50 Drill 12 1 /4" hole from 981 to 1540'. 03 -29 -2007 00:00 -14:30 14.50 Drill 121/4" hole from 1540 to 1977'. I 14:30 -15:00 0.50 Service rig & top drive. 15:00 -22:00 7.00 Drill 1214" hole from 1977 to 2101'. 22:00 -23:30 1.50 Circulate & clean hole. 23:30 -24:00 0.50 Wiper trip. I 03 -30 -2007 00:00 -04:00 4.00 Short trip /back ream from 1477 to 1296' & from 1172 to 1044'. 04:00 -04:30 0.50 Service rig & top drive. 04:30 -06:00 1.50 Trip in hole. I 06:00 -07:00 1.00 Circulate sweep, condition mud. 07:00 -07:30 0.50 Monitor well, blow down all lines. 07:30 -12:00 4.50 POOH & lay down jars. 12:00 -13:15 1.25 Stand back 5 jts HWDP. Lay down 2 non mag DC's. I 13:15 -18:00 4.75 Remove nuke sources. Down load MWD. Lay down BHA. 18:00 -21:00 3.00 Rig up casing running tools & landing joint, clean floor. 21:00 -24:00 3.00 RIH with casing to 1700'. 03 -31 -2007 I 00:00 -01:30 1.50 Run in hole with 9 5/8" Casing. 01:30 -04:00 2.50 Circulate casing. 04:00 -05:00 1.00 Rig down casing tools & blow down. 05:00 -07:00 2.00 Rig up to run in hole with drill pipe for inner string job. 07:00 -09:00 2.00 Pull out of hole to space out casing. I 09:00 -10:30 1.50 Rig up casing equipment & run two joints to re- space. 10:30 -12:30 2.00 Circulate casing, rig down casing tools, blow down. 12:30 -13:30 1.00 Run drill pipe for inner string job. 13:30 -14:30 1.00 Rig up cement head & break circulation. I 14:30 -17:00 2.30 Pump 5 bbls of water at 15:25. Pressure test to 2500 psi at 15:30. Pump 5 bbls of water & 20 bbls of 10.0 ppg alpha spacer. Start to pump 136 bbls of lead fluid at 4 -5 bpm. Pump 41 bbls of tail at 4 bpm. Drop plug & begin with 20.6 bbl starting at 3 bpm I & slowing to 1 bpm after pumping 17 bbls. Plug bump at 16:50 - floats held. 17:00 -18:00 1.00 Rig down cement head. 18:00 -20:00 2.00 Pull out of hole with inner string. 20:00 -21:00 1.00 Back out landing joint. 111 21:00 -24:00 3.00 Nipple down diverter. 1 1 DAILY ACTIVITY (I.A.D.C.) Time Elapsed Operations Breakdown FEX - AKLAQ #6 I (Hrs) Time 04 -1 -2007 00:00 -12:00 12.00 Nipple down diverter, with some trouble cleaning up cement in diverter. Nipple up FMC spool & test to 1000 psi for 10 min. Nipple up BOP. Change liners to 5 1 /2. 12:00 -16:00 4.00 Continue to nipple up, install kill line & choke line, function test BOP. I 16:00 -21:30 4.00 Rig up test plug & fill stack, blind ram door leak, drain stack & replace seals, test to 2500 psi, doors held. 21:30 -24:00 2.50 Test BOP. First test 250 psi annular low, 2500 psi, #2 top rams TIW valve, manual valve choke & kill 250 psi low & 5000 psi, #3 top rams Dart valve. I 04 -2 -2007 00:00 -06:00 6.00 BOP test #4, choke valves 1, 5, 9, 14 manual IBOP, 250 psi low & 5000 psi high for 10 min. Test #5, choke valves 4, 8, 12, 13, Hydraulic IBOP to 250 psi low, 5000 psi high for 10 minutes. Test #6 top rams choke valves 3, 7, 11, 250 psi low, 500 psi high for 10 minutes. Test #7 bottom rams 250 low & 5000 psi high for 10 minutes. Koomy test, pit alarm test, flow alarm test, gas alarm check. I 06:00 -08:00 2.00 Blow down test equipment & choke manifold. 08:00 -12:00 4.00 Pick up pipe. 12:00 -12:30 0.50 Rig service /tube. 12:30 -19:00 6.50 Pick up & rabbit pipe. 1 19:00 -20:45 1.75 Pressure test casing to 2600 psi, held 10 minutes, blow down. 20:45 -22:00 1.25 Pull out of hole. 22:00 -24:00 2.00 Pick up BHA & set motor to 1.22° bend. I 04-3-2007 00:00 -02:00 2.00 Pick up bottom hole assembly. 02:00 -04:30 4:30 Down load tools. 04 :30 -05 :00 0.50 Pickup bottom hole assembly, pre job safety meeting, down loading sources. I 05:00 -06:00 1.00 Download sources. 06:00 -07:30 1.50 Continue picking up downhole assembly. 07:30 -08:00 0.50 Rig service. 08:00 -09:00 1.00 Run in the hole to 1979'. 09:00 -10:30 1.50 Stage pumps up to 500 gpm. Drill float shoe & make "mad pass" at casing 1979 to 2041'. 10:30 -12:00 1.50 Drilling cement to 2070'. 12:00 -12:30 0.50 Drill out shoe at 2070'. Drill cement to 2101' & new hole to 2102'. 12:30 -13:30 1.00 Circulate clean hole. Rig up test pump. Perform formation integrity test to 700psi= E.M.W. 16.0 ppg. Pressured up to 700 psi & held for 10 minutes. 13:30 -24:00 10.5 Drill 8 1 /2" hole from 2102 to 2602'. I 04 -4 -2007 00:00 -08:00 8.00 Directional drill 8 1 /2 "hole from 2602 to 2911' - slide 206', rotate 101'. 08:00 -08:30 0.50 Service rig & top drive. I 08:30 -12:00 3.50 12:00 -24:00 12.0 Directional drill 8 1 /2" hole from 2911 to 3038' - slide for 80'. Directional drill 8 1 h" hole from 3038 to 3662' - slide for 348'. 04 -5 -2007 00:00 -08:00 8.00 Directional drill 8 1 /2 "hole from 3662 to 3912'. 1 08:00 -08:30 0.50 Circulate & clean hole. 08:30 -11:00 2.50 Short trip to 2072' (9 5/8" Casing shoe). 11:00 -11:15 0.25 Flow check, clean rig floor. 11:15 -12:00 0.75 Service rig & top drive /change out saver sub. I 12:00 -13:30 1.50 13:30 -24:00 10.50 Run back in hole - 8' Fill. Directional drill 8 1 /2" hole from 3912 to 4286' - slide 238'. 04 -6 -2007 00:00 -10:30 10.50 Directional drill 8 1/2" hole from 4286 to 4723' - slide 200'. I 10:30 -11:00 0.50 Service rig & top drive /adjust draw works brakes. 1 h 11:00 -12:00 1.00 Directional drill 8 " hole from 4723 to 4785'. 12:00 -24:00 12.00 Directional drill 8 1/2" hole from 4785 to 5285' - slide 15'. 1 2 DAILY ACTIVITY (LA.D.C.) Time (Hrs) Elapsed Time Operations Breakdown FEX - AKLAQ #6 1 04 -7 -2007 00:00 -06:00 6.00 Drill 8 '/z "hole from 5285 to 5534'. I 06:00 -07:30 1.50 Pump, pump pill, flow check. 07:30 -12:00 4.50 Wiper trip to 3900'. Rill to bottom - 5' Fill. 12:00 -20:15 8.25 Drill 8 '/z "hole from 5534 to 5906'. 20:15 -20:45 0.50 Lubricate rig. I 20:45 -24:00 3.00 Drill 8 '"hole from 5906 to 6033'. 04 -8 -2007 /z 00:00 -08:30 8.50 Drill 8 '/z "hole from 6033 to 6405'. I 08:30 -9:00 0.50 Rig service & conduct flow check. 09:00 -12:00 3:00 Drill 8 '/z "hole from 6405 to 6470'. 12:00 -15:00 3.00 Drill 8 '/z "hole from 6470 to 6500' - lost circulation, fluid loss 75 bbls. Monitor well, well flowing back, shut well in & monitor pressure (0). Blow down choke lines & kill lines. Drill 8 '/z "hole I from 6500 to 6554'. Pick up off bottom & reduce flow by using one pump at 112 gpm. 15:00 -16:00 1.00 Build lost circulation pill (50 bbls) & circulate. 16:00 -16:30 0.50 Spot 50 bbl lost circulation pill. I 16:30 -17:00 0.50 Pump out 2 stands to 6400'. 17:00 -17:30 0.50 Ream back to bottom at 6554 with pumps at 226 gpm. 17:30 -24:00 6.50 Drill 8 '/z "hole from 6564 to 6782'. Total mud losses at 728 bbls. 04 -09 -07 I 00:00 -12:00 12.0 Drill 8 '/z "hole from 6782 to 7125' - 32% gas at 6830 & 44.5% gas at 7128'. 12:00 -13:00 1.00 Condition mud & circulate, reciprocate pipe, shut down pumps & monitor well. I 13:00 -14:00 1.00 Pump out of hole with 5 stands, pump slug, blow down & monitor well. 14:16:30 2.50 Short trip back to 5500', pull 26 stands, monitor well. 16:30 -17:30 1.00 Run in the hole at controlled speed, monitor well. 17:30 -21:30 4.00 Break circulation ream to bottom, reduce pump rate, watch for I gains or losses. Circulate & condition mud, spot a 42 bbl pill at the bit. 21:30 -24:00 2.50 Pull 5 stands & pump a 30 bbl slug. Monitor the well - static. Blow down & condition hole. Pull out 30 stands to 5200'. I 04 -10 -07 00:00 -07:30 7.50 Control pipe speed while POOH. 07:30 -08:00 0.50 Conduct a flow check at the shoe. 08:00 -10:30 2.50 POOH & clean clay from tool joints. I 10:30 -11:00 0.50 Lay down jars & both crossovers. 11:00 -12:00 1.00 Lay down bottom hole assembly. Clean off all clay. 12:00 -13:00 1.00 PJSM - Nukes & unload nuke sources. 13:00 -15:30 2.50 Download MWD Tools. I 15:30 -06:30 1.00 Lay down TM, DM, & nuke collars. 16:30 -17:00 0.50 Move non mag DC to drillers side. Stand back drill motor & bit. 17:00 -18:30 1.00 Cut & slip 120' drill line. 18:30 -20:00 1.00 Service top drive, recharge nitrogen on gripper & adjust upper I torque beam. 20:00 -20:30 0.50 Pull wear bushing for BOP test. 20:30 -21:30 1.00 Install test plug, install test hoses, conduct pre job safety meeting & Test BOP stack. 21:30 -24:00 0.50 Test BOP. Loosen flange between kill HCR & check valve. Test I #1, Annular 250 low 2500 psi high charted 10 min each. Test #2 Upper pipe rams, floor ball valve manual choke & kill to 250 & 5000 psi. Test #3 Upper pipe, dart, choke & kill HCR's 250 & 5000 psi. 1 04-11-07 00:00 -0400 4.00 Test BOP's, test #4 top ram, top drive, manual drive, choke valves 1, 5, 9 & 14. Test #5 top rams, top drive hydraulic valve, choke valves 4, 8, 12 & 13. Test #7 bottom rams. Test #8 blind I rams. Test 310 Koomy test. 4:00 -5:00 1.00 Pull test plug, install wear ring. Conduct a pre job safety meeting on pickup coring assembly. 5:00 -08:30 3.50 Pickup coring & bottom hole assemblies. I 08:30 -09:00 0.50 Lay down Jars & pickup jars. 09:00 -11:00 2.00 Run in the hole slowly with core barrel. 3 1 1 DAILY ACTIVITY (LA.D.C.) Time Elapsed Operations Breakdown FEX - AKLAQ #6 1 (Hrs) Time 11:00 -12:00 1.00 Circulate bottoms up at the shoe 2085'. 12:00 -12:30 0.50 Blow down top drive. I 12:30 -14:30 2.00 RIH at reduced speed. 14:30 -15:00 0.50 Fill the pipe at 4286'. Blow down top drive & mud lines. 15:00 -17:00 2.00 RIH at reduced speed. 17:00 -18:30 1.50 Pump 50 bbl lost circulation material pill & work on tight spot. I 18:30 -19:30 1:00 19:30 -20:00 0.50 Wash & ream to 6352' with a loss of partial returns. Pump a 50 bbls lost circulation material pill & work pipe in an attempt to heal the hole. 20:00 -22:30 2.50 Wash down to 7025' with conditioned mud. 22:30 -24:00 1.50 Wash fill from 7025 to 7045' I 04 -12 -07 00:00 -04:00 4.00 Washing & pumping to total depth. Pumping Lost circulation material pills & high vis sweeps. I 04:00 -12:00 8.00 Drop ball at 74 spm - ball hit 563 psi. Core from 7125 to 7153'. 12:00 -17:30 5.50 Cut core from 7153 to 7182'. 17:30 -22:00 4.50 Circulate & condition mud to a weight of 10.0 ppg in & out. 22:00 -24:00 2.00 Monitor well while attending to injured man having to be flown to I Barrow. 04 -13 -07 00:00-12:00 12.00 Pull out of hole with core. POOH slowly following guidelines for pulling core. Hole took 22 bbls of mud to the shoe. I 12:00 -15:00 3.00 PJSM. Finish pulling out of hole with core assembly. Lay down & recovered 36' of core. 15:00 -16:00 1.00 Service top drive & charge compensator. 16:00 -17:00 1.00 Run in the hole with bore hole assembly 32 from derrick. Plug in & establish communications with MWD. I 17:00 -18:00 1.00 Remove core samples & core carrier from catwalk. Lay down core barrels. 18:00 -21:00 3.00 Pick up MWD tools & orient mud motor to upload. 21:00 -21:30 0.50 Repair hose on top drive. I 21:30 -22:30 1:00 Conduct a shallow pulse test, blow down top drive & mud lines. 22:30 -24:00 1.50 Run in the hole the remaining bottom hole assembly (HWDP & Jars). I 04 -14 -07 00:00 -01:00 1.00 Run in to shoe. 01:00 -04:00 3.00 Circulate bottoms up & get MWD tool working. Pump sweep. 04:00 -08:00 4.00 Run in the hole to 7110' I 08:00 -10:30 2.50 Wash & ream to bottom. 10:30 -12:00 2.00 Drill 8 1/2 "hole from 7162 to 7184'. 12:00 -15:00 3.00 Drill 8 V2 "hole from 7184 to 7280'. 15:00 -18:00 5.00 Condition mud & circulate. 18:00 -18:30 0.50 Spot lost circulation material pill in open hole. I 18:30 -19:30 1.00 Not able to pull - had to rotate & circulate out 90' due to excessive hole drag. 19:30 -24:00 4.50 Logging `Mad Pass" from 7170 to 6923' pump & rotate due to excessive hole drag. 1 04 -15 -07 00:00 -01:00 1.00 Logging "Mad Pass" from 6923 to 6835'. 01:00 -02:30 1.50 Pump sweep & spot pill. 02:30 -03:30 1.00 POOH & work through tight hole. I 03:30 -04:00 0.50 Pump slug & blow down all mud lines. 04:00 -08:30 4.50 POOH. 08:30 -12:00 3.50 Wash & ream from 3748 to 3400. Tight spots encountered at 3750, 3680, 3571, & 3447'. I 12:00 -15:00 3.00 Back ream from 3400 to 2970'. 15:00 -15:30 0.50 POOH from 2970 to 2590'. 15:30 -17:00 1.50 Circulate HighVis sweep & pump slug. Blow down top drive & mud lines. 17:00 -20:00 3.00 Continue to POOH, monitor hole at shoe & at BHA. I 20:00 -20:30 0.50 Lay down NMF Drill collars & nonmagnetic stabilizer. 20:30 -22:00 1.50 Pre job safety meeting, remove nuclear sources & lay down logging tool. 22:00 -24:00 2.00 Remove pulsar & lay down smart iron remove floor monitor. 1 4 i DAILY ACTIVITY (LA.D.C.) Time Elapsed Operations Breakdown FEX - AKLAQ #6 (Hrs) Time 04 -16 -07 00:00 -01:30 1.50 Replace IBOP Hydraulic seals. 01:30 -02:00 0.50 Lubricate the rig. 02:00 -02:30 0.50 Monitor well & pickup bottom hole assembly. 02:00 -03:30 1.00 Run in the hole to 2034' 03:30 -04:00 0.50 Circulate bottoms up. 04:00 -04:30 0.50 Wash & ream from 3300 to 3350', blow down all mud lines. 04:30 -08:00 3.50 Wash & ream from 6803 to 6962' 08:00 -12:00 4.00 Washing & reaming from 6803 to 6962' Hole took 165 bbls. 12:00 -15:30 3.00 Wash & ream from 6962 to 7270' At 14:25 to 14:45 conducted flow check. 15:30 -16:00 0.50 Finish circulating bottoms up & conducted flow check. Attempted to pull without rotating or pumps won't pull. 16:00 -16:30 0.50 Wash & ream from 7270 to 7280' - 4' of fill. 16:30 -19:30 3.00 Circulate Hi -Vis LCM pill. Circulate, build & spot LCM pill. I 19:30 -22:30 3.00 Back ream from 7280 to 7127' with no pump. Back ream from 7127 to 6423' with pump & rotary. 22:30 -23:00 0.50 Spot LCM pill in open hole. 23:00 -24:00 1.00 POOH. Hole is out of balance. Float leaking mud up to the top drive at each stand. Pump slug. 04 -17 -07 00:00 -06:00 6.00 POOH to run casing. 06:00 -07:30 1.50 Stand back & lay down bottom hole assembly. Lay down 1 111 joint of HWDP. Clean rig floor & lay down jars. 07:30 -08:30 1.00 Pull wear ring & set test plug. 08:30 -09:30 1.00 Conduct a pre job safety meeting & change top rams from 4" to 7 ". 09:30 -11:00 1.50 Pre job safety meeting & hook up Tesco running tool. I 11:00 -11:30 0.50 Clear floor for running casing. 11:30 -12:00 0.50 Rig up & test 7" rams. 12:00 -13:30 1.50 Pressure test 7" rams to 1500 psi for 10 minutes. Rig down & blow down. 13:30 -14:00 0.50 Make up shoe & weld same. 14:00 -14:30 0.50 Pre job safety meeting to make up float equipment & check same. 14:30 -22:00 7.50 Run 7" casing. Static mud Toss rate 18 bbls /hr. 22:00 -23:00 1.00 Break circulation @ 3683' & establish a Toss rate of 90 bbls /hr. 23:00 -24:00 1:00 Run 7" casing with mud loss rate of 19 bbls /hr. 04 -18 -07 00:00 -05:00 5.00 Run in the hole with 7" casing. 05:00 -12:00 7.00 Hit hard spot @ 7037, worked 13' to 7150. Appllied torgue & worked pipe down. 12:00- 23:0011.00 Circulate & work stuck 7" casing. Cut mud weight from 10.0 to Slug ppg. S 23:00 -24:00 1.00 Slug pipe, blow down top drive & mudline. Pick up cementing head. 04/19/07 I 00:00 -02:00 2.0 02:00 -05.00 3.00 Rig up cement head & hook up cement line to circulate. Pre job safety meeting on cement job. Circulate gas out max. of 4216 units. Circulate good mud aroung. 05:00 -07:00 2.00 Pump 5 bbls H2O, pressure test lines to 3500 psi -ok. Pump 5 bbls of H2, pump 20 bbls 11.5 ppg spacer, pump 23 bbls 15.8 1 ppg cement. Drop 1st plug, pump 5 bbls H2O behind. Pump 260 bbls with rig. Pump 6.25 bbls with cementers & bump plug. Presuure up system to 3200 psi to open second stage cementing collar. I 07:00 -12:00 5.00 Circulate through cementing collar - lost circulation. Pump using choke on the rig floor. Pump 17 strokes every 15 minutes. 12:00 -15:00 3.00 Pump 17 strokes every 15 minutes while WOC. 15:00 -16:00 1.00 Slug pipe, load second stage plug with rig. Pump with 100% loss of returns. 16:00 -18:00 2.00 Cement 2 stag, pump 10 bbls H2O, 20 bbls chaser, 60 bbls cement. Drop plug, 5 bbls H2O, use rig pump to chase plug to 1755 psi to close cement tool, 26.5 bbls returns total. 18:00 -18:30 0.50 blow down Halliburton & rig pumps. 18:30 -19:00 0.50 Rig down cement head & crossover to 7" casing. 5 I DAILY ACTIVITY (I.A.D.C.) Time Elapsed Operations Breakdown FEX - AKLAQ #6 I (Hrs) Time 19:00 -22:00 3.00 Monitor well with preparation to nipple down to set C -21 emergency slips & cut pipe. 22:00 -22:30 0.50 Lift BOP, set C -21 emergency slips on 7" casing. Set with 190K slips. 22:30 -24:00 0.50 Install cutter & cut 7" casing. 04 -20 -07 00:00 -01:00 1.00 Finish cutting 7" casing. Pull connection to rig floor. Break with rig tongs. Lay down joint # 174, lay down 13.57' of casing joint # 173. 01:00 -03:00 2.00 Per job safety meeting to install pack off. Lower BOP, hammer up the bolts on stack & choke line. Pull dresser sleeve on. Hook up lines on flow line & fill void & test pack off to 5000 psi - test ok. 03:00 -05:00 2.00 Change rams. Instal katch kan on the drilling nipple. Hold a pre job safety meting on rig down Tesco casing equipment. 05:00 -06:00 1.00 Rig down Tesco casing equipment & running tool. 06:00 -09:00 3.00 Clean up rig floor, chain BOP, Rig up Bails and elevators on top drive. I 09:00 -10:00 1.00 Rig up to test BOP. 10:00 -11:00 1.00 Test BOP. 11:00 -12:00 1.00 Choke line flange leak. Hammer up & check annular on a vac - hook up hole fill to 9 5/8 X 7 annulus & fill the same with 1.4 bbls in order to monitor during test of BOP's. I 12:00 -13:00 1.00 13:00 -20:00 7.00 Fill cellar & install suction to monitor losses during BOP test. Test BOP. Test #1 - annular 250/2500psi for 10 min each. Test # 2 - upper pipe rams, floor ball valve, manual choke & kill 250/5000 psi. Test #3 Top pipe, dart valve, choke & kill, HCR's 250/5000 psi. Test #4 Top pipe to hyd ball, choke No. 1, 5, 9, 14 250/5000 psi. Test # 5 Top pipe to hyd ball choke 4, 8, 12, 13, 250 & 5000 psi. Test # 6 Top pipe, choke 3, 7, & 11. Test # 7 Top pipe, choke 2, 6, & 10. Test # 8 Bottom pipe, unable to close due to tool joint will test with casing. Test #9 I Blind rams check valve & blind flange. Test # 10 Accumulator test. 20:00 -21:00 1.00 Rig down BOP test equipment, blow down top drive, choke & kill lines, choke manifold, line up choke. 21:00 -24:00 3.00 Make up bit, bottom sub, cross over & heavy weight drill pipe with 4 " drill pipe, running over top of slugged pipe. 04 -21 -07 00:00 -01:30 1.50 Run in the hole to drill out E -S cement staging tool. 01:30 -02:30 1:00 Slip & cut 120' of drilling line. 02:30 -03:30 1:00 Conduct Pre job safety meeting to discuss the rig up procedures for testing bottom rams. 03:30 -04:00 0:50 Rig service. 04:00 -06:00 2:00 Run in the hole to drill out E -S cement staging tool. I 06:00 -07:00 1.00 Drill out staging tool at 6386'. 07:00 -08:00 1.00 Circulate Hi -Vis sweep & work bit & pipe through staging tool. 08:00 -09:00 1.00 RIH to 6960'. Reconfirm tag. Drill pipe was flowing over. 09:00 -10:00 1.00 Circulate bottoms up & circulate H2O surface to surface. I 10:00 -11:00 1.00 Pressure test bottom rams to 250 psi for 10 mins & 3500 psi for 30 mins. 11:00 -12:00 1.00 Unscrew from top drive, install stripping rubber, lay down DP without pumps, up weight 240 klbs, down weight 140 klbs with pumps up to 170 down weight 150 klbs, rotation weight 160 I klbs, 80 rpm, 5 -7 torque, 5 -8 weight on bit, 137 strokes per minute, 1500 psi, 357 gpm. 12:00 -17:00 5.00 Lay down 20 joints. Run in hole with 9 stands. Continue to lay down DP. I 17:00 -17:30 0.50 Lubricate rig & top drive. 17:30 -18:00 0.50 Repair the indexer on pipe skate. 18:00 -20:00 1.00 Continue to lay down DP. 20:00 -24:00 3.00 Conduct pre job safety meeting for rig up & run SBT & Gamma Ray log & run Rpm Log. 1 6 t Customer: FEX Report No.: 1 ti Well: Aklaq #6 Sperry Drilling services Area: North Slope Midnight Depth 3/27/2007 400 I F Lease: Exploration Footage Last 24 hrs: 320 Rig: Arctic Wolf Rig Activity: Drill Surface 4 , Job No.: AK -AM- 4986881 Report For: Jaque Ledbetter Mudlogger's Morning Report Pr Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. na ft/hr 64 ft/hr ( na ft/hr @ 0 ) Pumps spm Flow rate gpm Gas* na units na unit; ( na units 0 ) Pump Capacity 3.14 gps ill Pump Liner & Strk 6X9 in. Sample Quality 0 Good IN Fair ❑ Poor Pump Pres psi p �;'i. "• �, -4444, i,i%. z.....:_ .. `•. r' � ,,,,fir' .. ".,: :., ,, ;✓ ,�.^ � . .<., _.:�.. ✓ „i�.�� , ,,. �' , „; Mud Wt In 9.90 ppg Visc 48 secs API filt 6.5 ml HTHP ml Mud Wt at Max Gas 9.8 ppg ' Mud Wt Out 9.90 ppg PV 9 cP YP 18 Ibs /100ft2 Gels 7 \ 10 \ 10 MBT 2.5 pH 10.5 Sd Bit No.: 1 Type: Mill -tooth Bit Size: 12.25" Jets: 1 x 12 , 3 x 16 , x _ TFA: 0.7000 A. Wt On Bit: na RPM: na Hrs. On Bit: na Total Revs on Bit: Footage for Bit Run 0 I ' 4444.. Trip Depth: 342 ft Trip Gas: Mud Cut: ppg Trip CI: ppm r' Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm I , Tight Spots: , , to Feet of Fill on Bottom: ft :!,' , r : ‘!' at Current Lithology: %Sd 10 %Clyst %Cly 90 %Sltst %Sst %Sh - , % 1 t", < iF; .phi IMENNOINERES ..,: x. = , Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg A.. I ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg I .:�� � �9.Y fir• ,�, ;.:::..z�� ��, �.. >�'` '.. : -_ xc �/ %/ �!.c ;z ,.. .. ,r. i.... .. . GAS PEAKS r : > Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot I 0' to 342' 59 8 5925 342' to 498' 43 12 4329 to I to to to I to to to to I to to to — s us > :i24 hr Recap P/U drillpipe; Repair flow line nipp!e; R/U mud pumps; Drill 300'; POOH; M/U MWD BHA; RIH; w Drill ahead f/ 300' t/ 400' Logging Engineer: Tom Mansfield /Jeff Porcianko * 10000 units = 100% Gas In Air %/ � , ,. '': ` .. .�� ;.. $/r r y F/ 1 614 t , %1Ar f r tea a . -:. ... � � �� . , ! .. �: , � � .. - -;'. ,.. „.: . a h , ., // -,-`. . , -�� . ... , 444.4 -; �.+ 1 ..: a. , : %F„...:_ / .,;v. M„� 9",F, X, ;: .. „ ; > r „fir - -., 4- :, Customer: FEX Report No.: 2 1-1"L.1-1E1-11:47") W ell: A klaq #6 D ate: 3 /28/2007 Sperry Driving siser..ic ®s Area: North Slope Midnight Depth 1400 : / Lease: Exploration Footage Last 24 hrs: 1000 Rig: Arctic Wolf Rig Activity: Drill ahead Job No.: AK -AM- 4986881 Report For: Jaque Ledbetter L. Mudlogger's Morning Report Or r2 Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 70 f t/hr 63 ft/hr ( 246 ft/hr @ 914 ) Pumps 160 spm Flow rate 500 gpm I Gas' 89 units 65 unit: ( 167 units @ 793 ) Pump Capacity 3.14 gps ,, Pump Liner & Strk 6X9 in. 3. Sample Quality 0 Good 0 Fair © Poor Pump Pres 1450 psi 4 I , , Mud Wt In 10.00 ppg Visc 45 secs API filt 6.6 ml HTHP ml Mud Wt at Max Gas 9.8 ppg Nil Mud Wt Out 10.00 ppg PV 11 cP YP 26 Ibs /100ft2 Gels 10 \ 18 \ 19 MBT 5.0 pH 9.7 Sd % �? Bit No.: 1 Type: Mill tooth Bit Size: 12.25" Jets: 1 x 12 , 3 x 16 , x TFA: 0.7000 5 Wt On Bit: 12 -20 RPM: 100 Hrs. On Bit: 29.0 Total Revs on Bit: Footage for Bit Run 1320 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm I Tight Spots: , to Feet of Fill on Bottom: ft C urrent Lithology: %Sd 10 %Clyst %Cly 70 %Sltst 20 %Sst %Sh Connection Gas and Mud Cut � , ft units ppg ft units ppg ft units ppg .:,,,,,,,:,,,,,,,,,,,,,, I ft units ppg ppg it units ppg ft units ppg ft ft _ units ft units ppg units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm i,; Max Average C1 C2 C3 C4 Tot C5 Tot I 549 to 569 131 9 14198 790 to 797 167 50 16474 826 to 835 146 67 16426 1 1012 to 1024 105 37 11114 to to 10 V to to to / io to to 1 ,• to to 24 hr Recap Drill 12 1/4" hole f/ 400 t/ 1400 ft' I 5 pip I Logging Engineer: Larry Lynch / Wayne Hermanson * units 100% Gas In Air /a ; y >y - r� Cus Well: Aklaq #6 Report /Date . „ , 3/29/2007 Ai' a. to er FEX No 3 e aq # Date: Sp®rry Grilling ServicBS Area: North Slope Midnight Depth 2101 I '1 Lease: Exploration Rig: Arctic Wolf Footage Last 24 hrs: 561 Rig Activity: Drill ahead Job No.: AK - AM - 4986881 Report For: Zenon Kotelko Mudlogger's Morning Report c ,> ,. . . Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data I R.O.P. ft/hr 31.2 ft/hr ( 106 ft/hr @ 1686 ) Pumps 178 spm Flow rate 557 gpm tid A: Gas* units 62 unit: ( 105 units @ 1683 ) Pump Capacity 9.28 gps . Pump Liner & Strk 6X9 in. Sample Quality 0 Good 0 Fair in Poor Pump Pres 1720 psi le Mud Wt In 10.30 ppg Visc as secs API filt 6.4 ml HTHP ml Mud Wt at Max Gas 10.2 ppg \ 1 Mud Wt Out 10.30 ppg PV 14 cP YP 26 Ibs/100ft2 Gels 1 1 \ 26 \ 29 MBT 5.0 pH 8.8 Sd 0.25 % Bit No.: 1 Type: Mill Tooth Bit Size: 12.25" Jets: 1 x 10 , 3 x 16 , _ x _ TFA: 0.7000 Wt On Bit: 12 -20 RPM: 100 Hrs. On Bit: 38.0 Total Revs on Bit: Footage for Bit Run 2003 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: Feet o to e Fill on Bottom: ft : Current Lithology: %Sd %Clyst %Cly 90 %Sltst %Sst %Coal 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg I ft ft units ppg ppg ft units – � — ppg ppg ft units ppg units ft units ft units ppg ft units ppg ft units ppg ft units ppg ' 7' , ; ` v aN :, ,. .',:w :: ,' , . �',; . tom *1,.. , `;3, ii „i, 4 „I-A I GAS PEAKS Depth Gas in units Chromatograph in ppm n Max Average C1 C2 C3 C4 Tot C5 Tot e, 1541 to 2101 105 62 6312 to to to to to to to to to I 11 to to 24 hr Recap iii Drill ahead in surface hole to casing point. 1 1 Logging Engineer: Larry Lynch / Eugene Payne 10000 units = 100% Gas In Air Customer FEX Report No.: 4 We Aklaq #6 Date: 3/30/2007 � q Sperry Drilling S®rvic ®s Area: North Slope Midnight Depth 2101 I a ; Lease: Exploration Footage Last 24 hrs: 0 Rig: Arctic Wolf Rig Activity: Run casing g Job No.: AK -AM- 4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data ' R.O.P. ft/hr ft/hr ( ft/hr @ ) Pumps spm Flow rate gpm Gas' units unit( units ) Pump Capacity gps Pump Liner & Strk 6X9 in. Sample Quality 0 Good D Fair 0 Poor Pump Pres psi 4 Mud Wt In 9.90 ppg Visc 43 secs API filt 6.4 ml HTHP ml Mud Wt at Max Gas ppg 0 ,, Mud Wt Out 9.90 ppg PV 13 cP YP 23 Ibs /100ft2 Gels 9 \ 17 \ 22 MBT 6.0 pH 8.0 Sd 0.50 Bit No.: Type: Bit Size: Jets: x _ x x TFA: / Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm t Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots , to Feet of Fill on Bottom: ft z r r Current Lithology: %Sd %Clyst %Cly %Sltst %Sst %Coal Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ppg ft units ppg ppg ft units -- - ppg ft units ft units ft units ppg ft units ppg ft units ppg ft units ppg i' GAS PEAKS , Depth Gas in units Chromatograph in ppm i 04 fil Max Average C1 C2 C3 C4 Tot C5 Tot to to to 111 to to to to ` 111 :li to to to to 1 to to I to . , , . , 4 24 hr Recap 1 Short trip, POOH, lay down BHA, download MWD, rig up and run 9 -5/8" surface casing. K Logging Engineer: Larry Lynch / Eugene Payne 10000 units = 100% Gas In Air 1 l .. ... . `;; ., , F�• 'i .. h::, .. !. 1 > dr ,... ..' './ v 'clf, `+ @ Customer: FEX Report No.: 5 Well: Aklaq #6 Date: 3/31/2007 sparry Drilling ser..icBS Area: North Slope Midnight Depth 2101 , I Lease: Exploration Footage Last 24 hrs: 0 Rig: Arctic Wolf Rig Activity: Nipple down Mudlogger's Morning Report Job No.: AK-AM-4986881 Report For: Zenon Kotelko Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data I y R.O.P. ft/hr ft/hr ( ft/hr @ ) Pumps spm Flow rate gpm .< Gas* units unit; ( units @ ) Pump Capacity gps Pump Liner & Strk 6X9 in. Sample Quality E Good 0 Fair ❑ Poor Pump Pres psi s r P. Mud Wt In 9.50 ppg Visc 51 secs API felt 6.8 ml HTHP ml Mud Wt at Max Gas ppg Mud Wt Out 9.50 ppg PV 13 cP YP 24 Ibs /100ft2 Gels 10 \ 25 \ 26 MBT 6.0 pH 8.6 Sd 0.25 % Bit No.: Type: Bit Size: Jets: _x _ _ x x TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run r 4 Ai Trip Depth: 2101 ft Trip Gas: 67 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm I Tight Spots: to Feet of Fill on Bottom: ft a ..,... , L i „r., ,y i , :jam' • Current Lithology: %Sd %Clyst %Cly %Sltst %Sst %Coal � r P,,-", ,;r' � ' -- .... -:t.L ; g - r �s� r ri .� ",,-- . — Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg I ft — units ppg - ft units ppg — ft units ppg ft units ppg ft units ppg ft units ppg z ` ft i units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 1 to to to to to to to I _ to to to to to to ' ' r r" l /r - C 24 hr Recap I Finish running 9 -5/8" casing, rig up and cement casing, nipple down. 1 -0 Logging Engineer: Larry Lynch / Eugene Payne , 10 un its = 100% Gas In Air ' l „ ' " y l r� L l H 1 Customer FEX Report No.: 6 Well: Aklaq #6 Date: 4/1/2007 Sparry Drilling S®rvicem Area: North Slope Midnight Depth 2101 Lease: Exploration Footage Last 24 hrs: 0 Rig: Arctic Wolf Rig Activity: Press. test BOP Job No.: AK -AM- 4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data t I R ft/hr ft/hr ( ft/hr @ ) Pumps spm Flow rate gpm y G as' units unit: ( units @ ) Pump Capacity gps ' Pump Liner & Strk 6X9 in S ample Quality 0 Good 0 Fair 0 Poor Pump Pres psi P I = w , _ , . � �s , ip Mud Wt In 9.30 ppg Visc 51 secs API filt 6.4 mi HTHP ml Mud Wt at Max Gas ppg Mud Wt Out 9.30 ppg PV 12 cP YP 25 Ibs/100ft2 Gels 10 \ 23 \ 25 MBT 6.0 pH 8.8 Sd 0.20 % :' =y. ,✓. i :.. : \ .. . ..e e;_ w, , ;ice % .. • °' Bit No.: Type: Bit Size: Jets: _ x _ _ x x _ TFA: z Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm IA Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm 1 Tight Spots: to Feet of Fill on Bottom: ft s Current Lithology: %Sd %Clyst %Cly %Sltst %Sst %Coal Connection Gas and Mud Cut ft units ppg ft units ppg ft units pp I ft units ppg ft units ppg ft units pp ft units _ _ppg ft __ units ppg _ ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm , Max Average C1 C2 C3 C4 Tot C5 Tot l 4 to to to ilx,!,,.,,, to ,. to ® to to to to 5. to to to , to to f- /ma ` 4*00 , ;. , , ,,, ,..c f r r p •i /-' .. ° f 24 hr Recap I Nipple up and pressure test BOP. 0 0 1 . Logg Eng Larry Lynch / Eugene Payne 10000 units = 100% Gas In Air 1 t Customer: FEX Report No.: 7 Well: Aklaq #6 Date: 4/2/2007 Sperry Drilling S erv%CBS Area: North Slope Midnight Depth 2101 I Lease: Exploration Footage Last 24 hrs: 0 Rig: Arctic Wolf Rig Activity: Pick up BHA r Mudlogger's Morning Report Job No.: AK -AM- 4986881 Report For: Zenon Kotelko y \.; ...::. ! ":.- � , { < n, , . - ;f . s,_' .. '" ,. %x'20 - . ., , Dpi Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R. O.P. ft/hr ft/hr ( ft/hr Q ) Pumps spm Flow rate gpm I Gas units unit ( units @ ) Pump Capacity gps Pump Liner & Strk 6X9 in. Sample Quality 0 Good E Fair ❑ Poor Pump Pres psi I off is -, a; # . g',�r, _ . -.... ? . ..... ; / ?' . .:v" i %1' `. TA St Mud Wt In 9.60 ppg Visc 55 secs API felt 6.4 ml HTHP ml Mud Wt at Max Gas ppg Mud Wt Out 9.60 ppg PV 12 cP YP 21 Ibs/100ft2 Gels 9 \ 21 \ 28 MBT 6.3 pH 9.0 Sd % Bit No.: Type: Bit Size: Jets: _ x _ _ x _ x _TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run lig Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm I Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Clyst %Cly %Sltst %Sst %Coal .. „ 'y:y, sir f. F .;i 6,,,,.s ,..,iii. ?. �. ;.,y��i,."y;. - :% , ✓'*` r .. -.. ,J,Lr ;, .c.. Connection Gas and Mud Cut _° ft units ppg ft units ppg ft units ppg I ft units ppg ppg �ft units ppg —'— ft units ppg ft _ units ft units ppg ft units — ppg ft units ppg ft units ppg ft units ppg 1 4 _ GAS PEA Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 1 to to to I to to to to i „, to to I to to 1 ` to RI to to 24 hr Recap :1 1 4 Pressure test, pick up drill pipe and BHA. 1 Logging Engineer: Larry Lynch / Eugene Payne 10000 units 100% Gas In Air 1 Customer FEX Report No.: 9 . Well: Aklaq #6 Date: 4/4/2007 Sperry i' riiiing SerViGee Area: North Slope Midnight Depth 3662 I Lease: Exploration Footage Last 24 hrs: 1060 Rig: Arctic Wolf Rig Activity: Drill ahead Job No.: AK -AM- 4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Jaque Ledbetter NIS Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data 4': I R.O.P. 54 ft/hr 45.1 ft/hr ( 225 ft/hr @ 3602 ) Pumps 89/86 spm Flow rate 467 gpm Gas' 46 units 77 unit ( 2500 units @ 3420 ) Pump Capacity „., 7.8 gps Pump Liner & Strk 6X9 in. Sample Quality D Good ❑ Fair © Poor Pump Pres 1770 psi III Mud Wt In 9.60 ppg Visc 56 secs API filt 4.6 ml HTHP ml Mud Wt at Max Gas 9.6 ppg ; ti Mud Wt Out 9.60 ppg PV 13 cP YP 21 lbs /100ft2 Gels 7 \ 18 \ 26 MBT 7.0 pH 9.0 Sd 0.10 % Bit No.: 2 Type: HCM605Z Bit Size: 8 1/2 Jets: 2 x 13 , 3 x 14 , x TFA: 0.7100 Wt On Bit: 10 RPM: 90 Hrs. On Bit: 34.0 Total Revs on Bit: NA Footage for Bit Run 1558 A . 1 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip C I: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm I Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd 10 %Sh 10 %Cly 60 %SIt 20 %Sst %Coal Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg I ft units ppg ppg ft units i` — ppg ppg ft units ppg ft units ft units ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm ir . Max Average C1 C2 C3 C4 Tot C5 Tot ti 2602 to 2722 Problems with Data Exchange, working on recovering data from Data Base 2722 to 3405 111 55 5689 3 0 0 0 3405 to 3440 2500 630 276990 2489 1265 750 147 I 3440 to 3659 115 65 6697 71 18 0 0 to to to III to to e to to 1 to, to 1 / . .... , , , e • :: / i ,,;, ? Fes.. ? f , nF . .`�, . l .' �� 3 24 hr Recap Drill and slide f/ 2589' t/ 3800' 1 1 ��� Logging Engineer: Larry Lynch / Eugene Payne 10000 units 100% Gas In Air 9” 0 % k y v; 1 Customer: FEX Report No.: 10 �°� Well: Aklaq #6 Date: 4/5/2007 PA Sperry Drilling Sarvicas Area North Sl ope Midnight Depth 4286 I n Lease: Exploration Footage Last 24 hrs: 624 Rig: Arctic Wolf Rig Activity: Drill ahead . Job No.: AK - 4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Jaque Ledbetter 1 Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 55.5 ft/hr 33.7 ft/hr ( 115 ft/hr @ 3961 ) Pumps 88/86 spm Flow rate 463 gpm -::` Gas` 40 units 42 unit: ( 70 units @ 3954 ) Pump Capacity 7.7 gps Pump Liner & Strk 6X9 in. Sample Quality 0 Good © Fair 0 Poor Pump Pres 1951 psi /y: r1 Mud Wt In 9.60 ppg Visc 50 secs API felt 6.0 ml HTHP ml Mud Wt at Max Gas 9.6 ppg \ Mud Wt Out 9.60 ppg PV 13 cP YP 17 Ibs/100ft2 Gels 5 \ 10 \ 16 MBT 7.0 pH 9.2 Sd 0.10 % Bit No.: 2 Type: HCM605Z Bit Size: 8 1/2 Jets: 2 x 13 , 3 x 14 , _ x _ TFA: 0.7100 Wt On Bit: 10 RPM: 125 Hrs. On Bit: 52.5 Total Revs on Bit: NA Footage for Bit Run 2185 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 3909 ft Short Trip Gas: 810 Mud Cut: _ppg Short Trip CI: ppm I Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Sh 70 %Clyst 30 %Slt %Sst %Coal 1 Connection Gas and Mud Cut j ft units ppg ft units ppg ft units p ' Z,,I, I ft units ppg — ft units ppg ft units ppg ft units ppg ft units ppg ft units p pg ft units ppg ft units ppg ft units ppg GAS PEAKS ,:: Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot I 3659 to 4286 70 42 3998 36 3 0 0 to to 1 to , to to .'" to to to to to 1 to to 24 hr Recap Drill and slide f/ 3800' t/ 3912'; Monitor well - static; 30 -stand short trip to shoe; I Monitor well and rig service - change out saver sub; RIH 30 stands - hole clean (8 ft of fill); N Drill and slide f/ 3912' t/ 4286'; Drill and slide f/ 4286' t/ 4460' 1 Logging Engineer: Larry Lynch / Eugene Payne 10000 units = 100% Gas In Air y; 1 ..,lam � , . , cx�21�''. , ��.,.. '.,.... :�kr // �°? � ^:•... �, ,,, ,,, � :3 � \. , .. ., � !'> u..� ,...,. ;. Customer: FEX Report No.: 11 0 1 Well: Aklaq #6 Date: 4/6/2007 Sperry Drilling Mar-vices Area: North Slope Midnight Depth 5285 PI Lease: Exploration Footage Last 24 hrs: 991 0 Rig: Arctic Wolf Rig Activity: Drill ahead Job No.: AK-AM-4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Jaque Ledbetter Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 68 ft/hr 42.5 ft/hr ( 170 ft/hr @ 5348 ) Pumps 87/84 spm Flow rate 458 gpm I Gas 84 units 121 unit; ( 1140 units @ 4905 ) Pump Capacity 7.6 gps Pump Liner & Strk 6X9 in. r Sample Qua © Good 0 Fair 0 Poor Pump Pres 2290 psi Mud Wt In 9.60 ppg Visc 60 secs API Tilt 4.0 ml HTHP ml Mud Wt at Max Gas 9.6 ppg ri ' Mud Wt Out 9.60 ppg PV 16 cP YP 16 Ibs/100ft2 Gels 4 \ 13 \ 20 MBT 7.0 pH 8.4 Sd 0.05 % y Bit No.: 2 Type: HCM605Z Bit Size: 8 1/2 Jets: 2 x 13 3 x 14 _ x _ TFA: 0.7100 Wt On Bit: 7 RPM: 120 Hrs. On Bit: 76.0 Total Revs on Bit: NA Footage for Bit Run 3184 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm / Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm I Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Sh 70 %Clyst 20 %Sltst 10 ° /oSst %Coal — a - . e. Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg I — ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot I % ' ; 4286 to 4410 58 42 4136 41 2 0 0 4425 to 4770 95 51 5136 68 12 0 0 4770 to 4810 322 166 36557 483 182 79 2 A. 4810 to 4855 102 80 8112 135 37 0 0 4855 to 4874 515 281 59754 826 315 127 1 3. 4874 to 4935 1140 701 128024 2046 956 545 88 4935 to 5000 146 199 15730 265 94 20 0 I 5000 to 5150 _ 125 83 _ 8439 162 65 4 0 5150 to 5162 289 155 36455 455 187 59 3 5170 to 5205 235 157 26385 329 140 37 2 to to 1 ," to to I � ,,F . , , . , ; y r . �: „ . s , ,� -;; � ,� c am, �f., ,. 24 hr Recap Dril! and slide f/ 4460' t/ 5491' ,.,: I L Plan short trip to shoe at 5501' 1 Logging Engineer: Larry Lynch / Eugene Payne 10000 units = 100% Gas In Air 1 I ..;, :4 . .. .;: :*.p: 0: ,,,,.,..,, '-. .-, - ..: -. - .: : , .4 Avi,,, 'S 047' : .: , . ;,: ",:i t ;# - . lf,,:a*,:::•%;' ';:: •:. - :;,:: A 4111:,:. - " ;5:. :i:E'4 '" : .''.':: ..' 4. :lir ::',:.:-"': " ..1' ,: 4.14--:AtA51.:,,,,,.:.; Customer: FEX Report No.: 12 t°t Well: Aklaq #6 Date: 4/7/2007 lik „t Sperry Drilling Services Area: North Slope Midnight Depth 6033 Lease: Exploration Footage Last 24 hrs: 748 Rig: Arctic Wolf Rig Activity: Drill ahead p. ,' Mudlogger's Morning Report Job No.: AK -AM- 4986881 Report For: Zenon Kotelko :�® Jaque Ledbetter l ir° s Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data I pi R.O.P. 51 ft/hr 42.7 ft/hr ( 146 ft/hr @ 5347 ) Pumps 102/100 spm Flow rate 540 gpm M • Gas` 645 units 162 unit: ( 1140 units @ 5979 ) Pump Capacity 9 gps V. Pump Liner & Strk 6X9 in Sample Quality © Good ❑ Fair ❑ Poor Pump Pres 2954 psi ., - :,, ;6. '- , - r :o.. .v. , :, , ..:ate . \ f +.. s . ' '.'Zt n ,v .. , W, ;;. V.d ...�,..: �i.,r. /,. ... a i ; ,, S Mud Wt In 9.95 ppg Visc 54 secs API felt 3.6 ml HTHP ml Mud Wt at Max Gas 9.9 ppg Mud Wt Out 9.95 ppg PV 18 cP YP 18 Ibs/100ft2 Gels 6 \ 18 \ 25 MBT 8.7 pH 9.0 Sd 0.05 Bit No.: " 2 Type: HCM605Z Bit Size: 8 1/2 Jets: 2 x 13 , 3 x 14 , x TFA: 0.7100 h ,; Wt On Bit: 8 RPM: 90 Hrs. On Bit: 93.5 Total Revs on Bit: NA Footage for Bit Run 3932 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm k' Short Trip Depth 5532 ft Short Trip Gas: 372 Mud Cut: _ ppg Short Trip CI: ppm Tight Spots to Feet of Fill on Bottom: ft if 10 , f=: gi Current Lithology: %Sd %Sh 10 %Clyst %Sltst 20 %Sst 70 %Coal z. I ; . ,o,.. ate; � ,F,, _., t,., ,'t H , Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ft units ppg ft units ppg ft un ppg ft units ppg ft units ppg ft units ppg „ r , GAS PEAKS qr Depth Gas in units Chromatograph in ppm , Max Average C1 C2 C3 C4 Tot C5 Tot 5285 to 5632 372 75 7286 159 73 5 0 5632 to 5642 304 136 32436 631 240 117 2 il::„.• 5642 to 5672 114 86 8682 287 86 9 0 5672 to 5720 976 251 103758 2632 1218 583 82 5720 to 5795 106 81 7760 254 92 12 0 5795 to 5810 770 363 83068 2335 916 401 9 5810 to 5828 589 493 63451 1837 744 344 31 R 5828 to 5850 933 568 99379 2905 1089 441 43 5850 to 5934 258 166 16749 570 200 61 0 5934 to 5950 859 223 83692 2401 883 355 43 5950 to 5970 130 96 8992 342 122 24 0 I 5970 to 6000 1140 360 117810 3395 1138 437 36 6000 to 6033 1090 448 106358 3997 2083 846 191 y to x 1 `. „,g 4 A ,? 24 hr Recap Drill f/ 5285' t/ 5530'; Monitor well; Short trip to 3900'; Drill ahead f/ 5530 t/ 6208 1 w Logging Engineer: Larry Lynch / Eugene Payne 10000 units = 100% Gas In Air 1 l. ... ,, 1" i ` Agg ... . , € , ,' ' gf 44',- .. : i .... V. '. ? .;` ., ✓ - A; :, s ; Vii, ,,fin Customer: FEX Report No.: 13 Well: Aklaq #6 Date: 4/8/2007 Sperry Drilling S Area: North Slope Midnight Depth 6782 gsti Lease: Exploration Footage Last 24 hrs: 749 Rig: Arctic Wolf Rig Activity: Drill ahead gi Mudlogger's Morning Report • Job No.: AK -AM- 4986881 Report For: Zenon Kotelko , Jaque Ledbetter Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data I R.O.P. 61 ft/hr 35.7 ft/hr ( 164 ft/hr @ 6659 ) Pumps 90/92 spm Flow rate 487 gpm Gas* < 327 units 162 unit: ( 1740 units @ 6431 ) Pump Capacity 8.1 gps 3_, Pump Liner & Strk 6X9 in. •°.-''. Sample Quality © Good El Fair El Poor Pump Pres 2674 psi AN Mud Wt In 9.95 ppg Visc 54 secs API filt 8.2 ml HTHP ml Mud Wt at Max Gas 9.9 ppg ft ;:, Mud Wt Out ppg PV 17 cP YP 17 Ibs /100ft2 Gels 8 \ 19 \ 21 MBT 8.5 pH 8.0 Sd 0.20 % k rA Bit No.: 2 Type: HCM605Z Bit Size: 8 1/2 Jets: 2 x 13 , 3 x 14 , x TFA: 0.7100 Wt On Bit: 6 RPM: 90 Hrs. On Bit: 114.0 Total Revs on Bit: NA Footage for Bit Run 4681 '.13',i,,' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip Cl: ppm f Tight Spots , to Feet of Fill on Bottom: ft 9Y� Current Lithology: %Sd %Sh 70 %Clyst 30 % % Sltst SSt %Coal .' r Connection Gas and Mud Cut ft 6529 ft 695 units 9.9 ppg ft units ppg ft units ppg 6556 ft 395 units 9.9 ppg ft units ppg ft units ppg 6553 ft 318 units 9.9 ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Li GAS PEAKS ''''''''''''''''''''''''.: 1 Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot I 6150 to 674 70513 2169 764 270 14 6187 to 807 83394 2754 1097 398 7 6234 to 757 81071 2411 806 361 12 t 6257 to 775 83503 2562 866 373 11 6270 to 6310 165 129 12009 441 154 55 0 6328 to 1280 92000 3900 720 120 0 • 6357 to 1690 164736 6412 2714 936 239 I 6379 to 765 81261 2461 882 316 5 6392 to 980 103538 3273 1150 398 50 6418 to 1540 150190 5194 1989 745 125 6431 to 1741 172074 6108 2394 906 277 ;r 6470 to 6500 294 235 21184 897 372 159 4 • 6520 to 1090 109395 3359 1299 9 418 9 6576 to 341 34000 1109 466 140 0 I 6617 to 540 55986 2010 886 340 5 r to e 24 hr Recap Drill f/ 6208 t/ 6500'; Lost 75 bbls - Monitor well - well flowing back - shut in well & monitor I pressures - no pressure - Blow down choke and kill lines; Drill ahead f/ 6500' t/ 6554'; P/U • off off bottom - reduce to one pump (112 GPM); Build 50 BBL LCM pill - Pump out 2 stands to 6400'; Ream back ', to bottom @ 6554' - 226 GPM; Drill ahead f/ 6782' (midnight depth) i . Logging Engineer: Larry Lynch Payne , units = 100% Gas In Air r r I � �� /,. i .< ,;_ . �i..�:... .::� „tee _.y � . ,'?���.�r . ,. ,�:���'����, !, . //� �` . I It Customer: FEX Report No. 14 Well: Aklaq #6 Date: 4/9/2007 PI Sperry Mrilling Services Area: North Slope Midnight Depth 7125 Lease: Exploration Footage Last 24 hrs: 343 Rig: Arctic Wolf Rig Activity: POOH gy M udlogger's Morning Report Job No.: AK-AM-4986881 Report For: Zenon Kotelko ii I Jaque Ledbetter It Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data I R.O.P. Gas` ft/hr 29.8 ft/hr ( 187 ft/hr © 6906 ) Pumps 93/89 spm Flow rate 484 gpm units 243 unit ( 4450 units © 7125 ) Pump Capacity 8.1 gps Pump Liner & Strk 5.5X9 in. Sample Quality © Good 0 Fair 0 Poor Pump Pres 2515 psi Mud Wt In 9.95 ppg Visc 61 secs API felt 4.5 ml HTHP ml Mud Wt at Max Gas 9.95 ppg ‘1 : ,,, , Mud Wt Out 9.95 ppg PV 16 cP YP 22 Ibs/100ft2 Gels 7 \ 17 \ 22 MBT 7.5 pH 8.5 Sd 0.10 % 1 . ., .. .% .., ,!r . t! 4 +s ri. ;/ .. \ce,'• \ Bit No.: 2 Type: HCM605Z Bit Size: 8 1/2 Jets: 2 x 13 , 3 x 14 , x TFA: 0.7100 I Wt On Bit 10 RPM: 90 Hrs. On Bit: 125.5 Total Revs on Bit: NA Footage for Bit Run 5024 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm I Short Trip Depth 7125 ft Short Trip Gas: 1500 Mud Cut ppg Short Trip CI ppm Tight Spots to Feet of Fill on Bottom: ft i Y. Current Lithology: %Sd %Sh 40 %Clyst %Sltst 20 %Sst 40 %Coal A. „ ... Connection Gas and Mud Cut 6781 ft 682 units 9.9 ppg 7032 ft 593 units 9.9 ppg ft units ppg ppg 6844 ft 836 units 9.9 ppg 7092 ft 354 units 9.9 ppg ft units 6906 ft 2321 units 9.9 ppg ft units ppg ft units ppg 6968 ft 2554 units 9.9 ppg ft units ppg ft units ppg - % GAS PEAKS •� F' Depth Gas in units Chromatograph in ppm F I Max 757 Average C1 C2 C3 C4 Tot C5 Tot 6655 to 81223 2127 996 428 13 6680 to 6817 559 333 31213 1454 772 369 19 6826 to 3411 291326 17401 8639 2890 771 I 6840 to 7119 212 183 15640 1043 434 196 2 7125 to 4450 281797 23057 8298 2204 297 to to 1 to ' to to to — , to to to __ -- to 24 hr Recap Drill to core point; Wiper trip; Trip for core Logging Engineer: Larry Lynch / Eugene Payne 10000 units = 100% Gas In Air „z , 9 a y '. I % Wel l: Aklaq 6. Report l.y t 4/10/2007 , . . „.., _ Customer: FEX eport No 15 i!-I _ ._ .................... __ _..... _................._...._..................... _..____........................ a aq # a e. Sperry Drilling Services Area: North Slope Midnight Depth 7125 I Lease: Exploration Footage Last 24 hrs: Rig: Arctic Wolf Rig Activity: BOP test Job No.: AK -AM- 4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Jaque Ledbetter Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data °>' I R.O.P. ft/hr ft/hr ( ft/hr @ ) Pumps spm Flow rate gpm ' .Gas' units unit: ( units @ ) Pump Capacity gps 1., FR Pump Liner & Strk 5.5X9 i Sample Quality © Good 0 Fair 0 Poor Pump Pres psi 1 - :� ,; • Mud Wt In 10.05 ppg Visc 61 secs API felt 4.8 ml HTHP ml Mud Wt at Max Gas ' ppg Mud Wt Out 10.05 ppg PV 17 cP YP 21 Ibs /100ft2 Gels 7 \ 24 \ 31 MBT 6.5 pH 10.0 Sd 0.30 % f ,. Bit No.: Type: Bit Size: Jets: x x , x TFA: F '. Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run , Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm � Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm I Tight Spots: to Feet of Fill on Bottom ft Current Lithology: %Sd %Sh 40 %Clyst %Sltst 20 %Sst 40 %Coal — , . .> Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ;ppg ft units ppg ft units ppg ft units ppg GAS PE Depth Gas in units Chromatograph in ppm I Max Average C1 C2 C3 C4 Tot C5 Tot to to to ili 1 ^ to to to 1 to to to 1 t,,,.: : to t to to to 1 to P , 24 hr Recap Continue POOH to surface; Handle BHA Slip & cut; Start BOP test 1 Logging Engineer: Larry Lynch / Eugene Payne 10000 units = 100% Gas In Air ` I Customer: FEX Report No.: 16 ', 1 Well: Aklaq #6 Date: aPeIrr-sf Drilling mil Area: North Slope Midnight Depth 4/11/2007 I 7125 z . Lease: Exploration Rig: Arctic Wolf Footage Last 24 hrs: 0 Rig Activity: Circulate , , „ , ” Job No.: AK-AM-4986881 Report For: Zenon Kotelko ill . 7, Mudlogger's Morning Report Jaque Ledbetter I Midnt-3 AM 24 hr Avg 24 hr Max Pump and Flow Data : 04 1 FLO R.O.P. Gas ft/hr units ft/hr ( unit ( ft/hr @ units @ ) Pumps 67/68 spm Flow rate 361 gpm ) Pump Capacity 6.02 gps ;.„ ;,- Pump Liner & Strk 5.5X9 in. ;.•,: Sample Quality El Good 0 Fair El Poor Pump Pres 1288 psi 11 1 23111V -5.,, 4111111r th':21.41ffir ',: :4 Y Mud Wt In 10.05 ppg Visc 64 secs API filt 4.0 ml HTHP ml Mud Wt at Max Gas 10.05 ppg :‘ Mud Wt Out 10.05 ppg PV 18 cP YP 21 lbs/100ft2 Gels 5\ 13 \ 19 MBT 6.5 pH 9.5 Sd 0.05 (Y. I ... 444 4Y 4: 4 '"4 r44,44 4 4 d sp& , ,,:-A-,;A , „ , ; ,, ,; , ;. ,- ;;;:t•MalletWirlAnn ••.'' A,: AZ': ,,, ,,!,,,A.: ; x,-,:;-.1MIRMINew:At -;,,g2; .A: Bit No • 3 Type: ARC-425 C3 Bit Size: 8 1/2 Jets: x , x , x _ TFA: 0.7500 . 'y I Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run !=. - ,-.:*.,,,, ' i '''',,-;`,,•',1111r'','A,r111?;* , V;'4,•, , ; , ,' , ': , :'.` , :?:,',;1? ,, -<• i0.1352iNgliii.' ... :"15111=: Oa 4 fl. Trip Depth: 7125 ft Trip Gas: 289 Mud Cut: ppg Trip CI: ppm :-.- I Short Trip Depth ft Short Trip Gas: Tight Spots: , , to Mud Cut: ppg Short Trip CI: Feet of Fill on Bottom: ppm ,.. ft 0 e '4 ' 4'' ' ' 47 ' ' . " ''''''' ltig 4 " ''' AVAR :'"' ':444 , I.j.'''' 4 4 - , :4 4=-Mffigar 4 ,4, 4' 4' - :1••:!.. Current %Sh 40 %Clyst %Sltst 20 4 %Sst 40 c7oCoal 46 I C t Lithl %Sd - - Sij .„,,,,,,,,,,,,,„.,,,,,,„:„,,,‘,,,,,.,,,,,,,,..„„„...,..:,..,(:.,..„„,,,:„ k g;- ' '' ' -- - 7: v>, - 4":%-" Connection Gas and Mud Cut :•-'-,,, ^V, I ft units ppg ft units ppg ft units ppg 2 '•--,`: 1l: •' ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg I '- '4 ', ' ' 7", '''" ''' --::::.;,' , - , :::':O:5,gW". --- "k1;''''::: . ':' . ...'` . ' '".,,';'-' ' -''' ' - --,' , , - .. ',- -:;',:',-:;':i-, - , :',, ,- , , ' , ;gi3 '4• ,04 'j, - ''-' -''' ., ' ''''',:' ' 770 ''. '7- ': '','- - ' ,, .:,.:TA,4 ,...„ GAS PEAKS Depth Gas in units Chromatograph in ppm I to Max Average C1 C2 C3 C4 Tot C5 Tot to to I ,• to to , A to ,..-v I ' ',.i' to to to fg to - 1 , „. „- ,, . to .„, to to , I t to to 'P ." ' ;45 , - ' , 4 A ,';';',: k: ; filifki, , 4 • , ;,, ' , 4A„ „ „ , ,- ;.. , :•: , •.,:isyrir4: 5 :;;;Iii..itir:, , ,,,,k6-',.;s.i.." 1.::::;,;1,:: I 1 24 hr Recap Complete BOP test; M/U core barrel & RIH - Build volume & manage losses with 3 LCM pills; -"-- Circulate hole clean ,.. .., I On bottom coring at 0430 hours 1 .'" -;'- Logging Engineer: Larry Lynch / Eugene Payne " 10000 units = 100% Gas In Air '- I P; Alrif:;;"-!:-::;;- ;::, ': .: ..: •:'.:,„ „; ! ''"',',74: '.,:l k*,, ,•':: , 7',; : , A #5: • 41,14-:, - . •' '': ' ';,14•7:•:'4 ',,:,%*:?::77 '1,,f,-,?:::::!,;;44:..F.,:FN,,,,,i):,',,' I i %„ y , .,\ \.„ y. ' ... .. „.,„ r,/ � .. , z . • .; ..- `i.. ..,. , /r;r il miekk_Limum-rcard Customer: FEX Report No.: 17 Well: Aklaq #6 Date: 4/13/2007 Sperry Drilling services Area: North Slope Midnight Depth 7163 7 ; • : Lease: Exploration Footage Last 24 hrs: 0 Rig: Arctic Wolf Rig Activity: Trip in Job No.: AK -AM- 4986881 Report For: Zenon Kotelko R� Mudlogger's Morning Report Jaque Ledbetter 1 Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ ) Pumps 88 spm Flow rate 243 gpm , Gas' units unit; ( units @ ) Pump Capacity 3.85 gps Pump Liner & Strk 5.5X9 in. Sample Quality I Good I Fair El Poor Pump Pres 953 psi I . Mud Wt In 9.90 ppg Visc 55 secs API felt 4.5 ml HTHP ml Mud Wt at Max Gas ppg Mud Wt Out 10.00 ppg PV 15 cP YP 17 Ibs /100ft2 Gels 4 \ 8 \ 12 MBT 7.5 pH 8.8 Sd 0.10 % 2 �; Bit No.: 4 (RR2) Type: HCM65Z Bit Size: 8 1/2 Jets: 3 x 14 , 2 x 13 , _x _ TFA: 0.7100 Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ': , I Tight Spots: to Feet of Fill on Bottom: ft q `/ Current Lithology: %Sd %Sh 20 %Clyst %Sltst 30 %Sst 50 %Coal ii i fr Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PE Depth Gas in units Chromatograph in ppm I to Max Average C1 C2 C3 C4 Tot C5 Tot to to 1 to to to to f to to to to to . to to to 24 hr Recap Trip out, recover core, lay down core barrel, make up BHA. r 1 Logging Engineer: Larry Lynch / Kerry Garner 10000 units = 100% Gas In Air .: Customer: FEX Report No.: 18 Well: Aklaq #6 Date: 4/14/2007 t Sperry Clrilling services Area: North Slope Midnight Depth 7280 Lease: Exploration Footage Last 24 hrs: 117 Rig: Arctic Wolf Rig Activity: Trip Out plg 1 Mudlogger's Morning Report Job No.: AK -AM- 4986881 Report For: Zenon Kotelko l Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data B R.O.P. 0 ft/hr 23 ft/hr ( 103 ft/hr @ 7279 ) Pumps 87 spm Flow rate 330 gpm I Gas' 0 units 133 unit: ( 1120 units @ 7193 ) Pump Capacity 3.85 gps Pump Liner & Strk 5.5X9 in. Sample Quality 0 Good © Fair 0 Poor Pump Pres 951 psi r 1/ tij Mud Wt In 10.00 ppg Visc 57 secs API filt 4.5 ml HTHP ml Mud Wt at Max Gas ppg IN Mud Wt Out 10.00 ppg PV 16 cP YP 14 Ibs/100ft2 Gels 4 \ 11 \ 18 MBT 5.0 pH 9.0 Sd 0.10 Bit No.: 4 Type: HCM605Z Bit Size: 8 1/2 Jets: 3 x 14 , 2 x 13 , _x _ TFA: 0.7100 Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run ,, . Trip Depth: 7163 ft Trip Gas: 241 Mud Cut: 0.2 ppg Trip CI: 9301 ppm I Y Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft , ni Current Lithology %Sd %Sh 30 %Clyst %Sltst 50 %S 20 %Coal Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ,,:,,:,,.:.,,,:,.,-,::.,, ft units ppg ft units ppg ft units ppg A K 4 v/. �. i GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 7193 to 7202 1120 168 76330 5606 1625 153 0 7202 to 7210 444 44 44395 3259 862 50 0 7220 to 7230 528 115 56721 3131 707 80 0 I 7230 to 7240 409 83 35737 2933 800 42 0 7250 to 7260 285 44 27075 2310 666 39 0 7260 to 7270 246 37 25163 2222 667 44 0 7270 to 7280 171 22 22560 1955 581 33 9 I Ift to to to 1 io pg -- -- __ to to to to to • off. •'. ,. ' 24 hr Recap 9 4 Trip in hole, drill to TD, circulate and condition hole, trip out to log. '" 1 , . Logging Engineer: Larry Lynch / Kerry Garner * 10000 units = 100% Gas In Air ', f r // r/f •is I ., r , - . t -- 4 /1 TZ . 0, r. , t , 1M ,,. Customer: FEX Re No 19 t ......... Well: Aklaq #6 Date: 5/2 007 Ix Sperry Drilling Services Area: North Slope Midnight Depth 7280 I Lease: Exploration Footage Last 24 hrs: 0 I R ON ig: Arctic Wolf Rig Activity: Mudlogger's Morning Report Job No.: AK -AM- 4986881 Report For: Zenon Kotelko , ague Ledbetter gp Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr ft/hr ( 0 ft/hr @ 0 ) Pumps 0 spm Flow rate 0 gpm I : Gas' 0 units 0 unit ( 0 units @ 0 ) Pump Capacity 0 gps Pump Liner & Strk 5.5X9 in Sample Quality E Good 0 Fair 0 Poor Pump Pres 0 psi I Mud Wt In 10.10 ppg Visc 53 secs API filt 4.9 ml HTHP ml Mud Wt at Max Gas ppg Mud Wt Out 10.10 ppg PV 13 cP YP 18 Ibs/100ft2 Gels 4 \ 15 \ 21 MBT 7.0 pH 9.0 Sd 0.10 ii j Bit No.: 4 Type: ARC -425 C3 Bit Size: 8 1/2 Jets: _x _ — x x _TFA: 0.7500 Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run � Trip Depth: 7280 ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm I 4, Tight Spots: to Feet of Fill on Bottom: ft % to pi Current Lithology: %Sd %Sh 30 %Clyst %Sltst 50 %Sst 20 %Co . . , / °r, ...., e . . . i Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg FP ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units npg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to L 1 to to to I to to to I to - — - -- to e to „, to 'g to >, 24 hr Recap 1 ;' Logging Engineer: Chuck Stringer / Kerry Garner 10000 units = 100% Gas In Air I IL.t Customer: FEX Report No.: 20 ilk Well: Aklaq #6 Date: 4/16/2007 L i Sperry Drilling Services Area: North Slope Midnight Depth 7280 Lease: Exploration Footage Last 24 hrs: 0 Pi Rig: Arctic Wolf Rig Activity: Trip out for csg Job No.: AK -AM- 4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ ) Pumps 69 spm Flow rate 0 gpm 0 Gas' units unit ( units @ ) Pump Capacity 0 gps Pump Liner & Strk 5.5X9 in. Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 0 psi 0 0 Mud Wt In 10.05 ppg Visc 62 secs API filt 4.1 ml HTHP 14.2 ml Mud Wt at Max Gas ppg / Mud Wt Out 10.05 ppg PV 16 cP YP 17 Ibs /100ft2 Gels 4 \ 14 \ 19 MBT 7.5 pH 8.8 Sd 0.10 Bit No.: 5 Type: MX -1 Bit Size: 8 1/2 Jets: 3 x 16 , 2 x 12 , _x _TFA: 0.8100 4 Wt On Bit: RPM: 90 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 7280 r % . , Trip Depth: Ream ft Trip Gas: 532 Mud Cut: 10.0 ppg 9.8 Trip CI: 57147 ppm / Short Trip Depth ft Short Trip Gas: Mud Cut: p Short Trip CI: pp m Tight Spots: to Fee of Fill on Bottom: f j P ;. Current Lithology: %Sd %Sh %Clyst %Sltst %Sst %Coal Connection Gas and Mud Cut kN ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg . GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 6800 to Ream 145 80 14534 312 83 3 1 to 138 64 13189 288 85 7 0 lz: to 105 60 8701 230 65 4 0 to 83 45 8245 183 58 1 0 to to to I s to to to i 4. to ° to to to y t0 $ t0 <, 7y " 9 24hrRecap � .. P;. Wiper Wiper trip to run casing. 1 ' Logging Engineer: Chuck Stringer / Kerry Garner . 0 " 10000 units = 100% Gas In Air , 'r. 1 Customer: FEX Report No.: 21 .. ........................_....... ............................... Well: Aklaq #6 Date: 4/17/2007 Sperry Drilling Services Area: North Slope Midnight Depth 7280 1 Lease: Exploration Footage Last 24 hrs: 0 Rig: Arctic Wolf Rig Activity: 11 Job No.: AK - AM - 4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Jaque Ledbetter Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr ft/hr ( 0 ft/hr @ 0 ) Pumps 44 spm Flow rate 117 gpm Gas 0 units 0 unit: ( 0 units @ 0 ) Pump Capacity 2.7 gps -;. Pump Liner & Strk 5.5X9 in. Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 0 psi -A . =7 , - ' ' ... - . N:, s - n:': "k . - .. - - - i . : . 4q M\ Vi• " �,.x Mud Wt In 10.10 ppg Visc 58 secs API filt 3.9 ml HTHP 13.8 ml Mud Wt at Max Gas ppg Mud Wt Out 10.10 ppg PV 14 cP YP 20 Ibs /100ft2 Gels 6 \ 12 \ 15 MBT 5.0 pH 9.0 Sd 0.25 % Bit No.: Type: Bit Size: Jets: x x x TFA: ,, Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm j; Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm 1 Tight Spots: to Feet Fill on Bottom: ft ,: '€ to /; Current Lithology: %Sd %Sh 30 %Clyst %Sltst 50 %Sst 20 %Coal Oi Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg I ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ff units ppg ft units ppg ft units ppg ft units ppg `; ii .. °_ ,., . GAS PEAKS Vii, . . Depth Gas in units Chromatograph in ppm Lo to Max Average C1 C2 C3 C4 Tot C5 Tot fr to — to to to to I if to to '` to _ to to 1 to _ — . to to 1 t° to A 4 z te' - , r 24 hr Recap , � ° '" \ ° \ � - .w, ` - s . Logging Engineer: Chuck Stringer / Kerry Garner 10000 units = 100% Gas In Air r „,j r ; /Y. ' ,., e e :.. 2, ,. '..° ', ...... .we ... , " VOI :v _ . , s ue, s . - ` . tko L.L.[ Customer. FEX Report No.: 22 A Lri Well: Aklaq #6 Date: 4/18/2007 Sperry Qrilling S Area: North Slope Midnight Depth 7280 Lease: Exploration Footage Last 24 hrs: 0 Rig: Arctic Wolf Rig Activity: Job No.: AK-AM-4986881 Report For: Zenon Kotelko Mudlogger's Morning Report Jaque Ledbetter .. . Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr ft/hr ( ft/hr @ ) Pumps 55 spm Flow rate 147 gpm Oill Gas' 16 units 109 unit: ( 420 units @ 7050 ) Pump Capacity 3.1 gps y Pump Liner & Strk 5.5X9 in. . Sample Quality 0 Good 0 Fair 0 Poor Pump Pres 0 psi Mud Wt In 9.90 ppg Visc 55 secs API filt 4.4 ml HTHP 13.2 ml Mud Wt at Max Gas 9.70 ppg ' Mud Wt Out 9.70 ppg PV 13 cP YP 16 Ibs/100ft2 Gels 5 \ 7 \ 11 MBT 5.0 pH 8.8 Sd % Bit No.: Type: Bit Size: Jets: _x _ _ x x _ TFA: ria Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run I \ \\ Trip ft Trip Gas: Mud Cut: ppg Trip CI: ppm ml Pi Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: , to Feet of Fill on Bottom: ft ,..., .... s , , 0. Current Lithology: %Sd %Sh 30 %Clyst %Sltst 50 %Sst 20 %Coal �; • < Connection Gas and Mud Cut ft units ppg ft units ppg `t units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Z ft units ppg ft units ppg ft units ppg .. ; . :r° ... GAS PEAKS xi... „ a, p': .7' .�. �. �, � . Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot I C asing Run a 7050 420 134 48170 921 215 5a 0 Time to 2244 185 92 21824 432 96 0 0 Time to 2251 208 102 19514 387 92 4 0 I Time to 2340 195 96 21510 427 96 0 0 Time to 130 217 112 24214 500 128 4 0 to to to , to i to to to to to to .. 24 hr Recap ' 1 The gas unit are time base.Please notice at the top is time not depth ' 1. I Logging Engineer: Chuck Stringer / Kerry Garner 10000 units = 100% Gas In Air Customer: FEX Report No.: 23 - Well: Aklaq #6 Date: 4/19/2007 Sperry Drilling services Area: North Slope Midnight Depth 7050 cased I Lease: Exploration Footage Last 24 hrs: 0 Rig: Arctic Wolf Rig Activity: Casing Job No.: AK -AM- 4986881 Report For: Zenon Kotelko tIIN Mudlogger's Morning Report Jaque Ledbetter 1 Midnt -3 AM 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr ft/hr ( ft/hr @ ) Pumps 0 spm Flow rate 0 gpm it R. Gas` 258 units 153 unit; ( 4216 units @ 3:12 ) Pump Capacity 3.1 gps _: Pump Liner & Strk 5.5X9 in Sample Quality 0 Good 0 Fair El Poor Pump Pres 0 psi LA Mud Wt In 9.80 ppg Visc 53 secs API Tilt 4.7 ml HTHP ml Mud Wt at Max Gas 8.40 ppg .. Mud Wt Out 9.80 ppg PV 11 cP YP 14 Ibs/100ft2 Gels 3 \ 12 \ 17 MBT 5.5 pH 8.8 Sd % it Bit No.: Type: Bit Size: Jets: x _ _ x x _ TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft J ' Current Lithology: %Sd %Sh 30 %Clyst %Sltst 50 %Sst 20 %Coal Connect Gas and Mud Cut ft units ppg ft units ppg ft units ppg , 1 ? I ft ft units ppg ft units ppg ppg ft units ppg units ppg ft units ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm I Max Average C1 C2 C3 C4 Tot C5 Tot Cementing at '3:12 4216 1181 421187 7765 1849 397 2 Time at "6:18 306 206 34760 726 161 5 0 Time at ***8:09 146 122 15445 389 114 9 0 II I to to to to I os to • to 1 to to to to to to ot '24hrRecap I Ni I 'Average values occur from 2:45 to 4:40; **Average values occur from 6:10 to 6:45; * "Average values occur from 8:00 to 8:34. Chromatagraph values listed occured at maxiumum total gas readings. : 1:: Logging Engineer: Chuck Stringer / Wayne Hermastead 10000 un its = 100% Gas In Air — 1 I MI — s• s• Mall EN 1— 1 1 r s, — M MI — HALLIBURTON WELL NAME: Aklaq #6 LOCATION North Slope OPERATOR: FEX AREA: Barrow CONTRACTOR: Doyon - Arctic Wolf STATE Alaska Sperry Drilling Services Drilling Project z . 2007 BIT RECORD ,ems R eserve AlaskO � BHA Bit Bit Bit Depth Depth Footage Bit TFA AVG WOB RPM PUMP FLOW GPM Bit Grade Remarks # # Type Size IN OUT Hours ROP PRESS 1 1 Hughes MX -1 12.25 99 2101 2002 46.50 0.670 43.1 12 - 20 100 1720 560 1- 1WT- A2- 1 -NO -TD POOH for casing 2 2 Hughes HCM605Z 8.50 2101 7280 5179 143.40 0.710 36.1 6 - 12 90 2515 560 0- 1- NO- A- X -0 -NO POOH for bit change 3 3 ARC -245 C.B. 8.50 7125 7163 38 13.40 2.8 8 - 20 70 730 240 Core Bit 4 4 rr2 Hughes HCM605Z 8.50 7163 7280 117 3.40 0.710 34.4 10 - 20 110 3000 450 0- 1- NO- A- X -0 -NO Total depth achieved am r on am am am G MB OM M i MB • MI I! GM - NB In ,.. :M a- ;:: � .�� � ' ..� 2,.... ' ,. ,.�a ,, , . , 'Ataivat q r: • HALLISURTON Casing Record Sperry Drilling Services Company FEX L.P. Area Barow - Alaska Well Aklaq #6 Job No: AK -AM- 4986881 16" CSG 80 ft MD Rig Arctic Wolf Spud Date 25 Mar 2007 9 5 /8" Csg 2072 ft MD Water -based Mud Record Mud Co Baroid TD Date: 14 Apr 2007 7" Csg 7050 ft MD Date Depth Wt Vis PV YP Gels T Filt R600112300 { Cake Solids Water Sd Pm ru pH MBT P C y or _...: R. a flMf Chlor Hard Remarks ft - MD ppg sec lb/100 Ili /100ft` m /30m 32nds % % % ppm(k) Ca++ 26 -Mar 0 9.80 45 9 19 7/10/11 3.5 37.0/28.0 1/- 5.2 93.0 0.12 9.7 0.16/0.43 22.0 100 Rig Up 27 -Mar 342 9.90 48 9 18 7/10/10 6.5 36.0/27.0 1/- 5.8 92.0 0.27 10.5 2.5 0.10/1.05 28.0 120 Test BOP's, drill to 300', POOH to change BHA. 28 -Mar 1472 10.00 45 11 26 10/18/19 6.6 48/37 1/- 6.6 90.0 0.50 0.21 9.7 5.0 0.19/2.19 32.0 140 Drill ahead, losing some fluid over shaker 29 -Mar 2026 10.30 46 14 26 11/26/29 6.4 54.0/40.0 1/- 7.3 90.0 0.25 0.70 8.8 5.0 0.10/1.15 35.0 120 Drill ahead. 30 -Mar 2101 9.90 43 11 23 9/17/22 6.4 45.0/34.0 1/- 7.3 90.0 0.50 8.0 6.0 -/0.58 35.0 120 Drill to 2101', short trip, POOH to run casing. 31 -Mar 2101 9.50 51 13 24 10/25/26 6.8 50.0/37.0 2/- 6.3 91.0 0.25 8.6 6.0 0.07/1.47 34.0 140 RIH w/ Casing, cement in place 01 -Apr 2101 9.30 51 12 25 10/23/25 6.4 49.0/37.0 1/- 2.9 95.5 0.20 0.50 8.8 6.0 0.10/1.40 31.0 140 Nipple up B0P's and Test 02 -Apr 2101 9.60 55 12 21 9/21/28 6.4 45.0/43.0 1/- 3.6 93.0 9.0 6.3 -/1.80 42.0 140 Finish BOP Testing, P/U DP and rack back, MU BHA 03 -Apr 2554 9.60 49 11 20 7/18/24 6.6 42.0/31.0 1/- 4.0 93.0 - 0.07 0.10 9.4 6.3 0.15/3.30 37.0 520 P/U BHA, drill out cement, perform FIT , drill ahead 04 -Apr 3653 9.60 56 13 21 7/18/26 4.6 47.0/34.0 1/- 6.2 91.0 0.10 0.05 9.0 7.0 0.15/3.10 35.0 420 Continue to drill 8.5" hole section 05 -Apr 4132 9.60 50 13 17 5/10/16 6.0 43.0/30.0 1/- 6.6 91.0 0.10 0.30 9.2 7.0 0.15/2.90 30.0 200 Drill to 3909', short trip 30 stands, RIH, drill ahead 06 -Apr 5022 9.60 60 16 16 4/13/20 4.0 48.0/32.0 1/2 6.8 91.0 0.05 8.4 7.0 0.10/3.20 28.0 200 Drill ahead, pumpingWalnut sweeps every 300 -500' 07 -Apr 5900 9.95 54 18 18 6/18/25 3.6 54.0/36.0 1/2 8.6 89.0 0.05 9.0 8.7 0.10/3.60 29.0 240 Drill f/ 5283 - 5534'. Short trip 26 stns. RIH.Drill ahead 08 -Apr 6766 9.95 54 17 17 8/19/21 8.2 51.0/34.0 1/- 8.7 89.0 0.20 8.0 8.5 0.10/2.80 30.0 280 Drill f/ 6045- 6789', loss 750 bbl, pumped 2 LCM pills 09 -Apr 7125 9.95 61 16 22 7/17/22 4.5 54.0/38.0 _ 1 /3 8.9 89.0 0.10 8.5 0.1 0.20/2.60 27.0 200 Drill f/ 6782- 7125', pull 26 stns, RIH, POOH. 10 -Apr 7125 10.05 61 17 21 7/24/31 4.8 55.0/38.0 2/3 8.3 89.0 0.30 0.55 10.0 6.5 0.41/2.80 34.0 120 Slowly POOH, flow check at shoe,Test BOP's 11 -Apr 7125 10.00 58 12 22 6/14/20 5.8 46.0/39.0 1/- 8.6 89.0 0.20 0.25 8.0 7.0 0.15/2.80 25.0 100 12 -Apr 7163 9.90 50 14 15 6/16/23 7.2 43.0/29.0 1/- 7.3 89.0 0.10 0.45 9.0 7.5 0.2/2.70 27.0 100 Build volume w /coring. Lost full returns. Pump LCM pill. 13 -Apr 7163 9.90 55 15 17 4/8/12 4.5 47.0/32.0 1/- 8.2 89.0 0.10 0.40 8.8 7.5 0.15/2.10 30.0 280 POOH with core. Monitor well @shoe 4bph static 14 -Apr 7234 10.00 50 12 13 4/16/21 5.5 37.0/25.0 1/- 9.3 88.0 0.50 8.1 5.0 0.10/2.70 29.0 320 Ream core section. Drill to 7234 losses 12 -48bph 15 -Apr 7279 10.10 53 13 18 4/15/21 4.9 44.0/31.0 1/3 8.5 89.0 0.10 0.10 9.0 7.0 0.12/3.00 26.0 320 POOH, tight @ 3748, backream 3748 -2970, loss 30bph 16 -Apr 7280 10.05 56 15 16 5/18/22 4.2 46.0/31.0 2/3 9.2 88.0 0.10 8.8 7.0 0.10/2.60 30.0 240 RIH w /wiper trip, ream 3300 -3330, 6992 - 6803,6962 -7270 17 -Apr 7279 10.00 55 14 16 6/11/12 4.7 44.0/30.0 1/- 7.7 90.0 0.40 9.5 5.0 0.20/2.40 29.0 200 Finish POOH from cleanout. Begin to run 7" casing. 18 -Apr 7280 9.70 53 14 17 6/9/12 4.2 45.0/31.0 1/- 5.5 92.0 0.10 0.20 8.9 5.0 0.10/3.40 31.0 200 Run 7" casing, @7040 stopped. Losses 20 -25 bbls /hr 19 -Apr 7280 9.80 53 11 14 3/12/17 4.7 63.0/25.0 1/- 7.0 91.0 0.10 0.10 11.2 5.5 0.35/2.50 25.0 340 Mix & Pump 23 & 60 bbls cement, WOC, Lift BOP, Rig casing cutter. 20 -Apr 7280 9.80 55 55 14 4/9/12 4.1 36.0/25.0 1/- 6.7 91.0 0.20 9.5 5.5 0.10/2.70 29.0 200 Cut 7" casing, Test BOP, RIN w/ 61/8" bit and BHA I sperry-sun Well Name: Aklaq #6 Depth (MD) 3408 to 3440 ft 1111 Location: NPRA (TVD) 3388 to 3419 ft 1111 Show Report II III D RILLING SERVICES 11:111 Operator: FEX Report Prepared By: Eugene Payne Date/Time Show Report No. 1 I : 04-Apr-07 . , Report Delivered To Zenon Kotelko I 1111 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly Formation: Argillaceous Siltstone 80%, m brn gry, IIII sli frm, rnd-sb blky, calc, arg grdg to slty sh ip. Sandstone, 20%, It-m gry, lwr v f gr-uppr v f gr, rr uppr v f gr- lw m f gr, sbang-sbrnd, 51- I i mod w cons, calc cmt, sl-mod arg, low relief, est upto 6% eff por, 0.1-0.8 mD perm. m 1 I _ % Hydrocarbon Ratios Depth 3420 ft Gas x Units 2500 Mud Chlorides (1000's) 35 Cl Cl Cl Cl •• I Flowline Background Show PPm ppm ppm C2 C3 C4 C5 Hydrocarbon Ratios 1000.0 - 1 - :III Hi C1 276990 - 7312 = 269678 C1/C2 = 112.1 I 1111 C2 2489 - 83 = 2406 C1/C3 = 217.3 IIII C3 1265 - 24 = 1241 C1/C4 = 359,6 III! C4 750 - 0 = 750 C1/C5 = 1834.5 NPH , 1111 C5 147 - 0 = 147 .. • IQ -- 100.0 ..... ...- •-• "" I 1111 Production 1111 Analysis pi: Gas H nWater nNon-Producible Hydrocarbons — „ — -• '-' 11 % ,. .... I :!: Depth ft Gas x Units Flowline Background Show PPm ppm ppm Mud Chlorides (1000's) Gas ---------- 1111 Hydrocarbon Ratios 10.0 — II C1 !III C I,III C3 - - = = C1/C2 C2 - = C1/C3 = = C1/C4 = Oil I III C4 - = C1/C5 = • 1 1111 C5 - = IIII Production 1111 1.0 Analysis [Gas f oil n Water 0 Non-Producible Hydrocarbons NPH 1111 3 % Hydrocarbon Ratios I Depth ft Gas L‹ Units Flowline Background Show Mud Chlorides (1000's) C1 C2 C1 C3 C1 C1 :II: C4 C5 1111 PPm ppm ppm Hydrocarbon Ratios 1000. 0 C2 0 . I C 1 !HI - - = = C1/C2 = C1/C3 = 1111 C3 - = C1/C4 = NPH 1111 C4 - = C1/C5 = I I:: C5 Production - = 1000 _— , -- 1 — 1111 Analysis MGas n1.2 nWater nNon-Producible Hydrocarbons „ ,...._... -- — IN 4 III I I Depth 1111 — % ft Gas x Units Mud Chlorides (1000's) Gas Flowline Background Show 1 i 111 IIII — __________ !!!! PPm PPm PPm I 11 1 Hydrocarbon Ratios 10.0 - I IN Cl - = !III = C1/C2 = _ C2 - C1/C3 = Oil 1111 C3 - = C1/C4 = ..... ... I C4 III1 - - = C1/C5 = C5 MPH = MI Production 1.0 1111 Analysis I Gas I Oil I Water U Non-Producible Hydrocarbons I 111111110WANI110:111:1:01:1:1111111111111EICAIIIIMIIMOMPAniiiiiiimmaniumommismommosom wommenommonmenommingiumessonseigiommemindismenumongemomml I I I 1 sperry-sun Wel Loc ation: R N a me: A Depth (MD) 4767 to 4796 ft (TVD) s47h2ow5 Report No 4 . 754 2 ft 11 I III DRILLING SERVICES Show Report Operator: FEX Report Prepared By: Larry Lynch Date/Time: 06-Apr-07 'NI Report Delivered To Zenon Kotelko „ .....:...:.........:...............:........ , , , ,...:,::,,:,:,:,,:,,,,,,:,:,:,......,.....,...„::::.::::::::,„:.:.,.„.,.,.,:,,,,: I q Interpretation: Chromatograph gas in air from possum belly. Sandstone 30%, clr transl, sub angular, sub rounded, vf gr grdg to sit q, 1111 w occ f gr, mod drt, cly matrix, calc, nsofc. Siltstone 10%, It gry, sft gummy, calc, sli aren. Shale 30%, m-drk gry, blky, pity, slty, sft-m frm. 1 I Claystone 30%, It gry, brnsh, calc, aren ip, sft-mod frm. This appears to be a poor gas show. :„...........,.:.:.:.:.....:.:.:.:............... ............... .., : : : : : :.:.:.:.,.,.,.:.....,...:._ :::„.:.:_,.,.:.,.: :.: : : : : : : .. . :.........,.....:.:.:.:.....:„...:.:.„.:. .:„... . .„ .„ „: : : : : : : : : : : : :.:.:.:...:...:.:.:...,.. .. ...„ , .„ „. . ..............„. ......... . . . ..................... ... . ..... .„ .„ „„„. . . „ . : . : : : : ... .. : : . ... .. ...... .......„........ ..... „.... . III Ei H Hydrocarbon Ratios it I) ) Depth 4782 ft Gas Units 158 Mud Chlorides (1000's) 30 Cl Cl Cl Cl I 4: Flowline Background Show PPm ppm ppm - 5 - 74 Hydrocarbon Ratios 1000.0 - 1111 Cl 15219 - 5343 = 9876 C1/C2 = 88.2 I 1111 C2 198 - 86 = 112 C1/C3= 379 8 't C3 50 - 24 = 26 C1/C4 = ., C4 0 - 0 = 0 C1/C5 = NPH I 100.0 - _.. liil C5 Ili: Production 0 - 0 = 0 MI Analysis FiGas n oil nWater nNon-Producible Hydrocarbons -...---"- ,...--• - .. "• '-' *' • ,, El — .._ _% ...., , I , • Depth 4795 ft Gas x Units 315 Mud Chlorides (1000's) 30 Ili Flowline Background ghow -- - PPm ppm ppm Gas - - - - - ------- Hydrocarbon Ratios 10.0 - - I • c i 55696 - 5343 = 50353 C1/C2 = 131.5 C2 469 - 86 = 383 C1/C3 = 359.7 IIII C3 164 - 24 = 140 C1/C4 = Oil : III: C4 66 - = C1/C5 = , I C5 NPH MI Production 1.0 - I , IN Analysis p1( Gas foil nWater n Non-Producible Hydrocarbons :: 3 % Hydrocarbon Ratios I I Depth ft Gas HUnits Flowline Background Show Mud Chlorides (1000's) Cl Cl Cl Cl C2 C3 C4 C5 PPm PPm ppm Hydrocarbon Ratios !!! Cl - - = = C1/C2 = C1/C3 = 1000.0 _ _ C2 111.1:: ---1 , [ ; 1! C3 - = C1/C4 = .; NPH 'lq 1 C4 - = C1/C5 = •! il I 1 p I C5 MI Production = 100.0 .... ... -- .. ..., • , 4 iF) Analysis Fic Gas f oil nWater n Non-Productle Hydrocarbons _ -- - _ Depth 111 111111 MI % ft Gas Units Iv: Mud Chlorides (1000's) Gas Flowline Background Show -... - - - ,.. - - - - - - - - - - PPm ppm ppm 4 I C 1 - = = Hydrocarbon Ratios C1/C2 = C2 - C1/C3 = 10.0 Oil ) 115 C3 - = C1/C4 = I C4 OH - - = = C1/C5 = C5 NPH 1.0 MI Production $ 111 Analysis I Gas I Oil I Water I Non-Producible Hydrocarbons ,11 I I I �� '''''''L''''''''"Ii: pi fill I;11[ Location: NPRA (TVD) 4819 to 4888 ft 4' I ', DRILLING SERVICES ,,,, Show Report Operator: FEX Report Prepared By: Larry Lynch Show Report No. 3 it Date/Time 06-Apr-0' ill „, Report Delivered To: Zenon Kotelko p Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 50%, clr, trans!, vfgr-grdg to Ilii slt w/occ f gr occ Ise qtz, sub angular, sub rounded, mod srt, calc, fri, crmbly, nsofc. Siltstone 20%, It gry, sft, gummy, aren ip. ri io 4 i t Hydrocarbon Ratios 4. Depth 4862 ft Gas 1 Units 515 Mud Chlorides (1000's) 30 C1 C1 C1 'q Flowline Background ''', Hydrocarbon Ratios 1000.0 NPH 0 - 0 = 0 ~�� ,, �� 100.0 �� -- �� _ �� �m � � • Depth 4�3o Gas 1unuo 644 Mud cmonueo<1000'� 30 Gas oi _~~~ I Flowline Background Show ���- ���~ ppm ppmn ppm _�~ nvu"vcammnRmiou 10.0 - C1 65892 - 8681 = 57211 c1x:2 = 55.0 �� � �� uu 1190 - 149 = 1041 o1/c3 = 97.6 ------ k ~" oo 624 - 38 = 586 C1/C4 = 1*9.4 cx/ ---- ~ ------ C4 383 - 0 = 383 C1/C5 ~ co - = 0 NPH I Production 10 ~~ xno/yx/s II Gas Iou Iwu�r Iwon'pmuummoH>mmuamvnx g' I % Hydrocarbon Ratios '; Depth 4893 ft Gas El Units 848 Mud Chlorides (1000'v) 30 Cl Cl Cl Cl 0 II I Background Show C2 C3 ppm ppm ppm ill Hydrocarbon Ratios 1000.0 Cl IN 78867 ' 8681 = 63888 c1/u2 = 73.1 ill ilk I oe 11n7 ' 143 = S5D o1/oo ~ 1rn.0 � C3 442 - 38 = 404 C1/C4 = 324.0 NPH C4 216 ' 0 = 216 o1/o5 = ____ I = Production 1oo.o _ ~— ~ -~ - lip zi Analysis Ioav Ion II Water Iwvn'pmduumoHyumxa,uuno r c~ - El 1% I Depth 4ouu n a"a Munus 1ono muuomonuoo(1000's) an aaw � Flowline Background Show _�~_�� Tr ppm ppm ppm ~� Hydrocarbon Ratios 10.0 I C1 117348 ' 8O01 = 1OOO88 o1x:u ~ 65.6 nu 1800 ' 149 ~ 1O57 C1/C3 = - 138.4 Oil C3 823 38 = 785 o1/C4 = 230.2 - C4 472 - 0 = 472 C1/C5 = 2*14.8 ---- I � oo 45 ' U ~ 45 NPH � _____- 10 Production ill Analysis El Gas Ion Iwute, • Non-Producible Hydrocarbons I I Depth (MD) 5796 to 5847 ft IIII IIII sperry-sun Well Name: Aklaq #6 Location: NPRA (TVD) 5743 to 5804 ft HI I DRILLING SERVICES I... Operator: FEX Show Report Report Prepared By: Eugene Payne/Larry Lynch Show Report No. 4 Date/Time: 08-Apr-07 Report Delivered To Zenon Kotelko I 1111 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 50%, clr, transl, qtzos, lithics 1111 w tr glau and carb mat, sub angular, sub rounded, cly matrix, calc, fri-cmtd, tr pyr, no stng, no for, slow diff pa yel v slowly bcmg unif, It yel ...... w tr v slow strng yel cut, brt pa yel ring cut. Siltstone 30%. Shale 10%. Claystone 10%. I Li] _ % Hydrocarbon Ratios NI Depth 5804 ft Gas x Units 770 Mud Chlorides (1000'$) , 29 Cl Cl Cl Cl I Flowline Background Show P C2 C3 C4 C5 Pm ppm ppm Hydrocarbon Ratios 1000.0 III C1 83068 - 6980 = 76088 C1/C2 = 36.4 I i.:. C2 2335 - 244 = 2091 C1/C3 = 92.1 III: C3 916 - 90 = 826 C1/C4= 195.6 Nil C4 401 - 12 = 389 C1/C5 = 8454.2 NPH 0 = 9 — • I 1111 Production 151( III Analysis Gas nail nWater nNon-Producible Hydrocarbons 100.0 - — — 1112 j % - I ::: Depth 5822 ft Gas x Units 586 Mud Chlorides (1000's) ^, Flowline Background Show __ - ppm ppm ppm Gas ____________ Hydrocarbon Ratios 10.0 - II 1111 C1 63451 - 6980 = 56471 C1/C2 = 35.4 !pi C2 1837 - 244 = 1593 C1/C3 = 86.3 1111. C3 744 - 90 = 654 C1/C4 = 170.1 Oil Ill C4 344 - 12 = 332 C1/C5 = 1821.6 Ili C5 :III Production 31 0 = 31 IIII: Analysis Fic Gas f oil riWater fl Non-Producible Hydrocarbons NPH 1.0 g_31 _ % Hydrocarbon Ratios I 6 Depth 5832 ft Gas x Units 933 Mud Chlorides (1000's) , 29 Cl Cl Flowline Background Show C2 C3 Cl Cl C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000.0 _ __ : __ ___ , _ • C 1 99379 - 6980 = 92399 C1/C2 = 34.7 NI C2 2905 - 244 = 2661 C1/C3 = 92.5 H p C3 1089 - 90 = 999 C1/C4 = 212.4 NPH HI C4 447 - 12 = 435 C1/C5 = 2148.8 I C5 IIII. Production 43 - 0 = 43 100.0 _w----- -- .... - ---- 1111 Analysis 171( Gas riCL riWater n Non Producible Hydrocarbons ......- — -- r 21 % I :::: Depth ft Gas x Units Flowline Background Show Mud Chlorides (1000's) , Gas i 11111 — ----- — — — ppm ppm ppm ________ 1 Hydrocarbon Ratios 10.0 . , HH C1 = Mi. - - = C1/C2 = C2 C1/C3 = Oil :Ill C3 - = C1/C4 = I :I* C4 IiIII - - = = C1/C5 C5 = NPH — — — — ft' il!k Production 1.0 Hil Analysis Jas ]0i1 Water nNon-Producible Hydrocarbons ... I I I ........ .......... ....:::.............. .::...::.............. .......... : : :.......... : : :.. : :. _....................... ..:............... ................. :............. 1111 " sperry -sun Well Name: Aklaq #6 Depth (MD) 6008 to 6070 ft 1::: Location: NPRA (TVD) 5965 to 6027 ft 1 II D RILLING SERVICES Operator: FEX Show Report No. 5 iiii Show Report Report Prepared By: Eugene Payne /Larry Lynch Date/Time: 08- Apr -07 F i ll Report Delivered To Zenon Kotelko I Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 70 %, clr, transl, gtzos, lithics w tr glau and carb mat, sub angular, sub rounded, cly matrix, calc, fri -cmtd, tr pyr, no stng, no flor, slow diff pa yel v slowly bcmg unif, It yel lilf w tr v slow strng yel cut, brt pa yel ring cut. Siltstone 10 %. Shale 10 %. Claystone 10 %. w ii ., ._... :,:::: :;:: :.::: :�: : : : : : : :: :::::::::::::::::::::::: : : ::. : : : : : : : :. ::: ::.. *i *::. *::: : :::*i:::: . :.. .,.: :*i* .::. .,,,,,,.,..,. .., : :: . 1 .., .., , , . .... ... 1 ,..:: ,...,......... : : : : :.. - : : -- 1111... -- -- 1111. , , ,,: :,,.:,.,... . ,.. ........... ... . ..... : : : ;: I' El ° Hydrocarbon Ratios pli Depth 6019 ft Gas Lx /0 Units 566 Mud Chlorides (1000's) 29 C1 C1 C1 Cl '9 Flowline Background Show C2 C3 C4 C5 PPm ppm PPm Hydrocarbon Ratios 1000.0 1111 C1 61894 - 8041 = 53853 01/02 = 29.7 - C2 2149 - 334 = 1815 C1 /C3 = 72.9 � C3 868 - 129 = 739 C1 /C4 = 178.3 C4 330 28 = 302 C1 /C5 = 13463 NPH C5 5 - 1 = 4 I :Ili Production 100.0 — Analysis © Gas U Oil II Water I Non - Producible Hydrocarbons — ( _ E - i i i Depth 6030 ft Gas x Units 1010 Mud Chlorides (1000's) 29 Gas , Flowline Background Show _ _ _ _ ppm PPm ppm _ — -- - - - - -- i Hydrocarbon Ratios 10.0 - C1 97404 8041 = 89363 C1 /C2 = 26.3 I 1111 C2 3728 334 = 3394 C1 /C3 = 48.9 C3 1955 - 129 = 1826 C1 /C4 = 115.0 Oil C4 805 - 28 = 777 C1 /C5 = 931 - — — • C5 97 - 1 = 96 NPH iiii Production 1.0 Analysis [Gas foil f Water fNon- Producible Hydrocarbons 1111 © % Hydrocarbon Ratios I 1111 Depth 6042 ft Gas 12j Units 1860 Mud Chlorides (1000's) 29 C1 C1 Cl Cl Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios :di 1000.0 '! 01 175455 - 8041 = 167414 C1 /C2 = 26.6 - -- -- 02 6616 - 334 = 6282 C1 /C3 = 47.8 $- C3 3634 - 129 = 3505 C1 /C4 = 110.5 NPH -- C4 1543 - 28 = 1515 C1 /C5 = 393 I NI C5 427 - 1 = 426 — — ..-• — iiii Production 100.0 Analysis [Gas f oil f Water f Non- Producible Hydrocarbons — _ ii 4 _ I MI Depth 6061 ft Gas x Units 878 Mud Chlorides (1000's) 29 Gas — — — .... — — — Flowline Background Show — — PPm ppm ppm — — — — Hydrocarbon Ratios 10.0 C1 91674 - 8041 _ _ 333 C1/02 = 30.0 02 3120 - 334 = 2786 01/03 = 69.7 Oil — C3 1329 - 129 = 1200 C1/04 = 176.4 i 1111 04 502 - 28 = 474 C1 /C5 = 9293 C5 10 - 1 = NPH Production 1.0 MI Analysis I Gas I Oil I Water II Non - Producible Hydrocarbons 1111 1111 .................:.. 1111:;: -: ..: ................... ..................:::.:. , 1111. ................:.. .. 1111. , I I I .< . >.::;<. . E E, , „ ,! 1 , .,.,., <£ ... ti , - -:E'e. ,... ., .,: :: ., , E , "L f€: u ESE?€ € t-" t- d , ,E E E € € €€ ` IE EE €E( i t ,• ! i 11 '.� K ,,. � I I �tid�G € � E € € i I rc t it f tf,( I ; ��i €ii�� iiii, itl ii i (e E .. i i . 1111 . wI I � EPo:iE � i u �iftLL' ��! i�: kt u�4€ WM€ fl��& 86tl6 i3i3 €�! ° `�,HE � 1 I � tl�Il6wa�E�l ��bi �� ' ��H , VV�o-Vr ,[ .- ,n i�� � > t��C��6 �i�Vi� S e C -s u n Well Name: Aklaq #6 Depth (MD) 6350 to 6362 ft ill iii p Location: NPRA (TVD) 6307 to 6319 ft r DRILLING SERVICES Operator: erator: FEX Show Report No. 6 ii Show Report Re port Prepared By: Eugene Payne/Larry Lynch Date/Time: 08 -A r 07 P p Y 9 Y rY Y P : €1 € i , Report Delivered To: Zenon Kotelko I Inter p Chromatograph gas analysis gas trap possum belly. 9 retation: Chromato ra h as in air anal sis from as tra at ossum bell Formation: Sandstone 40 %, clr, transl, sub angular, sub rounded, mod srt, cly matrix, sli talc, fri -cmtd, carb mat, lith specs, yel flor w slow blmg cut, no vis stng. i ly Siltstone 20 %, Shale 40 %. . !. - ... . .. .....< . . .e, .. ,,,l.b w it . ik :., ,ww: .. ..,, w. ,�...,. ,..e � ...,....,. .. ,> ,. . L., .., 4wJWl „wlw.L.,4... A I % Hydrocarbon Ratios Depth 6352 ft Gas © Units 1230 Mud Chlorides (1000's) 29 C1 C1 C1 C1 I Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000.0 C1 121980 - 8041 = 113939 C1 /C2 = 27.4 I C2 4486 - 334 = 4152 C1 /C3 = 65.4 _` C3 1872 - 129 = 1743 C1 /C4 = 184.4 C4 646 - 28 = 618 C1 /C5 = 1726 NPH C5 67 - 1 = 66 I WV Production © 100.0 _ -. — _ li�) Analysis Gas Oil Water Non- Producible Hydrocarbons �l 1 % Depth 6355 ft Gas © Units 1579 Mud Chlorides (1000's) 29 Gas Flowline Background Show _ _ _ PPm PPm PPm _ II I Hydrocarbon Ratios 10.0 — iii C1 150288 - 8041 = 142247 C1 /C2 = 26.4 C2 5717 - 334 = 5383 C1 /C3 = 62.6 E � 3 C3 2400 - 129 = 2271 C1 /C4 = 180.5 Oil C4 816 - 28 = 788 C1 /C5 = 708 - I ., C5 202 - 1 = 201 NPH € Production 1.0 h� Analysis © Gas 1 Oil II Water 1 Non - Producible Hydrocarbons © 1 % Hydrocarbon Ratios I Depth 6358 ft Gas © Units 1690 Mud Chlorides (1000's) 29 Cl C1 C1 Cl i� Flowline Background Show C2 C3 C4 C5 ppm ppm ppm , Hydrocarbon Ratios 1000.0 I i Cl 166152 - 8041 = 158111 C1 /C2 = 25.6 _ Al C2 6500 - 334 = 6166 C1 /C3 = 61.4 -- -- C3 2706 - 129 = 2577 C1 /C4 = 176.1 NPH I C4 926 - 28 = 898 C1 /C5 = 988 a II 0 C5 161 - 1 = 160 ' Production 100.0 _ ` Analysis 1 Gas I Oil 1 Water II Non - Producible Hydrocarbons I Iii, CI E Depth 6362 ft Gas 11 Units 1339 Mud Chlorides (1000's) 29 Gas �/� . E� Flowline Background Show (� ■ ppm ppm ppm -- Hydrocarbon Ratios 10.0 I � ' C1 120879 8041 = 112838 C1 /C2 = 22.9 Gas 1 Oil ! C2 5252 - 334 = 4918 C1 /C3 = 54.1 Oil 5' II 1 C3 2215 - 129 = 2086 C1 /C4 = 152.9 ii lii C4 766 28 = 738 C1 /C5 = 597 NPH it C5 190 1 = 189 1 i iii Production 1.0 LI E ,t! Analysis � le .., ..:; p p-N u.. l,. , t4 I Water 1 Non - Producible Hydrocarbons .,,: Eta t , .. ;.�,:.. , , ' t ,�<..� 1, .e €El t ... , . i p `� € � „ i �.t�� � �+ Ef ,( ,tE. ,SEE.. NI i i'4 € : I li i '1:11 1 rry�i 1 I L,ill - ;1 h N €E : E t E E E . I ',!''' '( € iIJE € € j�€ ,, I l ���1� i EEi I : E € € I..��,`h €�` l ., i , 1 , „ �[ E, f` E ,, *, k( €E "E E( { { {`€`iEE({{ E{E: i tl E k i : e[ € { E „ i,� I�r,, ' i `�` f `W{ E, €t , t :: �yt i (�({E; [ - ,'S'i I If:(14 €f€h- v :c111 Ws61e' 4t€ eb$ 1W�{} U� uEF1rt€ll��IIWLL L� ��bIf11�011�iW YSf /N:� ,i iW+ I.2 t R , v s c: f+> � tEE31G Ei N'�fil E4f f�tE '�IE[E�itf,IS{i€��€I�tE�ifA` itii I I I '. ■''':,!;'pLi„ .,, v ; 91; i.':,:.. tl - Flor/At ■ I stEi..,..w J1 pro 114 ,t , 1 : .t. sperry-sun Well Name: Aklaq #6 0 Depth (MD) 6380 to 6460 ft 0 '., Location: NPRA (TVD) 6337 to 6417 ft :.,. • !'il DRILLING SERVICES Operator: FEX Report Prepared By: Eugene Payne/Larry Lynch Show Report No. 7 Show Report Date/Time: ,,.• 08-Apr-07 — Report Delivered To Zenon Kotelko .., I '!' Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 50%, clr, trans!, sub angular, sub rounded, mod srt, cly matrix, sli calc, fri-cmtd, carb mat, lith specs, It yel for w slow blmg cut, no vis stng. Or Siltstone 20%, Shale 30%. ‘,r1 I " ' ll • % Hydrocarbon Ratios Depth 6380 ft Gas 15 Units 761 Mud Chlorides (1000's) 29 Cl Cl Cl C1 I Flowline Background ghow PPm C2 C3 C4 C5 PPm ppm Hydrocarbon Ratios 1000.0 Cl 69982 - 15717 = 54265 C1/C2 = 41.3 I C2 2010 - C3 742 - 695 = 315 = 1315 C1/C3 = 127.1 427 C1/C4 = 448.5 C4 269 - 148 = 121 C1/C5 = 54265 NPH I „ C5 4- 3= 1 ...- • ' Production 100.0 - Analysis 12 Gas I Oil I Water 11Non-Producible Hydrocarbons ■110 ......- ...._...—_ 1% - ... 1 Depth 6390 ft Gas CI Units 848 Mud Chlorides (1000's) 29 Flowline Background ghow Gas — PPm PPm ppm — ------------ Hydrocarbon Ratios 10.0 -111 .• C1 86852 - 15717 = 71135 C1/C2 = 33.1 C2 C3 2845 - 695 = 315 = 2150 C1/C3 = 101.9 1013 - 698 C1/C4 = 352.2 Oil - C4 350 - 148 = 202 C1/C5 = 71135 — • . _ I C5 4- 3= 1 illi Production 0 Analysis 12 Gas • Oil • Water I Non-Producible Hydrocarbons NPH 1.0 ' , B 1% Hydrocarbon Ratios I Depth 6417 ft Gas 11 Units 1530 Mud Chlorides (1000's) 29 Cl Cl iA IFf' Flowline Background ghow C2 C3 Cl Cl C4 C5 :rih !!! PPm PPm PPm th; ,h- Hydrocarbon Ratios i Cl 151832 - 15717 = 136115 C1/C2 = 30.0 1000.0 C2 5234 - 695 = 4539 C1/C3 = 80.0 k C3 2017 - 315 = 1702 C1/C4 = 229.1 NPH ' 4 C4 742 - 148 = 594 C1/C5 = 1039 Production I If C5 134 - 1 3 = 131 100.0 — , I 1,14 Analysis LI Gas • Oil 0 Water U Non-Producible Hydrocarbons •-• 2 - - 1:1 1% I Depth 6431 ft Gas 111 Units 1741 Mud Chlorides (1000's) 29 Flowline Background Show Gas — ,-------- — — — . 1 ..f PPm PPm PPm -------- 0! Hydrocarbon Ratios 10.0 C1/C2 = 28.9 I Cl 172074 - 15717 = 156357 C2 6108 - 695 = 5413 C1/C3 = 75.2 Oil C3 2394 - 315 = 2079 C1/C4 = 206.3 !'ll C4 •,-, 906 - 148 = 758 C1/C5 = 571 C5 277 - 3 = 274 Analysis W Gas • Oil N Water N Non Hydrocarbons NPH Production 1.0 €11 11 ',,' ,t,;It',L,,"LLE;;Sim,..,,,,.., ,,,,,q j 11.41' ' V.Pigii.gli qii , 111 1 4' 44° '. 4.1'4 1 '1. 1111,11:11:::: I , .. '. i igiv I b :61:;11 i■ ''• r i i d Iiiiiiiii111:440 'h: .iii I I ' 1 > . Er... „ i i L!,,E ii 3 '''I�•. i :� i Dili i,, E . €,E ASH= i'it f k A r.:r`;:. a r III I l ( tt 4 i'i I � „>,:u.1,n,� w •�����u��, dt ui. lau��u��d�e11��u6�G� 'Ali(III[Ji„ te����,.��,tr�,�� „� . �I�i��u���.a . _� _ �. . ;�������u�-����� ,v�r���wy����� i � ,, �,. mrf r s pe rry -sun Well Name: Aklaq #6 Depth (MD) 7120 to 7150 ft ny 1 Location: NPRA ,, (TVD) 7077 to 7106 ft , DRILLING SERVICES Operator: FEX ,, Show Report No. 8 € I Show Report Report Prepared By: Eugene Payne /Larry Lynch Date/Time: 09- Apr -07 �I Report Delivered To: Zenon Kotelko Ll I Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 50 %, clr, trans!, sub angular, sub rounded, brn cly matrix, n calc, fri -cmtd, cart mat, lith specs, glau ip, no flor, no cut, no vis stng. Siltstone 20 %, Shale 30 %. y rocarbon Ratios % H d Depth 7125 ft Gas IS Units 4450 Mud Chlorides (1000's) 29 C1 C1 C1 C1 I Flowline Background ppm ppm Show C2 C3 C4 C5 ppm Hydrocarbon Ratios 1000.0 C1 281797 - 7448 = 274349 C1 /C2 = 12.2 I 11 C2 23057 603 = 22454 C1 /C3 = 33.9 C3 8298 - 205 = 8093 C1 /C4 = 129.4 C4 2204 - 84 = 2120 C1 /C5 = 924 NPH It I C5 297 - 0 = 297 i Production 100.0 — — _ — s. Analysis El Gas Oil Water Non- Producible Hydrocarbons ( Depth 7128 ft Gas © Units 113 Mud Chlorides (1000's) 30 Gas I/ Flowline Background Show PPm ppm PPm it Hydrocarbon Ratios 10.0 C1 10855 - 2618 = 8237 C1 /C2 = 23.5 I C2 459 108 = 351 C1 /C3 = 61.5 C3 184 50 = 134 C1 /C4 = 343.2 Oil C4 30 - 6 = 24 C1 /C5 = - — — C5 0 - = 0 NPH „ 'li Production ili'i 1.0 Il�� Analysis 12 Gas I Oil III Water II Non-Producible Hydrocarbons 'f© 1 Hydrocarbon Ratios I €E ; `€ Depth 7143 ft Gas © Units 197 Mud Chlorides (1000's) 30 C1 C1 C1 Cl ,r Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000.0 I '- C1 48690 - 2618 = 46072 C1 /C2 = 34.6 / i C2 1440 108 = 1332 C1 /C3 = 149.6 r = C3 358 50 = 308 C1 /C4 = 555.1 w NPH C4 89 - 6 = 83 C1 /C5 = 15357 //:” ' -- .... I 1 C5 3 - 0 = 3 Production 100.0 Analysis © Gas I Oil U Water U Non - Producible Hydrocarbons ICI 1% Depth 7147 ft Gas ©Units 189 Mud Chlorides (1000's) 30 Gas ig Flowline Background Show -------- _ - PPm PPm PPm -- Hydrocarbon Ratios 10.0 C1 18869 - 2618 = 16251 C1 /C2 = 18.3 [Ili' C2 996 108 888 C1 /C3 = 77.8 Oil u C3 259 - 50 = 209 C1 /C4 = 325.0 I L, C4 56 6 = 50 C1 /C5 = 8126 — — — — gi C5 2 0 = 2 NPH P Production 1.0 Analysis Gas I Oil I Water I Non - Producible Hydrocarbons I I . •.• .•.• 1111 sperry-sun Well Name: Aklaq *6 Depth (MD) ? to ? ft III: Location: NPRA (TVD) ? to ? ft 1111 1:11 DRILLING SERVICES Operator: FEX Report Prepared By: Chuck Stringer/Kerry Garner Show Report No. 9 Show Report Date/Time Ill; : 16-Apr-07 Report Delivered To: Zenon Kotelko I I I I Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. .i1 % Hydrocarbon Ratios 111 Time 9:28 Gas -; Units 150 Mud Chlorides (1000's) Cl Cl Cl Cl Flowline Background Show C2 C3 C4 C5 PPm PPm ppm Hydrocarbon Ratios 1000.0 - I I I Cl 57147 - 7707 = 49440 C1/C2 = 45.0 ill C2 :Ill C3 1183 - 353 - 85 = 33 = 1098 C1/C3 = 154.5 — 320 C1/C4 = 441.4 C4 112 - 0 = 112 C1/C5 = 24720 NPH c5 1 Production 2 - 0 = 2 1111 100.0 Analysis FFIGas foil nWater Non-Producible Hydrocarbons 2 LI% Time 11:33 ft Gas x Units 500 Mud Chlorides (1000's) 30 Flowline Background ghow Gas .. - ... PPm PPm PPm _ _ Hydrocarbon Ratios 10.0 - .... C 1 :III C3 13189 - 6481 = 288 - 181 = 6708 C1/C2 = 62.7 C2 107 C1/C3 = 268.3 85 - 60 = 25 C1/C4 = 745.3 Oil - I 1 C4 9 - 0 = 9 C1/C5 = #DIV/0! — — - b • CS Production 0 0 = 0 NPH 1.0 01 Analysis U Gas I Oil U Water la Non-Producible Hydrocarbons 1 110 1% Hydrocarbon Ratios Depth 7143 ft Gas 13 Units 197 Mud Chlorides (1000's) 30 Cl Cl Cl Flowline Background Show C2 C3 C4 Cl C5 11:1 PPm PPm PPm Hydrocarbon Ratios 1000.0 Cl 1111 C2 0- 0 - 0 = 0 = 0 C1/C2 = #DIV/0! 0 C1/C3 = *DIV/0! r_ .•: C3 0 - 0 0 0 C1/C4 = #DIV/0! •• NPH C4 C 0 - 3 - 0= 0 = 0 C1/C5 = 3 Production 0 5 100.0 _ — Analysis fl Gas f oil nWater pi, Non-Producible Hydrocarbons — 4 ok Depth 7147 ft Gas H Units 189 Mud Chlorides (1000's) 30 Gas Flowline Background Show PPm ppm ppm — — — — . I 0 = Hydrocarbon Ratios 0 C1/C2 = *DIV/0! C2 0 - 0 C1/C3 = #DIV/01 10.0 Cl 0 - 0 = Oil C3 0 - 0 = 0 C1/C4 = #DIV/0! C4 C5 0 - 0 - 0 = 0 = 0 C1/C5 = #DIV/0! 0 NPH Production 1.0 Analysis Gas • Oil I Water U Non-Producible Hydrocarbons I Halliburton Company p Y I Survey Report Company: FEX Date: 4/25/2007 Time: 17:55:01 Page: 1 Field: NPRA (zone 5) Co- ordinate(NE) Reference: Well: Aktaq #6, True North Site: Aklaq #6 Vertical (TVD) Reference: Aklaq #6: 18.6 Well: Aklaq #6 Section (VS) Reference: Well (0.00N,0.00E,297.20Azi) Wellpath: Aklaq #6 Survey Calculation Method: Minimum Curvature Db: Oracle Field: NPRA (zone 5) i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 5 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 I Well: Aklaq #6 Slot Name: Well Position: +N / -S 0.00 ft Northing: 6110601.80 ft Latitude: 70 42 44.663 N +E / -W 0.00 ft Easting : 426473.10 ft Longitude: 154 36 27.778 W Position Uncertainty: 0.00 ft Wellpath: Aklaq #6 Drilled From: Well Ref. Point Tie -on Depth: 0.00 ft Ili Current Datum: Aklaq #6: Height 18.60 ft Above System Datum: Mean Sea Level Magnetic Data: 2/15/2007 Declination: 21.09 deg Field Strength: 57452 nT Mag Dip Angle: 80.58 deg Vertical Section: Depth From (TVD) +N / -S +E / -W Direction ft ft ft deg I 0.00 0.00 0.00 297.20 Survey Program for Definitive Wellpath Date: 4/25/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 321.30 7120.65 Aklaq #6 (321.30- 7120.65) MWD MWD - Standard Survey E MD Incl Azim TVD Sys TVD N/S VW M MapE Tool ft deg deg ft ft ft ft ft ft 18.60 0.00 0.00 18.60 0.00 0.00 0.00 6110601.80 426473.10 TIE LINE 321.30 1.12 267.69 321.28 302.68 -0.12 -2.95 6110601.71 426470.15 MWD 417.94 1.37 203.11 417.90 399.30 -1.22 -4.34 6110600.63 426468.74 MWD 475.47 0.94 202.15 475.42 456.82 2.28 -4.79 6110599.57 426468.29 MWD 604.93 0.51 173.86 604.87 586.27 -3.83 -5.13 6110598.02 426467.93 MWD 666.98 1.18 289.72 666.92 648.32 -3.89 -5.70 6110597.97 426467.36 MWD 729.49 0.87 201.27 729.42 710.82 -4.12 -6.48 6110597.75 426466.58 MWD 792.90 0.63 180.96 792.82 774.22 4.92 -6.66 6110596.95 426466.39 MWD 854.71 1.18 289.28 854.63 836.03 -5.04 -7.27 6110596.83 426465.78 MWD 917.30 1.43 230.25 917.21 898.61 -5.33 -8.47 6110596.55 426464.57 MWD 979.44 1.12 299.00 979.33 960.73 -5.53 -9.60 6110596.36 426463.44 MWD 1166.43 0.87 181.14 1166.31 1147.71 6.07 -11.23 6110595.85 426461.82 MWD 1416.23 3.47 194.43 1415.91 1397.31 -15.28 -13.14 6110586.65 426459.80 MWD 1605.57 7.18 250.25 1604.50 1585.90 -24.83 -25.72 6110577.23 426447.14 MWD I 1667.19 7.87 268.68 1665.60 1647.00 -26.23 6110575.91 426439.28 MWD 1730.43 8.01 212.36 1728.32 1709.72 -30.06 -40.26 6110572.15 426432.55 MWD 1793.24 9.55 271.80 1790.51 1771.91 -33.60 -47.82 6110568.69 426424.95 MWD 1 2130.87 12.66 264.25 2121.80 2103.20 -36.42 - 112.66 6110566.51 426360.09 MWD 2195.00 12.69 263.76 2184.36 2165.76 -37.89 - 126.66 6110565.18 426346.08 MWD 2250.33 12.06 265.20 2238.41 2219.81 -39.04 - 138.46 6110564.15 426334.27 MWD 2319.81 10.61 266.70 2306.53 2287.93 -40.01 - 152.08 6110563.32 426320.64 MWD II 2373.88 9.90 269.00 2359.74 2341.14 -40.38 - 161.70 6110563.04 426311.02 MWD 2443.24 8.24 274.53 2428.23 2409.63 -40.09 - 172.61 6110563.44 426300.11 MWD 2506.30 6.93 284.61 2490.74 2472.14 -38.78 - 180.80 6110564.84 426291.94 MWD 2568.99 5.87 299.81 2553.04 2534.44 -36.23 - 187.24 6110567.45 426285.53 MWD i 2630.44 4.38 332.79 2614.26 2595.66 -32.58 - 191.04 6110571.14 426281.76 MWD 2693.21 4.19 10.45 2676.86 2658.26 -28.20 - 191.72 6110575.53 426281.13 MWD 2755.86 3.63 40.67 2739.38 2720.78 -24.44 - 190.01 6110579.26 426282.87 MWD 2818.14 3.20 81.21 2801.55 2782.95 -22.68 - 187.00 6110581.00 426285.90 MWD 2880.64 3.39 133.17 2863.96 2845.36 -23.68 - 183.93 6110579.97 426288.96 MWD 1 1 i rton Company Hall bu p y Survey Report 1 Company: FEX Date: 4/25/2007 Time: 17:55:01 Page: 2 Field: NPRA (zone 5) Co- ordinate(NE) Reference: Well: Aklaq #6, True North I Site: Aklaq #6 Vertical (TVD) Reference: Aktaq #6: 18.6 Well: Aktaq #6 Section (VS) Reference: Well (O.00N,O.00E,297.20Azi) Wellpath: Aklaq #6 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVA Sys TVD N/S E/W M MapE Tool ft deg deg ft ft ft ft ft ft 2944.15 3.51 105.74 2927.36 2908.76 -25.49 - 180.68 6110578.12 426292.19 MWD I 2999.32 4.50 79.32 2982.40 2963.80 -25.55 - 176.93 6110578.03 426295.94 MWD 3068.73 6.38 55.85 3051.50 3032.90 -22.88 - 171.06 6110580.64 426301.84 MWD 3130.71 7.43 45.78 3113.03 3094.43 -18.15 - 165.34 6110585.31 426307.61 MWD 3186.24 10.79 42.98 3167.86 3149.26 -11.84 - 159.22 6110591.56 426313.79 MWD I 3255.80 12.13 49.57 3236.03 3217.43 3319.68 12.43 53.38 3298.45 3279.85 -2.33 -149.21 6110600.96 426323.89 MWD 6.12 - 138.58 6110609.31 426334.60 MWD 3379.03 12.83 56.28 3356.36 3337.76 13.59 - 127.97 6110616.67 426345.28 MWD 3442.67 14.19 59.11 3418.24 3399.64 21.52 - 115.40 6110624.47 426357.93 MWD L 3505.14 12.92 60.74 3478.97 3460.37 3563.29 12.97 66.14 3535.64 3517.04 28.86 -102.73 6110631.69 426370.67 MWD 34.68 -91.09 6110637.39 426382.37 MWD 3631.28 13.29 76.24 3601.87 3583.27 39.63 -76.52 6110642.19 426396.98 MWD 3691.59 14.78 83.08 3660.38 3641.78 42.20 -62.15 6110644.62 426411.38 MWD 3753.91 16.25 92.60 3720.43 3701.83 42.77 -45.54 6110645.02 426427.99 MWD 3816.47 17.20 102.96 3780.36 3761.76 40.29 -27.78 6110642.37 426445.73 MWD 3878.61 16.59 109.43 3839.82 3821.22 35.28 -10.46 6110637.18 426463.00 MWD I 3941.46 13.85 114.58 3900.46 3881.86 29.17 4.85 6110630.91 426478.24 MWD 4002.87 11.19 119.79 3960.41 3941.81 23.15 16.71 6110624.78 426490.04 MWD 4066.52 9.70 119.64 4023.00 4004.40 17.43 26.73 6110618.96 426500.00 MWD 4127.27 7.01 130.05 4083.11 4064.51 12.51 34.01 6110613.97 426507.24 MWD I 4192.30 4.94 148.28 4147.79 4129.19 7.58 38.52 6110608.99 426511.69 MWD 4256.10 4.60 186.68 4211.38 4192.78 2.70 39.67 6110604.10 426512.79 MWD 4314.74 5.07 202.87 4269.82 4251.22 -2.02 38.39 6110599.39 426511.46 MWD 4378.25 4.76 208.82 4333.09 4314.49 -6.92 36.03 6110594.52 426509.06 MWD 4440.34 3.41 230.26 4395.03 4376.43 -10.35 33.37 6110591.12 426506.36 MWD 1 4503.08 3.45 276.70 4457.67 4439.07 -11.33 30.06 6110590.18 426503.04 MWD 4565.18 3.62 297.12 4519.65 4501.05 -10.21 26.46 6110591.32 426499.46 MWD 4629.17 3.33 298.41 4583.52 4564.92 -8.41 23.03 6110593.16 426496.04 MWD 4687.61 3.17 296.53 4641.87 4623.27 -6.88 20.09 6110594.72 426493.12 MWD I 4751.47 3.10 297.70 4705.63 4687.03 -5.29 16.98 6110596.34 426490.03 MWD 4813.76 3.03 297.55 4767.83 4749.23 -3.75 14.03 6110597.91 426487.09 MWD 4875.78 2.93 296.24 4829.77 4811.17 -2.29 11.16 6110599.40 426484.23 MWD 4938.94 2.82 298.82 4892.85 4874.25 8.35 6110600.89 426481.44 MWD 5001.16 2.76 297.24 4955.00 4936.40 0.60 5.68 6110602.34 426478.78 MWD 5064.08 2.57 300.12 5017.85 4999.25 2.00 3.11 6110603.77 426476.23 MWD 5126.76 1.93 285.14 5080.48 5061.88 2.98 0.88 6110604.77 426474.01 MWD I 5187.76 1.82 285.89 5141.45 5122.85 3.51 -1.04 6110605.32 426472.10 MWD 5252.81 1.74 281.17 5206.47 5187.87 3.99 -3.00 6110605.81 426470.14 MWD 5315.13 1.75 285.31 5268.76 5250.16 4.42 -4.85 6110606.27 426468.29 MWD 5376.45 1.97 282.87 5330.05 5311.45 4.90 -6.79 6110606.77 426466.36 MWD 5435.66 1.96 282.54 5389.22 5370.62 5.35 -8.77 6110607.24 426464.39 MWD I 5500.91 1.67 283.79 5454.44 5435.84 5.82 -10.78 6110607.73 426462.38 MWD 5626.74 1.33 289.67 5580.23 5561.63 6.75 -13.93 6110608.68 426459.24 MWD 5814.88 1.41 293.95 5768.31 5749.71 8.42 -18.09 6110610.40 426455.09 MWD 5999.28 1.42 297.89 5952.66 5934.06 10.40 -22.18 6110612.42 426451.03 MWD I 6187.37 1.46 292.14 6140.69 6122.09 12.40 -26.46 6110614.46 426446.77 MWD 6374.61 1.36 295.66 6327.87 6309.27 14.26 -30.67 6110616.36 426442.57 MWD 1 6561.62 1.40 295.99 6514.83 6496.23 16.22 -34.73 6110618.37 426438.54 MWD 6750.80 1.29 301.04 6703.95 6685.35 6873.26 1.18 311.87 6826.38 6807.78 18.34 -38.65 6110620.52 426434.64 MWD 19.90 -40.77 6110622.10 426432.53 MWD 6998.65 1.08 306.80 6951.75 6933.15 21.47 -42.68 6110623.69 426430.64 MWD 7120.65 1.44 299.57 7073.72 7055.12 22.91 -44.93 6110625.16 426428.41 MWD 1 r 1 Halliburton Company P Y I Survey Report Company: FEX Date: 4/25/2007 Time: 17:55:01 Page: 3 Field: NPRA (zone 5) Co- ordinate(NE) Reference: Well: Aklaq#6, True North Site: Aklaq#6 Vertical (TVD) Reference: Aklaq#6: 18.6 Well: Aklaq #6 Section (VS) Reference: Well (0 00N,0.00E,297.20Azi) Wellpath: Aklaq#6 Survey Calculation Method: Minimum Curvature Db: Oracle Survey I MD Inc' Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 7280.00 1.44 299.57 7233.02 7214.42 24.88 -48.41 6110627.17 426424.95 PROJECTED to TD 1 1 1 1 1 1 1 1 1 1 1 1 i 1 1 1 I FEX, L.P. Aklaq #6 1 Days -vs- Depth 0 ognosed I I I I •Actual 1 Drilling Project -- ', — 1000 - ` -�� DIM 12 1/4" Hole I d 2007 , a, I m R R v ve Alas i . „. , a — ! s I I 1 Set 9 5/8" casing at 2072' 2000 — - -- - -- -- - - -- 3000 - - -- — - -- -- I 1 I al 4000 , \ Li — — 0 _. 3 ! \ . I µ Drill 8 1/2" L ( I 5000 I N 2 MN Mme I 6000 - - -- 1 liN, ..„ , . , _ ., Cut core from 7125 - 7163'. + 7000 - -- - - -- Unll a 1 /2- - ; I Set cog & Log v� _ _ . �� Total Depth 7280' I (. I 8000 -- - - -- Ms III III I 9000 — 0 5 10 15 20 25 30 Rig Days 1 �. Drilling Project y. 2007 e � e en, R .tom eserve Alaska FEX, LP Aklaqyaaq #1 API # 50- 279 - 20018 -00 DATA CD O 1 AKLAQ # 6 EMIR 01 -COVER PAGE a 02 -TABLE OF CONTENTS 'a 03- GENERAL INFO a 04 -DAILY SUMMARY Li 05 -Daily Activity IADC 06- MORNING REPORTS 07 -BIT RECORD 08 -MUD REPORTS ai 09 -SHOW REPORTS Ira 10- SURVEY DATA a 11 -DAYS vs DEPTH ASCII Data INSITE DataBase O Logs (PDF at EMF) EMF's !Ta Insite Plot Def PDF's HALLIBURTON Sperry Drilling Services • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. Formation Eval. Logs Engineering Log I I HALLIBURTDN Sperry Drilling Services I I END OF WELL REPORT I Aklaq #6 NPRA Exploration I ,. =" h r IF.4. / IC Ili 1. = , i 1 1 SO rte" ill II 4 ..,,,,./.... ., y , .... .. I Directional Drilling & MWD/LWD Services r I ' HAL.LIBURTON 1 End of Well Report ' for ' FEX L.P. Rig Arctic Wolf Well : Aklaq #6 Field : Exploration ' Country : U.S.A. Job Number : AK -MW- 0004986881 Date : 25-Mar-07 API Number : 50- 279 - 20019 -00 1 1 Sperry Drilling Services 1 1 HALLIBURTON Sperry Drilling Service ' General Information I Company: FEX L.P. Rig: Doyon Arctic Wolf Well: Aklaq #6 I Field: Exploration Lease Name: NW NPR -A State: Alaska I County: North Slope Country: U.S.A. I API Number: 50- 279 - 20019 -00 Sperry-Sun Job Number: AK -MW- 0004986881 Job start date: 25- Mar -07 I Job end date: 15- Apr -07 North reference: True Declination: 21.048 deg Dip angle: 80.588 deg Total magnetic field: 57455 nT I Date of magnetic data: 25 March, 2007 Wellhead coordinates N: 70 deg. 42 min 44.66 sec North Wellhead coordinates E: 154 deg. 36 min 27.78 sec West I Vertical section direction: 258.00 deg Unit Number: Unit 119 MWD Engineers: A. Munro, T. Onyekwelu, P. Orth, G. Samons I Company Representatives: G. Fischer, E. Natte Company Geologist: J. Ledbetter, Zenon Kotelko 1 1 Job No,: AK -MW- 0004986881 Well No.: Aklaq #6 End of Well Report Page 3 1 I 1 HALLIBURTON Sperry Drilling Service Operational Overview ' Sperry Drilling Services was called out on March 22, 2007 to provide MWD /BHA services for FEX L.P. In NW NPRA, Alaska, well Aklaq #6 with API 50- 279 - 20019 -00. MWD Run 100 was a 12 Yo" hole utilizing 8" Directional with Dual Gamma Ray, 4 Phase Electromagnetic Phase Resistivity, and Stabilized Litho - Density. This run spudded the well, drilling down to 9 5/8" surface casing point at 2101' MD. The casing shoe was set at 2072' MD. MWD Run 200 was a 8 %' hole utilizing 6.75" Directional, Dual Gamma Ray, 4 Phase Electromagnetic Phase Resistivity, Compensated Thermal Neutron, Stabilized Litho - Density, Pressure While Drilling, and recorded only Bi -Modal Acoustic. This run drilled out of the casing shoe and continued to 7125' MD where a trip was made for a coring run. MWD Run 300 was a 8'/ :" hole utilizing 6.75" Directional, Dual Gamma Ray, 4 Phase Electromagnetic Phase Resistivity, Compensated Thermal Neutron, Stabilized Litho- Density, Pressure While Drilling, and recorded only Bi -Modal Acoustic. This run drilled to TD. MWD Runs 100 -300 represent well Aklaq #6 API #50- 279 - 20019 -00. 1 1 I 1 1 Job No.: AK -MW- 0004986881 Well No.: Aklaq #6 End of Well Report Page 4 I E NM OM • M N — — — — — — — — — Nom r ea ow HAL.L.IBURTON Sperry Drilling Services Summary of MWD runs Run Bit Hole MWD Service Start End Drill/Wipe Run Start Date Run End Date BRT Oper. Circ. Max Serv. Trip Failure Type No. No. Size Depth Depth Distance Time Time Hrs. Hrs. Hrs. Temp. Int. for (in) (ft) (ft) (ft) (degF) MWD 100 1 12.250 PFE 342.00 2101.00 1759.00 27- Mar -07 09:45 30- Mar -07 13:00 75.25 64.900 46.900 100.40 No No 200 2 8.500 PFE 2101.00 7125.00 5024.00 03- Apr -07 06:15 10- Apr -07 12:00 173.75 177.730 128.320 133.10 No No 300 4 8.500 PFE 7162.00 7280.00 118.00 13- Apr -07 20:00 15- Apr -07 22:00 50.00 49.600 24.800 150.80 No No I I MEIN MI11=11 IIMINIIIMII MI NMI 1 111=1111 Mil IMI MI IIIIMIIIIIIN Job No.: AK -MW =0004986881 Well No.: Akleq #6 End of Well Report Page 5 I HALLIBURTON • Sperry Drilling Service I Bitrun Summary RUN TIME DATA I MWD Run : 100 Run Start : 27- Mar -07 09:45 BRT Hrs : 75.25 hr Circ. Hrs : 46.90 hr Rig Bit No : 1 Run End : 30- Mar -07 13:00 Hole Size 12.250 in Oper. Hrs : 64.90 hr DRILLING DATA I Start Depth : 342.00 ft Footage : 1759.00 ft Avg RPM : 75 rpm Avg ROP : 50.00 fph End Depth : 2101.00 ft Avg Flow Rate : 520.00 gpm Avg WOB : 10.0 klb Avg SPP : 331202 psf MUD DATA I Mud Type : Polymer Weight : 10.00 ppg Viscosity : 50.00 spqt PV : 10 cP YP : 50.00 fph Chlorides : 32000.00 ppm Max Temp. : 100.40 degF % Solids : 5.80 % % Sand : 0.50 % I pH : 9.70 pH Fluid Loss : 0 mptm % Oil : 0.00 % O:W : 0:100 MWD PERFORMANCE Tool OD : 8.00 in Type : PFE . Min. Inc. : 0.51 deg Min. Inc. Depth : 604.93 ft Final Az. : 316.29 deg Max Op. Press. : 2000 psig Max Inc. : 9.55 deg Max Inc. Depth : 1793.24 ft MWD Real -time % : 99 % MWD Recorded % : 99 Length Dist From Length Dist From I (ft) Bit(ft) (ft) Bit(ft) 1791.61 TM HOC 4" X 3.24" - 15.7# 5 -1/4" X 2- 13/16" NC 40 (4 FH) 1000.00 8.00 in OD / 1.92 in ID 4.00 in OD / 3.24 in ID SN :197545 9.02 0.00 * TM - SN :83657 791.61 Heavy Weight 248.59 4.00 in OD / 2.56 in ID I 6-1/ 543.02 Sledgehammer Jar 31.98 8" DM Collar 122.65 6.25 in OD / 2.25 in ID 8.00 in OD / 1.92 in ID 9.42 SN : 128581 511.04 * DM Sonde - SN : 138123 I HWDP 311.40 4.00 inOD /2.56inID p X -Over Sub 2 61 199.64 8.00 in OD /2.50 in ID 197.03 I NMDC 8.00 in 013 / 2.88 in ID 30.98 1 166.05 8" SLD Collar 91.49 8.00 in OD / 2.38 in ID 37.50 NMDC 30.99 * SLD Insert - SN : 136422 8.00 inOD /2.88inID 135.06 MWD 8333 _ I X-Over 8.00In Sub /02 51.33 70.84 8.00 in OD / 1.92 in ID 49.31 8 " MWD GR RES /PWD Pony Collar 15.22 8.00 in OD / 1.92 in ID 8.13 in OD / 3.25 in ID ' I 62.56 SN : 128829 27.79 I * PWD Insert - SN : 46437751919728860 Flozr Bnb 2 22 34.9 * EWR -P4 Insert - SN : 77613 8.00 in OD /2,88 in ID 31 * DGR Insert - SN : 157097 54.70 8" SperryDrill Lobe 4/5 - 5.3 stg 30.65 8.00 in OD / 5.00 in ID 12.251 OD /3.00 in ID 1.22 1.22 12.25 in COMMENTS Drilled from 342ft to section TD of 2101ft. Good detection. I Job No.: AK -MW- 0004986881 Well No.: Aklaq #6 End of Well Report Page 6 1 HALLIBURTON Sperry Drilling Service II Bitrun Summary RUN TIME DATA I MWD Run : 200 Run Start : 03- Apr -07 06:15 BRT Hrs : 173.75 hr Circ. Hrs : 128.32 hr Rig Bit No : 2 Run End : 10- Apr -07 12:00 Hole Size : 8.500 in Oper. Hrs : 177.73 hr DRILLING DATA I Start Depth : 2101.00 ft Footage : 5024.00 ft Avg RPM : 100 rpm Avg ROP : 69.00 fph End Depth : 7125.00 ft Avg Flow Rate : 500.00 qpm Avg WOB : 10.0 kib Avg SPP : 374402 psf I MUD DATA Mud Type : Polymer Weight : 9.95 ppg Viscosity : 52.00 spqt PV : 16 cP YP : 69.00 fph Chlorides : 31000.00 ppm Max Temp. : 133.10 degF % Solids : 7.30 % % Sand : 0.05 % I pH : 9.00 pH Fluid Loss : 5 mptm % Oil : 0.10 % 0:W : 0/100 _ MWD PERFORMANCE Tool OD : 6.75 in Type : PFE Min. Inc. : 1.08 deg Min. Inc. Depth : 6998.65 ft I Final Az. : 306.80 deg Max Op. Press. : 3700 psig Max Inc. : 17.20 deg Max Inc. Depth : 3816.47 ft MWD Real -time % : 99 % MWD Recorded % : 100 Length Dist From Length Dist From I ( ft) Bit (ft) (? 822.00 (ft) Bit (ft) • ` 4" X 3.24" - 15.7# 6" X 3" NC 46 (IF) 30.00 ii 4.00 inOD /3.24inID ll 6 -3/4" BAT Collar 792.00 6.71 in OD / 4.63 in ID 11737 SN :9012890806 22.42 4" X 2- 9/16" HWDP #29.7 - NC40(FH) 310.26 3 BAT Insert - SN : 0 4.00 in OD / 2.56 in ID I 481.74 4 -3/4" Sledgehammer Jar 22.47 TM HOC 105.50 4.00 in OD / 2.00 in ID 6.76 in OD / 4.88 in ID i 10.00 I SN : 728188`'. 1 i I 4" X 2 -9/16" HWDP #29.7 - NC40(FH) ) 261.78 459,27 4.00 inOD /2.56inID 6 3/4" PM3 Collar X - Over Sub / 00 197.49 6.79 in OD / 4.56 in ID 9.21 91.35 6.28 in OD / 2.88 in ID SN : 129369 195.49 * DM Sonde - SN : 154729 NM Flex Collar 31.08 6.68 in OD / 2.88 in ID 164.41 1 NM Flex Collar 30.87 6 3/4" ALD CTN Collar 86.29 6.75 inOD/2.88inID 6.73 inOD /4.63inID 29.73 SN : 129309 NM Welded Blade Stabilizer 5 62 133.54 . SLD Insert I 6.75 in OD / 2.81 in ID 127.92 MWD 99.32 56.56 Float Sub 2.58 28.60 6.80 in OD / 2.75 in ID 6 3/4" MWD GR/ RES/ PWD 3 26.02 6.76 in OD / 4.63 in ID 27.96 7" SperryDrill Lobe 7/8 - 6.0 stg SN : 129367 25.02 7.00 inOD /4.95inID I PDC -Modal HCM605 1 00 I.00 8.50131013/ 1.81101D COMMENTS • ' Drilled to core pt. I Job No.: AK -MW- 0004986881 Well No.: Aklaq #6 End of Well Report Page 7 II .._ 1 HALLIBURTON Sperry Drilling Service Bitrun Summary RUN TIME DATA 1 MWD Run : 300 Run Start : 13- Apr -07 20:00 BRT Hrs : 50.00 hr Circ. Hrs : 24.80 hr Rig Bit No : 4 Run End : 15- Apr -07 22:00 Hole Size : 8.500 in Oper. Hrs : 49.60 hr DRILLING DATA Start Depth : 7162.00 ft Footage 118.00 ft Avg RPM 90 rpm Avg ROP :38.00 fph End Depth 7280.00 ft Avg Flow Rate :440.00 gpm Avg WOB : 15.0 klb Avg SPP :331202 psf MUD DATA I Mud Type : Other Weight : 10.10 ppg Viscosity : 57.00 spqt PV : 16 cP YP : 38.00 fph Chlorides : 28000.00 ppm Max Temp. : 150.80 degF % Solids : 3.00 % % Sand : 0.10 % pH : 9.00 pH Fluid Loss : 4 mptm % 0i1 : 0.50 % O:W : 1/99 MWD PERFORMANCE . Tool OD : 6.75 in Type PFE Min. Inc. : 1.44 deg Min. Inc. Depth : 7120.56 ft Final Az. : 299.57 deg Max Op. Press. : 3750 psig Max Inc. : 1.44 deg Max Inc. Depth : 7120.56 ft MWD Real -time % : 99 % MWD Recorded % : 100 Length Dist From Length Dist From I (ft) Bit (ft) (ft) Bit (ft) 809.00 4" X 3.24" - 15.7# 6" X 3" NC 46 (IF) 30.00 4.00 in OD / 3.24 in ID 6 -3/4" BAT Collar no 1,; 779.00 6.71 in OD / 4.63 in ID 117.37 42 SN :9012890806 22. 4" X 2- 9/16" HWDP #29.7 - NC40(FH) 310.26 * BAT Insert - SN : 0 4.00 inOD /2.56inID 468.74 4 -3/4" Sledgehammer Jar 22.47 TM HOC 103.50 4.00 in OD / 2.00 in ID 6.76 in OD / 4.88 in ID 10.00 il SN:728188 446.27 I 4" X 2- 9/16" HWDP #29.7 - NC40(FH) ( 248 78 4.00 in OD / 2.56 in ID l 6 3/4" PM3 Collar X - Over Sub 2. 197.49 6 in OD / 4 in ID 91.35 9.21 6.28 in OD / 2.88 in ID SN :129369 195.49 . DM Sonde - SN : 154729 NM Flex Collar 31.08 6.68 in OD / 2.88 in ID 164.41 I 6.75 inOD /2.88inID NM Flex Collar 30.87 6 3/4" ALD CTN Collar 86.29 6.73 in OD / 4.63 in ID 29.73 SN :129309 NM Welded Blade Stabilizer 5 62 133 + SLD Insert ' 6.75 in OD / 2.81 in ID 127.92 MWD 9932 56.56 Float Sub 2 58 28.60 I 6.80 in OD / 2.75 in 1D 6 3/4" MWD GR/ RES/ PWD 26.02 6.76 in OD / 4.63 in ID 27.96 7" SperryDrill Lobe 7/8 - 6.0 stg 25 02 SN : 129367 7.00 in OD / 4.95 in ID PDC- Model HCM605 1.00 I.00 8.50 in OD/ I.01 in ID itii COMMENTS Cored 7125' MD to 7162' MD. Drilled to TD. MAD Pass from 7162' to 6844' MD. f Job No.: AK -MW- 0004986881 Well No.: Aklaq #6 End of Well Report Page 8 1 MN -- r 1 MI MN MN MN OM - MI NS r - - - M NM SECTION DETAILS REFERENCE INFORMATION Co-ordinate (N/E) Reference: Site Aidaq Exploration, True North F L. P Sec MD Inc Az TVD +N /-S +E/-W DLeg TFace VSec Target o Vertical (TVD) Reference: WELL g 37.10ft (Original Wet Etev) • 1 0.00 000 0.00 000 0.00 0.00 0.00 0.00 0.00 Measured Depth Reference: WELL © 37.10ft (Original Well Elev) 2 7267.00 0.00 0.00 7267.00 0 0.00 0.00 0.00 0.00 Calculation Method: Minimum Curvature • Project: NPRA CASING DETAILS Site:Aklaq Exploration HALLIBURTON Well: Aklaq #6 Na casings on this weilbore. Welibore: Aklaq #6 Sperry Drilling Services Plan: wp01 COMPANY DETAILS: FEX L.P. 0 0 Calculation Method: Mailman Curvature Error System: ISCWSA Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Eased 700 1400 — 1400 5° - 10 _ 2100 —2100 5 0 2800 I —2800 10 m cD 3500 —3500 15 v 10 ° - fD 4200 5° —4200 a - 0 4900 — 4900 5600 — 5600 6300 — 6300 7000 _ _ _ _ _ _ Aklaq #6 /Surveys — 7000 ------ Aklaq #6 /wp01 7700 — 7700 I I 1 1 I 1 I I I I 1 1 1 1 I 1 1 1 1 I 1 I I I I I I 1 1 I 1 1 I I I I 1 I I I 1 1 1 1 I 1 1 1 1 II I I I' I I I I I I I I I I 1 l 1 1 I I I I I I I I 1 I I I I I 11 -700 0 700 1400 2100 2800 3500 4200 4900 5600 6300 7000 7700 8400 9100 9800 10500 11200 I Halliburton Company Survey Report Company: FEX Date: 5/11/2007 Tbue: 08:53:45 Page: 1 I Field: NPRA (zone 5) Site: Aklaq #6 Co- ordinate(NE) Reference: Well: Aklaq#6, Trtie North Vertical (TVD) Reference: Aklak6: 95.9 Well: Aklaq#6 Section (VS) Reference: Well (0.00N,0.00E,297.21AZi) Wellpath: Aklaq#6 Survey Calculation Method: Minimum Curvature Db: Oracle I Field: NPRA (zone 5) Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 5 I Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Coordinate System: Well Centre Geomagnetic Model: bggm2006 Well: Aklaq #6 Slot Name: I Well Position: +N / -S 0.00 ft Northing: 6110601.80 ft Latitude: 70 42 44.663 N +E/ -W 0.00 ft Easting : 426473.10 ft Longitude: 154 36 27.778 W Position Uncertainty: 0.00 ft Wellpath: Aklaq #6 Drilled From: Well Ref. Point 502792001900 Tie -on Depth: 19.20 ft Current Datum: Aklak6: Height 95.90 ft Above System Datum: Mean Sea Level t Magnetic Data: 3/25/2007 Declination: 21.05 deg Field Strength: 57455 nT Mag Dip Angle: 80.59 deg Vertical Section: Depth From (TVD) +N / -S +E/ -W Direction I ft ft ft deg 19.20 0.00 0.00 297.21 Survey Program for Definitive Wellpath I Date: 4/25/2007 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 321.30 7120.65 Aklaq #6 (321.30- 7120.65) MWD MWD - Standard Survey MD Intl Aram TVD Sys TVD N/S E/W MON MapE _ tool ft deg deg It ft ft • It ft ft I 19.20 0.00 0.00 19.20 -76.70 0.00 0.00 6110601.80 • 426473.10 'TIE LINE 321.30 1.12 267.69 321.28 225.38 -0.12 -2.94 6110601.71 426470.15 MWD 417.94 1.37 203.11 417.90 322.00 -1.22 -4.34 6110600.63 426468.75 MWD 475.47 0.94 202.15 475.42 379.52 -2.28 -4.78 6110599.57 426468.29 MWD 604.93 0.51 173.86 604.87 508.97 -3.83 -5.12 6110598.02 426467.94 MWD I 666.98 1.18 289.72 666.92 571.02 0.87 201.27 729.42 633.52 -3.89 -5.69 6110597.97 426467.37 MWD 729.49 -4.12 -6.47 6110597.75 426466.59 MWD 792.90 0.63 180.96 792.82 696.92 -4.91 -6.65 6110596.95 426466.40 MWD 854.71 1.18 289.28 854.63 758.73 -5.04 -7.26 6110596.83 426465.79 MWD I 917.30 1.43 230.25 917.21 821.31 -5.33 -8.47 6110596.55 426464.58 MWD 979.44 1.12 299.00 979.33 883.43 -5.53 -9.60 6110596.36 426463.45 MWD 1166.43 0.87 181.14 1166.31 1070.41 -6.07 -11.22 6110595.85 426461.82 MWD I 1416.23 3.47 194.43 1415.91 1320.01 -15.28 -13.14 6110586.65 426459.81 MWD 1605.57 7.18 250.25 1604.50 1508.60 -24.83 -25.71 6110577.23 426447.14 MWD 1667.19 7.87 268.68 1665.60 1569.70 26.23 -33.55 6110575.91 426439.29 MWD 1730.43 8.01 212.36 1728.32 1632.42 -30.06 -40.25 6110572.15 426432.55 MWD I 1793.24 9.55 271.80 1790.51 1694.61 -47.82 6110568.69 426424.95 MWD 2130.87 12.66 264.25 2121.80 2025.90 -36.42 - 112.66 6110566.51 426360.09 MWD 2195.00 12.69 263.76 2184.36 2088.46 -37.89 - 126.65 6110565.18 426346.09 MWD 2250.33 12.06 265.20 2238.41 2142.51 -39.04 - 138.45 6110564.15 426334.28 MWD I 2319.81 10.61 266.70 2306.53 2210.63 -152.07 6110563.32 426320.65 MWD 2373.88 9.90 269.00 2359.74 2263.84 -40.38 - 161.69 6110563.04 426311.03 MWD 2443.24 8.24 274.53 2428.23 2332.33 -40.09 - 172.61 6110563.44 426300.12 MWD 2506.30 6.93 284.61 2490.74 2394.84 -38.77 - 180.79 6110564.84 426291.95 MWD j I 2568.99 5.87 299.81 2553.04 2457.14 -36.23 -187.23 6110567.45 426285.53 MWD 2630.44 4.38 332.79 2614.26 2518.36 -32.58 - 191.03 6110571.14 426281.77 MWD 2693.21 4.19 10.45 2676.86 2580.96 -28.20 - 191.71 6110575.53 426281.13 MWD 2755.86 3.63 40.67 2739.38 2643.48 -24.44 - 190.00 6110579.26 426282.88 MWD I 2818.14 3.20 81.21 2801.55 2705.65 -22.68 -187.00 6110581.00 426285.90 MWD 2880.64 3.39 133.17 2863.96 2768.06 -23.68 - 183.92 6110579.97 426288.97 MW D NM I Halliburton Company I Survey Report Company: FEX Date: 5/11 /2007 Time: 08:53:45 Page: 2 I Field: NPRA (zone 5) Site: Aklaq#6 Co- ordinate(NE) Reference: Well: Aklaq #6, True North Vertical (TVD) Reference: Aklak6: 95.9 Well: Aklaq #6 Section (VS) Reference: Well (0.00N,0.00E,297.21Azi) Welipath: Aklaq#6 Survey Calculation Method: Minimum Curvature Db: Oracle I Survey MD Inci Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft I 2944.15 3.51 105.74 2927.36 2831.46 -25.49 -180.68 6110578.12 426292.19 MWD 2999.32 4.50 79.32 2982.40 2886.50 -25.55 - 176.92 6110578.03 426295.95 MWD 3068.73 6.38 55.85 3051.50 2955.60 -22.88 - 171.05 6110580.64 426301.84 MWD 3130.71 7.43 45.78 3113.03 3017.13 -18.15 - 165.33 6110585.31 426307.61 MWD I 3186.24 10.79 42.98 3167.86 3071.96 -11.84 -159.21 6110591.56 426313.80 MWD 3255.80 12.13 49.57 3236.03 3140.13 -2.33 - 149.20 6110600.96 426323.89 MWD 3319.68 12.43 53.38 3298.45 3202.55 6.12 - 138.58 6110609.31 426334.61 MWD 3379.03 12.83 56.28 3356.36 3260.46 13.59 - 127.97 6110616.67 426345.29 MWD I 3442.67 14.19 59.11 3418.24 3322.34 21.52 - 115.39 6110624.47 426357.94 MWD 3505.14 12.92 60.74 3478.97 3383.07 28.86 - 102.73 6110631.69 426370.68 MWD 3563.29 12.97 66.14 3535.64 3439.74 34.68 -91.09 6110637.39 426382.37 MWD 3631.28 13.29 76.24 3601.87 3505.97 39.63 -76.52 6110642.19 426396.99 MWD I 3691.59 14.78 3753.91 16.25 83.08 3660.38 3564.48 42.20 -62.14 6110644.62 426411.39 MWD 92.60 3720.43 3624.53 42.77 -45.54 6110645.02 426428.00 MWD 3816.47 17.20 102.96 3780.36 3684.46 40.29 -27.77 6110642.37 426445.73 MWD I 3878.61 16.59 109.43 3839.82 3743.92 35.28 -10.45 6110637.18 426463.00 MWD 3941.46 13.85 114.58 3900.46 3804.56 29.17 4.86 6110630.91 426478.25 MWD 4002.87 11.19 119.79 3960.41 3864.51 23.15 16.72 6110624.78 426490.05 MWD 4066.52 9.70 119.64 4023.00 3927.10 17.43 26.74 6110618.96 426500.01 MWD 4127.27 7.01 130.05 4083.11 3987.21 12.51 34.02 6110613.97 426507.24 MWD I 4192.30 4.94 148.28 4147.79 4051.89 7.58 2.70 38.53 6110608.99 426511.70 MW D 4256.10 4.60 186.68 4211.38 4115.48 39.68 6110604.10 426512.80 MWD 4314.74 5.07 202.87 4269.82 4173.92 -2.02 38.40 6110599.39 426511.47 MWD 4378.25 4.76 208.82 4333.09 4237.19 -6.92 36.04 6110594.52 426509.06 MWD I 4440.34 3.41 230.26 4395.03 4299.13 -10.35 33.38 6110591.12 426506.37 MWD 4503.08 3.45 276.70 4457.67 4361.77 -11.32 30.07 6110590.18 426503.05 MW D 4565.18 3.62 297.12 4519.65 4423.75 -10.21 26.47 6110591.32 426499.46 MWD I 4629.17 3.33 298.41 4583.52 4487.62 -8.41 23.04 6110593.16 426496.05 MW D 4687.61 3.17 296.53 4641.87 4545.97 -6.88 20.10 6110594.72 426493.13 MWD 4751.47 3.10 297.70 4705.63 4609.73 5.29 16.99 6110596.34 426490.03 MW D 4813.76 3.03 297.55 4767.83 4671.93 -3.75 14.04 6110597.91 426487.10 MW D I 4875.78 2.93 296.24 4829.77 4733.87 -2.29 11.16 6110599.40 426484.24 MWD 4938.94 2.82 298.82 4892.85 4796.95 -0.82 8.36 6110600.89 426481.45 MWD 5001.16 2.76 297.24 4955.00 4859.10 0.60 5.69 6110602.34 426478.79 MW D 5064.08 2.57 300.12 5017.85 4921.95 2.00 3.12 6110603.77 426476.24 MW D I 5126.76 1.93 285.14 5080.48 4984.58 2.98 0.89 6110604.77 426474.02 MW D 5187.76 1.82 285.89 5141.45 5045.55 3.51 -1.03 6110605.32 426472.10 MWD 5252.81 1.74 281.17 5206.47 5110.57 3.99 -3.00 6110605.81 426470.14 MWD 5315.13 1.75 285.31 5268.76 5172.86 4.42 -4.85 6110606.27 426468.30 MWD 5376.45 1.97 282.87 5330.05 5234.15 4.90 -6.78 6110606.77 426466.37 MWD 1 5435.66 1.96 282.54 5389.22 5293.32 5.35 -8.76 6110607.24 42646439 MWD 5500.91 1.67 283.79 5454.44 5358.54 5.82 -10.77 6110607.73 426462.39 MW D 5626.74 1.33 289.67 5580.23 5484.33 6.75 -13.92 6110608.68 426459.25 MWD I 5814.88 5999.28 1.41 293.95 5768.31 5672.41 8.42 -18.09 6110610.40 426455.10 MW D 1.42 297.89 5952.66 5856.76 10.40 -22.17 6110612.42 426451.04 MWD 6187.37 1.46 292.14 6140.69 6044.79 12.40 -26.45 6110614.46 426446.77 MWD 6374.61 1.36 295.66 6327.87 6231.97 14.26 -30.67 6110616.36 426442.58 MWD I 6561.62 1.40 295.99 6514.83 6418.93 16.22 -34.72 6110618.37 426438.54 MWD 6750.80 1.29 301.04 6703.95 6608.05 18.34 -38.64 6110620.53 426434.65 MW D 6873.26 1.18 311.87 6826.38 6730.48 19.90 -40.77 6110622.10 426432.54 MW D 6998.65 1.08 306.80 6951.75 6855.85 21.47 -42.68 6110623.69 426430.64 MWD I 7120.65 1.44 299.57 7073.72 6977.82 22.91 -44.92 6110625.16 426428.41 MWD I - - 1 Halliburton Company ' Survey Report Company: FEX Date:. 5/1. 1/2007 Time: 08:53:45 Page: 3 ' Field: NP RA (zone 5) Co- ordinate(NE) Reference: Well: Akiaq #6, True North Site: Akiaq #6 Vertical (TVD) Reference: Aklak6: 95.9 Well: Aklaq#6 Section (VS) Reference: Well (0.00N,0.00E,297.21Azi) Wellpath: Aklaq#6 Survey Calculation Method: Minimum Curvature Db: Oracle ' Survey MD Ines Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft ' 7280.00 1.44 299.57 7233.02 7137.12 24.88 - 48.40 6110627.17 426424.95 PROJECTED to TD I I i 1 1 I spat- -s+un I ' ORI LLIN3 S�RVA1C6Al SSDS GEOMAG. SHEET I SSDS Job # AK -MW- 4986881 Date 25- March -07 Field Name Exploration I Rig Name Arctic Wolf Well Identification Aklaq #6 I Side Track No I Northings 6110601.744 M/ft* Eastings 426473.107 M/ft* I Latitude +0 70:42:44.662 N /S* Longitude - 154:36:27.778 E /W* 1 Data Source (y /n) SSDS MAGUTM BGGM2006 — NAD 27 I State / Zone Alaska / 5 I If no, be specific: I Geomag. Values Office Generated Field Generated Dip Angle 80.588 I Total Intensity (nT) 57455 Declination (deg)* 21.048 I Convergence (deg)* N/A N/A I * Where appropriate Signature Date I SSDS District Supervisor Jack Foley 25- Mar -07 SSDS Lead Engineer I I HALLIBURTON 1 Sperry -Sun MWDILWD 1 After Action Review Employee Name: Orth, Samons Date: 04/11/2006 Well: Aklaq #6 Hole Section: Production What went as, or better than, planned? ' Good detection during the entire run. What experienced difficulty? 1 No MWD issues. ' Recommendations? None. Were there any innovations and /or cost savings realized on this well? Pulser stuffed in the pipe shed saved approximately 30 min. rig time. This rig is a double which makes it especially unaccomodating during tool turns with quad combo. We were able to stand back half the string during the coring run. This saved approximately 2 hrs of rig time. Additionally, we read the BAT Sonic and the Caliper in the pipeshed for an additional time savings of about 4 hrs. 1 1 1 1 1 1 1 Sperry-Sun Confidential 1 HALLIBURTON 1 Sperry -Sun MWD /LWD 1 After Action Review INTERNAL COMMENTS 1 The Artic Wolf can only use lifting subs with 4" necks because they do not have a set of 5" elevators. A lifting sub was cut for this rig but it came out with a solid pin so we could 1 not use it with our tools. Also, we were previously told nothing leaves the rig as this is a "Super tight" hole. Then, 400' from TD, an FEX Drilling Engineer called and said that we (all the MWD hands on I both rigs) had misunderstood him and all the job data was to go to town at the conclusion of the well. 1 1 1 1 1 1 111 1 1 1 1 1 1 Sperry-Sun Confidential
