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Home My WebLink About209-007 • ConocoPhillips TRANSMITTAL FROM: Sandra D. Lemke, AT01808 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99503-3536 9 RE: Grandview 1 Permit: 209-007 DATE: 07/13/2016 Transmitted: NPRA, North Slope, Alaska Gran iew 1 501032059400 Grandview 1 -Weatherford/Omni Labs Routine Core analysis-June 1, 2009; Job# HH-42820; 8112.1-8217.1. CC: eSearch digital well file-Grandview 1 Receipt. Date: / i .) ' GIS-Technical Data Management I ConocoPhillips IAnchorage, Alaska I Ph: 907.265.6947 Sandra.D.Lemke@Conocophillips.com N0\11 201b • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ..cl q- 007 Well History File Identifier Organizing (done) Viwo-sided 111 IJIIIJIIIII 11 111 ❑ Rescan Needed 111 I 111111 RE DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Di kettes, No. ❑ Maps: Greyscale Items: Other, No/Type: Cp No. 1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: AMMO Date: Si t7 I I /s/ Yll I Project Proofing 111 UIIIIIIIlI 11111 BY: Maria Date: 6 i7 `1 /s/ Scanning Preparation / c -. x 30 = = TOTAL PAGES 3 & 0 < t! / 1 i (Count does not include cover sheet) P BY: Maria Date: /s/ Production Scanning III III I I il II 111 Stage 1 Page Count from Scanned File: 36 1 (Count does include er sheet) Pa•e Count Matches Number in Scannin j�Pre a r a tion: YES �� /E NO BY: Date: �Li' / / /s/ 1/ �/ 1 r F Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 11 ReScanned 111 IIIIIIUI IIIU BY: Maria Date: /s/ Comments about this file: Quality Checked III 1111111111111 I 1 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 4/19/2011 Permit to Drill 2090070 Well Name /No. GRANDVIEW 1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20594 -00 -00 MD 8425 TVD 8424 Completion Date 3/10/2009 Completion Status P &A Current Status P &A UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey y 1 " -- DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval OH / Ty Med /Frmt Number Name Scale Media No Start Stop CH Received Comments rl'iog Induction /Resistivity 25 Col 222 8425 Open 4/17/2009 MD DGR, EWR, CTN, ALD 09- Mar -2009 D C Lis 17864 ✓fnduction /Resistivity 173 8376 Open 4/17/2009 EWR logs in CGM, PDS � and EMF graphics D C Jpg 17929�Sample 8111 8217 Open 5/1/2009 Omni Core photos --L'og Sonic 5 Col 2341 7420 Case 5/1/2009 SSL, Quality Control Print 7- Mar -2009 (....-ED C Pds 17930'nic 2341 7420 Case 5/1/2009 SSL, Quality Control Print 7- Mar -2009 �I Log Sonic 25 Col 2341 7420 Case 6/3/2009 Sonic Scanner t C Pds 18085/ Sonic 2341 7420 Case 6/3/2009 Sonic Scan 7- Mar -2009 Graphics Files in .PDS and .TIFF formats pt Report: Final Well R 0 0 Open 6/15/2009 End of Well Report: Tab of Con, Equip & Crew, Well 0 Data, Geo Data, Pres /Form, Drilling Data, Daily Reps D C 18174 Report: Final Well R 0 0 Open 6/15/2009 End of Well Report: Tab of Con, Equip & Crew, Well Data, Geo Data, Pres /Form, Drilling Data, Daily Reps 1 F0 g Mud Log 2 Col 80 8425 Open 6/15/2009 MD Formation Logs 9 Mud Log 2 Col 80 8425 Open 6/15/2009 MD LWD Combo Log g Mud Log 2 Col 80 8425 Open 6/15/2009 MD Gas Ratio Log L. Mud Log 2 Col 80 8425 Open 6/15/2009 MD Drilling Dynamics Log Mud Log 2 Col 80 8425 Open 6/15/2009 MD Pore Pressure DATA SUBMITTAL COMPLIANCE REPORT 4/19/2011 Permit to Drill 2090070 Well Name /No. GRANDVIEW 1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20594 -00 -00 MD 8425 TVD 8424 Completion Date 3/10/2009 Completion Status P &A Current Status P &A UIC N D C 19327 Analysis -Misc 0 0 Open 2/6/2010 Goechemical Analytical Results w /graphics j'ED C Asc Directional Survey 28 8425 Open 1,140 Directional Survey 28 8425 Open pt Analysis - Misc 0 0 Open 2/6/2010 Goechemical Analytical Results 8raphics Digital files on T18085 Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cores and /or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 1/16/2009. , ADDITIONAL INFORMATION Well Cored? O N Daily History Received? N Chips Received? G/ N Formation Tops / N . Analysis 6/N GGd,V,tUn;, (j,,,$ S1 e 4 Cct s. Received? 1 Comments: — • Compliance Reviewed By: __ Date: y'.� -c2 m' .at. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, DATE: August 11, 2009 P.I. Supervisor �ef,l 'firf o7 FROM: Chuck Scheve, SUBJECT: Location Inspection Petroleum Inspector Conoco Phillips Grandview#1 PTD 2090070 Tuesday, Auqust 11, 2009; I per a Location Clearance Inspection of the Conoco Phillips exploratory well Grandview#1. I was accompanied on today's inspection by Mary Mae Ashcroft (Conoco environmental). This exploratory location was clean with no evidence of past drilling activity other than a slight discoloration of the tundra in the area of the pad and access roads. The cellar area was mounded nicely to prevent ponding. SUMMARY: I performed a Location Inspection of the Conoco Phillips abandoned Exploratory Well Grandview #1 and recommend this location be approved final location clearance. Attachments: Grandview #1.jpg Grandview #1 from air.jpg 2009 - 0811 _Location_Clearance_Grandview -1 _cs.doc ,; 0 S Location Clearance — Grandview ;1 (CPAI) Photos by AOGCC Inspector Chuck Scheve August 11, 2009 " ,,,� -- J . ' «V .. .. .+" 3, ' .,-.« 'e. ''''f"*".";',.„. _ •'" , gyp ..--- ' '► , c fi K ..> ;' � . +. et . `-� x ihr l y , '' I I s .. � ' ' .°` "?0;00110t T- 1- e ' ''''''' -,,, lit , .4 ,.„--- e -,,,,,, ,, ,t4.1 0 Y qR � x . k > , ! w" 1 � , •1 j ,y 7 • i x *.„. Ifr '''*4`..4` - - ' -- * -1 . L7'. 411..1'4,:: -"..-.t*Ii ''''' " ..t(' , : . +i#w�+ pw ax ':5 2009 -0811 _Location_ Clearance _Grandview -1 _cs.doc Grandview #1 P &A Page 1 of 2 • 11/ Maunder, Thomas E (DOA) From: Reimer, David J [David.J.Reimer @conocophillips.com] Sent: Monday, June 22, 2009 3:02 PM To: Maunder, Thomas E (DOA); Allsup- Drake, Sharon K Cc: Alvord, Chip; Chambers, Mark A Subject: RE: Grandview #1 (209 -007) Tom: No, I don't have a record that the original hard copy was submitted. At various times during the course of drilling in NPRA this winter, I would hand deliver documents and then neglected to make a note of it on our log. Lesson learned on my part. Thanks Dave From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, June 22, 2009 2:54 PM To: Reimer, David 3; Allsup- Drake, Sharon K Cc: Alvord, Chip; Chambers, Mark A Subject: RE: Grandview #1 (209 -007) Dave, I acknowledge that you sent electronic copies of the documents on March 6; however hard copies are required to be submitted. Do you have any record that original hard copies were submitted? Tom From: Reimer, David J [mailto: David .J.Reimer @conocophillips.com] Sent: Monday, June 22, 2009 2:50 PM To: Maunder, Thomas E (DOA); Allsup- Drake, Sharon K Cc: Alvord, Chip; Chambers, Mark A Subject: RE: Grandview #1 (209 -007) Tom: Checking our files, we have copies of the PDF documents that were attached as part of the email sent on March 6 along with a color copy of the original cover letter, 10 -403 form and log example. The original is not in our file. I can easily make another color copy of the original and hand carry it over this afternoon, if that will work for you and help take care of this issue. I appreciate your patience and regret any inconvenience this issue has caused. Thanks Dave From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, June 22, 2009 2:02 PM To: Reimer, David 3; Allsup- Drake, Sharon K Cc: Alvord, Chip; Chambers, Mark A 6/22/2009 'Grandview #1 P &A • Page 2 of 2 • Subject: RE: Grandview #1 (209 -007) Dave, et al, I am looking for the sundry that should have been submitted for the P &A of this well. The message below is one of the last I have on the subject. Dave initiated contact via email at - 1000 am on March 6 and provided a draft program with log sections and a wellbore drawing. It is noted in that message "Sundries are being prepared." I responded at 1430 with Commissioner Norman's oral approval to proceed with the plan. Prior to sending my note, Dave sent the note below with attachments. I do not find any listing of a 403 to P &A Grandview #1 in our incoming sundry log. Was a hardcopy 403, in duplicate, submitted to the Commission? I look forward to your reply, Tom Maunder, PE aOGCC From: Reimer, David J [mailto:David.J.Reimer @conocophillips.com] Sent: Friday, March 06, 2009 1:32 PM To: Maunder, Thomas E (DOA) Subject: Grandview #1 P&A Tom: Attached please find the signed cover letter and AOGCC 10-403 form for the Grandview #1 P &A. «AOGCC Cover Letter Grandview #1 P &A.PDF» «AOGCC 10-403 Grandview #1 P&A.PDF» Hopefully the review of requested log section and discussion on the operations while coring helped clarify matters for you. Let me know if any additional information is required. Thanks Dave 6/22/2009 ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510 -0360 March 6 200 ' Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry approval to P&A: Grandview #1 Surface Location: 1080' FNL, 902' FEL, Sec. 5, T9N, R1 E, UM X= 260,867 & ¥= 5,914,606 ASP4 NAD27 Target Location: 1080' FNL, 902' FEL, Sec. 5, T9N, R1 E, UM BHL: 1080' FNL, 902' FEL, Sec. 5, T9N, R1E, UM Dear Commissioner: ConocoPhillips Alaska, Inc. would like to permanently plug and abandon the Grandview #1 wellbore, located in the National Petroleum Reserve- Alaska. Doyon Rig 141 spud this well on 2/18/09 and TD'd the well on 3/5/09 The attached Sundry form 10-430 and back -up information describes the P&A procedure for the existing wellbore and has been discussed with BLM personnel. If you have any questions or require any further information, please contact me at 263 -4347 or Chip Alvord at 265 -6120. Sincerely, r- &144/(,.:Reti/MA David Reimer Staff Drilling Engineer cc: CONFIDENTIAL — Grandview #1 Chip Alvord ATO -1570 Leslie Senden ATO -1390 III • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon in 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: ConocoPhillips Alaska, Inc. Development ❑ Exploratory 151 209 -007 3. Address: Stratigraphic ❑ Service ❑ 6. API Number P. O. Box 100360, Anchorage, Alaska 99510 50 - 20594 - 7. KB Elevation (ft): 9. Well Name and Number: 94' BPMSL Grandview #1 8. Property Designation: 10. Field/Pools(s): ADL AA- 081785 / ALK 932520 Exploration- NPRA 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 8425' 8425' 8425' 8425' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' Surface 2313' 9.625" 2341' 2341' 5750 3090 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program 51 BOP Sketch ❑ Exploratory 51 Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/8/2009 Oil ❑ Gas ❑ Plugged ni Abandoned E2 1 16. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Reimer @ 263 - 4347 Printed Name Chip Alvord Title Drilling Manager Signature L r. / a Phone 265 -6120 Date 4 -d7 NAive �,s Att.elez, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 7/2005 SUBMIT IN DUPLICATE 0 • ConocoPhif i 5 i TRAN MITTA CONFIDENTIAL DATA f � : 0 FROM: Sandra D. Lemke, AT01808 TO: Christine Mahnken . 14494'a al,f 1 6 - 2 0 09 ConocoPhillips Alaska, Inc. AOGCC 3s P.O. Box 100360 333 W. 7 Ave. Suite 100 ' Y ncyo r iDj2S Co Anchorage AK 99510 -0360 Anchorage, Alaska 99503 -3536 age /492 49 8 / 0,1 RE: Grandview 1 Permit: 209 -007 DATE: 06/12/2009 Transmitted: NPRA, North Slope, Alaska Grandview 1 501032059400 1 CD and hardcopy report I Epoch Final Well Report - Mudlogging Data; 3/8/2009; contents; equipment and crew;well data;geological data; pressure /formation strength data; drilling data; daily reports; CD contains final well report; daily reports, LAS Mudlog data; Log PDF (images) files; DML database files; sample manifests; remarks files; TIFF files. I Color Togs prints (1 each): Formation log MD 80 -8425' I LWD Combo Log MD 80 -8425' RECEIV Gas Ratio Log MD 80 -8425' Drilling Dynamics MD 80 -8425' JUN 1. 2 { j Pore Pressure Log MD 80- 8 Oil & Gas Anal To all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: Grandview 1 - eSearch digital well file Kent S 0 - CPAIGeologist Receipt: lir Date: l 4 , 7 - r; Sanrira. D. Lemke %Conocnphiilips, corn 0 ConocoPhillips , vrx TRANSMITTAL ��114,4y . 2009 �� CONFIDENTIAL DATA s k 8 ail ��Ch ®nS. C nmmissi� de FROM: Sandra D. Lemke, AT01808 TO: Christine Mahnken age ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7` Ave. Suite 100 Anchorage AK 99510 -0360 Anchorage, Alaska 99503 -3536 RE: Grandview 1 Permit: 209 -007 DATE: 05/20/2009 Transmitted: NPRA, North Slope, Alaska Grandview 1 501032059400 1 CD and 1 color log print Schlumberger - LDWG edit of the OH REW log data in TIF format; with final graphics in PDS and TIFF format; 2040 -7420' md; log date 3/7/2009 To all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: Grandview 1 - eSearch digital well file Kent Smith - CPAIGeologist Receipt: Date: - GIS- Technical Data Management 1 ConocoPhillips Anchorage, Alaska 1 Ph: 907265.6947 Sandra, D, Lemke0Conocophillips. com 0 0 4 ) —Ov i- `` 3 .D.- • • Co oPhi11i TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01808 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510 -0360 Anchorage, Alaska 99503 -3536 RE: Grandview 1 Permit: 209 -007 DATE: 04/28/2009 Transmitted: NPRA, North Slope, Alaska Grandview 1 501032059400 1 color print and CD Schlumberger- Sonic Scanner; Log quality control print; 03/07/2009; run 1; 2341 -7420' md; 5" -100' and Graphics in PDS format 1 CD Omni Core Photos, Grandview 1; Foot by foot photos in White light only; Box photos in UV and White Light; 4/24/2009 To all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: Grandview 1 - eSearch digital well file Kent Smith - CP IG ologist Receipt: 0 i.- Date .- Date: JI/ Ali . ` �_ GI5- Technical Data Management 1 ConocoPhillips !Anchorage, Alaska 1 Ph: 907.265.6947 Sandra. D. Lemke0Conocophillips. com 009 -©b.2- t '-4-9a9 / 1-9 3 6 • G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510 -0360 ConocoPhillips Phone: 907 - 265 -6120 April 21, 2U09 V Commissioner faii'; State of Alaska Alaska Oil & Gas Conservation Commission Alaska 00 & Gas 'Crlt:l; Commission 333 West 7 Avenue Suite 100 Anihorarj Anchorage, Alaska 99501 Subject: Well Completion Report for Grandview 1 (209 -007) Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits this Well Completion Report for the recent work on the exploration well Grandview #1. The attachments include a summary of the daily drilling operations, a directional survey, an as- built, a summary of the P&A operations, list of the formation markers and photos of the site. We request that this data be held confidential as required under AS 31.05.035(c) ✓ and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future. If you have any questions regarding this matter, please contact me at 265 -6120. Sincerely, G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/skad • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 2 no,9 W ELL COMPLETION OR R ECOMPLETION REP�fRa TU ,,, 0 ,��,4$ ; '; la. Well Status: Oi ❑ G as LJ Plugged Abandoned Q Sus ❑ 1b. Well Cla Wf , 08 ` 20AAC 25.105 20AAC 25.110 Development L � J 7 Exploratory - 0 GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test El 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. b d. j March 10, 2009 209 - 007 / 3. Address: 6. a Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 February 18, 2009 ' 50 103 - 20594 - 00 ' 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1080' FNL, 902' FEL, Sec. 5, T9N, R1E, UM March 5, 2009 Grandview #1 Top of Productive Horizon: 8. KB (ft above MSL): 91.9' RKB 15. Field /Pool(s): not applicable Ground (ft MSL): 63.9' AMSL Exploration Total Depth: 9. Plug Back Depth (MD + TVD): 1084' FNL, 934' FEL, Sec. 5, T9N, R1E, UM surface 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 260867 ' y 5914606 . Zone 4 - 8425' MD / 8424' TVD . AA 081785 TPI: x - na y - not applicable Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 260835 . y 5914602 • Zone 4 none Tobin 932520 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22 . CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 28' 108' 28' 108' 26" 200 sx AS 1 9.625" 40# L -80 28' 2341' 28' 2341' 12.25" 315 sx AS Lite, 258 sx Class G 23. Open to production or injection? Yes ❑ No Q If Yes, list each 24. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET entire liner is slotted except for the following blank intervals: none none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug #1 6888' -7388' 474 sx Class G cement plug #2 6388' -6888' 474 sx Class G cement plug #3 5460' -5815' 141 sx Class G cement plug #5 28' -341' 137 sx AS 1 cement plug #4 2126' -2140' 147 sx AS 1 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) 24 -Hour Rate -> 27. CORE DATA Conventional Core(s) Acquired? Yes 0 - No ❑ Sidewall Cores Acquired? Yes 0 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. COMPLETION DATE , TO BE SENT UNDER SEPARATE COVER SHEET - 't'c' 67 i WE 1E1 ED Form 10-407 Revised 2/2007 ' t (..- ! s_ t. CIONTINUED ON REVERSE SIDE C°1l�a 7' a- 1 aDms 7--e'7 III 28. GEOLOGIC MARKERS (List all formations and marfcers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? E Yes Q No . If yes, list intervals and formations tested, Permafrost - Top ground surface - ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom not present not present needed, and submit detailed test information per 20 AAC 25.071. K3 2520' 2520' Top HRZ 7285' 7285' Alpine C sand 8046' 8046' Nuiqsut Marker 8350' 8349' . N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, P&A photos, as - built 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Reimer @ 263 - 4347 Printed Name G. L. Alvord as 265 - 6120 Title: Alaska Drilling Manager Signature A� Q, Phone 265 -6120 Date 4( ( Sharon Allsup -Drake 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 and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 • 0 ConocoPhillips(Alaska) Inc. Western North Slope WNS Non -Pad Grandview 1 Permit to Drill: 209 -007 API: 50- 103 - 20594 -00 Sperry Drilling Services Definitive Survey Report re = 12 March, 2009 I z HALLIBURTON 111r RV X ME Sperry Drilling Services • II/ Conoco Phillips Definitive Survey Report _ . .. . . Company :TiVi:- ConocoPhillips(Alaska) Inc. ", Grandview 1 PrOject:•' ••;:1 North Slope -, ;$1ii Reference :!' z- ?•:: ; RKB Doyon 141 © 91.90ft (Doyon 141 (28+63.9))i• Site : 1 ,:::=;i:: WNS Non-Pad - MD Reference .: ;:,;- ' ' `.?1- , ,:t : li::,.:: RKB Doyon 141 @ 91.90ft (Doyon 141 (28+63.9)) Well. :',- --,",;•,:: Grandview 1 :I.., • i]:'North Referen :'~ f.''.. ''.IA': True Woliborix ‘,:!!:0::: Grandview 1 .,,: Survey Calcitatieri Method *•;',.,. Minimum Curvature ,, • • •-,:: , ..,• , e . ,,, • , ^ . Desigm ••••j., ''' Grandview 1 Database - .- .,- - -" CPAI EDM Production , , .. . . ....... .. . . .. . .,-....„.„. ...,..,.. project 14.- . Western NorthSlope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor , , „ . , „.. .„.„........,,,.. , ................ ............ ,....„.. ,... . Waft , , :; 1 =! 1 :: . '•;'- .1 ig!: Grandview 1 , Well Position +N/-S 0.00 ft Northing: 5,914,605.63ft Latitude: 70° 10 3.345 N +E/-W 0.00 ft Easting: 260,867.00 ft Longitude: 151° 55' 28.484 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 63.90ft Weljamni,' -:- " :5:'.' Grandview 1 Magnetictil:;,i.: MCdal Name._ '..-:::::;:- , Sample Dat#0::„:9 ';,' , - 2 :: :-..Declination ,:::,:;-- ' . -:. l'Dtp;ittigle : FleM P . ; - ::-,."--; . 1-'.&' - 11;!: , /;"- -:', - :: '‘: 1-°)S' i! IT:: ‘:- '. : :.J'T: .i.:.., :.--- .:,:':: Y::::: .:".2 1,1 '-?' .' '' :', ..':,-. :., : ,J i= : `.',-;::':>‘!'.:,.'. : . ..' -:.: 1. :. .i: ,::::: .::•:::::::::::P.'„ :,:i::,..:...:. ' ' ': : -1.,,.;:...?- :-- BGGM2007 2/26i2006 ii.i 6 86.48 57,553 Design •-!,,,:,„ -:,--- i- Grandview 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 0.00 Vertical Section LT..; - I- - . - :::... - D From (TVD)i. . ' --:: .- :: 4N/4S t .-: .-.. - +E/4/1/ -'.-- , ::iT.i: - .%:;:: .-.:-blieciiitii (ft) -,:::: .;.: :. , 1:--!.. .8 .; :(ft): : ..;; ,.„ .:,-:- . - .. 28.00 0.60 0.00 0.00 . , . ,.. . .. Survey Program : ::.: - -:,-!:!:::', „. . Date i.: ::::::::,-' .. , - • - ' . 1,.From ••:, . To . • -: ...:.! ,..- . ':, - - -- - :-: .---- --- -.. • ::: ,: --:- ..';-:',-: --. : : '::-'-'''". -- ,,:•:. - -:'', 2 -1" : - : - (ft)' ::::. (ft) Survey (Went:ore) : . ' - •• Tool Name -: -. - ti,scriptipn .r. ,-:: :-.,- ...:::'.,:: - , : - -: 7 Survey 100.00 8,354.92 Grandview 1 MWD (Grandview 1) MWD MWD - Standard 2/18/2009 1: I I Survey - j,, • :i! . . ..„ ,•:. .: . .. • . .:.,:- . , : . 'H , .:':',•,. --' ., .:;-:,:::1- - " , ,- !: Map ::::::-..-. :=.:- Map ii :::-:: :.,'.. ' Vertica(K: OD, - Inc • .. ,.)I4z/. 'ITV-I?: -- TVIDS* :A:-:+N/-S . - ':' , i: - 1 - E1 - , - Northing : Eisting,? DLS Seal ' ' • ' -' -:- .;; :- :.- ':-- -:::,,- . :1 #0 ....::. (') : ( : ' (It) - ''' (ft) ' -: ''. (ft) ---- (ft) . ;'', ' :- (ft) -. . - , - - "':-:.' - f/1001 (It) : ... Survey Tool Name 28.00 0.00 0.00 28.00 -63.90 0.00 0.00 5,914,605.63 260,867.00 - 0.00 0.00 UNDEFINED 100.00 0.18 66.54 100.00 8.10 0.05 0.10 5,914,605.67 260,867.11 0.25 0.05 MWD (1) 211.50 0.56 32.75 211.50 119.60 0.57 0.56 5,914,606.19 260,867.58 0.38 0.57 MWD (1) 304.94 0.51 30.27 304.93 213.03 1.32 1.02 5,914,606.91 260,868.06 0.06 1.32 MWD (1) 397.51 0.42 34.55 397.50 305.60 1.95 1.42 5,914,607.54 260,868.48 0.10 1.95 MWD (1) 489.27 0.37 38.83 489.26 397.36 2.46 1.79 5,914,608.03 260,868.87 0.06 2.46 MWD (1) 580.38 0.36 38.24 580.37 488.47 2.91 2.15 5,914,608.48 260,869.25 0.01 2.91 MWD (1) 672.47 0.33 31.49 672.45 580.55 3.37 2.47 5,914,608.92 260,869.58 0.05 3.37 MWD (1) 762.82 0.31 42.10 762.80 670.90 3.77 2.77 5,914,609.31 260,869.89 0.07 3.77 MWD (1) 855.22 0.37 37.01 855.20 763.30 4.19 3.12 5,914,609.72 260,870.25 0.07 4.19 MWD (1) 948.26 0.32 42.47 948.24 856.34 4.63 3.47 5,914,610.14 260,870.62 0.06 4.63 MWD (1) 1,041.44 0.25 31.01 1,041.42 949.52 4.99 3.76 5,914,610.50 260,870.91 0.10 4.99 MWD (1) 1,133.86 0.27 41.53 1,133.84 1,041.94 5.33 4.00 5,914,610.83 260,871.17 0.06 5.33 MWD (1) 1,226.68 0.20 20.93 1,226.66 1,134.76 5.64 4.21 5,914,611.14 260,871.39 0.12 5.64 MWD (1) 3/12/2009 1:41:46PM Page 2 COMPASS 2003.16 Build 42F • • Conoco Phillips Definitive Survey Report compa4:-., . Inc. - Local Cci,ordinate Grandview 1 F- Project "" North Slope '.1VDitefaietice: -'Y-;1:: ,::::!RKB Doyon 141 @ 91.90ft (Doyon 141 (28+63.9)) Site! 4: . . Non-Pad - MD Reference - . - '::' -/--;" - RKB Doyon 141 @ 91.90ft (Doyon 141 (28+63.9)) ilValk:::!!!': ..,: 4Grandview 1 tioitlilteflieiice: ! ', :-:. ;;;. True WOW* ; :,'-::<,'A Grandview 1 --- SitOiekOaidOtiion *Obit '':::Ai Minimum Curvature ...... ..„, ........ De007.:::: :. -..;:ii Grandview 1 : i;:10r3..:- - .7:1 .'<:; CPAI EDM Production Survey - " ;: , .:1 :: .i:: : y: : : . : . --, :-,- -...),:',- -:::.: -- ,• ,.; : 7 . E '' ' :;: '.:! ..; ;: '', , i! .. ...; . ' ; .j:' ;':713fi;l:: ,-- .. , : J : :: .:: : , ;]i!;!iir, ‘ 1, :.:‘‘ -1 ,'' ;E:; d :::: ' c '::: ;;-'.;:':‘' .: S' :: ,s' [ .- Jf 5 -!' :: .', ,‘...;-::::::::` --"--'.--•: - -:',- 1 --t: NialtK.. Map -::- :'''• i, ,::---- - ViortkPIA: 1■ID.'::: : i'.: TVDS$11,:::--,'±')*-S , ' ,:. , Northing ;' ,:: OLS :.•• Aectit#W.;': 2 ‘ ':.1 • . ::, -;:1‘:i.:- ' . :„:..-!,,' , ::: ifti igi flf!' ' ' :i.-40:''..AViit:t02':::::,. . (ft) -..*.iftfi ito,, F:.e 1,318.42 0. 57:23 1,318.40 1,226.50 5.93 4.49 5,914,611.42 260,871.67 0.22 5.93 MIND (1) 1,411.50 0.16 31.38 1,411.48 1,319.58 6.19 4.78 5,914,611.67 260,871.98 0.21 6.19 MWD (1) 1,504.18 0.13 21.58 1,504.15 1,412.25 6.40 4.88 5,914,611.87 260,872.09 0.04 6.40 MWD (1) 1,597.43 0.24 29.13 1,597.40 1,505.50 6.67 5.02 5,914,612.14 260,872.23 0.12 6.67 MWD (1) 1,690.44 0.19 60.45 1,690.41 1,598.51 6.91 5.25 5,914,612.38 260,872.47 0.14 6.91 MWD (1) 1,782.61 0.18 55.39 1,782.58 1,690.68 7.07 5.50 5,914,612.53 260,872.72 0.02 7.07 MWD (1) 1,875.18 0.22 55.61 1,875.15 1,783.25 7.25 5.77 5,914,612.70 260,873.00 0.04 7.25 MWD (1) 1,967.26 0.26 254.14 1,967.23 1,875.33 7.30 5.71 5,914,612.74 260,872.94 0.51 7.30 MWD (1) 2,059.78 0.72 257.22 2,059.75 1,967.85 7.11 4.94 5,914,612.58 260,872.17 0.50 7.11 MWD (1) 2,151.75 0.79 253.54 2,151.71 2,059.81 6.80 3.77 5,914,612.31 260,870.99 0.09 6.80 MWD (1) 2,243.25 0.77 260.03 2,243.20 2,151.30 6.52 2.56 5,914,612.07 260,869.77 0.10 6.52 MWD (1) 2,282.76 0.74 263.83 2,282.71 2,190.81 6.45 2.05 5,914,612.01 260,869.25 0.15 6.45 MWD (1) 2,352.84 1.01 258.68 2,352.78 2,260.88 6.28 0.99 5,914,611.87 260,868.19 0.40 6.28 MWD (1) 2,449.87 1.03 251.42 2,449.80 2,357.90 5.83 -0.68 5,914,611.48 260,866.51 0.13 5.83 MWD (1) 2,542.47 1.11 256.73 2,542.38 2,450.48 5.36 -2.34 5,914,611.06 260,864.84 0.14 5.36 MWD (1) 2,635.21 1.05 258.29 2,635.10 2,543.20 4.98 -4.04 5,914,610.74 260,863.12 0.07 4.98 MWD (1) 2,727.21 1.38 241.58 2,727.08 2,635.18 4.28 -5.84 5,914,610.10 260,861.30 0.52 4.28 MWD (1) 2,819.12 1.16 249.16 2,818.97 2,727.07 3.42 -7.69 5,914,609.30 260,859.43 0.30 3.42 MWD (1) 2,912.34 1.07 246.79 2,912.17 2,820.27 2.75 -9.37 5,914,608.67 260,857.73 0.11 2.75 MWD (1) 3,005.17 1.09 245.62 3,004.99 2,913.09 2.04 -10.97 5,914,608.02 260,856.10 0.03 2.04 MWD (1) 3,097.53 0.88 251.74 3,097.33 3,005.43 1.45 -12.44 5,914,607.48 260,854.61 0.25 1.45 MWD (1) 3,193.14 0.79 269.07 3,192.93 3,101.03 1.21 -13.80 5,914,607.28 260,853.25 0.28 1.21 MWD (1) 3,285.30 0.92 244.76 3,285.08 3,193.18 0.89 -15.10 5,914,607.00 260,851.94 0.41 0.89 MWD (1) 3,375.26 0.68 241.72 3,375.03 3,283.13 0.33 -16.23 5,914,606.47 260,850.80 0.27 0.33 MWD (1) 3,465.33 0.12 276.09 3,465.10 3,373.20 0.08 -16.79 5,914,606.25 260,850.22 0.65 0.08 MWD (1) 3,562.85 0.25 39.57 3,562.62 3,470.72 0.26 -16.76 5,914,606.42 260,850.26 0.34 0.26 MWD (1) 3,654.70 0.17 354.10 3,654.47 3,562.57 0.55 -16.64 5,914,606.71 260,850.39 0.19 0.55 MWD (1) 3,747.94 0.23 325.77 3,747.71 3,655.81 0.84 -16.76 5,914,607.00 260,850.28 0.12 0.84 MWD (1) 3,840.38 0.38 307.06 3,840.15 3,748.25 1.18 -17.11 5,914,607.35 260,849.94 0.19 1.18 MWD (1) 3,933.06 0.41 295.08 3,932.83 3,840.93 1.50 -17.66 5,914,607.69 260,849.40 0.09 1.50 MWD (1) 4,025.75 0.50 299.96 4,025.51 3,933.61 1.85 -18.31 5,914,608.06 260,848.76 0.11 1.85 MWD (1) 4,118.06 0.43 324.38 4,117.82 4,025.92 2.33 -18.86 5,914,608.56 260,848.23 0.23 2.33 MWD (1) 4,210.92 0.48 343.37 4,210.68 4,118.78 2.99 -19.17 5,914,609.22 260,847.93 0.17 2.99 MWD (1) 4,301.88 0.38 346.02 4,301.63 4,209.73 3.64 -19.36 5,914,609.88 260,847.77 0.11 3.64 MWD (1) 4,394.92 0.06 62.46 4,394.67 4,302.77 3.97 -19.39 5,914,610.21 260,847.75 0.40 3.97 MWD (1) 4,487.27 0.35 127.69 4,487.02 4,395.12 3.82 -19.12 5,914,610.05 260,848.01 0.36 3.82 MWD (1) 4,579.61 0.17 69.38 4,579.36 4,487.46 3.69 -18.77 5,914,609.91 260,848.36 0.32 3.69 MWD (1) 4,672.27 0.12 34.21 4,672.02 4,580.12 3.82 -18.59 5,914,610.04 260,848.55 0.11 3.82 MWD (1) 4,766.02 0.07 345.08 4,765.77 4,673.87 3.96 -18.55 5,914,610.17 260,848.59 0.10 3.96 MWD (1) 4,859.13 0.09 320.46 4,858.88 4,766.98 4.07 -18.61 5,914,610.29 260,848.54 0.04 4.07 MWD (1) 3/12/2009 1:41:46PM Page 3 COMPASS 2003.16 Build 42F III • ConocoPhillips Definitive Survey Report Company:; 1 : ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference ' a'' Well Grandview 1 -3_ : a - = °, RKB Doyon (Doyon 141 (28 +63.9)) ;Project, _;, ,'; _? Western North Slope T1rD,: -.A < ,.: , yon 141 © 91.90ft (Do ,Site iWNS Non -Pad MD : Reference:= " .. RKB Doyon 141 © 91.90ft (Doyon 141 (28 +63.9)) . Well ; . : ; ,; <: - i Grandview 1 T North Reference:.: . ; True Wellbore:; '; _._ Grandview 1 ;_ Calculation Method: x Minimum Curvature • Desi n:; : ,.._ <_ g , , ; Grandwew 1 = Database::~:; : ° :' CPAI EDM Production Survey k °! Ma Ma E Vertical • „N` , , i ' 1 : = MD nc I Az. DID TVDSS +N!-S = +W Et . Northing Easting DtS, ' Section , (ft)° (14,1..-, (1 Ift) - ' , _,;,: Y (ft) (ft) rll ) E - Ift} Survey T 4,951.54 0.15 346.32 4,951.29 4,859.39 4.24 -18.68 5,914,610.46 260,848.47 0.09 4.24 MWD (1) 5,044.38 0.27 346.84 5,044.13 4,952.23 4.57 -18.76 5,914,610.79 260,848.40 0.13 4.57 MWD (1) 5,138.59 0.27 346.64 5,138.34 5,046.44 5.00 -18.86 5,914,611.23 260,848.31 0.00 5.00 MWD (1) 5,231.07 0.94 245.48 5,230.82 5,138.92 4.90 -19.60 5,914,611.15 260,847.57 1.11 4.90 MWD (1) 5,323.53 0.27 343.50 5,323.27 5,231.37 4.80 -20.35 5,914,611.07 260,846.81 1.10 4.80 MWD (1) 5,415.79 0.36 2.25 5,415.53 5,323.63 5.29 -20.40 5,914,611.57 260,846.78 0.15 5.29 MWD (1) 5,508.77 0.28 353.64 5,508.51 5,416.61 5.81 -20.42 5,914,612.09 260,846.78 0.10 5.81 MWD (1) 5,601.39 0.26 330.35 5,601.13 5,509.23 6.22 -20.55 5,914,612.50 260,846.66 0.12 6.22 MWD (1) 5,693.82 0.29 337.23 5,693.56 5,601.66 6.62 -20.74 5,914,612.90 260,846.48 0.05 6.62 MWD (1) 5,786.66 0.22 341.88 5,786.40 5,694.50 7.00 -20.89 5,914,613.29 260,846.35 0.08 7.00 MWD (1) 5,877.27 0.24 0.00 5,877.00 5,785.10 7.36 -20.94 5,914,613.65 260,846.30 0.08 7.36 MWD (1) 5,970.72 0.32 51.64 5,970.45 5,878.55 7.72 -20.74 5,914,614.00 260,846.52 0.27 7.72 MWD (1) 6,063.85 1.46 75.43 6,063.57 5,971.67 8.18 -19.39 5,914,614.42 260,847.89 1.26 8.18 MWD (1) 6,155.26 2.54 72.81 6,154.92 6,063.02 9.07 -16.32 5,914,615.21 260,850.98 1.19 9.07 MWD (1) 6,247.55 3.05 76.46 6,247.10 6,155.20 10.25 -11.98 5,914,616.25 260,855.35 0.59 10.25 MWD (1) 6,340.62 2.74 89.98 6,340.06 6,248.16 10.83 -7.35 5,914,616.69 260,860.00 0.80 10.83 MWD (1) 6,435.72 2.30 98.05 6,435.06 6,343.16 10.56 -3.19 5,914,616.29 260,864.15 0.59 10.56 MWD (1) 6,528.11 2.67 111.90 6,527.37 6,435.47 9.50 0.64 5,914,615.10 260,867.95 0.76 9.50 MWD (1) 6,620.52 2.02 149.21 6,619.71 6,527.81 7.30 3.48 5,914,612.81 260,870.71 1.75 7.30 MWD (1) 6,713.26 1.91 212.33 6,712.40 6,620.50 4.59 3.49 5,914,610.11 260,870.63 2.22 4.59 MWD (1) 6,805.88 1.93 259.55 6,804.97 6,713.07 3.00 1.13 5,914,608.59 260,868.22 1.66 3.00 MWD (1) 6,898.77 0.81 49.64 6,897.85 6,805.95 3.14 0.09 5,914,608.77 260,867.19 2.87 3.14 MWD (1) 6,989.71 1.14 46.44 6,988.78 6,896.88 4.18 1.23 5,914,609.77 260,868.37 0.37 4.18 MWD (1) 7,082.08 1.26 218.46 7,081.14 6,989.24 4.02 1.27 5,914,609.61 260,868.40 2.59 4.02 MWD (1) 7,174.94 1.61 239.43 7,173.97 7,082.07 2.56 -0.49 5,914,608.20 260,866.59 0.67 2.56 MWD (1) 7,267.54 1.59 255.86 7,266.54 7,174.64 1.58 -2.86 5,914,607.30 260,864.20 0.49 1.58 MWD (1) 7,360.31 2.06 256.43 7,359.26 7,267.36 0.87 -5.73 5,914,606.69 260,861.31 0.51 0.87 MWD (1) 7,454.59 1.86 260.04 7,453.48 7,361.58 0.21 -8.88 5,914,606.12 260,858.14 0.25 0.21 MWD (1) 7,545.85 1.99 260.60 7,544.69 7,452.79 -0.30 -11.90 5,914,605.70 260,855.10 0.14 -0.30 MWD (1) 7,639.83 2.10 259.75 7,638.61 7,546.71 -0.88 -15.21 5,914,605.24 260,851.78 0.12 -0.88 MWD (1) 7,731.19 1.84 258.92 , 7,729.92 7,638.02 -1.46 -18.29 5,914,604.75 260,848.67 0.29 -1.46 MWD (1) 7,823.89 1.44 261.11 7,822.58 7,730.68 -1.92 -20.90 5,914,604.37 260,846.05 0.44 -1.92 MWD (1) 7,915.32 1.15 259.18 7,913.99 7,822.09 -2.27 -22.94 5,914,604.09 260,844.00 0.32 -2.27 MWD (1) 8,008.69 1.14 248.46 8,007.34 7,915.44 -2.79 -24.72 5,914,603.63 260,842.20 0.23 -2.79 MWD (1) 8,102.37 1.19 259.89 8,101.00 8,009.10 -3.30 -26.55 5,914,603.17 260,840.36 0.25 -3.30 MWD (1) 8,192.24 1.06 257.53 8,190.85 8,098.95 -3.64 -28.28 5,914,602.88 260,838.62 0.15 -3.64 MWD (1) 8,283.93 0.91 251.08 8,282.53 8,190.63 -4.06 -29.80 5,914,602.51 260,837.10 0.20 -4.06 MWD (1) 8,354.92 0.91 252.62 8,353.51 8,261.61 -4.41 -30.87 5,914,602.19 260,836.01 0.03 -4.41 MWD (1) 8,425.00 0.91 252.62 8,423.58 8,331.68 -4.75 -31.93 5,914,601.90 ' 260,834.94 , 0.00 -4.75 PROJECTED to TD 3/12/2009 1:41:46PM Page 4 COMPASS 2003.16 Build 42F • S s ' f Ellanrig, Operations Summary (Detailed) &W ens GRANDVIEW 1 ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 2/15/2009 07:00 12:00 5.00 MIRU MOVE MOB Blow down, un plug, break apart moduals, pipe 0.0 0.0 shed, boiler house, rock washer, generator modual, prepare pits for the road. Hook the trucks up to the first five loads. 2/15/2009 12:00 12:30 0.50 MIRU MOVE SFTY Prejob safety meeting. Rig move. 0.0 0.0 2/15/2009 12:30 17:00 4.50 MIRU MOVE MOB Move five loads from Alpine to Grandview. Pits, 0.0 0.0 Pumps, Generators, Boiler, Rock Washer. 2/15/2009 17:00 19:00 2.00 MIRU MOVE MOB Shuttle sows and trucks from Grandview to 0.0 0.0 Alpine CD1. Fuel all rolling stock. 2/15/2009 19:00 00:00 5.00 MIRU MOVE MOB Load traction weights on sows. Move sub base 0.0 0.0 off CD1 -48. Position sub and two pipe shed sections for road alignment. Move off location to end of runway. Crew change. 2/16/2009 00:00 12:00 12.00 MIRU MOVE MOB Move sub base, pipe sheds from Alpine to 0.0 0.0 Grandview. Spot sub, pipe sheds, pits, pump room, boiler house on Grandview well. 2/16/2009 12:00 15:00 3.00 MIRU MOVE RURD Lay herculite, set rock washer, and Tioga 0.0 0.0 heater. Level up complexes, pipe sheds, Berm around Tioga heater, and rig. 2/16/2009 15:00 20:00 5.00 MIRU MOVE RURD Connect all supply lines, water air fuel, glycol. 0.0 0.0 Flow lines. R/U pumps, pits, pipe skate, operate conveyors, set geronimo line. 2/16/2009 20:00 22:00 2.00 MIRU MOVE RURD Berm rock washer, set all landings, hand 0.0 0.0 railings. Set camp, Acceot ria (q) 92 hrs, 2/16/2009 22:00 00:00 2.00 SURF... DRILL PULD Rig accepted @ 22:00 hrs. Load pipe shed with 0.0 0.0 5" 'G' DP. 2/17/2009 00:00 01:00 1.00 SURF... DRILL PULD Pick up, thaw, and install 20" riser, air up boots. 0.0 0.0 2/17/2009 01:00 02:00 1.00 SURF... DRILL PULD Load pipe shed with 81 joints 5" DP. Strap. 0.0 0.0 2/17/2009 02:00 05:00 3.00 SURF... DRILL PULD Pick up and make up 5" drill pipe. thaw and rack 0.0 0.0 back. SIMOPS: tighten alien screws on the diverter, install the 4" ball valves in cellar on the conductor, and the 90 degree to torque valve onto the diverter head. 2/17/2009 05:00 06:00 1.00 SURF... DRILL PULD Load pipe shed with 20 joints 5" HWDP, drilling 0.0 0.0 jars, strap. plub diverter bag, and knife valve. 2/17/2009 06:00 12:00 6.00 SURF... DRILL PULD Pick up and rack back HWDP, jars, load 189 0.0 0.0 joints 5" DP in pipe shed, strap, calibrate gas detectors, put containment under gray water tank. 2/17/2009 12:00 12:30 0.50 SURF... DRILL SFTY Prejob safety meeting, hazard recognition, 0.0 0.0 picking up DP. 2/17/2009 12:30 13:30 1.00 SURF... DRILL SFTY PreSpud meeting with T. Brassfield, and D. 0.0 0.0 Reimer. Both crews. Discuss Grandview and Pioneer. Possible shallow gas, hydrates. 2/17/2009 13:30 19:00 5.50 SURF... DRILL PULD Pick and stand back 141 joints of 5" DP. 0.0 0.0 2/17/2009 19:00 19:45 0.75 SURF... DRILL BOPE Function test Diverter. Bag close in 16 secs. 0.0 0.0 Knife open in 16 secs. Accumulator test 2900 -1700 psi. 200 psi build back in 48 secs. Tested gas alarms. 2/17/2009 19:45 00:00 4.25 SURF... RIGMNT EQRP Rig repair in derrick. Monkey board. Bull rail 0.0 0.0 broken. 2/18/2009 00:00 02:00 2.00 SURF... RIGMNT EQRP Continue to weld bull rail on derrick board on the 0.0 712.0 712.00 drillers side and retie 48 stands back to repaired bull rail. 2/18/2009 02:00 02:30 0.50 SURF... DRILL PULD Pick up stabilizers, non magnetic float sub, 4 lift 0.0 712.0 712.00 subs and cross over 2/18/2009 02:30 04:00 1.50 SURF... DRILL PULD Pick up and make up 45 joints of 5" DP and 0.0 712.0 712.00 rack back. Page 1/15 Report Printed: 4/8/2009 • • ' .Ma Operations Summary (Detailed) &W GRANDVIEW 1 ConocoPhil lips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 2/18/2009 04:00 04:30 0.50 SURF... DRILL PULD Make up bit, motor, float sub, stabilizer, jars, 0.0 712.0 712.00 HWDP. 2/18/2009 04:30 05:00 0.50 SURF... DRILL DHEQ Tagged up © 88.5'. Set MWD depth. Flood 0.0 712.0 712.00 conductor, no leaks. Test lines, no leaks. 2/18/2009 05:00 09:30 4.50 SURF... DRILL DRLG Drill from 88' to 222'. ADT =4.52, Jar hours= 0.0 712.0 712.00 30.28, P /U =42k, S` 76 =45k, ROT =42k, Rpm =40, TQ =0 2/18/2009 09:30 09:45 0.25 SURF... DRILL PULD Stand back two stands of HWDP 0.0 712.0 712.00 2/18/2009 09:45 12:00 2.25 SURF... DRILL PULD P/U and make up BHA #1. Plug into MWD, and 0.0 712.0 712.00 up load. 2/18/2009 12:00 13:00 1.00 SURF... DRILL PULD Pick up and make up stabilizer, and floex collar. 0.0 712.0 712.00 2/18/2009 13:00 13:15 0.25 SURF... DRILL SFTY Safety meeting on rig floor. Loading nuclear 0.0 712.0 712.00 sources. 2/18/2009 13:15 13:45 0.50 SURF... DRILL PULD Load sources in neutron /density tools. Make up 0.0 712.0 712.00 flex collar, jars, 2 stands HWDP. Tag bottom @ 222'. No fill. 2/18/2009 13:45 00:00 10.25 SURF... DRILL DRLG Drill from 222' MD to 712' MD. P /U =65k, 0.0 712.0 712.00 S /O =70k, ROT =68k, WOB =5 to 10k, RPM =100, TQ On =1.5k, TQ Off =1 k, GPM 470, PP =910, Max gas 22 units. ADT =7.89, ART =7.89. No slides. Bit hours 12.41. Jar hours 42.69. 2/19/2009 00:00 08:00 8.00 SURF... DRILL DRLG Drilling from 712' MD to 1387' MD. ADT =6.84 712.0 2,350.0 1,638.00 hrs., P /U =85 S /0 =90 ROT =90, 602 gpm, 1360 psi, 100 rpm. 2k max TQ Gas max 94 units 2/19/2009 08:00 08:45 0.75 SURF... DRILL WPRT Short trip from 1387' MD to 834' MD. (865', 712.0 2,350.0 1,638.00 1020', 1112', 10 to 15k overpull) Hole fill 1 bbl long. 2/19/2009 08:45 09:00 0.25 SURF... DRILL CIRC Circulate BU, 50% increase in cuttings. 712.0 2,350.0 1,638.00 2/19/2009 09:00 12:00 3.00 SURF... DRILL DRLG Drilling from 1387' MD to 1575' MD. ADT =2.2. 712.0 2,350.0 1,638.00 P /U =85 S /0 =90 ROT =90, 602 gpm, 1360 psi, 100 rpm. 2k max TQ 10 to 20k WOB. 2/19/2009 12:00 22:45 10.75 SURF... DRILL DRLG Drilling from 1575' MD to 2350' MD. TD. 712.0 2,350.0 1,638.00 ADT =9.16 AST =.34 ART =8.82. P /U =104K S /0 =105k ROT =107K RPM =100 TQ on =2k TQ off=1 k. Max gs= 85 units. Drop carbide lag on bottom. 2/19/2009 22:45 00:00 1.25 SURF... DRILL CIRC Circulate the hole clean. Carbide lag showed 712.0 2,350.0 1,638.00 2% washout. 2/20/2009 00:00 01:15 1.25 SURF... DRILL WPRT Short trip from 2350' MD to 834' MD and back to 2,350.0 2,350.0 0.00 2350' MD. (Excess pull of 20k at 1800' and 1580') Hole fill 1.5 bbls long out and short 5 bbls going in. 2/20/2009 01:15 02:45 1.50 SURF... DRILL CIRC Circulate hole clean for running casing. 2,350.0 2,350.0 0.00 2/20/2009 02:45 03:15 0.50 SURF... DRILL SRVY Drop ESS and flow check well, static. Blow 2,350.0 2,350.0 0.00 down top drive. 2/20/2009 03:15 04:30 1.25 SURF... DRILL PULD Pull out of hole to run 9 5/8" casing. Strapped 2,350.0 2,350.0 0.00 out of the hole, no correction. (ESS survey © 2345', 2229', 1952', 566', 382', 236' MD.) 2/20/2009 04:30 05:45 1.25 SURF... DRILL PULD Lay down BHA #1 (2 Jts of HWDP, jars, 2 flex 2,350.0 2,350.0 0.00 collars, ESS, and stabilizer) Displacement was 5 bbl long. 2/20/2009 05:45 07:15 1.50 SURF... DRILL PULD Hold pre job safety meeting, and unload the 2,350.0 2,350.0 0.00 nuke sources and download MWD data. 2/20/2009 07:15 08:30 1.25 SURF... DRILL PULD Continue to lay down BHA #1, MWD, float sub, 2,350.0 2,350.0 0.00 motor and bit. 2/20/2009 08:30 13:30 5.00 SURF... CASING RURD Clear and clean rig floor. Rig up casing 2,350.0 2,350.0 0.00 equipment. Page 2/15 Report Printed: 4/8/2009 • S Operations Summary (Detailed) & W GRANDVIEW 1 ConocoPhil lips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start lime End Time Dur (hrs) Phase Op Code Activity Code_ Operation (ftKB) (ftKS) Progress (ft) 2/20/2009 13:30 15:30 2.00 SURF... CASING RNCS Run in hole with casing. Average make up 2,350.0 2,350.0 0.00 torque 10,000 ft -ins. At /15' MD no slackoff weight and 2.8 bbls over calculated displacement. 2/20/2009 15:30 16:15 0.75 SURF... CASING CIRC Hole was getting sticky so we started to 2,350.0 2,350.0 0.00 circulate and condition mud © 2 BPM. 25% flow out, ICP 250 psi. PU = 55k. No slack off weight. Pump 72 bbls. PU = 55k. SO = 50k. 200 psi FCP. Hole cleaned up. 2/20/2009 16:15 17:00 0.75 SURF... CASING RNCS Continue running in the hole with 9 5/8" casing 2,350.0 2,350.0 0.00 to 1239' MD. 2/20/2009 17:00 17:45 0.75 SURF... CASING CIRC Circulate hnttnms up while reciprocating. pU = 2,350.0 2,350.0 0.00 70K, SO = 65K. 1.5 BPM with 300 psi. 17% flow out. Stage up to 3 BPM with 320 psi. 27% flow out. Pumped 114 bbls. FCP = 200 psi. PU = 74K. SO = 72K. 2/20/2009 17:45 18:30 0.75 SURF... CASING RNCS Continue running in the hole with 9 5/8" casing 2,350.0 2,350.0 0.00 to 1888' MD. 2/20/2009 18:30 20:30 2.00 SURF... CASING CIRC Circulate bottom up two times while 2,350.0 2,350.0 0.00 reciprocating and conditioning mud. ICP = 370 psi © 1.5 BPM. PU = 100K. SO = 70k. Increase pump rate to 4 BPM, lost 50 bbls at this rate so slowed the pump back down to 1.5 BPM. Then to 1 BPM to re- establish circulation. Stage pumps back up to 5 BPM. FCP = 300 psi. 34% flow out. PU = 90K. SO = 87K. The hole cleaned up. 2/20/2009 20:30 22:00 1.50 SURF... CASING RNCS Wash down 7 joints of casing. From 1888' to 2,350.0 2,350.0 0.00 2182'. 2 BPM. 14% flow, good returns. Run next two dry, wash down the last one. Land hanger A 28.60' from rig floor. Tally adjusted. 2/20/2009 22:00 00:00 2.00 SURF... CASING CIRC Circulate and condition mysJ system fnr nement 2,350.0 2,350.0 0.00 iob. reciprocate casing. Stage pumps up from 2 BPM to 6 BPM. 380 psi. Good returns. 2/21/2009 00:00 00:30 0.50 SURF... CASING PULD Lay down Franks tool and blow down top drive. 2,350.0 2,350.0 0.00 Make up cement head. 2/21/2009 00:30 02:00 1.50 SURF... CEMENT CIRC Circulate and condition mud for cement job. 2,350.0 2,350.0 0.00 2/21/2009 02:00 05:00 3.00 SURF... CEMENT CMNT Pre job safety meeting. Pumped 5 bbl of 2,350.0 2,350.0 0.00 CW100 to fill up the cement lines to test. Test lines to 4000 psi. Pump 20 bbls of CW100 with red dye at 8.33 ppg. Drop the bottom plug. Pump 50 bbls of mud push at 10.5 ppg. Start pumping ARTICSET LITE (10.8 ppg) lead slurry with an average pump rate at 5 BPM, 315 sx (270 bbl) with a yield of 4.49 ft3 /sk. Pump 50 bbl X258 sx) tail slurry (15.8 ppg) with an average pump rate of 5 tsl-M and yeild of 1.16 ft3 /sk. Drop the bottom plug. Cement returns to surface approximatly 145 bbl, which gives an approximate washout of 25% to the hole. 2/21/2009 05:00 05:45 0.75 SURF... CEMENT DISP Displace with the rig pumps at 5 BPM, slow 2,350.0 2,350.0 0.00 down the rate to 1.5 BPM at 1500 stks, bump the plug at 1600 stks, 560 psi, pressure up to 1100 psi and hold 5 mins. Bleed off, floats good. 2/21/2009 05:45 07:00 1.25 SURF... CEMENT PULD Flush riser, flowline and lines. Blow down and 2,350.0 2,350.0 0.00 rig down cement head. Lay down the landing joint. Page 3/15 Report Printed: 4/8/2009 • • • *-t Operations Summary (Detailed) sWelIs 1 GRANDVIEW 1 Conocophiiiips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 2/21/2009 07:00 10:00 3.00 SURF... CASING NUND Lay down casing equipment and nipple down 2,350.0 2,350.0 0.00 the diverter. 2/21/2009 10:00 12:00 2.00 SURF... DRILL NUND Nipple up well head and tubing spool. Set the 2,350.0 2,350.0 0.00 BOP stack. 2/21/2009 12:00 16:00 4.00 SURF... DRILL NUND Pre job safety meeting. Hazard recognition. 2,350.0 2,350.0 0.00 Nipple up BOPE. Test lower wellhead seals to 2000 psi for 10 min (witnessed), test good. Continue to nipple up BOPE, install kill line and choke valve, close valve on annular. 2/21/2009 16:00 00:00 8.00 SURF... DRILL BOPE Pre job safety meeting. Flood stack and choke. 2,350.0 2,350.0 0.00 Test BOPE. BLM Test. 250 psi low, 5mins / 5,000 psi high 10 mins. charted for each test. Top Pipe Rams, choke valves, 1,12,13,14, Manual Kill, Upper IBOP, HCR check, Valves 9,11, Lower IBOP, Valves 5,8,10, dart valve, Choke valves, 4,6,7,TIW valve, #2, HCR choke, Manual choke, Lower Pipe Rams, Blind Rams, Choke valve #3. Annular Preventer 250 psi low/ 2500 psi high. (HCR Kill failed. to be replaced and tested before drill out. as per Mr. Noble.) Koomey test 3000 psi system: Draw down to 1725 psi. 200 psi build back 37 secs. Full recovery 2mins 43 secs. (5 bottles, 2,000 psi average.) Test witnessed by AOGCC Rep. Bob Noble. 2/22/2009 00:00 03:00 3.00 PROD1 DRILL PULD Hoist BHA and nukes to the rig floor. P/U mouse 2,350.0 2,855.0 505.00 hole, 1 stand of HWDP, jars and 3 joints of non magnetic drill collars. Rack back same into the derrick. Lay down mouse hole. (SIMOPS change out HCR valve on the kill line side.) 2/22/2009 03:00 04:00 1.00 PROD1 RIGMNT SVRG Service top drive and blocks. 2,350.0 2,855.0 505.00 2/22/2009 04:00 05:00 1.00 PROD1 DRILL BOPE Test NCR valve on the kill side and check valve 2,350.0 2,855.0 505.00 flange. Blow down choke and pull test plug. 2/22/2009 05:00 05:30 0.50 PROD1 DRILL RURD Install wear bushing. 2,350.0 2,855.0 505.00 2/22/2009 05:30 07:15 1.75 PROD1 DRILL PULD Make up BHA. Bit/ Motor /Float sub /Stabilizer/ 2,350.0 2,855.0 505.00 MWD tripple combo system. 2/22/2009 07:15 08:15 1.00 PROD1 DRILL PULD Up load MWD. 2,350.0 2,855.0 505.00 2/22/2009 08:15 09:30 1.25 PROD1 DRILL DHEQ Shallow hole test @ 110' MD/TVD. 550 GPM, 2,350.0 2,855.0 505.00 wtih 975 psi. Pre job safety meeting and load nukes. 2/22/2009 09:30 10:30 1.00 PROD1 DRILL TRIP Run in hole to 2243' MD/TVD and tag cement. 2,350.0 2,855.0 505.00 PU = 90K. SO = 100K. 2/22/2009 10:30 12:00 1.50 SURF... DRILL COCF Wash and ream cement to 2253' MD/TVD. 2,350.0 2,855.0 505.00 Circulate and condition mud for casing test. 540 GPM with 1300 psi. RPM = 50. PU = 90K. SO = 100K. ROT = 99K. 2/22/2009 12:00 13:30 1.50 SURF... DRILL PRTS Pre job safety meeting., Rio up to test casin at 2,350.0 2,855.0 505.00 3000 psi for 30 minutes. Perform casing t Charted. Rig down testing equipment and blow down choke lines. 2/22/2009 13:30 15:15 1.75 SURF... DRILL DRLG Wash and ream cement to 2253' MD/TVD - Tag 2,350.0 2,855.0 505.00 float collar @ 2256', Drill collar, shoe track, shoe. Tag top of shoe @ 2337' MD. 2/22/2009 15:15 15:30 0.25 SURF... DRILL DRLG Displace to new mud while drilling out shoe anti, 2,350.0 2,855.0 505.00 fat hole. 2337' to 2350' MD/TVD. 450 GPM at 1080 psi. RPM = 50. 33% flow. Torque = 1K. WOB = 5 -7K. PU = 90K. SO = 100K. ROT = 99K. Page 4/15 Report Printed: 4/8/2009 • • ILPinnuummsl, Operations Summary (Detailed) GRANDVIEW 1 Y ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 2/22/2009 15:30 15:45 0.25 PROD1 DRILL DRLG Drill 20' of new formation from 2350' to 2370', 2,350.0 2,855.0 505.00 MD/TVD. 450 GPM with 1080 psi. RPM = 50. 33% flow. Torque = 1K. WOB = 5 -7K. PU = 90K. SO = 100K. ROT = 99K. Clean hole ECD =10.6 ppg 2/22/2009 15:45 16:00 0.25 PROD1 DRILL CIRC Circulate and condition mud to 10 ppg in and 2,350.0 2,855.0 505.00 out. 2/22/2009 16:00 17:00 1.00 PROD1 DRILL LOT Stand back 1 stand in the derrick. Blow down 2,350.0 2,855.0 505.00 top drive. Rig up and perform leak off test. (EMW = 15.4 ppg). Rig down and blow down kill and choke lines. Line up choke manifold. 2/22/2009 17:00 00:00 7.00 PROD1 DRILL DRLG Drill from 2370' to 2855' MD. 2855' ND. 550 2,350.0 2,855.0 505.00 GPM with 1550 psi. RPM = 100. 37% flow out. Torque on bottom = 1.5K ft-lbs. Torque off bottom = 1K ft -lbs. WOB = 5 -7K. PU = 105K. SO = 110K. ROT = 109K. ECD = 11.17. Max gas = 174 units. ADT = 5.25. ART = 4.55. AST = 0.7. 2/23/2009 00:00 12:00 12.00 PROD1 DRILL DRLG Drill from 2855' to 3595' MD. 3595' ND. 550 2,855.0 4,372.0 1,517.00 GPM with 1650 psi. RPM = 110. 37% flow out. Torque on bottom = 2K ft-lbs. Torque off bottom = 1K ft -lbs. WOB = 7 -10K. PU = 118K. SO = 119K. ROT = 122K. ECD = 10.96. Max gas = 107 units. ADT = 9.22. ART = 7.91. AST = 1.31. 2/23/2009 12:00 12:15 0.25 PROD1 DRILL DRLG Drill from 3595' to 3631' MD. 3631' ND. 2,855.0 4,372.0 1,517.00 2/23/2009 12:15 12:30 0.25 PROD1 DRILL CIRC Circulate bottoms up. 550 GPM at 1650 psi. 2,855.0 4,372.0 1,517.00 37% flow out. RPM = 110. Torques = 1K ft -lbs. 2/23/2009 12:30 12:45 0.25 PROD1 DRILL OWFF Blow down top drive, monitor well for flow. Well 2,855.0 4,372.0 1,517.00 static. 2/23/2009 12:45 14:15 1.50 PROD1 DRILL WPRT Short trip from 3631' to 2336' and back down 2,855.0 4,372.0 1,517.00 again. No problems. (Calcualted diplacement = 11.25 bbls, actual was 11 bbls.) Monitoring well, still static. 2/23/2009 14:15 14:30 0.25 PROD1 DRILL WASH Wash and ream from 3600' to 3631' MD. 550 2,855.0 4,372.0 1,517.00 gpm with 1625 psi. RPM = 110. 38% flow out. PU = 120K. SO = 124K. ROT = 125K. 2/23/2009 14:30 00:00 9.50 PROD1 DRILL DRLG Drill from 3631' to 4372' MD. 4372' ND. 550 2,855.0 4,372.0 1,517.00 GPM with 1950 psi. RPM = 110. 39% flow out. Torque on bottom = 2.5K ft-lbs. Torque off bottom = 1K ft -lbs. WOB = 10K. PU = 133K. SO = 135K. ROT = 135K. Max gas = 84 units. ECD = 11.10. ADT = 7.1. ART* = 6.42. AST =0.68. 2/24/2009 00:00 12:00 12.00 PROD1 DRILL DRLG Drill from 4372' MD to 5206' MD. 5206' ND. 4,372.0 5,855.0 1,483.00 Torque on bottom = 2 -3K ft -lbs. Torque off bottom = 1K ft -lbs. PU = 150K. SO = 150K. ROT = 154K. Max gas = 768 units. ECD = 11.05. ADT = 9.08. ART = 8.45. AST = 0.63. 2/24/2009 12:00 12:30 0.50 PROD1 DRILL CIRC Pre job safety meeting. Hazard recognition. 4,372.0 5,855.0 1,483.00 Circulate bottoms up 550 GPM with 1800 psi. 38% flow out. RPM = 110. Torque 2 -3k. Blow down top drive. Monitor well - static. 2/24/2009 12:30 14:00 1.50 PROD1 DRILL WPRT Short trip from 5206' to 3631' MD. (Slight 4,372.0 5,855.0 1,483.00 overpull at 3852' MD.) Calcualted displacement 12 bbls, actual displacement 10.5 bbls. Monitor well - static. Trip back in hole to 5114' MD, no problems. 2/24/2009 14:00 14:15 0.25 PROD1 DRILL WASH Wash and ream to bottom from 5114' to 5206' 4,372.0 5,855.0 1,483.00 MD. Page 5/15 Report Printed: 4/8/2009 • • ;::, p Operations Summary (Detailed) &W+Es G RAN DVIEW 1 ConocoPhillips , Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 2/24/2009 14:15 00:00 9.75 PROD1 DRILL DRLG Drill from 5206' to 5855' MD. 5855' TVD. 550 4,372.0 5,855.0 1,483.00 GPM with 1900 psi. RPM = 115. 39% flow out. Torque on bottom = 3-4K ft-lbs. Torque off bottom = 1.5K ft -lbs. WOB = 8-11K. PU = 162K. SO = 163K. ROT = 164K. Max gas = 863 units. ECD = 10.94. ADT = 7.14. ART = 7.14. AST = 0. 2/25/2009 00:00 12:00 12.00 PROD1 DRILL DRLG Pre job safety meeting. Drill from 5855' MD to 5,855.0 6,597.0 742.00 6411' MD. 6410' TVD. 550 GPM with 2300 psi. Torque on bottom = 2 -5K ft -lbs. Torque off bottom = 1.5K ft -lbs. PU = 171K. SO = 171K. ROT = 173K. Max gas = 116 units. ECD = 11.73. ADT = 9.99. ART = 6.16. AST = 3.83. 2/25/2009 12:00 18:45 6.75 PROD1 DRILL DRLG Pre job safety meeting. Hazard recognition. Drill 5,855.0 6,597.0 742.00 from 6411' MD to 6597' MD. 6597' TVD. 550 GPM with 2300 psi. 39% Flow out. Torque on bottom = 2 -5K ft -lbs. Torque off bottom = 1.5K ft -lbs. PU = 174K. SO = 173K. ROT = 174K. RPM = 115. ECD = 11.73. ADT = 6.25. ART = 0.82. AST = 5.43. 2/25/2009 18:45 19:30 0.75 PROD1 DRILL CIRC Circulate 1.5x's bottoms up. 520 GPM with 2100 5,855.0 6,597.0 742.00 psi. Hole cleaned up nicely. 2/25/2009 19:30 19:45 0.25 PROD1 DRILL SRVY Survey on bottom. Gather slow pump rates. 5,855.0 6,597.0 742.00 Monitor well, static. Blow down top drive. 2/25/2009 19:45 21:00 1.25 PROD1 DRILL TRIP Pull out of hole from 6597' to 4557' MD. 5,855.0 6,597.0 742.00 2/25/2009 21:00 21:15 0.25 PROD1 DRILL SRVY Check shot at 4557' MD. Blow down top drive. 5,855.0 6,597.0 742.00 2/25/2009 21:15 22:30 1.25 PROD1 DRILL TRIP Continue pulling out of hole. Tight spot at 3565' 5,855.0 6,597.0 742.00 MD. Pulled 50k over. Drop back down. Make up top drive and back ream from 3600' to 3536' MD (Did not see any indication of tight spot when back reaming and when we pulled back through this area). tight spot cleaned up. 285 GPM with 700 psi. 30% flow out. RPM = 100. Continue pulling out of hole to 2300' MD. 2/25/2009 22:30 22:45 0.25 PROD1 DRILL OWFF Monitor well for flow at casing shoe. Well static. 5,855.0 6,597.0 742.00 2/25/2009 22:45 00:00 1.25 PROD1 DRILL TRIP Continue pulling out of hole to HWDP. Monitor 5,855.0 6,597.0 742.00 well. Static. Crew change. Trip 6 BBLS long at the top of the HWDP. 2/26/2009 00:00 00:30 0.50 PROD1 DRILL TRIP Continue pulling out of the hole and rack back 6,597.0 7,012.0 415.00 the BHA. 2/26/2009 00:30 01:00 0.50 PROD1 DRILL PULD Pre job safety meeting, lay down nukes. 6,597.0 7,012.0 415.00 2/26/2009 01:00 03:15 2.25 PROD1 DRILL PULD Down load MWD. 6,597.0 7,012.0 415.00 2/26/2009 03:15 04:00 0.75 PROD1 DRILL PULD Inspect the bit. Adjust bend in motor to 1.22 6,597.0 7,012.0 415.00 from .62. 2/26/2009 04:00 05:00 1.00 PROD1 DRILL PULD Make up BHA 3. Orient motor/MWD. Orient 6,597.0 7,012.0 415.00 neutron density sensors. Pulse check the MWD sysytem. 2/26/2009 05:00 06:00 1.00 PROD1 DRILL PULD Upload /program MWD tools on rig floor. Pulse 6,597.0 7,012.0 415.00 check tools @ 115' MD with 550 GPM at 1150 psi. Good. 2/26/2009 06:00 07:00 1.00 PROD1 DRILL PULD Have a pre job safety meeting. Time/ distance / 6,597.0 7,012.0 415.00 shielding from nuclear sources. Load nukes into the BHA. 2/26/2009 07:00 11:00 4.00 PROD1 DRILL TRIP Run in hole to 6507' MD. Take surveys at 3260' 6,597.0 7,012.0 415.00 MD, 3352' MD and 5298' MD.(JORPS). 2/26/2009 11:00 11:30 0.50 PROD1 DRILL REAM Wash and ream from 6507' to 6597' MD. Did not 6,597.0 7,012.0 415.00 see any fill. Page 6/15 Report Printed: 4/8/2009 • • Una Operations Summary (Detailed) &Wens \ GRANDVIEW 1 ConocoPhillips , Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 2/26/2009 11:30 12:00 0.50 PROD1 DRILL DRLG Drill from 6597' MD to 6602' MD. 6602' TVD. 6,597.0 7,012.0 415.00 520 GPM with 2100 psi. WOB = 10k. Torque on bottom = 2 -5K ft -lbs. Torque off bottom = 2K ft -lbs. PU = 175K. SO = 174K. ROT = 174K. Max gas = 54 units. ECD = 11.89. ADT = 0.29. ART = 0.0. AST = 0.29. 2/26/2009 12:00 00:00 12.00 PROD1 DRILL - DRLG Drill from 6602' MD to 7012' MD. 7012' TVD. 6,597.0 7,012.0 415.00 550 GPM with 2640 psi. WOB = 5 -10k. Torque on bottom = 2 -5K ft -lbs. Torque off bottom = 1.5K ft-lbs. PU = 181K. SO = 182K. ROT = 181K. Max gas = 54 units. ECD = 11.88. ADT = 9.82. ART = 4.40. AST = 5.42. 2/27/2009 00:00 12:00 12.00 PROD1 DRILL DRLG J Drill from 7012' MD to 7518' MD. 7518' TVD. 7,012.0 7,986.0 974.00 550 GPM with 2650 psi. WOB = 10 -12k. Torque on bottom = 2 -7K ft-lbs. Torque off bottom = 2K ft -lbs. PU = 186K. SO = 186K. ROT = 193K. Max gas = 157 units. ECD = 11.97. ADT = 10.0. ART = 7.05. AST = 2.95. 2/27/2009 12:00 00:00 12.00 PROD1 DRILL DRLG Drill from 7518' MD to 7978' MD. 7978' ND. 7,012.0 7,986.0 974.00 550 GPM with 2650 psi. WOB = 8 -10k. Torque on bottom = 4K ft -lbs. Torque off bottom = 2K ft-lbs. PU = 200K. SO = 195K. ROT = 195K. Max gas = 157 units. ECD = 11.92. ADT = 9.15. ART = 8.47. AST = 0.68. 2/28/2009 00:00 04:00 4.00 PROD1 DRILL DRLG Drill from 7986' MD to 8102' MD. From 8040' 7,986.0 8,111.0 125.00 MD to 8058' MD drilled at 30 FPH. From 8058' MD to 8102' MD continued drilling at 30 FPH. Circulating samples to the suface. 550 GPM with 2650 psi. WOB = 5 -8k. Torque on bottom = 4K ft -lbs. Torque off bottom = 3K ft -lbs. PU = 210K. SO = 200K. ROT = 208K. Max gas = 171 units. ECD = 11.88. ADT = 4.10. ART = 4.10. AST = 0.0. 2/28/2009 04:00 04:45 0.75 PROD1 DRILL CIRC Circulate bottoms up for sample. 7,986.0 8,111.0 125.00 2/28/2009 04:45 05:15 0.50 PROD1 DRILL DRLG Drill from 8102' MD to 8111' MD. 8109' ND. 7,986.0 8,111.0 125.00 Drilled at 20 FPH to 8111' MD core point. 2/28/2009 05:15 06:00 0.75 PROD1 DRILL CIRC Circulate bottoms up for sample. 7,986.0 8,111.0 125.00 2/28/2009 06:00 08:00 2.00 PROD1 DRILL WPRT Blow down top drive. Short trip 8111' MD to 7,986.0 8,111.0 125.00 6517' MD. PU = 175k. SO = 175k. Monitor well and run back in hole to 8082' MD. 2/28/2009 08:00 08:15 0.25 PROD1 DRILL REAM Wash and ream hole from 8082' MD to 8111' 7,986.0 8,111.0 125.00 MD. At 512 GPM with 2500 psi. RPM = 100. Torque = 3K. Ledge @ 8106. Hard fill from 8106' MD to 8111' MD. 2/28/2009 08:15 12:00 3.75 PROD1 DRILL CIRC Hole taking fluid, reduce pumps from 500, 300, 7,986.0 8,111.0 125.00 200, 150 GPM at this point losses were at 139 bbls and the decision was made to shut the pumps down and circulate across the top of the hole while on the trip tank. Started mixing and LCM pill. While on the trip tank losses started at 32 BPH and were reduced down to 4 BPH in 3 h i s. Total losses were 179 bbls. 2/28/2009 12:00 15:00 3.00 PROD1 DRILL CIRC Continue to work pipe while on trip tank. Losses 7,986.0 8,111.0 125.00 still at 3 -4 BPH. At 13:30 hours well became static. Mixing a LCM pill with Form -A- Squeeze. Page 7/15 Report Printed: 4/8/2009 • Daring, Operations Summary (Detailed) GRANDVIEW 1 conocoPhiilips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 2/28/2009 15:00 16:00 1.00 PROD1 DRILL CIRC Pump 10 bbl Form -A- Squeeze pill @ 2.5 bpm 7,986.0 8,111.0 125.00 with 200 psi, while washing down to bottom with RPM = 40. Tag up @ 8097' MD set 10K, 2K on torque would not go any further. Pill was spotted at this depth. Still no losses. 2/28/2009 16:00 17:00 1.00 PROD1 DRILL SQEZ Pull back to 8082' Md and close the annular 7,986.0 8,111.0 125.00 preventer and pressure up and hold 300 psi on the pill for 20 minutes. End pressure was 240 psi. 2/28/2009 17:00 17:30 0.50 PROD1 DRILL REAM Dress the Form -A- Squeeze pill from 8082' to 7,986.0 8,111.0 125.00 8111' MD. 500 GPM @ 2600 psi. 90 RPM. Torque = 2K. ( 8097' MD possible ledge put 5 -7K WOB and cleaned out fill to TD @ 8111' MD.) 2/28/2009 17:30 18:00 0.50 PROD1 DRILL CIRC Circulate bottoms up @ 3.5 BPM. Held at 2600 7,986.0 8,111.0 125.00 psi for a short time and then losses started again and pump pressure came Gown to bUO psi. (Total losses 27bbls in 15 minutes.) 2/28/2009 18:00 21:30 3.50 PROD1 DRILL CIRC Pull back to 7989' MD. Reciprocate pipe with 7,986.0 8,111.0 125.00 the pumps off. Circulate across the top of the hole while on the trip tank. Building 100 bbls of 11.3 ppg mud in pit #5.Before circulating bottoms up. 2/28/2009 21:30 00:00 2.50 PROD1 DRILL CIRC Circulate bottoms up. Start at a circulation rate 7,986.0 8,111.0 125.00 of 1 BPM with 300 psi. Did not encounter any losses after 15 minutes so the pump rate was increased to 1.5 BPM with 350 psi. Did not encounter any losses after 15 minutes, the pump rate was increased to 2 BPM with 350 psi. Did not encounter any losses after 15 minutes, the pump rate was increased to 2.5 BPM with 450 psi. Flow out = 20 %. PU = 210k. SO = 195k. ROT = 200k. No losses on this 2.5 hour curculation. 3/1/2009 00:00 01:00 1.00 PROD1 DRILL CIRC Continue to circulate bottoms up @ 7989' MD. 3 8,111.0 8,111.0 0.00 BPM at 450 psi. Max gas = 25 units. Total loss = 10 bbls. 3/1/2009 01:00 02:30 1.50 PROD1 DRILL CIRC Circulate and condition mud to 11.25 ppg. Stage 8,111.0 8,111.0 0.00 pump up to 3.5 BPM - Total losses 10 bbls. 3/1/2009 02:30 03:45 1.25 PROD1 DRILL TRIP Blow down top drive. Monitor well - static. Pull 8,111.0 8,111.0 0.00 out of hole from 7989' MD to 7155' MD. Hole was taking proper fill. Break circulation at 7155' MD @ 2 BPM with 300 psi. Mix and pump a 12.3 ppg slug, no losses while circulating. 3/1/2009 03:45 08:30 4.75 PROD1 DRILL TRIP Continue pulling out of the hole to 2320' MD and 8,111.0 8,111.0 0.00 monitor the well - static. Pull out of the hole to the HWDP and drop a 2 1/8" rabbit. Continue pulling out of the hole to 252' MD. 3/1/2009 08:30 10:15 1.75 PROD1 DRILL PULD Pre job safety meeting, remove nukes and 8,111.0 8,111.0 0.00 donwload MWD. 3/1/2009 10:15 12:00 1.75 PROD1 DRILL PULD Continue to lay down the BHA. Calculated 8,111.0 8,111.0 0.00 displacement = 72.64 bbls. Actual = 73 bbls. 3/1/2009 12:00 13:00 1.00 PROD1 DRILL PULD Clear and clean rig floor. Pull wear bushing. 8,111.0 8,111.0 0.00 Page 8/15 Report Printed: 4/8/2009 • • Operations Summary (Detailed) 14 &W � GRANDVIEW 1 ? u. ConocoPhillips e Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 3/1/2009 13:00 16:30 3.50 PROD1 DRILL BOPE Test BOPE. 250 low, 3500 high for 5 8,111.0 8,111.0 0.00 minutes.Pre job safety meeting. Flood stack and choke. Test BOPE. Top Pipe Rams, choke valves, 1,12,13,14, Manual Kill, Upper IBOP, HCR check, Valves 9,11, Lower IBOP, Valves 5,8,10, dart valve, Choke valves, 4,6,7,TIW valve, #2, HCR choke, Manual choke, Lower Pipe Rams, Blind Rams, Choke valve #3. Annular Preventer 250 psi low/ 2500 psi high. Koomey test 3000 psi system: Draw down to 1600 psi. 200 psi build back 36 secs. Full recovery 3mins 00 secs. (5 bottles, 2,000 psi average.) Test witness waived by AOGCC Rep. Bob Noble. 3/1/2009 16:30 17:30 1.00 PROD1 DRILL BOPE Pre job safety meeting. Nipple up kill line flange 8,111.0 8,111.0 0.00 and test. 3500 psi. Good. Blow down choke line and kill line. Rig down test equipment. 3/1/2009 17:30 18:00 0.50 PROD1 DRILL PULD Lay down test plug, and set wear bushing. 8,111.0 8,111.0 0.00 3/1/2009 18:00 22:30 4.50 PROD1 DRILL PULD Pre job safety meeting. Pick up core barrel 8,111.0 8,111.0 0.00 assembly. 3/1/2009 22:30 23:00 0.50 PROD1 DRILL PULD Pick up circulating sub, ball catchers, non 8,111.0 8,111.0 0.00 magnetic flex drill collars, jars, 4 stands of HWDP to 672' MD. 3/1/2009 23:00 00:00 1.00 PROD1 DRILL CIRC Break circulation @ 200 GPM with 150 psi. Blow 8,111.0 8,111.0 0.00 down top drive. 3/2/2009 00:00 01:00 1.00 PROD1 DRILL TRIP Continue running in hole with the corina 8,111.0 8,120.0 9.00 assembly. From 609' MD to 2273' MD. Break circulation © 2 BPM with 130 psi. 3/2/2009 01:00 02:15 1.25 PROD1 DRILL SVRG Slip and cut 81' of drill line. (Simops - staging 8,111.0 8,120.0 9.00 pumps up from 1 BPM to 3 BPM with 140 psi. No losses. 3/2/2009 02:15 04:45 2.50 PROD1 DRILL TRIP Continue running in hole with coring assembly 8,111.0 8,120.0 9.00 to 5053', Proper displacement. 3/2/2009 04:45 07:30 2.75 PROD1 DRILL CIRC Break circulation at 5053' MD with 1 BPM. 8,111.0 8,120.0 9.00 Stage up to 3 BPM with 210 psi. Mud wei ht 11.2 ppg. Max as = 115 units. o losses) 3/2/2009 07:30 11:00 3.50 PROD1 DRILL TRIP Run in hole to 7556' MD and break circulation. 8,111.0 8,120.0 9.00 Drill string taking weight 15 -30K. Circulate and rotate stand through, area cleaned up. Continue running in hole to 7833' MD. 3/2/2009 11:00 12:00 1.00 PROD1 DRILL REAM Wash and ream from 7833' to 7926' MD. Break 8,111.0 8,120.0 9.00 circulation with 1.5 BPM with 250 psi. Stage up to 2 BPM with 350 psi. RPM = 5. Torque 2 -4K. ROT = 200K. (Calculated displacement 62.45 bbls, actual 71.04 bbls.) 3/2/2009 12:00 19:00 7.00 PROD1 DRILL CIRC Circulate, stage pumps up from 2 BPM at 350 8,111.0 8,120.0 9.00 psi to 2.5 BPM at 280 psi to 3 BPM at 300 psi. RPM = 30. Torque = 4K. Stage up again to 3.5 BPM, 145 GPM with 340 psi. ROT = 200K. (Bottoms up gas = 215 units.) After one full circulation start adding tracer to the mud system. 3/2/2009 19:00 22:00 3.00 PROD1 DRILL REAM Wash and ream to 8111' MD @ 3.0 BPM with 8,111.0 8,120.0 9.00 300 psi. RPM = 50. Torque = 5 -10K. (5 -10K drag on stabilizers hanging up at 8031' MD.) Increase flow rate to 4 BPM with 450 psi. Page 9/15 Report Printed: 4/8/2009 • • i , , _ i Operations Summary (Detailed) �.: &Wiens GRANDVIEW 1 r CoocoPhillips . n Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 3/2/2009 22:00 00:00 2.00 PROD1 DRILL CORE Drop ball and pump ball onto seat. 2 BPM with 8,111.0 8,120.0 9.00 200 psi. Ball set. Coring parameters GPM = 220. RPM = 70. Torque = 4K. Core to 8120' MD. Mud loss while coring = 164 bbls. ADT = 1.4. PU = 220K. SO = 195K. ROT = 205K. Torque on bottom = 5K. Torque off bottom = 4K. Max Gas = 215 units. 3/3/2009 00:00 12:00 12.00 PROD1 DRILL CORE Core from 8,120 ft MD to 8,208 tf MD with 8,120.0 8,216.0 96.00 continual losses. Total fluid lost = 315 bbl. Max gas = 1245 units. Well breathing - 28 bbl gain, atter connection. 3/3/2009 12:00 14:00 2.00 PROD1 DRILL CORE Continue coring from 8,208 ft MD to 8,216 ft 8,120.0 8,216.0 96.00 MD. Total fluid lost = 8 bbl. 3/3/2009 14:00 15:00 1.00 PROD1 DRILL REAM BROOH from 8,216 ft MD to 8,174 ft MD © 5 8,120.0 8,216.0 96.00 bpm and 450 psi. Overpull = 20k, PU =200k, SO =195k, ROT =195k, TQ= 5- 10kft -lb. 3/3/2009 15:00 17:30 2.50 PROD1 DRILL CIRC CBU at 4 bpm, 350 psi and 50 rpm., Max gas = 8,120.0 8,216.0 96.00 1820 units. Pump rate slowed to 2 bpm at 240 psi. Gas circulated clean. 14 bbl gained while circulating 2,500 additional strokes at this rate. 3/3/2009 17:30 18:30 1.00 PROD1 DRILL REAM BROOH from 8,174 ft MD to 7,896 ft MD @ 2 8,120.0 8,216.0 96.00 bpm, 240 psi and 50 rpm. Monitor flow - 7 bbl gain over 15 minutes. 3/3/2009 18:30 21:45 3.25 PROD1 DRILL CIRC Circulate bottoms up at 2 bpm and 200 psi. 8,120.0 8,216.0 96.00 Rotate at 40 rpm. Gas on bottoms up: 119 units 3/3/2009 21:45 22:00 0.25 PROD1 DRILL OWFF Monitor well. Gained 4 bbl in 1st 5 minutes; 1.5 8,120.0 8,216.0 96.00 bbl in 2nd 5 minutes; 1.5 bbl in 3rd 5 minutes. 3/3/2009 22:00 00:00 2.00 PROD1 DRILL TRIP Pump out of the hole from 7896' to 7248'. Hole 8,120.0 8,216.0 96.00 took 1.25 bbl over calculated fill. P/U 200k, S/O 195k. 3/4/2009 00:00 00:30 0.50 PROD1 DRILL TRIP Continue pumping out of the hole from 7,248 ft 8,216.0 8,216.0 0.00 to 7,000 ft at 2 bpm and 200 psi. Hole taking proper fill. PU =190k, SO =185k. 3/4/2009 00:30 01:00 0.50 PROD1 DRILL OWFF Monitor well. No pit gain and only slight flow 8,216.0 8,216.0 0.00 after 15 min. Pump 25 bbl, 12.8 ppg slug. 3/4/2009 01:00 06:00 5.00 PROD1 DRILL TRIP POOH to 2,634 ft on elevators at reduced trip 8,216.0 8,216.0 0.00 speed as per program - 3.5 min /stand to 6,000 ft and 4 min /stand to 2,634 ft. Well swabbing. 3/4/2009 06:00 07:30 1.50 PROD1 DRILL REAM ' BROOH to 2,273 ft at 2 bpm, 350 psi and 30 8,216.0 8,216.0 0.00 rpm. 3/4/2009 07:30 08:15 0.75 PROD1 DRILL OWFF Monitor well- static. Pump slug 8,216.0 8,216.0 0.00 3/4/2009 08:15 12:00 3.75 PROD1 DRILL TRIP Pull out of th ehole on elevators per tripping plan 8,216.0 8,216.0 0.00 to 149' 3/4/2009 12:00 12:30 0.50 PROD1 DRILL PULD Lay down circulating sub and ball catcher 8,216.0 8,216.0 0.00 3/4/2009 12:30 14:00 1.50 PROD1 DRILL PULD Lay down inner core barrel 8,216.0 8,216.0 0.00 3/4/2009 14:00 15:00 1.00 PROD1 DRILL PULD Lay down outer core barrel 8,216.0 8,216.0 0.00 3/4/2009 15:00 15:30 0.50 PROD1 DRILL OTHR Clear rig floor 8,216.0 8,216.0 0.00 3/4/2009 15:30 17:30 2.00 PROD1 DRILL PULD Make up BHA 8,216.0 8,216.0 0.00 3/4/2009 17:30 18:30 1.00 PROD1 DRILL PULD Upload MWD 8,216.0 8,216.0 0.00 3/4/2009 18:30 19:30 1.00 PROD1 DRILL PULD Load nuclear sources 8,216.0 8,216.0 0.00 3/4/2009 19:30 00:00 4.50 PROD1 DRILL TRIP Trip in the home to 5486' 8,216.0 8,216.0 0.00 3/5/2009 00:00 01:00 1.00 PROD1 DRILL TRIP Continue to RIH from 5,486 ft to 6,042 ft. Fill 8,216.0 8,425.0 209.00 pipe and break circulation at 2 bpm, 300 psi and 20 rpm with 2 kft-lb torque. 3/5/2009 01:00 02:00 1.00 PROD1 DRILL TRIP RIH from 6,042 ft to 6,300 ft. Take check shot 8,216.0 8,425.0 209.00 survey with 460 gpm and 1,580 psi. Blow down top drive. Page 10/15 Report Printed: 4/8/2009 • • Operations Summary (Detailed) GRANDVIEW 1 ConocoPhillips "` r Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 3/5/2009 02:00 02:30 0.50 PROD1 DRILL TRIP RIH from 6,300 ft to 6,783 ft. Monitor well for 8,216.0 8,425.0 209.00 10 min. - 2.5 bbl gained. 3/5/2009 02:30 03:15 0.75 PROD1 DRILL CIRC Circulate to check for gas - Max. gas = 100 8,216.0 8,425.0 209.00 units. Monitor well for 10 min. - 2.5 bbl gained. 3/5/2009 03:15 12:00 8.75 PROD1 DRILL TRIP RIH to 6,876 ft on elevators. Wash and ream 8,216.0 8,425.0 209.00 from 6,876 ft to 7,432 ft. RIH on elevators from 7,710 ft @ 2bpm, 20 rpm and 240 psi - Pumps staged up to 8.5 bpm at 1,200 psi and 80 rpm - Torque = 3 - 15 kft-Ib. Ream from 7,710 ft to 8,007 ft at staged up rate. Note - While reaming in hole, the top drive stalled out at 15 kft-lb torque. Pulled 50 k over string weight to free up. Packing off occuring each time. Total losses for tour = 356 bbl. 3/5/2009 12:00 16:45 4.75 PROD1 DRILL REAM Continue reaming in hole from 8,007 ft to 8,216 8,216.0 8,425.0 209.00 ft © 360 gpm, 1,200 psi, 80 rpm with 5 kft-Ib torque. Top drive stalling periodically, as well as hole packing off. P /U =210k, S /0 =200k, ROT =205k. MADPASS from 8,111 ft to 8,216 ft at 1.5 fpm. 3/5/2009 16:45 00:00 7.25 PROD1 DRILL DRLG Drilling from 8,216 ft to 8,425 ft. P /U =210k, 8,216.0 8,425.0 209.00 S /0 =205k, ROT =205k. ECD =11.75 ppg. Max Gas =1337 units. Total losses for tour = 258 bit 3/6/2009 00:00 00:15 0.25 PROD1 DRILL SRVY Survey at 8,425 ft. 8,425.0 8,425.0 0.00 3/6/2009 00:15 00:30 0.25 PROD1 DRILL OWFF Circulate hole at 102 spm, 1,600 psi, 60 rpm 8,425.0 8,425.0 0.00 with 2.5 kft-lb torque. Monitor well for gas - 241 units max gas. 3/6/2009 00:30 03:45 3.25 PROD1 DRILL REAM BROOH from 8,425 ft to 7,245 ft. PU =195k, 8,425.0 8,425.0 0.00 S0 =185k. Gained 103 bbl over calculated volume. Max as = 858 units. 3/6/2009 03:45 04:00 0.25 PROD1 DRILL OWFF Monitor well. Max flow =12 %. 8,425.0 8,425.0 0.00 3/6/2009 04:00 05:00 1.00 PROD1 DRILL TRIP RIH from 7,245 ft to 7,730 ft. Drill string taking 8,425.0 8,425.0 0.00 weight while running in. 3/6/2009 05:00 07:30 2.50 PROD1 DRILL REAM Ream in hole from 7,730 ft @ 400 gpm, 1,500 8,425.0 8,425.0 0.00 • psi, 80 rpm and 4 kft -lb torque. While reaming a tight spot at 7,885 ft, the drill string became plugged and blew pop off. Unable to circulate. Several attempts made to clear obstruction failed. 3/6/2009 07:30 11:00 3.50 PROD1 DRILL REAM Ream and work pipe out of hole from 7,885 ft to 8,425.0 8,425.0 0.00 6,969 ft. Pull 40 - 60k overpull with 70 rpm and 5 -15 kft -Ib. PU =205k, SO =195k, ROT =200k. 3/6/2009 11:00 11:30 0.50 PROD1 DRILL OWFF Monitor well for flow - static. Attempt to 8,425.0 8,425.0 0.00 circulate failed. 3/6/2009 11:30 12:00 0.50 PROD1 DRILL TRIP POOH at reduced rate on elevators from 6,969 8,425.0 8,425.0 0.00 ft to 6,516 ft. Monitoring hole fill volumes with trip tank. Hole taking correct volumes. 3/6/2009 12:00 19:30 7.50 PROD1 DRILL TRIP Continue pulling out of hole from 6,516 ft to 8,425.0 8,425.0 0.00 2,300 ft. PU =185, SO =175. Hole fill volumes monitored with trip tank - Hole taking correct volumes. 3/6/2009 19:30 20:30 1.00 PROD1 DRILL TRIP Hole swabbing at 2,300 ft. Monitor well - static. 8,425.0 8,425.0 0.00 Make up top drive and rotate out of hole at 10 -15 fpm pulling speed, 70 rpm and 2 kft-Ib torque. PU =120k, SO =120k. 3/6/2009 20:30 21:30 1.00 PROD1 DRILL TRIP Rack back HWDP. Lay down jars and NM flex 8,425.0 8,425.0 0.00 collars. Page 11/15 Report Printed: 4/8/2009 • • pan . Operations Summary (Detailed) r`- GRANDVIEW 1 ConocoPhillips ;- Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 3/6/2009 21:30 22:00 0.50 PROD1 DRILL OTHR Wash down floor and prepare to handle nukes 8,425.0 8,425.0 0.00 before crew change. 3/6/2009 22:00 22:15 0.25 PROD1 DRILL SFTY Crew change. PJSM regarding unloading 8,425.0 8,425.0 0.00 nukes. 3/6/2009 22:15 00:00 1.75 PROD1 DRILL DHEQ Plug in and download MWD. 8,425.0 8,425.0 0.00 3/7/2009 00:00 01:15 1.25 PROD1 DRILL PULD Continue laying down BHA #5 - TM collar, 8,425.0 8,425.0 0.00 nukes, DM, RLL, Integral Stabilizer and Motor., Motor Darted, leaving bit box and bit in hole. Rotor still intact and jammed in stator - Likely cause of plugged drilistring. 3/7/2009 01:15 01:30 0.25 PROD1 DRILL OTHR Clear and clean drill floor prior to rigging up for 8,425.0 8,425.0 0.00 e -line logs. 3/7/2009 01:30 01:45 0.25 PROD1 EVALFM SFTY Pre job safety meeting prior to rigging up 8,425.0 8,425.0 0.00 wireline equipment. 3/7/2009 01:45 03:30 1.75 PROD1 EVALFM RURD Rig up wireline equipment and make up logging 8,425.0 8,425.0 0.00 tools. 3/7/2009 03:30 10:15 6.75 PROD1 EVALFM ELNE RIH with wireline to 7,420 ft. Log hole with 8,425.0 8,425.0 0.00 sonic scanner. 3/7/2009 10:15 10:30 0.25 PROD1 EVALFM SFTY Pre job safety meeting prior to laying down 8,425.0 8,425.0 0.00 logging equipment. 3/7/2009 10:30 12:00 1.50 PROD1 EVALFM RURD Lay down logging tools and wireline equipment. 8,425.0 8,425.0 0.00 3/7/2009 12:00 14:30 2.50 PROD1 DRILL PULL Lay down 7 stands of HWDP and 14 stands of 8,425.0 8,425.0 0.00 drill pipe. 3/7/2009 14:30 14:45 0.25 PROD1 PLUG SFTY Pre job safety meeting prior to rigging in tubing 8,425.0 8,425.0 0.00 running equipment. 3/7/2009 14:45 15:00 0.25 PROD1 PLUG RURD Rig up 2 -7/8" tubing running equipment. 8,425.0 8,425.0 0.00 3/7/2009 15:00 17:00 2.00 PROD1 PLUG PUTB Pick up 49 joints of 2 -7/8" tubing 8,425.0 8,425.0 0.00 3/7/2009 17:00 17:30 0.50 PROD1 PLUG PULL rake up 2 -7/8" to 3 -1/2" IF XO and 3 -1/2" IF to 8,425.0 8,425.0 0.00 4 -1/2" IF XO. 3/7/2009 17:30 18:30 1.00 PROD1 PLUG TRIP RIH with drill pipe. Tag up at 7,455 ft with 5k. 8,425.0 8,425.0 0.00 Kelly up and wash down t boo gpm and 1,850 psi. Tag up again at same depth wit;O, 3/7/2009 18:30 00:00 5.50 PROD1 PLUG CIRC Circulate and condition mud for cement @ 400 8,425.0 8,425.0 0.00 gpm and 1350 psi while working pipe. Tag up at 7,419 ft. Could not get stinger back down o previous depth. Circulate well at 140 gpm and 300 psi. PU =145k, SO =145k. 3/8/2009 00:00 04:00 4.00 PROD1 PLUG CIRC Contine to circulate and condition mud for 8,425.0 8,425.0 0.00 cement plugs. Pumping at 140 gpm and 350 psi. 3/8/2009 04:00 04:15 0.25 PROD1 PLUG RURD Rack back stands from 7,419 ft to 7,388 ft. 8,425.0 8,425.0 0.00 Blow down top drive. Rig up cement head and cement hose. 3/8/2009 04:15 05:15 1.00 PROD1 PLUG CMNT Start of 1st plug - Depth = 7,388 ft. Pump 5 bbl 8,425.0 8,425.0 0.00 CW. Pressure test lines to 3,000 psi. Continue pumping 18 bbl of CW, 37 bbl of 15.8 ppg cement and 3 bbl CW. 'Displace with 105 bbl 11.3 rig mud. Plug balanced. TOC estimated at 6,888 ft. 3/8/2009 05:15 05:45 0.50 PROD1 PLUG TRIP POOH from 7,388 ft to 6,888 ft 8,425.0 8,425.0 0.00 3/8/2009 05:45 06:45 1.00 PROD1 PLUG CIRC Circulate bottoms up. Stage pumps up to 10 8,425.0 8,425.0 0.00 bpm @ 1,750 psi. 3/8/2009 06:45 07:30 0.75 PROD1 PLUG CMNT Start Plug #2 - Depth = 6,888 ft. Pump 23 bbl 8,425.0 8,425.0 0.00 CW, 37 bbl 15.8 ppg cement, 3 bbl CW. Displace wi o . rig mud. Plug balanced. TOC estimated at 6,388 ft. 3/8/2009 07:30 08:15 0.75 PROD1 PLUG TRIP POOH from 6,888 ft to 6,0 85 ft. 8,425.0 8,425.0 0.00 Page 12/15 Report Printed: 4/8/2009 • • [Miring, Operations Summary (Detailed) &Wels GRANDVIEW 1 ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 3/8/2009 08:15 09:15 1.00 PROD1 PLUG CIRC Circulate bottoms up © 10 bpm and 1,730 psi. 8,425.0 8,425.0 0.00 Spot 10 bbl H2O followed by 10 bbl high vis pill Displace with 91 bbl of 11.3 rig mud. 3/8/2009 09:15 09:30 0.25 PROD1 PLUG TRIP POOH from 6,085 ,to 5,815 ft. 8,425.0 8,425.0 0.00 3/8/2009 09:30 10:15 0.75 PROD1 PLUG CMNT Start Plug #3 - Depth 5,815 ft. Pump 23 bbl 8,425.0 8,425.0 0.00 CW, 25 bbl 15.8 ppg cement, 3 bbl CW. Displace with 77 bbl of i 1.3 ppg rig mud. Plug balanced. 3/8/2009 10:15 10:45 0.50 PROD1 PLUG TRIP POOH from 5,815 ft t 5,260 ft. 8,425.0 8,425.0 0.00 3/8/2009 10:45 11:30 0.75 PROD1 PLUG CIRC Circulate bottoms up @ 10 bpm and 1,700 ps. 8,425.0 8,425.0 0.00 3/8/2009 11:30 12:00 0.50 PROD1 PLUG RURD Blow down cement line. Prepare rig floor for 8,425.0 8,425.0 0.00 laying down 5" drillpipe. 3/8/2009 12:00 16:00 4.00 PROD1 PLUG WOC Lay down mousehole. Wait on cement plug #3. 8,425.0 8,425.0 0.00 3/8/2009 16:00 16:30 0.50 PROD1 PLUG TRIP RIH from 5,260. Tag cemen plug #3 at 5,460 8,425.0 8,425.0 0.00 ft. Set 10k on plug - held. Pull back to 5,360 ft. 3/8/2009 16:30 17:30 1.00 PROD1 PLUG CIRC Circulate at 10.5 bpm and 1,300 psi to clean out 8,425.0 8,425.0 0.00 cement from string. 3/8/2009 17:30 19:30 2.00 PROD1 PLUG TRIP Pump dry job. POOH from 5,360 ft to top of 8,425.0 8,425.0 0.00 tubing string - 1,460 ft. 3/8/2009 19:30 23:00 3.50 PROD1 PLUG TRIP Rig up and lay down 1,460 ft of 2 -7/8" tubing. 8,425.0 8,425.0 0.00 3/8/2009 23:00 23:30 0.50 PROD1 PLUG RURD Rig down casing equipment. 8,425.0 8,425.0 0.00 3/8/2009 23:30 00:00 0.50 PROD1 PLUG OTHR Clean up rig floor. 8,425.0 8,425.0 0.00 3/9/2009 00:00 01:30 1.50 PROD1 PLUG TRIP Make u• Baker K -1 cement retaingr, pup joint, 8,425.0 8,425.0 0.00 24 stands 5" drillpipe and 1 single. PU =70k. 3/9/2009 01:30 02:45 1.25 PROD1 PLUG DHEQ Set cement retainer ca 2,264 ft - 15 turns to the 8,425.0 8,425.0 0.00 right, PU 35k over and SO 20k to confirm set. Test drillpipe to 1 000 psi. Close rams and test annulus to 1,000 psi. Unscrew top drive and blow down. Unlatch and latch back up to retainer. Test annulus again as per Baker rep instructions - 20k down weight and pressure up to 1,000 psi. String jumped and drillpipe stump began to flow. 3/9/2009 02:45 03:45 1.00 PROD1 PLUG SQEZ Sting back into retainer - depth was 2 ft lower 8,425.0 8,425.0 0.00 than original setting depth. Perform squeeze cement job with rams closed -75 bbl GW, 26 bbl 15.8 ppg cement, 2 bbl CW. Displace with 30 bbl rig mud. Unsting and spot 100 ft of cement above retainer. TOC = 2,166 ft. 3/9/2009 03:45 04:45 1.00 PROD1 PLUG OTHR Discussion with town engineer. Decision made 8,425.0 8,425.0 0.00 to sting back into retainer and cement. 3/9/2009 04:45 05:00 0.25 PROD1 PLUG TRIP O•en rams and •ull 1 stand to 2 143 8,425.0 8,425.0 0.00 3/9/2009 05:00 06:00 1.00 PROD1 PLUG CIRC Circulate bottoms up @ 6.5 bpm and 250 psi. 8,425.0 8,425.0 0.00 Flow seen at surface through 4" outlets on conductor. 3/9/2009 06:00 08:30 2.50 PROD1 PLUG TRIP Lay down 5" drillpipe in hole and 3 stands in 8,425.0 8,425.0 0.00 derrick - Total of 75 joints, 1 pup and cement retainer running tool. 3/9/2009 08:30 09:00 0.50 PROD1 PLUG OTHR Clear and clean rig floor. 8,425.0 8,425.0 0.00 3/9/2009 09:00 09:45 0.75 PROD1 PLUG TRIP Rig up tubing tongs and RIH with 10 joints of 8,425.0 8,425.0 0.00 2.875" tubing. 3/9/2009 09:45 10:30 0.75 PROD1 PLUG TRIP Continue running in hole with 5" drillpipe to 605 8,425.0 8,425.0 0.00 ft. 3/9/2009 10:30 11:00 0.50 PROD1 PLUG WOC Wait on cement to set up prior to tagging. 8,425.0 8,425.0 0.00 3/9/2009 11:00 12:30 1.50 PROD1 PLUG PRTS Attempt to test plug to 1,500 psi. No build up in 8,425.0 8,425.0 0.00 pressure. Switch pumps. Stage from 2 bpm @ 150 psi to 4 bpm @ 350 psi. 10 bbl pumped away. Page 13/15 Report Printed: 4/8/2009 • Operations Summary (Detailed) &Weft GRANDVIEW 1 ConocoPhillip5 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 3/9/2009 12:30 14:00 1.50 PROD1 PLUG TRIP RIH and attempt to tag cementplug at 8,425.0 8,425.0 0.00 estimated top of 2,166 ft. No sign of plug or retainer. RIH to 2,266 ft - No tag. t onttnue KIH to 2,520 ft with no indication of cement retainer. 3/9/2009 14:00 15:00 1.00 PROD1 PLUG OTHR Spot 11 bbl high viscosity pill. 8,425.0 8,425.0 0.00 3/9/2009 15:00 16:00 1.00 PROD1 PLUG TRIP POOH to 296 ft. 8,425.0 8,425.0 0.00 3/9/2009 16:00 17:00 1.00 PROD1 PLUG TRIP Rig up casing tongs. Lay down 10 joints of 8,425.0 8,425.0 0.00 2 -7/8" cement stinger. 3/9/2009 17:00 20:30 3.50 PROD1 PLUG OTHR Clean and perform maintenance on rig while 8,425.0 8,425.0 0.00 waiting on new cement retainer. 3/9/2009 20:30 22:30 2.00 PROD1 PLUG TRIP Make up cement retainer and RIH to 2,226 ft. 8,425.0 8,425.0 0.00 3/9/2009 22:30 23:30 1.00 PROD1 PLUG DHEQ Set retainer at 2,226 ft. Test drillpipe to 500 psi. 8,425.0 8,425.0 0.00 Test backside to 500 psi. Pull to 115k and SO to 35k. Unlatch and relatch into retainer. Retest backside to 500 psi. PU =70k. 3/9/2009 23:30 23:45 0.25 PROD1 PLUG SFTY Pre job safety meeting prior to cement job. 8,425.0 8,425.0 0.00 3/9/2009 23:45 00:00 0.25 PROD1 PLUG RURD Rig up cement equipment. 8,425.0 8,425.0 0.00 3/10/2009 00:00 00:45 0.75 PROD1 PLUG CMNT Pressure test cement lines to 4,000 psi. Pump 8,425.0 8,425.0 0.00 cement as per well program - 25 bbl CW, 25 bbl 15.7 ppg cement, 3 bbl CW. Displace with 29 bbl rig mud. Unsting from retainer with 8 bbl cement left in drillpipe and spot to 2,126 ft. 3/10/2009 00:45 01:00 0.25 PROD1 PLUG TRIP POOH from 2,226 ft to 2,011 ft. 8,425.0 8,425.0 0.00 3/10/2009 01:00 01:15 0.25 PROD1 PLUG CIRC Circulate bottoms up @ 5 bpm and 200 psi. 8,425.0 8,425.0 0.00 3/10/2009 01:15 02:00 0.75 PROD1 PLUG PRTS Pressure test plug for 30 min at 1,500 psi - 8,425.0 8,425.0 0.00 Recorded on chart. 3/10/2009 02:00 03:00 1.00 PROD1 PLUG TRIP POOH. Lay down 3 joints of 5" drillpipe. Rack 8,425.0 8,425.0 0.00 back 23 stands of 5" drillpipe. Lay down retainer running tool. 3/10/2009 03:00 03:15 0.25 PROD1 PLUG PULD Pick up and make up Baker K1 retainer. 8,425.0 8,425.0 0.00 3/10/2009 03:15 03:30 0.25 PROD1 PLUG TRIP Trip in hole to 341 ft. 8,425.0 8,425.0 0.00 3/10/2009 03:30 03:45 0.25 PROD1 PLUG DHEQ Set retainer at 341 ft and pressure test to 500 8,425.0 8,425.0 0.00 psi. 3/10/2009 03:45 05:00 1.25 PROD1 PLUG CMNT Pressure test lines to 3,000 psi. Pump cement 8,425.0 8,425.0 0.00 as per program - 25 bbl CW ,26 bbl 15.7 ppg cement. 3/10/2009 05:00 05:15 0.25 PROD1 PLUG PULD Lay down cementing head and one 5" drillpipe 8,425.0 8,425.0 0.00 single. Rack back 3 stands 5" drillpipe. Lay down retainer running tool. 3/10/2009 05:15 06:00 0.75 PROD1 PLUG OTHR Pick up stack washing tool. Flush stack with 50 8,425.0 8,425.0 0.00 bbl treated H20. Lay down tool and install mouse hole. 3/10/2009 06:00 06:30 0.50 PROD1 PLUG RURD Pick up wear ring retrieving tool. Remove wear 8,425.0 8,425.0 0.00 ring. Lay down tool. 3/10/2009 06:30 07:00 0.50 PROD1 MOVE OTHR Clean and clear rig floor. Remove retainer 8,425.0 8,425.0 0.00 running tools. 3/10/2009 07:00 09:00 2.00 PROD1 MOVE PULD Remove mouse hole. Blow down choke and kill 8,425.0 8,425.0 0.00 lines. Nipple down stack and secure. 3/10/2009 09:00 10:45 1.75 PROD1 MOVE PULD Install mouse hole. Lay down 23 stands of 5" 8,425.0 8,425.0 0.00 drillpipe. Lay down mouse hole. 3/10/2009 10:45 11:15 0.50 PROD1 MOVE NUND Install bell nipple boot protector. Niipple down 8,425.0 8,425.0 0.00 tubing head from starter casing head. Secure skate rail to rig floor. Disconnect choke line between sub and pits. 3/10/2009 11:15 12:00 0.75 PROD1 MOVE MOB Clean pits and rock washer. Blow down mud 8,425.0 8,425.0 0.00 lines. Start preparing pumps for move. Page 14/15 Report Printed: 4/8/2009 • Operations Summary (Detailed) _• & , GRANDVIEW 1 ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Depth Start Depth End Depth Start Date Start Time End Time Dur (hrs) Phase Op Code Activity Code Operation (ftKB) (ftKB) Progress (ft) 3/10/2009 12:00 13:45 1.75 PROD1 MOVE MOB Continue preparing rig for move. Blow down 8,425.0 8,425.0 0.00 rock washer. Clean cellar box. Jack up pipe sheds. Remove top drive handler for repair. 3/10/2009 13:45 14:00 0.25 PROD1 MOVE MOB Release rig. 8,425.0 8,425.0 0.00 Page 15/15 Report Printed: 4/8/2009 0 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 2/14/09 AG DB TB ISSUED PER K090003ACS t .ri \ t. C {� -- it TRW r �y ' \S NOTES: s � � .�,,. ( �•; ,—;.K � \ i ; ,�_: r f-'r, - - t ' 1-12.. �' L . — 1. BASIS OF COORDINATES: OPUS SOLUTION f; , T1114.. , 1 , 4 ' a �� OF GPS STATIC OBSERVATIONS 1/21/2009. -- ,e0. : * ,) ' - ‘ & - � '` 2. COORDINATES ARE NAD83, ALASKA STATE . . ' - .. " PLANE ZONE 4. k ) - 0;-?.,;- =� 4 0 3, „ 3. ELEVATIONS ARE CONVERTED FROM OPUS NAVD88 i ` '' ' � 1 a TO B.P.M.S.L. VERTICAL DATUM. (-6.5' t DIFF.) ;4 ' - U " _ ' d ''- 4. DISTANCES ARE TRUE. ALL DISTANCES O^ c "" l 11 AND ELEVATIONS ARE IN US SURVEY FEET. * '4 J) CJ O '° ,� L • k " 5. DATE OF SURVEY 2/13/2009. ( ` _1 , PI) C „--`,y.-' �'"''� ? ` , � /" { S� s :1 b \,'f AS T lo , KUUKPIK - � �T10N f P- iEV1(� 4 ii i r9N 7L • P r7 ■ �1 " (' i. P N E E C� , PR , 1.-,, (J BO 'tll v « Y ` 199E5119Aw- A9d,011199.9IuU8 99509.1007)273 -1930 ` CO ,;."" V'/ Apb. office (907)0704730 + � �` () , .�' , Alpine survey Office Vicinity Map NOT TO SCALE T. 10 N., R. 1 E., SEC. 32 T. 9 N, R. 1 E., SEC. 5 lt oiS AGE P 1080' ' v ' U '0 \ O N In /� ', \ W W . / 60 '0 el / - ce c- z z \ 0) 03 20 c I. 902' / No, -0 \NN GF' `"2 0 0 � \ 0 �' N G G, s c\.-2/- PP a � P (. GRANDVIEW #1 �0"' / ALT 141 f N $oo.a GRANDVIEW 1 o LOCATED WITHIN PROTRACTED ° SECTION 5, T. 9 N., R. 1 E. ' UMIAT MERIDIAN, ALASKA N �� ° �� oo/ , R OA D A� e GND ELEV. 9 63.9' ' SS ICE PAD ELEV. = 65 BPMS L PREVAILING TOP OF COND. ELEV. = 65.42' BPMSL LCMF WIND NAD83 Datum N 70'10'02.045" W 151 °55'39.691" 0 200 ASPC ZN4 • • — (Y) 5,914,348.870 • • • (X) 1,400,903.322 SCALE IN FEET ALPINE MODULE: APO° UNIT: AP Conoc.Phillips GRANDVIEW 1 EXPLORATORY WELL CONDUCTOR Alaska, Inc. AS -BUILT LOCATION CADD FILE NO. DRAWING NO: PART: REV: 08- 12 -05 -1C 2/14/09 CE -AP00 -1088 1 OF 1 1 . et,,,,,o,00,010.4000 . 0010 ,10.04, t 1 , * ..,; I , il Ip 4 , ., _. i ,., \.. ' ( vt , —. , 4 ( , _ 1( t ._ .. , c , , , ... .,_,............. , s , . , ' 447, ,,,,, ) '' C 4 ' , ---* , '„ 4:4$ A ' , , I k/* 1 4.. . .4,,,, '.* ; 1‘.. ii, , , • , 1 _ „,,,,. ) ',.. C f At 4 potil i , ito „ , , ,,,,-- ,°•, ,- . , . 3 ^, s .. I ' ” t , ' Coric)coPhillips Al!Is k 9, Inc. , This photo is wyright-by ConocaPhillips Alaska, Inc. and cannot be ., released or published witFiout the express consent of ConocoPhillips Alaska, Inc. ka, T his phu is copyright it + r� �t hillip A " and be released or pu blished ritho t the exp ress cons 'tit o orioc Phill p� lask 1rr f U �� 1 y Y J t m A, r 4^,$s »5 r J C p 4 R AYE. „-,.• Y } ,,,,,[,-.....ii:,,,,,,,,, .,, '2:(2y; 2 d i fix r� a > � .v way .�s .ts,1 � f § a d � � k., r-, � � �F 2 a _ f '�f= 9 e q � �,t� Sg � � fi� I-- ,'- a` , z - ". � Y T a'. ac zg 4 ` ry - ,n�, � U z £ 0, .< ,:, 9 ,a. '''§ fib S j 3 t41' e r r a sd s. , s � ' i.x .,� s r k - r �� _ t , 4 � #� - ° 1 t '',..,-,' ',,;. ' '-'-',.;,:.:„-- - ' 7 '..:',;" '-,::::':''', - #. -',.'-'. , i , - „ A„ _.7'..,' ', .:, I ,e'''":=; ', - , , - , , _ ,, . , ,, . � '� 4 r� ate ' - u _ ,;•-: � � ! . , 't, ,, = � - � �. � � "?�� "� r , "� '' �� ` n",‘„,, ax ` 1 * ,,t 5t, ` . '4 , v � �tpK3��, c1 is �s, ��n.^ s � q., e , t a s � K . oriocoPhillips Alaska, Inc. If This photo is copyiii, ht by ConocoP'hillips Iaska inc. and cannot be released or published without the express consent of anocoP'hillips la l a, Inc. , • . Conoco Phillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01808 TO: Christine Mahnken ConocoPhillips Alaska, Inc. State of Alaska - AOGCC P.O. Box 100360 333 W. 7 Ave., Suite 100 Anchorage AK 99510 -0360 Anchorage, Alaska 99501 -3539 RE: Grandview 1 Permit: 209 -007 DATE: 04/16/2009 Transmitted: NPRA, North Slope, Alaska ;Grandview 1 501032059400 Hardcopy X2 and CDROM Definitive Directional Surveys; Halliburton survey date 2/18/2009; report date 3/12/2009; 0 -8425' md; 2 reports - 1) NAD83; 2) NAD27 coordinates CDROM — Halliburton Dual Gamma Ray /EWR -Phase 4 /Compensated Thermal Neutron /Azimuthal LithoDensity; LDWG digital log data and Digital Log Images in EMF- PDF -CGM -TIFF formats; color print is 2 &5" =100' combo in MD. Color Log print Halliburton Dual Gamma Ray /EWR -Phase 4 /Compensated Thermal Neutron /Azimuthal LithoDensity; 2 &5" =100' combo in MD To all data reciaents: All data is confidential until State of Alaska designated AOGCC release date CC: eSearch digital well file - Grandview 1 _ APR 7 2009 Receipt: Dat iVEsit Oil & GOA COM. Commiuion Anchorage G1S Techn /cal Data Management I ConocoPh /ll /ps i Anchorage, Alaska I Ph: 90Z265.6947 Sandra . D .Lemke (Co n o co p h i /lips . co m jt Grandview #1 Weekly summa. Page 1 of 1 Maunder, Thomas E (DOA) From: Reimer, David J [David.J.Reimer @conocophillips.com] Sent: Wednesday, March 11, 2009 9:03 AM To: Maunder, Thomas E (DOA); Tim_Lawlor @ak.blm.gov; tzelenka @blm.gov; Greg_Noble @ak.blm.gov Cc: Brassfield, Tom J a�C, 00-1 Subject: Grandview #1 Weekly summary Al The weekly operations summary report for Grandview will be delayed by about a day due to the fact that final daily report was not sent in from the rig since the camp is being moved to the Pioneer location. The rig was released from Grandview at 14:00 Mar 10 and moved to the Pioneer location. The weekly report will be sent out as soon as the information is received from the rig. Thanks Dave 3/11/2009 • • Grandview #1 Well Status through Mar 10, 2009 Permit Number: AOGCC 209 -007 Current Operations: Weekly Summary: Mar 4: POOH and lay down core and core barrel. Cored from 8111' to 8216' MD (105' net), recovered 105'. PU drilling BHA w/ MWD /LWD suite and TIH to 5486' MD. Total losses 323 bbls. Total losses to date: 829 bbls. Trouble time: 0.0 hrs. Total to date: 24.5 hrs. Mar 5: TIH and take check shot survey at 6300' MD. Continue TIH to 6783' MD, CBU, max gas 100 units. Well breathing. TIH to 6876' MD and ream to 7432' MD. TIH to 7710' MD and ream to 8007' MD. Ream and MadPass with LWD suite from 8007' to 8216' MD. Hole packing off and shale splinters coming over shakers. Drill from 8216' to 8425' MD. Well TD. Total losses 614 bbls. Total losses to date: 1443 bbls. Trouble time: 0.0 hrs. Total to date: 24.5 hrs. Mar 6: Wiper trip from TD to 7245' MD by backreaming. RIH from 7245' to 7730'. Ream from 7730'. Ream tight spot, drillstring plugged, unable to circulate. Attempts to clear obstruction failed. POOH at reduce speed to avoid swabbing. Stand back HWDP, LD jars and flex DC. Download MWD /LWD tools, LD BHA. Total losses 0 bbls. Total losses to date: 1443 bbls. Trouble time: 0.0 hrs. Total to date: 24.5 hrs. Mar 7: Continue to LD BHA. Motor parted leaving bit & bit box in the hole. Rotor jammed in stator, likely cause of drillstring plugging. RU wireline equipment and logging tools. Log with MSIP (sonic scanner) to 7240' MD. LD wireline equipment and logging tools. LD 7 stands HWDP & 14 stands DP. PU & RIH with 1460' of 2 -7/8" tubing. Continue to RIH w/ DP to 7419' MD. C &C mud while waiting on cementers. Tag @ 7419' MD, could not get stinger back to same depth. Total losses 0 bbls. Total losses to date: 1443 bbls. Trouble time: 0.0 hrs. Total to date: 24.5 hrs. Mar 8: Continue to C &C mud waiting on cementers. RU cement equipment. Set 500' 15.8 ppg cement plug from 7388' to 6888' MD. Plug balanced. Spot second 500' 15.8 ppg cement plug from 6888' to 6388' MD. Plug balanced. Start third 25 bbl 15.8 ppg cement plug at 5815' MD. POOH from 5815' to 5260' MD. CBU. Wait on cement plug #3. RIH to 5260', tag cement plug #3 @ 5460' MD, set 10K on plug, held. POOH, LD tubing, RD cementers. Tim Lawlor with the BLM witnessed P &A operations. Total losses 0 bbls. Total losses to date: 1443 bbls. Trouble time: 0.0 hrs. Total to date: 24.5 hrs. Mar 9: Set cement retainer @ 2264' MD. While pressure testing annulus, drillstring seen slipping and returns started over drillpipe stump. Sting back into retainer, 2' lower than original setting depth, squeeze 26 bbl 15.8 ppg cement —18 below retainer, 8 above. TOC 2166' MD. CBU, returns through 4" conductor ports seen on surface, close 4" valves. Pressure test to 1500 psi on plug failed. RIH and attempt to tag TOC @ 2166' MD — no cement. Continue to RIH to 2520' MD w/ no indication of cement or retainer. POOH and wait on new cement retainer. RIH and set new retainer @ 2226' MD — set and test good. RU for cement plug. Tim Lawlor with the BLM witnessed P &A operations. Total losses 0 bbls. Total losses to date: 1443 bbls. Trouble time: 13.5 hrs. Total to date: 38.0 hrs. Mar 10: Set cement plug from 2126' to 2401' MD. Sting into retainer pump 25 bbl 15.7 ppg cement, unsting from retainer and spot 8 bbl cement to 2126' MD. POOH, pick up second retainer. Set retainer @ 341' MD, pressure test to 500 psi — test good. Pump 25 bbl 15.7 ppg cement plug form 341' MD to surface.ND stack, LD 23 stands of 5" DP. Prepare rig for move to Pioneer. Tim Lawlor with the BLM witnessed P &A operations. Release rig at 14:00. Total losses 0 bbls. Total losses to date: 1443 bbls. Trouble time: 13.5 hrs. Total to date: 38.0 hrs. • • Grandview #1 Well Status through Mar 3, 2009 Permit Number: AOGCC 209 -007 Current Operations: 0 \"d O'\ Weekly Summary: Feb 25: Drill 8 -3/4" hole from 5855' to 6597' MD /TVD. Unable to stop the wellbore from building angle and turning to the east with 100% sliding using a 0.62° bend motor. CBU 1.5x. POOH to adjust the motor bend to 1.22 °. Tight spot at 3565' MD/TVD. Pulled 50K over. TIH, make up top drive and back ream from 3600' to 3536' MD/TVD, tight spot cleaned up. POOH to HWDP. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs. Feb 26: POOH to adjust motor bend higher, set bend to 1.22 °. Inspect bit. Download /upload MWD /LWD suite, load sources. Orient motor & MWD, TIH. Drill from 6597' to 7012' MD/TVD, slide as required to bring wellbore back to west. Maintain wellbore position in west portion of target. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs Feb 27: Drill 8 -3/4" hole from 7012' to 7986' MD, sliding periodically to maintain the wellbore position in the west portion of the target. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs Feb 28: Drill to core point as per geologist. Drill 8 -3/4" hole from 7986' to 8111' MD (8809' TVD), core point. CBU. Short trip from 8111' to 6517' MD. Back on bottom after short trip experiencing mud losses of 50 bbls /hr. Pumps off Toss rate drop to 32 bbis /hr. Spotted LCM pill with Form -A- Squeeze. Close annular and hold 300 psi for 20 min. Dress of plug from 8082' to 8111, CBU, plug held 2600 psi for short time then losses started again at 27 bbis /hr. Pump 280 bbls of mud w/ calcium carbonate /Dynared fine & medium. POOH 2 stands. Circ across top of the hole, build 100 bbis of 11.3 mud on location. Ordered 1160 bbis of mud from Deadhorse plant. CBU, starting at a rate of 1 bpm, increasing % bpm every 15 min. Reached 3 bpm, no losses, hole stable. Total losses 322 bbis. Total losses to date: 322 bbls. Trouble time: 15.75 hrs for Lost Circulation — Expected. Total to date: 22.0 hrs. Mar 1: Continue to CBU at 3 bpm, max gas - 25 units, total loss — 10 bbis. Increase pump rate to 3.5 bpm, heal losses in wellbore. POOH with proper fill. LD BHA. Test BOPE, no failures. Test witness waived by AOGCC B Noble. PU coring BHA: core barrel (120') /circ sub /ball catchers /NM flex DC's /jars/ HWDP, TIH. Total losses 20 bbls. Total losses to date: 342 bbis. Trouble time: 2.5 hrs for Lost Circulation — Expected. Total to date: 24.5 hrs. Mar 2: TIH with coring BHA from 609' to 2273' MD. Break circulation — no losses. Slip & cut 81' of drill line. TIH to 5053' MD, good displacement, break circulation, no gas or losses. TIH to 7556' MD, tight spot, circ and cleaned up. Wash & ream to 7926' MD. CBU, start adding potassium iodide tracer, CBU 2x. Ream to bottom, began taking weight at 8050' MD, wash & ream to 8111' MD. Being coring, initial loss rate at 80 bbl /hr. Core from 8111- to 8120' MD. Total losses 164 bbis. Total losses to date: 506 bbis. Trouble time: 2.5 hrs for Lost Circulation — Expected. Total to date: 24.5 hrs. Mar 3: Core from 8120' to 8216' MD. Core barrel jammed. Backream OOH to 8174' MD. CBUI had 1800 units of gas on bottom, circ gas clean, gained 14 bbis while circ. Backream OOH to 7896' MD. CBU, had 119 units of gas on bottoms up. We breathing. Pump out of hole to 7248' MD. Total losses 323 bbis. Total losses to date: 829 bbis. Trouble time: 0.0 hrs. Total to date: 24.5 hrs. • • Grandview #1 Well Status through Feb 24, 2009 Current Operations: Drilling 8 -3/4" hole to core point. Weekly Summary: Feb 15: Rig Doyon 141 released from CD1 -48 at 07:00 on Feb 15. Begin rig move to Grandview #1 location. Rig on generators for move, camp on high line power until 17:00. Feb 16: Move rig to Grandview #1 location. Rig up all rig modules. Set camp. Accept rig at 22:00 Feb 16. Feb 17: P/U and install riser boots. Load pipe shed and P/U and stand back 5" DP (270 jts). Pre -spud meeting in camp with both crews. Discuss the possibility of shallow gas. P/U and stand back 5" DP (141 jts). Function test diverter — test good. Rig repair due to bull rail in derrick cracking Assemble welding tools in rig floor for repair. Trouble time: 4.25 hrs. Total to date: 4.25 hrs. wc,.1`se h C.Ls—lc.��ht�scc CSl_• Feb 18: Complete rig repair. Weld up bull rail on monkey board in derrick. P/U and stand back 5" DP (45 jts). M/U drilling BHA consisting of Bit/Motor /Fit Sub /Stab /HWDP. Spud Grandview #1 at 05:00. Drill from 88.5' to 222' MD/TVD. M/U MWD /LWD system, orient to motor, and Toad nuclear sources in LWD suite. Drill from 222' to 712' MD/TVD. Trouble Time: 2.0 hrs. Total to date: 6.25 hrs. Feb 19: Drill from 712" to 1387' MD/TVD. Conduct short trip to 834' MD/TVD. Three tight spots with 10 -15K over pull. Circulate bottoms up and continue drilling. Drill from 1387' to 2350' MD /TVD. Pick surface hole TD at 2350' MD/TVD. Geology came in approximately 300' higher than prognosis. Circulate hole clean, prepare for a short trip into old hole. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs. Feb 20: Conduct short trip after reaching surface hole TD. Over pull of 20K at 1800' & 1580' MD /TVD. Circulate a sweep. Drop ESS, POOH. L/D BHA, R/U to run casing. Run 9 -5/8" 40# L- 80 casing. Land casing at 2341' MD/TVD. Circulate and condition wellbore for cement job, reciprocate casing. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs. Feb 21: Circulate and condition wellbore for cement. Pump cement job as per plan. Pump 50 bbls of mud push @ 10.5 ppg. Start pumping ARCTICSET LITE (10.8 ppg) lead slurry, 270 bbls; OA A pump 50 bbl tail slurry (15.8 ppg). Full returns, bump plug on schedule, floats good. L/D casing equipment. Nipple down riser & diverter. N/U well head and tubing spool, set BOP's. N/U and osvrLe.�. test BOP's, 250 psi low for 5 minutes, 5000 psi high for 10 minutes. HCR kill valve failed, replace and test before drilling out. Test witnessed by AOGCC, waived by BLM. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs. L4 lab t- o\4>kcC 4-txv. k5c Feb 22: Service top drive. P/U 3 monel flex collars, jars, 2 HWDP and stand back. Replace HCR kill valve, test HCR 250 psi low /5000 psi high for 10 min, test good. P/U BHA #2, TIH to float collar. Wash & ream cement to 2253' MD/TVD. R/U to test casing, test casing to 3000 psi for 30 minutes, test good. Tag float collar @ 2256'. Drill collar, shoe track, shoe and 20' of new hole to 2370' MD/TVD. CBU. R/U and perform leak off test (EMW = 15.4 ppg). Drill 8 -3/4" hole from 2370' to 2855' MD/TVD. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs. Feb 23: Drill 8 -3/4" hole from 2855' to 3631' MD/TVD. CBU. Short trip from 3631' to 2336' MD /TVD, no problems. Drill from 3631' to 4372' MD/TVD. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs. Feb 24: Drill 8 -3/4" hole from 4372' to 5206' MD /TVD. CBU. Short trip from 5206' to 3631' MD/TVD, slight overpull at 3852' MD/TVD. Drill from 5206' to 5855' MD /TVD. Trouble Time: 0.0 hrs. Total to date: 6.25 hrs. Grandview P &A -Plug at the Slice Casing Shoe • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, March 09, 2009 2:52 PM To: ' Brassfield, Tom J'; tzelenka @blm.gov Cc: Reimer, David J; Chambers, Mark A Subject: RE: Grandview (209 -007) P &A -Plug at the Surface Casing Shoe Tom, et al, I acknowledge your call and receipt of this message. Good luck, this one doesn't seem to want to cooperate. Tom Maunder, PE AOGCC From: Brassfield, Tom 3 [mailto:TOM.J.Brassfield @conocophillips.com] Sent: Monday, March 09, 2009 2:49 PM To: Maunder, Thomas E (DOA); tzelenka @blm.gov Cc: Reimer, David 3; Chambers, Mark A Subject: Grandview P&A -Plug at the Surface Casing Shoe Gents, after attempting to set and cement thru a leaking retainer at the shoe (approx. 2264'); WOC- we were unable to get a casing pressure test. RIH to the shoe and did not find any cement or retainer. The plan forward is to set another retainer approx 120' above the shoe i.e. not in the shoe track and re- cement. Thanks, Tom & Dave 3/9/2009 Grandview P &A revision props. • Page 1 of 1 Maunder, Thomas E (DOA) From: Reimer, David J [ David .J.Reimer @conocophillips.com] Sent: Saturday, March 07, 2009 11:52 AM To: Maunder, Thomas E (DOA) Subject: RE: Grandview P&A revision proposal Note has been forward to the rig. Thanks for the help and have a good rest of the weekend! Dave From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Saturday, March 07, 2009 11:45 AM To: Reimer, David 3 Subject: RE: Grandview P&A revision proposal . Dave, Unfortunate event. It is possible that the fish may have dropped down hole, but with it being "short" it is also possible that it may have bridged as well. 20 AAC 25.112 (a)(1)(C) allows plugging to occur above the top of fill or junk provided the plugging objectives are met. Planning to plug as deep as possible is appropriate. It is possible that the stinger may chase the bit to bottom. Placing the 1000' of cement as above the fish should provide the necessary isolation to confine fluids to their native strata, although as was noted in our conversation the lower interval is tight however some amount of lost circulation was experienced. It is most important that the bottom plugs go into place without experiencing lost circulation. If the lower plugs can be place without losses, it is not necessary to perform a tag however I will also defer to BLM representative Tim Lawlor who you indicated is traveling to location. Call or message with any questions. Tom Maunder, PE AOGCC From: Reimer, David 3 [mailto: David .].Reimer @conocophillips.com] Sent: Saturday, March 07, 2009 9:51 AM To: Maunder, Thomas E (DOA) Subject: Grandview P&A revision proposal Tom: Per our discussion, attached are the logs & mud logs for the target interval of Grandview «Abandonment_elog_mar7.ppt» «abandonment mudlog.ppt» We suspect that the fish (bit & bit box) in the hole is at a depth of approximately 7815' MD, which is where the pressure increase was noticed. Wireline logs were run to 7420' MD at which point we suspect we hit a ledge. We would like to propose the following revision to the P &A procedure. Run in the hole with 2 -7/8" tubing as deep as possible, to the top of the fish. Pump 2 - 500' plugs for a total of 1000'. Proceed up the hole and spot the hanging plug from 5545' to 5815' MD as per procedure. Proceed with the remaining plugs are per procedure. Please review and let me know if this change meets with your approval. 3/9/2009 NIIIMI=IIMMEMINIIIMIEIMMINEIMIIMMEIMIMINIIIIIIMMINIMIIIIIIIIIIMMIIMMEMIIIIMMIIIIIMMIIIIIMMIIMIMI 200 ROP 0 Depth Lin iolegy I filhr 50 Avg WOE 0 _ _ _ _ _ klbs a nterp Lith <10 Oil 5JD 5i0 <in <10 TtI Gac PP MS. 4As It tot• f..1 .99 Emil Ca Flutn 0.-4 PP nt 0.5 10(1K> 10(1K> 10CLIS2 100Ka - 113 1 2K? inaK) 10(110. 10(110. Remarks <10 Survey Data, Mud Reports, Other Into. , , .:_ --•-•-•-•-•-•-•-•- . :•. 1 . .c7:•: : : '": : : .:-•: MI I-1 SHALE CONTACIB: OVERALL'S fIFT; • ::::::. :"•//:::: : : :::::: : : :::::: MODERATE COHESIVENESS; NON ADHESIVE; . . • *: • SUB PLANAR FRACTURE SUB PLATY TO PLATY • .-L _ _ _ _._._._._....- SLibe* ' * ''' _ •_ •.--•- -•-.----•-•- ....... '*':•:': .. ': ":•?* • • •: • } ET P A I T T I1` 1 ? li A L P I PEAI F ULZE L TR I ZC% Ta • •:::•: ... • SURVEY. .ra: : , ,..vc.;::. . DECREASING SILTY SHALES GRADING TO SILT. ROTATE' * ..,__ . . * .1* * * * * NCI:44 • ''' . ■ 7.7'4 • 22:58'. :* SILTSTONE (7840 MODERATE .......... • t , . ._._.-._._.-.-.-._._ iv) 78 **:•1".* * ': YELLOWISH BROWN; MODERATE INDURATION; . :. .i .: :.i:;. ::>")...: MODERATE COHESIVENESS; NON ADHESIVE; ..... . ......•-•-•-•-•-•-•-•-•- .:-.i , SUB PLANAR FRACTURE; SUB PLATY TO PLATY _ ._._._._._.-._._._._ :::;.::: . • .:-:•'' HABIT; DULL EARTHY LUSTER; SILTY TEXTURE -•-•-•-•-•-•-•--- - EARTHY APPEARANCE; TRACE F RAM BO PYRITE 68. . •_-_-_-...- - -•-•-•-•-•-•- : 111 AND AGGREGATED PYRITE; TRACE MEDIUM GRAY --•-•-•---------•- ' * . SILTY SHALE; TRACE GRAYISH ORANGE SIUC :*:.::. .ij; ........ • • .;:::::::::::::::::: . .. . . •••-■: ...... , , r .._.-.-._.-._.-._._ -_-.--•-•-•-•-•-•-•-•- . • OF F U Ds SAMPLE = FLUORESCENCE PSSI B POSSIBLE S L O WO OR OIL CUTS. SILTS TONE (7900-7950)= PALE YELLOWISH BROWN TO A YELLOWISH BROWN; • .......... : , .„4 ._._.-._._.-._.-._._ .. ......-• MODERATE INDURATION; STIFF IN PARTS; ::. • V. . SLIGHT TO MODERATE COHESIVENESS; NON .. -.. . ..:.. ADHESIVE; SUB PLANAR FRACTURE; SUB PLATY •-•-•-•---•-•-•-•-•- SLIFV6/EV• • :T9 5.14 .. • .. -..:::-:: .:::: HABIT; DULL EARTHY LUSTER; SILTY TEXTURE Nt t:Pc: ,. t2 .fe.,:.:!:: '•- ...... ::::'.. SOME SILTS GRADING TO SILTY CLAY (SOFT); ------------ ND 79 3,"";'::::::• :::::: :::.: MASSIVE BEDS OF HOMOGENEOUS SILTS; TRACE .r."•::•:*: • i••: .:::: FRAMBOIDAL PYRITE; NO SHOW OF SAMPLE j 1 ... :::ii ::::: FLUORESCENCE OR OIL CUTS. ._._._._.-._._._._ ..... • .. . 1 SILTSTONE (7960-8010)= PALE YELLOWISH " " •::* ...* ... .-,_.-._._._._._._._ _._._._._._._._._ _ • :: • ?...-" :::: :::•:: ::: ' 1:: ::: i ii : ::• ..:•. BROWN TO DARK YELLOWISH BROWN : ; ::::: MODERATE INDURATION: STIFF IN PARTS; ..,.- •1:3••: :: . SLIGHT TO MODERATE COHESIVENESS; NON :::: • :.:',•:•• :.::.::;: ::::: ADHESIVE; SUB PLANAR FRACTURE; SUB PLATY " ...-_-_-.•-•-•-•-•-•-•--- . „ . ..:.::;. .... ‹...t7.•:. ••;• t . :•: HABIT; DULL EARTHY LUSTER; SILTY TEXTURE ::::' ',:t" ;;; ::::: SOME SILTS GRADING TO SILTY CLAY(SOFT); , . ..:'.. s • ":::':i' • ' -::::". MASSIVE BEDS OF HOMOGENEOUS SILTS; TRACE :••:•• C,:::::• • .:••••• :::•: FRAMBOIDAL PYRITE; NO SHOW OF SAMPLE . . . . ...._.-.-._.-....--- * * • • ::•: '* 4:: : :•.::.: ..:.: FLUORESCENCE OR OIL CUTS: INCREASE IN 2/28/09 .... : :::••. - ;;4.:::...: ::::: .... ::::: VERY SOFT HYDROPHILIC YELLOWISH BROWN • : • - • .: *. • .'-f• : *- ..:*'.:•• - .. : '‘. ildtWOthilt . . _ . . <200 : * : 1Q : :::- ',:trtl:PeA : ::::::: : 100}(. WO RCA To: i14 2 VE :--:: .0 iji 1% 4't'lYREAVI FOTCO O ELI . -+: , - • ',-., 4 .. , .4$ , - ::-; COHESIVE; NON ADHESIVE: SUB PLANAR COMIENCE IS! SAMP :- ....-._._._.-._.-._... 1 8.001:3- 1. : • FRACTURE; SUB PLATY HABIT; DULL EARTHY .. . ... ' * *:::: • ' : ' ( : V::: • LUSTER; SILTY TEXTURE; TRACE FRAMBOID . - • - . . • .-,_._.-.-.-.-.-._... ::-:: •.;:4.!::: PYRITE; DISTINCT GREEN GLAUCONITE IN THE CONTROL DRILL 31) it ..—',. • - - ::;'.. ' f :i 8040' SAMPLE; GRADING TO CLAY 08055' °CAUL ONITE 16 8040' _... :-.. t s' ••::• WITH NO GLAUCONITE. .:.• ..„,....,.....: . . CtiSAIPLES 8043.-80 .. - :' _ •-_-.-•-•-•-•-•-•-•- . : : ' S MW 11.3 FV 44 PV 19 YP 22 GEL 5/12/17 . • •_-_-_-_-_.. - - • - - - • - • - - . ---':- --,- FL 5.9 50L15 SD .125 PH 9.7 CL 35000 • ------•-•--- .• • WOR ONO *: .... . • • . .: ■.•:'"" SAND/SANDSTONE (8050-8100) CLEAR: ......... CLAST SIZE VERY FINE; SUB ROUND TO ROUND ; ... : ...... . . . •_-_•_-_-_-. -.- - . . .-. .- •• •':).;',•.. - :. MODERATE TO WELL DEVELOPED SPHERICITY; ', • . c• • ' MODERATE SORTING; IMPACTED TO PITTED TEX . . .. . .. : ... t... . • -'''T.:a,:• ": IMMATURE GRADING TO MATURE NATURE; . * i. : :::' MATRIX SUPPORT f8075 ' TO GRAIN SUPPORT *C0*Sitf4OLES 8085410r • *:' ' co •-•4.-z-"..• • • • : :* .4: * ';• . • :. . @8000'; WHITE DEVITRFIED ASH @8100; 08 tarr2 • : : ' __ • - • - . .- . ::',:,--.• ..-. ::- NO SHOW OF FLUORESCENCE OR OIL CUTS. HRS:95:53 FTG: ' 8 ::. . i 03101/09 03/024'09: : : • • ::: :::••• *N8 MI HtC OOREBIT.81 • ......... . . ....... ..... • ..... • • • • ---.... .. IN AT 8 1' : :::::. .... ::: .. - - ... " ' . ' ' " ..... :':."•: • • " ":".:,:.;: ::,:•: ::•.':• •••:': •••:'-: • •::.:: • •::.: ^ ........ C ... :.::..: • .... :.:::. .... ::::::•....:.::::: . Cf . ::•::: ::•::: : :::::: ....... ! ... :.::.::: , ''. . . :::::: H::i• :::::: :::;:: • . • sCP • • ! — • • ••• ...... • ::::::.; ;i: ::::i: :.'.:::•• 8 .- .• .... -.... ..... ...,....... —..• 1 • :::.;:: :::;;:,:: :::::. . ..::•.; •••.• . • ".' - .. ; . • - • .... .- , ..... ...:.• .. • --,-. . • 0 0 03 g ::: FM: 105! 14RS:15111k s v4,09.-w50 7' 1� : :::: NO SHOW OF FLUORESCENCE OR OIL CUTS. NB02RR3 • . . _ _._._._._._ • • • 'REED HTC,40S78FNPV • - - - _._._. - -- • • • 4.::::.1.:: • ' ABNT LCM BEING ADDED TO MUD SYSTEM IN:AT:8218': POOR SAMPLE QUALITY TO 8280' -- -• - - -- . LOSING MUD TO THE FORMATION TOTCO WSB ON -LINE '- '- ._. -'- •�` MW IN 11.2+ MW OT 112 VERY POOR SAMPLES = _._ _._._ _` : SILTSTONE (8217'43300'). LIGHT BROWNISH •- •- • -• - - �••. GRAY TO BROWNISH GRAY AND VARIOUS HUES •- •-•-•- :':: ) : OF BOTH; MODERATE INDURATION; CRUMBLY TO CONNECTION +SU ._._._._._ .:.<'•::- l' CRUNCHY; STIFF; MODERATE COHESIVE; NON • --- - - - --- -- . . ADHESIVE; SUB PLANAR FRACTURE SUB PLATY - • . ...... ...... .. .- •- •- •- . -. -._ :f••':I EARTHY T ' ... HABIT; DUL L EAR HY LUSTER. SILTY TO •- •- •- •- •- - - -- • • J :" : ' GRITTY TEXTURE; COMPOSED OF >90% FRIABLE .- .- •- •- .- .- - -. -.- - >r': :* : : ' ' SILT; TRACE GLAUCONITE; OVERALL EARTHY ■ :::y' A PPEARANC ; SOME HYDROPHILIC CLAYS. ' ' BECOMING SLIGHT CARBONACEOUS WITH DEPTH --'-'-'-'-'-'-'- . SILTSTO ' -8 .:•• (•..; -� ; :.: ..:, NE R O310 3C0R =LIGHT BROWNISH VARIOUS HUES GRAY TO BROWNISH GRAY AND R IOUS H S _. - •-•- •- • -• - --- - • J:: ' OF BOTH; MODERATE INDURATION; CRUMBLY TO •- •- • -• --- --- - - - ..: H.J :: CRUNCHY: STIFF; MODERATE COHESIVE; NON • • �• : '•'-- •- •- • - - - - -- t ' :' ' ' ' ' ' FRACTURE ADHESIVE; SUB PLANAR FRACTUR SUB PLATY -- -• -•- - - - - - ■::•.a. HABIT; DULL EARTHY LUSTER; SILTY TO " • - • ' ' ' -''" ' - =4_ : ' ' ' "' ' ' ' GRITTY TEXTURES; MASSIVE BEDS OF SILT ! :::ri : AND HYDROPHILIC CLAY(20 %); OVERALL '$ •- -- •- • -• -•- -- -- ' 1:::';y ' ' ' ' EATHY APPEARANCE; ABUNDANT LCM IN • ' •- •- • -• -•- - - - - . ;: ":'• SAMPLES TO COMBAT MUD LOSSES MAKING . - - -• --- - - - - SAMPLE QUALITY VERY POOR IN SPOTS. ' "' • • ' ' ' ' 1 ' ' - '1:*:: ''' ' ' ' ' ' - `:: SILTSTONE (8370'- 8425'). LIGHT BROWNISH - - - - - -- �• GRAY TO BROWNISH GRAY AND VARIOUS HUES • "' ' ' ' ' 'S __ . - --- • -• -' -- • • • • .::::••• • ' ' : OF BOTH; MODERATE INDURATION; CRUMBLY TO • - .- .- -- .- . -. -.- - CRUNCHY; STIFF; MODERATE COHESIVE; NON ' ' ' _ -- •-- '- '-' - ' - '- ; (:' ; 'f' ' ':::`.: ' ' ' ADHESIVE; SUB PLANAR FRACTURE SUB PLATY _ ___ --- -- • -• - -- HABIT; DULL EARTHY LUSTER; SILTY TO ' ' ' ' ' ' ■ • • • • • • :.:•::•:.:* • • ::.(!::' !' ' . 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Should be out there about 6 pm or so. Tim Lawlor BLM- Alaska Energy Branch Phone: 907 - 267 -1442 Cell: 907 - 240 -5243 Fax: 907 - 267 -1304 "Maunder, Thomas E (DOA)" To "Reimer, Reimer, David J" < David .J.Reimer ©conocophillips.com> cc Tim_Lawlorepak.blm.gov, tzelenka @blm.gov, DOA AOGCC Prudhoe Bay 03/06!2009 + '30 PM < doa .aogcc.prudhoe.bay(�alaska.gov> Subject FW: Grandview P&A Procedures Dave, I have apprised Commissioner Norman of your re• est and he has given his oral approval of your plan. Regarding the bottom plug, so long as it is placed with• t problems, we will waive tagging it. You correctly plan to tag the 2nd plug. Please have your ri• pervisor contact the Inspector regarding tagging the 2 plug, witnessing the pressure test above the retainer an • .e cutoff prior to welding the plate. The pressure test should be charted. Please obtain photos of the cutoff, • the plate in place and the plate. Call or message with any questions. Tom Maunder, PE AOGCC From: Reimer, David J [mailto: David .].Reimer @conocophillips.com] Sent: Friday, March 06, 2009 9:55 AM To: Maunder, Thomas E ( DOA); Tim_ Lawlor @ak.blm.gov; tzelenka @blm.gov Subject: FW: Grandview P&A Procedures All: CC) 6/17/2009 FW: Grandview P &A Procedu• Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, March 06, 2009 2:30 PM To: 'Reimer, David J' Cc: 'Tim_Lawlor @ak.blm.gov'; 'tzelenka @blm.gov'; DOA AOGCC Prudhoe Bay Subject: FW: Grandview P &A Procedures Attachments: Grandview #1 PA Procedures DRAFT TJB 3 6 09 09.rtf; Grandview #1 P &A schematic Rev 3 6 09.xls; Grandview #1 P &A AOGCC cover 3 6 09.rtf; Grandview #1 P&A BLM cover 3 6 09.rtf Dave, I have apprised Commissioner Norman of your request and he has given his oral approval of your plan. Regarding the bottom plug, so long as it is placed without problems, we will waive tagging it. You correctly plan to tag the 2 plug. Please have your rig supervisor contact the Inspector regarding tagging the 2 plug, witnessing the pressure test above the retainer and the cutoff prior to welding the plate. The pressure test should be charted. Please obtain photos of the cutoff, with the plate in place and the plate. Cali or message with any questions. Tom Maunder, PE AOGCC From: Reimer, David J [mailto: David .].Reimer @conocophillips.com] Sent: Friday, March 06, 2009 9:55 AM To: Maunder, Thomas E (DOA); Tim_Lawlor @ak.blm.gov; tzelenka @blm.gov Subject: FW: Grandview P&A Procedures All: Please review the P &A procedures for Grandview #1. Sundries are being prepared. Please provide any comments. Thanks Dave From: Brassfield, Tom 3 Sent: Friday, March 06, 2009 9:10 AM To: Reimer, David 3 Cc: Chambers, Mark A Subject: Grandview P&A Procedures Dave, here are some revised procedures for the P &A. Probably need to get to Domenica to work the slurries! Need to fill -out the one page sundries. Tom «Grandview #1 PA Procedures DRAFT TJB 3 6 09 09.rtf» «Grandview #1 P &A schematic Rev 3 6 09.xls» «Grandview #1 P &A AOGCC cover 3 6 09.rtf» «Grandview #1 P &A BLM cover 3 6 09.rtf» 3/6/2009 FW: Grandview P &A Proced• • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, March 06, 2009 10:19 AM To: 'Reimer, David J' Cc: Brassfield, Tom J; Alvord, Chip Subject: RE: Grandview P&A Procedures Ocx Dave, The plan does not look unreasonable. I do have some requests ... 1. Could you provide relevant log sections of the intervals that the plugs are intended to isolate? 2. I'd like some further information on the operations while coring and the trip you are attempting. Depending on the hole behavior, it may be necessary to tag the deep plug as well. Thanks in advance for the information. I will be out of pocket for a bit, but will be back to you in the early afternoon. Tom Maunder, PE AOGCC From: Reimer, David 3 [mailto: David .].Reimer @conocophillips.com] Sent: Friday, March 06, 2009 9:55 AM To: Maunder, Thomas E (DOA); Tim_ Lawlor @ak.blm.gov; tzelenka @blm.gov Subject: FW: Grandview P&A Procedures All: Please review the P &A procedures for Grandview #1. Sundries are being prepared. Please provide any comments. Thanks Dave From: Brassfield, Tom ] Sent: Friday, March 06, 2009 9:10 AM To: Reimer, David 3 Cc: Chambers, Mark A Subject: Grandview P&A Procedures Dave, here are some revised procedures for the P &A. Probably need to get to Domenica to work the slurries! Need to fill -out the one page sundries. Tom «Grandview #1 PA Procedures DRAFT TJB 3 6 09 09.rtf» «Grandview #1 P &A schematic Rev 3 6 09.xls» «Grandview #1 P &A AOGCC cover 3 6 09.rtf» «Grandview #1 P &A BLM cover 3 6 09.rtf» 3/9/2009 ....: 73_ _ _ _ _ _ ____ i.."0.._....,i....2t 5 . r il) S . FX E 0.1 hours SEXP 1 oh-h-) ioo . SNP2 SESP SCO2 I: n s!ele ::tro n A 0 i t 1 " II' M 100 -0.75 gram per cc SROP SEMP TNPS feet per hr 1 ohm-m 100 n pu 0 SGRC SEDP SBD2 . c.C. ari ‘;:ri 1:600 ohm-rn 100 1.65 gram I - - r cc 0 — 2.65 -- --. '--- 550— - _____ ■ I ._ _j. L_ '' ---f= -4----------- , r: .._ _...__4 • _______ _ ___1 ..-. 1 I I I - ii , -- t -,,„„_ .. , ..› - I • I ' , __ _ _______,__________ .----i- I ' 5600 L.,. 1 -,..i . =-- ._. - ' — _______ ___ • ______________ • ti ' ..—.... - . .. . - . ..____........... .. , 4 I ' ` , .1 _-____.- . i : INUI11111-111 . 7 .-- 1 ->,-- , - MIIEVEL MIMI L-- ------- _--........, ;..... _ . . 5700 ______________ i . MIMI IIIIIII—__AiW NE iC5111111M1 ..., . sin MilliW.-14 .7L ' tiMMOS11 --_-- . -t i , I. I& I 1. : ' 1011MITM wic--•'`.._ lialMIKM ----- - ------------ .... - - millw ,_ -- 771 -- 1 -.57,- _______ . - . , DiM111111111 7 - _ __ .,,,-_,--- $.., .,.....„414.__ , 4 ; I •. NNIIIIIIMI 01111E11111M, - -- ------.---^" 5800 '-'-')-- i.lizz.- ..ri.. -xe C -4... !I : 1 ,)- — , _________ -- -. — _____....,.... , - , 41 , . . i ___ __ _ , -- . ----- . — MIIIIMIIM ____ ____ _ ______ --,- I . . ,, --_-- ,..„-7,1„. I Grandview #1 P &A Revision 3/6/09 Drilling &wells Depths based on rig RKB Schematic not to scale ConocoPhillips 300' cement plug to surface _ inside 9 -5/8" csg or +/- 23 bbls. or .0758 bpf 16" 65# H-40 @ 108' MD Retainer set @ +/- 2266 MD/TVD or 75' from shoe Surface csg. with +/- 75' of 15.8 ppg cement below 9 -5/8" 40# L -80 BTC retainer in csg and +/- 100' of cement in open hole +/- 2341' MD/TVD , Place 100' of cement on top of retainer. Cemented to surface. Top of 15.8 ppg plug @ +/- 5545' MD/TVD 8 -3/4" open hole Bottom of plug @ +/- 5815' MD/TVD 270' 15.8 ppg balanced cement plug dia 09 from 5545' - 5815' MD/TVD / ( +/- 125' above & below interval from 5670' - 5690' MD �j /r 91 Top of 15.8 ppg plug @ +/- 7700' MD/TVD 1000' 15.8 ppg balanced cement plug. TD @ 8425' MD/TVD or 6084' of 8 -3/4" hole TJB 3/6/09 Weekly update Grandview #1 2 -24 -09 Page 1 of 1 • 0 Maunder, Thomas E (DOA) From: Reimer, David J [ David .J.Reimer @conocophillips.com] Sent: Wednesday, February 25, 2009 10:09 AM To: Maunder, Thomas E (DOA) Subject: RE: Weekly update Grandview #1 (209 -007) 2 -24 -09 Tom: See below: Hope this helps Thanks Dave From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, February 25, 2009 9:42 AM To: Reimer, David J Subject: RE: Weekly update Grandview #1 (209 -007) 2 -24 -09 Dave, A couple of questions /comments. 1. Please include the permit number in the message title. 2. How much cement was circulated? 270 bbl of ARCTICSET LITE, 50 bbl tail slurry, cement returns to surface was 145 bbl. 3. Do you have the identity of the Inspectors that waived the diverter test (I know it was Chuck Scheve) and witnessed the initial BOP test? Tim Law for waived the diverter test. BOP test w itnessed by B ob Noble, Tim Lawlor waived, Thanks in advance. Tom Maunder, PE AOGCC From: Reimer, David J [mailto:David.J.Reimer @conocophillips.com] Sent: Wednesday, February 25, 2009 9:34 AM To: tzelenka @blm.gov; Tim_Lawlor @ak.blm.gov; Maunder, Thomas E (DOA) Cc: Chambers, Mark A; Brassfield, Tom J Subject: Weekly update Grandview #1 2 -24 -09 Attached is the weekly drilling operations summary for Grandview #1 «Grandview #1 weekly summary 2- 24- 09.doc» The summary starts from when the rig got on location through Feb 24, which was 1 week from spud. Future summaries will be distributed on a weekly basis. Please let me know if there is this report meets your needs. Thanks Dave 2/25/2009 Page 1 of • Maunder, Thomas E (DOA) From: Senden, Leslie [ Leslie .Senden @conocophillips.com] Sent: Tuesday, February 03, 2009 11:37 AM To: Maunder, Thomas E (DOA) Subject: RE: Weekly Reporting for NPRA Exploration Tom, That helped a lot — thanks! -- Leslie From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] `7 ��Q L ac c 1 _ Sent: Tuesday, February 03, 2009 10:12 AM 1 0 To: Senden, Leslie Subject: RE: Weekly Reporting for NPRA Exploration Leslie, Just checking back on this matter. Any issues? Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, January 27, 2009 12:04 PM To: Senden, Leslie Subject: RE: Weekly Reporting for NPRA Exploration Leslie, Sorry for the delay in getting back to you. I have scanned an example of the weekly report Mike sent in last year during the testing of Rondy 2. This information is similar to what was submitted for Char #1 as well. What he submitted was very complete. For a weekly report, I don't know if graphs and half hourly test information is necessary. That information should be submitted with the completion report, however you are certainly free to send it as it is developed. The first two pages with the daily summary are a minimum. Mike emailed the document to me, mailed it to Commissioner Norman (if you do that now, it should be to Daniel T. Seamount, Jr.) and he faxed it. All three methods are not needed. I get most of the weekly reports regarding exploration activities by email and then route that information to the well file. If you desire to mail a copy to Commissioner Seamount, that is fine too. I hope this helps. Call or message with any questions. Tom Maunder, PE AOGCC From: Senden, Leslie [mailto:Leslie .Senden @conocophillips.com] Sent: Wednesday, January 21, 2009 10:31 AM To: Maunder, Thomas E (DOA) Subject: Weekly Reporting for NPRA Exploration Tom, Thanks for the call back yesterday. As we discussed, could you reply back to this message with a few details of what is generally expected from the weekly report e-mail? I really appreciate your help. -- Leslie Leslie Senden ConocoPhillips Alaska 2/3/2009 4, • • J 3 -, L L;' i � SARAH PALM, GOVERNOR I I OIL AND �T ALASKA OIL AN GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Exploration, Grandview #1 ConocoPhillips Alaska, Inc. Permit No: 209 -007 Surface Location: 1079' FNL, 902' FEL, Sec 5, T9N, R1E, UM Bottomhole Location: 1079' FNL, 902' FEL, Sec 5, T9N, R1E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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. 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) . cerely, Daniel T. Seamount, Jr. Chair DATED this 15th day of January, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA v ALASKA OIL AND GAS CONSERVATION COMMISSION JAN . 2 O Q • • PERMIT TO DRILL � fka ►� &Gas; , 20 AAC 25.005 �� t‘-‘ OS, "fi mil t. iti la. Type of Work: lb. Current Well Class: Exploratory 0 , Development Oil ❑ 1c. Specify if well is proposed for: Drill 51 • Re -drill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone❑ Single Zone 0 , Shale Gas ❑ 2. Operator Name: 5. Bond: In Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 , Grandview #1 - 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 8700' TVD: 8700' Exploration • 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1079' FNL, 902' FEL, Sec 5, TSN, R1 E, UM • AA 081785 • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1079' FNL, 902' FEL, Sec 5, T9N. R1 E, UM Tobin 932520 2/15/2009 Total Depth: 9. Acres in Property: 14. Distance to 1079' FNL, 902' FEL, Sec 5, T9N, R1 E, UM 5720 Nearest Property:AA 081787 or 5 mi 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x 260867 • y 5914606 • Zone 4 (Height above GL): 28' RKB feet Rendezvous "A" approx 4.3 miles 16. Deviated wells: Kickoff depth: 0 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: <5' d eg. Downhole: 4162 psig Surface: 1879 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom � c. f. or sacks , Hole Casing Weight Grade Coupling Length MD TVD MD TVD / ` (including stage data) 24 16 62 Pig` 9 PRB 80 Surface Surface 108 108 ;Cs0 200 sx AS1 12 5 8 40 p 50 9TG 2672 Surface Surface 2700 2700 Vesx ASLite +240 sx Class G + 8-3/4" 7" 26 ppf L -80 BTC -M 8589 Surface Surface 8700 8700 240 sx ClassG + additives 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) • Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch❑ Drilling Program Time v. Depth Plot❑ Shallow Hazard Analysis 0 Property Plat ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 51 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfield @ 265 - 6377 Printed Name Chip Alvord Title Drilling Manager Signature /_ ./ /� Phone 2656120 Date r (f2 ( / Z.0 l• -(J'` Commission Use Only Permit to Drill API Number: �r� Permit Approval See cover letter Number: 7L " 50- X "�.� / �� I Date: 1 A sip f for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce oalbed methane, gas hydrates, or gas contained ins ales: Er 35 % tj t A I C t'A Samples req'd: Yes No ❑ Mud log req'd: Yes [.7 No ❑ Other: a S i t , AMV�brry \ht � IJ H2S measures: Yes 'No 11 Directional svy req'd: Yes ❑ No 44 A y k �v ` c� 1ca�s t MS.N m alto rAOT.t . 't` Sn`(`we" eft. StrLrve� re goct . 1 n 1.61 � arr APPROVED BY THE COMMISSION DA , COMMISSIONER or 1U - 4U 1 �e ed 1205 Submrt rn upIi e G • ConocoPhillips RECEIVED Box 100360 ! h,��S Alaska 99510 -0360 Alaska Oil teas ot15. �ori1►ttissi Anchorage January 12, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill: Grandview #1 (Exploratory Test) Surface Location: 1079' FNL, 902' FEL, Sec 5, T9N -R1E X= 260,867 & Y= 5,914,606 ASP4 NAD27 Target Location: 1079' FNL, 902' FEL, Sec 5, T9N -R1E Bottom Hole Location: 1079' FNL, 902' FEL, Sec 5, T9N -R1E Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the NPRA — Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling 12 -1/4" surface hole to approx. 2700' MD followed by an 8 -3/4" production hole to the objective with . a LWD logging suite for evaluation. The hole section will also be cored in the zone of interest. E -line Togs will be run to determine if the well will be cased (with 7 ") and tested post -rig or be P&A'd. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" production casing if completed , and 3 -1/2" tubing. There is a possibility that CPAI could request authorization for the disposal of drilling waste via the annulus by filing with the AOGCC a 10 -403 supplement with additional information as required under 20 AAC 25.080. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). (Straight Hole) 3) Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 141) as required by 20 AAC 25.035 (a) (1) and (b) have been submitted previously. • 4) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 5) The drilling fluid program as required by 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a). are attached in this APD package 8) ConocoPhillips does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 9) Complete logging, and mud logging operations are planned and descriptions are attached. The following are ConocoPhillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon Allsup- Drake, Drilling Technologist (20 AAC 25.070) 263 -4612 2) Geologic Data and Logs Greg Wilson, Geologist (20 AAC 25.071) 263 -4748 The anticipated spud date for this well is February 15, 2009. If you have any questions or require further information, please contact Tom Brassfield at (907) 265- 6377 or Chip Alvord at (907) 265 -6120 Sincerely, Tom Brassfield Senior Drilling Engineer cc: CONFIDENTIAL — Grandview #1 Well File Chip Alvord ATO -1570 Leslie Senden ATO -1390 • Conoco Phillips Alaska, Inc. Drill and Case Plan for Grandview #1. General Procedure: 1. MIRU Doyon 141 over pre - installed 16" conductor casing with welded landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12 1/4" hole to the surface casing point at 2700' MD /2700' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. • Employ lightweight permafrost cement lead slurry and a Dowell Class "G" plus additives system tail slurry to assure cement returns to the surface in a one -stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 3/4" bit and BHA and RIH to top of float equipment. • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 8. Drill float equipment and approximately 20' of new hole • Perform LOT (or FIT if gradient reaches 18 ppg equivalent) • Record results and fax to town 9. Drill 8 -3/4" Pilothole to Top of Jurassic at approx. +8216' MD/ ±8216' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. POOH with drilling assembly. • Condition hole and mud for coring operations. 10. PU 90' coring assembly /RIH /core zone of interest. POOH and LD core. 11. Make up 8 -3/4" bit/BHA and RIH. Drill 8 -3/4" hole to TD at approx. ±8700' MD / ±8700' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. POOH with drilling assembly. • Condition hole and mud for logging operations. 12. Log 8 -3/4" hole as directed. Decision to complete the wellbore or P&A. 13. Make clean -out conditioning trip for 7" casing if being completed. 14. Run and cement 7" casing per program to TD (est.@ 8700' MD/ 8700' TVD). Cement casing to bring cement +/- 700' above Jurassic or +/- 500' above top significant hydrocarbon zone. 15. Make a cleanout run with bit and scrapers (Optional) • Displace to filtered seawater or brine- depending on formation pressure • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 16. Run and land 3 -1/2" completion per schematic. Carry out a leak -off test down the 9 -5/8" x 7" casing annulus to confirm the fracture pressure gradient and freeze protect. 17. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 18. Freeze protect the tubing and tubing x 7" annulus. 19. Drop ball and rod, set packer, and test tubing /annulus to 3000 psi. ORIGINAL Conoco Phillips Alaska, Inc. 20. Set BPV, secure well, release rig. 21. MIRU well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or trucked to Kuparuk or Alpine production facilities. 22. Upon completion of testing or if the well is not completed, plug and abandon the well, or temporarily shutdown per applicable regulations. Thoroughly clean location and block off further ice road access to location. R!G1NAL C • onoco Phillips Alaska, Inc DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Grandview #1 Drilling Fluid Properties: Spud to surface Drill Out casing point Production Hole Density 10.0 - 10.2 ppg 9.6 — 11.3 ppg PV 16 -26 6 -20 YP 30 -40 25 -35 Funnel Vis 75 - 90 75 - 90 Initial Gel 10 - 20 10 - 20 10 Minute Gel 15 - 40 14 — 20 API Filtrate 7 - 15 <6 pH 9.5 -10 9.0 -10 % Solids ± 10% < 11% Drilling Fluid System: Equipment list for Doyon 141 should be on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Pore Casing Casing Fracture Pressure Pore Size Setting Depth Gradient Gradient Pressure MASP Drilling 16" 108' MD / 108' TVD 11.0 ppg 9.0 51 NA 9 -5/8" 2700' MD / 2700' TVD 15.5 ppg 9.0 1264 50 psi 7" 8700' MD / 8700' TVD 17.8 ppg 9.2 • 4162 1879 psi Expected Maximum Mud Weights: 12 -1/4" surface hole to 2700' MD / 2700' TVD: 10.2 ppg, pore pressures of up to 9.0 ppg may be present ✓ just below the permafrost at -800' SS. ( See Seismic Pore Pressure Analysis attached.) 8 -3/4" production hole to 8700' MD / 8700' TVD: 11.3 ppg The pore pressure is predicted (per the pore pressure analysis) to increase below -4000' SS from normal pressure gradient to up to 10.1 ppg. We believe the elevated prediction is due to Geology and not an actual shift in pore pressure. However, the expected maximum weight of 11.3 is anticipated to control the Miluveach shales above the zone '' of interest and not required for pore pressure control. ARCO Spark 1A was 9.1 ppg EMW @ 7979' ssTVD, Rendezvous A was 9.0 ppg EMW © 8071' ssTVD, Spark #4 was 9.5 ppg EMW © 7620' ssTVD, Spark DD was 9.07 ppg EMW @ 7981' ssTVD, Rendezvous 2 was 8.93 ppg EMW @ 8245' ssTVD �. 1.L • Conoco Phillips Alaska, Inc. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) — 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi /ft 0.11 = Gas Gradient in psi /ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP — (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) — 0.11] x D = [(11.0 x 0.052) — 0.11] x 108' = 50 psi OR MASP = FPP — (0.11 x D) = 1264 — (0.11 x 2700') = 967 psi 2. Drilling below 9 -5/8" Surface Casing MASP = [(FG x 0.052) — 0.11] x D MASP = [(15.5 x 0.052) — 0.11] x 2700' MASP = 1879 psi OR MASP = FPP — (0.11 x D) = 4162 — (0.11 x 8700') = 3205 psi Casing Design Performance Properties Size Internal Tensile Strength Weight Grade Connection Yield Collapse 16" 63 ppf B PEB Conductor Casing Joint Body 9 -5/8" 40 ppf L -80 BTC 5750 psi 3090 979 M 916 M 7" 26 ppf L -80 BTC -M 7240 psi 5410 667 M 519 M Casing Setting Depth Rational: 16" @ 108' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. ORIGINAL • Conoco Phillips Alaska, Inc. 9 -5/8" @ 2700' MD RKB Surface casing to provide good anchor for BORE and sufficient fracture gradient and well control while drilling 8 -3/4" hole to top of reservoir. 7" @ 8700' MD RKB Production casing is set thru the zone of interest in a successful case so there is sufficient rathole below the bottom perf. Well Proximity Risks: None Drilling Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Grandview #1 area are surface interval clays, intermediate interval sloughing shales, and lost circulation /breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached Pre -Drill Seismic Pore Pressure Prediction which includes offset well mud weight versus depth graphs and predicted formation pressure gradient for Grandview #1 Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The Grandview #1 surface /production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. CPAI may request approval to inject or dispose of fluids in the Grandview #1 9 -5/8" x 7" annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 AAC 25.080. Geology: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (ss) UNCERTAINTY POSSIBLE FLUID EST. PORE RKB = 111' TYPE PRESSURE, psi Permafrost Base 800' 250' 374 Sequence 96 3220' 150 1507 Torok 3810 150' 1783 Sequence 91 5625' 150' 2925 Top Fill 5962' 200' 2852 Top Block 6350' 200' 2972 Top HRZ 7180' 150' 3360 Base HRZ 7325' 100' 3428 LCU 7450' 100' 3487 Jurassic Alpine C Sand 8105' 200' Oil and /or Gas 3877 UJU 8190' 200' 3918 Nuiqsut Marker 8320' 200' 3981 TD 8589' 200' 4109 ORIGINAL • Conoco Phillips Alaska, Inc. Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 — Surface Casing setting depth) LWD: GR/Res /Density/Neutron • 8 -3/4" Production Hole (9 -5/8" Shoe to TD) LWD: GR/Res /Density/Neutron /PWD /BAT • Wireline: FMI or MSIP /MSCT /Chechshot . II. Coring 90' of 4" core & possible MSCT wireline cores, see Logging above II. Mudlogging Mudlogging service should be in operation from the base of the conductor casing to TD. Service . most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H detection Thirty to sixty-foot (30' -60') wet and dry samples will be collected from surface to surface casing setting depth. Thirty-foot (30') wet and dry samples will be collected from surface casing setting depth to TD, and ten -foot (10') wet and dry samples, or continuous, collected across any hydrocarbon intervals for these intervals. III. Flow Testing Flow testing and pressure build -up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build -up. The flow period will be determined on -site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build -up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. ORIGINAL ! Conoco Phillips Alaska, Inc. • Grandview #1 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12 -1/4" Hole / 9 -5/8" Casing Interval Event Risk Level Mitigation Strategy Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud temperatures Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in Low Diverter drills, increased mud weight. Pore Surface Formations pressure /shallow hazards study does not indicate any abnormal surface hole pressures. Lost Circulation Medium Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled running speeds. 8 -3/4" Hole/ 7" Casing Interval Event Risk Level Mitigation Strategy Lost circulation High Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre - planned LCM pills, lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Medium BHA design, on -sight geologic review and advisement of potential slump blocks. Sloughing Shale, Tight High Increased mud density to control the shales Hole and fluid composition according to plan, controlled trip speeds, sweeps, ECD monitoring. Abnormal Reservoir Low Well control drills, increased mud weight, Pressure offset well data does not indicate abnormal pressures in the area. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers o R u 3'NAL Grandview #1 Schematic -aft • Rev 11/26/08 by TJB 3 -1/2" FMC Gen V tubing hanger with 3.5" L -80 9.3# EUE 8rd Mod pin down. Special Drift F 2.91" 16" conductor s 3 -1/2 ", L -80, 9.3# EUE 8rd Mod Tubing and spcaeout pups to the @ +/- 108' MD tubing hanger. 1 /2" Cam o DS La Drift 3-1/2" Nipple with 2.875" ID No -Go profile set @ +/- 500' MD. 3-1/2", DV,s L-80, spaced out as ow EUE 8rd Mod Tubing to the 'DS' Nipple with 3-1/2" x 1" Camco 'KGUG' GLM's 9-5/8" 40# L-80 BTC @ 2700' MD/TVD Note: Each GLM should have 10' L -80 handling pups installed on top and bottom. 3 -1/2" x 1" Camco 'KGUG' GLM @ 3400' MD/TVD 3 -1/2" x 1" Camco'KBUG' GLM @ 5600' MD/TVD ,I 3 -1/2" x 1" Camco 'KBUG' GLM @ 7000' MD/ TVD 3 -1/2" Halliburton "X" Landing Nipple with 2.81" ID profile. ■ 3 -' /z" Weatherford Smart b� Mandrel Baker "K" anchor. Baker 7" x 3- 1 /2 " 'SAB' Retrievable Packer @ approx 7116' MD/TVD Minimum ID through the packer 3.00 ". 3 -1/2 ", L -80, 9.3# EUE 8rd Mod Tubing to Packer. 3 -1/2" x 1 -1/2" 'MMG' GLM. 3 -1/2 ", L -80, 9.3# EUE 8rd Mod Tubing 3 -1/2" Halliburton XN Nipple w/ 2.75" No -Go Profile Baker 3 -1/2" Shear Out Sub w/ WL Re -entry Guide. Tubing tail @ 7,216' MD. Jurassic Sands@ approx 8216' MD /TVD 7" 26# L -80 TD @ 8700' MD/TVD 8700' FII4: approx. MD/TVD ' ' :: pp TJB 11/26/08 ORIGINAL Grandview 1 Well Plan , ,,,,., 16" Surface Hole: Wellsite geologist Casing point selection, sampling supervision Base Permafrost - 800 Mudlogging Gas monitoring, sample description LWD Gamma Ray — Res. Correlation to casing pt; AOGCC regulations LWD NPHI -RHOB Only if required by AOGCC Washed /Unwashed cuttings 30' as soon as physically possible Mud gas for isotopes 500' samples in tubes or at any show 9 5/8" at -2589 — • D N Sequence 96 -3,220 G7 ■ 8'/2" Hole: Wellsite geologist Casing point selection, sampling supervision Torok - 3,810 ti, Mudlogging Gas monitoring, sample description M LWD GR- R- NPHI -RHOB Formation evaluation, core point selection r --- ■ Washed /Unwashed cuttings 30' as soon as physically possible Top Fill 5,962 Mud gas for isotopes 100' samples in tubes starting at 5000' depth Collect 10' gas samples over reservoir III Collect gas BAGS in reservoir Top Block - 6350 EVALUATION at TD: Top HRZ - 7,180 Drillpipe- conveyed MDT Ascertain HC phase, reservoir pressure MSIP (sonic scanner) Formation evaluation, seismic analysis LCU - 7, 450 MSCT (sidewall cores) Missed core over main reservoir • Shallow reservoirs if P >15 %, SW <50 %, 15 feet NM Well Success case, confirm zone isolation Well Test Reservoir productivity, ascertain phase Top Alpine C - 8,105 UJU - 8,190 FULL CORE Over reservoir section (4" diameter, 90 — 120' length) Ascertain reservoir quality, HC phase, depositional environment Top Nuiqsut -8,320 ati ConocoPhillips on `Or@ TD -8589 .6. ::: • Grandview, v2 Schlumberger CemCADE Preliminary Job Design 9 5/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only Rig: Doyon 141 Volume Calculations and Cement Systems Location: Alpine Client: t: Conoco Phillips Alaska, Inc. (Volumes are based on 300% excess in the permafrost and 50% excess below the Revision Date: 1/13/2009 permafrost. The top of the tail slurry is designed to be at 2,200' MD. Prepared by: Domenica Mendoza Location: Anchorage, AKA Lead Slurry (minimum pump time 220 min.) Phone: (907) 265 - 6336 ARCTICSET Lite @ 10.7 ppg - 4.49 ft3 /sk Mobile: (907) 748 - 0170 email: dmendoza2 @s1b.com 0.7632 ft /ft x (108') x 1.00 (no excess) = 82.4 ft 0.3132 ft /ft x 803' x 4.00 (300 %excess) = 1006 ft < TOC at Surface 0.3132 ft /ft x 1289' x 1.50 (50% excess) = 605.6 ft 82.4 ft + 1006 ft 605.6 ft = 1694 ft 1694ft / 4.49 ft /sk = 377.3 sks Round up to 380 sks 0 Have 270 sks of additional Lead on location for Top Out stage, if necessary. Previous Csg. Tail Slurry (minimum pump time 170 min.) < 16 ", 62.6# casing 15.8 ppg Class G + 0.8 %S1, 0.2 %D46, 0.3 %D65 - 1.16 ft3 /sk qi at 108' MD 0.3132 ft /ft x 500x 1.50 (50% excess) = 234.9 ft 0.4257ft x 80' (Shoe Joint) = 34.1 ft !' 234.9 ft + 34.1 ft = 269 ft 269 ft 1.16 ft /sk = 231.9 sks Round up to 240 sks BHST = 69 °F, Estimated BHCT = 75 °F. < Base of Permafrost at (BHST calculated using a gradient of 2.2 °F /100 ft. below the permafrost) 911' MD (911' TVD) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time < Top of Tail at Stage (bpm) (bbl) (min) (min) Comments 2,200' MD CW100 5 20 4.0 4.0 Start Pumping Wash Drop Bottom Plug 15.0 19.0 MudPUSH II 5 50 10.0 29.0 Start Pumping Spacer Lead Slurry 6 304 50.7 79.7 Mix and Pump Lead Slurry Tail Slurry 5 50 10.0 89.7 Mix and Pump Tail Slurry Drop Top Plug 8.0 97.7 Displacement 7 179 25.6 123.3 Start Displacement Slow Rate 2 20 10.0 133.3 Slow Rate to Bump Plug < 9 5/8 ", 40.0# casing in 12 1/4" OH MUD REMOVAL TD at 2,700' MD Recommended Mud Properties: 10.2 ppg, P < 20, T < 30. As thin and light as possible to aid in mud removal during cementing. (2,700' TVD) Spacer Properties: 10.5 ppg MudPUSH* II, P 28, T 47 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement and 2 per joint on the last 2 joints of the shoe. Please refer to CemCADE report. * Mark of Schlumberger ORIGINAL • Grandview, vi Schiumherger Cep CADE* Preliminary Job Design 7 ".Intermediate` Preliminary Job Design based on limited input data. For estimate purposes only Rig: Doyon 141 Location: GMT Intermediate Client: ConocoPhillips Alaska, Inc. Revision Date: 12/17/2008 Volume Calculations and Cement Systems Prepared by: Domenica Mendoza Location: Anchorage, AK Mobile: (907) 748 - 0170 Volumes are based on 40% excess. Slurry is designed for TOC of the cement at 7500' email: dmendoza2 @slb.com MD. Tail Slurry Minimum thickening time: 200 min. (Pump time plus 120 min.) 15.8 ppg, Class G + 0.2 %D46, 0.3 %D65, 0.07 %B155, 0.4% D167 - 1.16 ft3 /sk 0.1503ft /ft x 1200' x 1.40 (40% excess) = 252.5ft 0.2148ft x 80' (Shoe Joint) = 17.2ft 252.5ft + 17.2ft = 269.7ft 269.7ft 1.16 ft /sk = 232.5 sks Round up to 240.0 sks BHST = 174 °F, Estimated BHCT = 135 °F. Previous Csg. (BHST calculated using a gradient of 1.85 °F /100 ft. below the permafrost) < 9 5/8 ", 40.0# casing at 2,700' MD PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments CW100 5 20 4.0 4.0 Start Pumping Wash < Top of Slurry at Drop Bottom Plug 10.0 14.0 Pressure Test Lines, Drop Plug 7,500' MD MudPUSH II 5 25 5.0 19.0 Start Pumping Spacer Tail Slurry 5 50 10.0 29.0 Mix and Pump Tail Slurry Drop Top Plug 10.0 39.0 Drop Top Plug 3 z Water 5 20 4.0 43.0 Start Pumping Water Switch to Rig Pump 5.0 48.0 Switch to Rig pump to Displace Displacement 7 290 41.4 89.4 Start Displacement Slow Rate 2 20 10.0 99.4 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 11.3 ppg, Pv < 15, T < 15. As thin and Tight as possible to aid in mud removal during cementing. Spacer Properties: 13.5 ppg MUDPUSH II, Pv = 33, Ty = 25 < 7 ", 26.0# casing in 8 3/4" OH Centralizers: Please refer to cementing program. 1 centralizer every 2 joints per zones of interest and 2 centralizers per joint on the last 2 joints at shoe are recommended. TD at 8,700' MD (8,700' TVD) ORIGINAL 16" set@ 107' DRILLING TIME AND MUD WEIGHT CURVE --•— Depth ARCO Spark #1 & #1A Mud Weight o I I I I I I I 1 I i I 1 L J 1 L I 1 L I 1 L 1 1 L J L 1 1 J L i 1 J 1 L — 11.9 I r 7 r 1 r r I r r I 7 r I 7 r 7 r r 7 r 1 r 1 7 1 7 7 r I J 1 L t 1 L J L 1 L .1 L I 1 1 I J L J 1 I J 1 L I 1 1 Drill 9-7/8 11 Hole 1 I 1 1 I 1 1 I 1 1 1 1 1 1 1 I 1 1 I I 1 1 1 1 1 -- -1 -'7 - r r r 1 r 7 r i - r r 1 7 r 1 r 7 I 1 7 r — 11.7 1000 r 1 1 1 1 1 r 1 r r I I I I t 1 1 1 7 I I 1 - I 1 7 1 r - - -- -1 -- -- k- - -- 4 -- 'J - - ✓- i + F - - 1 -- - i -t 1- 1 4 T 4 !- I 4 --- ! --- I -- - I I -- - ---- - -- 41 - - L -= 11.5 I i 1 1 i , t I I I 1 1 , 1 1 1 1 1 I 1 1 i I i i -- - -- I r 1 7 1 1 r I I 1 , 7 1 1 4 - - -- 7 " set @2610' ; 1 - - F - - � - I -- - - r - - -- - 'L - - l - - -- 4-- }-- 1----- -I- - +- -1---1 I- I -1 - 1-- 4 - -1-- 2000 ; - 15.9 ppg LOT 1 D isplace to KCI /Gem 1 1.3 - - - - -- 4__,_ - - -- } -- - -- - I - - -- r - ---4 } -- I - - -1-- -1- 4 4- - -I- P I 1 ■ 7 I I 1 ■ " I 1 1 i I "' i r I 1 1 1 1 1 1 1 1 I 1 1 } -- I - - � - -- - -1- 1 i } — 11 40 I i 1 I i 1 I I i ^ I 1 1 1 1 1 - 1 3000 ■ I I I I I I I I I I ! I i 1 1 I 1 I 1 I - 10.9 \,, W I 1 1 1 I 1 1 - I 1 I S�..v�.+�'' ,- - - - - -, ,-- - - - -, - - r - - - - - - r K - r - - r - - 1 - - - - - t ! I I t 1 I I I °�-' 1 I 1 1 — 10 .7 hJ r Y r -r r r Y r Y r Y r Y _ r __ i __ y _____ r ____ r __ y __ t __ r __ — 4 000 2 Drill 6 -3/4" Hole 1 1 1 1 I 1 I I 1 I 11- i — - r — T r -- - - - 1 -- r - r - -- - Y - -r - - -- - - r - - r - - -- 1 - r i - - t - - - r - -- - - - - E 7 t - - r -- V / a L J L 1 L J L 1 L - �L - -i - - J --- L 1----- J- - - -L -- 10.5 M t { ■ E 1 I I I I I t ; f 1 I I I 1 1 t I - �r w r Y r 1 { __ ____ { __ r ____ Y __. r _ _ Y __.__ r Y _.�__ r Y _ ____ w CI J 1 L J 1 L 1 L J .'-- ___1__L _ -- J__L J _1__I__J_ -- L 1 1 -- __J__1__L -- k 1 1 1 i E I I I f , 1 - i I I - 1 0 . 3 D 5000 p N w N J 1 L J I _L L L 1 1 1 L J _L__ 1 _Li__I_J_____L_ _t _ a Li I 1 I 1 1 I I I 1 I I I 1 1 1 1 I I I 1 I 2 - I 7 r 1 1 - r T r 1 r 7 r - I - - r - -- - - -- f - r - I 1 - - - - r - - - 1 - - 7 - -- ' - - 1-- 7 - - - 1 0.1 1- F J 1 L J J. L _ 1 L J 1 1 L _ _ _ _ J _ _ L _ _ L _ _ _ 1 _ L - _I_ _ J _ _ _ _ _ L _ _ _ _ J _ _ 1 _ _ _ _ J _ _ J. _ _ L 1 I 1 1 1 1 1 1 I 1 I I 1 I 1 I 1 1 I 1 I I 4 r1T r T r 7 1 7 r 7 r r 1 1 r 1 7 l 7 - - x -- W 6 0 00 1 I t I 1 I 1 1 1 I 1 1 1 I 1 I I 1 I 1 — 9.9 2 1 7 r 1 T T r 7 1 1 7 T _ ____ r - r I - r , 7 - 1 L J- A ! 1 L 1 I I 1 1 _ ___ _ 1 __1__I__.a___ __I- ____J__1_ ____1__1__L I 1 1 I 1 1 I 1 I I I I 1 1 I I I i I I I 1 I I I I 1 7 r 1 T -- r 1 1 I I I I 1 I 1 r 7 r 1 - r I 7 1 ■ r — 9.7 7000 TD/attempt t fo to & ` ' I 1 V i r p g I 4 ►_ -- d- -- --1 - -- - - - -�— k — - - - -'a - , 5.5" csg no + — I 1 , 9.5 4 I- 4 4 _ go /plugback &sidetrack 4 1 I 1 _ 9.3 1 I I I 1 1 - 1 1 I I 8000 1 1 1 1 f 1 1 1 1 1 1 I I I 1 1 1 1 1 1 1 1 1 1 i i I I 1 I I I 1 ! r 1 1 I I ■ 1 1 1 ■ 1 i I I I '� 1 1 t r I' r 1 I 1 1 r 1 9 1 I I I 1 ! 1 1 1 1 1 1 i 1 • • , • j _ I 1 ■ ■ ■ 1 1 1 1 I 1 f I I 1 I f ' r r '� 1 - - I - TD /Run 5 -1/2" csg /Cement /run - -I - -t - - -- 1,-- -1- -+ - - ;- 9000 i 1 — 8 9 1 t 1 I I I I I I I I \ /On I I I 1 - t -- r ---- Y - - t - - r t - r - - I - I - -t - - r - I 1 t- - r - - 1 - -- 1 r 1 -- 1 - - t -- - - i - I -- t - - r - - I I L 1 I 1 1 1 J 1 1 1 1 I I I 1 1 1 L 1 1 1 1 1 1 1 0 5 10 15 20 25 30 35 40 Spud Well © 1100 hrs 3/24/00 TIME TO DRILL (DAYS) Release Rig @ 2400 hrs 4/29/00 prepared by WBL 5/701 DRILLING TIME AND MUD WEIGHT CURVE —+ — Depth 16" set@ 107' „ o Mud Weight Rendezvous A L I 1 1 1 1 J L --1 -1, 1 J 1 7 7 7 7 7 11.4 J L L 1 L 1 I I 1 I 1 Dri 9 -7/8” Hole 1 1 1 1 I 1 -- - -"� - -- r 7 I 7 I 7 1 I 7 I 7 1000 L 1 t I I 1 -7 1 1 .2 1 I 7 I 7 1 1 7 I 7 I 7 -J I_ k 4 I- 7 -i 7 I _ 4 I 4 I I I I I I i I 1 I 7 -5/8 set @2661' 1 - - - - -- - - - - I 4 - - 11 2000 FIT \ 159PP9 r -1 - - - 4 i _ N I . , 1----- 4 - - -' -- 4 4 10.8 3000 1 I U I -+ r r -, r - - -1 -1 rt + m- LL 10.6 1 -, r y r r y r -- -r -F ;-- --t r + 4000 10.4 = I - I r 7 r -r -t r i I 7' d J L J r L .1 L 1 1 L 1 1 1 0 W t 1 1 1 1 1 1 1 1 1 1 1 r 7 Drill 6 -3/4" Hole r -r r -r , r w CI 3 L J L 1 L 1 ■ I 1 1 1 I 1 ' ' - 1 0 .2 D 5000 1 I 1 " / W � J L -II L L _1 1 1 1 2 W I i 1 I I 1 i C ' l r 1 r r 7 7 1 7 7 T L L J L L- J 1 1 1 1 1 I - 10 1 1 I I I I 4 1 r r "( 1 7 7 1 7 7 7 W 6000 I 1 ; I Displace to I 1 I 1 • 1E 1 LiA4 r 7 7 1 7 7 I d a I ., , i - 98 4 I 4 4 I 4 r 700 i M I r 1 i I I r 1 8000 I 1 1 I I 1 I I — 9 4 i I ■ I I I = I i • Core 60' /recover 60' 1 I I 1 I i 1 _ I I i I I I i I I - 9.2 r -1 r r - -1 r Y- I + 9000 ; ; ; TD / Run 5 -1/2" csg /Cement r r 7 r r 1 1 -t 1 t 1 L J L L 1 I 1 I- 1 I 1 1 1 -i 1 1 — 0 5 10 15 20 Spud Well @ 0600 hrs 4/13/00 TIME TO DRILL (DAYS) Release Rig @ 1200 hrs 5/4/00 prepared by WBL 5/701 16 "set @117' DRILLING TIME AND MUD WEIGHT CURVE —40—Depth Spark #4 -Mud Weight 0 I I I I II I I I I I I I I I I II I I I I I I II 12.0 _1 1 1 J L J L J 1 _ L 1 L 1 L 1 1 L J 1 __L _J I __L I _ - I I I 1 1 1 1 1 I I 1 I I I I I 1 - I I I 1 1 1 I 1 1 1 1 1 I I 1 1 1 1 I 1 I I I I 1 1 -- Drill 12 -1/4" Hole +- - - 1 J 1 1 1 1 i L 1 1 11 1 L J 1 __L_J- -L_1__ 1 1000 _ _ J I_ 1 _ I_ J L -I L J L _ 1 L 1 L L 1 1 L J 1 _ _ L _ -I _ _ L _ 1 _ _ _ _ 1 _ _ _ _ L _ J 1 1 11 I 1 1 1 1 1 1 1 1 11.6 T " 9-5/8" set @ 1 + + 1 + + F ,- + + r + + r + + + 2663' ■ ■ ■ ■ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1: 1 1 1 1 1 1 1 1 I I I I 1 1 1. 2000 I , I I , I 11.4 4 1 1 1 J L 1 L 1 1 L 1 1 L J 1 _ _ 1 _ J__ L_ 1__ 1 J 1 1 1 1 1 t ■ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 r, I i 1 I i r 1 r I T r r 1 I r 1 1 1 I 1 1 + - + - - - I- + 1 - I - + + + --1- + r 4 1 + + + 1 I I I i, 1 1 1 1 I I , I I 1 1 I 1 1 1 1 1 1 1 11.2 3000 1 1 1 1 I I I I I I II I II I 1 1 1 1 1 11 - _J__1__1__I_ _J J J L 1 1 J L__ I__ 1____ L____ L_ 1____ 1____ L_ J_ _I__1____L_J__L_1____1____L_J__ I 11 I I I I I I II 1 1 1 1 1 1 1 1 1 1 I 11.0 71 I T 1 r 1 T r r T r 1 1 I T r 1 r - 7 T r 1 W N.I I I I 1 1 I 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 ' 4000 1 1 1 1 I I I I 1 I II I 1 1 1 1 1 I 1 10.8 ., «y® __J__I__1__I_ _ J_ I L-1 L J L 1 J L I 1 L L 1 I L4 I I 1 1 4 1 1 1 , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11 II ,rT__1__ 1 r - 1 1 6 7 1 1 T r T E r W Drill 8 1/2" Hole , I — 1 0.6 t7 11 1 1 1 , 1 1 1 1 11 I I 1 1 1 1 1 11 w 5000 MI I L I - I I 1 1 J ____ 1__ 1__ L__ L 1_ ___ 1_LJ____11_J__L_1____1____ 1_ J__ i i o W/� L — 10.4 1 • -r 1 r 1 -r T r ---- r - ---r----r-T----r----r-1---- T ---- r-1--r-T----r----r _1 - Y./ J - L -I L 4- _ L _ _ 1 _ . _ _ _ - _ L _ _ _ _ L _ 4 _ _ _ _ + _ _ _ _ {- _ --1 - - 1- _ 4 _ _ _ _ .4 - - _ _ 4 _ 4 _ _ C 1 1 ■ ■ ■ _ 1 1 1 I I 1 1 1 1 1 1 I I 1 I 1 C I I I 11 1 1 I 1 I 11 1 11 I 1 1 1 1 1 a 1 6000 I I 4 1 I 1 I ■ 1 I 11 I 1 1 1 1 I 10.2 Q J 1 J_ I L L 1 L 1____ L____ _ 1____ 1____ _ J ____1____1_J_L- 11____1_J_ fV I 1 I 1 1 I I 1 1 IL 1 1 IL 1 I I 1 1 1 1 T I 1 1 r V r r 7 7 r - 7 r r 1 7 7 — r 1 r r 1 12 4 1 I J -L L L L L+ L L J 1 1 — Core 93 I I I I 1 1 1 1 1 1 1 1 1 1 1 1 10.0 I 1 1 I 1 1 ■ 1 1 1 1 I 1 1 1 I I I 1 7000 1 1 1 I 1 1 1 1 I 1 1 1 I 1 1 1 1 1 1 --J- - - -1 -- ,. ? L 1 L 1: 1 1 L J 1 --L-J--L-1----1----L-1-- 1 1 1 1 1 1 1 1 I 1 1 1 1 1 'I— 9.8 - 1 T r - 1 1 r T r 77 r r7 J 1 L L 1 L 1 1 L4 1 __L_J__L_1__ 1 J I 1 . I.1 1 I 1 I II 1 1 1 1 1 I 1 1 1 1 1 1 1 I 1 II 1 1 1 1 1 I 8000 I ♦ ♦.' 1 1 1 11 I 1 1 1 1 I I 9.6 I I ._ 1 1 1 ■ 1 L .� 1 L ■ 1 1 L J J. _L_J__L_1__ I 1 I I Run "Csg , 1 1 I 1 , 1 I 1 I - I I 1 I I , 1 1 T 1 r - 1 r 1 r T r r T r r 1 1 1 J L J ' J L 1 1 1 1 I I I I TD, log, P &A 1 T 1 1 I r 1 1 ' - - t 2 2 T r r 1 1 1 I 1 -- r - 1 -- r -- r ---- r ---- r --- 9000 I I 1 , 1 1 1 II I I 1 1 /I I II I 1 1 1 1 1 II I 1 1 1 1 I I I I I I 11 1 1 1 1 1 1 1 1 1 1 1 1 1 I II I I I I I I I I I I I II 1 1 1 1 1 1 1 1 1 1 1 1 1 I il— 92 - 1 T - 1 r 1 r r -- - - T -- 1 r 1 r r r 7 1 r r 1 T r r 7 r r 1 J 1 J L J 1 J L 1 1 L 1J- L L 1 1 1 L J 1 1 1 J L 1 1 L J 1 1 I 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I T 1 r 1 I 1 1 r 1 I 1 T r 1 T 1 r r 1 1 1 1 I r T I r 1 10000 - ' ' , , 9.0 0 5 10 15 20 25 30 35 40 45 Spud Well @ 1730 hrs 3/26/04 TIME TO DRILL (DAYS) Release Rig @ 0300 hrs 4/14/04 DRILLING TIME AND MUD WEIGHT CURVE —*—Depth Spark DD -9 —Mud Weight 16 " set @110' 0 I I I I III I I I I I I , I I I I I! I l I 1 I I I I I I I 1 1 I I I 12.0 J 1 J L 1 I 1 J L 11 J L 1 1 I L L 4 1 1 L J 11 1 J L- 1---- 1-- I- -L_J__ I 1 I I I 1 I I I I I I I 1 1 1 I I 1 I I 1 I I I I I 1 I I 1 I I 1 I 1 II I 1 1 1 1 1 I I 1 1 1 I I 1 1 1 1 1 I I 1 1 I 1 1 1 I I I — --4 — I +-- I ---- —+ - - r -— I } - -4 - - -- -- I + + - � - - - - I - + - - 1 } + - + , - +- I - - } -� — 11.8 __J I 1 I I I 1 , 1 I I , 1 1 I L I I 1 I I I 1 1 I 1 I 1 I I I I 1 I 1 1 ' 1000 Drill 12-1/4" _ 1_ I– _ J I 1 1 J L i 1 L 1 L L-1 1 L J I 1 L J L .1 ____ 1____ 1_ J__ -1 T I t 1 I ■ , I T r T I , ■ i r I I T I I I 1 T r 1 — 11.6 _ ' 9-5/8" set@ ± + ± + + II I 11 III 2000 2712' 11.4 J_ _,_ J. _ I_ is _ J L 1 _ _ is L 1 L L1 1 L J 1 L J 1 1 1 1 1 II T– ` - -` 1 1 11 I I I I I L 1 I i f 1 r T r r T T r 1 T r 1 r 1 T r 1 1 L 1 1 1– 4 1 L 1 1 1 J L J 1 L J . 1 I „ 1 1 1 1 1 1 1 1 11.2 I 1 1 11 1 1 1 1 1 1 1 1 3000 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I 1 1 1 __1__1__1__ J_ _L J____ ____L_JL_ 1 1 L 1 L L 1 1 L J 1 L1 L 1 1 L J -- 11.0 F- 1 r r r r T r r 1 r r 1 T r 1 r 1 r r 1 W 1 1 -- 1- - J- L -1- L 1 L L 1 L L a 1 1-4 I– 1 1 1-1 W 1 1 1 1 1 LL 1 I 1 I 4000 I I 1 ■ I 1 1 II II 1 1 1 1 1 11 10.8 J 1 I I 1 I 1 I L I 1 II 1 L I 1 1 J L 1 I 1 1 I 1 I I t t € , I 1 1 F 1 II 1 1 I 1 I I r I t r r T r r r r T r r T r r T T r Z 1 1 J L 1 1 L 1 1 L J 1 1 J L 4 1 1 J — w ( ; I 1 , 10.6 W " r T r r r I Z� 5000 � Drill 8 3/4 Hole 1 F , i � � � � CI I I I I I 1 1 1 1 I I I — 10.4 0 W 7 t 1 — 1 r 1 r 1 r TI r TI r r t r r 1 t r I r I r r 1 N __ J___ 1____J._J 4 L J L– 1 I L 1 IL L.1 1 L4 1 L J L 1 1 L 1 C r-m Y• I I I I i I 1 I I I I 1 1 I 1 I I I I I C T 1 r F T r r r 1 r r r r T r 1 a 6000 I , . 10.2 I I I I II 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 I I 1 I I I I I I I I I II I I I 1 I I I I 1 II MI – I t – r 1 r – I – – r – – ? r 1 r t _ 1 – _ _ _ _ r 1 _ _ _ _ t _ _ _ _ r _ 1 _ _ _ _ t _ _ _ _ t _ —1 _ _ r _ t — _ _ — t 2 1 1 L J L J L 1 IL 1 1 L L 1 1 L J 1 L J L 1 1 L J I ■ I 1 I I 1 I 1 1 1 1 1 1 1 1 10.0 1 1 T I 7F Core 90' from 8091' to 8181' T1 r 77 r F7 T r 1 r 1 r T1 7000 , I I I I I I , I I 1 I I 1 I I ■ , i , ■ I I I , I ' !: 1 1 1 I 1 I 1 1 , , I ■ f. ■ I I I , I s — —— 1 2 1, 1 1 1 I I I I I I I I � 9.8 , r r r + r t r t— r y —t t y r— t— * y — _1__1__1__1___.1 L _ " 1 L 1 L L 1 1 H J L 1 1 - J - 1 1 I I 1 , , - D r ill 8 - 3/4 Hole to TD 1 1 1 1 1 , 1 1 I 1 , 1 1 1 T – I r � T ' r 7 r r 1 T r 1 r T r 77 8000 ;;;; I 1 1 I I j 1 I I � � � � 1 1 9.6 1 1 1 1 1 11 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 i I 1 r t 1 I 1 1 1 I I 1 L J 1 1 1 J 1 1 1 1 I J 1 1 1 1 1 1 1 I 1 11 1 1 1 1 1 1 1 1 I I I I 1 1 1 1 11 1 1 1 1 1 1— 9.4 1 1 T 1 1 1 1 1 1 r 1 r , T 1 r r T 1 r 1 1 r r 1 r T r 1 9000 I I I I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 DP conveyed & W ireline Logs - -, - r P &A Operations; LD DP; Release Rig - r I I I T r - I 1 - r I I r 1 9.2 I I I I I I I I 1 I I I , I I I I I I 1 1 1 1 1 1 I I I I I I, 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 T 1 r 1 1 r r r r r r r r t r r 1 t t r r 10000 I I I I I I I 9.0 0 5 10 15 20 25 30 35 40 45 Spud Well @ 12:45 on 3/12/08 TIME TO DRILL (DAYS) Release Rig @ 23:59 on 4/2/08 16 "set @115' DRILLING TIME AND MUD WEIGHT CURVE —+—Depth Rendezvous #2 —Mud Weight 0 I I I I I 1 L J L J L J I 1 1 I L 1 i J I I I I I , I r 11.4 - - -- r 1 r r 1 1 1 I 1 I I 7 I 7 Drill 12 -1/4" Hole 1 L L 1 h - i I I 1 J. 1000 , 1 I , I 4 — 11.2 1 r 1 r I - -- I 1 1 7 _a I- -I 1- I---- -4 - - -- I- J 4 4 4 4 1 I 1 I I 1 1 1 F - - 9 -5/8 set @2680' 1 1- - - - a F 4 l- --, I 4 4 i — 11 2000 14.5 ppg FIT ■ I 1 I I I F___ F -___4_ - F___ 4 ____4 4 .} — 10 I , U I I I , 3000 1 1 1 R i I W — --- r - - - -— r - --- - - - - r r - - - — — I — I + -I + - - - --- 10.6 W 1 1 ■ r- 1 r r r t 1 4000 I �}} = I v r - - - - r _, r r r rt r 1 10. d L J L i L 1 1 L 1 1 1 0 I ■ I I 1 I I 1 k LLl 1 I (��) — r - - - - ,- - Drill 8 -1/2 "Hole -- r , r I 7 w V L J J L 1 J 1 I I 1 I I 1 I , I 1 1 s — 10.2 0 . 5000 1 r I t 1 e 4 F W t L J� L J L 1 J I 1 J. _1 LL/ I 1 1 I I I 1 i C 1 r 1 r r 7 r 7 7 I 7 7 7 C 1 J L L J L 1 J I 1 .1 1 iii I I I I I I I I I 1 — 10 1 1 r r — 1 I 1 1 I 7 7 1 W 6000 1 I 1 I 1 MWD Failure I 1 1 � I E I r 1 r 1 1 1 I — 1 1 L _I L - - -- I J J J I _ 1 1 — 9 . 8 go 1 I 1 I , i I 1 I , I I I I I I , 7000 ¢ F - - - - "� ?-- - --- F - - - - 'a 1-- - --� ~ - - -- F 1. - - - - °— 9.6 I I I I I I I h 1 1 F- _ _ _ _ 4 1- _ _ _ _ -I F _ _ _ + 4 I- _ _ _ _ + 4 i I I I I 1 8000 � � � � 1 � � — 9.4 I , , Control LC, Core 60' /recover 57' 1 1 t***--■.,,iv -- ' — 9.2 9000 TD /Run 7 " /Cement/Run GR/JB/USITNSP/Run I - r 7 r - r 1 r 1 Completion /Operational SD I J L J L L 1 1 F I 1 I I i 1 1 — 9 0 5 10 15 20 Spud Well @ 1600 hrs 4/8/01 TIME TO DRILL (DAYS) Release Rig @ 2400 hrs 4/23/01 prepared by WBL 5/701 * • ConocoPhillips (Alaska) Inc. -Expl Western North Slope WNS Non -Pad Grandview 1 Grandview 1 Plan: Grandview 1 (wp01) Standard Proposal Report 17 December, 2008 HALLUBURTON Sperry Drilling Services ORIGINAL Project: Western North Slope REFERENCE INFORMATION SECTION DETAILS Site: WNS Non -Pad Co- ordinate (N /E) Reference: Well Grandview 1, True North Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target Well: Grandview 1 Vertical (TVD) Reference: RKB @ 111.0ft 1 0.0 0.00 0.00 0.0 0.0 0.0 0.00 0.00 0.0 Wellbore: Grandview 1 Section (VS) Reference: Slot - (O.ON, 0.0E) 2 8216.0 0.00 0.00 8216.0 0.0 0.0 0.00 0.00 0.0 Target 1- Alpine C Sand W 01 Measured Depth Reference: RKB @ 111.Oft 3 8700.0 0.00 0.00 8700.0 0.0 0.0 0.00 0.00 0.0 Plan: Grandview 1 p � Calculation Method: Minimum Curvature CASING DETAILS FORMATION TOP DETAILS TVD MD Name Size TVDPath MDPath Formation 219.0 219.0 16" 16 611.0 611.0 Base ice- bearing permafrost 2700.0 2700.0 9 5/8" 9 - 5/8 911.0 911.0 Base Permafrost (32 isotherm) 8700.0 8700.0 7" 7 3331.0 3331.0 Seq -96 3921.0 3921.0 Torok 5736.0 5736.0 Seq -91 6073.0 6073.0 Top Fill 0 = 16" 6461.0 6461.0 Top Block �- 7291.0 7291.0 Top HRZ 7436.0 7436.0 Base HRZ 7561.0 7561.0 LCU 600 = SHL: 1079' FNL, 901.9' FEL, SEC 5, TO9N, RO1E 8216.0 8216.0 Alpine C Sand 8301.0 8301.0 - Base ice - bearing permafrost 8431.0 8431.0 Nuiqsut Marker • 1200- Base Permafrost (32 isotherm) 1800 - 2400 - L9 5/8" 3000 - c G )83600._= Seq -96 a)4200- 1 - a) > - N • 1-5400- Seq -91 6000- _Top Top Fill Top Block 6600 - - - - - -- - - -- -- - Top HRZ 7200- Target 1- Alpine C Sand - _ Base HRZ 7800- - LCU BHL: 8700' MD; 8700' TVD: 1079' FNL, 901.9' FEL, SEC 5, TO9N, RO1E Alpine C Sand - - 8400 UJU: - 1 7 " - - - cor,o ,�iups - Nuiqsut Marker Grandview 1 (wp01) -7200 -6600 -6000 -5400 -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 Vertical Section at 0.00° (1500 ft/in) Project: Western North Slope REFERENCE INFORMATION SECTION DETAILS Site: WNS Non -Pad Co- ordinate (N /E Reference: Well Grandview 1, True North Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target Well: Grandview 1 Vertical (TVD Reference: RKB 111.00ft 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Wellbore: Grandview 1 Section (VS Reference: Slot - (0.00N, 0.00E) 2 8216.00 0.00 0.00 8216.00 0.00 0.00 0.00 0.00 0.00 Target 1- Alpine C Sand w 01 Measured Depth Reference: RKB 111.00ft 3 8700.00 0.00 0.00 8700.00 0.00 0.00 0.00 0.00 0.00 Plan: Grandview 1 p � Calculation Method: Minimum Curvature CASING DETAILS TVD MD Name Size 219.00 219.00 16" 16 2700.00 2700.00 9 5/8" 9 -5/8 8700.00 8700.00 7" 7 187 - • - 95% conf. 150 - CD = DD- Polygon 112 - • _ / `� Geo- Polygon 75- / 37- 16" Lie , 9 5/8" + _ A 7" r 0- Z - 1 - I Grandview 1 1 w • - U) \ V / \ Target 1- Alpine C Sand / 1 / -75- \ / \ / \ / \ / \ / / -112- \\ / \ / \ / - \ / _ \ / • / - \ / -150- \\\ i -187- _ `- _______ ` ConoccPhillips - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 l l 1 1 1 1 1 1 1 1 mr -375 -337 -300 -262 -225 -187 -150 -112 -75 -37 0 37 75 112 150 187 225 262 300 337 375 West /East + (75 ft/in) • • ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well Grandview 1 Company: ConocoPhillips (Alaska) Inc. -Expl TVD Reference: RKB @ 111.0ft . Project: Western North Slope MD Reference: RKB @ 111.0ft Site WNS Non -Pad North Reference: True Well: Grandview 1 Survey Calculation Method: Minimum Curvature Wellbore: Grandview 1 Design: Grandview 1 (wp01) Protect Western North Slope, North Slope Alaska, United States Map System: US estate Plane (lSE7 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site WNS Non -Pad Site Position: Northing: 5,951,400.00ft Latitude: 70° 16' 20.268 N From: Map Easting: 315,900.00ft Longitude: 151° 29' 20.835 W Position Uncertainty: 0.0 ft Slot Radius: 0" Grid Convergence: -1.40 ° Well Grandview 1 Well Position +N/-S 0.0 ft 5.93 ; , , ft . Latitude: 70° 10' 3.348 N +E / -W 0.0 ft Easting: (00 ft Longitude: 151° 55' 28.485 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 0.0ft Wellbore Grandview 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2007 12/17/2008 16.24 79.38 57,202 Design Grandview 1 (wp01) Audit Notes: Version: Phase: PLAN Tie On Depth: 0.0 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 0.0 0.0 0.0 0.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/ -W Rate Rate Rate Tool Face (ft) ( ( (ft) ft (ft) (ft) ( 1100ft) (1100ft) ( °1100ft) ( 0.0 0.00 0.00 0.0 -111.0 0.0 0.0 0.00 0.00 0.00 0.00 8,216.0 0.00 0.00 8,216.0 8,105.0 0.0 0.0 0.00 0.00 0.00 0.00 8,700.0 0.00 0.00 8,700.0 8,589.0 0.0 0.0 0.00 0.00 0.00 0.00 12/17/2008 2:18:49PM Page 2 COMPASS 2003.16 Build 42F i 1t / 1 t ,. 1 i 9 i 5 \i i A L • • ConocoPhillips • HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well Grandview 1 Company: ConocoPhillips (Alaska) Inc. -Expl TVD Reference: RKB @ 111.0ft Project: Western North Slope MD Reference: RKB @ 111.0ft Site: WNS Non -Pad North Reference: True Well: Grandview 1 Survey Calculation Method: Minimum Curvature Wellbore: Grandview 1 Design: Grandview 1 (wp01) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing Easting DLS Vert Section (ft) ( °) ( °) (ft) ft (ft) (ft) (ft) (ft) - 111.00 0.0 0.00 0.00 0.0 -111.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 100.0 0.00 0.00 100.0 -11.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 SHL: 1079' FNL, 901.9' FEL, SEC 5, T09N, R01E 200.0 0.00 0.00 200.0 89.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 219.0 0.00 0.00 219.0 108.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 16" 300.0 0.00 0.00 300.0 189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 400.0 0.00 0.00 400.0 289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 500.0 0.00 0.00 500.0 389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 600.0 0.00 0.00 600.0 489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 611.0 0.00 0.00 611.0 500.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Base ice bearing permafrost 700.0 0.00 0.00 700.0 589.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 800.0 0.00 0.00 800.0 689.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 900.0 0.00 0.00 900.0 789.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 911.0 0.00 0.00 911.0 800.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Base Permafrost (32 isotherm) 1,000.0 0.00 0.00 1,000.0 889.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,100.0 0.00 0.00 1,100.0 989.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,200.0 0.00 0.00 1,200.0 1,089.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,300.0 0.00 0.00 1,300.0 1,189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,400.0 0.00 0.00 1,400.0 1,289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,500.0 0.00 0.00 1,500.0 1,389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,600.0 0.00 0.00 1,600.0 1,489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,700.0 0.00 0.00 1,700.0 1,589.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,800.0 0.00 0.00 1,800.0 1,689.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 1,900.0 0.00 0.00 1,900.0 1,789.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,000.0 0.00 0.00 2,000.0 1,889.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,100.0 0.00 0.00 2,100.0 1,989.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,200.0 0.00 0.00 2,200.0 2,089.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,300.0 0.00 0.00 2,300.0 2,189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,400.0 0.00 0.00 2,400.0 2,289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,500.0 0.00 0.00 2,500.0 2,389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,600.0 0.00 0.00 2,600.0 2,489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,700.0 0.00 0.00 2,700.0 2,589.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 9 5/8" 2,800.0 0.00 0.00 2,800.0 2,689.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 2,900.0 0.00 0.00 2,900.0 2,789.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,000.0 0.00 0.00 3,000.0 2,889.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,100.0 0.00 0.00 3,100.0 2,989.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,200.0 0.00 0.00 3,200.0 3,089.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,300.0 0.00 0.00 3,300.0 3,189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,331.0 0.00 0.00 3,331.0 3,220.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Seq - 96 3,400.0 0.00 0.00 3,400.0 3,289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 12717/2008 2:18:49PM Page 3 COMPASS 2003.16 Build 42F ORIGINAL • 0 ConocoPhillips HALL1BURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well Grandview 1 Company: ConocoPhillips (Alaska) Inc. - Expl TVD Reference: RKB @ 111.0ft Project: Western North Slope MD Reference: RKB @ 111.0ft Site: WNS Non - Pad North Reference: True Well: Grandview 1 Survey Calculation Method: Minimum Curvature Welibore: Grandview 1 Design: Grandview 1 (wp01) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N / -S +E/ -W Northing Easting DLS Vert Section (ft) ( ( °) (f() ft (ft) (ft) (ft) (ft) 3,388.99 3,500.0 0.00 0.00 3,500.0 3,389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,600.0 0.00 0.00 3,600.0 3,489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,700.0 0.00 0.00 3,700.0 3,589.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,800.0 0.00 0.00 3,800.0 3,689.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,900.0 0.00 0.00 3,900.0 3,789.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 3,921.0 0.00 0.00 3,921.0 3,810.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Torok 4,000.0 0.00 0.00 4,000.0 3,889.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,100.0 0.00 0.00 4,100.0 3,989.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,200.0 0.00 0.00 4,200.0 4,089.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,300.0 0.00 0.00 4,300.0 4,189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,400.0 0.00 0.00 4,400.0 4,289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,500.0 0.00 0.00 4,500.0 4,389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,600.0 0.00 0.00 4,600.0 4,489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,700.0 0.00 0.00 4,700.0 4,589.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,800.0 0.00 0.00 4,800.0 4,689.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 4,900.0 0.00 0.00 4,900.0 4,789.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,000.0 0.00 0.00 5,000.0 4,889.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,100.0 0.00 0.00 5,100.0 4,989.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,200.0 0.00 0.00 5,200.0 5,089.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,300.0 0.00 0.00 5,300.0 5,189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,400.0 0.00 0.00 5,400.0 5,289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,500.0 0.00 0.00 5,500.0 5,389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,600.0 0.00 0.00 5,600.0 5,489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,700.0 0.00 0.00 5,700.0 5,589.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,736.0 0.00 0.00 5,736.0 5,625.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Seq - 91 5,800.0 0.00 0.00 5,800.0 5,689.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 5,900.0 0.00 0.00 5,900.0 5,789.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,000.0 0.00 0.00 6,000.0 5,889.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,073.0 0.00 0.00 6,073.0 5,962.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Top Fill 6,100.0 0.00 0.00 6,100.0 5,989.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,200.0 0.00 0.00 6,200.0 6,089.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,300.0 0.00 0.00 6,300.0 6,189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,400.0 0.00 0.00 6,400.0 6,289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,461.0 0.00 0.00 6,461.0 6,350.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Top Block 6,500.0 0.00 0.00 6,500.0 6,389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,600.0 0.00 0.00 6,600.0 6,489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,700.0 0.00 0.00 6,700.0 6,589.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,800.0 0.00 0.00 6,800.0 6,689.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 6,900.0 0.00 0.00 6,900.0 6,789.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,000.0 0.00 0.00 7,000.0 6,889.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,100.0 0.00 0.00 7,100.0 6,989.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 12/17/2008 2 :18:49PM Page 4 COMPASS 2003.16 Build 42F 1 • 0 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Grandview 1 Company: ConocoPhillips (Alaska) Inc. -Expl TVD Reference: RKB @ 111.0ft Project: Western North Slope MD Reference: RKB @ 111.0ft Site: WNS Non -Pad North Reference: True Well: Grandview 1 Survey Calculation Method: Minimum Curvature Wellbore: Grandview 1 Design: Grandview 1 (wp01) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/-W Northing Easting DLS Vert Section (ft) ( °) (°) (ft) ft (ft) (ft) (ft) (ft) 7,088.99 7,200.0 0.00 0.00 7,200.0 7,089.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,291.0 0.00 0.00 7,291.0 7,180.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Top HRZ 7,300.0 0.00 0.00 7,300.0 7,189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,400.0 0.00 0.00 7,400.0 7,289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,436.0 0.00 0.00 7,436.0 7,325.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Base HRZ 7,500.0 0.00 0.00 7,500.0 7,389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,561.0 0.00 0.00 7,561.0 7,450.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 LCU 7,600.0 0.00 0.00 7,600.0 7,489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,700.0 0.00 0.00 7,700.0 7,589.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,800.0 0.00 0.00 7,800.0 7,689.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 7,900.0 0.00 0.00 7,900.0 7,789.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 8,000.0 0.00 0.00 8,000.0 7,889.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 8,100.0 0.00 0.00 8,100.0 7,989.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 8,200.0 0.00 0.00 8,200.0 8,089.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 8,216.0 0.00 0.00 8,216.0 8,105.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Alpine C Sand - Target 1 Alpine C Sand 8,300.0 0.00 0.00 8,300.0 8,189.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 8,301.0 0.00 0.00 8,301.0 8,190.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 UJU 8,400.0 0.00 0.00 8,400.0 8,289.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 8,431.0 0.00 0.00 8,431.0 8,320.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 Nuiqsut Marker 8,500.0 0.00 0.00 8,500.0 8,389.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 8,600.0 0.00 0.00 8,600.0 8,489.0 0.0 0.0 5,914,606.00 260,867.00 0.00 0.00 8,700.0 0.00 0.00 8,700.0 , 8,589.0 0.0 0.0 5,914,606.00 • 260,867.00 • 0.00 0.00 BHL: 8700' MD; 8700' TVD: 1079' FNL, 901.9' FEL, SEC 5, T09N, R01E -7" Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N /-S +E/-W Northing Easting - Shape ( ( (ft) (ft) (ft) (ft) (ft) Target 1- Alpine C Sand 0.00 0.00 8,216.0 -0.2 -0.3 5,914,605.76 260,866.68 - plan hits target - Circle (radius 200.0) 12/17/2008 2:18:49PM Page 5 COMPASS 2003.16 Build 42F INN • • ConocoPhillips HAL HALL1BURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Grandview 1 Company: ConocoPhillips (Alaska) Inc. - Expl TVD Reference: RKB @ 111.0ft Project: Western North Slope MD Reference: RKB @ 111.0ft Site: WNS Non -Pad North Reference: True Well: Grandview 1 Survey Calculation Method: Minimum Curvature Wellbore: Grandview 1 Design: Grandview 1 (wp01) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (1 ( ") 219.0 219.0 16" 16 24 2,700.0 2,700.0 9 5/8" 9 -5/8 12 -1/4 8,700.0 8,700.0 7" 7 8 -1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) ( °) 3,921.0 3,921.0 Torok 0.00 611.0 611.0 Base ice - bearing permafrost 0.00 7,561.0 7,561.0 LCU 0.00 8,216.0 8,216.0 Alpine C Sand 0.00 7,291.0 7,291.0 Top HRZ 0.00 911.0 911.0 Base Permafrost (32 isotherm) 0.00 6,461.0 6,461.0 Top Block 0.00 5,736.0 5,736.0 Seq -91 0.00 3,331.0 3,331.0 Seq -96 0.00 7,436.0 7,436.0 Base HRZ 0.00 8,301.0 8,301.0 UJU 0.00 6,073.0 6,073.0 Top Fill 0.00 8,431.0 8,431.0 Nuiqsut Marker • 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nt-S +El -W (ft) (ft) (ft) (ft) Comment 100.0 100.0 0.0 0.0 SHL: 1079' FNL, 901.9' FEL, SEC 5, T09N, R01E 8,700.0 8,700.0 0.0 0.0 BHL: 8700' MD; 8700' TVD: 1079' FNL, 901.9' FEL, SEC 5, T09N, RO1E 12/17/2008 2 :18:49PM Page 6 COMPASS 2003.16 Build 42F R!G • • Legal Coordinates CPAI Coordinate Cntl'f.,. 01.xi From To Datum: NAD27 .i Region: jalaska Datum: 1NAD27 Region: alaska C Latitude /Longitude 'Decimal Degrees L , C Latitude /Longitude 1Decimal Degrees t UT Zone: i 1 . South t` UTM Zone: True 1 South State Plane Zone: R Units: us ft State Plane Zone: True Units: us-ft C �. .. Legal Description (NAD27 only) Starting Coordinates: — - Legal Description 1260867 Township: 1009 N Range: 1001 1FE Y: 15914606 Meridian: 1 � Section:15 - � FNL 11 FETE 1901. 87397 • i Transform I Quit Help 1 ORIGINA • Subject: Pre -Drill Seismic Fluid and Fracture Pressure Analysis and Shallow Hazards Analysis For The Proposed Grandview and Pioneer Prospects Introduction: The purpose of this project is to provide 3D fluid and fracture pressure interpretation and shallow hazard analysis on a 3D velocity volume containing the Grandview and Pioneer prospects in Alaska. The velocity and seismic volume contained the two prospects, as well as the Rendezvous_A and Rendezvou__2 wells. The Altamura_l well was located just outside of the seismic volume to the south of the study area. Summary: Interpretation of the velocity cube with calibrated velocity /stress functions show very little development of excess fluid pressure near the two prospects within the proposed drilling depths. A small fluid pressure increase was interpreted between 8000 and 10,000 feet near the reservoir depth for the prospects. The interval velocity, fluid pressure gradient and fracture pressure gradient interpretations along line A -A' (Figure 1) are shown on Figures 2 -4. The velocity and reflection character of the seismic data was examined for any indications of shallow gas hazards or hydrate development. Four shallow zones in the vicinity of the Grandview proposed location showed evidence of amplitude anomalies ✓ and Vp/Vs ratio anomalies that could be indicative of the presence of gas in the section. No anomalies were observed at the Pioneer proposed location. The shallow velocity data does indicate a base of permafrost that can be inferred due to a change from high to low velocities that is consistent across the study area. A second zone of very low velocities below the permafrost can also be mapped across the study area and may represent a zone of low velocity and suppressed reflectivity that may indicate the presence of hydrates. Seismic Processing: The initial seismic data that were received from COP included PSTM gathers and stacked data. The PSTM gathers were conditioned using Fusion's proprietary data conditioning work flow. Dense velocity analysis was performed and these velocity picks were used as the input to residual velocity analysis. REVEL was performed on the seismic volume using a spatial smoothing of 33x33 CDP's and a temporal smoothing of 480 milliseconds to stabilize the variations in the velocities without distorting the variations across faults and other primary structures. Due to the fact that the REVEL velocities didn't have the resolution needed to highlight the anomalies in the thin layers observed in the shallow section, Fusion used its proprietary high- resolution inversion procedure to generate a high resolution model rck nnirlio : L • • guided by the REVELTM velocities. The conditioned seismic gathers and velocity cube from REVEL were used in the HazPRO shallow hazards inversion procedure. The first step in the inversion process is to generate an acoustic inversion. The inputs to the inversion are the near -angle stack and the REVEL velocities. The outputs from this inversion include an inverted acoustic impedance volume and an inverted Vp volume. These volumes are then used along with Fusion's proprietary elastic impedance calibration equation for shallow hazards that matches Vp to the Vp/Vs ratio for the background trend. The elastic impedance uses the Fusion equation as the background trend for Vp/Vs and Vs and then uses the far -angle stack to invert for the elastic variations around the background trend. The outputs of the elastic inversion include the inverted Vs, and the Vp/Vs ratio volume. All of the volumes are then loaded to SMT/Kingdom Suite+ for interpretation purposes. Pressure Prediction Procedure Local MDT data and mud weight profiles were used to constrain an interpretation of the fluid pressure profiles in the control wells (Figures 5 -7). The two control wells with MDT data, the Altamura -1 and the Rendezvous_A, have MDT data between 9.2 and 9.6 ppg. Part of the slightly elevated pressure in these wells can be attributed to hydrocarbon / displacement pressure and does not indicate an increased aquifer or shale fluid pressure. The mud weight data indicates that the reservoir intervals 8000 to 8500 feet (Figures 5- 7), were drilled with mud weights between 11 and 11.5 ppg, which are significantly greater than the MDT data and may indicate that the encasing shales have slightly higher fluid pressures than were observed in the MDT tests. Well log density data (Figure 8) were used to generate a locally- calibrated overburden (vertical stress) profile (Figure 9). Vertical stress (OBG) in psi is represented as, (1) OBG = .0005902 *d ^ i.o645 *1000, where d is depth in feet. Effective stress /depth profiles were generated at the control wells by assuming the vertical stress profile (Figure 9) and fluid pressures as indicated by mud weights or pressure measurements. The seismic interval velocity data were used to establish interval velocity /effective stress relationships at the control wells. The velocity data were imported at 100% of their interpreted values, rather than the 90% procedure commonly employed. Comparison of interval velocity profiles with sonic log indicates that the 100% interval velocity data ranged from good agreement with the sonic log (Rendezvous_A and Rendezvous_2, Figures 10 and 11). For both these wells, the two velocity sets are consistent from the surface to about 4000 feet. Between 4000 and 7000 feet the Rendezvous -2 well has an interval velocity minimum that is not observed in the sonic log, while the Rendezvous -A interval velocity is slightly faster than the sonic log in this interval. Between 7000 and +m.,e ID 8000 feet both interval velocity profiles contain velocity reversals that are similar to the sonic log patterns. The interval velocity profile nearest the Altamura -1 well (Figure 12) is very similar to the sonic log from the surface to about 7000 feet. Below that depth the two data sets diverge, with the log -based velocity reversal either greatly suppressed in the interval velocity profile or displaced from 7000 feet (log depth) to nearly 9000 feet in the interval velocity profile. The Altamura -1 well is outside the seismic velocity volume and the nearest velocity profile is on the edge of the velocity volume. These factors may account for the differences in the two profiles. The interval velocities from the nearest locations to the control wells are crossplotted with the effective stress values calculated from the mud weights and MDT data. From the surface to about 6500 feet, a consistent relationship exists between the mud weight - based effective stress and the interval velocity (Figure 13). Below that depth, the velocities are slower than expected based on the shallower data (Figure 10). The log data (Figure 8) shows substantial changes in several parameters near about 7000 feet. The gamma ray shows a spike to higher values; the resistivity drops to lower values; neutron porosity increases dramatically and the sonic log slows significantly. The density log shows a small decline, although the change is less dramatic than for the resistivity, sonic or neutron logs. These log changes indicate that the shale lithology has changes below 6500 feet. A lithology change can result in a change in the compaction model. The shallow compaction model of Figure 13 is offset slightly to the high effective stress side of the data trend. This offset is because use of mud weights to calculate effective stress results in an underestimation of the actual effective stress, unless the fluid pressure and mud weight are exactly in balance. The fluid pressure interpretation based on the shallow calibration is shown in green on Figures 5 -7 for the three control wells. For all three wells, below about 7500 feet, the shallow calibration indicates a fluid pressure substantially greater than the pressure indicated by the mud weight and MDT data (Figures 5 -7). A horizon was defined which allows separation of the time /depth interval interpreted with the shallow compaction model (Figure 10) from the deeper interval. This horizon is shown in cyan on Figures 2 -4. The MDT data from the Rendezvous_A well (Figure 6) provides a reliable pressure calibration point for this deeper interval. Figure 10 shows a second velocity /effective stress calibration based on the Rendezvous_A MDT data. The fluid pressure interpretations for the interval beneath the horizon are also shown on Figures 5 -7. The velocity /effective stress relationships described above were applied across the seismic volume and effective stress was determined as a function of time and depth. The shallow function was applied to all time values above the top Second Compaction surface 0R1rim 1\1 ,0 t. • (blue horizon, Figure 2) and the deeper function was applied to all time values below the top Second Compaction horizon. Fluid pressure was interpreted from the Terzhagi relationship, (2) Overburden = Fluid Pressure + Effective Stress. When the calculated fluid pressure from the interval velocity was less than hydrostatic pressure, the hydrostatic value was substituted for the calculated value. ConocoPhillips- Anchorage provided 3 leak -off test (LOT) data; this data is displayed on Figures 14 and 15. The two shallow values are similar and are interpreted to be tests taken to full leak -off. The deep value is lower in terms of pressure gradient than the shallow tests and is interpreted as a formation integrity test. A Matthews and Kelly stress ratio approach was applied to the shallow data, yielding the stress ratio profile shown in Figure 15. With this model fracture pressure is calculated as (3) Fracture Pressure = Fluid pressure + Stress Ratio *(Overburden Pressure -Fluid Pressure) One of the important features of Matthews and Kelly models is that fracture pressure increases rapidly with increasing fluid pressures. The fracture pressure calculated for this project employs the interpreted fluid pressure from the calibrations and horizon described previously. Pressure Calibration from Offset Control Wells Figures 16 -18 display the interpreted fluid and fracture pressures at the three control wells. Note that there are some minor discontinuities (6500 feet in Figure 16) where the compaction model changes at the interpreted surface. The Altamura -1 and Rendezvous_A interpretations (Figures 16 and 17) are essentially hydrostatic to 6500 feet. The Rendezvous_2 interpretation (Figure 18) shows a small pressure peak at 6000 feet. This pressure high is not present in the other wells and is probably due to a lithology or fluid saturation (gas ?) effect and not a regional pressure increase. Below 6500 feet, each interpretation contains small overpressured intervals. Based on the MDT data, these slightly higher pressure interpretations are probably due to a combination of lithology and fluid saturation effects on the velocity. Seismic Fluid and Fracture Pressure Analysis for Proposed Wells Grandview Figure 19 shows the fluid and fracture pressure interpretation for the Grandview location. The interpretation indicates essentially hydrostatic conditions from surface to 9,000 feet. ✓ � R c.1 !k - \! _,_ • • The small pressure interpretations at 6000 and 9500 feet are probably due to lithology and fluid saturation effects. Pioneer Figure 21 shows the fluid and fracture pressure interpretation for the Pioneer location. The interpretation indicates essentially hydrostatic conditions from surface to 9,000 feet. The small pressure interpretations at 6000 and 9500 feet are probably due to lithology and fluid saturation effects. Seismic Fluid and Fracture Pressure Interpretation for Line A - A' The velocity distribution in Figure 2 shows essentially continuous and uniform velocity increase with time from the surface to about one second. Below that time the velocity distribution is somewhat patchy, with slow velocities associated with the Rendezvous_2 location (between 1.1 and 1.3 seconds) and just west of the Pioneer location (between 1.1 and 1.2 seconds). A regional slow zone is located at about 1.6 seconds. The fluid pressure gradient interpretation, along line A -A' (Figure 3) shows essentially hydrostatic conditions from surface to about 1.75 seconds. Local anomalies occur near the Rendezvous_2 location and west of the Pioneer location. A regional pressure increase is interpreted below 1.8 seconds near the west end of the line. Figure 4 displays the interpreted fracture pressure gradients along line A -A'. The fracture pressure increases continuously with depth. Figure 23 displays the overburden stress gradient along line A -A'. Potential for the Presence of Shallow Gas and Gas Hydrates The shallow hazards inversion process generated three additional attributes for the evaluation of the presence of free gas and hydrate in the zone below the permafrost. These attributes included inverted Vp (Figure 24), inverted Vs (Figure 25) and inverted Vp/Vs ratio (Figure 26). Hazard analysis and interpretation using elastic inversion is a technology that was pioneered by Dr. Alan R. Huffman and Dr. John P. Castagna. The technology was first developed at Conoco in the Seismic Imaging Technology Center under the supervision of Dr. Huffman, Dr. Castagna and Dr. Bill Lamb of the University of Oklahoma were funded by Conoco to assist in the development of the technology. Mr. Carlos Moreno also worked on this technology as part of his thesis work at OU following the filing and publication of Dr. Huffman's patent for the technology which was awarded by the USPTO in 2002. The key to understanding the interpretation of hazards using the inversion method is to recognize which physical properties are affected by the presence of a specific hazard. Ontr " .' • • In the study area, mapping was performed to identify the base of permafrost, which is identified by an inflection from high velocities near the surface to slower velocities in the sediments trapped below the permafrost. In the study area, the high velocities from the permafrost layer are clearly visible in the velocity cube. The base of permafrost is shown as the most shallow red horizon in Figures 24 -26. The base of permafrost map is shown in Figure 27. Below the base of permafrost, there is a second layer characterized by low velocities and high Vp/Vs ratios. The base of this layer was mapped using the Vp/Vs ratio data as shown by the cyan horizon in Figures 24 -26. The map for the base of this zone is shown in Figure 28. This zone is believed to be the interval where conditions are good for the formation of hydrates. The interpretation of this zone is difficult because the offsets available for the inversion process are very limited. However, variations in the Vp/Vs ratio across the study area and also in the coherency of reflectors in the layer may indicate variations in the degree of disseminated hydrates in the sediments. If this interpretation is correct, the areas of slightly higher Vs and lower Vp/Vs ratio may indicate higher concentrations of hydrate. It is unclear how far this interpretation can be pushed, and the well log data in the study area are not sufficient to make a conclusive argument about the presence of hydrate in the zone. The next step in the hazard mapping was to identify and map any reflector packages in the shallow section that show anomalous responses for Vp and Vp/Vs ratio. At Grandview, 4 zones of potential shallow gas were identified, which were labeled Zone 1 through 4. Each zone was mapped and amplitude extractions were made along with extractions for Vp, Vs and Vp/Vs ratio. Each zone will be discussed in sequence. Zone 1 (red horizon) shows a low - impedance signature on the stacked seismic data. The amplitude map for this zone (Figure 29) shows several areas with anomalous negative reflectivity which suggests low impedance rocks. The anomalous zones show a patchy behavior and only one anomaly just to the SW of the Grandview proposed location. The Vp, Vs and Vp/Vs maps (Figures 20 -32) confirm the presence of a mildly anomalous area, but this area does not extend to the proposed location. This anomaly may represent some free gas in the zone. Zone 2 (magenta) shows a low- impedance signature on the stacked seismic data. The amplitude map for this zone (Figure 33) shows several areas with anomalous negative reflectivity which suggests low impedance rocks. The anomalous zones show a strong anomaly to the south of the well and an additional anomaly that is very close to the Grandview proposed location and just SW of the location. The Vp, Vs and Vp/Vs maps (Figures 34 -36) confirm the presence of a significantly anomalous area that is contiguous with the proposed location. This anomaly may represent some free gas in the zone. Zone 3 (blue) shows a low- impedance signature on the stacked seismic data. The amplitude map for this zone (Figure 37) shows several areas with strongly anomalous negative reflectivity which suggests low impedance rocks. The anomalous zones show a • • strong anomaly trending NNE to the west of the well and an additional anomaly that occurs at the Grandview proposed location and extends to the NE of the location. The Vp, Vs and Vp/Vs maps (Figures 38 -40) do not confirm the presence of a significantly anomalous area that is contiguous with the proposed location. This suggests that the amplitude may not be indicative of free gas in the system. Zone 4 (orange) shows a weak low- impedance signature on the stacked seismic data. The amplitude map for this zone (Figure 41) shows some weaky patchy areas with mildly anomalous negative reflectivity. The anomalous zone does not extend to the Grandview location because it intersects the base of the low- velocity layer above it that is interpreted to be the hydrate prone interval. The Vp, Vs and Vp/Vs maps (Figures 42 -44) also show only mild variations that appear to present no significant hazard. - In addition to the 4 zones described above, several other apparent zones were observed on the seismic data, but they were sufficiently incoherent that they were not mapped. The Grandview location Vp, Vs and Vp/Vs sections along the line A -A' are also shown in Figures 45 -47. These sections show the relationship between Zone 4 and the base of the presumed hydrate layer. The Pioneer location was also evaluated for shallow hazards using the same approach from the Grandview location. The sections for Vp (Figure 48), Vs (Figure 49) and Vp/Vs ratio (Figure 50) show no indication of any shallow zones of free gas below the presumed hydrate layer. The variations in the velocity and Vp/Vs in the hydrate layer may suggest some variations in this layer that could be related to variations in hydrate concentration. k • • Conclusions An interval velocity data cube was used for the interpretation of fluid pressure near two prospects in the Rendezvous area including the Grandview and Pioneer locations. A two - layer fluid pressure interpretation was calibrated to MDT, mud weight and interval velocity data from three control wells near the two prospects. The two -layer model was necessary to model the shallow and deep compaction trends in the area. A fracture pressure model, based on the depth and vertical stress, was developed and calibrated. The interpreted fluid pressures near the prospects indicate near hydrostatic conditions. The interval velocity distribution and reflection character along with inversion volumes for Vp, Vs and Vp/Vs were examined for evidence of shallow hazards and/or hydrate development. The base permafrost, base of presumed hydrate and 4 potential shallow gas zones were identified and mapped from the data. pl t�. Figure Captions Figure 1: Base map showing arbitrary line A through the prospects and control wells. Figure 2: Interval velocity section along arbitrary line A showing well ties. The blue horizon at 1.3 to 1.5 seconds TWT is the boundary between the shallow and deep effective stress calibration layers. The shallow horizons include the base of permafrost (red), base of low velocity hydrate layer (cyan), and the 4 zones of potential gas at the Grandview location (orange, red, magenta and blue). Logs shown on the figure include the sonic log (to right of well) and density log (to left of well). Figure 3: Fluid Pressure gradient section datumed to sea level on arbitrary line A through the prospects and control wells. Figure 4: Fracture Pressure gradient section datumed to sea level on arbitrary line A through the prospects and control wells. Figure 5: Calibration at the Altamura_1 well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient and actual pressure data (right panel). Figure 6: Calibration at the Rendezvous_A well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient and actual pressure data (right panel). Figure 7: Calibration at the Rendezvous_2 well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient and actual pressure data (right panel). Figure 8: Well logs from offset wells including the Altamura_1 (blue /red for resistivity), Rendezvous_A (orange) and Rendezvous_2 (purple). Figure 9: Overburden calibration from offset wells including the Altamura_l (blue), Rendezvous_A (orange) and Rendezvous_2 (purple). Left panel shows the density data and right panel shows the integration of the density data to produce the vertical stress function for overburden. Figure 10: Comparison of sonic log (blue) from well Rendezvous_A with the interval velocity profile nearest the surface well location (green). Figure 11: Comparison of sonic log (blue) from well Rendezvous_2 with the interval velocity profile nearest the surface well location (green). Figure 12: Comparison of sonic log (blue) from well Altamura -1 with the interval velocity profile nearest the surface well location (green). • • Figure 13: Effective stress calibration for the control wells using mud weight data (blue) and MDT data (cyan for Altamura and red for Rendezvous_A). The green calibration is for the shallow section, and the red calibration is for the deep section (below the blue horizon in Figure 2). Figure 14: Available FIT and LOT data from the Rendezvous_A (orange), Rendezvous_2 (purple) and Altamura_l (red) wells. The overburden curve is also plotted. Figure 15: Stress ratio calibration for the calculation of fracture gradients using Matthews and Kelly's method. Figure 16: Final prediction at the Altamura_1 well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Figure 17: Final prediction at the Rendezvous_A_A well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Figure 18: Final prediction at the Rendezvou__2 well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Figure 19: Final prediction at the Grandview proposed well location showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Figure 20: Final predictions for pressure (psi) and pressure gradient (ppg) for the Grandview proposed location. Figure 21: Final prediction at the Pioneer proposed well location showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Figure 22: Final predictions for pressure (psi) and pressure gradient (ppg) for the Pioneer proposed location. Figure 23: Overburden Pressure gradient section datumed to sea level on the arbitrary line through the prospects and control wells. Figure 24: Inverted Vp section along the arbitrary line through the prospects and control wells. fT • • Figure 25: Inverted Vs section along the arbitrary line through the prospects and control wells. Figure 26: Inverted Vp/Vs ratio section along the arbitrary line through the prospects and control wells. Figure 27: Time map to base of permafrost with depth contours datumed to sea level. Figure 28: Time map to base of low - velocity zone and potential hydrate layer with depth contours. Figure 29: Amplitude map for Potential Shallow Gas Zone 1 with depth contours. Strong negative amplitudes indicate potential free gas in the system. Figure 30: Inverted Vp for Potential Shallow Gas Zone 1 with depth contours. Figure 31: Inverted Vs for Potential Shallow Gas Zone 1 with depth contours. Figure 32: Inverted Vp/Vs for Potential Shallow Gas Zone 1 with depth contours. Figure 33: Amplitude map for Potential Shallow Gas Zone 2 with depth contours. Strong negative amplitudes indicate potential free gas in the system. Figure 34: Inverted Vp for Potential Shallow Gas Zone 2 with depth contours. Figure 35: Inverted Vs for Potential Shallow Gas Zone 2 with depth contours. Figure 36: Inverted Vp/Vs for Potential Shallow Gas Zone 2 with depth contours. Figure 37: Amplitude map for Potential Shallow Gas Zone 3 with depth contours. Strong negative amplitudes indicate potential free gas in the system. Figure 38: Inverted Vp for Potential Shallow Gas Zone 3 with depth contours. Figure 39: Inverted Vs for Potential Shallow Gas Zone 3 with depth contours. Figure 40: Inverted Vp/Vs for Potential Shallow Gas Zone 3 with depth contours. Figure 41: Amplitude map for Potential Shallow Gas Zone 4 with depth contours. Strong negative amplitudes indicate potential free gas in the system. Figure 42: Inverted Vp for Potential Shallow Gas Zone 4 with depth contours. Figure 43: Inverted Vs for Potential Shallow Gas Zone 4 with depth contours. Figure 44: Inverted Vp/Vs for Potential Shallow Gas Zone 4 with depth contours. • • Figure 45: Inverted Vp on the arbitrary line for all four potential shallow hazard zones at Grandview. Figure 46: Inverted Vs on the arbitrary line for all four potential shallow hazard zones at Grandview. Figure 47: Inverted Vp/Vs ratio on the arbitrary line at Grandview showing the base of permafrost (321 ft. bmsl), base of mapped potential hydrate layer (571 ft bmsl), Potential Gas Zone 1 (702 ft bmsl), Potential Gas Zone 2 (836 ft bmsl), Potential Gas Zone 3 (904 ft bmsl) and Potential Gas Zone 4 (600 ft bmsl). Figure 48: Inverted Vp on the arbitrary line for the shallow section at Pioneer. Figure 49: Inverted Vs on the arbitrary line for the shallow section at Pioneer. 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X 1 0 y r ' 'i Iray 11 , Sri rti e' 'G'rw . lili 1 a 1 Figure 2: Interval velocity section along arbitrary line A showing well ties. The blue horizon at 1.3 to 1.5 seconds TWT is the boundary between the shallow and deep effective stress calibration layers. The shallow horizons include the base of permafrost (red), base of low velocity hydrate layer (cyan), and the 4 zones of potential gas at the Grandview location (orange, red, magenta and blue). Logs shown on the figure include the sonic log (to right of well) and density log (to left of well). Grandview Rendezvous A Rendezvous 2 Pioneer t:' 1 ": :' ♦s a A o 22865 ft r 15922 ft — 0"0 30955 ft 1. 0 1 16.000 : 19859 8398810 880110791107811877118761187511874 E18730.972ot07071 8687 86671864 86271 86071. 959410583857 7 33210 . 048 21 046dB44218422104 02183 82f 836 21834x 826382 cline: 102541 2730283 046t104771046Q0443104290403D392. 0401104211D4 411 04 611 0 854 4 611 04 61t04611. 0461104611D46Q04601046aD46 Q .04321044 11045Q04590463 1047710486.0 202.0 ' 15.360 ..._ ._.. gnu 2721 0.896 ,,,Ln I. • ln8 o3 o368t u. bu,h,,, •,,b udn.l.nh.dnnlunl nr,.....I un Ludu. butli ,,I,, uxlni din J nh n nLinluu L, .I a I. nhnilnuL�nla d, ,I,, IunI., .1, lnnlunr.�i�unI,,, I l .1 ....= 1.,;; un6ndirn L nl.�d n - �� nline 15.Oa0 �. 14.7 60 0.1004 ` 14.440 I 14.120 13.840 0. 11 _ ..... """ter.. 13.520 13200 12.920 12.600 0.300 ' :-- 12.280 kj 11.960 �f a 0 400 f `` _ 11.680 «s ! � L 1 dyw t I 11.360 0 500 r A,,—......-` ` - z "� ', , e �� fiiI` � � r 4 y ' j as. x _ .fax t 10 40 • A 4 -, xY }ter . °»ric'k +rl. y u' s :p' 10.x40 0 60U - ; - -" r ' j� x , t r � ' ' k-- -$a Mc ..f, ` a 4 r 10.120 > 1s 6f r + ,� .•! T 3 ' *Vs ' .. ' .. >. " -$ " Y! - .s're°'s- r.+.,ygaae; ', 9.640 • -.., +` i '�' `Yi, = J u u i' . + , . 0.'"- - 9.520 0 700 x ;w r i �� 4 e ft r *m < ' aw e m,. r� .' . x. gy 9.200 r 1 fi --`• °" `'" 3 '' 8.920 ;3%h ,-> x,.r::,.'..- � ,,,_. °o-e 8.600 n m 5 >awt u� 1 0800 - r t 8.000 ; ., y 4�� 3 . i, .a 0900 p ` , . s `'"° °n °RU 9 .. °" q i "E E y3' "° ros +mss rt t..r " ' ' 1 DOD } 1 7 p f d wl �,r#F w r F r pK fn7 r t till- 4 � {. °" S" sr t "gym # . f a7 , ,w .e! '' 1 `VIt'ge r � .. t � a Lr t '" 3.f 1 C} t { r V 1a '`iF d S s r ' ay' = " N < z ` 2 i' r u, ', ' .,. i.�r ., s 48. 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L . $4 .. , - • ., '. ' 4- ' - --44: - ' ''' --" 41: - = '•47. - ' -- -- -- '''k , f4s , .. 1 / 2 ?',A - 2::;;;• .."' krof . S tkiki, leit- )44 •4)yq• 411- - . et '- e• • — -- • - ..- '- i , ..., : ,#,,,i,,,k i ,i, t 5,•• 1 eval,(4494, Ivory 1.700 . "' 94111 ''''''' 4 " 1 104101 .: :' .".' • - - - - - - - .1,■...,„ ..■.4 ' WI . ' 11 1- ..'' ' 1 t . °01 i ))64 qii...■ .}.L.) $ \l VsNIfill+.,Nr'',::;: i'A ,if, 0 E *,,,,,, -; , , -: . • ,'.-,:!':'..._!...,.. _.. . --,,,....; • -,--,..-4 , d 0 iipa q' iilmii) )1i'.19 .),11114 il' VP 'I i 1 . v 1 ' A ' 4 ' -, :40110 1.800i 1,01 moi 1 1,01, 0 , — J. , j .) , , i , , .1 ill , , .iritotro of, , it 41. ti..44taix 11,t.glitpho 641ft 6 04 .4,41 0*,1;,.4 , ii„Vii„ 0; . • 1 i , , I l l i f Yq l rh iroAfflogi ) litiJ 1 0 1 1 900- 1 01k , ..A Oki i i k 4 0 il ) 1 ., AQ 4)2 VAV ' 1 i 41 I I 110411 1 ' 1 !$1 'Iiiq 4f4"14 fiV i lk 1 10 ' 0 1 1001 Arcl i.:- k geeP . ;,- i* 4 AAe 04 1 . . md . ' ' • " ' -..'' , Nit- ed# 14{0 ,A) 0614 v .4 1 . . + i ' .0- ,(s i 00 leitopii;fip , ( # . , . 11 ..' ; ..1' q.. v 44" ' ' ' '" ' ' . " ' 1 - . . ---:c.- --''''• • ''. - ----:.:: - 1 . ' I - _. __., Y. d !/...,..,.- . . ),+Lkt, ■ 1 • , -2 non' - --- -•- Figure 4: Fracture Pressure gradient section datumed to sea level along arbitrary line A through the prospects and control wells. Velocity (ft /s) Pore Pressure (PPG) 6000 8000 10000 12000 14000 10 12 14 6 18 2 U- rb_line_i 11_ c• _iliLratian_V'int_Revel_SeaLcv ltamura_1_MW Hltamura_1 u c 2000 2000 D 4000 4000 D e , e P P t 41 t h 6000 6000 h Pass_ 2_ Top_Second_G_.,paction_12_31_08 f f t t —.I S 8000 8000 s 'Ca: e e 1 rnura Hltamura_1 e e CD y 10000 � 10000 y -■-' -� e e l 1 Q 12000 - 12000 • 14000 14000 I Figure 5: Calibration at the Altamura_I well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient and actual pressure data (right panel). Velocity (ft /s) Pore Pressure (PPG) 6000 8000 10Q00 12000 14000 41 1 1 16 18 ? I line_rae11_ calibration _'vint_Reve1_SeaLevel none ,er�dezvous_R_MbI REr dezvous_H I G < 2000 S 2000 \ 3 t D 4000 • 4000 D e e P . p t . t h 6000 h 6000 n _Second_Compact f • f t t s 8000 I . E ?endez�,�ousI�_MD i !ez�,;ou 8000 s e '4 e a a 1 1 e e 10000 10000 v e e e 1 1 12000 12000 • 14000 14000 I Figure 6: Calibration at the Rendezvous_A well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient and actual pressure data (right panel). Velocity (ft /s) Pore Pressure (PPG) 6000 8000 10800 12800 14000 10 112 14 16 18 21— ti U Well_ calibration_Vint_Revel_SeaLevel none Rb1L_1 Rende 1Rendezvous_2_MW Rendezvous_2 2000 N 2000 Nil D 4000 4000 D e e il P t t t h 6000 F'ass_2_Top_Second_C action_12_31_0$ 6000 h f 11". f _I t t S 8000 8000 S e e / mm n 1 v • 10000 10000 e cx e e CD 1 1 12000 12000 • 14000 14000 1 _ Figure 7: Calibration at the Rendezvous_2 well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient and actual pressure data (right panel). Gamma Ray Resistivii Porosity 1 Velocity Density 0 0 60 /0 5 I015 ; _ ... 3 .4, 21 5 ....... 101;100 ? 2,4 ,..i_ ti f A 1 taniura_" 1 H 1 :arrilir a_ lr 01 t - aniura_i r u ... ......., ..„- A 1 .5 ..-..t D 2000 _ ---1 - 1 ,— _ ,„,... 2000 D ......‘ ......_!*„. P _ - F:, P t - -n • h 4000 ..... ..... ......". . -% ur , 11 4000 I ,J., ...0.- ..- il u 6000 II, 4 , - - r° - i 6000 u - d A .... 1 74' I i um 4, 7+ _ " A 8000 . w- , 8000 e Jo— e --I 1 1 i i . ---- 1 . • 10000 - - - 10000 Figure 8: Well logs from offset wells including the Altamura 1 (blue/red for resistivity), Rendezvous _ A (orange) and Rendezvous _ 2 (purple). i 1 Density (q / cc) Overburden Stress (]qsi ) 1 0 2 2 2 4 2 6 2 4 6 L Jk lc D e 2001 2000 e a t h h • 4001 4000 t t 1 600 ; 6000 It u u d - 41., d 1 k,- 1 1 8001 8000 1 n 11 t e e ' • 10001 L10000 Figure 9: Overburden calibration from offset wells including the Altamura_1 (blue), Rendezvous_A (orange) and Rendezvous_2 (purple). Left panel shows the density data and right panel shows the integration of the density data to produce the vertical stress function for overburden. Velocity (ft/ s ) 6000 80,00 10900 12000 14000 16000 18000 20(_ 1 -r - endezvou :_Fl IIT_II _LS 2000 2000 e e P P t 4000 4000 t • h h f 6000 6000 f 14 8000 t 8000 N C :,: u u cL 10001 10000 1 1 • n 12000 — 1 000 e e 14000' 14000 Figure 10: Comparison of sonic log (blue) from well Rendezvous_A with the interval velocity profile nearest the surface well location (green). Velocity (ft /s) 6000 8000 10 00 12 00 14000 16000 181,100 2011 �,� 2 I T h� I ,,�M er� I _1II_S I _� III III e 2000 I 2000 p t 4000 4000 t • h ilk h f 6000 —KM 6000 f t t N 8000 8000 N t."D U U 10000 10000 1 1 i i • n 12000 1 000 e e 14000 — 14000 Figure 11: Comparison of sonic log (blue) from well Rendezvous_2 with the interval velocity profile nearest the surface well location (green). velocit (ft/ s ) 6j00 8000 101)00 12000 14000 16000 18000 20IL � 1 tamer . _l TIT_MELIII_S U III 2000 - -- 2000 B e e t 4000 AIL 4000 t f 6000 6000 f It 8000 tiMit 8000 m t u u CD 10000 10000 1 1 i i• • ri 1200 - I F 12000 11 14000 14000 Figure 12: Comparison of sonic log (blue) from well Altamura -1 with the interval velocity profile nearest the surface well location (green). Effective Stress (kpsi) 2 6 8 11 14001 14000 o 12001 - 12000 V , - V • e e 1 1 Data derived from depths o 117MOBS 7d i greater than 6500 feet i t 10001 - 10000 t t - t le/ a , (7) s 8001 — -8000 s • . 6001 — - 6000 Figure 13: Effective stress calibration for the control wells using mud weight data (blue) and MDT data (cyan for Altamura and red for Rendezvous A ). The green calibration is for the shallow section, and the red calibration is for the deep section (below the blue horizon in Figure 2). Pore Pressure (PPG) 1 12 14 7 8 r:111_1 F,er '. ui.a :_Fi ~-- U 2000 2000 B e 40 e P P t 4000 4000 t h h \ \ I • f 6000 6000 f t t —I N 8000 8000 bt = u. U V 1 10000 10000 1 [X 1 1 0 n 12000 12000 ' e e • 1400 – 14000 Figure 14: Available FIT and LOT data from the Rendezvous A (orange), Rendezvous 2 (purple) and Altamura (red) wells. The overburden curve is also plotted. Stress Ratio (k) 0.2 0.4 0 0.8 L u El ooh 2000 II e e P \ P t 4000 \ 4000 t • II X h t f 6000 1 6000 f t 1 t 8000 8000 }1 OC U 1 u o 10000 10000 1 i 1 i i i n 12000 12000 ri • e e i d 14000 — 14000 Figure 15: Stress ratio calibration for the calculation of fracture gradients using Matthews and Kelly's method. Velocity (ft/s) Pore Pressure (PPG) 600 80 0 1000 12400 14400 F 10 14 16 18 2L ti ibration Virit Pe.;e.1 SeiLe 2000 — J 2000 4000 — — 4000 D D • e P P t �" I_ t h 6000 6000 h y:S ? TL =1 0^ I f 1 f t t S 8000 8000 S e e a a s e 1 1 e e ✓ 10000 - —I 10000 v -= . - 1 l 12000 - 12000 • 14000 I 14000 Figure 16: Final prediction at the Altamura_1 well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Velocity (ft /s) Pore Pressure (PPG) 60 r- 00 8000 10400 12400 14000 10 tr .---7----".%.--"A 1 16 8 ? U �i_Uint_ �1_SeaLevel nur-ie I 2000 I - 2000 St, 4000 I 4000 D slit, D e e • P t t t —..�! h 6000 6000 _i`G_L_Top_Secur, om act.ion_1� _U 8 � h f \ f t t S 8000 8000 S t V a .. e a 4.L e e v 10000 - � — 10000 " e e 1111111 1 \ 1 1 12000 - — - 12000 • 14000 - — j 14000 I �. Figure 17: Final prediction at the Rendezvous_A well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Velocity (ft /s) Pore Pressure (PPG) 6000 8000 10900 12900 14000 10 12 14 16 I u 18 2 — - tr i_ calibr .ition_'Jint_kevel_DeaLevel none 2000 — 2000 4000 4000 D D e e -4---11---4.---411–> • t., t 6000 } 6000 +� M U ys�' _ Iup_ 5c�_cr�d_CunFact.iun_12__1_,�� o 1 f f t t S 8000 8000 S e e CD a a _ 1 e 1 :: e e ✓ 10000 -- — 10000 v cD e e 1 1 I 12000 12000 • I 14000 — — I ( 14000 I i Figure 18: Final prediction at the Rendezvous_2 well showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Velocity (ft /s) Pore Pressure (PPG) 6000 8000 10400 12900 14400 10 12 14 1,6 18 2 0 0-10. -line_ 1de11_ ca1ibrat .lon_lrt_Reve1_SeaLeve^ U r . 2000, 2000 4000 4000 D \ D e e . p t h 6000- ass _2_Top_becond_Compac #.ion_L' I - 6000 h f f —...1 t t S 8000 8000 S e e a a 1 -: 1 CD e e 10000 10000 v CC 1 1 12000 12000 • \ ) i 14000 \ a 14000 I i Figure 19: Final prediction at the Grandview proposed well location showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Pressure (psi) Pressue Gracfiert Data (m9) 0 4000 8000 12000 16000 20000 24000 28000 8.00 10.00 12.00 14.00 16.00 18.00 20.00 0 0 2000 2000 4000 — 4000 Q 6000 6000 __.. ____ ___ ____ 8000 8000 • 10000 10000 12000 12000 _— Figure 20: Final predictions for pressure (psi) and pressure gradient (ppg) for the Grandview proposed location. Velocity (ft /s) Pore Pressure (PPG) 6000 8000 10100 12900 14000 10 I 14 16 18 2 _ U r ell _calibration_Vint_Reve1_SeaLt 200D 2000 4000 4000 D D • P P t t \ \ h 6000 6000 h f paction_', I f s t t .......—.0 S 8000., 8000 S ( C - e e a �° l 1 CD ✓ 10000 10000 — v e e 1 1 C) 12000 I — - - 12000 • 14000 — — 14000 Figure 21: Final prediction at the Pioneer proposed well location showing the velocity function and calibration curves (left panel) and predicted pore pressure gradient (red), fracture pressure gradient (brown), and overburden gradient (orange) in the right panel. Pressure (psi) Pressure Gradient Data (ppg) 0 4000 8000 12000 16000 20000 24000 28000 8.00 10.00 12.00 14.00 16.00 18.00 20.00 0 0- H 2000 ? 2000 4000 - -- - 4000 -- 6000 z 6000 O. 8000 - 8000 10000 10000 12000 12000 — Figure 22: Final predictions for pressure (psi) and pressure gradient (ppg) for the Pioneer proposed location. Grandview RendezvousA Rendezvous 2 Pioneer t: 1a f 0 y 22865 ft ► -o r 15922 ft r 0 r 30955 ft 20.000 — o nkne: 1 98590839081908011879118781 07711076110751107408730 .97201870718687186671864 B62RB60A.8594195838573956a8542 105221650x. 841 2183630342.9322 B 26 2 10 2421822218202 19.520 $ ne: 1Q254t027?l 0280030d0328t034903690389040904290448 .046810477104600443042 04030392. 0' 301104211044110451104611046tt04611. 046 0 43210440 4 5304690 47 7 1 0486 19 : P . h, 61,. 1� „.1 N�,.y., .0... d...h.,2uu,n . iihiu�nidu , i 1 �i�, i n�di 1 , 1 Aiinln �Jiin�nnl i�n�n � d�� .,L� nu�di i n ln iilinilnn�,„lu idiinluidiin u,I,u .Iniiliilnii Liulnid idi�n�niduu�ni,lnu�nnlu ul uln nln nlu } . ,.i , '•I � - 1N�tt111r1fif7l If I I �u {(1 {�� @' �� "j��? }� ; �qg . [ ��( p } I 1 14 I I I i n 1 1 6 7 1 660 �j � , b e ' ' �1�� r Z >� t 10d ` 1 "'+' t ' , t ; l o w l � � i t 1 $ 4 { ;ti ryh , t t s 0 20 nf�� k t i n"` r 4, 4, 1 s v 0 ' j140 1∎ J r •k `4 ` i i + �j•�ti k „� [tR . a 6 .e' ,, 15a °�a -• :caa� %R< 0 .e n� � u,, ' � y .. S.-�'.ry ' •ln,M1 0.500= 4b\ ' 4. r 3 , �.” 3.. eu � + . s +�3? l vAab r . .. ^ a',2' 11.660 0.600 .. �" ; e �� - i ' 4 ' ,, s�'t d . -� 4 4.. `a :." I 41, ' r x1 S, id :, 11.180 a � �.� �1 �a. 10. `- - ._: ;! e, . 4 . • ' ; A". <*' � . ,,?-= ,,. � s .r^,., � 4 - ' ...t +; 10.280 • 0.700 .. ,.. , . _ -' ..,¢ , � ,- : ,... s4':at<;' , ', ' 'H,.,>�6' ,• '�...i�.x w.r d- r� c,.•' :. ` , q .. ti �'r, ; »% .",w _ � ' °. • ,,.� 9 380 9.800 a . '�- •,.: J y � K rte, ~ •r � i,. 0.800 17 .. e; 0 *,:- ,b zy, k s. ' v<. • 'r . ,.: < .pg, . r: a a --' 7 s w - " Z ,, r irf J�� • 8.900 • ' "!'a '.j:w.M." J am ' ! .. 1 " r-ra's4,..- .1 n ;.°' aar, -r : 4y;, , l'e' •. ''s. ' , 0 1 4 .1. e - .''' r -- s: f + ss �., ' - a ,::- , - ;,:.:s .a u9'. lit yst &'^°"i r .. i, :'"•3 -33 : ' :^' a" i. J' i'• a- Nn{ ce "^'i� .,s :1, 8.000 0 900' . a n q 4 _ `!d it r N � � 1 ti 6 !�� Ss ,. ' -.. i r-- x... : : AF+f iec q .�F�6 ??Js7�''Zlr'2Ci e �i • 1 OQO 1 . - — Ij '� . � I . �`"t' o.� ,.�er,;y.,- ' �. , -_ Wr. � 7J : � -.. ;� r �5 e ± 1 xN L"�y1. r2��4r€r 1.1 0o- , . ,,., s " • *of 4,' 0,i iir * * 4. "-■=% 44 :1:1410 lei. 0),,•!7 qfpie494.•,i 4,-. e••40),.,- �a , r��i' 1 20o- N I , a � �' � � a i � �v l ! `" mss 4 t '4 4 ; .� y 1i{ ,4 t' 1 1'' 7 2 ' 4., _ -'vs , 0 P4' 'l 'a" rlsai i1';`i fad ' !i1' 5 S •k r t, xi (;, . 1.300 _ y am �� ' ` g y • M^ r Vt 43' s x • - S- •a, I ,' ryy �r r e �. �� / ,a y d I !a >fi . t �c . '� r � � N lr F r ^S'+ , a> . i � x k r .; !N r - - -a � {... L,... 111 I G �i , 1.400 r i ?E. � • r i r Y . ; �v: ,.. '` .. .y "R' r 4i Y � 1 1 .. LV 1 { . To letek.-. itt } 11 L �� W a ] `C 4 ] C) 1.500 1 k , , i , ,i ; 1 N { l 1 .!, r l , .--, lad «a Ss y r - ! 4x 3 � I f4J�4Si , , r 4 „ , . ' t 1 „ 1 C J, I .k 111 I • 1 600 , a 'k ..3 w :5zs::& ,....` i""i air �r s ift i I 'M � , u pA 4 y � .4. 117 , . -. 7 4: 1'. : :,r7 .' s n.. 4' .w s'xa . s q -..-.� • - ysx +4. ' J. gY�i • 1.7011: I, wllla xa+a 1. trMe . .. 1.soo- i+ f f ' ' „ ' � - ;.i. - ' ' f � ' �rfir' ' ' ry M • I I • 1 ” I ! ¢ V trf1•�� C. . 1 900- 1 _ ' i 1 ! if . J 4 . Figure 23: Overburden Pressure gradient section datumed to sea level on the arbitrary line through the prospects and control wells. Grandview Rendezvous Rendezvous Pioneer YW+ a jr I 0 r 22865 ft ► -0 -15922 ft-•0 II 30955 ft - o 14000.000 ! 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' - 1 Z----14.. .. -- - -_ � ao -yr,7---- Pitamura 1 2 q ' / '21 7 5888500 ti 0)" `5O • g f - ^ � , 4:' ... at � ° ._ / 74 1 o ., 5883500- � 0) 43, / kb 5878500- I 1 I I I I I I t i I I 6 � &I 70 I •1100 1398100 1403100 1408100 1413100 1418100 1423100 1428100 1433100 1438100 1443100 1448100 1453100 14o81 146 1 00 1468100 cb v ., Figure 27: Time map to base of permafrost with depth contours datumed to sea level. xN ' 1398100 t ttt , 1403100 1408100 1413100 1418100 1423100 1428100 1433100 1438100 1443100 1448100 1453100 1458100 1463100 1468100 o- Feet , 1,, ,1 ,, ,,1, ,, ,1 „ I.,,,r,,,, ,,,. ,,,.I,,., •,,,i,,,, ,,,, ,,,, ,,,,i.,,,i,.,. ,.., ,,.. ..,, .,,,I,,,,i „ .. .,., ,,,, ,,,. ,,.,I,.„ I,., ,© 0 1"•"x" Q t l 1 z t 5933500 - 9� ,r , ` -..a !ZIA � `�, r V - •• _ gyp, •-_ ,p r >,'ri 11 4 ^ a � 0. 165 7 Q 4 ? i. , 1 , i11 .. -4r 0.169 rt �Q 5928500 -r 7 If ..t1t/7U2? ?2 "'I/t PP JIt 7FiIV54 -`4.V.42..... -`4.V.42..... -`4.V.42..... !� 0.172 - Oq/� .,.:,./ df [ nv pnVi rtl iYr r lSt ^Q 0.175 "i/ { iL It . _jJ f .- " c 1 Ad z-'Pr �i' .11 !,. �1 r t A yr . I 1 . -,.,, c ' 0.178 7 0 1 1SMS ^. t ' 1 I� Jrr 0.181 - t ?l d 1 fl t fl - .E'r. i / -, 7 �'L 1 �J Q ` k7 ,1MY1ltAPIIIPA 1 f r , -,,,I. f J `i Tar l't r.' .. rS 0.184 5923500 7Cti, 07 s % 1 ,r$W, , ,'Yl�i� It 7 f -- Ir ate - .1 sS l d9' 0.187 !f A. "Al: , - "a1�i.Jr 1'. xi =.1 tom-.. .J • • Q rd - rr•• ,--- P iJ� 't d`- + a - ti� i a J 7 r r r \ C .•-., r ^Q a 0.190 7 07_ I G/? ii 1 /fa7'��.r - ':UJY .v - 'Sr 1..: 1, f JS r _ . Z' .N...- , iii - -- Q '40 I r It •• l. °..d' �' t Ur I,, ' -k I • rJ I \\ 1 t \313` •• r 0' 0. - 70 I f ,- / %1J l ; r t l r,. - ` at ti. r a:.. '\t S -ti ^Q � g 0.196 ,•-,.._ . 7 1 III( P, f +. i...- ! [ 1 1 .;I'�ed C I + ^- a' --=.1[ [ 7L C�: E ih. Q �0 :....1 •' 71 I ! fir." ' /' ) 14 1 ` _L)A- + '11,..U7. 7 '! •• r iif c .:•ss 1.`. Z- r . t. IItit 13 ^°j 0. 199 0. 202 5918500 1 \ »iwr� e rr wt i �Ia r i ti _ tl 1 _••, + .'- - 0 205 )1\ ^^ /fe " ,dr It :' \` .' - i r ' t c r yt\; - 1 / "- t " i,)x3c_�waE;. ,,, C.' 0. \`+.. .r'.f,.Jr�►s° �,r1 I , J` -'a,. \ I '.. W c 1 trr�'., s.. '` :�" '.,i rArrvBit#" f r - r 4ti r•ti.. -t L. . `s'. ,',e,111 ,/ :+ J L:.ICiI'F•l '^^ - 0.211 � lti . '•, - '.'emu-'•. I • f ! 1I . 1 , 1,vc' • ,•• 1J 1 7 I 1 �5r.,e1r.A1 'J' +.r 7 f r , > se.. -r 2 •-:Jr ' ' - .,. .� 1,v........ fry P...-;: .1-1 I V -- z. _; �r ^ 0.215 ,.rr �d 1' s1 �l l ti,.l \ N) -Z'•. t \•;a:.1. :6' C."1 0.217 r r I ' 4 . "-') fa.. Q .l- ulea••'� �. \'-- / Jl rul ^ 0.220 t a r i• J 1I f a a1rc. „ 11.0„ , ,S. rSS�.tS�ti '` s,. . \i ' , 1. I - •-' . — 1 ' - f 1 1 11 12? 0 .-.- -,i � 1.: )- -,• CI!tVsfr- -- - ,- .� / = f 711 !!1 . 0.224 - ti r `�.r i �l u'�S�.C'o1. •:\U 2 _N .- I/ \?I -.-il 'f't •• ^ 0.226 - �`. 1.. • ,t f-.."ti nr- -:`i,:..?° I15F; , .� -_.) .7- r '. \(.^ 'mot I f„� \�. ,a AS 't� -- � i a ,, 1'. 1. v�. ..r �., 1 r I I r ; Haiti _ 1t / 1 J r `r � ,, 0.230 5908500• - a Q Sw>a1+'f \;�:.0 I J\ F -: �s.�,ll �..'�1l 1 r Y �J.-- s r -i-,y,:_ r I ' � i�. .‘•-•!)- Q 0.233 .» tr �`A. \t r t t7.1 - - • Ar }y r / C P-- :-' t \- f...r JJ1 rX A - co ,{� 0.235 - 1- ti , Q o ,. .... 'R3 . , 170- 1 _,1,=. 1 ,‘.1,-, 3 `°.- 1 I ..r -”. "A4A A ` \ / T-., , ,' • aI r r t-. + C r t .. (CI eft; . 21.,- t. ^ n ? - �Q 0.239 Z - ± 'ti?1 , . '' . ` , r ... . ! / _ di ' .1r r -: lt r ) � Qi .•^Y' '\,! , if r � 11 1 XI .., -..Jn V' r 151 -117-: LSJ 1. i - ^ A, O - F.1 ' ; t � .ICI i (Mak L- ^ JJ'�1/ ] / . / { 4�' �.. - / /,,,,, // � . / PL.' / , ' 77 1r wwM / ka - ° 0 4�._ r.Q Qi " 1. -2.-' L:. I r_a....._ ' •- wR+mt.. -r.:.� v r` ''c. / f ',P, 7 .J I t ! r ! ! ! !., hl J a if _ � '� Y 7 f ti./ ,_t .. 0.245 ^ ' - -4.....), - Att..... - -4.....), - Att..... m L �*. s i } �/ / / / 1 4F-‘ nl �r r IJ r rye 111 i 5903500 - (Is, iu� ,,, ` fi tsrr r . t n ' > .� ^ ...„.,t..,,,,,,,,,,...1„..,.214(,.. f � / �! r:kiCff,rf /i % ...� "tip �,L r J )1 )*•,' - .....t.) t '11d'•`faS Mr` \V r I _ f !(`-.. + . +1` f S ll� f i b r 'S 7f tE 3 J ']®'.•..5 - \C _ ^ ��'ti ^ F ,�"�R�.•',l r ` ' 7 ' ■ o8 1 f .f1 i..! r r 1f f '- -I 11 .. 311. `` -'._> QJ .S7 r.1384111161,- 7 / ,-, _.., r- .)."). r . ..++ a I1 .n1ir —,- J .. Q ,. ' ,+ ' - ! ~ ` v fr. `1 ! i IItrY�✓ .. �}1 lr;r+tw 5898500 _ - ^ ). $ : I! -' 7 •�I t4 ,t t� • .. t 71 C. 7 04 j ^ rr ` 5893500- - ^ ^� , I � . 70 ,7 Z -- -- , i ----.... _ -, - y( • 5888500_ - 0 ^ ^ ^�� ° r � $ Q r , � - / o • - r ^ ^Q ` t~ � f; 7 0 3 � - ^ / 5883500 0 Q 5878500= 1 i I i I I I i I i I i^ I 7Q ;100 1398100 1403100 1408100 1413100 1418100 1423100 1428100 1433100 1438100 1443100 1448100 1453100 { 1 4 100 146 Figure 28: Time map to base of low- velocity zone and potential hydrate layer with depth contours. x1r 1398100 1403100 l 1408100 1413100 1418100 ® a r> Feet I I I t t . / ./. 11/4 ^ t k 1. 0 7 "t ► _!J 411 7 T .rte �/� 1 i pi - i�AMR Masi ..tw ri a . 1.311 1.039 5923500 'V — .%s��► 0. 767 .f� 0.529 — — r 0.257 - �. -0.016 7- / / _ — � -0.254 qp , — ��r � - -0.526 /..- 0 .79 8 / i F ' t M 1 I e 1 E Tr -1.308 . 44 I!t s, r : + ♦ t za`,+ttttttttttttttra� 1 I . ° I.,r • :' 40 X y i I n• . -1.853 1��1' • _ at . .did •t, N..7 , I I _ i. -2.091 -2.363 5918500- � � -.N. -.N. is t 7p i I 1 • 2.635 0 ' ' rt 1 >; is i ��► 2 r 13 s 3 w -3.418 I I a -. '- r .■4 = ( _3.656 7 I a 1 —,I ► rr'" 3 �� / .....- .. ' �� r 1 r r - Ir. *x r x a - -, ys 4.200 Ai. , . .- .I as ,Lie? ?" �.r'i ,iE ( rran- o. � , t t r - - 4.438 It�,flt 7 441 'f __ .. a 4 4.711 1+ I ` ° Y"• "" Y1 1 "R 1 ' I 4 J9�i — .� 1 'T LT . Vii ',+' . 8 :'4 t► a +�+ I ': - 5.221 5913500- ,.y�- ,� - . :/16.1 I I 1. wit _ �.� q, 1 i w._ I�1 =.�. w . 0 L I t '6 1- : . ` it . _ ,��F.i l� ' .. 4w ;' 1 . 1 1 "� o•-qr. P'!°tl+� i"`1' ? f i ,J1S - a Via A, . s+ I ..t'; tt,C i _ •.2 i�f�Ri,. !'Jt.. �, si !r 1. _ ,.d.�!"_ 7i3lk' °�4..iPY+ 6.1i xi- +L . 7�Yi� ._ tom, ' Jami,Jt r'' i 1 tr " t T' agiMr --_- - C 7=1tv ' PIA ■ r ice w +G'..■_ it 'f f ! . Wi'� - ' 4 1NWAMMG _ "ALA '# VW 1 '—, "war nKT wa mt... ., - T - oar - "kW 7 1 1. t 5 } `�.. Y . Wt. {a„ e A � ■ 1 I C) - I J I ►^ Mi - VC + A1� f"+^+' \ 590850o- 1� I a A'. i sXwr _ e . -�. 7 1 r I 1.SI'..,kt.._i "WAX ' _ 7 Li r, h . -... - � / ` ( 7 JN1` j. `f'• 1� 1 . p 'NIL f J " �� ±f/t'IP'7lE I TF� �.°� v at , 1 �- ' - - -- I 4467W/ .f 1 1■1111,111■IMININIF , jai , . M -- 1 w a t, 5903500- a '''-'4'&1411=117 ' .3) _ � r - l / v Figure 29: Amplitude map for Potential Shallow Gas Zone 1 with depth contours. Strong negative amplitudes indicate potential free gas in the system. WY: 1398100 14031100 1408100 1413100 1418100 (3 F! a Fes I I ) ) I t r ( ' - - F� 7500.000 1 - ° i - 7440.000 - �� 1 -' 1 .IL :�` 7380.000 5923500 T Qt � ::'' i ,- hair 7320.000 7267.500 !11►A+11111l16.■1 i 1 t. ":_ /� 7207 500 A�. ?� 7147.500 T Fes: r F t 1 r' _ r r 7095.000 ` - T /`f — ? 7035.000 65.000 .. . -� , _.....' --°" _ _ -_- ...._ _ r ` . 6 92 2.500 _ _7 i 6862.500 7{n ` , -' " - A _ - , 6802.500 ++�� / - T _ 6690 000 5918500 cz ` , 1 - CI - ._ -- - - ` - ._ - - - -- - - - r - 6630.000 r r h r g 4 l 6570.000 gyp 2+ i i t l i + % - 6517.500 il�w - t t I ■ 6457.500 6397.500 n -� �a = 6345.000 7.0 I t t r I 1 - - t h l 6285.000 2 f • , r I ' r r 1 t f..� ' - �•- 6225.000 `� 1 - ' F i 1 I �' r- A ' 1 1 �a�. I „- ..�,.r, ! s r � - - . I ) a� - 6172.500 - ►��: ! t t Cy 1 6112.500 - ■' a t / ~ xri t *. • 1 1 1 - 5913500 56,.. a1.- 1 1 ) r - 1. r rx ... t - . - 0 - , i 6000.000 , lr� ' / I I S !.).. t. J P S / '` s. - • I i J• °,� u _ is \ 1 I ..' i:� . � s I _ -- + �■ I t t \ ` L 't 7iZ! N / `N •. �e 1 I i 1 r i- ' 5908500 I i i — r Abb.- . / Q - ' - ' / f 1 1 t ri Xh CD - 113 r slnau ,syz w - r L/ i l + 1 l 1 5 l i 1 I % 4 • A t t 1 l ti ` T 5903500- ^) ; / - v' Figure 30: Inverted Vp for Potential Shallow Gas Zone 1 with depth contours. _ _.._. Feet I 1398100 1403100 1408100 1413100 1418100 '1= ® ' _ _ i - ,,,,, n t- ' 1.. aT r ./ /iX mo . o > -� , ' - ' ° jJ" C .f i _ i' - _ � 114.7:r N. t ►rte- -. . 2440.000 di.7 ►'�— 1 . "'•" . �.Ir�:. 2380.000 5923500- 4 3 / \ .I — �.i. 1 / . t l� 2320.000 -- r * 'Ys1/.�� ` - 2267.500 .1 1 1 1 t •. 4f nf�/r/ 2207.500 i . 1 V .� "-rte' IR rte.: #,nI - 1 7, I 1 i , t s - 41 1 rAff'r - 2147.500 � N-ti r ` 1 I '' L -- , t. : oi, 2095.000 "E 2035.000 - r I I .. i t t - - mil. 1 1975.000 - ,e► 1922.500 !�ll� \ ,` -\ i s ~- - ; I il,.r.I► >x ( 1862.500 "' 1 `� \ t. f I ; - _ - T Q :' I i 1 \ 1 1802.500 1742.500 5918500 ��t "-------- n . j' * _ 1690.000 r I *s 1630.000 • _ i j 1570.000 1517.500 �� ?! t l - r r t 11F *�1- t t 1• I I �! 1457.500 l - - .t A -i:` I ,rte. / 1397.500 i , i - r tr. , ; r .0 -, t _ I ._ 1345.000 70,, .4. } t/ 1 ', % _ ,1 j 1285.000 � .. t I 7 I 7 f , __ 1225.000 1172.500 �� / �J i L1 Y s' P �" "C / 1 11 2. 500 - y r 591 s i' . I t 1000.000 5.. Z7. E4�1f. � r 1 v J_' -.r.. , I t f-'"" _ �� J i ' Irlwt „yrN��l I r' r t - t 1 r , - • „.....,,,,. - 1 • I I - j (1) • I -\ - r '" l 1- \ \ 1 1 4 t ,... O ,, 1 1 1 f , A r� -- 1 '�• J s '. 5908500- o ' — 1 J t + _ ,� 1 1 / I mot` t n i ' t 1 ti 4 . ,z... • _ �. 1 \. n 4 1 I \ ' .” '4 N. J ' 1 ate t---' f . N:.., 1 � ” i f t 1 l I �. i \ „ 5903500 ,, -.. ' ",� - ` r i t /I — // I C1 t H 1. i I. Figure 31: Inverted Vs for Potential Shallow Gas Zone 1 with depth contours. Feet 1398100 1403100 1408100 1413100 1418100 Lf N , . i i i j A tl 1. • 70 _ ' . _ '� lJdraiff • 7■5111. _ , 0 . _.. Jf—�� I 1 ge:44 4.500 • i = ,4.,i. J/ 4.380 - i•01■11111VJl■:► 4.260 5923500 Ta i i f i i. 4.140 v . , i�J 4.035 r fir➢∎ 3.915 i 3.795 ■ I i i . '1 I 3 - I � t ,< 3 � .- _ - •' 1 /4"S 11 I 1 r I 3.450 ac i ` r i i r srt / 3.345 7 - . .°f 3.225 rn_ . btt 3.105 CO, `t __ 2.985 • • 5918500 � �! -_ t t 2.880 ° t_ 1.1/47111M! I -�! 2.760 7Q ! L> `�. I '� . 1r. - I I I 1 r t f r ( " -? r✓ - -7 2.640 �p I t f 7 2 535 •+C-'` 1 J � 1 ' t i 7 ` � i 1mi��ar c t y r 4 I 1 1 1 ', t 2.415 �''� "' 1 .. _I ? I I t = ` 'ib 2.295 - t r 1 .r ..--- .,-- -- ' r i I / '-, *. �-�� r _ 2.190 .7.0., t I 1. Jr . as 1 1 1 . r - \. �@� - C r � ', t / 7 " I 1- l 1.950 7 �t , (77 . I 1 . r x f ``` ` , �� . 41710 , '. ar sr r r i s r 1 o., —_ —r I �. c - - .T, I r , I , , t I . 1.845 - : / = yJi - � ?r I / I ' 1 r ty t <.1 'i 1.725 ' I L. 0 '..f � A : I I 1 \ � 1 I I + 1 t6 r ] r t \ 1 1.500 5913500-^ � .,+ ma. . 1 , ) ,r r1 r ►..+ -. 7. 1 I v` a s 1 1 r� z 7 A ..armo r E =a• t s r . I T t , r 7 1 r ti 1 ssi. t • 1 r =110 . I I l 7 +r r 1- -- .x112 r N JI f, t / \ ( -- ��► � • jI &I Y - . ✓ 1 1 A • 1 , " 1 sIfii/ t — I l • ♦ F;a�s r at► '. `. � � ~ l I .-' iii t - �,Mrir IIW . i \ , \ N. 1 ---,. \ 1 \ "4I r I "t. I '.' h �i M I'. NA7� reAO., '. 1 \ 1. 4 1 I `, 1 '^-.... J 40111 IA 'NW . k'• »... %gm. A. 1 7 1 A _ —. �L- n r r - 1 • •••••• ► , .s N 7 5908500- 7 _ � 'ti -, -'. .ate.., t. _ I 1 7 I, Mr C Clint �4 L �L ' w1 : idittt�U U v 7 \. 1 1 ��► _ 1 1 ) • 4 � — -Al alt And.-... ! a.. C�� 1 ti+ ' 1:I :�� .a �►. - K. ter,;; r 4 -- • �n ti r' �'- O �:._ - 1 - 5903500- .° .� .. �� -- Ne !. Figure 32: Inverted Vp /Vs for Potential Shallow Gas Zone 1 with depth contours. : Feet 1393100 1398100 1403100 1408100 1413100 1418100 2. ® '< c 1 1 1 1 I I I 1 _ t 1 1 I t Tp ' �' x r _ ; ' -- -s ""Ai�s•A�f 2.240 5923500 ?3500_ Tp j i j/ 1.960 p �i ti i 1.680 et i 1 t — �' 1.401 1.156 / T •-... •-... 0.876 v XJY - I + ; - ._ 0.596 p3 gp V 1 0.351 I ��- -. 0.071 f - 4 I r i _ 1 1. , = i ( ' -0.208 `" « 1 t '' .. -0.453 .*r - 0.733 2p I m l i _ get I L i f - 1. 013 / ..• t 1 , - 1 J r ■ 5918500-18 500— f I r r r 4��- -1.292 ! r r n s ' -I i 1 .I. -� -1• f 1 1.4,- +'s f I l 1. - -\ ,�,i. / ' 1 ' �. ` 7� / \ r ■iflf T I rL / . r J \ l t v f '� - 817 ( 1 I .4 J ` t / ' 2.097 1 L• r' ate. t � II t r . -- 2.342 .4 t r I , t "-'v` \1 L..- L -2.621 i r- I / - 1 - . 1 ■ ( 2.901 T O € ��s! L I std -3.146 �8 p i t 3.426 7s .. '- -_ I • I -3. t t -` 4 I. I , i t ! -3.951 A..— i r i 4.230 135 1� 5913500- 4 I ..--, ■ r I ► Y t t *A; > 1 - '" R f ► L 1 k 1 1 t +. e x, F 1 1 1 5 t , . a t • r : _+ i .11 - h - 1 .. `,� `` �N \ 1 ,�`.• I .- . .�� / `, - I Y 1 'I 1 L l �\ 1 ' I I / >Fii . iAM 1 I 1 t 1 I % 1 I \ ' - 1'�i �t - " 1-..i..„ �^+q 5908500 - 38500— �- 1 L r 1 y- 1 i s : >:`s�.► ; 7M. D .. �,- I 1 I I I r . t I 4 - r.. I I 4 r I 1 L I i \ �-% ��.� A. t1 1 1 I I I - 3' ". R' . - I r L I , - Q � .` `� ✓ �� Jam►. • �� Y II sew • I ti �l 1 1 e �� .-. , ■ 5903500- 33500— i • ` 4 rd' -_ 1 // - � � s,' / .v I- r Figure 33: Amplitude map for Potential Shallow Gas Zone 2 with depth contours. Strong negative amplitudes indicate potential free gas in the system. Feet 1393100 1398100 1403100 r 1408100 1413100 1418100 0 r } T / 'C.; l a lit Amor - ' 7500.000 5923500 ?3500— Tp i .a ! 7440.000 'w,0� .1. 0 If d 7380.000 . _wow t siw-..i' i - r 7320 000 L"4/ k '4. i 7267.500 I -walw .r te .r " 7207.500 70 3 r\ . r wq Met < 7147.500 4 0 ! 1 •" xr- flMIIIrdp'f .5 T095.000 - I • • -� 1 !! �'f dw I_ 1 t "'W.‘1■115=1 I i 'f'ss .c• 7035 000 i I — ' i *,r , . s far 6975.000 Tp r = r r - 6922 500 `4;�+ t wl.. ice 5' 6862 500 ` l 5918500 r N. I i ' r r f r 6802 500 'It' f Off v 4 271111E. 18500_ , ~� , v i ..'. r t. - ! 6742.500 i i ti t i 6690.000 74 r , r t r f 6630.000 COI , 1 i ` — 1 ' 4" 6570.000 • r r r i >r ; I ( i T r 6517.500 t 6457.500 - ! / ..- , i t � • _ . � 6397.500 T70 : P - I 6345.000 } ✓ Art A;& , � - � -._ �_ „ ,, / � 6285.000 .r .-- r �.f r / . t. > 6225 000 • ! 1 y J_ I 1 ti r r ' - � r r r berr r •� * r -- I - - f+lalJPk u e - 6172.500 r t . 5913500- (! 6112.500 ! 1 « aria►► +� rlrs r,r. a r< — r 4 r I J 1 4 J4rtf i•✓'..f/ f 'i ! r1 a ,mss ' - ; .. t 4 • l 1 0.4.411 TAW I Ti.11. Yf r ft* ASEINEVA, WIN, b '+PC - r > rcr44str.,rrr €ci ra r 1 6000 000 - ARF % i t r w +� , r cfi�ruaSF+)<i�lr,.� ' ■ 1 ^ l • ti.O t / hile+r'd6'3ii'1 . -..:#. - 4 i f to A 1 4 • t 1 aRlrrTll a �dC ` "► . � r r ) r 1 - \ t `.. 4 fu ..-r,' 014-r't.wA 1 . ^1 .+fi r t' : " `• I p+...+ - ,4 / ..�. "t 't 1 ii t ^[ . Y,.+ , . s 3 +.. - ^ 4 - ^ Qj • . .. \ 1 N. 1 t n. �I ,'1F ! w, r. tea► . . t_ r � ___ ...,,.,n `~l `. L. \ } it 1 ..��`. ) .. _ I 5 ' 1 • 4 . 1 -"•+, A. 1 I Yid x' +... I I } I I 1 I .3 .Y'; (fit - a 5908500- ]8500_ , 4 r I I i r . 1 ,- I,. ,� . . - ° .:f. �I 1 I I I • tf I \` • - - - 4 • I N. t I 4 • 1'l • 'V •■raliIIIIMMII■ "s I 1 I I I - 1 "•-s 7� l ft ! \- _ \ ti `A � . '--' cb h s,6 Vr Via. ` ti . � I % r 'f ^ I h � m in - t L I 1 ! ( " _4.,:: 5903500 - ]3500— , . ' ' • i ` 1 r r � ' x s o , - .46... 1 i I JIINIIINIff 4 h ~ �,, 5Cf / - I, i Figure 34: Inverted Vp for Potential Shallow Gas Zone 2 with depth contours. XN. 1393100 1398100 I 1403100 1408100 1413100 1418100 Feet 1 I • a` f 7 � , t . . - 1 y. ' -- ,/ . f / + f _ + - f �a % • �iPAP - 2$00.000 5923500_23500 7 6 "E / 2440.000 O r r .n r,� — . ,fig 2380.000 ` 2320 -000 AP t . ---r lr7r _ + + 2267.500 + .ra .w.. ir 0 w _�ar _ _ + 2207.500 f 70 3y q _ n r i ti 2147.500 - ! ..- . t ! .� _ 2095.000 - +r�r't+naa s R� 203$.000 ^�S Ito 7r ✓ . s 5+ R ! + j I 1975.000 . a.x Y. s + r � 1 70 7. `~ 1922.500 ` tic: r - . 7# ss�rr f s a , s 1862.500 ., , — *",r�Par■t f , . F Zia + ( 1602.500 - 5918500_18500_ a I ss .e: .. r 11 1742.500 f -, f t '.r. s'� ' , ,, � . 1690.000 7 I t tot ', I di...'. r" c dAIEF` 4 "` +t r i 1630.000 - q r I I L ;i ++r~ - J ./FA , r' O u ,F r 1570.000 0 r .L, t > td ,�4' A tr t krr - 1517.500 / .. f 1 V 4., -' - Ir1.�:' - ‘.....r k f I r t r: er rs '--. r - 1457.500 r -. ! i . L. t l9I r, r l.F,fx !tv 1397.500 749 f + er r ' #r� - , O O _f + 1345.000 • r ? r .rtw�wr i ' x,. , ' 1285.000 , - 1225.000 � i. 7 y R' L 1172.500 r 1112.500 • 5913500-135069250.. I 5 :. - "" - Vxf . ef" Ir w` — S. � .+ T 1000.000 AftF — L. Y;a.#:ZWifrox,rr�MS 1�l alt 1 _ 5 _ h f I � .. - . - t\ 1 — ■( }am i i i �.1..�1' w , I t �. .._ r f ' t i d 5908500 . �..i1 } 1 1 1 I . 1 � r �.r f 1 I t - - .t t '- - �•• a. • . •. � min _ is l O . h� 5903500 13500 h to --- cb h r— Figure 35: Inverted Vs for Potential Shallow Gas Zone 2 with depth contours. xn: Feet 1393100 1398100 1403100 1408100 1413100 1418100 % � t:::1 k. I . 5923500 ?3500 T L t`,.� // 4# - 4.500 : �. r - 4.380 4.260 _ 4.140 Y' - - 4.035 T t . / _ 3.915 / t 1 pis / r _ 3.795 / j N` i - t 1 f \ . 3 690 3.570 I N ...! - t,ili l 3.450 r Y �•[ i, t 1 i +- r r � . - Via ■ t 1 3.345 - 7.9. 2 � r s r T / I 14s 3.225 i r YL J r� i^' : i t 3.105 5918500 - 18500 _ 1 , i t 1 I I 2.985 /' ` . 1 \ ' - 1 I r i 1 t i I - ..... - / _ \ 1 I t ! ! / 1 \ �' 2.880 Th r "' ' 7 , , t I i J \ 7 't t fs ��r i I - i 2.760 . r 7 ' ,- r 1 I v.__ - r 1 I ` . I r r 2.640 la 7 i --% ( , i t 2.535 r 11 I. 7 r s r 1 I �a�u r z . ^ 2.415 r i 7 f Itr � t � i t n 2 T O O _ � m i /W ' t - l • ) ----. 4 1 4.. tl. 2.190 Y / . �_ t \ I • r 2.070 1 % ► �► J I - ./ .- 7 cY ' y - f : ' ,- l -,. 1 I 1 1.950 �. r ..-- -- -; . - �_ s I ,, I i 1. 845 1350 ._:.w�...... :A 5913500 '" �'" 1 i i i i 1.725 r< 1 1 r 1 . 4 - t i i I ! J % i \ '� r 1.500 i 1 i i c f r r ) - t,,, t l t l 1 1 J 1 7 I r / . : \ t t \ .,.r.7 \ I / -S L- - h Qi 1 ' z^ y^'R t "lU4t. �. 1 \ `\ 1 1 ii... - \ I - Jam;! ✓£ \ 1 ` �. ' - \ 1 l 1 1 � W 2 .' _ i sr MM. r sa..IIIMIL I 4. . I r 111'1.. 1 _... 5908500 ]8500 h ' — 1 I r t 1 ( i_ I .016.- - t t n X '- , ...itail ;, N `� N._ ,d I .f1� 1 M a4 ,., , a.t I ___l r i _ O 1 N. I 5903500-335 0 0 h� � • . - o I: ,11_■ r - g _� . ivI L. s� .. Figure 36: Inverted Vp /Vs for Potential Shallow Gas Zone 2 with depth contours. Feet 1393100 139100 1403100 1408100 CS E2 1393100 _ �I if - r - t'a k lZ t 5923500 - 23500 - 3.047 � f� j �∎ �� 2.752 axle mri■... i 2.457 I' 7 2.162 1.904 j 1 609 I — - , / _ - 1.314 I ■ 1 -055 t a I O _ D - - e ms .. [ Z aa� �i / 0 .207 0.207 - I w , 1 „ MINIM s �V A�I - 0.088 I I - ,' -WUI ti ' - �r �rl��E - 0.383 - r . — /ES - -0.678 7 f ' i._ ` I — i I a a1a -- � _ i -0.937 - 7,0„ p ! � r I s / r -1.232 - i r - - r _ E! -1.527 �- i _ fad _ I 1.785 5918500 18500— i ti � �� 2.080 - ► l I / r ,' S ;4r -2 . 375 s I / r r \ - aMI■ r / AP''... -2.634 - 7, I I ! r r __ I anGr /! : -- -2.929 ' '',, I I r \ t s. -swrAir -3. i i 1 jr i I e * f f T! 3.482 motimer i _ r 1 - i `-'. I I f 3.777 i ` , t I W - 4.330 I o- . t l I - 1 ti '4 1 1 - 74. 0 t ,, I ' � I . 1 . I - / 1 J 1 G J r - ■ I I , .r-`- f ! 1 L- i I J I �� r _ - . F iri1/I■f i 1 L - l ,. / .-,,..,. 5913500-135002428,i \ ` t r S I , 1 - . l 4\ ., 1 I imr.... . 'aIP : "i �. 1 I f �� z i .., a 1 xAMMJ I A t1 1 tI V 1 1 i 1.B. ►ry , i 0 ti� c ■ J §I ■IIIIIIIMI■Wlia.■111111111111111111M■Fal■W 5908500- ]8500— ” __ v Figure 37: Amplitude map for Potential Shallow Gas Zone 3 with depth contours. Strong negative amplitudes indicate potential free gas in the system. XIY: _ _ Feet 1393100 1398100 1403100 1408100 ja 12 4 I ! • ■ – __ „ t o la a t r ■ / / 7 i i --_ _ /+ , 5923500- 23500 ,?` ,r' �- / 7� _ 7500.000 £0 - - -- / 7440.000 - 7380.000 j 'e.. 7320.000 / 7267.500 - „ 7207500 + 7147.500 7 — ( r 7095.000 r f 4 7035.000 ■ '' 6975.000 6922 500 f f s .. / � ._ _�ii:'i 6862.500 �' • ` �,i�' 6802 500 - 7's ` ` r � ' - 6742 500 - T f ■ 6690.000 _ .+ i 71: a 1 � N9. r I i 6570.000 6630000 • r r - � ,i- ■ �� N., 6517.500 5918500 18500- ■ ` ` - ii ■ ` l b . • - rr 6457.500 ■ ti t r a, irk► r ,1 — c.�.rrr.. 6397 w f' o' •a _Ar 6345.000 ■ if • IV ‘.14. .IM 6285.00 I !. I T 7 I f n r 6225.000 < • i k •, c, t r L.l! 7 6172.500 ■ l i\ .T max' • - r ice' .77 r 6112.500 i ■ 7 6000 000 'i / c}, t 5 f �f^Z _ i . ., moor sw 7 ! / I / r > 1 • J I .r Y"a fr IF 1 t. Q � ■ V l I l + �f , r . f i ' r 5913500-1 35 0 0 ..,:,? f v I x< J + - , J t I ;7 ■ V 1 w '` , J A -A '1 ti 1 .. I F , r� 1 I \ 1 11 t 1 V- / - \ l r ( a L , , I 1 , S ,, • / / /• ' t1 5908500-38500— ' ` cb 1 e ii'f Figure 38: Inverted Vp for Potential Shallow Gas Zone 3 with depth contours. Feet 1393100 1398100 1403100 1408100 F3 „ t„."4. l r 1 5923500- 0 '`w. / 7500.000 / 7440.000 °6 � � J ;r. 7380.000 �- 7320.000 - �. , 7267.500 - 3 7207.500 - -- 1 f 7147.500 7p� .. __ - ( 7095.000 _ ' 7035.000 _ J; t � �r 6975.000 • 1 ! i� ��Jr 6922.500 1 ! �� AAMIIIIIIIIMMIPOPAKAIV 6862.500 ti — � ...-+ �Ii -.. 6802 500 r �� l! r r r �t 6742.500 - 7 4 9 4 ! _� r fi _._ �llr� 6690 000 � " I J!■ 6630.000 • - r !�— 6570.000 • !- N. 'V a _ AP,41/■ _ ' 6517.500 591 8500 - 1 8 5 0 0- .r ` , r _�� 6457.500 !Al' i t r f i r , i r � i 6345.000 7, i r , i i s ue ' # w 6285.000 c I I 1 / 1 F /if. T Ls' .0 . 6225.000 - I c : i .,rte r , r. `�`.. 6172 500 ! t ., I a1 / V MM.. t 7i.- 6112 500 ! i 1 - UAW if ref f • - - ■ I . If I r fir° ,Ir>., 's r ___ '. ! ` s000.aao • / %1 a. ` t 5 .4 ,arm • i or - taffilltr 7 , ! — ) / I I ■ if #e7rlilli! -M l ! ! I • / 1 i- 1 I 11•p ONG ,. f l / J ' i t ' iit' it I 1 # - - - / I I i 1.-.- 1 ,! I !` a 9irow T . - rer - — l / it [jf.,r AU 1 - !. i .' / .:.L J J / fit *MIL 10+0. i' a...- .._. -- l l , .1 af 10.110111111411110106/... I �I 4 / ! T I..a Xi 591 3500 -1 3 5 0 0 V"' ' } s ' r !" / s •, ' ,... w e' t f t ti \ \ , I ' - f ®7�' r I \ 1 1 1. 1 - ` , - - 1 ; 1 1 �1 i i ` i I - A - / ' / • �` • / 5908500- ]8500— '` ■ - t R �.. Figure 39: Inverted Vs for Potential Shallow Gas Zone 3 with depth contours. Feet 1393100 1398100 1403100 1408100 F — ' '' t.v1. k l t T 5923500 23500_ 7c#3, M `` / ,, asoo 4.380 '', 4r' 4. 4.140 260 — — 1 \ -. 4.035 - 3.915 I 3.795 ' ',!'l• ' 3.690 - Q3� I ! 3.570 „N. _,MIIIIMEIF 3.450 — _ . �aM�.r� 3 - — F �s • 3.225 .. - r �l�� 3.105 r „. rj�� 2.985 • f r '' 2.880 :7 ! . .- �rA ■ � 2.760 - . v %PAP' 1 • 2.640 :NM' 5918500_1 8500_ ` - • 2.415 �-� w 1 t I 1_ — — 2.295 1 :' I } .f ■F. dF �.. I • 2.190 / .r ,. �� • 2.070 . D j f ' t 1 .950 ./ - , - r t I 1.845 • r r r f�� 1.725 I I 'o ff , ''''' - �. i �� 1.500 IBUIRMIIIIIIIM . r I r i i t , 1 - ■ - �. < r r a r I ' % � — � i ( . _ 1 . / - t \ -rT -? :t =� r . fir- - ! f ! _ . r-- t 1� 5913500-1 35o:_ N ` i► ; - ' r -a, Air L t .r`• . •\. } 1 } I I. 4 � i - ; � 1 1 - `\ f / ~ \ r 1 5908500 - ] 8500— -, _ Figure 40: Inverted Vp /Vs for Potential Shallow Gas Zone 3 with depth contours. Alt Air Feet 1398100 1403100 1408100 API" 141310 1418100 ® •a -- / 1.706 � 1' _ a ,. 1. 561 �� mow" 1.417 �. — — — 1.272 — — - - -_' _ �.-. 1.145 591: 11 =mow — — — 1 r 1.001 — — i " '�, 0. 856 j 1 0.729 I h' I .t I 1 1 � , 3 R 3 "585 —Ash , r 3 r •, , '� 0.440 � L• 1 I ti r i `: V 0.314 .1 1 ` 1 1 I 1' i t -- - , I t I I ■ I 0.169 0.024 f apt b- t w i,� -0. 120 4 f'1 ♦ — .v s�� r r.- -, . + �, - - 0.247 �l�,I . ¥. ' .c r I. ( 1 - � � ` \ i�iv - 0. 392 �. m r rs ( l l ' :711.1b- �� , O►.� # `t - I t _ - 1 1 \ 0.536 ' .0 - a 1 : ■e��i'riz I I i x -0.663 0 —� ..V +M��' \, 4' .s, i# / 71∎ -0.807 5 913 ll ' r .' r av r .. ,�. +. a•�.� 0.952 1 +.r• r - \ ..rte _ I I I ■ ( . mar -1 079 r t: r I ._., -� t 1 'Ai. i -1.223 '� I -1.368 sue . ; E _1 .495 1 ■ s I t 8 ( -1.639 � ' , . 1 :,, ' `.. - Wr+ V — A3 . l id I F wimiii■sw e. VV. ��,• y; c ` � I 3 J t� t r , . ■ , • J'V ss t+ I r e 1.911 moo f �- r 4 - - -- , i I p.n.s.. '� i - ...... \ 1 ��► / r ]" , I J a r \ r J 41. - I y i \ 1 I 1 3 t f 5 V7 '�! '�✓ I ■ 1 1 '� 3 l + J! , ■ H T 5908500- r .1 1 ,r o+a 4 . I ■ / l 3 l c -' V' M. O ', I ! f 1 4`— dr { \._..._ i i I I mom, - 4, I 1 % l Q J4'I ._ J\ . ("v_ /MIT& \ S r r \ 1 W I 4 ! -NIL 1 I . . \. ... I ■ I 1 .( t , 1 , 1. . ' l 1 I \ r♦' ' - ,�a i i `' 1 ' I i ; ` ` ` asissaw — s. I 1 • ' 1 \ 1 � � 1 wiz if 5903500- ,:b I a7� v / Qi fiiiiiiniiiM ,R + v i t Figure 41: Amplitude map for Potential Shallow Gas Zone 4 with depth contours. Strong negative amplitudes indicate potential free gas in the system. All Feet 1398100 ( 1403100 1408100 1413100 1418100 0 a � ' _J f r - - ..� : .� t:: 1: �t 'r w5411• -� f f �= 7500.000 INIMIPAIMMIIIIMMIIIM �� / % r 1 I. i 7440.000 s f i I I 7380 000 wi■N■asiimirminom1■ 7320 000 �� % \ 1 1 t- 7267.500 N +e 1 1 1 1 ,' --- ; -� 7207.500 591850 E I ' • I. I I / 7147.500 �. I 1 • i 1 i 7095.000 i - I �t I ■ I / 1; / 1 Y ""‘Ml■ 7035 000 i. ' 6975 000 �i � _. , 1 . , 1 i I I i 1 ! I , I ti 1 ' _.. ' 6922 500 -•• r r i s 1 1 _ ._�_ ` +i._ , a„ 6862.500 • Ora r - J i t [ � . 6602.500 r , \\ `: ` '� i t75 6690.000 .r I ♦ .� ` 67$2.500 �e�w. i 1 - \ 6630 000 t., I. t I, .` 1 5 - 11,1111M .fd' f I 1 I ' 6570.000 II) - r ar: r i I s I 6517 500 �r�.�: rr I r 1 I f > � l / 1111111111 6457.500 �� M'� 1 f } L. _ t 1 55 l l 1 A�r ;.r �y� I r - �' l a Y E r f 6397.500 5 913501 �r��i� r r i 1 r t N,„1 �� ' te r I / .wue i I I \ t goo 6345 000 f r 1 � J - - Y 3 1 I I I ♦ • ! 1 I I f� f.. F ,. 1 t I \ 7pi.. 6285.000 ---... v. r r I �� i f 1 . � S. t \ 6225 000 ♦ 1 J l ii u 1 1 t r ` ♦ 6172.500 _r ♦ i l orarinsit G 1 1 ti.- - � ' ! 6112.500 aCk • 1 ` } I + \ 1 � r , I �` t r 1 ` ♦ 1 u r 1 6000.000 I I I IV f Y \ 1 1 �- - / \ ~� L ` l Z l 1 '7INIMIr r — l 1 / I / u...�. s 1 ' f 1 I I I 1 ( \ 1 \ I \ r 1 , i t / o '- ' 4 ,._ \ I r Y i -. l I ~ 5, L .1 1 l . 5908500 ^a � 1 1 ` \ ■ 1 1 1 - t r . 1 r . 1 4, i I 1 r l I 1 1 • L \ � � 1 I 5 - 1 1 \ • ..-.- `, 1 7 a..:. y r . "• 1 t J I 1 N. 1 t I 1 /. - cb \ ," \ f 1 r ,`a l} I , "� ] i ■ r.- ! `h- \ t - l 1 f - ^p •' ... i I , `1 t ` �.. p -411.6. ti - - - -.- \ 1 . fQ I I 1 , I • . i I l I a•- I 5903500- � ( `.: I . 1 —� r l 11 ` r - ri . _ -. Figure 42: Inverted Vp for Potential Shallow Gas Zone 4 with depth contours. F et 1398100 I 1403100 1408100 1413100 1418100 [ g � ' K t. 1 „.I I I ' -- r 1 •. �" - j " / w; ._ ! r t. ~'- 2500.000 -` - F ! 2440 000 ` ' "` ;, i 4 :_ �" 2380.000 v � � r !.. .�.. , 2320.000 — 2267.500 �11 ., ! 591' 3 t °axe 5R _ 2207.500 2147.500 ��. 1 i _ t i — _� _ % d. 2095.000 t f 1 r 7 r ! 6 2035.000 1 ', t 1 ', -- ,J 1975.000 i I 11 I 1 J ' 1922.500 `� 1 1 1 1 1 r ` I ' _ 1 862.500 ,r ,I I 1\ ' I. , . 1802.500 t 1 t ♦, — ; .. 1742.500 I r t 1 V .. -. r /. I t t _-- 1 1630.000 #1 l 1 I ' \ 1 1570.000 �r�- �v i 5 t t l 1517.500 l i t V 591 .. 1 t -+r ____ _ f I i r <. 1 1397.500 . J t 5 1457.500 - ∎ I I r / 1 -. Y 3 1 f I I t � _ 1345.000 t I ll� .� _.� t J 1285.000 ' 1 1 - - / 1225.000 i I 1 �� " t ti r 1172.500 t N I t _ f r 1112.500 l i t i= , i 1 I 1000.D00 / �;i ! / 1 1 I r I 1 l 1 'tea' I r — l ,. ! 1 ; \ � 1 5 ! ■ '� I S - 4 r 1 1. r 1 r I rs r r 1 4 I ,� r "' • t r s V I I I 1 � t I t I 5908500- h i I f i r' - N. N. i t om, I --14"..... I t 1 r I 1 1 1 4 - �, , - I t ! t �-. N. mil.! ! t J I I \ 1 '1. I 1 ""h4.. / 1 J �. t \ . %..! .- \ 1 1 I t ( +W \. i t I ,- - _ 1 ` } 1 t l 1 ! ,� "'No, 4 l - , I I �! `i 1 I 5 I I 7�. N I 71L 1 1 1 1 t .— h X16_ \ t �. t. t .1 41111.11=1.11101■11111W 5903500 h^ ! I S t -� ' 1 h i .. , - J , V _ Figure 43: Inverted Vs for Potential Shallow Gas Zone 4 with depth contours. nor: 1398100 1403100 I 1408100 1413100 1418100 0 ® (;=1 Feet * s t_ k -; 1 I -�' / =111 = :_ 1 f ° 4.500 t 1 4.380 - I t i i f - � `� 4 _ f 1 4.140 5918500- / ,. . - i i 3.915 � `' . -. . . ., ir .. I / - ,. _ 3.795 ` ;' e/ �. 3.690 �. ..` rj I I 4 i ` 3. 70 - . ° . 3.450 mss -.,d , - if i i I 3345 • - I t r i 3.225 _ s 1 / ' sde, i t . I 2.985 3.105 F i - 2.880 wP = - 4 ; T ., - 2.760 e/ - �— 2.640 .......... _ `, 5 ,., �, 5 t 1 .1 1 2.415 2.295 2.535 • 591 . n .rro� — 5 1 f ! \ 4 \_J 1.950 1.845 t' 1.725 . t 1.500 r if • — — - — / I _ — _ v . / tw , , I l J� 'W.* 1 ,e ,' t —. I 1 Mt - t� �r t t 5908500- . _ I �. ' "i — — ^p _ 8 5903500 �... ` — !, _ / 4 1 1'' �I , . r� / I v; Figure 44: Inverted Vp /Vs for Potential Shallow Gas Zone 4 with depth contours. ' Grandview AendezvousA Rendezvous t: ' 1 I 01 22865 ft ►O 11 15922 ft r 0 8000.000 1 nline: 19856.0 19836.0 19816.0 19801. 19791.0 19781.0 19771.0 19761.0 19751.0 19740.0 19730.0 19720.0 19707.0 19687.0 19667.0 19647.0 19627.0 19607.0 19594.0 195830 19573.0 195620 19542.0 195220 j 7860.000 online 10254 0 10289.0 10308. 10328.0 10348010368010388.0104080 10428.0 10448 10468.0 10477 10460 10443. 10426 0 010392.0 10401.0 10421. 10441. 1 0461. 0 10461. 10461.0 7760.000 7640.000 7535.000 7415.000 7295.000 7190.000 ' I I I I �, I . � .I. f -` '�� I I I 707000 111 I I I 6950.000 +� I 1 ' 6845.000 rr V ``V ` , 6725.00 r - I f J I f 1/ I I ` l 1 1 I I iiii.c,,:ci.o. - 4 l i � , � 1 , ` �; , I + I I � 11 ,ti L !1 .ti , ,,,r + ,1 I ; r + l . ii I IJl 1� �, I �� ,� .t � ,� l , �� { I I , ti I i 0.10o- l 1 It r M f I I 4, I' , ■ t 1�1� , 1 i� sass 000 il I ' i - d i i f I I 5915.000 j I 5795.000 5 I r 1 � I li I I; i /( 1 I f it I s69o.o00 • : lt1 i 1 i tjy j 5450 000 i !! �I` .. 5225.000 1 ` 1 ' 5000.000 t I t ',,., ( I Ii Imo II K {lt((q ! li �, 1 0. 200- , I� { � t E�. i 1 l 1 I 1 �� }cl.• . ►►,tea. '''11 4 .t, f Potential Gas 4 !) i +I F! .a riyuraEe ea. 91)&5 * 1. I : 0 ,friq -1 . t • 1 ? 1�' � ) 1 . Potential Gas � II ,, ,. 1 1,... iii ,ii I., i ., il a30)- 1 ki Potent Gas 3 f li. p otent i al Gas 2 1 1 - 'H 1 i i H , . (, 1 1 1 1 . 4 0 i / . : 1( ,1 N i i dt '4 4 ;1M , 111111i/41 1 0 w - 1/( iliff0,- ,:. ' 4 till 6„4 �� ., ti i 4 1 ) 1 i . i . i . i 1.0. <4. 1--.... < lei fe ,--# : ' 4A \‘' ' C i )1 i ' . ') `:‘ ' ' 1) i' ' 1 (1 i 1 i le.(40.4 1 ' 4 " 4:4 A (14 k (' 40 ) 1 ' Figure 45: Inverted Vp on the arbitrary line for all 4 potential shallow hazard zones at Grandview. Grandview _. _. Rendezvous ----- R - endezvous 2 t 0 4 la 0 - y 22865 ft ■ -O 15922 ft r 0 40 Inline: 19856.0 19836.0 19816.0 19801.0 19791.0 19781.0 19771 19761.0 19751.0 19740.0 19730.0 19720.0 19707.0 19687.0 19667.0 19647.0 19627.0 19607.0 19594.0 19583.0 19573.0 195620 19542.0 19522.0 3880. rossline: 10254.0 10272.0 10289.0 10308.0 10328.0 1 0348.0 10368. 10388.0 10408.0 10428.0 10448.0 10468.0 10477, 0 10460.0 10443.0 10426.0 10409.0 10392.0 10401.0 10421 10461.0 10461.0 10461.0 3760000 . Ulf- -i � 3640.000 A ! 3535.000 3415.000 3295.000 3190.000 1 ) J J • `f 3070.000 ` I I , , 2950.000 2845.000 2725.000 i I I i �` l i 2 05. 000 1 � 1 23680 h �1 l li 1 , z2 so. 0 00 i I ii 1 � ,1 21 010o- t ' . 1 � �I I �� Y ) . , ... , ., 20 i _ 157 I t 1 I. � I l' ` I H' 1450.000 � �i ' k .I 1 S III ( I i) 1345.000 l� y r y 1225.000 t al �t� �} � - � i 1' f �I� ' �� I �� 1 � l �11!::1 (� � ( i 1000.000 1 _ t ,V II tl {�� t IStillr �. � f a � �... ti f ) HI 7 , a2lja- .`f ',' 1 i \ ; 1 I i, ct Pi. N f • t� :, fir 1. , 1 � " IC;"" ; II le e Zone ir , 1 . P otential Gas 4 f :,' � �;, Ill ) 1 ' . )) i,;„.. ti, 1 , il l i i / ( ( . , V r , 1 -,- I . ; fitii _ {) ) l. . Po te n tial Gas 1 • I, li • c � �, 1. N. - I 1 1 . 4 i l } , 1. li 0.300- � Potential Gas 3 ` ) .� � 1 ,, I 11 i k . i'.. i . ii . !I . i . ' l ' ' fl A , I :: ', 0. . i 141 ' itiiiii j i )'..11 ) ) I 1 11 ') . j '',' 0 -' g J i • - 1 f r ). i ,...„ , . • 1 ,,) 4i f f r ii i 4, ' , / 1 . ' 1 i 0 �1- ti 1 .. r . ) - 1 ( t e ).i i' '. 11) )• )) 4 . . i 1 ' , 1 i ,,,„„ , ,. i v . . . Figure 46: Inverted Vs on the arbitrary line for all 4 potential shallow hazard zones at Grandview. Grandview Rendezvous Rendezvous 1 NO li lT 0 * 22865 ft r -0 * 15922 ft IN a Wine: 19856.0 19836.0 19816.0 19801.0 19791. 19781.0 19771.0 19761.0 19751.0 19740.0 19730.0 19720.0 19707.0 19687 0 19667 0 19647.0 19627.0 19607.0 19594.0 19583.0 19573.0 19562.0 19542.0 19522.0 1 4 4.380 500 ossline: 10254.0 10 10289 1038. 00 1032 1 10 038.0 400 1428.0 448 1468.0 10477 1460 10443.0 10 1040.0 10392.0 401 1042 104 1461 1046 4. Ini�li� lin iIi ! ! u �ilin ri i li 0 I�in l! * +L il ir� ili Ji !, 10 iL inli !I• ul� ilia rli� 0 J� �I� it !!I,,i ilia ,ri r, iiI • it !I ! !I� ,r J 441 . 0 ig Ji ,$ i �I , �r!$ . ! !I j 260 OAUt;= 0 0 10 10 1061 1.0 .140 - .n 4.035 3.915 3.795 - LI''l 3.690 3.570 _ ( , I I � I 3.450 3.345 ` r I I j 1 1 3.1 OS 5 �r I� , . � ��j ,� `` ++ � , , �M!!; ' [ � � 2.96 • „ ( 4 I i t t� E t�t r I i!; I 2760 0.100 1. r 1 (f 7 t li ,) ; �J',jI ; 2.6 { r e `I I `. I 2. i1 2.070 yy .950 , i 1 li { + ? 1 1 .725 : Ik ) y+`` 7 1 } 11 I 4 . .00 I . - - r ' r 11111 K{ r 1 i V I M i,ktPit;/)') � tik�!l111(hUlirin�1r<I II�„u, n �� ,�� ,. � . r i 1 P Gas a� y. .. I, A ' 4, : ow.. l ' �� 1 • Potential Gas � 1 + , ti,1 Ii _ 4 lie i i I ii ic \,'_ , ' • i 1 ; ) ' ' 1 NMI f' i 1 iN - '', i,' "II.j f 1 ' P' Fl 0.30o- Potential Gas 3 ' . �' . doll 10 . R t / A 1 ., ,,,,, r j i 0 _ It i 1 141;4;./. 9 .42 . ' .., ‘ . j 1/4 cS . i i ! : '''.. 1 Jii di '1, ; ,0 i;.- ri l i a 1/44 . . ,i' i i ri t 1* , rr Figure 47: Inverted Vp /Vs ratio on the arbitrary line at Grandview showing the base of permafrost (321 ft. bmsl), base of mapped potential hydrate layer (571 ft bmsl), Potential Gas Zone 1 (702 ft bmsl), Potential Gas Zone 2 (836 ft bmsl), Potential Gas Zone 3 (904 ft bmsl) and Potential Gas Zone 4 (600 ft bmsl). 1`= 8000.000 0 Inline 1 2.0 19442.0 19422.0 19402.0 19382.0 19362.0 19342.0 Pioneer 19322.0 19302.0 19282.0 19262.0 19242.0 19222.0 19202.0 19184.0 7880.000 I rossbne. 10 1.0 10460.0 10460.0 10460.0 10460.0 10460.0 10445.0 10432.0 10441.0 10450.0 10459.0 10468.0 10477.0 10486.0 10494.0 7760.000 u:uuu „ „ „ i , ta " 7640.000 A 7535.000 7295.000 l 90.000 � 000 I + 707 000 6845.000 f 6725.000 6605.000 6485.000 I i 6380 000 �mafrOSt ss 0.100 67144105.0000w 0 60 sss 35.000 -� � j l � � � � I 57 56 71 000 5570.000 5450.000 5345.000 5225.000 5000.000 0.200- � Ill _ _ Base Hydrate Zone 1 1 t i ,0 CD - ll Illi Il II I f .1i i 0 CD 1 0.300- , i iiil 41(4 1 11 1 4 ,,, f IA o ( 1 i i( , l /di , ./10f ( (i 1 it i 4 0 / • 7 < 1 / 4 4 1) ‘4) d 1 iitil i. 0 *( A ‘ , - f - /' 00 ( d 1 i 4 ) . )c0 44 1 ) i 4 . S (t14 1 Figure 48: Inverted Vp on the arbitrary line for the shallow section at Pioneer. Pioneer t' r[) 1= ` 0 .. 4000.000 Wine: 19462.0 19442.0 19422.0 19402.0 19382.0 19362.0 19342.0 19322.0 19302.0 19282.0 19262.0 19242.0 19222.0 19202.0 19184.0 3880.000 rossline: 10461.0 10460.0 10460.0 10460.0 10460.0 10460.0 10445.0 10432.0 10441.0 10450.0 10459.0 10468.0 10477.0 10486.0 10494.0 3760.000 I 3640.000 " 3535.000 3415.000 3295.000 r 3190.000 3070.000 1 . { ( 4 ( i i i 2950.000 ! 2845.000 ` I 2725.000 R I 2605.000 I 2485.000 h III ( I 2380.000 rr y r I 2260.000 2140.000 0.100- ff � I !. L 2035.000 M { I j f ) ► U + 1915.000 0 ) 4 1 1 { 1 Base Permafrost 1795.000 � �� +lljj� l 1 l � t I. 1690.000 f l ` t 4 � t (� 1 1 r S 1570.000 I t 1 J � 1450.000 • t l i� Iii r l y ti , , f 4 1 i ) l + 1 ! 1345.00 �f 1f l �r I 1n5.0 � ' � 1 �/ C, I f l � , ) f 1000.000 ) my:: ; i i t r '' `` �� t , � rf y J I 1 I c jJ I l+ 0.200- t 1 j i t (i.\.,) I {` f f h I I)/ -s 1, , I IM` t l / ) ! 1 i � I � 1 ti ' I L I 1 `` 4 1 Base Hydrate Zone 1 1)i , / („,,) ( d . A ( \ Y ) ' , ! (,,, 0 0.300 - f 1J]l! 41 1 v,/ ; jl! . 110 , 1 If ( ` T .r t k • ( ,,,ic ,4...41 A t� {► <. _ ' 1 r / k 1 111 1 ( A/ I 1 Figure 49: Inverted Vs on the arbitrary line for the shallow section at Pioneer. Pioneer l 0 40 I Inline: 19462. 19442.0 19422.0 19402.0 19382.0 19362 19342.0 193 19 302.0 19282.0 19262.0 19242.0 19222.0 19202.0 19184.0 tom' = ' 4.38.500 rossline. 10461. 10460.0 10460.0 10460.0 10460.0 10460.0 10445.0 10432.0 10441.0 10450.0 10459 10468.0 10477.0 10486.0 10494.0 4260 _J 4.140 ., 4 .035 3.915 3.795 3.690 {r i I 3.570 � ( ( 1 I 3.345 3.225 3.105 2.985 � { . � , 2.880 0.100 I 11r t I r I 2 1 1 I � I` r I I 1 2.535 II I ! 2.415 r ! ` r ! ' 2 1so 11 11 ai -� <f 1 • _ 22.070 � ; 1111. sso ' I 845 i s t 725 ii 1 500 11 ill 0.200 I ..... i I a cn I-ydrite Zone 4 ili I )i , CD 1 0 4 i t c.'1 _I 11. e .4 i 1 )11 / e 1 \S ( i 1$ 1 "°-- 0 ' 14 til 4 PI i‘ i( 4 , )1 i ......_. . -_-' 44. 1 ,,.,,,,,, <1 „il I k . 0 11 0A ( (iA:i4 ' t4 44 ! 1 j) 1' /' 4i,,i d 4 0 <5<-- , , e .1 / ..' Figure 50: Inverted Vp /Vs ratio on the arbitrary line at Pioneer showing the base of permafrost (432 ft. bmsl) and the base of mapped potential hydrate layer (760 ft bmsl). t 1. 7, PI038 NOTES C...- .941 ..... 11.,._,:, , ,. o , ,),,./,,,,, _ .01.,_.,.,.. 1 L,ilw,., ,., __iF,‘ne...4.e. ..,_,,.ThizIr,.,..,:,E:::::.,.„pv,i:.,,..:„,.,i,.::.,.l,af.a A N ,.,,:,,,..,.,..._:_T.,,., ,..„_..,._...,._,:\,..;..,,..i,,.,,,,÷,,.,,,,, 4b,<,,,, \ . ,..N.,,,,,,,, .. ., 7:,,,RIT)C Tim, C141.t!, ' .' ,." :: POINT NORTHING FASTING LATITUDE LONGITUDE POINT NORTHING EASTING LAITUDE LONGITUDE -I 090 l - 00dV -30 :O - tOZ :ON 0111MYRO N oor ens :ON eor • • . t, • , I • \i \ n , a . Iv ,, '''--.-./ (,/ '44 - , = „,,, ., , .,,,,, v , . 174312 ■..„.: „kei IP'. 11 .,..:,..,_,,?...,, 1 3. A E .... ,. , a., 4•.. -7.• 0 , " -,,. --,._. 1. ,,,,,,,,li 1 , x ,,.,.3.,,,, BEA.F0.7 ?* -'::.,,, - . .. .„ '4" i,. •.19 S EA Tg , .,,,,\ ,-0 ,,,;t,,:, , ,. _ _ HARRISON .....-.F"-" ..:..,:,.."*. ..-... ,„,,.. -. '.------.\---""-- , Yi. ',.., , •,. '.'•:•,' ilkirlier 7 itik ,• c \i' f ‘,..,._,, I ng' t k' BAY j '",",, 1 . ,, 1 . 1 . ,,A * . MCA . ' . ,, L.% , . „ I__ . pine T,. l _ . , . ,.. , A _ n f 4 /91 ., ji) ,-, ,, 1,.;, . _ - 1 _ • . 1 . , . ,1) \ - -,,r" , , 1 ,..,...- . g.tal 4 . t '/ 1 , „., i IL tik a . : - .,. ‘ i' . ; . 4 NPR-1 5.948,146 1,517,487 70'16 15759'38.7W PI -G26 5,903,392 1.465G46 7708"31.6 151'24"34.7V ■ :' ''' 47 } /".'. I ,,,,-,, '' - . . yAll rs,„,. , ( NPR-1A 5,947,962 1.516,931 7716 I 505954.8W PI -G25 5,904,045 1,464,097 7708"37.8 151'25 /- , .. d , fik V -,,, V 117:-'..gz : •/: : ,§ ' '-' '' • p. '\ \ NPR-2A 5,947,869 1,515.785 70'1568.9N 151'00'28.1W PI-G24 5,903,627 1.462,410 7708 151 - NPR-3A 5.946,639 1.515,167 7715 1510045.5W PI-G23 5,900832 1,459,329 7038 1512718.3W -" • . "I f ri , , ' ,,, ., ') ! %'',\ • .,,- ; ''. vmpi Ari A1 . ... "' / 73/4k- „ ' '*.' . C k : ? ' , '; 4, 9 i ll'i''- -''' \ \'' ' ' ' 7 ' ' ' ' -: :• NPR-4A 5,947,079 1.513,755 7715 1510126.8W ' PI-G22 5,901,023 1,457,726 7708"06.61 " 15128.04.8"W °:/XP ; . ... . NPR-5 5,946,884 1,512,065 70 151'02"15.9W PI -G21 5.901.902 1.455,883 770814.8N 151'28°58.7"W ,4 '' 4; ; • 0% _ NPR -6 5,946,357 1511375 7715 n 151 PI -G20 5,902,984 1,454460 7708 151'29*40.6W ,ir7 -■,\ *Ulf /' ...." , ; ... .. I , 9 NPR-7 5,945,330 1.508,474 701 5'32.7“1 151'03"59.6 PI - as ..2.1 G19A 5,905,363 1.449.616 770847.3N 151'32%12.4W , . ', As , :Ss ' ' ' • r • 4•44 4 44 . 1 NPR-8 5,944,455 1.507,328 701 5"23.9"N 151'04 PI -G19 5,905.637 1,448,798 7708"49.8"N 151'32 , l',... , ' '''..,. .4, ' ,,,S ••••..... / 3 4 . 4 ,..,, ,,.• • " 4 \•1 . t NPR-9 5,944,001 1,505,432 701 5"19.1''N 151'05'27.4 PI -G18 5,907,206 1,447,089 70'09"04.8"N 151'33 6 ' ' --- , ''',. \ ' NPR-10 5,942,887 I .502,345 7015' 151'06 PI-017 5,90G164 1,442.545 7708''53.4"N 151'35 4,.. - , r ..,,_, a _ 111 I , , , , - ' -01 a , 4 NOT TO SCALE "'" ; .. L A S i< A „ 4 NPR-11 5,942.808 1,501,144 771506.6N 151-07 PI -G16 5,905,587 1,437,805 7708 15117.44.3W . k 17:i:::;: , _, " O ..:.: ) '.:••••'''''' 4 1 '' \ VICINITY MAP NPR-12 5,943,133 1,500G46 7015 151'0803.6"W PI-015 5.905.1358 1,432,338 7708 48.0'N 151'40'22.7V c 4 1 ' z I I Ce,•• '';",-• 11:,... 'r. ••,., '''''- '••• j z...,..2.4„,..,iiiin. ,.--,...• NPR-13 5,943,438 1,495,221 7715 n "N 151'10 PI-014 5.904.709 1,428,658 r08 151'42'08.2V /•-,) ... '. - -I ''': ,- it:::::::::::::::::::.::::. - . NPR -14 5,942,621 1492,805 7015 151'1133.9W P1 013 5,904,962 1,425,802 7708 151'43 .-...', . - , ---" • * " I ' '• ' . % c` tz,''' .4igaingg:: . .: g z ..,.x:;.(e .. 1 , :.mogew 1 :::i;:.• ,. ' „. P1-041 5,941,418 1,488,328 7714'50 N 5 151'13 P1 012 5,907.792 1,422.848 7709%14.1 ' N 151.44.58.8V a a .,, ' '\ '‘i 44' L T'7 ' AllriNk ' •••• " --4 4 ' : 1 ;i:i ' :g: 1 E:!:;:li: g - : -- ' -- ficl.;' .,'"-- , ...' ... ' ...'.'' PI-040 5.938,523 1,488.700 7714'22.1N 151'13 - 3G9Yi * PI-GI I 5,908,889 1,421 -W , 7 ,853 7709 151' 45'28.5 ''.''' '.. agir k. ..: ' ' ..) n'OP ' *•' 4,316 i ' " '" • . :'. PI -039 5,933,374 1,49G896 771 3 151'12 PI-G I 0 5,910G21 1,421,053 7709 151'45 , _,.. ,..- - ' -- T'I FP' ' 4.9 P1 038 5,932,293 1490,558 7713'21.2"N 151'12 Fl 09 5, 910,856 1,419 S72 7009 33 A'N 151'4624.6"W .., PI-037 5,928,546 1,491,334 7712 151'120E1.6W El 08 5,911,386 1,417,842 7709 W "38G 151*47 ''' i .7"W ,'''' 1 .: ' r i -' Air - ,e.gc, I ' `,.. 7 ' . PI-536 5,927,685 1,491,162 7512 - 36G "N 151'12 PI-07 5,911,405 1,413,434 7009 151'49-34.31X • . -. b. N , '-t--.. ,,,,i• - "I: ,.,- X PI-535 5,921,230 1,493,645 701 1 151•10"57. eV PI-06 5,914,552 1,409,944 771006.8 ''" ' N 151'51 "18.1"W ; 1 .'` C:'...'''''', ' , 1 ... 4 f.1 .::::::::t.. y .....„.. .:;**A,.. ' ... 46 . ,..:--- . 0: PI-534 5,915,475 1,491,559 7010 "36.0W 151'11"54.6W PI -G5 5,914.692 1,409,023 7710%17.9N 151'51 ,, 1V - 77 ,, „.r. , ., 1 „..... PI - G33 5,910643 149G121 700948.2W 151'12 PI 5.915.462 1,408,435 7710"15.3N 151'52'02.6 / 19 1,,,,,,,,• ( , '-'• z 'ii . ....,, -,-.------------ ...4 - ' LCMF P1 532 5,909,859 1,49G181 7709"40.5'N 151'12'31.3W El 03 5,917,526 1,407,822 7710'35.4W 151'52 ; 1 ■ I) ''- m PI -G31 5,907,191 1,487.326 770913.714 151 P1 02 5,919,820 1,407 Ni ,313 7710'57.8"N 151'52'39.0 ` - " ., • , . P1-530 5,907,559 1,484 1 ,701 7709 151'15'08.61V PI-01 5,920.997 1,407,401 701 1 151'52 "W 37.5 P1 529 5,905,015 1,481,397 7708 151'16 PI -SOS 5,914,932 1,406,823 70.1009.6N 151.52'48.8W ....c.. 1 .. All / '' ilk N : 11 : 15, I. 410 p---) PI-G25 5,90Z 924 1.469.979 77013 W 28.1 151'2211.7W El 055 5.914.792 1,402,502 70 151.5453.8W . 1 „, „ '''' , _ _ i -. . _ P1-027 5,902,978 1,466.686 70 151'23'47.7W PI -G5C 5,914,223 1,401,193 771700.9N 151.55'31.2W I. •"' I 1 . ' " ' r''''': :PTII '7 "A' '..... , PIONEER2 5902628 1,467,730 770824.7 151.23-16.ov * . e - . ,------,--- ,. . , „,?, A __, : PIONEER I 5,903478 1,455,098 70 I 5129"22.5-W 4'. ,, " \.. ' ,. ; GV1EW2 5,921,278 I ,407G84 70'1112.1N 15152"46.9 .... 14) ' r..,.?il I , tiv4 _,. ?, i. - , II I .,' k GVIEW1 5,913,726 I ,399,415 7009'55.5N 1515622.219 y ' .. c I ...* Mee ) - 0 5280 GV1ALT141 5,914,349 1,400,903 7710 2.01 151.5539.7 ' 7.70 - 1 "'" . ., ..■_. ;;;;:;; 1 . ' GV1ALTALL 5,914,461 1,401,025 701703.2"N 151.5536 ''.:: "P .3'W SCALE IN FEET . ' • ' 7 1:111111 'wW.,.., \. I "P ' , ::.. „..7 „ , , . • 1 k16532 ) , 44144.4. -.. . a ,,,, ., * 7: .._................. .................. ....... ....,...,.......,..:„.„........... ...........,........_•.,- i . 4 . -....• H (/ 1 ".. 4 \ / 7 ' . ....„....„.„....„ ••••••••••••• - ..1 _ •.::. .11 , 6,............. ............ r e: ' ' • , l662■ ...........7.............. . ........,•............_.....,...... . .............. - ...: . I ...,:::::::::::*:::::::::::::::. L ' :;;;,. ,4. ',,, *,,, Ft ' . ,..„ LEGEND Is , ,) ; ••-• I - 1:::::::::::::::::::!::::::::1::::::: ...... ,41 .. i - . .... • • 1 ' ,,, i 'Nr .--.1 ' NPR -1 PROPOSED ICE ROAD PI ,,,, • . ' ' L71 7." 1 91 ...s. _ ,„./.. ' \ /,. '' -., ' fke ,., Pr '' - . . Ie ,. i L ,i :; Pi --,,,, lirt--- t s ...--, , :::::::::::::::::::m:::::: .. ........ 208 29 PLORATION ,,L,) I -,. ' '1 /I ) , t .., ' .. ' ' . 1 MX ,, , ., e '1 1 ICE ROAD PROPOSED E X 1 , , '' j •,.., ''''r! ' ' 1 . • .*:. • 4 PY -. I tiiFj' .- - ..,- ! 1 i 111X ik'''' 0661.1.2 , , 626 ":41!i`i, - = n. • •' / , • ' " : 1 1:1:].. - .:::;:'::::::• •• . :.: • i lip„.&„,, .41' ' ss A2 . f9 . 2008- 2009 EXPLORATION WELLS i - . . ... .„..„... . •...• . -- - L • • s J I / •i•iliiiiiiilion 0 PERMITTED WATER SOURCE LAKE 0 I ., - '. 1 ‘I, • i y ' woes .. , 1- v „ ::;:::,;•:.:-::: L : *) w -... - , - v • ..........6 74.- PRO ion , , lk :,,,, ,,,,, ,:',, EXPIRED ,7,71,TvTAE„D77'.7spouu.Rrz. s 4 yir / ,, t NPR12 ilPi '.L,,... , , N - Y''''' "1, - ( 0 "-- I . - ' ' . : I', - . i ',/' r ..:.,• I - 1::::1:::. ',L 4 ' AO - ! . , .-.. .:::.:-:.,.-:•••-,... , 'i.'. Jr.r.-.r. o ..:.}■:.. ' .., . . ,ALPINE C A ) I R L BLE 70 WATER PI LAKE E A C..---. . ::?,:. - • - . . Ns , ... . ,`. At - . m ..,:. i L -: - .: ; . ____ . , . ,, ''''..,*.,:.:•• " k ., '',... ',, .. .... . .... •• • •• ....„- \ Illi:W ,., •,-,,, ,I,.. c ,e 1. ' c -• • • - , - .. . ...... •-• .•-•-.. , , , • .:::::::::• .-, .,. 1111 39 . •' ,(waill 4 , i • ' / , ,--- ,1 - 1 v , _ ' \...,.. ' •4 ( e 1 . 4 ' - ..... •'••• ' '' 4 .. , 14,--' ' 4 W i 'q i ''' '• , -- : i •',_ + " 1: •••'• 1 ('' 1. ALL COORDINATES ARE ASPC ZONE 4, NAD 83 la . 1 ... . . . . . ,,, . ,,, 1 II \ NAD 83. ,.. ',. ' < )., 1. , .. t .e. .,./ t ...„ , i ie . :>. IIIMitl. 111 'ii;:i::::' ,-‘ , 6 „., ,' E , . 0 - t. . ■ " ' , : : " ‘-- 2. HYDROLOGY WAS DEVELOPED FROM U.S.G.S. OLD "1 r4 r, FORMAT FILES (1: 5 2 OR SERIES). , " ,,,1 ..- , /41 , 1 l , 0 , f ,- • ,, ). 1 .. / 0„ K f C : ■ ' :<, -.' .. - - I' E s 7 . . . . ' g " \lir: - - -;\ tir T 77 GEODETIC VALUES ARE " , " " lit • • • '. •,,, Y ' ..:*: 1, i '''',. ' . ' .. T r “ OR . Npyi ,- - .= , ...., $$: ; :i ,„ds h , , - .k• r i . - , - „.::::„..::::::: , ,. „ , - - - -G3 61 44 l'' , OOP . • li , i'' ' ~ -- ... , .. * KUUKPIK s „/ PI :,,, ., - -- . , ' .. ' - -.. 1 ' 1, . . • `,.. . , , , Af , LCIIIIF. 4 G . NDVIE 1,, Pi ' 3 \ 4'44 ',-, ( ,, 44‘k m . . -\... " : ), 1 . . . 1 * . A q . {? ... •••• '-'."" A'7 77, , . 07-d: \ r : '...., '•,, • :‘... ‘..., 15 \ A AIpI , . .... !.......:....!.:..'..!::::... FPI-G ' ..,:('''''' . .. , ' .-: PP'-' A T 14 :' R0,6,„„„.::::: .. ,,... ..., ,,,,,„ z , t, .: A., • .. , G -....5r ...,,,,,, ........ , • V D ----- ' ' i ;.:::::::,.::: ... . 4, 1 = .,' 1 ' „,„„,„,„,, j ' , .., , 2 - ._ I -G8R49 a I, , e ° , 2, . ; .- a L...S , 11 ,1 - 4 r : : I .. ,-, „ •-• , 4 , CenocePhillips .... PI-G If .. 0 a„ Alaska, Inc. . ...., Pl- • B : :•'•• . . • • • .•1 . 1 ,' 1 ' , , ,' ; / • 41 , ' k., t ;:%:;:;::: ..::::::',:'•:;;.. &. s ' . 4 t 3/4r I .. , = .,„, - ...' .■'... 0 F..„ .. „ r..361. f,. , 1-G12 PM" 'Iiii..gii: -, ., , ........ ,, • lir. ALPINE MODULE APO° UNIT: AP . .... 1. g "".." • • ...,, T . .'‘,,, •: C. RO , 1 7 ‘01.. 4( pr ,.. - , PROPOSED 2008-2009 / j n, IIICAIIIIIIM , ~, __ ::::.-::.:::::::: . 6 r ". .G ,, ) , 4r :4.rA,/ cii REDRAWN FR ' •••• i I . E0 1 9 1 N l e.5L A MI E. '4 '''': . * EPLORATION ICE ROAD ... ... .. ,::,....,....,.. . :.• . 4' .1114S ( ' a' 9 ' .1 gi9 t, ,, ... . . ..... , :.:.:.. ,....... . s . ALPINE, ALASKA - ,\• %., ' - - . -.., ..k•-', . , 0. 0 .. r '."4=4.-Rier ''' A - • -'''• OM: CCNSTRUCTION SHEET V -----'4\ , 1 \' , . ....p , ,... (9 ,,, PI.G23„ , , '• ,... , ,,, ..,,,,1 i . :'..:•;!:::,.., : . ,. .,.. ,P t , .■ . oF , *. 6 - I • ., : : , : . .1 . 1 . . * : ' .' '::i::ii . . :' ",, 1 ** • ' ., N.:;:;:;;:;:;;; - ,n I 2 3 4 5 6 FOR : OOZE ' ' I 00 NOT SCALE ABOVE SCALE FOR REFERENCE ONLY REFERENCE DWG NO/SOT NO DATE: DRAWN: DESIGN: ECM NO: AG - K080010ACS 8/17/08 CHECKED: CC NO: SCALE: GD _ APP CADD FILE NO. 2 9/10/08 ADDED PI - G19A GD AG 1"=5280' ROVAL. - )8-07-19-1A - 1 8/17/08 ISSUED PER K080010ACS AG GO JOB NO: SUB JOB Na CRANING NO PART: REV: REV DATE REIASICNS BY 0-VT ES R184 5VPII REV DATE REVISIONS BY (J EE R Et , ctsA0 0 4 - CE - APOO -1080 1 OF 1 1 1,1 i - 2 I i Nii 6 TRANSMITTAL LETTER CHECKLIST WELL NAME i^a-Ptd V //'Lt., PTD# 2 - 7 Development Service V Exploratory Stratigraphic Test Non - Conventional Well FIELD: Ly OCn;43k POOL: Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segme nt of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, 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 togs 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. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed 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: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool Well Name: GRANDVIEW 1 Program EXP Well bore seg PTD#: 2090070 Company CONOCOPHILLIPS ALASKA INC _ Initial Class/Type .__ EXP / PEND GeoArea 890 _ _ _ Unit On /Off Shore On —_ Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Federal NPRA lease AA- 081785 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 1079' from lease boundary; 2 -3/4 miles to nearest ownership change according to MapMaker's lease map. 6 Well located proper distance from other wells Yes Nearest well is Rendevous A, 4 -1/4 miles to northeast 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included NA Vertical well 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 111 Permit can be issued without conservation order Yes Appr Date 112 Permit can be issued without administrative approval Yes • 13 Can permit be approved before 15 -day wait Yes SFD 1/14/2009 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(1.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs Yes No USDWs expected in area. No aquifer finding in AIO 18A, conclusion 3 immediately to the NE. 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). !25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Nearest well — 4.3 miles distant. 27 If diverter required, does it meet regulations Yes Appr Date 1 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 10.1 EMW. MW planned up to 11.3 or as needed. TEM 1/14/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP w/ shoe breakdown 1879 psi, w/o shoe breakdown 3205 psi. 3500 psi BOP test appropriate. icg 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S has not been reported in the area. Rig equipped with sensors and alarms. %34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data resented on potential overpressure zones Yes Reservoir pressure up to 10.1 expected; will be drilled with 9.6- 11.3 mud as hole conditions dictate p P P P p ppg PP9 Appr Date 37 Seismic analysis of shallow gas zones Yes Evacuation of seismic & velocity data suggest gas hydrates and shallow gas may be present at Grandview 1. SFD 1/14/2009 ;38 Seabed condition survey (if off - shore) NA Mitigation measures discussed in the Drilling Hazards Summary. 39 Contact name /phone for weekly progress reports [exploratory only] Yes Chip Alvord 907 - 265 -6120; Tom Brassfield 907 - 265 -6377 Geologic Engineering Public Commissioner: Date: Commission r: / Date C.�!missioner Date � r /'�� ` ��i 4 `. 1 • • 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. ConocoPhillips Technology 2009 Geochemical Data Report Geochemical Analytical Results: Aff,ce " L r • Grandview 1 well, North Slope, Alaska By Albert G. Holba cONFID ENTIAL ConocoPhillips Technology, , _C p ri Petroleum & Paleobiology Systems January 19, 2010 Geochemical analytical data for the Grandview 1 well, (e.g., mud gas, and core chip solvent extracts) are reported here. Geochemical analyses of rocks were performed by Weatherford Laboratories. (current address: 143 Vision Park Blvd., Shenandoah, TX, 77384), reference project number 09- 489-A. Data is provided in the Vendor Data Appendices. Mud gas samples (Isotubes, Isojars, and Cali -5 gas bags) were analyzed at Isotech Laboratories (1308 Parkland Court, Champaign, Illinois, 61821). Isotech job numbers for Grandview 1 are #11298 (Isotube mud gas & Cali -5 mud gas bags), and #11371 (Isojar mud gas) for gas analyses. Core chips from the Jurassic interval were collected at well site by Leslie Senden, frozen, and shipped to Weatherford Laboratories for a sequential solvent extraction of petroleum • (bitumen). Core chips were initially extracted at room temperature with ultra - sonication using carbon disulfide solvent, followed by exhaustive Soxhlet extraction with methylene chloride. Grandview 1 core chip extracts were analyzed using a whole -oil gas chromatographic (GC) method. Initially, select extracts from both ultra - sonication and Soxhlet extraction were analyzed by gas chromatography (GC). Based on the extract GCs it was decided to only GC the ultra -sonic extracts of the remaining core chips. Only the ultra -sonic extracts of the remaining core chips were analyzed by GC. All chromatograms may be found in the Data Appendices. Asphaltenes were precipitated with pentane and the remaining petroleum fractions were isolated by medium pressure liquid chromatography (MPLC) for selected samples. Biomarker analysis using gas chromatography /mass spectrometry (GC/MS) was done on saturate and aromatic hydrocarbon fractions for selected Grandview 1 core chip samples. The Grandview ultra -sonic and Soxhlet extracts were combined for further analysis using GC -tandem mass spectrometry (GC/MS/MS). Carbon isotopes were measured on select extracts. • 1 i ConocoPhillips Technology 2009 Geochemical Data Report Table of Report Contents 0 Vendor Data Appendices Miscellaneous Vendor Data Separator gas analysis (1 page). Mud gas analyses (1 page). Solvent Extraction (1 page) Seperator Oil MPLC (1 page). Core Extract MPLC (1 page). Carbon Isotopes Oil Fractions (1 page). Carbon Isotopes Core Extract Fractions (1 page). Gas Chromatograms and numerical data for Whole Oil (WGC): Grandview 1 Sample ID Well Depth Data File Number of ft. Pages US146113 Grandview 1 8111 G2090772.D (3 pages) US 146114 Grandview 1 8114 G2090774.D (3 pages) US146115 Grandview 1 8117 G1090457.D (3 pages) • US146115 Grandview 1 8117 G1090451.D (3 pages) US 146116 Grandview 1 8120 G2090775.D (3 pages) US 146117 Grandview 1 8123 G2090790.D (3 pages) US146118 Grandview 1 8125 G2090791.D (3 pages) US 146119 Grandview 1 8128 G2090792.D (3 pages) US 146120 Grandview 1 8131 G2090793.D (3 pages) US 146121 Grandview 1 8134 G2090789.D (3 pages) US 146122 Grandview 1 8137 G2090794.D (3 pages) US 146123 Grandview 1 8140 G2090795.D (3 pages) US146124 Grandview 1 8143 G2090798.D (3 pages) US 146125 Grandview 1 8146 G2090799.D (3 pages) US 146126 Grandview 1 8149 G2090800.D (3 pages) US 146127 Grandview 1 8152 G2090807.D (3 pages) US146128 Grandview 1 8155 G2090809.D (3 pages) US146129 Grandview 1 8158 G1090460.D (3 pages) US146129 Grandview 1 8158 G1090462.D (3 pages) US 146130 Grandview 1 8161 G2090810.D (3 pages) US 146131 Grandview 1 8164 G2090811.D (3 pages) US146132 Grandview 1 8167 G2090812.D (3 pages) US146133 Grandview 1 8170 G2090834.D (3 pages) US146134 Grandview 1 8173 G2090835.D (3 pages) US146135 Grandview 1 8176 G2090825.D (3 pages) US146136 Grandview 1 8179 G2090826.D (3 pages) • US146137 Grandview 1 8182 G2090837.D (3 pages) 2 ConocoPhillips Technology 2009 Geochemical Data Report US146138 Grandview 1 8185 G2090838.D (3 pages) US146139 Grandview 1 8188 G2090839.D (3 pages) US 146140 Grandview 1 8191 G2090828.D (3 pages) US 146141 Grandview 1 8194 G2090840.D (3 pages) US146142 Grandview 1 8197 G2090843.D (3 pages) US 146143 Grandview 1 8200 G2090829.D (3 pages) US146144 Grandview 1 8203 G2090830.D (3 pages) US 146145 Grandview 1 8206 G2090831.D (3 pages) US 146146 Grandview 1 8209 G2090832.D (3 pages) US146147 Grandview 1 8212 G1090461.D (3 pages) US146147 Grandview 1 8212 G1090463.D (3 pages) US146148 Grandview 1 8215 G2090833.D (3 pages) US146149 Grandview 1 8217.4 G2090836.D (4 pages) Gas Chromatography/Mass Spectrometry (GC/MS) saturate hydrocarbon chromatograms and numerical data; Grandview 1 Sample ID Well Depth Data File Number of ft. Pages US146129 Grandview 1 8158 M2090845.D (5 pages) Gas Chromatography/Mass Spectrometry (GC/MS) aromatic hydrocarbon chromatograms and numerical data. Grandview 1 Sample ID Well Depth Data File Number of ft. Pages US146129 Grandview 1 8158 M1090733.D (6 pages) Gas Chromatography/Tandem Mass Spectrometry (GC/MS/MS) saturate hydrocarbon chromatograms and numerical data. Grandview 1 Sample ID Well Depth Data File Number of ft. Pages US146129 Grandview 1 8158 MS090271.D (5 pages) • 3 ConocoPhillips Technology 2009 Geochemical Data Report • • 4 ConocoPhillips Technology 2009 Geochemical Data Report DISTRIBUTION LIST: • Gregory C. Wilson (ConocoPhillips Alaska Inc.) (4 copies) ConocoPhillips Alaska records (archive copy) Greg Wilson file copy Anadarko Petroleum (partner copy) Bureau of Land Management, BLM Albert Holba (CoP/ Technology) (1 copy) ConocoPhillips Records, Houston (1 archive copy). • 5 Number Sample_ID Sample Type Depth (ft) Data File of Pages Grandview -1 Core Chips US146113 Ultrasonic / CS2 8111 G2090772.D US146114 Ultrasonic / CS2 8114 G2090774.D US146115 Soxhlet /DCM 8117 G1090457.D US146115 Ultrasonic / CS2 8117 G1090451.D US146116 Ultrasonic / CS2 8120 G2090775.D US146117 Ultrasonic / CS2 8123 G2090790.D US146118 Ultrasonic / CS2 8125 G2090791.D US146119 Ultrasonic / CS2 8128 G2090792.D US146120 Ultrasonic / CS2 8131 G2090793.D US146121 Ultrasonic / CS2 8134 G2090789.D US146122 Ultrasonic / CS2 8137 G2090794.D US146123 Ultrasonic / CS2 8140 G2090795.D US146124 Ultrasonic / CS2 8143 G2090798.D US146125 Ultrasonic / CS2 8146 G2090799.D US146126 Ultrasonic / CS2 8149 G2090800.D US146127 Ultrasonic / CS2 8152 G2090807.D US146128 Ultrasonic / CS2 8155 G2090809.D US146129 Soxhlet / DCM 8158 G1090460.D US146129 Ultrasonic / CS2 8158 G1090462.D US146130 Ultrasonic / CS2 8161 G2090810.D US146131 Ultrasonic / CS2 8164 G2090811.D US146132 Ultrasonic / CS2 8167 G2090812.D • US146133 Ultrasonic /CS2 8170 G2090834.D US146134 Ultrasonic /CS2 8173 G2090835.D US146135 Ultrasonic / CS2 8176 G2090825.D US146136 Ultrasonic / CS2 8179 G2090826.D US146137 Ultrasonic / CS2 8182 G2090837.D US146138 Ultrasonic / CS2 8185 G2090838.D US146139 Ultrasonic / CS2 8188 G2090839.D US146140 Ultrasonic / CS2 8191 G2090828.D US146141 Ultrasonic / CS2 8194 G2090840.D US146142 Ultrasonic / CS2 8197 G2090843.D US146143 Ultrasonic / CS2 8200 G2090829.D US146144 Ultrasonic / CS2 8203 G2090830.D US146145 Ultrasonic / CS2 8206 G2090831.D US146146 Ultrasonic / CS2 8209 G2090832.D US146147 Soxhlet / DCM 8212 G1090461.D US146147 Ultrasonic / CS2 8212 G1090463.D US146148 Ultrasonic / CS2 8215 G2090833.D US146149 Ultrasonic / CS2 8217.4 G2090836.D • Depth Number Sample_ID Sample Type (ft) Data File of Pages • Grandview -1 Core Chips US146129 Ultrasonic / CS2 8158 M2090845.D • • Depth Number • Sample_ID Sample Type (ft) Data File of Pages Grandview -1 Core Chips US146129 Ultrasonic / CS2 8158 M1090733.D • • Depth Number Sample_ID Sample Type (ft) Data File of Pages • Grandview -1 Core Chips US146129 combined* 8158 MS090271.D * combined Soxhlet + Ultrasonic extracts • 411 Measure • Sample ID Well depth ft. TVD Sample Type Rock US146113 Grandview -1 8111 8109.6 core chips US146114 Grandview -1 8114 8112.6 core chips US146115 Grandview -1 8117 8115.6 core chips US146116 Grandview -1 8120 8118.6 core chips US146117 Grandview -1 8123 8121.6 core chips US146118 Grandview -1 8125 8123.6 core chips US146119 Grandview -1 8128 8126.6 core chips US146120 Grandview -1 8131 8129.6 core chips US146121 Grandview -1 8134 8132.6 core chips US146122 Grandview -1 8137 8135.6 core chips US146123 Grandview -1 8140 8138.6 core chips US146124 Grandview -1 8143 8141.6 core chips US146125 Grandview -1 8146 8144.6 core chips US146126 Grandview -1 8149 8147.6 core chips US146127 Grandview -1 8152 8150.6 core chips US146128 Grandview -1 8155 8153.6 core chips US146129 Grandview -1 8158 8156.6 core chips US146130 Grandview -1 8161 8159.6 core chips US146131 Grandview -1 8164 8162.6 core chips US146132 Grandview -1 8167 8165.6 core chips US146133 Grandview -1 8170 8168.6 core chips US146134 Grandview -1 8173 8171.6 core chips US146135 Grandview -1 8176 8174.6 core chips US146136 Grandview -1 8179 8177.6 core chips US146137 Grandview -1 8182 8180.6 core chips US146138 Grandview -1 8185 8183.6 core chips US146139 Grandview -1 8188 8186.6 core chips US146140 Grandview -1 8191 8189.6 core chips US146141 Grandview -1 8194 8192.6 core chips US146142 Grandview -1 8197 8195.6 core chips US146143 Grandview -1 8200 8198.6 core chips US146144 Grandview -1 8203 8201.6 core chips US146145 Grandview -1 8206 8204.6 core chips US146146 Grandview -1 8209 8207.6 core chips US146147 Grandview -1 8212 8210.6 core chips US146148 Grandview -1 8215 8213.6 core chips US146149 Grandview -1 8217.4 8216.0 core chips Mud Gas US146273 Grandview -1 1000 isotube US146274 Grandview -1 1500 isotube US146275 Grandview -1 2000 isotube US146276 Grandview -1 2500 isotube US146277 Grandview -1 3000 isotube US146278 Grandview -1 3500 isotube US146279 Grandview -1 4000 isotube • US146280 Grandview -1 4500 isotube Measure Sample ID Well depth ft. TVD Sample Type • US146281 Grandview -1 4805 isotube US146282 Grandview -1 4847 isotube US146283 Grandview -1 4853 isotube US146284 Grandview -1 4996 isotube US146285 Grandview -1 5000 isotube US146286 Grandview -1 5100 isotube US146287 Grandview -1 5200 isotube US146288 Grandview -1 5300 isotube US146289 Grandview -1 5400 isotube US146290 Grandview -1 5500 isotube US146291 Grandview -1 5600 isotube US146292 Grandview -1 5700 isotube US146293 Grandview -1 5800 isotube US146294 Grandview -1 5900 isotube US146295 Grandview -1 6000 isotube US146296 Grandview -1 6100 isotube US146297 Grandview -1 6200 isotube US146298 Grandview -1 6300 isotube US146299 Grandview -1 6400 isotube US146300 Grandview -1 6500 isotube US146301 Grandview -1 6600 isotube US146302 Grandview -1 6700 isotube US146303 Grandview -1 6800 isotube US146304 Grandview -1 6900 isotube US146305 Grandview -1 7000 isotube • US146306 Grandview -1 7100 isotube US146307 Grandview -1 7200 isotube US146308 Grandview -1 7248 isotube US146309 Grandview -1 7300 isotube US146310 Grandview -1 7400 isotube US146311 Grandview -1 7500 isotube US146312 Grandview -1 7600 isotube US146313 Grandview -1 7700 isotube US146314 Grandview -1 7800 isotube US146315 Grandview -1 7900 isotube US146316 Grandview -1 8000 isotube US146323 Grandview -1 8025 Gas Bag US146324 Grandview -1 8040 Gas Bag US146317 Grandview -1 8055 isotube US146326 Grandview -1 8070 Gas Bag US146327 Grandview -1 8085 Gas Bag US146328 Grandview -1 8100 Gas Bag US146329 Grandview -1 8104 Gas Bag US146318 Grandview -1 8110 isotube US146319 Grandview -1 8118 isotube Grandview -1 8119 isojar US146320 Grandview -1 8130 isotube US146321 Grandview -1 8140 isotube US146322 Grandview -1 8148 isotube US146333 Grandview -1 8150 Gas Bag • Measure • Sample ID Well depth ft. TVD Sample Type US146334 Grandview -1 8160 Gas Bag US146335 Grandview -1 8170 Gas Bag US146336 Grandview -1 8172 Gas Bag US146337 Grandview -1 8180 Gas Bag US146338 Grandview -1 8190 Gas Bag US146339 Grandview -1 8200 Gas Bag US146340 Grandview -1 8210 Gas Bag US146341 Grandview -1 8220 Gas Bag US146342 Grandview -1 8230 Gas Bag US146343 Grandview -1 8240 Gas Bag Duplicates US146325 Grandview -1 8055 Gas Bag US146330 Grandview -1 8118 Gas Bag IUS146406 Grandview -1 8118 isojar US146331 Grandview -1 8130 Gas Bag IUS146407 Grandview -1 8130 isojar US146332 Grandview -1 8140 Gas Bag US146408 Grandview -1 8140 isojar US146409 Grandview -1 8150 isojar US146410 Grandview -1 8160 isojar US146411 Grandview -1 8170 isojar al US146412 Grandview -1 8180 isojar US146413 Grandview -1 8190 isojar US146414 Grandview -1 8200 isojar US146415 Grandview -1 8210 isojar • • 0 • Carbon Measure Ultrasonic Soxhlet Extract GCMS GCMS GCMSMS Isotopes Sample ID Well depth ft. TVD Extraction Extraction GC MPLC Sat Aro Sat HC Core Chips US146113 Grandview -1 8111 8109.6 YES YES US146114 Grandview -1 8114 8112.6 YES YES US146115 Grandview -1 8117 8115.6 YES YES US146116 Grandview -1 8120 8118.6 YES YES US146117 Grandview -1 8123 8121.6 YES YES US146118 Grandview -1 8125 8123.6 YES YES US146119 Grandview -1 8128 8126.6 YES YES US146120 Grandview -1 8131 8129.6 YES YES US146121 Grandview -1 8134 8132.6 YES YES US146122 Grandview -1 8137 8135.6 YES YES US146123 Grandview -1 8140 8138.6 YES YES US146124 Grandview -1 8143 8141.6 YES YES US146125 Grandview -1 8146 8144.6 YES YES US146126 Grandview -1 8149 8147.6 YES YES US146127 Grandview -1 8152 8150.6 YES YES US146128 Grandview -1 8155 8153.6 YES YES US146129 Grandview -1 8158 8156.6 YES YES YES YES YES YES YES YES US146130 Grandview -1 8161 8159.6 YES YES US146131 Grandview -1 8164 8162.6 YES YES US146132 Grandview -1 8167 8165.6 YES YES US146133 Grandview -1 8170 8168.6 YES YES US146134 Grandview -1 8173 8171.6 YES YES , US146135 Grandview -1 8176 8174.6 YES YES US146136 Grandview -1 8179 8177.6 YES YES US146137 Grandview -1 8182 8180.6 YES YES US146138 Grandview -1 8185 8183.6 YES YES US146139 Grandview -1 8188 8186.6 YES YES US146140 Grandview -1 8191 8189.6 YES YES US146141 Grandview -1 8194 8192.6 YES YES US146142 Grandview -1 8197 8195.6 YES YES US146143 Grandview -1 8200 8198.6 YES YES US146144 Grandview -1 8203 8201.6 YES YES US146145 Grandview -1 8206 8204.6 YES YES Carbon Measure Ultrasonic Soxhlet Extract GCMS GCMS GCMSMS Isotopes Sample ID Well depth ft. TVD Extraction Extraction GC MPLC Sat Aro Sat HC US146146 Grandview -1 8209 8207.6 YES YES US146147 Grandview -1 8212 8210.6 YES YES US146148 Grandview -1 8215 8213.6 YES YES US146149 Grandview -1 8217.4 8216.0 YES YES • III III • • • Carbon Measure Ultrasonic Soxhlet Extract GCMS GCMS GCMSMS Isotopes Sample ID Well depth ft. TVD Extraction _Extraction GC MPLC Sat Aro Sat HC Core Chips US146113 Grandview -1 8111 8109.6 YES YES US146114 Grandview -1 8114 8112.6 YES YES US146115 Grandview -1 8117 8115.6 YES YES US146116 Grandview -1 8120 8118.6 YES YES US146117 Grandview -1 8123 8121.6 YES YES US146118 Grandview -1 8125 8123.6 YES YES US146119 Grandview -1 8128 8126.6 YES YES US146120 Grandview -1 8131 8129.6 YES YES US146121 Grandview -1 8134 8132.6 YES YES US146122 Grandview -1 8137 8135.6 YES YES US146123 Grandview -1 8140 8138.6 YES YES US146124 Grandview -1 8143 8141.6 YES YES US146125 Grandview -1 8146 8144.6 YES YES US146126 Grandview -1 8149 8147.6 YES YES US146127 Grandview -1 8152 8150.6 YES YES US146128 Grandview -1 8155 8153.6 YES YES US146129 Grandview -1 8158 8156.6 YES YES YES YES YES YES YES YES US146130 Grandview -1 8161 8159.6 YES YES US146131 Grandview -1 8164 8162.6 YES YES US146132 Grandview -1 8167 8165.6 YES YES US146133 Grandview -1 8170 8168.6 YES YES US146134 Grandview -1 8173 8171.6 YES YES US146135 Grandview -1 8176 8174.6 YES YES US146136 Grandview -1 8179 8177.6 YES YES US146137 Grandview -1 8182 8180.6 YES YES US146138 Grandview -1 8185 8183.6 YES YES US146139 Grandview -1 8188 8186.6 YES YES US146140 Grandview -1 8191 8189.6 YES YES US146141 Grandview -1 8194 8192.6 YES YES US146142 Grandview -1 8197 8195.6 YES YES US146143 Grandview -1 8200 8198.6 YES YES US146144 Grandview -1 8203 8201.6 YES YES US146145 Grandview -1 8206 8204.6 YES YES Carbon Measure Ultrasonic Soxhlet Extract GCMS GCMS GCMSMS Isotopes Sample ID Well depth ft. TVD Extraction Extraction GC MPLC Sat Aro Sat HC US146146 Grandview -1 8209 8207.6 YES YES US146147 Grandview -1 8212 8210.6 YES YES US146148 Grandview -1 8215 8213.6 YES YES US146149 Grandview -1 8217.4 8216.0 YES YES 1111 • • • • • Methane Metane Measure Sample Carbon Deuterium Sample ID Well depth ft. Type Composition Isotopes Isotopes Etane Deuterium Isotopes C2+ Carbon Isotopes Mud Gas US146273 Grandview -1 1000 isotube YES YES YES US146274 Grandview -1 1500 isotube YES YES US146275 Grandview -1 2000 isotube YES YES US146276 Grandview -1 2500 isotube YES YES YES US146277 Grandview -1 3000 isotube YES YES YES US146278 Grandview -1 3500 isotube YES YES US146279 Grandview -1 4000 isotube YES YES US146280 Grandview -1 4500 isotube YES YES US146281 Grandview -1 4805 isotube YES YES US146282 Grandview -1 4847 isotube YES YES US146283 Grandview -1 4853 isotube YES YES US146284 Grandview -1 4996 isotube YES YES YES US146285 Grandview -1 5000 isotube YES YES US146286 Grandview -1 5100 isotube YES YES US146287 Grandview -1 5200 isotube YES YES US146288 Grandview -1 5300 isotube YES YES US146289 Grandview -1 5400 isotube YES YES YES YES US146290 Grandview -1 5500 isotube YES YES US146291 Grandview -1 5600 isotube YES YES US146292 Grandview -1 5700 isotube YES YES YES YES US146293 Grandview -1 5800 isotube YES YES US146294 Grandview -1 5900 isotube YES YES US146295 Grandview -1 6000 isotube YES YES US146296 Grandview -1 6100 isotube YES YES US146297 Grandview -1 6200 isotube YES YES US146298 Grandview -1 6300 isotube YES YES US146299 Grandview -1 6400 isotube YES YES US146300 Grandview -1 6500 isotube YES YES US146301 Grandview -1 6600 isotube YES YES US146302 Grandview -1 6700 isotube YES YES US146303 Grandview -1 6800 isotube YES YES US146304 Grandview -1 6900 isotube YES YES US146305 Grandview -1 7000 isotube YES YES Methane Metane Measure Sample Carbon Deuterium Sample ID Well depth ft. Type Composition Isotopes Isotopes Etane Deuterium Isotopes C2+ Carbon Isotopes US146306 Grandview -1 7100 isotube YES YES US146307 Grandview -1 7200 isotube YES YES US146308 Grandview -1 7248 isotube YES YES YES YES US146309 Grandview -1 7300 isotube YES YES YES YES US146310 Grandview -1 7400 isotube YES YES US146311 Grandview -1 7500 isotube YES YES US146312 Grandview -1 7600 isotube YES YES US146313 Grandview -1 7700 isotube YES YES US146314 Grandview -1 7800 isotube YES YES US146315 Grandview -1 7900 isotube YES YES US146316 Grandview -1 8000 isotube YES YES US146323 Grandview -1 8025 Gas Bag YES YES US146324 Grandview -1 8040 Gas Bag YES YES US146317 Grandview -1 8055 isotube YES YES US146326 Grandview -1 8070 Gas Bag YES YES US146327 Grandview -1 8085 Gas Bag YES YES YES YES US146328 Grandview -1 8100 Gas Bag YES YES US146329 Grandview -1 8104 Gas Bag YES YES YES YES YES US146318 Grandview -1 8110 isotube YES YES US146319 Grandview -1 8118 isotube YES YES US146320 Grandview -1 8130 isotube YES YES YES YES US146321 Grandview -1 8140 isotube YES YES US146322 Grandview -1 8148 isotube YES YES US146333 Grandview -1 8150 Gas Bag US146334 Grandview -1 8160 Gas Bag YES YES US146335 Grandview -1 8170 Gas Bag YES YES US146336 Grandview -1 8172 Gas Bag YES YES YES YES US146337 Grandview -1 8180 Gas Bag YES YES IUS146412 Grandview -1 8180 isojar YES YES US146338 Grandview -1 8190 Gas Bag YES YES US146339 Grandview -1 8200 Gas Bag YES YES YES YES YES US146340 Grandview -1 8210 Gas Bag YES YES US146341 Grandview -1 8220 Gas Bag YES YES US146342 Grandview -1 8230 Gas Bag YES YES • • • • • • Methane Metane Measure Sample Carbon Deuterium Sample ID Well depth ft. Type Composition Isotopes Isotopes Etane Deuterium Isotopes C2+ Carbon Isotopes US146343 Grandview -1 8240 Gas Bag YES YES Duplicates + Unanalyzed Samples US146325 Grandview -1 8055 Gas Bag US146330 Grandview -1 8118 Gas Bag IUS146406 Grandview -1 8118 isojar US146331 Grandview -1 8130 Gas Bag IUS146407 Grandview -1 8130 isojar US146332 Grandview -1 8140 Gas Bag US146408 Grandview -1 8140 isojar US146409 Grandview -1 8150 isojar US146410 Grandview -1 8160 isojar US146411 Grandview -1 8170 isojar US146413 Grandview -1 8190 isojar US146414 Grandview -1 8200 isojar US 146415 Grandview -1 8210 isojar ... 1 1 111 1 ] 1 .7, ? i 1 1 t i L 1 1 Y Y i-221§E§I§E§H§§§§1§§1]§§§§1§§E§E§E§§§§§111§ELMEEHEFAILHEE§1]§§§§1 1 §E 81g0Agggmgmgg§§ggg=2,P.P.,22.,22HP.r!zz2z.z.22 lafflfflkunummammuncHrffinEiEEEEMINNAMinuMWOO, fq,EMFAUTAMEMEHEMEWCAMMEUTIMMEMMEMMEMEMCM ilEflifliiiniffinAllifilitilliaiiiffillitblinnTiln i kIMMONIMIIMIIIMINIMMIIINIMIIIIIII gIMFRHi§H§.UMMAM 6 111/1 g.04 4i 4 4 4 44 4 4 4 4 4 ..A -.0 e , . ..._____,...._..._........„,..._,..._...._.„....„ -,---:- ic.!-Ath.54-74%lqqq4;;;44;44qq;44;7?q4;;;;Wq-00000r;;;;wet4V441;44W-r;gur044 ,54,----AsPInAMEPEEEHEiRMFgEFWEliFOrani ii.-------MiERRE?5.H. 40------4MEMT,ZMIIFFiEF =1,-----g1F gl.....—:2w1-UH=1-,E1=FEEEqg4RLA.73if.,FINFgMFEHRFogcA2 . . 61 ii 8i - 64,--"rWIMMWIWWFWAPWIMIMMIplglifill!ppIEW 4ii 611011111WWWOMIMMIMMIVIIIMMIgIONIPPAMI LP - 2-5 Sixr,p,:gF.4WAHFFF 44 1.4 i- .MEIIIIIIMMIIIIIRMIIMIliglIPPOMPIMIE::=I5IMEEMIUM 711$ --. . 73 idEUEEEFIRAEE.ERUMEUEMOMMRLF ill a : a ,%2g.t*WW44444M44'4444',V4V4WWW4444'4W444=44M4V4M'444'44'44W444'4W tg= - '3 Z'S3ES'Sgg'gSgS'SSV8SSVgSS"SS"gSSgSSS"gS"SgSSS'S2SVMSSVAS ni : 22E1 2 !.:: - 5 0 .,,, 122222S2222222 2222222232222222222 2222.52222222221.2g2MMTW_ZWW,TRZ 1-5. L s--_,2 2.2gggggg.E.. .2,2,2,2.=g2,2,2,2,2 .2.2,2E,F,2,2,EggTTTT,TT,TTT.T2TT,TTTT Eg2 • ,m2 si wwsg2222g 2,9S,9,2,12ggW222S222 5 2,1g 222 g 2,9225 g220333gg33133',1agagg L2-: W ballad SOXH LET • tAeoa:tren +Es Company: CONOCOPHILLIPS Well: Grandview 1 Project #: 09 -489 -A Depth Rock Ultrasonic Ext. Soxhlet Ext Total % Total EOM Client ID (m.d. ft.) Lab ID Weight (g) Weight (g) Weight (g) Extract (ppm) US146113 8111 CP293027 5.2149 0.0076 0.0067 0.27 2734 US146114 8114 CP293028 4.3513 0.0181 0.0040 0.51 5070 US146115 8117 CP293029 9.0553 0.0090 0.0118 0.23 2297 US146116 8120 CP293030 4.4775 0.0019 0.0028 0.10 1050 US146117 8123 CP293031 4.1590 0.0018 0.0011 0.07 709 US146118 8125 CP293032 3.6185 0.0027 0.0006 0.09 918 US146119 8128 CP293033 9.2864 0.0065 0.0027 0.10 986 US146120 8131 CP293034 5.3463 0.0024 0.0017 0.08 767 US146121 8134 CP293035 7.7631 0.0040 0.0015 0.07 703 US146122 8137 CP293036 9.6686 0.0032 0.0035 0.07 695 US146123 8140 CP293037 8.3166 0.0011 0.0022 0.04 394 US146124 8143 CP293038 8.7671 0.0019 0.0027 0.05 527 US146125 8146 CP293039 8.9423 0.0014 0.0025 0.04 432 US146126 8149 CP293040 9.4284 0.0018 0.0021 0.04 408 US146127 8152 CP293041 8.0159 0.0006 0.0027 0.04 417 US146128 8155 CP293042 10.8534 0.0014 0.0011 0.02 234 US146129 8158 CP293043 12.6305 0.0021 0.0196 0.17 1718 US146130 8161 CP293044 7.1989 0.0016 0.0015 0.04 431 US146131 8164 CP293045 8.1299 0.0014 0.0013 0.03 337 US146132 8167 CP293046 9.9237 0.0017 0.0015 0.03 322 40 US146133 8170 CP293047 6.8430 0.0014 0.0008 0.03 321 US146134 8173 CP293048 9.7729 0.0016 0.0020 0.04 368 US146135 8176 CP293049 7.5197 0.0011 0.0012 0.03 307 US146136 8179 CP293050 6.6890 0.0016 0.0010 0.04 389 US146137 8182 CP293051 5.6050 0.0013 0.0011 0.04 425 US146138 8185 CP293052 5.6572 0.0019 0.0005 0.04 424 US146139 8188 CP293053 6.7125 0.0006 0.0019 0.04 375 US146140 8191 CP293054 5.6162 0.0008 0.0015 0.04 413 US146141 8194 CP293055 4.6060 0.0008 0.0015 0.05 499 US146142 8197 CP293056 4.8303 0.0000 0.0017 0.04 352 US146143 8200 CP293057 3.0190 0.0021 0.0008 0.09 944 US146144 8203 CP293058 3.8417 0.0004 0.0007 0.03 284 US146145 8206 CP293059 3.9897 0.0011 0.0022 0.08 822 US146146 8209 CP293060 6.3195 0.0007 0.0027 0.05 544 US146147 8212 CP293061 9.0012 0.0016 0.0052 0.08 755 US146148 8215 CP293062 3.4111 0.0017 0.0004 0.06 610 US146149 8217.4 CP293063 3.7467 0.0015 0.0004 0.05 512 III Geochemical Services Group, 143 Vision Park Blvd , Shenandoah, Texas 77384 • Phone 281 - 681 -2200 • Fax: 281 - 681 -0326 • Email: geocheminfo @weatherfordlabs.com VP Weatherford` ISOTOPES S L A B O R A T O R I E S Company: CONOCOPHILLIPS Project #: 09 -489 -A et 8 "C et PC 813C Client ID Lab ID Saturate Aromatic Resin Asph Whole US146129 CP293043 -30.3 -27.4 -26.8 -26.8 S • Geochemical Services Group, 143 Vision Park Blvd., Shenandoah, Texas 77384 • Phone: 281- 681 -2200 • Fax: 281- 681 -0326 • Email: geocheminfo @weatherfordlabs.com VP • elord WHOLE OIL GC L A 3 O R A O R 1 £ 9 Company: CONOCOPHILLIPS Client ID: US146115 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293029 Lease: Sample Type: CORE CS2 extract ultrasonic Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8117 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G1090451.D • z s f z Z z a " z z z z t z o �:. , z z z z z � � � 1 � 1 {11 47 IuI r I I.R�VlI11 -41°` J WGC parameters Thompson Mango Halp Pristane /Phytane 2.05 A. BZ/n C6 0.09 P, 17.26 Tr, 19.16 Pristane /n C17 0.57 B. TOUnC 1.41 P2 9.16 Tr 13.59 Phytane /n C18 0.33 C. (n C + /(CH +MCH) 1.21 P3 2.09 Tr 3.84 n C18 /n C19 1.10 I. Isoheptane Value 1.21 5N 4.83 Tr 3.37 n C /n C29 4.31 F. n C 7 /MCH 0.47 N2 5.44 Tr 7.21 n C 15 /(nC +nC 0.52 U. CH /MCP 0.49 6N, 61.23 Tr 1.61 n C, 7 /(nC +nC 0.81 R. nC /2MH 4.03 K 1.01 Tr 4.51 CPI Hunt 1.04 S. n C 6 /22DMB K2 0.63 C 0.08 CPI Marzi 1.03 H. Heptane Value 20.88 5N 0.08 C2 0.50 Normal Paraffins 17.8 MCH /nC 2.14 P /N 0.38 C 0.18 Isoprenoids 2.6 mpXYUn Ce 1.11 In(24DMP /23DMP) -1.03 C4 0.08 40 Cycloparaffins 3.6 C5 0.17 Branched (iso -) Paraffins 0.7 BTX aromatics 3.2 Resolved unknowns 71.7 'Thompson, K.F.M.,1983.GCA:V.47, p.303. 2 Mango, F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.l.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 SMarzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US146115 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8117 - FT Lab ID: CP293029 Sampling Point: File Name: G1090451.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 6.001 336 189 23DMB 2,3- Dimethylbutane 6.026 242 175 2MP 2- Methylpentane 6.083 2151 1363 3MP 3- Methylpentane 6.329 5459 3286 NC6 Normal Alkane C6 6.702 81991 49700 22DMP 2,2- Dimethylpentane 7.348 326 267 MCP Methylcyclopentane 7.399 40941 22332 24DMP 2,4- Dimethylpentane 7.530 766 403 223TMB 2,2,3 - Trimethylbutane 7.682 129 59 BZ Benzene 8.140 7657 3894 33DMP 3,3- Dimethylpentane 8.350 323 153 CH Cyclohexane 8.465 19868 10020 2MH 2- Methylhexane 8.843 8991 4466 23DMP 2,3- Dimethylpentane 8.894 2137 1124 11DMCP 1,1- Dimethylcyclopentane 8.982 2667 1285 3MH 3- Methylhexane 9.181 10237 5013 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.413 4461 2154 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.526 4294 2055 3EP 3- Ethylpentane 9.587 708 521 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.639 7157 3362 NC7 Normal Alkane C7 10.229 36233 17145 ISTD Internal Standard MCH Methylcyclohexane 11.078 77449 33935 113TMCP 1,1,3, - Trimethylcyclopentane 11.242 4350 1857 ECP Ethylcyclopentane 11.647 2975 1311 124TMCP 1,2,4 - Trimethylcyclopentane 12.092 4149 1779 123TMCP 1,2,3 - Trimethylcyclopentane 12.459 3661 1556 TOL Toluene 12.771 51099 21667 NC8 Normal Alkane C8 15.409 64234 23885 IP9 Isoprenoid C9 17.274 6643 2502 EB Ethyl- benzene 17.971 9533 3585 MXYL m- xylene 18.476 55287 20370 PXYL p- xylene 18.536 16234 6732 OXYL o- xylene 19.729 23256 7875 NC9 Normal Alkane C9 21.143 64528 21549 IP10 Isoprenoid C10 23.127 10462 2868 PB Propyl- benzene 23.298 6568 1843 NC10 Normal Alkane C10 26.758 63244 18796 IP11 Isoprenoid C11 28.060 11207 3323 NC11 Normal Alkane C11 32.042 63034 18212 NC12 Normal Alkane C12 36.987 54902 16176 IP13 Isoprenoid C13 37.729 13763 3380 1P14 Isoprenoid C14 40.504 9462 2742 III NC13 Normal Alkane C13 41.620 51736 15223 IP15 Isoprenoid C15 45.086 13571 3821 NC14 Normal Alkane C14 45.975 46005 13338 I 1110 • Weatherford M P LC L A B O R A T O R I E S 1 Company: CONOCOPHILLIPS Project #: 09 -489 -A Client ID Lab ID Sample SAT ARO NSO ASPH % % °!o % Weight Weight Weight Weight Weight SAT ARO NSO ASPH US146129 CP293043 0.0042 0.0007 0.0008 0.0003 0.0010 16.67 19.05 7.14 23.81 Geochemical Services Group, 143 Vision Park Blvd., Shenandoah, Texas 77384 • Phone: 281- 681 -2200 • Fax 281- 681 -0326 • Email: geocheminfo @weatherfordlabs.com I I Company: CONOCOPHILLIPS Client ID: US146115 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8117 - FT Lab ID: CP293029 Sampling Point: File Name: G1090451.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.650 18430 4211 NC15 Normal Alkane C15 50.078 42051 11406 NC16 Normal Alkane C16 53.961 35049 9900 IP18 Isoprenoid C18 55.914 14927 3089 NC17 Normal Alkane C17 57.641 31872 8956 IP19 Isoprenoid C19 (Pristane) 57.996 18044 3462 PHEN Phenanthrene 59.06:3 3116 801 NC18 Normal Alkane C18 61.136 26309 7367 IP20 Isoprenoid C20 (Phytane) 61.594 8794 1488 NC19 Normal Alkane C19 64.465 23975 6565 NC20 Normal Alkane C20 67.641 22257 5904 NC21 Normal Alkane C21 70.672 19017 5241 C25HBI Highly Branch Isoprenoid C25 70.933 1360 269 NC22 Normal Alkane C22 73.575 17533 4761 NC23 Normal Alkane C23 76.360 16164 4460 NC24 Normal Alkane C24 79.029 14302 3957 NC25 Normal Alkane C25 81.600 13052 3507 NC26 Normal Alkane C26 84.072 11434 3001 NC27 Normal Alkane C27 86.454 9461 2464 NC28 Normal Alkane C28 88.753 7627 1955 NC29 Normal Alkane C29 90.973 7387 1779 al NC30 Normal Alkane C30 93.122 5534 1361 NC31 Normal Alkane C31 95.199 4599 1123 NC32 Normal Alkane C32 97.210 3992 886 NC33 Normal Alkane C33 99.166 4293 851 NC34 Normal Alkane C34 101.061 2851 611 NC35 Normal Alkane C35 102.956 2421 497 NC36 Normal Alkane C36 105.048 3186 378 NC37 Normal Alkane C37 107.410 1481 227 NC38 Normal Alkane C38 110.102 1253 160 NC39 Normal Alkane C39 113.196 1054 130 NC40 Normal Alkane C40 116.839 632 109 NC41 Normal Alkane C41 121.121 770 78 • IIMP • W;Qrd$ WHOLE OIL GC L A 3 0 R A 0 2 I £ A Company: CONOCOPHILLIPS Client ID: US146129 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293043 Lease: Sample Type: CORE CS2 extract Ultrasonic Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8158 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G1090462.D I 0 • s E so z' . z . z WGC parameters Thompson Mango Halpern Pristane /Phytane 2.16 A. BZ/n C6 3.70 P 13.17 Tr, 47.60 Pristane /n C„ 0.43 B. TOUn C7 2.99 P2 6.15 Tr 15.94 Phytane /n C18 0.25 C. (n C + /(CH +MCH) 0.38 P3 1.33 Tr 4.01 n C 18 /n C19 1.13 I. Isoheptane Value 1.15 5N 3.89 Tr 3.43 n C /n C29 6.07 F. n C 7 /MCH 0.41 N2 3.73 Tr 7.44 n C 18 /(nC +nC 0.53 U. CH /MCP 2.82 6N, 71.73 Tr 1.73 n C 17 /(nC +nC 0.86 R. n C 7 /2MH 4.65 K 0.99 Tr 4.82 CPI Hunt 1.05 S. n C 6 122DMB K2 0.62 C 0.07 CPI Marz 1.04 H. Heptane Value 20.12 5N 0.05 C2 0.50 Normal Paraffins 12.1 MCH /nC 2.46 P /N 0.36 C 0.15 Isoprenoids 1.8 mpXYL/nC 2.08 In(24DMP /23DMP) -1.23 C 0.10 40 Cycloparaffins 2.5 C 0.18 Branched (iso -) Paraffins 0.4 BTX aromatics 5.8 Resolved unknowns 76.7 'Thompson, K.F.M.,1983.GCA:V.47, p.303. "Mango, F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 5Marzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: G1090462.D Peak Compound Ret. ppt ppt 40 Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.950 173 93 23DMB 2,3- Dimethylbutane 5.975 42 36 2MP 2- Methylpentane 6.036 428 262 3MP 3- Methylpentane 6.287 500 298 NC6 Normal Alkane C6 6.664 2880 1756 22DMP 2,2- Dimethylpentane 7.310 159 91 MCP Methylcyclopentane 7.367 4446 2430 24DMP 2,4- Dimethylpentane 7.498 341 174 223TMB 2,2,3 - Trimethylbutane 7.651 99 35 BZ Benzene 8.111 10647 5393 33DMP 3,3- Dimethylpentane 8.322 223 99 CH Cyclohexane 8.437 12532 6236 2MH 2- Methylhexane 8.818 5129 2491 23DMP 2,3- Dimethylpentane 8.869 1165 603 11DMCP 1,1- Dimethylcyclopentane 8.958 1495 700 3MH 3- Methylhexane 9.157 6000 2862 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.390 2656 1243 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.503 2593 1205 3EP 3- Ethylpentane 9.564 423 318 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.617 4463 2040 NC7 Normal Alkane C7 10.208 23832 11002 ISTD Internal Standard MCH Methylcyclohexane 11.058 58588 25366 113TMCP 1,1,3, - Trimethylcyclopentane 11.225 2384 980 ECP Ethylcyclopentane 11.630 2571 1112 124TMCP 1,2,4 - Trimethylcyclopentane 12.076 2355 997 123TMCP 1,2,3 - Trimethylcyclopentane 12.444 2019 841 TOL Toluene 12.758 71169 29868 NC8 Normal Alkane C8 15.398 50236 18643 IP9 Isoprenoid C9 17.266 4804 1796 EB Ethyl- benzene 17.965 13377 5033 MXYL m- xylene 18.474 80879 29140 PXYL p- xylene 18.532 23811 10067 OXYL o - xylene 19.721 32247 11387 NC9 Normal Alkane C9 21.133 49315 17208 IP10 Isoprenoid C10 23.119 6188 1779 PB Propyl- benzene 23.290 7652 2337 NC10 Normal Alkane C10 26.746 46888 14495 IP11 Isoprenoid C11 28.049 6307 1904 NC11 Normal Alkane C11 32.028 46039 12965 NC12 Normal Alkane C12 36.970 36056 10373 IP13 Isoprenoid C13 37.716 8499 1953 IP14 Isoprenoid C14 40.491 4956 1419 NC13 Normal Alkane C13 41.603 33091 9465 • IP15 Isoprenoid C15 45.075 10491 2950 NC14 Normal Alkane C14 45.958 27786 7763 Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: G1090462.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.632 10731 2320 NC15 Normal Alkane C15 50.060 22293 6244 NC16 Normal Alkane C16 53.943 17453 5023 IP18 Isoprenoid C18 55.898 6312 1310 NC17 Normal Alkane C17 57.622 15354 4151 IP19 Isoprenoid C19 (Pristane) 57.983 6527 1239 PHEN Phenanthrene 59.047 4431 1269 NC18 Normal Alkane 018 61.118 11880 3389 IP20 Isoprenoid C20 (Phytane) 61.578 3023 548 NC19 Normal Alkane C19 64.445 10495 2847 NC20 Normal Alkane C20 67.620 9510 2461 NC21 Normal Alkane C21 70.654 7374 2057 C25HBI Highly Branch Isoprenoid C25 70.927 701 163 NC22 Normal Alkane C22 73.558 6747 1851 NC23 Normal Alkane C23 76.339 5761 1602 NC24 Normal Alkane C24 79.010 4949 1378 NC25 Normal Alkane C25 81.579 4430 1180 NC26 Normal Alkane C26 84.051 3827 1009 NC27 Normal Alkane C27 86.436 3158 811 NC28 Normal Alkane C28 88.734 2506 660 NC29 Normal Alkane C29 90.954 2528 586 40 NC30 Normal Alkane C30 93.103 1875 462 NC31 Normal Alkane C31 95.183 1636 376 NC32 Normal Alkane C32 97.191 1418 291 NC33 Normal Alkane C33 99.145 1455 272 NC34 Normal Alkane C34 101.044 855 196 NC35 Normal Alkane C35 102.934 825 153 NC36 Normal Alkane C36 105.020 701 108 NC37 Normal Alkane C37 107.380 628 89 NC38 Normal Alkane C38 110.073 513 65 NC39 Normal Alkane C39 113.178 669 65 NC40 Normal Alkane C40 116.798 689 53 NC41 Normal Alkane C41 • W • Weatherford* WHOLE OIL GC L A 3 0 R A O � F E y Company: CONOCOPHILLIPS Client ID: US146147 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293061 Lease: Sample Type: CORE CS2 extract ultrasonic Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8212 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G1090463.D I 0 • E x Z Z Z Z Z ..; Y2 4 .y �n ,. Y o .. .. ,-6 z ti U a m ri ^ y a S U y U z Z U Z y Z Z I SoAVL,.� II " lr 4 J �' � r. � 11 1� la1r.....L1.J � wA6 VVGC parameters Thompson Mango Halpern Pristane /Phytane 2.53 A. BZ/n Cs 8.51 P, 9.61 Tr, 103.73 Pristane /n C17 0.38 B. TOL/n C7 5.93 P2 4.07 Tr 17.50 Phytane /n C, 0.19 C. (n C +n C 7 ) /(CH +MCH) 0.37 P 0.82 Tr 3.98 n C18 /n C,9 1.07 I. Isoheptane Value 1.11 5N, 2.58 Tr 3.43 n C /n C29 3.81 F. nC /MCH 0.41 N2 2.59 Tr 7.41 n C, /(nC, +n C 0.52 U. CH /MCP 3.13 6N, 80.33 Tr, 1.84 nC /(nC +n C 29 ) 0.79 R. nC /2MH 5.10 K, 0.98 Tr 5.10 CPI Hunt 1.07 S. nC K2 0.61 C, 0.06 CPI Marzi 1.04 H. Heptane Value 20.23 5N 0.03 C2 0.48 Normal Paraffins 10.5 MCH /n 2.43 P /N 0.32 C3 0.15 Isoprenoids 1.7 mpXYL/n 2.41 In(24DMP /23DMP) -1.15 C4 0.10 Cycloparaffins 1.8 C 0.21 Branched (iso-) Paraffins 0.2 BTX aromatics 6.2 Resolved unknowns 79.0 'Thompson, K.F.M.,1983.GCA:V.47, p.303. 2 Mango, F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.L,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 4Marzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US146147 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8212 - FT Lab ID: CP293061 1 6 1 Sampling Point: File Name: G1090463.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.940 96 53 23DMB 2,3- Dimethylbutane 5.965 21 18 2MP 2- Methylpentane 6.027 214 124 3MP 3- Methylpentane 6.279 245 140 NC6 Normal Alkane C6 6.657 1653 996 22DMP 2,2- Dimethylpentane 7.305 67 38 MCP Methylcyclopentane 7.361 2751 1497 24DMP 2,4- Dimethylpentane 7.493 180 84 223TMB 2,2,3 - Trimethylbutane 7.647 37 14 BZ Benzene 8.105 14066 7231 33DMP . 3,3- Dimethylpentane 8.316 115 44 CH Cyclohexane 8.431 8608 4321 2MH 2- Methylhexane 8.812 2783 1373 23DMP 2,3- Dimethylpentane 8.863 571 298 11DMCP 1,1- Dimethylcyclopentane 8.952 811 378 3MH 3- Methylhexane 9.152 3226 1559 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.385 1525 720 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.498 1490 699 3EP 3- Ethylpentane 9.560 245 178 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.612 2423 1133 NC7 Normal Alkane C7 10.202 14193 6658 ISTD Internal Standard MCH Methylcyclohexane 11.052 34511 15110 113TMCP 1,1,3,- Trimethylcyclopentane 11.220 1298 542 ECP Ethylcyclopentane 11.626 1388 605 124TMCP 1,2,4 - Trimethylcyclopentane 12.073 1387 590 123TMCP 1,2,3 - Trimethylcyclopentane 12.441 1147 482 TOL Toluene 12.756 84128 35481 NC8 Normal Alkane C8 15.394 31480 11928 IP9 Isoprenoid C9 17.264 2643 988 EB Ethyl- benzene 17.964 9613 3629 MXYL m- xylene 18.472 58015 21247 PXYL p- xylene 18.531 17930 7388 OXYL o- xylene 19.724 23240 8309 NC9 Normal Alkane C9 21.135 33855 12059 IP10 Isoprenoid C10 23.121 3730 1130 PB Propyl- benzene 23.293 4176 1298 1 NC10 Normal Alkane C10 26.745 29566 9772 IP11 Isoprenoid C11 28.050 3918 1258 NC11 Normal Alkane C11 32.024 26504 8021 NC12 Normal Alkane C12 36.966 20876 6494 IP13 Isoprenoid C13 37.715 5227 1210 IP14 Isoprenoid C14 40.490 4626 1419 • NC13 Normal Alkane C13 41.599 20443 6068 IP15 Isoprenoid C15 45.072 10290 2981 NC14 Normal Alkane C14 45.953 19519 5480 Company: CONOCOPHILLIPS Client ID: US146147 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8212 - FT Lab ID: CP293061 Sampling Point: File Name: G1090463.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.633 10090 2280 NC15 Normal Alkane C15 50.058 16492 4644 NC16 Normal Alkane C16 53.939 13988 3965 IP18 Isoprenoid C18 55.895 4837 1034 NC17 Normal Alkane C17 57.619 12749 3542 IP19 Isoprenoid C19 (Pristane) 57.983 4886 934 PHEN Phenanthrene 59.043 4559 1308 NC18 Normal Alkane C18 61.114 10391 2979 IP20 Isoprenoid C20 (Phytane) 61.582 1935 356 NC19 Normal Alkane C19 64.443 9743 2700 NC20 Normal Alkane C20 67.616 9088 2298 NC21 Normal Alkane C21 70.650 7407 2142 C25HBI Highly Branch Isoprenoid C25 70.919 608 145 NC22 Normal Alkane C22 73.554 7234 1939 NC23 Normal Alkane C23 76.339 6226 1721 NC24 Normal Alkane C24 79.008 5629 1537 NC25 Normal Alkane C25 81.575 5198 1362 NC26 Normal Alkane C26 84.047 4514 1175 NC27 Normal Alkane C27 86.433 4072 1040 NC28 Normal Alkane C28 88.730 3411 864 NC29 Normal Alkane C29 90.951 3342 800 fra NC30 Normal Alkane C30 93.099 2442 569 NC31 Normal Alkane C31 95.177 2124 504 NC32 Normal Alkane C32 97.189 1764 374 NC33 Normal Alkane C33 99.147 2149 381 NC34 Normal Alkane C34 101.039 1032 233 NC35 Normal Alkane C35 102.934 810 162 NC36 Normal Alkane C36 105.021 951 116 NC37 Normal Alkane C37 107.375 604 90 NC38 Normal Alkane C38 110.060 434 57 NC39 Normal Alkane C39 113.179 455 51 NC40 Normal Alkane C40 116.819 388 38 NC41 Normal Alkane C41 121.080 259 33 • AV • Weatherford W e a t h e # EXTRACT GC L A B O R A T O R f E$ Company: CONOCOPHILLIPS Client ID: US146113 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293027 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8111 FT Longitude: Bottom Depth: FT Extract GC Trace G2090772.D z Z H z z • Z z Z z ° z z _: z m. , ; 11 �Iyl z z u z z z z v �M1l1 h z z J 1 1 1 11111 WGC parameters Thompson Mango Ha Pristane /Phytane 2.18 A. BZ/n C6 0.96 P 16.09 Tr, 21.62 Pristane /n C17 0.58 B. TOUn C 1.66 P2 8.27 Tr 13.04 Phytane /n C 0.32 C. (n C +n C 7 ) /(CH +MCH) 0.40 P3 1.94 Tr 3.60 nC /(nC +nC 0.53 I. Isoheptane Value 1.15 5N, 4.70 Tr 3.10 n C 17 /(nC +nC 0.83 F. n C 7 /MCH 0.43 N2 5.13 Tr 6.70 CPI Hunt 1.06 U. CH /MCP 2.85 6N, 63.86 Tr 1.56 Normal Paraffins 20.0 R. n C 7 /2MH 4.21 K, 1.00 Tr 4.39 Isoprenoids 3.4 S. n C /22DMB K2 0.62 C 0.07 Cycloparaffins 2.8 H. Heptane Value 20.29 5N, /6N, 0.07 C2 0.50 Branched (iso -) Paraffins 0.5 MC /n C 7 2 .31 P3 /N2 0.38 C3 0.16 BTXaromatics 3.5 mpXYUn 1.12 In(24DMP /23DMP) -1.14 C 0.08 Resolved unknowns 69.2 C5 0.19 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.L,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146113 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8111 - FT Lab ID: CP293027 Sampling Point: File Name: G2090772.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 6.118 234 140 23DMB 2,3- Dimethylbutane 6.139 173 124 2MP 2- Methylpentane 6.195 923 592 3MP 3- Methylpentane 6.432 1052 644 NC6 Normal Alkane C6 6.795 4831 2850 22DMP 2,2- Dimethylpentane 7.428 309 198 MCP Methylcyclopentane 7.481 6822 3629 24DMP 2,4- Dimethylpentane 7.609 695 369 223TMB 2,2,3 - Trimethylbutane 7.759 118 55 BZ Benzene 8.212 4631 2266 33DMP 3,3- Dimethylpentane 8.418 347 157 CH Cyclohexane 8.533 19423 9639 2MH 2- Methylhexane 8.905 8808 4287 23DMP 2,3- Dimethylpentane 8.956 2173 1142 11DMCP 1,1- Dimethylcyclopentane 9.044 2841 1352 3MH 3- Methylhexane 9.240 10233 4948 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.469 4549 2150 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.581 4420 2078 3EP 3- Ethylpentane 9.641 815 617 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.693 7535 3512 NC7 Normal Alkane C7 10.276 37039 17307 ISTD Internal Standard MCH Methylcyclohexane 11.117 85552 37051 113TMCP 1,1,3, - Trimethylcyclopentane 11.279 5078 2169 ECP Ethylcyclopentane 11.680 3288 1434 124TMCP 1,2,4 - Trimethylcyclopentane 12.121 4894 2103 123TMCP 1,2,3 - Trimethylcyclopentane 12.485 4392 1860 TOL Toluene 12.795 61411 25897 NC8 Normal Alkane C8 15.415 81087 30042 IP9 Isoprenoid C9 17.269 8864 3368 EB Ethyl- benzene 17.962 12107 4543 MXYL m- xylene 18.465 70153 25838 PXYL p- xylene 18.524 20537 8581 OXYL o- xylene 19.709 29657 10143 NC9 Normal Alkane C9 21.121 87130 30337 IP10 Isoprenoid C10 23.097 13971 4115 PB Propyl- benzene 23.268 8796 2491 NC10 Normal Alkane C10 26.722 87266 26287 IP11 Isoprenoid C11 28.018 15764 4718 NC11 Normal Alkane C11 31.995 88289 25703 NC12 Normal Alkane C12 36.931 78644 22840 IP13 Isoprenoid C13 37.670 19872 5140 IP14 Isoprenoid C14 40.441 14043 4168 NC13 Normal Alkane C13 41.556 75160 22399 IP15 Isoprenoid C15 45.011 19723 5663 NC14 Normal Alkane C14 45.902 67804 19596 Company: CONOCOPHILLIPS Client ID: US146113 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8111 - FT Lab ID: CP293027 Sampling Point: File Name: G2090772.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.569 27590 6294 NC15 Normal Alkane C15 49.998 63073 16976 NC16 Normal Alkane C16 53.872 50668 14826 IP18 Isoprenoid C18 55.817 21914 4570 NC17 Normal Alkane C17 57.545 45501 13065 IP19 Isoprenoid C19 (Pristane) 57.904 26399 5080 PHEN Phenanthrene 58.963 3726 903 NC18 Normal Alkane C18 61.032 37435 11085 IP20 Isoprenoid C20 (Phytane) 61.484 12126 2122 NC19 Normal Alkane C19 64.356 33770 9537 NC20 Normal Alkane C20 67.522 30867 8497 NC21 Normal Alkane C21 70.549 26119 7441 C25HBI Highly Branch Isoprenoid C25 70.808 1667 363 NC22 Normal Alkane C22 73.447 23997 6793 NC23 Normal Alkane C23 76.223 21828 6117 NC24 Normal Alkane C24 78.890 19129 5250 NC25 Normal Alkane C25 81.452 17387 4611 NC26 Normal Alkane C26 83.919 14930 4100 NC27 Normal Alkane C27 86.295 12418 3299 NC28 Normal Alkane C28 88.589 9731 2589 NC29 Normal Alkane C29 90.804 9242 2275 41) NC30 Normal Alkane C30 92.949 6955 1698 NC31 Normal Alkane 031 95.020 5712 1414 NC32 Normal Alkane C32 97.028 4255 1071 NC33 Normal Alkane C33 98.977 5140 1063 NC34 Normal Alkane C34 100.868 3256 757 NC35 Normal Alkane C35 102.745 2938 608 NC36 Normal Alkane C36 104.796 2214 396 NC37 Normal Alkane C37 107.108 2107 308 NC38 Normal Alkane C38 109.749 1426 197 NC39 Normal Alkane C39 112.795 1689 175 NC40 Normal Alkane C40 116.322 1475 139 NC41 Normal Alkane C41 120.467 848 75 • • Weatherford TORIES* EXTRACT GC L A 8 0 R A T O R i E S Company: CONOCOPHILLIPS Client ID: US146114 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293028 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8114 FT Longitude: Bottom Depth: FT Extract GC Trace G2090774.D • z z z X O Z K H 0 . Z Z • O Z ltir , z z z z U u z - Z Z Z Z y U •• .1 Z Z Z ,1, a 5_ yy i Hill WGC parameters Thompson' Mango Halp Pristane /Phytane 2.15 A. BZ/n 0.72 P 13.76 Tr 27.61 Pristane /n C 0.57 B. TOUn C7 2.30 P2 7.21 Tr 12.00 Phytane /n C18 0.32 C. (n C + / (CH +MCH) 0.35 P3 1.83 Tr 3.40 nC /(nC +nC 0.52 I. Isoheptane Value 1.10 5N 4.45 Tr 2.88 nC /(nC +nC 0.83 F. n C 7 /MCH 0.38 N2 4.62 Tr 6.28 CPI Hunt 1.06 U. CH /MCP 2.92 6N 68.14 Tr 1.50 Normal Paraffins 22.2 R. n C 7 /2MH 4.17 K 0.99 Tr 4.08 Isoprenoids 4.0 S. n C /22DMB K2 0.61 C 0.08 Cycloparaffins 1.5 H. Heptane Value 18.76 5N 0.07 C2 0.50 40 Branched (iso-) Paraffins 0.3 MCH /nC 2.65 P /N 0.40 C3 0.17 BTXaromatics 2.5 mpXYUn 1.17 In(24DMP /23DMP) -1.07 C 0.08 Resolved unknowns 69.1 C 0.17 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.I.,1995,AAPG Bull.: V.79. p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146114 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8114 - FT Lab ID: CP293028 i i Sampling Point: File Name: G2090774.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 6.134 188 129 23DMB 2,3- Dimethylbutane 6.154 195 135 2MP 2- Methylpentane 6.210 841 549 3MP 3- Methylpentane 6.445 854 500 NC6 Normal Alkane C6 6.807 2429 1399 22DMP 2,2- Dimethylpentane 7.439 201 125 MCP Methylcyclopentane 7.492 3570 1878 24DMP 2,4- Dimethylpentane 7.620 426 218 223TMB 2,2,3 - Trimethylbutane 7.769 84 35 BZ Benzene 8.223 1751 831 33DMP 3,3- Dimethylpentane 8.428 207 94 CH Cyclohexane 8.542 10440 5128 2MH 2- Methylhexane 8.914 4673 2254 23DMP 2,3- Dimethylpentane 8.965 1239 641 11DMCP 1,1- Dimethylcyclopentane 9.053 1623 764 3MH 3- Methylhexane 9.248 5520 2640 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.478 2481 1159 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.590 2427 1127 3EP 3- Ethylpentane 9.649 425 319 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.702 4335 1975 NC7 Normal Alkane C7 10.282 19472 9064 ISTD Internal Standard MCH Methylcyclohexane 11.122 51594 22275 113TMCP 1,1,3, - Trimethylcyclopentane 11.286 3190 1345 ECP Ethylcyclopentane 11.687 1960 851 124TMCP 1,2,4 - Trimethylcyclopentane 12.127 3170 1355 123TMCP 1,2,3 - Trimethylcyclopentane 12.490 2919 1229 TOL Toluene 12.798 44804 18817 NC8 Normal Alkane C8 15.413 59839 22515 IP9 Isoprenoid C9 17.267 7161 2702 EB Ethyl- benzene 17.961 8968 3329 MXYL m- xylene 18.460 54045 20029 PXYL p- xylene 18.520 15697 6453 OXYL o- xylene 19.704 23945 8154 NC9 Normal Alkane C9 21.109 78343 27962 IP10 Isoprenoid C10 23.085 13171 3799 PB Propyl- benzene 23.256 7999 2219 NC10 Normal Alkane C10 26.707 90131 24259 IP11 Isoprenoid C11 28.007 16699 4319 NC11 Normal Alkane C11 31.988 102823 25178 NC12 Normal Alkane C12 36.927 98707 24936 IP13 Isoprenoid C13 37.667 24992 5593 IP14 Isoprenoid C14 40.437 18186 4660 • NC13 Normal Alkane C13 41.555 99283 25892 IP15 Isoprenoid C15 45.010 25593 6709 NC14 Normal Alkane C14 45.904 89912 24608 Company: CONOCOPHILLIPS Client ID: US146114 Well Name: GRANDVIEW 1 Project #: 09 -489 -A . Depth: 8114 - FT Lab ID: CP293028 Sampling Point: File Name: G2090774.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.567 36554 7957 NC15 Normal Alkane C15 50.002 84433 22126 NC16 Normal Alkane C16 53.875 69976 19872 IP18 Isoprenoid C18 55.816 30398 6208 NC17 Normal Alkane C17 57.547 63945 17840 IP19 Isoprenoid C19 (Pristane) 57.906 36528 7031 PHEN Phenanthrene 58.963 4766 1140 NC18 Normal Alkane C18 61.036 52588 15252 IP20 Isoprenoid C20 (Phytane) 61.486 16985 3029 NC19 Normal Alkane C19 64.357 47708 13299 NC20 Normal Alkane C20 67.524 43062 11801 NC21 Normal Alkane C21 70.552 36724 10581 C25HBI Highly Branch Isoprenoid C25 70.810 2381 506 NC22 Normal Alkane C22 73.447 33457 9154 NC23 Normal Alkane C23 76.226 30212 8627 NC24 Normal Alkane C24 78.891 26327 7320 NC25 Normal Alkane C25 81.454 23989 6667 NC26 Normal Alkane C26 83.920 20861 5795 NC27 Normal Alkane C27 86.297 17187 4678 NC28 Normal Alkane C28 88.589 13605 3654 NC29 Normal Alkane C29 90.805 12985 3171 S NC30 Normal Alkane C30 92.947 9767 2472 NC31 Normal Alkane C31 95.021 8126 2027 NC32 Normal Alkane C32 97.030 5952 1497 NC33 Normal Alkane C33 98.978 7546 1517 NC34 Normal Alkane C34 100.865 4688 1042 NC35 Normal Alkane C35 102.745 4051 869 NC36 Normal Alkane C36 104.797 2888 536 NC37 Normal Alkane C37 107.112 2467 405 NC38 Normal Alkane C38 109.761 2004 278 NC39 Normal Alkane C39 112.787 1829 209 NC40 Normal Alkane C40 116.332 1476 157 NC41 Normal Alkane C41 120.473 1159 108 S iv • Weatherford EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146116 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293030 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8120 FT Longitude: Bottom Depth: FT Extract GC Trace G2090775.D z z Z z z z • I 7. z z o z a I .. ., z -2"::, ., ' .. z z z cv � " � z .. z z u u ^' u u u m P ' w = V u I I I I z ' .nl.4..w... WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.17 A. BZIn C6 3.29 P, 12.84 Tr, 57.20 Pristane /n C17 0.57 B. TOL/n 3.26 P2 5.09 Tr 17.55 Phytane /n C18 0.33 C. (n C +nC /(CH +MCH) 0.36 P3 1.00 Tr 3.85 n C t8 /(nC +nC 0.53 I. IsoheptaneValue 1.02 5N, 3.63 Tr 3.11 nC, +nC 0.84 F. n C 7 /MCH 0.40 N2 3.43 Tr 6.96 CPI Hunt 1.06 U. CH /MCP 4.01 6N, 74.00 Tr 1.84 Normal Paraffins 22.0 R. n C 7 /2MH 5.64 K, 0.96 Tr 5.18 Isoprenoids 3.9 S. n C 6 /22DMB K2 0.60 C 0.05 Cycloparaffins 2.4 H. Heptane Value 20.89 5N 0.05 C2 0.54 Branched (iso -) Paraffins 0.3 MCH /nC 2.50 P /N 0.29 C3 0.11 BTXaromatics 5.7 mpXYUn 1.60 In(24DMP /23DMP) -1.58 C 0.07 Resolved unknowns 64.9 C 0.23 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,I994.GCA: V.58, p.895. 3 Halpern,H.I.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146116 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8120 - FT Lab ID: CP293030 Ill Sampling Point: File Name: G2090775.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 6.107 64 35 23DMB 2,3- Dimethylbutane 6.129 33 28 2MP 2- Methylpentane 6.185 230 138 3MP 3- Methylpentane 6.424 329 199 NC6 Normal Alkane C6 6.788 2688 1554 22DMP 2,2- Dimethylpentane 7.432 214 121 MCP Methylcyclopentane 7.476 5113 2751 24DMP 2,4- Dimethylpentane 7.605 435 229 223TMB 2,2,3 - Trimethylbutane 7.755 70 34 BZ Benzene 8.207 8833 4425 33DMP 3,3- Dimethylpentane 8.414 281 127 CH Cyclohexane 8.528 20522 10225 2MH 2- Methylhexane 8.901 9123 4482 23DMP 2,3- Dimethylpentane 8.951 2112 1115 11DMCP 1,1- Dimethylcyclopentane 9.039 2929 1398 3MH 3- Methylhexane 9.235 11275 5485 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.465 5417 2582 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.577 5384 2552 • 3EP 3- Ethylpentane 9.636 895 637 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.689 9189 4311 NC7 Normal Alkane C7 10.271 51414 24144 ISTD Internal Standard MCH Methylcyclohexane 11.114 128767 55749 113TMCP 1,1,3, - Trimethylcyclopentane 11.274 7045 3029 ECP Ethylcyclopentane 11.675 5342 2334 124TMCP 1,2,4- Trimethylcyclopentane 12.115 7483 3203 123TMCP 1,2,3 - Trimethylcyclopentane 12.479 6864 2897 TOL Toluene 12.797 167533 68986 NC8 Normal Alkane C8 15.416 149489 53012 IP9 Isoprenoid C9 17.263 16428 6232 EB Ethyl- benzene 17.956 31871 11993 MXYL m- xylene 18.474 185906 61939 PXYL p- xylene 18.528 53586 24472 OXYL o- xylene 19.713 76832 26217 NC9 Normal Alkane C9 21.129 174297 52919 IP10 Isoprenoid C10 23.100 28288 7628 PB Propyl- benzene 23.267 20047 5508 NC10 Normal Alkane C10 26.734 173966 48192 IP11 Isoprenoid C11 28.022 31177 8984 NC11 Normal Alkane C11 32.008 176939 48757 NC12 Normal Alkane C12 36.942 145754 42842 IP13 Isoprenoid C13 37.674 38052 9602 IP14 Isoprenoid C14 40.443 26485 7886 • NC13 Normal Alkane C13 41.567 143033 41238 IP15 Isoprenoid C15 45.016 39284 11347 NC14 Normal Alkane C14 45.914 124260 35454 Company: CONOCOPHILLIPS Client ID: US146116 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8120 - FT Lab ID: CP293030 Sampling Point: File Name: G2090775.D Peak Compound Ret, ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.574 50643 11611 NC15 Normal Alkane C15 50.009 112861 29801 NC16 Normal Alkane C16 53.881 87814 25693 IP18 Isoprenoid C18 55.820 37652 7985 NC17 Normal Alkane C17 57.553 77886 21750 IP19 Isoprenoid C19 (Pristane) 57.913 44662 8575 PHEN Phenanthrene 58.964 9575 2566 NC18 Normal Alkane C18 61.040 62918 18146 IP20 Isoprenoid C20 (Phytane) 61.499 20599 3627 NC19 Normal Alkane C19 64.361 56044 15781 NC20 Normal Alkane C20 67.527 50660 13948 NC21 Normal Alkane C21 70.555 42020 11787 C25HBI Highly Branch Isoprenoid C25 70.812 2905 661 NC22 Normal Alkane C22 73.451 38178 10716 NC23 Normal Alkane C23 76.228 34246 9585 NC24 Normal Alkane C24 78.893 29868 8306 NC25 Normal Alkane C25 81.457 26821 7339 NC26 Normal Alkane C26 83.920 23050 6198 NC27 Normal Alkane C27 86.298 18833 4924 NC28 Normal Alkane C28 88.591 14867 3915 NC29 Normal Alkane C29 90.803 14290 3518 • NC30 Normal Alkane C30 92.947 10625 2687 NC31 Normal Alkane C31 95.022 8777 2207 NC32 Normal Alkane C32 97.029 6471 1636 NC33 Normal Alkane C33 98.979 8260 1635 NC34 Normal Alkane C34 100.868 5111 1129 NC35 Normal Alkane C35 102.745 4545 937 NC36 Normal Alkane C36 104.796 3550 606 NC37 Normal Alkane C37 107.115 2740 441 NC38 Normal Alkane C38 109.754 2080 310 NC39 Normal Alkane C39 112.792 1902 232 NC40 Normal Alkane C40 116.333 1885 194 NC41 Normal Alkane C41 120.463 1379 126 • Ile • Weatherford* EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146121 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293035 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8134 FT Longitude: Bottom Depth: FT Extract GC Trace G2090789.D P '' z • z Z E z Z Z U L2 Z iiiiitiA01, ji E7 r■ , - - Z _ a I r+ v Z Z Z U ^i I : A Z U m £ Z E 4 � z z WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.12 A. BZ/n C6 3.41 P, 8.80 Tr, 119.15 Pristane /n C 0.55 B. TOL/n C 6.81 P2 3.22 Tr 17.50 Phytane /n C18 0.32 C. (n C + /(CH +MCH) 0.35 P3 0.62 Tr 3.58 nC18 /(nC18 +nCis) 0.53 I. Isoheptane Value 0.98 5N, 2.59 Tr 2.82 nC /(nC +n C 29 ) 0.88 F. nC /MCH 0.39 N2 2.20 Tr 6.40 CPI Hunt 1.07 U. CH /MCP 4.16 6N, 82.58 Tr 1.68 Normal Paraffins 25.0 R. nC /2MH 6.21 K, 0.95 Tr 5.37 Isoprenoids 5.1 S. nC K2 0.59 C 0.05 Cycloparaffins 0.8 H. Heptane Value 20.83 5N 0.03 C2 0.59 0 Branched (iso -) Paraffins 0.1 MCH /n 2.58 P /N 0.28 C3 0.12 BTX aromatics 4.2 mpXYL/n 2.67 In(24DMP /23DMP) -1.56 C4 0.10 Resolved unknowns 64.0 C5 0.13 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.1.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146121 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8134 - FT Lab ID: CP293035 Sampling Point: File Name: G2090789.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 lso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.837 44 21 23DMB 2,3- Dimethylbutane 5.868 16 11 2MP 2- Methylpentane 5.935 86 54 3MP 3- Methylpentane 6.205 118 71 NC6 Normal Alkane C6 6.595 825 504 22DMP 2,2- Dimethylpentane 7.250 63 36 MCP Methylcyclopentane 7.307 1593 887 24DMP 2,4- Dimethylpentane 7.440 144 73 223TMB 2,2,3 - Trimethylbutane 7.592 35 16 BZ Benzene 8.055 2813 1401 33DMP 3,3- Dimethylpentane 8.265 114 50 CH Cyclohexane 8.380 6622 3395 2MH 2- Methylhexane 8.761 2737 1373 23DMP 2,3- Dimethylpentane 8.812 687 358 11DMCP 1,1- Dimethylcyclopentane 8.900 971 469 3MH 3- Methylhexane 9.100 3477 1718 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.333 1647 785 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.446 1634 787 III 3EP 3- Ethylpentane 9.502 150 146 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.560 3056 1382 NC7 Normal Alkane C7 10.151 16989 7985 ISTD Internal Standard MCH Methylcyclohexane 11.001 43758 19180 113TMCP 1,1,3, - Trimethylcyclopentane 11.170 2243 935 ECP Ethylcyclopentane 11.576 1944 847 124TMCP 1,2,4 - Trimethylcyclopentane 12.023 2363 1010 123TMCP 1,2,3 - Trimethylcyclopentane 12.393 2183 924 TOL Toluene 12.710 115696 48435 NC8 Normal Alkane C8 15.358 62189 22848 IP9 Isoprenoid C9 17.228 7331 2759 EB Ethyl- benzene 17.930 20651 7775 MXYL m- xylene 18.445 128759 45421 PXYL p- xylene 18.501 37293 16159 OXYL o- xylene 19.691 55286 19589 NC9 Normal Alkane C9 21.107 100809 36051 IP10 Isoprenoid C10 23.084 16870 5445 PB Propyl- benzene 23.253 15745 5011 NC10 Normal Alkane C10 26.718 134101 45278 IP11 Isoprenoid C11 28.008 24889 8502 NC11 Normal Alkane C11 31.996 168513 53711 NC12 Normal Alkane C12 36.932 160098 49500 IP13 Isoprenoid C13 37.663 44874 12440 IP14 Isoprenoid C14 40.432 32476 10451 • NC13 Normal Alkane C13 41.557 171163 50572 IP15 Isoprenoid C15 45.005 55362 16703 NC14 Normal Alkane C14 45.906 169299 50497 Company: CONOCOPHILLIPS Client ID: US146121 Well Name: GRANDVIEW 1 Project #: 09 -489 -A • Depth: 8134 - FT Lab ID: CP293035 Sampling Point: File Name: G2090789.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.564 73358 16982 NC15 Normal Alkane C15 50.005 166963 44714 NC16 Normal Alkane C16 53.875 130532 38295 IP18 Isoprenoid C18 55.809 54402 11591 NC17 Normal Alkane C17 57.545 116532 33021 IP19 Isoprenoid C19 (Pristane) 57.901 63852 12300 PHEN Phenanthrene 58.950 19452 5356 NC18 Normal Alkane C18 61.032 93422 27738 IP20 Isoprenoid C20 (Phytane) 61.481 30063 5321 NC19 Normal Alkane C19 64.352 82671 22982 NC20 Normal Alkane C20 67.518 75015 20268 NC21 Normal Alkane C21 70.542 59942 17100 C25HBI Highly Branch Isoprenoid C25 70.798 4598 1046 NC22 Normal Alkane C22 73.437 52884 14785 NC23 Normal Alkane C23 76.215 45717 12812 NC24 Normal Alkane C24 78.877 38024 10649 NC25 Normal Alkane C25 81.440 32771 9032 NC26 Normal Alkane C26 83.904 27289 7264 NC27 Normal Alkane C27 86.281 21623 5851 NC28 Normal Alkane C28 88.572 16677 4449 NC29 Normal Alkane C29 90.788 15847 3801 I. N 30 Normal Alkane C30 92.930 11611 2921 N C31 Normal Alkane C31 95.003 9440 2220 NC32 Normal Alkane C32 97.009 6868 1693 NC33 Normal Alkane C33 98.954 9285 1695 NC34 Normal Alkane C34 100.847 4988 1095 NC35 Normal Alkane C35 102.723 4020 837 NC36 Normal Alkane C36 104.772 2835 537 NC37 Normal Alkane C37 107.073 2676 412 NC38 Normal Alkane C38 109.714 1925 288 NC39 Normal Alkane C39 112.771 1439 180 NC40 Normal Alkane C40 116.285 1386 142 NC41 Normal Alkane C41 120.416 1089 93 • • WeatherfoE rd$ EXTRACT GC L A B O R A T O R 1 E$ Company: CONOCOPHILLIPS Client ID: US146117 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293031 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8123 FT Longitude: Bottom Depth: FT Extract GC Trace G2090790.D • z Z z a z z z U, i YPo a Z M U n M £ r Z U Z U U Z z L Z Z Z li+ 1 < .!1111. 71 _ X111 WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.05 A. BZ/n C6 2.47 P, 10.93 Tr, 78.91 Pristane /n C17 0.56 B. TOL/n C7 4.59 P2 4.18 Tr 17.20 Phytane /n C,8 0.34 C. (n C +n C /(CH +MCH) 0.36 P 0.80 Tr 3.66 nC, /(nC, +n C 0.53 I. Isoheptane Value 0.97 5N, 3.20 Tr 2.91 n C /(nC +n C 0.84 F. n C /MCH 0.39 N2 2.94 Tr 6.57 CPI Hunt 1.09 U. CH /MCP 3.78 6N, 77.95 Tr 1.80 Normal Paraffins 22.4 R. n C /2MH 5.91 K, 0.95 Tr 5.31 Isoprenoids 4.2 S. n C K2 0.59 C, 0.05 Cycloparaffins 1.8 H. Heptane Value 20.56 5N 0.04 C2 0.57 III Branched (iso -) Paraffins 0.2 MCH /n C 2.54 P /N 0.27 C 0.12 BTX aromatics 5.4 mpXYL/nC 1.99 In(24DMP /23DMP) -1.56 C4 0.08 Resolved unknowns 65.4 C5 0.18 'Thompson, K.F.M.,I983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146117 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8123 - FT Lab ID: CP293031 Sampling Point: File Name: G2090790.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.828 46 30 23DMB 2,3- Dimethylbutane 5.856 18 14 2MP 2- Methylpentane 5.926 147 96 3MP 3- Methylpentane 6.197 197 118 NC6 Normal Alkane C6 6.588 1300 787 22DMP 2,2- Dimethylpentane 7.243 69 39 MCP Methylcyclopentane 7.301 2198 1236 24DMP 2,4- Dimethylpentane 7.433 161 87 223TMB 2,2,3 - Trimethylbutane 7.586 28 14 BZ Benzene 8.049 3217 1588 33DMP 3,3- Dimethylpentane 8.259 109 48 CH Cyclohexane 8.374 8304 4230 2MH 2- Methylhexane 8.755 3161 1594 23DMP 2,3- Dimethylpentane 8.806 767 404 11DMCP 1,1- Dimethylcyclopentane 8.895 1086 527 3MH 3- Methylhexane 9.094 3972 1973 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.327 1974 956 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.440 1958 946 3EP 3- Ethylpentane 9.499 238 199 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.554 3452 1599 NC7 Normal Alkane C7 10.146 18675 8867 ISTD Internal Standard MCH Methylcyclohexane 10.996 47467 20849 113TMCP 1,1,3, - Trimethylcyclopentane 11.164 2399 1011 1 ECP Ethylcyclopentane 11.570 2019 880 124TMCP 1,2,4 - Trimethylcyclopentane 12.018 2572 1104 123TMCP 1,2,3 - Trimethylcyclopentane 12.387 2372 1004 TOL Toluene 12.703 85700 36221 NC8 Normal Alkane C8 15.353 54100 19950 IP9 Isoprenoid C9 17.224 5993 2267 EB Ethyl- benzene 17.926 14055 5256 MXYL m- xylene 18.434 83342 30260 PXYL p - xylene 18.493 24586 10236 OXYL o- xylene 19.685 34834 12315 NC9 Normal Alkane C9 21.099 66970 24248 IP10 Isoprenoid C10 23.079 10684 3430 PB Propyl- benzene 23.249 8939 2787 NC10 Normal Alkane C10 26.704 72887 25260 IP11 Isoprenoid C11 28.002 13554 4601 NC11 Normal Alkane C11 31.978 80001 26110 NC12 Normal Alkane C12 36.913 72758 23818 IP13 Isoprenoid C13 37.654 19419 5211 IP14 Isoprenoid C14 40.423 13351 4297 • NC13 Normal Alkane C13 41.537 74733 23975 IP15 Isoprenoid C15 44.994 23050 6913 NC14 Normal Alkane C14 45.885 69131 21102 Company: CONOCOPHILLIPS Client ID: US146117 Well Name: GRANDVIEW 1 Project #: 09 -489 -A fib Depth: 8123 - FT Lab ID: CP293031 Sampling Point: File Name: G2090790.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.552 29625 6822 NC15 Normal Alkane C15 49.982 64836 18204 NC16 Normal Alkane C16 53.854 52195 15464 IP18 Isoprenoid C18 55.799 22353 4747 NC17 Normal Alkane C17 57.525 47469 13749 IP19 Isoprenoid C19 (Pristane) 57.887 26799 5178 PHEN Phenanthrene 58.941 8739 2374 NC18 Normal Alkane C18 61.015 38373 11298 IP20 Isoprenoid C20 (Phytane) 61.473 13048 2292 NC19 Normal Alkane C19 64.336 34611 9991 NC20 Normal Alkane C20 67.502 32065 8554 NC21 Normal Alkane C21 70.531 26079 7439 C25HBI Highly Branch Isoprenoid C25 70.794 2305 496 NC22 Normal Alkane C22 73.426 23845 6601 NC23 Normal Alkane C23 76.204 21463 6121 NC24 Normal Alkane C24 78.870 18154 5135 NC25 Normal Alkane C25 81.431 16141 4471 NC26 Normal Alkane C26 83.899 14166 3849 NC27 Normal Alkane C27 86.274 11664 3162 NC28 Normal Alkane C28 88.569 9323 2442 NC29 Normal Alkane C29 90.783 9016 2202 NC30 Normal Alkane C30 92.928 6745 1675 NC31 Normal Alkane C31 94.999 5638 1419 NC32 Normal Alkane C32 97.007 4156 1015 NC33 Normal Alkane C33 98.948 7648 1457 NC34 Normal Alkane C34 100.844 2955 667 NC35 Normal Alkane C35 102.719 2473 525 NC36 Normal Alkane C36 104.769 1947 331 NC37 Normal Alkane C37 107.076 1631 237 NC38 Normal Alkane C38 109.707 1168 163 NC39 Normal Alkane C39 112.765 772 101 NC40 Normal Alkane C40 116.292 860 87 NC41 Normal Alkane C41 120.430 692 61 • • Weatherfort EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146118 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293032 Lease: Sample Type: CORE Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8125 FT Longitude: Bottom Depth: FT Extract GC Trace G2090791.D F Z • Z • E z Z z _ X ti v Z N - Z a. Z .. 4 Y4Y Z Z ..• LI 0.1444 k L kL ffl m mI Z ._, WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.19 A. BZ/n C6 2.76 P 6.17 Tr, 178.70 Pristane /n C17 0.57 B. TOUnC 11.24 P2 2.22 Tr 15.89 Phytane /n C18 0.33 C. (n C +n C 7 ) /(CH +MCH) 0.32 P3 0.53 Tr 3.28 nC /(nC +n C 1s ) 0.54 I. Isoheptane Value 0.96 5N, 1.95 Tr 2.43 nC /(nC +nC 0.89 F. nC /MCH 0.34 N2 1.53 Tr 5.72 CPI Hunt 1.07 U. CH /MCP 4.30 6N, 87.60 Tr 1.47 Normal Paraffins 24.8 R. nC /2MH 6.54 K, 0.93 Tr 4.35 Isoprenoids 5.1 S. nC /22DMB K2 0.59 C 0.06 Cycloparaffins 0.5 H. Heptane Value 19.47 5N 0.02 C2 0.55 al Branched (iso -) Paraffins 0.1 MCH /n 2.96 P /N 0.35 C3 0.10 BTX aromatics 3.2 mpXYUn 1.80 In(24DMP/23DMP) -1.75 C4 0.11 Resolved unknowns 65.8 C5 0.19 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. 'Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146118 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8125 - FT Lab ID: CP293032 Sampling Point: File Name: G2090791.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.940 37 21 3MP 3- Methylpentane 6.209 49 29 NC6 Normal Alkane C6 6.599 323 186 22DMP 2,2- Dimethylpentane 7.252 26 13 MCP Methylcyclopentane 7.310 418 229 24DMP 2,4- Dimethylpentane 7.442 43 22 223TMB 2,2,3- Trimethylbutane 7.597 22 7 BZ Benzene 8.059 892 424 33DMP 3,3- Dimethylpentane 8.267 48 19 CH Cyclohexane 8.382 1798 913 2MH 2- Methylhexane 8.763 829 414 23DMP 2,3- Dimethylpentane 8.813 248 127 11DMCP 1,1- Dimethylcyclopentane 8.902 341 162 3MH 3- Methylhexane 9.102 1120 544 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.334 499 235 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.447 502 238 3EP 3- Ethylpentane 9.505 83 65 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.561 1021 467 NC7 Normal Alkane C7 10.152 5419 2524 ISTD Internal Standard MCH Methylcyclohexane 11.000 16059 7055 113TMCP 1,1,3, - Trimethylcyclopentane 11.170 1150 476 ECP Ethylcyclopentane 11.576 696 296 124TMCP 1,2,4 - Trimethylcyclopentane 12.024 1186 507 123TMCP 1,2,3- Trimethylcyclopentane 12.393 1154 485 TOL Toluene 12.706 60935 25668 NC8 Normal Alkane C8 15.354 37116 13886 IP9 Isoprenoid C9 17.226 4966 1862 EB Ethyl- benzene 17.928 8329 3089 MXYL m- xylene 18.432 51991 19235 PXYL p- xylene 18.492 14889 6027 OXYL o- xylene 19.685 23190 7929 NC9 Normal Alkane C9 21.100 68774 25016 !P10 Isoprenoid C10 23.080 12447 3967 PB Propyl- benzene 23.251 8099 2488 NC10 Normal Alkane C10 26.708 90393 31223 IP11 Isoprenoid C11 28.003 17479 5934 NC11 Normal Alkane C11 31.984 109656 35440 NC12 Normal Alkane C12 36.920 106226 34112 IP13 Isoprenoid C13 37.655 28441 7863 IP14 Isoprenoid C14 40.424 20433 6640 • NC13 Normal Alkane C13 41.545 111601 34522 IP15 Isoprenoid C15 44.995 29728 9123 NC14 Normal Alkane C14 45.892 105334 32420 Company: CONOCOPHILLIPS Client ID: US146118 Well Name: GRANDVIEW 1 Project #: 09 -489 -A S Depth: 8125 - FT Lab ID: CP293032 Sampling Point: File Name: G2090791.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.555 43263 10052 NC15 Normal Alkane C15 49.988 98428 27146 NC16 Normal Alkane C16 53.859 73916 22094 1P18 Isoprenoid C18 55.800 31072 6541 NC17 Normal Alkane C17 57.531 63671 18652 IP19 Isoprenoid C19 (Pristane) 57.889 36297 7118 PHEN Phenanthrene 58.942 6199 1598 NC18 Normal Alkane C18 61.018 50690 14833 IP20 Isoprenoid C20 (Phytane) 61.472 16552 2965 NC19 Normal Alkane C19 64.339 43665 12326 NC20 Normal Alkane C20 67.505 38423 10652 NC21 Normal Alkane C21 70.531 30445 8750 C25HBI Highly Branch Isoprenoid C25 70.793 2041 454 NC22 Normal Alkane C22 73.428 26478 7351 NC23 Normal Alkane C23 76.206 22567 6422 NC24 Normal Alkane C24 78.870 18772 5226 NC25 Normal Alkane C25 81.433 16336 4470 NC26 Normal Alkane C26 83.897 13586 3684 NC27 Normal Alkane C27 86.275 10919 2872 NC28 Normal Alkane C28 88.570 8088 2157 NC29 Normal Alkane C29 90.781 7617 1833 NC30 Normal Alkane C30 92.926 5408 1319 NC31 Normal Alkane C31 95.000 4334 988 NC32 Normal Alkane C32 97.007 3138 724 NC33 Normal Alkane C33 98.954 3857 734 NC34 Normal Alkane C34 100.850 2182 457 NC35 Normal Alkane C35 102.721 1762 351 NC36 Normal Alkane C36 104.764 1164 215 NC37 Normal Alkane C37 107.071 1142 168 NC38 Normal Alkane C38 109.721 748 104 NC39 Normal Alkane C39 112.762 521 70 NC40 Normal Alkane C40 116.287 627 63 NC41 Normal Alkane C41 120.418 490 45 • IV Weatherford` EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146119 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293033 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE- OXFORDIAN Latitude: Top Depth: 8128 FT Longitude: Bottom Depth: FT Extract GC Trace G2090792.D r z z Z U Z Z Z Z a. Z C a. Z Z U 1 [ £ Z y m n M U U U U ••- '1 Z Z Z Z Z Z Z Z Z Z a. _e __ el ill W parameters Thompson' Mango Halpern Pristane /Phytane 2.18 A. BZ/n C6 1.98 P, 11.73 Tr, 60.49 Pristane /n C17 0.55 B. TOUn C, 3.99 P2 5.06 Tr 15.15 Phytane /n C18 0.32 C. (n C +n C,) /(CH +MCH) 0.38 P 1.15 Tr 3.58 n C 18 /(nC +nC 0.54 I. Isoheptane Value 1.11 5N, 3.34 Tr 2.95 nC /(nC +n C 29 ) 0.90 F. n C, /MCH 0.41 N2 3.20 Tr 6.53 CPI Hunt 1.04 U. CH /MCP 3.45 6N, 75.53 Tr, 1.56 Normal Paraffins 21.9 R. n C, /2MH 5.13 K 0.98 Tr 4.54 Isoprenoids 4.1 S. n C K 0.61 C 0.06 Cycloparaffins 1.6 H. Heptane Value 20.79 5N 0.04 C2 0.52 0 Branched (iso -) Paraffins 0.2 MCH /n C, 2.45 P /N 0.36 C3 0.13 BTX aromatics 5.0 mpXYUn 1.84 In(24DMP /23DMP) 1.36 C4 0.09 Resolved unknowns 66.5 C 0.19 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 1-falpern,H.L,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146119 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8128 - FT Lab ID: CP293033 1 . Sampling Point: File Name: G2090792.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.844 66 31 23DMB 2,3- Dimethylbutane 5.870 28 20 2MP 2- Methylpentane 5.941 199 126 3MP 3- Methylpentane 6.210 238 146 NC6 Normal Alkane C6 6.600 1285 790 22DMP 2,2- Dimethylpentane 7.254 99 57 MCP Methylcyclopentane 7.312 2002 1105 24DMP 2,4- Dimethylpentane 7.444 203 109 223TMB 2,2,3 - Trimethylbutane 7.597 48 22 BZ Benzene 8.060 2541 1266 33DMP 3,3- Dimethylpentane 8.269 137 64 CH Cyclohexane 8.385 6915 3519 2MH 2- Methylhexane 8.765 3137 1573 23DMP 2,3- Dimethylpentane 8.816 793 414 11DMCP 1,1- Dimethylcyclopentane 8.905 1063 511 3MH 3- Methylhexane 9.105 3807 1867 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.337 1679 804 4110 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.450 1654 789 3EP 3- Ethylpentane 9.512 296 218 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.564 2914 1362 NC7 Normal Alkane C7 10.155 16105 7561 ISTD Internal Standard MCH Methylcyclohexane 11.004 39397 17192 113TMCP 1,1,3, - Trimethylcyclopentane 11.173 2212 914 ECP Ethylcyclopentane 11.578 1667 720 124TMCP 1,2,4 - Trimethylcyclopentane 12.025 2170 929 123TMCP 1,2,3- Trimethylcyclopentane 12.394 1978 834 TOL Toluene 12.707 64303 26907 NC8 Normal Alkane C8 15.354 51093 19005 IP9 Isoprenoid C9 17.222 5582 2099 EB Ethyl- benzene 17.924 11920 4439 MXYL m- xylene 18.429 72785 26726 PXYL p - xylene 18.488 21458 8838 OXYL o- xylene 19.680 31064 10898 NC9 Normal Alkane C9 21.095 72991 26273 IP10 Isoprenoid C10 23.076 11712 3696 PB Propyl- benzene 23.246 8846 2710 NC10 Normal Alkane C10 26.702 83364 28179 IP11 Isoprenoid C11 28.000 14325 4776 NC11 Normal Alkane C11 31.977 87670 27726 NC12 Normal Alkane C12 36.912 75036 23818 IP13 Isoprenoid C13 37.653 19382 5317 IP14 Isoprenoid C14 40.422 13263 4230 • NC13 Normal Alkane C13 41.536 72514 22593 IP15 Isoprenoid C15 44.994 19962 6013 NC14 Normal Alkane C14 45.882 63788 19445 Company: CONOCOPHILLIPS Client ID: US146119 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8128 - FT Lab ID: CP293033 Sampling Point: File Name: G2090792.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IP16 Isoprenoid C16 48.553 25349 5891 NC15 Normal Alkane C15 49.979 57521 16012 NC16 Normal Alkane C16 53.851 44039 13077 IP18 Isoprenoid C18 55.797 18198 3860 NC17 Normal Alkane C17 57.525 38307 10937 IP19 Isoprenoid C19 (Pristane) 57.882 21011 4038 PHEN Phenanthrene 58.942 5402 1429 NC18 Normal Alkane C18 61.011 30096 8737 IP20 Isoprenoid C20 (Phytane) 61.473 9658 1706 NC19 Normal Alkane C19 64.331 26028 7436 NC20 Normal Alkane C20 67.499 22983 6314 NC21 Normal Alkane C21 70.527 18283 5289 C25HBI Highly Branch Isoprenoid C25 70.790 1356 293 NC22 Normal Alkane C22 73.424 16017 4497 NC23 Normal Alkane C23 76.201 13670 3833 NC24 Normal Alkane C24 78.866 11371 3178 NC25 Normal Alkane C25 81.428 9661 2677 NC26 Normal Alkane C26 83.894 7888 2106 NC27 Normal Alkane C27 86.271 6054 1643 NC28 Normal Alkane C28 88.564 4565 1220 NC29 Normal Alkane C29 90.780 4145 1025 NC30 Normal Alkane C30 92.924 2969 736 NC31 Normal Alkane C31 94.996 2287 579 NC32 Normal Alkane C32 97.002 1944 455 NC33 Normal Alkane C33 98.954 2086 417 NC34 Normal Alkane C34 100.845 1188 263 NC35 Normal Alkane C35 102.719 983 213 NC36 Normal Alkane C36 104.768 743 134 NC37 Normal Alkane C37 107.071 691 104 NC38 Normal Alkane C38 109.713 491 72 NC39 Normal Alkane C39 112.751 382 49 NC40 Normal Alkane C40 116.274 403 38 NC41 Normal Alkane C41 120.419 329 27 ill VP 0 Weaera EXTRACT GC L A S O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146120 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293034 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8131 FT Longitude: Bottom Depth: FT Extract GC Trace G2090793.D U U F Z Z E III „.., Z Z Z U U Z Z E .,":, 0 X U O y Z ,. ' -A „' r+ r Z Z Z U � � P m w m m , i Z U, m m o ., N M m r, ,. m , 0 9 gy :T , r Z Z Z U U n r, Z Z Z Z Z Z Z Z Z 7 7 �: --� 4 Z Z Z Z 'ills i WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.17 A. BZ/n C6 2.59 P 10.45 Tr, 68.42 Pristane /nC 0.55 B. TOUnC, 4.70 P2 4.63 Tr 14.55 Phytane /n C18 0.32 C. (n C6 + /(CH +MCH) 0.34 P3 1.09 Tr 3.57 n C 18 /(nC +nC 0.53 I. Isoheptane Value 1.06 5N, 3.22 Tr 2.89 n C 17 /(nC +nC 0.90 F. n C 7 /MCH 0.37 N2 3.03 Tr 6.45 CPI Hunt 1.07 U. CH /MCP 3.82 6N, 77.59 Tr 1.59 Normal Paraffins 21.2 R. n C 7 /2MH 5.04 K 0.97 Tr 4.41 Isoprenoids 4.1 S. n C 6 /22DMB K2 0.60 C, 0.06 Cycloparaffins 1.4 H. Heptane Value 19.36 5N 0.04 C2 0.52 40 Branched (iso -) Paraffins 0.2 MCH /n C, 2.73 P /N 0.36 C3 0.12 BTXaromatics 4.5 mpXYUn 1.89 In(24DMP /23DMP) -1.44 C4 0.09 Resolved unknowns 67.9 C 0.20 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146120 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 1 1) Depth: 8131 - FT Lab ID: CP293034 Sampling Point: File Name: G2090793.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.820 44 21 23DMB 2,3- Dimethylbutane 5.844 19 12 2MP 2- Methylpentane 5.916 106 67 3MP 3- Methylpentane 6.184 138 79 NC6 Normal Alkane C6 6.573 725 431 22DMP 2,2- Dimethylpentane 7.225 64 35 MCP Methylcyclopentane 7.283 1260 695 24DMP 2,4- Dimethylpentane 7.414 131 68 223TMB 2,2,3 - Trimethylbutane 7.567 36 15 BZ Benzene 8.030 1875 923 33DMP 3,3- Dimethylpentane 8.238 94 41 CH Cyclohexane 8.354 4809 2448 2MH 2- Methylhexane 8.733 2086 1044 23DMP 2,3- Dimethylpentane 8.784 554 286 11DMCP 1,1- Dimethylcyclopentane 8.873 723 351 3MH 3- Methylhexane 9.072 2580 1267 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.305 1172 561 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.418 1153 550 3EP 3- Ethylpentane 9.479 216 148 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.532 2070 977 NC7 Normal Alkane C7 10.122 10523 4943 ISTD Internal Standard MCH Methylcyclohexane 10.973 28677 12537 113TMCP 1,1,3, - Trimethylcyclopentane 11.142 1642 685 ECP Ethylcyclopentane 11.549 1174 511 124TMCP 1,2,4 - Trimethylcyclopentane 11.997 1623 693 123TMCP 1,2,3 - Trimethylcyclopentane 12.366 1494 629 TOL Toluene 12.679 49467 20849 NC8 Normal Alkane C8 15.333 36750 13707 IP9 Isoprenoid C9 17.209 4237 1598 EB Ethyl- benzene 17.912 8832 3273 MXYL m- xylene 18.417 53744 19929 PXYL p- xylene 18.477 15873 6400 OXYL o- xylene 19.672 22926 8030 NC9 Normal Alkane C9 21.087 51014 18559 IP10 Isoprenoid C10 23.071 8322 2661 PB Propyl- benzene 23.242 6388 1971 NC10 Normal Alkane C10 26.697 59420 20517 IP11 Isoprenoid C11 27.998 10447 3572 NC11 Normal Alkane C11 31.975 67644 22048 NC12 Normal Alkane C12 36.911 61553 20170 IP13 Isoprenoid C13 37.653 15167 4264 IP14 Isoprenoid C14 40.422 11171 3583 • NC13 Normal Alkane C13 41.536 59700 18954 IP15 Isoprenoid C15 44.993 16914 5134 NC14 Normal Alkane C14 45.881 52760 16292 Company: CONOCOPHILLIPS Client ID: US146120 Well Name: GRANDVIEW 1 Project #: 09 -489 -A ca Depth: 8131 - FT Lab ID: CP293034 Sampling Point: File Name: G2090793.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.551 21955 5081 NC15 Normal Alkane C15 49.977 46906 13454 NC16 Normal Alkane C16 53.850 36612 10947 1P18 Isoprenoid C18 55.798 15206 3186 NC17 Normal Alkane C17 57.523 31859 9156 IP19 Isoprenoid C19 (Pristane) 57.882 17504 3354 PHEN Phenanthrene 58.943 4350 1152 NC18 Normal Alkane C18 61.011 25453 7459 IP20 Isoprenoid 020 (Phytane) 61.468 8055 1436 NC19 Normal Alkane C19 64.333 22137 6282 NC20 Normal Alkane C20 67.500 19661 5321 NC21 Normal Alkane C21 70.527 15577 4588 C25HBI Highly Branch Isoprenoid C25 70.791 1106 240 NC22 Normal Alkane C22 73.423 13690 3867 NC23 Normal Alkane C23 76.201 11583 3269 NC24 Normal Alkane C24 78.865 9709 2706 NC25 Normal Alkane C25 81.428 8317 2292 NC26 Normal Alkane C26 83.896 6855 1879 NC27 Normal Alkane C27 86.271 5413 1434 NC28 Normal Alkane C28 88.563 4027 1060 NC29 Normal Alkane C29 90.780 3649 891 i l l NC30 Normal Alkane C30 92.921 2604 659 NC31 Normal Alkane C31 94.994 2083 507 NC32 Normal Alkane C32 97.004 1506 368 NC33 Normal Alkane C33 98.950 2228 447 NC34 Normal Alkane C34 100.846 1004 234 NC35 Normal Alkane C35 102.717 943 185 NC36 Normal Alkane C36 104.762 718 126 NC37 Normal Alkane C37 107.066 641 94 NC38 Normal Alkane C38 109.715 451 65 NC39 Normal Alkane C39 112.752 369 46 NC40 Normal Alkane C40 116.291 411 37 NC41 Normal Alkane C41 120.407 284 24 • VP Weatherford' EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146122 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293036 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8137 FT Longitude: Bottom Depth: FT Extract GC Trace G2090794.D 0 • OD Z U U H CO Z Z Z a z z . !, H �� ]] Z Z Z Z U Z M ri U m _$ (,J x U Si i 9a �] v z U z z z WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.36 A. BZ/n C6 2.31 P 5.93 Tr, 156.53 Pristane /n C17 0.45 B. TOUnC 11.26 P2 2.60 Tr 13.90 Phytane /n C18 0.24 C. (n C +n C 7 ) /(CH +MCH) 0.28 P3 0.59 Tr 3.34 nC /(nC +n C is ) 0.54 I. Isoheptane Value 0.88 5N, 2.16 Tr 2.74 n C 17 /(nC 17 +nC 0.85 F. n C 7 /MCH 0.30 N2 2.07 Tr 6.09 CPI Hunt 1.11 U. CH /MCP 3.12 6N, 86.66 Tr 1.90 Normal Paraffins 20.8 R. n C 7 /2MH 5.06 K, 0.97 Tr 4.66 Isoprenoids 4.1 S. n C 5 /22DMB K2 0.56 C, 0.06 Cycloparaffins 1.5 H. Heptane Value 16.02 5N 0.02 C2 0.51 0 Branched (iso -) Paraffins 0.2 MCH /n 3.36 P /N 0.28 C3 0.15 BTX aromatics 6.6 mpXYUn 4.37 In(24DMP /23DMP) -1.25 C4 0.10 Resolved unknowns 66.0 C5 0.18 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,I994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146122 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8137 - FT Lab ID: CP293036 Sampling Point: File Name: G2090794.D Peak Compound Ret. pp pp Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.820 151 81 23DMB 2,3- Dimethylbutane 5.847 37 32 2MP 2- Methylpentane 5.916 333 220 3MP 3- Methylpentane 6.184 343 212 NC6 Normal Alkane C6 6.571 1772 1102 22DMP 2,2- Dimethylpentane 7.223 58 35 MCP Methylcyclopentane 7.281 2754 1529 24DMP 2,4- Dimethylpentane 7.413 143 71 223TMB 2,2,3 - Trimethylbutane 7.567 53 19 BZ Benzene 8.027 4097 2063 33DMP 3,3- Dimethylpentane 8.237 99 39 CH Cyclohexane 8.352 8592 4398 2MH 2- Methylhexane 8.731 2064 1039 23DMP 2,3- Dimethylpentane 8.782 501 260 11DMCP 1,1- Dimethylcyclopentane 8.871 752 366 3MH 3- Methylhexane 9.070 2515 1245 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.303 1465 700 110 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.416 1429 687 3EP 3- Ethylpentane 9.477 181 132 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.530 2334 1106 NC7 Normal Alkane C7 10.120 10452 4926 ISTD Internal Standard MCH Methylcyclohexane 10.971 35124 15405 113TMCP 1,1,3, - Trimethylcyclopentane 11.140 1085 454 ECP Ethylcyclopentane 11.547 1480 646 124TMCP 1,2,4 - Trimethylcyclopentane 11.995 1184 505 123TMCP 1,2,3 - Trimethylcyclopentane 12.364 1049 440 TOL Toluene 12.683 117707 49377 NC8 Normal Alkane C8 15.328 23086 8544 IP9 Isoprenoid C9 17.206 2442 919 EB Ethyl- benzene 17.910 12637 4739 MXYL m- xylene 18.418 77499 28181 PXYL p-xylene 18.477 23286 9675 OXYL o- xylene 19.670 33739 12240 NC9 Normal Alkane C9 21.080 25173 9230 IP10 Isoprenoid C10 23.068 3287 1049 PB Propyl- benzene 23.238 6432 2124 NC10 Normal Alkane 010 26.689 28175 9793 IP11 Isoprenoid C11 27.993 3981 1356 NC11 Normal Alkane 011 31.965 34666 10495 NC12 Normal Alkane C12 36.903 35028 11304 IP13 Isoprenoid C13 37.649 11586 3021 IP14 Isoprenoid C14 40.418 10645 3451 • NC13 Normal Alkane C13 41.530 54937 17118 IP15 Isoprenoid C15 44.994 27434 8358 NC14 Normal Alkane C14 45.882 69951 21861 Company: CONOCOPHILLIPS Client ID: US146122 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8137 - FT Lab ID: CP293036 Sampling Point: File Name: G2090794.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.550 34502 8150 NC15 Normal Alkane C15 49.982 79866 21423 NC16 Normal Alkane C16 53.855 66183 19894 IP18 Isoprenoid C18 55.798 26069 5575 NC17 Normal Alkane C17 57.526 60575 17402 IP19 Isoprenoid C19 (Pristane) 57.879 27543 5359 PHEN Phenanthrene 58.941 15276 4282 NC18 Normal Alkane C18 61.015 49584 14341 IP20 Isoprenoid C20 (Phytane) 61.474 11675 2125 NC19 Normal Alkane C19 64.334 41542 11795 NC20 Normal Alkane C20 67.500 34587 9263 NC21 Normal Alkane C21 70.525 25772 7281 C25HBI Highly Branch Isoprenoid C25 70.794 2200 490 NC22 Normal Alkane C22 73.423 22686 6364 NC23 Normal Alkane C23 76.200 20067 5778 NC24 Normal Alkane C24 78.866 17685 5002 NC25 Normal Alkane C25 81.430 16593 4641 NC26 Normal Alkane C26 83.894 14597 3964 NC27 Normal Alkane C27 86.272 13212 3549 NC28 Normal Alkane C28 88.564 10983 2964 NC29 Normal Alkane C29 90.779 10678 2678 NC30 Normal Alkane C30 92.922 7933 1988 NC31 Normal Alkane C31 94.991 6427 1610 NC32 Normal Alkane C32 97.000 5073 1218 NC33 Normal Alkane C33 98.943 10901 2127 NC34 Normal Alkane C34 100.839 3171 707 NC35 Normal Alkane C35 102.715 2670 544 NC36 Normal Alkane C36 104.758 1799 331 NC37 Normal Alkane C37 107.068 1724 267 NC38 Normal Alkane C38 109.701 1275 185 NC39 Normal Alkane C39 112.733 938 120 NC40 Normal Alkane C40 116.278 877 90 NC41 Normal Alkane C41 120.398 702 62 S VP • Weatherford; EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146123 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293037 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8140 FT Longitude: Bottom Depth: FT Extract GC Trace G2090795.D ill 1 f U O Z Z Z Z Z Z Z Z S_, 4 ' �. a � Z z z, ,,,, r,,, _,,] 0_, z ¢i rX' .a a■ Z Z Z Z U oM n r n a. �q Al %`_ "' ti Z 2 2 Z Z Z Z Z i i i .1 1yAUL WGC parameters Thompson Mango H alpern 3 Pristane /Phytane 2.12 A. BZ/n C6 2.48 P, 8.89 Tr, 123.02 Pristane /nC 0.47 B. TOL /nC 6.55 P2 3.56 Tr 18.79 Phytane /n C 0.28 C. (n C +n C 7 ) /(CH +MCH) 0.35 P 0.64 Tr 4.13 nC /(nC +nC 0.53 I. Isoheptane Value 1.04 5N, 2.66 Tr 3.39 nC /(nC +n C 29 ) 0.88 F. n C 7 /MCH 0.37 N2 2.34 Tr 7.52 CPI Hunt 1.06 U. CH /MCP 3.50 6N 81.91 Tr 1.96 Normal Paraffins 17.4 R. n C 7 /2MH 5.54 K, 0.96 Tr 5.65 Isoprenoids 3.2 S. n C /22DMB K2 0.60 C 0.05 Cycloparaffins 2.1 H. Heptane Value 19.91 5N 0.03 C2 0.56 Branched (iso -) Paraffins 0.3 MCH /nC 2.67 P /N 0.27 C3 0.13 BTXaromatics 8.7 mpXYUn 3.39 In(24DMP /23DMP) -1.48 C4 0.09 Resolved unknowns 67.3 C5 0.17 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 1-talpem,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146123 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8140 - FT Lab ID: CP293037 4 1i Sampling Point: File Name: G2090795.D Peak Compound Ret. ppt - ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.827 65 30 23DMB 2,3- Dimethylbutane 5.854 17 13 2MP 2- Methylpentane 5.924 161 102 3MP 3- Methylpentane 6.192 204 128 NC6 Normal Alkane C6 6.580 1774 1104 22DMP 2,2- Dimethylpentane 7.233 77 45 MCP Methylcyclopentane 7.291 2817 1565 24DMP 2,4- Dimethylpentane 7.423 187 98 223TMB 2,2,3 - Trimethylbutane 7.576 33 17 BZ Benzene 8.037 4402 2211 33DMP 3,3- Dimethylpentane 8.246 140 61 CH Cyclohexane 8.362 9867 5050 2MH 2- Methylhexane 8.741 3755 1885 23DMP 2,3- Dimethylpentane 8.792 822 435 11DMCP 1,1- Dimethylcyclopentane 8.881 1108 534 , 3MH 3- Methylhexane 9.081 4577 2256 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.313 2206 1060 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.427 2176 1047 3EP 3- Ethylpentane 9.485 248 208 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.540 3668 1700 NC7 Normal Alkane C7 10.131 20820 9803 ISTD Internal Standard MCH Methylcyclohexane 10.982 55583 24412 113TMCP 1,1,3, - Trimethylcyclopentane 11.150 1868 777 ECP Ethylcyclopentane 11.556 2555 1114 124TMCP 1,2,4 - Trimethylcyclopentane 12.004 2026 866 123TMCP 1,2,3 - Trimethylcyclopentane 12.374 1759 741 TOL Toluene 12.694 136309 56460 NC8 Normal Alkane C8 15.339 46648 17137 IP9 Isoprenoid C9 17.213 4608 1734 EB Ethyl- benzene 17.916 19989 7512 MXYL m- xylene 18.430 122303 42956 PXYL p- xylene 18.487 35825 15496 OXYL o- xylene 19.677 50277 18177 NC9 Normal Alkane C9 21.088 50338 18291 IP10 Isoprenoid 010 23.072 6564 2090 PB Propyl- benzene 23.242 10920 3591 NC10 Normal Alkane 010 26.696 55232 19246 IP11 Isoprenoid C11 27.996 8428 2860 NC11 Normal Alkane C11 31.972 65189 20228 NC12 Normal Alkane C12 36.907 58102 18635 IP13 Isoprenoid C13 37.650 14671 4008 IP14 Isoprenoid C14 40.419 10247 3257 • NC13 Normal Alkane C13 41.532 61382 19243 IP15 Isoprenoid C15 44.993 22541 6851 NC14 Normal Alkane C14 45.879 54209 16335 Company: CONOCOPHILLIPS Client ID: US146123 Well Name: GRANDVIEW 1 Project #: 09 -489 -A fil Depth: 8140 - FT Lab ID: CP293037 Sampling Point: File Name: G2090795.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.547 23475 5342 NC15 Normal Alkane C15 49.974 46462 13122 NC16 Normal Alkane C16 53.846 35629 10633 IP18 Isoprenoid C18 55.795 13854 2956 NC17 Normal Alkane C17 57.517 31039 8926 IP19 Isoprenoid C19 (Pristane) 57.879 14714 2846 PHEN Phenanthrene 58.935 10739 3103 NC18 Normal Alkane C18 61.005 24886 7350 IP20 Isoprenoid C20 (Phytane) 61.473 6939 1259 NC19 Normal Alkane C19 64.328 21904 6141 NC20 Normal Alkane C20 67.494 20090 5351 NC21 Normal Alkane C21 70.522 15404 4395 C25HBI Highly Branch Isoprenoid C25 70.794 1436 338 NC22 Normal Alkane C22 73.420 13956 3765 NC23 Normal Alkane C23 76.196 11717 3380 NC24 Normal Alkane C24 78.862 9949 2746 NC25 Normal Alkane C25 81.425 8577 2365 NC26 Normal Alkane C26 83.889 7223 1958 NC27 Normal Alkane C27 86.264 5718 1519 NC28 Normal Alkane C28 88.561 4443 1149 NC29 Normal Alkane C29 90.773 4408 1017 NC30 Normal Alkane C30 92.919 3197 786 NC31 Normal Alkane C31 94.994 2730 635 NC32 Normal Alkane C32 96.998 2278 522 NC33 Normal Alkane C33 98.947 2819 535 NC34 Normal Alkane C34 100.840 1534 328 NC35 Normal Alkane C35 102.711 1431 279 NC36 Normal Alkane C36 104.759 1110 196 NC37 Normal Alkane C37 107.070 1078 153 NC38 Normal Alkane C38 109.704 849 118 NC39 Normal Alkane C39 112.732 535 71 NC40 Normal Alkane C40 116.278 662 61 NC41 Normal Alkane C41 120.405 567 45 VP Weatherford* EXTRACT GC L A B O R A T O R I E S S Company: CONOCOPHILLIPS Client ID: US146124 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293038 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8143 FT Longitude: Bottom Depth: FT Extract GC Trace G2090798.D z • y U ry £ Z L z z z nz 1 z z z z z z xW J� g ., _ H z z H Z 2 V "' V V •� IW l .INYM WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.11 A. BZ/n C6 5.12 P 7.38 Tr, 125.07 Pristane /n C17 0.48 B. TOL /n 8.09 P2 2.92 Tr 15.46 Phytane /n C18 0.28 C. (n C +n C 7 ) /(CH +MCH) 0.27 P3 0.60 Tr 3.44 nC /(nC +nC 0.53 I. Isoheptane Value 0.92 5N, 2.56 Tr 2.68 nC, /(nC +n C 29 ) 0.87 F. n C 7 /MCH 0.30 N2 2.17 Tr 6.12 CPI Hunt 1.06 U. CH /MCP 4.64 6N, 84.38 Tr 1.77 Normal Paraffins 19.4 R. n C 7 /2MH 5.77 K, 0.94 Tr 4.95 Isoprenoids 3.5 S. n C 6 /22DMB K2 0.57 C 0.04 Cycloparaffins 2.0 H. Heptane Value 17.17 5N 0.03 C2 0.55 0 Branched (iso -) Paraffins 0.2 MCH /nC 3.35 P /N 0.28 C 0.10 BTX aromatics 8.9 mpXYL/n 3.44 In(24DMP /23DMP) -1.74 C4 0.09 Resolved unknowns 64.8 C5 0.22 'Thompson, K.F.M.,1983.GCA:V.47, p303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. 'Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146124 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8143 - FT Lab ID: CP293038 Sampling Point: File Name: G2090798.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.818 41 21 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.917 76 50 3MP 3- Methylpentane 6.188 122 77 NC6 Normal Alkane C6 6.579 1087 668 22DMP 2,2- Dimethylpentane 7.235 81 47 MCP Methylcyclopentane 7.292 2801 1559 24DMP 2,4- Dimethylpentane 7.425 186 99 223TMB 2,2,3 - Trimethylbutane 7.577 45 20 BZ Benzene 8.040 5569 2827 33DMP 3,3- Dimethylpentane 8.250 174 78 CH Cyclohexane 8.365 13009 6658 2MH 2- Methylhexane 8.746 4201 2121 23DMP 2,3- Dimethylpentane 8.797 1063 557 11DMCP 1,1- Dimethylcyclopentane 8.886 1568 766 3MH 3- Methylhexane 9.086 5390 2665 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.318 2776 1339 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.432 2778 1341 3EP 3- Ethylpentane 9.493 435 317 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.545 4927 2332 NC7 Normal Alkane C7 10.137 24245 11481 ISTD Internal Standard MCH Methylcyclohexane 10.989 81233 35564 113TMCP 1,1,3, - Trimethylcyclopentane 11.156 3124 1303 ECP Ethylcyclopentane 11.562 3471 1522 124TMCP 1,2,4 - Trimethylcyclopentane 12.009 3263 1403 123TMCP 1,2,3 - Trimethylcyclopentane 12.379 2917 1233 TOL Toluene 12.704 196111 79873 NC8 Normal Alkane C8 15.346 74218 26602 IP9 Isoprenoid C9 17.216 8395 3179 EB Ethyl- benzene 17.919 32253 12113 MXYL m- xylene 18.442 198290 65511 PXYL p- xylene 18.497 57141 26043 OXYL o- xylene 19.684 81730 29310 NC9 Normal Alkane C9 21.094 82965 29715 IP10 Isoprenoid C10 23.073 11568 3714 PB Propyl- benzene 23.242 17197 5587 NC10 Normal Alkane C10 26.700 90948 31473 IP11 Isoprenoid C11 27.995 14493 4888 NC11 Normal Alkane C11 31.975 112188 35245 NC12 Normal Alkane C12 36.912 105143 33562 IP13 Isoprenoid C13 37.647 26102 6961 IP14 Isoprenoid C14 40.416 17080 5397 • NC13 Normal Alkane C13 41.535 108102 33167 IP15 Isoprenoid C15 44.991 35784 10668 NC14 Normal Alkane C14 45.880 93143 27806 Company: CONOCOPHILLIPS Client ID: US146124 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8143 - FT Lab ID: CP293038 Sampling Point: File Name: G2090798.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.544 37661 8569 NC15 Normal Alkane C15 49.976 80696 21984 NC16 Normal Alkane C16 53.847 60978 18035 IP18 Isoprenoid C18 55.790 23469 5038 NC17 Normal Alkane C17 57.519 52560 15274 IP19 Isoprenoid C19 (Pristane) 57.872 25013 4850 PHEN Phenanthrene 58.934 17026 4899 NC18 Normal Alkane C18 61.005 42222 12426 IP20 Isoprenoid C20 (Phytane) 61.463 11875 2162 NC19 Normal Alkane C19 64.326 37214 10614 NC20 Normal Alkane C20 67.493 34221 8758 NC21 Normal Alkane C21 70.520 26322 7566 C25HBI Highly Branch Isoprenoid C25 70.788 2519 567 NC22 Normal Alkane C22 73.418 23722 6546 NC23 Normal Alkane C23 76.193 20267 5667 NC24 Normal Alkane C24 78.859 17136 4701 NC25 Normal Alkane C25 81.421 14912 4144 NC26 Normal Alkane C26 83.886 12591 3466 NC27 Normal Alkane C27 86.263 10068 2704 NC28 Normal Alkane C28 88.555 7856 2070 NC29 Normal Alkane C29 90.773 7814 1776 NC30 Normal Alkane C30 92.913 5757 1357 NC31 Normal Alkane C31 94.985 4339 1061 NC32 Normal Alkane C32 96.997 3409 788 NC33 Normal Alkane C33 98.942 4572 872 NC34 Normal Alkane C34 100.835 2634 581 NC35 Normal Alkane C35 102.704 2244 469 NC36 Normal Alkane C36 104.759 1748 316 NC37 Normal Alkane C37 107.054 1712 252 NC38 Normal Alkane C38 109.697 1281 183 NC39 Normal Alkane C39 112.715 1000 119 NC40 Normal Alkane C40 116.252 962 93 NC41 Normal Alkane C41 120.387 798 66 • IV • Weatherford' A B EXTRACT GC LAB O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146125 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293039 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8146 FT Longitude: Bottom Depth: FT Extract GC Trace G2090799.D • Z Z Z Z I Z U� T Z Z a A Z Z n m 4'' � -, AA Iy - �� Z r',' U U Z Z Z Z -a V1I IYR ,`',+' c U U U ill J Z Z Z Z Z Z Z Z WGC parameters Thompson Mango H alpern 3 Pristane /Phytane 2.12 A. BZ/n C6 4.14 P, 7.37 Tr, 125.73 Pristane /n C17 0.47 B. TOUn C 8.02 P2 2.96 Tr 15.67 Phytane /n C18 0.28 C. (nC +nC /(CH +MCH) 0.27 P3 0.58 Tr 3.51 nC /(nC, +n C, 9 ) 0.53 I. Isoheptane Value 0.90 5N, 2.61 Tr 2.77 n C /(nC +n C 0.87 F. nC /MCH 0.29 N2 2.24 Tr 6.29 CPI Hunt 1.06 U. CH /MCP 4.34 6N, 84.24 Tr 1.88 Normal Paraffins 17.2 R. nC /2MH 5.65 K, 0.95 Tr 5.27 Isoprenoids 3.2 S. nC /22DMB K2 0.57 C, 0.04 Cycloparaffins 2.6 H. Heptane Value 16.84 5N, /6N, 0.03 C2 0.56 Branched (iso -) Paraffins 0.2 MCH /nC 3.40 P /N 0. C3 0.10 BTX aromatics 10.7 mpXYUn C6 3.98 In(24DMP /23DMP) -1.70 C 0.09 Resolved unknowns 64.7 C5 0.21 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.L,1995,AAPG Bull.: V.79, p.801. 'Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146125 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8146 - FT Lab ID: CP293039 SamplingPoint: File Name: G2090799.D ill Peak Compound Ret, ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.827 68 33 23DMB 2,3- Dimethylbutane 5.855 17 14 2MP 2- Methylpentane 5.925 150 91 3MP 3- Methylpentane 6.193 220 134 NC6 Normal Alkane C6 6.582 1969 1192 22DMP 2,2- Dimethylpentane 7.236 107 64 MCP Methylcyclopentane 7.293 4507 2507 24DMP 2,4- Dimethylpentane 7.426 260 139 223TMB 2,2,3 - Trimethylbutane 7.579 60 27 BZ Benzene 8.040 8161 4153 33DMP 3,3- Dimethylpentane 8.250 225 102 CH Cyclohexane 8.365 19570 10048 2MH 2- Methylhexane 8.745 5927 2984 23DMP 2,3- Dimethylpentane 8.796 1427 751 11DMCP 1,1- Dimethylcyclopentane 8.885 2136 1049 3MH 3- Methylhexane 9.084 7504 3717 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.317 4023 1950 • _ 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.430 4020 1943 3EP 3- Ethylpentane 9.491 531 424 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.544 6951 3278 NC7 Normal Alkane C7 10.136 33471 15801 ISTD Internal Standard MCH Methylcyclohexane 10.989 113763 49448 113TMCP 1,1,3, - Trimethylcyclopentane 11.154 3714 1558 ECP Ethylcyclopentane 11.560 4903 2153 124TMCP 1,2,4 - Trimethylcyclopentane 12.007 3955 1699 123TMCP 1,2,3 - Trimethylcyclopentane 12.377 3475 1469 TOL Toluene 12.708 268549 105702 NC8 Normal Alkane C8 15.345 81815 29140 IP9 Isoprenoid C9 17.214 8753 3302 EB Ethyl- benzene 17.919 41093 15526 MXYL m- xylene 18.447 253122 80100 PXYL p - xylene 18.500 72483 33606 OXYL o- xylene 19.686 103220 37021 NC9 Normal Alkane C9 21.092 79690 28999 IP10 Isoprenoid C10 23.072 10492 3364 PB Propyl- benzene 23.242 20102 6658 NC10 Normal Alkane 010 26.700 84281 29064 IP11 Isoprenoid C11 27.994 13233 4430 NC11 Normal Alkane C11 31.975 104823 32354 NC12 Normal Alkane C12 36.911 96095 30844 IP13 Isoprenoid C13 37.648 24733 6372 IP14 Isoprenoid C14 40.417 15671 5000 NC13 Normal Alkane C13 41.535 103848 32106 IP15 Isoprenoid C15 44.994 40799 12217 NC14 Normal Alkane C14 45.882 90724 27230 Company: CONOCOPHILLIPS Client ID: US146125 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 40 Depth: 8146 - FT Lab ID: CP293039 Sampling Point: File Name: G2090799.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.547 37450 8739 NC15 Normal Alkane C15 49.978 79586 21315 NC16 Normal Alkane C16 53.848 59415 17243 IP18 Isoprenoid C18 55.793 22472 4764 NC17 Normal Alkane C17 57.519 50549 14437 IP19 Isoprenoid C19 (Pristane) 57.881 23901 4737 PHEN Phenanthrene 58.937 24133 6956 NC18 Normal Alkane C18 61.006 40287 11792 IP20 Isoprenoid C20 (Phytane) 61.468 11249 2069 NC19 Normal Alkane C19 64.326 35382 9912 NC20 Normal Alkane C20 67.493 32529 8354 NC21 Normal Alkane C21 70.518 24270 7094 C25HB1 Highly Branch Isoprenoid C25 70.790 2746 646 NC22 Normal Alkane C22 73.418 21570 5959 NC23 Normal Alkane C23 76.195 18357 5083 NC24 Normal Alkane C24 78.859 15452 4316 NC25 Normal Alkane C25 81.422 13421 3620 NC26 Normal Alkane C26 83.887 11486 3077 NC27 Normal Alkane C27 86.264 9332 2381 NC28 Normal Alkane C28 88.556 7121 1836 NC29 Normal Alkane C29 90.778 7272 1632 NC30 Normal Alkane C30 92.916 5471 1285 NC31 Normal Alkane C31 94.988 4327 1017 NC32 Normal Alkane C32 96.997 3843 814 NC33 Normal Alkane C33 98.942 4769 808 NC34 Normal Alkane C34 100.836 2483 542 NC35 Normal Alkane C35 102.706 2117 433 NC36 Normal Alkane C36 104.758 1727 305 NC37 Normal Alkane C37 107.058 1605 229 NC38 Normal Alkane C38 109.701 1139 162 NC39 Normal Alkane C39 112.735 805 107 NC40 Normal Alkane C40 116.259 812 88 NC41 Normal Alkane C41 120.405 639 59 0 V • Weatherford EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146126 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293040 Lease: Sample Type: CORE Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8149 FT Longitude: Bottom Depth: FT Extract GC Trace G2090800.D • XSEP - a aa WPM • '` °z : ., z a,,, .. °' z a z � �a � z� z z z z� z z WGC parameters ; Thompson' Mango Halpern Pristane /Phytane 2.06 A. BZ/n C6 2.75 P 10.99 Tr, 62.40 Pristane /n C17 0.48 B. TOL /nC 4.41 P2 5.17 Tr 14.15 Phytane /n C18 0.29 C. (n C +nC /(CH +MCH) 0.37 P3 1.18 Tr 3.62 nC,e/(nC18 +nCis) 0.53 I. Isoheptane Value 1.17 5N, 3.26 Tr 3.02 n C 17 /(nC +nC 0.87 F. n C 7 /MCH 0.40 N2 3.11 Tr 6.65 CPI Hunt 1.06 U. CH /MCP 3.36 6N, 76.28 Tr 1.49 Normal Paraffins 6.5 R. n C 7 /2MH 4.68 K 1.00 Tr 4.48 Isoprenoids 1.1 S. n C K2 0.62 C, 0.07 Cycloparaffins 1.0 H. Heptane Value 20.17 5N 0.04 C2 0.54 il Branched (iso-) Paraffins 0.1 MCH /nC 2.53 P /N 0.38 C3 0.13 BTX aromatics 2.8 mpXYL/n Ce 2.39 In(24DMP /23DMP) -1.40 C4 0.09 Resolved unknowns 88.2 C 0.17 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.1.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146126 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8149 - FT Lab ID: CP293040 Sampling Point: File Name: G2090800.D Peak Compound Ret. ppt ppt Label Name Time Area. Height (Area) (tight) 0 IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.796 99 61 23DMB 2,3- Dimethylbutane 5.824 69 54 2MP 2- Methylpentane 5.895 616 440 3MP 3- Methylpentane 6.168 797 527 NC6 Normal Alkane C6 6.559 5376 3369 22DMP 2,2- Dimethylpentane 7.214 395 235 MCP Methylcyclopentane 7.272 7322 4132 24DMP 2,4- Dimethylpentane 7.405 789 438 223TMB 2,2,3 - Trimethylbutane 7.558 164 84 BZ Benzene 8.019 14809 7603 33DMP 3,3- Dimethylpentane 8.230 547 264 CH Cyclohexane 8.345 24583 12729 2MH 2- Methylhexane 8.726 12157 6188 23DMP 2,3- Dimethylpentane 8.777 3197 1666 11DMCP 1,1- Dimethylcyclopentane 8.865 4021 1904 3MH 3- Methylhexane 9.065 14571 7223 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.298 6104 2975 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.411 5977 2895 3EP 3- Ethylpentane 9.472 1038 738 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.525 10723 5097 NC7 Normal Alkane C7 10.119 56893 26795 ISTD Internal Standard MCH Methylcyclohexane 10.974 143795 62176 113TMCP 1,1,3, - Trimethylcyclopentane 11.137 6427 2697 ECP Ethylcyclopentane 11.543 6170 2711 124TMCP 1,2,4 - Trimethylcyclopentane 11.991 6157 2651 123TMCP 1,2,3 - Trimethylcyclopentane 12.361 5871 2295 TOL Toluene 12.691 250928 99541 NC8 Normal Alkane C8 15.338 121484 42292 IP9 lsoprenoid C9 17.205 12288 4656 EB Ethyl- benzene 17.909 37239 13922 MXYL m- xylene 18.435 226649 72816 PXYL p- xylene 18.489 64294 29460 OXYL o- xylene 19.677 89313 31755 NC9 Normal Alkane C9 21.091 113628 40272 IP10 Isoprenoid C10 23.068 14885 4750 PB Propyl- benzene 23.237 20456 6613 NC10 Normal Alkane C10 26.701 114207 38764 IP11 Isoprenoid C11 27.993 17716 5942 NC11 Normal Alkane C11 31.978 133822 42218 NC12 Normal Alkane C12 36.915 124881 40111 IP13 Isoprenoid C13 37.649 30982 8274 IP14 Isoprenoid C14 40.417 20106 6362 NC13 Normal Alkane C13 41.539 129848 39558 IP15 Isoprenoid C15 44.991 38929 11674 NC14 Normal Alkane C14 45.886 114722 34277 Company: CONOCOPHILLIPS Client ID: US146126 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8149 - FT Lab ID: CP293040 Sampling Point: File Name: G2090800.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.546 44997 10380 NC15 Normal Alkane C15 49.981 101724 27823 NC16 Normal Alkane C16 53.852 77361 22789 IP18 Isoprenoid C18 55.792 29856 6375 NC17 Normal Alkane C17 57.523 67209 19117 IP19 Isoprenoid C19 (Pristane) 57.878 32109 6145 PHEN Phenanthrene 58.934 15787 4388 NC18 Normal Alkane C18 61.009 53827 15724 IP20 Isoprenoid C20 (Phytane) 61.467 15560 2750 NC19 Normal Alkane C19 64.330 47266 13159 NC20 Normal Alkane C20 67.498 43081 11439 NC21 Normal Alkane C21 70.523 33756 9691 C25HBI Highly Branch Isoprenoid C25 70.786 2642 637 NC22 Normal Alkane C22 73.419 30229 8256 NC23 Normal Alkane C23 76.197 25840 7391 NC24 Normal Alkane C24 78.860 21874 6185 NC25 Normal Alkane C25 81.422 19404 5380 NC26 Normal Alkane C26 83.888 16524 4361 NC27 Normal Alkane C27 86.265 13118 3481 NC28 Normal Alkane C28 88.560 10133 2768 NC29 Normal Alkane C29 90.773 9780 2301 NC30 Normal Alkane C30 92.918 7171 1690 NC31 Normal Alkane C31 94.989 5552 1357 NC32 Normal Alkane C32 96.997 4158 987 NC33 Normal Alkane C33 98.942 5699 1113 NC34 Normal Alkane C34 100.837 3079 672 NC35 Normal Alkane C35 102.708 2603 547 NC36 Normal Alkane C36 104.759 1961 357 NC37 Normal Alkane C37 107.057 1964 274 NC38 Normal Alkane C38 109.697 1411 200 NC39 Normal Alkane C39 112.742 1055 131 NC40 Normal Alkane C40 116.266 1038 106 NC41 Normal Alkane C41 120.396 961 81 • V' • Weatherfo EXTRACT GC L A B O R A T D R I E S Company: CONOCOPHILLIPS Client ID: US146127 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293041 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8152 FT Longitude: Bottom Depth: FT Extract GC Trace G2090807.D z • . .', Y z z x• ..:7.:1 qty '- e,5 Z Z £ Z y U m ' i d _ " Z Z U U ',,s' .r Z U L =,ii�:.i I i I L z WGC parameters Thompson' Mango Halpern Pristane /Phytane 1.81 A. BZ/n C6 4.59 P, 7.12 Tr, 123.09 Pristane /n C17 0.70 B. TOL /nC 8.22 P2 2.89 Tr 14.97 Phytane /n C18 0.41 C. (n C + /(CH +MCH) 0.25 P3 0.56 Tr 3.40 nC /(nC +n C, 9 ) 0.49 I. IsoheptaneValue 0.86 5N, 2.63 Tr 2.67 nC /(nC +n C 29 ) 0.67 F. nC /MCH 0.27 N2 2.29 Tr 6.07 CPI Hunt 1.08 U. CH /MCP 4.51 6N, 84.50 Tr 1.90 Normal Paraffins 16.0 R. nC /2MH 5.60 K, 0.94 Tr 5.27 Isoprenoids 2.7 S. n C /22DMB K2 0.56 C, 0.04 Cycloparaffins 3.1 H. Heptane Value 15.89 5N, /6N, 0.03 C2 0.55 Branched (iso -) Paraffins 0.3 MCH / nC7 3.64 P /N 0.2 C3 0.10 BTX aromatics 12.0 mpXYL/n 4.38 In(24DMP /23DMP) -1.74 C 0.09 Resolved unknowns 64.5 C 0.23 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146127 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8152 - FT Lab ID: CP293041 Sampling Point: File Name: G2090807.D Peak Compound - - Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 lso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.836 46 26 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.933 117 77 3MP 3- Methylpentane 6.201 219 139 NC6 Normal Alkane C6 6.590 2326 1426 22DMP 2,2- Dimethylpentane 7.244 119 73 MCP Methylcyclopentane 7.301 6057 3378 24DMP 2,4- Dimethylpentane 7.434 305 162 223TMB 2,2,3 - Trimethylbutane 7.587 67 30 BZ Benzene 8.047 10678 5400 33DMP 3,3- Dimethylpentane 8.258 282 125 CH Cyclohexane 8.373 27341 13941 2MH 2- Methylhexane 8.753 7323 3701 23DMP 2,3- Dimethylpentane 8.803 1739 920 11DMCP 1,1- Dimethylcyclopentane 8.892 2739 1335 3MH 3- Methylhexane 9.092 9314 4613 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.324 5239 2545 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.437 5211 2517 ill 3EP 3- Ethylpentane 9.499 714 512 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.551 8824 4208 NC7 Normal Alkane C7 10.143 41000 19389 ISTD Internal Standard MCH Methylcyclohexane 10.998 149271 64562 113TMCP 1,1,3, - Trimethylcyclopentane 11.160 4313 1814 ECP Ethylcyclopentane 11.565 6323 2767 124TMCP 1,2,4 - Trimethylcyclopentane 12.012 4646 1996 123TMCP 1,2,3 - Trimethylcyclopentane 12.381 4016 1686 TOL Toluene 12.718 337130 128048 NC8 Normal Alkane C8 15.347 91525 32176 IP9 Isoprenoid C9 17.214 9428 3546 EB Ethyl- benzene 17.919 49970 18746 MXYL m- xylene 18.453 312358 93880 PXYL p- xylene 18.505 88967 42216 OXYL o- xylene 19.689 130151 46161 NC9 Normal Alkane C9 21.090 81941 29543 IP10 Isoprenoid C10 23.068 9562 3068 PB Propyl- benzene 23.238 23186 7732 NC10 Normal Alkane C10 26.693 77723 26981 IP11 Isoprenoid C11 27.988 10605 3528 NC11 Normal Alkane C11 31.965 87641 26160 NC12 Normal Alkane C12 36.897 67606 21733 IP13 Isoprenoid C13 37.640 15988 4040 IP14 Isoprenoid C14 40.408 9510 2987 NC13 Normal Alkane C13 41.520 71371 21881 IP15 Isoprenoid C15 44.989 41971 12300 I NC14 Normal Alkane C14 45.868 61475 17701 Company: CONOCOPHILLIPS Client ID: US146127 Well Name: GRANDVIEW 1 Project #: 09 -489 -A S Depth: 8152 - FT Lab ID: CP293041 Sampling Point: File Name: G2090807.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight)'; IP16 Isoprenoid C16 48.537 31480 7057 NC15 Normal Alkane C15 49.963 49105 13868 NC16 Normal Alkane C16 53.837 42384 12149 IP18 Isoprenoid C18 55.782 20211 4169 NC17 Normal Alkane C17 57.508 39708 11388 IP19 Isoprenoid C19 (Pristane) 57.873 27609 5408 PHEN Phenanthrene 58.930 32258 9525 NC18 Normal Alkane C18 60.999 37444 10798 IP20 Isoprenoid C20 (Phytane) 61.458 15266 2857 NC19 Normal Alkane C19 64.320 38625 10625 NC20 Normal Alkane C20 67.489 42306 10701 NC21 Normal Alkane C21 70.516 37187 10452 C25HBI Highly Branch Isoprenoid C25 70.783 3866 893 NC22 Normal Alkane C22 73.414 38180 10642 NC23 Normal Alkane C23 76.190 35981 10039 NC24 Normal Alkane C24 78.857 32245 9066 NC25 Normal Alkane C25 81.418 30063 8190 NC26 Normal Alkane C26 83.881 26553 7269 NC27 Normal Alkane C27 86.259 23748 6353 NC28 Normal Alkane C28 88.554 19719 5253 NC29 Normal Alkane C29 90.768 19311 4690 NC30 Normal Alkane C30 92.912 14662 3631 NC31 Normal Alkane C31 94.983 12003 2929 NC32 Normal Alkane C32 96.989 8508 2090 NC33 Normal Alkane C33 98.936 13077 2226 NC34 Normal Alkane C34 100.831 6234 1334 NC35 Normal Alkane C35 102.700 5046 1074 NC36 Normal Alkane C36 104.747 3461 644 NC37 Normal Alkane C37 107.051 3569 520 NC38 Normal Alkane C38 109.685 2682 385 NC39 Normal Alkane C39 112.714 1891 235 NC40 Normal Alkane C40 116.233 1807 179 NC41 Normal Alkane C41 120.348 1472 131 • Weatherfo EXTRACT GC LABORATORIES Company: CONOCOPHILLIPS Client ID: US146128 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293042 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8155 FT Longitude: Bottom Depth: FT Extract GC Trace G2090809.D 0 a K X X • al z z I a La z Z U U Z � J = = Z Z Z to ..y U ',',°' U U U U .+ Z Z U it �,�...� � Z ..,� .�.... VVGC parameters Thompson Mango Halpern Pristane /Phytane 2.12 A. BZ/n C6 6.77 P 7.94 Tr, 120.86 Pristane /n C17 0.44 B. TOL /nC 6.77 P2 2.97 Tr 17.86 Phytane /n C18 0.26 C. (nC +nC /(CH +MCH) 0.24 P3 0.51 Tr 3.80 n C 18 /(nC, +nC 0.53 I. Isoheptane Value 0.87 5N, 2.92 Tr 2.88 nC 1(nC +n C 29 ) 0.80 F. n C 7 /MCH 0.27 N2 2.24 Tr 6.68 CPI Hunt 1.09 U. CH /MCP 5.81 6N, 83.42 Tr 2.03 Normal Paraffins 18.3 R. n C 7 /2MH 6.21 K, 0.91 Tr 5.85 Isoprenoids 3.1 S. n C 6 /22DMB K2 0.57 C 0.03 Cycloparaffins 2.4 H. Heptane Value 16.38 5N 0.04 C2 0.59 Branched (iso -) Paraffins 0.2 MCH /n C 3.74 P /N 0.23 C3 0.08 BTX aromatics 10.0 mpXYL/n Ce 3.73 In(24DMP /23DMP) -2.05 C4 0.08 Resolved unknowns 64.6 C 0.23 Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.I.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146128 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8155 - FT Lab ID: CP293042 ill Sampling Point: File Name: G2090809.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.868 49 32 3MP 3- Methylpentane 6.146 104 63 NC6 Normal Alkane C6 6.542 1310 796 22DMP 2,2- Dimethylpentane 7.201 104 63 MCP Methylcyclopentane 7.259 4496 2545 24DMP 2,4- Dimethylpentane 7.392 269 148 223TMB 2,2,3- Trimethylbutane 7.546 55 25 BZ Benzene 8.009 8875 4540 33DMP 3,3- Dimethylpentane 8.221 280 133 CH Cyclohexane 8.336 26101 13524 2MH 2- Methylhexane 8.718 8990 4572 23DMP 2,3- Dimethylpentane 8.769 2089 1111 11DMCP 1,1- Dimethylcyclopentane 8.858 3126 1547 3MH 3- Methylhexane 9.059 11891 5933 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.291 6263 3047 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.405 6358 3091 3EP 3- Ethylpentane 9.466 826 638 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.519 11281 5346 NC7 Normal Alkane C7 10.115 55842 26366 ISTD Internal Standard MCH Methylcyclohexane 10.975 209064 88790 113TMCP 1,1,3, - Trimethylcyclopentane 11.135 6809 2872 ECP Ethylcyclopentane 11.540 9266 4072 124TMCP 1,2,4 - Trimethylcyclopentane 11.989 7672 3297 123TMCP 1,2,3 - Trimethylcyclopentane 12.360 6730 2830 TOL Toluene 12.700 377794 140588 NC8 Normal Alkane C8 15.344 172896 57165 IP9 Isoprenoid C9 17.206 19539 7344 EB Ethyl- benzene 17.915 80849 29846 MXYL m- xylene 18.465 510524 130299 PXYL p- xylene 18.514 134651 67524 OXYL o- xylene 19.695 204835 69152 NC9 Normal Alkane C9 21.103 184325 62260 IP10 Isoprenoid C10 23.071 22313 7128 PB Propyl- benzene 23.240 45210 14877 NC10 Normal Alkane C10 26.713 184092 59789 IP11 Isoprenoid C11 27.996 25400 8433 NC11 Normal Alkane C11 31.987 205735 63069 NC12 Normal Alkane C12 36.921 173297 52668 IP13 Isoprenoid C13 37.651 41641 10720 IP14 Isoprenoid C14 40.418 24888 7909 NC13 Normal Alkane C13 41.544 184785 53666 • IP15 Isoprenoid C15 45.000 74924 20749 NC14 Normal Alkane C14 45.892 159221 46954 Company: CONOCOPHILLIPS Client ID: US146128 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8155 - FT Lab ID: CP293042 Sampling Point: File Name: G2090809.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.548 66886 14957 NC15 Normal Alkane C15 49.988 142120 37407 NC16 Normal Alkane C16 53.857 106886 31175 IP18 Isoprenoid C18 55.795 38820 8259 NC17 Normal Alkane C17 57.527 91796 26132 IP19 Isoprenoid C19 (Pristane) 57.881 40443 7986 PHEN Phenanthrene 58.945 47297 13653 NC18 Normal Alkane C18 61.014 74104 21477 IP20 Isoprenoid C20 (Phytane) 61.475 19093 3597 NC19 Normal Alkane C19 64.335 66807 18082 NC20 Normal Alkane C20 67.500 58268 15077 NC21 Normal Alkane C21 70.526 45266 12607 C25HBI Highly Branch Isoprenoid C25 70.795 5522 1346 NC22 Normal Alkane C22 73.419 39838 11400 NC23 Normal Alkane C23 76.198 35376 9826 NC24 Normal Alkane C24 78.864 32419 9015 NC25 Normal Alkane C25 81.427 33434 9091 NC26 Normal Alkane C26 83.895 31242 8214 NC27 Normal Alkane C27 86.269 27140 6936 NC28 Normal Alkane C28 88.562 22744 5971 NC29 Normal Alkane C29 90.779 23328 5430 al NC30 Normal Alkane C30 92.920 18245 4409 NC31 Normal Alkane C31 94.994 15819 3747 NC32 Normal Alkane C32 97.002 12142 2856 NC33 Normal Alkane C33 98.947 20093 3467 NC34 Normal Alkane C34 100.838 9231 2013 NC35 Normal Alkane C35 102.712 7772 1705 NC36 Normal Alkane C36 104.759 6149 1081 NC37 Normal Alkane C37 107.058 6599 893 NC38 Normal Alkane C38 109.703 4767 699 NC39 Normal Alkane C39 112.732 3199 415 NC40 Normal Alkane C40 116.261 3324 328 NC41 Normal Alkane C41 120.397 2814 253 • A V • Weatherford' EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146130 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293044 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8161 FT Longitude: Bottom Depth: FT Extract GC Trace G2090810.D x . x * .;', 'Z'', 2 , o z z z I u Z Z u c o 4 y i m • .r ti ti '-' "" Z Z Z Z Z Z U Z ' M U U U m " 1 .4 i - 10 LA Z y U Z u z U • i .l. �-+ U Z Z Z Z Z Z Z VV GC parameters Thompson' Mango 2 Ha Pristane /Phytane 2.11 A. BZ/n C6 5.24 P, 8.88 Tr, 94.95 Pristane /n C17 0.43 B. TOUn C 5.52 P2 3.44 Tr 17.22 Phytane /nC, 0.26 C. (n C +nC /(CH +MCH) 0.25 P3 0.65 Tr 3.77 nC /(nC +nC 0.53 I. IsoheptaneValue 0.91 5N 3.18 Tr 2.89 n C 17 /(nC +nC 0.86 F. n C 7 /MCH 0.27 N2 2.52 Tr 6.67 CPI Hunt 1.08 U. CH /MCP 5.18 6N 81.32 Tr 1.96 Normal Paraffins 17.1 R. n C 7 /2MH 5.95 K, 0.92 Tr 5.38 Isoprenoids 3.0 S. n C 6 /22DMB K2 0.58 C, 0.03 Cycloparaffins 2.5 H. Heptane Value 16.57 5N 0.04 C2 0.55 0 Branched (iso-) Paraffins 0.2 MCH /n 3.64 P /N 0.26 C3 0.08 BTXaromatics 9.7 mpXYUn 3.48 In(24DMP /23DMP) -1.90 C4 0.08 Resolved unknowns 66.2 C 0.24 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.I.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146130 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8161 - FT Lab ID: CP293044 Sampling Point: File Name: G2090810.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.839 50 23 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.935 88 53 3MP 3- Methylpentane 6.204 146 84 NC6 Normal Alkane C6 6.593 1396 849 22DMP 2,2- Dimethylpentane 7.247 99 60 MCP Methylcyclopentane 7.304 3838 2124 24DMP 2,4- Dimethylpentane 7.436 246 133 223TMB 2,2,3 - Trimethylbutane 7.589 55 25. BZ Benzene 8.050 7309 3640 33DMP 3,3- Dimethylpentane 8.260 252 114 CH Cyclohexane 8.375 19887 10152 2MH 2- Methylhexane 8.755 6944 3504 23DMP 2,3- Dimethylpentane 8.806 1648 868 11DMCP 1,1- Dimethylcyclopentane 8.894 2400 1167 3MH 3- Methylhexane 9.094 9054 4501 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.326 4653 2262 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.439 4695 2273 3EP 3- Ethylpentane 9.501 726 563 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.553 8232 3916 NC7 Normal Alkane C7 10.145 41318 19541 ISTD Internal Standard MCH Methylcyclohexane 11.000 150509 65040 113TMCP 1,1,3, - Trimethylcyclopentane 11.162 5248 2200 ECP Ethylcyclopentane 11.567 6584 2888 124TMCP 1,2,4 - Trimethylcyclopentane 12.014 5766 2474 123TMCP 1,2,3 - Trimethylcyclopentane 12.383 5076 2151 TOL Toluene 12.710 227891 91216 NC8 Normal Alkane C8 15.354 133805 45847 IP9 Isoprenoid C9 17.217 15669 5886 EB Ethyl- benzene 17.922 57982 21734 MXYL m- xylene 18.460 364714 104278 PXYL p- xylene 18.511 100853 49036 OXYL o- xylene 19.694 147982 51629 NC9 Normal Alkane C9 21.103 154078 53373 IP10 Isoprenoid C10 23.073 19648 6299 PB Propyl- benzene 23.242 32043 10438 NC10 Normal Alkane C10 26.709 156210 51828 IP11 Isoprenoid C11 27.994 21210 7015 NC11 Normal Alkane C11 31.981 162601 50373 NC12 Normal Alkane C12 36.912 125708 39373 IP13 Isoprenoid C13 37.646 30690 7479 IP14 Isoprenoid C14 40.414 18266 5787 NC13 Normal Alkane C13 41.533 120823 36794 • IP15 Isoprenoid C15 44.992 49034 14265 NC14 Normal Alkane C14 45.879 100133 29555 Company: CONOCOPHILLIPS Client ID: US146130 Well Name: GRANDVIEW 1 Project #: 09 -489 -A fa Depth: 8161 - FT Lab ID: CP293044 Sampling Point: File Name: G2090810.D Peak Compound Ret, ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.542 43979 9809 NC15 Normal Alkane C15 49.974 83076 22316 NC16 Normal Alkane C16 53.844 61611 18037 IP18 Isoprenoid C18 55.788 22472 4825 NC17 Normal Alkane C17 57.515 52903 14766 IP19 Isoprenoid C19 (Pristane) 57.870 22899 4454 PHEN Phenanthrene 58.934 27860 8154 NC18 Normal Alkane C18 61.002 42400 12042 IP20 Isoprenoid C20 (Phytane) 61.466 10833 2092 NC19 Normal Alkane C19 64.324 37939 10489 NC20 Normal Alkane C20 67.490 34737 9108 NC21 Normal Alkane C21 70.517 25626 7401 C25HBI Highly Branch Isoprenoid C25 70.790 3516 819 NC22 Normal Alkane C22 73.413 23723 6536 NC23 Normal Alkane C23 76.189 19540 5373 NC24 Normal Alkane C24 78.855 16656 4553 NC25 Normal Alkane C25 81.417 14829 3985 NC26 Normal Alkane C26 83.883 12941 3513 NC27 Normal Alkane C27 86.261 10770 2730 NC28 Normal Alkane C28 88.555 8450 2217 NC29 Normal Alkane C29 90.769 8649 1902 N C30 Normal Alkane C30 92.912 6392 1488 NC31 Normal Alkane C31 94.984 5464 1200 NC32 Normal Alkane C32 96.993 4038 907 NC33 Normal Alkane C33 98.941 5465 1013 NC34 Normal Alkane C34 100.833 3151 677 NC35 Normal Alkane C35 102.705 2750 557 NC36 Normal Alkane C36 104.750 2459 394 NC37 Normal Alkane C37 107.051 2593 322 NC38 Normal Alkane C38 109.690 1827 242 NC39 Normal Alkane C39 112.720 1159 144 NC40 Normal Alkane C40 116.248 1119 127 NC41 Normal Alkane C41 120.385 1215 109 • VP • Weatherford EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146131 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293045 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8164 FT Longitude: Bottom Depth: FT Extract GC Trace G2090811.D • E 0 co z z z a z "® z z m ,,, I. azZ ZZZZZZZ z �z zz � z � J Z Z Z • WGC parameters Thompson Mango Halpern Pristane /Phytane 2.10 A. BZIn C6 5.49 P, 8.17 Tr, 121.87 Pristane /n C17 0.41 B. TOL/nC 6.79 P2 2.99 Tr 17.94 Phytane /n C18 0.24 C. (n C + GO/ (CH +MCH) 0.26 P3 0.55 Tr 3.69 nC /(nC, +n C 0.52 I. Isoheptane Value 0.89 5N, 2.76 Tr 2.88 nC /(nC +n C 29 ) 0.73 F. n C 7 /MCH 0.29 N2 2.27 Tr 6.57 CPI Hunt 1.08 U. CH /MCP 5.03 6N, 83.26 Tr 2.00 Normal Paraffins 15.6 R. nC /2MH 6.23 K, 0.93 Tr 5.52 Isoprenoids 2.6 S. n C 6 /22DMB K2 0.57 C, 0.03 Cycloparaffins 3.0 H. Heptane Value 17.27 5N 0.03 C2 0.55 0 Branched (iso -) Paraffins 0.3 MCH /nC 3.40 P /N 0.24 C3 0.09 BTX aromatics 11.6 mpXYL/n C8 3.69 In(24DMP /23DMP) -1.84 C4 0.08 Resolved unknowns 65.5 C 0.25 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. 1979 Company: CONOCOPHILLIPS Client ID: US146131 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8164 - FT Lab ID: CP293045 Sam ling Point: File Name: G2090811.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.818 49 23 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.913 91 53 3MP 3- Methylpentane 6.180 141 86 NC6 Normal Alkane C6 6.567 1509 916 22DMP 2,2- Dimethylpentane 7.217 84 50 MCP Methylcyclopentane 7.275 4079 2265 24DMP 2,4- Dimethylpentane 7.406 230 121 223TMB 2,2,3 - Trimethylbutane 7.560 47 22 BZ Benzene 8.019 8278 4183 33DMP 3,3- Dimethylpentane 8.228 216 99 CH Cyclohexane 8.344 20518 10527 2MH 2- Methylhexane 8.722 6345 3196 23DMP 2,3- Dimethylpentane 8.773 1446 757 11DMCP 1,1- Dimethylcyclopentane 8.862 2203 1054 3MH 3- Methylhexane 9.061 8131 4018 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.293 4399 2123 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.406 4400 2120 • 3EP 3- Ethylpentane 9.468 645 482 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.520 7396 3530 NC7 Normal Alkane C7 10.112 39530 18692 ISTD Internal Standard MCH Methylcyclohexane 10.967 134515 58166 113TMCP 1,1,3, - Trimethylcyclopentane 11.130 4057 1708 ECP Ethylcyclopentane 11.535 5947 2598 124TMCP 1,2,4 - Trimethylcyclopentane 11.983 4512 1928 123TMCP 1,2,3- Trimethylcyclopentane 12.353 4034 1643 TOL Toluene 12.684 268487 105068 NC8 Normal Alkane C8 15.326 102114 35845 IP9 Isoprenoid C9 17.195 10118 3804 EB Ethyl- benzene 17.901 46896 17436 MXYL m- xylene 18.435 293045 89099 PXYL p - xylene 18.487 83938 39497 OXYL o- xylene 19.673 118270 41889 NC9 Normal Alkane C9 21.081 97271 34721 IP10 Isoprenoid C10 23.060 10860 3502 PB Propyl- benzene 23.229 22608 7480 NC10 Normal Alkane C10 26.691 91445 31192 IP11 Isoprenoid C11 27.985 11548 3838 NC11 Normal Alkane C11 31.966 96561 29924 NC12 Normal Alkane C12 36.900 73362 23334 IP13 Isoprenoid C13 37.642 17509 4376 IP14 Isoprenoid C14 40.410 11250 3524 • NC13 Normal Alkane C13 41.523 73334 22496 IP15 Isoprenoid C15 44.988 38055 11216 NC14 Normal Alkane C14 45.871 63610 18394 Company: CONOCOPHILLIPS Client ID: US146131 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8164 - FT Lab ID: CP293045 Sampling Point: File Name: G2090811.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.540 30894 6954 NC15 Normal Alkane C15 49.966 50631 14266 NC16 Normal Alkane C16 53.838 41290 12187 IP18 Isoprenoid C18 55.788 14695 3131 NC17 Normal Alkane C17 57.511 35878 10085 IP19 Isoprenoid C19 (Pristane) 57.866 14836 2882 PHEN Phenanthrene 58.931 24587 7170 NC18 Normal Alkane C18 60.999 29166 8281 IP20 Isoprenoid C20 (Phytane) 61.463 7058 1395 NC19 Normal Alkane C19 64.319 26672 7306 NC20 Normal Alkane C20 67.486 24651 6218 NC21 Normal Alkane C21 70.515 17950 4996 C25HBI Highly Branch Isoprenoid C25 70.785 2707 634 NC22 Normal Alkane C22 73.413 17049 4451 NC23 Normal Alkane C23 76.188 13855 4022 NC24 Normal Alkane C24 78.853 13031 3668 NC25 Normal Alkane C25 81.416 13439 3669 NC26 Normal Alkane C26 83.882 13705 3748 NC27 Normal Alkane C27 86.258 13536 3528 NC28 Normal Alkane C28 88.553 12327 3192 NC29 Normal Alkane C29 90.769 13239 3193 NC30 Normal Alkane C30 92.912 10753 2563 NC31 Normal Alkane C31 94.983 9381 2178 NC32 Normal Alkane C32 96.992 7123 1744 NC33 Normal Alkane C33 98.939 10436 1887 NC34 Normal Alkane C34 100.830 5419 1219 NC35 Normal Alkane C35 102.705 4581 981 NC36 Normal Alkane C36 104.751 3343 620 NC37 Normal Alkane C37 107.053 3440 501 NC38 Normal Alkane C38 109.686 2770 390 NC39 Normal Alkane C39 112.727 1734 213 NC40 Normal Alkane C40 116.243 1652 172 NC41 Normal Alkane C41 120.360 1393 121 • A V • Weatherford' EXTRACT GC L A a O R A T D R I E S S Company: CONOCOPHILLIPS Client ID: US146132 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293046 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8167 FT Longitude: Bottom Depth: FT Extract GC Trace G2090812.D 0 E • E x Z U I Z Z Z w y2 U W '.'� .r .-r ti m Zd+� �b Z U 0 U 7, n m m .y .. ,J.::1 ti a. Z t Z Z Z Z Z Z N Z Z U U te '�* I Z Z Z if;ll a WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.08 A. BZ/n C6 4.76 P, 7.64 Tr, 133.39 Pristane /n C17 0.45 B. TOUn C 7.59 P2 2.94 Tr 17.58 Phytane /nC, 0.26 C. (nC +n C 7 ) /(CH +MCH) 0.26 P3 0.54 Tr 3.76 n C 16 /(nC, +nC 0.51 I. IsoheptaneValue 0.92 5N, 2.58 Tr 2.99 n C /(nC +n C 0.70 F. n C 7 /MCH 0.29 N2 2.16 Tr 6.75 CPI Hunt 1.09 U. CH /MCP 5.05 6N, 84.14 Tr 1.99 Normal Paraffins 14.4 R. n C 7 /2MH 5.88 K 0.94 Tr 5.52 Isoprenoids 2.4 S. n C 6 /22DMB K2 0.58 C 0.04 Cycloparaffins 3.2 H. Heptane Value 16.89 5N 0.03 C2 0.54 0 Branched (iso -) Paraffins 0.3 MCH /nC 3.42 P /N 0.25 C3 0.10 BTX aromatics 12.5 mpXYUn C8 3.74 In(24DMP /23DMP) -1.74 C4 0.08 Resolved unknowns 65.7 C 0.24 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D., I 994.GCA: V.58, p.895. 3 Halpem,H.1.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146132 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8167 - FT Lab ID: CP293046 Sampling Point: File Name: G2090812.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 lso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.825 61 33 23DMB 2,3- Dimethylbutane 5.854 17 12 2MP 2- Methylpentane 5.921 144 89 3MP 3- Methylpentane 6.190 221 136 NC6 Normal Alkane C6 6.578 2169 1329 22DMP 2,2- Dimethylpentane 7.231 120 73 MCP Methylcyclopentane 7.288 5496 3067 24DMP 2,4- Dimethylpentane 7.420 305 164 223TMB 2,2,3- Trimethylbutane 7.573 67 30 BZ Benzene 8.033 10334 5265 33DMP 3,3- Dimethylpentane 8.244 271 124 CH Cyclohexane 8.359 27752 14161 2MH 2- Methylhexane 8.739 7818 3929 23DMP 2,3- Dimethylpentane 8.790 1744 918 11DMCP 1,1- Dimethylcyclopentane 8.878 2616 1268 3MH 3- Methylhexane 9.078 9847 4843 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.310 5210 2498 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.424 5198 2495 3EP 3- Ethylpentane 9.485 761 580 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.537 8708 4100 NC7 Normal Alkane C7 10.130 45993 21510 ISTD Internal Standard MCH Methylcyclohexane 10.984 157358 67474 113TMCP 1,1,3, - Trimethylcyclopentane 11.146 4698 1948 ECP Ethylcyclopentane 11.551 6809 2963 124TMCP 1,2,4 - Trimethylcyclopentane 11.999 5136 2185 123TMCP 1,2,3 - Trimethylcyclopentane 12.368 4362 1820 TOL Toluene 12.704 348946 131276 NC8 Normal Alkane C8 15.337 114307 39929 IP9 Isoprenoid C9 17.202 11226 4206 EB Ethyl- benzene 17.906 52924 19762 MXYL m- xylene 18.442 333391 98097 PXYL p- xylene 18.493 94450 44933 OXYL o- xylene 19.676 137200 48239 NC9 Normal Alkane C9 21.082 105177 37082 IP10 Isoprenoid C10 23.060 11483 3664 PB Propyl- benzene 23.229 24773 8198 NC10 Normal Alkane C10 26.690 92155 31076 IP11 Isoprenoid C11 27.984 11434 3707 NC11 Normal Alkane C11 31.964 95681 28129 NC12 Normal Alkane C12 36.898 70028 21728 IP13 Isoprenoid C13 37.641 15920 3756 IP14 lsoprenoid C14 40.409 9123 2815 NC13 Normal Alkane C13 41.521 71187 21262 IP15 Isoprenoid C15 44.992 45132 13269 NC14 Normal Alkane C14 45.869 60672 17277 Company: CONOCOPHILLIPS Client ID: US146132 Well Name: GRANDVIEW 1 Project #: 09 -489 -A S Depth: 8167 - FT Lab ID: CP293046 Sampling Point: File Name: G2090812.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.538 32229 7285 NC15 Normal Alkane C15 49.964 47019 13385 NC16 Normal Alkane C16 53.839 39071 11025 IP18 Isoprenoid C18 55.786 14750 3065 NC17 Normal Alkane C17 57.509 34411 9657 IP19 Isoprenoid C19 (Pristane) 57.868 15657 3110 PHEN Phenanthrene 58.933 35211 10410 NC18 Normal Alkane C18 60.999 28581 7994 IP20 Isoprenoid C20 (Phytane) 61.466 7528 1574 NC19 Normal Alkane C19 64.318 27162 7139 NC20 Normal Alkane C20 67.486 24110 6255 NC21 Normal Alkane C21 70.513 18580 5263 C25HBI Highly Branch Isoprenoid C25 70.786 3351 811 NC22 Normal Alkane C22 73.411 17346 4694 NC23 Normal Alkane C23 76.187 15217 4267 NC24 Normal Alkane C24 78.854 14455 3985 NC25 Normal Alkane C25 81.418 15451 4184 NC26 Normal Alkane C26 83.881 15714 4198 NC27 Normal Alkane C27 86.260 15329 3931 NC28 Normal Alkane C28 88.554 14157 3723 NC29 Normal Alkane C29 90.770 14922 3454 • NC30 Normal Alkane C30 92.910 11956 2913 NC31 Normal Alkane 031 94.984 10261 2468 NC32 Normal Alkane C32 96.992 8064 1860 NC33 Normal Alkane C33 98.943 12700 2106 NC34 Normal Alkane C34 100.834 6039 1297 NC35 Normal Alkane C35 102.707 4989 998 NC36 Normal Alkane C36 104.752 3662 659 NC37 Normal Alkane C37 107.050 3858 532 NC38 Normal Alkane C38 109.678 2830 406 NC39 Normal Alkane C39 112.720 1884 232 NC40 Normal Alkane C40 116.246 1986 206 NC41 Normal Alkane C41 120.370 1558 140 VP 0 Weatherford EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146135 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293049 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8176 FT Longitude: Bottom Depth: FT Extract GC Trace G2090825.D i • m z t o z M z z I Z2 z z z z ..:. iii` lira lakkei ' WGC "parameters Thompson' Mango Halpern Pristane /Phytane 2.12 A. BZ/n C6 3.28 P 8.08 Tr 148.38 Pristane /n C17 0.40 B. TOUn C 7.11 P2 2.71 Tr 20.88 Phytane /n C18 0.24 C. (n C +n C /(CH +MCH) 0.28 P3 0.50 Tr 3.95 nC /(nC +n C 19 ) 0.53 I. Isoheptane Value 0.94 5N 2.55 Tr 3.05 nC /(nC +n C 29 ) 0.85 F. nC /MCH 0.30 N2 1.92 Tr 7.00 CPI Hunt 1.07 U. CH /MCP 5.15 6N 84.24 Tr, 1.99 Normal Paraffins 16.3 R. nC /2MH 6.85 K 0.92 Tr 5.52 Isoprenoids 2.8 S. nC K2 0.59 C 0.04 Cycloparaffins 2.2 H. Heptane Value 18.17 5N 0.03 C2 0.55 0 Branched (iso-) Paraffins 0.2 MCH /nC, 3.31 P /N 0.26 C3 0.09 BTXaromatics 9.8 mpXYUn 2.79 In(24DMP /23DMP) -1.75 C4 0.09 Resolved unknowns 67.5 C5 0.23 'Thompson, K.F.M.,1983.GCA:V.47, p.303."Mango, F.D.,1994.GCA: V.58, p.895. 3 1-1alpem,H.1.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146135 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8176 - FT Lab ID: CP293049 III Sampling Point: File Name: G2090825.D Peak Compound Ret. ppt ppt Label Name Time Area Heig (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.838 176 92 23DMB 2,3- Dimethylbutane 5.864 42 35 2MP 2- Methylpentane 5.935 317 203 3MP 3- Methylpentane 6.202 245 149 NC6 Normal Alkane C6 6.591 1136 679 22DMP 2,2- Dimethylpentane 7.242 60 36 MCP Methylcyclopentane 7.300 1989 1098 24DMP 2,4- Dimethylpentane 7.432 142 73 223TMB 2,2,3 - Trimethylbutane 7.586 39 16 BZ Benzene 8.045 3724 1860 33DMP 3,3- Dimethylpentane 8.254 134 57 CH Cyclohexane 8.369 10241 5225 2MH 2- Methylhexane 8.748 3595 1815 23DMP 2,3- Dimethylpentane 8.799 816 429 11DMCP 1,1- Dimethylcyclopentane 8.887 1180 573 3MH 3- Methylhexane 9.087 4663 2306 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.319 2323 1123 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.432 2345 1129 III 3EP 3- Ethylpentane 9.492 344 270 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.545 4116 1939 NC7 Normal Alkane C7 10.136 24641 11601 ISTD Internal Standard MCH Methylcyclohexane 10.985 81677 35929 113TMCP 1,1,3, - Trimethylcyclopentane 11.152 2950 1223 ECP Ethylcyclopentane 11.557 3652 1600 124TMCP 1,2,4 - Trimethylcyclopentane 12.004 3292 1410 123TMCP 1,2,3 - Trimethylcyclopentane 12.372 2866 1207 TOL Toluene 12.695 175088 72002 NC8 Normal Alkane C8 15.338 90507 32575 IP9 Isoprenoid C9 17.203 9487 3581 EB Ethyl- benzene 17.906 31330 11715 MXYL m- xylene 18.428 195864 64517 PXYL p- xylene 18.482 56929 25583 OXYL o- xylene 19.668 78185 27945 NC9 Normal Alkane C9 21.081 98213 35141 IP10 Isoprenoid C10 23.056 11864 3791 PB Propyl- benzene 23.226 16924 5465 NC10 Normal Alkane 010 26.682 89525 30657 IP11 Isoprenoid C11 27.976 12037 4013 NC11 Normal Alkane C11 31.952 87273 27466 NC12 Normal Alkane C12 36.884 67557 21904 IP13 Isoprenoid C13 37.626 16176 4075 IP14 Isoprenoid C14 40.393 11471 3620 N • C13 Normal Alkane C13 41.507 65149 19992 1P15 Isoprenoid C15 44.968 28230 8563 NC14 Normal Alkane C14 45.853 55664 16248 Company: CONOCOPHILLIPS Client ID: US146135 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 40 Depth: 8176 - FT Lab ID: CP293049 Sampling Point: File Name: G2090825.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.522 25928 5857 NC15 Normal Alkane C15 49.947 45667 12213 NC16 Normal Alkane C16 53.818 33548 9728 IP18 Isoprenoid C18 55.767 11660 2509 NC17 Normal Alkane C17 57.490 28540 8115 IP19 Isoprenoid C19 (Pristane) 57.853 11529 2230 PHEN Phenanthrene 58.908 14464 4159 NC18 Normal Alkane C18 60.979 22929 6575 IP20 Isoprenoid C20 (Phytane) 61.447 5435 1032 NC19 Normal Alkane C19 64.301 20525 5736 NC20 Normal Alkane C20 67.468 18554 4900 NC21 Normal Alkane C21 70.494 14045 4063 C25HBI Highly Branch Isoprenoid C25 70.767 1995 450 NC22 Normal Alkane C22 73.390 13715 3517 NC23 Normal Alkane C23 76.167 10750 3063 NC24 Normal Alkane C24 78.833 9304 2650 NC25 Normal Alkane C25 81.393 8365 2302 NC26 Normal Alkane C26 83.861 7327 2017 NC27 Normal Alkane C27 86.238 6104 1667 NC28 Normal Alkane C28 88.531 4848 1265 NC29 Normal Alkane C29 90.746 5003 1106 NC30 Normal Alkane C30 92.893 3728 881 NC31 Normal Alkane C31 94.962 2917 702 NC32 Normal Alkane C32 96.973 2375 552 NC33 Normal Alkane C33 98.919 3483 654 NC34 Normal Alkane C34 100.808 1902 417 NC35 Normal Alkane C35 102.680 1661 351 NC36 Normal Alkane C36 104.726 1258 224 NC37 Normal Alkane C37 107.021 1178 191 NC38 Normal Alkane C38 109.647 940 137 NC39 Normal Alkane C39 112.690 736 90 NC40 Normal Alkane C40 116.188 705 71 NC41 Normal Alkane C41 120.329 502 45 • VP ID r d * EXTRACT GC L A B O RAT O R I E S Company: CONOCOPHILLIPS Client ID: US146136 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293050 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8179 FT Longitude: Bottom Depth: FT Extract GC Trace G2090826.D 0 • E z z I z _ ., z ssz n z "y r►li�..,lll.�.a, z z z z z z z z z z z z z z WGC parameters Thompson Mango Halpern Pristane /Phytane 2.10 A. BZ/n C6 5.51 P, 9.34 Tr, 116.41 Pristane /n C17 0.41 B. TOUn C 5.76 P2 3.17 Tr 20.20 Phytane /nC 0.24 C. (n C +nC /(CH +MCH) 0.30 P3 0.58 Tr 3.86 nC /(nC +n C is ) 0.53 I. Isoheptane Value 0.98 5N, 2.79 Tr 2.99 nC +n C 29 ) 0.85 F. n C 7 /MCH 0.33 N2 2.16 Tr 6.85 CPI Hunt 1.07 U. CH /MCP 5.59 6N, 81.96 Tr 1.84 Normal Paraffins 18.5 R. n C 7 /2MH 6.75 K 0.93 Tr 5.61 Isoprenoids 2.9 S. n C K 0.59 C, 0.04 Cycloparaffins 2.5 H. Heptane Value 19.35 5N 0.03 C2 0.56 0 Branched (iso -) Paraffins 0.2 MCH /n 3.01 P /N 0.27 C3 0.09 BTX aromatics 9.8 mpXYL /n C8 2.59 In(24DMP /23DMP) -1.87 C4 0.09 Resolved unknowns 64.8 C5 0.22 Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146136 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8179 - FT Lab ID: CP293050 Sampling Point: File Name: G2090826.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.830 20 13 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.929 74 43 3MP 3- Methylpentane 6.197 119 72 NC6 Normal Alkane C6 6.586 1169 716 22DMP 2,2- Dimethylpentane 7.238 104 61 MCP Methylcyclopentane 7.296 3284 1820 24DMP 2,4- Dimethylpentane 7.428 245 130 223TMB 2,2,3 - Trimethylbutane 7.580 55 26 BZ Benzene 8.042 6437 3189 33DMP 3,3- Dimethylpentane 8.251 248 114 CH Cyclohexane 8.366 18357 9422 2MH 2- Methylhexane 8.746 6934 3502 23DMP 2,3- Dimethylpentane 8.796 1596 845 11DMCP 1,1- Dimethylcyclopentane 8.885 2318 1128 3MH 3- Methylhexane 9.084 8938 4433 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.316 4217 2050 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.429 4271 2062 3EP 3- Ethylpentane 9.489 636 487 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.543 7686 3610 NC7 Normal Alkane C7 10.135 46812 22070 ISTD Internal Standard MCH Methylcyclohexane 10.988 140754 61013 113TMCP 1,1,3, - Trimethylcyclopentane 11.151 5362 2241 ECP Ethylcyclopentane 11.555 6311 2764 124TMCP 1,2,4 - Trimethylcyclopentane 12.002 5821 2501 123TMCP 1,2,3 - Trimethylcyclopentane 12.371 5022 2114 TOL Toluene 12.702 269843 105758 NC8 Normal Alkane C8 15.345 157396 54207 IP9 Isoprenoid C9 17.204 15847 5945 EB Ethyl- benzene 17.908 50707 18925 MXYL m- xylene 18.442 318309 94806 PXYL p- xylene 18.493 89804 42428 OXYL o- xylene 19.677 125105 43713 NC9 Normal Alkane C9 21.091 168277 57481 IP10 Isoprenoid C10 23.058 20035 6389 PB Propyl- benzene 23.227 27986 9038 NC10 Normal Alkane C10 26.693 154194 51033 IP11 Isoprenoid C11 27.979 20926 6949 NC11 Normal Alkane C11 31.963 153357 47930 NC12 Normal Alkane C12 36.894 119737 37669 IP13 Isoprenoid C13 37.630 27664 7107 IP14 Isoprenoid C14 40.397 17033 5366 • NC13 Normal Alkane C13 41.516 116955 35304 IP15 Isoprenoid C15 44.973 43456 12862 NC14 Normal Alkane C14 45.862 99965 30030 Company: CONOCOPHILLIPS Client ID: US146136 Well Name: GRANDVIEW 1 Project #: 09 -489 -A S Depth: 8179 - FT Lab ID: CP293050 Sampling Point: File Name: G2090826.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.525 40415 9189 NC15 Normal Alkane C15 49.956 84362 22642 NC16 Normal Alkane C16 53.826 62106 18671 IP18 Isoprenoid C18 55.770 21820 4725 NC17 Normal Alkane C17 57.497 53783 15517 IP19 Isoprenoid C19 (Pristane) 57.854 22058 4316 PHEN Phenanthrene 58.913 24103 7035 NC18 Normal Alkane C18 60.984 43262 12655 IP20 Isoprenoid C20 (Phytane) 61.445 10522 1954 NC19 Normal Alkane C19 64.306 38541 10526 NC20 Normal Alkane C20 67.471 35477 9244 NC21 Normal Alkane C21 70.500 26727 7744 C25HBI Highly Branch Isoprenoid C25 70.771 3098 746 NC22 Normal Alkane C22 73.394 24256 6792 NC23 Normal Alkane C23 76.171 20897 6021 NC24 Normal Alkane C24 78.836 17869 4947 NC25 Normal Alkane C25 81.398 16109 4525 NC26 Normal Alkane C26 83.863 14089 3771 NC27 Normal Alkane C27 86.241 11777 3027 NC28 Normal Alkane C28 88.534 9343 2468 NC29 Normal Alkane C29 90.750 9591 2169 NC30 Normal Alkane 030 92.894 7285 1704 NC31 Normal Alkane 031 94.965 5558 1353 NC32 Normal Alkane C32 96.975 4685 1032 NC33 Normal Alkane C33 98.920 6654 1210 NC34 Normal Alkane C34 100.814 3751 841 NC35 Normal Alkane C35 102.686 3253 677 NC36 Normal Alkane C36 104.729 2529 452 NC37 Normal Alkane C37 107.026 2380 362 NC38 Normal Alkane C38 109.657 1857 266 NC39 Normal Alkane C39 112.689 1371 170 NC40 Normal Alkane C40 116.217 1318 141 NC41 Normal Alkane C41 120.314 914 86 AV • Weatherford' EXTRACT GC L A B O R A Company: CONOCOPHILLIPS Client ID: US146140 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293054 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8191 FT Longitude: Bottom Depth: FT Extract GC Trace G2090828.D • E 0 z u z z z 4 z Z z z u. - & z . u M M o ' j °. . t z z I ii i ll 1 WGC parameters Thompson Mango Halpern Pristane /Phytane 1.78 A. BZ/n C6 0.33 P 6.56 Tr, 315.96 Pristane /n C17 0.41 B. TOUn C 10.72 P2 3.58 Tr 29.48 Phytane /n C18 0.29 C. (n C +nC7) /(CH +MCH) 0.64 P3 1.01 Tr3 9.66 n C 18 /(nC +nC 0.52 I. Isoheptane Value 1.71 5N, 1.79 Tr 6.43 n C 77 /(nC + 0.82 F. n C 7 /MCH 0.43 N2 1.33 Tr 16.09 CPI Hunt 1.08 U. CH /MCP 1.95 6N, 85.73 Tr 2.46 Normal Paraffins 19.3 R. n C 7 /2MH 4.58 K 0.93 Tr 3.58 Isoprenoids 3.4 S. n C 6 /22DMB K2 0.73 C 0.02 Cycloparaffins 1.8 H. Heptane Value 21.14 5N 0.02 C2 0.66 40 Branched (iso -) Paraffins 0.7 MCH /nC 2.35 P /N 0. C3 0.10 BTXaromatics 11.5 mpXYUnC 4.20 In(24DMP /23DMP) -1.93 C4 0.04 Resolved unknowns 62.2 C 0.19 'Thompson, K.F.M.,1983.GCA:V.47, p.303. 2 Mango, F.D.,1994.GCA: V.58, p.895. 3 1-lalpern,H.I_,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146140 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8191 - FT Lab ID: CP293054 Sampling Point: File Name: G2090828.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 3.934 71 26 NC4 Normal Alkane C4 4.051 777 340 IC5 Iso - alkane C5 4.490 2305 697 NC5 Normal Alkane C5 4.740 8356 1658 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.835 1200 724 23DMB 2,3- Dimethylbutane 5.861 1489 1109 2MP 2- Methylpentane 5.931 7487 5220 3MP 3- Methylpentane 6.199 9642 6312 NC6 Normal Alkane C6 6.588 22194 14032 22DMP 2,2- Dimethylpentane 7.241 79 48 MCP Methylcyclopentane 7.298 5866 3266 24DMP 2,4- Dimethylpentane 7.430 438 230 223TMB 2,2,3 - Trimethylbutane 7.581 36 12 BZ Benzene 8.044 7360 3703 33DMP 3,3- Dimethylpentane 8.253 162 63 CH Cyclohexane 8.368 11434 5856 2MH 2- Methylhexane 8.748 6578 3324 23DMP 2,3- Dimethylpentane 8.798 3027 1546 11DMCP 1,1- Dimethylcyclopentane 8.887 1023 475 3MH 3- Methylhexane 9.087 9879 4903 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.318 2554 1233 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.431 2518 1208 • 3EP 3- Ethylpentane 9.510 893 558 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.545 4559 2106 NC7 Normal Alkane C7 10.136 30158 14222 ISTD Internal Standard MCH Methylcyclohexane 10.984 70934 31107 113TMCP 1,1,3, - Trimethylcyclopentane 11.152 2032 867 ECP Ethylcyclopentane 11.557 3685 1613 124TMCP 1,2,4 - Trimethylcyclopentane 12.004 2666 1140 123TMCP 1,2,3- Trimethylcyclopentane 12.373 2465 987 TOL Toluene 12.708 323228 123541 NC8 Normal Alkane C8 15.335 71373 25876 IP9 Isoprenoid C9 17.202 6638 2501 EB Ethyl- benzene 17.906 37475 14068 MXYL m- xylene 18.432 230779 74342 PXYL p- xylene 18.485 68664 31208 OXYL o- xylene 19.670 95682 34374 NC9 Normal Alkane C9 21.076 75566 27413 IP10 Isoprenoid C10 23.055 8709 2790 PB Propyl- benzene 23.225 16353 5398 NC10 Normal Alkane C10 26.677 70224 24452 IP11 Isoprenoid C11 27.974 10408 3501 NC11 Normal Alkane C11 31.949 80137 25071 NC12 Normal Alkane C12 36.886 78209 25399 IP13 Isoprenoid C13 37.626 20063 5511 IP14 Isoprenoid C14 40.396 18751 6084 NC13 Normal Alkane C13 41.512 93076 28962 • IP15 Isoprenoid C15 44.971 43617 13210 NC14 Normal Alkane C14 45.861 95793 28504 Company: CONOCOPHILLIPS Client ID: US146140 Well Name: GRANDVIEW 1 Project #: 09 -489 -A . Depth: 8191 - FT Lab ID: CP293054 Sampling Point: File Name: G2090828.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.526 45887 10534 NC15 Normal Alkane C15 49.957 89084 24294 NC16 Normal Alkane C16 53.828 67434 19944 IP18 Isoprenoid C18 55.771 23973 5282 NC17 Normal Alkane C17 57.500 57521 16856 IP19 Isoprenoid C19 (Pristane) 57.856 23850 4667 PHEN Phenanthrene 58.912 19668 5722 NC18 Normal Alkane C18 60.987 46760 13617 IP20 Isoprenoid C20 (Phytane) 61.446 13416 2282 NC19 Normal Alkane C19 64.308 42532 11926 NC20 Normal Alkane C20 67.476 40678 10788 NC21 Normal Alkane C21 70.504 32466 9369 C25HBI Highly Branch Isoprenoid C25 70.765 1848 641 NC22 Normal Alkane C22 73.400 33774 8756 NC23 Normal Alkane C23 76.177 27092 7585 NC24 Normal Alkane C24 78.841 23643 6553 NC25 Normal Alkane C25 81.403 21184 5843 NC26 Normal Alkane C26 83.869 18294 4935 NC27 Normal Alkane C27 86.246 15961 4313 NC28 Normal Alkane C28 88.540 13045 3490 NC29 Normal Alkane C29 90.751 12882 3135 NC30 Normal Alkane C30 92.894 9679 2455 NC31 Normal Alkane C31 94.969 8093 1940 NC32 Normal Alkane C32 96.976 5835 1449 NC33 Normal Alkane C33 98.928 8480 1543 NC34 Normal Alkane C34 100.816 4402 990 NC35 Normal Alkane C35 102.686 3520 755 NC36 Normal Alkane C36 104.730 2549 473 NC37 Normal Alkane C37 107.028 2349 376 NC38 Normal Alkane C38 109.657 1912 279 NC39 Normal Alkane C39 112.692 1422 172 NC40 Normal Alkane C40 116.210 1326 137 NC41 Normal Alkane C41 120.335 874 80 • AV Weatherford` L A B O R A T O R I E S EXTRACT GC Company: CONOCOPHILLIPS Country: Client ID: US146143 UNITED STATES Project #: 09 - 489 -A Basin: NORTH SLOPE Lab ID: C Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE- OXFORDIAN Latitude: Top Depth: 8200 FT Longitude: Extract GC Trace Bottom Depth: F T G2090829.D O E Z Z F U Z £ Z Z U Z U 4 . . :. Sample Z Z Z v4 z M n " a, u il, Z WGC parameters Thompso Mango Halpern n. Pristane/Phytane 2.51 A. BZ /n C 0.43 P 11.57 Tr, 112.09 *al Pristane /n C17 0.47 B. TOL /nC 4.39 P2 4.97 Trz 25.53 40 Phytane /nC 0.22 C. (n Ce +nC7) /(CH +MCH) 0.50 P3 1.16 Tr 6.32 nC /(nC +nC 0.51 I. Isoheptane Value 1.47 5N 2.80 Tr, 4.65 n C +n C 0.81 F. n C 7 /MCH 0.44 NZ 2.26 Tr 10.97 CPI Hunt 1.06 U. CH /MCP 2.89 6N1 77.24 Tr 1.98 Normal Paraffins 24.9 R. n C 7 /2MH 5.49 K 0.95 Tr 4.36 Isoprenoids 3.9 S. n C e /22DMB K 0.69 C1 0.02 Cycloparaffins 1.4 H. Heptane Value 22.56 5N 0.04 C2 0.62 Branched (iso -) Paraffins 0.3 MCH /nC 2.29 P /N 0.51 C3 0.09 BTX aromatics 5.4 mpXYUn 1.80 In(24DMP /23DMP) -1.88 C4 0.05 Resolved unknowns 63.3 C5 0.21 Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,I994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146143 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8200 - FT Lab ID: CP293057 ill Sampling Point: File Name: G2090829.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 4.045 224 96 IC5 Iso - alkane C5 4.481 623 194 NC5 Normal Alkane C5 4.728 1958 483 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.811 346 220 23DMB 2,3- Dimethylbutane 5.837 449 312 2MP 2- Methylpentane 5.906 2257 1559 3MP 3- Methylpentane 6.174 2931 1910 NC6 Normal Alkane C6 6.561 7921 4940 22DMP 2,2- Dimethylpentane 7.213 62 37 MCP Methylcyclopentane 7.270 3000 1664 24DMP 2,4- Dimethylpentane 7.401 250 131 223TMB 2,2,3- Trimethylbutane 7.556 45 15 BZ Benzene 8.016 3400 1665 33DMP 3,3- Dimethylpentane 8.224 135 55 CH Cyclohexane 8.339 8672 4426 2MH 2- Methylhexane 8.718 4911 2453 23DMP 2,3- Dimethylpentane 8.768 1639 834 11DMCP 1,1- Dimethylcyclopentane 8.857 1056 480 3MH 3- Methylhexane 9.056 6678 3282 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.288 2124 1017 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.402 2094 1002 3EP 3- Ethylpentane 9.482 571 367 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.515 3682 1729 NC7 Normal Alkane C7 10.106 26955 12789 ISTD Internal Standard MCH Methylcyclohexane 10.955 61653 27048 113TMCP 1,1,3, - Trimethylcyclopentane 11.123 2671 1117 ECP Ethylcyclopentane 11.529 2848 1239 124TMCP 1,2,4 - Trimethylcyclopentane 11.976 3124 1332 123TMCP 1,2,3 - Trimethylcyclopentane 12.345 2695 1138 TOL Toluene 12.664 118362 49319 NC8 Normal Alkane C8 15.318 98343 35752 IP9 Isoprenoid C9 17.184 9249 3464 EB Ethyl- benzene 17.888 21364 8013 MXYL m- xylene 18.404 136470 47711 PXYL p- xylene 18.460 40718 17704 OXYL o- xylene 19.651 56893 20210 NC9 Normal Alkane C9 21.075 141275 49336 IP10 Isoprenoid 010 23.047 18232 5845 PB Propyl- benzene 23.216 14281 4393 NC10 Normal Alkane C10 26.684 143897 48157 IP11 Isoprenoid C11 27.973 22016 7444 NC11 Normal Alkane C11 31.958 142640 45694 NC12 Normal Alkane C12 36.893 121010 38252 IP13 Isoprenoid C13 37.626 27879 7415 IP14 Isoprenoid C14 40.396 20610 6698 • NC13 Normal Alkane C13 41.516 113824 35268 IP15 Isoprenoid C15 44.968 37286 11139 NC14 Normal Alkane C14 45.862 103745 31027 Company: CONOCOPHILLIPS Client ID: US146143 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 404040 Depth: 8200 - FT Lab ID: CP293057 Sampling Point: File Name: G2090829.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.525 44146 9893 NC15 Normal Alkane C15 49.957 97895 26374 NC16 Normal Alkane C16 53.827 76229 22381 IP18 Isoprenoid C18 55.770 29332 6530 NC17 Normal Alkane C17 57.499 70814 20514 IP19 Isoprenoid C19 (Pristane) 57.854 33047 6461 PHEN Phenanthrene 58.909 13739 3762 NC18 Normal Alkane C18 60.987 58904 17568 IP20 Isoprenoid 020 (Phytane) 61.442 13189 2280 NC19 Normal Alkane C19 64.309 55599 15484 NC20 Normal Alkane C20 67.475 50742 13895 NC21 Normal Alkane C21 70.501 42702 12320 C25HBI Highly Branch Isoprenoid C25 70.761 2427 634 NC22 Normal Alkane C22 73.399 39643 11116 NC23 Normal Alkane C23 76.175 35781 10111 NC24 Normal Alkane C24 78.840 31444 8705 NC25 Normal Alkane C25 81.402 28400 7845 NC26 Normal Alkane C26 83.868 24771 6717 NC27 Normal Alkane C27 86.245 21117 5649 NC28 Normal Alkane C28 88.537 17136 4529 NC29 Normal Alkane C29 90.752 17101 4274 NC30 Normal Alkane C30 92.896 13203 3269 NC31 Normal Alkane C31 94.967 11423 2790 NC32 Normal Alkane C32 96.975 8990 2191 NC33 Normal Alkane C33 98.924 11365 2155 NC34 Normal Alkane C34 100.816 6756 1493 NC35 Normal Alkane C35 102.685 6081 1204 NC36 Normal Alkane C36 104.726 4186 778 NC37 Normal Alkane C37 107.028 3614 589 NC38 Normal Alkane C38 109.663 2984 433 NC39 Normal Alkane C39 112.690 2241 297 NC40 Normal Alkane C40 116.207 2356 231 NC41 Normal Alkane C41 120.321 1744 151 ASP 4110 Weatherford' EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146144 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293058 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8203 FT Longitude: Bottom Depth: FT Extract GC Trace G2090830.D E • „, , z z Z z U Z £ U Z O SZ Z Z Z L8 C - Z Z Z ti Z O ,,„ . L U Z -' ' AM a Z Z Z Z � III 4. .r�.M� RI�W .... WGC parameters Thompson Mango Halpern Pristane /Phytane 2.46 A. BZ/n C6 1.14 P 8.79 Tr, 161.11 Pristane /n C17 0.47 B. TOUn C, 6.92 P2 3.41 Tr 23.28 Phytane /n C, 0.23 C. (n C +n C,) / (CH +MCH) 0.40 P3 0.73 Tr 5.07 nC, /(nC +nC 0.52 I. IsoheptaneValue 1.23 5N, 2.25 Tr 3.96 nC, +nC 0.81 F. n C 7 /MCH 0.40 N2 1.89 Tr 9.03 CPI Hunt 1.08 U. CH /MCP 3.65 6N, 82.94 Tr 1.99 Normal Paraffins 20.5 R. nC /2MH 5.89 K, 0.96 Tr 4.88 Isoprenoids 3.5 S. n C 6 /22DMB K2 0.64 C, 0.03 Cycloparaffins 1.5 H. Heptane Value 21.15 5N 0.03 C2 0.59 0 Branched (iso -) Paraffins 0.2 MCH /n 2.52 P /N 0.39 C3 0.10 BTXaromatics 7.1 mpXYUn 2.56 In(24DMP /23DMP) -1.75 C4 0.07 Resolved unknowns 66.2 C 0.21 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.1.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146144 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8203 - FT Lab ID: CP293058 Ill Sampling Point: File Name: G2090830.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 4.047 199 85 IC5 Iso - alkane C5 4.483 443 126 NC5 Normal Alkane C5 4.731 1299 262 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.801 146 89 23DMB 2,3- Dimethylbutane 5.828 178 123 2MP 2- Methylpentane 5.898 849 581 3MP 3- Methylpentane 6.168 1053 683 NC6 Normal Alkane C6 6.558 2928 1796 22DMP 2,2- Dimethylpentane 7.211 37 22 MCP Methylcyclopentane 7.269 1783 988 24DMP 2,4- Dimethylpentane 7.401 128 65 223TMB 2,2,3 - Trimethylbutane 7.556 56 14 BZ Benzene 8.015 3333 1634 33DMP 3,3- Dimethylpentane 8.224 84 35 CH Cyclohexane 8.339 6509 3314 2MH 2- Methylhexane 8.719 2662 1326 23DMP 2,3- Dimethylpentane 8.769 738 377 11DMCP 1,1- Dimethylcyclopentane 8.858 673 316 3MH 3- Methylhexane 9.057 3415 1683 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.290 1360 649 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.403 1340 642 3EP 3- Ethylpentane 9.464 259 183 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.516 2259 1056 NC7 Normal Alkane C7 10.107 15666 7352 ISTD Internal Standard MCH Methylcyclohexane 10.955 39451 17378 113TMCP 1,1,3, - Trimethylcyclopentane 11.125 1461 608 ECP Ethylcyclopentane 11.531 1746 756 124TMCP 1,2,4 - Trimethylcyclopentane 11.978 1727 736 123TMCP 1,2,3 - Trimethylcyclopentane 12.348 1464 612 TOL Toluene 12.665 108430 45522 NC8 Normal Alkane C8 15.314 52445 19571 IP9 Isoprenoid C9 17.185 4517 1693 EB Ethyl- benzene 17.888 15979 5968 MXYL m- xylene 18.400 102936 36897 PXYL p- xylene 18.458 31254 13155 OXYL o- xylene 19.649 43210 15559 NC9 Normal Alkane C9 21.064 71935 26255 IP10 Isoprenoid C10 23.044 8571 2759 PB Propyl- benzene 23.215 8920 2831 NC10 Normal Alkane 010 26.671 73297 25565 IP11 Isoprenoid C11 27.968 10537 3564 NC11 Normal Alkane 011 31.944 74046 23906 NC12 Normal Alkane C12 36.878 60464 20095 IP13 Isoprenoid C13 37.620 14115 3676 IP14 Isoprenoid C14 40.390 11414 3688 • NC13 Normal Alkane C13 41.502 57917 17980 IP15 Isoprenoid C15 44.963 26273 7996 NC14 Normal Alkane C14 45.848 54173 16198 Company: CONOCOPHILLIPS Client ID: US146144 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0104 Depth: 8203 - FT Lab ID: CP293058 Sampling Point: File Name: G2090830.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.519 27146 6276 NC15 Normal Alkane C15 49.944 48296 13575 NC16 Normal Alkane C16 53.817 38778 11607 IP18 Isoprenoid C18 55.764 15022 3294 NC17 Normal Alkane C17 57.489 36071 10398 IP19 Isoprenoid C19 (Pristane) 57.848 17115 3387 PHEN Phenanthrene 58.904 12481 3516 NC18 Normal Alkane C18 60.977 29703 8657 IP20 Isoprenoid C20 (Phytane) 61.444 6964 1177 NC19 Normal Alkane C19 64.298 27834 7737 NC20 Normal Alkane C20 67.465 25585 6875 NC21 Normal Alkane C21 70.492 20648 6012 C25HBI Highly Branch Isoprenoid C25 70.762 1274 385 NC22 Normal Alkane C22 73.389 20729 5493 NC23 Normal Alkane C23 76.167 17809 4988 NC24 Normal Alkane C24 78.831 15724 4280 NC25 Normal Alkane C25 81.392 14084 3869 NC26 Normal Alkane C26 83.859 12055 3296 NC27 Normal Alkane C27 86.237 10668 2809 NC28 Normal Alkane C28 88.529 8740 2360 NC29 Normal Alkane C29 90.744 8673 2077 NC30 Normal Alkane C30 92.888 6390 1601 NC31 Normal Alkane C31 94.961 5634 1293 NC32 Normal Alkane C32 96.967 4075 979 NC33 Normal Alkane C33 98.914 5322 970 NC34 Normal Alkane C34 100.808 2544 562 NC35 Normal Alkane C35 102.678 2218 465 NC36 Normal Alkane C36 104.720 1539 273 NC37 Normal Alkane C37 107.020 1415 219 NC38 Normal Alkane C38 109.650 1280 170 NC39 Normal Alkane C39 112.682 793 103 NC40 Normal Alkane C40 116.197 826 83 NC41 Normal Alkane C41 120.317 920 70 V • Weatherford* EXTRACT GC L A 9 0 R A T O R 1 E S S Company: CONOCOPHILLIPS Client ID: US146145 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293059 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8206 FT Longitude: Bottom Depth: FT Extract GC Trace G2090831.D 0 f 0, z z . ,, z z ,_, z , E z will , z Z .. ,„ _ Lis ° - z ` c 1 I u u u t,,..„2„.„...._ I I I 1 I z l Z z Z 2 Z I i II • l WGC parameters Thompson Mango Halpern Pristane /Phytane 2.71 A. BZ/n C6 0.55 P 9.29 Tr, 177.67 Pristane /n C17 0.43 B. TOL /nC 6.61 P2 3.94 Tr 26.86 Phytane /n C18 0.19 C. (n C +n C 7 ) /(CH +MCH) 0.51 P3 0.89 Tr 6.58 n C t5 /(nC +nC 0.52 I. Isoheptane Value 1.45 5N, 2.23 Tr 4.80 n C 17 /(nC +nC 0.84 F. n C 7 /MCH 0.46 N2 1.81 Tr 11.39 CPI Hunt 1.08 U. CH /MCP 2.89 6N, 81.84 Tr 2.09 Normal Paraffins 21.9 R. n C 7 /2MH 5.59 K, 0.94 Tr 4.45 Isoprenoids 3.6 S. n C K2 0.69 C 0.02 Cycloparaffins 1.5 H. Heptane Value 23.00 5N 0.03 C2 0.63 40 Branched (iso -) Paraffins 0.3 MCH /nC 2.19 P /N 0.49 C 0.09 BTX aromatics 7.7 mpXYUn C8 2.40 In(24DMP /23DMP) -1.91 C 0.05 Resolved unknowns 64.0 C 0.21 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. 1979 Company: CONOCOPHILLIPS Client ID: US146145 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8206 - FT Lab ID: CP293059 Sampling Point: File Name: G2090831.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 4.047 289 124 IC5 Iso - alkane C5 4.485 791 228 NC5 Normal Alkane C5 4.735 2603 517 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.824 370 232 23DMB 2,3- Dimethylbutane 5.850 469 327 2MP 2- Methylpentane 5.920 2300 1592 3MP 3- Methylpentane 6.188 2983 1945 NC6 Normal Alkane C6 6.576 8101 5056 22DMP 2,2- Dimethylpentane 7.228 66 38 MCP Methylcyclopentane 7.285 3288 1820 24DMP 2,4- Dimethylpentane 7.418 247 129 223TMB 2,2,3 - Trimethylbutane 7.570 25 10 BZ Benzene 8.031 4431 2197 33DMP 3,3- Dimethylpentane 8.240 128 51 CH Cyclohexane 8.355 9488 4823 2MH 2- Methylhexane 8.735 4973 2487 23DMP 2,3- Dimethylpentane 8.785 1662 851 11DMCP 1,1- Dimethylcyclopentane 8.874 1035 473 3MH 3- Methylhexane 9.073 6814 3356 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.305 2207 1048 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.418 2165 1035 al 3EP 3- Ethylpentane 9.497 547 363 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.532 3757 1749 NC7 Normal Alkane C7 10.123 27800 13116 ISTD Internal Standard MCH Methylcyclohexane 10.971 60967 26791 113TMCP 1,1,3, - Trimethylcyclopentane 11.139 2324 971 ECP Ethylcyclopentane 11.545 2903 1263 124TMCP 1,2,4 - Trimethylcyclopentane 11.992 2838 1211 123TMCP 1,2,3 - Trimethylcyclopentane 12.361 2428 1021 TOL Toluene 12.684 183890 75250 NC8 Normal Alkane C8 15.328 88817 32389 IP9 Isoprenoid C9 17.194 7635 2885 EB Ethyl- benzene 17.897 25310 9457 MXYL m- xylene 18.416 164376 56018 PXYL p- xylene 18.471 49024 21654 OXYL o- xylene 19.660 68561 24456 NC9 Normal Alkane C9 21.078 123227 43692 IP10 Isoprenoid C10 23.050 14489 4648 PB Propyl- benzene 23.220 14847 4716 NC10 Normal Alkane C10 26.683 124011 42308 IP11 Isoprenoid C11 27.973 17575 5949 NC11 Normal Alkane C11 31.955 123680 39781 NC12 Normal Alkane C12 36.888 100880 32371 IP13 Isoprenoid C13 37.625 21854 5862 IP14 Isoprenoid C14 40.393 17130 5596 • NC13 Normal Alkane C13 41.509 96174 29960 IP15 Isoprenoid C15 44.967 39996 11975 NC14 Normal Alkane C14 45.856 87983 26452 Company: CONOCOPHILLIPS Client ID: US146145 Well Name: GRANDVIEW 1 Project #: 09 -489 -A le Depth: 8206 - FT Lab ID: CP293059 Sampling Point: File Name: G2090831.D Peak Compound Ret ppt ppt Label Name Time Area Height (Area) (tight) IP16 Isoprenoid C16 48.523 40221 9317 NC15 Normal Alkane C15 49.952 79943 21735 NC16 Normal Alkane C16 53.823 62943 18705 IP18 Isoprenoid C18 55.766 22821 5113 NC17 Normal Alkane C17 57.496 57555 16542 IP19 Isoprenoid C19 (Pristane) 57.850 24990 4800 PHEN Phenanthrene 58.908 19590 5582 NC18 Normal Alkane C18 60.982 47390 13781 IP20 Isoprenoid C20 (Phytane) 61.443 9218 1673 NC19 Normal Alkane C19 64.303 44161 12366 NC20 Normal Alkane C20 67.470 40159 10682 NC21 Normal Alkane C21 70.497 32672 9444 C25HBI Highly Branch Isoprenoid C25 70.762 2223 573 NC22 Normal Alkane C22 73.392 30225 8410 NC23 Normal Alkane C23 76.169 25907 7244 NC24 Normal Alkane C24 78.834 22015 6039 NC25 Normal Alkane C25 81.398 19430 5278 NC26 Normal Alkane C26 83.862 16376 4485 NC27 Normal Alkane C27 86.238 14279 3750 NC28 Normal Alkane C28 88.531 11513 3026 NC29 Normal Alkane C29 90.746 11338 2678 NC30 Normal Alkane C30 92.890 8381 2040 NC31 Normal Alkane C31 94.964 6666 1629 NC32 Normal Alkane C32 96.967 4892 1183 NC33 Normal Alkane C33 98.916 6773 1246 NC34 Normal Alkane C34 100.810 3263 742 NC35 Normal Alkane C35 102.680 2790 561 NC36 Normal Alkane C36 104.721 1874 341 NC37 Normal Alkane C37 107.017 1837 275 NC38 Normal Alkane C38 109.656 1510 204 NC39 Normal Alkane C39 112.684 938 121 NC40 Normal Alkane C40 116.186 987 97 NC41 Normal Alkane C41 120.314 737 68 III 1 1 1 Weatherfo EXTRACT GC A B O R A T O R Company: CONOCOPHILLIPS Client ID: US146146 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293060 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8209 FT Longitude: Bottom Depth: FT Extract GC Trace G2090832.D 0 X • X Z Z O Z Z Z Z Z Z Z 4 _ U ' •. J'. 4 $ � iLd4d1iLk j 1Fi a WGC parameters Thompson' Mango H Pristane /Phytane 2.61 A. BZ/n 0.80 P, 7.08 Tr, 267.93 Pristane /n C17 0.40 B. TOUn C 9.96 P2 3.02 Tr 26.90 Phytane /n C 0.19 C. (n C +n C 7 ) /(CH +MCH) 0.51 P 0.71 Tr 6.67 nC18 /(nC18 +nCis) 0.52 I. Isoheptane Value 1.46 5N, 1.72 Tr 4.81 n C /(nC +n C 0.81 F. n C 7 /MCH 0.46 N2 1.38 Tr 11.48 CPI Hunt 1.08 U. CH /MCP 2.91 6N, 86.08 Tr 2.11 Normal Paraffins 19.5 R. n C 7 /2MH 5.60 K 0.94 Tr 4.30 Isoprenoids 3.6 S. n C /22DMB K2 0.69 C 0.02 Cycloparaffins 1.4 H. Heptane Value 22.84 5N 0.02 C2 0.63 0 Branched (iso-) Paraffins 0.3 MCH /nC 2.19 P /N 0.52 C 0.09 BTX aromatics 9.4 mpXYUn 3.33 In(24DMP /23DMP) -1.97 C 0.05 Resolved unknowns 64.7 C 0.21 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 14alpem,H.1.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146146 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8209 - FT Lab ID: CP293060 Sampling Point: File Name: G2090832.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 4.047 208 74 IC5 Iso - alkane C5 4.485 488 142 NC5 Normal Alkane C5 4.734 1857 360 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.813 330 201 23DMB 2,3- Dimethylbutane 5.840 384 271 2MP 2- Methylpentane 5.909 1929 1337 3MP 3- Methylpentane 6.179 2611 1697 NC6 Normal Alkane C6 6.568 7454 4634 22DMP 2,2- Dimethylpentane 7.221 52 31 MCP Methylcyclopentane 7.278 3136 1744 24DMP 2,4- Dimethylpentane 7.411 218 114 223TMB 2,2,3 - Trimethylbutane 7.563 38 13 BZ Benzene 8.024 5975 2937 33DMP 3,3- Dimethylpentane 8.233 120 45 CH Cyclohexane 8.348 9122 4640 2MH 2- Methylhexane 8.728 4451 2216 23DMP 2,3- Dimethylpentane 8.779 1569 797 11DMCP 1,1- Dimethylcyclopentane 8.868 926 414 3MH 3- Methylhexane 9.067 6180 3072 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.299 1968 950 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.412 1953 938 3EP 3- Ethylpentane 9.492 513 343 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.526 3381 1576 NC7 Normal Alkane C7 10.117 24913 11696 ISTD Internal Standard MCH Methylcyclohexane 10.966 54614 23996 113TMCP 1,1,3, - Trimethylcyclopentane 11.134 1906 800 ECP Ethylcyclopentane 11.540 2672 1166 124TMCP 1,2,4 - Trimethylcyclopentane 11.987 2405 1026 123TMCP 1,2,3 - Trimethylcyclopentane 12.356 2099 872 TOL Toluene 12.686 248106 98403 NC8 Normal Alkane C8 15.323 73560 27035 IP9 Isoprenoid C9 17.190 6342 2384 EB Ethyl- benzene 17.895 29447 11097 MXYL m- xylene 18.416 188469 62974 PXYL p - xylene 18.471 56720 25350 OXYL o- xylene 19.659 79359 28662 NC9 Normal Alkane C9 21.072 98916 35556 IP10 Isoprenoid C10 23.048' 10923 3527 PB Propyl- benzene 23.218 14737 4761 NC10 Normal Alkane 010 26.677 98448 34017 IP11 Isoprenoid C11 27.971 13123 4447 NC11 Normal Alkane C11 31.950 99785 31648 NC12 Normal Alkane C12 36.883 83266 27263 IP13 Isoprenoid C13 37.624 20922 5441 IP14 Isoprenoid C14 40.394 21798 7005 • NC13 Normal Alkane C13 41.509 87432 26800 IP15 Isoprenoid C15 44.968 49841 14878 NC14 Normal Alkane C14 45.857 87548 25471 Company: CONOCOPHILLIPS Client ID: US146146 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8209 - FT Lab ID: CP293060 Sampling Point: File Name: G2090832.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IP16 Isoprenoid C16 48.524 50000 11723 NC15 Normal Alkane C15 49.951 78505 20533 NC16 Normal Alkane C16 53.822 58387 17052 IP18 Isoprenoid C18 55.766 21212 4778 NC17 Normal Alkane C17 57.493 52533 14916 IP19 Isoprenoid C19 (Pristane) 57.855 21049 4108 PHEN Phenanthrene 58.907 20829 5892 NC18 Normal Alkane C18 60.982 42262 12243 IP20 Isoprenoid C20 (Phytane) 61.444 8068 1515 NC19 Normal Alkane C19 64.303 39470 10958 NC20 Normal Alkane C20 67.469 36911 9581 NC21 Normal Alkane C21 70.497 28903 8453 C25HBI Highly Branch Isoprenoid C25 70.772 1657 643 NC22 Normal Alkane C22 73.396 30986 8019 NC23 Normal Alkane C23 76.171 24659 6882 NC24 Normal Alkane C24 78.837 21979 6177 NC25 Normal Alkane C25 81.399 19823 5355 NC26 Normal Alkane C26 83.862 17033 4703 NC27 Normal Alkane C27 86.241 15181 4153 NC28 Normal Alkane C28 88.532 12327 3344 NC29 Normal Alkane C29 90.749 12273 3034 NC30 Normal Alkane C30 92.892 9130 2264 NC31 Normal Alkane C31 94.963 7568 1805 NC32 Normal Alkane C32 96.969 5439 1290 NC33 Normal Alkane C33 98.918 8047 1456 NC34 Normal Alkane C34 100.810 3777 858 NC35 Normal Alkane C35 102.680 3243 651 NC36 Normal Alkane C36 104.722 2256 425 NC37 Normal Alkane C37 107.019 2189 330 NC38 Normal Alkane C38 109.660 1877 271 NC39 Normal Alkane C39 112.689 1220 154 NC40 Normal Alkane C40 116.201 1200 126 NC41 Normal Alkane C41 120.310 977 86 • I V • Weatherfo EXTRACT GC L A B O R A T O R 1 E S Company: CONOCOPHILLIPS Client ID: US146148 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293062 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8215 FT Longitude: Bottom Depth: FT Extract GC Trace G2090833.D al 1 £z z - z z 0 z z " z z z z = - - - z a T z y z z A ii WGCparameters Thompson' Mango Halpern Pristane /Phytane 2.55 A. BZ/n C6 0.73 P, 10.30 Tr, 168.28 Pristane /n C17 0.38 B. TOUn C7 5.75 P2 4.30 Tr 29.29 Phytane /n C18 0.19 C. (n C +n C 7 ) /(CH +MCH) 0.53 P3 1.00 Tr 7.11 nC /(nC +nC 0.52 I. IsoheptaneValue 1.49 5N, 2.34 Tr 5.10 nC /(nC +n C 29 ) 0.80 F. n C 7 /MCH 0.49 N2 1.92 Tr 12.21 CPI Hunt 1.08 U. CH /MCP 3.01 6N, 80.14 Tr 2.21 Normal Paraffins 22.8 R. n C 7 /2MH 5.74 K, 0.93 Tr 4.34 Isoprenoids 3.5 S. n C 6 /22DMB K2 0.69 C, 0.02 Cycloparaffins 1.6 H. Heptane Value 24.07 5N 0.03 C2 0.62 40 Branched (iso -) Paraffins 0.4 MCH /nC 2.03 P /N 0. C3 0.08 BTX aromatics 7.4 mpXYUn 2.31 In(24DMP /23DMP) -2.01 C 0.04 Resolved unknowns 63.4 C5 0.23 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.L,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146148 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8215 - FT Lab ID: CP293062 Sampling Point: File Name: G2090833.D Peak Compound Ret. ppt ppt Label Name Time Area Height : (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 4.052 187 77 IC5 Iso - alkane C5 4.491 491 144 NC5 Normal Alkane C5 4.740 1721 338 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.823 281 174 23DMB 2,3- Dimethylbutane 5.849 343 240 2MP 2- Methylpentane 5.920 1701 1181 3MP 3- Methylpentane 6.189 2332 1515 NC6 Normal Alkane C6 6.579 6730 4247 22DMP 2,2- Dimethylpentane 7.233 53 30 MCP Methylcyclopentane 7.290 2871 1595 24DMP 2,4- Dimethylpentane 7.423 209 107 223TMB 2,2,3 - Trimethylbutane 7.571 27 10 BZ Benzene 8.037 4900 2447 33DMP 3,3- Dimethylpentane 8.245 109 44 CH Cyclohexane 8.361 8636 4407 2MH 2- Methylhexane 8.741 4542 2274 23DMP 2,3- Dimethylpentane 8.791 1561 795 11DMCP 1,1- Dimethylcyclopentane 8.880 891 418 3MH 3- Methylhexane 9.079 6339 3129 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.311 2003 961 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.424 1971 948 3EP 3- Ethylpentane 9.506 576 358 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.538 3352 1585 NC7 Normal Alkane C7 10.129 26093 12291 ISTD Internal Standard MCH Methylcyclohexane 10.977 53011 23301 113TMCP 1,1,3, - Trimethylcyclopentane 11.145 1988 838 ECP Ethylcyclopentane 11.550 2581 1126 124TMCP 1,2,4 - Trimethylcyclopentane 11.997 2498 1068 123TMCP 1,2,3- Trimethylcyclopentane 12.366 2156 910 TOL Toluene 12.687 149938 62343 NC8 Normal Alkane C8 15.331 71946 26693 IP9 Isoprenoid C9 17.196 6216 2348 EB Ethyl- benzene 17.900 19745 7381 MXYL m- xylene 18.413 127242 44928 PXYL p - xylene 18.470 39309 16890 OXYL o- xylene 19.659 53480 19130 NC9 Normal Alkane C9 21.074 94697 34083 IP10 Isoprenoid C10 23.050 11007 3540 PB Propyl- benzene 23.220 11044 3474 NC10 Normal Alkane C10 26.676 90436 31180 IP11 Isoprenoid C11 27.970 12206 4108 NC11 Normal Alkane C11 31.947 83718 26782 NC12 Normal Alkane C12 36.880 71017 23167 IP13 Isoprenoid C13 37.621 17298 4440 IP14 Isoprenoid C14 40.390 14022 4507 • NC13 Normal Alkane C13 41.504 75449 23795 IP15 Isoprenoid C15 44.963 31191 9424 NC14 Normal Alkane C14 45.853 76764 23083 Company: CONOCOPHILLIPS Client ID: US146148 Well Name: GRANDVIEW 1 Project #: 09 -489 -A • Depth: 8215 - FT Lab ID: CP293062 Sampling Point: File Name: G2090833.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.520 33627 7730 NC15 Normal Alkane C15 49.949 75462 20659 NC16 Normal Alkane C16 53.820 58790 17471 IP18 Isoprenoid C18 55.765 20118 4544 NC17 Normal Alkane C17 57.492 53054 15379 IP19 Isoprenoid C19 (Pristane) 57.852 20413 3939 PHEN Phenanthrene 58.904 14529 4056 NC18 Normal Alkane C18 60.978 42992 12718 IP20 Isoprenoid C20 (Phytane) 61.439 8002 1455 NC19 Normal Alkane C19 64.300 40133 11471 NC20 Normal Alkane C20 67.468 37245 10132 NC21 Normal Alkane C21 70.493 31213 8742 C25HBI Highly Branch Isoprenoid C25 70.760 1751 484 NC22 Normal Alkane C22 73.394 30491 8652 NC23 Normal Alkane C23 76.170 27986 8045 NC24 Normal Alkane C24 78.834 25267 6929 NC25 Normal Alkane C25 81.396 23230 6311 NC26 Normal Alkane C26 83.862 19556 5327 NC27 Normal Alkane C27 86.238 17229 4601 NC28 Normal Alkane C28 88.531 13464 3614 0 NC29 Normal Alkane C29 90.746 12911 3207 NC30 Normal Alkane C30 92.890 9111 2247 NC31 Normal Alkane C31 94.961 7234 1725 NC32 Normal Alkane C32 96.967 4921 1205 NC33 Normal Alkane C33 98.916 6799 1259 NC34 Normal Alkane C34 100.808 3185 730 NC35 Normal Alkane C35 102.677 2785 583 NC36 Normal Alkane C36 104.720 1855 327 NC37 Normal Alkane C37 107.013 1718 263 NC38 Normal Alkane C38 109.651 1407 189 NC39 Normal Alkane C39 112.687 815 107 NC40 Normal Alkane C40 116.171 834 84 NC41 Normal Alkane C41 120.323 598 55 • I V 0 Weatherford` EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146133 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293047 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8170 FT Longitude: Bottom Depth: FT Extract GC Trace G2090834.D Z Z Z • 2 O z U z U Z C - W 2 Z LUkJ LL L fflffim 1 z WGC parameters Thompson Mango Halpern Pristane /Phytane 2.11 A. BZ/n C6 1.30 P, 9.98 Tr, 102.10 Pristane /n C17 0.41 B. TOL /nC 5.08 P2 3.95 Tr 20.10 Phytane /n C 0.24 C. (n C +nC /(CH +MCH) 0.33 P3 0.75 Tr 4.47 n C 1B /(nC +nC 0.52 I. Isoheptane Value 1.09 5N, 3.00 Tr 3.49 nC /(nC +n C 29 ) 0.83 F. n C 7 /MCH 0.34 N2 2.44 Tr 7.96 CPI Hunt 1.07 U. CH /MCP 4.48 6N, 79.88 Tr 1.96 Normal Paraffins 18.1 R. n C 7 /2MH 5.76 K, 0.94 Tr 5.36 Isoprenoids 3.0 S. n C 6 /22DMB K2 0.62 C, 0.03 Cycloparaffins 2.0 H. Heptane Value 19.08 5N 0.04 C2 0.58 0 Branched (iso -) Paraffins 0.3 MCH /nC 2.93 P /N 0.31 C3 0.10 BTXaromatics 8.2 mpXYUn 3.10 In(24DMP /23DMP) -1.80 C4 0.07 Resolved unknowns 67.1 C 0.21 Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146133 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8170 - FT Lab ID: CP293047 Sampling Point: File Name: G2090834.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 4.052 384 169 IC5 Iso - alkane C5 4.491 973 293 NC5 Normal Alkane C5 4.740 2589 558 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.823 275 178 23DMB 2,3- Dimethylbutane 5.849 393 270 2MP 2- Methylpentane 5.919 1759 1213 3MP 3- Methylpentane 6.189 2165 1421 NC6 Normal Alkane C6 6.578 6137 3877 22DMP 2,2- Dimethylpentane 7.232 137 84 MCP Methylcyclopentane 7.289 5624 3139 24DMP 2,4- Dimethylpentane 7.422 389 208 223TMB 2,2,3 - Trimethylbutane 7.575 68 31 BZ Benzene 8.036 7978 3958 33DMP 3,3- Dimethylpentane 8.246 297 135 CH Cyclohexane 8.361 25181 12776 2MH 2- Methylhexane 8.741 9478 4705 23DMP 2,3- Dimethylpentane 8.791 2355 1226 11DMCP 1,1- Dimethylcyclopentane 8.880 2716 1292 3MH 3- Methylhexane 9.080 12138 5907 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.312 5325 2538 IS 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.425 5322 2519 3EP 3- Ethylpentane 9.486 858 645 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.539 9244 4254 NC7 Normal Alkane C7 10.132 54588 25269 ISTD Internal Standard MCH Methylcyclohexane 10.984 159750 67993 113TMCP 1,1,3, - Trimethylcyclopentane 11.147 5634 2327 ECP Ethylcyclopentane 11.551 7175 3094 124TMCP 1,2,4 - Trimethylcyclopentane 11.999 6227 2627 123TMCP 1,2,3 - Trimethylcyclopentane 12.367 5331 2198 TOL Toluene 12.697 277305 107972 NC8 Normal Alkane C8 15.339 167849 57215 IP9 lsoprenoid C9 17.197 17746 6638 EB Ethyl- benzene 17.902 62522 23043 MXYL m- xylene 18.442 407068 113219 PXYL p- xylene 18.492 112655 55352 OXYL o- xylene 19.674 168835 58250 NC9 Normal Alkane C9 21.088 216144 71555 IP10 lsoprenoid C10 23.052 26512 8436 PB Propyl- benzene 23.220 39724 12763 NC10 Normal Alkane C10 26.696 221777 69303 IP11 lsoprenoid C11 27.976 29496 9628 NC11 Normal Alkane 011 31.968 228133 69920 NC12 Normal Alkane C12 36.899 176085 53301 IP13 lsoprenoid C13 37.628 39362 10282 IP14 lsoprenoid C14 40.396 23592 7343 • NC13 Normal Alkane C13 41.519 170851 49706 IP15 lsoprenoid C15 44.977 74277 21044 NC14 Normal Alkane C14 45.865 142269 42060 Company: CONOCOPHILLIPS Client ID: US146133 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8170 - FT Lab ID: CP293047 Sampling Point: File Name: G2090834.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.523 60866 13733 NC15 Normal Alkane C15 49.959 123992 31460 NC16 Normal Alkane C16 53.829 88375 25418 IP18 Isoprenoid C18 55.768 30997 6616 NC17 Normal Alkane C17 57.497 76498 21478 IP19 Isoprenoid C19 (Pristane) 57.852 31559 6103 PHEN Phenanthrene 58.918 50712 14392 NC18 Normal Alkane C18 60.987 61630 17925 IP20 Isoprenoid C20 (Phytane) 61.449 14940 2996 NC19 Normal Alkane C19 64.308 56576 15300 NC20 Normal Alkane C20 67.472 50404 12964 NC21 Normal Alkane C21 70.497 39036 11060 C25HBI Highly Branch Isoprenoid C25 70.770 6113 1446 NC22 Normal Alkane C22 73.394 34841 9603 NC23 Normal Alkane C23 76.170 30489 8523 NC24 Normal Alkane C24 78.836 26040 7406 NC25 Normal Alkane C25 81.397 23733 6436 NC26 Normal Alkane C26 83.863 21242 5692 NC27 Normal Alkane C27 86.240 18182 4478 NC28 Normal Alkane C28 88.532 14752 3867 • NC29 Normal Alkane C29 90.749 15630 3472 NC30 Normal Alkane C30 92.891 12300 2883 NC31 Normal Alkane C31 94.961 9502 2319 NC32 Normal Alkane C32 96.970 8903 1881 NC33 Normal Alkane C33 98.919 12889 2126 NC34 Normal Alkane C34 100.812 6408 1374 NC35 Normal Alkane C35 102.680 5583 1100 NC36 Normal Alkane C36 104.724 4262 795 NC37 Normal Alkane C37 107.022 4467 655 NC38 Normal Alkane C38 109.650 3290 467 NC39 Normal Alkane C39 112.681 2239 297 NC40 Normal Alkane C40 116.202 2390 238 NC41 Normal Alkane C41 120.336 1738 156 III Weatherford EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146134 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293048 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8173 FT Longitude: Bottom Depth: FT Extract GC Trace G2090835.D x • rz c L z z z c 1 z v X - z m m o ~ - „ H ' Z Z Z Z Z Z Z Z Z VV GC parameters Thompson' Mango Halpern Pristane / Phytane 2.09 A. BZ/n Cs 1.89 Pi 8.07 Tr, 124.41 Pristane /n C17 0.40 B. TOL /n 7.20 P2 3.13 Tr 17.28 Phytane /n C18 0.24 C. (n C +n C 7 ) /(CH +MCH) 0.30 P3 0.64 Tr 3.76 n C 18 /(nC +nC 0.53 I. Isoheptane Value 1.00 5N, 2.59 Tr 2.94 n C /(nC +n C 0.86 F. n C 7 /MCH 0.32 N2 2.13 Tr 6.70 CPI Hunt 1.07 U. CH /MCP 4.14 6N, 83.45 Tr 1.78 Normal Paraffins 17.1 R. n C 7 /2MH 5.87 K 0.95 Tr 4.96 Isoprenoids 2.7 S. n C K2 0.59 C 0.04 Cycloparaffins 2.5 H. Heptane Value 17.96 5N 0.03 C2 0.56 0 Branched (iso -) Paraffins 0.3 MCH /nC 3.15 P /N 0.30 C3 0.11 BTX aromatics 11.4 mpXYL/n 3.50 In(24DMP /23DMP) -1.65 C4 0.08 Resolved unknowns 64.6 C5 0.21 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146134 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8173 - FT Lab ID: CP293048 Sampling Point: File Name: G2090835.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 4.050 222 96 IC5 Iso - alkane C5 4.488 510 149 NC5 Normal Alkane C5 4.736 1495 289 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.840 222 125 23DMB 2,3- Dimethylbutane 5.865 199 141 2MP 2- Methylpentane 5.935 1015 688 3MP 3- Methylpentane 6.202 1248 799 NC6 Normal Alkane C6 6.590 4101 2523 22DMP 2,2- Dimethylpentane 7.241 128 75 MCP Methylcyclopentane 7.298 4865 2702 24DMP 2,4- Dimethylpentane 7.431 307 163 223TMB 2,2,3 - Trimethylbutane 7.583 58 29 BZ Benzene 8.044 7745 3898 33DMP 3,3- Dimethylpentane 8.253 233 108 CH Cyclohexane 8.368 20126 10188 2MH 2- Methylhexane 8.748 6257 3088 23DMP 2,3- Dimethylpentane 8.798 1597 827 11DMCP 1,1- Dimethylcyclopentane 8.887 2126 1001 3MH 3- Methylhexane 9.086 7985 3870 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.318 3776 1788 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.431 3794 1783 • 3EP 3- Ethylpentane 9.492 608 448 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.545 6617 3052 NC7 Normal Alkane C7 10.136 36739 16983 ISTD Internal Standard MCH Methylcyclohexane 10.985 115571 49576 113TMCP 1,1,3, - Trimethylcyclopentane 11.150 3814 1572 ECP Ethylcyclopentane 11.555 5176 2226 124TMCP 1,2,4 - Trimethylcyclopentane 12.001 4159 1761 123TMCP 1,2,3 - Trimethylcyclopentane 12.369 3571 1487 TOL Toluene 12.698 264500 104112 NC8 Normal Alkane C8 15.332 113528 40154 IP9 Isoprenoid C9 17.192 11179 4179 EB Ethyl- benzene 17.896 49330 18444 MXYL m- xylene 18.428 308930 93083 PXYL p- xylene 18.480 88476 41690 OXYL o- xylene 19.662 122810 43571 NC9 Normal Alkane C9 21.072 131651 46161 IP10 Isoprenoid C10 23.045 15398 4890 PB Propyl- benzene 23.214 25342 8217 NC10 Normal Alkane C10 26.677 127812 42399 IP11 Isoprenoid C11 27.968 16762 5465 NC11 Normal Alkane C11 31.949 129609 39539 NC12 Normal Alkane C12 36.881 98974 30684 IP13 Isoprenoid C13 37.619 22338 5593 IP14 Isoprenoid C14 40.387 13107 4061 • NC13 Normal Alkane C13 41.503 93679 28337 IP15 Isoprenoid C15 44.963 36558 10859 NC14 Normal Alkane C14 45.848 76553 22873 Company: CONOCOPHILLIPS Client ID: US146134 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8173 - FT Lab ID: CP293048 Sampling Point: File Name: G2090835.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.513 31430 7129 NC15 Normal Alkane C15 49.944 64388 17369 NC16 Normal Alkane C16 53.814 46779 13677 IP18 Isoprenoid C18 55.760 16066 3459 NC17 Normal Alkane C17 57.485 40190 11617 IP19 Isoprenoid C19 (Pristane) 57.847 16118 3149 PHEN Phenanthrene 58.901 21455 6229 NC18 Normal Alkane C18 60.972 32307 9396 IP20 Isoprenoid C20 (Phytane) 61.439 7714 1452 NC19 Normal Alkane C19 64.294 28873 7891 NC20 Normal Alkane C20 67.461 26533 6674 NC21 Normal Alkane C21 70.485 19372 5620 C25HBI Highly Branch Isoprenoid C25 70.760 2283 562 NC22 Normal Alkane C22 73.383 17591 4832 NC23 Normal Alkane C23 76.160 14677 4106 NC24 Normal Alkane C24 78.826 12711 3544 NC25 Normal Alkane C25 81.387 11480 3015 NC26 Normal Alkane C26 83.852 10031 2682 NC27 Normal Alkane C27 86.230 8434 2143 NC28 Normal Alkane C28 88.525 6587 1762 NC29 Normal Alkane C29 90.742 6722 1504 NC30 Normal Alkane C30 92.884 4913 1173 NC31 Normal Alkane C31 94.952 4051 954 NC32 Normal Alkane C32 96.964 3046 699 NC33 Normal Alkane C33 98.907 3605 702 NC34 Normal Alkane C34 100.802 2063 455 NC35 Normal Alkane C35 102.675 1892 379 NC36 Normal Alkane C36 104.715 1568 268 NC37 Normal Alkane C37 107.004 1795 216 NC38 Normal Alkane C38 109.644 1273 165 NC39 Normal Alkane C39 112.660 643 85 NC40 Normal Alkane C40 116.190 742 79 NC41 Normal Alkane C41 120.280 708 64 • V 0 Weatherford* EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146149 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293063 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A W ell Name: G 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8217.4 FT Longitude: Bottom Depth: FT Extract GC Trace G2090836.D 0 • , E z I z z 0 z z z z z z �r ill I I l i i z= z z z z z z z z WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.78 A. BZJn C6 8.46 P 7.24 Tr, 249.76 Pristane /n C17 0.43 B. TOUn C, 9.50 P2 2.18 Tr 26.28 Phytane /n C18 0.19 C. (nC +n C,) /(CH +MCH) 0.36 P3 0.34 Tr 4.41 nC /(nC +n C 19 ) 0.52 I. IsoheptaneValue 1.01 5N 1.74 Tr, 3.52 nC /(nC +nC 0.81 F. nC /MCH 0.40 N2 1.46 Tr 7.93 CPI Hunt 1.07 U. CH /MCP 5.61 6N, 87.05 Tr, 2.15 Normal Paraffins 22.2 R. nC 7.46 K 0.93 Tr 6.57 Isoprenoids 3.2 S. nC /22DMB K2 0.60 C 0.03 Cycloparaffins 2.1 H. Heptane Value 22.00 5N 0.02 C2 0.57 40 Branched (iso -) Paraffins 0.2 MCH /n C, 2.52 P /N 0.23 C 0.09 BTX aromatics 10.8 mpXYUn 2.12 In(24DMP /23DMP) -1.85 C 0.08 Resolved unknowns 60.5 C5 0.24 'Thompson, K.F.M., I 983.GCA:V.47, p.303."Mango, F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146149 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8217.4 - FT Lab ID: CP293063 Sampling Point: File Name: G2090836.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.835 32 14 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.931 58 29 3MP 3- Methylpentane 6.198 79 45 NC6 Normal Alkane C6 6.586 789 462 22DMP 2,2- Dimethylpentane 7.238 41 24 MCP Methylcyclopentane 7.294 2086 1152 24DMP 2,4- Dimethylpentane 7.426 134 71 223TMB 2,2,3 - Trimethylbutane 7.577 28 10 BZ Benzene 8.039 6671 3351 33DMP 3,3- Dimethylpentane 8.248 116 47 CH Cyclohexane 8.363 11702 5964 2MH 2- Methylhexane 8.742 4370 2195 23DMP 2,3- Dimethylpentane 8.792 850 452 11DMCP 1,1- Dimethylcyclopentane 8.881 1241 600 3MH 3- Methylhexane 9.080 5474 2709 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.312 2647 1278 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.425 2671 1283 3EP 3- Ethylpentane 9.485 358 270 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.538 4436 2086 NC7 Normal Alkane C7 10.129 32609 15411 ISTD Internal Standard MCH Methylcyclohexane 10.978 82251 36029 113TMCP 1,1,3, - Trimethylcyclopentane 11.144 3135 1334 ECP Ethylcyclopentane 11.549 3385 1474 124TMCP 1,2,4 - Trimethylcyclopentane 11.996 3849 1653 123TMCP 1,2,3 - Trimethylcyclopentane 12.365 3227 1365 TOL Toluene 12.699 309946 119000 NC8 Normal Alkane C8 15.332 105234 38169 IP9 Isoprenoid C9 17.194 8410 3173 EB Ethyl- benzene 17.897 26582 9944 MXYL m- xylene 18.416 170732 57968 PXYL p - xylene 18.471 52251 23068 OXYL o- xylene 19.659 68249 24453 NC9 Normal Alkane C9 21.074 116079 41403 IP10 Isoprenoid C10 23.047 12198 3921 PB Propyl- benzene 23.217 13252 4203 NC10 Normal Alkane C10 26.674 97012 33381 IP11 Isoprenoid C11 27.967 12444 4150 NC11 Normal Alkane C11 31.945 89012 28485 NC12 Normal Alkane C12 36.879 78432 25446 IP13 Isoprenoid C13 37.619 16440 4208 IP14 Isoprenoid C14 40.386 11821 3778 NC13 Normal Alkane C13 41.503 80714 25536 • IP15 lsoprenoid C15 44.962 30473 9276 NC14 Normal Alkane C14 45.849 77537 23508 Company: CONOCOPHILLIPS Client ID: US146149 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 40 Depth: 8217.4 - FT Lab ID: CP293063 Sampling Point: File Name: G2090836.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.515 32355 7439 NC15 Normal Alkane C15 49.947 76995 21068 NC16 Normal Alkane C16 53.818 61958 18707 IP18 Isoprenoid C18 55.762 21009 4715 NC17 Normal Alkane C17 57.490 57282 16776 IP19 Isoprenoid C19 (Pristane) 57.848 24895 4884 PHEN Phenanthrene 58.902 15824 4501 NC18 Normal Alkane C18 60.978 47252 14091 IP20 Isoprenoid C20 (Phytane) 61.442 8959 1620 NC19 Normal Alkane C19 64.301 44171 12287 NC20 Normal Alkane C20 67.466 40552 10916 NC21 Normal Alkane C21 70.492 33649 9744 C25HBI Highly Branch Isoprenoid C25 70.758 2182 509 NC22 Normal Alkane C22 73.389 30128 8584 NC23 Normal Alkane C23 76.166 27023 7785 NC24 Normal Alkane C24 78.834 24017 6754 NC25 Normal Alkane C25 81.394 22078 5986 NC26 Normal Alkane C26 83.860 19241 5204 NC27 Normal Alkane C27 86.236 17273 4700 NC28 Normal Alkane C28 88.530 14102 3772 NC29 Normal Alkane C29 90.745 13532 3315 N C30 Normal Alkane C30 92.887 9724 2419 NC31 Normal Alkane C31 94.959 7345 1814 NC32 Normal Alkane C32 96.969 5270 1275 NC33 Normal Alkane C33 98.914 6820 1264 NC34 Normal Alkane C34 100.809 3383 777 NC35 Normal Alkane C35 102.677 2674 559 NC36 Normal Alkane C36 104.713 1772 318 NC37 Normal Alkane C37 107.016 1675 262 NC38 Normal Alkane C38 109.638 1271 189 NC39 Normal Alkane C39 112.683 909 112 NC40 Normal Alkane C40 116.189 830 86 NC41 Normal Alkane C41 120.317 618 56 • • Weatherford EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146137 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293051 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8182 FT Longitude: Bottom Depth: FT Extract GC Trace G2090837.D E • E o z z z z , l z z z •, � R 2 P N • •' £� _ ry Z L Z y Z Z U U U Z U U W ,y IA I z U U z U z � P WI. WGC parameters Thompson Mango Halpern Pristane /Phytane 1.94 A. BZ/n 5.75 P 6.25 Tr, 189.17 Pristane /n C17 0.38 B. TOUn C 10.31 P2 2.23 Tr 18.35 Phytane /n C 0.23 C. (n C +n C 7 ) /(CH +MCH) 0.25 P3 0.43 Tr 3.69 n C 18 /(nC +nC 0.51 I. Isoheptane Value 0.89 5N, 2.15 Tr 2.85 n C /(nC +n C 0.67 F. n C 7 /MCH 0.27 N2 1.69 Tr 6.55 CPI Hunt 1.09 U. CH /MCP 5.44 6N, 87.25 Tr 1.99 Normal Paraffins 15.5 R. n C 7 /2MH 6.43 K 0.92 Tr 5.28 Isoprenoids 2.7 S. n C /22DMB K2 0.57 C, 0.04 Cycloparaffins 1.9 H. Heptane Value 16.54 5N 0.02 C2 0.53 0 Branched (iso -) Paraffins 0.2 MCH /n 3.66 P /N 0.26 C3 0.09 BTX aromatics 10.4 mpXYUn 4.17 In(24DMP /23DMP) -1.76 C4 0.09 Resolved unknowns 67.9 C5 0.25 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,I994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146137 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8182 - FT Lab ID: CP293051 ill Sampling Point: File Name: G2090837.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.737 32 17 23DMB 2,3- Dimethylbutane 5.769 18 11 2MP 2- Methylpentane 5.842 78 43 3MP 3- Methylpentane 6.122 113 67 NC6 Normal Alkane C6 6.520 973 569 22DMP 2,2- Dimethylpentane 7.180 64 37 MCP Methylcyclopentane 7.238 2658 1500 24DMP 2,4- Dimethylpentane 7.371 164 83 223TMB 2,2,3 - Trimethylbutane 7.525 46 16 BZ Benzene 7.988 5593 2818 33DMP 3,3- Dimethylpentane 8.199 170 69 CH Cyclohexane 8.313 14455 7454 2MH 2- Methylhexane 8.696 4135 2095 23DMP 2,3- Dimethylpentane 8.746 951 500 11DMCP 1,1- Dimethylcyclopentane 8.835 1450 708 3MH 3- Methylhexane 9.036 5356 2653 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.268 2878 1391 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.382 2885 1390 3EP 3- Ethylpentane 9.444 447 322 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.496 4905 2345 NC7 Normal Alkane C7 10.089 26607 12556 ISTD Internal Standard MCH Methylcyclohexane 10.942 97251 42594 113TMCP 1,1,3, - Trimethylcyclopentane 11.109 2913 1211 ECP Ethylcyclopentane 11.515 4244 1855 124TMCP 1,2,4 - Trimethylcyclopentane 11.964 3346 1430 123TMCP 1,2,3 - Trimethylcyclopentane 12.334 2878 1209 TOL Toluene 12.666 274295 107463 NC8 Normal Alkane C8 15.308 85201 30161 IP9 Isoprenoid C9 17.178 9028 3384 EB Ethyl- benzene 17.884 42577 15859 MXYL m- xylene 18.416 276078 85053 PXYL p- xylene 18.468 78945 36816 OXYL o- xylene 19.655 117637 41936 NC9 Normal Alkane C9 21.063 91997 33133 IP10 Isoprenoid C10 23.043 10240 3323 PB Propyl- benzene 23.211 22588 7407 NC10 Normal Alkane C10 26.671 88294 30272 IP11 Isoprenoid C11 27.966 11010 3627 NC11 Normal Alkane C11 31.945 96131 28778 NC12 Normal Alkane C12 36.877 71573 22827 IP13 Isoprenoid C13 37.621 16911 4094 IP14 Isoprenoid C14 40.388 11765 3673 • NC13 Normal Alkane C13 41.500 75405 22618 IP15 Isoprenoid C15 44.970 54089 15682 NC14 Normal Alkane C14 45.849 65658 18601 Company: CONOCOPHILLIPS Client ID: US146137 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8182 - FT Lab ID: CP20051 Sampling Point: File Name: G2090837.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.518 37647 8415 NC15 Normal Alkane C15 49.943 50115 14344 NC16 Normal Alkane C16 53.815 45158 12758 IP18 Isoprenoid C18 55.764 15373 3242 NC17 Normal Alkane C17 57.488 41547 11791 IP19 Isoprenoid C19 (Pristane) 57.851 15742 3110 PHEN Phenanthrene 58.912 43596 12788 NC18 Normal Alkane C18 60.979 35227 10143 IP20 Isoprenoid C20 (Phytane) 61.446 8124 1754 NC19 Normal Alkane C19 64.299 34083 8947 NC20 Normal Alkane C20 67.466 30435 7721 NC21 Normal Alkane C21 70.492 22932 6539 C25HBI Highly Branch Isoprenoid C25 70.767 4195 1006 NC22 Normal Alkane C22 73.388 22804 5980 NC23 Normal Alkane C23 76.165 19062 5235 NC24 Normal Alkane C24 78.832 17682 5000 NC25 Normal Alkane C25 81.394 19207 5196 NC26 Normal Alkane C26 83.861 20197 5466 NC27 Normal Alkane C27 86.238 20598 5459 NC28 Normal Alkane C28 88.532 19089 5077 NC29 Normal Alkane C29 90.748 20709 4946 NC30 Normal Alkane C30 92.893 17324 4148 NC31 Normal Alkane C31 94.964 14448 3662 NC32 Normal Alkane C32 96.969 11257 2729 NC33 Normal Alkane C33 98.919 18341 3158 NC34 Normal Alkane C34 100.810 8762 1906 NC35 Normal Alkane C35 102.680 7236 1553 NC36 Normal Alkane C36 104.721 4883 947 NC37 Normal Alkane C37 107.014 4690 736 NC38 Normal Alkane C38 109.649 3751 563 NC39 Normal Alkane C39 112.681 2711 346 NC40 Normal Alkane C40 116.193 2664 265 NC41 Normal Alkane C41 120.305 1925 174 4110 V 0 Weatherford* EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146138 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293052 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8185 FT Longitude: Bottom Depth: FT Extract GC Trace G2090838.D 0 F z • X u y O Z Z 0 y I ['. Z Z Z Z y Z U " Z U b ,Pa `� ti Z 2 ' • z r ;3 "' o. al ,, :: I z y y z z v y r ...alit. ► emu+-. I� liih IR WGC parameters Thompson Mango 2 Halpern Pristane /Phytane 2.13 A. BZ/n 4.37 P, 8.35 Tr, 130.71 Pristane /n C17 0.48 B. TOUn C 6.56 P2 2.87 Tr 19.92 Phytane /n C 0.28 C. (n C +n C 7 ) /(CH +MCH) 0.26 P3 0.50 Tr 3.86 nC /(nC +nC 0.53 I. Isoheptane Value 0.91 5N, 2.73 Tr 3.01 n C /(nC +n C 0.84 F. n C 7 /MCH 0.29 N2 2.12 Tr 6.86 CPI Hunt 1.08 U. CH /MCP 5.19 6N, 83.42 Tr 2.04 Normal Paraffins 20.3 R. n C 7 /2MH 6.63 K, 0.93 Tr 5.81 Isoprenoids 3.9 S. n C 6 /22DMB K2 0.58 C, 0.03 Cycloparaffins 1.9 H. Heptane Value 17.46 5N 0.03 C2 0.56 0 Branched (iso -) Paraffins 0.2 MCH /n 3.43 P /N 0.24 C 0.09 BTXaromatics 8.5 mpXYUn 3.42 In(24DMP /23DMP) -1.84 C4 0.09 Resolved unknowns 64.1 C5 0.22 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.1.,1995,AAPG Bull.: V.79, p.801. 'Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146138 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8185 - FT Lab ID: CP293052 I ll Sampling Point: File Name: G2090838.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.818 66 33 23DMB 2,3- Dimethylbutane 5.842 19 14 2MP 2- Methylpentane 5.914 135 85 3MP 3- Methylpentane 6.182 212 116 NC6 Normal Alkane C6 6.570 1489 903 22DMP 2,2- Dimethylpentane 7.221 81 49 MCP Methylcyclopentane 7.279 3729 2078 24DMP 2,4- Dimethylpentane 7.411 211 113 223TMB 2,2,3 - Trimethylbutane 7.564 35 19 BZ Benzene 8.024 6509 3242 33DMP 3,3- Dimethylpentane 8.233 205 89 CH Cyclohexane 8.348 19367 9813 2MH 2- Methylhexane 8.728 5999 2974 23DMP 2,3- Dimethylpentane 8.778 1329 693 11DMCP 1,1- Dimethylcyclopentane 8.867 1995 952 3MH 3- Methylhexane 9.066 7691 3756 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.298 4031 1910 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.411 4061 1921 • 3EP 3- Ethylpentane 9.471 530 434 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.525 6934 3213 NC7 Normal Alkane C7 10.116 39749 18391 ISTD Internal Standard MCH Methylcyclohexane 10.968 136502 58447 113TMCP 1,1,3, - Trimethylcyclopentane 11.132 4177 1725 ECP Ethylcyclopentane 11.537 6085 2626 124TMCP 1,2,4 - Trimethylcyclopentane 11.983 4872 2056 123TMCP 1,2,3 - Trimethylcyclopentane 12.352 4173 1730 TOL Toluene 12.680 260770 102205 NC8 Normal Alkane C8 15.320 130730 45728 IP9 Isoprenoid C9 17.182 12724 4760 EB Ethyl- benzene 17.887 54473 20122 MXYL m- xylene 18.422 348707 101622 PXYL p- xylene 18.473 98600 47165 OXYL o- xylene 19.656 140769 49283 NC9 Normal Alkane C9 21.066 141861 49305 IP10 Isoprenoid C10 23.039 16110 5104 PB Propyl- benzene 23.207 28938 9391 NC10 Normal Alkane 010 26.674 136592 44272 IP11 Isoprenoid C11 27.964 19780 6432 NC11 Normal Alkane C11 31.951 156896 46822 NC12 Normal Alkane C12 36.889 148974 44679 IP13 Isoprenoid C13 37.623 45606 11721 IP14 Isoprenoid C14 40.391 33806 10597 • NC13 Normal Alkane C13 41.516 168770 49575 IP15 Isoprenoid C15 44.967 69519 20540 NC14 Normal Alkane C14 45.863 154244 45417 Company: CONOCOPHILLIPS Client ID: US146138 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 4 Depth: 8185 - FT Lab ID: CP293052 Sampling Point: File Name: G2090838.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.523 75987 17248 NC15 Normal Alkane C15 49.961 152361 38737 NC16 Normal Alkane C16 53.833 114124 32539 IP18 Isoprenoid C18 55.767 43979 9533 NC17 Normal Alkane C17 57.501 101891 28532 IP19 Isoprenoid C19 (Pristane) 57.855 48540 9278 PHEN Phenanthrene 58.910 36126 10343 NC18 Normal Alkane C18 60.988 82680 24547 IP20 Isoprenoid C20 (Phytane) 61.440 22834 4128 NC19 Normal Alkane C19 64.307 74337 20438 NC20 Normal Alkane C20 67.475 66593 17906 NC21 Normal Alkane C21 70.498 51918 14808 C25HBI Highly Branch Isoprenoid C25 70.762 4709 1100 NC22 Normal Alkane C22 73.396 48477 12917 NC23 Normal Alkane C23 76.169 40728 11382 NC24 Normal Alkane C24 78.836 35065 9896 NC25 Normal Alkane C25 81.398 32036 8561 NC26 Normal Alkane C26 83.864 27777 7498 NC27 Normal Alkane C27 86.239 23386 6061 NC28 Normal Alkane C28 88.533 18916 4976 NC29 Normal Alkane C29 90.749 18900 4614 • NC30 Normal Alkane C30 92.885 14931 3582 NC31 Normal Alkane C31 94.961 12049 2921 NC32 Normal Alkane C32 96.969 9008 2152 NC33 Normal Alkane C33 98.911 13829 2419 NC34 Normal Alkane C34 100.807 6528 1426 NC35 Normal Alkane C35 102.676 5741 1201 NC36 Normal Alkane C36 104.717 4154 728 NC37 Normal Alkane C37 107.018 3890 554 NC38 Normal Alkane C38 109.638 3104 442 NC39 Normal Alkane C39 112.677 2139 271 NC40 Normal Alkane C40 116.180 2140 218 NC41 Normal Alkane C41 120.297 1848 154 VP • Weather fort EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146139 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293053 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8188 FT Longitude: Bottom Depth: FT Extract GC Trace G2090839.D 2 ill ,., z z „..,, co p Z _, Z Z Z ,, ,, z ,0 ._. Z I U Z Z ._, o Z Z Z Z U N x� v. z z c,,, ,, ,. 0_ m „ :. z a. 5 `- � .. zz z z 1�y z WGC parameters Thompson Mango Halpe Pristane /Phytane 2.13 A. BZ/n C6 5.16 P, 7.67 Tr, 154.37 Pristane /n C17 0.43 B. TOUn C, 7.77 P2 2.69 Tr 19.87 Phytane /n C 0.24 C. (n C +n C,) /(CH +MCH) 0.27 P3 0.49 Tr 3.90 n C 18 /(nC +nC 0.53 I. Isoheptane Value 0.94 5N, 2.41 Tr 3.07 n C 1 , /(nC +nC 0.84 F. n C, /MCH 0.30 N2 1.94 Tr 6.97 CPI Hunt 1.08 U. CH /MCP 5.06 6N, 84.80 Tr, 2.01 Normal Paraffins 20.2 R. n C, /2MH 6.47 K, 0.94 Tr 5.54 Isoprenoids 3.5 S. n C /22DMB K2 0.58 C, 0.03 Cycloparaffins 2.1 H. Heptane Value 17.88 5N 0.03 C2 0.54 1111 Branched (iso -) Paraffins 0.2 MCH /nC, 3.29 P /N 0.26 C 0.09 BTX aromatics 9.8 mpXYUn C8 3.41 In(24DMP /23DMP) -1.81 C4 0.09 Resolved unknowns 62.9 C 0.25 Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.1.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146139 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8188 - FT Lab ID: CP293053 Sampling Point: File Name: G2090839.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.793 64 33 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.893 104 64 3MP 3- Methylpentane 6.166 151 96 NC6 Normal Alkane C6 6.557 1410 852 22DMP 2,2- Dimethylpentane 7.212 83 50 MCP Methylcyclopentane 7.269 3678 2051 24DMP 2,4- Dimethylpentane 7.402 211 114 223TMB 2,2,3 - Trimethylbutane 7.555 41 19 BZ Benzene 8.016 7271 3681 33DMP 3,3- Dimethylpentane 8.226 204 90 CH Cyclohexane 8.341 18602 9564 2MH 2- Methylhexane 8.722 5861 2963 23DMP 2,3- Dimethylpentane 8.772 1293 682 11DMCP 1,1- Dimethylcyclopentane 8.861 1907 936 3MH 3- Methylhexane 9.061 7435 3697 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.293 3819 1852 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.406 3842 1855 • 3EP 3- Ethylpentane 9.468 609 448 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.519 6450 3079 NC7 Normal Alkane C7 10.112 37897 17876 ISTD Internal Standard MCH Methylcyclohexane 10.965 124801 54291 113TMCP 1,1,3, - Trimethylcyclopentane 11.129 3991 1672 ECP Ethylcyclopentane 11.534 5460 2394 124TMCP 1,2,4 - Trimethylcyclopentane 11.981 4549 1953 123TMCP 1,2,3 - Trimethylcyclopentane 12.351 3871 1634 TOL Toluene 12.684 294390 113991 NC8 Normal Alkane C8 15.323 120773 42473 IP9 Isoprenoid C9 17.186 11774 4428 EB Ethyl- benzene 17.892 50375 18877 MXYL m- xylene 18.427 320156 95150 PXYL p- xylene 18.478 91453 43323 OXYL o- xylene 19.662 130269 46134 NC9 Normal Alkane C9 21.072 131613 46313 IP10 Isoprenoid C10 23.044 15543 5001 PB Propyl- benzene 23.213 25728 8383 NC10 Normal Alkane C10 26.676 123680 42191 IP11 Isoprenoid C11 27.966 18373 6144 NC11 Normal Alkane C11 31.950 135661 42687 NC12 Normal Alkane C12 36.884 125147 39727 IP13 Isoprenoid C13 37.619 34499 8950 IP14 Isoprenoid C14 40.388 23429 7489 • NC13 Normal Alkane C13 41.510 138650 41775 IP15 Isoprenoid C15 44.963 55577 16515 NC14 Normal Alkane C14 45.857 128605 38476 Company: CONOCOPHILLIPS Client ID: US146139 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 411) Depth: 8188 - FT Lab ID: CP293053 Sampling Point: File Name: G2090839.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.516 55844 12776 NC15 Normal Alkane C15 49.954 125385 32500 NC16 Normal Alkane C16 53.823 95025 27521 IP18 Isoprenoid C18 55.762 33631 7361 NC17 Normal Alkane C17 57.495 83188 24442 IP19 Isoprenoid C19 (Pristane) 57.848 35378 6776 PHEN Phenanthrene 58.905 31020 8942 NC18 Normal Alkane C18 60.981 69209 20221 IP20 Isoprenoid C20 (Phytane) 61.438 16646 3115 NC19 Normal Alkane C19 64.302 61795 16948 NC20 Normal Alkane C20 67.467 57286 15003 NC21 Normal Alkane C21 70.492 42783 12227 C25HBI Highly Branch Isoprenoid C25 70.759 3910 939 NC22 Normal Alkane C22 73.389 38183 10416 NC23 Normal Alkane C23 76.167 32764 9305 NC24 Normal Alkane C24 78.829 28214 8080 NC25 Normal Alkane C25 81.393 25151 6846 NC26 Normal Alkane C26 83.857 21681 5938 NC27 Normal Alkane C27 86.235 18357 4963 NC28 Normal Alkane C28 88.527 15206 4140 NC29 Normal Alkane C29 90.742 15637 3841 NC30 Normal Alkane C30 92.884 12305 3033 NC31 Normal Alkane C31 94.957 10402 2537 NC32 Normal Alkane C32 96.964 7707 1893 NC33 Normal Alkane C33 98.910 11406 1984 NC34 Normal Alkane C34 100.803 5874 1298 NC35 Normal Alkane C35 102.673 4990 1057 NC36 Normal Alkane C36 104.714 3528 655 NC37 Normal Alkane C37 107.011 3634 537 NC38 Normal Alkane C38 109.643 2953 405 NC39 Normal Alkane C39 112.661 1772 231 NC40 Normal Alkane C40 116.186 1848 191 NC41 Normal Alkane C41 120.276 1510 129 • VP • W � LABORATORIES EXTRACT GC Company: CONOCOPHILLIPS Client ID: US146141 Country: STATES Project #: 09 -489 -A Basin: UNITED NORTH SLOPE Lab ID: CP293055 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8194 FT Longitude: Bottom Depth: FT Extract GC Trace G2090840.D a P. z • z z I z z z z z Z £$ ,q o. Z Z U U m Z z Z Z Z , II. aim L. . WGC parameters Thompson' Mango Halpern' Pristane /Phytane 2.53 A. BZ/n C6 6.01 P 7.23 Tr, 201.54 Pristane /n C17 0.49 B. TOUn C 9.06 P2 2.49 Tr 22.24 Phytane /n C18 0.24 C. (n C +n C,) /(CH +MCH) 0.31 Po 0.44 Tr 4.25 n C 18 /(nC +nC 0.52 I. Isoheptane Value 1.02 5N, 2.00 Tr 3.42 nC 1(nC +n C 29 ) 0.84 F. n C 7 /MCH 0.35 N2 1.67 Tr 7.66 CPI Hunt 1.09 U. CH /MCP 4.97 6N, 86.18 Tr, 2.07 Normal Paraffins 22.6 R. n C 7 /2MH 6.51 K, 0.94 Tr 5.87 Isoprenoids 3.9 S. n C /22DMB K2 0.60 C 0.04 Cycloparaffins 1.7 H. Heptane Value 19.73 5N 0.02 C2 0.54 0 Branched (iso -) Paraffins 0.2 MCH /n C, 2.86 P /N 0.26 Co 0.10 BTX aromatics 8.3 mpXYUn 2.73 In(24DMP /23DMP) -1.65 C 0.10 Resolved unknowns 62.5 C 0.22 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpern,H.1.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146141 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8194 - FT Lab ID: CP293055 ill Sampling Point: File Name: G2090840.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 5.807 24 13 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.906 54 31 3MP 3- Methylpentane 6.176 89 46 NC6 Normal Alkane C6 6.565 732 442 22DMP 2,2- Dimethylpentane 7.218 44 24 MCP Methylcyclopentane 7.275 1798 991 24DMP 2,4- Dimethylpentane 7.408 121 59 223TMB 2,2,3 - Trimethylbutane 7.555 34 13 BZ Benzene 8.021 4397 2184 33DMP 3,3- Dimethylpentane 8.230 111 44 CH Cyclohexane 8.345 8943 4578 2MH 2- Methylhexane 8.725 3048 1532 23DMP 2,3- Dimethylpentane 8.775 627 332 11DMCP 1,1- Dimethylcyclopentane 8.864 892 431 3MH 3- Methylhexane 9.063 3789 1864 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.295 1836 885 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.408 1842 882 • 3EP 3- Ethylpentane 9.470 261 198 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.522 3043 1436 NC7 Normal Alkane C7 10.112 19839 9331 ISTD Internal Standard MCH Methylcyclohexane 10.961 56696 24982 113TMCP 1,1,3, - Trimethylcyclopentane 11.129 1952 817 ECP Ethylcyclopentane 11.535 2442 1062 124TMCP 1,2,4 - Trimethylcyclopentane 11.982 2261 964 123TMCP 1,2,3- Trimethylcyclopentane 12.351 1890 795 TOL Toluene 12.674 179773 73634 NC8 Normal Alkane C8 15.316 64320 23763 IP9 Isoprenoid C9 17.184 5604 2115 EB Ethyl- benzene 17.887 21179 7928 MXYL m- xylene 18.402 134874 47063 PXYL p- xylene 18.459 40598 17591 OXYL o- xylene 19.648 56123 20141 NC9 Normal Alkane C9 21.063 81088 29458 IP10 Isoprenoid C10 23.040 9924 3179 PB Propyl- benzene 23.211 11428 3671 NC10 Normal Alkane C10 26.667 82154 28505 IP11 Isoprenoid C11 27.963 12505 4247 NC11 Normal Alkane C11 31.940 88891 28636 NC12 Normal Alkane C12 36.875 82056 26908 IP13 Isoprenoid C13 37.615 19798 5400 IP14 Isoprenoid C14 40.383 14713 4699 • NC13 Normal Alkane C13 41.501 87247 27341 1P15 Isoprenoid C15 44.956 30854 9354 NC14 Normal Alkane C14 45.847 82739 25695 Company: CONOCOPHILLIPS Client ID: US146141 Well Name: GRANDVIEW 1 Project #: 09 -489 -A fp Depth: 8194 - FT Lab ID: CP293055 Sampling Point: File Name: G2090840.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.512 35733 8415 NC15 Normal Alkane C15 49.943 80059 22302 NC16 Normal Alkane C16 53.815 63135 19131 IP18 Isoprenoid C18 55.757 24177 5314 NC17 Normal Alkane C17 57.487 56936 16682 IP19 Isoprenoid C19 (Pristane) 57.848 27984 5422 PHEN Phenanthrene 58.898 14476 4078 NC18 Normal Alkane C18 60.974 46484 13775 IP20 Isoprenoid C20 (Phytane) 61.436 11071 1976 NC19 Normal Alkane C19 64.294 42773 11903 NC20 Normal Alkane C20 67.463 39464 10654 NC21 Normal Alkane C21 70.488 32972 9261 C25HBI Highly Branch Isoprenoid C25 70.751 2202 506 NC22 Normal Alkane C22 73.384 29608 8240 NC23 Normal Alkane C23 76.162 24861 7023 NC24 Normal Alkane C24 78.827 20514 5696 NC25 Normal Alkane C25 81.387 17902 4905 NC26 Normal Alkane C26 83.853 15281 4101 NC27 Normal Alkane C27 86.231 13460 3571 NC28 Normal Alkane C28 88.523 11049 2986 NC29 Normal Alkane C29 90.737 10818 2621 NC30 Normal Alkane C30 92.882 7958 2014 NC31 Normal Alkane C31 94.952 6736 1603 NC32 Normal Alkane C32 96.962 4569 1125 NC33 Normal Alkane C33 98.909 6345 1151 NC34 Normal Alkane C34 100.803 3212 709 NC35 Normal Alkane C35 102.673 2678 537 NC36 Normal Alkane C36 104.710 1913 318 NC37 Normal Alkane C37 107.005 1956 270 NC38 Normal Alkane C38 109.635 1687 214 NC39 Normal Alkane C39 112.664 853 109 NC40 Normal Alkane C40 116.178 903 90 NC41 Normal Alkane C41 120.283 826 74 • • Weatherforit EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146142 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293056 Lease: Sample Type: CORE - CS2 ultrasonic extraction Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8197 FT Longitude: Bottom Depth: FT Extract GC Trace G2090843.D x U • Z ItiiiiiI4 Y Z Z Z Z Y2 Z Z Z U Z . ...„ i .441 .: Iv .ri L. WGC parameters Thompson' Mango Halpern Pristane /Phytane 2.35 A. BZ/n C6 7.13 P, 9.67 Tr, 139.28 Pristane /n C17 0.44 B. TOL /n 5.66 P2 3.07 Tr 24.61 Phytane/n C18 0.23 C. (n C +n C 7 ) /(CH +MCH) 0.32 P3 0.54 Tr 4.37 n C 18 /(nC, +n C 0.52 I. Isoheptane Value 1.02 5N, 2.58 Tr 3.44 n C17/(nC17+n C29) 0.79 F. n C 7 /MCH 0.35 N2 2.01 Tr 7.81 CPI Hunt 1.06 U. CH /MCP 5.52 6N, 82.13 Tr 2.06 Normal Paraffins 24.4 R. n C 7 /2MH 7.15 K, 0.93 Tr 6.02 Isoprenoids 4.3 S. n C K 0.60 C 0.04 Cycloparaffins 0.7 H. Heptane Value 20.48 5N 0.03 C2 0.55 40 Branched (iso-) Paraffins 0.1 MCH /nC 2.83 P /N 0.27 C 0.10 BTX aromatics 3.8 mpXYL/n Ce 2.35 In(24DMP /23DMP) -1.72 C 0.11 Resolved unknowns 66.1 C5 0.20 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.1.,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146142 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8197 - FT Lab ID: CP293056 Sampling Point: File Name: G2090843.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (tight) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 5.917 25 14 3MP 3- Methylpentane 6.187 35 18 NC6 Normal Alkane C6 6.577 267 150 22DMP 2,2- Dimethylpentane 7.230 20 11 MCP Methylcyclopentane 7.287 604 325 24DMP 2,4- Dimethylpentane 7.418 50 25 223TMB 2,2,3 - Trimethylbutane 7.571 30 9 BZ Benzene 8.034 1903 893 33DMP 3,3- Dimethylpentane 8.241 54 22 CH Cyclohexane 8.356 3332 1685 2MH 2- Methylhexane 8.736 1329 661 23DMP 2,3- Dimethylpentane 8.786 278 146 11DMCP 1,1- Dimethylcyclopentane 8.875 386 185 3MH 3- Methylhexane 9.075 1685 827 1C3DMCP 1- cis -3- Dimethylcyclopentane 9.307 796 377 • 1T3DMCP 1- trans -3- Dimethylcyclopentane 9.420 794 378 3EP 3- Ethylpentane 9.478 99 81 1T2DMCP 1- trans -2- Dimethylcyclopentane 9.533 1372 631 NC7 Normal Alkane C7 10.123 9500 4425 ISTD Internal Standard MCH Methylcyclohexane 10.969 26909 11873 113TMCP 1,1,3, - Trimethylcyclopentane 11.139 1107 459 ECP Ethylcyclopentane 11.545 1161 500 124TMCP 1,2,4 - Trimethylcyclopentane 11.991 1311 560 123TMCP 1,2,3 - Trimethylcyclopentane 12.359 1120 474 TOL Toluene 12.672 53761 22610 NC8 Normal Alkane C8 15.320 47072 17584 IP9 Isoprenoid C9 17.188 4836 1828 EB Ethyl- benzene 17.891 12862 4794 MXYL m- xylene 18.399 85203 31058 PXYL p- xylene 18.457 25621 10667 OXYL o- xylene 19.648 37703 13398 NC9 Normal Alkane C9 21.065 89506 32181 IP10 Isoprenoid C10 23.041 12411 3987 PB Propyl- benzene 23.211 10257 3183 NC10 Normal Alkane C10 26.670 106422 36158 IP11 Isoprenoid C11 27.962 16937 5759 NC11 Normal Alkane C11 31.942 114296 36973 NC12 Normal Alkane C12 36.876 104522 33668 IP13 Isoprenoid C13 37.612 25888 7064 IP14 Isoprenoid C14 40.382 22264 7216 • NC13 Normal Alkane C13 41.500 105268 33153 1P15 Isoprenoid C15 44.953 38519 11698 NC14 Normal Alkane C14 45.846 98516 29385 Company: CONOCOPHILLIPS Client ID: US146142 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8197 - FT Lab ID: CP293056 1 Sampling Point: File Name: G2090843.D Peak Compound Ret.: ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.511 46581 10613 NC15 Normal Alkane C15 49.941 89633 23997 NC16 Normal Alkane C16 53.811 66135 19775 IP18 Isoprenoid C18 55.752 25274 5715 NC17 Normal Alkane C17 57.481 58805 17128 IP19 Isoprenoid C19 (Pristane) 57.839 25974 5111 PHEN Phenanthrene 58.891 11749 3210 NC18 Normal Alkane C18 60.970 48156 13983 IP20 Isoprenoid C20 (Phytane) 61.425 11063 1817 NC19 Normal Alkane C19 64.289 44700 12418 NC20 Normal Alkane C20 67.457 41647 11220 NC21 Normal Alkane C21 70.484 34142 9912 C25HBI Highly Branch Isoprenoid C25 70.745 1477 536 NC22 Normal Alkane C22 73.381 34806 9288 NC23 Normal Alkane C23 76.158 29275 8091 NC24 Normal Alkane C24 78.823 26728 7468 NC25 Normal Alkane C25 81.386 24884 6879 NC26 Normal Alkane C26 83.851 22374 5896 NC27 Normal Alkane C27 86.228 19285 5174 NC28 Normal Alkane C28 88.521 15681 4153 NC29 Normal Alkane C29 90.733 15615 3871 ill NC30 Normal Alkane C30 92.877 12081 3034 NC31 Normal Alkane C31 94.951 10619 2615 NC32 Normal Alkane C32 96.957 8199 1959 NC33 Normal Alkane C33 98.907 10852 2069 NC34 Normal Alkane C34 100.797 6626 1399 NC35 Normal Alkane C35 102.668 5903 1161 NC36 Normal Alkane C36 104.705 4012 732 NC37 Normal Alkane C37 107.006 3380 528 NC38 Normal Alkane C38 109.633 2861 410 NC39 Normal Alkane C39 112.652 2365 294 NC40 Normal Alkane C40 116.160 2163 223 NC41 Normal Alkane C41 120.277 1705 141 • Parameter Formula • WGC Parameters Pnstane/Ph IP1911P20 Pristane /nC17 IP19 /NC17 Phytane /nC18 IP20 /NC18 nC18 /nC19 NCI8/NC19 nC17 /nC29 NC17 /NC29 nC +nC NC18 /(NC18 +NC19) nC17 /(nC17 +nC29) NC17 /(NC17 +NC29) CPI Hunt4 ((NC23 +NC25 +NC27+ NC29 +NC31) +(NC25 +NC27+ NC29+ NC31+ NC33)) /(2 *(NC24 +NC26 +NC28 +NC30+ NC32)) CPI Marzi ((NC23 +NC25+ NC27) +( NC25+ NC27 +NC29)) /(2 *(NC24 +NC26 +NC28)) 100 *(NC4 +NC5+ NC6+ NC7+ NC8+ NC9+ NC10+ NC11+ NC12+ NC13 +NC14 +NC15 +NC16 +NC17 +NC18 +NC19+ Normal Paraffins NC20 +NC21 +NC22 +NC23 +NC24+ NC25+ NC26+ NC27+ NC28 +NC29 +NC30 +NC31 +NC32 +NC33 +NC34+ NC35+ NC36+ NC37+ NC38 +NC39 +NC40 +NC41)/TOTAL_RESOLVED Isoprenoids 100*( IP9+ IP10+ IP11+ IP13+ 1P14+ IP15+ IP16+ 1P18+ 1P19 +1P20 +C25HBI) / TOTAL_RESOLVED Cycloparaffins 100 *(CP+ MCP +CH +11 DMCP +1 T3DMCP +1 T2DMCP+ MCH +113TMCP +ECP +124TMCP +123TMCP +1 C3DMCP+ 1 C2DMCP)/TOTAL_RESOLVED Branched (iso-) Paraffins 100 *(IC4 +IC5+ 22DMB +23DMB +2MP +3MP+ 22DMP+ 24DMP+ 223TMB +33DMP +2MH +23DMP +3MH +3EP)1 TOTAL_RESOLVED BTX aromatics 100 *(BZ +TOL +MXYL +PXYL +OXYL) /TOTAL_RESOLVED ( *OXYL added 05/21/2007) Thompson BZ/nC6 BZ/NC6 TOUnC7 TOL /NC7 (nC6 +nC7) /(CH +MCH) (NC6 +NC7) /(CH +MCH) Isoheptane Value ( 2MH +3MH) /(1C3DMCP +1T3DMCP +IT2DMCP) nC7 /MCH NC7 /MCH CH/MCP CH/MCP nC7 /2MH NC7 /2MH nC6/22DMB NC6 /22DMB Heptane Value 100 *NC7 /(CH+ 2MH+ 23DMP +11 DMCP+ 3MH +1C3DMCP +1T3DMCP +IT2DMCP +MCH +NC7) MCH /nC7 MCH /NC7 mpXYUnC8 (MXYL +PXYL) /NC8 Mango P1 100* NC7 /( 22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +1 T3DMCP +3EP+ 1T2DMCP +NC7 +MCH +ECP +TOL) P2 100 *( 2MH+ 3MH) /( 22DMP +24DMP +223TMB +33DMP +2MH +23DMP +1 IDMCP +3MH +1C3DMCP +IT3DMCP+ 3EP +IT2DMCP +NC7 +MCH +ECP +TOL) P3 100 *( 3EP+ 33DMP+ 23DMP+ 24DMP+ 22DMP+ 223TMB) /( 22DMP +24DMP +223TMB +33DMP +2MH +23DMP+ 11 DMCP+ 3MH +1C3DMCP +IT3DMCP +3EP +IT2DMCP +NC7 +MCH +ECP +TOL) 5N1 100 *(ECP +IT2DMCP) /(22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +I IDMCP +3MH +1C3DMCP+ 1 T3DMCP +3EP +1 T2DMCP +NC7 +MCH +ECP +TOL) N2 100 *(11 DMCP +1 C3DMCP +1 T3DMCP) /( 22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP+3MH+ 1C3DMCP +1T3DMCP +3EP +1T2DMCP +NC7 +MCH +ECP +TOL) 6N1 100 *(MCH +TOL) /(22DMP +24DMP +223TMB +33DMP +2MH +23DMP +1 IDMCP +3MH +1 C3DMCP +1T3DMCP+ 3EP+1T2DMCP+NC7+MCH+ECP+TOL) K1 (2MH +23DMP) /(3MH +24DMP) K2 (2MH +3MH) /(2MH +3MH +11 DMCP +1 C3DMCP +1T3DMCP) 5N1/6N1 (ECP +1T2DMCP) /(MCH +TOL) P3/N2 (3EP +330MP +23DMP +24DMP +22DMP +223TM B)/(11 DMCP +1 C3DMCP+1 T3DMCP) In(24DMP /23DMP) In(24DMP /23DMP) Halpern' Tr1 TOU11 DMCP Tr2 NC7 /11 DMCP Tr3 3MH/11DMCP Tr4 2MH /I 1 DMCP Tr5 (2MH +3MH) /11 DMCP Tr7 1 T3DMCP /11 DMCP Tr8 ( 2MH+ 3MH ) /(22DMP +23DMP +24DMP +33DMP +3EP) C1 22DMP /(22DMP+23DMP +24DMP +33DMP +3EP) C2 23DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C3 24DMP1(22DMP +23DMP +24DMP +33DMP +3EP) C4 33DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C5 3EP /(22DMP +23DMP +24DMP +33DMP +3EP) AV • Weatherford ` EXTRACT GC L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146115 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293029 Lease: Sample Type: CORE - soxhlet extraction after ultraso Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8117 FT Longitude: Bottom Depth: FT Extract GC Trace G1090457.D • T. z z z z z z m 1 i I ji u i l ij i iii ji6 z ` 1 0 EGG parameters Thompson Mango Halpern Pristane /Phytane 1.95 A. BZ/n C6 P, 3.27 Tr, Pristane /n C17 0.57 B. TOUn C 26.44 P2 Tr Phytane /n C18 0.35 C. (n C C 0.34 P3 Tr3 n C 18 /(nC +nC 0.52 I. Isoheptane Value 5N 0.88 Tr n C 17 /(nC +nC 0.81 F. n C 7 /MCH 0.34 N2 Tr CPI Hunt 1.08 U. CH /MCP 6N, 95.85 Tr, Normal Paraffins 30.9 R. n C /2MH K Tr Isoprenoids 5.8 S. n C K2 C1 Cycloparaffins 0.1 H. Heptane Value 25.53 5N 0.01 C2 0 Branched (iso -) Paraffins MCH /n C 2.92 P3 /N2 C3 BTX aromatics 2.0 mpXYUn 3.18 In(24DMP /23DMP) C4 Resolved unknowns 60.7 C5 Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.L,1995,AAPG Bull.: V.79, p.801. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146115 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8117 - FT Lab ID: CP293029 1 6 Sampling Point: File Name: G1090457.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 3MP 3- Methylpentane NC6 Normal Alkane C6 22DMP 2,2- Dimethylpentane MCP Methylcyclopentane 24DMP 2,4- Dimethylpentane 223TMB 2,2,3 - Trimethylbutane BZ Benzene 33DMP 3,3- Dimethylpentane CH Cyclohexane 2MH 2- Methylhexane 23DMP 2,3- Dimethylpentane 11DMCP 1,1- Dimethylcyclopentane 3MH 3- Methylhexane 1C3DMCP 1- cis -3- Dimethylcyclopentane • 1T3DMCP 1- trans -3- Dimethylcyclopentane 3EP 3- Ethylpentane 1T2DMCP 1- trans -2- Dimethylcyclopentane NC7 Normal Alkane C7 10.087 679 271 ISTD Internal Standard MCH Methylcyclohexane 10.945 1981 854 113TMCP 1,1,3, - Trimethylcyclopentane 11.118 177 73 ECP Ethylcyclopentane 11.433 184 59 124TMCP 1,2,4 - Trimethylcyclopentane 11.983 293 109 123TMCP 1,2,3 - Trimethylcyclopentane 12.355 291 110 TOL Toluene 12.669 17950 7510 NC8 Normal Alkane C8 15.344 12448 4650 IP9 Isoprenoid C9 17.231 2338 818 EB Ethyl- benzene 17.935 6443 2125 MXYL m- xylene 18.443 30745 11488 PXYL p- xylene 18.504 8820 3571 OXYL o- xylene 19.703 13743 4769 NC9 Normal Alkane C9 21.123 38707 14042 IP10 Isoprenoid C10 23.113 7924 2517 PB Propyl- benzene 23.284 4605 1420 NC10 Normal Alkane C10 26.750 63320 21783 IP11 Isoprenoid C11 28.051 12756 4287 NC11 Normal Alkane C11 32.039 81315 26151 NC12 Normal Alkane C12 36.988 82107 26548 IP13 Isoprenoid C13 37.724 21294 5783 IP14 Isoprenoid C14 40.500 15332 4800 • NC13 Normal Alkane C13 41.621 83966 25952 IP15 Isoprenoid C15 45.080 22090 6506 NC14 Normal Alkane C14 45.978 80464 24096 Company: CONOCOPHILLIPS Client ID: US146115 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 40 Depth: 8117 - FT Lab ID: CP293029 Sampling Point: File Name: G1090457.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.646 34185 7948 NC15 Normal Alkane C15 50.082 79046 21526 NC16 Normal Alkane C16 53.965 67781 19580 IP18 Isoprenoid C18 55.911 30210 6350 NC17 Normal Alkane C17 57.643 65198 17817 IP19 Isoprenoid C19 (Pristane) 57.998 37281 7210 PHEN Phenanthrene 59.060 6448 1661 NC18 Normal Alkane C18 61.139 54348 15380 IP20 Isoprenoid C20 (Phytane) 61.588 19095 3274 NC19 Normal Alkane C19 64.467 51052 13919 NC20 Normal Alkane C20 67.643 48063 12800 NC21 Normal Alkane C21 70.674 40095 10906 C25HBI Highly Branch Isoprenoid C25 70.936 3343 701 NC22 Normal Alkane C22 73.577 36451 9977 NC23 Normal Alkane C23 76.360 32645 8896 NC24 Normal Alkane C24 79.031 28347 7627 NC25 Normal Alkane C25 81.599 25766 6821 NC26 Normal Alkane C26 84.070 22190 5854 NC27 Normal Alkane C27 86.451 18315 4727 NC28 Normal Alkane C28 88.751 14629 3850 NC29 Normal Alkane C29 90.968 14837 3477 • NC30 Normal Alkane C30 93.118 10996 2600 NC31 Normal Alkane C31 95.192 9447 2193 NC32 Normal Alkane C32 97.207 6859 1655 NC33 Normal Alkane C33 99.161 9565 1721 NC34 Normal Alkane C34 101.056 5763 1176 NC35 Normal Alkane C35 102.953 4693 885 NC36 Normal Alkane C36 105.035 3400 586 NC37 Normal Alkane C37 107.388 3260 441 NC38 Normal Alkane C38 110.099 2752 307 NC39 Normal Alkane C39 113.203 1917 230 NC40 Normal Alkane C40 116.827 1769 166 NC41 Normal Alkane C41 121.048 1215 103 • • Weatherford' EXTRACT GC L A B 0 R A T O R 1 E S S Company: CONOCOPHILLIPS Client ID: US146129 • Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293043 Lease: Sample Type: CORE - soxhlet extraction after ultraso Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8158 FT Longitude: Bottom Depth: FT Extracl GC Trace G1090460.D E Z • z 1" 5 z z a - ZZ m� u EGC parameters Thompson' Mango Halpern Pristane /Phytane 2.00 A. BZ/n C6 P, 2.42 Tr, Pristane /n C„ 0.44 B. TOUn C, 36.49 P2 Tr Phytane /n C18 0.27 C. (nC6 +n C /(CH +MCH) 0.29 P3 Tr3 nC /(nC18 +nCis) 0.52 I. IsoheptaneValue 5N 0.77 Tr n C 1 , /(nC +nC 0.82 F. n C, /MCH 0.29 N2 Tr5 CPI Hunt 1.08 U. CH /MCP 6N 96.81 Tr, Normal Paraffins 22.5 R. n C, /2MH K Tr Isoprenoids 3.8 S. n C 6 /22DMB K2 C1 Cycloparaffins 0.2 H. Heptane Value 22.27 5N 0.01 C2 Branched (iso -) Paraffins MCH /n C, 3.49 P /N C3 0 BTX aromatics 5.4 mpXYL/n C8 4.47 In(24DMP /23DMP) C4 Resolved unknowns 67.1 C5 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,I994.GCA: V.58, p.895. 3 Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. ° Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: G1090460.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 3MP 3- Methylpentane NC6 Normal Alkane C6 22DMP 2,2- Dimethylpentane MCP Methylcyclopentane 24DMP 2,4- Dimethylpentane 223TMB 2,2,3 - Trimethylbutane BZ Benzene 33DMP 3,3- Dimethylpentane CH Cyclohexane 2MH 2- Methylhexane 23DMP 2,3- Dimethylpentane 11 DMCP 1,1- Dimethylcyclopentane 3MH 3- Methylhexane 1C3DMCP 1- cis -3- Dimethylcyclopentane • 1T3DMCP 1- trans -3- Dimethylcyclopentane 3EP 3- Ethylpentane 1T2DMCP 1- trans -2- Dimethylcyclopentane NC7 Normal Alkane C7 10.090 869 368 ISTD Internal Standard MCH Methylcyclohexane 10.949 3033 1318 113TMCP 1,1,3, - Trimethylcyclopentane 11.123 205 83 ECP Ethylcyclopentane 11.533 277 95 124TMCP 1,2,4 - Trimethylcyclopentane 11.986 310 115 123TMCP 1,2,3 - Trimethylcyclopentane 12.359 257 106 TOL Toluene 12.674 31709 13111 NC8 Normal Alkane C8 15.347 14041 5178 IP9 Isoprenoid C9 17.234 2360 822 EB Ethyl- benzene 17.939 9806 3212 MXYL m- xylene 18.449 48808 17898 PXYL p- xylene 18.509 14018 5794 OXYL o- xylene 19.706 20286 7184 NC9 Normal Alkane C9 21.123 31963 11616 IP10 Isoprenoid C10 23.115 4865 1511 PB Propyl- benzene 23.285 5644 1811 NC10 Normal Alkane C10 26.746 40980 14165 IP11 Isoprenoid C11 28.049 6019 2051 NC11 Normal Alkane C11 32.031 46670 14607 NC12 Normal Alkane C12 36.974 40494 12897 IP13 Isoprenoid C13 37.719 9896 2430 IP14 Isoprenoid C14 40.494 6061 1827 NC13 Normal Alkane C13 41.607 40056 12234 • IP15 Isoprenoid C15 45.077 12434 3610 NC14 Normal Alkane C14 45.962 36074 10394 Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: G1090460.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.635 14288 3242 NC15 Normal Alkane C15 50.065 30781 8937 NC16 Normal Alkane C16 53.947 25733 7460 IP18 Isoprenoid C18 55.900 9660 1996 NC17 Normal Alkane C17 57.627 23039 6434 IP19 Isoprenoid C19 (Pristane) 57.985 10177 1957 PHEN Phenanthrene 59.049 6380 1797 NC18 Normal Alkane C18 61.121 18762 5392 IP20 Isoprenoid C20 (Phytane) 61.585 5091 901 NC19 Normal Alkane C19 64.450 17175 4704 NC20 Normal Alkane C20 67.624 16458 4085 NC21 Normal Alkane C21 70.656 13144 3516 C25HBI Highly Branch Isoprenoid C25 70.937 1455 417 NC22 Normal Alkane C22 73.560 12387 3285 NC23 Normal Alkane C23 76.344 10408 2829 NC24 Normal Alkane C24 79.014 9117 2462 NC25 Normal Alkane C25 81.584 8378 2262 NC26 Normal Alkane C26 84.056 7301 1909 NC27 Normal Alkane C27 86.435 6075 1524 NC28 Normal Alkane C28 88.737 4850 1263 NC29 Normal Alkane C29 90.957 5114 1171 0 NC30 Normal Alkane C30 93.107 3792 875 NC31 Normal Alkane C31 95.182 3303 723 NC32 Normal Alkane C32 97.199 2469 525 NC33 Normal Alkane C33 99.151 3279 542 NC34 Normal Alkane C34 101.048 1748 355 NC35 Normal Alkane C35 102.939 1453 274 NC36 Normal Alkane C36 105.026 1239 191 NC37 Normal Alkane C37 107.380 818 135 NC38 Normal Alkane C38 110.071 827 109 NC39 Normal Alkane C39 113.202 697 79 NC40 Normal Alkane C40 116.813 514 60 NC41 Normal Alkane C41 121.076 418 59 • • �Ileetherfo EXTRACT GC LAB O RAT O R 1 E$ Company: CONOCOPHILLIPS Client ID: US146147 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293061 Lease: Sample Type: CORE - soxhlet extraction after ultraso Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8212 FT Longitude: Bottom Depth: FT Extract GC Trace G1090461.D 7. Z Z U Z • Z Z Z Z 2 Z O r. Z Z H r , OL' e ' ajtj. i i „Lh A titoltii.i.N. ,,,, m _ t .l )I EGC parameters Thompson' Mango Halpern3 Pristane /Phytane 2.41 A. BZ/n C6 P1 0.90 Tr, Pristane /n C17 0.39 B. TOUn C, 102.63 P2 Tr Phytane /n C, 0.19 C. (n C +n C /(CH +MCH) 0.15 P Tr nC18 /(nC18 +nCis) 0.51 I. Isoheptane Value 5N, 0.73 Tr n C /(nC +n C 0.78 F. n C /MCH 0.15 N2 Tr5 CPI Hunt 1.16 U. CH /MCP 6N, 98.37 Tr, Normal Paraffins 27.8 R. n C /2MH K, Tr5 Isoprenoids 4.4 S. n C K2 C1 Cycloparaffins 0.0 H. Heptane Value 12.68 5N 0.01 C2 0 Branched (iso -) Paraffins MCH /n C7 6.89 P /N C3 BTX aromatics 1.1 mpXYUn 9.45 In(24DMP /23DMP) C4 Resolved unknowns 66.0 C5 'Thompson, K.F.M.,1983.GCA:V.47, p.303. F.D.,1994.GCA: V.58, p.895. 3 Halpem,H.1.,1995,AAPG Bull.: V.79, p.80I. 4 Hunt, 1979 Company: CONOCOPHILLIPS Client ID: US146147 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8212 - FT Lab ID: CP293061 i ll, Sampling Point: File Name: G1090461.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IC4 Iso - alkane C4 NC4 Normal Alkane C4 IC5 Iso - alkane C5 NC5 Normal Alkane C5 22DMB 2,2- Dimethylbutane CP Cyclopentane 23DMB 2,3- Dimethylbutane 2MP 2- Methylpentane 3MP 3- Methylpentane NC6 Normal Alkane C6 22DMP 2,2- Dimethylpentane MCP Methylcyclopentane 24DMP 2,4- Dimethylpentane 223TMB 2,2,3 - Trimethylbutane BZ Benzene 33DMP 3,3- Dimethylpentane CH Cyclohexane 2MH 2- Methylhexane 23DMP 2,3- Dimethylpentane 11DMCP 1,1- Dimethylcyclopentane 3MH 3- Methylhexane 1C3DMCP 1- cis -3- Dimethylcyclopentane • 1T3DMCP 1- trans -3- Dimethylcyclopentane 3EP 3- Ethylpentane 1T2DMCP 1- trans -2- Dimethylcyclopentane NC7 Normal Alkane C7 10.095 27 11 ISTD Internal Standard MCH Methylcyclohexane 10.951 186 79 113TMCP 1,1,3, - Trimethylcyclopentane ECP Ethylcyclopentane 11.486 22 10 124TMCP 1,2,4 - Trimethylcyclopentane 11.987 28 11 123TMCP 1,2,3 - Trimethylcyclopentane 12.361 26 10 TOL Toluene 12.677 2771 1119 NC8 Normal Alkane C8 15.347 1780 634 IP9 Isoprenoid C9 17.235 759 240 EB Ethyl- benzene 17.940 2542 831 MXYL m- xylene 18.445 13364 4989 PXYL p- xylene 18.508 3458 1384 OXYL o- xylene 19.706 6926 2444 NC9 Normal Alkane C9 21.121 13977 5064 IP10 Isoprenoid C10 23.115 2881 913 PB Propyl- benzene 23.287 2355 736 NC10 Normal Alkane C10 26.746 34657 12079 IP11 Isoprenoid C11 28.051 5816 1946 NC11 Normal Alkane C11 32.033 48200 15614 NC12 Normal Alkane C12 36.978 47776 15460 IP13 Isoprenoid C13 37.721 11382 2771 IP14 Isoprenoid C14 40.495 8368 2588 • NC13 Normal Alkane C13 41.612 50724 15775 IP15 Isoprenoid C15 45.081 18356 5272 NC14 Normal Alkane C14 45.968 49916 14808 Company: CONOCOPHILLIPS Client ID: US146147 Well Name: GRANDVIEW 1 Project #: 09 -489 -A • Depth: 8212 - FT Lab ID: CP293061 Sampling Point: File Name: G1090461.D Peak Compound Ret. ppt ppt Label Name Time Area Height (Area) (Hght) IP16 Isoprenoid C16 48.642 21154 4811 NC15 Normal Alkane C15 50.072 48231 13190 NC16 Normal Alkane C16 53.953 41721 12286 IP18 Isoprenoid C18 55.904 14892 3250 NC17 Normal Alkane C17 57.633 39721 11069 IP19 Isoprenoid C19 (Pristane) 57.995 15500 3014 PHEN Phenanthrene 59.056 11589 3270 NC18 Normal Alkane C18 61.131 33374 9574 IP20 Isoprenoid C20 (Phytane) 61.595 6429 1158 NC19 Normal Alkane C19 64.458 31710 8696 NC20 Normal Alkane C20 67.633 29887 7765 NC21 Normal Alkane C21 70.666 25540 7068 C25HBI Highly Branch Isoprenoid C25 70.936 2604 681 NC22 Normal Alkane C22 73.568 23958 6544 NC23 Normal Alkane C23 76.351 21452 5831 NC24 Normal Alkane C24 79.022 18617 5207 NC25 Normal Alkane C25 81.590 17318 4678 NC26 Normal Alkane C26 84.060 14785 3896 NC27 Normal Alkane C27 86.445 13196 3441 NC28 Normal Alkane C28 88.743 11174 2942 NC29 Normal Alkane C29 90.963 11372 2646 4111/ N 3 93.111 Normal Alkane C30 93.111 8411 1990 N C31 Normal Alkane C31 95.189 7130 1631 NC32 Normal Alkane C32 97.201 5073 1157 NC33 Normal Alkane C33 99.153 14840 2561 NC34 Normal Alkane 034 101.050 3600 755 NC35 Normal Alkane C35 102.944 2926 561 NC36 Normal Alkane C36 105.039 2154 363 NC37 Normal Alkane C37 107.394 1874 275 NC38 Normal Alkane C38 110.069 2950 302 NC39 Normal Alkane C39 113.192 1342 152 NC40 Normal Alkane C40 116.825 1061 101 NC41 Normal Alkane C41 121.074 843 69 • Parameter Formula • W P PristanGC elPhytane arameters IP19/IP20 Pristane /nC17 IP19/NC17 Phytane /nC18 IP20 /NC18 nC18 /nC19 NC18 /NC19 nC17 /nC29 NCI7 /NC29 nC +nC NC18 /(NC18 +NC19) nC17/(nC17 +nC29) NC17 /(NC17 +NC29) CPI Hunt4 ((NC23 +NC25 +NC27+ NC29 +NC31) +(NC25 +NC27+ NC29+ NC31+ NC33)) /(2 *(NC24 +NC26 +NC28 +NC30+ NC32)) CPI Marzi ((NC23 +NC25 +NC27) +(NC25+ NC27 +NC29)) /(2 *(NC24 +NC26 +NC28)) 100 *(NC4+NC5+ NC6+ NC7+ NC8+ NC9+ NC10+ NC11+ NC12+ NC13 +NC14 +NC15 +NC16 +NC17 +NC18 +NC19+ Normal Paraffins NC20 +NC21 +NC22 +NC23 +NC24+ NC25+ NC26+ NC27+ NC28 +NC29 +NC30 +NC31 +NC32 +NC33 +NC34+ NC35+ NC36+ NC37+ NC38 +NC39 +NC40 +NC41)/TOTAL_RESOLVED Isoprenoids 100*( IP9+ 1P10+ tP11+ IP13+ IP14+ IP15 +IP16 +IP18 +IP19 +1P20 +C25HBI) /TOTAL RESOLVED Cycloparaffins 100 *(CP+ MCP +CH +11 DMCP +1 T3DMCP +1 T2DMCP+ MCH +113TMCP +ECP +124TMCP +123TMCP +1 C3DMCP+ 1 C2DMCP)/TOTAL_RESOLVED Branched (iso -) Paraffins 100 *(IC4 +IC5+ 22DMB +23DMB +2MP +3MP+ 22DMP+ 24DMP+ 223TMB +33DMP +2MH +23DMP +3MH +3EP)/ TOTAL_RESOLVED BTX aromatics 100 *(BZ +TOL +MXYL +PXYL +OXYL) /TOTAL_RESOLVED ( *OXYL added 05/21/2007) Thompson' BZ/nC6 BZ/NC6 TOUnC7 TOUNC7 (nC6 +nC7) /(CH +MCH) (NC6 +NC7) /(CH +MCH) lsoheptane Value ( 2MH +3MH) /(1C3DMCP +IT3DMCP +IT2DMCP) nC7 /MCH NC7 /MCH CH /MCP CH/MCP nC7 /2MH NC7 /2MH nC6 /22DMB NC6 /22DMB Heptane Value 100 *NC7 /(CH+ 2MH+ 23DMP +11 DMCP +3MH +IC3DMCP +1T3DMCP +1T2DMCP +MCH +NC7) MCH /nC7 MCH /NC7 mpXYL /nC8 (MXYL +PXYL) /NC8 Mango P1 100* NC7 /( 22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +1 T3DMCP +3EP+ 1T2DMCP +NC7 +MCH +ECP +TOL) P2 100 *(2MH +3MH) /(22DMP+24DMP+223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +1 T3DMCP+ 3EP +IT2DMCP +NC7 +MCH+ECP +TOL) P3 100 *( 3EP+ 33DMP+ 23DMP+ 24DMP+ 22DMP+ 223TMB) /( 22DMP +24DMP +223TMB +33DMP +2MH +23DMP+ 11 DMCP+ 3MH +1C3DMCP +1T3DMCP +3EP +IT2DMCP +NC7 +MCH +ECP +TOL) 5N1 100 *( ECP +1 T2DMCP) /( 22DMP+ 24DMP+ 223TMB +33DMP +2MH +23DMP +1 I DMCP+3MH +1 C3DMCP+ IT3DMCP +3EP +IT2DMCP +NC7 +MCH +ECP +TOL) N2 100 *(11 DMCP +1C3DMCP +1T3DMCP) /( 22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH+ 1C3DMCP +IT3DMCP +3EP +1T2DMCP +NC7 +MCH +ECP +TOL) 6N1 100 *(MCH +TOL) /(22DMP +24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +IC3DMCP +IT3DMCP+ 3EP +IT2DMCP +NC7 +MCH +ECP +TOL) K1 (2MH +23DMP) /(3MH +24DMP) K2 (2MH +3MH) /(2MH +3MH +11 DMCP +IC3DMCP +IT3DMCP) 5N1/6N1 (ECP +1T2DMCP) /(MCH +TOL) P3/N2 ( 3EP+ 33DMP +23DMP +24DMP +22DMP +223TMB) /(11 DMCP +1 C3DMCP +1T3DMCP) In(24DMP /23DMP) In(24DMP /23DMP) Halpern Tr1 TOU11 DMCP Tr2 NC7 /11 DMCP Tr3 3MH /11 DMCP Tr4 2MH /11 DMCP Tr5 (2MH +3MH) /11 DMCP Tr7 1 T3DMCP /11 DMCP Tr8 ( 2MH+ 3MH ) /(22DMP +23DMP +24DMP +33DMP +3EP) C1 22DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C2 23DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C3 24DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C4 33DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C5 3EP /(22DMP +23DMP +24DMP +33DMP +3EP) Ve • Weatl�erfo r d SATURATE GCMS L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146129 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293043 Lease: Sample Type: CORE Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8158 FT Longitude: Bottom Depth: FT m/z 191: Tri- and Pentacyclics M2090845.D RATIOS (on Areas)' Appl` TEV Steranes (m /z 217; 218) %C a(3(3S (218) 31.1 D %C28 aR(3S (218) 34.9 D %C a(3(3S (218) 34.0 D %C aaaR (217) 35.6 D %C aaaR (217) 25.3 D %C aaaR (217) 39.0 D S /(S +R) (C aaa) (217) 0.42 M 0.55 (0.8 %) 88S /((3(3S +aaR) (C29) (217) 0.43 M 0.70 (0.9 %) (C21 +C22)/(C27 +C28 +C29) (217) 0.22 C27 /C29 (4{3S) (218) 0.92 D C28/C29 (a(3(3S) (218) 1.03 D • m/z 217: Steranes M2090845.D Diaster /aaa Ster (C (217) 2.64 M/D 1.00 (1.4 %) C30 Sterane Index (218) 7.58 D Terpanes (m /z 191) Oleanane /Hopane D/A Gammacerane /Hopane 0.06 D I1 I I 1 Norhopane /Hopane 0.56 D i i I Bisnorhopane /Hopane 1 0.49 M/D ,\ I n A W f� Diahopane /Hopane 1 W �1" f N Moretane /Hopane 0.18 M 0.05 (0.7 %) 25- nor - hopane / hopane B Ts /(Ts +Tm) trisnorhopanes 0.72 M/D 1.00 (1.4 %) C29Ts /C29 Hopane 0.51 M m/z 218: (3(3 Steranes M2090845.D H32 S /(R +S) Homohopanes 0.55 M 0.60 (0.6 %) H35/H34 Homohopanes 0.91 D C24 Tetracyclic /Hopane 0.24 D C24 Tetracyclic /C26 Tricyclics 0.53 D C23/C24 Tricyclic terpanes 1.40 D C19/C23 Tricyclic terpanes 0.66 D C26/C25 Tricyclic terpanes 1.40 D 4 (C28 +C29 Tricyclics)/Ts 1.33 A 1 I Various (m/z 191; 217) i 11� + I, ' I Steranes /Hopanes 0.28 D ft V � YYY f� � \,..ki Tricyclic terpanes /Hopanes 0.70 M 1.00 (1.4 %) Tricyclic terpanes /Steranes 2.53 M/D 1.00 (1.4 %) 40 'Definition and utility of the ratios can be found on our website www.brilabs.com 2 A= Source Age; D= Depositional environment; M= Maturity; B= Possible Biodegradation 3 Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8158 - FT Lab ID: CP293043 ill Sampling Point: File Name: M2090845.D Peak Compound Ret. ppm ppm Ion Label Name Time Area Height (Area) (Hght) 217 CHOL 5/3 cholane (internal standard) 62.322 11000 2872 100.0 100.0 125 H30_125 C30 17a(H)- hopane (125) 76.557 3359 529 30.5 18.4 125 GCAR y- carotane 125 BCAR 0- carotene 177 L24BNR1 24,28 - bisnorlupane isomer 177 LA24BNR 17a(H)24,28- bisnorlupane 177 LB24BNR 170(H)24,28- bisnorlupane 177 L24BNR2 24,28 - bisnorlupane isomer 177 L24NOR 24- norlupane 191 TR19 C19 tricyclic terpane 44.567 1109 216 10.1 7.5 191 TR20 C20 tricyclic terpane 47.643 1363 227 12.4 7.9 191 TR21 C21 tricyclic terpane 50.719 1288 243 11.7 8.5 191 TR22 C22 tricyclic terpane 53.427 416 92 3.8 3.2 191 TR23 C23 tricyclic terpane 56.428 1680 351 15.3 12.2 191 TR24 C24 tricyclic terpane 57.988 1200 298 10.9 10.4 191 C24DEOL C24 des -A- oleanane 191 C24DELUP C24 des- A- lupane 191 TR25A C25 tricyclic terpane (a) 61.065 530 118 4.8 4.1 191 TR25B C25 tricyclic terpane (b) 61.152 514 102 4.7 3.6 191 C24DEURS C24 des -A- ursane 191 C24DEHOP C24 des -E- hopane 191 TET24 C24 tetracyclic terpane (TET) 63.037 773 152 7.0 5.3 40 191 TR26A C26 tricyclic terpane (a) 63.319 657 121 6.0 4.2 191 TR26B C26 tricyclic terpane (b) 63.492 803 149 7.3 5.2 191 TR28A C28 tricyclic terpane (a) 68.150 588 127 5.3 4.4 191 TR28B C28 tricyclic terpane (b) 68.497 593 129 5.4 4.5 191 TR29A C29 tricyclic terpane (a) 69.515 763 200 6.9 7.0 191 TR29B C29 tricyclic terpane (b) 69.905 683 162 6.2 5.6 191 TS Ts 18a(H)- trisnorhopane 70.902 1978 509 18.0 17.7 191 TM Tm 17a(H)- trisnorhopane 71.769 781 210 7.1 7.3 191 TR30A C30 tricyclic terpane (a) 72.115 503 110 4.6 3.8 191 TR3OB C30 tricyclic terpane (b) 72.527 725 154 6.6 5.4 191 H28 C2817a18a21(3(H)- bisnorhopane 191 NOR25H C29 Nor -25- hopane 191 H29 C29 Tm 17a(H)210(H)- norhopane 74.737 1798 428 16.3 14.9 191 C29TS C29 Ts 18a(H)- norneohopane 74.889 918 221 8.3 7.7 191 DI-130 C30 17a(H)-diahopane 75.236 1571 382 14.3 13.3 191 M29 C29 normoretane 75.777 239 59 2.2 2.1 191 OL oleanane 191 H30 C30 17a(H)-hopane 76.536 3198 826 29.1 28.8 191 M30 C30 moretane 77.359 560 135 5.1 4.7 191 TARAX Taraxerane 191 H31S C31 22S 17a(H) hopane 78.616 2084 440 18.9 15.3 191 H31R C31 22R 17a(H) hopane 78.854 1258 266 11.4 9.3 191 GAM gammacerane 79.157 186 73 1.7 2.5 • Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: M2090845.D Peak Compound Ret. ppm ppm Ion Label Name Time Area Height (Area) (Hght) 191 H32S C32 22S 17a(H) hopane 80.241 1156 272 10.5 9.5 191 H32R C32 22R 17a(H) hopane 80.587 936 193 8.5 6.7 191 H33S C33 22S 17a(H) hopane 82.104 749 171 6.8 6.0 191 H33R C33 22R 17a(H) hopane 82.581 530 142 4.8 4.9 191 H34S C34 22S 17a(H) hopane 84.054 608 101 5.5 3.5 191 H34R C34 22R 17a(H) hopane 84.639 499 90 4.5 3.1 191 H35S C35 22S 17a(H) hopane 86.026 468 83 4.3 2.9 191 H35R C35 22R 17a(H) hopane 86.806 540 92 4.9 3.2 217 S21 C21 sterane 53.838 1181 218 10.7 7.6 217 DIA27S C27 pa 20S diasterane 65.724 1697 378 15.4 13.2 217 C27R C27 as 20R sterane 70.360 644 157 5.9 5.5 217 C28R C28 as 20R sterane 72.722 458 55 4.2 1.9 217 C29S C29 as 20S sterane 73.415 503 94 4.6 3.3 217 C29BBR C29 (3(3 20R sterane( +5 (3aa) 73.805 775 155 7.0 5.4 217 C29BBS C29 (3(3 20S sterane 73.935 529 107 4.8 3.7 217 C29R C29 as 20R sterane 74.716 706 137 6.4 4.8 218 C27ABBR C27 pp 20R sterane 69.645 1109 233 10.1 8.1 218 C27ABBS C27 pp 20S sterane 69.862 736 167 6.7 5.8 218 C28ABBR C28 pp 20R sterane 71.942 631 138 5.7 4.8 218 C28ABBS C28 pp 20S sterane 72.115 827 155 7.5 5.4 218 C29ABBR C29 1313 20R sterane 73.805 910 207 8.3 7.2 40 218 C29ABBS C29 pp 20S sterane 73.935 804 182 7.3 6.3 218 C30ABBR C30 1313 20R sterane 75.344 143 45 1.3 1.6 218 C30ABBS C30 pp 20S sterane 75.431 194 42 1.8 1.5 259 D27S C27 pa 20S diasterane 65.745 954 261 8.7 9.1 259 D27R C27 pa 20R diasterane 66.590 602 149 5.5 5.2 259 D28SA C28 pa 20S diasterane a 67.804 439 115 4.0 4.0 259 D28SB C28 pa 20S diasterane b 67.955 567 110 5.2 3.8 259 D28RA C28 pa 20R diasterane a 68.714 606 128 5.5 4.5 259 D28RB C28 pa 20R diasterane b 68.822 498 95 4.5 3.3 259 D29S C29 pa 20S diasterane 69.667 1065 179 9.7 6.2 259 D29R C29 pa 20R diasterane 70.620 774 124 7.0 4.3 259 C30TP1 C30 tetracyclic polyprenoid 75.647 126 40 1.1 1.4 259 C30TP2 C30 tetracyclic polyprenoid 75.734 116 44 1.1 1.5 177 DI-128 C28 demethylated hopane 177 DH29 C29 demethylated hopane 177 DH30S C30 S demethylated hopane 177 DH30R C30 R demethylated hopane 177 DH31S C31 S demethylated hopane 177 DH31R C31 R demethylated hopane 177 DH32S C32 S demethylated hopane 177 DH32R C32 R demethylated hopane 177 DH33S C33 S demethylated hopane 177 DH33R C33 R demethylated hopane • Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: M2090845.D • Peak Compound Ret. ppm ppm ion Label Name Time Area Height (Area) (tight) . 135 1 MAM 1- Methyladamantane 135 2MAM 2- Methyladamantane 135 1EAM 1- Ethyladamantane 135 2EAM 2- Ethyladamantane 136 AM Adamantane 149 13DMAM 1,3- Dimethyladamantane 149 C14DMAM 1,4- Dimethyladamantane, cis 149 T14DMAM 1,4- Dimethyladamantane, trans 149 12DMAM 1,2- Dimethyladamantane 149 1 E3MAM 1- Ethyl- 3- methyladamantane 163 135TMAM 1,3,5- Trimethyladamantane 163 136TMAM 1,3,6- Trimethyladamantane 163 C134TMAM 1,3,4 - Trimethyladamantane, cis 163 T134TMAM 1,3,4 - Trimethyladamantane, trans 163 1 E35DMAM 1- Ethyl -3,5- dimethyladamantane 177 1357TMAM 1,3,5,7 - Tetramethyladamantane 177 1257TMAM 1,2,5,7- Tetramethyladamantane 187 4MDI 4- Methyldiamantane 25.538 122 32 1.1 1.1 187 1MDI 1- Methyldiamantane 27.021 198 49 1.8 1.7 187 3MDI 3- Methyldiamantane 28.108 287 59 2.6 2.1 188 DI Diamantane 25.099 99 27 0.9 0.9 201 49DMDI 4,9- Dimethyldiamantane 25.956 56 10 0.5 0.3 40 201 1424DMDI 1,4 and 2,4- dimethyldiamantane 27.126 108 22 1.0 0.8 201 48DMDI 4,8- Dimethyldiamantane 27.335 149 35 1.4 1.2 201 34DMDI 3,4- Dimethyldiamantane 28.609 327 60 3.0 2.1 215 TMDI Trimethyldiamantane 27.376 108 23 1.0 0.8 • Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A S Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: M2090845.D Miscellaneous Ratios By Areas By Heights Steroids %C27 apRS (218) 31.1 33.1 %C a(3(3S (218) 34.9 30.8 %C a(3[3S (218) 34.0 36.1 C27/C29 ((OS) (218) 0.92 0.92 C28/C29 (aRRS) (218) 1.03 0.85 C29/C27 (aRRS) (218) 1.09 1.09 %C aaaR (217) 35.6 45.0 %C aaaR (217) 25.3 15.8 %C aaaR (217) 39.0 39.3 S/R (C aaa) (217) 0.71 0.69 S /(S +R) (C aaa) (217) 0.42 0.41 1 + (C29) (217) 0.52 0.53 a[3(3S /aaaR (C (217) 0.75 (C21 +C22)/(C27 +C28 +C29) (217) 0.22 0.20 Diaster /aaa Ster (C (217) 2.64 2.41 Terpenoids C19/C23 Tricyclic terpanes 0.66 0.62 C23/C24 Tricyclic terpanes 1.40 1.18 C26/C25 Tricyclic terpanes 1.40 1.23 C24 Tetracyclic/C26 Tricyclics 0.53 0.56 C24 Tetracyclic /Hopane 0.24 0.18 Ts /Tm trisnorhopanes 2.53 2.42 Ts /(Ts +Tm) trisnorhopanes 0.72 0.71 C29Ts /C29 Hopane 0.51 0.52 Bisnorhopane /Hopane Norhopane /Hopane 0.56 0.52 Diahopane /Hopane 0.49 0.46 Oleanane /Hopane Gammacerane /Hopane 0.06 0.09 Moretane /(Moretane +Hopane) 0.15 0.14 H32 S /(S +R) Homohopanes 0.55 0.58 H35/H34 Homohopanes 0.91 0.92 [Steranes] /[Hopanes] 0.28 0.24 [Tricyclic terpanes] /[Hopanes] 0.70 0.63 [Tricyclic terpanes] /[Steranes] 2.53 2.58 DIAMONDOID Ratios Methyl Adamantane Index • Methyl Diamantane Index 0.20 0.23 Parameter Formula WGC Parameters • Pristane /Phytane IP19/IP20 Pristane /nC17 IP19/NC17 Phytane /nC 18 IP20/NC18 nC18 /nC19 NC18 /NC19 nC17 /nC29 NC17 /NC29 nC +nC NCI8 /(NC18 +NC19) nCt7 /(nC17+nC29) NC17 /(NC17 +NC29) CPI Hunt ((NC23 +NC25 +NC27+ NC29 +NC31) +(NC25 +NC27+ NC29+ NC31+ NC33)) /(2 *(NC24 +NC26+NC28 +NC30+ NC32)) CPI Marzi ((NC23+ NC25 +NC27) +( NC25+ NC27 +NC29)) /(2 *(NC24 +NC26 +NC28)) 100 *(NC4 +NC5+ NC6+ NC7+ NC8+ NC9+ NC10+ NC11+ NC12+ NC13 +NC14 +NC15 +NC16 +NC17 +NC18 +NC19+ Normal Paraffins NC20 +NC21 +NC22 +NC23 +NC24+ NC25+ NC26+ NC27 +NC28 +NC29 +NC30 +NC31 +NC32 +NC33 +NC34+ NC35+ NC36+ NC37+ NC38 +NC39 +NC40 +NC41)/TOTAL_RESOLVED Isoprenoids 100*( IP9+ IP10+ IP11+ IP13+ 1P14+ IP15+ IP16+ IP18+ IP19 +IP20 +C25HBI)fTOTAL_RESOLVED Cycloparaffins 100 *(CP+ MCP +CH +11 DMCP +1 T3DMCP +1 T2DMCP+ MCH +113TMCP +ECP +124TMCP +123TMCP +1 C3DMCP+ 1 C2DMCP)/TOTAL_RESOLVED Branched (iso -) Paraffins 100 *(IC4 +IC5+ 22DMB +23DMB +2MP +3MP+ 22DMP +24DMP+223TMB+330MP +2MH +23DMP +3MH +3EP)/ TOTAL RESOLVED BTX aromatics 100 *(BZ +TOL +MXYL +PXYL +OXYL) /TOTAL_RESOLVED ( *OXYL added 05/21/2007) Thompson' BZ/nC6 BZ/NC6 TOUnC7 TOL /NC7 (nC6 +nC7) /(CH +MCH) (NC6 +NC7) /(CH +MCH) Isoheptane Value (2MH +3MH) /(1C3DMCP +IT3DMCP +1T2DMCP) nC7 /MCH NC7 /MCH CH /MCP CH/MCP nC7 /2MH NC7 /2MH nC6 /220MB NC6 /22DMB Heptane Value 100* NC7 /(CH+ 2MH+ 23DMP +11 DMCP+ 3MH +1C3DMCP +1T3DMCP +1T2DMCP +MCH +NC7) MCH /nC7 MCH /NC7 mpXYL /nC8 (MXYL +PXYL) /NC8 Mango P1 100* NC7 /(22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +1 T3DMCP +3EP+ 1T2DMCP +NC7 +MCH +ECP +TOL) P2 100 *( 2MH +3MH) /(220MP +240MP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +1 T3DMCP+ 3EP +1T2DMCP +NC7 +MCH +ECP+TOL) P3 100 *( 3EP+ 33DMP+ 23DMP+ 24DMP +22DMP+ 223TMB) /(22DMP +24DMP +223TMB +33DMP +2MH +23DMP+ 11 DMCP+ 3MH +1C3DMCP +IT3DMCP +3EP +1T2DMCP +NC7 +MCH +ECP +TOL) 5N1 100 *(ECP +1 T2DMCP) /( 22DMP +240MP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP+ IT3DMCP +3EP +1T2DMCP +NC7 +MCH +ECP +TOL) N2 100 *(11DMCP +1C3DMCP +1T3DMCP) /( 22DMP+ 24DMP+ 223TMB +33DMP +2MH +23DMP +11 DMCP +3MH+ 1C3DMCP +1T3DMCP +3EP +1T2DMCP +NC7 +MCH +ECP +TOL) 6N1 100 *(MCH +TOL) /( 22DMP +24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +IT3DMCP+ 3EP +1T2DMCP +NC7 +MCH +ECP +TOL) K1 (2MH +23DMP) /(3MH +24DMP) K2 (2MH +3MH) /(2MH+3MH +11 DMCP +1 C3DMCP +IT3DMCP) 5N1/6N1 (ECP +1T2DMCP) /(MCH +TOL) P3/142 ( 3EP+ 33DMP +23DMP +24DMP +220MP +223TMB) /(11 DMCP +IC3DMCP +IT3DMCP) In(24DMP /23DMP) In(24DMP /23DMP) Halpern Tr1 TOL/11DMCP Tr2 NC7 /11 DMCP Tr3 3MH /11 DMCP Tr4 2MH /11 DMCP Tr5 (2MH +3MH) /11 DMCP Tr7 1 T3DMCP /1 I DMCP Tr8 ( 2MH+ 3MH ) /(22DMP +23DMP +24DMP +33DMP +3EP) C1 22DMP/ (22DMP +230MP +240MP +33DMP +3EP) C2 23DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C3 24DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C4 33DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C5 3EP /(22DMP +23DMP +24DMP +33DMP +3EP) V • Weatherford* AROMATIC GCMS L A B O R A T O R I E S Company: CONOCOPHILLIPS Client ID: US146129 Country: UNITED STATES Project #: 09 -489 -A Basin: NORTH SLOPE Lab ID: CP293043 Lease: Sample Type: CORE Block: Sampling Point: (combined sonic + Soxhlet ext.) Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8158 FT Longitude: Bottom Depth: FT m/z 253: Monoaromatic steroids M1090733.D RATIOS (on Areas)' Applz TEV Mono- (MAS) and Triaromatic Steroids (TAS) (C20 +C21) /E TAS 1.00 M 1.0 (1.3 %) TAS #1 20/20 +27 1.00 M TAS #2 21/21+28 1.00 M %26 TAS D %27 TAS D %28 TAS D %29 TAS D C28/C26 20S TAS C28 /C27 20R TAS Dia /Regular C27 MAS %27 MAS D 40 m/z 231: Triaromatic steroids M1090733.D %28 MAS D %29 MAS D (C21 +C22) /E MAS M 1.0 (1.3 %) I TAS /(MAS +TAS) 1.00 M TA28 /(TA28 +MA29) M 1.0 (0.8 %) ` Triaromatic Methylsteroids Dinosteroid Index A 1 I C4 /C3 +C4 Mester A d I Phenanthrenes, Naphthalenes, and D �� MM 1Mhkr�+nr n*IM wh444, 414, 0.� MPI -1 0.89 M Rc(a) if Ro < 1.3 (Ro %) 0.91 M m/z 245 Triaromatic Methylsteroids M1090733.D Rc(b) if Ro > 1.3 (Ro %) 1.76 M MPI -2 0.97 M DNR -1 3.19 M DNR -2 1.90 M TNR1 0.94 M I I TDE -1 3.35 M 1,(1,11111,1t1,110 TDE -2 0.20 M I MDR 5.46 M I iL i 111140111 Rm (Ro %) 1.03 M M MDR23 1.57 MDR1 0.48 M DBT /Phenanthrene 0.13 D 0 'Definition and utility of the ratios can be found on our website www.brilabs.com 2 A= Source Age; D= Depositional environment; M= Maturity 3 Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: M1090733.D 1 10 Peak Compound Ret. ppm ppm Ion Label Name Time Area Height ; (Area) (Hght) 230 OTP Ortho- terphenyl (internal standard) 74.990 51463 12612 300.0 300.0 92 16AB C16 Alkyl Benzene 66.704 2801 598 16.3 14.2 92 17AB C17 Alkyl Benzene 71.559 2912 728 17.0 17.3 92 18AB C18 Alkyl Benzene 75.729 3132 711 18.3 16.9 92 1TH1092 Dimethyl dibenzothiophene 1 77.523 3293 657 19.2 15.6 92 2TH1092 Dimethyl dibenzothiophene 2 78.262 3883 649 22.6 15.4 92 19AB C19 Alkyl Benzene 79.493 2951 625 17.2 14.9 92 20AB C20 Alkyl Benzene 82.942 1993 538 11.6 12.8 92 21AB C21 Alkyl Benzene 86.126 1960 540 11.4 12.8 92 22AB C22 Alkyl Benzene 89.152 1802 400 10.5 9.5 92 23AB C23 Alkyl Benzene 92.002 1240 285 7.2 6.8 92 PHYBz Phytanyl Benzene 92 24AB C24 Alkyl Benzene 94.729 965 292 5.6 6.9 92 25AB C25 Alkyl Benzene 97.350 839 206 4.9 4.9 92 26AB C26 Alkyl Benzene 99.866 657 141 3.8 3.4 106 16ATM C16 Alkyl Toluene (meta) 65.965 3827 858 22.3 20.4 106 16ATO C16 Alkyl Toluene (ortho) 66.932 2452 487 14.3 11.6 106 17ATM C17 Alkyl Toluene (meta) 70.855 6155 1378 35.9 32.8 106 17ATO C17 Alkyl Toluene (ortho) 71.700 2485 617 14.5 14.7 106 18ATM C18 Alkyl Toluene (meta) 75.095 6370 1548 37.1 36.8 106 18ATO C18 Alkyl Toluene (ortho) 75.869 2752 677 16.0 16.1 106 1THIO106 Dimethyl dibenzothiophene 1 77.523 3720 818 21.7 19.5 0 106 2TH10106 Dimethyl dibenzothiophene 2 78.280 3934 586 22.9 13.9 106 19ATM C19 Alkyl Toluene (meta) 78.860 5794 1165 33.8 27.7 106 19ATO C19 Alkyl Toluene (ortho) 79.617 2592 622 15.1 14.8 106 20ATM C20 Alkyl Toluene (meta) 82.308 4028 844 23.5 20.1 106 20ATO C20 Alkyl Toluene (ortho) 83.065 1616 399 9.4 9.5 106 21ATM C21 Alkyl Toluene (meta) 85.545 3859 880 22.5 20.9 106 21ATO C21 Alkyl Toluene (ortho) 86.267 3050 1003 17.8 23.9 106 22ATM C22 Alkyl Toluene (meta) 88.571 2983 900 17.4 21.4 106 22ATO C22 Alkyl Toluene (ortho) 89.310 1676 655 9.8 15.6 106 23ATM C23 Alkyl Toluene (meta) 106 23ATO C23 Alkyl Toluene (ortho) 106 24ATM C24 Alkyl Toluene (meta) 106 24ATO C24 Alkyl Toluene (ortho) 106 PHYTL Phytanyl Toluene 95.820 7558 1849 44.1 44.0 106 25ATM C25 Alkyl Toluene (meta) 106 25ATO C25 Alkyl Toluene (ortho) 106 26ATM C26 Alkyl Toluene (meta) 106 26ATO C26 Alkyl Toluene (ortho) 134 15A1 C15 Aryl Isoprenoids 134 16AI C16 Aryl Isoprenoids 134 17A1 C17 Aryl Isoprenoids 134 18AI C18 Aryl Isoprenoids 134 19AI C19 Aryl Isoprenoids 134 20A1 C20 Aryl Isoprenoids 134 21AI C21 Aryl Isoprenoids 134 22A1 C22 Aryl Isoprenoids 134 ISOR Isorenieratane Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A 0 Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: M1090733.D Peak Compound Ret. ppm ppm Ion, Label Name Time Area Height (Area) (Hght) 142 2MN 2- Methylnaphthalene 37.974 2601 505 15.2 12.0 142 1MN 1- Methylnaphthalene 39.188 3072 511 17.9 12.2 149 MTTC578 5,7,8, - triMe - MTTChroman 156 2EN 2- Ethylnaphthalene 46.138 806 136 4.7 3.2 156 1EN 1- Ethylnaphthalene 46.225 433 86 2.5 2.0 156 26DMN 2,6- Dimethylnaphthalene 47.052 5846 1005 34.1 23.9 156 27DMN 2,7- Dimethylnaphthalene 47.211 6970 1098 40.6 26.1 156 1317DMN 1,3 & 1,7- Dimethylnaphthalenes 48.178 16829 2210 98.1 52.6 156 16DMN 1,6- Dimethylnaphthalene 48.460 13795 2371 80.4 56.4 156 23DMN 2,3- Dimethylnaphthalene 49.621 2286 414 13.3 9.8 156 14DMN 1,4- Dimethylnaphthalene 49.726 4452 609 26.0 14.5 156 15DMN 1,5- Dimethylnaphthalene 49.814 4019 859 23.4 20.4 156 12DMN 1,2- Dimethylnaphthalene 50.782 2989 524 17.4 12.5 161 MTTC8 8- Me- MTTChroman 168 2MBP 2- Methylbiphenyl 168 DPM Diphenylmethane 168 3MBP 3- Methylbiphenyl 53.298 4919 814 28.7 19.4 168 4MBP 4- Methylbiphenyl 53.949 3156 565 18.4 13.4 168 DBF Dibenzofuran 55.391 1295 199 7.5 4.7 170 BB_EMN Ethyl- methyl - Naphthalene 55.110 5785 763 33.7 18.1 170 AB_EMN Ethyl- methyl - Naphthalene 56.324 3498 623 20.4 14.8 0 170 137TMN 1,3,7 - Trimethylnaphthalene 56.781 24287 4168 141.6 99.1 170 136TMN 1,3,6 - Trimethylnaphthalene 57.151 41531 7213 242.1 171.6 170 146135T (1,4,6 +1,3,5) - Trimethylnaphthalenes 58.224 32110 4807 187.2 114.3 170 236TMN 2,3,6 - Trimethylnaphthalene 58.488 30286 5629 176.6 133.9 170 127TMN 1,2,7 - Trimethylnaphthalene 59.227 6519 1178 38.0 28.0 170 167126T (1,6,7 +1,2,6) - Trimethylnaphthalenes 59.402 32628 5081 190.2 120.9 170 124TMN 1,2,4 - Trimethylnaphthalene 60.317 3781 718 22.0 17.1 170 125TMN 1,2,5 - Trimethylnaphthalene 60.757 12671 2244 73.9 53.4 178 PHEN Phenanthrene 70.275 399510 87556 2328.9 2082.7 184 1357 1,3,5,7 - Tetramethylnaphthalene 64.716 24192 4590 141.0 109.2 184 1367 1,3,6,7 - Tetramethylnaphthalene 65.877 41479 9130 241.8 217.2 184 1247 (1,2,4,7 +1,2,4,6 +1 ,4,6,7) - Tetramethylnaphthalenes 66.633 21579 4281 125.8 101.8 184 1257 1,2,5,7 - Tetramethylnaphthalene 66.809 13480 2983 78.6 71.0 184 2367 2,3,6,7 - Tetramethylnaphthalene 67.179 9446 2099 55.1 49.9 184 1267 1,2,6,7 - Tetramethylnaphthalene 67.618 11633 2445 67.8 58.2 184 1237 1,2,3,7 - Tetramethylnaphthalene 67.794 4826 1160 28.1 27.6 184 1236 1,2,3,6 - Tetramethylnaphthalene 68.058 7403 1553 43.2 36.9 184 1256 1,2,5,6 - Tetramethylnaphthalene 68.779 13076 3041 76.2 72.3 184 DBT Dibenzothiophene 68.991 51933 11249 302.7 267.6 191 BH32 C32 Benzohopane 191 BH33 C33 Benzohopane 191 BH34 C34 Benzohopane 191 BH35 C35 Benzohopane 192 3MP 3- Methylphenanthrene 75.218 285165 62554 1662.4 1488.0 192 2MP 2- Methylphenanthrene 75.394 343783 81023 2004.1 1927.3 192 9MP 9- Methylphenanthrene 76.080 377164 87428 2198.7 2079.6 40 192 1MP 1- Methylphenanthrene 76.274 281259 63732 1639.6 1516.0 Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: M1090733.D Peak Compound Ret. ppm ppm Ion Label Name Time Area Height (Area) (Hght) 198 CAD Cadalene 198 12467PMN 1 ,2,4,6,7 - Pentamethylnaphthalene 73.072 4799 1162 28.0 27.6 198 12357PMN 1 ,2,3,5,7 - Pentamethylnaphthalene 73.389 3917 789 22.8 18.8 198 4MDBT 4 Methyl Dibenzothiophene 73.547 137374 30131 800.8 716.7 198 23MDBT 2 & 3 Methyl Dibenzothiophenes 74.321 81323 18120 474.1 431.0 198 1MDBT 1 Methyl Dibenzothiophene 75.130 25177 5261 146.8 125.1 206 36DMP 3,6- Dimethylphenanthrene 79.441 51726 12079 301.5 287.3 206 26DMP 2,6- Dimethylphenanthrene 79.687 127005 29170 740.4 693.9 206 27DMP 2,7- Dimethylphenanthrene 79.810 76428 18743 445.5 445.8 206 39DMP (3,9 +3,10+ 2,10 +1,3) - Dimethylphenanthrenes 80.320 466095 90666 2717.1 2156.7 206 29DMP (2,9 +1,6)- Dimethylphenanthrenes 80.514 235917 41770 1375.3 993.6 206 17DMP 1,7- Dimethylphenanthrene 80.655 161534 37402 941.7 889.7 206 23DMP 2,3- Dimethylphenanthrene 80.918 75064 16851 437.6 400.8 206 19DMP 1,9- Dimethylphenanthrene 81.042 84798 22595 494.3 537.5 206 18DMP 1,8- Dimethylphenanthrene 81.464 37110 8514 216.3 202.5 206 12DMP 1,2- Dimethylphenanthrene 81.956 19193 4379 111.9 104.2 206 9_10DMP 9,10 - Dimethylphenanthrene 82.607 3541 782 20.6 18.6 212 DMDBT Dimethyldibenzothiophene 219 RET Retene 86.232 5745 1254 33.5 29.8 226 TMDBT Trimethyldibenzothiophene 81.622 316556 14874 1845.3 353.8 231 231A20 C20 Triaromatic Steroid 92.301 3904 877 22.8 20.9 231 231821 C21 Triaromatic 94.799 4668 851 27.2 20.2 40 231 231C26 C26 20S Triaromatic 231 231D26 C27 20S & C26 20R Triaromatic 231 TADMD1 C28 23,24 - Cholestane Triaromatic 231 TADMD2 C28 23,24 - Cholestane Triaromatic 231 231E28 C28 20S Triaromatic 231 231F27 C27 20R Triaromatic 231 TADMD3 C28 23,24 - Cholestane Triaromatic 231 C29TA1 C29 Triaromatic 231 C29TA2 C29 Triaromatic 231 TADMD4 C28 23,24 - Cholestane Triaromatic 231 231G28 C28 20R Triaromatic 231 TADMD5 C28 23,24 - Cholestane Triaromatic 231 C29TA3 C29 Triaromatic 245 C3S C27 20S 3- Methyl Triaromatic Steroid 245 C4S C27 20S 4- Methyl Triaromatic Steroid 245 E2S C28 20S 2- Methyl Triaromatic Steroid 245 E3SC3R C28 20S 3- Methyl & C27 20R 3- Methyl TAS 245 E4SC4R C28 20S 4- Methyl & C27 20R 4- Methyl TAS 245 S2S C29 20S 2- Methyl Triaromatic Steroid 245 DA Triaromatic Dinosteroid a 245 S3S C29 20S 3- Methyl Triaromatic Steroid 245 DB Triaromatic Dinosteroid b 245 S4SE2R C29 20S 4- Methyl & C28 20R 2- Methyl TAS 245 E3R C28 20R 3- Methyl Triaromatic Steroid 245 E4R C28 20R 4- Methyl Triaromatic Steroid 245 DC Triaromatic Dinosteroid c 245 DD Triaromatic Dinosteroid d • Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: M1090733.D Peak Compound Ret. ppm ppm Ion Label Name Time Area Height (Area) (Hght) 245 S2R C29 20R 2- Methyl Triaromatic Steroid 245 S3R C29 20R 3- Methyl Triaromatic Steroid 245 DE Triaromatic Dinosteroid e 245 S4R C29 20R 4- Methyl Triaromatic Steroid 245 DF Triaromatic Dinosteroid f 253 S253A C21 Ring -C Monoaromatic Steroid 253 S253B C22 Monoaromatic steroid 253 S253C C27 Reg 5p(H),10p(CH3) 20S 253 S253D C27 Dia 10p(H),5p(CH3) 20S 253 S253E C27 Dia1013H,50CH3 20R +Reg5(3H,10(3CH3 20R 253 S253F C27 Reg 5a(H),100(CH3) 20S 253 S253G C28 Dia 10aH,5aCH3 20s +Reg5pH,10pCH3 20S 253 S253H C27 Reg 5a(H),10p(CH3) 20R 253 S253l C28 Reg 5a(H),10p(CH3) 20S 253 S253J C28 Dia 10aH,5aCH3 20R +Reg5pH,10pCH3 20R 253 S253K C29 Dia 10pH,5pCH3 20S +Reg5pH,10pCH3 20S 253 S253L C29 Reg 5a(H),10p(CH3) 20S 253 S253M C28 Reg 5a(H),100(CH3) 20R 253 S253N C29 Dia 10pH,53CH3 20R +Reg5pH,10pCH3 20R 253 S2530 C29 Reg 5a(H),100(CH3) 20R 182 DMBP1 Dimethybiphenyl peak 1 60.053 1651 283 9.6 6.7 182 DMBP2 Dimethylbiphenyl peak 2 60.828 6596 1291 38.5 30.7 182 DMBP3 Dimethylbiphenyl peak 3 61.039 17800 3652 103.8 86.9 182 DMBP4 Dimethylbiphenyl peak 4 61.215 1464 239 8.5 5.7 182 DMBP5 Dimethylbiphenyl peak 5 61.672 19223 3904 112.1 92.9 182 DMBP6 Dimethylbiphenyl peak 6 62.094 5314 982 31.0 23.4 182 DMBP7 Dimethylbiphenyl peak 7 62.288 403 81 2.3 1.9 182 DMBP8 Dimethylbiphenyl peak 8 62.710 8655 1578 50.5 37.5 182 DMBP9 Dimethylbiphenyl peak 9 62.921 393 105 2.3 2.5 182 DMBP10 Dimethylbiphenyl peak 10 63.167 8765 1831 51.1 43.6 182 DMBP11 Dimethylbiphenyl peak 11 63.484 11089 1711 64.6 40.7 182 DMBP12 Dimethylbiphenyl peak 12 63.748 2033 446 11.9 10.6 182 DMBP13 Dimethylbiphenyl peak 13 63.941 8420 1628 49.1 38.7 182 DMBP14 Dimethylbiphenyl peak 14 64.205 757 244 4.4 5.8 182 DMBP15 Dimethylbiphenyl peak 15 64.469 884 277 5.2 6.6 182 DMBP16 Dimethylbiphenyl peak 16 64.751 905 313 5.3 7.4 212 ET4DBT 4- Ethyldibenzothiophene 77.154 8278 1849 48.3 44.0 212 DM46DBT 4,6- Dimethyldibenzothiophene 77.523 104335 23159 608.2 550.9 212 DMDBT3 Dimethyldibenzothiophene peak 3 77.822 1201 251 7.0 6.0 212 DMDBT4 Dimethyldibenzothiophene peak 4 78.086 41771 10059 243.5 239.3 212 DMDBT5 Dimethyldibenzothiophene peak 5 78.280 143472 25029 836.4 595.4 212 DMDBT6 Dimethyldibenzothiophene peak 6 78.895 39598 8076 230.8 192.1 212 DM14DBT 1,4- Dimethyldibenzothiophene 79.089 47904 8394 279.3 199.7 212 DMDBT7 Dimethyldibenzothiophene peak 7 79.581 32053 4720 186.9 112.3 212 DMDBT8 Dimethyldibenzothiophene peak 8 79.669 11710 2781 68.3 66.2 212 DMDBT9 Dimethyldibenzothiophene peak 9 80.162 6614 1431 38.6 34.0 Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Project #: 09 -489 -A Depth: 8158 - FT Lab ID: CP293043 Sampling Point: File Name: M1090733.D Miscellaneous Ratios By Areas By Heights Triaromatic Steroids m/z 231 (C20 +C21) /E TAS 1.00 1.00 TAS #1 20/20 +27 1.00 1.00 TAS #2 21/21+28 1.00 1.00 %26TAS %27TAS %28TAS %29TAS C28/C26 20S TAS C28/C27 20R TAS Monoaromatic Steroids m/z 253 Dia /Regular C27 MAS %27 MAS %28 MAS %29 MAS (C21 +C22) /E MAS TAS /(MAS +TAS) 1.00 1.00 TA28/(TA28+MA29) Triaromatic Methylsteroids m/z 245 • Dinosteroid Index C4 /C3 +C4 Mester Phenanthrenes and Naphthalenes MPI -1 0.89 0.90 MPI -2 0.97 1.02 Rc(a) if Ro < 1.3 (Ro %) 0.91 0.91 Rc(b) if Ro > 1.3 (Ro %) 1.76 1.76 DNR -1 3.19 2.45 DNR -2 1.90 2.06 TNR1 0.94 1.17 TDE -1 3.35 3.13 TDE -2 0.20 0.23 MDR 5.46 5.73 Rm (Ro %) 1.03 1.10 MDR23 1.57 1.61 MDR1 0.48 0.47 DBT /Phenanthrene 0.13 0.13 Parameter Formula WGC Parameters • Pristane/Phy cane lP19 /1P20 Pristane /nC17 IP19/NC17 Phytane/nC18 1P20/NC18 nC18 /nC19 NC18 /NC19 nC17 /nC29 NCI7/NC29 nC18 /(nC +nC NC18 /(NC18 +NC19) nCt7 /(nC17 +nC29) NC17/(NC17 +NC29) CPI Hunt ((NC23 +NC25 +NC27+ NC29 +NC31) +(NC25 +NC27+ NC29+ NC31+ NC33)) /(2 *(NC24 +NC26 +NC28 +NC30+ NC32)) CPI Marzi ((NC23+ NC25+ NC27) +( NC25 +NC27 +NC29)) /(2 *(NC24 +NC26 +NC28)) 100 *(NC4 +NC5+ NC6 +NC7+ NC8+ NC9+ NC10+ NC11+ NC12+ NC13 +NC14 +NC15 +NC16 +NC17 +NC18 +NC19+ Normal Paraffins NC20 +NC21 +NC22 +NC23 +NC24+ NC25+ NC26+ NC27+ NC28 +NC29 +NC30 +NC31 +NC32 +NC33 +NC34+ NC35+ NC36+ NC37+ NC38 +NC39 +NC40 +NC41)/TOTAL_RESOLVED Isoprenoids 100*( 1P9+ IP10+ IP11+ 1P13+ 1P14+ 1P15 +IP16 +1P18 +1P19 +1P20 +C25HB1) /TOTAL RESOLVED Cycloparaffins 100 *(CP+ MCP +CH +11 DMCP +1T3DMCP +IT2DMCP+ MCH +1I3TMCP +ECP +124TMCP +123TMCP +1C3DMCP+ 1 C2DMCP)/TOTAL_RESOLVED Branched (iso-) Paraffins 100 *(IC4 +105+ 22DMB +23DMB +2MP +3MP+ 22DMP+ 24DMP+ 223TMB +33DMP +2MH+230MP +3MH +3EP)/ TOTAL_RESOLVED BTX aromatics 100 *(BZ +TOL +MXYL +PXYL +OXYL) / TOTAL_RESOLVED ( *OXYL added 05/21/2007) Thompson' BZ/nC6 BZ/NC6 TOUnC7 TOL/NC7 (nC6 +nC7) /(CH +MCH) (NC6 +NC7) /(CH +MCH) Isoheptane Value (2MH +3MH) /(1C3DMCP +1T3DMCP +1T2DMCP) nC7 /MCH NC7 /MCH CH/MCP CH /MCP nC7 /2MH NC7 /2MH nC6 /220MB NC6 /22DMB Heptane Value 100* NC7 /(CH+ 2MH +23DMP +11 DMCP+ 3MH +IC3DMCP +IT3DMCP +IT2DMCP +MCH +NC7) MCH /nC7 MCH /NC7 mpXYL /nC8 (MXYL +PXYL) /NC8 Nlango P1 100 *NC7 /( 22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +1 T3DMCP +3EP+ 1T2DMCP +NC7 +MCH +ECP +TOL) P2 100 *( 2MH +3MH) /( 22DMP+ 24DMP +223TMB +330MP+ 2MH+ 23DMP +1 I DMCP +3MH +1 C3DMCP +IT3DMCP+ 3EP +IT2DMCP +NC7 +MCH +ECP +TOL) P3 100 *( 3EP+ 33DMP+ 23DMP +24DMP+ 22DMP+ 223TMB) /( 22DMP +24DMP +223TMB +33DMP +2MH +23DMP+ 11 DMCP+ 3MH +1C3DMCP +1T3DMCP +3EP +1T2DMCP +NC7 +MCH +ECP +TOL) 5N1 100 *(ECP +IT2DMCP) /( 22DMP +24DMP+223TMB+ 33DMP +2MH +23DMP +11 DMCP +3MH +IC3DMCP+ 1T3DMCP +3EP +IT2DMCP +NC7 +MCH +ECP +TOL) N2 100 *(11 DMCP +IC3DMCP +1T3DMCP) /( 22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH+ 1C3DMCP +IT3DMCP +3EP +IT2DMCP +NC7 +MCH +ECP +TOL) 6N1 100 *( MCH +TOL) /(22DMP +24DMP +223TMB +33DMP +2MH +23DMP +1 I DMCP +3MH +IC3DMCP +IT3DMCP+ 3EP +IT2DMCP +NC7 +MCH +ECP +TOL) K1 (2MH +23DMP) /(3MH +24DMP) K2 (2MH +3MH) /(2MH +3MH +11 DMCP +1 C3DMCP +IT3DMCP) 5N1/6N1 (ECP +IT2DMCP) /(MCH +TOL) P3 /N2 ( 3EP+ 33DMP+ 23DMP+ 24DMP+ 22DMP+ 223TMB ) /(110MCP +1C30MCP +IT3DMCP) In(24DMP /23DMP) In(24DMP /23DMP) Halpern Tr1 TOL/11DMCP Tr2 NC7 /11 DMCP Tr3 3MH/11DMCP Tr4 2MH/11DMCP Tr5 (2MH +3MH) /11 DMCP Tr7 1 T3DMCP /I I DMCP Tr8 ( 2MH+ 3MH ) /(22DMP +23DMP +24DMP +33DMP +3EP) C1 22DMP/ (22DMP +23DMP +24DMP +330MP +3EP) C2 23DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C3 240MP/(220MP +23DMP +24DMP +33DMP +3EP) C4 33DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C5 3EP /(22DMP +23DMP +24DMP +33DMP +3EP) IV • Weatherford' SATURATE GCMSMS L A B O R A T O R I E S Company: CONOCOPHILLIPS Project #: 09 -489 -A Country: UNITED STATES Lab ID: CP293043 Basin: NORTH SLOPE Client ID: US146129 Lease: Sample Type: CORE Block: Sampling Point: Field: WILDCAT Formation: ALPINE A Well Name: GRANDVIEW 1 Geologic Age: KIMMERDIGE - OXFORDIAN Latitude: Top Depth: 8158 FT Longitude: Bottom Depth: FT 358 - >217: C26 Steranes MS090271.D RATIOS (on Area)' Appl TEV Steranes %27 Steranes 28.2 D %28 Steranes 36.5 D %29 Steranes 35.3 D %27 Diasteranes 31.0 D %28 Diasteranes 36.1 D %29 Diasteranes 32.9 D 414,11A41, t, ' ) 'Pe � ', Yi , C30 Sterane Index D C30 iso /n- propyl sterane Index A C27 a88/(aaa +a83) 0.53 M 414 - >217: C30 Steranes C28 a88/(aaa +a83) 0.61 M C29 a(3(3 /(aaa +a(3(3) 0.52 M C30 a(3(3 /(aaa +a(3(3) M 1 C27 S /(S +R) 0.45 M C28 S /(S +R) 0.31 M C29 S /(S +R) 0.48 M C30 S /(S +R) M � I�I I) J 11'144 L Diasteranes /Steranes 1.47 NJV�4V�V� ��" 1 � � !'�t �� I' I I � ; 24- Nordiacholestane ratio (NDR) A 24- Norcholestane ratio (NCR) A 21- Norcholestane ratio D/M 414 - >231: C30 Methylsteranes Dinosterane ratio A 4- Methyl sterane ratio A Terpane Ratios Oleanane Index ( %) A DesA Oleanane Index ( %) A Gammacerane Index ( %) D ( I Bicadinane Index ( %) A/D � ,� ^ I , , � DiaHopane Index ( %) 21.1 D 13 r 1 �f 1 u�J TPP D 1 0n response factored areas. Definition and utility of the ratios can be found on our website www.brilabs.com 2 A= Source Age; D= Depositional environment; M= Maturity 3 Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached • Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Lab ID: CP293043 Top Depth: 8158 FT Fraction: SATURATE Bottom Depth: FT File Name: MS090271.D is Acquisition Parameters: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR= 2E -7MBAR CE =25 Peak Label Compound Retention Area Area Resp fact Time Count ppm Area ppm 330.3 - >217.2: Internal Standard ISTD 53- Cholane 51.694 1151258 100.0 100.0 358.3 - >217.2: C26 Desmethylsteranes D26N24baS 1313,17a,24- nordiacholestane 20S D26N24baR 1313,17a,24- nordiacholestane 20R D26N27baS 1313,17a,27- nordiacholestane 20S D26N24abS 13a,17p,24- nordiacholestane 20S D26N24abR 13a,1713,24- nordiacholestane 20R D26N27baR 13p,17a,27- nordiacholestane 20R D26N27abS 13x,1713,27- nordiacholestane 20S D26N27abR 13a,17p,27- nordiacholestane 20R S26N24aaaS 5a,14a,17a,24- norcholestane 20S S26N24abbR 5a, 14(3,17(3,24- norcholestane 20R S26N24abbS 5a,14p,17F3,24- norcholestane 20S S26N24aaaR 5a,14a,17a,24- norcholestane 20R S26N21 21- norcholestane S26N27baaR 5p,14a,17a,27- norcholestane 20S S26N27aaaS 5a,14a,17a,27- norcholestane 20S S26N27abbR 5a,1413,17r3,27- norcholestane 20R S26N27abbS 5a,14p,17p,27- norcholestane 20S S26N27aaaR 5a,14a,17a,27- norcholestane 20R 10 372.3 - >217.2: C27 Desmethylsteranes D27baS 13p,17a- diacholestane 20S 56.733 976718 84.8 35.1 D27baR 1313,17a- diacholestane 20R 58.039 902354 78.4 45.5 D27abS 13a,1713- diacholestane 20S 58.945 354074 30.8 10.6 D27abR 13a,17p- diacholestane 20R 59.692 521722 45.3 27.3 S27aaaS 5a,14a,17a- cholestane 20S 62.358 326860 28.4 10.4 S27abbR 5a,14p,1713- cholestane 20R 62.678 255923 22.2 13.4 S27abbS 5a,14p,1713- cholestane 20S 62.971 216931 18.8 13.0 S27aaaR 5a,14a,17a- cholestane 20R 63.744 346905 30.1 12.8 386.4 - >217.2: C28 Desmethylsteranes , D28baSA 13p,17a- diaergostane 20S (24S) 59.825 698020 60.6 27.7 D28baSB 1313,17x- diaergostane 20S (24S) 60.039 747166 64.9 30.2 D28baRA 1313,17x - diaergostane 20R (24R) 61.292 302197 26.2 9.9 D28baRB 1313,17a- diaergostane 20R (24R) 61.425 582880 50.6 26.0 D28abS 13a,17p- diaergostane 20S 62.251 405255 35.2 35.2 D28abRA 13a,17p- diaergostane 20R 63.104 216902 18.8 18.8 D28abRB 13a,17p- diaergostane 20R 63.131 407073 35.4 35.4 C28UNK9 C28 Unknown 9 S28aaaSA 5a,14a,17a- ergostane 20S 65.690 65547 5.7 2.6 S28aaaSB 5a,14a,17a- ergostane 20S 65.824 148456 12.9 5.4 S28baaR 5p,14a,17a- ergostane 20R S28abbR 5a,14p,1713- ergostane 20R 66.090 448101 38.9 26.7 S28abbS 5a,14p,173- ergostane20S 66.464 215622 18.7 12.2 S28N21 21- norstigmastane 66.890 189021 16.4 16.4 S28aaaR 5a,14a,17a- ergostane 20R 67.423 420646 36.5 17.4 0 Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Lab ID: CP293043 0 Top Depth: 8158 FT Fraction: SATURATE Bottom Depth: FT File Name: MS090271.D Acquisition Parameters: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR= 2E -7MBAR CE =25 Peak Label Compound Retention Area Area Resp fact Time Count ppm Area ppm 400.4 - >217.2: C29 Desmethylsteranes D29baS 1313,17a- diastigmastane 20S 62.651 1264647 109.8 47.8 D29baR 13[3,17a- diastigmastane 20R 64.171 792513 68.8 37.5 D29abS 13a,171- diastigmastane 20S 64.837 477328 41.5 41.5 D29abR 13a,17(3- diastigmastane 20R 66.010 605224 52.6 52.6 C29UNK5 C29 Unknown 5 S29aaaS 5a,14a,17a- stigmastane 20S 68.516 339038 29.4 14.3 S29abbR 5a,1413,1713- stigmastane 20R 69.050 262957 22.8 15.5 S29baaR 5p,14a,17a- stigmastane 20R S29abbS 5a,1413,17p- stigmastane 20S 69.183 320193 27.8 16.6 S29aaaR 5a,14a,17a- stigmastane 20R 70.489 428079 37.2 15.8 414.4 - >217.2: C30 Desmethylsteranes D30nPbaSA 1313,17a - dia -24 -n- propylcholestane 20S 64.864 215468 18.7 16.7 D30nPbaSB 1313 ,17a - dia -24 -n- propylcholestane 20S 64.917 175816 15.3 7.1 D30nPbaR 1313,17a- dia -24 -n- propylcholestane 20R 66.517 317033 27.5 18.9 D30nPabSA 13a,17 3- dia -24 -n- propylcholestane 20S 66.837 115735 10.1 10.1 D30nPabSB 13a,17p- dia -24 -n- propylcholestane 20S 67.050 88804 7.7 7.7 D30nPabR 13a,171- dia -24 -n- propylcholestane 20R 68.357 202552 17.6 17.6 DC30UNK7 dia -C30 Unknown 7 DC30UNK8 dia -C30 Unknown 8 DC30UNK8A dia -C30 Unknown 8A S30nPaaaS 5a ,14a,17a- 24- n- propylcholestane 20S C30UNK10 C30 Unknown 10 S30iPaaaS 5a,14a,17a -24 -iso- propylcholestane 20S S30nPabbR 5a,14 3,1713 -24 -n- propylcholestane 20R S30nPabbS 5a ,1413,1713 -24 -n- propylcholestane 20S S30nPbaaR 513,14a,17a -24 -n- propylcholestane 20R S30iPabbR 5a,14[3,1713-24- iso - propylcholestane 20R S30nPaaaR 5a ,14a,17a- 24- n- propylcholestane 20R C30UNK14 C30 Unknown 14 S30iPaaaR 5a,14a,17a -24- iso - propylcholestane 20R C30UNK16 C30 Unknown 16 388.4- >231.2: C28 Methylsteranes D283MbaS 313- Methy1- 1313,17a- diacholestane 20S DC28UNK16 dia -C28 Unknown 16 D283MbaR 313- Methyl- 13p,17a- diacholestane 20R DC28UNK3 dia -C28 Unknown 3 DC28UNK17 dia -C28 Unknown 17 D284MbaS 4a- Methy1- 13F3,17a- diacholestane 20S D284MbaR 4a- Methyl- 1313,17a- diacholestane 20R S283MaaaS 313- Methyl- 5a,14a,17a- cholestane 20S S283MabbR 313 - Methyl- 5a,1413,1713- cholestane 20R S283MabbS 313- Methy1- 5a,143,1713- cholestane 20S S284MaaaS 4a- Methyl- 5a,14a,17a- cholestane 20S S284MabbR 4a- Methy1- 5a,143,173- cholestane20R S283MaaaR 33- Methy1- 5a,14a,17a- cholestane 20R • S284MabbS 4a- Methy1- 5a,143,173- cholestane 20S S284MaaaR 4a- Methyl- 5a,14a,17a- cholestane 20R XS28aaaR 5a,14a,17a- ergostane 20R Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Lab ID: CP293043 Top Depth: 8158 FT Fraction: SATURATE Bottom Depth: FT File Name: MS090271.D Acquisition Parameters: SAT 0.2UL 1000/1 RES 70EV 7000A 250C AR= 2E -7MBAR CE =25 Peak Label Compound Retention Area Area Resp fact Time Count ppm Area ppm 400.4 — >231.2: C29 Methylsteranes D293MbaSA 3(3- Methyl- 13(3,17a- diaergostane 20S D293MbaSB 313- Methyl- 13F3,17a- diaergostane 20S DC29UNK27 dia -C29 Unknown 27 DC29UNK28 dia -C29 Unknown 28 D293MbaRA 313- Methy1- 133,17a- diaergostane 20R D293MbaRB 313- Methyl- 133,17a- diaergostane 20R D294MbaSA 4a- Methy1- 138,17a- diaergostane 20S D294MbaSB 4a- Methy1- 1313,17a- diaergostane 20S D294MbaRA 4a- Methy1- 1313,17a- diaergostane 20R D294MbaRB 4a- Methyl- 138,17a- diaergostane 20R D294MabS 4a- Methyl- 13a,1713- diaergostane 20S D294MabRA 4a- Methy1- 13a,1713- diaergostane 20R S293MaaaSA_4abRB 313- Methy1- 5a,14a,17a- ergostane 20S + 4a- methyl- 13a,17b- diaergostane 20R S293MaaaSB 38- Methy1- 5a,14a,17a- ergostane 20S S293MabbR 3( 3- Methyl- 5a,14(3,17(3- ergostane 20R S293MabbS 38- Methy1- 5a,14G3,1713- ergostane 20S S294MaaaSA 4a- Methyl- 5a,14a,17a- ergostane 20S S294MaaaSB 4a- Methyl- 5a,14a,17a- ergostane 20S S294MabbR 4a- Methyl- 5a,14(3,17(3- ergostane 20R S294MabbS_3MaaaR 4a- Methyl- 5a,14(3,17(3- ergostane 20S + 3b- Methyl- 5a,14a,17a- ergostane 20R • S294MaaaR 4a- Methyl- 5a,14a,17a- ergostane 20R XS29aaaR 5a,14a,17a- stigmastane 20R 414.4 — >231.2: C30 Methylsteranes S302MaaaS 2a- Methyl- 5a,14a,17a- stigmastane 20S S303MaaaS 38- Methy1- 5a,14a,17a- stigmastane 20S + (coelution) S302MabbR 2a- Methy1- 5a,14(1,17(3- stigmastane 20S + (coelution) S302MabbS 2a- Methy1- 5a,148,17j3- stigmastane 20S S303MabbR 313- Methy1- 5a,148,1713- stigmastane 20R BBDINO (3(3 -dino ( ?) S303MabbS 3b- Methyl- 5a,14b,17b- stigmastane 20S + (coelution) S304MaaaS 4a- Methyl- 5a,14a,17a- stigmastane 20S S304MabbR 4a- Methyl- 5a,1413,1713- stigmastane 20R S304MabbS_2MaaaR 4a- Methyl- 5a,14(3,17(3- stigmastane 20S + 2a- Methyl- 5a,14a,17a- stigmastane 20R + (coelution) S303MaaaR 3p- Methy1- 5a,14a,17a- stigmastane 20R + (coelution) DS4aSS2OR 4a, 23S ,24S- trimethyl -20R- cholestane DS4aSR2OR 4a, 23S ,24R - trimethyl -20R- cholestane S304MaaaR 4a- Methyl- 5a,14a,17a- stigmastane 20R DS4aRR2OR 4a,23R ,24R - trimethyl -20R- cholestane DS4aRS2OR 4a,23R ,24S - trimethyl -20R- cholestane • Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Lab ID: CP293043 4110 Top Depth: 8158 FT Fraction: SATURATE Bottom Depth: FT File Name: MS090271.D Acq Parameters: SAT 0.2UL 1000/1 RES 70EV 7000A 250C AR= 2E -7MBAR CE =25 Peak Label Compound Retention Area Area Resp fact Time Count ppm Area ppm 414.4 - >259.2: Tetracyclic polyprenoids and C30 30propylsteranes S303PaaaS 3 f3- Propyl- 5a,14a,17a- cholestane 20S PP1 Tetracyclic polyprenoid PP2_S303PabbR Tetracyclic polyprenoid+ 3(3- propy1- 5a,14(3,173- cholestane 20R S303PabbS 3(3- Propy1- 5a,14(3,17(3- cholestane 20S S303PaaaR 3(3- Propyl- 5a,14a,17a- cholestane 20R 414.2- >19t2: Pentacyclic Triterpenoids REARNGHOP Rearranged hopane 65.690 153730 13.4 13.4 OLEANOID13 5(4 -*3)abeo- 3a(H), 5(3- Oleanane TRITERP14 C30 unknown triterpane OLEANOID15A Oleanoid OLEANOID15 Oleanoid OLEANOID16 Oleanoid C3OUNKT2 5(4- +3)abeo- 313(H)- Oleanane 70.223 158540 13.8 13.8 OLEANOID17 3(3- methyl -24- nor - 1(10- >5)abeo- 10(3(H), 18a- oleanane TRITERP17A C30 plant terpane DH30 Diahopane 71.182 276009 24.0 24.0 TRITERP18 C30 unknown triterpane OL18a 18a Oleanane OL18b 18(3 Oleanane • H3Oab 17a, 21(3- Hopane 73.209 763571 66.3 89.8 H30N30 30- Norhomohopane H3OTS 18a,17(3- Neohopane 73.849 92967 8.1 8.1 H30aa 17a,21a- Hopane 74.168 74503 6.5 6.5 H3Oba 1713, 21a- Hopane (Moretane) 74.382 74458 6.5 11.6 GamA Gammacerane -A GamB Gammacerane -B 414.2 - >313.3: Bicadinanes B3OW Bicadinane W (cis,cis,trans) B3OT Bicadinane T (trans, trans,trans) B30T1 Bicadinane T1 B3OR Bicadinane R 274.3 - >203.2: Norpregnanes NORPREG1 Norpregnane -1 NORPREG2 Norpregnane -2 NORPREG3_4 Norpregnane -3 +Norpregnane -4 NORPREG5 Norpregnane -5 NORPREG6 Norpregnane -6 NORPREG7 Norpregnane -7 NORPREG8_9 Norpregnane -8 +Norpregnane -9 NORPREG10 Norpregnane -10 NORPREG11 Norpregnane -11 NORPREG12 Norpregnane -12 • Company: CONOCOPHILLIPS Client ID: US146129 Well Name: GRANDVIEW 1 Lab ID: CP293043 Top Depth: 8158 FT Fraction: SATURATE Bottom Depth: FT File Name: MS090271.D 410 Acquisition Parameters: SAT 0.2UL 1000/1 RES 70EV 7000A 250C AR= 2E -7MBAR CE =25 Peak Label Compound Retention Area Area Resp fact Time Count ppm Area ppm 330.3x191.2: Tetracyclics DesAOL Des -A- Oleanane DesALUP Des -A- Lupane DesATARAX Des -A- Taraxastane DesEHOP Des -E- Hopane 410.4 - >218.2: Monounsaturated C30 Pentacyclic Triterpenoids Bicadinene Bicadinene OL1318ene Olean- 13(18) -ene OL12ene Olean -12 -ene OL18ene Olean -18 -ene OL12ene18a 18x- Olean -12 -ene Unk_Peak1 Unknown peak 1 426.4 — >205.2: C31 Pentacyclic Triterpenoids H312Mab C31 2a-Methylhopane H31abS C31 22S 17a(H)Hopane 76.488 118836 10.3 10.3 H31abR C31 22R 17a(H)Hopane 76.861 59991 5.2 5.2 H313Mab C31313- Methylhopane • Parameter Formula • WGC Parameters Pristane /Phytane IP1911P20 Pristane /nC17 IP19/NC17 Phytane /nC18 IP20/NC18 nC18 /nC19 NC18 /NC19 nC17 /nC29 NCI71NC29 nCi8 /(nC78 +nC1s) NC18 /(NC18 +NC19) nC17 /(nOir+nC29) NC17 /(NC17 +NC29) CPI Hunt ((NC +NC +NC NC29 +NC31) +(NC25 +NC27+ NC29+ NC31+ NC33)) /(2 *(NC24 +NC26 +NC28 +NC30+ NC32)) CPI Marzi° ((NC23 +NC25 +NC27) +(NC25+ NC27 +NC29)) /(2 *(NC24 +NC26 +NC28)) 100 * (NC 4 +NC NC6+ NC7+ NC8+ NC9+ NC10+ NC11+ NC12+ NC13 +NC14 +NC15 +NC16 +NC17 +NC18 +NC19+ Normal Paraffins NC20 +NC21 +NC22 +NC23 +NC24+ NC25+ NC26+ NC27+ NC28 +NC29 +NC30 +NC31 +NC32 +NC33 +NC34+ NC35+ NC36+ NC37+ NC38 +NC39 +NC40 +NC41)/TOTAL_RESOLVED Isoprenoids 100 IP9+ IP10+ IP11+ IP13+ IP14+ IP15 +IP16 +IP18 +1P19 +1P20 +C25HBI) /TOTAL RESOLVED Cycloparaffins 100 *(CP+ MCP +CH +11 DMCP +1 T3DMCP +1 T2DMCP+ MCH +113TMCP +ECP +124TMCP +123TMCP +1 C3DMCP+ 1 C2DMCP)/TOTAL_RESOLVED Branched (iso -) Paraffins 100 * (IC 4 + 22 DMB +23DMB +2MP +3MP+ 22DMP+ 24DMP+ 223TMB +33DMP +2MH +23DMP +3MH +3EP)/ TOTAL_RESOLVED BTX aromatics 100 *(BZ +TOL +MXYL +PXYL +OXYL) /TOTAL_ RESOLVED ( *OXYL added 05/21/2007) Thompson' BZ/nC6 BZ/NC6 TOUnC7 TOUNC7 (nC6 +nC7) /(CH +MCH) (NC6 +NC7) /(CH +MCH) Isoheptane Value ( 2MH +3MH) /(1C30MCP +IT3DMCP +1T2DMCP) nC7 /MCH NC7 /MCH CH /MCP CH/MCP nC7 /2MH NC7 /2MH nC6 /22DMB NC6/22DMB 41, Heptane Value 100 *NC7 /(CH+ 2MH+ 23DMP +11 DMCP+ 3MH +1C3DMCP +1T3DMCP +IT2DMCP +MCH +NC7) MCH /nC7 MCHINC7 mpXYL /nC8 (MXYL +PXYL) /NC8 Mango P1 100 *NC7 /( 22DMP+ 24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1C3DMCP +1T3DMCP +3EP+ IT2DMCP +NC7 +MCH +ECP +TOL) P2 100 * (2MH +3MH) /(220MP +24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +IT3DMCP+ 3EP +IT2DMCP +NC7 +MCH +ECP +TOL) P3 100 * ( 3EP+ 33DMP+ 23DMP+ 24DMP +22DMP +223TMB) /( 22DMP +24DMP +223TMB +33DMP +2MH +23DMP+ 11DMCP+ 3MH +1C3DMCP +1T3DMCP +3EP +1T2DMCP +NC7 +MCH +ECP +TOL) 5N1 100 *(ECP +1 T2DMCP) /( 22DMP +24DMP +223TMB +33DMP +2MH +23DMP +1 I DMCP +3MH +1C3DMCP+ 1T3DMCP +3EP +IT2DMCP +NC7 +MCH +ECP +TOL) N2 100 *(11 DMCP +1 C3DMCP +1 T3DMCP) /( 22DMP +24DMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH+ 1C3DMCP +1T3DMCP +3EP +1T2DMCP +NC7 +MCH +ECP +TOL) 6N1 100 * ( MCH +TOL) /(220MP +24OMP +223TMB +33DMP +2MH +23DMP +11 DMCP +3MH +1 C3DMCP +IT3DMCP+ 3EP +1T2DMCP +NC7 +MCH +ECP +TOL) K1 (2MH +23DMP) /(3MH +24DMP) K2 (2MH +3MH) /(2MH +3MH+11 DMCP +1 C3DMCP +IT3DMCP) 5N1/6N1 (ECP +1T2DMCP) /(MCH +TOL) P3/N2 (3EP +33DMP +230MP +24DMP +22DMP +223TMB) /(11 DMCP +1 C3DMCP +1 T3DMCP) In(24DMP /23DMP) In(24DMP /23DMP) Halpern Tr1 TOL /11 DMCP Tr2 NC7I1 I DMCP Tr3 3M H/11 DMCP Tr4 2MH /11DMCP Tr5 (2MH +3MH) /11 DMCP Tr7 1 T3DMCP /11 DMCP Tr8 ( 2MH+ 3MH ) /(22DMP +23DMP +24DMP +33DMP +3EP) C1 22DMPI(220MP +23DMP +24DMP +33DMP +3EP) C2 23DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C3 24DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C4 33DMP /(22DMP +23DMP +24DMP +33DMP +3EP) C5 3EP /(22DMP +23DMP +24DMP +33DMP +3EP) 0 ConocoPhilhi Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA Grandview #1 Provided by: IA EPOCH Approved by: Kent W. Smith Compiled by: Lees F. Browne Jr. D .01 Steven Pike Date: 03/08/09 Distribution: 5/19/09 '0t \q‘IT-1' Conoco 'hiIIips Alaska. Inc. Grandview #1 • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 2 1.1 Equipment Summary 2 1.2 Crew 2 2 WELL DETAILS 3 2.1 Well Summary 3 2.2 Hole Data 3 2.3 Daily Activity Summary 4 3 GEOLOGICAL DATA 6 3.1 Lithostratigraphy 6 3.2 Mudlog Summary 7 3.3 Chromatograph Gas Ratio Equations Used 12 3.4 Gas Ratio Log - Hydrocarbon Types 12 3.5 Connection Gases 13 3.6 Trip (Wiper) Gases 13 3.7 Sampling Program / Sample Dispatch 14 4 PRESSURE / FORMATION STRENGTH DATA 18 4.1 Pore Pressure Gradient Evaluation 18 4.2 Quantitative Methods 19 5 DRILLING DATA 20 5.1 Survey Data 20 5.2 Bit Record 23 5.3 Mud Record Contractor: MI SWACO 24 6 DAILY REPORTS 25 • E 2 "/100' Formation Log (MD) 2 "/100' Drilling Dynamics Log 2 "/100' Gas Ratio Log 2 "/100' LWD / Lithology Log 2 "/100' Pore Pressure Log El • EPOCH 1 onoc P hillips Alaska, Inc Gr andvie w #1 • 1 MUDLOGGING EQUIPMENT & 1.1 Equipment Summary Ditch as Total Parameter Effective Circulating Density (ECD) Equipment Type / Position Downtime Comments (Hrs) QGM Agitator Change out g (Mounted in possum belly) faulty gas trap, Flame ionization total 1 failed when not gas & chromatography drilling From Sperry-Sun 226' to 8425' 0 Hook Load / Weight on bit Totco WITS Feed 0 Mud Flow In Derived from Strokes /Minute 0 and Pump Output Mud Flow Out Totco WITS Feed 0 Mudlogging unit computer HP Compaq Pentium 4 0 system (x2, DML & Rigwatch) Mudlogging unit DAC box In -unit data collection /distribution 0 gg g center Pit Volumes, Pit Gain /Loss Totco WITS Feed 0 Pump Pressure Totco WITS Feed 0 Pump stroke counters Totco WITS Feed 0 Totco Well Monitoring Totco computer networked 0 Components in Mudlogging Unit Rate of penetration Totco WITS Feed 0 RPM Totco WITS Feed 0 Torque Totco WITS Feed 0 1.2 Crew Unit Type Arctic Steel Unit Number : ML015 Years Days 6 Days Mudloggers <� *2 Sample Catchers •1 =2 Technician *2 2 Steven Pike 22 Zach Beekman 1 20 Allan Williams Lees Browne 29 21 Tollef Winslow 1 20 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well Years Days F1 EPOCH 2 ConocoPhillips Alaska, Inc. Grandview #1 0 2 WELL DETAILS 2.1 Well Summary Well: Grandview #1 API Index #: 50- 103 - 20594 -00 Field: Greater Mooses Tooth Surface Co- Ordinates: 1079.18'FEL, 901.49'FEL, Unit Sec 5, T9N, R01 E, UM Borough: North Slope Primary Target Depth: Jurassic Alpine C, 8046' MD, 7952'TVDSS State: Alaska TD Depth: 8425' MD Rig Name / Type: Doyon 141, Arctic Triple Suspension Date: Primary Target: Jurassic Alpine C Sands License: Spud Date: 02/18/2009 Ground Elevation: 63.9' AMSL Completion Date: 3/10/2009 (Rig released) RT Elevation: 94.9' AMSL Completion Status: P & A Secondary Target: None Depth: Classification: Exploration TD Date: 3/6/2009 TD Formation: Kingkak / Nuiqsut Marker Days Testing: NONE Days Drilling: 16 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole TD Dev. Casing/ LOT Section MD TVDSS Formation Weight (Inc) Coring Liner MD TVDSS (ppm (ft) (ft) (ppg) (ft) (ft) 12.25 2350 - 2258.9 NA 10.0 0.74 NA 9 5/8" 2341 2256 15.4 8.75 8425 - 8331.7 Nuiqsut 11.3 0.91 105' - - - - Additional Comments: 110 L4 I EPOCH 3 Conoc Phillips Alaska. Inc. Grandview #1 • 2.3 Daily Activity Summary 2/15/2009: Rig Up Epoch Unit. Wait on rig to move to ice pad. 2/16/2009: Wait on living quarters to move to ice pad. 2/17/2009: Rig up Epoch logging unit, calibrate gas equipment, connect communication lines. 2/18/2009: Drill out of the conductor at 0430 and begin collecting samples and logging services. 2/19/2009: Spud well and drill to 222', pull out of the hole and pick up the final BHA, trip in the hole and drill ahead with zero trip gas. 2/20/2009: Drill formation from 712' to 1386', wiper trip to 975', no trip gas noted, drill formation to 2350', drop carbide = 10.5 BBLS /gauge hole, prepare for wiper trip. 2/21/2009: Complete wiper trip at 2350', wiper gas was 139 units, trip out of the hole and lay down BHA and rig up to run 9 5/8" casing, run 16 jts and circulate out 110 units, run in the hole to joint #29 and circulate out 52 units, trip to bottom and circulate out 153 units of trip gas, circulate hole. 2/22/2009: Cement 9 5/8" casing to hole, (max gas circ was 16 units), nipple down /up, test BOPs. 2/23/2009: Finish testing BOPs, pick up BHA, run in the hole to 2350', drill out shoe and 20' of new formation, run fit, trip gas was zero drilling out, drilling ahead. 2/24/2009: Drill formation to 3641' wiper trip, wiper gas = 85 units, drill ahead. 2/25/2009: Drill formation to 5206' wiper trip, wiper gas = 201 units, drill Ahead to 5855'. 2/26/2009: Drill formation to 6597' circulate the hole clean, pull out of the hole for BHA. 2/27/2009: Pull out of the hole for BHA change, change BHA and trip to bottom, trip gas was 55 units, drill /slide ahead from 6597' to 7012'. 2/28/2009: Drill /slide ahead from 7012' to 7986'. 3/01/2009: drill /slide ahead to 8043', circulate out samples, drill to 8101', circulate out samples, drill to 8111' (core point), circulate out hole, wiper trip to 6520, wiper gas was 23 units, experience mud losses, spot Icm pill, regain circulation and work hole at 30 spm. 3/02/2009: Pull out of the hole with bit #2rr2, lay down bit, rig up and test BOPs, pick up core #1, trip into the hole to 560', circulate the drilling mud, maximum gas was 11 units, continue to trip in the hole at midnight. 3/03/2009: Trip in the hole with core #1 to 2450' circulate out 20 units, trip in to 5040' circulate out 112 units, trip in to 8050' circulate out 215 units of trip gas, trip in to 8111' and start coring. Mud Loss @ midnight 244 bbl. Cored to 8115' at midnight. 3/04/2009: Core from 8115' to 8216' decrease pump rate from 50 spm to 21 spm and pull up to 8020', down time /swab gas of 1820 units recorded at bottoms up, work the string and monitor the hole for grains /loss, recycled 118 units noted from swab 410 gas, begin to pull out of the hole and monitor at 7000'. El EPOCH 4 ConocoPhillips Alaska, Inc Grandview #1 3/05/2009: Pull out of the hole with Core #1, lay down core and make up BHA and Bit #2RR3, trip into the hole and monitor mud system for loss /gain. 3/06/2009: Trip in the hole with drilling BHA, Trip Gas was 969 units, drill to 8260' connection gas was 1338 units with 270 units of survey gas, drill to 8357', connection gas was 927units with survey gas of 40 units, drill to 8425' and circulate the hole clean at TD, swab gas of 238 units was noted after bottoms up. 3/07/2009: Survey well at 8425' and monitor the well. Back ream out of the hole to 7425' and gained 103 bbls over gauged hole. Run in the hole to 7730' and the drill string started to take weight. Ream in the hole to 7885' and the string packed off. Unable to circulate, so reamed and worked the pipe out of the hole to 6969'. Monitored the well and no circulation was encountered. Pulling out of the hole on the elevators to 2300' and the hole started to swab. Pulled out of the hole very slowly and laid down the BHA. El EPOCH 5 Conoco Phillips Alaska, Inc. Grandview #1 IP 3 GEOLOGICAL DATA 3.1 Lithostratigraphv All tops provided by ConocoPhillips Operations Geologist. FORMATION MD TVD SS TVD (ft) (ft) (ft) Permafrost 947 947 -855.1 Nanushuk (K3) 2437 2437 - 2345.1 Torok (log) 3670 3669.8 - 3577.9 Top Block - - - Top HRZ 7284 7282.9 - 7191.1 K1 / Pebble Shale 7375 7374 - 7282.1 LCU 7458 7456.9 - 7365.0 Top Alpine (MFS) 8047 8045.6 - 7953.7 • UJU / Top Alpine A 8055 8053.6 - 7961.7 Nuiqsut Marker 8352 8350.5 - 8258.6 Total Depth: 8425 8423.6 - 8331.7 th PI EPOCH 6 ConocoPPhillips Alaska. Inc. Grandview #1 • 3.2 Mudlog Summary Conductor to Base Permafrost (80' MD to 947' MD) Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 263.3 5 88.6 53 1 10.1 The permafrost section was encountered from the base of conductor to 947 feet MD . The upper portions of this section from 80 feet MD to 370 feet MD consisted primarily of claystones and siltstones with minor amounts of sand. Claystones from this interval appeared as light gray to yellowish gray; very soft to soft; slightly crumbly to crunchy; slightly sectile; mushy to pasty; some becoming stiff in parts; slightly cohesive; slight to moderate adhesive; sub planar to earthy fracture; sub nodular to sub platy habit; dull earthy fracture; silty to clayey texture massive gradational silty clays; slight carbon material in matrix. The siltstones consisted of very light gray to medium gray with some medium dark gray hues; very clumpy to curdy; crumbly to very brittle; very irregular fracture; mostly amorphous cuttings habit; mostly silty texture with some slightly gritty to clayey in places; predominantly thin interbedded with very thin lenses of sand and thick beds of claystone; abundant dark colored lithic fragments throughout sample; of claystone; no visible sample fluorescence; no solvent cut; no other petroleum hydrocarbon indicators were observed. The minor sand fractions from the upper portions appeared as white to light gray with some clear to translucent, with some moderate blue, and pale blue green to moderate green hues; predominantly quartz • grain sand matrix; lower very fine to lower coarse grain sand; poorly sorted throughout; subrounded to very well rounded with some slightly subangular; moderate sphericity; some sand grains appeared to be slightly frosted; no visible sample fluorescence; no solvent cut. At 370 feet MD to 390 feet MD, minor amounts of devitrified ash were observed. From 390' to the base of permafrost at 947 feet, the dominant lithology was claystone with only minor amounts of siltstone. These claystones appeared as yellowish gray; very soft to soft; malleable to slightly sectile; mushy to pasty; tacky to slimy; slightly cohesive; slight to moderate adhesive; amorphous fracture; massive habit; dull earthy to greasy luster; clayey to silty texture; thin gradations of siltstone. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 938' 53 8880 Colville Group (947' MD to 2437' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 339.6 11.0 111.8 132 1 37.3 The Colville Group is comprised of alternating sequences of claystone, siltstone, with very thin lenses of sand . This is interval extends from 947 feet MD to 2437 feet MD. The claystones in this interval are comprised of medium light gray to light gray with some dark gray; very • mushy to pasty; somewhat elastic to brittle; irregular fracture; amorphous cuttings habit; somewhat waxy to EPOCH 7 Conoc Phillips Alaska, Inc. Grandview #1 • overall dull luster; very clayey to slightly smooth texture; slightly thicker beds of claystone; interbedded with thick beds of siltstone; no visible sample fluorescence; no solvent cut. The siltstones in this interval are made up of very light gray to light gray with some medium gray to medium light gray; clumpy to clotted; very crumbly to brittle; irregular fracture; amorphous cuttings habit; dull to earthy luster; mostly silty texture with some slightly gritty in places; moderately thick siltstone beds interbedded with thin lenses of indurated sand and thick beds of claystone; no visible sample fluorescence; no solvent cut. The sands appeared as translucent to clear with some light gray to white; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout; lower very fine to upper medium grain sand with small amounts of lower coarse grains throughout; moderate to fairly sorted; well rounded to subrounded with some very angular to subangular; moderate to high sphericity; mostly loose sand grains with little or no apparent cementing observed; the sand grains appeared to be indurated throughout; poor to fair apparent sample porosity; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 2334 132 20112 45 7 0 0 0 0 Nanushuk Group (2437' MD to 3670' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 240.5 10.9 111.3 174 10 57.3 110 The Nanushuk Group is composed of predominantly claystone with minor amounts of siltstone. The Nanushuk interval extends from 2437 feet MD to 3670 feet MD. The claystones in this interval are comprised of medium gray to gray to dark gray with some gray; very pasty to mushy; mostly elastic to brittle; irregular fracture; amorphous cuttings habit; mostly dull to very earthy luster; very clayey to slightly smooth texture; slightly thicker beds of claystone, interbedded with thin beds of siltstone; no sample fluorescence; no solvent cut; no other petroleum indicators were observed.. The siltstones in this interval consisted of dark gray to gray with medium dark gray to very dark gray; lumpy to somewhat clumpy; very elastic with some slightly flexible; irregular fracture; amorphous cuttings habit; very earthy to somewhat dull in luster; mostly silty texture with some slightly clayey in places; thin siltstone beds interbedded with very thick beds of claystone; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 2636 174 32452 1827 68 0 50 0 0 Torok Group (3670' to 7284' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 230.7 10.4 88.8 861 6 83.1 • The Torok Group is characterized by predominantly claystone with subordinate amounts of siltstone. The Torok extends from 3670 feet MD to 7284 feet MD. El EPOCH 8 ConocoPhillips Alaska, Inc. Grandview #1 • The claystones in this section is appeared as medium gray to gray to very dark gray and dark gray; very mushy to pasty; somewhat flexible to elastic; irregular fracture; amorphous cuttings habit; overall dull to earthy luster; very clayey to slightly smooth texture; slightly thicker beds of claystone, interbedded with moderately thick beds of siltstone; no visible sample fluorescence; no solvent cut; no other petroleum indicators were observed in the sample. The siltstones in this formation consist of light gray to gray with some dark gray to very dark gray and medium gray; very pasty to somewhat slightly firm; some slightly stiff to brittle overall; irregular fracture throughout; amorphous cuttings habit; earthy to somewhat dull luster; very silty texture throughout with some slightly clayey in places; thick bedded siltstone interbedded with thick beds of claystone; dark colored lithic fragments throughout; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C4l C4N C5l C5N 5671 861 121295 13549 5346 2890 2549 HRZ Formation / Pebble Shale (7284' to 7375' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 155.5 9.1 79.6 118 47 85.9 This interval is comprised of predominantly shale, carbonaceous shale and minor siltstones from approximately 7284 feet MD to 7375 feet MD. • The shales in the HRZ appeared as medium gray to gray with some grayish brown to slightly brownish gray in places; moderately firm to slightly stiff; brittle to crumbly; very planar fracture with some slightly blocky; platy to flaky cuttings habit; very dull to somewhat greasy luster; mostly smooth to slightly abrasive texture; moderately thick shale beds interbedded with thinning beds of siltstone; very bright greenish yellow sample fluorescence; no solvent cut. The carbonaceous shales in this formation consisted of dark gray to medium gray; very firm to stiff; stiff to dense; blocky to planar fracture; very platy cuttings habit; resinous to slightly greasy luster; slightly smooth to granular texture; moderately thick shale beds interbedded with thin beds of siltstone; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C4l C4N C5l C5N 7321 155.5 10653 2404 2054 659 306 Lower Cretaceous Unconformity / Miluveach Shale (7375' to 7458' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 213.5 9.7 107.7 95 28 58.9 This group, which is comprised of alternating sequences of claystone' and siltstones with some very thin sands and shales, was drilled from 7375 feet MD to 7458 feet MD. • The claystones in this formation are composed of brown to light brown with some brownish gray; very mushy to pasty; mostly elastic to slightly brittle; irregular fracture; amorphous cuttings habit; mostly earthy El EPOCH 9 ConocoPhillips Alaska, Inc. Grandview #1 to overall dull luster; very clayey to slightly gritty texture; slightly thinner beds of claystone; interbedded 4110 with thick beds of siltstone and very thin beds of shale; no visible sample fluorescence; no solvent cut. Shales in this section are made up of brownish gray to light brownish gray with some grayish brown and dusky brown hues; slightly firm to somewhat stiff; crumbly to mostly brittle; slightly blocky or planar fracture; overall platy to slightly flaky cuttings habit; slightly resinous to somewhat dull luster; overall silty texture with some slightly abrasive; very thin shale beds interbedded with thick beds of siltstone and thinner beds of claystone; no visible sample fluorescence; no solvent cut; no other petroleum indicators were observed in the sample. The siltstones in this unit are comprised of light brown to pale yellowish brown with some brownish gray and dusky brown hues; slightly stiff to somewhat clumpy; very crumbly to brittle; irregular fracture; amorphous cuttings habit; dull to earthy luster; mostly silty texture with some very clayey in places; moderately thick siltstone beds interbedded with thick beds of claystone and thin beds of shale; no sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7388 95 8429 1909 1643 570 272 Jurassic Alpine Equivalent (8046' to 8215' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 31 4 21 406 19 109 • The Jurassic Alpine Equivalent sandstone is composed of sand and sandstone with alternating sequences of siltstone and claystone, from approximately 8046 feet MD to 8215 feet MD. The Alpine C equivalent is very thin ranging from 8046 feet MD to 8056 feet MD. The Alpine A equivalent is present from 8056 feet MD to 8215 feet MD. The drill rate was controlled to 30 ft/hr and 15' samples were started at 8000'. Samples were collected every 10' at 8030' to discern between siltstones and the beginning of dark green glauconite in the samples. The 8040' sample yielded distinct dark green glauconite interbedded within the siltstones. Sample were then collected every 5' for glauconite identification. The glauconite ranged from moderate to abundant in the 8040' (Samples were circulated out from 8043' to 8048' to aid in sample identification) and gradually dissipated with depth to 8055', in which the glauconite was not present in the samples. No glauconite was noted in samples from 8055' to 8111'. Core #1 was commenced at 8111'. The sand and sandstone in this formation are comprised of yellowish gray to very light gray; clast size fine lower to very fine lower some grading to silt; sub round to sub angular; moderate sphericity; poor to moderate sorting; impacted texture; sub mature to mature nature; silic cement; slight secondary grain enlargement/overgrowths; poor to fair (scattered) porosity; permeability is poor; no oil odor, no stain, slight 30% dull patchy sample fluorescence at 8,117 feet with no oil cuts; slight residue stain; no sample oil cuts through zone; samples grading to light brownish gray bioturbated silts at 8,164 feet with minor silty sand interbedded to 8,216 feet. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 8130 406 45136 7108 2958 839 492 631 159 • El EPOCH 10 ConocoPPhillips Alaska, Inc Grandview #1 • Kingak to T.D. (8215' MD to 8425' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 86 3.3 44.9 148 37 86.6 The Kingak was encountered from 8215 feet MD to TD at 8425 feet MD. The Kingak consisted of primarily medium -dark gray to very dark gray to grayish black brittle to crumbly interbedded siltstones and claystone's with a generally blocky to irregular cuttings habit. Textures were primarily gritty to silty with a dull earthy to slightly greasy luster. These silts and shales displayed some faint yellow green sample fluorescence and produced instantaneous bright yellowish white cuts. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8241 148 11729 1836 886 - 328 - 126 El EPOCH 11 ConocoPhillips Alaska, Inc. Grandview #1 • 3.3 Chromatoqraph Gas Ratio Equations Used Chromatograph Ratio Calculations: (After Haworth, Sellens and Whittaker, 1985) Wetness W = [(C2 +C3 +iC4 +nC4 +iC5+nC5) / (C1 +C2 +C3 +iC4 +nC4 +iC5+nCs)] x 100 Balance Bh = (Ci + C2) / (C3 +iC4 +nC4+iC5+nC5) Character Ch = (iC +nC +iC / C3 3.4 Gas Ratio Log - Hydrocarbon Types The Hydrocarbon Types present in the Type Column of the Gas Ratio Log are defined below: 1. Type 1: Non productive - ultra -dry non associated gas, possibly geopressured methane. 2. Type 2: Non productive - dry non associated gas - possibly coal gas. 3. Type 3: Productive petroleum gas - wetness increases as Wetness and Balance curves converge. 4. Type 4: Productive petroleum gas - grading from wet gas to condensate as the Wetness curve increases. 5. Type 5: Productive medium to high gravity oil - oil gravity decreasing with increased divergence of wetness and balance curves. 6. Type 6: Low primary production potential - low gravity oil with low gas saturation 7. Type 7: Non - productive oil- very low gravity oil and /or residual oil. • El I EPOCH 12 Conoc Alaska, Inc Grandview #1 • 3.5 Connection Gases 1 unit = 0.05% Methane Equivalent Depth Gas over BGG (feet) (units) 1286 70 4743 175 4836 70 5021 400 5114 50 5206 201 8265 1338 8360 927 3.6 Trip (Wiper) Gases 1 unit = 0.05% Methane Equivalent Depth Trip to Gas Downtime (feet) (feet) (units) (hours) 1286 975 0 1.5 2350 975 139 2.0 2350 0 NA 60.0 3631 2347 85 2.0 . 5206 3628 201 1.5 6597 0 55 16 8111 0 215 43 8216 0 969 39 8425 7290 856 Pump out of hole • Ell EPOCH 13 Alaska. Inc. Grandview #1 • 3.7 Sampling Program / Sample Dispatch ih illips Set Type / Purpose Frequency Interval Dispatched to 30' 90' — 8010' / 8230' — 8425' Hallib urton A Unwashed Samples 15' 8025' — 8085' 6900 Arctic Boulevard Set owner: CPAI Unwashed Samples Set owner: CPAI -Trade Unwashed Samples • Set owner: Anadarko Type /Purpose Washed Samples Set owner: CPAI Washed Samples Set owner: CPAI - Trade • Washed Samples Set owner: Anadarko 10' 8100' — 8210' Anchorage, AK 99518 Attn: Robert Haverfield 273 3559 5' 8095' — 8100' 30' 90' — 8010' / 8230' — 8425' Halliburton i3 15' 8025' — 8085' 6900 Arctic Boulevard 10' 8100' — 8210' Anchorage, AK 99518 Attn: Robert Haverfield 273 -3559 5' 8095' — 8100' 30' 90' — 8010' / 8230' — 8425' Halliburton 15' 8025' — 8085' 6900 Arctic Boulevard 10' 8100' — 8210' Anchorage, AK 99518 Attn: Robert Haverfield 273 -3559 5' 8095' — 8100' Set Frequency Interval Dispatched to 30' 90' — 8010' / 8230' — 8425' CPAI 15' 8025' — 8085' Bayview Geologic Facility A 619 East Ship Creek Ave Ste 14 10' 8100' — 8210' Anchorage, AK 99501 5' 8095' — 8100' Attn: D. Przywojski 265 -6340 30' 90' — 8010' / 8230' — 8425' CPAI 15' 8025' — 8085' Bayview Geologic Facility B 619 East Ship Creek Ave Ste 14 10' 8100' — 8210' Anchorage, AK 99501 5' 8095' — 8100' Attn: D. Przywojski 265 -6340 30' 90' — 8010' / 8230' — 8425' CPAI 15' 8025' — 8085' Bayview Geologic Facility 619 East Ship Creek Ave Ste 14 10' 8100' — 8210' Anchorage, AK 99501 5' 8095' — 8100' Attn: D. Przywojski 265 6340 30' 90' — 8010' / 8230' — 8425' CPAI • Washed Samples 15' 8025' — 8085' Bayview Geologic Facility Set owner: AOGCC 619 East Ship Creek Ave Ste 14 10' 8100' — 8210' Anchorage, AK 99501 5' 8095' — 8100' Attn: D. Przywojski 265 -6340 30' 90' — 8010' / 8230' — 8425' CPAI E Washed Samples 15' 8025' — 8085' Bayview Geologic Facility Set owner: BLM 619 East Ship Creek Ave Ste 14 10' 8100' — 8210' Anchorage, AK 99501 5' 8095' — 8100' Attn: D. Przywojski 265 -6340 El EPOCH 14 Conoc Phillips Alaska. Inc. Grandview #1 Set / Purpose Frequency Interval Dispatched to 10' — or Isotech Laboratories, Inc. A Gas B ags as show 8025' — 8425' 1308 Parkland Court Champaign, IL 61821 requires (877) 362 -4190 Isotope Logging Inc (Isolog) A Isotubes 500' 110' — 5000' 2435 N. Central Expressway 100' 5100' — 8425' Suite 1200 Richardson, TX. 75080 CPAI Bayview Geologic Facility A !so Jars Type 10' 8119' — 8210' 619 East Ship Creek Ave Ste 14 Anchorage, AK 99501 Attn: D. Przywojski 265 -6340 Sample frequency was locally altered according to drill rate constraints and zones of interest. El • EPOCH 15 ConocoPhillips °al Alaska, Inc. Grandview #1 IsoBag Gas Sample Inventory — Provided by Isotech Time Date !so Bag Number 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2400 m /dd /yr Total Gas Units Depth MD 0127 2/28/09 28 8025 0151 2/28/09 23 8040 0224 2/28/09 27 8055 0315 2/28/09 46 8070 0357 2/28/09 90 8085 0427 2/28/09 88 8100 0524 2/28/09 171 8104 1131 3/2/09 213 8118 0149 3/3/09 300 8130 0307 3/3/09 125 8140 0416 3/3/09 177 8150 0519 3/3/09 172 8160 0652 3/3/09 87 8170 0704 3/3/09 275 8172 0750 3/3/09 114 8180 0910 3/3/09 60 8190 1120 3/3/09 820 8200 1215 3/3/09 45 8210 1730 3/5/09 70 8220 20 1800 3/5/09 92 8230 21 1830 3/5/09 140 8240 IsoTube Gas Sample Inventory — Provided by Isotech Depth MD 1000 1500 2000 2500 3000 3500 4000 Gas Units Date Time Comments 34 1 /19/09 0312 GOOD 35 1 /19/09 1050 GOOD 26 1 /19/09 1740 GOOD 47 2/22/09 1900 GOOD 70 2/23/09 0142 GOOD 40 2/23/09 1030 GOOD 26 2/23/09 1580 GOOD 4500 4805 4847 4853 4996 5000 5100 5200 5300 5400 5500 5600 5700 5800 52 2/24/09 0207 GOOD 257 2/24/09 0600 GOOD 375 2/24/09 0640 GOOD 600 2/24/09 0645 GOOD 640 2/24/09 0840 GOOD 233 2/24/09 0845 GOOD 152 2/24/09 1015 GOOD 153 2/24/09 1150 GOOD 132 2/24/09 1600 GOOD 430 2/24/09 1735 GOOD 113 2/24/09 1857 GOOD 87 2/24/09 2027 GOOD 327 2/24/09 2145 GOOD 198 2/24/09 2306 GOOD 5900 95 2/25/09 0023 GOOD 6000 68 2/25/09 0145 GOOD Ea 1 EPOCH 16 Depth MD • 6100 6200 6300 Conoc Phillips Alaska, Inc. Grandview #1 Gas Units Date Time Comments 44 2/25/09 0318 GOOD 102 2/25/09 0445 GOOD 55 2/25/09 0809 GOOD 6400 6500 6600 6700 6800 6900 7000 7100 20 2/25/09 1145 GOOD 15 2/25/09 1425 GOOD 9 2/26/09 1159 GOOD 14 2/26/09 1545 GOOD 19 2/26/09 1854 GOOD 21 2/26/09 2053 GOOD 12 2/26/09 2340 GOOD 25 2/27/09 0242 GOOD 7200 7248 7300 7400 7500 7600 7700 7800 7900 8000 8055 38 2/27/09 0524 GOOD 144 2/27/09 0640 GOOD 108 2/27/09 0753 GOOD 75 2/27/09 0943 GOOD 41 2/27/09 1147 GOOD 43 2/27/09 1359 GOOD 51 2/27/09 1557 GOOD 35 2/27/09 1811 GOOD 27 2/27/09 2118 GOOD 29 2/28/09 0046 GOOD 25 2/28/09 0225 GOOD 8118 8130 156 3/3/09 0032 GOOD 346 3/3/09 0145 GOOD 8140 125 3/3/09 0308 GOOD 8148 260 3/3/09 0408 GOOD IsoJar Sample Inventory — Provided by Isotech Depth MD 8119 8130 8140 8150 8160 8170 Gas Units Date Time Comments 215 3/03/09 0039 GOOD 345 3/03/09 0145 GOOD 105 3/03/09 0305 GOOD 179 3/03/09 0415 GOOD 150 3/03/09 0515 GOOD 121 3/03/09 0652 GOOD 8180 8190 108 3/03/09 0751 GOOD 60 3/03/09 0920 GOOD 8200 919 3/03/09 1122 GOOD 8210 60 3/03/09 1223 GOOD Ell EPOCH 17 1 • Cono hiHips • Alaska, Im Grandview #1 4 PRESSURE / FORMATION STRENGTH DATA The pore pressure gradient (PPG) is estimated to have varied from 10.0 to 10.4 from the base of the Permafrost through the Torok to the Top HRZ, and 11.2 to 11.3 through the base of the Nuiqsut Marker, increasing mud weight as per the well plan. Excessive concentrations of gas encountered in the Alpine C formation caused an increase in connection gases and continued high concentrations of gas (900 -1300 units) developing through surveys and down time. No increase in the mud weight was noted and only a half pound mud cut was noted sporadically. All gas kicks where sharp peaks with immediate burn off. No sustained or "bell gas" peaks. 4.1 Pore Pressure Gradient Evaluation Primary Secondary Trend Interval Tops Pore Pressure (EMW) Formation Lithology Indicators Lithology o MDRKB TVD TVDSS Min Max (��) Interval ( %) (ft) (ft) (ft) (ppg) (ppg) Trend Base Permafrost Sltst 60% Clyst 40% 947 _ 947.0 -855.1 10.0 10.0 Flat BG Nanushuk Clyst 60% Sltst40% 2437 _ 2437.0 - 2345.1 10.0 10.0 Flat BG Torok Sltst 70% Clyst 30% 3670 3669.8 - 3577.9 10.0 10.0 Flat BG,CG Top HRZ Sh 70% Sltst 30% 7284 7282.9 - 7191.1 11.2 11.2 Flat BG K1/ Pebble Shale Sh 60% Sltst 40% 7375 7374.0 _ - 7282.1 11.3 11.3 Flat BG LCU Sltst 60% Sh 40% 7458 7456.9 - 7365.0 11.3 11.3 Flat BG Top Alpine (MFS) Sn 70% Sltst 30% 8047 8045.6 - 7953.7 11.2 11.3 Incr BG,CG, TG UJU Sltst Sltst/Clyst 8055 _ 8053.6 - 7961.7 11.2 11.2 Flat BG Nuiqsut Marker Sltst 80% Sltst 20% 8352 8350.5 - 8258.6 11.2 11.2 Incr BG,CG, TG Total Depth - - 8425 8423.6' - 8331.7 - - - - NOTE: Clyst = Claystone /Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sst = Sandstone; Mdst = Mudstone Pi EPOCH 18 Coillips • Ala, Inc Grandview #1 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Epoch, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD — (0.6- ((.001 *TLGSU) +(0.05 *DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when estimating trends, as with DXC data, with data points in shale intervals. Ell EPOCH 19 ConocoPhillips Alaska, Inc. Grandview #1 • 5 DRILLING DATA 5.1 Survey Data Measured True Latitude Departure Vertical Dogleg Depth Incl. I . Azom. Vertical (ft) (ft) Section Rate (ft) () () Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE -IN 211.50 0.56 32.75 211.50 0.87 0.56 0.87 0.26 304.94 0.51 30.27 304.93 1.61 1.02 1.61 0.06 397.51 0.42 34.55 397.50 2.25 1.42 2.25 0.10 489.27 0.37 38.83 489.26 2.76 1.79 2.76 0.06 580.38 0.36 38.24 580.37 3.21 2.15 3.21 0.01 672.47 0.33 31.49 672.45 3.66 2.47 3.66 0.05 762.82 0.31 42.10 762.80 4.07 2.77 4.07 0.07 855.22 0.37 37.01 855.20 4.49 3.12 4.49 0.07 948.26 0.23 42.47 948.24 4.92 3.47 4.92 0.06 1041.44 0.25 31.01 1041.42 5.29 3.76 5.29 0.10 1133.86 0.27 41.53 1133.84 5.62 4.00 5.62 0.06 1226.68 0.20 20.93 1226.66 5.94 4.21 5.94 0.12 1318.42 0.33 57.23 1318.40 6.23 4.49 6.23 0.22 1411.50 0.16 31.38 1411.47 6.49 4.78 6.49 0.21 1504.18 0.13 21.58 1504.15 6.70 4.88 6.70 0.04 • 1597.43 0.24 29.13 1597.40 6.96 5.02 6.96 0.12 1690.44 0.19 60.45 1690.41 7.21 5.25 7.21 0.14 1875.18 0.22 55.61 1875.15 7.56 5.81 7.56 0.02 1967.26 0.26 254.14 1967.23 7.59 5.71 7.59 0.51 2059.78 0.72 257.22 2059.75 7.41 4.94 7.41 0.50 2151.75 0.79 253.54 2151.71 7.10 3.77 7.10 0.09 2243.25 0.77 260.03 2243.20 6.82 2.56 6.82 0.10 2282.76 0.74 263.83 2282.71 6.74 2.05 6.74 0.15 2352.84 1.01 258.68 2352.78 6.29 1.03 6.29 0.40 2449.87 1.03 251.42 2449.80 5.85 0.64 5.85 0.13 2542.47 1.11 256.73 2542.38 5.38 2.30 5.38 0.14 2635.21 1.05 258.29 2635.10 5.00 4.00 5.00 0.07 2727.21 1.38 241.58 2727.08 4.30 5.80 4.30 0.52 2819.12 1.16 249.16 2818.97 3.44 7.65 3.44 0.30 2912.34 1.07 246.79 2912.17 2.76 9.33 2.76 0.11 3005.17 1.09 245.62 3004.99 2.06 10.93 2.06 0.03 3097.53 0.88 251.74 3097.33 1.47 12.40 1.47 0.25 3189.44 0.92 246.77 3189.23 0.96 13.75 0.96 0.10 3282.61 1.04 243.21 3282.39 0.28 15.19 0.28 0.14 3375.26 0.68 241.72 3375.03 0.36 16.43 -0.36 0.39 3465.33 0.12 276.09 3465.09 0.60 16.99 -0.60 0.65 3562.85 0.25 39.57 3562.61 0.42 16.96 -0.42 0.34 • 3654.70 0.17 354.10 3564.46 0.13 16.84 -0.13 0.19 3747.94 0.23 325.77 3747.70 0.16 16.96 0.16 0.12 El I EPOCH 20 Conoc Phillips Alaska, Inc. Grandview #1 III Measured Incl. zim True Latitude Departure Vertical Dogleg p Vertical (ft) (ft) Section Rate (ft) (°) () Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 3840.38 0.38 307.06 3840.14 0.50 17.31 0.50 0.19 3933.06 0.41 295.08 3932.82 0.82 17.86 0.82 0.09 4025.75 0.50 299.96 4025.51 1.16 18.51 1.16 0.11 4118.06 0.43 324.38 4117.81 1.65 19.06 1.65 0.23 4210.92 0.48 343.37 4210.67 2.30 19.37 2.30 0.17 4301.88 0.38 346.02 4301.63 2.96 19.56 2.96 0.11 4394.92 0.06 62.46 4394.67 3.28 19.59 3.28 0.40 4487.27 0.35 127.69 4487.02 3.13 19.32 3.13 0.36 4579.61 0.17 69.38 4579.36 3.01 18.97 3.01 0.32 4672.27 0.12 34.21 4672.02 3.14 18.79 3.14 0.11 4766.02 0.07 345.08 4765.77 3.27 18.75 3.27 0.10 4859.13 0.09 320.46 4858.88 3.39 18.81 3.39 0.04 4951.54 0.15 346.32 4951.28 3.56 18.88 3.56 0.09 5044.38 0.27 346.84 5044.12 3.89 18.96 3.89 0.13 5138.59 0.27 346.64 5138.33 4.32 19.06 4.32 0.00 5230.65 0.25 284.05 5230.39 4.58 19.31 4.58 0.29 5323.53 0.27 343.50 5323.27 4.84 19.57 4.84 0.28 5415.79 0.36 2.25 5415.53 5.34 19.62 5.34 0.15 5508.77 0.28 353.64 5508.51 5.86 19.63 5.86 0.10 5601.39 0.26 330.35 5601.13 6.26 19.76 6.26 0.12 5693.82 0.29 337.23 5693.56 6.66 19.95 6.66 0.05 • 5786.66 0.22 341.88 5786.40 7.05 20.10 7.05 0.08 5877.27 0.24 0.00 5877.00 7.40 20.15 7.40 0.08 5970.72 0.32 51.64 5970.45 7.76 19.95 7.76 0.27 6063.85 1.46 75.43 6063.57 8.22 18.60 8.22 1.26 6155.26 2.54 72.81 6154.92 9.11 15.54 9.11 1.19 6247.55 3.05 76.46 6247.10 10.29 11.19 10.29 0.59 6340.62 2.74 89.98 6340.06 10.87 6.56 10.87 0.80 6435.72 2.30 98.05 6435.06 10.61 2.40 10.61 0.59 6528.11 2.67 111.90 6527.37 9.54 1.43 9.54 0.76 6620.52 2.02 149.21 6619.71 7.12 3.54 7.12 1.75 6713.26 1.91 212.33 6712.40 4.41 3.55 4.41 2.22 6805.88 1.93 259.55 6804.97 2.83 1.19 2.83 1.66 6898.77 0.81 49.64 6897.85 2.97 0.15 2.97 2.87 6989.71 1.14 46.44 6988.78 4.01 1.29 4.01 0.37 7082.08 1.26 218.46 7081.14 3.85 1.33 3.85 2.59 7174.94 1.61 239.43 7173.97 2.38 0.43 2.38 0.67 7267.54 1.59 255.86 7266.54 1.41 2.79 1.41 0.49 7360.31 2.06 256.43 7359.26 0.70 5.66 0.70 0.51 7454.59 1.86 260.04 7453.48 0.04 8.82 0.04 0.25 7545.85 1.99 260.60 7544.69 0.48 11.84 -0.48 0.14 7639.83 2.10 259.75 7638.61 1.05 15.14 -1.05 0.12 7731.19 1.84 258.92 7729.92 1.63 18.23 -1.63 0.29 7823.89 1.44 261.11 7822.58 2.09 20.84 -2.09 0.44 • 7915.32 1.15 259.18 7913.99 2.44 22.88 -2.44 0.32 8008.69 1.14 248.46 8007.34 2.96 24.66 -2.96 0.23 El EPOCH 21 Conoc Alaska, Inc. Grandview #1 • Measured Depth Incl. Az True Vertical Latitude Departure Vertical Dogleg om. (ft) (ft) Section Rate (ft) () () Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 8102.35 1.19 259.89 8100.98 -3.28 -26.51 -3.28 0.05 8192.22 1.06 257.53 8190.83 -3.63 -28.24 -3.63 0.15 8283.91 0.91 521.08 8282.51 -4.05 -29.76 -4.05 0.20 8354.92 0.91 252.62 8353.51 -4.40 -30.83 -4.40 0.03 8425.00 0.91 252.62 8423.58 -4.73 -31.89 -4.73 0.00 S • El I EPOCH 22 S C o i llips • Alaska, Inc Grandview #1 5.2 Bit Record Depth In Total Bit Avg. WOB PP Bit Size Make Type / S# Jets / TFA ROP RPM MD / Footage Hrs (Klbs) (psi) Wear BHA (ft/hr) 1 12.25 Hughes MXL -1X 1X12, 110 2240 29:20 104 11 94 1192 1- 2- CT- G- E -I -TD 1 5161545 3X16 2 8.75 Reed DS7OFNPV 6x13 2340 4057 53.32 75.8 8 100 1200 - 2 Hycalog 201807 2rr2 8.75 Reed DS7OFNPV 6x13 6597 5771.6 86.53 66.3 10 -12 120 1400 1- 2- WT- G- X -i -CP 3 Hycalog 201807 CORE 3 8.75 HTC _ 8111 104 15.06 6.9 8 -10 140 1400 - 4 7119053 2rr3 7.75 Reed DS7OFNPV 6x13 8216 209 6.05 34.8 10 -12 160 1450 5 Hycalog 201807 HI EPOCH 23 • Coillips • Alaska. Inc. Grandview #1 5.3 Mud Record Contractor: MI SWACO Mud Type: 6% KCL /Klagard MW ECD VIS FL SoIs O/W Sd CI Ca Date Depth (ppg) (ppg) (s /qt) PV YP Gels (cc) FC ( %) Ratio ( %) pH (m1 /1) (m1 /1) 2/17/09 110 10.0 10.4 156 14 32 8/9/9 5.8 1 8 /92 9.8 31000 40 2/18/09 350 10.0 10.4 156 16 40 13/17/19 4.6 1/ 8 /92 9.7 29000 40 2/19/09 2350 10.0 10.4 102 15 32 13/24/30 5.0 1/ 9 /91 0.5 9.4 31000 40 2/20/09 2350 10.0 10.4 96 20 27 12/17/25 5.3 1/ 9 /91 0.5 9.2 31000 40 2/21/09 2350 9.9 10.3 61 13 23 7/11/16 5.8 1/ 9 /91 0.25 9.0 28000 40 2/22/09 2855 10.0 10.6 55 18 22 6/14/20 5.3 1/ 8 /92 Tr 9.2 29000 140 2/23/09 4375 10.0 10.6 53 17 23 6/11/18 5 1/ 9 /91 Tr 9.4 30000 40 2/24/09 5855 10.0 10.6 48 17 23 6/14/22 5.8 1/ 9 /91 0.1 9.5 32000 40 2/25/09 6597 11.1 11.9 49 22 27 6/15/24 5.8 2/ 13.5 Tr /87 0.125 9.2 33000 40 2/26/09 7012 11.1 11.9 47 20 23 5/14/22 5.9 2/ 14 Tr /86 0.125 9.3 35000 140 2/27/09 7986 11.3 12.0 44 19 22 5/12/17 5.9 2/ 15 Tr /85 0.125 9.7 35000 120 2/28/09 8111 11.3 12.0 55 18 28 6/14/18 5.7 2/ 15 Tr /85 0.125 9.5 35000 120 3/01/09 8111 11.3 11.3 53 16 22 3/7/11 4.5 2/ 14 Tr /85 0.125 9.5 33000 200 3/02/09 8111 11.3 12.0 50 16 18 3/10/14 4.3 2/ 14 Tr /86 0.125 9.5 34000 200 3/03/09 8216 11.2 11.9 50 18 19 4/8/12 3.8 2// 14 Tr /86 Tr 9.5 34000 160 3/04/09 8216 11.3 11.9 52 18 19 4/8/13 3 1// 14 Tr /86 Tr 9.5 35000 140 3/5/09 8269 11.2 11.6 45 17 18 4/8/11 3.4 1// 15 Tr /85 Tr 9.5 31000 80 3/6/09 8425 11.2 - 45 17 23 3/5/12 3.5 2// 14 Tr /86 Tr 10.0 34000 120 Abbreviations MW = Mud Weight Gels = Gel Strength Sd = Sand content ECD = Effective Circulating Density WL = Water or Filtrate Loss CI = Chlorides VIS = Funnel Viscosity FC = Filter Cake Ca = Hardness Calcium PV = Plastic Viscosity Sols = Solids O/W = Oil to Water ratio YP = Yield Point El EPOCH 24 6 DAILY REPORTS • • S El EPOCH 25 ConocoPhillips Alaska Inc. Grandview #1 Daily Report S Report for: Wahl /Springer Date: 2/18/09 Time: Midnight Current Depth (MD): 743 Current Current Depth (TVD): Operations: 24 hr Footage (MD): 632 Drilling Parameters ROP: Current: 81 Max: 263 Torque: Current: Max: WOB: Current 7.9 Max: 23 RPM: Current: 78.3 Max: 101 PP: Current: 774 Max: 1093 Lag: Strokes: 942 Time: 8 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10.0 FV: 156 PV: 14 YP: 32 FL: 5.8 Gels: 8/9/9 Sol: 8 pH: 9.8 Cl 31000 Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 9 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 222' 0 Connection 0 C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N II I Lithologies: Current: 90% clay, 10% silt Last 24 hrs: clay, silt, ash, sand Operational Summary: Spud well and drill to 222', pull out of hole and pick up the final BHA, trip in the hole and drill ahead with zero trip gas. Calibrations: Chromatograph, THA. Failures: None Daily Cost: S El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report Report for: Wahl /Springer Date: 2/19/09 Time: Midnight Current Depth (MD): 743 Current Current Depth (TVD): Operations: 24 hr Footage (MD): 632 Drilling Parameters ROP: Current: 81 Max: 263 Torque: Current: Max: WOB: Current 7.9 Max: 23 RPM: Current: 78.3 Max: 101 PP: Current: 774 Max: 1093 Lag: Strokes: 942 Time: 8 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10.0 FV: 156 PV: 14 YP: 32 FL: 5.8 Gels: 8/9/9 Sol: 8 pH: 9.8 Cl 31000 Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 9 • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas 222' 0 Connection 0 C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 90% clay, 10% silt Last 24 hrs: clay, silt, ash, sand Operational Summary: Spud well and drill to 222', pull out of hole and pick up the final BHA, trip in the hole and drill ahead with zero trip gas. Calibrations: Chromatograph, THA. Failures: None Daily Cost: S El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 2/19/09 Time: Midnight Current Depth (MD): 743 Current Current Depth (TVD): Operations: 24 hr Footage (MD): 632 Drilling Parameters ROP: Current: 81 Max: 263 Torque: Current: Max: WOB: Current 7.9 Max: 23 RPM: Current: 78.3 Max: 101 PP: Current: 774 Max: 1093 Lag: Strokes: 942 Time: 8 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10.0 FV: 156 PV: 14 YP: 32 FL: 5.8 Gels: 8/9/9 Sol: 8 pH: 9.8 Cl 31000 Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): Avg BG : 9 5 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas 222' 0 Connection 0 C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N 0 10% Lithologies: Current: 90% clay, 10 /o silt Last 24 hrs: clay, silt, ash, sand Operational Summary: Spud well and drill to 222', pull out of hole and pick up the final BHA, trip in the hole and drill ahead with zero trip gas. Calibrations: Chromatograph, THA. Failures: None Daily Cost: S PI EPOCH ConocoPhillips Alaska Inc. Grandview #1 • Daily Report Report for: Wahl /Springer Date: 2/20/09 Time: Midnight Current Depth (MD): 2350' Current Current Depth 2349.94' Operations: (TVD): 24 hr Footage (MD): 1607' Drilling Parameters ROP: Current: 0 Max: 248 Torque: Current: Max: WOB: Current 0 Max: 24 RPM: Current: 0 Max: 106 PP: Current: 0 Max: 1790 Lag: Strokes: 2910 Time: 22 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10.0 FV: 156 PV: 16 YP: 40 FL: 4.6 Gels: 13/17/19 Sol: 8 pH: 9.7 Cr 29000 Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): 0 Avg BG : 35.2 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 1386'/1386' 0 Connection C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 1000'/1000' 34 5653 2 1500'/1500' 35 6356 3 2000'/2000' 36 7090 Lithologies: Current: 2350 = 80% Siltstone, 20% Sandstone Last 24 hrs: Siltstone, Claystone, Sandstone Operational Summary: Drill formation from 743' to 1386', wiper trip to 975', no trip gas noted, drill formation to 2350', drop carbide = 10.5 BBLS /Gauge hole, prepare for wiper trip. Calibrations: None Failures: None III Daily Cost: U EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 2/21/09 Time: Midnight Current Depth (MD): 2350' Current Current Depth 2349.94' Operations: (TVD): 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: Max: WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 2800 Time: 22 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10.0 FV: 102 PV: 15 YP: 32 FL: 5 Gels: 13/24/30 Sol: 9 pH: 9.4 Cr 31000 Ca + +: 80 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 35 Circ Gas Events Depth ( MD/TVD) C1 C2 C3 C4l C4N C5I C5N Trip Gas 2350'/2349.94' 153 Connection C1 C2 C3 C4l C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 1000'/1000' 34 5653 2 1500'/1500' 35 6356 3 200072000' 36 7090 Lithologies: Current: 2350 = 90% Siltstone, 10% Sandstone Last 24 hrs: 90% Siltstone, 10% Sandstone Complete wiper trip at 2350', wiper gas was 139 units, trip out of hole and lay Operational Summary: down BHA and rig up to run 9 5/8" casing, run 16 JTS and circulate out 110 units gas, run in the hole joint #29 and circulate out 52 units, trip to bottom and circulate out 153 units of trip gas, circulate hole. Calibrations: None • Failures: None Daily Cost: PI EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 2/22/09 Time: Midnight Current Depth (MD): 2350' Current Current Depth Test BOPs 2349.94' Operations: (TVD): 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10.0 FV: 96 PV: 20 YP: 27 FL: 5.3 Gels: 12/17/25 Sol: 9 pH: 9.2 Cl 31000 Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): • Avg BG : 7 Gas Events Depth ( MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection C1 C2 C3 C4I C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVDL TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 100% Cement Last 24 hrs: Operational Summary: Cement 9 5/8" casing to hole, (max gas circ was 16 units, nipple down /up, test ROPE. Calibrations: None Failures: None Daily Cost: El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 2/23/09 Time: Midnight Current Depth (MD): 2890' Current Drilling Current Depth (TVD): Operations: 24 hr Footage (MD): 540' Drilling Parameters ROP: Current: 55.4 Max: 339 Torque: Current: Max: WOB: Current 3.2 Max: 18 RPM: Current: 90.3 Max: 109 PP: Current: 1369 Max: 1769 Lag: Strokes: 1364 Time: 10 Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 2350' MW: 9.9 FV: 61 PV: 13 YP: 23 FL: 5.8 Gels: 7/11/16 Sol: 9 pH: 9.0 Cl 28000 Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: 70 Max: 174 Depth (MD /TVD): 2636' Avg BG : 65 ID Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 0 2350' Connection C1 C2 C3 C41 C4N C51 C5N Gases Wiper Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 4 2500' 47 8273 15 Lithologies: Current: 60% Silt, 30% Clay, 10% VF Sand Last 24 hrs: Silt and Clay, Minor Sand Operational Summary: Finish testing BOPE, pick up BHA, run in the hole to 2350', deill out shoe and 20' of new formation, run FIT, trip gas was zero, drilling out, drill ahead. Calibrations: None Failures: None Daily Cost: • El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 2/24/09 Time: Midnight Current Depth (MD): 4380' Current Drilling Current Depth (TVD): Operations: 24 hr Footage (MD): 1490' Drilling Parameters ROP: Current: 25 Max: 227 Torque: Current: Max: WOB: Current 4.2 Max: 17 RPM: Current: 103 Max: 113 PP: Current: 1747 Max: 2098 Lag: Strokes: 2102 Time: 16 Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 2855' MW: 10.0 FV: 55 PV: 18 YP: 22 FL: 5.3 Gels: 6/10/11 Sol: 8 pH: 9.2 Cl 29000 Ca + +: 140 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: 45 Max: 110 Depth (MD /TVD): 3374' Avg BG : 47 • Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 0 2350' Connection C1 C2 C3 C41 C4N C51 C5N Gases Wiper Gas 85 3631' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N 5 3000' 70 13139 34 6 6 3500' 40 7192 125 7 7 4000' 26 3916 247 91 12 25 5 1 Lithologies: Current: 60% Silt, 40% Clay Last 24 hrs: Silt and Clay Operational Summary: Drill formation to 3631', wiper trip, wiper gas = 85 units, drill ahead. Calibrations: None Failures: None Daily Cost: • El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 2/25/09 Time: Midnight Current Depth (MD): 5907' Current Drilling Current Depth (TVD): 5907' Operations: 24 hr Footage (MD): 1527' Drilling Parameters ROP: Current: 95 Max: 230 Torque: Current: Max: WOB: Current 7.4 Max: 13 RPM: Current: 102 Max: 116 PP: Current: 1867 Max: 2309 Lag: Strokes: 2860 Time: 22 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 4375' MW: 10.0 FV: 53 PV: 17 YP: 23 FL: 5 Gels: 6/11/18 Sol: 9 pH: 9.4 Cl 30000 Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: 85 Max: 861 Depth (MD /TVD): 5671'/5671' Avg BG: 143 • Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 0 2350' Connection C1 C2 C3 C4I C4N C5I C5N Gases Wiper Gas 201 5206'/5206' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 23 5900'/5900' 95 12752 1379 743 496 408 22 5800'/5800' 198 25618 3242 1674 952 632 21 5700'/5700' 327 43098 5163 2117 1078 1341 20 5600'/5600' 87 12026 1179 633 430 269 Lithologies: Current: 70% Silt, 30% Clay Last 24 hrs: Silt and Clay Operational Summary: Drill formation to 5206', wiper trip, wiper gas = 201 units, drill ahead. Calibrations: None Failures: None Daily Cost: • PI EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 2/26/09 Time: Midnight Current Depth (MD): 6597' Current POOH (BHA) Current Depth (TVD): Operations: 24 hr Footage (MD): 690' Drilling Parameters ROP: Current: 0 Max: 154 Torque: Current: Max: WOB: Current 0 Max: 15 RPM: Current: 0 Max: 117 PP: Current: 0 Max: 2702 Lag: Strokes: 3200 Time: 25 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 6597' MW: 11.1 FV: 50 PV: YP: FL: Gels: Sol: pH: Cr Ca + +: MW Change: Depth: 6000' From: 10.1 To: 11.1 Reason: Well Plan Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: 0 Max: 116 Depth (MD /TVD): 6202'/6202' Avg BG : 41 • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas 0 2350' Connection C1 C2 C3 C4I C4N C5I C5N Gases Wiper Gas 201 5206'/5206' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N 28 6500'/6500' 15 1812 199 125 100 122 27 6400'/6400' 20 2367 261 177 127 134 26 6300'/6300' 55 6490 702 550 362 322 Lithologies: Current: 70% Silt, 30% Clay Last 24 hrs: Silt and Clay, Trace of Sand Operational Summary: Drill formation to 6597', circulate the hole clean, pull out of hole for BHA. Calibrations: None Failures: None Daily Cost: • E EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report 0 Report for: Wahl /Springer Date: 2/27/09 Time: Midnight Current Depth (MD): 6998' Current Drilling Current Depth (TVD): 6997' Operations: 24 hr Footage (MD): 401' Drilling Parameters ROP: Current: 25 Max: 130 Torque: Current: Max: WOB: Current 10 Max: 21 RPM: Current: Slide Max: 111 PP: Current: 2364 Max: 2738 Lag: Strokes: 3401 Time: 27 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 11.1 FV: 50 PV: YP: FL: Gels: Sol: pH: Cr Ca + +: MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: 17 Max: 35 Depth (MD /TVD): 6882'/6881' Avg BG : 20 • Gas Events Depth ( MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 55 6597'/6596' Connection 0 C1 C2 C3 C41 C4N C5I C5N Gases Wiper Gas 201 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N 32 6900'/6899' 21 2272 461 273 144 94 31 6800'/6799' 19 2556 225 136 70 51 30 6700'/6699' 14 1727 183 106 66 72 Lithologies: Current: 50% Silt, 40% Clay, 10% Sandstone Last 24 hrs: Silt and Clay, Trace of Sandstone Operational Summary: Pull out of the hole for BHA change, change BHA and trip tp bottom, trip gas was 55 units, drill /slide ahead. Calibrations: None Failures: None Daily Cost: 0 El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 2/28/09 Time: Midnight Current Depth (MD): 7990' Current Drilling Current Depth (TVD): 7989' Operations: 24 hr Footage (MD): 992' Drilling Parameters ROP: Current: 41 Max: 83 Torque: Current: Max: WOB: Current 5.6 Max: 17 RPM: Current: 99 Max: 114 PP: Current: 2545 Max: 2895 Lag: Strokes: 3892 Time: 30 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 7012' MW: 11.1 FV: 47 PV: 20 YP: 23 FL: 5.9 Gels: 5/14/22 Sol: 14 pH: 9.3 Cr - 35000 Ca + +: 140 MW Change: Depth: 7200' From: 11.1 To: 11.3 Reason: Well Plan Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: 26 Max: 154 Depth (MD /TVD): 7250'/7249' Avg BG : 48 • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas Connection C1 C2 C3 C41 C4N C5I C5N Gases Wiper Gas Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N 43 7900'/7899' 27 1198 287 205 100 46 42 7800'/7799' 35 3539 555 447 218 106 41 7700'/7699' 51 4209 972 864 413 212 40 7600'/7599' 43 3576 820 722 313 157 Lithologies: Current: 90% Siltstone, 10% Claystone Last 24 hrs: Silt and Clay, Carbon Shale (HRZ) and Shale Operational Summary: Drill /slide ahead. Calibrations: None Failures: None Daily Cost: • El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 3/01/09 Time: Midnight Current Depth (MD): 8111' Current Circ at 8111' Current Depth (TVD): 8109' Operations: 24 hr Footage (MD): 121' Drilling Parameters ROP: Current: 0 Max: 68 Torque: Current: Max: WOB: Current 0 Max: 10 RPM: Current: 28 Max: 100 PP: Current: 500 Max: 2749 Lag: Strokes: 3953 Time: 31 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 7986' MW: 11.3 FV: 44 PV: 19 YP: 22 FL: 5.9 Gels: 5/12/17 Sol: 15 pH: 9.7 Cr 35000 Ca + +: 120 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: 8111' Volume: Losing Mud Gas Data Ditch Gas: Current: 20 Max: 159 Depth (MD /TVD): 8105'/8104' • Avg BG : 48 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas Connection C1 C2 C3 C4I C4N C51 C5N Gases Wiper Gas 23 t Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N 45 8055'/8054' 25 2318 624 383 218 131 44 8000'/7999' 29 2888 612 434 243 111 Lithologies: Current: 40% Sandstone, 30% Sand, 30% Siltstone Last 24 hrs: Silt and Clay, Ash, Sandstone, Sand Drill /slide ahead to 8043', circulate out samples, drill to 8101', circulate out Operational Summary: samples, drill to 8111', circulate out hole, wiper trip to 6520', wiper gas was 23 units, experience mud losses, spot LCM pill, regain circulation and work hole at 30 SPM. Calibrations: None Failures: None • Daily Cost: E EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report 110 Report for: Wahl /Springer Date: 3/02/09 Time: Midnight Current Depth (MD): 8111' Current Trip in hole with Core #1 Current Depth (TVD): 8109' Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: Max: WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 3953 Time: 31 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 8111' MW: 11.3 FV: 55 PV: 18 YP: 28 FL: 5.7 Gels: 6/14/18 Sol: 15 pH: 9.5 Cl 35000 Ca + +: 120 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: 8111' Volume: 323 bbls Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): • Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 560'/560' 11 Connection C1 C2 C3 C4I C4N C51 C5N Gases Wiper Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 45 8055'/8054' 25 2318 624 383 218 131 Lithologies: Current: 40% Sandstone, 30% Sand, 30% Siltstone Last 24 hrs: Operational Summary: Pull out of the hole with bit #2rr, lay down bit, rig up and test BOPE, pick up core #1, trip in hole to 560', circulate to trip in the hole at midnight. Calibrations: Yes (THA and Chromatograph) Failures: None Daily Cost: • Ell EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report Report for: Wahl /Springer Date: 3/03/09 Time: Midnight Current Depth (MD): 8122' Current Core #1 in progress Current Depth (TVD): 8120' Operations: 24 hr Footage (MD): 11' Drilling Parameters ROP: Current: 12 Max: 23 Torque: Current: Max: WOB: Current 11 Max: 13 RPM: Current: 76 Max: 99 PP: Current: 956 Max: 2627 Lag: Strokes: 3953 Time: 31 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 8111' MW: 11.3 FV: 53 PV: 16 YP: 22 FL: 4.5 Gels: 3/7/11 Sol: 14 pH: 9.5 Cr 33000 Ca + +: 200 MW Change: Depth: None From: To: Reason: ' 244 Mud Loss event: Depth: 8111' Volume: bbls Gas Data Ditch Gas: Current: 136 Max: 224 Depth (MD/TVD): 8119'/8117' • Avg BG : Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 8111'/8109' 215 Connection C1 C2 C3 C41 C4N C51 C5N Gases Wiper Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N 45 8055'/8054' 25 2318 624 383 218 131 Lithologies: Current: 60% Safe Carb (mud add) 30% Large Shale, 10% Silty Sandstone Last 24 hrs: Trip in hole with core #1 to 2450', circulate out 20 units, trip to 5040', circulate out Operational Summary: 112 units of trip gas, trip in tp 8111' and start coring. Mud loss at midnight 244 units. Calibrations: Yes (THA and Chromatograph) @8111' Failures: None • Daily Cost: PI EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Wahl /Springer Date: 3/04/09 Time: Midnight Current Depth (MD): 8216' Current Trip out with Core #1 Current Depth (TVD): 8214' Operations: 24 hr Footage (MD): 94' Drilling Parameters ROP: Current: 0 Max: 15 Torque: Current: Max: WOB: Current 0 Max: 14 RPM: Current: 0 Max: 81 PP: Current: 0 Max: 804 Lag: Strokes: 3994 Time: 50 spm Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 8111' MW: 11.3 FV: 50 PV: 16 YP: 18 FL: 4.3 Gels: 3/10/14 Sol: 14 pH: 9.5 Cl 34000 Ca + +: 200 MW Change: Depth: None From: To: Reason: ' 244 Mud Loss event: Depth: 8111' Volume: bbls Gas Data Ditch Gas: Current: 0 Max: 1245 Depth (MD /TVD): 8202'/8200' • Avg BG : 201 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas SWAB /DTG 8216'/8214' C1 C2 C3 C41 C4N C5I C5N 1820 Wiper Gas Gas Samples (Iso Bags) No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N 1 18 8210'/8208' 45 7946 526 195 73 44 1 17 8200'/8198' 919 125716 9057 3398 1287 766 16 8190'/8188' 60 8155 636 240 93 55 15 8180'/8178' 114 14156 1258 487 197 118 Lithologies: Current: 8126' = ditch cuttings from core = 20% Clay, 40% Sand, 10% Shale, 30% Silt Last 24 hrs: Sand, Silt, Clay, Shale Core from 8111' to 8216', decrease pump rate from 50 spm to 21 spm and pull up Operational Summary: to 8020' down time /swab gas of 1820 units recore3d at bottoms up, work the string and monitor the hole for gains /loss, recycled 118 units noted from swab gas, begin to pull out of the hole and monitor at 7000'. Calibrations: None 410 Failures: None Daily Cost: El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Company Man Date: 3/05/09 Time: Midnight Current Depth (MD): 8216' Current Trip in with new bit Current Depth (TVD): 8214' Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: Max: WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 80 Lag: Strokes: 3994 Time: 50 pm Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 8214' MW: 11.2 FV: 50 PV: 18 YP: 19 FL: 3.8 Gels: 4/8/12 Sol: 14 pH: 9.5 Cl 34000 Ca + +: 160 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth (MD /TVD): • Avg BG : 0 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas SWAB /DTG C1 C2 C3 C41 C4N C5I C5N Wiper Gas Gas Samples (Iso Bags) No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: 8126' = 100% Siltstone Last 24 hrs: Sand, Silt, Operational Summary: Pull out of hole with core #1, lay down core and make up BHA and bit #2RR3, trip into hole and monitor mud system for loss /gain. Calibrations: None Failures: None Daily Cost: • El EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report • Report for: Company Man Date: 3/06/09 Time: Midnight Current Depth (MD): 8425' Current Circulate hole at 8425' Current Depth (TVD): 8424' Operations: (TD) 24 hr Footage (MD): 209' Drilling Parameters ROP: Current: 0 Max: 96 Torque: Current: Max: WOB: Current 0 Max: 11 RPM: Current: 0 Max: 122 PP: Current: 0 Max: 2025 Lag: Strokes: 4100 Time: 40 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 8216' MW: 11.3 FV: 52 PV: 18 YP: 19 FL: 3 Gels: 4/8/13 Sol: 14 pH: 9.5 CI 35000 Ca + +: 140 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 148 Depth (MD /TVD): 8241'/8240' Avg BG : 87 • Gas Events Depth (MD /TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas 8217'/8216' 969 Connection Gas 8260' C1 C2 C3 C41 C4N C5I C5N 1338 Wiper Gas Gas Samples (Iso Bags) No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 8245' = 90% Siltstone, 10% Clay Last 24 hrs: Sand, Silt, Clay Trip in the hole with drilling BHA, trip gas was 969 units, drill to 8260' connection Operational Summary: gas was 1338 units with 270 units of survey gas, drill to 8357' connection gas was 927 units with survey gas of 40 units, drill to 8425' and circulate the hole clean at TD, swab gas of 238 units was noted after bottoms up. Calibrations: None Failures: None 411 Daily Cost: E EPOCH ConocoPhillips Alaska Inc. Grandview #1 Daily Report Report for: Hill/Whitlock Date: 3/07/09 Time: Midnight Current Depth (MD): 8425' Current Pull out of hole with bit Current Depth (TVD): 8424' Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: Max: WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 4100 Time: 40 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 8269' MW: 11.2 FV: 45 PV: 17 YP: 18 FL: 3.4 Gels: 4/8/11 Sol: 15 pH: 9.5 Cr 31000 Ca + +: 80 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 854 Depth (MD /TVD): 8080'/8079' Avg BG : 25 Circ • Gas Events Depth (MD /TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas Connection Gas C1 C2 C3 C41 C4N C5I C5N Wiper Gas 8080'/8078' 854 Gas Samples (Iso Bags) No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 8245' = 90% Siltstone, 10% Clay Last 24 hrs: Sand, Silt, Clay Begin to pull out of the hole with drilling BHA, pump out of the hole, maximum gas Operational Summary: pumping out of the hole was 854 units at 8080', pull out of the hole and begin to handle nuke sources. Calibrations: None Failures: None • Daily Cost: EPOCH