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Home My WebLink About204-254 · . 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. Q.Qi{ - as-4- Well History File Identifier Organizing (done) ~WO-Sided 1111111111111111111 o Rescan Needed 1111111111111111111 RESCAN ¿ 5>'lor Items: \Ø" Greyscale Items: DIGITAL DATA ~iskettes, No.1 o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: Date. ?iaf 07 OVERSIZED (Non-Scannable) ~09S of various kinds: o Other:: o Other: NOTES: BY: ~ Isl mP 1111111111111111111 yVt{J Project Proofing BY: ~ Date b a/D7 I X 30 =.,"jfO + Date &/ð I 07 151 BY: ~ J 7f. = TOTAL PAGES (3 4-8 (Count does not include cover sheet) .M .p Isl 1 I ~ Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: .:) Lf 1 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date:S!3/ 0 7 Stage 1 If NO in stage 1, page(s) discrepancies were found: 1111111111111111111 NO YES 151 mp NO BY: Maria Date: 151 1/11111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • ~. ~ - .. MICRt~FILMED 03/01/2048 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFichelC;vrPgs_Inserts~Articrofilm Marker.~c ~g ~V'~ ( DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042540 Well Name/No. IAPETUS 2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20506-00-00 MD 9300 TVD 7986 Completion Date 3/28/2005 Completion Status P&A Current Status P&A UIC N ~_.--~.._.~----~._.._-_.- REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes ~__M'_'__'___'______ --~_.~ DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens/Neut, DSI/DensMSCT/MDT/SWC (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr e Data Digital Dataset Log Log Run Interval OH/ J2 Med/Frmt Number Name Scale Media No Start Stop CH Received Comments 0 Asc Directional Survey 0 9300 Open 6/15/2005 ~ Directional Survey 0 9300 Open 6/15/2005 ¿ C Lis 13206 I ndu ction/Resistivity 170 9255 Open 6/15/2005 DGR EWR CNT SLD ~ 13154 Sonic 5 Col 2050 9250 Open 6/1/2005 Dipole Sonic Shear Imager/GR/Caliper ~ 13155 See Notes 5 Blu 6 8714 8890 6/1/2005 Chronological Sample Taker/GRlSmall Rings :.J49 13155 See Notes 5 Col 2,3,4 8721 8887 6/1/2005 Mechanical Sidewall ~ Coring tool/GR 13154 Density 5 Col 7900 9289 6/1/2005 Triple Detector Litho- d Density Tool/GR 13155 Formation Tester 5 Col 5 8717 8877 6/1/2005 Modular Formation Dynamic Tester/GRlDrill ~C Pipe Conveyed e, Pds 13155 See Notes 8714 8890 6/1/2005 MDT, MSCT, CST ~C Pds 13154 See Notes 178 9295 Open 6/1/2005 Final LDWG openhole edit tJ-óg 13156 See Notes 2 Col ¡viI) 122 9300 Open 6/1/2005 Formation Log ...cog 13156 See Notes 2 Col 1-vÞ 122 9300 Open 6/1/2005 Formation Log ""'Log 13156 See Notes 2 Col 122 9300 Open 6/1/2005 Drilling Dynamics Log ~og 13156 See Notes 2 Col 122 9300 Open 6/1/2005 LWD Combo Log ~ 13156 See Notes 2 Col 122 9300 Open 6/1/2005 Gas Ratio Log ~ 13156 See Notes 2 Col 122 9300 Open 6/1/2005 Pore Pressure Log ~ C Pdf 13156 Report: Final Well R 0 0 6/1/2005 Final Well Report/Morning Reports/LAS Data/PDF Files/DML Data/Remarks File DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042540 Well Name/No. IAPETUS 2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20506-00-00 MD 9300 TVD 7986 Completion Date 3/28/2005 Completion Status P&A Current Status P&A UIC N #~ ~-~'- See Notes 0 0 Open Core Analysis Results by ~ Core Lab C Exc 13178 See Notes 0 0 Open Core Analysis Report by CoreLab XLS and PDF I Induction/Resistivity 25 Col 221 9300 Open 6/15/2005 ROP DGR EWR ß Induction/Resistivity 25 Col 221 9300 Open 6/15/2005 DGR CTN SLD pt Report: Final Well R 0 0 6/1/2005 Final Well Report/Morning e I. Reports/LAS Data/PDF Files/DML Data/Remarks File vt'D C Exc 13308 See Notes 10/3/2005 Fluid Analysis and PVT Study on MDT Samples ~ 13308 See Notes 10/3/2005 Fluid Analysis and PVT Study on MDT Samples ~ See Notes 0 0 4/25/2006 Geochemical Analytical Results by Conoco Phillips Subsurface Technology ._~-- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Cores and/or Samples are required to be --1 submitted. This record automatically created I from Permit to Drill Module on: 1/5/2005. -.-J ~----~ -.'~._._~.~~- -- ADDITIONAL INFORMATION (þN Chips Received? ~,Sw L ð)N Daily History Received? (}/N c:YN e Well Cored? o-l, Formation Tops Analysis Received? ~'-"---~---'---"-----~--'---~~- -.-"~'..-'-~------.~--~-'---._. ---~-_..~~._-~~-~.~.,------------,-- ---,_._._.__.._---_.._--~"--~.- "-~-~------_..__.._---~--~._-_.~~. ----~_._-----~---,_._--_._- Comments: Compliance Reviewed By: -~-~ -~----.'-- - -'--~- --~~ ~,.__.,---~--~-- ---------- Date:-T Ò ~" ~~ '1 ~-- · . y ConocoPhillips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Celeste Tolley AOGCC 333 w.ih Ave., Suite 100 Anchorage, Alaska 99501 RE: IAPETUS 2 Permit: 204-254 DATE: 3/27/2006 Fedex IAPETUS 2.501032050600 Transmitted: Report _ Geochemical Analysis Results: lapetus-2 Well Samples 2005; ConocoPhillips Subsurface Technology, November 2005 Please check off each item as received, promptly sign and return this transmittals to address below. To a/l data recipients: All data is confidential until State of Alaska designated AOGCC release date. CC: ~eVerlY Bf\u~ns, CPAI Geologist Receipt: c..,. ,VJ.J\.------ Return receipt to: Date: '1 { ~ O(p ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 GIS-Technical Data Management I ConocoPIJ//lips I Anchorage, Alaska I Ph: 907.265.69471 Sandra. D. Lem,ke(mconocophillips. com 1\ Ù 4 -- :Ã ~'- '1 r:I-c '~ iF :ì 'I '! i ,j U fr i? ¡L¡ :==o.,J .e FRANK H. MURKOWSKI, GOVERNOR AIfASIiA. OIL AND GAS CONSERVATION COMMISSION I i , 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 December 29, 2005 Paul Mazzolini ConocoPhillips Alaska Inc. POBox 100360 Anchorage, AK 99510 Re: Location Clearances Kokoda # 1 (PTD 204-253) Kokoda # 5 (PTD 204-259) Iapetus # 2 (PTD 204-254) Dear Mr. Mazzolini: The Alaska Oil and Gas Conservation Commission ("AOGCC") has completed its location clearance inspection of the above reference wells. The AOGCC inspection shows the locations to be in compliance with 20 AAC 25.170, Onshore Location Clearance. The Commission requires no further work on the subject well or location. However, ConocoPhillips Alaska Inc. will remain liable if any problems should occur in the future with these wells. Final location clearance is hereby APPROVED for the above listed wells. · . ~illips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: IAPETUS 2 Permit: 204-254 DATE: 10103/2005 TO: AOGCC Librarian Alaska Oil and Gas Conservation Commission 333 w. ¡th Ave., Suite 100 Anchorage, Alaska 99501 Fedex IAPETUS 2,501032050600 Report and CORaM digital data ~id Analysis on MDT Samples; PVT Study on MDT Samples, Iapetus 1; prepared by Meisong Van, Schlumberger WCP Oilphase-DBR; Report 200500058; 9/2/2005 Transmitted: Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. CC: Beve~prns, C)lAI Ge~~ogift Receipt: ~ CJflVv}, Date: Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 :s ð~N)~ GIS-Technical Data Management 1 ConocoPhi//ips 1 Anchorage, Alaska I Ph: 907265.69471 Sandra. D. Lem, ke@conocophHlips.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~ ~~~2:ViSOr RØf¡iG~s' DATE: August 13, 2005 THRU: FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Location Inspection Conoco Phillips Kokoda #1 PTO 204-253 Kokoda #5 PTO 204-259 vtâpetus #2 PTO 204-254 Saturday. Au~ust 13. 2005; I made a Location Clearance Inspection of the Conoco Phillips exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2. I was accompanied today by Chris Brown (Conoco environmental). The exploratory locations were clean with no evidence of past drilling activity other than a small mound of dirt over the cellar area of the two Kokoda Wells and a slight depression in the cellar area of the Iapetus Well SUMMARY: I made a Location Inspection of the Conoco Phillips abandoned Exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2 I Iapetus #2 2005-0813_location_ Clear _lapetus2_cs.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ...-, r,/ J. P.I. Supervisor . k)ær1Ýf&/fJ5' DATE: August 13, 2005 THRU: FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Location Inspection Conoco Phillips Kokoda #1 PTO 204-253 Kokoda #5 PTO 204-259 Saturday, AUQust 13, 2005; I made a Location Clearance Inspection of the Conoco Phillips exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2. I was accompanied today by Chris Brown (Conoco environmental). The exploratory locations were clean with no evidence of past drilling activity other than a small mound of dirt over the cellar area of the two Kokoda Wells and a slight depression in the cellar area of the Iapetus Well SUMMARY: I made a Location Inspection of the Conoco Phillips abandoned Exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2 2005-0813_Location_ Clear _Ia petus2_cs. doc ~r . ...../ ConocoPhi I lips . TRANSMITTAL CONFIDENTIAL DA TA FR Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Helen Warman AOGCC 333 W. ih Ave., Suite 100 Anchorage, Alaska 99501 RE: IAPETUS 2 Permit: 204-254 DATE: 6/21/2005 Hand carry IAPETUS 2, 501032050600 Schlumberger COROM digital and color image pds files Transmitted: _ Field MDT(Modular Dynamic Tester) DLlS and PDS; MSCT and CST PDS files _ Final LDWG Open Hole Edit Schlumberger log prints _ color log prints (1 each) *triple detector litho-density tool, run 1,3/8/2005 *chronological sample taker/gamma raylsmall rings, run 6,3/14/2005 *mechanical sidewall coring tool, runs 2,3,4, 3/08/2005 *Dipole Sonic Shear Imager/Gamma ray, caliper, run 1, 3/8/2005 * Modular Formation Dynamic testr/GR/Drill pipe conveyed, run 5, 3/1312005 Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date ~~~YIO~Date. [¡{'fílo ~ Return receipt to. U ConocoPhillips Alaska, Inc. 7 ~ 7 U ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 GIS-Technical Data Management 1 ConocoPhillips 1 Anchorage, Alaska I Ph: 907.265.69471 Sandra.D.Lem,ke@conocophillips.com · . ...../ ConocoPhillips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: IAPETUS 2 Permit: 204-254 DATE: 6/15/2005 Hand delivery IAPETUS 2, 501032050600 Sperry Sun L/Hard copy report and floppy disk digital data; Definitive directional survey, 0'-9300' md _vtOROM; LDWG LWD Data; Digital Logging data and color log images* ~Ior log prints (1 each) TO: Helen Warman AOGCC 333 W. ih Ave., Suite 100 Anchorage, Alaska 99501 Transmitted: *ROP/DGR/EWR (MD) 2&5" *DGR/EWR (TVD) 2&5" *DGR/CTN/SLD (MD) 2&5" *DGR/CTN/SLO (TVO) 2&5" Please check oft each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: BeVer1~ns, C,,/!,I GeoloÐI;t ð Receipt -~. CI 11M. Date: Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Ct. Anchorage, AK 99501 GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907265.69471 Sandra.D.Lem,ke@conocoph/llips.com · . ../ ...". ConocoPhi II ips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage ÁK 99510-0360 RE: IAPETUS 2 Permit: 204-254 DATE: 7/14/2005 Fedex TO: Helen Warman AOGCC 333 w.ih Ave., Suite 100 Anchorage, Alaska 99501 Transmitted: } \::J '-f ',- ;( ç L( I-t I-.L IAPETUS 2, 501032050600 Report and CDROM digital data _ Core Labs; Core Analysis Results, Iapetus 2, Colville Delta Field; CL file 57111-105078CP, June 21, 2005 Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date. Proprietary data may R celpt: . ~ Date is- ftJ n rece' t to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 GIS-Technical Data Management 1 ConocoPhi//ips 1 Anchorage, Alaska 1 Ph: 907.265.69471 Sandra.D. Lem, ke@conocophillips.com · . ~illips TRANSMITTAL CONFIDENTIAL DA TA FROM:· Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Helen Warman AOGCC 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 RE: IAPETUS 2 Permit: 204-254 DATE: 6/10/2005 Hand-delivered Transmitted: IAPETUS 2,501032050600 Epocl:vMudlog hardcopy report & CDROM / ~ IAPETUS 2 Epoch Final Well Report Mudlogging Data; includes color Formation 10g(MD & TVD), Drilling Dynamics, LWD Combo, Pore Pressure, and Gas Ration Log; CDROM contains reports, LAS data, PDF color log images and DML data; lithology remarks files, 3/6/2005. Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: Beverly~ur ~f?r;¡::)AI Go~gi~t 1\ /' -< L ~ Receipt: 0 'µ£I.. 'í.f. j ·lúf;l~'¿{.(CÁ..~------Ðate: ¡:{-//6; 0 5 Return rece pt to: / ConocoPhillips Alaska, Inc. { ATTN: S. Lemke, ATO-1486 I¡, . 700 G. Street Anchorage, AK 99501 GIS-Technical Data Management 1 ConocoPh¡llips I Anchorage, Alaska 1 Ph: 907.265.69471 Sandra. D. Lem,ke@conocoph¡llips.com . ConocJPhillips . Paul Mazzolini Exploration Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 April 15,2005 RECEIVED APR 2 7 Z005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: Well Completion Report for Iapetus 2 (204-254 I 305-067) Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits this Well Completion Report for the recent work on the exploration well Iapetus 2. The attachments include a summary of the daily drilling operations, a directional survey, an as-built, a summary of the P&A operations and photos of the site. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, ~?~y~~ P. Mazzolini Exploration Team Leader CPAI Drilling PM/skad OR\G · STATE OF ALASKA . ALAYA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 20AAC 25.105 No. of Completions _ GINJ 0 2. Operator Name: WlNJ 0 WDSPL 0 ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): { Surface: 2448' FNL, 3290' FEL, Sec. 8, T12N, R4E, UM At Top Productive Horizon: 1493' FSL, 2420' FEL, Sec. 7, T12N, R4E, UM Total Depth: 3760' FNL, 2729' FEL, Sec. 7, T12N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface: x- 354532 y- 6000626 Zone- 4 TPI: x- 350101 y- 5999374 Zone- 4 Total Depth: x- 349793 y- 5999408 Zone- 4 18. Directional Survey: Yes 0 NoU 21. Logs Run: GRlReslDens/Neut, DSI/Dens/MSCT/MDT/SWC 22. Suspended 0 20AAC 25.110 Other WAG 0 5. Date Comp., Susp., or Aband.: March 28, 2005 6. Date Spudded: February 25, 2005 7. Date TD Reached: March 6, 2005 r 8. KB Elevation (ft): 42.5' AMSL 9. Plug Back Depth (MD + 1VD): surface 10. Total Depth (MD + 1VD): -' 9300' MD I 7689' TVD ,/ ,/ 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A feet MSL CASING SIZE GRADE B L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH 1VD TOP BOTTOM TOP BOTTOM 28' 115' 28' 115' 28' 2501' 28' 2258' wr. PER FT 63# 40# 16" 9.625" 23. Perforations open to Production (MD + 1VD of Top and Bottom Interval, Size and Number; if none, state "none"): HOLE SIZE 12.25" 24. SIZE nla 1 b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic TestD 12. Permit to Drill Number: ./ 204-254 I 305-067 13. API Number: 50-103-20506-00 14. Well Name and Number: Iapetus 2 15. Field/Pool(s): Exploration 16. Property Designation: ADL 388465 / 390344 / 390350 17. Land Use Permit: n/a 20. Thickness of Permafrost: 1125' MD CEMENTING RECORD AMOUNT PULLED 24" 25 bbls AS I 394 sx AS Lite, 170 sx Class G cement retainer @2410' TUBING RECORD DEPTH SET (MD) PACKER SET 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Plug 1: 8830'-9231' 190 sx Class G Plug 2: 8346'-8722' 170 sx Class G Plug 3: 2360'-2501' 101 sx Class G Plug 4: 45'-300' 117 sx AS 1 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) none 26. Date First Production n/a Date of Test Hours Tested Production for OIL-BBL Test Period --> Calculated OIL-BBL 24-Hour Rate -> Flow Tubing Casing Pressure press. psi 27. GAS-MCF Plugged and Abandoned WATER-BBL CHOKE SIZE IGAS-OIL RATIO GAS-MCF WATER-BBL CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". rEÕ¡;-;1Pli::?~:~1'r~'·-~f Dß,T¿~. ! ..:.L_:?--2 "C~t ¡:-_~~:~J._ j TO BE SENT UNDER SEPARATE COVER Form 10-407 Revised 12/2003 OIL GRAVITY - API (corr) RBDMS 8Ft APR .2 9 2005 RECEIVED APR 2 7 2005 """'\·<''''100 GF 0" {\ G-&s Cani !.nn1l11·'" A\aSka \I Ol ! G I i\I A L Anchorage CONTINUED ON REVERSE 28. GEOLOGIC MARKERS . 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Iapetus #2 HRZ Base HRZ K1 Marker Kuparuk C Sands LCU Top Nechelik Base Nechelik 8268' 8560' 8622' 8714' 8728' 8798' 9130' 6822' 7064' 7116' 7192' 7204' 7262' 7542' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations Directional Survey, P&A Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed N~ () ~aul Mazz !ini, Signature ~ r~ Title: Phone Drillina Team Leader Date ð4/lff /2J:JóS Prepared by 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. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completec 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, showin;¡ the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 29: List all test information. If none, state "None". RECEIVED APR 2 7 2005 Item 27: If no cores taken, indicate "none". Form 10-407 Revised 2/2003 Alaska Oil & Gas Cons. Commission L Anchorage Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon 1 @ppco.com Doyon 19 Start: 2/14/2005 Rig Release: 3/21/2005 Rig Number: 19 Anchorage Spud Date: 2/25/2005 End: 3/21/2005 Group: 2/16/2005 15:00 - 00:00 9.00 MOVE DMOB MOVE Rig down and move to Iapetus 2. 2/17/2005 00:00 - 16:00 16.00 MOVE MOB MOVE Skidded Rig package on to scissor lift for move to Iapetus 2. 16:00 - 00:00 8.00 MOVE MOB MOVE Prep rig modules while waiting on location. 2/18/2005 00:00 - 00:00 24.00 WAlTON OTHR MOVE General Rig maintance while Conductor is being installed on Iapetus 2. 2/19/2005 00:00 - 22:00 22.00 WAlTON OTHR MOVE Waiting on conductor to be installed on Iapetus 2. 22:00 - 23:00 1.00 RIGMNT RGRP MOVE Attempted to move sub. worked on moving system. 23:00 - 00:00 1.00 MOVE MOB MOVE Moving Sub to Iapetus 2. 2/20/2005 00:00 - 11 :00 11.00 MOVE MOB MOVE Moved Sub Module to Cross road and parked. 11 :00 - 12:30 1.50 MOVE RGRP MOVE While preping Motors Module found Hydrolic hose leaking and replaced same. 12:30 - 16:00 3.50 MOVE MOB MOVE Connected Peak trucks to Motors module and to Mudpits module. Moved to Y pulled into NPRA road and found a flat tire on Motors module. 16:00 - 19:00 3.00 MOVE RGRP MOVE Changed and repaired tire on Motors Module while Mudpits continued to move. 19:00 - 20:30 1.50 MOVE RGRP MOVE Started to move Motors module and a 2nd Hydrolic hose leaked and was replaced. 20:30 - 21 :00 0.50 MOVE MOB MOVE Continued moving the Motor and Mudpit modules. 21 :00 - 22:00 1.00 MOVE MOVE MOVE Repaired air line on Peak truck. 22:00 - 00:00 2.00 MOVE MOB MOVE I Continued moving the Motor and Mudpit modules to Iapetus 2 turn off. 2/21/2005 00:00 - 02:00 2.00 MOVE MOB MOVE Moved Mudpit and Motor Modules 4.3 Miles up the Iapetus 2 road. 02:00 - 00:00 22.00 MOVE RGRP MOVE Right front Drive system failed on Mudpit Blocking road and stopping move. Repairing moving system and building Bypass road around stranded module. Installing rebuilt planitary drive. Ice road bypass will be done between 12 (noon) and 6 PM 2/22/05. 2/22/2005 00:00 - 13:45 13.75 MOVE RGRP MOVE Finished Installing rebuilt planitary drive in Pit Complex. Finished Ice road bypass. 13:45 - 14:15 0.50 MOVE MOVE MOVE Move Pit and Motor complexs (Hydralic motor heating up on Pit complex) 14:15 - 19:00 4.75 MOVE RGRP MOVE Remove hydralic drive motor from Pit complex. 19:00 - 00:00 5.00 MOVE MOVE MOVE Finish moving Pit & Motor complexs to Iapetus Pad, Move Sub complex from NPRA Intersection to Iapetus Pad. 2/23/2005 00:00 - 09:30 9.50 MOVE MOB MOVE . Tieded onto and moved Rig transporter to Iapetus 2. 09:30 - 14:00 4.50 MOVE MOB MOVE Moved trucks and cat back to CD 2. Tied onto Ball Mill and Pipe shed. 14:00 - 22:00 I 8.00 MOVE MOB MOVE Moved pipe shed and ball mill. 22:00 - 00:00 2.00 MOVE MOB MOVE Skidding rig package onto sub. Prep camp for move. 2/24/2005 00:00 - 12:00 12.00 MOVE POSN RIGUP Skid rig floor from Scissor complex to Sub complex, Spot Sub complex in position, Skid rig over well, Install cattle shute, Reconnect cable tray, Install service lines. 12:00 - 15:00 3.00 MOVE POSN RIGUP Spot Pipe shed, Motor & Pit complexs, Spot ball mill, Rig all service lines. 15:00 - 20:00 5.00 WELCTL NUND SURFAC Accept rig @ 15:00 hrs 2/24/05, Install FMC landing & Slip lock head, Nipple up diverter system. 20:00 - 00:00 4.00 DRILL RIRD SURFAC Take on mud in pits, Unload drilling tools. Note; Held Pre Spud meeting with crews. 2/25/2005 00:00 - 01 :00 1.00 DRILL OTHR SURFAC Test surface adapter spool to 500 psi, Load pipe shed w/ 5" drill pipe & HWDP. 01 :00 - 02:30 1.50 WELCTL BOPE SURFAC Thaw out 21-1/4" Diverter with steam, Function test same for AOGCC Chuck Scheeve, Held diverter drill with crew. 02:30 - 03:30 1.00 WELCTL NUND SURFAC Install 16" diverter line. 03:30 - 10:45 7.25 DRILL PULD SURFAC PJSM, Pick up 48 jts. 5" drill pipe and 27 jts 5" HWDP and stand back in derrick. 10:45 - 11 :45 1.00 DRILL PULD SURFAC Pick up BHA components to rig floor. i (" í 1\1 Printed: 4/8/2005 11: 1 0:29 AM ~O\1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon1@ppco.com Doyon 19 Start: Rig Release: Rig Number: APR 2 7 2005 Spud Date: ?/~5/2005 "¡~,m GatRuhs. .com~~Y2005 ~J~'Î~005 Anchlf~' 19 2/25/2005 11:45-12:15 0.50 DRILL CIRC SURFAC Fill conductor and check for leaks, Test surface lines to 3300 psi. 12:15 - 12:45 0.50 DRILL SFTY SURFAC Held Pre Spud meeting with new crew. 12:45 - 13:00 0.25 DRILL PULD SURFAC Make up Bit, Float sub, Stab, XIO. 13:00 - 13:15 0.25 DRILL REAM SURFAC Clean out ice plug in conductor fl 48' to 115'. 13:15 - 14:15 1.00 DRILL DRLG SURFAC Spud well @ 13: 15 hrs 2/25/2005, Drill f/115' to 221', OI7K WOB, 50 RPM, 436 gpm @ 490 psi. 14:15 - 14:45 0.50 DRILL CIRC SURFAC Circ hole clean, Calibrate Epoch equip. 14:45 - 15:00 0.25 DRILL TRIP SURFAC POOH, Stand back 2 std's HWDP. 15:00 - 17:30 2.50 DRILL TRIP SURFAC Make up BHA, Program MWD/LWD, RIH & test MWD tools@ 179'. 17:30 - 00:00 6.50 DRILL DRLG SURFAC Drill 12-1/4" hole f/221' to 761' (540') 759' TVD, AST= 2.12 hrs, ART= 2.22 hrs, WOB 8/15K, RPM 70, UP 105K, ON 105K, ROT 108K, TQ on btm 6000 ftIlb, TO off btm 4500 ftIlb, 486 gpm @ 1160 psi, Mud wt 10.0 ppg, Vis 83. 2/26/2005 00:00 - 19:00 19.00 DRILL DRLG SURFAC Drill 12-1/4" hole f/761' to 2511' (1750') 2267' TVD, AST= 3.43 hrs, ART= 10.05 hrs, WOB 20/35K, RPM 70, UP 145K, ON 130K, ROT 137K, TQ on btm 8000 ftIlb, TO off btm 6500 ftIlb, 650 gpm @ 1940 psi, Mud wt 10.0 ppg, Vis 71. 19:00 - 20:15 1.25 DRILL CIRC SURFAC Pump Hi-vis weighted sweep around (10-20% increase in cuttings) at i rate of 650 gpm @ 1850 psi, Circ hole clean with total of 3 time btm's I up, Stand back 1 stand every 30 min to 2227'. 20:15 - 00:00 3.75 DRILL WIPR SURFAC Back ream out of hole f/2227 to 633', Start back reaming at rate of 650 gpm w/ 70 RPM and slow rate down 50 gpm every 5 stands to 500 gpm. Back reamed at 25 to 30 ftImin, No noticeable packing off, Had large amount of cuttings while back reaming, Slowed back reaming speed down to 3 to 5 ftImin for last 2 stands and circ 2 times btm's up, Clay cuttings slowed after 1 btm's up but the Sand and Small size gravel did not slow very much, Shut down pumps and pull 1 stand to 539'. 2/27/2005 00:00 - 01 :30 1.50 DRILL WIPR SURFAC RIH f/539' to 1760', Washed thru bridges @ 620',860',1245'. 01 :30 - 03:30 2.00 DRILL WIPR SURFAC Wash & Ream at rate 465 gpm @ 1200 psi wI 40 RPM f/1760' to 2511' ( Tight spot @ 2110'). 03:30 - 05:30 2.00 DRILL CIRC SURFAC Circ & Raise vis f/ 75 cc to 150 cc, Pump Hi-vis weighted sweep at rate of 600 gpm @ 1850 psi w/ 70 RPM. 05:30 - 06:00 0.50 DRILL TRIP SURFAC Attempt to POOH on elevators f/2511' to 2375' (Tight). 06:00 - 07:30 1.50 DRILL TRIP SURFAC Pump out of hole f/ 2375' to 1750' at rate of 450 gpm @ 1200 psi, Packed off @ 1750'. 07:30 - 08:00 0.50 DRILL CIRC SURFAC Circ btm's up at rate of 450 gpm @ 1160 psi wI 70 RPM. 08:00 - 10:00 2.00 DRILL TRIP SURFAC Back ream out of hole f/1750 to 990' at rate of 450 gpm @ 1100 psi w/ 70 RPM. 10:00 -12:45 2.75 DRILL TRIP SURFAC RIH to 1370' (Hit bridge), Wash & Ream f/1370' to 2511' (No fill) at rate of 450 gpm @ 1210 psi wI 70 RPM. 12:45 - 14:45 2.00 DRILL CIRC SURFAC Pump Hi-vis weighted sweep, Circ hole clean at rate of 600 gpm @ 1890 psi w/ 70 RPM & Raise vis to 250 cc. 14:45 - 15:45 1.00 DRILL TRIP I SURFAC Attempt to POOH on elevators f/ 2511 to 2002' (Hole tight) 15:45 - 18:00 2.25 DRILL TRIP SURFAC Pump out of hole at rate of 200 gpm w/ 50 RPM fl 2002' to 1842' (Tight spots @ 2002', 1968', 1960', 1933', 1906' 1842'), Continue to pump out of hole to 1371' with out rotation. 18:00 - 19:15 1.25 DRILL TRIP SURFAC POOH on elevators f/1371' to 179' (BHA) 19:15 - 21 :00 1.75 DRILL PULD SURFAC Set back DC's, Down load MWD, Lay down BHA. 21 :00 - 22:30 1.50 CASE RURD SURFAC Rig to run 9-5/8" casing, PJSM with all personnel. 22:30 - 00:00 1.50 CASE RUNC SURFAC Run 9-5/8" Weatherford Model 303 Shoe, 2 joints 9-5/8", 40.0#, L-80, BTC, Weatherford Model 402 Float collar, Break circ thru same & check that foats function, RIH w/9-5/8" csg to 314'. Printed: 4/8/2005 11:10:29AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon 1 @ppco.com Doyon 19 ï Start: 2/N~Meil & fà.~~teö~@~~; Rig Release: 3/21/2005 ~w~~e Rig Number: 19 2/28/2005 00:00 - 01 :30 1.50 CASE RUNC SURFAC RIH w/9-5/8", 40#, L-80, BTC csg to 1233' (Washed thru minor bridge @ 356'), Running speed 40 to 45 ftlmin, Very good displacement & returns. 01 :30 - 02:00 0.50 CASE CIRC SURFAC Break circ & circ btm's up while running 2 jts slowly f/1233' to 1272' at rate of 4 bpm @ 300 psi. 02:00 - 03:00 1.00 CASE RUNC SURFAC Continue RIH w/ 9-5/8" csg to 2040' at 40 to 45 ftlmin. with very good displacement & returns, Began taking weight @ 2040'. 03:00 - 06:30 3.50 CASE RUNC SURFAC Wash & work pipe f/ 2040' to 2464' at rate of 5 bpm @ 450 psi, Make up FMC Gen V Mandrel Hanger and wash & land hanger on landing ring w/ Shoe @ 2501.27' & Float collar @ 2420.35' (Total of 64 jts 9-5/8" csg in hole). 06:30 - 07:30 1.00 CEMENT PULD SURFAC Lay down Frank's fill up tool and make up Dowell cmt head. 07:30 - 09:30 2.00 CEMENTCIRC SURFAC Circ & condition mud for cmt. 09:30 - 12:00 2.50 CEMENT PUMP SURFAC PJSM, Cement 9-5/8" csg as follows; Pumped 40 bbls biozan water wI , nut plug - 6 bpm @ 250 psi w/ rig pump, Swith to Dowell, Pump 5 bbls CW100, Test lines to 2700 psi, Pumped 45 bbls CW100. Dropped plug, Mixed & pumped 50 bbls MudPUSH XL spacer @ 10.5 ppg - 4.5 bpm @ 250 psi. Mixed & pumped 312 bbls of Lead slurry (ASL "G" wI 30% 053,0.6% 046,1.5% 079,1.5% S001, 43.1% 0124, 9% BWOW 044, 0.5% 065) @ 10.7 ppg -7.5 bpm @ 150-350 psi, Swith to Tail slurry ( "G" w/ 0.2% 046, 0.3% 065, 2% S001) @ 12 ppg - 5.2 bpm @ 325-500 psi, Dropped top plug & pumped 20 bbls water wI Dowell, Swithed to rig pumps - Displaced w/1 0 ppg KCL Klayguard mud @ 6.5 bpm 370-650 psi for first 158 bbls - slowed to 3 bpm @ 500 psi for last 5 bbls - Bumped plug w/1 040 psi - CIP @ 12:00 hrs, Floats held OK, Had full returns thru out job wI 78 bbls cement returns to surface, Reciprocated pipe until start of Tail slurry, Landed hanger on landing ring. 12:00 - 13:00 1.00 CEMENT PULD SURFAC Rig down cmt head, Lay down landing jt. 13:00 - 14:00 1.00 WELCTL NUND SURFAC Flush & drain Diverter system, Nipple down diverter line. 14:00 - 16:30 2.50 WELCTL NUND SURFAC PJSM, Nipple down & clean Diverter system. 16:30 - 17:30 1.00 WELCTL NUND SURFAC Install FMC Gen V well head, Test same to 1000 psi. 17:30 - 19:45 2.25 WELCTL NUND SURFAC Install & Nipple up BOPE. 19:45 - 00:00 4.25 WELCTL BOPE SURFAC I Test all BOPE to 250 low & 5000 psi high, Hydril to 250 low & 3500 I high, Witnessed by AOGCC Chuck Scheve. 3/1/2005 00:00 - 01 :30 1.50 WELCTL BOPE SURFAC Cont. BOPE test - Tested manual choke & kill valves, lower pipe rams, 01 :30 - 02:30 1.00 DRILL OTHR SURFAC I floor TIW & dart valves, & blind rams to 250 psi & 5000 psi Blow down choke & kill lines - Install wear bushing - PU drilling bails & 5" DP elevators 02:30 - 03:30 1.00 DRILL PULD SURFAC PJSM - LD NM flex DC's & 2 stds. 5" DP 03:30 - 07:00 3.50 DRILL PULD SURFAC Change over to 4" handling equipment - PU 72 jts 4" DP f/ pipe shed to 2290' 07:00 - 07:30 0.50 DRILL CIRC SURFAC Circ pipe volume 6 BPM @250 psi - pump dry job - blow down TO 07:30 - 11 :30 4.00 DRILL PULD SURFAC POOH & std. back 24 stds in derrick - PU 72 jts. 4" DP f/ pipe shed to 2290' 11 :30 - 12:00 0.50 DRILL CIRC SURFAC Circ pipe volume 8 BPM @ 330 psi - pump dry job - blow down TO 12:00 - 14:45 2.75 DRILL PULD SURFAC POOH & std. back 24 stds in derrick - PU 72 jts. 4" dp fl pipe shed to I 2290' 14:45 - 15:15 0.50 DRILL CIRC ! SURFAC Circ pipe volume 8 BPM @ 370 psi - pump dry job - blow down TO 15:15 - 17:15 2.00 DRILL ,PULD SURFAC POOH & std. back 24 stds in derrick - PU 36 jts. 4" dp fl pipe shed to 1145'. 17:15 - 17:30 0.25 DRILL CIRC SURFAC Break circ, Pump dry job, Blow down TO. 17:30 - 18:15 0.75 DRILL PULD SURFAC POOH & Stand back 12 std's 4" drill pipe. 18:15 - 22:00 3.75 DRILL PULD SURFAC Make up BHA #2, Bit, Motor, Float sub, Stab, MWD tools, Install pulser, Printed: 4/812005 11:10:29AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon 1 @ppco.com Doyon 19 Alaska~ ÐuEÍiW2$7ŒJftðtÏ6sion Start: 2/14/2005 End: Anchoralii1/2005 Rig Release: 3/21/2005 Group: Rig Number: 19 3/1/2005 18:15 - 22:00 3.75 DRILL PULD SURFAC Program MWD tools, Load sources, Make up DC's, Surface test Tools, Blow down top drive. 22:00 - 23:30 1.50 DRILL TRIP SURFAC RIH wI HWDP, Jars, Ghost reamers to 2365'. 23:30 - 00:00 0.50 DRILL CIRC SURFAC Circ btm's up at rate of 465 gpm @ 1100 psi. 3/2/2005 00:00 - 02:00 2.00 RIGMNT RSRV SURFAC PJSM - Slip & cut 60' - Service TO & adjust brakes 02:00 - 02:30 0.50 DRILL CIRC SURFAC Circulate btms. up for csg test 550 GPM @ 1420 psi w/40 rpm 02:30 - 03:30 1.00 DRILL DEQT SURFAC RU & test 9 5/8" csg to 3500 psi for 30 mins. 03:30 - 04:00 0.50 WELCTL SFTY SURFAC Held Table Top stripping drill- Well kill drill- blow down TO 04:00 - 05:30 1.50 CEMENT DSHO SURFAC Wash down f/2397' to 2420' (tagged up) Clean out cmt & float equipment - clean out rat hole to 2511' - drill 20' new hole to 2531' 05:30 - 06:00 0.50 DRILL CIRC SURFAC Circulate & condition mud for LOT / FIT - 500 gpm @ 1111230 psi wI 60 rpm 06:00 - 07:00 1.00 DRILL FIT SURFAC RU & perform FIT to 16.4 ppg EMW wI 760 psi surface pressure w/9.9 ppg mud @ 2258' TVD - RD 07:00 - 12:00 5.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/2531' to 3000' MD - 2662' TVD ADT - 3.05 hrs.= ART - 2.62 hrs. AST - .43 hrs. WOB 5/10 k GPM 650 @ 2300 psi RPM 70 String wt. PU 145 SO 128 Rot 135 Torque onloff btm. - 7500nOOO ft. Ibs ECD - 11.8 to 12.3 Bumped mud wt. to 10.5 ppg while drilling ahead 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/3000' to 4172' MD, 3589' TVD (1172'), ART= 7.04 I hrs. AST= 1.27 hrs., WOB 5/15K, RPM 40/70, 651 gpm @ 2840 psi, UP 165K, ON 135K, ROT 152K, Torque on btm 9,000 ftllb I Off btm 7700 ftllb, Mud weight 10.5 ppg, vis 48 ce, ECD's ranging f/12.0 to 12.5 ppg, Ave. BGG 15 to 20 units, Max 129 units. 3/3/2005 00:00 - 07:00 7.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/4172' to 5032' MD - 4264' TVD ADT - 4.3 hrs. ART - 3.9 hrs. AST - .4 hrs. WOB 10/20 k RPM 80 GPM 650 @ 3420 psi String wt. PU 175 SO 140 Rot 155 I Torque on/off btm - 8000n5000 ft. Ibs. I ECD - 11.87 to 12.75 07:00 - 08:00 1.00 DRILL ICIRC INTRM1 Circ btms. up - Pump hi vis wieghted sweep - 650 gpm @ 3120 psi wI i 100 rpm - Observed large amount of cuttings @ shakers with sweep to surface 08:00 - 09:30 1.50 DRILL ITRIP INTRM1 POOH wI pump f/5032' to 4555' - 650 gpm @ 3050 psi w/1 00 rpm - i observed large amount of cuttings @ shakers while pumping out 09:30 - 10:00 0.50 DRILL ICIRC INTRM1 Pump hi-vis weighted sweep - 650 gpm @ 3000 psi wI 100 rpm - once i again observed large amount of cuttings @ shakers with sweep to I I surface - circ clean - 10:00 - 12:00 2.00 DRILL TRIP INTRM1 Flow check well (static) - POOH on TT f/ 4555' to 2933' - hole taking proper fill - no excessive drag 12:00 - 12:30 0.50 DRILL TRIP INTRM1 Continue POOH on TT f/ 2933' to 2456' - Monitor well (static) * Held 12:30 - 13:45 1.25 DRILL TRIP INTRM1 RIH f/2456; to 4941' - hole in good condition - Break circulation 13:45 - 14:00 0.25 DRILL REAM INTRM1 Precautionary wash & ream f/ 4941' to 5032' ( no fill) 14:00 - 14:30 0.50 DRILL CIRC INTRM1 Pump hi-vis weighted sweep & circulate btms up @ 650 gpm wI 80 rpm - Observed good results from sweep @ shakers w/ btms up 14:30 - 00:00 9.50 DRILL DRLG INTRM1 Drill 8 1/2" hole fl 5032' to 5988' MD, 5000' TVD (956'), ART= 5.8 hrs. AST= 1.57 hrs., WOB 15/20K, RPM 90, 651 gpm @ 3940 psi, UP 190K, ON 145K, ROT 165K, Torque on btm 10,000 ftllb I Off btm 9000 ftllb, Mud weight 10.5 to 10.6 ppg, vis 50 ce, ECD's ranging f/12.2 to 12.6 ppg, Ave. BGG 20 units, Max 182 units. 3/4/2005 00:00 -12:00 12.00. DRILL DRLG INTRM1 Drill 8 1/2" hole f/5988' to 6872' MD 5717 TVD Printed: 4/812005 11: 1 0:29 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon 1 @ppco.com Doyon 19 APR 2 7 2005 Spud Date: 2/25/2005 Start: 2/14/Jtiø5ka Oi/l&Oas Cons. :t'~Q9ffin Rig Release: 3/21/2005 GWMfhorage Rig Number: 19 3/4/2005 00:00 - 12:00 12:00 - 00:00 3/5/2005 00:00 - 03:00 12.00 DRILL DRLG INTRM1 ADT 10.04 hrs. = ART - 7.71 hrs. AST - 2.33 hrs. WOB 12/17 k RPM 90 GPM 600 @ 4040 psi String wt. PU 202 SO 155 Rot 172 Torque on/off btm - 10500/9000 ft. Ibs. ECD - 12.2 to 12. 7 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/6,872' to 7,419' MD, 6,151' TVD (547'), ART= 3.81 hrs. AST= 1.88 hrs., WOB 15/20K, RPM 90, 600 gpm @ 4030 psi, UP 210K, ON 155K, ROT 180K, Torque on btm 11,500 ftIlb I Off btm 9,500 ftIlb, Mud weight 10.5 to 10.6 ppg, vis 50 cc, ECD's ranging f/11. 7 to 12.6 ppg, Ave. BGG 20 units, Max 34 units. 3.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f17419' to 7610' MO 6302' TVO WOB 10/17 k RPM 90 GPM 592 @ 4030 psi String wt. PU 215 SO 160 Rot 188 Torque onloff btm. - 11,000/9500 ft. Ibs. ECD -11.9 Circulate for wiper trip - 600 gpm @ 4000 psi w/1 00 rpm - std back 1 std to 7514' Circulate hi-vis weigthed sweep - 600 gpm @ 4000 psi w/1 00 rpm - std. back 1 std. to 7419' Flow check (static) - POOH on TT fl 7419' to 6942' - tight hole @ 6942' MU top drive - POOH w/ pump f/6942' to 6560' w/452 gpm @ 1460 psi wI 100 rpm (std. back 4 stds) Flow check (static) - POOH on TT f/6560' to 4940' - no tight hole & hole took proper fill - Flow check (static) 03:00 - 04:00 1.00 DRILL CIRC INTRM1 04:00 - 05:00 1.00 DRILL CIRC INTRM1 05:00 - 05:30 0.50 DRILL TRIP INTRM1 05:30 - 07:00 1.50 DRILL TRIP INTRM1 07:00 - 08:30 1.50 DRILL TRIP INTRM1 08:30 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 00:00 * Note: Changed liners in mud pumps to 5 1/2" during trip 1.00 DRILL TRIP INTRM1 RIH f/4940' to 7514 1.00 DRILL REAM INTRM1 Wash down F/7514' to 7610' - Circulate btms up - 580 gpm @ 3980 psi w/ 60 rpm 1.50 DRILL DRLG INTRM1 Drill 8 1/2" hole f/761 0' to 7640' MD 6325' TVO WOB 10/20 k RPM - sliding GPM 580 @4200 psi String wt. PU 230 SO 155 Rot 188 Torque on/off btm. - 10,500/10,000 ft. Ibs ECD - 11.4 to 11.9 ADT last 12 hrs. - 3.35 = ART 1.45 hrs AST 1.9 hrs. 12.00 DRILL DRLG IINTRM1 Drill 8 1/2" hole f/7,640' to 8,182' MD, 6,743' TVD (542'), ART= 3.68 hrs. AST= 3.27 hrs., WOB 15/20K, RPM 80, 600 gpm @ 4350 psi, UP 220K, ON 165K, ROT 195K, Torque on btm 11,500 ftIlb I Off btm 9,500 ftIlb, Mud weight 10.5 to 10.6 ppg, vis 50 cc, ECD's ranging f/11.4 to 11.7 ppg, Ave. BGG 20 units, Max 110 units. Note; Top of HRZ @ 7,952' MD /6,569' TVD. Drill 8 1/2" hole f/8182' to 8686' MD (64' below K-1 marker) Circulate btms up - 530 gpm @ 3660 psi - std back 1 std. - Observed no signs of excseeive shale f/ HRZ - hole in good condition Blow down TO & mud line - Change out bumper hose in mud pits - test line to 4500 psi Drill 8 1/2" hole f/ 8686' to 8778' MD 7246' TVD ADT - 8.55 hrs. = ART - 6.54 hrs. AST - 2.01 hrs. WOB 8/17 k RPM 90 GPM 550 @ 4200 psi String wt. PU 250 SO 165 Rot 200 Torque onloff btm - 12,000/10,000 ft.lbs. ECD - 11.4 to 11.6 3/6/2005 00:00 - 07:30 7.50 DRILL DRLG INTRM1 07:30 - 08:30 1.00 DRILL CIRC INTRM1 I 08:30 - 09:00 0.50 RIGMNT RGRP INTRM1 09:00 - 12:00 3.00 DRILL DRLG INTRM1 """'\, '~'''. Printed: 4/812005 11: 1 0:29 AM ~~\J^f Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon1@ppco.com Doyon 19 Start: Rig Release: Rig Number: APR 2 7 200 .41j1Ur~J1.1 & ~pud Date.: 2/25/2005 2/1~72'OU'5"1 ~t~ons. l;O~~OO5 3/21/2005 AÐ~ptge 19 3/6/2005 09:00 - 12:00 3.00 DRILL DRLG INTRM1 12:00 - 23:00 11.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/8,778' to 9,300' MD, 7,689' TVD (522') T.D., ART= 9.13 hrs. AST= 0 hrs., WOB 15/20K, RPM 80, 575 gpm @ 4420 psi, UP 250K, ON 175K, ROT 215K, Torque on btm 12,00 ftllb I Off btm 11,500 ftllb, Mud weight 10.5 to 10.6 ppg, vis 50 ce, ECD's ranging f/ 11.4 to 11.5 ppg, Ave. BGG 35 units, Max 182 units. 23:00 - 00:00 1.00 DRILL CIRC INTRM1 Circulate btm's up at rate of 570 gpm @ 4250 psi w/1 00 RPM. 3m2005 00:00 - 01 :30 1.50 DRILL CIRC INTRM1 Circ hi vis weighted sweep - finsih circulating 3X btms up 574 gpm @ 4200 psi w/1 00 rpm - std back stds to 9040' 01 :30 - 03:30 2.00 DRILL WIPR INTRM1 Flow check (static) - Wiper trip on TT f/ 9040' to 6850' - hole in good condition - proper fill - flow check (static) 03:30 - 05:00 1.50 DRILL TRIP INTRM1 RIH to 9230' - wash down to 9300' 05:00 - 07:30 2.50 DRILL CIRC INTRM1 Circulate btms up 570 gpm @ 4200 psi w/1 00 rpm (max. trip gas 175 units) Pump hi vis sweep & circulate 2X btms up - same pump rate - std back stds. to 9040' - shakers were clean 07:30 - 12:00 4.50 DRILL TRIP INTRM1 Flow check (static) - POOH on TT f/9040' to 3314' - hole in good shape - no excessive drag - hole took porper fill * pump dry job @ 8090', Drop 2.25" Rabbit. 12:00 - 12:30 0.50 DRILL TRIP INTRM1 Continue to POOH on TT f/ 3314' to 2570', On last stand had 2 bbl gain, RIH to 2646'. 12:30 - 13:00 0.50 DRILL CIRC INTRM1 Establish circ at rate of 500 gpm @ 2200 psi, Return flow dropped off f/ 21 % to 4%, lost 300 psi pump pressure- lost 15 bbls mud. 13:00 - 14:00 1.00 WELCTL OBSV INTRM1 Monitor well - Flowing, Shut in well and observe pressures - SIDPP . dropped f/130 psi to 80 psi in 30 min., SDCP 80 psi constant for 30 I min. 14:00 - 14:30 0.50 WELCTL OBSV INTRM1 Bleed off well- Slight flow, Pull to 2614', Install Safety valve & IBOP, Blow down top drive. 14:30 -17:30 3.00 DRILL TRIP INTRM1 RIH slow to 4555', Flow check well- Static. 17:30 - 00:00 6.50 DRILL TRIP INTRM1 Fill pipe, Stage rate up to 450 gpm & wash down to 4650' - started lossing +1- 1 bpm @ 450 gpm, Slowed rate down to 250 gpm @ 950 psi w/ very little losses, Back ream out of hole to shoe @ 2501' at rate of 250 to 280 gpm @ 950 psi wI 70 RPM at 20 ftlmin., Added 3 to 5 ppb Mix II fine & med. to mud f/4555' to 2501' (Stopped mix LCM at shoe), Mud weight coming out 10.8 to 10.9 ppg - Lowered mud weight f/10.8 to 10.5 ppg while back reaming, Lost total of 125 bbls mud, Ave BGG 20 units, Max gas 350 units 3/8/2005 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 Flow check (static) Circulate & condition 300 gpm @ 810 psi w/50 rpm - lost 2 bbls in 30 mins. - flow check (static) 01 :00 - 03:00 2.00 DRILL TRIP INTRM1 Blow down TO - Change over to 5" handling equipment - POOH on TT to 1000' - flow check (static) 03:00 - 04:30 1.50 DRILL PULD INTRM1 LD ghost reamers - std back HWDP - LD jars ( 2.25 drift stuck in jars) 04:30 - 07:30 3.00 DRILL PULD INTRM1 Std. back NMflex DC's - Remove RA source f/ MWD - down load MWD - LD MWD, FS, motor & bit ( found 1 broke cutter & 1 jet plugged - found spring for flapper on float broken) 07:30 - 09:00 1.50 LOG PULD PROD Clean up rig floor - Held PJSM w/ Loggers - RU loggers - MU logging tools for run #1 ( load RA rource) 09:00 - 12:30 3.50 LOG ELOG PROD Ran log #1 DSI - Density - Calip 12:30 - 13:30 1.00 LOG PULD PROD I Remove RA source - LD logging tools from run #1 13:30 - 14:00 0.50 LOG PULD PROD MU tools for log run #2 - MSCT 14:00 - 22:00 8.00 LOG ELOG PROD Ran log #2 - MSCT * Hole static during logging operations 22:00 - 00:00 2.00 LOG PULD . PROD Recover core samples - LD tools f/ run #2 I I Printed: 4/812005 11:10:29AM 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: Rig Release: Rig Number: Alaska éip&<G~ßüni(:uö'~ion 2/14/2005 EndAnchora~21/2005 3/21/2005 Group: 19 3/912005 00:00 - 00:30 0.50 LOG RURD PROD RD Schlumberger equipment 00:30 - 05:30 5.00 WELCTL BOPE PROD Pull waer bushing and set test plug. Test annular preventor 250/3500 psi - test rams, choke, kill, manifold and surface safety valves 250/5000 psi. Install wear bushing - blow down lines 05:30 - 08:30 3.00 WAlTON WOW PROD Ice roads in Phase III conditions - W.O.W. 08:30 - 09:30 1.00 WAlTON WOW PROD W.O.w. Held safety meeting with rig team 09:30 - 10:00 0.50 LOG PULD PROD MU tools for log run #3 - MSCT 10:00 - 14:00 4.00 LOG OTHR PROD RIH with MSCT tool string - attempted to obtain cores, tool jammed. POH, found cuttings packed off around coring motor, no recovery. 14:00 - 14:30 0.50 LOG OTHR PROD Cleaned and function test MSCT 14:30 - 20:00 5.50 LOG ELOG PROD Ran MSCT - cut 23 -tool jamed POOH 20:00 - 22:30 2.50 LOG PULD PROD Recovered core samples (15 of 23) LD tools & RD SWS 22:30 - 00:00 1.50 WAlTON WOW PROD Monitor well - WOW 3/10/2005 00:00 - 08:30 8.50 WAlTON WOW PROD Ice roeads in Phase III condition - W.O.W. - monitor well. 08:30 - 08:45 0.25 LOG SFTY PROD PJSM - Hazard analysis prior to MU BHA. 08:45 - 12:30 3.75 LOG TRIP PROD MU BHA #3-8 1/2" clean out assembly - RIH - PU 30 joints of 4" drill pipe to 2450' 12:30 - 13:45 1.25 LOG CIRC PROD Stage pumps up to 350 gpm / 670 psi - circ and cond mud - strip LCM from returns - monitor well, static. - Blow down Top Drive. 13:45 - 00:00 10.25 WAlTON WOW PROD W.O.W. Ice roads closed - Phase III weather conditions 3/11/2005 00:00 - 10:45 10.75 WAlTON WOW PROD W.O.W. Phase III weather conditions 10:45 - 11 :45 1.00 LOG CIRC PROD Stage pumps up to 350 gpm /650 psi - circ and condition mud prior to continuing wiper trip - monitor well, static. Blow down Top Drive. 11 :45 - 13:00 1.25 LOG TRIP PROD RIH to 3888' - wiped tight spot@ 3300'. 13:00 - 14:00 1.00 LOG CIRC PROD Staged pumps up to 360 gpm / fcp 1080 psi /110 rpm - circ and cond mud - max BGG 275 units, final 25 units - monitor well, static. Blow down Top Drive. PUW 155K SOW 133K 14:00 - 15:00 1.00 LOG TRIP PROD RIH from 3888' to 5200' - wiped tight spots from 5200' to 5225' 15:00 - 16:15 1 .25 LOG CIRC PROD MU top Drive and wash and ream from 5225' to 5320'- 250 gpm / 890 psi / 50 rpm - staged pumps up to 420 gpm / fcp 1700 psi I 75 rpm and circ hole clean - max BBG 160 units, final 1 0 units - monitor well, static. Blow down Top Drive. PUW 177K SOW 145K 16:15 - 17:45 1.50 LOG TRIP PROD RIH from 5320' to 7229' - wiped tight hole from 6600' to 6630'. 17:45 - 19:30 1.75 LOG CIRC PROD Break circulation - circulate btms up + - 336 gpm @ 1400 psi 19:30 - 21:30 2.00 LOG TRIP PROD RIH f/ 7229' to 9237' - flow check (static) 21 :30 - 22:00 0.50 LOG CIRC PROD Establish circ - Wash & ream fl 9237' to 9287' (13' fill) 175 gpm @ 930 psi - Attempt to clean out fill - hole tried to pack off - stayed above fill 22:00 - 00:00 2.00 LOG CIRC PROD Circulate & condition for logging - stage pumps up to 450 gpm @ 2960 psi w/ 80 rpm - Circulate 2.5 X btms. up ( max. gas on btms up 760 units) String wt. PU 260 SO 160 Rot 200 - No losses 3/12/2005 00:00-01:15 1.25 LOG TRIP PROD Pumped 40 bbl high vis sweep and circulated hole clean - 450 gpm / 2900 psi / 80 rpm - Flow check well, static. 01 :15 - 02:45 1.50 LOG TRIP PROD Backream from 9139' to 8660' - 420 gpm I 2300 psi / 80 rpm Hole began pulling tight and packing off from 8690' to 8660' 02:45 - 03:30 0.75 LOG TRIP PROD RIH to 8755' - wash down to 8851' - 210 gpm 1780 psi / 80 rpm Backream from 8851' to 8660' - 420 gpm /2240 psi 180 rpm - no problems. 03:30 - 04:45 1.25 LOG TRIP PROD Flow check well, static. Blow down Top Drive - POOH on trip tank from 8660' to 7706' 04:45 - 05:00 0.25 LOG TRIP PROD Flow check well, static. Pump dry job. 05:00 - 10:00 5.00 LOG TRIP PROD POOH from 7706' to 1028' - hole in good condition - took proper hole fill. Printed: 4/8/2005 11:10:29AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon 1 @ppco.com Doyon 19 Start: Rig Release: Rig Number: Alaska Oil & Gæp¡ø~~~~~05 2/14/2005 Anamtsge 3/21/2005 3/21/2005 Group: 19 3/12/2005 05:00 - 10:00 5.00 LOG TRIP PROD Flow checked well at shoe and BHA, static. 10:00 - 11 :30 1.50 LOG TRIP PROD POOH - stand back hwdp and flex collars - laid down jars, ghost reamers, subs and bit. Clear tools from rig floor. 11 :30 - 11 :45 0.25 LOG SFTY PROD Held PJSM with Schlumberger and crew. 11 :45 - 14:00 2.25 LOG RURD PROD Rig up Schlumberger - MU and test MDT tool string 14:00 - 16:30 2.50 LOG DLOG PROD RIH with MDT on 4" drill pipe to 2496' - Fill pipe & circulate @ 5 I bbls/min. @ 220 psi 16:30 - 17:30 1.00 RIGMNT RGRP PROD Trouble breaking out TD - changed out saver sub & changed out 1 jt. DP 17:30 - 00:00 6.50 LOG DLOG PROD RIH w/ MDT on 4" DP f/ 2496' to 6321' - Circulate 5 mins. every 5 stds. ran as per Schlumberger 3/13/2005 00:00 - 03:30 3.50 LOG DLOG PROD RIH w/ MDT on 4" DP f/6321' to 8384'- Circulate 5 mins. every 5 stds. ran as per Schlumberger 03:30 - 06:00 2.50 LOG RURD PROD Install side entry sub and pump down wet latch to docking head - 4.5 bpm / 850 psi 06:00 - 12:15 6.25 LOG OTHR PROD RIH - log as directed - 10 pressure sets - 2 fluid sets 12:15 - 13:45 1.50 LOG DLOG PROD POOH from 8903' to 8384' - worked through tight hole 8744'-8740', 10K over at tool. 13:45 -15:30 1.75 LOG RURD PROD Pulled wet latch free with 6500 ftIlbs - POOH with e-line - Laid down side entry sub and lowered top sheave from monkey board. 15:30 - 16:45 1.25 LOG DLOG PROD Flow check well, static. POOH from 8384' to 7942'. 16:45 -17:15 0.50 LOG DLOG PROD Flow check well, static. Pump dry job. 17:15 - 21 :00 3.75 LOG DLOG PROD POOH on TT w/ 4" DP & MDT tools fl 7942' to 2500' - hole slick coming out - took proper fill - Flow check @ 9 5/8" shoe - static 21 :00 - 22:00 1.00 LOG DLOG PROD Continue POOH on TT f/2500' to 118' ( MDT tools) - Flow check - static 22:00 - 00:00 2.00 LOG PULD PROD PJSM - Collect samples & LD MDT tool string - monitor well on TT - static 3/14/2005 00:00 - 01 :00 1.00 LOG PULD PROD Finish LD MDT tools 01 :00 - 03:30 2.50 LOG ELOG PROD RU & ran sidewall core guns 03:30 - 04:00 0.50 LOG PULD PROD LD sidewall core guns - RD SWS 04:00 - 07:00 3.00 ABANDt-. TRIP ABANDN RU to run tbg stinger - PJSM - PU 24 jts. 3 1/2" 9.3# L-80 EUE tbg for cmt stinger- RIH w/ tbg on 4" DP to 2474' 07:00 - 08:00 1.00 RIGMNT RSRV ABANDN Cut & slip drilling line 08:00 - 11 :00 3.00 ABANDt-. TRIP ABANDN Continue RIH w/ tbg stinger on 4" DP f/2474' to 6480' 11 :00 - 12:00 1.00 ABANDt-. CIRC ABANDN Circulate btms up @ 6480' - 420 gpm @ 1670 psi 12:00 - 14:00 2.00 ABANDt-. TRIP ABANDN Flow check (static) Continue RIH f/6480' to 9185' - string took wt. 14:00 - 16:00 2.00 ABANDt-. CIRC ABANDN Establish circulation - 3 BPM @ 470 psi - stage pumps up to 9 BPM @ 1870 psi - Wash down fl 9185' to 9290'- Hard fill @ 9290' - Circulate hole clean for cmt job - Max. gas 605 units - final gas 20 units 16:00 - 16:30 0.50 ABANDt-. OTHR ABANDN i Std back 1 std. PU 1 single - Circulate & work pipe 16:30 - 18:00 1.50 ABANDt-. OTHR ABANDN I PJSM - Blow down TO - RU cmt line - Set P&A plug #1 - w/ tbg stinger @ 9281' - test lines to 3000 psi - Mixed & pumped 39.7 bbls (190 sxs Class G wI .3% 065, .4% 0167, .05% B155, .2% 046) @ 15.8 ppg- Displaced to equalize w/10.5 ppg mud w/ rig pumps - CIP @ 1730 hrs. 18:00 - 00:00 6.00 ABANDt-. OTHR ABANDN RD cmt line - POOH to 9247' - Stuck pipe - Work stuck pipe - RU for SWS to run Free point - monitor annulus & DP 3/15/2005 00:00 - 07:30 7.50 WAlTON EQIP ABANDN Work stuck pipe - Wait on SWS to run Free point - monitor annulus & I I DP 07:30 - 07:45 0.251 FISH 'SFTY ABANDN PJSM with Sclumberger and crew. 07:45 - 09:00 1.25· FISH RURD ABANDN RU Schlumberger - Hang top sheave - RU drill pipe swivel and Y-tool. 09:00 - 16:00 7.00 FISH ELlN ABANDN Ran free point indicator tool - set tool calibration - took free point pipe stretch readings: 2220' - 100% Printed: 4/8/2005 11: 1 0:29 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: Rig Release: Rig Number: Alaska Oil & g~s~M~~,~:OPÆ~ÆBß5 2/14/2005 ~B~rage 3/21/2005 3/21/2005 Group: 19 3/15/2005 09:00 - 16:00 7.00 FISH ELlN ABANDN 2450' - 90% 2980' - 70% 3536' - 22% 4026' - 0% POOH - LD FPI. 16:00 - 17:00 1.00 FISH ELlN ABANDN Changed tool head for cement evallog 17:00 - 19:00 2.00 FISH ELlN ABANDN Make 2" drift run - 8817' and sat down. 19:00 - 20:30 1.50 FISH ELlN ABANDN Broke off GR and made up Cement Evaluation Tool. 20:30 - 00:00 3.50 FISH ELlN ABANDN RIH with Cement Evaluation Log - Logged down to 8775' where tool sat down. No cement observed on Log. 3/16/2005 00:00 - 01 :00 1.00 FISH ELlN ABANDN POOH with SCMT e-line tools 01:00 - 01:15 0.25 FISH SFTY ABANDN Held PJSM on hazards of tubing punch and jet cutter 01:15 - 03:00 1.75 FISH ELlN ABANDN RIH with tubing punch on e-line - perforated tubing from 8726' to 8728'. Pulled running tool to surface and established circulation through perfs - RURD IABANDN 2.7 bpm /750 psi 03:00 - 05:30 2.50 FISH Lay down tubing punch - blow down top drive - RD drill pipe swivel and I wireline Y-tool. RU to run jet cutter. 05:30 - 08:00 2.50 FISH ELlN ' ABANDN RIH with 2.25" jet cutter to 8723' - fire cutter - POOH with e-line, LD tools. 08:00 - 09:00 1.00 FISH OTHR ABANDN MU top drive - staged pumps up to 5.8 bpm / 940 psi - worked pipe to 350K - continued to work pipe increasing torque to 15,000 ftllbs pipe came free - appeared to have had a partial cut from jet cutter. ! 09:00 - 11 :00 2.00 FISH CIRC ABANDN Increased pumps to 8.0 bpm 11500 psi - circ and cond mud - max BGG 63 units - monitor well, static. Blow down Top Drive - LD space out pups TIW valve and xo's - flow check well, static. 11 :00 - 13:45 2.75 ABANDI\ TRIP ABANDN Wiped hole from 8723' to 7341' - RIH, no problems. 13:45 - 14:45 1.00 ABANDI\ CIRC ABANDN Circ and condition mud - 8.0 bpm 11510 psi - flow check well, static. PUW 210K SOW 150K 14:45 - 15:30 0.75 CEMENT PLUG ABANDN PJSM - Blow down TO - RU cmt line - Set P&A plug #2 - w/ tbg stinger @ 8722' - test lines to 3000 psi - Mixed & pumped 35.1 bbls (170 sxs Class G w/ .3% 065, .4% 0167, .05% B155, .2% 046) @ 15.8 ppg- Displaced to equalize wI 10.5 ppg mud w/ rig pumps - CIP @ 1530 hrs. Estimated TOC @ 8322' 15:30 - 17:00 1.50 ABANDI\ TRIP ABANDN POOH to 7731' - circ 55 bbls of mud to clear drill string of cement I residue. Flow check well, static. 17:00 - 18:00 1.00 ABANDt-\ TRIP ABANDN POOH to 6338' on TT. 18:00 - 00:00 6.00 ABANDN PULD ABANDN Laid down 5" DP while WOC. 3/17/2005 00:00 - 02:00 2.00 ABANorÚRIP ABANDN RIH from 6337' - tagged cement plug with slow pump and 15K set down @ 8346', witnessed by John Spaulding (AOGCC). 02:00 - 09:00 7.00 ABANDI\ TRIP ABANDN POOH from 8346', set back 25 stands of 4" drill pipe to 6814'. Continue to POOH - laid down remainder of drill pipe. RU tubing tongs and laid down 7 full joints and cutoff 10.45' Get cut) RD tubing tongs. 09:00 -13:15 4.25 ABANDI\ PLUG ABANDN I MU 9 5/8" Baker K-1 cement retainer and RIH - establish injection rate of 3.0 bpm @ 540 psi - Set retainer with top @ 2410' - pull test retainer to 40 K - set down with 35k - released from retainer and circ 6.0 bpm @ 520 psi. PJSM 13:15 - 14:30 1.25 CEMENT PLUG ABANDN Blow down top drive - RU cement lines - test lines to 3000 psi. Mix and pump 20.7 bbls (101 sxs) of Class G + 1.0% S2, 0.3% 065, 0.2% 046 slurry at 15.8 ppg - stab into retainer and squeezed 16 bbls of cement @ 4.9 bpm 1740 psi - pulled out of retainer and displace 4.7 bbls of cement above retainer. CIP @ 1425 hrs. ETOC @ 2348' 14:30 - 15:30 1.00 ABANDI\ OTHR ABANDN RD cement lines - LD space out pups - POOH to 2200' and circulate to Printed: 4/8/2005 11: 1 0:29 AM " t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: IAPETUS #2 IAPETUS #2 ROT - DRILLING doyon 1 @ppco.com Doyon 19 Start: 2/14/2005 Rig Release: 3/21/2005 Rig Number: 19 Alaska Oil & Gas Cons. Commission SOOlifflt1& 2/25/2005 End: 3/21/2005 Group: 3/17/2005 14:30 -15:30 1.00 ABANDtI OTHR ABANDN clear pipe - pump dry job. 15:30 - 17:30 2.00 ABANDtI TRIP ABANDN POOH - laid down 4" drill pipe. Stood back 2 stands. 17:30 - 18:30 1.00 ABANDtI PULD ABANDN RU and RIH with 3 1/2" Tubing to 320' (10 Jts.). 18:30 - 19:00 0.50 ABANDtI TRIP ABANDN Changed Elevators and RIH to 508'. 19:00 - 20:00 1.00 ABANDtI PULD ABANDN Displaced to Hi Vis pil from 508' to surface. POOH to 300'. RU cement line. 20:00 - 21 :00 1.00 CEMENT PLUG ABANDN PJSM. Displaced hole to water. Tested lines to 2000 PSI. Mixed and pumped 20.1 Bbls (117 Sxs) of ARTICSET 1 Cement @ 15.7 PPG. Displaced with 1 Bbl Water. CIP @ 2040 Hrs. ETOC 45'. 21 :00 - 21 :30 0.50 CEMENT PULD ABANDN POOH and laid down 3 1/2" tubing. 21 :30 - 22:30 1.00 CEMENTOTHR ABANDN Made up wash tool and RIH to 45'. Washed stack. LD 2 stands 4" DP in mousehole. 22:30 - 00:00 1.50 ABANDtI RURD ABANDN Laid down wash tool. Blew down lines and pulled wear ring. Prep for NO BOP. 3/18/2005 00:00 - 01 :00 1.00 ABANDtI RURD ABANDN Rigged down tubing tools and wear bushing. Changed saver sub on top drive. 01 :00 - 03:00 2.00 ABANDtI NUND ABANDN Nippled down BOP. 03:00 - 09:00 6.00 ABANDtI OTHR ABANDN Cleaned pits. 09:00 - 12:00 3.00 MOVE DMOB MOVE Rig released to move @ 0900. Moved back Motor and Pit complex. Backed sub off well. 12:00 - 00:00 12.00 MOVE DMOB MOVE Positon sub and transporter. Skid back floor and removed pipe shed. 12.00 WAITONEQIP Skidding rig onto transporter. 3/19/2005 00:00 - 12:00 MOVE (Wait on Peak trucks to move camp.) Skidded rig onto transporter and lowered transporter. Turned sub around. Trucks arrived @ 1030 Hrs I and started hooking up to camp. 12:00 - 00:00 12.00 MOVE !DMOB MOVE Camp departed @ 1230 Hrs. Moving camp to CD 2. Camp on location I @ 1630 Hrs. Camp on Highline @ 1745 Hrs. Moved Sub and I Transporter to Iapetus 2 Turnoff. 3/20/2005 00:00 - 12:00 12.00 MOVE IMOB MOVE Moved Transporter to CD 3 and jacked up Transporter. Moved Sub to i guard shack. I 12:00 - 00:00 12.00 MOVE ¡MOB MOVE Moved Sub to CD 3 and spotted. Aligned Transporter and Sub. Began I jacking Rig from Transporter to Sub. Moved Motors and pits to CD 2 I turn off. i Moved Ball mill and pipe shed off Iapetus 2. Skidded Rig onto Sub. 3/21/2005 00:00 - 08:30 8.50 MOVE I RURD MOVE I I I I ! Printed: 4/8/2005 11: 1 0:29 AM . . ,Allsup-Drake, Sharon K Cc: Subject: Cunningham, DMOOSEJ RECEIVED Wednesday. March 30, 2005 9:40 AM Mazzolini, Paul; Brassfield, Tom J; Chambers, Mark A; Allsup-A>PJte2Sf1á!SB$<; 'john_ crisp@admin.state.ak.us' Hayden, Philip Alaska Oil & Gas Cons. Commission Iapetus #2 PTD # 204-254 API 50-103-20506-00 P&A Anchorage From: Sent: To: Good Morning Excavation of the Iapetus Exploration well for the P&A was as follows: Contacted AOGCC (Mr. John Crisp) in Prudhoe 27 March for status and dates we estimated for excavation and completion of P&A. Pre-job safety meeting held with all contractors involved as well as safety rep. from Alpine 28 March. Tapped conductor at surface with hand drill to sniff for gas or hydro carbons. No hydro carbons present at surface. Cement was in the 16" annulus at surface. Cleaned cement from annulus and drilled 9 5/8" casing string at surface and checked for gas. Cement also at surface in the 9 " casing string, no hydrocarbons. Cut starting head from 16" at surface to eliminate the extra weight on 16" string. No problems. Continued excavation of cellar and 16" conductor down to 8' +- below ice pad and ground level. Drilled and checked both drilling strings for hydro carbons. None present. Confirmed cement in both annulus strings (16" and 95/8") (see pics below) Contacted AOGCC and confirmed cement to surface on both drilling strings, AOGCC elected to waive on sight inspection due to other commitments and we agreed to forward all pictures of the P&A process. 29 March "05" Per Mr. Crisp request. Due to the location of the Iapetus exploration well, located close to the flood plain of the Nigliq channel, we elected to remove the drillings strings to a depth of 4 Ft. 6 inches. To ensure that the cut off would be well below surface elevation, this will ensure any flooding and washing effect would not affect the buried drilling strings. AOGCC requires the P&A of wells to be at or below 3 Ft. above ground level. Removal of the pipe strings were completed with no safety incidents or environmental issues. Replaced all material back in to the excavation point. (see pic) DSCF0275.JPG DSCF0278,JPG DSCF0281.JPG DSCF0282,JPG DSCF0284,JPG DSCF0286.JPG DSCF0288,JPG (306 KB) (299 KB) (315 KB) (306 KB) (311 KB) (299 KB) (311 KB) ~ DSCF0292,JPG DSCF0294.JPG DSCF0295,JPG DSCF0302,JPG (297 KB) (294 KB) (300 KB) (294 KB) Regards Dennis Cunningham/Mike Winfree CPAI Exploration 659-7154 office 448-1975 vehicle 1 R~VI2/~~ìo51 :~ I ~~ ~~ lis. ~~~IP~~:110ACS ¡REVI DATE I BY'K I APP I DESCRIPTION NOTES: 1. BASIS OF COORDINATES: ALPINE MONUMENTS MON 19 AND MON 12. 2. COORDINATES ARE NAD83, ALASKA STATE PLANE ZONE 4. 3. ELEVATIONS ARE REFERENCED TO BRITISH PETROLEUM MEAN SEA LEVEL DATUM (BPMSL). 4. DISTANCES ARE TRUE. ALL DISTANCES AND ELEVATIONS ARE IN ENGLISH FEET. 5. DATE OF SURVEY 2/22/05 + BEAUFORT SEA KUUKPIK LCMF LIe t3QE.5tIlA...· __,_ _. II07)273-t830 Alpine Office (907) 610-4739 Alpine Survey Office Vicinity Map NOT TO SCALE IAPETUS #2 LOCATED WITHIN PROTRACTED SECTION 8, T.12 N., R.4 E. UMIAT MERIDIAN, ALASKA 2832' FSL 3290' FEL GND ELEV.=1.80' BPMSL ICE PAD ELEV.=5.71' BPMSL TOP CONDo ELEV.=8.18' BPMSL NAD83 Datum N 70°24'31.477" / W 151°11'15.563" ASPC ZN4 (Y) 6,000,373 (X) 1,494,563 / :::2: ~ ::> ::> W W <;t- v ci. ci. z Z N N ¡..: ¡..: as c¡; u u RECEIVED w w (f) (f) APR 2 7 2005 // -z.. ¡0 o. o o. o o~ Ž 0' o O. V' ?0 0'. 0_ 70 0\'"\ H Alaska Oil & Gas Cons. Commission Anchorage SCALE 1 "=200' SEC. 8, T.12 N., R.4 E., U.M. SEC. 17, T.12 N., R.4 E., U.M. / / ConocJPhillips Alaska, Inc. I DRAWING NO: 02/26/05 ALPINE MODULE:APOO UNIT: AP IAPETUS #2 EXPLORATORY WELL CONDUCTOR AS-BUILT LOCATION I PART: I REV: 1 CE - APpO-1 027 1 OF 1 ¡ I. '" ""- CADD FILE NO. 04-11-19-10 . Halliburton Global . Survey: Start Date: Company: Tool: Engineer: Tied-to: RECEIVED ^PR 2 7 Z005 Field: Zone 4 (Nad 83) Exploration Map System:US State Plane Coordinate System 1983 Geo Datum: GRS 1980 Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska Oil & Gas Cons. Commission Alaska, Zone 4 Anchorage Well Centre bggm2004 Site: Iapetus Site Position: Northing: 6000375.00 ft Latitude: 70 24 31.382 N From: Map Easting: 1494565.00 ft Longitude: 151 11 15.596 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -1.12 deg Well: Iapetus 2 Slot Name: Well Position: +N/-S -2.04 ft Northing: 6000373.00 ft Latitude: 70 24 31.362 N +E/-W -1.96 ft Easting : 1494563.00 ft Longitude: 151 11 15.653 W Position Uncertainty: 0.00 ft Wellpath: Iapetus 2 Drilled From: Well Ref. Point 501032050600 Tie-on Depth: 36.77 ft ,,/ Current Datum: Iapetus 2: Height 42.48 ft Above System Datum: Mean Sea Level Magnetic Data: 2/15/2005 Declination: 23.63 deg Field Strength: 57522 nT Mag Dip Angle: 80.64 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.77 0.00 0.00 251.25 Survey Program for Definitive Wellpath Date: 5/14/2003 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 148.69 9229.72 Iapetus 2 (148.69-9229.72) MWD MWD - Standard Survey 36.77 0.00 0.00 36.77 -5.71 0.00 0.00 6000373.00 1494563.00 TIE LINE 148.69 0.76 196.54 148.69 106.21 -0.71 -0.21 6000372.29 1494562.77 MWD 197.09 0.83 56.57 197.08 154.60 -0.83 -0.01 6000372.17 1494562.97 MWD 288.95 0.72 90.47 288.94 246.46 -0.46 1.12 6000372.51 1494564.11 MWD 379.07 1.19 85.42 379.04 336.56 -0.39 2.62 6000372.55 1494565.61 MWD 470.36 1.00 215.63 470.33 427.85 -0.97 3.10 6000371.97 1494566.08 MWD 560.03 3.22 251.39 559.93 517.45 -2.41 0.26 6000370.59 1494563.21 MWD 649.84 6.34 251.30 649.42 606.94 -4.80 -6.83 6000368.33 1494556.08 MWD 739.34 9.07 249.47 738.10 695.62 -8.86 -18.12 6000364.50 1494544.71 MWD 829.86 11.17 249.78 827.21 784.73 -14.39 -33.03 6000359.26 1494529.70 MWD 921.07 14.24 254.74 916.18 873.70 -20.40 -52.15 6000353.62 1494510.47 MWD 1016.00 16.39 252.56 1007.73 965.25 -27.49 -76.19 6000347.01 1494486.29 MWD 1111.65 18.02 250.06 1099.10 1056.62 -36.58 -102.98 6000338.44 1494459.34 MWD 1206.56 21.17 250.43 1188.50 1146.02 -47.33 -132.93 6000328.28 1494429.18 MWD 1302.29 25.16 248.06 1276.50 1234.02 -60.73 -168.11 6000315.57 1494393.75 MWD 1397.27 28.67 248.25 1361.18 1318.70 -76.72 -208.01 6000300.36 1494353.54 MWD 1492.60 31.81 248.13 1443.53 1401.05 -94.56 -252.58 6000283.40 1494308.64 MWD 1587.43 34.83 248.59 1522.76 1480.28 -113.76 -301.00 6000265.15 1494259.86 MWD 1682.70 35.52 248.64 1600.63 1558.15 -133.77 -352.10 6000246.14 1494208.38 MWD . Halliburton Global . 1777.97 35.98 248.61 1677.95 1635.47 -154.06 -403.93 6000226.87 1494156.17 MWD 1872.98 36.51 248.25 1754.57 1712.09 -174.71 -456.17 6000207.25 1494103.54 MWD 1967.84 36.94 251.85 1830.61 1788.13 -194.05 -509.48 6000188.95 1494049.87 MWD 2062.70 37.13 252.25 1906.34 1863.86 -211.65 -563.83 6000172.41 1493995.19 MWD 2158.24 36.91 251.62 1982.62 1940.14 -229.49 -618.52 6000155.65 1493940.17 MWD 2253.64 36.69 251.95 2059.01 2016.53 -247.36 -672.80 6000138.85 1493885.55 MWD 2349.14 36.32 252.32 2135.77 2093.29 -264.78 -726.87 6000122.48 1493831.15 MWD 2440.66 35.70 251.69 2209.80 2167.32 -281.40 -778.05 6000106.86 1493779.66 MWD 2580.86 37.77 251.94 2322.16 2279.68 -307.57 -857.71 6000082.26 1493699.51 MWD 2676.27 37.19 252.13 2397.87 2355.39 -325.48 -912.94 6000065.44 1493643.95 MWD 2771.27 36.31 250.61 2473.99 2431.51 -343.63 -966.80 6000048.34 1493589.75 MWD 2866.50 35.32 250.13 2551.21 2508.73 -362.34 -1019.28 6000030.66 1493536.91 MWD 2961.57 36.52 249.90 2628.20 2585.72 -381.41 -1071.70 6000012.62 1493484.14 MWD 3057.10 35.48 249.37 2705.49 2663.01 -400.94 -1124.34 5999994.12 1493431.13 MWD 3152.02 37.00 248.50 2782.04 2739.56 -421.12 -1176.70 5999974.97 1493378.39 MWD 3249.57 38.51 249.54 2859.17 2816.69 -442.49 -1232.47 5999954.69 1493322.22 MWD 3343.39 37.74 249.21 2932.97 2890.49 -462.90 -1286.68 5999935.35 1493267.63 MWD 3438.75 38.36 252.76 3008.07 2965.59 -482.03 -1342.23 5999917.31 1493211.72 MWD 3533.97 37.46 253.99 3083.20 3040.72 -498.77 -1398.28 5999901.67 1493155.35 MWD 3629.37 36.62 252.46 3159.35 3116.87 -515.35 -1453.30 5999886.17 1493100.02 MWD 3724.66 37.68 251.72 3235.30 3192.82 -533.05 -1508.06 5999869.54 1493044.94 MWD 3819.80 36.83 251.89 3311.03 3268.55 -551.03 -1562.77 5999852.63 1492989.89 MWD 3915.28 35.75 250.60 3387.99 3345.51 -569.19 -1616.28 5999835.52 1492936.04 MWD 4010.46 37.60 249.37 3464.32 3421.84 -588.66 -1669.69 5999817.10 1492882.26 MWD 4105.75 37.03 249.40 3540.11 3497.63 -609.00 -1723.75 5999797.82 1492827.82 MWD 4201.05 39.10 248.36 3615.14 3572.66 -630.18 -1778.55 5999777.72 1492772.62 MWD 4296.64 38.81 247.73 3689.47 3646.99 -652.65 -1834.29 5999756.34 1492716.45 MWD 4392.20 38.17 247.22 3764.27 3721.79 -675.43 -1889.23 5999734.64 1492661.08 MWD 4487.59 39.30 250.11 3838.68 3796.20 -697.12 -1944.82 5999714.04 1492605.09 MWD 4583.29 38.78 248.96 3913.01 3870.53 -718.20 -2001.29 5999694.07 1492548.22 MWD 4678.73 39.16 250.25 3987.22 3944.74 -739.11 -2057.55 5999674.27 1492491.57 MWD 4774.16 38.19 250.76 4061.72 4019.24 -759.01 -2113.76 5999655.46 1492434.98 MWD 4870.11 37.45 250.57 4137.51 4095.03 -778.49 -2169.28 5999637.07 1492379.10 MWD 4963.49 38.62 251.98 4211.06 4168.58 -796.95 -2223.77 5999619.68 1492324.26 MWD 5061.35 38.12 253.72 4287.79 4245.31 -814.87 -2281.81 5999602.91 1492265.89 MWD 5156.89 37.16 253.22 4363.44 4320.96 -831.47 -2337.74 5999587.41 1492209.65 MWD 5252.16 36.57 252.75 4439.66 4397.18 -848.19 -2392.40 5999571.75 1492154.68 MWD 5347.72 37.79 253.72 4515.80 4473.32 -864.84 -2447.69 5999556.19 1492099.08 MWD 5443.26 37.01 254.30 4591.70 4549.22 -880.83 -2503.47 5999541.29 1492043.00 MWD 5539.08 38.47 254.09 4667.47 4624.99 -896.80 -2559.90 5999526.42 1491986.27 MWD 5634.58 37.59 254.60 4742.69 4700.21 -912.68 -2616.55 5999511.66 1491929.32 MWD 5730.08 38.50 251.72 4817.91 4775.43 -929.74 -2672.86 5999495.70 1491872.69 MWD 5825.62 37.38 250.63 4893.25 4850.77 -948.69 -2728.46 5999477.84 1491816.74 MWD 5921.03 39.16 250.30 4968.16 4925.68 -968.45 -2784.15 5999459.17 1491760.68 MWD 6016.42 38.68 251.16 5042.37 4999.89 -988.23 -2840.72 5999440.51 1491703.74 MWD 6111.83 37.82 250.Q7 5117.30 5074.82 -1007.83 -2896.44 5999422.00 1491647.65 MWD 6207.03 38.29 250.62 5192.26 5149.78 -1027.56 -2951.70 5999403.35 1491592.02 MWD 6301.93 37.31 249.96 5267.25 5224.77 -1047.18 -3006.46 5999384.81 1491536.89 MWD 6398.64 36.72 250.25 5344.47 5301.99 -1066.99 -3061.21 5999366.07 1491481.78 MWD 6494.26 38.30 250.92 5420.32 5377.84 -1086.34 -3116.12 5999347.80 1491426.50 MWD I 6589.59 39.23 250.86 5494.65 5452.17 -1105.88 -3172.52 5999329.36 1491369.74 MWD I 6684.91 38.27 249.74 5568.99 5526.51 -1125.98 -3228.69 5999310.36 1491313.19 MWD I ---1 . Halliburton Global . Survey 6780.35 37.41 250.18 5644.36 5601.88 -1146.05 -3283.69 5999291.38 1491257.81 MWD 6875.80 38.16 249.31 5719.79 5677.31 -1166.30 -3338.55 5999272.20 1491202.56 MWD 6971.22 37.12 249.06 5795.35 5752.87 -1187.00 -3393.02 5999252.57 1491147.71 MWD 7064.95 35.65 249.75 5870.81 5828.33 -1206.57 -3445.06 5999234.03 1491095.29 MWD 7160.33 36.98 249.16 5947.66 5905.18 -1226.39 -3497.95 5999215.24 1491042.03 MWD 7257.36 37.82 249.22 6024.74 5982.26 -1247.33 -3553.04 5999195.38 1490986.55 MWD 7352.47 39.58 247.56 6098.97 6056.49 -1269.25 -3608.32 5999174.55 1490930.86 MWD 7448.14 38.44 247.57 6173.30 6130.82 -1292.23 -3663.98 5999152.66 1490874.76 MWD 7541.35 38.03 250.59 6246.53 6204.05 -1312.83 -3717.85 5999133.12 1490820.51 MWD 7638.73 38.24 256.46 6323.15 6280.67 -1329.86 -3775.46 5999117.22 1490762.58 MWD 7733.99 38.72 261.46 6397.74 6355.26 -1341.19 -3833.60 5999107.03 1490704.24 MWD 7829.57 38.91 265.28 6472.22 6429.74 -1348.10 -3893.08 5999101.28 1490644.63 MWD 7925.18 38.54 269.07 6546.82 6504.34 -1351.05 -3952.80 5999099.50 1490584.88 MWD 8020.79 37.18 270.44 6622.31 6579.83 -1351.31 -4011.47 5999100.38 1490526.21 MWD 8116.00 36.12 269.63 6698.69 6656.21 -1351.27 -4068.30 5999101.53 1490469.40 MWD 8211.44 35.22 267.77 6776.23 6733.75 -1352.52 -4123.93 5999101.36 1490413.75 MWD 8306.65 35.32 272.47 6853.98 6811.50 -1352.41 -4178.87 5999102.55 1490358.83 MWD 8402.32 34.42 274.44 6932.47 6889.99 -1349.12 -4233.47 5999106.90 1490304.32 MWD 8497.87 33.02 274.07 7011.94 6969.46 -1345.18 -4286.36 5999111.87 1490251.51 MWD 8593.32 33.47 271.79 7091.77 7049.29 -1342.52 -4338.61 5999115.56 1490199.33 MWD 8688.30 33.51 272.11 7170.99 7128.51 -1340.73 -4390.99 5999118.37 1490147.00 MWD 8783.99 34.20 275.36 7250.46 7207.98 -1337.25 -4444.17 5999122.89 1490093.91 MWD 8879.21 33.41 275.90 7329.58 7287.10 -1332.05 -4496.89 5999129.11 1490041.30 MWD 8974.49 32.66 275.14 7409.46 7366.98 -1327.05 -4548.59 5999135.12 1489989.71 MWD 9070.01 31.54 274.95 7490.37 7447.89 -1322.59 -4599.15 5999140.57 1489939.25 MWD 9163.93 30.47 274.43 7570.87 7528.39 -1318.63 -4647.37 5999145.47 1489891.12 MWD 9229.72 29.74 275.66 7627.79 7585.31 -1315.73 -4680.24 5999149.01 1489858.32 MWD 9300.00 29.74 275.66 7688.81 7646.33./ -1312.29 -4714.93 5999153.13 1489823.70 MWD RECEIVED APR 2 7 2005 Alaska Oil & Gas Cons. Commission Anchorage ~ I . . PETROLEUM SERVICES .. [ore Lab RESERVOIR DPTIKIZATIOJl CORE ANALYSIS RESULTS CONOCOPHILLlPS ALASKA, INC. IAPETUS 2 WELL COLVILLE DELTA FIELD CL FILE 57111-1 05078CP Performed by: Core laboratories 3430 Unicorn Road Bakersfield, CA 93308 (661) 392-8600 ,4œéê / . ~M1A.Lr lDI- 29/ CONFIDENTIAL . . Petroleum Services Division 3430 Unicorn Road Bakersfield, California 93308 Tel: 661-392-8600 Fax: 661-392-0824 www.corelab.com Core LaIi REstRVDIR OPTIHJZATIOJf Ms. Beverly Burns ConocoPhillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 June 21,2005 Subject: Core Analysis Data Well: Iapetus 2 Field: Colville Delta File No.: 105078CP Dear Ms. Burns Rotary sidewall cores recovered from the subject well were submitted for permeability, porosity, and fluid saturation determinations. Preliminary reports of these results contained depth errors. All samples from below 8722.5 feet were reported with depths 100 feet shallower than the actual depths. The results of the measurements with corrected depths are presented in the accompanying report. Fluid saturations were determined by Dean-Stark methods with toluene as the distillation solvent. Following distillation, the samples were extracted of remaining hydrocarbon by soxhlet with methylene chloride/methanol. Prior to measurement of porosity and permeability to air, the samples were dried at 235 degrees Fahrenheit. Grain volumes were measured by Boyle's Law double-cell methods using helium as the gaseous medium. Sample bulk volumes were determined at ambient conditions by mercury displacement. Pore volume and porosity were calculated using the measured bulk volumes and grain volumes. Permeability measurements were made by steady-state methods with the samples under 400 psig confining pressure. Three of the sample plugs were subsequently cut in half, and permeability was then measured on each of the halves to see how the values varied. There were no significant differences noted in comparing the top half, bottom half and whole plug permeabilities. CT scans were requested upon a separate set of three samples to assess their degree of bioturbation. We are pleased to have performed this service and hope it is beneficial in the evaluation of this reservOIr. /'~ 1 original, 5 copies, 6 CDs: Addressee CtB omm NY.5E . Company: ConocoPhillips Alaska File No.: 57111-105078 Well: Iapetus 2 API No.: 50-103-20506 Field: Colville Delta Core Lab Rotary Sidewall Core Analysis Results Sample Depth Rec Perm. Porosity Fluid Saturation Grain Sample Method Description No. Kalr Oil I Water I OIW I Total Den Wt. ft in md % % % Ratio % glee 9 1 8719.0 0.9 83.84 21.5 20.3 39.7 0.51 60.1 2.68 21.9 (3) 5st bm vfgr slty m stn gld flor . 2c 8721.0 0.9 1.80 17.7 24.8 45.0 0.55 69.9 2.74 23.3 (3) Sst Ibm vfgr vslty/ chty lam m stn gld flor 3 8722.0 0.9 59.83 21.3 22.2 40.6 0.55 62.8 2.68 22.3 (3) 5st bm vfgr slty m stn gld flor 4 8722.5 1.1 0.02 6.1 16.9 51.3 0.33 68.3 3.23 33.4 (3) Lst gry-tan slty pyr Isp stn gld flor 5K 8850.0 1.1 0.18 10.4 16.6 62.7 0.26 79.3 2.71 30.2 (3) 5st bm-gry vfgr vsltyl calc incl msp stn gld flor 6 8851.0 1.0 0.04 7.7 25.9 56.7 0.46 82.6 2.73 30.3 (3) 5st Ibm-gry vfgr vslty vcalc msp stn gld flor 7 8854.0 0.7 <0.01 13.9 24.4 44.4 0.55 68.8 2.70 13.7 (4) 5st Ibm vfgr vslty m stn gld flor 8 8855.0 0.7 0.40 11.8 20.9 57.9 0.36 78.8 2.70 17.7 (3) Sst Ibm-gry vfgr vslty msp stn gld flor 9c 8856.0 0.9 0.88 13.8 18.6 51.4 0.36 70.0 2.68 26.3 (3) Sst bm vfgr vslty m stn gld flor 10 8858.0 0.5 0.31 12.0 22.1 58.1 0.38 80.3 2.66 14.7 (3) Sst bm-gry vfgr vslty msp stn gld flor 11K 8859.0 1.1 0.15 10.3 18.4 60.3 0.31 78.7 2.69 27.7 (3) Sst bm-gry vfgr vslty msp stn gld flor 12 8860.0 0.5 5.44 11.9 21.9 56.6 0.39 78.5 2.66 13.8 (3) Sst brn-gry vfgr vslty msp stn gld flor 13c 8861.0 0.9 0.49 12.7 19.2 57.7 0.33 76.9 2.67 26.0 (3) Sst bm-gry vfgr vslty msp stn gld flor 14K 8863.0 0.9 0.07 5.9 31.2 32.0 0.98 63.2 2.69 25.9 (3) 5st gry-tan vfgr vslty/slt strk calc Isp stn wh-gld flor 15 8865.0 1.2 0.60 12.6 23.2 45.5 0.51 68.7 2.68 29.7 (3) Sst bm-gry vfgr vslty msp stn gld flor . 16 8866.0 1.0 0.27 12.1 25.1 50.9 0.49 76.0 2.68 22.7 (3) Sst bm-gry vfgr vslty msp stn gld flor 17 8867.0 1.0 0.31 11.5 22.8 57.8 0.39 80.5 2.68 25.7 (3) 5st bm-gry vfgr vslty msp stn gld flor 18 8868.0 1.0 0.40 11.7 12.4 63.4 0.19 75.8 2.67 22.8 (3) Sst bm-gry vfgr vslty msp stn gld flor c CT -scanned samples K Steady-state permeability on half samples CONFIDENTIAL For Method Definitions See Procedures Page . Core LaI:Ï Company: ConocoPhillips Alaska Well: Iapetus 2 Field: Colville Delta File No.: 105078 API No.: 50-103-20506 ROTORY SIDEWALL CORE ANALYSIS PROCEDURES AND CONDITIONS Procedure (1) Procedure (2) Procedure (3) Procedure (4) Procedure (5) Sampling Method Rotary Rotary Rotary Rotary Rotary Drill Coolant N/A N/A N/A N/A N/A . Jacket Material Lead Aluminum None None N/A Saturation Method Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Retort Porosity Method Grain Volume Boyle's Law (Helium) Boyle's Law (Helium) Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Pore Vol Pore Volume Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Grain Vol Bulk Vol-Grain Vol Summation Of Fluids Bulk Volume Pore Vol + Grain Vol Pore Vol + Grain Vol Mercury Displacement Mercury Displacement Mercury Displacement Permeability Method Steady-state perm. to air Steady-state perm. to air Steady-state perm. to air Empirical Empirical . Common Conditions Sleeved Sample Seating Pressure: N/A Confining Pressure Pore Vol & Permeability: 400 psig Samples Dried At 235 Degrees Fahrenheit Additional Extraction by Soxhlet with Methylene Chloride/Methanol Oil Density used in Calculation: 0.9 g/cc CONFIDENTIAL A Company: ConocoPhillips Alaska File No.: 57111-105078 . Well: Iapetus 2 API No.: 50-103-20506 Field: Colville Delta Core LaIÌ Permeability Comparison Results Sample Depth Perm. Sample Grain Description No. Kalr Length Den ft md em glee 5 8850.0 0.18 2.79 2.71 Sst brn-gry vfgr vsltyl calc incl msp stn gld flor . 5T 8850.0 0.23 1.40 Top "half' of sample plug. 5B 8850.0 0.20 1.20 Bottom "half' of sample plug. Average 0.20 11 8859.0 0.15 2.79 2.69 Sst brn-gry vfgr vslty msp stn gld flor 11T 8859.0 0.18 1.40 Top "half' of sample plug. 11B 8859.0 0.22 1.10 Bottom "half' of sample plug. Average 0.18 14 8863.0 0.07 2.29 2.69 Sst gry-tan vfgr vslty/slt strk calc Isp stn wh-gld flor 14T 8863.0 0.09 1.00 Top "half' of sample plug. . 14B 8863.0 0.10 1.30 Bottom "half of sample plug. CONFIDENTIAL . . . . Core Lab RESERVDIR OPTIMIZATION Petroleum Services 6316 Wind/em Houston, Texas 77040 USA Tel: 713-328-2565 Fax: 713-328-2567 www.corelab.com Ult:ra!icari CT Scan Report for Conoco Phillips Iapetus 2 Coleville Delta Umiat Meridian, Alaska April 12, 2005 HOU-050312 · Coæ lab J1tStavli¡n !lPTlM!ZATHJN 8721.00 8856.00 09J Conoco Philli Iapetus 2 Coleville Delta Alaska File No.: HOU-050312 Date April 12, 2005 Core lab Rr.Sr:¡¡ViHR OpnM¡lATW)¡ 8861.00 " 13J Conoco Philli Iapetus 2 Coleville Delta Alaska · ~ tj -:(s+ ." l '/ \~ \ \)) Good Morning Excavation of the Iapetus Exploration well for the P&A was as follows: Contacted AOGCC (Mr. John Crisp) in Prudhoe 27 March for status and dates we estimated for excavation and completion of P&A. Pre-job safety meeting held with all contractors involved as well as safety rep. from Alpine 28 March. Tapped conductor at surface with hand drill to sniff for gas or hydro carbons. No hydro carbons present at surface. Cement was in the 16" annulus at surface. Cleaned cement from annulus and drilled 95/8" casing string at surface and checked for gas. Cement also at surface in the 9 " casing string, no hydrocarbons. Cut starting head from 16" at surface to eliminate the extra weight on 16" string. No problems. Continued excavation of cellar and 16" conductor down to 8' +- below ice pad and ground level. Drilled and checked both drilling strings for hydro carbons. None present. Confirmed cement in both annulus strings (16" and 9 5/8") (see pics below) Contacted AOGCC and confirmed cement to surface on both drilling strings, AOGCC elected to waive on sight inspection due to other commitments and we agreed to forward all pictures of the P&A process. 29 March "05" Per Mr. Crisp request. Due to the location of the Iapetus exploration well, located close to the flood plain of the Nigliq channel, we elected to remove the drillings strings to a depth of 4 Ft. 6 inches. To ensure that the cut off would be well below surface elevation, this will ensure any flooding and washing effect would not affect the buried drilling strings. AOGCC requires the P&A of wells to be at or below 3 Ft. above ground level. Removal of the pipe strings were completed with no safety incidents or environmental issues. Replaced all material back in to the excavation point. (see pic) «DSCF0275.JPG» «DSCF0278.JPG» «DSCF0281.JPG» «DSCF0282.JPG» «DSCF0284.JPG» «DSCF0286.JPG» «DSCF0288.JPG» «DSCF0292.JPG» «DSCF0294.JPG» «DSCF0295.JPG» «DSCF0302.JPG» Regards Dennis Cunningham/Mike Winfree CPAI Exploration 659-7154 office 448-1975 vehicle Iapetus~2 Pl'])~2º4-254. API. ?0-1 03- 2º?06-0º. P&A.eIl11 10f2 4/13/20052:04 PM , .. 20f2 . DSCF0275.JPG DSCF0278.JPG DSCF0281.JPG DSCF0282.JPG DSCF0284.JPG DSCF0286.JPG DSCF0288.JPG DSCF0292.JPG DSCF0294.JPG DSCF0295.JPG . DSCF0302.JPG . 4/13/20052:04 PM Iapetus #2 (ConocoPhillips) Surface Abandonment Inspection Photos from ConocoPhillips March 28, 2005 ì0Þ J.( - ~~"- Í1e.<. .-- ,'s cA- 'SuU:00$ " I fht..+o; fíD\J ,,~~ ~ G:>f.?e.s.· cV'~ cl4,cJ ¡ uJ?- ' <Jí<'1 5f1ß/¡),Ç Excavation depth; casing stub Cement to surface '" Marker plate info Maker plate installed P&A'd wen buried -z.-. Iapetus #"2 . e Subject: Iapetus #2 From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Thu, 17 Mar 2005 09:02:48 -0900 dO 4 - d- S ~ To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us>, AOGCC North Slope Office <aogcc yrudhoe _ bay@admin.state.ak.us> Philip, You are isolated from the identified hydrocarbon zones with a verified plug. Your request is accepted, barring any difficulties no further BOP test should be needed on this well. Tom Maunder, PE AOGCC Hayden, Philip wrote: Tom, We would like to request a BOP test extension until the end of P&A operations on Iapetus 2. We have set our second abandonment plug on top of the hydrocarbon bearing zones and have tagged it successfully with 15 klbs with circulation at 8346 ft MD. This covers the zones of interest with 366 ft of cement. We plan to have effectively P&A'd the well by setting and cementing in place the 9 5/8" cement retainer today, Thursday 3/17. We feel there would be no benefit in conducting the test so close to the end of open hole operations. Of course, if there are further delays we would expect this to be revisited. Regards Philip 1 of 1 3/18/20058:16 AM Current Status Planned P&A 3/16/2005 16" 63# @ +/-155' MD All depths are referred to RKB Plug 4: ARCTICSET 1 Weight: 15.7 ppg Plug 3: Class G + Add. Weight: 15.8 ppg Plugs 1 & 2: Class G + Add. Weight: 15.8 ppg Surface csg. 95/8" 40.0# L-80 BTC 2501' MD /2258' TVD Surface csg. 2501' MD /2258' TVD 10.5 ppg mud ( 8%"holetoTD@ U 9300' MD / 7689' TVD 8 W' hole to TD @ 9300' MD I 7689' TVD TOC @ 45' MD ~ TOC @ 2390' MD f Cement retainer @ 2440' MD BOC @ 2610' MD TOC @ 8400' MD BOC & TOF @ 8723' MD 3 %" Tubing stinger TOC @ 8836' MD Calculated BOC @ 9279' MD . ~. o ~ \ qJ V\ .1 AOGCC Iapetus 2 Weekly update #43/17/2005 e e Subject: AOGCC Iapetus 2 Weekly update #4 3/1712005 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> Date: Thu, 17 Mar 2005 16:30:51 -0900 To: tom_maunder@admin.state.akus CC: "Mazzolini, Paul" <Pau1.Mazzolini@conocophillips.com> dG~- ;;2$.' 3/10 0830hrs: MU clean out BHA & begin RIH 3/12 1130hrs: Rig up Schlumberger & Run MDT (logging run#5) 3/14 0400hrs: Completed logging operations with Run#6: sidewall core gun 3/14 1800hrs: Finished placing first abandonment cement plug. Stuck cement stinger in plug. 3/15 2400hrs: Ran free point indicator tool indicating pipe stuck at 4000 ft MD. Ran SCMT log to 8775 ft MD - no cement observed at this depth. 3/16 0300hrs: Punched cement stinger at 8726 ft MD & circulated 3/16 0800hrs: Fired jet cutter at 8723 ft MD 3/16 0900hrs: Pipe free at jet cutter depth 3/16 1530hrs: 400 ft cement plug # 2 placed on fish. Cement plug # 2 was tagged this morning at 8346 ft MD with circulation and 15klbs weight. The plan ahead is to set a cement retainer in the 9 5/8" shoe and set cement plug # 3. The surface cement plug should be in place by this evening. We plan on beginning to move the rig back to Alpine on Saturday 3/19. Please let me know if you need any more information. Regards Philip 1 of 1 3/18/20058:15 AM Re: Iapetus 2 Revised P&A plan . . Subject: Re: Iapetus 2 Revised P&A plan From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 16 Mar 2005 12:37:17 -0900 To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> Philip, It appears your plan makes the best of the recovery from the "flash set". da4-d-5~ Pumping 400' of cement without a pill may allow the cement to fall a little. Any excess you can pump is probably best. Have Dave make sure he contacts the Inspector to witness the tag. Good luck to all. Keep the gremlins at bay. Tom Maunder, PE AOGCC Hayden, Philip wrote: Tom, As per our discussion this morning I am sending you our revised planned P&A schematic. We are assuming we have pulled our string free from the jet cut made at 8723 ft MD. Our plan is to proceed directly with plug # 2 which will be set from the top of fish at 8723 ft MD to approximately 300 ft MD above the Kuparuk interval. Our P&A plan from that point forward is unchanged from that reviewed by you earlier. Please let me know if you need additional information. Regards Philip «Iapetus 2 Planned P&A Schematic Revision# 1.ppt» 1 of 1 3/16/2005 12:40 PM Re: Iapetus 2 Update 3/16 . . Subject: Re: Iapetus 2 Update 3/16 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 16 Mar 200509:09:00 -0900 To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> Thanks Philip. Some progress and good news about the circulation. Keep us advised as you plan. Tom Hayden, Philip wrote: dO~-d-S- ~ Tom, Here is where we stand as of this morning: Calculated TOC with 25% excess hole volume: 8836 ft Top Nechelik: 8790 ft Top Kuparuk: 8712 ft Tubing tail: 9247 ft DP - Tubing XIO: 8490 ft Ran free point tool- indicated we were stuck at approx. 4000 ft MD. We are assuming we are differentially stuck at this point. Ran a 2" drift to 8817 ft where it tagged up on something firm. Repeated the tag several times. Ran SCMT tool to 8775 ft where it tagged up. No cement was observed. Punched tubing at 8726 - 8728 ft based on SCMT log. Established circulation with 2.7 bpm at 750 psi. Pumped approx. 35 bbls. Ran in hole and fired a jet cutter at 8723 ft. Currently RD eline. The immediate plan ahead is to rig down the eline unit and screw back in with the top drive. This will allow us to work both torque and tension into the string to see if we can move the freepoint deeper and possibly free the pipe at the cut. If freeing the pipe at the cut becomes impossible/impractical our next suggested course of action would be to pump cement through the cut & perfs as our second P&A plug. We would then recover the DP from a shallower depth and continue with planned P&A operations. We would like to point out that we feel that the first plug has been laid in successfully based on the job log and also on the 2" drift tag at 8817 ft. We will keep you updated on our progress and inform you of our ultimate plans for your approval as more information becomes available. Regards Philip 10fl 3/16/2005 12:40 PM ~~~,.. s:;-? .!À\A' ? '.. ,.1.6. ,~ , ", i' U\ 1 ¡ ¡ ®ULruULb . f-:-";--' i"':l II~ ¡ r /.8\. ï! !! F 11\1 ~W u'U . h;l~~s1 AI,ASHA. OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Exploration Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Iapetus #2 Sundry Number: 305-067 Dear Mr. Mazzolini: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. /,,<",; Sincerely y ¿--.:/ ¿ \¿~;=..._.~~/'// ,f, JofuJ. K. Norman Chairman DATED this~y of March, 2005 Encl. Conoc~hillips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Philip Hayden Phone (907) 265-6481 Email: Philip.Hayden@conocophillips.com March 9, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry approval to Plug and Abandon: Iapetus 2 Surface Location: Secondary Target (Brookian Sand): Primary Target (Nechelik sand): Bottom Hole Location (Planned): 2445' FNL, 3289' FEL, Sec. 8, T12N, R4E, UM 3811' FNL, 2033' FEL, Sec. 7, T12N, R4E, UM 3779' FNL, 2533' FEL, Sec. 7, T12N, R4E, UM 3741' FNL, 3123' FEL, Sec. 7, T12N, R4E, UM Dear Sir / Madam ConocoPhillips Alaska, Inc. would like to permanently plug and abandon the Iapetus 2 well bore, located in the Colville River delta. Doyon 19 spudded this well on 2/25/05 and TD'd the well on 3/6/05. The attached Sundry and back-up information describes the P&A procedure for the existing wellbore and has been discussed with AOGCC personnel. If you have any questions or require any further information, please contact me at 265-6481 or Paul Mazzolini at 263-4603 Sincerely, P. 1\ _ I J___ PhiJIP~'-' Drilling Engineer CC: CONFIDENTIAL Paul Mazzolini Mike Morgan Iapetus 1 Well File ATO-1570 ATO-1438 RECEIVED MAR 0 9 2005 Aluka Oil & Gas ConI. Commission Anchorage OR'Gtl~AL · STATE OF ALASKA . RECEIVED ALASKA OIL AND. GAS CONSERVATION COMMISSION MAR 0 9 2005 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 å a~ka Oil & G,s Cons. Commission 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): 42.5 ft above MSL 11. Total depth MD (ft): Total Depth TVD (ft): 9300 7689 Casing Length Size Conductor 121 16" Surface 2467 9 5/8" 204-254 6. API Number: 50-1 03-20506-00 9. Well Name and Number: Iapetus 2 10. Field/Pool(s): Exploratory PRESENT WELL CONDITION SUMMARY TVD ADL 388465 I 390344 I 390350 MD 155 2501 TVD Burst Collapse Perforation MD Perforation Tubing Size: N/A Tubing Grade: N/A Tubing MD (ft): N/A Packers and SSSV Type: NIA Packers and SSSV MD (ft) NIA Conditions of approval: Notify Commission so that a representative may witness SUndry Numbe~~¿>S:'¿;;6 ? Plug Integrity~ Test D Mechanical Integrity Test D Location Clearance .'¢. Other: <:.c""C>c.-\. ~~~1è..~{ ÅC, -\ú~~~ ,,\~, ~ d ~ c.~cæ -) RBDMS 8Ft MAR 1 7 2005 Subsequent Form Required: '-\0" OrIginal Signed By DAN SEAMOUNT o I L_ BY ORDER OF THE COMMISSION ~ Date:3/16~ Approved by: COMMISSIONER Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate . Iapetus 2 P&A . RECEIVED MAR 0 9 2005 Summary: Iapetus 2 well was spudded 1315 hrs on 2/25/05 and TD'd on 3/6/05. After running e-line logs the wellbore is to be P&A'd. Please see the attached wA¥ftI(iOil & Gas Cons. Commission schematic for details. Anchorage 1. Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Mobilize and rig up D/S for well P&A operation. 3. RIH with cement stinger to TD. Condition the mud for cementing operations. Spot a balanced cement plug from TD at 9300' MD to 8400'MD (approx. 300' above top of the Kuparuk interval at 8712' MD). This plug will be laid in two 450' intervals. Total cemented interval is planned to be approximately 900' in length. This will cover the two sand packages penetrated in the well (9130' to 8790' MD & 8728' to 8712' MD) WOC and prepare to tag top of plug with AOGCC representative as witness. <~'-U:)<>~ ~ ':,\J<Õ"'~ }271r 4. By the down squeeze method through a retainer set 50' minimum above the shoe (or approx. 2440' MD) pump cement plug #3 as per AOGCC regulations. Pump sufficient cement through the retainer to extend 160' below (60' of casing volume plus 100' of open hole) and lay a 50' cement cap on top of the retainer. Weight test retainer before pumping cement. Not required to tag the plug. Leave 10.5 ppg mud above and below the plug.(Weight of mud needed to TD the hole) ·~·'.l S ~'1- 'Ñ '~~S ~1yv1 5. Spot a viscosified mud gel pill from 500' to 300'. Spot a balanced Arctic Set 1 cement plug #4 from 300' to surface. . ''2~n. (' ~ ~'J ">-r- ow ~ 'L <) ~~ 6. Clear lines and shut down pumps. Rig down cementing unit and clean up. 7. Cut off wellhead and all casing strings at 3 feet below ground level. Send casing head with stub to Materials for repair / re-dressing. 8. Weld cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top: ConocoPhillips Alaska, Inc. Iapetus #2 PTD# 204-254 API# 50-103-20506-00 9. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and de mob all materials and equipment. J~Q Exploration Drillin .1/ ¡; f~Jtt6-~t-/2.Ì1; 16.. 63# @ +/- 155' MD Surface csg. 95/8" 40.0# L-80 BTC 2501' MD / 2258' TVD Current Status 1 8 W' hQle to TD @ 9300' MD / 7689' ND { - All depths are referred to RKB Plug 4: ARCTICSET 1 Weight: 15.7 ppg Plug 3: Class G + Add. Weight: 15.8 ppg Plugs 1 & 2: Class G + Add. Weight: 15.8 ppg Surface csg. 2501' MD / 2258' TVD Top @ 8712' MD / ND Btm @ 8728' MD / TVD Top @ 8790' MD / TVD Btm @ 9130' MD TVD Planned P&A TOC @ 45' MD TOC @ 2390' MD Cement retainer @ 2440' MD BOC @ 2610' MD 10.5 ppg mud TOC @ 8400' MD 8 Yz" hole to TD @ 9300' MD / 7689' ND BOC @ 9300' MD TRANSMITTAL TO: AOGCC 333 W 7TH AVE Anchorage, AK 99501 OPERATOR: CPA I SAMPLE TYPE: DRIES SAMPLES SENT: IAPETUS 2 r ~ /' Dries 120-9300 SENT BY: Mike McCracken DATE: 03-15-05 AIRBILL: 53254508 CPBV 05-03-15-16 CHARGE CODE#: 10058689 WELL: IAPETUS 2 NUMBER OF BOXES: 1 Bdl (9bxs) ~ ... 1 S UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED BY: /1 t~' ~lj ConocoPhillips Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Dan Przywojski DATE: 'r-~Â6 ~)- SCANNED JUN 0 6 2007 !3:~frI- ~ç- '1 Re: Iapetus 2 BOP test extension - . ;¿Ol-\ - ~S L\ Subject: Re: Iapetus 2 BOP test extension From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 15 Mar 2005 15:52:15 -0900 To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us>, AOGCC North Slope Office <aogccyrudhoe _ bay@admin.state.ak.us> Philip, Your request is appropriate. Please keep us advised of your progress. Note, this is not a "blanket" extension until all operations are completed on Iapetus. Tom Maunder, PE AOGCC Hayden, Philip wrote: Tom, As discussed on the phone we still have stuck pipe in the hole that we are working to free. Our BOP test is due tomorrow, Wednesday 3/16, and we kindly ask for an extension of this test due to the current difficulties. I will keep you updated as we progress. Regards Philip 1 of 1 3/15/20054:31 PM AOGCC Iapetus 2 Weekly update #33/10/2005 e . Subject: AOGCC Iapetus 2 Weekly update #3 3/1012005 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> Date: Thu, IOMar200513:25:34-0900:)O L\, - ~~ To: tom_maunder@admin.state.ak.us CC: "Mazzolini, Paul" <Paul.Mazzolini@conocophillips.com>, "Brassfield, Tom J" <TOM.J .Brassfield@conocophillips.com> 3/6 2300hrs: Drilled 8 1/2" hole to TO at 9300 ft MD (7689 ft TVD) 3/8 0900hrs: Began logging operations with Run #1: DSI-Density-Caliper 3/8 2400hrs: Completed Run #2 with MSCT 3/9 0530hrs: Finished BOP test 3/9 2230hrs: Completed Runs #3 & 4 with MSCT 3/9 2400hrs: WOW The plan ahead is as follow: A wiper trip to TO as soon as weather permits but hopefully completed 3/11. Logging run #5 with MDT on drill pipe 3/11-12 P&A beginning 3/12 Please let me know if you need any more information. Regards Philip 1 of! 3/10/20051:39 PM · STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Bm re.QQ(á¿admín.state.ak.us ao.Qcc prudhoe bay(Ç2admin.state.ak.us bob f1eckenstein(á¿admin .state .ak. us Rig No.: 19 DATE: 3/9/2005 Rig Phone: 670-4302 Rig Fax: 670-4303 Op. Phone: 670-4300 Op. Fax: 670-4301 11/09/04 Contractor: Doyon Rig Rep.: Welsh/Grazulis Operator: Conoco Phillips Alaska Rep.: Burley/ Mickey Field/Unit & Well No.: Iapetus #2 Operation: Test: Test Pressure: Drlg: X Initial: Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 2 1 o Well Sign Dr!. Rig Hazard Sec. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Size 13-5/8 3-1/2x 6 3-1/2x 6 blinds 3-1/8 3-1/8 3-1/8 MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Alarm Test P P P P P e PTD # 204-254 Workover: Weekly: X Annular: 250/3500 TEST DATA Test Result P P P Test Result P P P P P P P NA Explor.: Bi-Weekly Valves: 250/5000 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Closure 1450 P 200 psi Attained 35sec P Full Pressure Attained 3 min 10 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2300 Test Results Number of Failures: º Test Time: 3.0 Hours Components tested 28 Repair or replacement of equipment will be made within Immedeatly days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Bm re.Qg(á¿admin.state.ak.us Remarks: Test chokemanifold durinq wireline operation - Tst went qood. 24 HOUR NOTICE GIVEN YES X NO Date 03/08/05 Time Waived By 9:10:00PM John Crisp Witness Test start 2:00AM 3-9-0 Finish /9/05 5:00: AM BOP Test (for rigs) BFL 11/09/04 Ed Grazulis Doyon19 03-9-05 Iapetus #2.xls Iapetus #2 P&A e e Philip, Sorry I missed you when you dropped the sundry off. I have examined the document and it repeats (as expected) the information you sent over earlier. By copy of this email, you have "verbal" approval to proceed with the abandonment as planned. Please have the Company Representative contact the Inspector to witness the tag of plug #2 and the cutoff prior to welding on the plate. If for some reason the Inspector cannot come out to view the cutoff, have the Company Rep take some digital photos for documentation. Please call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 12/22/2005 1: 17 PM Iapetus 2 BOP test extension e e Tom, We have TO'd Iapetus 2 last night at approximately 9300 ft MO /7689 ft TVO. We plan on being out of hole not long after lunch today. We will begin our wireline logging operations then. We forecast our logging operations to last through 'tillate Wednesday / early Thursday. These include (at the moment!) one run with dipole sonic on wire, two runs with rotary sidewall cores on wire and an MDT run, at the moment conservatively planned to be run on pipe. After the MDT run we will P&A the well as originally planned (sundry notice being prepared). As this plan puts us beyond our required BOP test date of tomorrow, Tuesday 3/8/2005 we kindly request an extension of our BOP test until the logging programme is complete. In effect this would eliminate this BOP test as the well would be P&A'd immediately after the last log was run. Regards Philip 1 of 1 12/22/2005 1:13 PM RE: AOGCC Iapetus 2 Weekly update #2 3/4/2005 e e As of this morning the plan is to drill 8 1/2" hole to TO and then run logs. There are no cores planned for this well. Assuming things go well from here on out we would be looking at P&Aing late next week/next weekend. That would put the rig on the road the week beginning March 14. Philip -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 04, 2005 8:39 AM To: Hayden, Philip Subject: Re: AOGCC Iapetus 2 Weekly update #2 3/4/2005 Thanks Philip. What sort of remaining schedule do you see?? I forget if there were any cores planned. Thanks, Tom Hayden, Philip wrote: 2/24 1500hrs: Accepted rig and NU diverter system 2/25 0100hrs: Function test diverter with AOGCC witness (Chuck Scheeve) 2/25 1315hrs: Spud Iapetus 2 2/26 1900hrs: Drilled 121/4" surface hole to casing point at 2511 ft MO (2267 ft TVD) 2/28 1200hrs: Ran and cemented surface casing. 78 bbls of good cement back to surface 1/3 0130hrs: Finished BOP test with AOGCC witness (Chuck Scheeve) 2/3 0230hrs: Pressure tested surface casing to 3500 psi for 30 minutes 2/3 0700hrs: Drilled out surface casing and performed FIT to 16.4 ppg equivalent 3/3 2400hrs: Drilling 8 1/2" hole at 5988 ft MD (5000 ft TVD) Please let me know if you need any more information. Regards Philip ~w .""~ ~c.~ 1 of 1 12/22/2005 1:10 PM e STATE OF ALASKA e OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Jim reQg~admín_state.ak.us ao~cc prudhoe bay@admin.state.ak.ti5 bob fieckenste¡n~admín_state.ak.us Rig No.: 19 DATE: 3/1/2005 Rig Phone: 670-4302 Rig Fax: 670-4303 Op. Phone: 670-4300 Op. Fax: 670-4301 11/09/04 Contractor: Doyon Rig Rep.: Krupa/Grazulis Operator: Conoco Phillips Alaska Rep.: Hill / Thorton Field/Unit & Well No.: Iapetus #2 Operation: Test: Test Pressure: Drlg: X Initial: X Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 2 1 o Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Well Sign Dr!. Rig Hazard Sec. Size 13-5/8 3-1/2x 6 3-1/2x 6 blinds 3-1/8 3-1/8 3-1/8 Alarm Test P P P P P PTD #204-254 Workover: Weekly: Annular: 250/3500 TEST DATA Test Result P P P Test Result P P P P P P P NA Explor.: Bi-Weekly Valves: 250/5000 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Closure 1350 P 200 psi Attained 40 see P Full Pressure Attained 3 min 40 see P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2350 Test Results Number of Failures: ~ Test Time: 5.5 Hours Components tested 28 Repair or replacement of equipment will be made within Immedeatly days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: nm reQg~admín.state.ak.us Remarks: Serviced HCR choke and Manual choke - re-tested and passed 24 HOUR NOTICE GIVEN YES X NO Date 02/26/05 Time Waived By 9:00:00AM Witness.d Grazulis / Chuck Schev Test start i:OOPM 2-28-( Finish /1/05 1 :30: AM BOP Test (for rigs) BFL 11/09/04 Doyon19 03-1-05 Iapetus #2.xls Re: Iapetus 2, 2/25/05 L WD logs under the conductor e e Philip, This shouldn't be a problem. I suspect that the missing interval is similar to that drilled in other nearby wells. Good luck with the well. Tom Maunder, PE AOGCC Hayden, Philip wrote: Tom, As per our telephone conversation this afternoon I would like to inform you that we have spudded Iapetus 2 today. I would also like you to know that since we first had to clean out the conductor and drill some hole before picking up our logging suite we will not be logging the first 70-80 ft of hole under the conductor. Regards Philip 1 of 1 ~,,&J ~~~ 12/22/2005 1 :08 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Submit to: torrU11i3.unde:@admin.state.ak.us aogcc...prudhoe...bay@admìn.state.ak.us b<;b...f:E:ckenstE;in@,~dm¡n. statø .ak. U~; Date: 25-Feb-05 Exploratory: x 204-254 Rig Ph. # 670-4300 Drlg Contractor: Doyon Operator. Conoco Phillips Alaska Inc. Field/Unit & Well No.: Exploratory I Iapetus #2 Location: Sec. 8 1. T12N R. ........ . ....... ,_. ........... . . . . . . . . . . . . . . ........... . ..... ,_...... .... ....... ......... . ......... . . . . . . . . . . - . . . . . . . . . . . . . . . . . . . . ......... . ....... -.. . . . . . . . . . . . . . . . . . . . . ..... -... . .. ... ........ -,.. . . . . . . . . . . .. . .. ............ . ......... . MISC. INSPECTIONS: Location Gen.: OK Housekeeping: P Reserve Pit: N/A Well Sign: (Gen.) Drlg. Rig: Flare Pit: DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 16 Vent Line(s) Length: 85 Line(s) Bifurcated: N/A Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted I Long Radius: N/A in. in. ft. . . . . . . . . . . . . . . . ...... ......... ........ ......' ............. .. ............. .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ...".... ...... .......... . ........,;.. . ............ . ............. ........... .............",.,..... ' ,.. ,.......,. ...,...... . . , , . . . . . . . . . .......... . ........ . Operation: Rig No. Oper. Rep.: Rig Rep.: R4E Development 19 PTD # Hill / Thorton Krupa I Lupton Merdian UM :::Jtl!;$t:D.ÄTAIH. . .....,........ . . . . . . . . , . . . . . . . ....,....... " . . . . . . . . . . . . . . . ............. . .......,...,.. . ....., ........ .............. . . . . . . . . . . . . . . . . ..... ... ........ . ........ . ,... . P P N/A ACCUMULATOR SYSTEM: Systems Pressure: 2850 psig Pressure After Closure: 1500 psig 200 psi Attained After Closure:_ min ~ sec. Systems Pressure Attained: ~ mim 35 sec. Nitrogen Bottles: 4 @ 2300 psi average MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: GAS DETECTORS: Methane Hydrogen Sulfide: ....,.....,... . ..,......... . ......... . "...... . :....b.IS/ÊRTERscHÊMAiîê ...,..,..........,................ . ....,.,............,.,..,.......... . .. IRIG 19 SUB Non Compliance Items --2....- Repair Items Withir Remarks: Test went good Diverter Test (for rigs) BFL 11/20100 II Div. Vent line I þ psig Light P P P Alarm P P P Light P P Alarm P -p ....,..... . . . . . . . . . . . . .,....... . .......... . ......... . . . ... ... .......... . . , . . . . . . . . . . . . . . . . . . . . .. . ....... ... ..........., ........ ............ .,.. .... ...... N/A Day (5) And contact the Inspector @ 659-3607 AOGCC REP.: Chuck Scheve OPERATOR REP.: Hill I Thorton Diverter Test Iapetus #2 Doyon 19, 2-25-05.xls AOGCC Iapetus 2 Weekly update #12/24/20_ Subject: AOGCC Iapetus 2 Weekly update #12/24/2005 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> Date: Thu, 24 Feb 2005 16:36:53 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Mazzolini, Paul" <Paul.Mazzolini@conocophillips.com> e ;¡OL\-ðSL\ 2/16 1500hrs: Doyon 19 released from Alpine drilling to exploration. Preparing rig for move while also waiting on ice road and pad completion. 2/19: Ice road & pad completed. Conductor installed (last joint of conductor driven after encountering water at approximately 70ft below ground level. Conductor cemented from 50ft below ground level to surface ). 2/19 2300hrs: Begin moving rig to Iapetus 2 location. 2/23 2200hrs: All rig modules located on pad. Spud planned for 2/24 Please let me know if you need any more information. Regards Philip I of I 2/25/2005 8:03 AM ~ . ~ u!Æ1f ;--"'! lID ¡--"' ~ ï r:;¡ .~ J. n ru I .. ' ¡ r fA; J.ni' : ¡ . i å\ ¡ Le OrF fiJ~~~:~ . . AI,~"1iA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Exploration Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Iapetus #2 ConocoPhillips Alaska, Inc. Permit No: 204-254 Surface Location: 2445' FNL, 3289' FEL, SEe. 8, TI2N, R4E, UM Bottomhole Location: 3741' FNL, 3123' FEL, SEC. 7, TI2N, R4E, UM Dear Mr. Mazzolini: 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. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (TIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10,-403 AD prior to the approval of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Your application indicates that flow testing is unlikely, however if flow testing should be determined necessary a Sundry Application (Form 403) detailing the planned activities should be submitted for approval. At the end of operations, a Sundry Application (Form 403) for P&A or suspension (if desired) should be submitted for approval. 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. ase provide at least twenty-four (24) hours notice for a representative of the Commissio to witness any required test. Contact the Commission's petroleum field inspector at (907) 65.:.3 - (pager). DATED thisi day of January, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation wlo encl. Conoc~hillips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Philip Hayden Phone (907) 265-6481 Email: Philip.Hayden@conocophillips.com December 22, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill: Iapetus 2 (Exploratory Test) Surface Location: Secondary Target (Brookian Sand): Primary Target (Nechelik sand): Bottom Hole Location (Planned): 2445' FNL, 3289' FEL, Sec. 8, T12N, R4E, UM 3811' FNL, 2033' FEL, Sec. 7, T12N, R4E, UM 3779' FNL, 2533' FEL, Sec. 7, T12N, R4E, UM 3741' FNL, 3123' FEL, Sec. 7, T12N, R4E, UM Dear Sir / Madam ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, Iapetus 2, from the location referenced above approximately 8 miles Northwest of Alpine. This well will be accessed via ice road originating from either CD-lor CD-2 pad on the Alpine field and will be drilled with Doyon Rig 19. As indicated in the attachments the drilling program will entail an 8 112" well bore through the objective with a full logging suite for evaluation. As a contingency ConocoPhillips plan to run a 7" casing should the need arise. There are no plans to test post-rig. 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 drilling rig as is the standard operating procedure in the Colville River Unit drilling operation. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005 for this well. The following are ConocoPhillips designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 MC 25.070) 263-4612 2) Geologic Data & Logs Beverly Burns, Geologist (20 MC 25.071) 263-4978 The planned spud date for this well is 02/15/2004. If you have any questions or require any further information, please contact Philip Hayden at 265-6481 or Paul Mazzolini at 263-4603. r 111 j , RECEIVED DEC 2 3 2004 Alaska Oil & Gas Cons. Commission Anchorage CC: CONFIDENTIAL Paul Mazzolini Mike Morgan Iapetus 1 Well File ATO-1570 ATO-1438 . . ft-\ / '-\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of Work: Drill 0 Redrill U Re-entry 0 /1 b. Current Well Class: Stratigraphic Test 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. location of Well (Governmental Section): / Surface: 2445' FNL, 3289' FEL, Sec. 8, T12N, R4E, UM Top of Productive Horizon: Exploratory~ Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: Blanket 0 Single WellO 11. Well Name and Number: Bond No. 59-52-180 Iapetus 2 6. Proposed Depth: 12. Field/Pool(s): '" / MD: 10035' TVD: 8300' Exploratory 7. Property Designation: ADL 388465 I 390344 I 390350 8. land Use Permit: 13. Approximate Spud Date: 3779' FNL, 2533' FEL, Sec. 7, T12N, R4E, UM NIA 2/15/2005 Total Depth: / 9. Acres in Property:,. / / 14. Distance to Nearest 3741' FNL, 3123' FEL, Sec. 7, T12N, R4E, UM 1157 I 839 I 441 Property: 1350' @ Surface 4b. location of we'y~~~~ Plane Coordinates): {. ~C¡, ~_.ój.- 10. KB Elevation 15. Distance to Nearest Well Surface: x- J~ y- ~ Zone- 4 (Height above GL): 36.5 feet Within Pool: None, 16. Deviated wells: Kickoff depth: 500 - feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 37.77 deg Downhole: 4316 Surface: 3403 /' Setting Depth Quantity of Cement c. f. or sacks (including stage data) 500sx Artic Set I 390sx ASLite, 170sx DeepCRETE 290sx Class G I Perforation bePth TVD (ft): Drilling Program0 Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: 18. Casing Program: Specifications Size Hole Casing Weight Grade Coupling length 24" 16" 62.5# H-40 Weld 80 12.25" 9.625" 40# L-80 BTC 2450 8.5" 7" 26# L-80 STCM 10000 19 Total Depth MD (It): PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Perforation Depth MD (ft): 20. Attachments: Filing Fee 0 Property Plat 0 BOP SketchO Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Paul Mazzolini ?~0~ Top Bottom MD TVD MD TVD 35 35 115 115 35 35 2485 2244 35 35 10035 8300 (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 Contact Philip Hayden @ 265-6481 Title Exploration Drilling Team Leader Phone Z'-~-4føo3 Date /Z'¡Z:Z"/ZD64 o Permit to Drill ,'/ Number: 2-0:"" 2.5Y/ Conditions of approval : Commission Use Only I API Number: . / Permit Approval , / 50-/03-ZC1S-ó6-tX:J Date: 1/1/tJS see cover letter for other requirements Yes g No 0 Mud log required Yes ~ No 0 gen sulfide measures Yes '!8j No 0 Directional survey required Yes ~ No 0 O1ho, 5"~ \SO ~ ~," ,...\q ">" \ ~ '\ ~"'~;R;'~:~~'<" ,\~ j~ï. ~-"" APprovkbV~ THE COMMISSION Date: í J. ~ Form 1 0-401 Revise~2004 0 RIG I N A L Submit in Duplicate · . Application for Permit to Drill, Iapetus 2 Revision No.O Saved: 21-Dec-Q4 Permit It -Iapetus 2 Application for Permit to Drill Document Moximize Welll/olue Table of Contents 1. Well Name ............... ........ ....... ... .............. .... .......... ...... .......... ............... ....... ......... ..... 2 Requirements of 20 AAC 25.005 (f)........................................................................................................ 2 2. Location Sum mary ........ ........ ................... ............ ...... ........ ........................ ..... ......... 2 Requirements of 20 AAC 25.005(c)(2) .. ....................... ........................ ......... ........... ......... .............. ....... 2 Requirements of 20 AAC 25. 050(b)............ ..................... ....................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ........................................... ............... ......................................... 3 4. Dri II i ng Hazards Information ........ ....................... ....... .......... ................... ........... ..... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program............................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ..... ................ ................. ............... ....... ..................... ..... ............. 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25. 005( c)(7) .. .......... ................ ....... ........... ..................... ....... ....... ............ ...... 4 8. Dri II i ng FI u id Program ..... ...... .......................... ........ ..... ... ............ ............................ 5 Requirements of 20 AAC 25.005(c)(B) ........... ................................ .............. ............. ............................. 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis............ ....... ....................... ...... ..... ....... ........... ...... ..... ..................... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ......................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................6 12. Evidence of Bonding ...............................................................................................6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 Page 1 0'8 Printed: 21-Dec-04 ORiGINAL . . Application for Permit to Drill, Iapetus 2 Revision No.O Saved: 21-Dec-04 13. Proposed Drilling Program ......................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................8 15. Attachments .. .................... ........ ........... .......... ............... ... ....... ......... ............. .............. .......... ...... ... 8 Attachment 1 Directional Plan (8 pages) ................................................................................................ 8 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 8 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 8 Attachment 4 Seismic Pore Pressure Analysis (20 pages) .................................................................... 8 Attachment 5 Well Schematic (1 page) .................................................................................................. 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified bya unique flame and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as Iapetus 2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pem¡it to Drill must be accompanied by each of the following item~ except for an item already 017 file wIth the commission and identified in the application: (2) a plat identifying the property and the properly's owners and showing {A)the coordinates of the proposed location of the well at the surfac~ at the top of each objective formatiol7, and at total depth, referenced to govemmental :,-ectiofllines. (B) the coordinates of the proposed location of the well at the surfac~ referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; The NGS coordinates are ASP 4 & NAD83. Location at Surface NGS Coordinates Northings: 6,000,375 Eastings: 1,494,565 2445' FNL, 3289' FEL, Section 8, T12N, R4E, UM I RKB Elevation I 49.5' AMSL Pad Elevation 13' AMSL Location at Top of Secondary Target (Brookian Sand) NGS Coordinates Northings: 5,999,088 3811' FNL, 2033' FEL, Section 7, T12N, R4E, UM Eastings: 1,490,520 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8,055 6,650 6,600 ui'~IGiNAL Page 2 of 8 Printed: 21-Dec-04 . . Application for Permit to Drill, Iapetus 2 Revision No.O Saved: 21-Dec-Q4 Location at Top of Primary Target (Nechelik Sand) NGS Coordinates Northings: 5,999,130 Eastings: 1,490,021 3779' FNL, 2533' FEL, Section 7, T12N, R4E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8,932 7,370 7,320 Location at Total Depth NGS Coordinates Northings: 5,999,180 Eastings: 1,489,431 3741' FNL, 3123' FEL, Section 7, T12N, R4E, UM Measured Depth, RKB: 10,035 Total Vertical Depth, RKB: 8,300 Total Vertical Depth, 55: 8,250 and (D) other information required by 20 AAC 25.050{b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Pe¡m¡t to Drill (Form 10-401) must (l) include a plot drawn to a sUitable scale, showing the path of the proposed wellbore, including all adjacent well bores within 200 feet of any portion of the proposed well," Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells; to the extent that those names are known or discoverable in public records~ and show that each named operator has been furnished a copy of the application by certified mail/ or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and Identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25. 03~ 20 AAC 25.03~ or 20 AAC 25.037, as applicable; An API 13 5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete Iapetus 2. Please see information on the Doyon Rig 19 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pem7it to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) info¡mation 017 drilling hazards, ineluding (A) the maximum downhole pressure that may be encountered, criteria used to deter/mile it and maxlÌTlum potential surface pressure based 017 a methane gradient/ The expected maximum pore pressure is 0.52 psi/ft, or 10.0 ppg EMW (equivalent mud weight). This / pressure was predicted based on seismic velocity analysis and offset data. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the well is 3403 psi, calculated as follows: / MPSP = (8300 ft)(0.52 - 0.11 psi/ft) = 3403 psi ' (B) data on potential gas zones; ORIGINAL Page 3 of 8 Printed: 21-Dec-04 . . Application for Permit to Drill, Iapetus 2 Revision No.O Saved: 21-Dec-Q4 None. and (C) data conceming potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone~ and zones that have a propensity for differential sticking/ Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Pemlit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identitied in the application: (5) a desc:ription of the procedure for conducting formation integrity tes~ as required under 20 MC 25.030(f),' Iapetus 2 will be drilled with 9 5/8" surface casing landed in a competent shale/mudstone above the C-30 interval. The casing shoe will be drilled out and a leak off test will be performed in accordance with the "Leak Off Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Pemlit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and Identitied in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030.. and a description of any slotted line~ pre- perforated line~ or screen to be installed/ Casing and Cementing Program See also Attachment 3: Cement Summary Ho/e Size (in) 24 Top MD/TVD (tt) 35 / 35 Btm MD/TVD (tt) 115 / 115 CsglTbg 00 (in) 16 Weight (/bltt) 62.5 Length (tt) 80 Grade H-40 Connection Welded 9 5/8 12 V4 40 L-80 BTC 35 / 35 2485 / 2244 2450 7 8 V2 26 L-80 BTCM 35 / 35 10035 / 8300 10000 Cement Program Cemented to surface with ==500 sx Artic Set! Cement to Surface with 390 sx ASLite Lead, 170 sx DeepCRETE Tail Cement Top planned @ 8400' MD / 6928' TVD. Cemented w/ 290 sx Class G 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) All application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on tile with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 03~ unless tllis requirement is waived by the commission under 20 MC 25.035(h)(2),· A 21 V4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of Iapetus 2. Please see diagrams of the Doyon 19 diverter system on file with the Commission. ORIGINAL Page 4 of 8 Printed: 21-Dec-04 . . Application for Permit to Drill, Iapetus 2 Revision No.O Saved: 21-Dec-04 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Pemlit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fiuid system,as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Surface Hole (KCIIPolymer/Klagard) Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 10.0 10.0 10.0 10.0 Funnel Viscosity 75 - 90 75 - 90 75 - 90 75 - 90 (seconds) Yield Point (cP) 40-60 40-60 40 - 60 40 - 60 Plastic Viscostiy 12 - 18 12 - 18 12 - 18 12 - 18 (/b1100 sf) 10 second Gel 15 - 25 15 - 25 15 - 25 15 - 25 Strength (lb1100 sf) 10 minute Gel 39 - 50 39 - 50 39 - 50 39 - 50 Strength (lbI100sf) pH 9.0 - 9.5 9.0 - 9.5 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) <8 <8 <8 <8 Chlorides <28,000 <28,000 <28,000 <28,000 Solids (%) 5-8 5-8 5-8 5-8 Intermediate/Production (KCIIPolymer/Klagard) Density (ppg) Yield Point (cP) Plastic Viscostiy (lb1100 sf) Chlorides pH API Filtrate(cc) MBT Solids ppb Initial Value 10.5 25 - 35 10 - 15 28 - 32000 9-9.5 <6 8 - 10 8 - 11 Final Value 10.5 - 10.8 25 - 35 10 - 15 28 - 32000 9-9.5 <6 8 - 10 11 - 17 /' Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 19. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f),· Anticipated geologic markers, depth uncertainty, fluid properties and pore pressures are as follows: ORIGINAL Page 5 of 8 Printed: 21-Dec-04 . . Application for Permit to Drill, Iapetus 2 Revision No.O Saved: 21-Dec-Q4 Formation Depth Uncertainty Possible Fluid PP Estimated (TVD-SS) Type (psi) Permafrost - Base 960 100 C40 2070 75 C30 2330 75 C20 2670 75 K-3 3765 75 Brookian Sand 6600 100 Oil/Gas 3430 ,- Base HRZ 7110 75 K1 Marker 7160 60 LCU Kuparuk Sands 7235 75 Oil/Gas 3760 Nechelik Sands 7320 75 Oil/Gas 3810 " Total Depth 8300 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratOfY or stratigraphic test we/~ a seismic refraction or reflection analysis as required by 20 MC 25.061(aJ· Please see Attachment 4: Seismic Pore Pressure Analysis 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a PermIt to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the applicatíon: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vesset an analysis of seabed conditions as required by 20 MC 25.061{b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on tile with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on tile with the commission and identítied in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Doyon Rig 19 over preinstalled 16" conductor casing. 2. NU diverter and function test same. Notify regulatory agencies prior to test. 3. Spud and directionally drill 12 %" hole to casing point at 2485' MD / 2244' TVD as per the directional plan. Run MWD tools as required for directional monitoring and LWD tools as required for data acquisition. (see Data Acquisition Plan below). / 4. Circulate and condition well bore. Perform short trip if required. POOH to run casing. 5. Run and cement 9 5/8", 40# L-80, BTC casing to surface. Page 6 of 8 Printed: 21-Dec-04 ORIGINAL . . Application for Permit'to Drill, Iapetus 2 Revision No.O Saved: 21-Dec-Q4 Note: Light weight permafrost cement lead slurry and Dowell DeepCrete high compressive, lightweight tail slurry will be used to ensure 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. A top job may be performed if required and after consulting with the AOGCC. 6. Remove diverter system and install wellhead and test. Install and test 13 5/8" x 5,000 psi SOPE and test to 5000 psi (annular preventer to 3500 psi). Notify AOGCC 48 hrs before test. , , 7. PU directional drilling assembly with MWD and LWD. RIH and clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. Notify AOGCC 48 hrs before test. 8. Drill out cement and 20' of new hole. Perform LOT or FIT to 16.0 ppg EMW recording the results. These test results must demonstrate that the integrity of the casing shoe will be sufficient to contain the anticipated well bore pressures. 9. Directionally drill 8 W' hole to TD at +1- 10035' MD I 8300' TVD as per the directional plan. Run MWD tools as required for directional monitoring and LWD tools as required for data acquisition (see Data Acquisition Plan below). In case of wellbore instability a 7" 26# L-80 STCM intermediate casing may be set before reaching TD to isolate unstable shales from the target intervals. In this case a 61/8" hole will be drilled to TD. / 10. Circulate and condition the well bore. Perform short trip if required. POOH to run open hole logs. 11. RU e-line unit. RIH and log well as required (see Data Acquisition Plan below). RD e-line unit. 12. RIH with cement stinger and set cement abandonment plugs as per AOGCC requirements. Notify AOGCC 48 hrs prior to P&A. 13. LD drillpipe, ND SOPE and prepare rig for move. 14. Move rig off location. 15. Recover wellhead, notify AOGCC to witness cutoff and welding P&A marker plate. Thoroughly clean location and block off further ice road access to ice location. Note: In the unlikely event that the well will be completed and flow tested it will be subsequently plugged and abandoned as per AOGCC regulations before the end of the ice road season. Data Acauisition Plan Anticipated logging, coring and testing for this well is as follows: I Logging 12 1'4" S rf I t I I' U ace n erva I LWD: GR/Res Please note that with this planned logging suite ConocoPhillips is requesting a waiver from the requirement to provide logs that prove the absence of a fresh water aquifer at the proposed drilling location. ConocoPhillips feel these logs are unnecessary based on experience in the area at the Nechelik, Temptation and Nigliq wells. 8 V2" Production Interval LWD: E-Line / DP Conveyed: Success Case: GR/Res/Den/Neu / DSI DSI/MDT/Rotary Side Wall Cores II Coring None planned. Page 7 of 8 Printed: 21-Dec-04 ORIGINAL . . Application for Permit to Drill, Iapetus 2 Revision No.O Saved: 21-Dec-Q4 III Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TO. v Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography and H2S detection. Sixty foot (60') USGS Gas Hydrate Samples will be collected from Surface to 3000' MD-RKB Thirty foot (30') wet and dry samples will be collected from surface to surface casing point Thirty foot (30') wet and dry samples will be collected from surface casing point to TD Ten foot (lO') wet & dry samples, or continuous, collected across all shows and all target intervals ,/ IV Flow Testing Currently ConocoPhillips has no plans to complete and test the Iapetus 2 well. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following itemSr except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; 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). All cuttings generated may be first stored on the pad before being disposed at a permitted disposal facility at Kuparuk, Prudhoe Bay or Alpine. If an intermediate casing string is run ConocoPhillips may request approval to inject or dispose of fluids in the Iapetus 2 95/8" x 7" annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's AAC 25.080. 15. Attachments Attachment 1 Directional Plan (8 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Seismic Pore Pressure Analysis (20 pages) Attachment 5 Well Schematic (1 page) ORIGINAL Page 8 of 8 Printed: 21-Dec-04 . . Standard Planning Report c . ·~Ph····' ····1·1· Conoco . · I.. IPS ConocoPhillips Alaska Inc. Exploration 2005 (Iapetus) Iapetus Iapetus 2 Iapetus 2 Plan: Iapetus 2 (wp04) 07 December, 2004 Of~ G1NAL Galcu!atlon lVIethod: Error System: Scan Method: Error Surface: Warning Method: Minimum Curvature !SGWSA Elliptical Conic Rules Based Trav. Cylinder North o lD ~ I I I I í I -4875 I I I I I I I I -3375 -3000 I I I -1500 I I I I I -1125 I I I I I I I I I I I ! -750 -375 0 West(-)/East(+) (750 Win) SECTION DETAiLS Engineering Calculation Methoô: Mimmum Curvature Error System: ¡SCWSA Scan Method: Trav, Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based ~ 4500 (¡) > () ;:¡ 5250-~~ ¡:: 6000 -750 8250 9000 -2250 10034ft, 8299,995ft, (3741ft FNL, 3123ft FEL, Sec7-T12N-R4E I , , I , I ,-, 11 I , , I I I I I Ii' 4500 5250 6000 I , SECTION DEl" J\1L$ . CorI<>OOPhillips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration 2005 (Iapetus) Iapetus Iapetus 2 Iapetus 2 Iapetus 2 (wp04) Well Iapetus 2 RKB @ 49.500ft (RKB from WRP) RKB @ 49.500ft (RKB from WRP) True Minimum Curvature Project Exploration 2005 (Iapetus) Map System: Geo Datum: Map Zone: US State Plane 1983 North American Datum 1983 Alaska Zone 4 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor I Site Iapetus o.OOOft Northing: Easting: Slot Radius: 6,000,375.00°ft 1,494,565.000ft 0" Latitude: Longitude: Grid Convergence: 70· 24' 31.500" N 151· 11'15.515" W -1.12 . Site Position: From: Position Uncertainty: Map ~- Well Iapetus 2 Position Uncertainty O.OOOft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 6,000,375.000 ft 1,494,565.000 ft ft Latitude: Longitude: Ground Level: 70· 24' 31.500" N 151· 11' 15.515"W O.OOOft Well Position +N/-S +EJ-W ~- ~- ~~~,---, Wellbore Iapetus 2 MOdel Name Declination (0) BGGM2004 11/17/2004 23.73 80.64 57,512 Design Audit Notes: Version: Iapetus 2 (wp04) 10 Phase: PLAN Tie On Depth: 36.500 255.773 ~- 36.500 0.000 0.000 36.500 0.000 0.000 0.00 0.00 0.00 0.00 500.000 0.000 0.000 500.000 0.000 0.000 0.00 0.00 0.00 0.00 1,759.167 37.775 250.473 1,669.908 -133.789 -377 .242 3.00 3.00 0.00 250.47 7,585.512 37.775 250.473 6,275.181 -1,326.730 -3,740.967 0.00 0.00 0.00 0.00 8,054.843 37.191 273.692 6,649.492 -1,365.841 -4,019.404 3.00 -0.12 4.95 101.59 8,932.621 32.451 273.692 7,369.890 -1,333.575 -4,519.445 0.54 -0.54 0.00 180.00 10,034.842 32.451 273.692 8,300.000 -1,295.491 -5,109.646 0.00 0.00 0.00 0.00 L-.... ----~--~--~ -- 12/7/2004 10:58:12AM Page 2 of 6 COMPASS 2003. 11 Build 48 ORIGlt~AL . ConocóPhillips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration 2005 (Iapetus) 36.500 0.000 0.000 36.500 0.000 0.000 0.000 0.00 0.00 0.00 SHL - 2445ft FNL & 3289ft FEL, Sec8-T12N-R4E 100.000 0.000 0.000 100.000 0.000 0.000 0.000 0.00 0.00 0.00 199.999 0.000 0.000 199.999 0.000 0.000 0.000 0.00 0.00 0.00 500.000 0.000 0.000 500.000 0.000 0.000 0.000 0.00 0.00 0.00 Begin Dir @ 3.00: SOO.010ft,500.01Oft 600.000 3.000 250.473 599.954 -0.875 -2.467 2.606 3.00 3.00 0.00 700.000 6.000 250.473 699.635 -3.497 -9.861 10.418 3.00 3.00 0.00 800.000 9.000 250.473 798.768 -7.859 -22.161 23.413 3.00 3.00 0.00 900.000 12.000 250.4 73 897.082 -13.950 -39.335 41.557 3.00 3.00 0.00 1,000.000 15.000 250.4 73 994.308 -21 .752 -61.334 64.799 3.00 3.00 0.00 1,015.746 15.472 250.473 1,009.500 -23.135 -65.234 68.919 3.00 3.00 0.00 Base Permafrost 1,100.000 18.000 250.473 1,090.179 -31.244 -88.099 93.076 3.00 3.00 0.00 1,200.000 21.000 250.473 1,184.432 -42.400 -119.556 126.310 3.00 3.00 0.00 1,300.000 24.000 250.4 73 1,276.810 -55.190 -155.619 164.410 3.00 3.00 0.00 1,400.000 27.000 250.4 73 1,367.058 -69.578 -196.190 207.272 3.00 3.00 0.00 1,500.000 30.000 250.4 73 1 ,454.930 -85.526 -241.156 254.779 3.00 3.00 0.00 1,600.000 33.000 250.473 1,540.184 -102.988 -290.395 306.799 3.00 3.00 0.00 1,700.000 36.000 250.473 1,622.587 -121.918 -343.772 363.191 3.00 3.00 0.00 1,759.167 37.775 250.4 73 1,669.908 -133.789 -377.242 398.552 3.00 3.00 0.00 End Dir, Start Sail @37.775: 1759.200ft MD, 1669.934ft TVD 1,800.000 37.775 250.473 1,702.183 -142.149 -400.817 423.458 0.00 0.00 0.00 1,900.000 37.775 250.473 1,781.225 -162.624 -458. 550 484.453 0.00 0.00 0.00 2,000.000 37.775 250.4 73 1,860.268 -183.099 -516.283 545.447 0.00 0.00 0.00 2,100.000 37.775 250.4 73 1,939.310 -203.574 -574.016 606.441 0.00 0.00 0.00 2,200.000 37.775 250.473 2,018.352 -224.049 -631.749 667.436 0.00 0.00 0.00 2,300.000 37.775 250.4 73 2,097.394 -244.524 -689.482 728.430 0.00 0.00 0.00 2,327.967 37.775 250.473 2,119.500 -250.250 -705.628 745.488 0.00 0.00 0.00 C40 2,400.000 37.775 250.4 73 2,176.437 -264.999 -747.215 789.424 0.00 0.00 0.00 2,485.478 37.775 250.473 2,244.000 -282.500 -796.563 841.561 0.00 0.00 0.00 9-518" Csg Pt ... Drill out 8-1/2" Hole: 2482.652ft, 2244.00Oft 2,486.110 37.775 250.473 2,244.500 -282.630 -796.929 841.947 0.00 0.00 0.00 2,500.000 37.775 250.473 2,255.479 -285.474 -804.948 850.419 0.00 0.00 0.00 2,600.000 37.775 250.4 73 2,334.521 -305.949 -862.681 911.413 0.00 0.00 0.00 2,656.905 37.775 250.473 2,379.500 -317.600 -895.534 946.122 0.00 0.00 0.00 C30 2,700.000 37.775 250.473 2,413.563 -326.424 -920.414 972.407 0.00 0.00 0.00 2,800.000 37.775 250.473 2,492.606 -346.899 -978.147 1 ,033.402 0.00 0.00 0.00 2,900.000 37.775 250.4 73 2,571.648 -367.374 -1,035.880 1,094.396 0.00 0.00 0.00 3,000.000 37.775 250.4 73 2,650.690 -387.849 -1,093.613 1,155.390 0.00 0.00 0.00 3,087.055 37.775 250.473 2,719.500 -405.673 -1,143.872 1,208.489 0.00 0.00 0.00 C20 3,100.000 37.775 250.473 2,729.732 -408.324 -1,151.346 1,216.385 0.00 0.00 0.00 3,200.000 37.775 250.473 2,808.775 -428.799 -1,209.079 1 ,277.379 0.00 0.00 0.00 3,300.000 37.775 250.473 2,887.817 -449.274 -1,266.812 1,338.373 0.00 0.00 0.00 3,400.000 37.775 250.4 73 2,966.859 -469.748 -1,324.545 1,399.368 0.00 0.00 0.00 3,500.000 37.775 250.473 3,045.901 -490.223 -1 ,382.278 1,460.362 0.00 0.00 0.00 3,600.000 37.775 250.473 3,124.944 -510.698 -1,440.011 1,521.356 0.00 0.00 0.00 3,700.000 37.775 250.473 3,203.986 -531.173 -1,497.744 1,582.351 0.00 0.00 0.00 ___3,800.000 37.775 250.473 3,283.028 -551.648 ~555.477 1,643.345 O.OO~ 0.00 0.00 12/7/2004 10:58:12AM Page 3 of 6 COMPASS 2003. 11 Build 48 ORIGINAL . c:onocJ'Pt,illips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 2005 (Iapetus) 3,900.000 37.775 250.473 3,362.070 -572.123 -1,613.210 1,704.339 0.00 0.00 0.00 4,000.000 37.775 250.473 3,441.112 -592.598 -1,670.943 1,765.334 0.00 0.00 0.00 4,100.000 37.775 250.473 3,520.155 -613.073 -1,728.676 1,826.328 0.00 0.00 0.00 4,200.000 37.775 250.473 3,599.197 -633.548 -1,786.409 1,887.322 0.00 0.00 0.00 4,300.000 37.775 250.473 3,678.239 -654.023 -1,844.142 1,948.317 0.00 0.00 0.00 4,400.000 37.775 250.4 73 3,757.281 -674.498 -1,901.875 2,009.311 0.00 0.00 0.00 4,472.390 37.775 250.473 3,814.500 -689.320 -1,943.668 2,053.465 0.00 0.00 0.00 K-3 4,500.000 37.775 250.473 3,836.324 -694.973 -1,959.608 2,070.305 0.00 0.00 0.00 4,600.000 37.775 250.4 73 3,915.366 -715.448 -2,017.341 2,131.299 0.00 0.00 0.00 4,700.000 37.775 250.473 3,994.408 -735.923 -2,075.074 2,192.294 0.00 0.00 0.00 4,800.000 37.775 250.4 73 4,073.450 -756.398 -2,132.807 2,253.288 0.00 0.00 0.00 4,900.000 37.775 250.473 4,152.493 -776.873 -2,190.540 2,314.282 0.00 0.00 0.00 5,000.000 37.775 250.4 73 4,231.535 -797.348 -2,248.273 2,375.277 0.00 0.00 0.00 5,100.000 37.775 250.473 4,310.577 -817.823 -2,306.006 2,436.271 0.00 0.00 0.00 5,200.000 37.775 250.4 73 4,389.619 -838.298 -2,363.739 2,497.265 0.00 0.00 0.00 5,300.000 37.775 250.473 4,468.662 -858.773 -2,421.472 2,558.260 0.00 0.00 0.00 5,400.000 37.775 250.473 4,547.704 -879.248 -2,479.205 2,619.254 0.00 0.00 0.00 5,500.000 37.775 250.473 4,626.746 -899.723 -2,536.938 2,680.248 0.00 0.00 0.00 5,600.000 37.775 250.473 4,705.788 -920.198 -2,594.671 2,741.243 0.00 0.00 0.00 5,700.000 37.775 250.473 4,784.830 -940.672 -2,652.404 2,802.237 0.00 0.00 0.00 5,800.000 37.775 250.473 4,863.873 -961.147 -2,710.137 2,863.231 0.00 0.00 0.00 5,900.000 37.775 250.473 4,942.915 -981.622 -2,767.870 2,924.226 0.00 0.00 0.00 6,000.000 37.775 250.473 5,021.957 -1,002.097 -2,825.603 2,985.220 0.00 0.00 0.00 6,100.000 37.775 250.473 5,100.999 -1,022.572 -2,883.336 3,046.214 0.00 0.00 0.00 6,200.000 37.775 250.4 73 5,180.042 -1,043.047 -2,941.069 3,107.209 0.00 0.00 0.00 6,300.000 37.775 250.473 5,259.084 -1,063.522 -2,998.802 3,168.203 0.00 0.00 0.00 6,400.000 37.775 250.4 73 5,338.126 -1,083.997 -3,056.535 3,229.197 0.00 0.00 0.00 6,500.000 37.775 250.4 73 5,417.168 -1,104.472 -3,114.268 3,290.192 0.00 0.00 0.00 6,600.000 37.775 250.473 5,496.211 -1,124.947 -3,172.001 3,351.186 0.00 0.00 0.00 6,700.000 37.775 250.473 5,575.253 -1,145.422 -3,229.734 3,412.180 0.00 0.00 0.00 6,800.000 37.775 250.473 5,654.295 -1,165.897 -3,287.467 3,473.175 0.00 0.00 0.00 6,900.000 37.775 250.473 5,733.337 -1,186.372 -3,345.200 3,534.169 0.00 0.00 0.00 7,000.000 37.775 250.4 73 5,812.380 -1,206.847 -3,402.933 3,595.163 0.00 0.00 0.00 7,100.000 37.775 250.4 73 5,891.422 -1,227.322 -3,460.666 3,656.158 0.00 0.00 0.00 7,200.000 37.775 250.473 5,970.464 -1,247.797 -3,518.399 3,717.152 0.00 0.00 0.00 7,300.000 37.775 250.473 6,049.506 -1,268.272 -3,576.132 3,778.146 0.00 0.00 0.00 7,400.000 37.775 250.473 6,128.549 -1,288.747 -3,633.865 3,839.141 0.00 0.00 0.00 7,500.000 37.775 250.473 6,207.591 -1,309.222 -3,691.598 3,900.135 0.00 0.00 0.00 7,585.512 37.775 250.473 6,275.181 -1,326.730 -3,740.967 3,952.292 0.00 0.00 0.00 Begin Dir @ 3.00DLS: 7585.52Oft MD,6275.188ft TVD 7,600.000 37.690 251.168 6,286.640 -1,329.643 -3,749.341 3,961.125 2.99 -0.59 4.80 7,700.000 37.215 256.040 6,366.043 -1,346.808 -3,807.635 4,021.849 3.00 -0.48 4.87 7,800.000 36.943 260.996 6,445.842 -1,358.807 -3,866.675 4,082.029 3.00 -0.27 4.96 7,900.000 36.878 265.992 6,525.818 -1,365.608 -3,926.302 4,141.498 3.00 -0.06 5.00 8,000.000 37.023 270.977 6,605.751 -1,367.190 -3,986.351 4,200.094 3.00 0.14 4.99 8,054.843 37.191 273.692 6,649.492 -1,365.841 -4,019.404 4,231.802 3.00 0.31 4.95 Secondary Target (Brookian Sand) : 8055ft, 6649.502ft, (3811ft FNL, 2033ft FEL, Sec7-T12N-R4E - 8,100.000 36.947 273.692 6,685.523 -1,364.088 -4,046.567 4,257.701 0.54 -0.54 0.00 8,200.000 36.407 273.692 6,765.724 -1,360.242 -4,106.173 4,314.534 0.54 -0.54 0.00 8,300.000 35.867 273.692 6,846.485 -1,356.444 -4,165.023 4,370.645 0.54 -0.54 0.00 8,400.000 35.327 273.692 6,927.798 -1,352.696 -4,223.110 4,426.030 0.54 -0.54 0.00 8,500.000 34.787 273.692 7,009.655 -1,348.998 -4,280.430 4,480.6.?1.. 0.54 -0.54 0.00 12/71200410:58:12AM Page 4 of 6 COMPASS 2003. 11 Build 48 ORIGINAL . ~illips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc, NAD 83 Exploration 2005 (Iapetus) Iapetus Iapetus 2 Iapetus 2 Iapetus 2 (wp04) Well Iapetus 2 RKB @ 49,5ooft (RKB from WRP) RKB @ 49.5000 (RKB from WRP) True Minimum Curvature 8,600.000 34.247 273.692 7,092.051 -1,345.349 -4,336.977 4,534.599 0.54 -0.54 0.00 8,681.385 33.808 273.692 7,159.500 -1,342.416 -4,382.425 4,577.932 0.54 -0,54 0.00 Base HRZ 8,700.000 33.707 273.692 7,174.976 -1,341.750 -4,392.747 4,587.774 0.54 -0.54 0.00 8,741.447 33.483 273.692 7,209.500 -1,340.273 -4,415.633 4,609,595 0.54 -0.54 0,00 K-1 Marker 8,800.000 33.167 273.692 7,258.425 -1,338.202 -4,447.735 4,640.203 0.54 -0.54 0.00 8,801.284 33.160 273.692 7,259.500 -1,338.157 -4,448.436 4,640.872 0.55 -0.55 0.00 7" Csg Pt Contingency .n: 8797.412ft, 7259.500ft - Continue Dir -7" Contingency 8,831.120 32.999 273.692 7,284.500 -1,337.108 -4,464.687 4,656.366 0.54 -0.54 0.00 LCU Kuparuk Sands 8,900.000 32.627 273.692 7,342.389 -1,334.705 -4,501.935 4,691.882 0.54 -0.54 0,00 8,932.159 32.453 273.692 7,369.500 -1,333.591 -4,519.198 4,708.341 0.54 -0.54 0.00 8,932.621 32.451 273.692 7,369.890 -1,333.575 -4,519,445 4,708,577 0.54 -0.54 0.00 Primary Target (Nechelik Sand): 8932.ft, 7369.50Oft, (37700 FNL, 2533ft FEL, Sec7-T12N-R4E 9,000.000 32.451 273,692 7,426.748 -1,331.247 -4,555.524 4,742,977 0.00 0.00 0.00 9,100.000 32.451 273,692 7,511.133 -1,327.791 -4,609.071 4,794.032 0.00 0,00 0.00 9,200.000 32.451 273.692 7,595,518 -1,324.336 -4,662.617 4,845.087 0.00 0.00 0.00 9,300.000 32.451 273.692 7,679.903 -1,320.881 -4,716.163 4,896.142 0.00 0.00 0.00 9,400.000 32.451 273.692 7,764,288 -1,317.426 -4,769.710 4,947.197 0.00 0.00 0.00 9,500.000 32.451 273.692 7,848.673 -1,313.971 -4,823.256 4,998.252 0.00 0.00 0,00 9,600.000 32.451 273.692 7,933.058 -1,310.516 -4,876.803 5,049,307 0.00 0.00 0,00 9,700.000 32.451 273.692 8,017.443 -1,307.060 -4,930.349 5,100.362 0.00 0,00 0.00 9,800,000 32,451 273.692 8,101.828 -1,303.605 -4,983.896 5,151.417 0.00 0.00 0.00 9,900.000 32.451 273.692 8,186.213 -1,300.150 -5,037.442 5,202.4 72 0.00 0.00 0.00 10,000.000 32.451 273.692 8,270.598 -1,296.695 -5,090.989 5,253.527 0.00 0.00 0.00 10,034.842 32.451 273.692 8,300.000 -1,295.491 -5,109.646 5,271.316 0,00 0.00 0.00 TD: 10034ft, 8299.995ft, (3741ft FNL, 3123ft FEL, Sec7-T12N-R4E Iapetus 2 Secondary 1 0.00 0.00 6,649.500 -1,365.848 -4,019.401 5,999,088.000 1,490,520.000 70024' 18.056" N 1510 13'13.301"W - plan hits target - Polygon Upper Left -221.771 87.693 5,999,180.00 1,490,300.00 Upper Right 128.188 94.528 5,999,180.00 1,490,650.00 Lower Right 135.609 -285.428 5,998,800.00 1,490,650.00 Lower Left -314.339 -294.216 5,998,800.00 1,490,200.00 Iapetus 2 Primarry Tal 0.00 0.00 7,369.500 -1,333.598 -4,519.164 5,999,130.000 1,490,021.000 70024' 18.371" N 151013' 27.946" W - plan hits target - Polygon Upper Left -624.249 157.853 5,999,300.00 1,489,400,00 Upper Right 176.636 123.482 5,999,250.00 1,490,200.00 Lower Right 183.471 -226.478 5,998,900.00 1,490,200.00 Lower Left -616.437 -242.101 5,998,900.00 1 ,489,400.00 -- ----- 12f7/200410:58:12AM Page 5 of 6 COMPASS 2003.11 Build 48 ORlt;INAL . Conoc~illips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration 2005 (Iapetus) Iapetus Iapetus 2 Iapetus 2 Iapetus 2 (wp04) Well Iapetus 2 RKB @ 49.5ooft (RKB from WRP) RKB @ 49.500ft (RKB from WRP) True Minimum Curvature 2,486.110 2,244.500 95/8" 9-5/8 12-1/4 8,801.284 7,259.500 7" Contingency 7 8-1/2 ~- Format/om. Measured Deptl'l (ft) 1,015.746 Base Permafrost 0.00 2,327.967 C40 0.00 2,656.905 C30 0.00 3,087.055 C20 0.00 4,472.390 K-3 0.00 8,054.853 Brookian Sand 0.00 8,681.385 Base HRZ 0.00 8,741.447 K-1 Marker 0.00 8,831.120 LCU Kuparuk Sands 0.00 8,932.159 Nechelik Sands 0.00 36.510 500.010 1,669.934 2,244.000 6,275.188 6,649.492 7,259.500 7,369.890 8,299.998 Local Coordinates +N/-S +Ef.W (ft) (ft) 0.000 0.000 -133.795 -282.500 -1,326.732 -1,365.841 -1,338.157 -1,333.575 -1,295.491 0.000 0000 -377.262 -796.563 -3,740.972 -4,019.404 -4,448.436 -4,519.445 -5,109.644 121112004 10:58:12AM SHL -- 2445ft FNL & 3289ft FEL, Sec8-T12N-R4E Begin Dir @ 3.00 : 500.0100,500.0100 End Dir, Start Sail @ 37.775: 1759.2000 MD, 1669.934ft TVD 9-5/8" Csg Pt... Drill out 8-1/2" Hole: 2482.652ft, 2244.0000 Begin Dir @ 3.00DLS: 7585.52Oft MD,6275.188ft TVD Secondary Target (Brookian Sand) : 8055f1, 6649.50211, (3811ft FNL, 2033f1 FEI 7" Csg pt Contingency...: 8797.412ft, 7259.5000 - Continue Dir Primary Target (Nechelik Sand) : 8932.fI, 7369.50Oft, (37700 FNL, 2533f1 FEL, TD: 1OO34f1, 8299.995ft, (3741ft FNL, 31231t FEL, Sec7-T12N-R4E Page 60'6 COMPASS200~11BuHd48 ORIGINAL . Iapetus 2 DrillinCl Hazards Summary 12 1,4" Hole I 9 5/8" Casinq Interval Event Broach of conductor Gas Hydrates Running sands & gravel Abnormal pressure in surface formations Hole swabbingfTight hole on trips Stuck surface casing Stuck pipe Lost circulation 8 ¥2" Hole 17" Casinq Interval Event Insufficient or undetermined LOT High ECD I Tight hole on tripsl Swabbing Abnormal reservoir pressure Hydrogen Sulphide gas (H2S) Differential sticking Lost circulation Risk level Low Low Low Low Moderate Low Low Low Risk level Moderate Moderate Moderate Low / Low Low . / Mitigation Strategy I Contingency Monitor cellar continuously during interval Mud gas detection. If observed - control drill, minimize circulating time, minimize drilling fluid temperatures Maintain planned mud parameters, Increase mud weighVviscosity, Use weighted sweeps, monitor fill on connections Diverter drills, increased mud weight. Reduced/cautious trip speeds while drilling surface hole. Mudloggers to monitor gas r/ concentrations in returns. Geologist on location to assist in picking surface casing shoe depth Circulate hole clean prior to trip, proper hole filling (use of trip sheets), pumping out of hole as needed Clean the hole before running casing, pump high density high viscosity sweeps, wiper trip(s) Keep hole clean, use high density high viscosity sweeps, keep pipe moving/rotating with pumps on whenever possible Keep hole clean. If losses occur - reduce pump rates and mud rheology, use LCM, use of low density cement slurries / Mitigation Strategy I Contingency Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 16 ppg MW equivalent Condition mud & clean hole prior to trips. Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets). Utilise wiper trips as hole conditions dictate. Well control drills, monitor gas concentrations in mud returns, increased mud weight, contingencies for 7" intermediate casing string H2S drills, detection systems, standard well control practices Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever possible Pretreat mud before drilling reservoir section, keep hole clean - use PWD to monitor hole cleaning. If losses occur - reduce pump rates and mud rheology, use LCM ORIGINAL Rig: Doyon 19 Location: Exploration Client: CPAI Revision Date: 11/17/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-B205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",65 # casing at 115' MD < Base of Permafrost at 1,015' MD (960' TVD) < Top of Tail at 1,686' MD < 95/8",36.0# casing in 12 1/4" OH TO at 2,486' MD (2,244' TVD) Mark of Schlumberger Ich berger Preliminary Job Oesign based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 350% excess in the permafrost and 45% excess below the permafrost. The top of the tail slurry is designed to be at 1,686' MD. Lead Slurry Minimum pump time: 190 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 3 1.2684 ft 1ft x (115') x 1.00 (no excess) = 3 0.3132 ft 1ft x (1015' -115') x 4.50 (350% excess) = 0.3132 ft3/ft x (1686' -1015') x 1.45 (45% excess) = 119.2 ft3 + 1268.5 ft3+ 304.7 ft3 = 1719.1 ft3 14.45 ft3/sk = Round up to 390 sks 145.9 ft3 1268.5 ft3 304.7 ft3 1719.1 ft3 386.3 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 140 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.46 ft3/sk 0.3132 ft31ft x (2486' -1686') x 1.45 (45% excess) = 0.4341 ft3/ft x 80' (Shoe Joint) = 363.3 ft3 + 34.7 ft3 = 398 ft31 2.46 ft3/sk = Round up to 170 sks 363.3 ft3 34.7 ft3 398 ft3 161.8sks BHST = 58°F, Estimated BHCT = 69°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Dropbottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 299.8 42.8 76.1 DeepCRETE 6.0 70.8 11.8 87.9 Drop topplug 0.0 0.0 5.0 92.9 Mud 7.0 173.4 24.8 117.7 Slow & bump plug 3.0 9.0 3.0 120.7 MUD REMOVAL Recommended Mud Properties: 10 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, Ty = 20-25 Centralizers: Recommend 1 per joint throughout tail slurry ORIGINAL Rig: Doyon 19 Location: Exploration Client: CPAI Revision Date: 11/17/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 9 5/8", 36.0# casing at 2,486' MD S Iberger Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are basE!d on 50% excess. Tail slurry is designed for +/- 530' MD above target - (1635' MD annular length). Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.1% B155, 0.4% D167 -1.16 ft3/sk 3 0.1268 ft 1ft x 1635' x 1.50 (50% excess) = 0.2148 ft3/ft x 80' (Shoe Joint) = 311.0 ft3 + 17.2 ft3 = 328.2 ft3/ 1.16 ft3/sk = Round up to 290 sks 311.0ft3 17.2 ft3 328.2 ft3 282.9 sks BHST = 216°F, Estimated BHCT = 163°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 20.0 4.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 MUDPUSH " 6.0 30.0 5.0 26.0 Tail Slurry 6.0 58.5 9.7 35.7 Drop top plug 0.0 0.0 5.0 40.7 Mud 6.0 371.9 62.0 102.7 < Top of Tail at Slow & bump plug 3.0 9.0 3.0 105.7 8,400' MD < 7",26.0# casing in 8 1/2" OH TO at 10,035' MD (8,300' TVD) MUD REMOVAL Recommended Mud Properties: 10.6 ppg, Pv < 20, Ty < 25. Spacer Properties: 13.0 ppg MudPUSH* II, Pv < 75, Ty = 30 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL . . ConocÓÂ1i11ips Interoffice Communication To: Bob Kunemund ATO - 1428 From: Joe Comisky PR - 2012 Date: 5 November, 2004 Subject: Pre-Drill Seismic Pore Pressure Analysis for Proposed Iapetus #1 Well CONFIDENTIAL Cc: Mike Faust Lisa Isaacson ATO - 1376 PR - 2022 The purpose of this memo is to report and review the seismic velocity based pore pressure estimates for the proposed NPRA well listed above. Summary . Seismic velocity data were used to estimate pore pressure gradients likely to be encountered at the Iapetus well location. Local normal compaction trends and local velocity-to-pore pressure gradient translations were established using control from the Temptation #1 well. To estimate pore pressure gradients, a calibrated normal compaction trend and a translation function established from the control well were applied to seismic velocities in 3D sub-volumes extracted from larger 3D seismic velocity volumes. The velocity data indicate no apparent shallow hazards at the proposed surface location. However, based on seismic velocity and offset data, moderately elevated pore pressure gradients (9.5 to 10.0 ppg) may be present at 3500' TVD below MSL in between the surface and bottom-hole location for the Iapetus well. This conclusion is based on a local decrease in seismic velocity. ./ Seismic Processinq: The accuracy of seismic pore pressure analysis depends critically on the accuracy of the input velocity field. The velocities used in this study were generated using ConocoPhillips' proprietary AVEL\2 program, an automated high-resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a seismic velocity field defined at every CDP and every 4 milliseconds. 1 Swan, H.W., 2001, Velocities from amplitude variations with offset, Geophysics, v. 66, no. 6, p. 1735-1743. 2 Kan, T. K., and Swan, H. W., 2001, Geopressure prediction from automatically-derived seismic velocities, Geophysics, v. 66, no. 6, p. 1937-1946. f\ Û lil_ . . Apparent pressure buildups can result from velocity changes due to local lithology changes. For example, the low-velocity, low-density HRZ shales show up as overpressured zones, though they are often drilled with out problems using relatively low mud weights. Other potential causes of apparent pressure anomalies include errors in the velocity pick and lor inaccuracies in shallow seismic velocities due to low fold. Potential for the Presence of Gas Hvdrates and Seismic Pressure Prediction It is possible that methane hydrates in or around the base of the permafrost transition zone will not exhibit acoustic properties that are sufficiently different from permafrost to be detected seismically. Nevertheless, hydrates can pose a significant drilling risk if proper safeguards are not in place. . Gas-charged sands and hydrates within the permafrost zone are thought to have contributed to the blowout at the Cirque #1 well (approximately 10 miles southeast of Oberon #1 and 11 miles east-southeast of Titania #1). A thin zone of over-pressured, gas-charged sands was observed at the base of permafrost in the Cirque #2 well. Previous analysis (Heinlein, 20003) shows that ,- there is no apparent indication of the presence of gas hydrates or free gas within or below the permafrost layer on either 2D or 3D seismic data in the area surrounding the Cirque wells. Thin '" gas-charged sands sitting immediately below the permafrost (in the K-10 interval) also may not appear as a potential pore pressure anomaly on 2D or 3D seismic. Pressure Prediction Procedure: ConocoPhillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to estimate pore pressure gradients. Data from the existing Temptation #1 were used to establish a local normal compaction trend line (NCTL) and local velocity vs. pressure translation trend model. These models have been updated from previous NPRA models (Wyndriski 1999; Heinlein and Kilsdonk, 2000; Buggenhagen, 2002) to include additional data and better fit all available data. The current models differ in details from earlier models but produce similar results with slightly improved fits to offset well data. Procedure 1.) Openhole wireline logs for the Temptation #1 were compared to the seismic interval transit time (lIT) and show a good match. Special care was taken to ensure bulk density measurements were not reading too low due to washout and rugose zones in the well bore. 2.) In the area that includes the Temptation #1 well the logarithmic slope of the seismic and log- based NCTL is -3.8e-S with an intercept of 160 microseconds/foot. This NCTL was used for all log and seismic calculations. 3.) The inverse ratio of interval transit times (lIT), recorded by wireline sonic logs (~T) in the existing wells or by seismic velocities in the proposed wells, to interval transit times predicted by downward extensions of the NCTLs were calculated. These values are the interval transit time ratios, lIT r/TTo. 4.) A translation trend model was established by comparing transit time ratios (lIT r/TTo) to mud weights in offset wells. This model calculates pore pressure gradients (PPG) using the Eaton's equation4 fore pore pressure. PPG = OBG - [OBG - PPGn] (lIT r/TT o)N or equivalently 3 Heinlein, K. H., 2000, Pre-drill seismic pore prediction for proposed well location: Cirque #3, Phillips Alaska, Inc. 4 Eaton, Ben A, 1975. The equation for geopressure prediction from well logs, SPE 5544. .,ò<". /' ._,_, ., UkjGHi~AL . . VESNESn = (lIT n1TT O)N where: PPG is the pore pressure gradient OBG is the overburden gradient PPGn is the normal (not overpressured) pore pressure gradient (8.65 pgg or 0.45 psi/ft) IITn is the normal (not overpressured) interval transit time lITo is the observed interval transit time N is the Eaton exponent. VES is the vertical effective stress VESn is the normal (not overpressured) vertical effective stress In this case appropriate values of N were found to lie between 0.8 (best fit) and 1.0 (high side estimate). 5.) Fracture gradients were calculated using the Eaton method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile (from a West Cameron model). Bulk densities were computed from seismic data using the equation: Rhob = A (V)B Where Rhob is bulk density in glcc, V is seismic interval velocity in ft/s, and A and Bare constants with values of 0.0748 and 0.38354, respectively. Pressure Calibration from Offset Control Well Temptation #1 Figure 1 shows sonic velocity based pore pressurel fracture gradient I overburden analyses of this well plotted with observed mud weights, formation tops, and drilling data. Both a "low side" analysis and a "high side" fit analysis are shown. The left side is the wireline sonic DT (black curve) with the NCTL (red line). The right side contains the pore pressure gradient calculations (blue curves), actual mud weights (green curve), and the calculated fracture gradient (red curve). Casing points, areas of formation tests, and formation tops are as labeled. All depths are referenced to TVD with a KB height of 34'. The surface elevation is 2 ft above Mean Sea Level. The Temptation #1 was drilled with no reportable pore pressure related problems to a total ./ depth of 7750' with mud weights just above 10 ppg. Slightly elevated pore pressure gradients (9 ppg) may exist just below the 9 5/8" casing shoe based on the sonic log analysis. Two formation tests were taken in the Jurassic Nechelik sand at 7180' and 7412' measured depth with near normal pore pressure gradients (-8.7 ppg). The sonic log estimate of pore pressure in the surrounding HRZ shale shows pore pressure gradients as high as 10.0 ppg. The apparent increase in pore pressure gradient in the HRZ interval is most likely a lithology effect .I due to low velocity kerogen present in the shales. Seismic Pore Pressure Analvses for Proposed Wells A seismic velocity extraction at the Temptation #1 well location (Figure 2) reveals an acceptable tie with no need for scaling. Comparison of seismic and log-based pore pressure predictions show very close agreement in the shallow section (Figure 3). The seismic lIT also shows a slight increase in pore pressure gradient below 6000', with the high-side calibration not exceeding 9.5 ppg (Figure 4). ORiGINAL \. . . Iapetus Surface Location Figure 5 shows the seismic PPFG estimate for the Iapetus surface location at inline #19399 and xline #11380. The shallow velocity data indicate pore pressure gradients that are slightly elevated, though below 9 ppg. Although slightly elevated pore pressures may be encountered ,/ below permafrost, the pressure gradients are not high and should be normal (8.65 ppg) by 3000 feet. Pore pressures may begin to rise just below 7000 feet but should stay below 11 ppg until about 8500 feet. Maximum pore pressure gradient is estimated to be 10 to 11 ppg between 8500 and 10000 feet. Based on the pressure profile presented in Figure 5, no shallow hazards .,/ are expected at the location. Iapetus Bottom-hole Location Figure 6 shows the seismic PPFG estimate for the Iapetus bottom-hole location at inline #19430 and xline #11350. The shallow velocity data suggest normal pressures immediately below or permafrost at 1000 feet. Elevated pore pressure gradients may be encountered between 7000 and 10500', although they do not exceed 11 ppg. Based on the pressure profile presented in Figure 6, no shallow hazards are expected at the location. Iapetus Pseudowell Location Elevated pore pressures may be encountered in the shallow section in between the Iapetus ,/ surface and bottom-hole locations as highlighted in Figure 7. Figures 8 and 9 show seismic ITT as a function of depth with a shallow velocity anomaly highlighted by the red circle at 3500 feet. v lIT extractions from all relevant well locations (Figure 10) show the magnitude of this anomaly compared to the lIT profile at the Temptation and Iapetus surface and bottom-hole locations. A similar decrease in velocity at the Temptation #1 surface location is also noted (Figure 11), although the calculated increase in pore pressure gradient is much smaller, and the well was drilled without incident through that zone of interest. The shallow velocity anomaly presented in Figure 12 may represent a local increase in pore pressure gradient of 10 ppg with an areal extent highlighted in red in Figures 13 and 14. The colorbar represents a depthslice at 3500' of the high-end calculated pore pressure gradient volume. Purple colors represent a near normal pore pressure gradient at 3500', and the blue colors represent slightly elevated gradients on the order of 10 ppg. As a comparison, the wellpath between the Temptation #1 surface and Temptation #1A bottom-hole locations did not encounter anomalous pore pressure gradients at 3500'. Both wells were drilled without pore- pressure related incidents. Conclusions Seismic velocity data indicate no shallow hazards at the proposed surface and bottom- hole locations for the Iapetus well. However, shallow velocities in between the surface and bottom-hole locations indicate that: (1) slightly elevated pore pressure gradients of 9.5 to 10.0 ./ ppg are possible in the shallow section below permafrost at 3500'; and (2) pore pressure gradients up to 11.0 ppg may occur below 8000' at all locations. ./ ORIGINAL . . Figure Captions Figure 1: Wireline log based pore pressure estimate for the Temptation #1. The sonic log (left) was filtered to only use values in shales (red dots). The shale traveltimes were then used to calculate a normal compaction trend (NCT, red line). Two formation test samples taken in the Nechelik sand interval show that the sands are normally pressured with an equivalent gradient of 8.7 ppg. Fracture gradient (red curve in right track) was calculated using a model from the Gulf coast and slightly underpredicts the fracture pressure measured at the 9 5/8 casing point. The overburden (black curve in right track) was calculated by integrating the rhob log. Figure 2: Comparison of seismic and well log measurements at the Temptation #1 well location. The green sonic log ties nicely to the seismic-derived interval velocity without scaling to correct for any time/depth misties. The subsequent seismic-based density and log-measured densities also show a good match. Figure 3: Comparison of log and seismic based predictions. The left-most track shows the log based pore pressure gradient (red) compared to the seismic (green line) prediction using an Eaton exponent of 0.8. Track 2 shows the same curves, with log- based prediction in black and seismic in green using an Eaton exponent of 1.0. Track 3 is a comparison of the sonic log (black) and seismic-derived (red) interval velocities. The right-most track is a comparison of the overburden gradient calculated using the rhob log (red) compared to the velocity/density transform applied to the seismic. Figure 4: Seismic-based pore pressure prediction at the Temptation1 Surface Location (inline = 19342, xline = 11344). Figure 5: Pore Pressure estimation at the Iapetus Surface location. Figure 6: Pore Pressure estimation at the Iapetus bottom-hole location Figure 7: Pore pressure gradient calculated from seismic velocities using the high-side model calibrated at the Temptation #1. The analysis revealed no shallow anomalies at or in between the Temptation #1 and Temptation 1A BH locations. Pore pressure gradients appear to be near normal for the Iapetus surface and BH locations, although the velocity anomaly in between reveals itself as a pressure gradient increase in blue (circled in red). Figure 8: Seismic velocity (expressed as interval traveltime in us/ft) cross-section intersecting areas of interest. The red circle shows the low velocity zone located between the Iapetus surface and BH locations at 3500' TVD below MSL. Figure 9: Same as previous velocity cross-section with seismic wiggle overlay. Figure 10: Traveltime extractions for locations of interest. The Temptation#1 surface location (A) shows no indication of a velocity anomaly and the well was subsequently drilled without incident. An extraction from the Temptation 1A (B) surface location does show at region of low velocity, but the wellbore never encountered this particular interval . . since it is a sidetrack to the Temptation #1 with a kickoff depth of 1800' at location (A). Both the Iapetus Surface (C) and bottom-hole (E) locations show no indications of a velocity anomaly. A pseudowell extraction (0) in between the Iapetus surface and BH location does, however, reveal a velocity anomaly. Figure 11: Pore Pressure Gradient cross-section, this time comparing the seismic velocity extractions from the Temptation #1 and the location of the possible shallow hazard in between the Iapetus surface and BH locations. There is a small reversal in velocity near 3500' at the Temptation #1 location, and this well was drilled without incident. The velocity anomaly near the Iapetus locations, however, shows a much // slower zone at 3500' with estimated pore pressure gradients as high as 10 ppg. Figure 12: Pore Pressure gradients expected at the Pseudowelllocation in between the Iapetus surface and BH locations. The velocity anomaly between 3000 and 4000' TVO below MSL corresponds to a local increase of the pore pressure gradient of 10 ppg. ./ Figure 13: Oepthslice cut through the high-side pore pressure gradient model at 3500'. Purple colors represent areas of near normal pressure gradients (8.65 ppg) while blue colors represent areas of possible elevated pore pressure gradients (9.5 to 10 ppg). The area around Temptation #1 shows no indication of a low velocity zone and hence no shallow hazards were reported while drilling the well. A subsequent sidetrack to the Temptation #1A also did not encounter any shallow drilling hazards. Both the Iapetus Surface and BHL do not suggest the presence of a shallow hazard, although a low velocity zone highlighted in red exists between the surface and BHL at 3500' TVO below ,/ MSL. This low velocity zone may indicate a region of higher pore pressure gradients. Figure 14: Zoomed in view of previous slide. Again, although there appear to be no shallow hazards at the Iapetus surface and BH locations a low velocity zone (highlighted in red with limits marked by inline and xline) may exist between the locations at 3500' TVO below MSL. ORIGINAL / ConocóPhillips 10/2/04 Project HARR _SAY Well: Temptation #1 NCTL: 160, -3.8e-5 Modified Eaton Method: e=0.8, 1.0 J. Comisky DEPTH (DoJulTl ,etto RKB,$4 ftobo\'. MSL;i 34 To..lt>.liun FEn 34 3000 3000 1000 2000 4000 5000 5000 "000 7000 "0 ao 100 HCn. Intercept m GL " nUS! LogllrÏlllmíe Slope", -UU!e-S& ... Cacillg 00,111 * Kick II'I0w ... Repem I'ormalioll Tnt x Drill Stem Tem 11 Produc'öoll Preeeure m Leu-off Te3t ii!J Lo3t Circula:líoll ZOllea - I'ormalioll Top . SIIIc¡ Pipe Loca:líoll .... Sldelrack LOCalill1l 8: I'reeform 15 18 Figure 1 c ¡nips 10/2/04 Project: HARR_BAY Well: Temptation #1 NCTL: 160, -3.8e-5 Comparison of seismic vs. logs J. Comisky DEPTH (Oð!Ufr¡ ."tro RKB,:34 it we\'" i'A$L) -S8 Temptation 1 wen to seismic tie ¡ RH B DT Figure 2 y ConocoPhillips Project: HARR_BAY Well: Temptation #1 NCTL: 160, -3.8e-5 Modified Eaton Method: e=0.8, 1.0 10/2/04 J. Comisky DEPTH (DF.durn sette. PoKE!, (14 it wove M$L) 34 5000 6000 7000 8000 9000 l'if 9,0 11 ,0 60 100 120 140 10 12 14 16 80 9,0 9,5 10,0 9,5 10,0 10,5 Pressure (lb/gal) Low (lb/gal) High Sonic (us/±) Overburden (ppg) Figure 3 IIEPTII :34 1000 2000 :3000 4000 5000 6000 8000 9000 20 Project: HARR_BAY Well: Temptation #1 NCTL: 160, -3.8e-5 Modified Eaton Method: e=0.8, 1.0 ~/ ConocoPhillips 10/2/04 J. Comisky DEPTH (Da1Jm set!", RKB.341ta1:m,e M$L) 34 ro...,_un FEET 34 1000 2000 3000 4ÜOO 5000 60ÜO ,000 60 80 HeT!.. Intercept at GL '" LO!lN'illlmic Slope III. euing Depth + Repeat formation Tellt 8. Proclucücl! Pressure ø l.olIt Circulation Zones SIlIcic Pipe Location Z freeform 8034 21 20 *. Klcll t flow ]I{ Drill stem Tellt eI Leak-off T ellt formation Tcp .... Sidetrack !..ocatiCI'f igure 4 Project: HARR _BAY Well: Iapetus Surface Location NCTL: 160, -3.8e-5 Modified Eaton Method: e=0.8, 1.0 ·Y'·~ ConocoPhillips 10/2/04 J. Comisky DEPTH ma:tum setto ;,tSL) MSL' FEET t>ASL 1000 2000 3000 BO 80 NCT!.. Il'IIercept at 131. .. !..ogarilllmïc Slope .. Figure 5 ~/ ConocoPhillips 10/2/04 Project: HARR_BAY Well: Iapetus Bottom Location NCTL: 160, -3.8e-5 Modified Eaton Method: e=0.8, 1.0 J, Comisky FEET MSL 60 eo 100 MeT!. Intercept;IIiÎ GL " 16. LO!llli'itbmic Slope" -Ue-8S Figure 6 Temptation#l Surface Loc Temptation#lA BHL /Iapetus BHL Iapetus Surface Loc Pseudowell 1 1 9 :3 3 3 6 :3 .¡ 3 8,00 8. SO 9.00 :L 50 w.oo 10.50 11. Dü 11.50 12.00 12.50 18. ÙO 13.50 l·l.OO 14.50 J5.00 15.50 16. DO lt1.5D 17.00 17.50 J6.00 16.50 noo ~ 5000 ., Pore Pressure radient (ppg) xsection Figure þ. TemptatioJ1#l Loc Temptation#lA Iapetus Surface Loc 1 9 3 4 6 In liœ ... - 1 ¡ a X_linsi. ".2- 50. I! ¡ i Temptation#1 Temptation#1A Iap~tus Surface BHL Temptation 1 Surface Location 60 80 100 120 160 IEET(OeIJJ",,,troM$L) MSL 6010000 . Pmj9d MAFlR _FIJI. V Temptation lA BHL .0 eo BO 100 120 160 FEEt (D$l1Jrn $e'tK¡ M$l) M$l 60Q500Q ~ 6QOÛOOO . !,5:1~50f)Q ~!1PTAtrCN _1 . f;lSÚÙOO- Iapetus Surface Location 40 eo 130 iDO 120 1ßù flE1(Own"troM$L) MSl PseudoweH 40 GO ao 100 120 160 FEEt (DOOUrn $.etw MSL) MSL Iapetus BHL 40 60 BO 100 120 160 fEET (Ciclum ,clio MSt) MSL Seismic ITT (us/ft) extractions Figure 10 Tempt ation# 1 Temptation#lA Iapetus BHL Surface Lot BHL Surface Lot PseudoweU 1 1 1 1 ~ 1 ~ 9 3 3 3 3 4 4 4 ~ 6 ~ Ô 3 6.00 a.5-0 9.00 -9.50 16-,50 19.0Q I( 5000' Pore Pressure radient (ppg) xsection Figure 11 ~ Project: HARR_BAY Well: Pseudowell, in 19412, xl 11358 NCTL: 160, -3.8e-5 Modified Eaton Method: e=0.8, 1.0 ~..~ ConocoPhiIIi ps 10/2/04 J. Comisky DEPTH (Daium setto RKB ,:J411 abo,e MSL) 34 FEET 34 1000 2000 3000 4000 5000 6000 7000 10034 Figure 12 Project: HARR _BAY Well: Depthsiice at 3500' TVD of PPG NCTL: 160, -3.8e-5 Modified Eaton Method: e=1.0 ",,/ ConocoPhiIIi ps 10/2/04 J. Comísky 6006000 - 6007000 - 600600.0 - 6005000 - 6004000 - 6003000 - 6002000- 6001000 - 6000000 -, ~40000 . ~42000 . ~46000 , 646000 , ~4~000 , 050000 , 051000 652iJOO , 053000 , MWOO , 645000 ~47000 ~43000 644000 Pore Pressure radient (ppg) depthslice Figure 1 . ~54000 PPS ~.OO 0.50 ~.OO ~.50 10.00 10.50 11.00 11.5(1 12.00 12.50 1:,.50 14.00 14.50 15.00 15.50 16.00 16.50 1ï,(I(I 17,50 10.00 1~. 50 1~.00 Con Project: HARR_BAY We!!: DepthsHce at 3500' TVD of PPG NCTL: 160, -3.8e-5 Modified Eaton Method: e=1.0 lIips 10/2/04 J. Comisky 600f.WOO .. 6007000 .. 6006000 .. 6005000 ... 6004000 "'- JO -. 0000 64 Pore Pressure radient ( g) depthslice ppg fl.OO ~.50 ~.oo ~.50 10.00 10.50 11.00 11. 51) 12.00 12.51) 13.01) 13.51) 14.00 14.50 15.00 15.50 16.01) 16.51) 17.1)0 17.50 1fl.1)1) 1~.50 1~ 1)0 )01) Figure 14 Iapetu~ Proposed Schematic Exploration Well - Confidential ~ r i I ~ ~ ~ '- ~ ~ ~ I ~ ~ ~ ~ I ~ I ~ ~ I I I ~ ~ ~ ~ ~ I I I I ~ I I ~ ~ I i I ~ 16" 63# ~ ~ I ~ f @ +/-115' MD ~ i ~ I ~ i I ~ ~ I I I I i ~ I Depths are ~ i i f based on ~ ~ I ~ Doyon 19 ~ , RKB ~ ~ ~ ~ ~ i f. ~ ~ I ~ ~ I ~ I ~ ~ I f. I ~ ~ ~ ~ ~ i ~ ~ Surface csg. ~ ~ ~ ,¿, I I 95/8" 40.0# L-80 BTC I I +1- 2485' MD /2244' TVD ~ I ~ I I I I ~ I J. I ~ I i I I I I I I ~ I i I I I I ~ I I I ~ I I I ~ I I I ~ I I ~ ~ I I ~ I ~ I I I ~ I I I ~ I ~ I ~ I i I ~ I I ~ I ~ I I I i I I I ~ I ~ I ~ I I i ~ ~ I ~ I ~ I I i I I ~ ~ ! I i ~ I ~ I I I 7" Contingency Casing i ~ ~ I 7" 26# L-80 BTCM i ~ +/- 10035' MD / 8300' TVD , I ~ I ~ I I ~ . y CooocóPNiU.ps I I I I I I I I i I I ~ I I I I I I I I I I I I I I I I I I I I I I I ~ I I J. I I I I I I ~ I ~ ConocoPhillips does not intend to complete this well 8 Yo" Production hole to TD @ +/- 10035' MD / 8300' TVD ORIGINAL 11/01/2004 Iapetus 2 - Queries from Monday 27th of December . . Hi Steve, I got your email address from my colleague Steve McKeever so you can ignore that second message I left on your answering machine! Below are the co-ordinates of Iapetus 2 in NAD27, ASP 4. Regarding your question concerning shallow gas at the location the analysis provided by our specialist does not highlight any area of concern as highlighted in the Pre-Drill Seismic Pore Pressure Analysis that accompanied the application for the permit to drill. I will however speak to him again to confirm this. Regards Philip Surface Location: N 6000629 E 354533 Secondary Target: N 5999342 E 350488 Primary Target: N 5999384 E 349989 Bottom Hole Location: N 5999434 E 349399 1 of! 1/4/2005 11 :44 AM 1t>. <?NECHELlj.( 1 ,",,,,~.~MJ~1W.l~;W"'I'/~¡¡;r~i'IJfu'J"'-';"'m."""o~~_....IWf.l~!,"'" '. DATEV~l2,~~1 ~~~~~6HESrJfŒ:-or lfuts(Jf-fAcãcc --7:k~~{~ 'J~i60. SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK 99501 1085 1$\ {OO.OO ~ Se<:urtlyFuture. .....LLARS t· '""..... "'\.7 . DmallsooBac:k. ...... ·CH ASE <om__ ....,~ O. v"",, ~. 0 """ Dol"" U .__,"0___"'''' ~ . .'MO ~,ß_~~~ .: 0 ~ ~ ~ 0 0 ~.......: 2 ~ 8 ... ? V10 ? 11 2 ? b II- ~ 0 8 5 / . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ---r::tL/~dLZ-s 2-- {j 2-D tj - -¿Sf ,/ PTD# Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two. (2) digits are between 60-69) Exploration Stratigraphic ·'CLUE ". Tbe permit is for a new wellboresegment of existing well'. . Permit No, ,'API No. , Production. should continue to be reported as a function' of tbe original API number, stated above. HOLE )n accordance witb 20 AAC 25.005(1), an records, data and Jogs acquired .for tbe pilot bole must be dearly differentiated 'in botb name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for well (name on permi1). Pll..OT (PH) SPACING EXCEPTION / DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 2S.,OSS~ Approval to perforate Bnd produce is contingent upon issuance of ~ conservation order approving a spacing e:Jcep1ion. (Company Name) assumes tbe liability of any protest to tbe spacing .~:Jception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are fint caugbt and ] 0' sample inter:vals tbrougb target zones. PTD#: 2042540 Administration D D Appr Date SFD 1/3/2005 Engineering Appr Date TEM 1/4/2005 ~.\i~ Geology Appr SFD Date 1/4/2005 Geologic Commissioner: DT\S: Field & Pool Well Name: IAPETUS 2 Program j::XP _ Well bore seg Company CONOCOPHILLlPS ALASKA INC Initial ClassfType EXP I PEND GeoArea 973 Unit 50360 On/Off Shore On Annular Disposal I;::~:~t~::::;:::~opriate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .~:: . . . . $urta~ IPcaji~~ i~ ADL ~9Q3M,well passe~ throu~h·ADL 3903¿0, targets and TD In.A[)L3a6465.1hes~ 3 .U.niquewell.n.ame.andlJum"-er...................................... .Yes..... .leas.eswere.a[lcommitted.entir.eIyJothe;3(d.expa.nsiçH!OUhe.CoJvjlle.RjverUl'!ito.n.12-.3:2004............ . 4 Well located in a defil'!e9.ppol . . . . . . . . . . . . .NA . . . Exploratory well . . . . . . . . . . . . 5 WelUocated prJ)per .distance from driJling ul'!itb.oUl'!dary. . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 WelUocated pr.operdistance. from otber welJs . . . . . . . . . . . . . . . . . . . . . . . . yes . . . . . . . . . . . . . . . . . . . . . . . . . . 7 .S.ufficiel'!t<lcreageayail<lble indrillilJg unjt . . . . . . . . .Yes 8 Ifdevi¡¡ted, js weJlbore platil'!cJuded . . . . . . . . . . . . . . . . . . . . . . Yes. 9 Operator 01'!1y: affected party. . . . . . . . . . . . . . . . . .Yes. 10 .Operator bas.apprJ)priate.llond inJorç~ . . . . . . . . . . . . .. .................. .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Permit can be issued witbout conserva.tiol'! order. . . . . . . . . . . . .Yes . . . . . . . 12 Permit c.an be issued witbout ¡¡d.milJistratille.apprJ)vaJ. . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Can permit be approved before 15-day wait Yes 14 WeJUocated withil'! ¡¡rea ¡¡Ild.strataauthorized by.llJjectiPIJ Order # (puUO# in.cJ)mmelJts).(for NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 AJlwelJs.withi.n.1l4.mile.area.ofreyiewidelJtified(FJ)r~ervjcewellOI'!Iy:)............... .NA........................................................................... 16 Pr~-produ.ced injector; 9ur<ltion.of pre-pr09uctiplJ less. than.:3 mOlJtbs.(forservice well onJy) . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . 17 .AÇMPFïl'!djng.of Consistency. has bee.njssued for.tbis Project. . . . . . NA . . . . . . Con.si.stency.d.etermilJatiplJ inprogress;.has IJO effectofljssuing ofpermiUo drill, . . . . 18 .C.onductor stril'!g.provided _ . . . . . . . . . . . . . . _ . . . .Yes. . . . _ . . . . . . . . . . . . . . 19 .S.urfaceca~il'!g.protect~ alLknown. USDWs . . . . . . . . . . . . .Yes. . . . PerAJO 18B. no ~l'!ownUSDWsjlJ CRU.LJ)g alJaJysi.sfor NiqJiQ 1 showss¡¡lini.ty: at 25QO' = - 16QOO ppm,.sjmilar 20 .CMT vol adequate to circ.ulate oncOlJductor & su.rf csg . . .Yes. . . . an.alysis for Temptation 'I . ilJdicates .salinity: ~2.00QO ppm, Casing depth sJmilar tooth.er wells in. aJea. . 21 .CMT vol adeQu.ate.to tie-in Jong string to.surf çsg . . . . . . . . . . . . N.o. . . .ð.11 hydrocarbonzPlJes.!o be coyered. . An.nular di~ppsaJ may be proposed if T' JUn. . . . . . . . 22CMTwill coyeraJl!<lJowflproductiye borizon.s. _ . . . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23C.asing designs ¡¡d.equa.te fJ)r C,T, B& permafrost . Yes . . . . . . . . . . . . . . . . . . . . 24 .Mequ<lte.!ankageor re.serve pit. . . . . _ . . . Yes . . . Rig jse.quippedwitb steeLpits. No reseJV'e.pjtplanlJed, Waste.pJa.nlJed.to be bauJe9.to disposal wells, . . . 25 Jf.aJe-9rilt bas.a. to-40;3 for abandon.me.nt beelJ apPJoved . . . . . . . . . . . . N.A . . . . . . . . . . . . . 26 Agequ<lte.weJlbore ~eparatjo.n.PfOpose9. . . . .. . _ . _ . . . . . . . . . . . . . . . . . . . . . . .Yes . . . _ . . . There. are IJO proximate WellbPres.. . . _ . . . . . _ . . . . . . . . .. ..... _ . . . . . . . . . . . _ . . . . . . . . . 27 Jfdiver:terrequir~d.doesjtmeetreguJatiolJs... ................ Yes. .............. 28 DrillilJg fJuidprogram schem¡¡tic.& eq.uipJistadequate. . . . . . . . . . . . . . . . . . . . Yes . M¡¡ximum expected fJ)rmajtol'! pre~sure.10.0.EMW.. MWplanned.up.to '10.6 ppg . 29 .BPPEs,dJ).they meetreguJatiolJ . . . . . . . . _ . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 .BPPE.press ratilJg appropriate; .test to (pu.t psig i.n .commel'!ts) . . . . . . . . . Yes. . . M.ð.$!=> calcuJate.dat 340;3 psi. 50QOpsi. 6QP test proposed.. . . 31C.hokemanifold complie~ w/APIRP-53(May 84) . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . 32 Work wiJl pccw withput.operatioflsbutdown. . . . . . . . . . . . . . . . . . . . Yes. 33 J~ pre~ence of H2$ g¡¡s. probable. .N.o. 34 Mecba.nicaLcPlJdjtjon J)f wells withil'! .ð.OR yerified (Fpr.s.ervjce welJ onJy) . . . . . . . . . . NA - - - ~ - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ------- ---- - - ~ - - ---~ -~-- - - ~ -- - ~ - - - ~ - - - - - - - - . - - - - - - - e - - - - - ~ - - - - - - - -- . . .1::I2S has.nptbeseen. in theAlpjl'!earea, .RJg is equJpped withs.e[1sors. and.alarm~. . - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit c.a[1 be issued w/Q hydrogen. sulfide meaSjJres . 36 .D.atapreselJted on. pote.ntiC!1 pverpres.sure .zOl'!eJ>. . . 37SeLsmic.an¡¡lysJs of shallow gas.zJ)lJes . . . . . . . . . . . . . . . . . _ . 38 .SeabedcOl'!djtjPIJ survey (if off-sh.ore) . . . _ . . . 39 . Contact l'!am.elphOlleforweelsly prpgre~sreports [exploratpry .only] . . . . . . . _ Exploratory well. . . . _ . . . . . . . . . . . . . . . . . . . . . . . _ Expected pre~surej~ 10~0.ppgEMW;willb.edrilJedwitb '10.5 c 1Q.8 ppg.mud, . . Possibleeleyated pore pre~sure.(1 O~Q ppg) at.3500' TVD ¡¡lolJg weJI path;. will be. driJled. with 1 0..5 ppg mud. . Geophysicist ifldicates low shallow gas Jisk. Will be mudJ09ged. c.onductor to TO; gasdetectPrswJltb.e.uJ>ed. . . . Philip Hayden 265-6481. . . _ _ . . _ . . . . . . - - - ~ - - .. No. Yes . . Yes . _ . NA. - - - - - - Yes. Date: Engineering Commissioner: f!l0~ ;;/~ Date I / t¡~ . Well H ¡story File APPENDIX . Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infonnation 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. · · · ·~~·.¡';'.;;it¡¡r.':;';'¡~;.".',,,¡.tlr")';'J'v..';,\·:'¡;·.'·~-\'''''·"'1';,,;~,,::...,w,_,~.........:.·..~~.,··, -" ~, ..r.,~ CO!~l¡IJ)El",rTI¡~iL I y ConocoPhillips Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA IAPETUS #2 Provided by: ~ 3?OC=-= dOc/-dÇf Approved by: Andrew Buchanan Compiled by: Tim Smith John Morris Distribution: Date: 03/06/05 · · · "",/ ConocoPhillips Alaska. Inc. Iapetus #2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ....................................................................................................2 1 .1 Equipment Summary ......... .... .................................... ..... .......... ..... .......... ............... ............................... 2 1.2 Crew.. .................................. .... .............. .... ........... ..... ................ ..................... .................... ..................... 2 2 WELL DETAILS........ .......................... ................. ..................... ..................... ...................... .......................3 2.1 Well Summary................................................................................................................. .......................3 2.2 Hole Data ......... ............................................................... .................. .................... .................................. 3 3 GEOLOGICAL DATA.................................... .... .............. ........ ......... ........................................................... 4 3.1 Lithostratigraphy...... ...... ................... ............. ........................ ..................... ..................... .......................4 3.2 Mudlog Summary......... ............. ...................... ................................................................ .......................5 3.3 Gas Samples.......................................................................................................................... .............. 10 3.4 Connection Gasses......................................................................... ................... ...... ............................ 12 3.5 Sampling Program / Sample Dispatch ................................................................................................ 12 4 PRESSURE / FORMATION STRENGTH DATA..................................................................................... 13 4.1 Formation IntegritylLeak Off Tests ...................................................................................................... 13 4.2 Wireline Formation Tests............ ........................................................................................... .............. 13 4.3 Pore Pressure Evaluation Introduction ................................................................................................13 4.4 Pore Pressure Evaluation Conclusions ...............................................................................................13 4.5 Pore pressure evaluation..................................................................................................................... 15 5 DRILLING DATA.............................. ...................... ..................... .................................................. ............ 16 5.1 Survey Data ........ ........................................................ ......... ............................ ..................... ................ 16 5.2 Bit Record............... .............. ..... ................................... ............... ................ ..... ..... ...... ......................... 19 5.3 Mud Record.......................................................................................................................... ................19 6 MORNING REPORTS ..............................................................................................................................20 Enclosures 2"/100' Formation Log (MD) 2"/100' Formation Log (TVD) 2"/100' Drilling Dynamics Log 2"/100' Gas Ratio Log 2"/100' LWD / Lithology Log 2"/100' Pore Pressure Log [~ EPOCH 1 "",/ ConocoPhillips Alaska, Inc. Iapetus #2 . 1 MUDLOGGING EQUIPMENT & CREW Artic Series 10 Skid ML014 Years Davs Mudloggers *1 *1 John Morris 31 10 Tim Smith 9 10 ", Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 1.1 Equipment Summary Parameter Ditch gas Rate of penetration (ROP) . Pump stroke counter (SPM) Mud Flow In (MFI) Mud Flow Out (MFO) Hook Load (HL) / Weight on bit (WOB) Pit Volumes, Pit Gain/Loss RPM Torque Mudlogging unit computer system Quadco Well Monitoring Components Mudlogging unit DAC box 1.2 Crew Unit Type Unit Number Equipment Type I Position Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. Primary draw-works block position indicator Optical encoder on draw-works Magnetic proximity sensor Derived from StrokeslMinute From Quadco Hydraulic pressure transducer From Quadco From Quadco From Quadco HP Compaq Pentium 4 (X2, DML & Rigwatch) Quadco System in Mudlogging Unit In-unit data collection/distribution center Sample Catchers Todd Baham Fidel Morfin Years 2 0.5 Total Downtime o o o o o o 0.5 hrs Days 10 10 Comments Flawless performance - no ice blockages in sample line, little or no calibration drift for FID detectors. Flawless performance - exceptional calibration required no footage adjustment. Occasional adjustment after pump work - no lagged depth lost. Flawless performance once hookload heavy enough for Rigwatch logic. Required occasional rebooting Required occasional rebooting. Unit main disconnect blew due to excessive load - UPS, improperly set-up, failed to provide operational power Technician Pete Ramsey Days 2 Additional Comments The job started out with exceptional effort and teamwork from the crew. The unit was spotted in the afternoon and well spud was estimated for later the same night. Rigup/setup had to be accomplished, at least to the point of being able to collect data, in perhaps less than 10 hours. Because of extraordinary diligence in rigup and unit setup few problems were encountered during drilling. The few problems that did develop were relatively minor in nature and resolved with promptness and energy comparable to the rigup effort. . [~ EPOCH 2 ...../ ConocoPhillips Alaska, Inc. Iapetus #2 · 2 WELL DETAILS 2.1 Well Summary Well: Field: Borough: State: Rig Name I Type: Primary Target: Spud Date: Release Date: Completion Status: Classification: TD Formation: Days Drilling: Iapetus #2 Colville River North Slope Alaska Doyon #19 I Artie Triple Nechelik Sands 2/25/2005 3/18/2005 P&A Exploration Jurassic Kingak Fm. 10 API Index #: Suñace Co-Ordinates: Primary Target Depth: TD Depth: Suspension Date: License: Ground Elevation: RT Elevation: Secondary Target Depth: TD Date: Days Testing: 50-1 03-20506-00 Lat: 70.408749N Long: 151.187646W 8798' 9300' NIA NIA 5.78' Pad-MSL 42.55' RT-MSL Not present 3/6/2005 1.5 2.2 Hole Data · Hole Maximum Depth TD Mud Dev. Casingl Shoe Depth Section MD TVDSS Formation Weight (Oinc) Coring Liner MD TVDSS (ft) (ft) (ppg) (ft) (ft) Conduct. 115 -74.45 Undiffer- 10.0 0.0 16" 115 -76.45 entiated no 121/4" 2511 -2226.18 claystone 10.1 35.70 no 9 5/8" 2501 -2219.86 8 1/2" 9300 -7648.23 Shale/clay- 10.6 29.74 no none nla nla stone Additional Comments FIT (ppg) 16.37 nla · [~ EPOCH 3 ../ ConocoPhillips Alaska. Inc. Iapetus #2 · 3 GEOLOGICAL DATA 3.1 Lithostratiqraphv Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geologist. PROGNOSED ACTUAL WlRELlNE PICK FORMATION MD TVDSS MD TVDSS (ft) (ft) (ft) (ft) Base Permafrost 1016 -960 1125 -1068 C40 2328 -2070 2407 -2140 C30 2657 -2330 2680 -2175 C20 3087 -2670 3110 -2705 K-3 4340 -3660 4505 -3809 Brookian Sands 8055 -6600 NOT PRESENT HRZ 8380 -6860 8268 -6779 Base HRZ 8681 -7110 8560 -7022 K1 Marker 8741 -7160 8622 -7072 · Kuparuk C 8831 -7235 8714 -7150 LCU 8831 -7235 8728 -7161 Nechelik Sands 8932 -7320 8798 -7217 Base Nechelik 9206 -7550 9130 -7501 TD 10035 -8300 9300 -7646 · ~ EPOCH 4 ",,/ ConocoPhillips Alaska. Inc. Iapetus #2 · 3.2 MudloQ Summary T ophole to Base of Permafrost First Returns 122' to 1125' MD (-65' to -1068' TVDSS) The top 450 feet of this section consists of massive silty claystone with minor amounts of sand and gravel along with minor amounts of coal and carbonaceous material. The claystone is light to medium brownish gray with occasional olive hues. It is easily hydrated and appears as clay in the samples. The sand and gravel is multicolored and ranges from fine grain to pebble size. It is composed of 50 to 70% lithics with the balance quartz. The bottom of the section is massive sand and gravel with minor silty claystone interbeds. Maximum 246 Drill Rate (ftIhr) I Min~~um I Average 144 Maximum 3 Total Gas (%) I Mini~um I Average 0.5 Base of Permafrost to C40 1125' to 2407' MD (-1068' to -2140' TVDSS) The top 175 feet is multicolored sand and gravel with massive silty claystone below to the bottom of the section. The claystone is light to medium and dark brownish gray with scattered shaley zones of more indurated rock which appear as poorly developed shale in the samples. Minor thin beds of ash fall tuff appearing as bentonite appear at 2340' MD and become more common at the bottom of the section. The claystone remains poorly indurated and easily hydrated and appears as clay in the samples. · Maximum 188 Drill Rate (ftIhr) Minimum 43 Average 141 Maximum 14 Total Gas (%) Minimum o Average 5 C40 to C30 2407' to 2680' MD (-2140' to -2175' TVDSS) This section is massive silty claystone with up to 20% ash fall tuff and a few stringers of very fine to fine grain sand. It is medium to dark brownish gray with occasional slightly olive hues. It is very soft and easily hydrated and appears as clay in the samples. Maximum 238 Drill Rate (ftIhr) Minimum 32 Average 144 Maximum 129 Total Gas (%) Minimum 3 Average 17 · [~ EPOCH 5 Conoc;p'hillips Alaska. Inc. Iapetus #2 C30 to C20 · 2680' to 3110' MD (-2175' to -2705' TVDSS) This section is massive silty claystone with thin streaks of ash fall tuff and minor carbonaceous material along with minor thin sand stringers down to 2888' MD. An increase in thin shaley zones was noted toward the bottom of the section. The claystone is medium to dark brownish gray with occasional olive hues. It is very soft and easily hydrated and appears as clay in the samples. The shale is grayish brown with slight olive gray hues; soft to firm; crumbly to occasionally slightly brittle. The sands dominantly appear loose in the samples and are mostly clear, milky white and very light gray grains. They range from very fine lower to fine with occasional medium size grains. When consolidated the sandstone is friable, composed of mostly quartz with common carbonaceous material and minor lithics. Matrix material is clay with light calcite cement. Maximum 290 Drill Rate (ftIhr) Minimum 95 Average 147 Maximum 76 Total Gas (%) Minimum 5 Average 23 C20 to K-3 3110' to 4505' MD (-2705' to -3809' TVDSS) · This section is dominated by massive silty claystone interbedded with thin streaks of ash fall tuff, shale, siltstone, and sandstone. The claystone becomes increasingly tuffaceous in the lower portion of the section. Substantial amounts of ash fall tuff were observed in the last 200 feet of the interval. The claystone ranges from medium gray to dark brownish gray with olive hues. It is predominantly soft with occasional firmer, less hydrated cuttings seen in the samples. The siltstone tends to lighter shades of gray when clearly interbedded with claystone. The sandstone is more consolidated in this section than that seen in previous sections. Thin stringers of sandstone are seen down to 4100' MD with the highest concentration between 3420' MD and 3570' MD. Sandstone ranges from light gray to brownish gray with localized olive and greenish hues. It is easily friable to soft made up of well sorted lower fine to lower very fine quartz grains grading to silt-sized particles. The grains are subangular to subrounded of moderate sphericity and clay matrix supported. Localized stringers are possibly weakly cemented with calcite. Abundant carbonaceous debris is seen in the cuttings. No sample fluorescence or cut was discernible. Maximum 243 Drill Rate (ftIhr) Minimum 15 Average 180 Maximum 43 Total Gas (%) Minimum 4 Average 17 · [~ EPOCH 6 -.,/ ConocoPhillips Alaska, Inc. Iapetus #2 K-3 to HRZ · 4505' to 8268' MD (-3809' to -6779' TVDSS) Medium to dark brownish gray tuffaceous claystone with thin dark gray to dark brownish gray shale and medium to dark gray siltstone beds dominate the section until 5175' MD where a thin bed of sandstone is encountered. Ditch gas exceeded 100 units in several siltstone zones and in the sandstone at 5175' MD. No oil indicators were distinguishable above the background 1% oil in the drilling mud. Between 7475' MD and 7700' MD trace oil shows were seen in sandstones. The character of the shale changed markedly at about 7950' MD. It is dusky yellowish brown, medium to dark gray and dark brown to black in color. It appears highly organic and very fissile with common thin tuff beds. Note that this shale was not picked as the top of the HRZ. This shale continued to about 8150' MD where the organic character decreased markedly. The balance of the section was interbedded claystone, sand, and dark brownish gray shale. Drill Rate (ftIhr) Maximum Minimum 286 10 Average 127 Maximum 182 Total Gas (%) Minimum 8 Average 25 HRZ to Base HRZ 8268' to 8560' MD (-6783' to -7026' TVDSS) Dusky yellowish brown, occasionally medium to dark gray very fissile shale with high organic content and common thinly bedded tuff dominate the section. The top portion is interbedded with thin very fine to fine quartz rich sands and dark brownish gray claystone beds. · Drill Rate (ftIhr) Maximum Minimum 183 31 Average 108 Maximum 110 Total Gas (%) Minimum 14 Average 40 Base HRZ to K1 Marker 8560' to 8622' MD (-7022' to -7072' TVDSS) Dark gray to grayish black and brownish black very firm to moderately hard shale with minor thin tuff beds dominate this section. Darker colored cuttings with increased fissility become more common in the bottom of the section. Drill Rate (ftIhr) Maximum Minimum 163 25 Average 92 Maximum 62 TQtal Gas (%) Minimum 29 Average 40 · [~ EPOCH 7 · · · "",/ ConocoPhillips Alaska, Inc. Iapetus #2 K1 Marker to LCU Kuparuk Sands 8622' to 8728' MD (-7072' to -7161' TVDSS) This section is dark gray to grayish black and brownish black very firm to moderately hard shale with minor thin tuff beds Maximum 129 Drill Rate (ftIhr) Minimum 24 Maximum 70 Total Gas (%) Minimum 15 Average 33 Average 79 LCU Kuparuk Sands to Nechelik Sands 8728' to 8798' MD (-7161' to -7217' TVDSS) The Kuparuk sand is clear to white translucent, occasionally very light gray to light brownish gray, rarely pale green. Grains range from lower very fine to lower medium with upper to lower fine grains dominating. No sandstone is visible in the samples. 20% of the sample shows dull light yellow oil fluorescence with an instant milky white cut fluorescence. The residual cut ring is pale yellowish white with no discernible visible cut in white light. The bottom of the section is dark gray to grayish black very firm to moderately hard shale. Maximum 93 Drill Rate (ftIhr) Minimum 21 Total Gas (%) Minimum 22 Average 37 Average 60 Maximum 182 Nechelik Sands to Base Nechelik 8798' to 9130' MD (-7217' to -7501' TVDSS) This interval is dominated by loose sand and occasional clayey sandstone toward the bottom. Thin interbeds of shale and claystone are periodic throughout the section. Ashyltuffaceous material is fairly abundant in the upper half of the interval. The sand/sandstone is primarily quartz with undifferentiated lithic fragments increasing to 20% in the lower third. Dominant grain size ranges from very fine to fine with localized zones grading to silt-sized particles. Rarely, in the section's upper third, well rounded lower medium grains of high sphericity are seen. The finer sand transitions from rounded/subrounded to subangular and occasionally angular with depth. It is, in general, well sorted throughout the section. Grains range predominantly from colorless and transparent to milky white with varying translucence. Throughout, a portion is light brown to moderate yellowish brown - seemingly stained. Grains isolated for examination failed to yield discernible fluorescence and no dissolution with solvent. The clasts were too small to scrape the surfaces. The consolidated sandstone cuttings - more abundant in the lower half of the section - have weak calcareous cementation, are easily friable, have medium to dark yellowish brown clay matrix; are variably grain/matrix supported, and have locally good to poor visually estimated porosity and permeability. Overall sample fluorescence ranges from less than 10 to 30% in the top 30 feet, increases to 40 to 60% down to 8940' MD, and runs at 10 to 20% to the bottom of the section. Fluorescence ranges from dull medium yellow at the top to slightly brighter and lighter yellow in the middle and bottom footage. Solvent cuts were instant milky white to light yellow in loose sand and moderately slow streaming of similar intensity and color for sandstone chips. Maximum 122 Drill Rate (ftIhr) Minimum 26 Total Gas (%) Minimum 22 Average 59 Average 70 Maximum 159 [~ EPOCH 8 · · · y.... ConocoPhillips Alaska, Inc. Iapetus #2 Base Nechelik to TD 9130' to 9300' MD (-7501' to -7646' TVDSS) The lowest interval is characterized by four lithology types (in descending order of returns percentages): claystone, shale, sandstonelsand, and siltstone. Claystone returns are massive hydrated lumps with only occasional identifiable induration. Color is dominated by dark browns with dusky yellowish hues and little of the grays seen throughout the hole. It is locally moderately calcareous, silty, and gritty with occasional fine sands embedded in the returned lumps. The shale is similar in the yellowish brown coloration but is distinguished with noticeable grayness. It has moderately well developed fissility apparent even when hydrated from the mud and sample washing. It is non calcareous and has occasional zones of thin carbonaceous laminations and laminations of ashy-appearing material. As with most of the rest of this hole siltstone appears to be a gradational product of degree of claystone siltiness and an interbedded lithology. The sand/sandstone also has localized high silt content as it grades to a clayey siltstone. Consolidated sandstone cuttings are mostly seen at the top of this interval with increasing amounts of loose sand as the bottom of the hole is approached. About 10 percent sample fluorescence is seen in the first 30 feet. This could be due to cavings from the Nechelik Sands immediately above. Maximum 121 Drill Rate (ftIhr) Minimum 30 Average 38 Total Gas (%) Minimum 25 Average 76 Maximum 44 [~ EPOCH 9 ",,/ ConocoPhillips Alaska, Inc. Iapetus #2 · 3.3 Gas Samples 1 unit = 0.05% Methane Equivalent Depth Units C1 C2 C3 C4 C5 (feet) 1 u=0.05% (ppm) (ppm) (ppm) (ppm) (ppm) M.E. 250 1 105 0 0 0 0 500 2 401 0 0 0 0 750 1 102 0 0 0 0 1000 1 185 0 0 0 0 1250 1 169 49 0 0 0 1500 2 356 35 0 0 0 1750 6 1021 48 0 0 0 2000 8 1260 30 8 0 0 2250 9 1329 2 0 0 0 2500 21 3160 39 0 0 0 2750 36 5543 41 13 0 0 3000 18 3573 44 20 11 0 3250 9 1763 24 5 0 0 3500 20 3934 74 6 0 0 3750 16 2937 11 2 0 0 4012 10 1787 7 0 0 0 4200 28 3763 95 21 6 0 4260 26 4686 82 20 10 0 4327 40 6569 180 43 17 0 4510 40 6388 155 39 26 0 · 4600 43 7026 233 65 46 14 4700 18 2885 116 47 39 14 4800 30 4531 187 74 66 27 4900 25 3839 170 59 55 25 5000 18 3006 136 41 36 11 5100 19 3254 112 27 20 6 5192 136 19800 1140 576 332 211 5300 41 6367 316 166 108 25 5400 32 5108 212 121 84 36 5500 27 4194 166 84 76 15 NOTE: GAS BAGS IN SHORT SUPPLY - GO TO 500' INTERVALS FOR ROUTINE SAMPLING AS PER WELL-SITE GEOLOGIST'S INSTRUCTIONS 6000 19 I 3231 I 82 I 16 I 19 5 6500 13 2246 63 19 9 3 NOTE: SLOWER ROP - SAMPLE AT 250' INTERVALS 6750 12 I 2173 I 60 I 34 I 20 3 7000 19 3215 102 62 35 18 NOTE: RESUME SAMPLING AT 100' INTERVALS 7100 19 3319 115 60 28 8 7200 19 3156 130 56 29 8 7300 19 3247 143 80 39 2 7400 27 4005 198 146 86 12 7500 27 3850 216 164 99 34 · [~ EPOCH 10 ..../ ConocoPhillips Alaska, Inc. Iapetus #2 · Depth Units C1 C2 C3 C4 C5 (feet) 1 u=0.05% (ppm) (ppm) (ppm) (ppm) (ppm) M.E. 7600 34 4900 254 247 161 62 MDITVD Depth NOTE: BEGIN SAMPLING 100' TVD INTERVALS AT 6400' TVD 7736/6400 18 1814 122 170 180 98 7864/6500 28 3795 163 151 128 44 7994/6600 20 2787 120 113 100 43 8121/6700 80 13426 626 283 147 51 8249/6800 23 3398 186 126 98 22 8362/6900 27 4251 210 112 87 24 8481/6996 30 4702 283 160 101 50 8607/7100 43 8223 533 407 242 65 8722/7200 70 8913 591 627 881 558 MD Depth NOTE: BEGIN SAMPLING 10' MD INTERVALS AT 8732' MD 8732 182 24461 1713 1771 1066 483 8839 67 7964 559 581 410 206 8847 70 8442 607 680 445 278 8860 25 2434 196 244 225 109 8870 54 8228 592 599 363 157 8877 125 45483 3499 3663 2173 939 8890 153 18320 1441 1558 960 423 8898 128 15087 1202 1326 856 378 8910 103 11166 946 1105 757 310 8925 91 9331 781 1015 710 365 · 8935 89 8271 761 984 750 346 8950 50 3372 426 671 591 296 8960 60 4541 490 751 643 297 8970 51 4137 423 663 553 300 8980 48 3518 367 596 526 269 8990 48 3442 349 575 519 277 9005 58 4593 419 678 561 256 9018 58 4716 410 665 613 320 9030 51 3950 348 583 559 305 9040 41 3117 278 479 473 267 9050 39 3148 256 430 398 234 9060 41 3512 247 397 398 234 9070 44 4039 258 421 448 258 9080 44 4045 249 417 443 255 9090 36 2681 206 343 394 244 9100 SAMPLE MISSED 9120 43 4113 263 I 353 409 250 9130 43 3948 254 337 387 234 9140 SAMPLE MISSED 9150 44 I 4469 I 251 I 309 I 365 219 NOTE: BEGIN SAMPLING 50' MD INTERVALS AT 9200' 9200 38 4182 236 235 288 196 9250 39 4242 247 250 300 189 9300 35 4027 197 190 194 143 · [~ EPOCH 11 ....,..- ConocoPhillips Alaska, Inc. Iapetus #2 · 3.4 Connection Gases 1 unit = 0.05% Methane Equivalent Depth I Units I C1 I C2 I C3 I C4 I (feet) (ppm) (ppm) (ppm) (ppm) (ppm) NOTE: NO DISCERNIBLE CONNECTION GASES WERE SEEN WHILE DRILLING THE WELL. C5 3.5 Samplinq Proqram I Sample Dispatch Set Type I Purpose Frequency Interval Dispatched to Bayview Warehouse Unwashed Biostratigraphy 30' 120' - 7500' MD ConocoPhillips Alaska, Inc. A 619 E. Shipcreek Ave., Suite 102 Set owners: CPAI 10' 7500 - 9300' MD Anchorage, AK 99502 Attn: D. PrzywojskilM. McCracken Bayview Warehouse Unwashed Biostratigraphy 30' 120' - 7500' MD ConocoPhillips Alaska, Inc. B 619 E. ShipcreekAve., Suite 102 Set owners: Anadarko 10' 7500 - 9300' MD Anchorage, AK 99502 Attn: D. PrzywojskiIM. McCracken Washed, screened & dried Bayview Warehouse 30' 120' - 7500' MD ConocoPhillips Alaska, Inc. C Reference Samples 10' 7500 - 9300' MD 619 E. Shipcreek Ave., Suite 102 Set owner: CPAI Anchorage, AK 99502 Attn: D. PrzywojskilM. McCracken Washed, screened & dried Bayview Warehouse 30' 120' - 7500' MD ConocoPhillips Alaska, Inc. D Reference Samples 10' 7500 - 9300' MD 619 E. Shipcreek Ave., Suite 102 Set owner: CPAI Anchorage, AK 99502 · Attn: D. PrzywojskiIM. McCracken Washed, screened & dried Bayview Warehouse 30' 120' - 7500' MD ConocoPhillips Alaska, Inc. E Reference Samples 10' 7500 - 9300' MD 619 E. ShipcreekAve., Suite 102 Set owner: Anadarko Anchorage, AK 99502 Attn: D. Przywojski/M. McCracken Washed, screened & dried Bayview Warehouse 30' 120' - 7500' MD ConocoPhillips Alaska, Inc. F Reference Samples 10' 7500 - 9300' MD 619 E. ShipcreekAve., Suite 102 Set owner: State of AK Anchorage, AK 99502 Attn: D. PrzywojskilM. McCracken Gas bags lsotech Laboratories, Inc. Routine intervals and 250' 250' - ' 4000 G significant peaks above 100' 4000' - 9300' MD 1308 Parkland Court background Champaign, IL 61821 H Onsite Samplex Samples 30' 120' - 7500' MD To on-site geologist 10' 7500 - 9300' MD Tom Lorenson USGS canned 60' single u.s. Geological Survey J grab 60' - 3000' 345 Middlefield Road, MS-999 geochemical samples Menlo Park, CA 94025 samples Phone: (650) 329-4186 Fax: (650) 329-5441 Sample frequency was locally altered according to drill rate constraints. · [~ EPOCH 12 ...../ ConocoPhillips Alaska,lnc. Iapetus #2 · 4 PRESSURE I FORMATION STRENGTH DATA 4.1 Formation InteQritv/Leak Off Tests Equivalent mud weight (EMW) is calculated from rotary table (RT). MD TVDSS LOT I FIT (ft) (ft) (ppg EMW) 2532 -2244 16.37 FORMATION Claystone/shale 4.2 Wire line Formation Tests DSI, MSCT, MDT, SWC 4.3 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of a well; Background Gas (BG) Resistively (RES) Hole Conditions (HC) Trip Gas (TG) Mud Weight (MW) Corrected D exponent (DXC) Connection Gas (CG) Quantitative Methods · The primary indicators used for pore pressure evaluation were gas trends, as DXC and RES data plots did not suggest any reliable trends. Factors such as controlled drill rates, PDC bits, and absence of clean shale baselines to establish compaction trends precluded reliable estimation. Qualitative estimation was weighted heavily on gas trends relative to MW and ECD, including increases in background gas, appearance and trends of connection gases, magnitude of trip gases, and $urface manifestations of hole conditions. ECD data was measured downhole, continuously while drilling (PWD), and provided by Sperry- Sun. 4.4 Pore Pressure Evaluation Conclusions Qualitative estimation was limited to consideration of increases in background gas, appearance and trends of connection gasses, and surface manifestations of hole conditions. An increase in the background gas associated with a slight increase in wiper gas indicates a slight increase in the pore pressure towards the base of the K-3 Formation. No connection gasses were observed in this section and therefore pore pressure was considered well below the effective mud weight. Throughout the HRZ there was a slightly increasing trend in the background gas, suggesting an increase in the pore pressure to the base of this formation. The lack of any significant connection gases or changes in surface manifestations of hole conditions, suggest that the pore pressure remained well below the effective mud weight. Below the HRZ the background gas returned to a normal baseline suggesting a return to the pore pressure baseline. · The background gas suggests no significant changes in pore pressure until the Nechelik Sands where the [~ EPOCH 13 · · · '10-""'- ConocoPhillips Alaska, Inc. Iapetus #2 increase in background gas suggests a slight increase in the pore pressure, The lack of connection gas or changes in surface manifestations of hole conditions imply the pore pressure remained below the effective mud weight. The apparent complete absence of even traces of connection gas and seemingly suppressed drill gas implies the hole was drilled overbalanced by an indeterminate amount. [~ EPOCH 14 . COnOCailliPS . Alaska, Inc. Iapetus #2 4.5 Pore pressure evaluation Formation Primary Secondary Interval Tops Pore Pressure 'EMW) Trend Source of Interval Lithology Lithology MD rvDSS Min Max Trend Indicators Quantitative Estimate (%) (%) (ft) (ft) (ppg) (ppg) Base Permafrost Sd/gravel Clyst 1125 -1072 8.6 8.6 normal none No CG/ very low BG C40 Clyst Sltst 2407 -2144 8.6 8.6 normal none No CG/ very low BG C30 Clyst AshlTuff 2680 -2179 8.6 8.6 normal none No CG/ very low BG C20 Clyst Sltst 3110 -2709 8.6 8.6 normal none No CG/ very low BG K-3 Clyst Sh 4505 -3814 8.6 9.0 + BG,WG BG slightly elevated/low-mod WG Brookian Sands NOT PRESENT HRZ Sh Clyst 8268 -6783 9.0 9.0 normal none No CG/steady BG Base HRZ Sh Clyst 8560 -7026 9.0 9.2 + BG BG slightly elevated K1 Marker Sh Clyst 8622 -7076 9.2 9.2 normal none No CG/steady BG LCU Kuparuk Sands Sh Sd 8728 -7165 8.77 8.77 normal none MDT Nechelik Sands Sd Sltst 8798 -7221 9.2 9.2 normal none BG slightly elevated Base Nechelik Clyst Sh 9130 -7505 9.2 9.2 normal none No CG/steady BG TD 9300 -7691 9.2 9.2 normal none NOTE: Clyst = Claystone/Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sst = Sandstone [~ EPOCH 15 Conocð"Phillips Alaska, Inc. Iapetus #2 . 5 DRilLING DATA 5.1 Survey Data Measured True Vertical Dogleg Incl. Azim. Vertical Northings Eastings Depth (0) (0) Depth (ft) (ft) Section Rate (ft) (ft) (ft) (°/1000) 148.69 0.76 196.54 148.69 -0.95 -0.28 0.51 0.51 197.09 0.83 56.57 197.08 -1.07 -0.08 0.34 3.09 288.95 0.72 90.47 288.94 -0.71 1.05 -0.85 0.50 379.07 1.19 85.42 379.04 -0.64 2.55 -2.31 0.52 470.36 1.00 215.63 470.33 -1.21 3.03 -2.64 2.17 560.03 3.22 251.39 559.93 -2.64 0.19 0.47 2.77 649.84 6.34 251.30 649.42 -5.04 -6.90 7.93 3.47 739.34 9.07 249.47 738.10 -9.10 -18.19 19.87 3.06 829.86 11.17 249.78 827.21 -14.63 -33.10 35.68 2.33 921.07 14.24 254.74 916.18 -20.64 -52.22 55.69 3.57 1016.00 16.39 252.56 1007.73 -27.72 -76.26 80.73 2.34 1111.65 18.02 250.06 1099.10 -36.81 -103.04 108.93 1.88 1206.56 21.17 250.43 1188.50 -47.56 -133.00 140.61 3.32 1302.29 25.16 248.06 1276.50 -60.96 -168.18 178.00 4.28 1397.27 28.67 248.25 1361.18 -76.95 -208.08 220.61 3.70 1492.60 31.81 248.13 1443.53 -94.79 -252.64 268.19 3.29 . 1587.43 34.83 248.59 1522.76 -113.99 -301.06 319.84 3.20 1682.70 35.52 248.64 1600.63 -134.01 -352.16 374.30 0.73 1777 .97 35.98 248.61 1677 .95 -154.30 -404.00 429.53 0.48 1872.98 36.51 248.25 1754.57 -174.95 -456.24 485.24 0.60 1967.84 36.94 251.85 1830.61 -194.29 -509.54 541.66 2.31 2062.70 37.13 252.25 1906.34 -211.90 -563.89 598.68 0.33 2158.24 36.91 251.62 1982.62 -229.73 -618.58 656.07 0.46 2253.64 36.69 251.95 2059.01 -247.59 -672.87 713.08 0.32 2349.14 36.32 252.32 2135.77 -265.02 -726.94 769.78 0.45 2440.66 35.70 251.69 2209.80 -281.64 -778.12 823.47 0.78 2580.86 37.77 251.94 2322.15 -307.80 -857.79 907.13 1.48 2676.27 37.19 252.13 2397.86 -325.71 -913.01 965.06 0.62 2771 .27 36.31 250.61 2473.98 -343.86 -966.87 1021.73 1.33 2866.50 35.32 250.13 2551.21 -362.58 -1019.35 1077.21 1.08 2961.57 36.52 249.90 2628.20 -381.64 -1071.76 1132.69 1.26 3057.10 35.48 249.37 2705.49 -401.18 -1124.40 1188.52 1.13 3152.02 37.00 248.50 2782.04 -421.36 -1176.76 1244.23 1.68 3249.57 38.51 249.54 2859.17 -442.73 -1232.53 1303.54 1.68 3343.39 37.74 249.21 2932.98 -463.13 -1286.74 1361.10 0.85 3438.75 38.36 252.76 3008.07 -482.26 -1342.29 1419.65 2.38 3533.97 37.46 253.99 3083.20 -499.01 -1398.35 1478.11 1.24 3629.37 36.62 252.46 3159.35 -515.58 -1453.37 1535.51 1.31 3724.66 37.68 251.72 3235.30 -533.28 -1508.12 1592.93 1.21 . [=I EPOCH 16 .....,..- ConocoPhillips Alaska, Inc. Iapetus #2 · Measured True Vertical Dogleg Incl. Azim. Vertical Northings Eastings Depth (0) t) Depth (ft) (ft) Section Rate (ft) (ft) (ft) (0/10Oft) 3819.80 36.83 251.89 3311.03 -551.27 -1562.83 1650.39 0.90 3915.28 35.75 250.60 3387.99 -569.43 -1616.34 1706.72 1.38 4010.46 37.60 249.37 3464.33 -588.90 -1669.75 1763.27 2.09 4105.75 37.03 249.40 3540.11 -609.23 -1723.82 1820.68 0.59 4201.05 39.10 248.36 3615.14 -630.42 -1778.62 1879.01 2.27 4296.64 38.81 247.73 3689.47 -652.88 -1834.35 1938.56 0.51 4392.20 38.17 247.22 3764.27 -675.66 -1889.29 1997.41 0.74 4487.59 39.30 250.11 3838.68 -697.36 -1944.89 2056.63 2.23 4583.29 38.78 248.96 3913.01 -718.44 -2001.36 2116.55 0.94 4678.73 39.16 250.25 3987.22 -739.35 -2057.61 2176.22 0.94 4774.16 38.19 250.76 4061.72 -759.25 -2113.82 2235.60 1.07 4870.11 37.45 250.57 4137.51 -778.73 -2169.34 2294.20 0.77 4963.49 38.62 251.98 4211.06 -797.19 -2223.84 2351.56 1.56 5061.35 38.12 253.72 4287.79 -815.10 -2281.87 2412.22 1.22 5156.89 37.16 253.22 4363.44 -831.70 -2337.81 2470.52 1.05 5252.16 36.57 252.75 4439.66 -848.43 -2392.46 2527.61 0.69 5347.72 37.79 253.72 4515.79 -865.08 -2447.76 2585.30 1.42 5443.26 37.01 254.30 4591.69 -881.06 -2503.54 2643.30 0.90 5539.08 38.47 254.09 4667.46 -897.04 -2559.97 2701.93 1.53 · 5634.58 37.59 254.60 4742.69 -912.91 -2616.63 2760.75 0.98 5730.08 38.50 251.72 4817.90 -929.97 -2672.94 2819.53 2.09 5825.62 37.38 250.63 4893.25 -948.92 -2728.54 2878.08 1.37 5921.03 39.16 250.30 4968.15 -968.69 -2784.23 2936.91 1.88 6016.42 38.68 251.16 5042.36 -988.46 -2840.80 2996.61 0.76 6111.83 37.82 250.07 5117.29 -1008.06 -2896.52 3055.44 1.15 6207.03 38.29 250.62 5192.25 -1027.80 -2951.78 3113.86 0.61 6301.93 37.31 249.96 5267.23 -1047.41 -3006.54 3171.76 1.13 6398.64 36.72 250.25 5344.46 -1067.23 -3061.29 3229.70 0.63 6494.26 38.30 250.92 5420.30 -1086.58 -3116.20 3287.69 1.71 6589.59 39.23 250.86 5494.62 -1106.13 -3172.61 3347.16 0.97 6684.91 38.27 249.74 5568.96 -1126.23 -3228.77 3406.55 1.25 6780.35 37.41 250.18 5644.34 -1146.30 -3283.77 3464.79 0.94 6875.80 38.16 249.31 5719.77 -1166.55 -3338.64 3522.95 0.96 6971.22 37.12 249.06 5795.33 -1187.26 -3393.10 3580.84 1.10 7064.95 35.65 249.75 5870.79 -1206.82 -3445.15 3636.10 1.63 7160.33 36.98 249.16 5947.64 -1226.65 -3498.04 3692.23 1.44 7257.36 37.82 249.22 6024.73 -1247.59 -3553.12 3750.77 0.87 7352.47 39.58 247.56 6098.95 -1269.50 -3608.39 3809.74 2.15 7448.14 38.44 247.57 6173.29 -1292.48 -3664.05 3869.34 1.19 7541 .35 38.03 250.59 6246.51 -1313.08 -3717.92 3926.62 2.05 7638.73 38.24 256.46 6323.14 -1330.11 -3775.53 3986.64 3.73 7733.99 38.72 261.46 6397.73 -1341.43 -3833.67 4045.78 3.31 · [~ EPOCH 17 .../ ConocoPhillips Alaska, Inc. Iapetus #2 · Measured True Vertical Dogleg Incl. Azim. Vertical Northings Eastings Depth (0) (0) Depth (ft) (ft) Section Rate (ft) (ft) (ft) (0/10Oft) 7829.57 38.91 265.28 6472.21 -1348.34 -3893.16 4105.14 2.51 7925.18 38.54 269.07 6546.81 -1351.30 -3952.87 4163.76 2.52 8020.79 37.18 270.44 6622.29 -1351.56 -4011.55 4220.69 1.67 8116.00 36.12 269.63 6698.68 -1351.51 -4068.38 4275.77 1.22 8211.44 35.22 267.77 6776.21 -1352.77 -4124.02 4330.01 1.48 8306.65 35.32 272.47 6853.96 -1352.65 -4178.96 4383.24 2.85 8402.32 34.42 274.44 6932.45 -1349.37 -4233.55 4435.35 1.51 8497.87 33.02 274.07 7011.92 -1345.43 -4286.45 4485.65 1.47 8593.32 33.47 271.79 7091.75 -1342.76 -4338.70 4535.65 1.39 8688.30 33.51 272.11 7170.96 -1340.97 -4391.08 4585.98 0.19 8783.99 34.20 275.36 7250.43 -1337.49 -4444.26 4636.67 2.02 8879.21 33.41 275.90 7329.56 -1332.29 -4496.98 4686.50 0.89 8974.49 32.66 275.14 7409.43 -1327.29 -4548.68 4735.38 0.90 9070.01 31.54 274.95 7490.35 -1322.83 -4599.24 4783.29 1.17 9163.93 30.47 274.43 7570.85 -1318.87 -4647.46 4829.06 1.18 9229.72 29.74 275.66 7627.76 -1315.97 -4680.33 4860.21 1.45 9300.00 29.74 275.66 7688.78 -1312.53 -4715.02 4892.99 0.00 · · [~ EPOCH 18 "",'" ConocoPhillips Alaska. Inc. Iapetus #2 5.2 Bit Record Bit Depth In Total Bit Avg. WOB PP Make Type Jets I TFA MD / rvDSS Footage Hrs Rap (klbs) RPM (psi) Wear BHA (ft) (ftlhr) 121/4" Hole NB# 2X18,1X16 750- 1 HTC GT-CM1 ,1X12/ 115/-76 2396 17.82 134.46 5 - 30 39.2 2360 7 -5-WT -A-E-4-SD- TD #1 0.804 81/2" Hole NB# HTC I HCM-605 I 5X 16/ 2511/ 6789 I 66.74 101.72 I 1 - 32 73.8 1500 - 1-1-BT-H-X-1-NO-TD 1#2 2 0.982 -2227.82 4500 5.3 Mud Record Contractor :MI SWACO Mud Type :KCIIKlagard Spud Date MW I ECD I VIS PV YP Gels FL FC Sols OIW Sd CI Ca (ppg) (ppg) (s/qt) (cc) (%) Ratio (%) (mill) (mill) 12 %" Section 2/25/05 10.0+ 10.3 81 17 34 13/18/19 5.8 1/- 9.0 /91 0.50 34000 600 2/26/05 10.1 10.3 87 18 48 24/33/36 6.2 1/- 10.5 /90 0.75 29000 440 2/27/05 10.1+ N/A 220 22 88 46/54/57 6.4 1/- 10.5 /90 0.75 23000 500 8 %" Section 2/28/05 10.0 N/A 100 18 54 26/33/34 7.0 1/- 10.5 /90 0.75 22000 440 3/1/05 9.9 N/A 100 13 30 13/18/19 8.6 1/- 10.5 /90 0.75 22000 380 3/2/05 10.6 11.98 47 16 31 10/17/20 5.6 1/2 10.5 1/89 0.75 34000 380 3/3/05 10.5 12.63 46 15 31 12/24/28 7.0 1/2 12.0 1/88 0.25 30000 340 3/4/05 10.5 11.78 47 20 28 8/20/25 5.6 1/2 13.0 2/85 Tr 30500 260 3/5/05 10.5 11.60 46 19 26 7/18/22 5.2 1/2 13.0 3/84 Tr 30000 200 3/6/05 10.6 11.41 46 20 26 9/19/24 5.0 1/2 13.0 3/85 Tr 34500 200 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 . [~ EP~H . 19 . 6 Morning reports .ConocoPhillips Alaska Inc. Iapetus #2 I Report for: I Larry Hill Dick Owens Date: 2/2612005 Time: 03:00 Current Depth: Yesterdays Depth: 24 hr Footage: 1074' 115' 959' Operation: Drilling Drilling Parameters ROP: Current: 160 Max: Torque: Current: 4K Max: 4K WOB: Current 12 Max: 15 RPM: Current: 40 Max: 70 PP: Current: 1400 Max: 1400 Lag: Strokes: 1238 Time: 9.5 Circulation: Strokes: 1335 Time: 10.2 ECD: Current: 10.2 Max: 10.3 Mud Properties I MW: 110.0 FV: I 90 PV: I 17 YP: I 40 FH I Gels: Sol: pH: cr Ca . MW Change: None Mud Loss event: None . Gas Data I Ditch Gas: I Current: 11u I Max: 2u I Depth: 1253' Gas Events Trip Gas N/A Connection Gas 0 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 0-2u 0454 0 0 0 0 0 0 Gas Sam :>Ies No. Depth 1 250 2 500 3 750 TG .5 2 .5 C1 105 401 102 C2 o o o C3 o o o C41 o o o C4N o o o C51 o o o C5N o o o Lithologies: Current: Last 24 hrs: 40% SAND, 40% GRAVEL, 20% CLAY 30% SAND, 20% GRAVEL, 40% CLAY, 1 0% SILTSTONE . Operational Summary: I Clean out conductor. Drill ahead. Calibrations: I THA, Chromatograph, hookload, block height. Failures: None [~ EPOCH 20 · I Report for: I Larry Hill Dick Owens ConocoPhillips Alaska Inc. Iapetus #2 Date: 2/27/2005 Time: 04:30 Current Depth: 2511' Operation: Wiper trip. Yesterdays Depth: 1074' 24 hr Footage: 1437' Drilling Parameters ROP: Current: 101 Max: 187 Torque: Current: 8k Max: 8k WOB: Current 20-35 Max: 35 RPM: Current: 70 Max: 70 PP: Current: 1970 Max: 1970 Lag: Strokes: 3280 Time: 21 min Circulation: Strokes: 3536 Time: 23min ECD: Current: 10.2 Max: 10.3 Mud Properties I MW: 110.1 1 Gels: 24/33/36 FV: I 87 Sol: 10.5 PV: I 18 pH: 9.5 YP: I 48 cr 29000 FL: 16.2 Ca ++ 440 MW Change: None Mud Loss event: None Gas Data I Ditch Gas: I Current: 118u Max: 21u I Depth: 12502' Gas Events · Trip Gas N/A Wiper Gas 35u pk/10u bkgnd Connection Gas Ou Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N No Significant Peaks Gas Sam )Ies No. Depth TG C1 C2 C3 C41 C4N C51 C5N 4 1000 1u 185 0 0 0 0 0 0 5 1250 1u 169 49 0 0 0 0 0 6 1500 2.2u 356 35 0 0 0 0 0 7 1750 6u 1021 48 0 0 0 0 0 Lithologies: Current: Last 24 hrs: 70% claystone, 30% volcanic tuff. 30% sand and gravel, 50% claystone, 10% siltstone, 10% volcanic tuff. I Operational Summary: I Drill to 2511', circulate hole clean, pump out 500' continue wiping hole. I Calibrations: I THA, Chromatograph I Failures: I Unit power failure-reset circuit breaker. · [=I EPOCH 21 ConocoPhillips Alaska Inc. · Iapetus #2 I Report for: I Larry Hill Dick Owens Date: 2/28/2005 Time: 03:00 Current Depth: 2511' Operation: Running casing. Yesterdays Depth: 2511' 24 hr Footage: 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 3280 Time: 21 min Circulation: Strokes: 3536 Time: 23min ECD: Current: 10.2 Max: 10.2 Mud Properties I MW:/ FV"' PV: , YP: I FL: I Gels: Sol: pH: cr· Ca++: MW Change: None Mud Loss event: None Gas Data I Ditch Gas: I Current: 2u I Max: 15u I Depth: I 2511' Gas Events · Trip Gas N/A Wiper Gas 5u pkl2u bkgnd Connection Gas N/A Peaks I Depth I TG C1 C2 C3 C41 C4N C51 C5N Gas Sam :>Ies No. Depth TG C1 C2 C3 C41 C4N C51 C5N 8 2000 8u 1260 30 8 0 0 0 0 9 2250 9 1329 2 0 0 0 0 0 10 2500 21 3160 39 0 0 0 0 0 Lithologies: Current: No new hole Last 24 hrs: I Operational Summary: I Wipe hole, wash and ream tight spots, circulate, pull out of hole. Run casing.. I Calibrations: I None I Failures: I None · [1 EPOCH 22 · I Report for: I Larry Hill Dick Owens ConocoPhillips Alaska Inc. Iapetus #2 Date: 3/112005 Time: 03:00 Current Depth: Yesterdays Depth: 24 hr Footage: 2511' 2511' 0' Operation: Pick up pipe. Drilling Parameters: (Not applicable.) ROP: Current: Max: WOB: Current Max: PP: Current: Max: Lag: Strokes: Time: ECD: Current: Max: Torque: Current: Max: RPM: Current: Max: Circulation: Strokes: Time: Mud Properties I MW: \9.8 Gels: FV: I 40 Sol: PV: I pH: YP: I cr Fb I Ca . MW Change: None Mud Loss event: None Gas Data I Ditch Gas: I Current: 10 I Max: 15u I Depth: I 2511' Gas Events · Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N 2511' 5u Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N No New Hole Gas Sam :>Ies No. Depth TG C1 C2 C3 C41 C4N C51 C5N No New Hole Lithologies: Current: No new hole. Last 24 hrs: I Operational Summary: I Land casing. Cement casing. Nipple down. Nipple up. Test BOPs. Pick up pipe. I Calibrations: I Failures: I None. · [~ EPOCH 23 . I Report for: I Don Mickey Dick Owens Date: 312105 Time: 03:00 ConocoPhillips Alaska Inc. Iapetus #2 Current Depth: Yesterdays Depth: 24 hr Footage: 2511' 2511' o Operation: Testing casing. Drilling Parameters: (No new hole.) ROP: Current: Max: WOB: Current Max: PP: Current: Max: Lag: Strokes: Time: ECD: Current: Max: Mud Properties I MW: 19.9 I Gels: 13/18/19 MW Change: Mud Loss event: Torque: Current: Max: RPM: Current: Max: Circulation: Strokes: Time: FV: 1100 Sol: 10.5 PV: I 13 pH: 9.1 YP: 130 cr 22000 FL: 18.6 Ca++: 380 Depth: 2511' Depth: None Reason: Csg. . Gas Data I Ditch Gas: I Current: I 0 Gas Events Trip Gas N/A Connection Gas Peaks I Depth I TG N/A Gas Sam Jles I No. Depth N/A N/A C1 TG Lithologies: Current: No new hole. Last 24 hrs: I Operational Summary: From: 10.1 Volume: To: 9.9 I Max: /0 I Depth: TG C1 C2 C3 C41 C4N C51 C5N TG C1 C2 C3 C41 C4N C51 C5N C2 C3 C41 C4N C51 C5N C1 C2 C3 C41 C4N C51 C5N I Pick up drill pipe and BHA. Run in hole to2390'. Circ. Bottoms up. Slip and cut drilling line. Test 95/8" casing. I Failures: I Calibrations: I THA, Chromatograph I None . [~ EPOCH 24 · I Report for: I Don Mickey Dick Owens ConocoPhillips Alaska Inc. Iapetus #2 Date: 3/312005 Time: 03:00 Current Depth: 4550' Operation: Drilling Yesterdays Depth: 2511' 24 hr Footage: 2039' Drilling Parameters: ROP: Current: 190 Max: 290 Torque: Current: 9500 Max: 9500 WOB: Current 8-20K Max: 20K RPM: Current: 70 Max: 70 PP: Current: 2920 Max: 2920 Lag: Strokes: 2488 Time: 16.2 Circulation: Strokes: 2953 Time: 19.2 ECD: Current: 12.25 Max: 12.7 Mud Properties I MW: 110.6 I Gels: 10/17120 FV: I 47 Sol: 10.5 PV: I 16 pH: 8.9 YP: 131 C( 34000 FL: 15.6 Ca++: 380 MW Change: Mud Loss event: Depth: 2531' Depth: NONE From: 9.9 Volume: To: 10.5 Reason: Planned Gas Data I Ditch Gas: I Current: Max: 129u Depth: I 2657' Gas Events · Trip Gas N/A TG C1 C2 C3 C41 C4N C51 C5N Connection Gas None TG C1 C2 C3 C41 C4N C51 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 4200 28 3763 95 21 3 3 4327 40 6569 180 43 7 10 Gas Sam :>Ies No. Depth TG C1 C2 C3 C41 C4N C51 C5N 11 2750 36 5543 41 13 0 0 0 0 12 3000 18 3573 44 20 7 4 0 0 13 3250 9 1763 24 5 0 0 0 0 14 3500 20 3934 74 6 0 0 0 0 15 3750 16 2937 11 2 0 0 0 0 16 4012 10 1787 7 0 0 0 0 0 17 4200 28 3763 95 21 3 3 0 0 18 4260 26 4686 82 20 5 5 19 4327 40 6569 180 43 7 10 20 4510 40 6388 155 39 14 12 Lithologies: Current: Last 24 hrs: Note: trace oil show from 3920' to 3950'. 40% tuffaceous claystone, 20% claystone, 10% tuff, 10% shale, 20% siltstone. 10% sand, 50% claystone, 20% tuffaceous claystone, 10% tuff, 10% shale I Operational Summary: I Clean out casing float and shoe. Drill 20'. Perform leak off test. Drill ahead. · I Calibrations: I None Failures: None [:I EPOCH 25 · ConocoPhillips Alaska Inc. Iapetus #2 Daily Report I Report for: I Don Mickey Dick Owens Date: 3/412005 Time: 03:00 Current Depth (MD): Yesterday's Depth : 24 hr Footage (MD): 6210' 4550' 1660' Current Operations: DRILLING Drilling Parameters ROP: Current: 120 Max: 286 Torque: Current: 10K Max: 10K WOB: Current 20 Max: 20 RPM: Current: 90 Max: 90 PP: Current: 3950 Max: 3950 Lag: Strokes: 3390 Time: 22.0 Circulation: Strokes: 4024 Time: 26.1 ECD: Current: 12.40 Max: 12.84 Mud Properties I MW: 110.5 FV: I 47 PV: I YP: I FL: I Gels: Sol: pH: cr Ca++: MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data · I Ditch Gas: I Current: I 20u I Max: 182u I Depth (MDfTVD): 14730' Gas Events Depth Trip Gas (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N Wiper Gas 5030' 22u/12u Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NONE Peaks Depth (MD) TG C1 C2 C3 C41 C4N C51 C5N 4555 127 10638 307 78 25 33 1 1 4730 182 13671 476 171 38 53 13 14 5190 167 24329 1408 713 174 236 107 109 Gas Samples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 21 4600 43 7026 233 65 21 25 7 7 22 4700 18 2885 116 47 16 23 5 9 23 4800 30 4531 187 74 30 36 15 12 24 4900 25 3839 170 59 21 34 11 14 25 5000 18 3006 136 41 14 22 6 5 26 5100 19 3254 112 27 8 12 3 3 27 5192 136 19800 1140 576 141 191 94 117 28 5300 41 6367 316 166 45 63 13 12 29 5400 32 5108 212 121 36 48 25 11 30 5500 27 4194 166 84 34 42 10 5 31 6000 19 3231 82 16 8 11 2 3 · [~ EPOCH 26 I Lithologies: I Current: 170% claystone, 10% tuffaceous claystone, 10% siltstone, 10% shale. · Last 24 hrs: 40% claystone, 30% tuffaceous claystone, 20% siltstone, 10% volcanic tuff. Operational Summary: I Drill from 4550' to 5030', wipe hole, drill to report depth. Calibrations: None Failures: None. · · [~ EPOCH 27 · Co no coP hill ips Alaska Inc. Iapetus #2 Daily Report I Report for: I Don Mickey Dick Owens Date: 3/5/2005 Time: 03:00 Current Depth (MD): Yesterday's Depth: 24 hr Footage (MD): 7540' 6210' 1330' Current Operations: DRILLING Drilling Parameters ROP: Current: 60 Max: 191 Torque: Current: 11k Max: 11k WOB: Current 20k Max: 20k RPM: Current: 90 Max: 90 PP: Current: 4020 Max: 4020 Lag: Strokes: 4162 Time: 29 Circulation: Strokes: 4939 Time: 35 ECD: Current: 11.55 Max: 12.82 Mud Properties I MW: 110.5 FV: 149 PV: 120 YP: I 28 FL: 112 Gels: 8/20/25 Sol: 13 pH: 9.0 C( 30500 Ca ++: 260 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data I Ditch Gas: I Current: I 20u I Max: 135u I Depth (MDITVD): I 7507' · Gas Events Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MDfTVD) N/A Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MDITVD) NONE Peaks Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 7372 34 5228 283 207 38 72 12 13 7507 35 5059 296 225 42 90 20 20 Gas Samples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 32 6500 13 2246 63 19 5 4 1 2 33 6750 12 2173 60 34 8 12 2 1 34 7000 19 3215 102 62 13 22 11 7 35 7100 19 3319 115 60 9 19 3 5 36 7200 19 3156 130 56 12 17 4 4 37 7300 19 3247 143 80 14 25 1 1 38 7400 27 4005 198 146 29 57 7 5 39 7500 27 3850 216 164 34 65 19 15 · [~ EPOCH 28 I Lithologies: I Current: 180% CLAYSTONE, 10% SHALE, 1 0% SILTSTONE · Last 24 hrs: 80% CLAYSTONE, 10% SHALE, 1 0% SILTSTONE Operational Summary: I Drill from 6210' to 7540'-report depth. Calibrations: I NONE I Failures: NONE · · [~ EPOCH 29 · ConocoPhillips Alaska Inc. Iapetus #2 Daily Report r Report for: I Don Mickey Dick Owens Date: 3/612005 Time: 03:00 Current Depth (MD): Yesterday's Depth: 24 hr Footage (MD): 8310' 7540' 770' Current Operations: Drilling. Drilling Parameters ROP: Current: 125 Max: 167 Torque: Current: 11.5K Max: 11.5K WOB: Current 17K Max: 20K RPM: Current: 90 Max: 90 PP: Current: 4040 Max: 4350 Lag: Strokes: 5380 Time: 34.5 Circulation: Strokes: 6388 Time: 40.9 ECD: Current: 11.78 Max: 11.95 Mud Properties I MW: 110.5 FV: 146 PV: I 19 YP: 126 FL: 15.2 Gels: 7/18/22 Sol: 13 pH: 8.8 Cr 30000 Ca ++: 200 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data · I Ditch Gas: I Current: I 18u I Max: 1110u I Depth (MDfTVD): 18078' Gas Events Depth Trip Gas (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N Wiper Gas 7610' 123u/62u Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NONE Peaks Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 7687 74 10832 581 541 110 237 72 71 8078 110 18902 891 435 71 161 40 37 8106 104 18255 813 376 76 109 37 27 8144 94 15668 784 345 59 117 29 40 Gas Samples No. I Depth (MDfTVD) I TG I C1 I C2 I C3 I C41 I C4N I C51 C5N 40 7600/ 34 4900 254 247 57 104 25 37 NOTE: ROUTINE GAS BAG SAMPLES COLLECTED EVERY 100' TVD AFTER 7600' MD 41 7736/6400 17 1566 112 159 53 125 52 33 42 7864/6500 28 3795 163 151 40 88 27 17 43 7994/6600 20 2787 120 113 30 70 23 20 44 8121/6700 80 13426 626 283 47 100 30 21 45 8249/6800 23 3398 186 126 33 65 12 10 · [~ EPOCH 30 fLithOIOgies: I Current: 150% CLAYSTONE, 30% SHALE, 20% SAND. · Last 24 hrs: 40% CLAYSTONE, 20% SIL TSTONE, 20% SAND, 20% SHALE. I Operational Summary: I Drill to 7610', wipe hole. Drill to report depth. I Calibrations: I THA, CHROMATOGRAPH I Failures: I NONE · · [1 EPOCH 31 ConocoPhillips Alaska Inc. · Iapetus #2 Daily Report I Report for: I Don Mickey I Dick Owens Date: 3/7/2005 Time: 03:00 Current Depth (MD): 9300 Current Wiper trip. Prior Depth (MD): 8310 Operations: 24 hr Footage (MD): 990 Drilling Parameters ROP: Current: 77 Max: 183 Torque: Current: 12K Max: 12K WOB: Current 8-22K Max: 22K RPM: Current: 80 Max: 90 PP: Current: 4400 Max: 4400 Lag: Strokes: 5952 Time: 37.2 Circulation: Strokes: 7081 Time: 44.3 ECD: Current: 11.4 Max: 11.85 Mud Properties I MW: 110.6 FV: I 46 PV: 120 YP: 1 26 FL: 15 Gels: 9/19/24 Sol: 13 pH: 9.1 cr 34500 Ca ++; 200 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data · I Ditch Gas: I Current: I 35u 1 Max: I 182u 1 Depth (MD): 18732' Gas Events Depth Trip Gas (MD) TG C1 C2 C3 C41 C4N C5/ C5N N/A Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MD) NONE Peaks Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 8732/ 182 24461 1713 1771 310 2081 248 1314 88661 144 16018 1131 1162 231 547 182 166 88761 132 50914 3911 4083 643 1771 544 499 88921 159 19040 1502 1632 275 742 232 216 Gas Samples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C5/ C5N 46 8463/6900 27 4251 210 112 19 58 13 11 47 8481/6996 30 4702 283 160 32 69 29 21 48 8607/7100 43 8223 533 407 75 166 33 32 49 8722/7200 70 8913 591 627 127 754 66 492 50 8732/ 182 24461 1713 1771 310 756 248 235 51 8839/ 67 7964 559 581 116 294 107 99 52 8847/ 70 8442 607 680 138 307 134 144 53 8860/ 25 2434 196 244 75 150 56 53 54 8870/ 54 8228 592 599 101 262 82 75 · 55 8877/ 125 45483 3499 3663 580 1593 490 449 56 88901 153 18320 1441 1558 260 700 220 203 57 8898/ 128 15087 1202 1326 231 625 194 184 58 8910/ 103 11166 946 1105 205 552 145 165 [~ EPOCH 32 59 8925/ 91 9331 781 1015 183 527 186 179 60 8935/ 89 8271 761 984 203 547 177 169 . 61 8950/ 50 3372 426 671 157 434 154 142 62 8960/ 60 4541 490 751 171 472 153 144 63 8970/ 51 4137 423 663 131 422 158 142 64 8980/ 47 3518 367 596 138 388 139 130 65 8990/ 48 3442 349 575 139 380 145 132 66 9005/ 58 4593 419 678 128 433 119 137 67 9018/ 58 4716 410 665 165 448 168 152 68 9030/ 51 3950 348 583 145 414 159 146 69 9040/ 41 3117 278 479 119 354 139 128 70 9050/ 39 3148 256 430 107 319 129 118 71 9060/ 41 3512 247 397 102 296 123 111 72 9070/ 44 4039 258 421 120 328 134 124 73 9080/ 44 4045 249 417 119 324 134 121 74 9090/ 36 2681 206 343 110 284 128 116 75 9100/ Missed 76 9120/ 43 4113 263 353 114 295 129 121 77 9130/ 43 3948 254 337 109 278 123 111 78 9140/ Missed 79 9150/ 44 4469 251 309 102 263 111 108 Switched to 50 foot interval. 80 9200 38 4182 236 235 87 201 101 95 81 9250 39 4242 247 250 97 203 99 90 82 9300 35 4027 197 190 69 125 77 66 I Lithologies: I Current: 130% claystone, 30% shale, 20% sand, 20% siltstone Last 24 hrs: 30% claystone, 40% shale, 10% sand, 20% siltstone . I Operational Summary: I Drill to 9300', circulate, wipe hole. I Calibrations: I NONE I Failures: I NONE . [=I EPOCH 33 Well Logs - - - -- - - - -- 2,1'1 .. "L~ Pore Pressu_r~ Log - --- -------- ---~-- - --~--- -----.---.------.---. --------- -;;;;;1--------- 1...,., l.~T Gas Ratio Log _ __... _JI' ~-~--~ - - - ------~------~-- -~-,~-_.,~--- --------20., - - z t;ij------- LWD Combo Log - - - ,- - -----þ-.,-:-., S .,------.------- Drtlling _D_yna.mi_c~J~9g --~_. -_.__._----~ . ----" ,_.._----------_.-----~--- z,t.f- 2 ''I ----~ Formation Log (MD) - - ._-------------------~------------ ~ol(..U, _Formation LC?g CrVD) . -- - ----- ~-- ---~- - --~- -------~ ----~--_._----_.----~,~~_.__._----- "-r-- \ \ ~ . I 0 ~ \JJ.J2JJ...) ) ~ V&-G~ ~ .~~ f~cbv · .c.~ Aoaee (ðfY . Ii· nL·· \1 ,.1 ?~ 207.,.:2-~7 .:: '. ;"",~::. GeochemicalA;n~lytical Results: lapetus~,2 VVeli"SninpJes 2005, North St'ope';'Alaska CONFIDENTIAL ConocoPhillips Subsurface Technology November 2005 ConocoPhillips Subsurface Technology 2005 Geochemical Data Report By Albert G. Holba Vickie Webb 5fJz i ~A- -zo'Î ~ zS?! evf,? CONHOEN1\~L . Geochemical Analytical Results: Iapetus-2 Well, North Slope, Alaska ConocoPhillips Subsurface Technology, Data Report November 2005 Geochemical analytical data for core extracts, sidewall core extracts, MDT oil, MDT gas, and mud gas samples from the 2005 well, Iapetus-2, are reported here. Table 1 provides sample identification and description as well as an inventory of analyses performed on the samples in 2 parts. Analyses of oil and rock samples were performed by Baseline Resolution Inc. (current address: 143 Vision Park Blvd., Shenandoah, TX, 77384). Iapetus-2 samples are referenced to Baseline project code 05-252-A. Data is provided in the Vendor Data Appendices. . Gas and mud gas analyses were performed at Isotech Laboratories, (1308 Parkland Court, Champaign, Illinois, 61821) under Isotech Jobs 6116 and 6006. Gas compositions and isotopic ratios (carbon and deuterium) MDT gases are provided in the Miscellaneous Vendor Data section of the Vendor Data Appendices. Select archived samples, from Iapetus area wells were re-analyzed by whole oil gas chromatography for this study and the data is included here. Complete data for these samples is available in previous reports. . Samples were analyzed in 2005 under the technical work agreement for the Iapetus-2 well, WBT.160417.IB. . ConocoPhillips Subsurface Technology 2005 Geochemical Data Report Table of Report Contents --. Vendor Data Appendices Miscellaneous Vendor Data Gas Analysis (1 page). Isotech Mudgas Data Analysis (2 pages). API Gravity (1 page). Soxhlet Extraction (1 page). Medium Pressure Liquid Chromatograghy Fractionation (1 page). Carbon Isotopes Oil Fractions (1 page). Gas Chromatoerams and numerical data for Whole Oil (WGC): Sample ID Raw Data Depth Formation Number File Number of Paees Iapetus 2 US 136203 G4050356, 8719.0 Kuparuk (3 pages); US 136203 G4050367, 8719.0 Kuparuk (3 pages); US 136204 G4050358, 8721.0 Kuparuk (3 pages); US 136205 G4050359, 8854.0 N echelik (3 pages); US 136206 G4050360, 8859.0 N echelik (3 pages); US 136207 G4050361, 8861.0 Nechelik (3 pages); . US 136208 G4050362, 8867.0 Nechelik (3 pages); US 136209 G4050363, 8872.0 Nechelik (3 pages); US136210 G4050346, 8722.1 Kuparuk (3 pages); US136210 G4050351, 8722.1 Kuparuk (3 pages); Nil!liq 1 US039525 G4050349, 7259.0 Kuparuk (3 pages); Temptation 1 US 118448 G4050348, 7180.5 Kuparuk (3 pages); US118449 G4050350, 7412.0 Nechelik (3 pages); Fiord 5 US 120653 G405034 7, 6877.5 Kuparuk (3 pages); Gas Chromatoeraphv/Mass Spectrometrv (GC/MS) saturate hydrocarbon chromatograms and numerical data; Iapetus 2 US 136207 M2050506, 8861.0 Nechelik (17 pages); US136210 M2050432, 8722.1 Kuparuk (17 pages); . 2 ConocoPhillips Subsurface Technology 2005 Geochemical Data Report . Gas Chromatosæ;raphvffandem Mass Spectrometry (GC/MS/MS) saturate hydrocarbon mass chromatograms and numerical data; Iapetus 2 US 136210 MS050174, 8722.1 Kuparuk (16 pages); Gas Chromatosæ;raphv/Mass Spectrometry (GC/MS) aromatic hvdrocarbon chromatograms and numerical data. Iapetus 2 US 136207 US136210 M1050547, M1050456, 8861.0 8722.1 N echelik Kuparuk (16 pages); (16 pages). . . 3 Sample_ID US136485 US136210 US136203 US136204 US136205 US136206 US136207 US136208 US 136209 US039525 US118449 US118448 US120653 Site Name lapetus-2 lapetus-2 lapetus-2 lapetus-2 lapetus-2 lapetus-2 lapetus-2 lapetus-2 lapetus-2 Nigliq-1 Temptation-1 Temptation-1 Fiord-5 Sample Type MDT gas MDT oil percussion SWC TABLE 1. Sample Identification Depth (ft) 8722.1 8722.1 8719 percussion SWC 8721 percussion SWC 8854 core plug core plug core plug 8867 percussion SWC 8872 oil oil oil oil 7259 7412 7180.5 6877.5 1 - Analyzed in previous study, not part of this study. . Formation Kuparuk C Kuparuk C Kuparuk C Nechelik Nechelik Nechelik Nechelik Nechelik Nechelik Nechelik Nechelik Kuparuk C Kuparuk C OldlD Number 01X07840 96X04459 96X04458 99X07597 page 4 . C Q) o > :;:;:;:; 0 ~J! O:I: ~~ C)-oJ w!1I õ;J â)o cn :c ..!. < .!! :E >< E D: .co _0 OQ)<I cn cn u:!: C) o Q. C :I: e II) 0 0-oJ 1'1I0'1':;:; :I: ca T ïñ II) cn - UJ 0 Q) ëcn mz e,Q. c(:E II) II) ES cn US Q) Q) 0 0 :E :E go go 0 .!! Õ Õ Õ Õ = = C)C) II) II)(!)C) x X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X 1 1 1 1 X 1 X 1 X 1 X 1 X X 1 1 1 1 1 1 1 1 1 1 1 1 . TABLE 1 (part 2) Sample Identification . en c en CÞ 0 0- :¡:¡ CÞ .s Iii 0- 0 0 0 Õ .!! 0- S .!! en 0 en !'IS 0 !'IS C) Sample Depth en C) '1' Sample_ID Site Name Type (ft) Formation !'IS .... N C) 0 0 US136265 lapetus-2 mud gas 250 X US136266 lapetus-2 mud gas 500 X US136267 lapetus-2 mud gas 750 X US136268 lapetus-2 mud gas 1000 X US136269 lapetus-2 mud gas 1250 X US136270 lapetus-2 mud gas 1500 X US136271 lapetus-2 mud gas 1750 X X US136272 lapetus-2 mud gas 2000 X X US136273 lapetus-2 mud gas 2250 X US136274 lapetus-2 mud gas 2500 X X US136275 lapetus-2 mud gas 2750 X X US136276 lapetus-2 mud gas 3000 X X US136277 lapetus-2 mud gas 3250 X X US136278 lapetus-2 mud gas 3500 X US136279 lapetus-2 mud gas 3750 X X US136280 lapetus-2 mud gas 4012 X X US136281 lapetus-2 mud gas 4200 X X US136282 lapetus-2 mud gas 4260 X X . US136283 lapetus-2 mud gas 4327 X X US136284 lapetus-2 mud gas 4510 X X US136285 lapetus-2 mud gas 4600 X X US136286 lapetus-2 mud gas 4700 X X US136287 lapetus-2 mud gas 4800 X X US136288 lapetus-2 mud gas 4900 X X US136289 lapetus-2 mud gas 5000 X X US136290 lapetus-2 mud gas 5100 X X US136291 lapetus-2 mud gas 5192 X X X US136292 lapetus-2 mud gas 5300 X X US136293 lapetus-2 mud gas 5400 X X US136294 lapetus-2 mud gas 5500 X X US136295 lapetus-2 mud gas 6000 X X US136296 lapetus-2 mud gas 6500 X X US136297 lapetus-2 mud gas 6750 X X US136298 lapetus-2 mud gas 7000 X X US136299 lapetus-2 mud gas 7100 X X US136300 lapetus-2 mud gas 7200 X X US136301 lapetus-2 mud gas 7300 X X US136302 lapetus-2 mud gas 7400 X X US136303 lapetus-2 mud gas 7500 X X US136304 lapetus-2 mud gas 7600 X X US136305 lapetus-2 mud gas 7736 X X US136306 lapetus-2 mud gas 7864 X X US136307 lapetus-2 mud gas 7994 X X US136308 lapetus-2 mud gas 8121 X X . US136309 lapetus-2 mud gas 8249 X X US136310 lapetus-2 mud gas 8363 X X US136311 lapetus-2 mud gas 8481 X X TABLE 1 (part 2) Sample Identification UI · C UI Q) 0 Q. ~ Q) 0 ¡ii Q. ... 0 0 0 ... .!! Q. 0 E .!! UI 0 UI lIS 0 lIS C) Sample Depth UI C) .,. SampleJD Site Name Type (ft) Formation lIS .... N C) 0 0 US136312 lapetus-2 mud gas 8609 X X US136313 lapetus-2 mud gas 8722 X X lapetus-3 mud gas 8732 X X X US136314 lapetus-2 mud gas 8839 X X US136315 lapetus-2 mud gas 8847 X X US136316 lapetus-2 mud gas 8860 X X US136317 lapetus-2 mud gas 8870 X X US136318 lapetus-2 mud gas 8877 X X US136319 lapetus-2 mud gas 8890 X X X US136320 lapetus-2 mud gas 8898 X X US136321 lapetus-2 mud gas 8910 X X US136322 lapetus-2 mud gas 8925 X X US136323 lapetus-2 mud gas 8935 X X US136324 lapetus-2 mud gas 8950 X X US136325 lapetus-2 mud gas 8960 X X US136326 lapetus-2 mud gas 8970 X X US136327 lapetus-2 mud gas 8980 X X US136328 lapetus-2 mud gas 8990 X X US136329 lapetus-2 mud gas 9005 X US136330 lapetus-2 mud gas 9018 X X · US136331 lapetus-2 mud gas 9030 X X US136332 lapetus-2 mud gas 9040 X X US136333 lapetus-2 mud gas 9050 X X US136334 lapetus-2 mud gas 9060 X X US136335 lapetus-2 mud gas 9070 X X US136336 lapetus-2 mud gas 9080 X X US136337 lapetus-2 mud gas 9090 X X US136338 lapetus-2 mud gas 9120 X X US136339 lapetus-2 mud gas 9130 X X US136340 lapetus-2 mud gas 9150 X X US136341 lapetus-2 mud gas 9200 X X US136342 lapetus-2 mud gas 9250 X X US136343 lapetus-2 mud gas 9300 X X US136484 lapetus-2 mud gas 8732 X X · ConocoPhillips Subsurface Technology . DISTRIBUTION LIST: Albert Holba (CoP/ Sub-Surface Technology) Bev Burns ConocoPhillips Alaska Inc Post drill Summary reports, for partners, etc. To Bev Burns ConocoPhillips Records, Houston . . (1 copy) (1 copy) 2005 Geochemical Data Report (4 archive copies) (1 archive copy). 7 ANALYSIS Lab#: Sample Name/Number: Company: Date Sampled: Container: Field/Site Name: Location: Formation/Depth: Sampling Point: Date Received: Component Carbon Monoxide ------------ Hydrogen Sulfide ------------. H el i u m -------------------------- Hydrogen ----------------------. Argon --------------------------- Oxygen ------------------------- Nitrogen ------------------------ Carbon Dioxide --------------- Methane -----------------------. Ethane -------------------------- Ethylene ------------------------ Propane ------------------------ Iso-butane --------------------- N-butane ----------------------- Iso-pentane -------------------. N-pentane --------------------- Hexanes + --------------------- EPO 82372 Job #: 8722 ConocoPhillips, Alaska 3/13/2005 500 ml stainless Iapetus 2 5/10/2005 Date Reported: Chemical mol. % nd nd 0.0284 0.0172 0.0091 nd 1.82 0.54 90.87 2.99 nd 2.39 0.344 0.632 0.139 0.116 0.106 6/14/2005 Delta 13C per mil Delta 0 per mil Delta 15N per mil -57.60 -36.78 -215.4 T 6116 nd = not detected. na = not analyzed. Isotopic composition of carbon is relative to VPDB. Isotopic '~ composition of hydrogen is relative to VSMOW. Calculations for BTU and specific gravity per ASTM 03588. Chemical compositions are normalized to 100%. Mol. % is approximately equal to vol. %. Chemical analysis based on standards accurate to within 2% (A1ISOTECH Laboratories, Inc. 1308ParklandCt. Champaign,IL61821 217/398-3490 -34.98 -34.13 -35.11 Total BTU/cu.ft. dry @ 60deg F & 14.7psia, calculated: 1083 Specific gravity, calculated: 0.626 ANALYSIS ',-=I EPORT Isotech Mudgas Data Job 6006 Iapetus #2 Isotech Depth 1 Gas GC O2 + Ar CO2 N2 CO C1 C2 C2H4 C3 C3He iC4 nC4 iCs nCs Ce+ 813C1 8DC1 813C2 8DC2 813C3 öDC3 813iC4 813nC4 Comments Lab No. Feet Units Date ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm %0 %0 %0 %0 %0 %0 %0 %0 81394 250 0-1 4/08/2005 216300 6000 777700 0 12 0 0 0 0 0 0 0 0 5 81395 500 2 4/08/2005 218200 430 781300 0 32 0 0 0 0 1 0 0 0 6 81396 750 0-1 4/08/2005 218600 480 780900 0 23 0 0 0 0 0 0 0 0 3 81397 1000 1 4/08/2005 218700 400 780900 0 26 0 0 0 0 0 0 0 0 4 81398 1250 1 4/08/2005 218300 410 781100 0 227 0 0 1 0 0 0 0 0 3 81399 1500 2.2 4/08/2005 218600 400 781000 0 38 1 0 1 0 0 1 0 0 2 81400 1750 6 4/08/2005 216500 350 782200 0 990 4 0 1 0 0 0 0 0 2 -76.2 81401 2000 8 4/08/2005 216200 340 782500 0 981 1 0 0 0 0 0 0 0 4 -74.2 81402 2250 9 4/08/2005 216900 460 781700 0 906 2 0 1 0 1 1 0 0 2 81403 2500 21 4/08/2005 215800 400 781000 0 2750 6 0 2 0 1 1 0 0 2 -52.0 81404 2750 35 4/08/2005 215400 430 777300 0 6880 10 0 6 0 3 2 1 0 2 -44.7 81405 3000 19 4/08/2005 216100 520 780400 0 2960 10 0 4 0 2 2 1 1 2 -47.5 81406 3250 9 4/08/2005 217100 480 781000 0 1380 7 0 3 0 2 2 1 1 5 -47.6 81407 3500 20 4/08/2005 218500 410 780600 0 435 5 0 1 0 0 0 0 0 2 81408 3750 16 4/08/2005 216200 510 780800 0 2510 14 0 1 0 1 1 1 1 3 -48.8 81409 4012 10 4/08/2005 217200 480 780900 0 1410 15 0 2 0 1 1 1 0 2 -47.0 81410 4200 28 4/08/2005 214500 580 781400 0 3420 59 0 16 0 4 5 3 2 4 -46.7 81411 4260 26 4/08/2005 213700 560 781500 0 4120 83 0 22 0 4 6 2 1 4 -45.4 81412 4327 40 4/08/2005 214600 560 778300 0 6260 166 0 47 0 5 8 2 1 6 -45.7 81413 4510 40 4/08/2005 214300 500 779000 0 5960 130 0 41 0 9 9 4 3 8 -44.1 81414 4600 43 4/08/2005 215200 450 778500 0 5540 177 0 65 0 18 20 10 8 19 -43.7 81415 4700 18 4/08/2005 215100 480 781400 0 2810 102 0 49 0 14 19 9 7 19 -43.8 81416 4800 30 4/08/2005 215700 500 779500 0 3980 165 0 81 0 20 36 15 16 30 -43.7 81417 4900 25 4/08/2005 215200 520 780600 0 3390 137 0 61 0 15 28 12 12 30 -45.0 81418 5000 18 4/08/2005 215300 550 781300 0 2610 100 0 38 0 10 19 9 10 24 -45.4 81419 5100 19 4/08/2005 214800 520 781600 0 2930 93 0 27 0 6 11 5 5 14 -46.6 81420 5192 165 4/08/2005 208800 540 766100 0 22100 1180 0 712 0 144 199 68 48 60 -47.7 ·207.8 -33.0 -30.8 -31.7 -31.2 81421 5300 41 4/08/2005 213700 540 779200 0 5890 276 0 177 0 40 64 24 19 34 -47.1 81422 5400 32 4/08/2005 213900 540 780600 0 4510 190 0 116 0 29 42 16 14 25 -48.1 81423 5500 27 4/08/2005 213900 550 ·781100 0 4060 152 0 90 0 26 37 16 14 30 -48.7 81424 6000 19 4/08/2005 215000 590 781500 0 2810 61 0 24 0 5 8 3 3 10 -52.6 81425 6500 13 4/08/2005 215200 570 782100 0 2080 50 0 19 0 4 5 2 2 8 -54.4 81426 6750 15 4/09/2005 215500 540 781600 0 2220 69 0 39 0 7 12 4 4 8 -55.1 81427 7000 19 4/09/2005 213100 750 783200 0 2770 92 0 60 0 11 22 8 8 15 -55.8 81428 7100 19 4/09/2005 212900 560 783600 0 2770 98 0 55 0 8 15 5 5 10 -55.6 81429 7200 19 4/09/2005 213500 600 782900 0 2760 105 0 59 0 7 13 4 4 8 -56.1 81430 7300 18 4/09/2005 214900 620 782500 0 1770 94 0 65 0 8 16 4 4 11 -55.3 81431 7400 27 4/09/2005 213000 700 782600 0 3320 167 0 141 0 22 46 12 12 15 -56.5 81432 7500 27 4/09/2005 212400 740 782700 0 3670 192 0 178 0 31 63 17 17 27 -56.8 81433 7600 34 4/09/2005 212900 750 781300 0 4400 226 0 239 0 46 92 27 27 32 -57.0 81434 7736 18 4/09/2005 212700 770 784700 0 1280 99 0 177 0 52 107 39 39 53 -54.7 6400' TVD 81435 7864 28 4/09/2005 212400 790 782900 0 3380 152 1 152 0 33 71 23 24 33 -58.2 6500' TVD 81436 7994 20 4/09/2005 213500 990 782800 0 2310 113 1 107 0 22 53 18 20 33 -56.6 6600' TVD 81437 8121 80 4/09/2005 211800 750 776000 0 10600 451 1 233 0 35 62 17 16 17 -58.7 6700' TVD 81438 8249 23 4/09/2005 213500 930 782200 0 2960 157 1 128 0 27 54 18 18 28 -57.4 6800' TVD 81439 8363 27 4109/2005 213100 1100 781700 0 3720 179 1 113 0 23 49 18 17 30 -58.4 6900' TVD 81440 8481 30 4/09/2005 213100 1100 779400 0 5710 302 1 192 0 32 66 22 19 31 -57.3 6296' TVD (Al I SO TECH Laboratories, Inc. 1308 Parkland Ct. Champaign, IL 61821 217/398-3490 217/398-3490 1308 Parkland Ct. Champaign, IL 61821 lA1IsOTECH Laboratories, Inc. ( ANAL YSIS REPORT Isotech Mudgas Data Job 6006 Iapetus #2 Isotech Depth 1 Gas GC O2 + Ar CO2 N2 CO C1 C2 C2H4 C3 C3He iC4 nC4 iCs nCs Ce+ Õ13C1 õDC1 Õ13C2 õDC2 Õ13C3 õDC3 Õ13¡C4 õ13nC4 Comments Lab No. Feet Units Date ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm %0 %0 %0 %0 %0 %0 %0 %0 81441 8609 43 4/09/2005 213400 1200 780200 0 4410 292 1 249 0 40 85 26 22 36 -57.1 7100' TVD 81442 8722 70 4/09/2005 211700 580 778800 0 7350 471 2 563 0 103 215 66 57 69 -56.9 7200' TVD 81443 8732 182 4/09/2005 207700 620 766200 0 21100 1380 4 1640 1 275 583 173 150 160 -57.3 -212.6 -36.66 -206. 1 -32.92 -166.6 -33.8 -34.8 81444 8839 67 4/09/2005 211700 720 778000 0 7790 517 4 644 1 111 263 84 75 94 -55.8 7299' TVD 81445 8847 70 4/09/2005 215200 560 779600 0 36~0 261 2 331 1 59 145 48 45 73 -56.7 81446 8860 25 4/09/2005 213600 600 782800 0 2210 174 2 253 0 54 130 45 40 50 -55.7 81447 8870 54 4/09/2005 212600 760 781900 0 3360 334 3 518 1 97 232 74 68 77 -56.3 81448 8877 125 4/09/2005 208900 710 774900 0 12500 907 8 1140 3 176 412 119 108 105 -56.0 81449 8890 153 4/09/2005 208400 680 769800 0 17000 1270 13 1590 5 244 581 163 146 131 -56.2 -36.86 -34.94 -34.1 -35.5 81450 8898 128 4/09/2005 209800 690 772500 0 13400 1020 8 1340 3 215 528 158 145 152 -56.3 81451 8910 103 4/09/2005 211100 720 774900 0 10300 822 7 1130 3 188 458 139 125 126 -56.2 81452 8925 91 4/09/2005 211900 730 776500 0 8180 686 6 1000 3 171 424 132 120 128 -55.8 81453 8935 89 4/09/2005 211600 760 776700 0 8230 680 6 991 3 172 425 134 122 137 -55.7 81454 8950 50 4/09/2005 213200 740 781200 0 3000 353 3 667 2 134 337 112 104 118 -56.1 81455 8960 60 4/09/2005 213300 710 780400 0 3750 366 4 649 2 129 326 109 101 115 -56.4 81456 8970 51 4/09/2005 213300 750 781000 0 3270 329 4 612 2 125 316 108 100 113 -56.3 81457 8980 47 4/09/2005 213200 830 780900 0 3240 331 4 635 2 132 338 116 110 133 -56.0 81458 8990 48 4/09/2005 213400 850 781000 0 3100 307 4 597 2 126 323 112 105 123 -56.0 81459 9005 58 4/09/2005 bag leaking 81460 9018 58 4/09/2005 211200 610 781900 0 4350 362 4 695 2 150 378 129 118 132 -54.9 81461 9030 51 4/09/2005 211700 780 782200 0 3580 301 4 591 2 133 331 114 104 116 -56.1 81462 9040 41 4/09/2005 212500 760 782900 0 2530 215 3 441 1 106 263 95 87 109 -55.0 81463 9050 39 4/09/2005 212300 750 783300 0 2450 201 3 419 1 1 04 254 91 78 92 -55.5 81464 9060 41 4/09/2005 212100 770 782600 0 3150 224 3 429 1 107 271 100 92 107 -56.2 81465 9070 44 4/09/2005 212100 800 782200 0 3510 237 3 424 1 106 268 101 93 111 -56.3 81466 9080 44 4/09/2005 212300 730 782300 0 3370 227 3 401 1 102 255 96 88 106 -56.4 81467 9090 36 4/09/2005 212500 720 783300 0 2330 175 3 350 1 95 242 94 86 104 -55.3 81468 9120 43 4/09/2005 212000 580 782500 0 3720 222 3 360 1 99 240 95 85 101 -56.2 81469 9130 43 4/09/2005 212200 560 782500 0 3590 219 3 355 1 99 239 96 85 100 -56.0 81470 9150 44 4/09/2005 209700 770 784500 0 3950 214 3 315 1 90 214 87 78 95 -55.1 81471 9200 38 4/09/2005 212200 500 782700 0 3720 197 2 248 1 77 164 74 63 81 -56.3 81472 9250 39 4/09/2005 206100 600 788200 0 4080 225 3 277 1 89 170 82 67 93 -54.8 81473 9300 32 4/09/2005 214500 680 781100 0 3030 161 2 174 0 57 97 53 41 65 -55.7 Chemical analysis based on standards accurate to within 2% d isotope values obtained via off/ine-prep dual inlet MS BASELINE CGSI ..~ _·W _ _ ....·._IIW·. :...~_...... :..~ BASELINE DGSI, U.S.A. BASELINE DGSI, Brasil GEOCHEMICAL ANALYSIS OF Iapetus Prepared For: ConocoPhillips Performed By: Baseline Resolution Project: 05-252-A May 2005 8701 New Trails Drive, The Woodlands, Texas 77381-4241, Tel: 281.681.2200, Fax: 281-681-0326 E-mail: info@baselinedQsi.com. Rua Jardim Botânico 674/413, Jardim Botânico, 22460-030 Rio de Janeiro (RJ) - Brazil Tel/Fax: + 55.21 12259.5992 E-mail: office@reslabsolintec.com.br Web: httpJ/www.baselinedQsi.com OIL OIL SWC SWC SWC SWC SWC SWC SWC sWC MDT M[)T OIL CHIS 6877.5 FT 7180.5 FT 8719 8719 8721 8854 8859 8861 8867 8872 8722.1 8722.1 7259 FT 74.12FT FIORD 5 TEMPTATION 1 IAPETUS-2 IAPETUS-2 IAPETUS-2 IAPETUS"2 IAPETUS-2 IAPETUS-2 IAPETUS-2 IÁPËTUS,-2 IAPETUS-2 IAPETUS..2 NIGUQ 1 TEMPTATION 1 FIORD ? I.]l~,\ti¡ 05-252-A 05-252-A 05-252-A 05-252·A 05-252-A 05·252-A 05-252-A 05"252·A 05-252-A 05..252"A 05-252-A 05"'252-A 05-252-A 05'-252..A Field Well Name CP018944 CP023307 CP278514 CP278514 CP278515 CP2785t6 CP278517 CP278518 CP278519 CP278520 CP278521 CP278521 P A000046 PA000049 _tjn::mell US 120653 US118448 US 136203 US136203 US136204 US436205 US136206 US136207 US136208 US136209 US136210 US136210 US039525 U$1\1Æ3449 . LablD· TABLE OF CONTENTS ( I BULK PROPERTIES CGS .WI ~ ~. t-._,ª~?",",fê~6.~!iª"129"~..k "',",~OXT",=>,=~=~p'1 ~!,~.YI,TY ..,v' ..,=,= -'::;IU¡;;~,~ ..U' i"h"~"""r"''''-fy"",,'''J.'''~W:''.dF~'JIi''I1III'''''t.Jr''''f- ,W";;;;;;:;:.'''''~::;:·3IIi~,.~.a~W;;i~-'':; ......~.hX,,;,;, 'h.:~IJi:.i ;::'~j:i: ·~I, m....,- CòmpªJ1Y: CONOC()PElllliW1PS '~' I Client JDi ~ _ __·.m_ ' US136210 ",-.. Saseline/DGSI - USA 8701 New Tmìls Drive. The Woodlond$. TX 77381-4241 Telephone: 281-681-2200 Focsírníle: 281-681-0326 E-maìl: in lo@boselinedgsì.com Wet) Si1e: http://wwvv.bmeUnedgsi.com Baseline DGS¡ - Brazil RUQ Benjamin B(1lis1a 55 l 30 I J~1rdjm Bolônìco. 22461-120 Rio de Janeiro (RJ) - Brazil Tei/Fox:'" 55.21 ¡ 537 7893 E-mail: ssp.i!)solinlec.com.br I EOM ANAL YSIS CGS -. ~ BASELINE CGSI SOXHlET ~f1':''''' "~r~~;~Y4J'~i~¡i.iih~~'i~!~ji¡¡ì.i~!iiil~~iGi~!!:~;~'~~::=:'=::':;;;':Y:~;;::::ffi[~~~i':':::';;';~;;,;,',_¡~':::~·I~;~~;:~::::::'~.:::i;¡¡;:::~ '~ Company: .CONOCOPHILL1P~ Project#.:05..252-A 1--.·. - --- _..-_': l . . - J · k, -. US136203 US136204 U S136205 US136206 US136207 US136208 US136209 CP.278514 CP278515 GP27854ô CP278517 CP278518 CP278519 CP278520 8.7180 0.2219 0.1204- 0.0595 0.0873 0.0299 1.17 0.69 0.55 0.63 0.34 0:56 ~2627 11684 6862 5469 6333 3430 5630 "-'" '~~ 8asellne/DGSI . USA 8701 New Trails Drive. The Woodlands. TX 77381-4241 Telephone: 281-681-2200 Facsimile.: 281-681-0326 E-mail: ínfo.¡ì>boselinedgsí.com Web Site: http://www.baselinedgsi.com Bosellne DGSI - Brozll Rue Beniomin Beisle 55/30J Jardim Bolâníco. 22461-120 Rio de Janeíro (RJ) -Brazil Te!/Fox: + 55.2J /5377893 E-mail: ssp@solinJec.com.br 'I..'" I~., ..,.. BASEL;.IN~. ~ ~ . MPLC ANAL YSIS DGS .W: r;w: I .. :~r~z!.tl fìrj~15t""t cSt; f 301 .)zîrdirn t$øfðnk;x). Rk> d%t ,JçlMirç) (it}] EJ"oz¡¡ l ;5,37 7/?'R;;J I~$~~¡n(t DG$J .~ U$i%, £)701 t\~f*W 'frob (ìrhff:»,'fhtf+ \þloç¡<cHarn:;l$"TX 7i38J ",4241 28 * ~6{M ,,22(;0 23·¡ ~·Ôif) 1 ~OJ2~ Company: ÇQNOOOPHIL.LlJ'S Project#: 05-252-A Sample SAT ARO NSO ASPH 0/0 À §¡·o % À . 1,1 m"~'N n ¡ .~.., -. . . ,'~. II· - ~ ] us 136203 CP278514 0.0751 0.0362 0.0173 0.0126 0.0017 53.39 25.52 18.58 2.51 US136204 CP2785t5 0:0749 0.0325 0.0161 0.0127 0.0024 51.02 25.27 19~94 3.77 us 136205 CP278516 0.0717 0.0173 0.0095 0.0334 0.0025 27.59 15.15 53.27 3.99 US136206 CP27851'7 0.0576 0.0155 0.0085 0.0220 0.0024 32.02 17.56 45.45 4;.96 US 136207 CP278518 0.0757 0.0212 0.0110 0.0303 0.0034 32.17 16.69 45.98 5.16 US·136208 GP~'78519 0.0263 0:0080 0.0042 0.0068 0.0019 38;28 20.10 32.53 9:09 us 136209 CP278520 0.0284 0.0080 0.0045 0.0109 0.0014 32.26 18.14 43.95 5.65 008136210 C3P2785~1 0.0750 0:0267 o.01~0 0.0068 0;0007 5'7:'79 25.98 14:72 1.5.2 . '-'-'-.. '1"'.11. ......_ ANALYTICAL LABORATORIES MPLC CGSI (~ I ISOTOPIC ANAL YSIS CGS .W' ~ BASELINE CGSI ISOTOPES ,""·..··q\;~..~i·I:~j~¡Ii~~~~"¡¡;¡¡f~i.i!~;~;.~,,~~~~&flfi¡j'i~::':}i~'é~:j ...^~:~::';:X·C~~=:~"·.I:~~:lJr~~;:~~~c:~~~·::·:·;;~~. .1::::¡:][¡:;Y:~·>~~ '",-" Company: CON()CORHII.Jl..IR$ 05";252..Ä, US136207 US136210 QP.2·'ï'8'5~.:8 CP278521 -31.8 -31.0 -30.3 -29.9 ~ ~/ Basellne/OGSI - USA 870 I New Trails DrÎve. The Woodlands, TX 77381 -424 ! Telephone: 281-681-2200 Façsin'lile: 281-681-0326 E-mail: Info@baselinedgsi.com Web Site: h11p:/lwww.boselínedg~í.com Baseline DGSI - Brazìl Rua Benjamin B011510 55/301 J<J,dlm Bo!ðnlco. 2246 t -120 Rio de Janeiro {RJJ - Brazil Tel/Fax:.¡. 55.21 f 537 7893 E-mail: ssp@sollntec.com.br I WHOLE OIL GC ANAL YSIS CGS -~ ~ Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE IAPETUS-2 Whole Oil GC Trace u z ~ '-' ~ lD U Z '" u :.: "" u :.: "" r-- U ~ Z co U Z WHOLE OIL GC VI ;:===-'::"~:::;;;;;;;~-~--:~~:::II--'''-'''···~FS;-········''-~-:T'..·..m-~..~'-' Client ID: Project #: Lab I D: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: US136210 05-252-A CP278521 MDT Kuparuk River Early Cretaceous L ..... ~ ~ "':.: u~ ~ ~ N M i ~ ~ ~ ~ w ~~ Z ~ U ~ ~ ,~1~ ~ lD Z co ~ ~ ª ~ ~ ~ M ~ j M~ ><:¡..;¡ 0 1"'""i ....., L/)....... ...-I H Z U U N N If) <..D J_,1~~~]1 ffi U Z ~i pristáne/ehyt~ne .. 2.21 0.93 n C181n C19 n C17In C29 CPI Marzi4 1.07 1.05 Resolved unknowns 47.5 .-:- ~~~..~·_·__·~'w~,_~ ..m.J!.ínm. G4050346.D co ffi 0(38~~~;;;~~ ~ M M ZlzLz~~~~~~ ~ ~ ~ 1, L I..' , . . ¡¡'If': II I' .l'1I...., 121 -- 20.24 15.88 o U Z I.iJ:::J.I :,I. :J . J ì Trj Tr2 Tr Tr4 Tr'5 , "?Wi ----, ;'2.64: 9.96 0.06 0.26 3.34 12.55 lTI10mpson, K.F.M.,1983.GCAV.4 7, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.I.,1995,AAPG Bull.: V.79, p.80 1. 4Marzi,1993,OrgG;20,130 1. Cs 0.16 U. CH/MCP 0.58 33.14 0.53 0.32 Company: Well Name: Depth: Sampling Point: CONOCOPHILLIPS IAPETUS-2 Client ID: Project #: LablD: File Name: US136210 05-252-A CP278521 G4050346.D .~ ""-' Peak Compound - :. Label Name iiI Com pany: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 Client ID: Project #: Lab ID: File Name: US136210 05-252-A CP278521 G4050346.D Peak Compound Ret...,..... ppt ppt . · . Name Time ~ .. . .. ~ I .:. -. . . I NC16 Normal Alkane C16 54.116 109096 31202 5.61 3.68 NC17 57.800 102857 28563 5.29 3.37 59.062 678 0.18 0.08 61.765 2.21 0.93 3.69 2.27 0.21 0.10 55008 2.83 1.68 2.35 1.37 Normal Alkane C27 1.69 0.97 1.32 95.444 0.78 99.415 11978 0.62 103.234 0.35 0.13 107.737 0.16 0.05 113.664 0.03 Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLIPS UNITED STATES NORTH SLOPE IAPETUS-2 Whole Oil GC Trace ... u :<¡¡, OJ z; "., ~ '" u z ::c u ::E: '" u ::E: r- '" U Z ~ Client ID: Project #: Lab ID: SarnpleType: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: IX> '" u ;- ~ ¡:w z ~ 0 rot U z.-<.-< 5~ ~ ~ ~ M fQ ~ ~ ~ a ~ r- ~~ Z U 00 " ~~ '" z ~ .-< en ~ ~ -~i ~ ~ 8 ~ ~ N M f:) ~ ~ 8~ 0 ~ :V) iT) ~ ~ ::: z ~ ~ ~ iJ ~ ~ ¡ ~~ ~i~ 0:: ~ ~ ~ ~::: ~ ~ H Z Z ~ ~LtJJ,~~~I~U~~J.J Pristaneln CrT n C1a1n C19 CPI Marzi4 '~ Branched (iso-) Paraffins Resolved unknowns 47.9 0.93 ¡'If:IIl~~' _ US136210 replicate analysis 05-252-A CP278521 MDT oil Kuparuk River Early Cretaceous G4050351.D E~~(X)cn z ~ ~ tJ ~~~~~~~w r- CD m 0 l J Izz~f,i~f,i~f,i88 8 8 ~ " .,...J LJ.Ll-1 L .:: Z Z Z Z 'I'~--_.. ~--- Tr7 2.78 1.07 I. Isoheptane Value 0.73 JThompson, K.F.M.,1983.GCA:V.47, pJ03. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.I.,1 995,AAPG Bull.: V.79,p.801. '\1arzi,1993,OrgG;20,1301. Cs 1.05 6.7 Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 Client ID: Project #: LablD: File Name: US136210 05-252-A CP278521 G4050351.D I -eak Compound Ret. ppt p~ .." ~·II" "..- ~ -. .--., ~ ". H.. IC4 3.768 65324 3.21 6.82 4.324 202906 9.96 18.87 1411 0.07 0.11 11200 0.55 0.85 91995 4404 0.42 BZ 6206 0.62 0.70 CH 8.221 5.07 5.72 24350 1.20 1.40 4.36 4.70 4.71 4.98 3.52 3.52 1.76 1.69 33366 1.64 1.54 2.58 2.37 1.74 1.45 PXYL 0.65 0.58 185626 56446 9.11 6.39 7.90 5.71 7.99 5.65 IP13 2.08 NC13 6.87 NC14 129366 38035 6.35 4.31 NC15 Normal Alkane C15 50.235 133776 35820 6.57 4.05 ~.. ., " .- ¡:J"'~'Í- 11II ~;~'{*"':~i í. RIIIgI'.:.f *,_tmlffi.. 112685 31639 5.53 3.58 , -1i\1 ..L.\ ..mm:._:~ ~ ¡~~: - US136210 05-252-A CP278521 G4050351.D Client ID: Project#: LablD: File Name: CONOCOPHILLlPS IAPETUS-2 Company: Well Name: Depth: Sampling Point: "~ BASELINE CGSI ~¡"lIliF"_·.Já;¡é..I."Iuiií¡I..i"i*~"ïIÎi"~..:"}s;.i~"":;'¿B!~,·,.y;¡;:;::.;.· ~ .: ;l.-~.:.- . "",;,;,.,.' '.-,~':")~";;:~:~~~~,c~:~:' Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE IAPETUS-2 Whole Oil GC Trace u Z u"> U U U '" Z Z Z U r- u Z u z z u '" Z II.< '" '" WHOLE OIL GC Client ID: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: 00 '" US136203 05-252-A CP278514 SWC EARLY CREA T ACEOUS 8719 G4050356.D 00 u z u 0 Z N U Z N N ~ ~ ~ z ~ ~ ~ 2; U '" Z 8 z u"> 0 ~ ~ N m r-I 0.. Q.¡ MJmt~~4JL.~~wJwt~,,^,L_, ~~m~!" '~ci" Pristane/Pnytane Pristaneln C17 Phytaneln C1S n C181n C19 n CHIn C29 CPI Marzi4 Normal Paraffins Isoprenoids Cycloparaffins Branched (iso-) Paraffins BTX aromatics Resolved unknowns fUJ¡¡¡¡[~ 2.05 0.93 0.55 1.06 5.25 1.01 27.8 7.2 0.2 0.0 0.1 64.6 . . A. B. C. I. F. U. R. S. H. BZln Ga TOUn C7 (nC6+n C7)/(CH+MCH) Isoheptane Value n C7/MCH CH/MCP nC7/2MH n Ct/22DMB Heptane Value MCHln C7 mpXYUn Cs 6.68 0.44 0.51 0.62 0.51 1.90 6.36 23.20 1.95 0.23 ~t· P1 P2 P3 5N1 N2 6N1 K1 K2 5N1/6N1 P3/N2 In(24DMP/23DMP) r- "" ~ "" u U U Z Z Z ! , ~'I~ín 20.49 Tr1 8.49 8.74 Tr2 19.22 2.73 Tr3 5.18 11.30 Tr4 3.02 7.75 Trs 8.20 48.98 Tr7 3.24 0.79 Trs 3.20 0.53 C1 0.23 C2 0.49 0.35 C3 0.09 -1.72 C4 0.14 Cs 0.29 ¡Thompson, K.F.M.,1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.1.,1995,AAPG Bull.: V.79, p.80!. 4Marzi,1993,OrgG;20,1301. -~ Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS·2 8719 . US136203 05-252-A CP278514 G4050356.D Client ID: Project #: Lab ID: File Name: '>'<~ IC4 NC4 IC5 NC5 220MB CP 230MB 2MP 3MP NC6 220MP MCP 240MP 223TMB BZ 330MP CH 2MH 230MP 11 DMCP 3MH 1 C30MCP 1 T30MCP 3EP 1 T20MCP NC7 ISTO MCH 113TMCP ECP 124TMCP 123TMCP TOL NC8 IP9 MXYL PXYL OXYL NC9 IP10 NC10 IP11 NC11 NC12 IP13 IP14 NC13 IP15 NC14 IP16 NC15 .,,~~;'E 'H,~ 'C, Iso-alkane C4 Normal AlkaneC4 Iso-alkane C5 Normal Alkane 05 2,2-0imethylbutane Cyclopentane 2,3-0imethylbutane 2~Methylpentari$ 3-Methylpentane Normal Alkane 06 2,2-0imethylpentane Methylcyclopentane 2,4-0imethylpentane 2,2,3- Trimethylþ~tªne Benzene 3,3-,oimethylpehtan~ Cyclohexane 2-Methylhexane 2,3-Dimethylpentane 1, 1-Dimethylcy¢IQP~ritäl;H~ 3-Methylhexane 1-cis,,;3-DimethylqycIÒPentariè 1-trans-3-Dimethylcyclopentane 3-Ethylpentane 1-trans-2-0imethylcyclopentane Normal AlkaneG7 Internal Standard Methylcyclohex8ne 1,1,3,-Trimethylcyclopentane Ethylcyclopeltäne 1,2,4- Trimethylcyclopentane 1 ,2,3-Trimethylcycl()pent~ne Toluene NormalAlkaneC8 Isoprenoid C9 m-Xylene p-Xylene o-Xylene Normal Alkane C9 Isoprenoid C10 Normal Alkane C10 Isoprenoid C11 Normal Alkane C11 Normal Alkane C12 Isoprenoid C13 IsoprenoidC14 Normal Alkane C13 IsoprenoidC 15 Normal Alkane C14 IsoprenoidC16 Normal Alkane C15 30 8.384 1022 474 8;629 8.728 350 9.1 82 168 9.485 699 9.845 438 9i908 9.963 925 10.582 ~595 11>460 5056 2021 1 1 .636 968 383 208 1 176 474 723 1 146 414 5441 17.848 4904 1790 19.063 1002 19.130 795 283 20:339 895 21 .761 30974 1 0707 23:199 8720 27'81 27.41 1 51748 1 6766 1i6y36 5324 32.717 85532 26915 37:680 1tOO23 33515 ... 38.417 33843 9339 41 :199 25114- 8004- 42.326 128041 38025 45;7'89 382~8 10804- 46.691 133194 37951 67289 15785 50.808 139157 38232 Company: Well Name: De pth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8719 - Client ID: Project #: LablD: File Name: US136203 05-252-A CP278514 G4050356.D NC16 Normal Alkane C16 54.696 125849 35397 IP18 Isoprenoid C 18 56.642 71060 14464 NC17 Normal Alkane C17 58.383 119427 33104 IP19 Isoprenoid C 19 (Pristane) 58.752 111102 21031 PHEN Phenanthrene 59.840 5316 898 NC18 Normal Alkane C18 61.886 98829 27996 IP20 Isoprenoid C20 (Phytane) 62.344 54079 9463 NC19 Normal Alkane C19 65.223 93128 24903 NC20 Normal Alkane C20 68.404 84704 22103 NC21 Normal Alkane C21 71.446 71130 19428 C25HBI Highly Branch Isoprenoid C25 71.704 6155 1088 NC22 Normal Alkane C22 74.358 63247 17092 NC23 Normal Alkane C23 77.146 57681 15517 NC24 Normal Alkane C24 79.830 53054 13038 NC25 Normal Alkane C25 82.402 46558 11390 NC26 Normal Alkane C26 84.879 37919 8736 NC27 Normal Alkane C27 87.267 29814 6789 NC28 Normal Alkane C28 89.570 24022 4771 NC29 Normal Alkane C29 91.792 22739 4512 NC30 Normal Alkane C30 93.947 15603 2967 NC31 Normal Alkane C31 96.026 12870 2507 NC32 Normal Alkane C32 98.044 8497 1668 NC33 Normal Alkane C33 100.001 10912 1664 NC34 Normal Alkane C34 101.895 5584 1055 NC35 Normal Alkane C35 103.889 6953 901 NC36 Normal Alkane C36 106.093 3854 496 NC37 Normal Alkane C37 108.594 2574 339 NC38 Normal Alkane C38 111 .464 2085 246 NC39 Normal Alkane C39 114.788 2020 190 NC40 Normal Alkane C40 118.693 1719 148 NC41 Normal Alkane C41 ElASEL.INE CGSI WHOLE Oil GC ..'·~'*J.",.gil".i\it_ííííl~~.¡ii~¡-.~ïiji.-~;:::;;;;iií~~::~~;;;~;:~~-~.iiiR;¡¡;iiiJir-··---:::~~}.:..;--···--i:~~:r.··::~ -o;:;:;';"~~;;;;;:::;;;~~····_·····1tiE": Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE IAPETUS-2 Whole Oil GC Trace US136203 05-252-A CP278514 SWC Client ID: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: '" M .... U \D U .... ..... u Z Z U Z Z .... N U Z U Z .... .... '" u Z ... H EARLY CREA T ACEOUS 8719 CD U '" Z U 0 Z N U Z N o \D CD ~ ~ ~ U M U Ø-t Z N Z ~ ~ ~ ~ ~ ~ ~ ~ ~ H ~ .~ii ô 0 ~ I I I ~ ~ I ~ ~.lJj~~, ~~vl.l~k~.~~~U~~"'- ..~ "¡'lêt~tr.II'I:}(:qt--~~-:-:;; Pristane/Phytane 2.03 Pristaneln C17 0.92 Phytaneln C18 0.55 n CHin C19 1.05 nC171n C29 7.97 CPI Marzi4 1.01 Normal Paraffins 27.9 Isoprenoids 7.4 Cycloparaffins 0.2 Branched (iso-) Paraffins 0.0 BTX aromatics 0.1 Resolved unknowns 64.2 B. TOUn C7 C. (nC6+nG7)/(CHfMCH) I. Isoheptane Value F. nG¡/MCH U. CH/MCP R nC7/2MH S. n C¡/22DMB H. HeptaneVàlÚe MCH/nC7 IT)p)<'YL/ii.Ç{â 0.44 0.52 0.61 0:52 1.87 1.90 G4050367.D ~E:;;::;~~;;~~~ ~ ~ ZZ~~~~~~~~ ~ ~ o .... U Z P2 P3 5N1 N2 6N1 8.70 imì·~~ä~ : Tr1 Tr2 Tr3 Tr4 Trs Tr7 Bi67 19.61 5.23 3.03 3.53 2I94 11.19 48.47 0.52 C1 C3 C4 Cs 0.09 0.33 ¡Thompson, K.F.M.,1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.r.,1995,AAPG Bull.: V.79, p.80l. 4Marzi,1993,OrgG;20,130l. Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8719 - Client ID: Project #: Lab ID: File Name: US136203 05-252-A CP278514 G4050367.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 220MB 2,2-0imethylbutane CP Cyclopentane 230MB 2,3-0imethylbutane 2MP 2-Methylpentane 6.290 34 28 3MP 3-Methylpentane 6.563 66 33 NC6 Normal Alkane C6 6.966 198 114 220MP 2,2-0imethylpentane MCP Methylcyclopentane 7.706 213 103 240MP 2,4-0imethylpentane 7.848 36 14 223TMB 2,2,3- Trimethylbutane BZ Benzene 8.484 1250 586 330MP 3,3-0imethylpentane 8.728 67 28 CH Cyclohexane 8.826 398 175 2MH 2-Methylhexane 9.227 455 212 230MP 2,3-0imethylpentane 9.278 180 87 110MCP 1,1-0 imethylcyclopentane 9.369 150 64 3MH 3-Methylhexane 9.579 784 351 1 C30MCP 1-cis-3-0imethylcyclopentane 9.819 464 206 1 T30MCP 1-trans-3-Dimethylcyclopentane 9.937 529 213 3EP 3-Ethylpentane 10.001 139 88 1 T20MCP 1-trans-2-Dimethylcyclopentane 10.054 1037 443 NC7 Normal Alkane C7 10.669 2941 1263 ISTO Internal Standard MCH Methylcyclohexane 11.540 5602 2251 113TMCP 1,1,3,-Trimethylcyclopentane 11.715 1027 424 ECP Ethylcyclopentane 12.134 557 233 124TMCP 1,2,4- Trimethylcyclopentane 12.594 1305 533 123TMCP 1,2,3- Trimethylcyclopentane 12.971 2019 814 TOL Toluene 13.288 1300 485 NC8 Normal Alkane C8 15.981 17162 6222 IP9 Isoprenoid C9 17.882 5490 2025 MXYL m-Xylene 19.090 3290 1170 PXYL p-Xylene 19.154 898 329 OXYL o-Xylene 20.358 4058 1040 NC9 Normal Alkane C9 21.773 35229 12170 IP10 Isoprenoid C10 23.208 10058 3170 NC10 Normal Alkane C1 0 27.409 58966 18587 IP11 Isoprenoid G11 28.718 19136 5832 NC11 Normal Alkane C11 32.710 97517 28897 NC12 NormalAlkane C12 37.671 126469 36125 IP13 Isoprenoid C13 38.405 37409 10360 IP14 Isoprenoid C14 41.188 29281 8866 NC13 Normal Alkane C13 42.318 148518 42102 IP15 Isoprenoid C15 45.778 44113 12009 NC14 Normal Alkane C14 46.684 154805 43215 IP16 Isoprenoid C16 49.356 77491 18058 NC15 Normal Alkane C15 50.799 164093 43545 Company: WeJJ Name; Depth: Sampling Point: CONOCOPHILLlPS IAPETU5-2 8719 - IrU~li~~:!·l ,.~ NC16 IP18 NC17 IP19 PHEN NCt8 IP20 NC19 NC20 NC21 C25HBI NC22 NC23 NC24 NC25 NC26 NC27 NC28 NC29 NC30 NC31 NC32 NC33 NC34 NC35 NC36 NC37 NC38 NC39 NC40 NC41 Client ID: Project #: Lab ID: File Name: US136203 05-252-A CP278514 G4050367.D Normal Alkane C16 Isoprenoic:lG18 Normal Alkane C17 I soprenoidG 19 (Pfistane) Phenanthrene NormalAlkaneGt8 Isoprenoid C20 (Phytane) Normal Alkane Gt9 Normal Alkane C20 NormalAlkaneC21 Highly Branch Isoprenoid C25 Normal Alkane C22 Normal Alkane C23 Normal AlkaneG24 Normal Alkane C25 Normal AlkaneC26 Normal Alkane C27 Normal AlkaneG28 Normal Alkane C29 Normal AlkaneC30 Normal Alkane C31 NormalAlkaneC32 Normal Alkane C33 Normal Alkane G34 Normal Alkane C35 Normal AlkaneC36 Normal Alkane C37 Normal AlkaneC38 Normal Alkane C39 Normal AlkaneC40 Normal Alkane C41 59.835 62.339 68.400 71.701 74:356 77.146 79.835 82.410 84}891 87.284 89.591 91.814 143349 .~3j~99 6579 117329 64485 112066 101238 8541 70983 60519 53633 51531 40923 27560 22842 17981 12029 8116 7060 3303 38599 24£03 1056 32303 10937 28793 24607 20151 1499 16802 13886 10499 8127 5507 3485 2100 1874 1048 808 430 446 310 224 141 61 45 42 53 96.062 100.034 102;052 103.931 Company: Country: Basin: Lease: Block: Field: Well Name: LatitUde: Longitude: ASSL'NS OGS, WHOtSOIL GC . m~·~~___"_~~L_ CONOCOPH/lllPS Client 10: US136204 UNITED STATES Project #: 05-252-A NORTH SLOPE lab /0: CP278515 Sample Type: SWC Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: IAPETUS_2 Whole Oil GC Trace EARLYCREATACEOUS 8721.0 '" M '" ~ M ~ I '" ~ '" ! ~ '" .... M I '" ~ ¡l I '" "" .... '< .... o I '" ~ ~ '" !i "" .... ., "" .... ! 7 _ g '" '" .. '" Ii ,~1 ~ ~ §i ti t. . PristanelPhytane Pristaneln Cn Phytaneln C'8 n C,8/n C'9 n C171n C29 CPJ Marzi4 Normal· Paraffins Isoprenoids CYCIOparaffins Branched (isO~) Paraffins BTX arOmatics Resolved unknowns §i 1.97 0.90 0.56 0.98 8.66 0.98 16.3 4.2 0.2 0.1 0.1 78.6 '" -< A. BZJnCs 8. TOUnC7 C. (nCs+nC7)I(CH+MCH) I. Isoheptane Value F. nC71MCH U. CHIMCP R. nC712MH S. n Cal22DMB H. Heptane Value MCHln C7 mpxYUn C8 3.23 1.49 0.70 0.59 0.66 1.25 5.36 24.15 1.51 P, P2 P3 5N, N2 6N, K1 K2 5N,¡6N1 P3/N2 In(24DMP/23DMP) 17.33 8.02 4.88 8.64 9.09 52.05 0.83 0.47 0.17 0.54 -0.83 G4050358.D '" '" !i M ~ o M Tr1 Tr2 Tr3 Tr4 Trs Tr7 Tre C, C2 C3 C4 Cs 'n","",o.. KF.M., t 983.GCk VA 7, P.303. '",",0. F.D..1994.GCA, V.58. p.895. 'H>I""".H.I.. t995.AAPG ">II, V.79. p.8O t. 'Monzi.,993.CRgG;20.130 t. 29.05 19.48 5.38 3.63 9.02 5.88 1.64 0.24 0.11 0.38 0.27 Company: CONOCOPHILLlPS Client ID: US136204 Well Name: IAPETUS·2 Project #: 05-252-A Depth: 8721 - LablD: CP278515 Sampling Point: File Name: G4050358.D ~:~. ...., . . l.: y. Jt '. ~; 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 6.184 106 64 3MP 3-Methylpentane 6.476 92 51 NC6 Normal Alkane C6 6.889 288 145 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 7.639 242 115 24DMP 2,4-Dimethylpentane 7.778 35 10 223TMB 2,2,3- Trimethylbutane BZ Benzene 8.424 930 439 33DMP 3,3-Dimethylpentane 8.672 125 45 CH Cyclohexane 8.769 302 113 2MH 2-Methylhexane 9.174 218 95 23DMP 2,3-Dimethylpentane 9.226 80 37 11 DMCP 1,1-Dimethylcyclopentane 9.316 60 26 3MH 3-Methylhexane 9.529 323 141 1 C3DMCP 1-cis-3-Dimethylcyclopentane 9.769 200 87 1 T3DMCP 1-trans-3-Dimethylcyclopentane 9.892 353 95 3EP 3-Ethylpentane 9.964 89 56 1 T2DMCP 1-trans-2-Dimethylcyclopentane 10.005 368 169 NC7 Normal Alkane C7 10.625 1169 497 ISTD Internal Standard MCH Methylcyclohexane 11.500 1768 691 113TMCP 1,1,3,- Trimethylcyclopentane 11.677 290 105 ECP Ethylcyclopentane 12.098 215 77 124TMCP 1,2,4- Trimethylcyclopentane 12.560 334 120 123TMCP 1,2,3- Trimethylcyclopentane 12.939 509 182 TOL Toluene 13.256 1743 568 NC8 Normal Alkane C8 15.961 3517 1263 IP9 Isoprenoid C9 17.869 877 320 XYL Xylene NC9 Normal Alkane C9 21.767 5982 2086 IP10 Isoprenoid C10 23.205 1578 499 NC10 Normal Alkane C1 0 27.404 8726 2878 IP11 Isoprenoid C11 28.718 2648 816 NC11 Normal Alkane C11 32.698 13927 4222 NC12 Normal Alkane C12 37.653 16875 5382 IP13 Isoprenoid C13 38.402 5163 1465 IP14 Isoprenoid C14 41.182 4064 1268 NC13 Normal Alkane C13 42.293 21310 6730 IP15 Isoprenoid C 15 45.770 7941 1946 NC14 Normal Alkane C14 46.658 24565 7248 IP16 Isoprenoid C16 49.341 12778 3056 NC15 Normal Alkane C15 50.770 27779 7935 NC16 Normal Alkane C16 54.661 26781 7535 IP18 Isoprenoid C 18 56.620 14628 2879 Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8721 - Client ID: Project #: LablD: File Name: US136204 05-252-A CP278515 G4050358.D NC17 Normal Alkane C17 58.348 25720 7088 IP19 Isoprenoid Ci9 (Pristane) 58.716 23167 4438 PHEN Phenanthrene 59.828 1095 213 NC18 Normal Alkane C18 61.857 20908 5845 IP20 Isoprenoid C20 (Phytane) 62.329 11766 1955 NC19 Normal Alkane C19 65.193 21285 5422 NC20 Normal Alkane C20 68.379 19020 4274 NC21 Normal Alkane C21 71.421 16882 3646 C25HBI Highly Branch Isoprenoid C25 71.688 4316 885 NC22 Normal Alkane C22 74.333 14577 2977 NC23 Normal Alkane C23 77.122 11475 2473 NC24 Normal Alkane C24 79.802 10722 1888 NC25 Normal Alkane C25 82.379 8079 1584 NC26 Normal Alkane C26 84.853 5784 1211 NC27 Normal Alkane C27 87.243 4370 911 NC28 Normal Alkane C28 89.547 3498 658 NC29 Normal Alkane C29 91.768 2971 625 NC30 Normal Alkane C30 93.926 2513 475 NC3i Normal Alkane C31 96.004 2120 396 NC32 Normal Alkane C32 98.021 1013 243 NC33 Normal Alkane C33 99.978 1428 235 NC34 Normal Alkane C34 101.877 830 160 NC35 Normal Alkane C35 103.869 893 135 NC36 Normal Alkane C36 106.070 624 92 NC37 Normal Alkane C37 108.579 400 58 NC38 Normal Alkane C38 111.435 494 50 NC39 Normal Alkane C39 114.747 447 43 NC40 Normal Alkane C40 118.612 427 36 NC41 Normal Alkane C41 Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE IAPETUS-2 Whole Oil GC Trace .~~ 0 '" j cz> '" ... ~ ' ~«f\~~~~ ~~ ~ ø..!:< D.t H í ~.d L".1.~.... L . 'J.'Lc¡... phI t;llJt~(~ ~.... Pristane/Pl1ytàne Pristaneln C17 Phytaneln C18 n C1a1n C19 nC171nC29 CPI Marzi4 Normal Paraffins Isoprenoids Cycloparaffins Branched (iso-) Paraffins BTX aromatics Resolved unknowns ~.'; 1.46 0.85 0.65 0.89 5~52 0.94 16.1 1.4 0.4 0.1 81.5 IThompson, K.F.M., 1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.I.,1995,AAPG Bull.: V.79, p.80l. 4Marzi,1993,OrgG;20,130l. Client ID: Project #: LablD: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: US136205 05-252-A CP278516 SWC JURRASSIC LATE 8854.0 ... CD '" ~ ~ ~~~OH qo ~ Zen a ~ ~lli~~~ iJJl\~'~ .,~ U. CH/MCP 0.71 S. H. ~r' Pi G4050359.D ~ ~ G!u~t Tr1 C3 0.18 Cs 0.33 Company: Well Name: Depth: Sampling Point: CO NO CO PHILLIPS IAPETUS-2 8854 - Client ID: Project #: LablD: File Name: US136205 05-252-A CP278516 G4050359.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-0imethylbutane CP Cyclopentane 230MB 2,3-0imethylbutane 2MP 2-Methylpentane 6.189 150 100 3MP 3-Methylpentane 6.472 151 81 NC6 Normal Alkane C6 6.890 707 255 22DMP 2,2-0imethylpentane MCP Methylcyclopentane 7.637 336 179 24DMP 2,4-0imethylpentane 7.778 63 14 223TMB 2,2,3- Trimethylbutane BZ Benzene 8.423 588 280 33DMP 3,3-0imethylpentane 8.672 111 39 CH . Cyclohexane 8.767 238 86 2MH 2-Methylhexane 9.172 163 74 230MP 2,3-0imethylpentane 9.224 60 28 11 DMCP 1,1-0imethylcyclopentane 9.316 34 16 3MH 3-Methylhexane 9.528 236 108 1 C3DMCP 1-cis-3-Dimethylcyclopentane 9.768 178 75 1 T3DMCP 1-trans-3-Dimethylcyclopentane 9.887 209 76 3EP 3-Ethylpentane 9.975 117 58 1 T2DMCP 1-trans-2-Dimethylcyclopentane 10.004 340 144 NC7 Normal Alkane C7 10.628 82317 36066 ISTD Internal Standard MCH Methylcyclohexane 11 .494 1324 330 113TMCP 1,1,3,- Trimethylcyclopentane 11.674 108 40 ECP Ethylcyclopentane 12.093 92 33 124TMCP 1,2,4- Trimethylcyclopentane 12.557 136 47 123TMCP 1,2,3- Trimethylcyclopentane 12.937 161 60 TOL Toluene 13.255 428 117 NC8 Normal Alkane C8 15.959 683 233 IP9 Isoprenoid C9 17.866 148 51 XYL Xylene NC9 Normal Alkane C9 21.765 651 218 IP10 Isoprenoid C10 23.204 185 53 NC10 Normal Alkane C10 27.400 794 226 IP11 Isoprenoid C11 28.718 248 56 NC11 Normal Alkane C11 32.695 1008 260 NC12 Normal Alkane C12 37.649 932 219 IP13 Isoprenoid C13 38.401 417 74 IP14 Isoprenoid C 14 41 .180 315 68 NC13 Normal Alkane C13 42.287 1228 282 IP15 Isoprenoid C15 45.769 488 113 NC14 Normal Alkane C14 46.650 1700 495 IP16 Isoprenoid C16 49.336 1213 282 NC15 Normal Alkane C15 50.761 3183 865 NC16 Normal Alkane C16 54.654 3762 967 IP18 Isoprenoid C18 56.618 2059 388 Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8854 - Client ID: Project #: LablD: File Name: US136205 05-252-A CP278516 G4050359.D -.. ." ~ ". H~~. rrtt~i~' J' · . ."~~ Ii ~~.tl' NC17 Normal Alkane C17 IP19 Isoprenoid C 19 (Pristane) PHEN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenoid C20 (Phytane) NC19 Normal Alkane C19 NC20 Normal Alkane C20 NC21 Normal Alkane C21 C25HBI Highly Branch Isoprenoid C25 NC22 Normal Alkane C22 NC23 Normal Alkane C23 NC24 Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal Alkane C26 NC27 Normal Alkane C27 NC28 Normal Alkane C28 NC29 Normal Alkane C29 NC30 Normal Alkane C30 NC31 Normal Alkane C31 NC32 Normal Alkane C32 NC33 Normal Alkane C33 NC34 Normal Alkane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal Alkane C38 NC39 Normal Alkane C39 NC40 Normal Alkane C40 NC41 Normal Alkane C41 58.342 58. 711 59.832 61.851 62.327 65.187 68.370 71.414 71.681 74.324 77.115 79.797 82.370 84.846 87.235 89.536 91.765 93.920 95.997 98.013 99.973 101.876 103.852 106.052 108.554 3952 3369 177 3553 2300 4003 3423 2330 1865 1897 1560 1467 1331 1180 876 918 716 714 610 229 200 203 176 183 125 1011 580 35 861 347 863 588 487 415 409 347 309 271 241 193 164 150 121 102 58 61 42 33 25 21 BASELINE CGSI WHOLE OIL GC .·:_~~···';ImI>D~~ . ~~rR¡'i"'~f'!}ï(,~~:p"'''j1jo'~j~1.!;'1i¡jJ;¡¡¡''':;;::=:;;¡::0;;;r;::;~·:'":'"~:':~:::"~ïwU~:~'Ñ::::::::~=fW':"~'::W~~~~:jlí''''"".".:''U¡¡;;mm¡¡:¡~~;"~":~:::':J:'¥"1~11:;;;!!!!~:;~::':~~~' '.W'"1".. ·:'"~··';·"~'TW·'"'"'T' Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE Client ID: Project #: Lab 10: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: IAPETUS-2 Whole Oil GC Trace OJ "' u !i u Z u Z o u z !i u z !i >< !i '-' u Z u z ?' ,i¡,.¡J ~~l/ '" -< 0 ~ ~ H ~J1l~.J>..#~ r US136206 05-252-A CP278517 SWC JURRASSIC LATE 8859.0 G4050360.D "' !i '" U N Z !i u z o u Z ~ ~ ~ ~Y~ïl;r8lw.rtM:\mt- m· 'I~ ~-- ~ , ~.Ir~dl ~ , . Pristane/Phytane 1.23 A. BZln Ce 7.39 P1 85.29 Tr1 33.29 Pristaneln Cn 0.87 B. TOUn C7 0.05 P2 0.82 Tr2 691.23 Phytaneln C1S 0.73 C. (n Cs+n C7)1(CH+MCH) 20.20 P3 1.45 Tr3 4.32 n C1sIn C19 0.82 I. Isoheptane Value 0.19 5N1 0.58 Tr4 2.35 n Cnln C29 5.34 F. nC7/MCH 24.02 N2 4.20 Trs 6.68 CPI Marzi4 0.90 U. CH/MCP 1.51 6N1 7.66 Tr7 29.97 NormalParaffins 6.1 R. n C7/2MH 293.53 K1 0.75 Trs 0.57 Isoprenoids 1.3 S. n Cel22DMB K2 0.16 C1 Cycloparaffi ns 0.1 H. Heptane Value 89.85 5N1/'N1 0.08 C2 0.08 Branched (iso-) Paraffins 0.0 MCH/n C7 0.04 P3/N2 0.35 C3 BTX aromatics 0.1 mpXYUn Cs In(24DMP/23DMP) C4 0.28 Resolved unknowns 91.7 Cs 0.64 'Thompson, K.F.M.,1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.I.,1995,AAPG Bull.: V.79, p.801. 4Marzi,1993,OrgG;20,1301. Company: Well Name: Depth: Sampling Point: Peak . , H·'.~· ~ IC4 NC4 IC5 NC5 22DMB CP 23DMB 2MP 3MP NC6 22DMP MCP 24DMP 223TMB BZ 33DMP CH 2MH 23DMP 11 DMCP 3MH 1 C3DMCP 1 T3DMCP 3EP 1 T2DMCP NC7 ISTD MCH 113TMCP ECP 124TMCP 123TMCP TOL NC8 IP9 XYL NC9 IP10 NC10 IP11 NC11 NC12 IP13 IP14 NC13 IP15 NC14 IP16 NC15 NC16 IP18 CONOCOPHILLlPS IAPETU5-2 8859 - Client ID: Project #: LablD: File Name: US136206 05-252-A CP278517 G4050360.D ~~ ~ .;-~~. ~_~r Iso-alkane C4 Normal Alkane C4 Iso-alkane C5 Normal Alkane C5 2,2-Dimethylbutane Cyclopentane 2,3-Dimethylbutane 2-Methylpentane 3-Methylpentane Normal Alkane C6 2,2-Dimethylpentane Methylcyclopentane 2,4-Dimethylpentane 2,2,3- Trimethylbutane Benzene 3,3-Dimethylpentane Cyclohexane 2-Methylhexane 2,3-Dimethylpentane 1,1-Dimethylcyclopentane 3-Methylhexane 1-cis-3-Dimethylcyclopentane 1-trans-3-Dimethylcyclopentane 3-Ethylpentane 1-trans-2-Dimethylcyclopentane Normal Alkane C7 Internal Standard Methylcyclohexane 1,1,3,- Trimethylcyclopentane Ethylcyclopentane 1,2,4- Trimethylcyclopentane 1,2,3- Trimethylcyclopentane Toluene Normal Alkane C8 Isoprenoid C9 Xylene Normal Alkane C9 Isoprenoid C10 Normal Alkane C1 0 Isoprenoid C11 Normal Alkane C11 Normal Alkane C12 Isoprenoid C13 Isoprenoid C14 Normal Alkane C13 Isoprenoid C15 Normal Alkane C14 Isoprenoid C 16 Normal Alkane C15 Normal Alkane C16 Isoprenoid C18 6.108 67 32 6.466 76 32 6.892 188 67 7.636 118 60 8.420 1389 661 8.669 103 42 8.765 178 71 9.170 73 33 9.226 28 18 9.310 31 12 9.525 134 54 9.765 94 38 9.898 929 295 10.000 234 88 10.093 61 16 10.620 21428 9472 11.494 892 302 11.672 88 35 12.092 85 31 12.553 304 71 12.931 312 85 13.250 1032 309 15.953 1245 412 17.860 273 99 21.759 1877 639 23.198 445 141 27.395 3197 963 28.712 1261 293 32.690 5330 1451 37.644 5103 1583 38.395 1771 454 41.175 1353 414 42.283 6698 1913 45.766 2374 571 46.648 6957 2075 49.332 4062 946 50.760 8744 2414 54.650 9496 2548 56.612 5284 1011 Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8859 - Client ID: Project #: LablD: File Name: US136206 05-252-A CP278517 G4050360.D NC17 Normal Alkane C17 58.337 10429 2673 IP19 Isoprenoid C19 (Pristane) 58.706 9102 1652 PH EN Phenanthrene 59.819 587 122 NC18 Normal Alkane C18 61.847 10138 2570 IP20 Isoprenoid C20 (Phytane) 62.322 7393 1122 NC19 Normal Alkane C19 65.187 12338 2897 NC20 Normal Alkane C20 68.368 10327 1985 NC21 Normal Alkane C21 71.411 5730 1525 C25HBI Highly Branch Isoprenoid C25 71.685 13593 3444 NC22 Normal Alkane C22 74.323 6731 1554 NC23 Normal Alkane C23 77.112 5514 1286 NC24 Normal Alkane C24 79.791 5509 1173 NC25 Normal Alkane C25 82.369 4818 979 NC26 Normal Alkane C26 84.848 4231 900 NC27 Normal Alkane C27 87.231 2690 625 NC28 Normal Alkane C28 89.536 2761 471 NC29 Normal Alkane C29 91.759 1954 432 NC30 Normal Alkane C30 93.914 1858 362 NC31 Normal Alkane C31 95.994 2086 380 NC32 Normal Alkane C32 98.010 664 159 NC33 Normal Alkane C33 99.968 805 160 NC34 Normal Alkane C34 101.863 438 100 NC35 Normal Alkane C35 103.845 444 84 NC36 Normal Alkane C36 NC37 Normal Alkane C37 108.555 256 38 NC38 Normal Alkane C38 111.429 316 35 NC39 Normal Alkane C39 114.734 327 29 NC40 Normal Alkane C40 118.587 215 23 NC41 Normal Alkane C41 ............ ....... ... e~fflJ~:~~~I~=·~~~Q-9~!~""mM·m,r.~wT..~"~t1~··~'~1ir<¡rØl:"")(<<[[I.ffU'~(U1Ir'. ,1toî\·.J''7rrlftrtw. .j¡Iff..t'..~ifN~fIII¡i.~M!·H. . ..0 .. _ m'CU;!;....l . ...... .. .. ......n.. R.' .,~... k j n' " ... .... ~.. H.' . . . .0. . " Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHllllPS UNITED STATES NORTH SLOPE IAPETUs..2 Whole Oil GC Trace l- f;! .~_. '" ~ Q) u z .~ PI ... ~ '" ... ~ ¡¿ '" ... g '" ... .... g g f;! k o !;\ Client ID: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: US136207 05-252-A CP218518 SWC JURRAsslC LATE 8861.0 Q) ~ ~ ~ o '" u Ii!: '"' ~ ¡¡J '" fo7 ... g '" '" ~ ... Q) '" u ... z '" ~ OJ '" .. '" " ,-J :! U G4050361.D ... ... . '" '" I K '"~ i ~ E .... I r 4!t:JÜ l,,~ ~";~ '" ¡¿ ilill ~ ~ '" ... , ~~~:~,~~·~l.,)~ _~"P:~ Pristane/Phytane1.89 Pristaneln Cn 0.93 PhyìanelnC18 0,63 n C1a1n C19 1.03 nC171nC29 5.52 CPI Marzi4 0.92 Normal Paraffins Isoprenoids 1.9 Oycloparaffins 0.2 Branched (iso-) Paraffins 0.0 BTX aromatics {J.1 Resolved unknowns 90.0 .., -< '" ... '" ... PWfu1~~1 "W A..ßZl(lG:S B. MCH/n C7 mpX¥L.lriGa 0.32 ~~~IL~ pf1 19.9à 122.61 03 C4 05 0.35. 0.04 0.26 0.35 ¡Thompson, K.F.M., 1983.GCA:V.47, p.303. ZMango, F.D., 1994.GCA: V.58, p.895. 3HaIpern,H.I.,1995,AAPG Bull.: V.79, p.80!. 4Marzi,1993,OrgG;20,1301. Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8861 - Client 10: Project #: Lab 10: File Name: US136207 05-252-A CP278518 G4050361.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 220MB 2,2-0imethylbutane CP Cyclopentane 230MB 2,3-0imethylbutane 2MP 2-Methylpentane 6.192 203 107 3MP 3-Methylpentane 6.535 257 131 NC6 Normal Alkane C6 6.943 894 470 220MP 2,2-0 i methyl pentane MCP Methylcyclopentane 7.683 843 442 24DMP 2,4-Dimethylpentane 7.826 58 30 223TMB 2,2,3- Trimethylbutane BZ Benzene 8.461 2842 1339 33DMP 3,3-Dimethylpentane 8.706 402 151 CH Cyclohexane 8.804 1358 550 2MH 2-Methylhexane 9.206 1469 658 23DMP 2,3-Dimethylpentane 9.257 536 255 11DMCP 1,1-Dimethylcyclopentane 9.348 357 152 3MH 3-Methylhexane 9.559 2469 1073 1 C3DMCP 1-cis-3-Dimethylcyclopentane 9.798 1227 525 1T3DMCP 1-trans-3-Dimethylcyclopentane 9.915 5632 2105 3EP 3-Ethylpentane 9.989 530 315 1 T2DMCP 1-trans-2-Dimethylcyclopentane 10.034 2256 979 NC7 Normal Alkane C7 10.652 43771 19141 ISTD Internal Standard MCH Methylcyclohexane 11.522 13880 5581 113TMCP 1,1,3,-Trimethylcyclopentane 11.698 1721 664 ECP Ethylcyclopentane 12.116 2139 628 124TMCP 1 ,2,4- Trimethylcyclopentane 12.576 2117 777 123TMCP 1 ,2,3- Trimethylcyclopentane 12.954 2776 1049 TOL Toluene 13.269 7134 2649 NC8 Normal Alkane C8 15.969 22630 8013 IP9 Isoprenoid C9 17.872 4632 1631 XYL Xylene NC9 Normal Alkane C9 21.770 29432 10159 IP10 Isoprenoid C10 23.207 8286 2626 NC10 Normal Alkane C10 27.409 39844 13011 IP11 Isoprenoid C11 28.720 12295 3830 NC11 Normal Alkane C11 32.706 57039 17415 NC12 Normal Alkane C12 37.665 64407 19862 IP13 Isoprenoid C13 38.407 21209 5853 IP14 Isoprenoid C14 41 .188 15663 4863 NC13 Normal Alkane C13 42.305 74465 22740 IP15 Isoprenoid C15 45.798 25436 6847 NC14 Normal Alkane C14 46.682 81433 23217 IP16 Isoprenoid C16 49.353 41597 9925 NC15 Normal Alkane C15 50.785 81350 23556 NC16 Normal Alkane C16 54.674 77043 21008 IP18 Isoprenoid C18 56.627 42452 8443 Company: CONOCOPHILLlPS Client ID: US136207 Well Name: IAPETUS-2 Project #: 05-252-A Depth: 8861 - LablD: CP278518 ~~ Sampling Point: File Name: G4050361.D _~r~"!JI\. ". ~ . .... ~ ':. it. :, ~ ~ NC17 Normal Alkane C17 58.363 76676 20394 IP19 Isoprenoid C19 (Pristane) 58.728 71143 13096 PHEN Phenanthrene 59.827 5879 1074 NC18 Normal Alkane C18 61.867 59942 16452 IP20 Isoprenoid C20 (Phytane) 62.336 37694 6110 NC19 Normal Alkane C19 65.206 57962 15326 NC20 Normal Alkane C20 68.386 54216 12586 NC21 Normal Alkane C21 71.431 40417 10509 C25HBI Highly Branch Isoprenoid C25 71.701 23355 5612 NC22 Normal Alkane C22 74.342 41228 10130 NC23 Normal Alkane C23 77.132 39142 8984 NC24 Normal Alkane C24 79.845 39447 8100 NC25 Normal Alkane C25 82.394 33459 7036 NC26 Normal Alkane C26 84.870 28655 5758 NC27 Normal Alkane C27 87.252 19661 4377 NC28 Normal Alkane C28 89.553 18510 3491 NC29 Normal Alkane C29 91 .777 13880 2987 NC30 Normal Alkane C30 93.932 10036 2013 NC31 Normal Alkane C31 96.013 9352 1861 NC32 Normal Alkane C32 98.031 4508 1056 NC33 Normal Alkane C33 99.985 5552 1024 NC34 Normal Alkane C34 101.882 3553 698 NC35 Normal Alkane C35 103.869 3518 572 NC36 Normal Alkane C36 106.075 2083 310 NC37 Normal Alkane C37 108.570 1468 215 NC38 Normal Alkane C38 111 .448 1214 151 NC39 Normal Alkane C39 114.757 1156 118 NC40 Normal Alkane C40 118.640 1174 99 NC41 Normal Alkane C41 BASELINE CGSI WHOLE OIL GC . . ..~{; _~~¥~iÅ'I~~-~;ït~¡~1nf~íM'i}'i.~IR~;¡i;'1Ii;W~.¡:~r;;¡;'1r~r~~!f~;'X·;~-:;::C::U_¡:;·~;;;;wrï:ií~~~.'·r~~'-~~[;[If~:=;;i~K;:K;î:-:;í~:üWií¡Ú;;-,~ Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE Client ID: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: US136208 05-252-A CP278519 SWC IAPETUS-2 JURRASSIC LATE 8867.0 Whole Oil GC Trace G4050362.D U .-< z '" Ii u '" ~ !i Ii " " u " ~ " u '" z ~ oj tJ Z " u z '" .-< '" '" u z u z '" u Z u z '" '" H " t< ~ '" ~ ~ .; ~ ?J1L.U~J~ lk~.~' ,.~ n~ k ~ J)~~Jw.""",-l,.", I S \ '" N tJ Z '" H tJ " '" N tJ U " Z '" g u u " z U tJ Z Z Z ~!hltm.ì¡fi,i~]!~J r ~!~~r ... _~l ~ ~H~~I¡ Pristane/Phytane 2.20 A. BZlnCa 0.76 P1 16.43 Tr1 4.01 Pristaneln C17 0.94 B. TOUn C7 0.32 P2 8.73 Tr2 12.55 Phytaneln C18 0.53 C. (n CS+nC7 )/(CH+MCH) 0.64 P3 3.56 Tr3 3.92 n C1S/n C19 1.06 I. Isoheptane Value 0.26 5N1 11.06 Tr4 2.75 n C17/n C29 6.37 F. nC7/MCH 0.60 N2 27. 71 Trs 6.67 CPI Marzi4 1.02 U. CH/MCP 1.03 6N1 32.51 Tr7 17.20 Normal Paraffins 13.1 R. nC712MH 4.57 K1 0.88 Trs 2.45 Isoprenoids 3.3 S. n Cff22DMB K2 0.24 C1 Cycloparaffins 0.5 H. Heptane Value 17.57 5NlN1 0.34 C2 0.34 Branched (iso-) Paraffins 0.1 MCH/n C7 1.66 P3/N2 0.13 C3 0.09 BTX aromatics 0.1 mpXYUn Cs In(24DMP/23DMP) -1.32 C4 0.23 Resolved unknowns 82.6 Cs 0.33 ¡Thompson, K.F.M.,1983.GCA;V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.I.,1995,AAPG Bull.: V.79, p.80!. 4Marzi,1993,OrgG;20,130!. Company: CONOCOPHILLlPS Client ID: US136208 Well Name: IAPETU5-2 Project #: 05-252-A Depth: 8867 - LablD: CP278519 Sampling Point: File Name: G4050362.D n ... . -~ ......~ . .........-- 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 6.312 752 504 3MP 3-Methylpentane 6.580 774 462 NC6 Normal Alkane C6 6.982 2618 1504 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 7.720 3034 1513 24DMP 2,4-Dimethylpentane 7.862 187 77 223TMB 2,2,3- Trimethylbutane BZ Benzene 8.496 1986 943 33DMP 3,3-Dimethylpentane 8.741 480 208 CH Cyclohexane 8.838 3127 1292 2MH 2-Methylhexane 9.239 2072 931 23DMP 2,3-Dimethylpentane 9.290 703 335 11 DMCP 1 ,1-Dimethylcyclopentane 9.382 754 295 3MH 3-Methyl hexane 9.591 2957 1335 1C3DMCP 1-cis-3-Dimethylcyclopentane 9.830 2241 1004 1 T3DMCP 1-trans-3-Dimethylcyclopentane 9.942 12967 4542 3EP 3-Ethylpentane 10.023 682 467 1 T2DMCP 1-trans-2-Dimethylcyclopentane 10.065 3890 1736 NC7 Normal Alkane C7 10.679 9463 4142 ISTD Internal Standard MCH Methylcyclohexane 11.550 15698 6335 113TMCP 1,1,3,- Trimethylcyclopentane 11.725 2007 829 ECP Ethylcyclopentane 12.142 2479 756 124TMCP 1,2,4- Trimethylcyclopentane 12.601 2582 987 123TMCP 1,2,3- Trimethylcyclopentane 12.978 3402 1320 TOL Toluene 13.293 3025 1096 NC8 Normal Alkane C8 15.986 23404 8469 IP9 Isoprenoid C9 17.884 4679 1716 XYL Xylene NC9 Normal Alkane C9 21.776 33443 11599 IP10 Isoprenoid C10 23.212 9719 2937 NC10 Normal Alkane C1 0 27.411 42711 13707 IP11 Isoprenoid C11 28.721 11916 3693 NC11 Normal Alkane C11 32.706 59589 18438 NC12 Normal Alkane C12 37.669 73498 21951 IP13 Isoprenoid C13 38.410 22454 6148 IP14 Isoprenoid C 14 41.190 17558 5245 NC13 Normal Alkane C13 42.308 87571 26518 IP15 Isoprenoid C15 45.782 29341 7545 NC14 Normal Alkane C14 46.676 95945 27475 IP16 Isoprenoid C16 49.350 50840 11905 NC15 Normal Alkane C15 50.788 102258 28407 NC16 Normal Alkane C16 54.678 97636 26783 IP18 Isoprenoid C 18 56.628 53727 10741 Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8867 - Client ID: Project #: LablD: File Name: US136208 05-252-A CP278519 G4050362.D NC17 Normal Alkane C17 58.366 91914 25128 IP19 Isoprenoid C19 (Pristane) 58.733 86183 16328 PHEN Phenanthrene 59.829 6999 1373 NC18 Normal Alkane C18 61.869 74069 20443 IP20 Isoprenoid C20 (Phytane) 62.332 39186 6827 NC19 Normal Alkane C19 65.206 69957 18649 NC20 Normal Alkane C20 68.389 67761 16334 NC21 Normal Alkane C21 71.433 55518 13380 C25HBI Highly Branch Isoprenoid C25 71.691 6387 1266 NC22 Normal Alkane C22 74.343 48954 11787 NC23 Normal Alkane C23 77.132 45573 10393 NC24 Normal Alkane C24 79.813 39012 8339 NC25 Normal Alkane C25 82.386 34874 7409 NC26 Normal Alkane C26 84.862 26198 5660 NC27 Normal Alkane C27 87.247 20170 4434 NC28 Normal Alkane C28 89.552 17834 3207 NC29 Normal Alkane C29 91 .775 14429 2915 NC30 Normal Alkane C30 93.928 8729 1872 NC31 Normal Alkane C31 96.008 8055 1605 NC32 Normal Alkane C32 98.022 4514 1018 NC33 Normal Alkane C33 99.980 6020 1054 NC34 Normal Alkane C34 101.877 3296 644 NC35 Normal Alkane C35 103.861 3638 520 NC36 Normal Alkane C36 106.071 2062 304 NC37 Normal Alkane C37 108.573 1309 207 NC38 Normal Alkane C38 111 .440 1173 148 NC39 Normal Alkane C39 114.754 1188 122 NC40 Normal Alkane C40 118.619 1141 90 NC41 Normal Alkane C41 ... .. . ·.·.~ðl.e~I!t~...!.~.~~~.~Qgw!:,.'!~,r¡J1..'·mtm!¡:.nl~~;1mßE~rIº~tJ~·~~..wg~lj~r.m~¡ru~~""·""1u~lr"II.. ."'........'T\."lllt·~...:~:':1II'...J&t!F'Æru1Pt..1\'."."i;df"'mJllf"'nir.n, --..,-.... .,....,. ... ,,,...... ., ...,. ",..1 "" ....,. ML.«,illl,. .....",.... L.. Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHllLlPS UNITED STATES NORTH SLOPE IAPETUS..2 Whole Oil GC Trace ... ... o :>: III ... g u '" z .... u '" z .... g g u :>: '" '" .... .... u u z z .... '" H '" .. ., ... .. ... E Client 10: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: o '" g '" u z a :>: ... " '" u US136209 05-252-A CP278520 SWC JURRASSIC LATE 8872.0 '" u :>: ~ E z ~ g '" g I o ~ , ~ ;M.I. ~ ~~ ,~~~jt; 'IM....\II.t~,_w.'" ~-'L'. t.. I '.' ..-.L,."r......"L.L... ·l'.....}.-mlrm~J\~t-~ ....m:ø Pristane/Phytane 2,02 Prístaneln C17 0.93 PhytanelnC18 0.56 n C1e1n CHI 1.06 n C17/nC29 5,60 CPI Marzi4 1.02 Normal Paraffins 8.7 Isoprenoids 2.3 Cycloparaffins 0.2 Branched (iso-) Paraffins 0.0 BTX aromatics 0:0 Resolved unknowns 88.6 .., -< .... .. .. H ~~'J_ AI34f.nqs B. TOUn U. CH/MCP R S. 1.09 G4050363.D (þ '" g f") ., en 0 u '" '" :>: g u g z -~~ R~ ~~'i~ Trr 14.72 1.83 Cs 0.20 ¡Thompson, K.F.M.,1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.I., 1995,AAPG Bull.: V.79, p.80l. 4Marzi,1993,OrgG;20,130l. Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8872 - Client 10: Project #: LablD: File Name: US136209 05-252-A CP278520 G4050363.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 220MB 2,2-Dimethylbutane CP Cyclopentane 230MB 2,3-Dimethylbutane 2MP 2-Methylpentane 6.281 475 319 3MP 3-Methylpentane 6.554 499 279 NC6 Normal Alkane C6 6.960 1440 798 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 7.701 1228 630 24DMP 2,4-Dimethylpentane 7.844 77 39 223TMB 2,2,3- Trimethyl butane BZ Benzene 8.480 1190 516 33DMP 3,3-0 imethyl pentane 8.726 502 189 CH Cyclohexane 8.822 1333 495 2MH 2-Methylhexane 9.224 920 387 23DMP 2,3-Dimethylpentane 9.275 344 155 11DMCP 1,1-Dimethylcyclopentane 9.366 372 119 3MH 3-Methylhexane 9.577 1205 521 1 C3DMCP 1-cis-3-Dimethylcyclopentane 9.816 751 336 1 T3DMCP 1-trans-3-Dimethylcyclopentane 9.932 5474 1997 3EP 3-Ethyl pentane 10.013 236 186 1 T2DMCP 1-trans-2-Dimethylcyclopentane 10.051 1354 591 NC7 Normal Alkane C7 10.666 2880 1251 ISTD Internal Standard MCH Methylcyclohexane 11.537 4028 1625 113TMCP 1,1,3,- Trimethylcyclopentane 11.713 683 256 ECP Ethylcyclopentane 12.131 371 152 124TMCP 1,2,4- Trimethylcyclopentane 12.591 862 277 123TMCP 1,2,3- Trimethylcyclopentane 12.968 978 354 TOL Toluene 13.284 918 343 NC8 Normal Alkane C8 15.976 4852 1721 IP9 Isoprenoid C9 17.879 956 354 XYL Xylene NC9 Normal Alkane C9 21.769 6497 2230 IP10 Isoprenoid C1 0 23.208 1801 573 NC10 Normal Alkane C10 27.404 13633 4366 IP11 Isoprenoid C 11 28.718 4852 1475 NC11 Normal Alkane C11 32.700 33132 10263 NC12 Normal Alkane C12 37.663 51228 15692 IP13 Isoprenoid C13 38.408 16386 4527 IP14 Isoprenoid C 14 41.187 13224 3959 NC13 Normal Alkane C13 42.305 65354 19936 IP15 Isoprenoid C15 45.792 24336 6242 NC14 Normal Alkane C14 46.680 77307 21941 IP16 Isoprenoid C16 49.351 39581 9453 NC15 Normal Alkane C15 50.786 79781 22652 NC16 Normal Alkane C16 54.675 75536 20962 IP18 Isoprenoid C18 56.626 41204 8298 Company: Well Name: Depth: Sampling Point: CONOCOPHllLlPS IAPETUS-2 8872 - 1~~W1~~ ,_.~-~~ NC17 Normal Alkane C17 IP19 Isoprenoid C19 (Pristane) PHEN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenoid C20 (Phytane) NC19 Normal Alkane C19 NC20 Normal Alkane C20 NC21 Normal Alkane C21 C25HBI Highly Branch Isoprenoid C25 NC22 Normal Alkane C22 NC23 Normal Alkane C23 NC24 Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal Alkane C26 NC27 Normal Alkane C27 NC28 Normal Alkane C28 NC29 Normal Alkane C29 NC30 Normal Alkane C30 NC31 Normal Alkane C31 NC32 Normal Alkane C32 NC33 Normal Alkane C33 NC34 Normal Alkane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal Alkane C38 NC39 Normal Alkane C39 NC40 Normal Alkane C40 NC41 Normal Alkane C41 Client ID: Project #: LablD: File Name: US136209 05-252-A CP278520 G4050363.D 58.361 58.733 59.827 61.866 62.331 65.205 68.386 71.430 71.694 74.340 77.131 79.807 82.388 84.863 87.250 89.548 91.777 93.928 96.008 98.025 99.981 101.878 103.864 106.069 108.564 111.443 114.768 118.641 69977 64765 4770 57128 32072 53774 51214 40005 10171 37488 34410 30422 27875 23005 17797 14354 12504 8038 6902 4023 5345 2914 3994 2115 1322 959 1262 1167 19379 12348 957 16150 5438 14058 11937 9859 2532 8722 7797 6632 5800 4784 3810 2687 2532 1680 1477 924 917 600 543 289 183 136 118 96 BASELINE [JGSI WHOLE Oil GC ~:é.~iíV;.""A...~.t~._.~:V;:j£¡...¡;~.~.r.;iiÏ*§r::A.';"A-~"¡~;-'-j;:.:~5:íí:m.:""~f:::~~¡''';~;';;:~;·.:~'';'''''';'';;;';'';'''''~·:··:·í~9..J.·.·__~íU..II':;"''';;~..._;!í¡¡¡¡¡',,,,,,,,, Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE Client ID: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: ? NIGLlQ 1 70.41618 -151.0634 Whole Oil GC Trace o '" ~ t.. ~ ~ ~ ::i.N "9-< ClT' .., ~ ~ :i'! '" ~ ~~i ~ ~ ~ ~~~ ~: J~ Jl_LL~\. ,.,1" dJ' u Z u '" Z u :<: '" u L') Z 8 '"' ~ r-- U Z '"' u :<: u Z 0) u z '" u <:> U Z u z N U Z M U Z u z US039525 05-252-A P A000046 OIL N~. che..\ ~ ( 7259 FT FT G4050349.D N '" U N r-- Z U N Z ~ r-- 0) <:> M M M ~ U U U Z Z Z l~·ï~m I Pristane/Phytane 1.97 A. BZlnCs 0.09 P1 20.23 Tr1 3.97 Pristane/n C17 0.81 B. TOLIn C7 0.41 P2 14.73 Tr2 9.70 Phytaneln C1S 0.51 C. (n C6+n C7)/(CH+MCH) 0.93 P3 4.39 Tr3 3.96 n C1a1n C19 1.07 I. Isoheptane Value 0.83 5N1 10.66 Tr4 3.10 nC17/nC29 4.15 F. n C7/MCH 0.67 N2 11.57 Trs 7.06 CPI Marzi4 1.05 U. CH/MCP 0.81 6N1 38.41 Tr7 2.19 Normal Paraffins 27.3 R. nC7/2MH 3.13 K1 0.96 Trs 3.43 Isoprenoids 4.8 S. n C¡¡!22DMB 70.38 K2 0.56 C1 0.06 Cycloparaffins 7.9 H. Heptane Value 20.48 5N1/6N1 0.28 C2 0.54 Branched (iso-) Paraffins 4.8 MCH/n C7 1.49 P3/N2 0.38 C3 0.21 BTX aromatics 1.8 mpXYLln Cs 0.47 In(24DMP/23DMP) -0.94 C4 0.04 Resolved unknowns 52.9 Cs 0.14 ¡Thompson, K.F.M.,1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3HaIpem,H.I.,1995,AAPG Bull.: V.79, p.80!. 4Marzi,1993,OrgG;20, 1301. u z '" u Z r-- U Z ~ u Z Û 0 z ~ Z N N U N ~ Z ~ ~ 0 z '"' '" '"' 0) "" co H '"' '"' '"' 0.. N '" v.IJ~,~~~JI-'~~- Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS NIGLlQ 1 7259 - FT tIì1l_~rr1'n II!! ~ Îi~'~ _.~-'~' , .. . : ___ . .: ~ .u:~ L....:; ~r,li ~ i! IC4 NC4 IC5 NC5 22DMB CP 23DMB 2MP 3MP NC6 22DMP MCP 24DMP 223TMB BZ 33DMP CH 2MH 23DMP 11 DMCP 3MH 1 C3DMCP 1T3DMCP 3EP 1 T2DMCP NC7 ISTD MCH 113TMCP ECP 124TMCP 123TMCP TOL NC8 IP9 MXYL PXYL OXYL NC9 IP10 NC10 IP11 NC11 NC12 IP13 IP14 NC13 IP15 NC14 IP16 NC15 Client ID: Project #: Lab ID: File Name: US039525 05-252-Ä P A000046 G4050349.D Iso-alkane C4 Normal AlkaneC4 Iso-alkane C5 Normal AlkaneC5 2,2-Dimethylbutane Cyclopentane 2,3-Dimethylbutane 2-Methylpentane 3-Methylpentane Norrnal Alkane C6 2,2-Dimethylpentane Methylcyclopentane 2,4-Dimethylpentane 2,2, 3-Trimet~ylblltane Benzene 3, 3-Dim~thyJpentåhe Cyclohexane 2;.Methylhexanª 2,3-Dimethylpentane 1, 1-'Dimethylcy¢1()pêr1tar1E~ 3-Methylhexane 1-cis-3;.Dimethylcyclopèntanè 1-trans-3-Dimethylcyclopentane 3-Ethylpentane 1-trans-2-Dimethylcyclopentane Normal·AlkaneG7 Internal Standard Methylcyclohe)(ane 1,1,3,- Trimethylcyclopentane Ethylcyclopentane 1,2,4- Trimethylcyclopentane 1,2; 3..Trimethylcyclopentanè Toluene Normal AlkaneC8 Isoprenoid C9 m-Xylene p-Xylene o-Xylene Normal Alkane C9 Isoprenoid C10 Normal Alkane C1 0 Isoprenoid C11 Normal Alkane C11 NormalAlkarieC12 Isoprenoid C13 Isoprenoid C14 Normal Alkane C13 IsoprenoidC15 Normal Alkane C14 IsOprenoid G16 Normal Alkane C 15 27572 3.23 80950 69992 8.20 853'Z8 ~O}()1 1751 1209 0.14 7708 5065 0.39 0.59 66.897 43142 3.36 5106 47460 29162 2.38 3.42 t¥3~~~ 72681 6.48 8,52 7.045 1758 1074 0.09 0.13 7.102 94372 50937 4.73 5;97 7.245 6025 3060 0.30 0.36 0.03 7.876 11533 5669 0.58 0.66 8.220 76831 37415 3.85 4.39 8.675 15432 7721 0.77 0.91 8.979 55022 25624 2.76 3.00 15079 30367 13875 1.52 1.63 3747 0.21 0;44- 54968 24499 2.76 2.87 58548 6.75 6.86 68587 29349 3.44 3.44 ~OO38\1 80386 10.05 9.42 21353 8380 1.07 0.98 6696 0.80 0.79 8266 1.02 0.97 9932 1.16 12.685 21832 2.77 2.56 47110 7:;36 5.52 17.303 33292 12067 1.67 1.41 52552 18983 2;.64 2.23 18.582 17117 6629 0.86 0.78 1.35 21.242 132088 42665 6.63 5.00 8729 1.02 26.882 121479 38521 6.09 4.52 29888 9365 1.50 1.10 32.173 122482 37893 6.14 4.44 10il524 33567 5~39 3,$3 37.862 32666 8958 1.64 1.05 .6"703 1;08 0.79 41.763 103446 31350 5.19 3.68 9480 1.58 46.125 9676.3 28781 4.85 3.37 45693 101TZ 2.29 1.19 50.235 99700 26241 5.00 3.08 Company: Well Name: Depth: Sampling Point: Client ID: Project #: Lab ID: File Name: CONOCOPHILUPS NIGUQ 1 7259 - FT US039525 05-252-A P A000046 G4050349.D NC16 Normal Alkane C16 54.121 81607 23000 4.09 2.70 IP18 Isoprenoid C 18 56.065 42749 8935 2.14 1.05 NC17 Normal Alkane C17 57.806 77392 21624 3.88 2.53 IP19 Isoprenoid C19 (Pristane) 58.172 62536 11893 3.14 1.39 PH EN Phenanthrene 59.068 3123 613 0.16 0.07 NCt8 Normal Alkane C18 61 .306 62103 18232 3.12 2.14 IP20 Isoprenoid C20 (Phytane) 61.769 31754 5334 1.59 0.63 NC19 Normal Alkane C19 64.642 57851 15833 2.90 1.86 NC20 Normal Alkane C20 67.824 54212 14331 2.72 1.68 NC21 Normal Alkane C21 70.864 45947 12444 2.30 1.46 C25HBI Highly Branch Isoprenoid C25 71.119 3319 784 0.17 0.09 NC22 Normal Alkane C22 73.774 42265 11306 2.12 1.33 NC23 Normal Alkane C23 76.566 40840 10647 2.05 1.25 NC24 NormalAlkane C24 79.246 34373 9451 1.72 1.11 NC25 Normal Alkane C25 81.820 32045 8469 1.61 0.99 NC26 Normal Alkane C26 84.298 28643 7115 1.44 0.83 NC27 Normal Alkane C27 86.688 23851 6037 1.20 0.71 NC28 Normal Alkane C28 88.994 18535 4509 0.93 0.53 NC29 Normal Alkane C29 91.217 18631 4178 0.93 0.49 NC30 Normal Alkane C30 93.371 14268 3180 0.72 0.37 NC31 Normal Alkane C31 95.452 11619 2534 0.58 0.30 NC32 Normal Alkane C32 97.468 8343 1872 0.42 0.22 NC33 Normal Alkane C33 99.423 9437 1787 0.47 0.21 NC34 Normal Alkane C34 101.315 6379 1260 0.32 0.15 NC35 Normal Alkane C35 103.241 5953 1047 0.30 0.12 NC36 Normal Alkane C36 105.357 3442 581 0.17 0.07 NC37 Normal Alkane C37 107.745 2732 393 0.14 0.05 NC38 Normal Alkane C38 110.480 2438 308 0.12 0.04 NC39 Normal Alkane C39 113.670 2042 206 0.10 0.02 NC40 Normal Alkane C40 117.361 1229 123 0.06 0.01 NC41 Normal Alkane C41 Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE TEMPTATION 1 70.39208 -151.1532 Whole Oil GC Trace :z: u :f: '" r- U u :z: :z: ex> '" U '" u :z: u :z: :z: 0 u u '" :z: z u N '" ::E: 8 u M Z .... U 0 z :z: ~ u '" '" u z ~ u z ... u :z: 'i'le:1"~Þ.l~IIII:l(::n ..¿J . Pristane/Phytane Pristane/n C17 Phytane/n c1S n C18/n C19 nC17/n C:Z9 CPI Marzi4 Normal Paraffins Isoprenoids Cycloparaffins Branched (iso-) Paraffins BIX aromatics Resolved unknowns no, -,__~ 1;98 0.79 OA9 1.07 427 1.04 26.7 5.1 7.0 3A 1.6 55.7 A. B. C. I. Isoheptane Value F. nC7/MCP¡ U. CH/MCP R. 1l(}i/2MP¡ S. n C¡¡!22DMB H. HeptaneY'älue MCH/n C7 mþXYLlhGs WHOLE OIL GC ~;'~~~~i-[~Þ® ':"m'~~ "co< . ;:~~ Client ID: Project #: . Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: '" U r- Z U Z ex> .... u z '" .... 0 U N Z U Z N U N Z ~ ~ ..q< Z U N Z U '" Z ~ Z US118448 05-252-A CP023307 OIL k ",.,f> AA \A{é... CRETACEOUS 7180.5 FT FT G4050348.D '" ~ ~ CD 0) Z~~~;;;NM..;:rU') z~fi~~~~8~~ ~ 0 z ~ ~ ~ ~ 20:04 14.26 0.83 0,63 0.91 Øh11$i~~D ,;Er1 C3 c¡ Cs 0.21 Œ04 0.14 '" U :f: :s::> ~ 1!ij ~ ~ ~ '" ~ ~~:~ s ~: ~ :....; ~ ; H ~ ~C \~~~ ~ y~ jl~JJJJ ,.J, J~.~k~~~~l,!l.,¡.L- _1·· g1 Pz 67.12 2Œ22 1.59 0.46 Kz 5N1/6N1 P3/N2 In(24DMP/23DMP) 0.56 0.37 1TIlOmpson, K.F.M.,1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.I.,1995,AAPG Bull.: V.79, p.80l. 4Marzi,1993,OrgG;20,1301. Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS TEMPTATION 1 7180.5 - FT Client ID: Project #: LablD: File Name: US118448 05-252-A CP023307 G4050348.D IC4 Iso-alkane C4 3.766 9837 8899 0.50 1.05 NC4 Normal Alkane C4 3.883 28888 25652 1048 3.04 IC5 Iso-alkane C5 4.321 44251 35711 2.26 4.23 NC5 NormaJAlkane C5 4.564 56493 43328 2.89 5.13 220MB 2,2-0imethylbutane 5.022 1250 819 0.06 0.10 CP Cyclopentane 50498 11087 7216 0.57 0.85 230MB 2,3-0imethylbutane 5.534 5439 3531 0.28 0.42 2MP 2-Methylpentane 5.619 44921 28868 2.30 3042 3MP 3-Methylpentane 5.924 32824 19941 1.68 2.36 NC6 Normal Alkane C6 6.349 83894 49180 4.29 5.82 220M P 2,2-0imethylpentane 7.040 1444 876 0.07 0.10 MCP Methylcyclopentane 7.097 69757 37460 3.56 4043 240MP 2,4-Dimethylpentane 7.240 4766 2399 0.24 0.28 223TM B 2,2, 3-Tri methyl butane 7.397 499 207 0.03 0.02 BZ Benzene 7.872 7375 3588 0.38 0.42 330MP 3,3-Dimethylpentane 8.099 1039 497 0.05 0.06 CH Cyclohexane 8.215 63810 30949 3.26 3.66 2MH 2-Methylhexane 8.622 35268 16746 1.80 1.98 23DMP 2,3-Dimethylpentane 8.670 12571 6281 0.64 0.74 110MCP 1,1-0imethylcyclopentane 8.757 11944 5445 0.61 0.64 3MH 3-Methylhexane 8.974 45057 20811 2.30 2.46 1C3DMCP 1-cis-3-0imethylcycJopentane 9.208 26688 12268 1.36 1045 1T3DMCP 1-trans-3-Dimethylcyclopentane 9.325 24917 11360 1.27 1.34 3EP 3-Ethylpentane 9.391 3295 2883 0.17 0.34 1T2DMCP 1-trans-2-Dimethylcyclopentane 9.444 45188 20023 2.31 2.37 NC7 Normal Alkane C7 10.071 112893 49028 5.77 5.80 ISTD Internal Standard 1 0.294 69877 30172 3.57 3.57 MCH M ethylcyclohexane 1 0.938 180001 72651 9.20 8.60 113TMCP 1,1,3,-Trimethylcyclopentane 11 .106 19020 7471 0.97 0.88 ECP Ethylcyclopentane 11.523 13053 5461 0.67 0.65 124TMCP 1,2,4- Trimethylcyclopentane 11.987 18022 7388 0.92 0.87 123TMCP 1,2,3-Trimethylcyclopentane 12.366 21553 8648 1.10 1.02 TOl Toluene 12.679 44575 17608 2.28 2.08 NC8 Normal Alkane C8 150418 141063 45072 7.21 5.33 IP9 Isoprenoid C9 17.299 29902 10790 1.53 1.28 MXYl m-Xylene 18.516 49467 17930 2.53 2.12 PXYl p-Xylene 18.577 15371 5936 0.79 0.70 OXYL o-Xylene 19.785 34267 10800 1.75 1.28 NC9 Normal Alkane C9 21.240 134083 43469 6.85 5.14 IP10 Isoprenoid C10 23.224 27892 8985 1043 1.06 NC10 Normal Alkane C1 0 26.877 125059 40018 6.39 4.74 IP11 Isoprenoid C11 28.176 30500 9814 1.56 1.16 NC11 Normal Alkane C11 32.171 127409 39460 6.51 4.67 NC12 Normal Alkane C 12 37.122 110901 34376 5.67 4.07 IP13 Isoprenoid C13 37.859 33719 9293 1.72 1.10 IP14 Isoprenoid C14 40.634 22791 7052 1.16 0.83 NC13 Normal Alkane C13 41.758 107637 32456 5.50 3.84 IP15 Isoprenoid C15 45.216 32485 9763 1.66 1.16 NC14 Normal Alkane C14 46.119 100856 29802 5.15 3.53 IP16 Isoprenoid C16 48.789 48200 10518 2046 1.24 NC15 Normal Alkane C15 50.231 103174 27196 5.27 3.22 "'-- Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS TEMPTATION 1 7180.5 - FT .V."f- ~~1' ,~. ,- ~~l. ;~'" r.~I'. '. I' ': :r-.""'"\~' ;¡¡: 1 1&11' ~. -,,~ .- ~;o. .. ~ì:, . iö& L_ i ~ ~ .. :i. ............._-1 C::\,., NC16 IP18 NC17 IP19 PHEN NCt8 IP20 NC19 NC20 NC21 C25HB I NC22 NC23 NC24 NC25 N026 NC27 NC28 NC29 NC30 NC31 NC32 NC33 NC34 NC35 NC36 NC37 NC38 NC39 NC40 NC41 '~ Client ID: Project #: Lab ID: File Name: US118448 05-252-A CP023307 G4050348.D Normal Alkane C16 IsoprenoidC18 Normal Alkane C17 IsoprenoidC19 XPri$tane) Phenanthrene NormalAlkaheC 18 Isoprenoid C20 (Phytane) Normal AlkaneC19 Normal Alkane C20 Normal·AlkaneC21 Highly Branch Isoprenoid C25 Normal Alkane C22 Normal Alkane C23 Normal Alkane 024 Normal Alkane C25 Normal Alkane 026 Normal Alkane C27 Normal AlkaneC28 Normal Alkane C29 NormalAlkaneC30 Normal Alkane C31 Norrnal AlkaneC32 Normal Alkane C33 Normal Alkane C34 Normal Alkane C35 Normal Alkane C36 Normal Alkane C37 Normal AlkaneC38 Normal Alkane C39 Normal AlkåneC40 Normal Alkane C41 54.1 18 84620 24074 4.32 2.85 5ô;063 44289 9273 2.26 1.10. 57.803 79429 22435 4.06 2.66 58.165 -ô2932 3.~2 1.41 59.065 3187 564 0.16 0.07 61 .770 31782 5446 1 .62 0.64 67.823 56039 14907 2.86 1 .76 46823 12847 4i3~ 71 .1 15 3470 817 0.18 0.10 73.7/72 43269 11631 2.21 1.38 76.561 40789 10734 2.08 1 .27 79.241 34494 9523 1.76 1;13 81.819 31634 8093 1 .62 0.96 84.295 28488 7412 1.46 0.88 86.684 23224 5927 1 .19 0.70 88.987 1.8338 4617 0;94 0:55 91 .217 18615 4036 0.95 0.48 3076 95.450 1 1203 2491 0.57 0.30 1738 9374 1701 0.48 0.20 5615 1t32 0.29 0.13 5619 890 0.29 0.1 1 3037 494 0;16 0.06 107.738 2124 307 0.1 1 0.04 189 Ct02 1 13.661 1 181 124 0.06 0.02 78 0:01 BASELINE CGSI WHOLE OIL GC ~~'!Ii".:;'\da¡."'ÍiÌI¡~:;'._.i1m¡Íii...;~~"~j¡¡;1Ii~'~~ci-hli····~······~;,~~...}';:':-~""..:. ]¡·'···-'''iít~~~W·' ...."...-=n,{¡tn" )¡tjj¡¡ Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE TEMPTATION 1 70.39208 -151.1532 Whole Oil GC Trace :I: U :>: '" U I"- Z U Z ~ 0.. co Z U u :>: z '" '" u z 0 8 u u z z '" N l"- e ~ N ~ ~ ~5~o . 'ljl.II.,.HIJJ.l,J,~Ll~~~~ ¡¡ ~ ,;"\ ~ 1t\ ~ rI \,I\",~ ~ ~ 0.. li ~ o~ ~ ~ f '" ~.~ I- ~ ~ " 0.. ê ~j ~~ ~ oJ ., ~::<. > 6 ~ II í'l~i '_ ~vJ J "~ I . . . Pristane/Phytane Pristaneln C17 Phytane/n C1S n C1a1n C19 nC17/n CZ9 CPI Marzi4 Normal Paraffins Isoprenoids Cycloparaffins Branched (iso-) Paraffins BIX aromatics Resolved unknowns ,.;¡ >< ~~ H,.;¡ 0 ~ 0. o ... >- 2.08 0.89 0.53 1.08 4.12 1.05 27.1 5.4 7.2 3.6 1,1 55.1 N U Z M U Z Client ID: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: US118449 05-252-A P A000049 OIL tJ e.. c.J'\ ~ \ d( JURASSIC 7412 FT FT G4050350.D o ~ Tr1 Trz Tr3 Tr4 Trs Tr7 Trs c1 Cz c3 c4 Cs ¡Thompson, K.F.M.,1983.GCA:V.47, p.303. "Mango, F.D.,1994.GCA: V.58, p.895. JHalpem,H.I.,1995,AAPG Bull.: V.79, p.80!. 4Marzi,1993,OrgG;20,1301. u z '" u z 0.. "V) 0.. '" 0.. 0.. uœmJr}i'11 ~ A. BZJn Cs B. TOLIn C7 C. (nC6+n C7)/(CH+MCH) I. Isoheptane Value F. n C7/MCH U. CH/MCP R. n C7/2MH S. n Csl22DMB H. Heptane Value MCHlnC7 mpXYL/n Cs '" ~ I"- U Z U Z U 0 Z N '" U Z lu N N U N Z U N Z U N Z 0.. U N Z U Z 0,07 0.28 0.90 0.74 0.68 0.67 3.14 100.53 20.13 1.47 0.33 - P1 Pz P3 5N1 Nz 6N1 K1 Kz 5N1/6N1 P3/Nz In(24DMP/23DMP) ! 20.00 15.21 4.48 12.63 12.69 34.99 0.92 0.55 0.36 0.35 -1.08 2.86 10.30 4.55 3.28 7.83 2.68 3.45 0.04 0.57 0.19 0.03 0.16 Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS TEMPTATION 1 7412 - FT ¡.1.· -. '. ,I'..~m..hu .- " . .... fl. "-:\'.'ï11' .--: - ''-2· ,---" ..~. ~~.:h' . . ..... ~.Ju,.¿1,.. ,,~- IC4 NC4 IC5 NC5 220MB CP 230MB 2MP 3MP NC6 220MP MCP 240MP 223TMB BZ 330MP CH 2MH 230MP 110MCP 3MH 1C3DMCP 1 T3DMCP 3EP 1 T2DMCP NC7 ISTD MCH 113TMCP ECP 124TMCP 123TMCP TOL NC8 IP9 MXYL PXYL OXYL NC9 IP10 NC10 IP11 NC11 NC12 IP13 IP14 NC13 IP15 NC14 IP16 NC15 Client ID: Project #: Lab ID: File Name: US118449 05-252-A P A000049 G4050350.D Iso-alkane C4 Normal.AlkaneG4 Iso-alkane C5 Normal AlkaneC5 2,2-Dimethylbutane Cyclopentane 2,3-Dimethylbutane 2-Methylpentane 3-Methylpentane Normal Alkane C6 2,2-Dimethylpentane Methylcyclopentape 2,4-D i methyl pentane 2,2,3-Trimethylbutane Benzene 3,3-Dimethylpentane Cyclohexane 2-Methylhexane 2,3-Dimethylpentane 1,1-Dimethylcyclopentane 3-Methylhexane 1-cis-.3;.DimethylcY¢lopëntanë 1-trans-3-Dimethylcyclopentane 3-Ethylpentane 1-trans-2-Dimethylcyclopentane NormalAlkaneC7 Internal Standard Methylcyclohexéme 1,1,3,-Trimethylcyclopentane EthylcyclQpentane 1 ,2,4- Trimethylcyclopentane 1,2,3-Trimethyl¢yèlopéhtãl1e Toluene Normal Alkane C8 Isoprenoid C9 m-Xylene p-Xylene o-Xylene Normal Alkane C9 IsoprenoidC10 Normal Alkane C10 Isoprenoid C 11 Normal Alkane C11 Normal AlkaneC12 Isoprenoid C13 Isoprenoid C14 Normal Alkane C13 IsoprenpidC15 Normal Alkane C14 IsoprenòidC16 Normal Alkane C 15 3.769 4.326 4.570 5.029 9781 28948 54915 63981 927 8570 24996 42967 47667 596 0.50 1:47 2.79 3.25 0.05 Œ64 0.28 1.02 2.98 5.12 5.68 0.07 7.051 7.107 7.251 7.407 7.883 8.110 8.225 .8.633 8.681 5.542 5545 1105 8'7606 5170 457 6121 834 59121 38498 15263 3547 694 46154 2483 184 2948 396 28146 18144 7460 5190. 24427 15227 14101 3636 25963 52293 29038 70564 8620 7232 8802 8.985 2.91 53510 9.336 9.402 9.456 10.083 10.305 JO.948 11.116 11.997 12.371' 12.688 15.427 17.307 18.521 18.583 19.790 21.245 23.230 26.882 28;180 32.175 37.126 37.863 40.640 41.766 45.222 46.125 31434 4306 59071 121022 68145 20266 21755 0.06 4.45 0.26 Œ02 0.31 0.04 3.00 1.96 0.78 0.60 2.72 1.60 0.22 3.00 6.15 3.46 9:04- 1.03 0.88 1.11 0.08 5.50 0.30 0:02 0.35 0.05 3.35 2.16 0.89 1.68 0.43 3.09 6:23 3.46 8.41 1.03 1.05 1.39 1.56 5.54 1.46 1:63 0.51 1.13 5.32 33647 34207 37643 11366 30782 139655 30528 130432 33967 134986 119338 36504 24093 118227 34290 110626 50.236 113830 13087 46455 12214 13652 4289 9459 44618 9935 41568 10605 41729 36652 10027 7309 35729 10386 32570 11842 30156 1.71 7.47 1.74 1,91 0.58 1.56 7.09 1.55 6.62 6.85 6.06 1.85 1.22 6.00 1.74 5.62 2;69 5.78 4.95 1.26 4.97 4.37 1.20 0.87 4.26 1.24 3.88 1.41 3.59 Company: CONOCOPHILLlPS Client ID: US118449 Well Name: TEMPTATION 1 Project #: 05-252-A Depth: 7412 - FT Lab ID: P AOOOO49 Sampling Point: File Name: G4050350.D ; ,. 11!t! !~~ IL~~~" ,- NC16 Normal Alkane C16 54.122 96967 27730 4.92 3.30 IP18 Isoprenoid C18 56.063 53459 10960 2.71 1.31 NC17 Normal Alkane C17 57.807 90888 25142 4.62 3.00 IP19 IsoprenoidC19 (Pristane) 58.173 81197 15188 4.12 1.81 PHEN Phenanthrene 59.066 3671 684 0.19 0.08 NC18 Normal Alkane C18 61.306 73115 20751 3.71 2.47 IP20 Isoprenoid C20 (Phytane) 61.769 38998 6942 1.98 0.83 NC19 Normal Alkane C19 64.641 67618 18618 3.43 2.22 NC20 Normal Alkane C20 67.822 62447 17004 3.17 2.03 NC21 Normal Alkane C21 70.867 53509 14465 2.72 1.72 C25HBI Highly Branch Isoprenoid C25 71.113 3698 896 0.19 0.11 NC22 Normal Alkane C22 73.775 49776 13234 2.53 1.58 NC23 Normal Alkane C23 76.563 47856 12578 2.43 1.50 NC24 Normal Alkane C24 79.245 41402 11172 2.10 1.33 NC25 Normal Alkane C25 81.822 38880 10362 1.97 1.24 NC26 Normal Alkane C26 84.298 34442 8696 1.75 1.04 NC27 Normal Alkane C27 86.687 28590 7460 1.45 0.89 NC28 Normal Alkane C28 88.990 21893 5320 1.11 0.63 NC29 Normal Alkane C29 91 .220 22052 4937 1.12 0.59 NC30 Normal Alkane C30 93.368 16478 3715 0.84 0.44 NC31 Normal Alkane C31 95.449 13293 3016 0.68 0.36 NC32 Normal Alkane C32 97.464 9547 2078 0.49 0.25 NC33 Normal Alkane C33 99.423 10507 1902 0.53 0.23 NC34 Normal Alkane C34 101.320 6960 1361 0.35 0.16 NC35 Normal Alkane C35 103.237 6529 1082 0.33 0.13 NC36 Normal Alkane C36 105.350 3383 570 0.17 0.07 NC37 Normal Alkane C37 107.746 2354 356 0.12 0.04 NC38 Normal Alkane C38 110.492 2041 257 0.10 0.03 NC39 Normal Alkane C39 113.642 1768 172 0.09 0.02 NC40 Normal Alkane C40 117.329 833 93 0.04 0.01 NC41 Normal Alkane C41 BASELINE CGSI WHOLE OIL·GC ..:.'lI'~.¡;'~~j'l(~;:"~1íï~..iïî:i;;¡i'.~~j~'.~X~;íír:;:~~~'*~¡;¡~~F;!!Ií·ji~ii~~;;~r;;;~F:~·····'í!í¡~,;'.¡¡:~;~Øf ·:JF·.i':.¡1J1N··'··'.~j·j~···'il"'· .jK Client ID: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: US120653 05-252-A CP018944 OIL \< v...p o...{' \A \.i. CRETACEOUS 6877.5 FT FT CONOCOPHILLlPS UNITED STATES NORTH SLOPE Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: FIORD FIORD 5 70.4433 -150.888 Whole Oil GC Trace u z J) ~ """> ~ '" :I: U U Z ;:¡; r- U Z "" u ",,;:¡; ~ oo U Z :I: U 0"\ U Z o ... ... u u Z Z N '-' ... '" ~ ~ ~ ¡j .,. . (g · ~ ~ ~ ~ u ~ x ,. "" Z U ¡ ~~ t-l LO \D ~ Z 0. _ ~ C1 ~ 1"""'4 "V') .............. co ø.. J1..ì,~h~kJlJl~JlL lmr::fU=:f~'~·:M1~~~~:_U c~ Pristane/Phytane Pristaneln C17 Phytaneln 018 n C1s1n C19 nC17ln C29 OPI Marzi4 Normal Paraffins Isoprenoids Oycloparaffins Branched (iso-) Paraffins BTX aromatics Resolved unknowns 1:87 0.77 0.50 1.07 4.36 1.03 27.6 4.5 8.1 5.7 1.9 51.7 G4050347.D 0 N ... N U N '" Z U N N Z U U N Z Z U Z r- oo 0"\ 0 '" '" '" ~ u u u Z Z Z Tr2 9.82 54.84 S. n C¡¡I22DMB H. hleptal1eVálµe MCH/nC7 ITIPX~Cl.biqà 1.49 C1 0.07 03 0.22 05 0.13 ¡Thompson, K.F.M.,1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.1.,1995,AAPG Bull.: V.79, p.80!. 4Marzi,1993,OrgG;20,1301. Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS FIORD 5 6877.5 - FT Client ID: Project #: LablD: File Name: US120653 05-252-Ä CP018944 G4050347.D IC4 Iso-alkane C4 3.764 45948 41846 2.27 4.76 NC4 Normal AlkaneC4 3.881 142565 127092 7.03 14.46 IC5 Iso-alkane C5 4.320 117930 95916 5.81 10.91 NC5 Normal Alkane C5 4.562 153635 118952 7.57 13.53 22DM B 2,2-Dimethylbutane 5.020 2606 1731 0.13 0.20 CP Cyclopentane 5.496 21236 13881 1.05 1.58 23DMB 2,3-Dimethylbutane 5.532 9429 6237 0.47 0.71 2MP 2-Methylpentane 5.617 79441 51727 3.92 5.88 3MP 3-Methylpentane 5.922 53514 33444 2.64 3.80 NC6 Normal Alkane C6 6.348 142908 84632 7.05 9.63 22DMP 2,2-Dimethylpentane 7.038 2098 1266 0.10 0.14 MCP Methylcyclopentane 7.095 101741 55239 5.02 6.28 24DMP 2,4-Dimethylpentane 7.238 6573 3393 0.32 0.39 223TMB 2,2,3- Trimethylbutane 7.395 665 295 0.03 0.03 BZ Benzene 7.869 14612 7220 0.72 0.82 33DMP 3,3-Dimethylpentane 8.097 1465 707 0.07 0.08 CH Cyclohexane 8.213 87465 42948 4.31 4.89 2MH 2-Methylhexane 8.620 45968 21816 2.27 2.48 23DMP 2,3-Dimethylpentane 8.667 15847 8016 0.78 0.91 11 DMCP 1,1-Dimethylcyclopentane 8.754 14363 6639 0.71 0.76 3MH 3-Methylhexane 8.972 57026 26485 2.81 3.01 1 C3DMCP 1-cis-3-Dimethylcyclopentane 9.205 32286 14920 1.59 1.70 1 T3DMCP 1-trans-3-Dimethylcyclopentane 9.322 29878 13750 1.47 1.56 3EP 3-Ethylpentane 9.388 3934 3346 0.19 0.38 1 T2DMCP 1-trans-2-Dimethylcyclopentane 9.441 53744 24034 2.65 2.73 NC7 Normal Alkane C7 10.071 141102 61357 6.96 6.98 ISTD Internal Standard 10.291 69979 30333 3.45 3.45 MCH Methylcyclohexane 10.937 209582 84132 10.33 9.57 113TMCP 1,1,3,-Trimethylcyclopentane 11.103 20485 8127 1.01 0.92 ECP Ethylcyclopentane 11.520 15196 6410 0.75 0.73 124TMCP 1,2,4- Trimethylcyclopentane 11.984 19214 7939 0.95 0.90 123TMCP 1,2,3-Trimethylcyclopentane 12.363 22770 9183 1.12 1.04 TOL Toluene 12.677 59063 23666 2.91 2.69 NC8 Normal Alkane C8 15.415 147553 47142 7.27 5.36 IP9 Isoprenoid C9 17.296 31651 11427 1.56 1.30 MXYL m-Xylene 18.514 55330 20004 2.73 2.28 PXYL p-Xylene 18.574 18024 6974 0.89 0.79 OXYL o-Xylene 19.782 37070 11756 1.83 1.34 NC9 Normal Alkane C9 21 .235 130530 42817 6.44 4.87 IP10 Isoprenoid G10 23.221 26792 8512 1.32 0.97 NC10 Normal Alkane C1 0 26.874 120152 38503 5.92 4.38 IP11 IsoprenoidC11 28.172 28758 9094 1.42 1.03 NC11 Normal Alkane C11 32.1 67 122374 37605 6.03 4.28 NC12 Normal Alkane C12 37.118 105480 32952 5.20 3.75 IP13 Isoprenoid C13 37.856 32041 8812 1.58 1.00 IP14 Isoprenoid C14 40.632 21325 6550 1.05 0.75 NC13 Normal Alkane C13 41.754 101972 30555 5.03 3.48 IP15 IsoprenoidC15 45.213 31451 9478 1.55 1.08 NC14 Normal Alkane C14 46.114 95194 28382 4.69 3.23 IP16 Isoprenoid C16 48.789 44906 9724 2.21 1.11 NC15 Normal Alkane C15 50.224 99654 25659 4.91 2.92 Company: Well Name: De pth: Sampling Point: CONOCOPHILlIPS FIORD 5 6877.5 - FT Client ID: Project #: Lab ID: File Name: US120653 05-252-A CP018944 G4050347.D .:~"~~".H.. .M' r -" . r .r '''' -- ~ . :., ~.-.-. 3_~ ~ IJ .= i NC16 Normal Alkane C16 IP18 IsoprenoidC18 NC17 Normal Alkane C17 IP19 Isoprenoid C19(Pristane) PH EN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenoid C20 (Phytane) NC 19 Normal AlkaneC19 NC20 Normal Alkane C20 NC21 Normal AlkánèC21 C25HBI Highly Branch Isoprenoid C25 NC22 Normal Alkå/"leC22 NC23 Normal Alkane C23 NC24 Normal Alkane<C24 NC25 Normal Alkane C25 NC26 Normal AlkaneC26 NC27 Normal Alkane C27 NC28 Normal AlkaneC28 NC29 Normal Alkane C29 NC30 Normal Alkane<C30 NC31 Normal Alkane C31 NC32 Normal Alkanet32 NC33 Normal Alkane C33 NC34 Normal Alkane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal AlkaneC38 NC39 Normal Alkane C39 NC40 NormalAlkaneC40 NC41 Normal Alkane C41 54.113 79601 22895 3.92 2.60 56:060 0.95 57.797 73405 20571 3.62 2.34 1033.6 1.18 59.056 3168 590 0.16 0.07 61.761 30090 4853 1.48 0.55 67.819 52312 13778 2.58 1.57 11924 1.36 71.115 3490 768 0.17 0.09 73.771 40340 10828 1.99 1.23 76.560 37862 10018 1.87 1.14 1:00 81 .817 28658 7449 1.41 0.85 86.683 21128 5330 1.04 0.61 91 .214 16834 3698 0.83 0.42 95.449 10368 2204 0.51 0.25 7663 1618 0.38 0.18 99.421 8256 1558 0.41 0.18 101.313 1075 0.26 0.12 103.237 5097 864 0.25 0.10 105.i3.56 473 107.743 2136 331 0.11 0.04 113.635 1493 153 0.07 0.02 ( SATURATE GC-MS ANAL YSIS /~ I í, IAPETUS-2 .. .CliehfO:h .... Pi"()j~c;t #: 1..ªb.JPf .. ... ...... $ampl~'TypØ: .. . ·SAmpÎingF>øi.,t: For-rotation: . .. .. GøQløSi¢As~; "o,».[)~pth: ... .. BottomPøPth; O$1åêzo'7 . .. ()?..~$2"A CP278~1a ···..··.····.·.$WC COrnpany: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHI 1..1..1 p$ UNITED STATES NORTH SLOPE . . - . . - . .. .JURRASSICLAtE .. ....... .-- ... .. ." ... ·S$61 m/z 191: Tri- and Pentacyclics M2050506.D .-:;", :..¡ '.......,.,-:w¿~ ~,. r¡[ftLtf ~~~.:1.':.t--..l _ ~ÜT-': 1\::¡:....fln;.»...¡F~ I ... II I. -..J-. 'J_~1lL.JlL~ m/z 217: Steranes M2050506.D ~,/"-v.w' ^ V\,~IJJ\i,~v ~ ~ m/z 218: bb Steranes M2050506.D ~~W'''I ~I'~ ~ "'- J~ 1 Definition and utility of the ratios can be found on our website www.BaselineDGSl.com ..,,~ 2 A=Source Age; D=Depositional environment; M= Maturity; B=Possible Biodegradation ~hermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8861 - Client ID: Project #: Lab ID: File Name: US 136207 05-252-A CP278518 M2050506.D ~;¡ .~'~~: iìE-rn I III ~ '/Ii ~ , ~·\t_,~!,'¿H ~ .:":~ î; ~ , ! £. í~.: ;~~ m~~~: ; ;. ~. r~~-l: i t .. ,:;."'! L--= . '",,-, '",-, U$136207 Q§..2~2..A CP278518 M2050506.D CÖNÖCÖÞHIL..I...IPS . IAPETUS..2 8861 - Company: Well Name: Depth: Sampling Point: '~ Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8861 - Client ID: Project #: Lab ID: File Name: US136207 05-252-A CP278518 M2050506.D ~.;¡ . ','''''!i"'.... -~1~.._.~.'.¡.'_::' r' ;::;{ ~ ~ ~ ~'" ~ :.;"~ ~ ïi,";:;~.--~; I" T .fIti,J.\ëW: ...llI't.: -.-Iii - :,' I', ;¡¡;; 5 .....~: -, -- , J; .,: """1 ~"IK""- :~~~~ .i'~ :.. ..~ lut i#~_~' ¿ ~ ,~~ .... _~.IJJ. .w. I Ef. ; , i, . 1 _: .~ ~~ 21 0 0 0_ 1 8 0 0 0_ 15000_ 1 2 0 0 0_ Sampl e: Ion Mass 191 9000_ 6 0 0 0_ 30 0 0_ File: M2050506. D\data. ms Date & Time: 28 ApI: 05 3: 18 pm US136207 50'.0 60'.0 70'.0 Retention Time (min) ..lvJ4 J! cJlIA"l.J.,,~JJAv-klJ~ 80'.0 90'.0 Sampl e: US136207 Ion Mass 191 20000_ 10000_ ~~L~Lo~L , 6 9'. 0 72'. 0 75'. 0 78'. 0 81'. 0 84'.0 87'.0 Ion Mass 177 3000_ 2000 1000 vMA.. ~ 69.0 72'.0 75'.0 78'.0 81'.0 84'. 0 87'.0 Ion Mass 205 2000_ 1000. 69'.0 72'.0 75'.0 78'.0 81'.0 84'.0 87'.0 4000_ Ion Mass 163 3000. 2000_ 1000~Uu~ ~~"w-vL,--~ 6 9'.0 72'.0 75'.0 78'.0 81'.0 84'.0 87'.0 Retention Time (min) File: M20S0S06. D\data. ms Date & Time: 28 Apr 05 3: 18 pm Sarnpl e: US136207 4000. Ion Mass 217 3000. 2000. 1000~~JJ1^\J\ J~j MJiìJJv,~ 66'.0 6a'.0 70'.0 72'.0 74'.0 76'.0 Ion Mass 21a 3000. 2000. 1000. ~ J ~~, JlrlA/ljI ~ ~~ 66'.0 6 a'. 0 70'.0 72'.0 74'.0 76'.0 2000. Ion Mass 259 1000. ~~vJJJ~I~ J 66'.0 6 a'. 0 70'.0 72'.0 74'.0 76'.0 Ion Mass 231 aoo. 600. 200. ~,\)U ~~··MíNM lMJ¡ lJ~ 400. 66'.0 6a'.0 70'.0 72',0 74'.0 76',0 Retention Time (min) File: M2050506. D\data. ms Date & Time: 28 Apr 05 3: 18 pm Sample: US136207 Ion Mass 217 1200. 900_ 600_ 300 ~JJ JJ~\JfivW,~~J ~ 45'.0 48',0 51'.0 54'.0 57'.0 Ion Mass 218 1500. 1200 900 600. .fvv~,LLw~~ 300. 45'.0 48'.0 51'.0 54'.0 57'.0 Retention Time (min) File: M20SOS06. D\data. ms Date & Time: 28 Apr 05 3: 18 pm Sampl e US136207 5000. Ion Mass 123 4000. 3000 2000_ 1000. e L ( ~ ~ 16'.0 IS'. 0 Ion Mass 193 5000_ 4000_ 3000 2000_ 1000. 16'.0 IS'. 0 Flle: M20S0S06. D\data. ms Date & Time: 28 Apr 05 3: 18 pm (V) 00 (V) N ~ ('\ ~ '<I' r- ,'<I' (V)r- ('\ . ¡:¡:; ~ 0 00 a r-i , 00 a 0'1 ('\ '<I'r-i 0"1 ('\ 0:;; :;: ~ ;:;:;: :;: NO 0 ;'; ",,; .; /~_Ml~ N 20.0 22'.0 24',0 2 ('\ ¡:¡:; 00 <5" a œt' 0'1 r- ,.Q-I ~ " r- ~a..~~.~ M '<I' 0'1 ~ ,....; N' 0'1 .... ('\ ('\ 00 ~ --" ^~~ 20'.0 - ~ 22',0 R 24',0 etenti on Time (min) 26'.0 r- '<I' (V) ~ ('\ r- a ~ ~ ('\ 2S L!1 r-L!1 rlr- L!1 . . r- r-('\ ('\ o 26'.0 ¡:¡:; o o ~ o :J:: L!1 ('\ (V) ~ ('\ r- a ~ ~ ('\ 28,0 Fil e: Date M20 5050~ TimE' o \da ta )r 05 ms : 18 pm 69.0 72'. 0 75'.0 78', 0 Retention Time min) 81 o 84 o 87 o 1 000_ ~ ~ r-\0 \.0 ~ rl r- oo \.0 \.0 ~ \.0 '" \.0 rl 6"" .r- ",,0 \.0 . o r- (J) "" L{) Orl r-oo ro "" r---O \.0 8r- r- _ m. o::::r . rl rl \.0 '2 ,= ~r- ~; ~ it :: ~ ~ ILWf\ c-r-::: r- ~ (J) \.Or- r-o N r- r-- N r- L{) OON r-(Y) ro ro r- 00 "" r-I ~ ~ CJ L{) 00 . o ro r-I \.0 a 00 . (Y) N L{) co . N co (J) co "" (Y) 00 \.0 L{) r- lfÍ r- ~ r-i L{) \.0 r- 2000_ 3000_ Sampl e Ion Mass 177 US136207 \.0 rl r- <:1' r-¡-.. \.0 ro <:1' r- Sampl e US136207 Ion Mass 191 1 8 0 0_ 1500_ 1 2 0 0_ 900_ 0 6DD~ ~ E-< 0\ @ E-< rot'- 0 C"1 C"10 N N .-I 300_ t'-.-I <.D C"1 0 o.Ö\.Õ Uì r..: ex> """" \.Ò <:I' "" "" ~ rvJv -~ 44'. 0 48'.0 File: M2050506. D\data. 28 ADr 05 52'.0 Retention Time min) 56 o 60 o rl N p:; E-< N N p:; E-< C"1 N p:; E-< r-- m r-- <.D Uì "" N a:: E-< p::¡ ..c <OJ rQ:: ~ E- "" N E-< Iï1 E-< p::¡ Uì "" \D r-- ~ o.Ö lO E-< r-- ~ 0\ r-- N .$J N "R) JJJk' 64'.0 Sampl e US136207 Ion Mass 191 21 000_ 1 8000_ 15000_ 1 2 0 0 0_ 9000_ 6 000_ C!) 30 0 0_ E-< :E E-< ~ CQ ~ Œ\I Œ\ CQ 0 0000 N Œ\ U) ~~ çr: N r-1 E-< çr: E-< E-< E-< r- '"^- ~ ~ 69'.0 72.0 File: M20S0 a. Date & Time 05 o (') ::r:: C!) .-f (") Œ\ ::r:: N ::r:: ¡y; .-f (') C!) ::r:: N (") ::r:: C!) (") C!) ¡y; (") E-< N ::r:: ~ g ¡y; C!) U (") "" (") (") ::r:: ::r:: o ¡y; r- (") "" g õ!; :E I.D"" g ~ r- u)N ~ ~ 1 ~ ;$ Œ\ r- r-: ~ N Œ\~~ ; 0 0 ~ ~ "". ~ ~. I.D 00 r-..,..I.D a M (") U) ~~~Ú~-,A I ~ ~U~ 75'.0 78'.0 81. 0 84'.0 Retention Time (minI 87 C!) U) (") ::r:: o US136207 217 ~ple Ion Mass 1200~ rl C'\ CfJ 1 0 0 0_ II) f'1 o '<!' II) C1'> r- <:1' rl II) 800_ N N rl ["- II) '<!' CX) CX) <.0 II) 0'\ N rl N II) 600_ r- a:J a:J C'\ II) N II) N r- II) o <X> <X> '<!' II) 0) CX) f'1 N II) C1'> N <X> o If) o o r- 0) tf) r- <.0 N 01 II) N <:1' 0'1 co II) 59.0 C'\ (Y) C> ro If) ~ 58'.0 v o 57 0'1 f'1 00'1 .<.0 wrl If) . <.0 If) 56'.0 '<!' tf) ""' trÍ If) min) CV1 C> <:1' <:1' If) 55'.0 Retention Time \ o ~ 54 ex:> f'1 ro 0) <.0 "'" . . CV1 CV1 If) tf) 0'\ 0'1 0'1 rl If) File: M2050506. D\data. Date [. Time: 28 Aor OS 53.0 52'.0 o 51 3: 1 B rl o N C> tf) 400_ 2 8 0 0_ 2 4 00_ 2000_ 1 600_ 1 200_ Sampl e: US136207 Ion Mass 217 800_ 400_ ~ Lf1 ~ ~ N rl Lf1 '" C) ": ~o ~ ~ 60'. 2 60'. 9 Date & Time File: M20S0S0< ~\data. ms r 0 5 3: 18 Dm H o :r: () 0 0 0 CO ffi 0 f') r- .do CO r- <:t' r- r- '" 1.0 <:t' rl r- 1.0 rl ,....; '" 61'.6 62',3 63'. 0 63',7 64'.4 Retention Time (min) File: M2050506. D\data. ms Date & Time: 28 Apr 05 1 0 0 0_ I.f) '" o I.f) 1..0 66 '" M N r- 1..0 o 1..0 '<1' o r- 1..0 2 0 0 0_ 3000_ C/) r- N ~ H C¡ o '" I.f) \D W 68 1..0 I.f) '" r- 1..0 '<1' NO 1.f)00 1..0 . .r- ¡--I..O 1..0 o M o 00 "" . ,...fX) r--'O 00 1..0 '" --j ",f) ~ I ~ ~: N (V) '" ~ i.D J~~ I 70 '" "" '" '" 1..0 r- ~ / m o Retention Time N ~ ,.f> M r- .-i ~~ N ^ ~J~; ON, 0) 'M , M o r- ~ I 0) "'0) 1..000 r-, . M Mr- r- 72',0 ( min) rlO rl!- ~ C'N r-r- fü4 ~ ro N U ( I.D r- MI.D :xJ . "" ('" 'r- N) V C/) '" N {) I 74 o M ro r- "" '<1' l1) '" "" r- 76 o I.D r- N I.D r- "" M If) I.D r- I.D ro (V) '" I.D M "" ro '" 1..0 '" ~ '" r- If) N , {) 0 r- "" '" o N r- ~ I!I I!I '" N {) C/) I!I I!I 0'> N {) ~ '" N {) 1..0 "" I,() '" I,() 4 0 0 0_ l \ Sarnpl e Ion Mass US136207 217 Fil e )r 05 1 0 ° 0_ 66.0 l{) <:r r- tD 'P o m l{) \0 \0 68 H l{) H co"" \ON \0 (Y) \O~ \00 N \0 CO' r- . \0 N r- l{)\O \0 r-- \0 o 70 l \0 co (Y) '<!' . (Y) m N\O ffi \0 o "" ~ rl o r-- m (Y) (Y) o c- ~ ~ ~2~0 Retention Time (min) r4 r4 (Y) ~ (Y) <:r <:r r- N r-- "" m (Y) M r- 74 ~ r4 l{) \0 r-- o N r- \0 <:r r- ~ ~ @ U 76 ° 2000_ U) p:¡ ~ ex) N U p-:; p:¡ ~ ex) N U u¡ P:¡ ~ r- N U p-:; P:¡ ~ mu¡ NP:¡ u~ m N U Sample ~S136207 Ion Ma s s 21 8 3000 ¡:y; P:¡ P:¡ ,:Ç r- N U File: M20s0s06. D\data. ms Date & Time: 28 Apr 05 3 18 66'.0 72'.0 Retention Time (minI 300_\1 LO 0'\ o u-) ~ 600_ 0'\ CV) r- N, 0'\ If't- ,-I ~ N . r- 1..0' \.D <:/,r- r- 01..0 LO ,-I 1..0 1..0 68 o 1..0 <:/' CV) N . r-oo ,-11..0 ~ g¡ 00 N Q 0'\ o 0'1 . ..-I 00 NN \.D CV)r- '<:/' 0'1, 1..00'1 \D \ 70'.0 ,-I <:/' 00 0) \.D \r- r- LOoo 0,-1 åò \.0 '\} ~ N CV)..-I ,-I 0<:1' 0'\ ,..-I r- \.0 ..-I ' ,,-I r-..-I 0'1 ,-I ,-I r- CV) r- ' \ ; ~ r- oo <:I' 74'. 0 N CV) CV) N r- ..-I 1..0 m N r- 1..0 r-,-I 0<:1' CV) . .CV) CV)r- r- N \.0 r- M<:I' r-rl 0'\ M r- N p., rl!:-o p.,o !:-oCV) 00 CV1 o 76'. 0 <:/' rl LO 1..0 r- 900_ ÇQ UJ 00 N ~Q UJ 00 N Q ~ 00 N Q J:; 0'1 N Q 1 2 0 0_ 1 50 0_ J:; r- N Q UJ 0'1 N Q 1 8 0 0_ 21 0 0_ UJ r- N Q Sampl e Ion Mass 259 US136207 .Clie..nt1b: PtQjøç~ tI,: tr'~TYpQ: · S~pl.ln.s..Þºtnt: Førmêlti91'1: ... .. Ø~()løSh~Â9~: ...... .. T,?pº~ptþ::::.: .·····T·· ...SøttøfuDèpth:...··< ... CQmpany: Country: 13éishi: lease: Block: Field: WeHNê1me: Latitude: longitude: CQNÖC(jPHI~LIPS . UNITED STArES NORTH SL.OPE: IAPETUS-2 m/z 191: Tri- and Pentacyclics M2050432.D .. I. l..l..JI ~.. ~llLAl~~ . ! In 'm/z 217: Steranes M2050432.D .~~ ~ >J1;.. \flU· f!\ V\ ~ I JM I J\.fI., V .~ ~ m/z 218: bb Steranes M2050432.D ~~ W,'"I ~~..~ ~~ L . .. US1åöŽ10> . O$..~5Z;.;A CP~7ß$21 ·MOT . --. - .... . ..- -.-. ..... -....- - .-. . . .... .. ... .- - ... . . . . - -. ... J;AR.I..Y CRI;ATACEOU$·. ß722.1 1 Definition and utility of the ratios can be found on our website www.BaselineDGSLcom ~ 2 A=Source Age; D=Depositional environment; M= Maturity; B=Possible Biodegradation 3Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8722.1 - Client ID: Project #: Lab ID: File Name: US136210 05-252-A CP278521 M2050432.D Em.·.! . :~~~." ~r-~'.,.", ·'c .r~11. ~~ ~ r ~ ~. m u "'., r. "-\,;;;: :._~..~ ,:~ "'" ,I "'h~m ~ ' 1 r jjt;f. .. œ..j,,~~:~E"·~' /r ~,dl: ___~u m J ~ _ _ ...~- .. ~ . alP u " !"t~,~\~; {i~.t!!I~ 7994 1967 '1m ~.,.,. -T .-. ~ .. ::.~:.:: !.. . "JL1i' .. ,-. "... ' " . .... " . .... , 100.0 100.0 '~. ~ CONOCOþHU"l..lPS IAPETU$-2 8722.1.- Company: WØU Name: Depth: Sampling Point: ~ Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8722.1 - Client ID: Project #: Lab I D: File Name: US136210 05-252-A CP278521 M2050432.D i; I!! ;,!: ;L",_v 1I.ï~ :'":::'1'" I ""'Ill"-,. "",'" -"Inm ~m n . ~ ... J;. - n" ,~ ' \,,,~ if -- ' l'i r-~:;- ~ . ~:¡. . .:iII:~ ..1,: ;.~;:: ~~m~::=L. 1I1~_"I'__{J{ _ n. ,_ .. ... . rE~l~'d~~m~~~ ~ '-Ie:- n ". ~, :_11«« ____ _~~ .......... t: '.~I! ~... ~J.- r f;"m~~*1~1~ ~~: ' j "~~:~~ ..~~¡~_I 21 0 0 0_ 1 800 0_ 1 50 0 0_ 12 0 0 0_ Sampl e: Ion Mass 191 90 0 0_ 6 0 0 0_ 3 0 0 0_ File: M20s0432. D\data. ms Date & Time: 8 Aer 05 11: 00 em US136210 50'.0 ~ 60'.0 70'.0 Retention Time (min) -JltW"Jl d~J~~~~JJAv~L..r~ 80'.0 90'.0 Sampl e: US136210 20000. Ion Mass 191 10000 L~J~L 69'.0 72'.0 75'.0 78'.0 81'.0 84'.0 87'. 0 Ion Mass 177 3000. 2000 1000. 'vf"\;.Iw ~ 69',0 72'.0 75'.0 78'. 0 81'.0 84'.0 87'.0 Ion Mass 205 2000. 1000 ~~l~ 69.0 72'.0 75'.0 78'.0 81'.0 84'.0 87'. 0 Ion Mass 163 3000. 2000 lOOO.~ '~~V~---J~ 69'. 0 72',0 75'.0 78'. 0 81',0 84'. 0 87'. 0 Retention Time (min) File: M2050432. D\data. ms Date & Time: 8 Apr 05 11:00 pm Sample: US136210 4000. Ion Mass 217 3000_ 2000_ 1000 I I t ~ vJVW vAJ', AAA ) ~! M J rvJv i ~ 66'.0 68'.0 70'.0 72'.0 74'.0 76'.0 Ion Mass 218 3000. 2000_ 1000_ ~ Jrvv'~JUI~~ 66'.0 68'.0 70'.0 72'.0 74'.0 76'.0 Ion Mass 259 2000_ 1000 ~~vV\~1vv 66'.0 68'.0 70'. 0 72'.0 74'.0 76'.0 Ion Mass 231 800_ 600_ 400. ~L ^ '^['iU \v~ W j~J \ ^ 200~ 1J\jVVlfiJ'^V" ~\ ~ 66'.0 68'.0 70'.0 72'.0 74'.0 76'.0 Retention Time (min) File: M2050432. D\data. ms Date & Time: 8 Apr 05 11:00 pm Ion Mass 217 Sample: US136210 1500. 1200_ 900 600_ 300 Ion Mass 21a 2000 1600_ 12C 0_ aoo. 400_ File: M20s002. D\data. ms Date & Time: 8 Apr 05 11: 00 pm 45'.0 ~LJJ -AV A~I~AJ~J ~l 4 a'. 0 57'.0 51'.0 54'.0 45'.0 4 a'. 0 51'.0 57'.0 54'.0 Retention Time (min) o .-I ('") 00 r-- .-I r-- ~.-I CX> CX> 0 o. Lf) ~ vN~~~0~\ 16'.0 Ion Mass 193 8000_ 6000. 4000_ 2000_ 16'.0 18. File: M2050432. D\data. ms Date & Time: Apr 05 11:00 pm 20 o 1000_ 18 20 2000. r-- ('") ro ~ .-I ~ r-- q< o N Sampl e US136210 Ion Mass 123 6000. 5000. 4000. 3000. q< ~ o o N 0'1 ('") ('") N q< N 0 r-- ('") N N N q< . Lf) ('") .-I N r-i q< N r-- '<t N r-- Lf) o Lt" . q< q< .-I (V" N . "- (Y) )~\- 22.0 24'.0 0'1 ('") N ('") N . q< N . N ('") N . q< q< 0 q< ro r-- ~ .-I . ~q<~ ~ NN NLlL1IL 22'. 0 24'. 0 Retention Time (min) 26 .-I CX> N ~ N.-I q< Lf) ~ N o 28 o 26 o 28 o .-I CX> N ~ N.-I <:' Lf) ~ N Lf) .-I r-- ~ N File: Date M20S04 "' Tímr fJ\data. ms ~r 05 11: 00 Dm 69.0 72'.0 75'.0 78'.0 Retention Time minI 81 o 84 o 87'.0 1 0 0 0_ ~ qx, '-0. r-- ~ '-0 '-0 N '-0 aJ '-0 aJ lf1 lf1 a) '-0 M M lf1 .(Y) 0(1\ r-..-r- '<t' . <-r:P ¡-- o 00 m lf1 M r- . '-0 (Y) . r- (Y) r- N ro 00 \.0 r- N r- N r- r- r- o lf1 . lf1 OO'<t' r-r- 00 r- o M M r- .lf1 o '<t' 00 . o 00 (Y) r- m 0 lf1 M '<t' 00 . N 00 N o m (Y) 00 00 '-0 \.0 lf1 r- r- N '<t' '-0 r- 2000_ o 00 r- '<t' r- 3000_ Sampl e Ion Mass 177 US136210 o If) \.0 '<t' r- "" N E-< r>1 E-< ¡¡:¡ ~ t'!):Q ~ E-< N0I p:'J:Y; H-< I.D (Y) I.D u) I.D 1,,0 <IJf) 0) CIZ> CX) "" M <D'\ ui <::r <::r M ~ 1,,0 CX) .~ ~ I.D ~.~ 60.0 64'.0 <::r N ~ E-< (Y) N ~ E-< 0) 0) If) <::r If) N N ~ E-< <::r CX) CX) If) o . rl N . If) N If) rl N ~ E-< o N ~ E-< m <::r 0) r-- <::r o 56 minI 52'.0 Retention Time o 48 Sarnpl e US136210 Ion Mass 191 3000_ 2 500_ 2 0 0 0_ 1 50 0_ 1 0 0 0_ 0) rl 500_ ~ E-< (Y) If) I.D ui "" ~ ~ 44'.0 FH e: M¿0504 \data. Date & Time: Apr 05 Sampl e US136210 Ion Mass 191 21 0 0 0_ 1 800 0_ 1 50 0 0_ 1 2 0 0 0_ 9000_ 6 0 0 0_ 300 0_ (f) E-< 2: E-< ~ g; aJ 111 .:r; CJ\ 111 rl ro ~N C) C) N (V) (V) M ~ ¡;sr~ p:; p:; r- E-< .E-< E-< E-< ~ L Jv 69'.0 72'.0 File: M20S043? ~\data. Date & Time: 05 : 00 CJ\ N ::r:: 75 (fJ E-< CJ\ N o 78'.0 Retention Time p:; (V) (V) ::r:: C) (V) ::r:: (fJ rl (V) ::r:: ~ rl (V) ::r:: min) (f) N (V) ::r:: p:; N (Y) ::r:: 81 o (fJ (V) (V) ::r:: (fJ <:r (V) ::r:: p:; <:r (fJ (V) ::r:: tr) (V) p:; ::r:: tr) tr) (Y) aJ ::r:: _~LJ 84'.0 87.0 ( US136210 217 Sarnpl e Mass Ion 1 600_ 1 400_ .--I N (fJ '<I' I.D .--I r- l!) I.D l!) a r- l!) I.D 0'\ r- I.D l!) \ l!) rl co <;' l!) rl r- 0'\ <"1 l!) <"1 N co N l!) <;' N <"1 N l!) <;' I.D a N l!) l!) r-t <;' r-t l!) l!) I.D r- a l!) 1 2 0 0_ 1 0 0 0_ 800_ 600_ I.D <"1 4 0 0_ r; a l!) 0'\ r- r-t m l!) (V) r-t I.D m l!) I.D I.D 0'\ r- l!) L~ <;' (V) 0'\ r-t l!) (V) a a rl l!) 200k ~ 59.0 58.0 o 57 o 56 min) 55'.0 Retention Time o 54 o 53 52.0 o 51 00 1 ms File: M20S0432. D\data. Date & Time: 8 Aor 05 Sampl e: US136210 Ion Mass 217 2 4 0 0_ H o ::r: u 2 0 0 0_ 1 6 0 0_ 1 200_ 800_ "'1' rl r- M Oì N 400_ o <J\ I.D "" I.D 60'.2 60'. 9 61'.6 62'.3 Retention Time (min) 63'.0 63'.7 64'. 4 File: M20504'- "'\data. ms Date & TimE 'r0511:00 M rl ]V File: M2050432. D\data. ms Date & Time: 8 Aor 05 : 00 Retention Time 72'.0 ( min) 1 000_ 2 0 0 0_ 3 0 0 0_ ( 4000_ CI) e- (\ ~ H Q Sampl e Ion Mass 66 \P '<1' co r- \P \P rl r-- (") . ""r-- l!1\£) r-- \P o US136210 217 rl co "" \P \P o rl rl r- 1..0 68 (") rl r- oo ~ \P . ff) \p ro rl 'Q (")(") \Prl rl(") \P (\ (\ N' o' ro .0"\ OJ O"\I.CI ~ ~ /' co l!1 l!1 0) \P o ro 0"\ N 0) \P (") l!1 r-- cr) \P 70 rl ~I rl rl to ø::¡ . r-- 0 (\ r-- U o ~ l!1 "" = rl cP r- . rl r-- ~ ~ co o r-- ( rl l!1 U) o' ~I~ ¡:: ~ (") (") (")co o . r--rl . r- rl r-- 74 ~ ø::¡ f'N co .. N f'N U N- \l~ _v'~ ¡:r; çQ m NCI) uçQ çQ , 0"\ N U co N c:> N r- g{ (\ u o ex; 0\ (\ U (") 0'\ -0 '<1' 76'.0 co co rl \P r-- File: M20504 Date &. Tim.. '\da ta 05 : 00 1 0 0 0_ 2 0 0 0_ 66 (V) o Lf1 1.0 1.0 \D C'" \D Lf1 \D \ o o rl rl I'- 1.0 1.0 1.0<:1' rlOO I'- , . I'- 1'-1.0 r\\ ~ 68 o <"1 \D o 00 1.0 00 \D 1.0'" (V) <:I'N N ..-I' , 0'> 00 (V) 0;1.0 \D <:I' 1.0 00 I ;~ \\ 70 \D tn o o I'- M .-1 tn N o I'- 0 '" <:I' o I'- o 72',0 Retention Time (minI \D 1.0 '" o I'- (V) <:I' <:I' rl (V) 1'-..-10 tnl'- tn, , rl rll'- ~ (J) p:¡ p:¡ ~ 00 N ¡:t; U p:¡ ~ 00 N U co I'- \D 0 . '" N C')::> I'- o. J!\ (V) N N ~ I'-N ~ ~ 00 N (V) (V) I'- 74 v~ o r- N <:I' W I'- tn 00 Lf1 <:I' I'- l() rl 1'-00 . 00 <:1'00 I'- <:I' I'- ¡:t; t:Q ~iØ 0t:Q (V)~ Uo f') U 76'.0 00 00 rl \D I'- (J) p:¡ ~ r- N U (J) p:¡ ¡Y;t:Q t:Q~ ~~ "'U N U Sample US136210 Ion Mass 218 3000_ ¡y; t:Q p:¡ ~ I'- N U file.: MZ<J50432. D\data. Date & Time.: B jl,pr \)5 IDS 11 \)\) pm 72'.0 Retention Time (minI ~ ro ('o,J oæ a:J C\ Q e>') 1M ~ C\ m ex: \.D a:J e>') \0 a:J \.D ~ If) ~g If). 1!. .. a:,::g c)M ~: \.D~ \~\.D~ , <.0 ' ~ . _VI 400_ \.D l- e>') tÓ \.D ~~ 66'.0 o \.DM (Y1M m . .1- \.D\.D \.D o (Y) e>')<.o ~ I- <.0\ 68', 0 70 o If) <1'(Y) 0\1f) '0 o. r-M I- 74 a:J C\ o N I- (Y) I- a:J N I- o 76.0 800_ ,:¡;(1) U)U) roro NN aa p:; ð) N a 1 20 0_ p:; l- N a 1 6 0 0_ 2000_ Sample US136210 Ion Mass 259 24 0 0_ U) l- N a U) ð) N Q I.." I~., ~BASELINE . ~. ~ ~ . GC-MSMS ANAL YSIS CGS -~ ~ I CLIENT ID: US136210 FRACTION SATURATE BASELINE ID: CP278521 DATAFILE: MS050174.D RESULTS SATURATE GCMSMS ANALYSIS SATURATE GCMSMS 111 ~ n ., n ..'( H ..' J1L'J~::::'""n" ' ."" . ¡ Lm.~ BASELINE DGSI . ~:''\illt~':~~~.&t1ifIi..jf..i!i'..~;,t::~..~¡~~IiIc,,~~If~'' BASELINE CGSI SATURATE GCMSMS ï'~:;1J'~..~FIiI[~~h'if~~ÃYl~itàl.~~,;,.m:'B7·~·~.::.1::',;,lQt[]J~'1tW~JI~1.]1nJŒI:.:~,.flRmrr;t:,J]';K1l1....~. ì¡j,n~)]FjNID:lli.,I::;::::]¡J:[~\I¡~.[I[ Company: CONOCOPHILLlPS Project #: 05-252-A Country: UNITED STATES Lab ID: CP278521 Basin: NORTH SLOPE Client ID: US136210 Lease: Sample Type: MDT Block: Sampling Point: Field: Formation: Well Name: IAPETUS-2 Geologic Age: Latitude: Top Depth: Longitude: Bottom Depth: .__-_.---~l\,N µ~^~,~I\ \~, ~~ 'YÒ"n response factored areas. Definition and utility òf the' ratios can be found ~~-;åur website www.Baselin^eÓG~Ú.com 2A=Source Age; D=Depositional environment; M= Maturity 3Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached 358:>217: C26 Steranes MS050174.D ___-""'~ "¡.¡.l,, W . ~~JJcI 414->217: C30 Steranes "'_'__~_~~ \eM Jw:Â~L L",-- 414':>23'1: C30 Methylsteranes EARLY CREA T ACEOUS 8722.1 %27Stéranes %28 Steranes . %29 Steranes %27 Diasteranes %28 Diasteranes : %29 Diasteranes 32.0 D 27.7 D 40.2 D 36.6 D 26.8 D 36.6 D 0.12 D 0.04 A 0.63 M 0.66 M 0.61 M 0.59 M 0.48 M 0.46 M 0.54 M 0.37 M 1.35 C30 Sterane Index ; C30 iso/n-propyl sterane .Index ¡ 'C27 aßß/(aaa+o.ßß) C28 aßß/(aaa+aßß) ;C29 aßß/(aaa+aßß) .C30 aßß/(aaa+aßß) C27 S/(S+R) :C28 S/(S+R) !C29 S/(S+R) C30 S/(S+R) , Diasteranes/Steranes 24-Nordiacholestane ratio (NOR) ! 24-Norchole~tane ratio (NCR) ; i 21-Norcholestane ratio A A DIM 0.17 0.30 0.11 , Dinosterane ratio 4-Methylsterane ratio 0.35 0.10 A A Oleanane Index (%) ,DesA Oleanane<lndex(%) ·Gammacerane Index (%) ;Bicadinanelndex (%) 'DiaHopane Index (%) 'TPP A A D AID D D 0.3 4.9 0.06 Company: Well Name: Top Depth: Bottom Depth: Acquisition Parameters: CONOCOPHILLlPS IAPETUS-2 8722.1 Client ID: Lab ID: Fraction: File Name: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR=3E-7MBAR CE=25 US136210 CP278521 SATURATE MSOS0174.D 330.3->217.2: Internal Standard ISTD 5ß-Cholane 52.477 1718134 100.0 100.0 358.3->217.2: C26 Desmethylsteranes D26N24ba8 13ß, 17 a,24-nordiacholestane 20S 53.540 56911 3.3 3.3 D26N24baR 13ß, 17 a,24-nordiacholestane 20R 54.630 42172 2.5 2.5 D26N27baS 13ß, 17a,27-nordiacholestane 208 55.454 274279 16.0 16.0 D26N24abS 13a, 17ß,24-nordiacholestane 20S 55.667 18918 1.1 1.1 D26N24abR 13a, 17ß,24-nordiacholestane 20R 56.332 29115 1.7 1.7 D26N27baR 13ß, 17 a,27-nordiacholestane 20R 56.544 224981 13.1 13.1 D26N27abS 13a, 17ß,27 -nordiacholestane 208 57.581 81279 4.7 4.7 D26N27abR 13a, 17ß,27-nordiacholestane 20R 58.139 102410 6.0 6.0 S26N24aaaS 5a, 14a, 17a,24-norcholestane 20S 59.229 23474 1.4 1.4 S26N24abbR 5a, 14ß, 17ß,24-norcholestane 20R 59.442 47857 2.8 2.8 S26N24abb8 5a, 14ß, 17ß,24-norcholestane 208 59.787 39999 2.3 2.3 S26N24aaaR 5a, 14a, 17a,24-norcholestane 20R 60.532 34999 2.0 2.0 S26N21 21-norcholestane 60.718 61235 3.6 3.6 S26N27baaR 5ß, 14a, 17a,27-norcholestane 208 60.904 25003 1.5 1.5 S26N27aaaS 5a, 14a, 17 a,27 -norcholestane 208 61.010 80331 4.7 4.7 S26N27abbR 5a, 14ß, 17ß,27-norcholestane 20R 61.170 90961 5.3 5.3 S26N27abbS 5a, 14ß, 17ß,27 -norcholestane 20S 61.489 77677 4.5 4.5 S26N27aaaR 5a, 14a, 17 a,27 -norcholestane 20R 62.180 88463 5.1 5.1 372.3->217.2: C27 Desmethylsteranes D27baS 13ß, 17a-diacholestane 20S 57.554 5304349 308.7 165.8 D27baR 13ß, 17 a-diacholestane 20R 58.884 3409427 198.4 149.5 D27abS 13a, 17ß-diacholestane 20S 59.867 1287639 74.9 30.8 D27abR 13a, 17ß-diacholestane 20R 60.558 1751474 101.9 73.0 S27aaa8 Sa, 14a, 17 a-cholestane 20S 63.270 1527053 88.9 36.1 S27abbR 5a, 14ß, 17ß-cholestane 20R 63.562 1270987 74.0 66.1 S27abbS 5a, 14ß, 17ß-cholestane 208 63.855 1134654 66.0 63.1 S27aaaR 5a, 14a.17 a-cholestane 20R 64.652 1166530 67.9 38.8 386.4->217.2: C28 Desmethylsteranes D28baSA 13ß, 17a-diaergostane 20S (24S) 60.718 1563001 91.0 69.0 D28baSB 13ß, 17 a-diaergostane 20S (24S) 60.904 1581762 92.1 68.6 D28baRA 13ß. 17a-diaergostane 20R (24R) 62.180 1108371 64.5 43.0 D28baRB 13ß, 17 a-diaergostane 20R (24R) 62.313 988543 57.5 50.0 D28abS 13a, 17ß-diaergostane 208 63.110 850368 49.5 49.5 D28abRA 13a, 17ß-diaergostane 20R 64.014 573144 33.4 33.4 D28abRB 13a, 17ß-diaergostane 20R 64.120 418471 24.4 24.4 C28UNK9 C28 Unknown 9 64.891 531563 30.9 30.9 S28aaaSA 5a, 14a, 17a-ergostane 20S 66.619 314552 18.3 15.7 S28aaaSB Sa, 14a, 17 a-ergostane 20S 66.726 363234 21.1 12.3 S28baaR 5ß, 14a, 17a-ergostane 20R S28abbR 5a, 14ß, 17ß-ergostane 20R 67.124 958735 55.8 64.6 S28abbS 5a, 14ß, 17ß-ergostane 20S 67.390 740240 43.1 51.7 S28N21 21-norstigmastane 67.815 91027 5.3 5.3 S28aaaR 5a,14a,17a-ergostane 20R 68.400 698136 40.6 32.4 Company: CONOCOPHILLlPS Client ID: US136210 Well Name: IAPETUS-2 Lab ID: CP278521 Top Depth: 8722.1 Fraction: SATURATE Bottom Depth: File Name: MS050174.D Acquisition Parameters: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR=3E-7MBAR CE=25 ~¡:.~ , ....... 400.4->217.2: C29 Desmethylsteranes D29baS 13ß, 17 a-diastigmastane 20S 63.562 3045802 177.3 161.2 D29baR 13ß, 17a-diastigmastane 20R 65.104 2240565 130.4 154.0 D29abS 13a,17ß-diastigmastane 20S 65.769 771019 44.9 44.9 D29abR 13a, 17ß-diastigmastane 20R 66.938 1040391 60.6 60.6 C29UNK5 C29 Unknown 5 67.683 781373 45.5 45.5 S29aaaS 5a, 14a, 17a-stigmastane 20S 69.411 870365 50.7 53.8 S29abbR 5a,14ß,17ß-stigmastane 20R 69.996 1097077 63.9 92.5 S29baaR 5ß,14a, 17a-stigmastane 20R S29abbS 5a,14ß, 17ß-stigmastane 20S 70.182 960153 55.9 64.1 S29aaaR 5a, 14a, 17a-stigmastane 20R 71.431 818633 47.6 46.1 414.4->217.2: C30 Desmethylsteranes D30nPbaSA 13ß, 17 a-dia-24-n-propylcholestane 20S 65.795 303911 17.7 31.8 D30nPbaSB 13ß, 17 a-dia-24-n-propylcholestane 20S 65.875 318081 18.5 21.1 D30nPbaR 13ß, 17a-dia-24-n-propylcholestane 20R 67.443 422069 24.6 37.7 D30nPabSA 13a, 17ß-dia-24-n-propylcholestane 20S 67.895 71363 4.2 4.2 D30nPabSB 13a, 17ß-dia-24-n-propylcholestane 20S 68.028 80297 4.7 4.7 D30nPabR 130., 17ß-dia-24-n-propylcholestane 20R 69.331 244752 14.2 14.2 DC30UNK7 dia-C30 Unknown 7 69.836 76733 4.5 4.5 DC30UNK8 dia-C30 Unknown 8 69.969 40845 2.4 2.4 DC30UNK8A dia-C30 Unknown 8A 70.128 71443 4.2 4.2 S30nPaaaS 5a, 14a, 17 0.-24-n-propylcholestane 20S 71.617 155247 9.0 12.9 C30UNK10 C30 Unknown 10 71.803 35956 2.1 2.1 S30iPaaaS 50.,140.,17 a-24-iso-propylcholestane 20S 72.069 12924 0.8 0.8 S30nPabbR 50., 14ß,17ß-24-n-propylcholestane 20R 72.388 200218 11.7 26.3 S30nPabbS 50.,14ß,17ß-24-n-propylcholestane 20S 72.468 146969 8.6 23.9 S30nPbaaR 5ß, 140., 17 a-24-n-propylcholestane 20R 72.601 59023 3.4 3.4 S30iPabbR 50., 14ß, 17ß-24-iso-propylcholestane 20R 72.840 19239 1.1 1.1 S30nPaaaR Sa, 140., 17 0.-24-n-propylcholestane 20R 73.904 232438 13.5 21.7 C30UNK14 C30 Unknown 14 S30iPaaaR 50., 14a, 17 a-24-iso-propylcholestane 20R 74.196 14109 0.8 0.8 C30UNK16 C30 Unknown 16 386.4->231.2: C28 Methylsteranes D283MbaS 3ß-Methyl-13ß, 170.-diacholestane 20S 59.043 117457 6.8 6.8 DC28UNK16 dia-C28 Unknown 16 59.841 107710 6.3 6.3 D283MbaR 3ß-Methyl-13ß, 170.-diacholestane 20R 60.425 100375 5.8 5.8 DC28UNK3 dia-C28 Unknown 3 60.691 27584 1.6 1.6 DC28UNK17 dia-C28 Unknown 17 61 .223 87093 5.1 5.1 D284MbaS 40.-Methyl-13ß, 17 o.-diacholestane 20S 61.675 424871 24.7 24.7 D284MbaR 40.-Methyl-13ß, 170.-diacholestane 20R 63.004 267890 15.6 15.6 S283MaaaS 3ß-Methyl-5a, 140.,17 a-cholestane 20S 64.785 134408 7.8 7.8 S283MabbR 3ß-Methyl-5a, 14ß, 17ß-cholestane 20R 65.157 157663 9.2 9.2 S283MabbS 3ß-Methyl-50., 14ß, 17ß-cholestane 20S 65.423 178949 10.4 10.4 S284MaaaS 4a-Methyl-50., 140.,17 a-cholestane 20S 65.955 150436 8.8 8.8 S284MabbR 40.-Methyl-50., 14ß, 17ß-cholestane 20R 66.114 242960 14.1 14.1 S283MaaaR 3ß-Methyl-50., 140.,17 o.-cholestane 20R 66.167 89599 5.2 5.2 S284MabbS 40.-Methyl-50.,14ß ,17ß-cholestane 20S 66.380 204383 11.9 11.9 S284MaaaR 40.-Methyl-50., 140., 17 o.-cholestane 20R 67.364 150193 8.7 8.7 XS28aaaR 50.,14a,17a-ergostane 20R 68.427 28371 1.7 1.7 Company: Well Name: Top Depth: Bottom Depth: Acquisition Parameters: CONOCOPHILLlPS IAPETUS-2 8722.1 Client ID: Lab ID: Fraction: File Name: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR=3E-7MBAR CE=25 US136210 CP278521 SATURATE MS050174.D 400.4->231.2: C29 Methylsteranes D293MbaSA 3ß-Methyl-13ß, 17a-diaergostane 20S 62.127 34566 2.0 2.0 D293MbaSB 3ß-Methyl-13ß, 17a-diaergostane 20S 62.313 38344 2.2 2.2 DC29UNK27 dia-C29 Unknown 27 62.871 63132 3.7 3.7 DC29UNK28 dia-C29 Unknown 28 63.110 51290 3.0 3.0 D293MbaRA 3ß-Methyl-13ß, 17 a-diaergostane 20R D293MbaRB 3ß-Methyl-13ß, 17 a-diaergostane 20R 63.695 22853 1.3 1.3 D294MbaSA 4a-Methyl-13ß, 17a-diaergostane 20S 64.758 180406 10.5 10.5 D294MbaSB 4a-Methyl-13ß, 17a-diaergostane 20S 64.944 189431 11.0 11.0 D294MbaRA 4a-Methyl-13ß, 17 a-diaergostane 20R 66.220 134905 7.9 7.9 D294MbaRB 4a-Methyl-13ß, 17 a-diaergostane 20R 66.327 133773 7.8 7.8 D294MabS 4a-Methyl-13a, 17ß-diaergostane 20S 67.124 117193 6.8 6.8 D294MabRA 4a-Methyl-13a,17ß-diaergostane 20R 68,002 139862 8.1 8.1 S293MaaaSA_4abRB 3ß-Methyl-5a,14a,17a-ergostane 20S + 68.055 138330 8.1 8.1 4a-methyl-13a, 17b-diaergostane 20R S293MaaaSB 3ß-Methyl-5a, 14a, 17 a-ergostane 20S 68.214 32393 1.9 1.9 S293MabbR 3ß-Methyl-5a, 14ß, 17ß-ergostane 20R 68.640 73269 4.3 4.3 S293MabbS 3ß-Methyl-5a, 14ß, 17ß-ergostane 20S 68.905 100266 5.8 5.8 S294MaaaSA 4a-Methyl-5a, 14a, 17 a-ergostane 20S 69.251 53013 3.1 3.1 S294MaaaSB 4a-Methyl-5a, 14a, 17 a-ergostane 20S 69.384 78658 4.6 4.6 S294MabbR 4a-Methyl-5a, 14ß, 17ß-ergostane 20R 69.570 171415 10.0 10.0 S294MabbS_3MaaaR 4a-Methyl-5a, 14ß, 17ß-ergostane 20S + 69.863 242490 14.1 14.1 3b-Methyl-5a, 14a, 17a-ergostane 20R S294MaaaR 4a-Methyl-5a, 14a, 17 a-ergostane 20R 71.006 113249 6.6 6.6 XS29aaaR 5a,14a, 17 a-stigmastane 20R 71.431 38879 2.3 2.3 414.4->231.2: C30 Methylsteranes S302MaaaS 2a-Methyl-5a, 14a, 17 a-stigmastane 20S 70.368 44969 2.6 2.6 S303MaaaS 3ß-Methyl-5a, 14a, 17a-stigmastane 20S + (coelution) 70.820 204362 11.9 11.9 S302MabbR 2a-Methyl-5a, 14ß, 17ß-stigmastane 20S + (coelution) 71.006 26992 1.6 1.6 S302MabbS 2a-Methyl-5a, 14ß, 17ß-stigmastane 20S 71.139 19625 1.1 1.1 S303MabbR 3ß-Methyl-5a, 14ß, 17ß-stigmastane 20R 71.670 106862 6.2 6.2 BBDINO ßß-dino (?) S303MabbS 3b-Methyl-5a, 14b, 17b-stigmastane 20S + (coelution) 71.67 95926 5.6 5.6 S304MaaaS 4a-Methyl-5a, 14a, 17a-stigmastane 20S 71.990 76973 4.5 4.5 S304MabbR 4a-Methyl-5a, 14ß, 17ß-stigmastane 20R 72.388 111782 6.5 6.5 S304MabbS_2MaaaR 4a-Methyl-5a, 14ß, 17ß-stigmastane 20S + 72.601 147261 8.6 8.6 2a-Methyl-5a,14a,17a-stigmastane 20R + (coelution) S303MaaaR 3ß-Methyl-5a, 14a, 17a-stigmastane 20R + (coelution) 72.814 138985 8.1 8.1 DS4aSS20R 4a ,23S ,24S-trimethyl-20 R-cholestane 73.319 24503 1.4 1.4 DS4aSR20R 4a ,23S ,24R-trimethyl-20R-cholesta ne 73.691 10376 0.6 0.6 S304MaaaR 4a -Methyl-5a, 14a ,17 a -stigmastane 20 R 73.957 88932 5.2 5.2 DS4aRR20R 4a ,23R,24R-trimethyl-20 R-cholestane 74.090 18307 1.1 1.1 DS4aRS20R 4a,23R ,24S-trimethyl-20 R-cholesta ne 74.329 23175 1.3 1.3 Company: Well Name: Top Depth: Bottom Depth: Acquisition Parameters: ..ï Jf~j... -,.~ ~1;~~1 ... 414.4->259.2: Tetracyclic polyprenoids. andC30 >3ßpropylsteranes S303PaaaS 3ß-Propyl-5a, 14a, 17 a-cholestane 20S PP1 Tetracyclic polyprenoid PP2_S303PabbR Tetracycfic polyprenoid+ 3ß-propyl-5a, 14ß, 17ß-cholestane 20R S303PabbS 3ß-Propyl-5a, 14ß, 17ß-cholestane 20S S303PaaaR 3ß-Propyl-5a, 14a, 17a-cholestane 20R Peak Label . J ~ ~~ CONOCOPHILLlPS IAPETUS-2 8722.1 Client ID: Lab ID: US136210 CP278521 SATURATE MS050174.D Fraction: File Name: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR=3E·7MBAR CE=25 Rearranged hopane 5(4~3)abeo-3a(H), 5ß-Oleanane C30 unknown triterpane Oleanoid Oleanoid Oleanoid 5( 4~3 )abeo-3ß(H)-Oleanane 3ß-methyl-24-nor-1 (1 O~5)abeo-1 Oß(H), 18a-oleanane C30 plant terpane Diahopane C30 unknown triterpane 18a Oleanane 18ß Oleanane 17a, 21ß-Hopane 30-Norhomohopane 18a,17ß-Neohopane 17a, 21a-Hopane 17ß, 21a-Hopane (Moretane) Gammacerane-A Gammacerane-B 72.734 27485 1.6 1.6 72.920 27992 1.6 1.6 73.053 43827 2.6 2.6 73.292 29377 1.7 1.7 74.063 29294 1.7 1.7 66.593 141276 8.2 8.2 69.996 28484 1.7 1.7 414.2->191.2: Pentacyclic Triterpenoids REARNGHOP OLEANOID13 TRITERP14 OLEANOID15A OLEANOID15 OLEANOID16 C30UNKT2 OLEANOID17 TRITERP17A DH30 TRITERP18 OL 18a OL 18b H30ab H30N30 H30TS H30aa H30ba GamA GamB 71.139 91437 5.3 5.3 72.149 505211 29.4 29.4 72.601 39421 2.3 2.3 74.196 5447794 317.1 567.3 74.436 144906 8.4 8.4 74.834 395814 23.0 23.0 75.100 171563 10.0 10.0 75.393 363371 21.1 53.0 78.264 62512 3.6 1.2 78.450 19871 1.2 0.4 414.2->313.3: Bicadinanes B30W Bicadinane W (cis, cis, trans) B30T Bicadinane T (trans, trans, trans ) B30T1 Bicadinane T1 B30R Bicadinane R 274.3->203.2: Norpregnanes NORPREG1 NORPREG2 NORPREG3_ 4 NORPREG5 NORPREG6 NORPREG7 NORPREG8_9 NORPREG10 NORPREG11 NORPREG12 Norpregnane-1 Norpregnane-2 Norpregnane-3+ Norpregnane-4 Norpregnane-5 Norpregnane-6 Norpregnane-7 Norpregnane-8+Norpregnane-9 Norpregnane-10 Norpregnane-11 Norpregnane-12 30.599 29463 1.7 1.7 31.928 35166 2.0 2.0 32.779 125664 7.3 7.3 33.364 51062 3.0 3.0 33.922 21310 1.2 1.2 34.481 292523 17.0 17.0 34.746 68036 4.0 4.0 35.491 102924 6.0 6.0 36.262 18438 1.1 1.1 Company: Well Name: Top Depth: Bottom Depth: Acquisition Parameters: CONOCOPHILLlPS IAPETUS-2 8722.1 Client ID: Lab ID: Fraction: File Name: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR=3E-7MBAR CE=25 US136210 CP278521 SATURATE MS050174.D 330.3->191.2: Tetracyclics DesAOL Des-A-Oleanane DesALUP Des-A-Lupane DesA T ARAX Des-A- T a raxastane 51.919 32280 1.9 1.9 DesEHOP Des-E-Hopane 53.381 253433 14.8 14.8 410.4->218.2: Monounsaturated C30 Pentacyclic Triterpenoids Bicadinene Bicadinene OL 1318ene 0Iean-13(18)-ene OL 12ene 0Iean-12-ene OL 18ene 0Iean-18-ene OL 12ene18a 18a-0Iean-12-ene Unk_Peak1 Unknown peak 1 426.4->205.2: C31 Pentacyclic Triterpenoids H312Mab C31 2a-Methylhopane 74.409 61493 3.6 3.6 H31abS C31 22S 2a-Methylhopane 77.520 359319 20.9 20.9 H31abR C31 22R 2a-Methylhopane 77.945 276490 16.1 16.1 H313Mab C31 3ß-Methylhopane 78.424 40422 2.4 2.4 ~~' Steranes %C27 Steranes (372->217,386->217,400->217) %C28 Steranes (372->217,386->217,400->217) %C29 Steranes (372->217,386->217,400->217) %C27 Diasteranes (372->217,386->217,400->217) %C26 Diasteranes (372->217,386->217,400->217) %C29 Diasteranes (372->217,386->217,400->217) C30 Sterane Index (414->217) C30 iso/n-propyl Sterane Index (414->217) C27 aßß/(aaa+aßß) (372->217) C28 aßß/(aaa+aßß) (386->217) C29 aßß/(aaa+aßß) (400->217) C30 aßß/(aaa+aßß) (414->217) C27 S/(S+R) (372->217) C28 S/(S+R) (386->217) C29 S/(S+R) (400->217) C30 S/(S+R) (414->217) Oiasteranes/Steranes 24-Nordiacholestane Ratio (NOR) (358->217) 24-Norcholestane Ratio (NCR) (358->217) 21-Norcholestane Ratio (358->217) Dinosterane Ratio (414->231) 4-Methyl Sterane Ratio (400->217,414->231) Terpanes Oleanane Index (%) (412->191) Gammacerane Index (%) (412->191) Oiahopane Index (%) (412->191) Bicadinane Index (%) (412->191,412->369) OesA Oleanane Index (%) (330->191) TPP (358->217,414->259) 1 00*(S27 aaaS+S27 abbR+S27abbS+S27 aaaR)/(S27 aaaS+ S27abbR+S27abbS+S27aaªR+S28 aaaSA +S28aaaSB+S28abbR+S28abbS+S28aaaR+S29aaaS+S29abbR+S29abbS+S29aaáR) 1 00*(S28aaaSA +S28aaaSB+S28abbR+S28abbS+S28aaaR)/(S27 aaaS+S27 abbR+ S27abbS+S27aaaR+S28aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR+S29aaaS+ S29abbR+S29abbS+S29aaaR) 1 00*(S29aaaS+S29abbR+S29abbS+S29aaaR)/(S27 aaaS+ S27 abbR+S27 abbS+S27aaaR+S28 aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR+S29aaaS+S29abbR+S29abbS+S29aaaR) 100* (D27baS+D27ba R)/(D27baS+D27ba R+028baSA +028baSB+D28baRA +028baRB+ D29baS+D29baR) 1 00*(D28baSA +028baSB+028baRA+028baRB)/(027baS+ 027baR+ 028baSA+D28baSB+ 028 ba RA+ D28baRB+ 029baS+029baR) 100* (029baS+D29ba R)/(D27baS+D27baR+028baSA + 028baSB+028baRA+028baRB+ D29baS+D29baR) (S30NPaaaS+S30NPabbR+S30NPabbS+S30NPaaaR)/(S27 aaaS+S27 abbR+S27abbS+ S27aaaR+S28aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR+S29aaaS+S29abbR+ S29abbS+S29aaaR+S30NPaaaS+S30NPabbR+S30NPabbS+S30NPaaaR) (S30iPaaaS+S30iPaaaR)/(S30NPaaaS+S30NPaaaR+S30iPaaaS+S30iPaaaR) (S27 abbR+S27abbS)/(S27 aaaS+S27abbR+S27 abbS+S27 aaaR) (S28abbR+S28abbS )/(S28aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR) (S29abbR+S29abbS)/(S29aaaS+S29abbR+S29abbS+S29aaaR) (S30NPabbR+S30NPabbS )/(S30NPaaaS+S30NPabbR+S30NPabbS+S30NPaaaR) S27aaaS/(S27 aaaS+S27 aaaR) (S28aaaSA +S28aaaSB )/(S28aaaSA+S28aaaSB+S28aaaR) S29aaaS/(S29aaaS+S29aaaR) (S30NPaaaS )/(S30NPaaaS+S30NPaaaR) (027baS+D27baR+028baSA+ 028baSB+ 028baRA+028baRB+ 029baS+ D29baR/ (S27aaaS+S27abbR+S27abbS+S27aaaR+S28aaaSA+S28aaaSB+S28abbR+S28abbS+ S28aaaR+S29aaaS+S29abbR+S29abbS+S29aaaR) (026N24baS+ 026N24baR)/(026N24baS+026N24baR+ D26N27baS+ 026N27baR) (S26N24aaaS+S26N24abbR+S26N24abbS+S26N24aaaR)/(S26N24aaaS+S26N24abbR+S26N 24abbS+S26N24aaaR+S26N27aaaS+S26N27abbR+S26N27abbS+S26N27aaaR) S26N21/(S26N21 +S26N24aaaS+S26N24abbR+S26N24abbS+S26N24aaaR+ S26N27 aaaS+S26N27 abbR+S26N27 abbS+S26N27 aaaR) (OS4aSS20R+DS4aSR20R+OS4aRR20R+OS4aRS20R)/(S303MaaaR+0S4aSS20R+ OS4aSR20R+OS4aRR20R+OS4aRS20R) S304MaaaR/(S29aaaR+S304MaaaR) 1 OO*(OL 18a+OL 18b )/(H30ab+OL 18a+OL 18b) 100*(GamA+GamB)/(H30ab+GamA+GamB) 1 OO*OH30/(OH30+ H30ab) 1 OO*(B30T +B30T1 +B30R)/(H30ab+B30T +B30T1 +B30R) 1 OO*OesAOU(OesAOL +OesEHOP) (2*PP 1 )/(2*PP 1 +D26N27baS+D26N27baR+S26N27 aaaS+S26N27 abbR+S26N27abbS+ S26N27aaaR) Sample: 60000_ US136210 Ion Mass 358.350->217.200 40000_ 20000_ ~~JJWl~ 1.2x10: 52'.0 56'.0 60'.0 Ion Mass 372.400->217.200 64'.0 68'.0 72'.0 76'.0 9.0x10, 6.0x10, 3.0X10¡ i 52'.0 ~~"~~~ l_ 56.0 60.0 64.0 68'.0 72'.0 76'.0 f i Ion Mass 386.400->217.200 300000_ 200000_ 52'. 0 56'.0 -~ 60'.0 JJJJJJL 64'.0 68'.0 72.0 76'.0 100000, I I I i ~ 50000Q Ion Mass 400.400->217.200 400000_ 300000_ 200000_ 56'.0 ^A~~LLJJl1_ 64'.0 68'.0 72'.0 76'.0 100000_ 8 000 OJ I Ion Mass 414.400->217.200 52'.0 60'.0 60000_ 40000_ I 52'.0 56'.0 60'.0 ~ ~WV\L~~L~ 64'.0 68'.0 72'.0 76.0 2 0 0 0 0_ Retention Time (mln) File: MSOSOl 74, O\data. ms Date & Time: 15 APR 05 10:42:38 Sample: US136210 80000_ Ion Mass 414.400->217.200 60000_ 4000 oj 20000. ~ \rAfVvI\ 66'.0 Ion Mass 414.400->231.200 30000. 2000 O. ~ L~~·L~ 68'.0 70'.0 72'.0 74'.0 76'.0 100001~ U ~ JW p) ~ N ~ M I ~ 66',0 Ion Mass 414.400->259.200 9000_ 6000_ 68'.0 70'.0 72'.0 I J 300oJv~ '~1 ~ ~~'~ 66'.0 File: MSOS0174.D\data.ms Date & Time: 15 APR 05 10: 42: 38 68'.0 70'.0 72'.0 Retention Time (min) ............." 78.0 ~ 74'.0 76',0 78'.0 ~ 74'.0 76'.0 78'.0 Sample: US136210 Ion Mass 414.400->231.200 ~ w~~~~J)J ~~~A', ~\lr' 70'.0 72.0 ~ 66'.0 68·.0 74'.0 76'.0 78'.0 Ion Mass 414.400->290.300 12 000_ 9000_ 60 0 0_ 3000_ I I I I Ion Mass 414.400->98.100 1200_ I 800j \ 'J. I 400W~I\,) ~~ 4~ { .~ I,I~,I\ ~'~)JI~~~ 72'.0 74'.0 76'.0 66'.0 68'.0 70'.0 Retention Tlme (mln) File: MSOS0174.D\data.ms Date & Time: 15 APR 05 10: 42: 38 Sample: US136210 Ion Mass 412.400->191.200 9.0x10~ 6.0x10~ 3.0x10~ ^ 69'.0 !L_ 72'.0 j ~ ^^A 75.0 ---r- 78.0 81'.0 66'.0 60000. Ion Mass 412.400->369.300 40000. 20000. ~ 81'.0 72'.0 75'.0 78.0 66'.0 69'.0 Ion Mass 412.400->397.400 8000 a. 60000_ 4 0 0 0 a. 20000. 72'.0 78'.0 81'.0 66',0 69'.0 3000. Ion Mass 412.400->313.300 2000. l0004YN~V~\~#~~~,~\ÞA,>4 ~\A~ 'W~~~ "~ 66',0 69'.0 72'.0 75'.0 78'.0 81'.0 Retention Time (min) File: MSOS01'14.D\data.mB Date" Time: lS APR OS 10:42:38 rx; <1J <1J <1J r-- N 2 '" N (j) rJ) .0 .0 m r-- N 2 \0 N rJ) rx; .0 .0 'Ò' m co 'Ò' co N (j) 2 co m'" l1) mN m UJ '-O'Ò' (J)N 02 .'-0 (J)N l1)UJ rx; .0 C\'S r-- N 2 \.D N a U) .0 m r-- N 2 \0 N a I N CD ..--< r-- l1) o 64 6i.0 60.0 (mínl 58'.0 Retentíon Tlme Sample US136210 ~~- 60000_ lan Mass 358.350->217.200 UJ m .0 50000 r-- N 2 \.D N a rx; m .0 ,- N 40000_ 2 '" N a 30000 2 0 0 0 0_ U) m .0 "" N 2 rx; \.D N m a .0 'Ò' 10000_ N y; 2 Q \.D m N (f '" a L "\J ) <1 z; ) '" 1:) f' "\J 1 :z :::¡ \.C ) f' J \ c ~ A t -- 52'.0 - 54.0 S6:O File, MSOS0J74. O\data. ms Date & Time: It:" OS 10,42 38 UJ ro .0 ~ CD N Q Sample US136210 Ion Mass 386.400->231.200 90000_ 80000_ 70000_ 60000_ 50000_ ¡x; .0 (f) .0 .0 ro .0 ~ rr1 <;' ~ CD <;' N CD UJ N UJ ¡x; ro ..Q ~ <;' co N I.D N I.D <;' I.D UJ rr1 ro rr1 rl ~ I.D (V) 0) co . N (V) U) I.D ¡x; rr1 rr1 ro ~ <;' co N U) p:; 11 11 11 ¿; (") co U)N ro (') ro f1J ~ <;' co N U) UJ ¡x; .0 .0 .0 .Q ro f1J ~ ~ (V) (V) CD co N N UJ UJ ¡x; ro f1J ro CD N U) X N L() r-- ~ 72.0 70.0 ) 66'.0 Retention Time (min) o 64 r-- rl ~ Z ::J CD N r- U N Q rl N \.D I.D JL ¡x; ro .Q ~ (V) co N D I.D rl ~ Z ::J co N U D UJ f1J .0 ~ (V) CD N Q 40000_ 3 0 0 0 0_ 20000_ <;' 10000_ ;:6 co . <;' co L() L() . 0) ~~ 62.0 60'.0 38 2 File: MS050174. D\data. ms Date & Time: 15 APR 05 10 .Q ro o (Y) ::r:: Sample US136210 Ion Mass 412.400->191.200 1. Ox10~ 8 . OxlO~ 6.0x10~ 4.0x10= 2.0x10~ o 81 u:p fa) cD) œ'I fI"'- II- \.D N "" r- Lf) 0'\ 'ª ~ r-- r- ro (0 r-- r-- l'J l') 1.Al. I r) l/'-kl 78.0 CD N CD \.D r- _I I cro(Y) œ-"" cß"\N urn\.D rf'-r-- II~ g ~ ro N Ô ~ 0 ;§ I'-< p... 0 (Y)ro(Y) ~ II 0'\ Lf) (Y)::r:: ro ::r:: ~ê5 ~ ~ ~~ g ~ g CDO Lf) H .. (Y) ::r:: ~8,-; ~ ;::;:: ~ ::r:: r- r- ' ~, r-- , 'A, w ,^""Ulli 72'.0 75'.0 Retention Time (min) "" <4 0.. ¡r; W I'-< H ¡r; E-< 1~1 o 69 Lf) <4 CD r-- \.D U r- (Y) (Y) r-- \.D p... o ::r:: l'J Z ¡r; ~ W ¡r; IAI 66.0 F File, MSOS0114.D\data Date & Time: 15 APR 05 10: 42: 38 Sample US136210 Ion Mass 414.400->231.200 3 0 000_ 20000_ co N (1) If) <.0 <.0 r- "'" If) <.0 (1) crt If) to <.0 <.0 <.0 ,--¡ co crt 10000_ "'" N <.0 r- \ <.0 66.0 to <.0 m <.0 <.0 68'.0 ~~~ m m r- o \P co to <.0 co \P 00 o ,--¡ 00 <.0 \ . \ co r- N 0) \P 7Õ'.0 crt o r- 0) <.0 (f) (!} rr:J (!} ::s N o f') (f) \ Ret.ent.iQn Time 'ð ~m '" '" ~:2 ~ 0 p:; oC\! (f) N 0 ~::s ~ P:; N l1JN rr:J P:; ~ o "=!' C\! P:; \crt 80:;,;C\! '\ II I I ~ 2 ~~J_~~\Jt 72'.0 (min\ (f) {jj rr:J <U ~ o f') (f) 74'.0 78.0 P:; rr:J C\! rr:J ::s "'" o [Y) (f) o r- "=!' r- <.0 o 0'1 [Y) r- <.0 r- N "'" co <.0 rl N {"0 " COI <.0 I o 0'1 "=!' 0'1 ~ (f) <15 (!} (!} ::s (Y"\ o (Y) (/) "'" co "'" M r- P:; .a .a ro ::s [Y) o ("0 (f) P:; .a .a C\! ::s "'" o (V) (f) P:; (!} C\! ro ::s N I (f) .a .a cø ~ "=!' o MP:; (/) (!} C\! C\! ::s (V) o (Y) (f) , If) <.0 o en <.0 "'~. AROMATIC GCMS ANAL YSIS '!..~ 1'1'1' ". B.~~..I!!;J!!.~..,~~? I BASELINE CGSI ~ ~~..:.'" ~'\~tØl1i_..:.''''IIIIIT.:... ....1IJ:..~-._....... Company: Country: Basin: Lease: Block: Field: Well Name: Latitude: Longitude: CONOCOPHILLlPS UNITED STATES NORTH SLOPE IAPETUS-2 m/z 253: Monoaromatic steroids M1050547.D ~~~ljv ~\, ~ m/z 231: Triaromatic steroids M1050547.D ~L~~--.J"L~ m/z 245 Triaromatic Methylsteroids M1050547.D ~J\~wJ~,~,~'"V~ AROMATIC GCM$ ":,.L_.l_TÄ~~~;_~~,_.... Client ID: Project #: LablD: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: US136207 05-252-A CP278518 SWC JURRASSIC LATE 8861 (C2QtC21)Œ TAS TAS #1 20/20+27 TAS#221/21+28 %26 T AS %27 TAS %28 T AS %29 TAS C28/C26 20S T AS C28/C2720R TAS Dia/Regular C27 MAS %27 MAS %28 MAS %29 MAS (C21 +C22)/L MAS T AS/(MAS+ T AS) TA28/(TA28+MA29) 0.16 M 1.0 (1.3%) 0.41 M 0.31 M 19.8 D 30.5 D 38.9 0 10.7 0 2.24 1.27 3.52 28.3 0 39.9 0 31.8 0 0.11 M 1.0 (1.3%) 0.67 M 0.72 M 1.0 (0.8%) ...t:I('IIt:I~\Tj[;l~it'][:l(o}(']I.~~~_Jrf -~ - Dinosteroid Index 0.34 A C4/C3+C4 Mester 0.55 A :l1(0}1t:111 ~II (O) I (:Þ..~r:m11~1f:~~IÏ!..JI!t: .1)1 ~1~~n¡~m~IMK~ MPI-1' Rc(a) if Ro < 1.3 (Ro%) Rc(b)if Ro > 1.3 (Ro%) MPI-2 DNR-1 DNR-2 TNR1 TDE-1 TDE-2 MDR Rm(Ro%) MDR23 MDR1 DBT /Phenanthrene 0.57 M 0.71 M 1.96 M 0.59 M 4.17 M 1.66 M 0.69 M 4.31 M 0.29 M 1.15 M 0.64 M 0.88 M 0.86 M 0.18 0 1 Definition and utility of the ratios can be found on our website www.BaselineDGSl.com 2A=Source Age; D=Depositional environment; M= Maturity 3Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8861 - Client ID: Project #: LablD: File Name: US136207 05-252-A CP278518 M1050547.D '~ .- Peak Compound - Ret. - . I----_~If!-.·..,·< .. .,t, ,,' ..'. j ~ . u I.: . .. . . .. . -.:.. ~ Hei · ..' 1'..',_ 230 OTP Ortho-terphenyl (internal standard) 92 16AB C 16 Alkyl Benzene 92 17AB C 17 Alkyl Benzene 92 18AB C18 Alkyl Benzene 92 1THI092 Dimethyl dibenzothiophene 1 92 2THI092 Dimethyl dibenzothiophEme'2 92 19AB C 19 Alkyl Benzene 92 20AB C20 Alkyl Benzene 92 21AB C21 Alkyl Benzene 86.197 92 22AB C22 Alkyl Benzene 92 23AB C23 Alkyl Benzene 92 PHYBz Phytanyl Benzene 92 24AB C24 Alkyl Benzene 92 25AB C25 Alkyl Benzene 92 26AB C26 Alkyl Benzene 106 16A TM C16 Alkyl Toluene (meta)' 106 16ATO C16 Alkyl Toluene (ortho) 67.021 106 17 A TM C17 Alkyl Toluene (meta) 106 17ATO C17 Alkyl Toluene (ortho) 71.806 106 18A TM C18 Alkyl 106 18ATO C18 Alkyl Toluene (ortho)., 106 1THI0106 Dimethyl dibenzothiophene~; -- 106 2THI0106 Dimethyl dibenzothiophene 2 106 19A TM C19 Alkyl Toluene (meta) 106 19ATO C19 Alkyl Toluene (ortho) 106 20A TM C20 Alkyl Toluene (meta). 106 20A TO C20 Alkyl Toluene(ortho) 106 21ATM C21 Alkyl Toluene (meta) 106 21ATO C21 Alkyl Toluene (ortho) 106 22A TM C22 Alkyl Toluene (meta) 106 22ATO C22 Alkyl Toluene (ortho) 89.328 106 23A TM C23 Alkyl Toluene (meta) 106 23ATO C23 Alkyl Toluene (ortho) 92.178 106 24A TM C24 Alkyl Toluene (meta)' 106 24ATO C24 Alkyl Toluene (ortho) 106 PHYTL Phytanyl Toluene 106 25ATM C25 Alkyl Toluene (meta) 106 25A TO C25 Alkyl Toluene (ortho) 106 26A TM C26 Alkyl Toluene (meta) 106 26ATO C26 Alkyl Toluene (ortho) 134 15AI C15 Aryl Isoprenoids 134 16AI C 16 Aryl Isoprenoids 134 17AI C17 Aryl Isoprenoids 134 18AI C18 Aryl Isoprenoids 134 19AI C19 Aryl Isoprenoids 134 20AI C20 Aryl Isoprenoids 134 21AI C21 Aryl Isoprenoids 83.962 134 22AI C22 Aryllsoprenpids '(~ 134 ISOR Isorenieratane Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8861 - Client ID: Project #: Lab ID: File Name: US136207 05-252-A CP278518 M1050547.D 142 2MN 2-Methylnaphthalene 38.045 195035 33670 4500.1 3316.2 142 1MN 1-Methylnaphthalene 39.277 162760 26965 3755.4 2655.8 149 MTTC578 5,7,8,-triMe-MTTChroman 103.191 4677 668 107.9 65.8 156 2EN 2-Ethylnaphthalene 46.226 52452 7389 1210.2 727.7 156 1EN 1-Ethylnaphthalene 46.331 14961 4237 345.2 417.3 156 26DMN 2, 6-Dimethylna phthalene 47.141 86712 14096 2000.7 1388.3 156 27DMN 2,7 -Dimethylnaphthalene 47.299 90589 15198 2090.2 1496.8 156 1317DMN 1,3 & 1,7-Dimethylnaphthalenes 48.302 242848 32577 5603.3 3208.5 156 16DMN 1,6-Dimethylnaphthalene 48.548 1 99441 33489 4601.8 3298.3 156 23DMN 2,3-Dimethylnaphthalene 49.709 34518 6140 796.4 604.7 156 14DMN 1,4-Dimethylnaphthalene 49.815 72207 10605 1666.1 1044.5 156 15DMN 1,5-Dimethylnaphthalene 49.920 42541 8358 981.6 823.2 156 12DMN 1 ,2-Dimethylnaphthalene 50.870 57198 9169 1319.8 903.1 161 MTTC8 8-Me-MTTChroman 168 2MBP 2-Methylbiphenyl 46.701 3858 625 89.0 61.6 168 DPM Diphenylmethane 48.935 3319 547 76.6 53.9 168 3MBP 3-Methylbiphenyl 53.386 26467 4263 610.7 419.9 168 4MBP 4-Methylbiphenyl 54.037 9143 1542 211.0 151.9 168 DBF Dibenzofuran 55.462 32107 5012 740.8 493.6 170 BB_EMN Ethyl-methyl-Naphthalene 55.216 75253 9936 1736.3 978.6 170 AB_EMN Ethyl-methyl-Naphthalene 56.430 37346 5543 861.7 545.9 170 137TMN 1,3,7-Trimethylnaphthalene 56.870 78063 12652 1801.2 1246.1 170 136TMN 1,3,6- Trimethylnaphthalene 57.239 115784 18637 2671.5 1835.6 170 146135T (1,4,6+1,3,5)-Trimethylnaphthalenes 58.312 115788 17582 2671.6 1731.6 170 236TM N 2,3,6- Trimethylnaphthalene 58.576 79467 14092 1833.6 1387.9 170 127TMN 1,2,7 - Trimethylnaphthalene 59.315 36581 6233 844.0 613.9 170 167126T (1 ,6,7+1 ,2,6)-Trimethylnaphthalenes 59.508 126469 18890 2918.1 1860.5 170 124TMN 1,2,4-Trimethylnaphthalene 60.406 20024 3685 462.0 362.9 170 125TM N 1,2,5- Trimethylnaphthalene 60.863 86399 15510 1993.5 1527.6 178 PHEN Phenanthrene 70.346 179909 36778 4151.1 3622.3 184 1357 1,3,5,7 - T etramethylnaphthalene 64.822 34288 5509 791.1 542.6 184 1367 1,3,6,7 - Tetramethylnaphthalene 65.965 39490 8123 911.2 800.0 184 1247 (1 ,2,4,7+1 ,2,4,6+1,4,6,7)-Tetramethylnaphthalenes 66.704 45242 8421 1043.9 829.4 184 1257 1,2,5,7-Tetramethylnaphthalene 66.897 27684 5493 638.8 541.0 184 2367 2,3,6,7 - T etramethylnaphthalene 67.267 8069 1544 186.2 152.1 184 1267 1,2,6,7-Tetramethylnaphthalene 67.689 21677 4468 500.2 440.1 184 1237 1,2,3,7-Tetramethylnaphthalene 67.883 9937 2079 229.3 204.8 184 1236 1,2,3,6-Tetramethylnaphthalene 68.147 18814 3805 434.1 374.8 184 1256 1,2,5,6- T etramethylnaphthalene 68.868 48943 10158 1129.3 1000.5 184 DBT Dibenzothiophene 69.061 32650 6421 753.3 632.4 191 BH32 C32 Benzohopane 115.823 3681 1382 84.9 136.1 191 BH33 C33 Benzohopane 116.791 3111 993 71.8 97.8 191 BH34 C34 Benzohopane 117.653 1499 439 34.6 43.2 191 BH35 C35 Benzohopane 118.779 1019 175 23.5 17.2 192 3MP 3-Methylphenanthrene 75.272 71506 15714 1649.9 1547.7 192 2MP 2-Methylphenanthrene 75.448 75675 17340 1746.1 1707.8 192 9MP 9-Methylphenanthrene 76.134 110511 23546 2549.9 2319.0 192 1MP 1-Methylphenanthrene 76.327 95264 20683 2198.1 2037.1 Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8861 - Client ID: Project #: Lab ID: File Name: US136207 05-252-A CP278518 M1050547.D ~ 198 CAD Cadalene 198 12467PMN 1 ,2,4,6,7 -Pentamethylnaphth.al~n~,~<' 198 12357PMN 1 ,2,3,5,7-Pentamethylnaphthalene. . 198 4MDBT 4 Methyl Dibenzothiopherie<' 198 23MDBT 2 & 3 Methyl Dibenzothiophenes 74.392 28761 198 1 MDBT 1 Methyl Dibenzothiophene 206 36DMP 3,6-Dimethylphenanthrene 79.494 206 26DMP 2,6-Dimethylphenan'threne 206 27DMP 2,7 -Dimethyl phenanthrene 206 39DMP (3,9+3,1 0+2,1 0+1,3)~Dimethylph~¡{å~tÞ~eri~š;;, ;/ . ." ~ .: .:.' _.,; _ ".', r, >' _. ,'_ ":. 206 29DMP (2,9+1,6)-Dimethylphenanthrenes 206 17DMP 1,7 -Dimethylphenanthrene 206 23DMP 2,3-Dimethylphenanthrene 206 19DMP 1,9-Dimethylphenantþrene. .: .. 206 18DMP 1,8-Dimethylphenanthrene 206 12DMP 1,2-DimethylphenarÍthrel1;:':;'~'· . 206 9_ 10DMP 9,1 O-Dimethylphena~thr~n~.... 212 DMDBT Dimethyldibenzothiophene ...' 219 RET Retene 86.285 226 TMDBT Trimethyldibenzothiophene' ; 231 231A20 C20 Triaromatic Steroid 231 231B21 C21 Triaromatic '-/ 231 231 C26 C26 20S Triaromatic 231 231 D26 C27 20S & C26 20R 231 TADMD1 C28 23,24-Cholestane Triaromatic 106.112 231 T ADMD2 C28 23,24-Cholestane Trìárom~ti~', 231 231E28 C28 20S Triaromatic 106.851 231 231F27 C27 20R Triaromatic 231 TADMD3 C28 23,24-Cholestane Triaromatic 107.607 231 C29T A 1 C29 Triaromatic 231 C29TA2 C29 Triaromatic 231 TADMD4 C28 23,24-Cholestane Triaromatic 231 231G28 C28 20R Triaromatic 231 TADMD5 C28 23,24-Cholestane TriarÓmatic'·'; 231 C29TA3 C29 Triaromatic 245 C3S C27 20S 3-Methyl TriarornaticSterô,idf: 245 C4S C2! 20S 4~Methyl Triarorn~ti~~~E;¡r?i~ 245 E2S C28 20S 2-Methyl Triaroméjl1iþ'§t~~o~i~~;'i 245 E3SC3R C28 20S 3-Methyl & C27 20R 3-Methyl T AS :- :' ~.- -¡;:" .'-.7:", ,',' ":." "; ;'-. .--- 245 E4SC4R C28 20S 4-Methyl & C27 20R4:,M~thyJ"f\$ 245 S2S C29 20S 2-Methyl Triaromatic Steroid 245 DA Triaromatic Dinosteroid a: 245 S3S C29 20S 3-Methyl Triaromatic Steroid 245 DB Triaromatic. Dinosteroidb . '. ~ ,,;:. 245 S4SE2R C29 20S 4-Methyl & C28 20R 2-Methyl T AS 245 E3R ";".: ',. ._ '_'-~.'.>.<.':'~ .;_:-.- ~ ..;_C·-""'~~'O·'::.:::.':_}{ C2820R 3-MethyITriarolTlat.içSt~roicJ.'.(:·j 245 E4R C28 20R 4-Methyl !ri~romatic Steroid 245 DC Triaromatic. Dinosteròid "'~ 245 DD Triaromatic Dinosteroid d n' Company: CONOCOPHILLlPS Client ID: US136207 Well Name: IAPETUS-2 Project #: 05-252-A Depth: 8861 - LablD: CP278518 Sampling Point: File Name: M1050547.D œ~:~~ . ~..; r~.. · , _ ' ,¡;;;_,.,-;,~t~j' :11 .- 245 S2R C29 20R 2-Methyl Triaromatic Steroid 111.372 2411 425 55.6 41.9 245 S3R C29 20R 3-Methyl Triaromatic Steroid 111.583 7920 1543 182.7 152.0 245 DE Triaromatic Dinosteroid e 111.706 8464 1579 195.3 155.5 245 S4R C29 20R 4-Methyl Triaromatic Steroid 112.146 7906 1583 182.4 155.9 245 OF Triaromatic Dinosteroid f 112.269 12970 3030 299.3 298.4 253 S253A C21 Ring-C Monoaromatic§teroid 84.596 6056 1398 139.7 137.7 253 S253B C22 Monoaromatic steroid 87.059 5262 1105 121.4 108.8 253 S253C C27 Reg 5ß(H),10ß(CH3) 208 96.999 2475 496 57.1 48.9 253 82530 C27 Dia 10ß(H},5ß(CH3) 20S 97.157 8703 2150 200.8 211.8 253 8253E C27 Dia1 OßH,5ßCH3 20R+Reg5ßH,1 OßCH3 20R 98.617 8253 2051 190.4 202.0 253 8253F C27 Reg 5a(H),10ß(CH3) 208 98.758 3468 784 80.0 77.2 253 S253G C28 Dia 1 OaH,5aCH3 20s+Reg5ßH,1 OßCH3208 99.163 14938 2740 344.7 269.9 253 S253H C27 Reg 5a(H), 10ß(CH3) 20R 100.429 2170 608 50.1 59.9 253 S2531 C28 Reg 5a(H),10ß(CH3} 208 100.588 3545 868 81.8 85.5 253 S253J C28 Dia 10aH,5aCH3 20R+Reg5ßH,10ßCH3 20R 100.764 10714 2486 247.2 244.8 253 8253K C29 Dia 10ßH,5ßCH3 208+Reg5ßH,10ßCH3 208 100.887 12989 2570 299.7 253.1 253 S253L C29 Reg 5a(H),10ß(CH3) 208 102.171 3511 797 81.0 78.5 253 S253M C28 Reg 5a(H),10ß(CH3) 20R 102.470 6106 964 140.9 94.9 253 8253N C29 Dia 10ßH,5ßCH3 20R+Reg5ßH,10ßCH3 20R 102.576 10173 1871 234.7 184.3 253 82530 C29 Reg 5a(H),10ß(CH3) 20R 1 04.194 1535 542 35.4 53.4 182 OM BP1 Dimethybiphenyl peak 1 60.124 3808 716 87.9 70.5 182 DMBP2 Dimethylbiphenyl·peak 2 60:916 4673 875 107.8 86.2 182 DMBP3 Dimethylbiphenyl peak 3 61.127 12843 2409 296.3 237.3 182 DMBP4 Dimethylbiphenyl peak 4 61.303 1299 273 30.0 26.9 182 DMBP5 Dimethylbiphenyl peak 5 61.743 10423 2010 240.5 198.0 182 DMBP6 Dimethylbiphenyl peak 6 62.165 1669 325 38.5 32.0 182 DMBP7 Dimethylbiphenyl peak 7 62.394 1127 191 26.0 18.8 182 DMBP8 Dimethylbiphenyl peak 8 62.798 34983 5840 807.2 575.2 182 DMBP9 Dimethylbiphenyl peak 9 63.009 1884 347 43.5 34.2 182 DMBP10 Dimethylbiphenyl peak 10 63.256 8229 1633 ·189.9 160.8 182 DMBP11 Dimethylbiphenyl peak 11 63.537 45697 7097 1054.4 699.0 182 DMBP12 Dimethylbiphenyl peak 12 63.854 10116 1865 233.4 183.7 182 DMBP13 Dimethylbiphenyl peak 13 64.012 18286 3672 421.9 361.7 182 DMBP14 Dimethylbiphenyl peak 14 64.276 5367 1026 123.8 101.1 182 DMBP15 Dimethylbiphenyl peak 15 64.575 4950 915 114.2 90.1 182 DMBP16 Dimethylbiphenyl peak 16 64.874 4514 819 104.2 80.7 212 ET4DBT 4-Ethyld ibenzothiophene 77.224 3717 829 85.8 81.6 212 DM46DBT 4,6-0 i methyldibenzothiophene 77.594 13594 2843 313.7 280.0 212 DMDBT3 Dimethyldibenzothiophene peak 3 77.875 2828 507 65.3 49.9 212 DMDBT4 Dimethyldibenzothiophene peak 4 78.139 9884 2219 228.1 218.5 212 DMDBT5 Dimethyldibenzothiophene peak 5 78.333 26411 4364 609.4 429.8 212 DMDBT6 Dimethyldibenzothiophene peak 6 78.966 9057 1719 209.0 169.3 212 DM14DBT 1,4-Dimethyldibenzothiophene 79.160 18875 3204 435.5 315.6 212 DMDBT7 Dimethyldibenzothiophene peak 7 79.582 9654 1247 222.8 122.8 212 DMDBT8 Dimethyldibenzothiophene peak 8 79.740 4265 1052 98.4 103.6 212 DMDBT9 Dimethyldibenzothiophene peakß 80.233 2501 460 57.7 45.3 "~ Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8861 - US136207 05-252-A CP278518 M1050547.D Client ID: Project #: Lab ID: File Name: :,. ' '" '. ,~. '," ~ ,.,' _ . Misc~lI~neous Ratios _ By A~eas .' , ,~ Triaromatic Steroidsm/z231 (C20+C21 )/r. TAS T AS #1 20/20+27 TAS #2 21/21+28 %26T AS %27TAS %28T AS %29T AS C28/C2620S TAS . C28/C27 20R T AS Monoaromatic Steroids m/z 253 Dia/Regular C27 MAS %27 MAS %28 MAS %29 MAS (C21 +C22)/r. MAS TAS/(MAS+TAS) T A28/(T A28+MA29) 0.72 'z_· Triaromatic Methylsteroids m/~ 245 Dinosteroid Index C4/C3+C4 Mester 0.55 Phenanthrenes and Naphthalenes MPI-1 MPI-2 0.59 Rc(a) if Ro < 1;3 (Ro%) Rc(b) if Ro > 1.3 (Ro%) 1.96 DNR-1 DNR-2 TNR1 TDE-1 TDE-2 MDR Rm (Ro%) MDR23 MDR1 D BT /Phenanthrene '~ 4 0 0 0 0_ 30000_ 20000_ 1 00 0 0_ Sampl e: Ion Ma s s 1 4 2 +1 56 +1 7 0 +1 8 4 US136207 Date & Time" File: M1050547. D\data. ms 'r 05 3:20 pm z :>: N I~ z :>: .--I ~O'. 0 Z íi1 N ~ -i ----' <--..J ~ z :>: CI ~ ~ CI '" N ~ ~ .--I z :>: o <:!' .--I E-< '" N E-< .--I Lf) r- Z C') '" :>: .--I .--I E-< '" Z ill <:!' C') .--I :>: .--I E-< Lf) N .--I Z :>: E-< Z ill :>: C') E-< N Z r- C') :>: .--I íi11 p:¡ p:¡ ill Lf) N .--I r- r- <:!' ill N C') .--I .--I r- r- Lf) E-< Lf) N C') r- p:¡ .--I .--I ill 0 Nill .4-C') ~ .--1.--1 z :>: o N .--I 2; >' :5 ') -- :z 2: c r< N z ~ E-< r- N .--I z :>: íi11 ~ z ~ E-< <:!' N .--I ~ ,LJ~~VW~'"V 50.0 r- ill C') N ),w-' hJ tJ ~I \ ~ J \it.., \A t~ ~ 60'.0 70'.0 Retention Time (min) ( M3) 1 4 000_ 1 2000_ 1 0 0 0 0_ ( Sample: US136207 Ion Mass 184+198+212+226 80 0 0_ 6 0 0 0_ 4 0 0 0_ 2 0 0 0_ , I 64',0 File: MIOSOS47. D\data. ms Date & Time: 28 Apr 05 3: 20 pm r- I.D (Y) .-I r- If) (Y) .-I \ , ~ \ ~ i r- '<I' N .-I r- If) N .-I r- I.D (Y) N r- I.D N .-I \D (Y) N .-I r- (V) N .-I 68'.0 I.D If) N .-I E-< en §J '<I' E-< en §J .-I ~ Q E-< en §J (V) N If) E-< en §J Q E-< en Q <:!' .-I ~ Q ~ ~ E-< en Q I.D <:!' Z ~ '<I' ~ Q E-< ~ ~ ~~ ~ ~ ~ Q ~ .-I~ en \ R ~ ~'rn I~\\ ~rU ~"II'\t~rJ 4~E~~ ~ \\1#IWvt~'J~ E-< en §J E-< 72'.0 76',0 Retention Time (min) 80'.0 84'.0 (M4 ) 4 0 000_ 30000_ 20000_ 1 0 0 0 0_ Sampl e: US136207 Ion Mass 178+192+206 ~ - 70'. 0 Date & Time: File: M10sOs47 "'data. ms 05 3:20 pm z µ:¡ :r: (l, 72'.0 74'.0 Retention Time (min) 78'.0 ~ N (l, :E (Y] J\J I ~ m (l, :E c::1 m (Y] (l, :E rl 76'.0 (l, :E c::1 t- rl (l, :E c::1 m N (l, :E c::1 m rl (l, :E (l, c::1 V) :E (l, N c::1 :E (Y] c::1 (l, (l, N CX) :E rl :E c::1 \ c::1 t- V) N M ~ Iv ~ 80'.0 82'.0 (Ml) 400Q 300Q 200Q 100Q File: M10SOS47. D\data. ms Date & Time: 28 Apr 05 3: 20 1 9) 84 Sampl e US136207 Ion Mass 219 7000_ 6000_ 5000_ (Y) CX) o (Y) CX) o '<I' L!l (Y) CX) o L!l o '<I' CX) o r- \.0 (Y) '<I' CX) I N '<I' 00 '<I' . 00'<1' \.000 '<I' 00 86.0 E-< ~ 88'.0 Retention Time r- L!l '<I' r- \.0 '<I' o r-i .(Y) 0 (Y) N r- \.0 00 ~. L!l oor--: ~ . oor- r- ~. M ~ M CX) r- r-1 ~ \J~ '<I' L!l \.0 \.0 CX) I \.0 r- o r- oo min) r-i L!l (Y) r-i 0'1 00 00 00 . 0 00 0 00 ..-I 0\ 00 90.0 N r- '<I' o 0'1 92 o File: Date Ml05054' ~\data Time r OS 200 0_ 0'\ (Y) N Lf)~~ rl ~ o (TI roO'\ rl rl rl Lf) . N (TI o 8åg~ rl <J\ "'" (TI (TI C> (TI ~ Lf) to o N (TI r-- "'" ro N (TI o rl r-- N N .lO r-- r-- . to (TI r-- ro (TI . N o rl ~ ~ w""'- 96. 0 99.0 10:2. 0 Retention Time (min 21 rl 1<!;N ~1<!; N~ L.' UN fk. ,"0 U "'" ~ ro tI) ~ ~ rl C>~~ ~<ri ::E ~ ""'(TIrl~ C> ~tI) ·å JJLJ~ ~ .. ~:~ E1~rl :: ~~ ~ ~ r-b rl ~ r-i ~ ~ MJt~. 105~ 108 o (Y1 1<!; E1 (TI N U 4 0 0 0_ r-i N ¡:Q rl (Y1 N o N 1<!; rl (Y1 N \.D N U rl (Y1 N r-- N ¡., rl (Y1 N 6 0 0 0_ ro N ri1 rl (Y1 N ~ample US136207 Ion Mass 231 12000_ 10000_ 8000_ \.D N CJ r-i (Y1 N ro N CJ rl (Y1 N File: Ml0505 Date & Time: 28 Apr 05 3: 20 pm 22 108.0 Retention Time (min) 102 o co co <:I' N o r-f '-" co o ('V) o .--\ 104 o 106.0 ('V) 01<:1' r-('V) '-" rl''<t' 01'-" . .0'-" '-".--\0 a _ r-f .--\ 0'\ r- a r- a r-f tI) 01 U) \~ _1 Q) <:I' '-" <:I' a; Ll1 0 <:I' rl V no.o E~ oc:Þ ::::~ ,~ r-I ¡::£; 0'\ 01 o C/) ~\ 112 000 oLl1 0'\0 ric-.: r-fO- .--\0- .Y o 1000_ 0'\ r- r- N r-f .--\ ~ o C/) ('V) U en <:I' U en ('V) U) \ p:; CV) ¡:,:¡ Sampl e US136207 Ion Mass 245 4 0 0 0_ 3000_ 2000_ ¡::£; ('V) u C/) ('V) ¡:,:¡ p:; <:I' U en '<t' [i] II)¡::£; ON [i] en <:I' en ¡::£; u <;' 0 ¡i1 o o ¡::£;1ïI ('V) 0 en, , ¡::£; <;' U) r.. o File: M1050547 Date & Time D\data. 05 84. 0 3: 20 23 1 000_ 87 ~-~ ,D .0 -D '<1' :x> o ¡:Q (Y) If) N CJ) o r- N r- OO 96 minI ri 00 (Y) 0) 00 '<1' r- OO 0) 00 90'.0 93'.0 Retention Time 00 D' '<1' 00 . (Y) (Y) D' D' . (Y) D' o '" (Y) If) N :r: 0 CJ) (Y) If) 00 ~ ~ 0 N1> u r-: r- 0 (Y) D' ",0) If) r-D' 0 N (Y) ri CJ) 0) \ \ D' :y, <;' XJ -:ñ (j) ~J¥J\LL .~~ 99'.0 102 <D 0'\ í) <D ,D . :'oJ '<1' . 0 '" rl ~l t\~~ liw If) 00 '" (Y)",'-; ~r-o ONri riri 00 riri o J) '" ri \D N ri D' ,."j . N 0 (Y) (Y] rl 0 . ~ C'\ r-<--i C If"P ~ 00'0 f"11f) ~(Y) 0- . ri\ ~ \ ri r-< '" '<1' r-! ~ 4i> ~ <f51 '<1' µ¡> 0 N ri r.r¡ 105 o H (Y) If) N CJ) r-- o :>: D' f"" tr ri C'\ o u: riH (Y) If) N CJ) ,,¡:: (Y) If) N CJ) 2 0 0 0_ Q (Y) If) N CJ) [ii (Y) If) N CJ) z (Y) If) N CJ) 3000_ Sa mpl e Ion Mass 253 US136207 (C) (Y) If) N CJ) :<:; (Y) ~ N CJ) 1 200 0_ 10 0 0 0_ Sample: US136207 Ion Mass 91 +92 8 0 0 0_ 6 0 0 0_ 4 0 0 0_ 2000_ ~J;J)uJ}~,W~,~t,J ~h \ h~W\J'1/ tfll.\fl01.!Jd\~1\¡~~~~~~),;¡~ 4 O. 0 . \J.¡,¡., J.I. \J..<. 50. 0 6 0.. 0 . ..M VW\. 1M.. ""'.....1 1 70.0 80·.0· .~ Retention Time (min) 90.0 100.0 110.0 120.0 File: MI050547. D\data. ms Date & Time: 28 ADr 05 3: 20 Dm ( Ml 3 ) 16000_ Sampl e: US136 2 0 7 Ion Ma s s 1 0 5 +1 0 6 1 4 0 0 0_ 12000 1 0000_ 8000_ 6 000_ 4 0 0 0_ 2 0 00_ ~.j¡'\J.j',.I\hI~ j~I~,\ \, \ ,,~J 40'.0 File: M1050547. D\data. ms Date & Time: r 0 5 3: 20 pm 50'.0 60'.0 II" qIII~illl'1 ~ ~,I'¥ ~h ~II, I . r' , ~ 0\\ ~.y,¡ I »,h¡l¡.¡ ho\{~....t 70'.0 80'.0 Retention Time (min) 90'.0 100.0 110.0 ( Ml 4 ) 120.0 Sampl e. Ion . US13 Ma s s 62 0 7 133+134 4000 3000! 2000 -¡ File: 1110 Dat 50547 . . ".., ,;D\d"..~ 50. 0 Aor 05 3:20 Om 60.0 70. 0 Rete . 80.0 I1tl.OI1 Time (mil11 90.0 (M16) . 100.0 110.0 120.0 Company: Country: Basin: Lease: Block: Field: Well Name: IAPETUS-2 Latitude: Longitude: m/z 253: Monoaromatic steroids M1050456.D ~-...,~ l.JJJJ ~J ÁL m/z 231: Triaromatic steroids M1050456.0 ~ ~~~",-^,-vJr-.JL4~ m/z 245 Triaromatic Methylsteroids M1050456.0 ~JJvwI¡,~0V ~~ Client ID: Project #: Lab ID: Sample Type: Sampling Point: Formation: Geologic Age: Top Depth: Bottom Depth: AROMA llC GCMS ............___~-.~""d~J¿ - ~t ~~. ·~I US136210 05-252-A CP278521 MDT EARLY CREATACEOUS 8722.1 '~~g,fìi~gi1o)l&,T~§iM T AS #1 20/20+27 %26 T AS %28 T AS OialRegular C27 MAS ,·;c' . -"'O.13.J,M(i,;tt.0{1.3%l 0.35 M 20.2 D 20S T AS 2.24 4.07 0.70 M 1.0 (0.8%) T A28/(T A28+MA2~) j£ig~1¡t~£;¿~:~,_~~:/r:}Þ .~t:lt.JIlt:t~I';r.t~it']r:l(~(.J!~~ .~ I ' Oinosteroid Index _. , III ~ =--~::r_ 0.35 A . iI(~It:'I'~I'{~I(~"'~F.rnm~'t~~Il~'\nIIß.[~1r'(.}~I1-[.;~li~\~~~ ~~1~~nl;f~itwgi~~~1,¡\ig,;;,? . ...... ." .., ·'··'··'0.65 "fV1<> Rc(~) ifRo<'1.3 -(Ro%) 0.76M MPI-2 0.65 M ONR-2 1.96 M MOR 1.13 M 1.11 M MOR23 MRß: OBT/Phenanthrene 10efinition and utility of the ratios can be found on our website www.BaselineOGSl.com 2A=Source Age; O=Oepositional environment; M= Maturity 3Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value atwhich this value is reached Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8722.1 - Client ID: Project #: LablD: File Name: US136210 05-252-A CP278521 M1050456.D 230 OTP Ortho-terphenyl (internal standard) 75.043 18297 4535 300.0 300.0 92 16AB C16 Alkyl Benzene 66.792 39093 8357 641.0 552.8 92 17AB C17 Alkyl Benzene 71.630 34360 8435 563.4 558.0 92 18AB C18 Alkyl Benzene 75.817 28713 7675 470.8 507.7 92 1THI092 Dimethyl dibenzothiophene 1 77.524 4266 787 69.9 52.1 92 2THI092 Dimethyl dibenzothiophene 2 78.263 4114 604 67.5 40.0 92 19AB C19 Alkyl Benzene 79.565 24923 6961 408.6 460.5 92 20AB C20 Alkyl Benzene 82.995 22115 6138 362.6 406.0 92 21AB C21 Alkyl Benzene 86.197 21408 5497 351.0 363.6 92 22AB C22 Alkyl Benzene· 89.206 16759 4738 274.8 313.4 92 23AB C23 Alkyl Benzene 92.056 14427 3775 236.5 249.7 92 PHYBz Phytanyl Benzene 93.956 7086 1108 116.2 73.3 92 24AB C24 Alkyl Benzene 94.765 11797 2953 193.4 195.3 92 25AB C25 Alkyl Benzene 97.369 9861 2174 161.7 143.8 92 26AB C26 Alkyl Benzene 99.849 8671 2005 142.2 132.6 106 16A TM C16 Alkyl Toluene (meta) 66.036 40365 9478 661.8 627.0 106 16ATO C16 Alkyl Toluene (ortho) 66.986 26569 5846 435.6 386.7 106 17 A TM C17 Alkyl Toluene (meta) 70.927 37045 8559 607.4 566.2 106 17 A TO C17 Alkyl Toluene (ortho) 71.789 22232 5855 364.5 387.3 106 18A TM C18 Alkyl Toluene (meta) 75.167 31920 8206 523.4 542.8 106 18ATO C18 Alkyl Toluene (ortho) 75.958 18417 4742 302.0 313.7 106 1THI0106 Dimethyl dibenzothiophene 1 106 2THI0106 Dimethyl dibenzothiophene 2 106 19A TM C19 Alkyl Toluene (meta) 78.931 24243 6181 397.5 408.9 106 19ATO C19 Alkyl Toluene (ortho) 79.705 15274 3867 250.4 255.8 106 20A TM C20 Alkyl Toluene (meta) 82.397 21530 5995 353.0 396.6 106 20A TO C20 Alkyl Toluene (ortho) 83.118 12393 3487 203.2 230.7 106 21ATM C21 Alkyl Toluene (meta) 85.599 17632 4596 289.1 304.0 106 21ATO C21 Alkyl Toluene (ortho) 86.320 11492 2947 188.4 195.0 106 22A TM C22 Alkyl Toluene (meta) 88.625 17119 4671 280.7 309.0 106 22ATO C22 Alkyl Toluene (ortho) 89.329 11878 3127 194.8 206.9 106 23A TM C23 Alkyl Toluene (meta) 91.475 13193 3254 216.3 215.3 106 23ATO C23 Alkyl Toluene (ortho) 92.179 7851 2111 128.7 139.6 106 24ATM C24 Alkyl Toluene (meta) 94:202 12252 2981 200.9 197.2 106 24A TO C24 Alkyl Toluene (ortho) 94.888 6750 1596 110.7 105.6 106 PHYTL Phytanyl Toluene 95.891 79114 12240 1297.2 809.7 106 25ATM C25 Alkyl Toluene (meta) 96.806 9089 2142 149.0 141.7 106 25A TO C25 Alkyl Toluene (ortho) 97.492 4918 1199 80.6 79.3 106 26A TM C26 Alkyl Toluene (meta) 99.304 8864 1920 145.3 127.0 106 26ATO C26 Alkyl Toluene (ortho) 99.990 4151 928 68.1 61.4 134 15AI C15 Aryl Isoprenoids 60.899 8624 1449 141.4 95.9 134 16AI C16 Aryl Isoprenoids 66.089 6426 1273 105.4 84.2 134 HAl C17 Aryl Isoprenoids 70.733 3248 593 53.3 39.2 134 18AI C18 Aryl Isoprenoids 74.903 6904 1456 113.2 96.3 134 19AI C 19 Aryl Isoprenoids 77.190 7582 1275 124.3 84.3 134 20AI C20 Aryl Isoprenoids 81.007 4965 1178 81.4 77.9 134 21AI C21 Aryl Isoprenoids 83.963 2351 647 38.5 42.8 134 22AI C22 Aryl Isoprenoids 86.725 1667 335 27.3 22.2 134 ISOR Isorenieratane Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8722.1 - Client ID: Project #: LablD: File Name: US136210 05-252-A CP278521 M1050456.D ~-- ".,. c .'. Compoünd Ret. - " ,-- -. -----.., ,T -"..",-. .-\".~, ~ w·_"· , . . .' . _ ~ . . ...: ~ .. . , . It a 1 . ~ Hei . ht 'Area _ H. hi' 142 2MN 2aMethylnaphthalene 38.011 142 1MN 1 ~Methylnaphthalen~ _ , 149 MTTC578 5,7,8,-triMe-MTTChroman 156 2EN 2-Ethylnaphthalene 156 1EN 1-Ethylnaphthalene 46.279 156 26DMN 2,6-Dimethylnaphthalene 156 27DMN 2,7 -Dimethylnaphthalene 156 1317DMN 1,3 & 1, 7 -Dimethylnaphth~Jel1e~ 156 16DMN 1 ,6-Dimethylnaphthalene 156 23DMN 2,3-Dimethylnaphthalene 156 14DMN 1 ,4-Dimethylnaphthaleme 156 15DMN 1 ,5-Dimethylnaphthalene . 156 12DMN 1,2-Dimethylnaphthalene 161 MTTC8 8-Me-MTTChroman 168 2MBP 2-Methylbiphenyl 46.649 168 DPM Diphenylmethane 168 3MBP 3-Methylbiphenyl 168 4MBP 4-Methylbiphenyl 168 DBF Dibenzofuran 170 BB_EMN Ethyl-methyl-Naphthalene 170 AB_EMN Ethyl-methyl-Naphthalene 170 137TMN 1 ,3,7-Trimethylnaphthaler1~ ''''-' 170 136TMN 1,3,6-Trimethylnaphthalene ._..... 170 146135T (1 ,4,6+1,3,5)- Trimet~ylnaphthalenës'.- 170 236TMN 2,3,6- Trimethylnaphthalene 170 127TMN .;'! 1,2,7,. Trimethylnapt1~halene' 170 167126T (1,6,7+1,2,6)- Trimethylnaphthalenes " "" ,.'."-. -.'.---""'"'--" 170 124TMN .. . '-'-, ~ 1,2,4- Trimethylnaphthalene . . 170 125TMN 1 ,2,5- Trimethylnaphthalene 178 PHEN Phenanthrene 184 1357 1 ,3,5,7- T etramethylnaphth~lene 64.787 184 1367 1 ,3,6,7-Tetramethylnaphthal~q~ 184 1247 (1,2,4,7+1 ,2,4,6+1 :4~_~~7}-Te~ra,methyl~~phtha/enes 184 1257 1 ,2,5,7-Tetramethylné1phthal~ne 184 2367 2,3,6,7,. T etramethylnaphthalene 184 1267 1,2,6,7-Tetramethylnaphthélene 184 1237 1,2,3,7 -Tetramethylnaphthalene 184 1236 1 ,2,3,6-Tetramethyfnaphthal~n~ 184 1256 1,2,5,6- Tetramethylnaphthalene 184 DBT Dibenzothiophene 191 BH32 C32 Benzohopane 191 BH33 C33 Benzohopane 191 BH34 C34 Benzohopane 117.794 191 BH35 C35 Benzohopane 192 3MP 3-Methylphenanthrene 75.255 192 2MP 2-Methylphenanthrene 192 9MP 9-Methylphenanthrene 76.134 192 1MP 1-Methylphenanthrene ~./ Company: CONOCOPHILLlPS Client ID: US136210 Well Name: IAPETUS-2 Project #: 05-252-A Depth: 8722.1 - LablD: CP278521 Sampling Point: File Name: M 1050456. D ^"'_""....s. W : . IJj 198 CAD Cadalene 66.282 3951 847 64.8 56.0 198 12467PMN 1,2,4,6,7 -Pentamethylnaphthalene 73.126 9927 2140 162.8 141.6 198 12357PMN 1,2,3,5,7 -Pentamethylnaphthalene 73.442 7155 1515 117.3 100.2 198 4MDBT 4 Methyl Dibenzothiophene 73.601 38077 8223 624.3 544.0 198 23MDBT 2 & 3 Methyl Dibenzothiophenes 74.375 33656 6269 551.8 414.7 198 1MDBT 1 Methyl Dibenzothiophene 75.184 33656 6733 551.8 445.4 206 36DMP 3, 6-Di methylphenanthrene 79.477 11527 2822 189.0 186.7 206 26DMP 2,6-Di methylphenanthrene 79.741 24003 5396 393.6 357.0 206 27DMP 2,7 -Dimethylphenanthrene 79.846 13750 2952 225.4 195.3 206 39DMP (3,9+3,1 0+2,1 0+1 ,3)-Dimethylphenanthrenes 80.356 123316 24272 2021.9 1605.6 206 29DMP (2,9+1,6)-Dimethylphenanthrenes 80.550 63430 10199 1040.0 674.7 206 17DMP 1 ,7 -Dimethylphenanthrene 80.708 51451 11989 843.6 793.1 206 23DMP 2,3-Dimethylphenanthrene 80.972 19310 4208 316.6 278.4 206 19DMP 1,9-Dimethylphenanthrene 81.095 32432 7011 531.8 463.8 206 18DMP 1 ,8-Dimethylphenanthrene 81.518 15505 3368 254.2 222.8 206 12DMP 1,2-Dimethylphenanthrene 82.010 11175 2512 183.2 166.2 206 9_10DMP 9,10-Dìmethylphenanthrene 82.661 2761 617 45.3 40.8 212 DMDBT Dimethyld ibenzothiophene 219 RET Retene 86.285 28402 6858 465.7 453.7 226 TMDBT T rimethyld ibenzoth iophene 81.676 138342 3374 2268.3 223.2 231 231A20 C20 Triaromatic Steroid 92.320 24790 5976 406.5 395.3 231 231B21 C21 Triaromatic 94.818 21731 5193 356.3 343.5 231 231 C26 C26 20S Triaromatic 103.984 30739 6804 504.0 450.1 231 231026 C27 20S & C26 20R Triaromatic 105.567 79500 16859 1303.5 1115.3 231 T ADM 0 1 C28 23,24-Cholestane Triaromatic 106.130 1551 408 25.4 27.0 231 TADMD2 C28 23,24-Cholestane Triaromatic 106.693 5630 1146 92.3 75.8 231 231E28 C28 20S Triaromatic 106.886 68773 11189 1127.6 740.2 231 231F27 C27 20R Triaromatic 107,520 45643 7850 748.4 519.3 231 TADMD3 C28 23,24-Cholestane Triaromatic 107.625 5032 1458 82.5 96.5 231 C29TA1 C29 Triaromatic 107.872 16053 2917 263.2 193.0 231 C29T A2 C29 Triaromatic 108.065 10244 2350 168.0 155.5 231 TADMD4 C28 23,24-Cholestane Triaromatic 108.892 6023 1337 98.8 88.4 231 231 G28 C28 20R Triaromatic 109.103 59888 11 630 981.9 769.4 231 TADMD5 C28 23,24-Cholestane Triaromatic 109.191 4420 2482 72.5 164.2 231 C29TA3 C29 Triaromatic 110.405 16278 3697 266.9 244.6 245 C3S C27 20S 3-Methyl Triaromatic Steroid 106.640 5739 1264 94.1 83.6 245 C4S C27 20S 4-Methyl Triaromatic Steroid 107.256 8142 1965 133.5 130.0 245 E2S C28 20S 2-Methyl Triaromatic Steroid 107:819 2632 529 43.2 35.0 245 E3SC3R C28 20S 3-Methyl & C27 20R 3-Methyl T AS 108.171 18528 3093 303.8 204.6 245 E4SC4R C28 20S 4-Methyl & C27 20R 4-Methy1TAS 108.751 28041 4748 459.8 314.1 245 S2S C29 20S 2-Methyl Triaromatic Steroid 108.997 4109 621 67.4 41.1 245 DA Triaromatic Dinosteroid a 109.173 5859 1230 96.1 81.4 245 S3S C29 20S 3-Methyl Triaromatic Steroid 109.385 14632 1831 239.9 121.1 245 DB Triaromatic Dinosteroid b 109.772 12445 2996 204.1 198.2 245 S4SE2R C29 20S 4-Methyl & C28 20R 2-Methyl T AS 109.930 20265 2790 332.3 184.6 245 E3R C28 20R 3-Methyl Triaromatic9teroid 110.071 12753 1958 209.1 129.5 245 E4R C28 20R 4-Methyl Triaromatic Steroid 110.686 16939 3101 277.7 205.1 245 DC Triaromatic Dinosteroid c 110.862 13553 3093 222.2 204.6 245 DO Triaromatic Dinosteroid d 110.968 16720 3483 274.1 230.4 Company: Well Name: Depth: ~~ Sampling Point: CONOCOPHILLlPS IAPETUS-2 8722.1 - Client ID: Project #: LablD: File Name: US136210 05-252-A CP278521 M1050456.D ,0 'Peak ^ Cö"1J ~', 'nCt . . Ret. " j,_,,,,,,,,,' _'..... " Ion " ~>.' ~ ..'...... . . ..u'. . _ . I - Î 1* · ..,' ~'L. I,,, .~ 245 S2R 245 S3R 245 DE 245 S4R 245 OF 253 S253A 253 S253B 253 S253C 253 S253D 253 S253E 253 S253F 253 S253G 253 S253H 253 S2531 253 S253J 253 S253K 253 S253L 253 S253M 253 S253N 253 S2530 182 DMBP1 182 DMBP2 182 DMBP3 182 DMBP4 182 DMBP5 182 DMBP6 182 DMBP7 182 DMBP8 182 DMBP9 182 DMBP10 182 DMBP11 182 DMBP12 182 DMBP13 182 DMBP14 182 DMBP15 182 DMBP16 212 ET4DBT 212 DM46DBT 212 DMDBT3 212 DMDBT4 212 DMDBT5 212 DMDBT6 212 DM14DBT 212 DMDBT7 212 DMDBT8 212 DMDBT9 ~ --~: '( ."". -r- -:.1;. [lî\1j\)i~. "'. ,. I ~. ,,.. "-. ~ ~ f;~ ;;! -', Lii(¡ß -i. C29 20R 2-Methyl Triaromatic Steroid C29 20R 3-Methyl Tri~rornati~§~t3~()JçL.~·- Triaromatic Dinosteroid e C29 20R 4-Methyl TriaromaticSteroid·:~·· Triaromatic Dinosteroid! ... ..' . C21 Ring-C Monoar()mati9:~tefCJid- C22 Monoaromatic steroid C27 Reg 5ß(H),10ß(CH3)2,9§' ' C27 Dia 1 Oß(H),5ß(CH3) 20S C27 Dia1 OßH,5ßCH3 20R+~eg5ßH,19ßÇH3,?Qß;· C27 Reg 5a(H),1 Oß(CH3) 20S C28 Dia 10aH,5aCH320s+Reg5ßH,10¡3ÇH3~QS:,< C27 Reg 5a(H),10ß(CH3) 20R C28 Reg 5a(H),1 Oß(CH3)20§ C28 Dia 1 OaH,5aCH3 20R~Reg5~~, 1?~C~~_~9R, ........ C29 Dia 1 OßH,5ßCH3 20S+Reg5ßH,JOßçHª?0~r' C29 Reg 5a(H),10ß(CH3) 20S C28Reg 5a(H),10ß(CH3)20R' C29 Dia 1 OßH,5ßCH3 20R+Reg5ßH,1 OßCH3. 20R C29 Reg 5a(H),10ß(CH3) 20R. ' Dimethybiphenyl peak 1 Dimethyfbiphenyl peak 2 Dimethylbiphenyl peak 3 Dimethylbiphenyf peak 4 Dimethylbiphenyl peak 5 Dimethylbiphenyl peak. 6 Dimethylbiphenyl peak 7 Dimethylbiphenyl peak 8 Dimethylbiphenyl peak 9 Dimethylbiphenyl peak 10 . Dimethylbiphenyf peak 11 Dimethylbiphenyl peak 12 Dimethylbiphenyf peak 13 Dimethyfbiphenyl peak 14 Dimethylbiphenyl peak 15 Dimethylbiphenyl peak .16· 4-Ethyldibenzothiophene 4,6-Dimethyldibenzothiophe,?e .. Dimethyldibenzothiophene peak 3 Dimethyldibenzothiophene peak 4 ;.. Dimethyldibenzothiophene peak 5 Dimethyldibenzothiophene pe~k 6 1 ,4-Dimethyldibenzothiophe~e ... Dimethyldibenzothiophene pe~k;7 Dimethyldibenzothiophene pea~ ~. Dimethyldibenzothiophenep~ak 9- Company: Well Name: Depth: Sampling Point: CONOCOPHILLlPS IAPETUS-2 8722.1 - Client ID: Project #: LablD: File Name: US136210 05-252-A CP278521 M1050456.D ~ '-".,'.--. .,. / ' ".It "_1' , ," , ' -~" ". ...U ~ , M .. ~ellaneous Ratios By Areas By Heights , . . -" "' ,¿ ~ \ ' ,- ,_.. ", '.0_ _ . n' ,". Triaromatic Steroids m/z 231 (C20+C21)/L TAS 0.13 0.16 TAS #1 20/20+27 0.35 0.43 TAS #2 21/21+28 0.27 0.31 %26T AS 20.2 22.7 %27TAS 29.9 26.2 %28TAS 39.3 38.8 %29T AS 10.7 12.3 C28/C26 20S T AS 2.24 1.64 C28/C27 20R T AS 1.31 . 1.48 Monoaromatic Steroids m/z 253 Dia/Regular C27 MAS 4.07 4.57 %27 MAS 28.3 32.9 %28 MAS 34.9 33.5 %29 MAS 36.8 33.6 (C21 +C22)/L MAS 0.12 0.13 TAS/(MAS+TAS) 0.67 0.66 T A28/(T A28+MA29) 0.70 0.69 Triaromatic Methylsteroids m/z 245 Dinosteroid Index 0.35 0.40 C4/C3+C4 Mester 0.54 0.57 Phenanthrenes and Naphthalenes MPI-1 0.65 0.69 MPI-2 0.65 0.67 Rc(a) if Ro < 1.3 (Ro%) 0.76 0.78 Rc(b) if Ro > 1.3 (Ro%) 1.91 1.89 DNR-1 4.55 4.02 DNR-2 1.96 2.05 TNR1 0.66 0.76 TDE-1 4.09 4.15 TDE-2 0.29 0.32 MDR 1.13 1.22 Rm(Ro%) 0.64 0.65 MDR23 1.03 MDR1 1.11 DBT /Phenanthrene 0.21 1 2 0 0 0 0_ 100000_ 8 0 0 0 0_ 6 0 0 0 0_ 4 0 0 0 0_ 2000 0_ Sampl e: Ion Mass 142+156+170+184 US136210 Z :8 N z :8 .--i 1 ~ J ~ 40'.0 Z iÏI N ~ -I z :8 Q :æ- ~ Q I.D N ____~~...... ""_________J File: M1050456. D\data. ms Date & Time: 12 ADr 05 6: 24 am r- r- I.D <:r (Y) N .--i .--i r- r- Z ~ ~ r- :8 .--i rl ~I.D E-i ~(Y) E-i ~ r-.--iN ~ ~ Lv~JAJ"l~!v.~'Jv~)~Vl~ 1.l.L 50'.0 Z :8 Q r-z .-œ C'¥:\ .--w .--i z :8 Q ~ ~ :::) :an ~-I c: (Y" " Z :8 Q N .--i Retention Time (min) ( M3) ~ E-i E-i l!) I.D F:-t (Y) N I.D .--i .--i (Y) I.D r- Z .--i <:r I.D .--i .--i :8 F:-t l!) Z Z N :8 :8 .--i Z F:-t F:-t ~I r- I.D (Y) (Y) .--i N ÇQ ÇQ I.D l!) N .--i Z :8 iÏI ~ Z :8 F:-t r- N rl 60'.0 70'.0 1 800 0_ 1 5 0 0 0_ 1 2 0 0 0_ Sampl e: US136 21 0 Ion Mass 184+198+212+226 9000_ 6 0 0 0_ 3000_ If File: M1050456. D\data. ms Date & Time: 12> "5 6: 24 am 64'.0 \ , r- If) (Y) rl r- '" (Y) rl \ ~ ~ U r- '<1' N M r- If) N M r- '" N M '" (Y) r-N (Y)M N rl r- '" (Y) N ) 68'. 0 1\, '" lI) N M E-< IX) Q ~^ It'll \1 \ ' \ ¡' \ 72'.0 E-< IX) Q ;;;: '<1' E-< IX) Q ;;;: M E-< IX) ~ (Y) N E-< IX) Q '" '<1' ;;;: Q z ;;;: I1<z r-;;;: "'11< '<1'r- Nlf) M(Y) N rl E-< IX) Q '<1' E-< A\ ~ M"r\~ J\ ~ 76'.0 Retention Time (min) (HI)) '<1' E-< p:¡ Q ;;;: Q If) E-< p:¡ ~ Q E-< IX) Q '<1' M ;;;: Q E-< p:¡ ~ E-< '" E-< p:¡ ~ Q r- ¡ m ;;;: E-< ~ § I iš \ \ vJRN ~I f~ \ r¡f~ 80'.0 84'.0 30000_ A" 2 0 0 0 0_ .. ... ,~:I . 1 0 0 0 0_ Sampl e: US136210 Ion Mass 178+192+206 ~ File: M1050456 D Date & Time: . \data. ms 12 Apr 05 6; 24 am z ¡iJ ::r: p., ~~ (Y)N 70'.0 74'.0 Jv ~ ~ r-I 76'.0 Retention Time ( min) ( Ml) 78'.0 ~ Q w N ~ ~ A~ 80'.0 p., :E: Q 0\ (Y) ~ Q r-- ~r-I ~ N ~ ~ r-I ~ Q (Y) N ~ Q co r-I ~ ~ Q N r-I ~J~ 82'.0 US136210 9000_ Ion Mass 219 Sampl e: 8000 7000 6 000_ 5000_ 4 000_ 3000_ co '» (Y) 2 0 0 0_ "" co (Y) rl "" ~ ""~ N ~ ~ 1000_ ~ ~ V~ ~J co M co ~ 84'.0 File: Date &M1050456. D\data. InS T>me: 12 , 5 6; 24 E-< ~ N r- r- '» ~ r- 0 co ~ r- co tI) m '» "" co ~ "" co rl tI) CO(Y) 0 00 '» (Y) (Y) '» co "" 0 co N r- 0 m 0 rl "" rl '» ""r- ui ui (V) CO r- N co N tI) co c¡)--r rl m (Y) coc¡) co c¡) '» co co 86'. 0 88'.0 Retention Time (min) 90'.0 92'.0 ,. 9) 21 0 0 0_ 1 8 0 0 0_ 15000_ 1 2 0 0 0_ Sampl e: US136210 .-t N p:¡ .-t (Y) N (Y) r- (J) eo .-t N l!1 l!1 0 1.0 ~ 0 r- eo 0 (J) (J) eo r- (J) (J) eo .-t 96'.0 99.0 102.0 Ion Mass 231 9000_ o N ~ .-t (Y) N 6 0 0 0_ 3 0 0 0_ r- q< CX) Retention Time (min) Fil e: M10504 56. D\data. ms ( 21) Date & Time: 12 Apr 05 6: 24 am (Y) qU') (J) ~ ~ ~ o ~~Nq< 0 .-t l!1 N. N . ~~ 93'.0 1.0 N Q rl (Y) N eo N µ:¡ .-t (Y) N eo N l'J .-t (Y) N r- N rx.. .-t (Y) N 1.0 N U .-t (Y) N (Y) ~ ð:( ~ ~ ~N ::¡ ~~ ~ V) ~ q<E-i '<:1' :::¡ Q 0 N ~ 1.Oâ: r- ê ~ ~U) q< ~ g ~ 0 ~ ~ ~ ~~,W1:V ~-~- 105.0 108.0 File: Ml050456. D\data. Date & Time: 12 l "5 6: 24 am ')2 Retention Time 108. 0 ( miIJ) 110 o 112 N 0\ 1 0 0 0_ <r N f0"'; .-to . .-t r-I o l.-t 102.0 If) N 0\ .-t o r-I w o If) N o .-t 104 o o o (Y] <r o .-t 106 o c- m o c- o .-t (IJ N ¡£ If) o If) CX) o .-t (IJ N (IJ CX) o If) 0) y CX) If) "" o ~. ex; N (IJ Jiv If) r-i CX) N r-i .-t (IJ (Y] U ~( 2000_ (IJ (Y] (IJ (IJ "" U ex; (Y) ¡£ ex; '<:1' (IJ J 3 0 0 0_ ex; ¡:!)N Q¡£ (IJ '<:1' (IJ ex;¡£ (Y)Q (IJ¡ ex; (Y) U (IJ (Y) ¡£ ex; ""u ¡£ Q 4 0 0 0_ Q Q 5000_ ex; <r U (IJ "" ¡£ µ, ¡:::¡ 6 0 0 0_ 7 0 0 0_ Sampl e Ion Ma s s 245 US136210 ( \. Sampl e: US136210 Ion Mass 253 7000_ 6 0 0 0_ 5000_ 4 0 0 0_ ,:t; (Y) U) 3 0 0 O_ N CI) - D <0 2 0 0 0_ .;. co 1 0 0 0_ ~- 84'.0 File: M10504 56. D\data. ms Date & Time: 12 Apr 05 6: 24 23 87.0 u (Y) l!) N U) C¡ C") U) N U) ÇQ (Y) l!) N CI) (Y) l!) N r- ex> 90.0 N CO (Y) a) OJ ~ ¡-- O)~ OJOJ 93.0 Retention Time ex> 0) <;' (Y) 0) 96 min) o 99'.0 (Y) ~ o (Y) l!) ~ ~ ~ U) ~ 0) H O~rl ¡;:¡ r; o Ba""¡N 1fQ (Y) 0 r- r-: ~~,...¡ ~\ ~ ~ 0) l!)0ì" 0 . '" NO) (V) 0) CI) rl N ~ CI) l!) ~ \ : ~~ ~ ~ ~ I i ~ _~~J~~~U_~ _;1 r~ z (V) l!) N CI) (Y) (V) <.D r- Oì µ, :<1 .{) N CI) r:.J (Y) l!) N CI) ø (V) l!) N CI) ~ (Y) l!) N CI) ;.:; (V) l!) N CI) 102 o 105 o 21 00 0_ 1 800 0_ 1 50 0 0_ 12000_ (, ill J,t~\ j, Mt,kJ ~~ \.~I'I)~ UV~,JJd¡~,\W ~~~1lt~k~wW\\MIM~J1~ 40'.0 50'.0 Sample: US136210 Ion Mass 91 +92 9000_ 6 000_ 3 0 0 0_ 60'.0 70'.0 File: M1050456. D\data. ms Date & Time: 12 þ. ~5 6: 24 am 80'.0 Retention Time (min) ( M1 3) 90'.0 100.0 110.0 120.0 2 4 0 0 0_ 2 0 0 0 0_ 16 0 0 0_ 1 2 0 0 0_ Sample: US136210 Ion Mass 105+106 80 0 0_ 4 0 0 0_ I J ~~I II ,~.ll JW'~ U ~ ~\,,\ 40'.0 File: M10504 56. D\data. IUS Date & Time: 12 Apr 05 6: 24 am 50'.0 1 ,UJ ( I ,. ~ II , '~i 60'.0 ~" ~ Þ ~I I' ,(: I ~ . ~' I 't ~ ~ ~¡iIo¡f~I~~w~",,~ 70'.0 80'.0 Retention Time (min) ( Ml 4 ) 90'.0 100.0 110.0 120.0 2000_ File: M10504.'\ Date & T' 6,D\data lme: 12" . ms Sampl e' Ion Mass US136210 133+134 10000_ 8 0 0 0_ 60 0 0_ 4000_ I ..J j , ,¡ , , 6: 24 am M I 40.0 ~ I ,.;1 ¡ Ii t I I ',~ I 50.0 . !/I~ t " ,* I . 60.0 70.0 ~ " 1 / ; 'I.) r,' ' f, ,'I , Retent. 80'. 0 Wn Time (m' 90.0 ~n) 'j¡ M~~ 100. 0 110.0 12Ó.O !fI1II' Studv on MDT Samples for I I I I I I I I I I I I I I I I I I I SchlulDberger Fluid Analysis on MDT Samples ConocoPhillips Aøc$~ Field: Wildcat I"'·" " ,··We I J;.lapetus..#2....,.~_"...__~ t CO.r~l~]]) El~trli\L : ~,,~ - PVT Study on MDT Samples Prepared for Dennis Wegener ConocoPhillips Standard Conditions Used: Pressure: 14,696 psia Temperature: 60°F Prepared by: Meisong Yan Schlumberger WCP Oilphase-DBR 16115 Park Row, Suite 150 Houston, Texas, 77084 (281) 285 6379 Date: 9/2/2005 Report #200500058 I I Client: Well: Installation: 200500058 ConocoPhí II i ps Iapetus #2 Doyon #19 Field: Sand: Job #: Wildcat I Table of Contents List of Figures . List ofT abIes ."............ . I EXECUTIVE SUM.MARY. Objective Introduction Scope of Work.. Results PVT Study Data Duality.Check.Summary... Sequence of Events. . Chain of Sample,Custody.. , . . .. .... ..... I I I RESULTS AND. .DISCUSSIONS.. Fluids Preparation.and.Analysis. Reservoir Fluid.Analysis . . . . I PVT Analysis on Sample.t.03; ,C.ylindel.CSB.14185.-QA; .Depth. 8722.2 .ft.. MD. .... Constant Composition Expansion. at Ires. . Differential Vaporization. . . Oil Phase Properties.. Gas Phase Properties.. Compositions Reservoir Oil Viscosity at Tres .. . Multi-Stage Separation .Test,. I I Appendix A: Nomenclature and. Definitions.. Appendix B: Molecular Weights. and. Densities Used Appendix C: EQUIPMENT... ..... .... ........ Fluid Preparation. and .Validation.... Fluid Volumetric. (PVTJ .and. Viscosity. Equipment. . Appendix D: PROCEDURE.. Fluids Preparation .and. Validation. . . Constant Composition.Expansion.Proc.edure.. Differential Vaporization.Procedure.. Multi-Stage Separation. Test.. Liquid Phase Viscosity. and Density. Measurements Dur.ing. D.V Step Stock-Tank OiJ.{STOJVi.scosity.and.Density.Measurements.. . Asphaltene, Wax.aod Sulfur.Content.Measurements. .. SAR(P)A Analysis. . High- Temperature High. Pressure. Filtr.ation. Test. . ...... ..... ....... I I ..,.. .... .... ....".. I I I I I I I WCP Oilphase-DBR SChllm~lrglP 2 3 .......... ....... 4 4 4 4 4 6 6 6 ..... ........ 7 7 7 20 20 22 22 22 22 29 31 .."............ .... ............ 37 38 39 39 39 42 42 42 42 42 43 43 43 44 44 Job #: 200500058 I I Client: Well: Installation: ConocoPhì II i ps Iapetus #2 Doyon #19 Field: Sand: Job #: Wildcat Scblumbøpgø" 200500058 I List of Figures I Figure 1: Stock Tank 0i1.Cbr.omatogr.am.(Sample1.01!... Figure 2: k-PloUor .Equilibrium Check (Samp.le. 1.01).. Figure 3: Stock Tank 0i1.Cbr.omatogr.am.(Sample1.02)... Figure 4: k-PloUor .Equilibrium Check (Samp.le. 1.02).. Figure 5: Stock Tank .GiI.Cbr.omatogr.am.(Sample1.0J)... Figure 6: k-PloUor .Equilibrium Check (Samp.le. 1.03).. Figure 7: Constant.Composition.Ex:pansion.at .165.0°F .-. Relative. Volume... Figure 8: Differential.überatiou t65°.F.~.liquid .Prop.erties.. Figure 9: Differential.Liberatiou t65°.F.~Gas. Properties... Figure 10: Reservoir .Fluid .viscosjty.165~F.... Figure 11: Separation.Corrected.Oil.v.olume. Factor (B.o) .. Figure 12: Separation.Corrected.Solution.GOR.(Rs)... ......................... I ".....,.. ," 12 12 15 15 18 18 21 24 26 30 36 36 I .... ........... ..... ..... ....".. I I I I I I I I I I I I I WCP Oilphase-DBR 2 Job #: 200500058 I I Client: Well: Installation: ConocoPhillips Iapetus #2 Doyon #19 Field: Sand: Job #: Wildcat 200500058 SchlumÞePl8P I List of Tables I Table 1: Well and. Sample. Identification. . . . . . . .. .................................................................................... Table 2: Samplin.g.and.Transfer.Summar:y............................................................................................ Table 3: Reservoir.Flujd Properties.. .... ... .. . .. ... ... . ... .. . .. ... ... . ... ... .. ... . ... ................................................ Table 4: Stock-Tank Oil Prnperties................................................................... ............................. Table 5: C3o.+ Compositioß..GOR..OAPJ.. by. Zero"Flash.(Sample .1.0.1) Table 6: Calculated.Fluid.Prope.rties.. Table 7: C3o.+ Compositioß..GOR..oAPJ.. by. Zero"Flash .(Sample1.o.2). Table 8: Calculated.Fluid.Prope.rties....... Table 9: C3o.+ Compositioß..GOR..oAPJ.. by. Zero"Flash .(Sample1.o.3).. Table 10.: Calculated Fluid .P.roperties.. Table 11: Summary.of.ResultsofSample.1.03.. Table 12: Constant .Composition .Expaosion at.1.65.o.~F (Sample.1.o.3.)... Table 13: Differential Libela.tion.Test165°F.c liquid. Properties... Table 14: Differential Libela.ti.on .Test165°F.c .Gas.Properties.. . Table 15: Differential Libela.tion.Test165°F.c Vapor.&.SIO.Compositi.oß.(mol. %). Table 16: Differential Libela.tion.Test165°F.c SIO Comp.osition. (wt% and mol.%).. Table 17: Reservoir.FluidViscos.ity.165~L... . Table 18: MulticStage. Separati.on .Test.Vapor. & liquid. Properties... . Table 19: MulticStage. Separator. Test Vapor .Composition .(mol.%).. . Table 20.: MulticStage.Separa.tol Test ResidualUquid .Composition(wt% and. mol."!o).. Table 21: Separation Corrected GOR.and EVF... ""... .......... 8 8 9 9 10 11 13 14 16 17 19 20 23 25 27 28 29 32 33 34 35 I I I ....... .......... I I I I I I I I I I I I WCP Oilphase-DBR 3 Job #: 20.0.500058 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Iapetus #2 Doyon #19 Field: Sand: Job #: Wildcat 200500058 S.chlomblPger EXECUTIVE SUMMARY Objective To evaluate the composition and phase behavior of the bottomhole fluid samples collected during the modular formation dynamics testing (MDT). Introduction At the request of ConocoPhillips, Oilphase has conducted a fluid analysis study on bottomhole fluid samples collected during the modular formation dynamics testing (MDT) of Well Iapetus #2 drilled in the field Wildcat. Scope of Work . Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for five · Conduct preliminary evaluation on bottomhole hydrocarbon samples that include single-stage flash Gas-Oil Ratio (GOR), reservoir fluid composition, stock-tank oil (STO) and monophasic fluid properties. · Select a representative sample for the PVT study. · Conduct a Constant Composition Expansion ICCE) test at the reservoir temperature. · Conduct differential vaporization at the reservoir temperature. · Conduct a multi-stage separation test at the specified conditions. · Also conduct viscosity measurements of the oil at the reservoir temperature. Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon and water samples: · Three bottomhole samples were used for validation purposes. They were homogenized at the reservoir conditions for five days. · The zero flash GOR was determined to be from 608 - 613 SCF/STB, and the STO density to be from 0.845 - 0.853 glee. · Subsequently, sample 1.03 was selected for full PVT study. The following are the results of the reservoir fluids: · The bubble point pressure at reservoir temperature was determined to be 1,952 psia. · The reservoir fluid viscosity of sample 1.03 was measured to be 0.67 cP at bubblepoint pressure and 0.76 cP at the initial pressure. The stock tank oil viscosity at 165°F was measured as 2.47 cP. flASHING CUMULATIVE API Gas Relative FVF FVF OPERATION GOR (set/stb) GRAVITY Density (air=1) at Pres/T res at Psat/Tres Zero Flash 613 34.9 1.019 1.353 1.371 DL Flash @Tres 591 36.4 0.963 1.327 1.344 Separator Test 521 36.7 0.911 1.296 1.314 WCP Oilphase-DBR 4 Job #: 200500058 I I Client: Well: Installation: ConocoPhillips Iapetus #2 Doyon #19 Field: Sand: Job #: Wildcat 200500058 SchlUIDb81'g81' I Quality Assurance Process I Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottom hole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality. Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry. This objective requires persistent innovation and ongoing development of state-of-the-art technologies and equipment I A rigorous quality assurance program, continuous employee training and enforcement of strict safety standards maintain our compliance with Quality, Health, Safety and Environment (QHSE requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE policies and standards. I Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data. Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures. Details of these programs are available upon request The lab-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results. I a) Establish quality of measurement during data generation. bl Establish quality of processed data as per checklist during data processing by Data Quality Engineer. c) Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency d) The responsible Project Engineer confirms consistency of reported data el Engineering Project Manager review the results/report for overall consistency I I Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established Quality checklists designed for each operation and based on the level of complexity. All property measurements and calculation procedures are maintained in company archives for a period of 1 year. This information is available for review by clients upon request The file and laboratory records information are listed below to provide access reference to all records related to this project For any questions, please do not hesitate to contact the undersigned Project Engineer. I File No.: 200500058 Laboratory Records: 200500058 I Data Quality Data Reporting Suyu Ye Meisong Van I Data Quality Engineer Project Engineer I Overall Report Quality Dennis D'cruz I Denn is D'cruz Engineering Project Manager I I I I I WCP Oilphase-DBR 5 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Iapetus #2 Doyon #19 Field: Sand: Job #: Wildcat SChlllbBPIBP 200500058 Sequence of Events 03/30/05 04/15/05 04/15/05 04/16/05 05/03/05 05/16/05 OS/25/05 09/02/05 Samples arrived and informed client. Project work scope discussed. Work agreement approved. Prelim PVT tests request for all three samples issued. Sample PVT prelim results sent via e-mail. Sample 1.03 was selected for further PVT study. Sample 1.03 PVT results sent via e-mail. Final Revised Report sent via E-mail. Chain of Sample Custody The samples collected from the well Iapetus #2 were sent to Oilphase-DBR in Houston, Texas. The samples were used to preliminary measurements and subsequent PVT studies. The measurement details are in the following text. Samples remaining after measurements are stored in Oilphase-DBR storage unless otherwise instructed. WCP Oilphase-DBR 6 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Iapetus #2 Doyon #19 Field: Sand: Job#: Wildcat Schlumberger 200500058 RESUL IS AND DISCUSSIONS Fluids Preparation and Analysis Three bottomhole samples collected during the MDT were transferred to Oilphase-DBR. The well and formation data with their respective reservoir conditions for the bottomhole samples are summarized in Table 1. The quality check for the bottomhole samples were conducted and the results are summarized in Table 2. After 5-days of homogenization, sample validation test was conducted to evaluate the validity of the samples, and all the samples were good candidates for PVT analysis. Based on the preliminary results, representative samples can selected for PVT analysis. The reservoir fluid and stock-tank oil properties for all the samples are presented in Table 3 and Table 4. Reservoir Fluid Analysis The gas and liquid from zero flash were subjected to chromatography and their compositions were determined. These compositions were recombined mathematically according to single-stage flash Gas-Oil Ratio (GaR) to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Table 5, 7 and 9. The molecular weight of the stock-tank oil (STO) was measured. Other properties such as the plus fraction properties and heat content for the flash gas were calculated from the compositions and are listed in Table 6, 8 and 10. WCP Oi/phase-DBR 7 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: ConoeoPhillips Field: Wildcat Schlumberger Well: Iapetus #2 Sand: Installation: Doyon #19 Job#: 200500058 Table 1: Well and Sample Identification Client: ConoeoPhillips Job# 200500058 Field: Wildcat Well: Iapetus #2 Sample ID Chamber # Chamber Sampling Date Opening Pres. Reservoir Conditions Volume in the field Pressure Temperature Depth (ee) (psia¡OF) (psia) (OF) (ft) 1.01 MPSR 1397 450 03/13/05 1115/70 3,301 165 8722 1.02 MPSR 1398 450 03/13/05 1115/70 3,301 165 8722 1.03 MPSR 1399 450 03/13/05 1115/70 3,301 165 8722 Table 2: Sampling and Transfer Summary Opening Transfer Closing Opening Transferred Sample ID Chamber # conditions Cylinder conditions conditions FS&W Sample in the field ID in the field in the Lab Volume (psiarF) (psia¡OF) (psia¡OF) Ice) (ee) 1.01 MPSR 1397 1115/70 CSB 14186-QA 1215/74 N/D 420 1.02 MPSR 1398 1115/70 CSB 8611-QA 1115/74 N/D 420 1.03 MPSR 1399 1115/70 CSB 14185-QA 1215/74 N/D 410 WCP Oilphase-DBR 8 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Field: Wildcat Schlumbepgep Well: Iapetus #2 Sand: Installation: Doyon #19 Job#: 200500058 Table 3: Reservoir Fluid Properties Zero Flash Saturation Molar Mass of Sample ID Cylinder # Depth GOR* Bo** Pressure monophasic at Tres fluid (ft) (scf/stb) (psia) 1.01 CSB 14186-QA 8)22 612 116.3 1.02 CSB 8611-QA 8,722 608 113.1 1.03 CSB 14185-QA 8,722 613 1.371 1952 115.1 * Flashed gas volume (scf) per barrel of stock tank liquid @ 60°F ** Volume of live oil at it's bubble point pressure per flashed stock tank liquid volume @ 60°F Sample ID Table 4: Stock-Tank Oil Properties STO Properties Cylinder # Depth Molar Mass Density API (ft) (glee) 1.01 CSB 14186-QA 8,722 218.2 0.853 1.02 CSB 8611-QA 8,722 206.9 0.845 1.03 CSB 14185-QA 8,722 214.4 0.850 34.4 36.1 34.9 *Oilphase-DBR's calculation is API =141.5/Density -131.5. WCP Oilphase-DBR 9 Job #: 200500058 I I Client: ConocoPhillips Field: Wildcat Scblumberger Well: Iapetus #2 Sand: I Table 5: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.01) Sample 1.01; Cylinder CSB 14186-QA; Depth 8722.2 ft. MD Component MW Flashed Gas Flashed liquid Monophasic Fluid I (g/mole) WT% Mo.LE % WT% Mo.LE % WT% Mo.LE % Carbon Dioxide 44.01 0.74 0.50 0.00 0.00 0.10 0.27 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 0.74 0.79 0.00 0.00 0.10 0.42 Methane 16.04 32.96 61.26 0.00 0.00 4.57 33.11 Ethane 30.07 7.15 7.09 0.00 0.00 0.99 3.83 Propane 44.10 18.89 12.77 0.00 0.01 2.62 6.91 I I - Butane 58.12 5.82 2.99 0.01 0.04 0.82 1.63 N - Butane 58.12 13.87 7.11 0.08 0.29 1.99 3.98 I - Pentane 72.15 5.64 2.33 0.26 0.80 1.01 1.63 I N - Pentane 72.15 5.31 2.20 0.43 1.30 1.11 1.78 C6 84.00 4.11 1.46 1.55 4.02 1.90 2.64 M-C-Pentane 84.16 1.07 0.38 0.67 1.74 0.73 1.01 I Benzene 78.11 0.06 0.02 0.04 0.10 0.04 0.06 Cyclohexane 84.16 0.36 0.13 0.42 1.09 0.41 0.57 C7 96.00 1.67 0.52 2.78 6.31 2.63 3.18 M-C-Hexane 98.19 0.58 0.18 1.27 2.82 1.17 1.39 I Toluene 92.14 0.07 0.02 0.26 0.62 0.24 0.30 C8 107.00 0.65 0.18 3.98 8.11 3.52 3.82 E-Benzene 106.17 0.01 0.00 0.14 0.28 0.12 0.13 I M/P-Xylene 106.17 0.01 0.00 0.29 0.60 0.25 0.28 o.-Xylene 106.17 0.01 0.00 0.18 0.36 0.15 0.17 C9 121.00 0.23 0.06 3.91 7.06 3.40 3.27 I Clo 134.00 0.02 0.00 4.46 7.26 3.84 3.34 Cll 147.00 0.00 0.00 4.01 5.95 3.45 2.73 C12 161.00 0.00 0.00 3.85 5.22 3.32 2.40 C13 175.00 0.00 0.00 4.02 5.01 3.46 2.30 I C14 190.00 0.00 0.00 3.85 4.42 3.31 2.03 C15 206.00 0.00 0.00 3.71 3.93 3.19 1.80 C16 222.00 3.35 3.30 2.89 1.51 I C17 237.00 3.17 2.92 2.73 1.34 C18 251.00 3.35 2.91 2.89 1.34 C19 263.00 2.99 2.48 2.57 1.14 I C20 275.00 2.58 2.04 2.22 0.94 C21 291.00 2.47 1.85 2.13 0.85 C22 300.00 2.28 1.65 1.96 0.76 C23 312.00 2.19 1.53 1.88 0.70 I C24 324.00 2.03 1.36 1.75 0.63 C25 337.00 2.13 1.38 1.83 0.63 C26 349.00 1.65 1.03 1.42 0.47 I C27 360.00 1.81 1.09 1.56 0.50 C28 372.00 1.66 0.97 1.43 0.45 C29 382.00 1.72 0.98 1.48 0.45 I C3O+ 809.59 26.48 7.14 22.81 3.28 Total 100.00 100.00 100.00 tOO.OO 100.00 100.00 MW 29.81 218.16 116.35 I MOLE RATIO. 0.5405 0.4595 I WCP Oilphase-DBR 10 Job #: 200500058 I I Client: ConocoPhillips Field: Wildcat Schlumberger Well: Iapetus #2 Sand: I Table 6: Calculated fluid Properties Sample 1.01; Cylinder CSB 14186-QA; Depth 8722.2 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid I Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole % C7+ 4.75 1.50 97.67 93.53 84.80 43.79 I C12+ 0.00 0.00 75.25 51.21 64.83 23. 53 C20+ 46.97 21.03 40.46 9.66 C30+ 26.48 7.14 22.81 3.28 I Molar Mass C7+ 94.37 227.80 225.32 C12+ 320.60 320.60 I C20+ 487.19 487.19 C30+ 809.59 809.59 I Density C7+ 0.860 C12+ 0.893 0.893 C20+ 0.932 0.932 I C30+ 0.973 0.973 Fluid at 60°F 0.853 I Gas Gravity (Air = 1) 1.029 Dry Gross Heat Content (BTU/scf) I 1,723 I Wet Gross Heat Content (BTU/scf) 1,693 OBM Contamination Level (wt%) ISTO Basis I Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 218.16 218.16 I 809.59 I I Density (g/cm3) 0.853 0.973 Single Stage Flash Data I Original STO De-Contami nated GOR (scf/stb) 612 I STO Density (g/cm3) 0.853 I STO API Gravity 34.4 OBM Density (g/cm3) @60°F I I I I WCP Oilphase-DBR 11 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Well: Iapetus #2 Field: Wildcat Sand: Figure 1: Stock Tank Oil Chromatogram (Sample Un¡ Sample 1.01; Cylinder CSB 14186-QA; Depth 8722.2 ft MD - ~ pA: 900 ~ q¡ ~ ¡ 800 ~ 700 ~ 500 ~ 500 ~ 400~ 300 ~ 200 ~ 100 ~ 0 0 ; ;:: 1'1 (1') u'· 0 .,.. .,.. 1" ~1 o 0 .,.. o 0 , 1 25 , 1 ' 30 , 1 40 , 1 ' 10 , 1 15 , I 20 , 1 ' 35 , 1 ' iI/i min Figure 2: k-Plot for Equilibrium Check (Sample 1.(1) Sample 1.01; Cylinder CSB 14186-QA; Depth 8722.2 ft MD 5.00 . C3 400 3.00 ~ IC4 . nC4 2.00 . 100 + C6 000 . C7 . C8 -100 -200 -2.50 -2.00 -1.50 -100 -050 000 0.50 100 150 2.00 2.50 3.00 F WCP Oilphase-DBR 12 Job #: 200500058 I I Client: ConocoPhillips Field: Wildcat Scblumbepgep Well: Iapetus #2 Sand: I Table 7: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.02) Sample 1.02; Cylinder CSB 8611-QA; Depth 8722.2 ft. MD Component MW Flashed Gas Flashed liquid Monophasic Fluid I (g/mole WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 0.91 0.61 0.00 0.00 0.12 0.32 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 0.48 0.50 0.00 0.00 0.07 0.26 Methane 16.04 34.15 62.51 0.00 0.00 4.68 33.03 Ethane 30.07 7.26 7.08 0.00 0.00 1.00 3.74 Propane 44.10 18.58 12.37 0.16 0.74 2.68 6.88 I I - Butane 58.12 5.66 2.86 0.15 0.53 0.90 1.76 N - Butane 58.12 13.61 6.87 0.61 2.17 2.39 4.65 I - Pentane 72.15 5.49 2.23 0.70 2.01 1.36 2.13 I N - Pentane 72.15 5.15 2.10 0.92 2.64 1.50 2.35 C6 84.00 3.98 1.39 2.08 5.12 2.34 3.15 M-C-Pentane 84.16 1.05 0.36 0.82 2.02 0.85 1.15 I Benzene 78.11 0.06 0.02 0.04 0.11 0.05 0.07 Cyclohexane 84.16 0.35 0.12 0.48 1.19 0.47 0.63 C7 96.00 1.66 0.51 3.01 6.48 2.82 3.33 M-C-Hexane 98.19 0.59 0.18 1.33 2.80 1.23 1.42 I Toluene 92.14 0.08 0.02 0.26 0.59 0.24 0.29 C8 107.00 0.67 0.18 3.99 7.72 3.54 3.74 E-Benzene 106.17 0.01 0.00 0.14 0.26 0.12 0.13 I M/P-Xylene 106.17 0.01 0.00 0.29 0.56 0.25 0.27 a-Xylene 106.17 0.00 0.00 0.17 0.33 0.15 0.16 C9 121.00 0.24 0.06 3.82 6.53 3.33 3.11 I C10 134.00 0.03 0.01 4.32 6.67 3.73 3.15 C11 147.00 0.01 0.00 3.88 5.46 3.35 2.58 C12 161.00 0.00 0.00 3.73 4.80 3.22 2.26 C13 175.00 0.00 0.00 3.89 4.60 3.35 2.17 I C14 190.00 0.00 0.00 3.72 4.06 3.21 1.91 C15 206.00 0.00 0.00 3.59 3.61 3.10 1.70 C16 222.00 3.25 3.03 2.81 1.43 I C17 237.00 3.07 2.68 2.65 1.26 C18 251.00 3.24 2.67 2.80 1.26 C19 263. 00 2.89 2.27 2.49 1.07 I C20 275.00 2.50 1.88 2.15 0.89 C21 291. 00 2.39 1.70 2.06 0.80 C22 300.00 2.20 1.52 1.90 0.71 C23 312.00 2.12 1.40 1.83 0.66 I C24 324.00 1.96 1.25 1.69 0.59 C25 337.00 1.88 1.15 1.62 0.54 C26 349.00 1.77 1.05 1.53 0.50 I C27 360.00 1.75 1.01 1.51 0.47 C28 372.00 1.60 0.89 1.38 0.42 C29 382.00 1.65 0.89 1.43 0.42 I C30+ 946.56 25.64 5.61 22.13 2.64 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 29.36 206.93 113.12 MOLE RATIO 0.5283 0.4717 I WCP Oilphase-DBR 13 Job #: 200500058 I I I Client: ConocoPhillips Field: Wildcat Schlumberger Well: Iapetus #2 Sand: I Table 8: Calculated fluid Properties Sample 1.02; Cylinder CSB 8611-0A; Depth 8722.2 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid I Cn+ Composition Mass % Mole % Mass % Mole% Mass % Mole % C7+ 4.75 1.47 95.39 86.80 82.96 41.72 I C12+ 0.00 0.00 72.83 46.06 62.84 21.72 C20+ 45.45 18.34 39.21 8.65 C30+ 25.64 5.61 22.13 2.64 I Molar Mass C7+ 94.67 227.40 224.92 C12+ 327.24 327.24 I C20+ 512.69 512.69 C30+ 946.56 946.56 I Density C7+ 0.859 C12+ 0.893 0.893 C20+ 0.933 0.933 I C30+ 0.975 0.975 FI uid at 60°F 0.845 I Gas Gravity (Air = 1! 1.014 Dry Gross Heat Content (BTU/scf! I 1.702 I Wet Gross Heat Content (BTU/scf) 1,672 OBM Contamination Level (wt%) ISTO Basis I Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 206.93 206.93 I 946.56 I I Density (g/cm3) 0.845 0.975 Single Stage Flash Data I Original STO De-Contaminated GOR (scf/stb) 608 I STO Density (g/cm3) 0.845 I STO API Gravity 36.1 OBM Density (g/cm3) @60°F I I I I WCP Oilphase-DBR 14 Job #: 200500058 I I Client: Well: ConocoPhillips Iapetus #2 Field: Sand: Wildcat I Figure 3: Stock Tank Oil Chromatogram (Sample 1.02) Sample 1.02; Cylinder CSB 8611-QA; Depth 8722.2 ft MD I pA: 900 ~ I 100 ~ I 800 ~ I I I 700 ~ 500 ~ 500 ~ 400~ IJi 0 .,.. ('I Ü .,.. .,.. (1l ü ü .,.. .,.. 't l¡l Ü 0 .,.. ü .,.. ill I ü .,.. I ü 300 ~ 200 ~ o o , I 35 , I 40 , I 45 I I Figure 4: k-Plot for Equilibrium Check: (Sample 1.02) Sample 102; Cylinder CSB 8611-QA; Depth 8722.2 ft MD I I 300 2.50 +0 2.00 150 .. 100 <Ii> 0.50 .. C6 0.00 .. C7 -050 . C8 -100 -1.50 -200 .. ClO -2.50 -300 -200 -100 000 100 200 300 F I I I I I I WCP Oilphase-DBR 15 Job if: 200500058 I I Client: ConocoPhillips Field: Wildcat SchlumbePlep Well: Iapetus #2 Sand: I Table 9: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.03) Sample 1.03; Cylinder CS8 14185-0A; Depth 8722.2 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (gjmole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 0.95 0.63 0.00 0.00 0.13 0.34 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 0.47 0.50 0.00 0.00 0.07 0.27 Methane 16.04 33.76 62.09 0.00 0.00 4.65 33.37 Ethane 30.07 7.22 7.09 0.00 0.00 1.00 3.81 Propane 44.10 18.80 12.58 0.01 0.03 2.60 6.77 I I - Butane 58.12 5.76 2.92 0.03 0.11 0.82 1.62 N - Butane 58.12 13.68 6.94 0.18 0.65 2.04 4.03 I - Pentane 72.15 5.55 2.27 0.42 1.23 1.12 1.79 I N - Pentane 72.15 5.21 2.13 0.62 1.85 1.25 2.00 C6 84.00 4.00 1.41 1.83 4.66 2.12 2.91 M-C-Pentane 84.16 1.04 0.37 0.76 1.93 0.80 1.09 I Benzene 78.11 0.06 0.02 0.04 0.11 0.04 0.06 Cyclohexane 84.16 0.35 0.12 0.46 1.17 0.45 0.61 C7 96.00 1.62 0.50 2.95 6.58 2.76 3.31 M-C-Hexane 98.19 0.57 0.17 1.32 2.88 1.22 1.43 I Toluene 92.14 0.07 0.02 0.26 0.61 0.24 0.29 C8 1 07. 00 0.63 0.17 4.04 8.10 3.57 3.84 E-Benzene 106.17 0.01 0.00 0.14 0.28 0.12 0.13 I .MjP-Xylene 106.17 0.01 0.00 0.29 0.59 0.25 0.28 O-Xylene 106.17 0.00 000 0.18 0.35 0.15 0.16 C9 121.00 0.21 0.05 3.91 6.93 3.40 3.23 I C10 134.00 0.02 0.00 4.43 7.09 3.82 3.28 C11 147.00 0.00 0.00 3.98 5.80 3.43 2.68 C12 161. 00 0.00 0.00 3.82 5.09 3.30 2.36 C13 175.00 0.00 0.00 3.98 4.87 3.43 2.25 I C14 190.00 0.00 0.00 3.81 4.30 3.28 1.99 C15 206.00 0.00 0.00 3.67 3.82 3.17 1.77 C16 222.00 3.32 3.21 2.86 1.48 I C17 237.00 3.14 2.84 2.71 1.31 C18 251.00 3.31 2.83 2.86 1.31 C19 263.00 2.95 2.41 2.54 1.11 I C20 275.00 2.55 1.99 2.20 0.92 C21 291. 00 2.43 1.79 2.10 0.83 C22 300.00 2.25 1.61 1.94 0.74 C23 312.00 2.16 1.49 1.87 0.69 I C24 324.00 1.99 1.32 1.72 0.61 C25 337.00 1.98 1.26 1.71 0.58 C26 349.00 1.75 1.08 1.51 050 I C27 360.00 1.78 1.06 1.54 0.49 C28 372.00 1.64 0.94 1.41 0.44 C29 382.00 1.69 0.95 1.46 0.44 I C30+ 898.47 25.94 6.19 22.36 2.86 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 29.50 214.44 115.06 MOLE RATIO 0.5374 0.4626 I WCP Oilphase-DBR 16 Job #: 200500058 I I Client: ConocoPhíllips Field: Wildcat Scblumberger I Well: Iapetus #2 Sand: I Table 10: Calculated Fluid Properties Sample 1.03; Cylinder CS8 14185-0A; Depth 8722.2 ft. MD Properties Flashed Gas Flashed liquid Monophasic Fluid I Cn+ Composition Mass % Mole% Mass % Mole% Mass % Mole% C7+ 4.60 1.44 96.93 91.48 84.20 43.09 I C12+ 0.00 0.00 74.18 49.05 63. 96 22.69 C20+ 46.18 19.68 39.81 9.10 C30+ 25.94 6.19 22.36 2.86 I Molar Mass C7+ 94.32 227.22 224.83 C12+ 324.29 324.29 I C20+ 503.11 503.11 C30+ 898.47 898.47 I Density C7+ 0.859 C12+ 0.893 0.893 C20+ 0.933 0.933 I C30+ 0.976 0.976 Fluid at 60°F 0.850 I Gas Gravity (Air = 1) 1.019 Dry Gross Heat Content (BTU/scf) I 1,708 I Wet Gross Heat Content (BTU/scf) 1,679 OBM Contamination level (wt%) ISTO Basis Live Oil Basis I Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 214.44 214.44 I 898.47 I I Density (g/cm3) 0.850 0.976 Single Stage Flash Data I Original STO De-Contaminated GOR (scf/stb) 613 I STO Density (g/cm3) 0.850 I STO API Gravity 34.9 OBM Density (g/cm3) @60°F I I I WCP Oilphase-DBR 17 Job #: 200500058 I I I Client: ConocoPhillips Field: Wildcat Well: Iapetus #2 Sand: I Figure 5: Stock Tank Oil Chromatogram ¡Sample 1.(3) Sample 103; Cylinder CS814185-QA; Depth 8722.2 ft MD I - tJ pA: c LJ 900 ~ l! I 800 : I 700 : 600 : I 500 : 400~ I 300 : 200 : I 100 0 ' I ' I I 0 35 40 I Figure 6: k-Plot for Equilibrium Check ¡Sample 1.(3) Sample 1.03; Cylinder CS814185-QA; Depth 8722.2 ft MD I 5.00 4.00 . C3 I 300 '*' iC4 I 200 ~ nC4 100 <$> . C6 I 000 "" C7 <$> C8 -100 i' I -200 -2.50 -200 -1.50 -100 -0.50 000 0.50 100 1.50 200 2.50 300 I F I I WC!' Oilphase-DBR 18 Job #: 200500058 I I I I I I I I I Client: Well: I I I I I I I I I I WCP Oilphase-DBR ConocoPhillips Iapetus #2 Field: Sand: Wildcat Schlumbepger Table 11: Summary of Results of Sample 1.03 Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD Reservoir Conditions: Temperature: Summary of Fluid Properties: Bubble Point Pressure At T res Gas-Oil Ratio Si ngle-stage Flash: Total Differential Liberation: Total Separator Flash: Properties at 60°F Single-stage STO: Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: Compressibillity (Co): Density: Properties at Saturation Conditions Viscosity: 0.67 Compressibillity (Co): 10.2 Density: 0.719 Formation Volume Factor @Pres & Tres Single-stage Flash: 1.353 Total Differential Liberation: 1.327 Total Separator Flash: 1.296 Note: Standard conditions are 14.696 psi a and 60°F Pressu re: 3301 165 psia of 1,952 pSla 613 591 521 STO °API 34.9 36.4 36.7 sd/stb scf/stb sd/stb Gas Gravity (Average) 1.019 0.963 0.911 0.76 9.5 0.729 cP 10,B/psi g/cc cP 10'6¡psi g/cc @Psat & Tres 1.371 1.344 1.314 19 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Iapetus #2 Field: Sand: Wildcat Scblumbepger PVT Analysis on Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 It. MD Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 165.0°F and at a pressure of 9,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 12. The pressure-volume (P-V) plots of the CCE data are presented in Figure 7. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,952 psia at the reservoir temperature of 165.0 of. Also, calculated relative volume and oil compressibility is presented in Table 12. As seen in the table, the compressibility of this oil is 10.2 x 10e-6 1/psia at the saturation pressure. Table 12: Constant Composition Expansion at 165.0°F (Sample 1.03) Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD Pressure Relative Vol % Liquid % Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VINsat) (VINtotal) (g/cm3) (1 0-6/psi a) 1 9015 0.9417 0.764 7.0 2 8015 0.9485 0.758 7.4 3 7015 0.9557 0.753 7.8 4 6015 0.9634 0.747 8.2 5 5015 0.9716 0.740 8.7 6 4015 0.9803 0.734 9.1 Pi 3301 0.9868 0.729 9.5 8 3015 0.9895 0.727 9.6 9 2515 0.9944 0.723 9.9 10 2015 0.9994 0.720 10.2 Pb 1952 1.0000 100.0 100.0 0.719 10.2 12 1816 1. 0228 99.2 97.0 3.3 13 1773 1.0315 98.8 95.8 3.2 14 1693 1.0493 98.5 93.9 3.1 15 1555 1.0890 97.6 89.6 2.9 16 1435 1.1316 96.8 85.5 2.7 17 1251 1.2213 95.5 78.2 2.5 18 1053 1.3656 94.5 69.2 2.3 19 849 1.5758 93.2 59.1 2.3 20 708 1.8379 92.3 50.2 2.1 21 608 2.1051 91.6 43.5 2.0 WCP Oilphase-DBR 20 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Iapetus #2 2.2 2.0 ~ a.. ~ 1.6 i CD e = õ > CD ..Ëi 14 '" ä; a: WCP Oilphase-DBR Field: Sand: Wildcat Scblumberger Figure 7: Constant Composition Expansion at 165.0°F - Relative Volume Sample 1.03; Cylinder CSB 14185-0A; Depth 8722.2 ft. MD o o 1.8 o 1.2 1.0 0.8 o 4000 6000 8000 10000 2000 Pressure (psia) 21 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Iapetus #2 Field: Sand: Wildcat Schlumbepger Differential Vaporization Results of the differential vaporization test are presented in Tables 13 through 15 and graphically presented in Figures 8 through 9. Otl Phase Properties The oil properties such as oil formation volume factor, oil density and solution Gas-ail-ratios are summarized in Table 13. The oil formation volume factor is presented as afunction of differential pressures in Figure 8. As expected, the oil formation volume factor increases with decreasing pressure until the bubblepoint and subsequently, decreases with decreasing pressure. Solution GaR shows a decreasing trend with decreasing pressures (Figure 8). Oil densities were measured at the initial and the saturation pressure conditions and the intermediate values are calculated based on known mass and measured volume. The liquid density is measured to be 0.719 glcc at the bubblepoint pressure (Table 13). The liquid density decreases with decreasing pressure until the bubblepoint and increases with further decrease in pressure (Figure 8). Gas Phase Properties The calculated differentially vaporized gas properties are summarized in Table 14 and graphically presented in Figures 9. As seen in the table and figures, gas volume factor shows an increasing trend with a decrease in pressure. The Gas deviation factor and gas relative density values of the liberated gas tend to decrease slightly and then increase with a decreasing function of pressure. However, the gas viscosity that is calculated at the differential pressure steps from gas composition decrease with decrease in pressure as seen in Figure 9. Compositions Compositions of the differentially liberated gas at each differential pressure step are presented in Table 15 along with calculated molecular weights. Composition of the residual oil obtained from the differential vaporization is presented in Table 16. The API Gravity of the residual oil is measured to be 36.4. WCP Oilphase-DBR 22 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: ConoeoPhillips Iapetus #2 Field: Sand: Wildcat Schlumberger Table 13: Differential Liberation Test 165°F - Liquid Properties Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD Pressure (psi a) 1 9015 2 8015 3 7015 4 6015 5 5015 6 4015 Pi 3301 8 3015 9 2515 10 2015 Pb 1952 1 1715 2 1315 3 915 4 515 STO 14.696 Residual oil density at 60 of (glee) API Gravity WCP Oilphase-DBR Oil Volume Factor Bo (bbl/stb) 1.266 1.275 1.285 1.295 1.306 1.318 1.327 1.330 1.337 1.343 1.344 1.319 1.277 1.237 1.194 1. 055 0.843 36.4 Solution Gas GOR Rs (scf/stb) 591 591 591 591 591 591 591 591 591 591 591 535 438 336 230 o 23 Calculated Liquid Density (g/cm3) 0.764 0.758 0.752 0.746 0.740 0.734 0.729 0.727 0.723 0.720 0.719 0.726 0.739 0.750 0.762 0.799 Job #: 200500058 I I Client: ConocoPhillips Field: Wildcat SchlumbePlep Well: Iapetus #2 Sand: I Figure 8: Differential Liberation 165°F - Liquid Properties Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD I lAD :ë I ~ 1.30 0- -0-- .c ---0-- ~ --0 0 ID ... 0 I Ü 1.20 «I ... CD e = õ > 1.10 I is 1.00 f I 0 2000 4000 6000 8000 10000 700.0 I :ë 600.0 'Iii ~ -ª 500.0 I 0 '.;:I ~ 400.0 is :g 300.0 I t:I = .g 200.0 = Õ Vol 100.0 I 0.0 0 2000 4000 6000 8000 10000 I 0.82 I 0.8 .., 5 0.18 I ~ ~ 1) ï1i 0.16 CD c -= I 'g. 0.14 :::¡ 0.72 I OJ 0 2000 4000 6000 8000 10000 I Pressure (psia) WCP Oilphase-DBR 24 Job #: 200500058 I I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Iapetus #2 Field: Sand: Wildcat Schlumberger Table 14: Differential Liberation Test 165°F - Gas Properties Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD Pressure (1)Gas FVF Z (2)Predicted Vapor (3'Total FVF 8g Factor Gas Gravity Bt (psia) (ftJ/mm ftJ) Viscosity (cP) (air::1 ) (bbl/stb) Pb 1952 1.344 1 1715 8796 0.854 0.0158 0.691 1.406 2 1315 11713 0.872 0.0145 0.694 1.595 3 915 17368 0.900 0.0133 0.707 2.025 4 515 31964 0.932 0.0118 0.760 3.247 STO 14.696 1201659 1.000 0.0073 1.349 127.437 1. Bg = Reservoir gas at P & T per 1 million equivalent cubic ft. gas at 14.696 psia & 60°F 2. Lee & Gonzalez Correlation 3. Bt = Oil FVF + [(T otalliberated gas)*Gas FVF]*1 0.6 WCP Oilphase-DBR 25 Job #: 200500058 I Client: ConocoPhillips Field: Wildcat Schlumberger I Well: Iapetus #2 Sand: I Figure 9: Differential Liberation 165°F - Gas Properties Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD 1.04 I 1.00 E! I š .f 0.96 = CI ',¡: III I 1 0.92 CI III ~ III c:J 0.88 I ~ 0.84 0 500 1000 1500 2000 I 1.50 I 1.30 I 1I ~ 1.10 ~ '> III I ~ 0.90 III c:J 0.70 0 0 0 I 0.50 0 500 1000 1500 2000 I 0.0180 I 0.0160 ~ ~ 0.0140 E. I ~ "¡;¡ 8 0.0120 III :;: III I ~ 0.0100 0.0080 I 0.0060 0 500 1000 1500 2000 I Pressure (psial WCP Oilphase-DBR 26 Job #: 200500058 I I I Client: ConocoPhillips Field: Wildcat ScblumbePlep Well: Iapetus #2 Sand: I Table 15: Differential Liberation Test 165°F - Vapor & STO Composition (mol %) Sample 1.03; Cylinder CSB 14185-0A; Depth 8722.2 ft. MD Component MW Mol % at Specified Pressure (psia) Mol % at 14.696 psia I I (g/mol) 1715 1315 915 515 Vapor Residual Liquid Carbon Dioxide 44.01 0.55 0.59 0.65 0.76 0.64 0.00 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 1.80 1.17 1.07 0.50 0.06 0.00 Methane 16.04 85.98 85.87 84.24 79.39 37.21 0.00 Ethane 30.07 3.98 4.37 5.05 6.78 10.81 0.00 I Propane 44.10 3.99 4.27 5.00 7.11 22.73 1.10 I - Butane 58.12 0.68 0.71 0.80 1.13 4.90 0.83 N - Butane 58.12 1.44 1.47 1.65 2.30 11.03 3.24 I - Pentane 72.15 0.42 0.41 0.43 0.58 3.42 2.58 I N - Pentane 72.15 0.43 0.41 0.43 0.57 3.33 3.27 C6 84.00 0.32 0.30 0.29 0.37 2.48 5.51 M-C-Pentane 84.16 0.08 0.08 0.07 0.09 0.65 2.10 I Benzene 78.11 0.00 0.00 0.00 0.01 0.03 0.12 Cyclohexane 84.16 0.03 0.03 0.02 0.03 0.25 1.21 C7 96.00 0.14 0.14 0.12 0.15 1.10 6.44 I M-C-Hexane 98.19 0.05 0.05 0.04 0.06 0.36 2.76 Toluene 92.14 0.03 0.04 0.04 0.07 0.09 0.63 C8 107.00 0.06 0.06 0.05 0.07 0.54 7.43 E-Benzene 106.17 0.00 0.01 0.00 0.01 0.01 0.25 I M/P-Xylene 106.17 0.00 0.00 0.00 0.00 0.02 0.53 O-Xylene 106.17 0.00 0.00 0.00 0.01 0.01 0.32 C9 121.00 0.02 0.02 0.02 0.02 0.18 6.21 I C10 134.00 0.00 0.00 0.00 0.00 0.08 6.29 C11 147.00 0.00 0.00 0.00 0.00 0.03 5.15 C12 161.00 0.00 0.00 0.00 0.00 0.02 4.54 I C13 175.00 0.00 0.00 0.00 0.00 0.01 4.32 C14 190.00 0.00 0.00 0.00 0.00 0.00 3.83 C15 206.00 0.00 0.00 0.00 0.00 0.00 3.41 C16 222.00 0.00 0.00 0.00 0.00 0.00 2.93 I C17 237.00 0.00 0.00 0.00 0.00 0.00 2.53 C18 251.00 0.00 0.00 0.00 0.00 0.00 2.51 C19 263.00 0.00 0.00 0.00 0.00 0.00 2.12 I C20 275.00 0.00 0.00 0.00 0.00 0.00 1.75 C21 291.00 0.00 0.00 0.00 0.00 0.00 1.58 C22 300.00 0.00 0.00 0.00 0.00 0.00 1.42 I C23 312.00 0.00 0.00 0.00 0.00 0.00 1.31 C24 324.00 0.00 0.00 0.00 0.00 0.00 1.17 C25 337.00 0.00 0.00 0.00 0.00 0.00 1.10 C26 349.00 0.00 0.00 0.00 0.00 0.00 0.96 I C27 360.00 0.00 0.00 0.00 0.00 0.00 0.94 C28 372.00 0.00 0.00 0.00 0.00 0.00 0.84 C29 382.00 0.00 0.00 0.00 0.00 0.00 0.84 I C30+ 898.47 0.00 0.00 0.00 0.00 0.00 5.95 Total 100.00 100.00 100.00 100.00 100.00 100.00 Calculated MW 20.01 20.09 20.49 22.02 39.08 201.93 I Relative Density (air=1! 0.691 0.694 0.707 0.760 1.349 Dry Gross Heat Content (BTU/scf) 1181 1195 1216 1305 2229 I WCP Oilphase-DBR 27 Job #: 200500058 I Client: ConocoPhillips Field: Wildcat Scblumberger I Well: I a petus #2 Sand: I Table 16: Differential Liberation Test 165°F - STO Composition (wt % and mol %) Sample 1.03; Cylinder CSB 14185-0A; Depth 8722.2 ft. MD Component MW Residue liquid I (g/mol) (wt%) (mol%) Carbon Dioxide 44.01 0.00 0.00 Hydrogen Sulfide 34.08 0.00 0.00 I Nitrogen 28.01 0.00 0.00 Methane 16.04 0.00 0.00 Ethane 30.07 0.00 0.00 Prop a ne 44.10 0.24 1.10 I I - Butane 58.12 0.24 0.83 N - Butane 58.12 0.93 3.24 I - Pentane 72.15 0.92 2.58 I N - Pentane 72.15 1.17 3.27 C6 84.00 2.29 5.51 M-C-Pentane 84.16 0.88 2.10 I Benzene 78.11 0.04 0.12 Cyclohexane 84.16 0.50 1.21 C7 96.00 3.06 6.44 M-C-Hexane 98.19 1.34 2.76 I Toluene 92.14 0.29 0.63 C8 107.00 3.94 7.43 E-Benzene 106.17 0.13 0.25 I M/P-Xylene 106.17 0.28 0.53 Q-Xylene 106.17 0.17 0.32 C9 121.00 3.72 6.21 I C10 134.00 4.17 6.29 C11 147.00 3.75 5.15 C12 161.00 3.62 4.54 C13 175.00 3.75 4.32 I C14 190.00 3.60 3.83 C15 206.00 3.47 3.41 C16 222.00 3.22 2.93 I C17 237.00 2.96 2.53 C18 251.00 3.12 2.51 C19 263.00 2.76 2.12 I C20 275.00 2.38 1.75 C21 291.00 2.28 1.58 C22 300.00 2.10 1.42 C23 312.00 2.02 1.31 I C24 324.00 1.87 1.17 C25 337.00 1.84 1.10 C26 349.00 1.67 0.96 I C27 360.00 1.67 0.94 C28 372.00 1.54 0.84 C29 382.00 1.60 0.84 I C30+ 898.47 26.46 5.95 Total 100.00 Calculated MW 201.93 I WCP Oilphase-DBR 28 Job #: 200500058 I I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Iapetus #2 Field: Sand: Wildcat Scblumberger Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 165°F. These values as a function of selected pressure steps are summarized in Table 17. The liquid phase viscosity values are graphically presented in Figure 10. As seen in the figures and as expected. the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 17: Reservoir Fluid Viscosity 165°F Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD Pressure Viscosity @ Tres (psia) (cP) 1 2 3 4 5 6 7 Pi 9 10 11 Pb 13 14 15 16 17 18 19 20 STO WCP Oilphase-DBR 10653 9044 8037 7037 6030 5015 4039 3301 3019 2535 2034 1952 1770 1682 1582 1486 1394 1256 1136 928 14.696 1.34 1.16 1.07 1.00 0.93 0.87 0.80 0.76 0.74 0.71 0.68 0.67 0.69 0.69 0.70 0.72 0.74 0.77 0.80 0.86 2.47 29 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Well: Iapetus #2 2.50 ii:" E. i=" '¡;¡ 1.5 o u en :;: 0.5 WCP Oilphase-DBR Field: Sand: Wildcat Schlumbepgep Figure 10: Reservoir Fluid Viscosity 165°F Sample 1.03; Cylinder CSB 14185-0A; Depth 8722.2 ft. MD 3 2 o o 2000 4000 8000 10000 12000 6000 Pressure (psia) 30 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Iapetus #2 Field: Sand: Wildcat SchlumbePlep Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 18 - 20. The fluid properties (i.e., GOR, density and oil formation volume factor) are presented in Table 18. Multi-stage separation test conditions are: STAGE 1 165 psia 100 of STAGE 2 30 psia 170 of STAGE STO 14.696 psia 60 of As seen in Table 18, the GOR value obtained from the multi-stage separation test is 521 SCF/STB and the formation volume factor is 1.314. The compositional analyses of separator gas and tank gas are summarized in Table 19 and the composition of tank liquid is tabulated in Table 20. The total dry gross heat content of the separation gases is calculated to be 1,529 BTU/scf whereas the total wet gross heat content is calculated to be 1,503 BTU/scf. With reference to the assumption made in "The Properties of Petroleum Fluids" (McCain, 1990). the assumption made in generating reservoir fluid properties from a PVT study is that at pressures below the bubblepoint, the process in the reservoir can be mimicked by differential vaporization, while the process in the wellbore is simulated by the separator test. Hence, fluid properties at pressures below saturation pressure can be calculated by combining the data from the differential vaporization and a separator test. The differential vaporization flashes that occur in the reservoir at the reservoir temperature (165.0°F) would liberate more gas than flashes that occur during multi-stage separation test conducted at variable temperatures lower than the reservoir temperature. This expectation held true in this study and the overall solution GOR and Bo did see a significant decrease when the liberated data were combined with results of the separation test. Results are summarized in Table 21 and graphically presented in Figures 11 and 12. As seen in these figures, GOR and Bo values are decreased as the liberated reservoir oil is produced at the surface. WCP Oilphase-DBR 31 Job #: 200500058 I I Client: Well: Wildcat Scblumbepuep ConocoPhillips Iapetus #2 Field: Sand: I I Table 18: Multi-Stage Separation Test Vapor & Liquid Properties Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD STAGE Pb STAGE 1 STAGE 2 PROPERTY I Pressure (psia) 1952 165 30 Temperature (OF) 165 100 170 Liq. Den (g/cm3) 0.719 0.796 0.799 Yap. Gravity" 0.725 1.544 Yap. Mwt 20.99 44.71 Yap HeatVal.b 1236 2530 GORe 403 117 GORd 364 111 Sep. FVF" 1.314 1.107 1.053 a) Calculated, at 60°F (air=1) b) Calculated, Dry basis BTU/scf c) scf gas/bbl of oil at STD conditions d) scf gas/bbl of oil at separator conditions e) fluid volume at sep conditions/fluid volume at STD conditions I I I I Residual oil density at standard conditions 0,841 g/cc Sep gas gravity (average) Sg = }:RjSgjl£Rj 0.911 Where: R: GOR (scf gas/bbl of oil at STD conditions), j: separator stages Sep gas gross heating value (a Le =}:R¡*Le¡I£Ri 1529 BTU/scf (dry basis) Where: R: GOR (scf gas/bbl of oil at STD conditions), j: separator stages I SEPARATION TEST SUMMARY "Total Separation Test GOR 521 Separation Test STO Gravity 36.7 bSeparation Test FVF 1.314 a) scf gas/bbl of condensate at STD conditions b) Fluid volume at Psat & Tres/Fluid volume at STD I I I I I I I I I WCP Oilphase-DBR 32 STAGE STO 14.696 60 0.841 1.788 51.78 2911 1 1 1.000 Job #: 200500058 I I Client: ConocoPhillips Field: Wildcat Schlumbepgep Well: Iapetus #2 Sand: I Table 19: Multi-Stage Separator Test Vapor Composition (mol %) Sample 1.03; Cylinder CSB 14185-0A; Depth 8722.2 ft. MD Component MW Mole% I (g/mol) STAGE 1 STAGE 2 STAGE STO Carbon Dioxide 44.01 0.73 0.47 0.32 Hydrogen Sulfide 34.08 0.00 0.00 0.00 I !'J itrogen 28.01 1.43 0.40 0.20 Methane 16.04 81.25 19.34 12.23 Ethane 30.07 6.44 10.73 7.17 Propane 44.10 6.24 31.27 27.42 I I - Butane 58.12 0.89 7.51 8.24 N - Butane 58.12 1.73 17.27 20.99 I - Pentane 72.15 0.40 5.15 7.57 I N - Pentane 72.15 0.38 4.44 6.92 C6 84.00 0.24 2.18 4.61 M-C-Pentane 84.16 0.05 0.46 1.15 I Benzene 78.11 0.00 0.03 0.06 Cyclohexane 84.16 0.02 0.13 0.37 C7 96.00 0.09 0.40 1.52 M-C-Hexane 98.19 0.03 0.11 0.47 I Toluene 92.14 0.02 0.02 0.12 C8 107.00 0.03 0.07 0.44 E-Benzene 106.17 0.00 0.00 0.03 I M/P-Xylene 106.17 0.00 0.00 0.01 O-Xylene 106.17 0.00 0.00 0.03 C9 121.00 0.01 0.01 0.10 I C10 134.00 0.00 0.00 0.01 C11 147.00 0.00 0.00 0.01 C12 161.00 0.00 0.00 0.00 C13 175.00 0.00 0.00 0.00 I C14 190.00 0.00 0.00 0.00 C15 206.00 0.00 0.00 0.00 C16 222.00 0.00 0.00 0.00 I C17 237. 00 0.00 0.00 0.00 C18 251.00 0.00 0.00 0.00 C19 263.00 0.00 0.00 0.00 I C20 275.00 0.00 0.00 0.00 C21 291.00 0.00 0.00 0.00 C22 300.00 0.00 0.00 0.00 I C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 0.00 C25 337.00 0.00 0.00 0.00 C26 349.00 0.00 0.00 0.00 I C27 360.00 0.00 0.00 0.00 C28 372.00 0.00 0.00 0.00 C29 382.00 0.00 0.00 0.00 I C30+ 898.47 0.00 0.00 0.00 Total 100.00 100.00 100.00 MW 20.99 44.71 51.78 I Relative Density (air=1) 0.72 1.54 1.79 Dry Gross Heat Content (BTU/scf) 1236 2530 2911 WCP Oilphase-DBR 33 Job #: 200500058 I I I Client: ConocoPhillíps Field: Wildcat SchlumbePlep Well: Iapetus #2 Sand: I Table 20: Multi-Stage Separator Test Residual Liquid Composition (wt% and mol %) Sample 1.03; Cylinder CSB 14185-0A; Depth 8722.2 ft. MD COMPONENT MW Residual Liquid I (g/mol) (wt%) (mol%) Carbon Dioxide 44.01 0.00 0.00 Hydrogen Sulfide 34.08 0.00 0.00 I Nitrogen 28.01 0.00 0.00 Methane 16.04 0.00 0.00 Ethane 30.07 0.00 0.00 Propane 44.10 0.15 0.67 I I - Butane 58.12 0.19 0.66 N - Butane 58.12 0.78 2.72 I - Pentane 72.15 0.89 2.50 I N - Pentane 72.15 1.10 3.09 C6 84.00 2.27 5.45 M-C-Pentane 84.16 0.88 2.11 I Benzene 78.11 0.05 0.12 Cyclohexane 84.16 0.51 1.22 C7 96.00 3.11 6.54 M-C-Hexane 98.19 1.37 281 I Toluene 92.14 0.28 0.61 C8 107.00 4.03 7.60 E-Benzene 106.17 0.14 0.26 I M/P-Xylene 106.17 0.29 0.55 a-Xylene 106.17 0.17 0.32 C9 121.00 3.83 6.37 I C10 134.00 4.29 6.46 C11 147.00 3.83 5.26 C12 161.00 3.69 4.62 C13 175.00 3.83 4.42 I C14 190.00 3.68 3.91 C15 206.00 3.55 3.48 C16 222.00 3.25 2.95 I C17 237.00 3.05 2.59 C18 251.00 3.22 2.58 C19 263.00 2.86 2.20 I C20 275.00 2.47 1.81 C21 291.00 2.37 1.64 C22 300.00 2.18 1.46 I C23 312.00 2.09 1.35 C24 324.00 1.94 1.21 C25 337.00 1.88 1.12 C26 349.00 1.75 1.01 I C27 360.00 1.74 0.97 C28 372.00 1.60 0.87 C29 382.00 1.65 0.87 I C3O+ 898.47 25.04 5.62 Total 100.00 100.00 MW 201.66 I WCP Oilphase-DBR 34 Job #: 200500058 I I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Field: Wildcat Schlumberger Well: Iapetus #2 Sand: Table 21: Separation Corrected GOR and FVF Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD Pressure Measured GOR Corrected GOR Measured FVF Corrected FVF (psia) (scf/bbl) (scf/bbl) 1 9015 591 521 1.266 1.237 2 8015 591 521 1.275 1.246 3 7015 591 521 1. 285 1. 255 4 6015 591 521 1.295 1.266 5 5015 591 521 1.306 1.276 6 4015 591 521 1.318 1.288 Pi 3301 591 521 1.327 1.296 8 3015 591 521 1.330 1.300 9 2515 591 521 1.337 1.306 10 2015 591 521 1.343 1.313 Pb 1952 591 521 1.344 1.314 1 1715 535 467 1.319 1.289 2 1315 438 372 1277 1.248 3 915 336 272 1.237 1.209 4 515 230 169 1.1 94 1.167 STO 14.696 0 1.055 1.031 WCP Oilphase-DBR 35 Job #: 200500058 Client: ConocoPhillips Well: Iapetus #2 I I I I I I I I I I I I I I I I I I I Field: Wildcat Sand: Figure 11: Separation Corrected Oil volume Factor (Bo) Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD -o-Measured FVF Corrected FVF 140 1.35 1.30 125 ..... 1.20 æ: 115 1.10 105 1.00 0 2000 4000 6000 8000 10000 Pressure (psiaj Figure 12: Separation Corrected Solution GOR (Rs) Sample 1.03; Cylinder CSB 14185-QA; Depth 8722.2 ft. MD --e-- Measured GOR Corrected GOR 700.0 600.0 500.0 ::E ... ;;::, '" 400.0 $ a:: <::) CI e: 300.0 .g "" õ (I) 200.0 100.0 00 0 WCP Oilphase-DBR o 00 o o o o o o 2000 4000 6000 8000 10000 Pressure (psia) 36 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: API Gravity Bg Bo CCE DV GLR GOR LO n OBM P Pb PV Pi R Rs T V Vr STL STO %,wjw Z ConocoPhillips Iapetus #2 Doyon #19 Wildcat Field: Sand: Job#: SchlumbePlep 200500058 Appendix A: Nomenclature and Definitions American Petroleum Institute gravity Gas formation volume factor Oil formation volume factor Constant composition Expansion Differential Vaporization Gas Liquid Ratio Gas Oil Ratio Live Oil Number of moles Oil Based Mud Absolute pressure Bubble point pressure Pressure-Volume Method Initial Reservoir Pressure Universal gas constant Solution gas oil ratio Temperature Volume Relative volume Stock Tank Liquid Stock Tank Oil Weight Percent Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid. Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses, densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems" by M.B. Standing Compressibility in constant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation (Gas deviation factor, Z=l) The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. · A positive index indicates scaling tendencies. · A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. WCP Oilphase-DBR 37 Job It: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: WCP Oilphase-DBR ConoeoPhillips Iapetus #2 Doyon #19 Field: Sand: Job It. Wildcat 200500058 Schlumbepgep Appendix B: Molecular Weights and Densities Used Components MW Density (glee) 0.827 0.993 0.808 0.300 0.356 0.508 0.567 0.586 0.625 0.631 0.660 0.753 0.884 0.781 0.688 0.773 0.871 0.749 0.870 0.866 0.884 0.768 0.782 0.793 0.804 0.815 0.826 0.836 0.843 0.851 0.856 0.861 0.866 0.871 0.876 0.881 0.885 0.888 0.892 0.896 0.899 0.902 C02 H2S N2 C1 C2 C3 I-C4 N-C4 I-C5 N-C5 C6 MCYC-C5 BENZENE CYCL -C6 C7 MCYCL-C6 TOLUENE C8 C2-BENZEN M&P-XYLEN O-XYLENE C9 C10 C11 C12 C13 C14 C15 C16 C17 C18 C19 C20 C21 C22 C23 C24 C25 C26 C27 C28 C29 44.01 34.08 28.013 16.043 30.07 44.097 58.124 58.124 72.151 72.151 84 84.16 78.11 84.16 96 98.19 92.14 107 106.17 106.17 106.17 121 134 147 161 175 190 206 222 237 251 263 275 291 300 312 324 337 349 360 372 382 38 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Iapetus #2 Doyon #19 Field: Sand: Job#: Wildcat 200500058 Schlumberger Appendix C: EQUIPMENT fluid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies. A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer. This unit in conjunction with GC analysis (see below) provides the full fluid compositional analysis, GOR, density at sampling P& T corrected to standard conditions. The JEFRI gasometer consists of a motor-driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L. The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 psia) and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography (GC). Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FID). In this system, separation of individual components is carried out in a 30m long, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range, the components eluted are from C1 to C36 along with naphthenes and aromatics components. Based on the physical properties, these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas (helium) through the column. With prior knowledge of the amount of "retention" for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching "retention" times. The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns. The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas. The molecular sieve is used to achieve separation of the light gaseous components (nitrogen, oxygen, and methane) while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis. This column is capable of achieving separation of components up to C12+, along with the associated naphthenes and aromatics that are lumped into the C6+ fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector (TCD) while the C5+ components are analyzed for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns, and hence, allowing for the correct separation and analysis of the injected gas. fluid Volumetric (PVT) and Viscosity Equi¡Jment WCP Oilphase-DBR 39 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Field: Well: Iapetus #2 Sand: Installation: Doyon #19 Job #: 200500058 The preliminary saturation pressure, constant composition expansion (CCE). differential vaporization (OV), multi-stage separation tests (MSST) are measured using a pressure-volume-temperature (PVT) apparatus. The PVT apparatus consists of a variable volume, visual JEFRI PVT cell. The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm. An especially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury-free operation. The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc. The magnetically coupled impeller mixer, mounted on the bottom end cap of the PVT cell. allow quick equilibration of the hydrocarbon fluid. The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. Wildcat Schlumberger A variable volume JEFRI displacement pump controls the volume, and hence, the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell is mounted on a special bracket which can be rotated 360°. The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum resistance thermal detector (RTO) and displayed on a digital indicator with an accuracy of 0.2°F. The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to ± 0.1 % of full scale. The temperature and pressure ratings of this PVT system are 15,000 psi (103 MPa) and 360°F (182°C). The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with a high-resolution video camera that minimizes parallax in readings and uses a high- resolution encoder producing both linear and volumetric readings. The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test. The floating piston is designed in the shape of a truncated cone with gradually tapered sides, which allows measurement of extremely small volumes of liquid (0.005 cc) corresponding to roughly 0.01 % of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer, which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston. Viscosity is measured by the motion of the piston, which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe. The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig. The accuracy is ±1.5% of full scale for each individual piston range. The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. WCP Oilphase-DBR 40 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Field: Well: Iapetus #2 Sand: Installation: Doyon #19 Job #: 200500058 The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation (OHSP) due to changes in the temperature, pressure and/or composition. These fiber optic probes are mounted across the windows of the visual cell. The principle behind the measurement is based on the transmittance of a laser light in the near infra red (NIR) wavelength through the test fluid undergoing temperature, pressure or the fluid composition changes. In this system, a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation, isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies. The process variables (i.e., temperature, pressure, solvent volume, time and transmitted light power level) are recorded and displayed from the detector. The fiber optic light transmittance system referred to here that detects the conditions of OHSP is termed as the light scattering system (LSS). Wildcat Schlumberger High pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions. The filter manifold used is rated for 10,000 psia. The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. WCP Oilphase-OBR 41 Job #: 200500058 I I I I I I I I I I I I I I I I I I I CI ient: Well: Installation: ConocoPhillips Iapetus #2 Doyon #19 Field: Sand: Job#: Wildcat 200500058 Schlumberger Appendix D: PROCEDURE Fluids Preparation and Validation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio (GOR). The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid. The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids (gas and liquid) are then subjected to compositional analysis using gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values. In addition, a sub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently, a quick P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The CCE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps. At each pressure step, the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium. Total fluid volume (with visual observation of a single or two phase condition in the cell) is measured at each pressure stage, and subsequently, a pressure-volume (P-V) plot is created identifying the phase state at each P-V condition. The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute live oil compressibility above the bubblepoint pressure and relative oil volumes over the entire pressure range. Differential Vaporization Procedure Subsequent to the completion of the CCE experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A differential vaporization (OV¡ experiment is then conducted by incrementally reducing the pressure in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a OV test is described below: · The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the OV test. · The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the OV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. · The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) · The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. Multi-Stage Separation Test WCP Oilphase-DBR 42 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Field: Well: Iapetus #2 Sand: Installation: Doyon #19 Job #: 200500058 Subsequent to the completion of the DV experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A multi-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a separation test is described below: · The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the separation test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. Wildcat Scblumb8Pgep . · The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity, a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. A portion of the live reservoir fluid used in the DV test is then transferred into a high-pressure high-temperature electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer, flashing of oil takes place, and hence, the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps. At each pressure point, the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration. The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock- Tank D/I (STD; Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. Asphaltene, Wax and Sulfur Content Measurements Asphaltene content of stock-tank oil samples is conducted using the IP-143 (French Institute of Petroleum) procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil. Wax content of the STO is measured using UOP (Universal Oil Product) 46-64 procedure. The sulfur content of the STO is measured using ASTM D 2494 procedure. . All other STO analysis were measured according to industrial standards. WCP Oilphase-DBR 43 Job #: 200500058 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Iapetus #2 Doyon #19 Field: Sand: Job#: Wildcat 200500058 Scblumberger SAR(PjA Analysis A spinning band distillation was carried out on the original sample to establish two fractions. The initial boiling point to 300°C fraction was then analysed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes). This method dissolves the fraction in an equal weight of toluene, then 40 volumes of pentane were added to precipitate the insoluble portion of the sample. The precipitate was filtered, dried and weighed. The solvent was removed from the soluble portion of the sample, which was referred to as the maltenes. The maltenes were then redissolved in pentane and were chromatographically separated into saturates, aromatics and resins (polars) fraction by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents were then removed from each fraction and the amount of material weighed. The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High- Temperature High Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. WCP Oilphase-DBR 44 Job #: 200500058