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Home My WebLink About204-008TT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Exploration - Image logs Backlog DATE: 03/02/2024 Transmitted: North Slope, Exploration – Spark 4 Via hard drive data drop 1 of 1 Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 204-008 T38549 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 08:15:54 -09'00' • • -~, ,,. _. ~~„> ~` ~ _.~ ~ - ~~ ~;; MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicheiCvrPgs_Inserts\Microfilm Marker.doc }> ~ 'J...Jr.ð ~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 S,,~¿ A(ð~ ~"t Permit to Drill 2040080 Well Name/No. SPARK 4 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20480-00-00 /' ,,/ Completion Date 4/13/2004 ~ MD 8005 TVD 7997 Completion Status P&A Cu rrent Status P&A UIC N REQUIRED INFORMATION Directional surv.t.W__ Mud Log Yes Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes/NeuIlDens, Dipole Sonic, CMR, MDT (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ --~ C Asc Directional Survey 5/24/2004 , Directional Survey 0 0 5/24/2004 ~ I nd uction/Resistivity Blu 117 8005 Open 5/24/2004 ROP/DGRlEWR ~C Density Blu 117 8005 Open 5/24/2004 DGRlCTN/SLD/ACAL Lis 10860 See Notes 2653 7936 Open 5/24/2004 LDWG LWD Log Formation Micro Ima 5 Col 2 6650 8002 Open 9/15/2004 GRlCaliper ---{D C Pds 12698 Sonic 6500 8000 Open DIPOLE SHEAR SONIC IMAGER, DSI, FMI, CMR, MDT ~ Sonic Blu 6500 8000 Open DIPOLE SHEAR SONIC IMAGER, DSI, FMI, CMR, ~ MDT, DSN 12698 C Pds 12699 Magnetic Resonance 2900 3300 COMBINABLE MAGNETIC . RESONANCE TOOL, SANSTONE MODE / W/EPM Formation Tester Blu 2914 3023 MODULAR FORMATION ~ DYNAMIC TESTER ) f4; ~ '-( Sonic Blu 2522 4200 Open DIPOLE SONIC IMAGER, LOWER DIPOLE/P &S/ STONELEY ~ Magnetic Resonance Blu 2900 3300 COMBINABLE MAGNETIC RESONANCE TOOL, SANSTONE MODE W/EPM Y Magnetic Resonance Blu 2 7012 7986 MRT/GAMMA RAY/CALIPER DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040080 Well Name/No. SPARK 4 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20480-00-00 MD 8005 TVD 7997 Completion Date 4/13/2004 Completion Status P&A Current Status P&A UIC N ~ Sonic Blu 2 6650 8002 DIPOLE SONIC IMAGING TOOL, GAMMA RAY, ~ CALIPER Sonic Blu 2 7725 7742 MODULAR DYNAMICS .Af> FORMATION TESTER, It ~,u\l '1 C Pds 12700 Sonic 2522 4200 DIPOLE SONIC IMAGER, LOWER DIPOLE/P & ~ S/STONELEY . C Pds 12701 Sonic 2914 9625 modular formation, dynamic tester ~ Sample 0 0 10/8/2004 OmniLabs Core Analysis ~ Report w/CD 1 3 q 0 I Rpt Report: Final Well R 0 0 11/23/2004 Final Well Report w/CD 13 f CfCf See Notes 0 0 1/26/2005 PVT Study Report w/CDROM ¡ y.?~Û ..see NCit",.. n 0 e:- Notes 7711 7804 4/8/2005 CORE PHOTOS-WHITE LlGHT-CONOCO- PHILLlPS-MD (4) ~es 7711 7804 4/8/2005 CORE PHOTOS-UV CONOCO-PHILLlPS-MD (4) Well Cores/Samples Information: Name Cuttings Interval Start Stop 120 8005 Sent Sample Set Received Number Comments 4/13/2004 ~6 (.Qo6re chips 7711 to 7804 . ADDITIONAL INFORMATION \/N Chips Received? ~/ N (~ Daily History Received? Y/N Well Cored? Formation Tops (jN Analysis Received? ---- Comments: DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040080 Well Name/No. SPARK 4 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20480-00-00 MD 8005 TVD 7997 c~ate 4/13/2004 Completion Status P&A Current Status P&A UIC N Date: / S .~ 2 ~.\ Þ Compliance Reviewed By: . . . eonocó'Pt.illips . TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Spark 4 PERMIT 204-008 DATE: 4/8/2005 TO: Helen Warman AOGCC 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 Transmitted: Spark 4, NPRA, Alaska 501032048000 Hardcopy _ Spark 4, Omni Core Labs; White Light and UV Core photos; 7711-7804' md ¿2[)4- CTO SS 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 ~~~ ~r:gWil n~vé IG1~ Dare: ~ ~r Retu 8ceipt to: ). ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 I Sandra.D.Lem,ke@conocophi//ips.com ~ ·CO~III!b2 . TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Spark 4 PERMIT 204-008 DATE: 1/25/2004 TO: Helen Warman AOGCC 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 Transmitted: Spark 4, NPRA, Alaska 501032048000 1Þf'1C{(\G Hardcopy Report & CDROM digital data (2 copies each) ---=::::Spark 4, Schlumberger Oil Phase DBR PVT Study Report (Fluid Analysis on MDT samples); 11/30/2004; Report #200400111 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 Data marked proprietary is indefinitely confidential and is available only to owners and partners CC: ~reg WiISO. "o/CPAI GJtoI~ /¡ 1 Receipt: . ~ U µÁJvv1 ( ~, . Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: 1I-V /o.r GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 I Sandra.D.Lem,kerf;iJconocophillips.com ;¿ù'1- O@ ~ . ~ .. . . eonocó'Phillips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Spark 4 PERMIT 204-008 DATE: 10/8/2004 TO: Helen Warman State of Alaska -AOGCC 333 W. ih, Suite 100 Anchorage, Alaska Transmitted: Spark 4, NPRA, Alaska 501032048000 Hardcopy report _ Schlumberger Oil phase Sampling Services - Spark 4 - Formation Dynamics Tester Field Operations Report; Job CAL 069; testing April 10-16, 2004 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 "On behalf of itself and other owners, ConocoPhillips Alaska, Inc. submits the attached data for the Spark 4 Well, Drilling Permit No.204-008 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to ap Iy those provisions t i data in the future." CPAI LEGAL 2/ 2004 ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: l(of GIS-Technical Data Management I ConocoPhillips I Anchorage/ Alaska I Ph: 907.265.6947 I Sandra.D.Lem,ke@conocophillips.com . C~illips . TRANSMITTAL CONFIDENTIAL DA TA RECEIVED OCT 0 82004 Ala3iŒ CUllS, CQmmí3ìJíôn MIChorage FROM: TO: Howard Okland State of Alaska -AOGCC 333 W. th, Suite 100 Anchorage, Alaska Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Spark 4 PERMIT 204-008 DATE: 10/8/2004 Transmitted: Spark 4, NPRA, Alaska 501032048000 * l)q~ ( Hardcopy report w/CDROM digital data _ Omni Labs, Spark 4 Conventional Core Analysis, 9/7/2004; A-87001 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 "On behalf of itself and other owners, ConocoPhillips Alaska, Inc. submits the attached data for the Spark 4 Well, Drilling Permit No.204-008 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future." CPAI LEGAL 2/4/2004 CC: Greg "jftn, CPAI ~eolDß.istf í/ { Receipt: /1· (J U ~v--J' (\Í~_.. Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S, Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: f Ò ~Àð'~ \./{ Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IS-Tech Data Management 907.265.6947 Sandra. D. Lemke@ConocoPhillips.com "Î f"\ U .1\ \) ¿/\ \.J 1- 0 Dð It . Co~illips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Spark 4 PERMIT 204-008 DATE: 9/10/2004 TO: Howard Okland State of Alaska -AOGCC 333 w. ¡th, Suite 100 Anchorage, Alaska Transmitted: RECEIVED SEP 1 5 2004 Alp~h Oil ~ G"'~ r.An~_ Commission Anchorage Spark 4, NPRA, Alaska 501032048000 Hardcopy Color Log data -1 print each _ Schlumberger Fullbore Microlmaging Tool/GR/Caliper (run 2); 4/10/2004 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 "On behalf of itself and other owners, ConocoPhillips Alaska, Inc. submits the attached data for the Spark 4 Well, Drilling Permit No.204-008 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future." CPAI LEGAL 2/4/2004 CC: Greg Wi'Pf'¡CPAle'ß'~"i.st f, Receipt: I~ '!..i:)' Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: 1\' 14J ~'vl Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IS-Tech Data Management 907.265.6947 Sandra. D. Lemke@ConocoPhillips.com ') 6 v/ - 0 ~ ~ l,t!d ( f:·/.t r e . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, rJØ11,O\ll10l\- P.I. Supervisor ~~-( DATE: August 13, 2004 FROM: Jeff Jones, Petroleum Inspector SUBJECT: Location Clearance Well Site Inspections Exploration NPRA Placer 2 PTD 2040330 Spark 4 PTD 2040080 Spark 8 August 13, 2004: I traveled with CPAI representative Chris Brown via helicopter to inspect Conoco-Phillips Alaska Inc.'s (CPAI) Placer #2, Spark #4 and Spark #8 exploration well sites for the purpose of final location clearances. The Placer #2 exploration well has been plugged & abandoned and a site inspection revealed several large chunks of concrete on the surface that should be buried or removed prior to final approval. A small amount of "ponding", depressions left from drilling activities filling with water, was visible at this site and may require a small amount of additional fill material prior to approval. The Spark #4 exploration well has been plugged and abandoned and a site inspection revealed several large cement chunks that should be buried or removed and a "ponding" condition that will require more fill to meet the AOGCC requirements for final approval. The Spark #8 exploration well was not drilled but a conductor hole was drilled and subsequently filled in. This site also exhibited a "ponding" condition and will require additional fill material prior to final approval. During this trip I also was able to inspect the Carbon #1 and Placer #1 wellheads, which were wrapped with a black plastic to protect them from nesting ravens. I noted six old 55-gallon drums near the Carbon #1 wellhead of unknown origin. Chris Brown indicated she would have the substandard items corrected and notify the AOGCC when completed. Summary: I inspected CPAl's exploration well sites Placer #1 & #2, Carbon #1, and Spark #4 & #8 in the NPRA. e e Placer #1 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC Inspector Jeff Jones August 13, 2004 I Placer #1 wellhead I Placer #2 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC Inspector Jeff Jones August 13, 2004 Placer #2 - cement chunks, ponding 2 ., - ~ Spark #4 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC Inspector Jeff Jones August 13, 2004 I Spark #4 location Spark #4 - cement chunks, ponding 3 e . , Spark #8 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC Inspector Jeff Jones August 13, 2004 Spark #8 - conductor only; ponding Carbon #1 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC Inspector Jeff Jones August 13, 2004 Carbon #1 wellhead 4 It . Co~illips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Spark 4 PERMIT 204-008 DATE: OS/21/2004 TO: Howard Okland State of Alaska -AOGCC 333 W. th, Suite 100 Anchorage, Alaska Transmitted: Spark 4, NPRA, Alaska 501032048000 Diqital data _ Sperry Sun LDWG LWD log data; Image views and Directional Survey 4/10/2004 ~tz ~ 1)MJ Report _ Halliburton - Directional survey report - hardcopy l~ f)¡;) 1M ¡, Hardcopy Log data - 1 print each _ Sperry Sun MWD: ROP/DGR/EWR, 2"&5" MD f/.,~ /0 eM l DGR/CTN/SLD/ACAL 2"&5" MD (Lt1IJ r^ \ IO~'ó 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 Data marked proprietary is indefinitely confidential and is available only to owners and partners "On behalf of itself and other owners, ConocoPhillips Alaska, Inc. submits the attached data for the Spark 4 Well, Drilling Permit No.204-008 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future." RE.. CE IVE D CPAI LEGAL 2/4/2004 MAY 242004 CC: Greg W)}ffn, cPl}!. n, CP Geol~~1 Receipt: . ~ C)~lf..cj Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: Alaska Oil & Gas Cons. Commission Anchorage Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IS-Tech Data Management 907.265.6947 Sandra. D. Lemke@ConocoPhillips.com ~()t.f -.O()~ e ConocÓÂ,illips e Paul Mazzolini Exploration DrillingTeam Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 April 27, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for Spark #4 (204-008/304-120) Dear Commissioner: On behalf of itself and other owners, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent P&A operations on the exploration well Spark #4, Drilling Permit No. 204-008 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 MC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, ?JfY/~ P. Mazzolini Exploration Team Leader CPAI Drilling PM/skad RECEIVED APR 2 7 2004 Alaska Oil & Gas Cons. Commission Anchorage r r-' .-.. \ '" . \L e STATE OF ALASKA e ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged 0 Abandoned ~ Suspended 0 WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 Other Service 0 Stratigraphic Test 0 5. Date Comp., Susp.,;~ ,~~.<112. Permit to Drill Number: or Aband.: April j.9';"2004 204-008 / 304-120 6. Date Spudded: . 13. API Number: March 26, 2004 v 50-103-20480-00 7. Date TD Reached: 14. Well Name and Number: 1a. Well Status: Oil 0 Gas U GINJ 0 o WDSPL 0 WINJ No. of Completions _ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 682' FSL, 568' FEL, Sec. 23, T11 N, R1 E, UM At Top Productive Horizon: 687' FSL, 464' FEL, Sec. 23, T11 N, R1 E, UM Total Depth: 688' FSL, 443' FEL, Sec. 23, T11 N, R1 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 278295 y- TPI: x- 278400 y- Total Depth: x- 278421 . y- 18. Directional Survey: Yes 0 NoU 5958093 5958096 5958096 / Zone-4 Zone-4 Zone-4 21. Logs Run: GRlRes/NeuIlDens, Dipole Sonic, CMR, MDT 22. April 10, 2004 8. KB Elevation (It): RKB 37' /101' AMSL 9. Plug Back Depth (MD + TVD): surface 10. Total Depth (MD + TVD): / 8005' MD / 79971 TVD " 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A feet MSL CASING SIZE WT. PER FT. GRADE 16" 62.5# H-40 9.625" 40# L-80 7" 26# L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 117' Surface 2663' Surface 7710' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): none 26. Date First Production n/a Date of Test Hours Tested HOLE SIZE .,' Spark #4 15. Field/Pool(s): NPRA Exploration 16. Property Designation: ADL 5166 17. Land Use Permit: ALK AA081821 20. Thickness of Permafrost: 813' MD 24" CEMENTING RECORD 222 sx AS I AMOUNT PULLED 325 sx AS III Lite, 175 sx LiteCrete 180 sx Class G 12.25" 8.5" surface plug from surface to 315' cement retainer @ 7550' 24. SIZE n/a TUBING RECORD DEPTH SET (MD) PACKER SET (MD) n/a 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7" surface plug 0-315' 12 bbls AS I, 15.7 ppg 7"x9-5/8" plug from 0-3240' 95 bbls 12.0 ppg ArcticCrete 7" cement retainer from 7500'-8005' 25 bbls 15.8 ppg Class G PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) abandoned Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL Flow Tubing Casing Pressure press. 27. psi 24-Hour Rate -> WATER-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) Brief description of lithology, porosity, fractures., ap...p..a...re...n....t. d....iPS. and presence of oil, gas or water (attach separate sheet,~ecessary). Submit core chips; if none, state "none". !... .J':i.'. ~.1....~.-T.~,f r( Ec E IVE 0 ,,~l'I"'~,' " '~\ ~'r .~, ~ \ ~.Y~.~ \ ~ .,0 ! 'I·'._·~· n I .,X.:.ý ~~._.^~,^, \'''E-~__í ~ ,-0" ~~ ' k-,-"",~___.::=:J ér V¡ "" (Ò'. CORE DATA APR 2 7 2004 TO BE SENT UNDER SEPARATE COVER Alaska Oil & Gas Cons. Commission Anchorage RentAS ~ft N'Q. ~ \y~~E~"f3tN,~l Form 10-407 Revised 2/2003 Submit in duplicate c; ,.. \- G 28. GEOLOGIC MARKER~ 29. e 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". Spark 4 K-3 Seq 97 Seq 95 Seq 93 Seq 92 UJU 2880' 3430' 3825' 4007' 5750' 7689' 2880' 3430' 3825' 4007' 5749' 7682' N/A RECEIVED APR 2 7 2004 Alaska Oil & Gas Cons. Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Schematic, As-Built 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Billingsley @ 265-6531 p~nted NamP:J ¡ .A.,Mazzolil}i, , Signature ~"Iwrt~ Title: Phone Drillina Team Leader 04-/Z7/2. Á Date "0...,. 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 completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 e e Spark #4 API #50-103-20480-00 Permit #204-008 Daily Drilling Summary 3/25/04 Moved Doyon Rig 19 from Carbon #1 to Spark #4. Accept rig at Spark #4 on 3/25/04 at 21 :30 hr. NU Diverter. 3/26/04 Function test diverter. PU drill pipe and 12-1/4" drilling BHA. Spudded well at ....' and drilled to 617'. 3/27/04 Drilled from 617' to 1266'. Circ. Made wiper trip to 117'. Drilled to 2430'. 3/28/04 Drilled from 2430' to 2673'. CBU and made wiper trip. POOH. Ran 9-5/8" 40#, L-80 casing to 2663'. Circulated and cemented casing with 236 bb1s of 10.7 ppg lead cement followed by 77 bb1s of 12.0 ppg tail. Good returns throughout job, cement to surface. 3/29/04 ND Diverter. NU and test BOPs. PU 4" drill pipe. 3/30/04 Rill with 8-1/2" drilling BHA, tested 9-5/8" casing to 2500 psi, drilled out to 2693'and performed FIT to 14.5 EMW, drilled intermediate hole from 2693' to 3533'. 3/31/04 Drilled from 3533' to 5118'. 4/01/04 Drilled from 5118' to 5682', commenced wiper trip. Pumped out from 3578' to shoe, Rill and drilled from 5682' to 6254'. 4/2/04 Drilled from 6254' to 7019' for BHA change out and logs. POOH. 4/3/04 Ran CMR wireline logs from 2880' to 3310', ran DSI wireline log from 2630' to 4270'. Ran drillpipe conveyed MDT log. Took samples with MDT at 2915', 2964', 2994' and 2995'. 4/4/04 POOH w/ MDT logging tools and retrieved samples. Rill with 8-1/2" drilling BHA # 2. Drilled from 7019'-7368' with rotary assembly. 4/5/04 Drill from 7368' to TD of 8-1/2" intermediate hole section @ 7702'. Completed 10 stand wiper trip, POOH. Prep to run casing. 4/6/04 Ran 7" 26#, L-80 casing to TD at 7710' (casing tally correct, drill pipe tally for 8-1/2" hole TD was 8' shallow). Lost returns at 5150', pumped 3 LCM pills (35 bbls @ 20 ppb) but did not regain returns. e e 4/7/04 Cemented 7" casing with 37 bbls of 15.8 ppg slurry. No returns during cement job. ND BOPs, set slips. Tested 7" pack-off, NU and test BOP equipment. Rill with 6-1/8" cleanout BHA. Tested casing successfully to 3500 psi. 4/8/04 Cement cleaned out to shoe @ 7710', drilled I' new hole to 7711', change over to coring fluid, POOH. Rill with coring BHA, cored from 7711'-7789'. 4/9/04 Completed coring t07803'. Tripped OOH and UD core (recovered full interval approx.92'). Rill with 6-1/8" BHA, drilled from 7803' to 7814'. 4/10/04 Drilled from 7814' to TD @ 8005', completed short wiper trip and POOH. Run ,I DSI-FMI log on wireline. 4/11/04 Run CMR log on wireline. Ran MDT log on drill pipe conveyed. 4/12/04 Completed MDT logging and retrieved sample. Rill to TD with 6-1/8" bit for cleanout run while waiting on plan forward. Decide to P&A Spark #4. POOH, UD BHA, 5" DP. Rill with 7" cement retainer on drill pipe. 4/13/04 Set 7" retainer at 7550'. Mix and pump 25 bbls of 15.8 ppg cement, pump cement below retainer from 7550' to 8005' TD, unsting and lay in cement on top of retainer from 7550' to 7500'. Pump 95 bbls of 12.0 ppg Arctic Crete cement down 9-5/8" x 7" annulus from surface to 3240'. POOH with drill pipe to 561'. Spot viscous pill from 561' to 300', POOH with drill pipe and Rill with 3-1/2" tbg to 300', lay in surface plug consisting of 12 bbls of 15.7 ppg Arctic Set I inside 7" casing from 315' to surface:" POOH with 3-1/2" tbg. P&A operations witnessed by Tim Lawlor-BLM -/ 4/14/04 ND BOPs, released rig from Spark #4 at 03:00 on 4/14/04. Prepare to move to Alpine. 4/15-17/04 Move rig to Alpine. All rig modules on Alpine pad at 08:00 hrs on 4/17/04. 4/18/04 Surface P&A commenced including cutting off all casing strings 3' below ground level and re-filling 7" casing with cement (rig surface P&A cement had slumped 30'). 4/19/04 Weld on P&A plate. Refill area to ground level. Surface P&A work witnessed by Chuck Scheve-AOGCC. e . 2Dý~bO&' Spark #4 API #50-103-20480-00 Permit #204-008 Weekly Drilling Operations Report 3/25-3/29/04Move in Doyon Rig 19. NU and function test diverter. Mix mud and cleaned-out 16" conductor to 117'. Spud Sprak #4 at 17:30 on 3/26/04. Drill 12-1/4" hole to 2673'. Ran 9-5/8" 40#, L-80 BTC casing to 2663'. Cement with 236 bbls of 10.7 ppg Arctic Lite lead slurry and 77 bbls of 12.0 ppg LiteCrete tail slurry. Displace with 196 bb1s and bump plug. Good returns throughout job, 155 bbls cement returns to surface. ND diverter, NU & test BOPE. Current Operations: PU DP to drill out. . . 2Dl(~ Spark #4 API #50-103-20480-00 Permit #204-008 Weekly Drilling Operations Report 3/30-4/5/04 Rill with 8-1/2" bit, drill out cement in float track and 20' of new formation to 2693'. Perform FIT to 14.5 ppg EMW. Drill from 2693' to 7019'. POOH and ran CMR and Dipole Sonic wireline logs. Ran MDT log via drill pipe conveyed. RIH with 8-112" BHA and drill from 7019' to 7702', POOH. RU to run 7" casing. . . 26'( - oo<d Spark #4 API #50-103-20480-00 Permit #204-008 Weekly Drilling Operations Report 4/6-4/11/04 Run 7" 26#, L-80 casing. Unable to establish returns below 4300', RIH with casing to TD at 7710' (casing tally 8' deeper than DP tally). Pump 37 bbls of 15.8 ppg cement, displace with mud, bump plug. ND BOPs and set slips, install packoff, NU and test BOPs. RIH with 6-1/8" cleanout assy. Test casing to 3500 psi. Drill cement and l' of formation to 7711 " POOH with bit. RIH with coring assy. Core from 7711' to 7803'. POOH and recover core. RIH with 6-1/8" drilling BHA. MAD pass over cored interval, drill from 7803' to 8005' TD. Wiper trip to 7" shoe and POOH. Run Dipole Sonic/FMI log and CMR log on E-line. Run MDT log on drill pipe. Evaluating whether to complete well or P&A. -- -- Spark #4 API #50-103-20480-00 Pennit #204-008 Weekly Drilling Operations Report 4/12-18/04 Completed MDT logging and retrieved sample. Rill to TD with 6-1/8" bit for c1eanout run while waiting on plan forward. Decide to P&A Spark #4. POOH. Rill with 7" cement retainer on drill pipe. Set 7" retainer at 7550'. Mix and pump 25 bbls of 15.8 ppg cement, pump cement below retainer from 7550' to 8005' TD, unsting and lay in cement on top of retainer from 7550' to 7500'. Pump 95 bbls of 12.0 ppg Arctic Crete cement down 9-5/8" x 7" annulus from surface to 3240'. POOH with drill pipe to 561'. Spot viscous pill from 561' to 300', POOH with drill pipe and RIH with 3-1/2" tbg to 300', lay in surface plug consisting of 12 bbls of 15.7 ppg Arctic Set I inside 7" casing from 315' to surface. POOH with 3-1/2" tbg. Rig P&A operations witnessed by Tim Lawlor-BLM. ND BOPs, released rig from Spark #4 at 03:00 on 4/14/04. Move Doyon 19 rig to Alpine. All rig modules on Alpine pad at 08:00 hrs on 4/17/04. Cut off casing at 3' below surface. Re-fill 7" casing with cement (surface cement plug had slumped 30') on 4/18/04. Final plate being welded on top of cut-off casing strings on 4/19/04. Chuck Scheve-AOGCC witnessed surface cut-off and cementing inside 7" casing on 4/18. t: \ ¢'...ú.. \ ~~o \+ - Halliburton Sperry-Sun 2004 April, North Slope Alaska ConocoPhillips Exp Exploration 2004 Spark # 4 - Spark #4 Job No. AKMW2910261, Surveyed: 11 Survey Report 2004 15 April, e Your Ref: API 501032048000 Surface Coordinates: 5958093.47 N, 278295.21 E (70· 17' 16.1011" N, 151·47' 40.9824" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy954 W) Surface Coordinates relative to Project: 18346.53 S, 173053.79 W (Grid) Surface Coordinates relative to Structure: 23441.03 S, 172437.60 W (True) Kelly Bushing Elevation: 100~98ft above Mean Sea Level Kelly Bushing Elevation: 100.98ft above Structure 5i ~....I ·....y-5UI! DRILLING S,ª!"VICE!i,ª A Halliburton Company Halliburton Sperry-Sun Survey Report for Exploration 2004 - Spark # 4 - Spark #4 Your Ref: API 501032048000 Job No. AKMW2910261, Surveyed: 11 April, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -100.98 0.00 0.00 N 0.00 E 5958093.47 N 278295.21 E 0.00 MWD Magnetic 191.28 0.220 56.360 90.30 191.28 0.20 N 0.31 E 5958093.66 N 278295.52 E 0.115 0.20 286.30 0.250 56.100 185.32 286.30 0.42 N 0.63 E 5958093.87 N 278295.85 E 0.032 0.42 376.68 0.330 80.430 275.70 376.68 0.57N 1.05 E 5958094.01 N 278296.28 E 0.161 0.57 465.59 0.610 77.370 364.60 465.58 0.72 N 1.76 E 5958094.14 N 278296.99 E 0.316 0.72 e 556.80 0.780 89.060 455.81 556.79 0.84 N 2.86E 5958094.22 N 278298.09 E 0.242 0.84 645.66 0.970 97.840 544.66 645.64 0.74N 4.21 E 5958094.09 N 278299.44 E 0.261 0.74 734.64 1.150 101.130 633.62 734.60 0.47 N 5.83 E 5958093.77 N 278301.05 E 0.213 0.47 823.53 1.150 99.600 722.49 823.47 0.15 N 7.59 E 5958093.39 N 278302.80 E 0.035 0.15 912.37 1.050 103.660 811.32 912.30 0.198 9.26 E 5958093.00 N 278304.46 E 0.143 -0.19 1007.25 1.000 104.100 906.18 1007.16 0.60S 10.90 E 5958092.55 N 278306.09 E 0.053 -0.60 1102.07 1.020 106.830 1000.99 1101.97 1.05 S 12.51 E 5958092.05 N 278307.69 E 0.055 -1.05 1197.20 0.990 110.330 1096.10 1197.08 1.588 14.09 E 5958091.48 N 278309.25 E 0.072 -1.58 1292.56 1.080 105.980 1191.45 1292.43 2.118 15.73 E 5958090.90 N 278310.87 E 0.125 -2.11 1388.08 1.090 101.980 1286.95 1387.93 2.558 17.49 E 5958090.41 N 278312.61 E 0.080 -2.55 1483.42 1.100 101.230 1382.27 1483.25 2.918 19.27 E 5958089.99 N 278314.39 E 0.018 -2.91 1577.59 1.050 104.970 1476.43 1577.41 3.318 20.99 E 5958089.54 N 278316.09 E 0.091 -3.31 1673.52 0.280 37.460 1572.35 1673.33 3.358 21.98 E 5958089.47 N 278317.08 E 1.019 -3.35 1768.90 0.640 334.310 1667.73 1768.71 2.69 S 21.89 E 5958090.14 N 278317.01 E 0.599 -2.69 1864.21 0.530 339.160 1763.03 1864.01 1.808 21.51 E 5958091.04 N 278316.65 E 0.126 -1.80 1959.28 0.610 340.350 1858.10 1959.08 0.918 21.18 E 5958091.94 N 278316.35 E 0.085 -0.91 2053.51 0.560 334.790 1952.32 2053.30 0.02 S 20.81 E 5958092.84 N 278316.01 E 0.080 -0.02 e 2149.12 0.580 338.670 2047.93 2148.91 0.85N 20.44 E 5958093.72 N 278315.67 E 0.045 0.85 2244.14 0.610 322.230 2142.94 2243.92 1.70 N 19.95 E 5958094.58 N 278315.21 E 0.182 1.70 2339.20 0.700 333.590 2238.00 2338.98 2.62 N 19.39 E 5958095.52 N 278314.66 E 0.166 2.62 2434.41 0.770 325.960 2333.20 2434.18 3.67 N 18.77 E 5958096.59 N 278314.08 E 0.126 3.67 2529.39 0.620 324.040 2428.17 2529.15 4.62N 18.11 E 5958097.55 N 278313.45 E 0.160 4.62 2604.17 0.620 320.320 2502.95 2603.93 5.26N 17.61 E 5958098.20 N 278312.97 E 0.054 5.26 2751.93 0.720 327.800 2650.70 2751.68 6.66N 16.61 E 5958099.63 N 278312.01 E 0.090 6.66 2847.52 0.790 334.700 2746.28 2847.26 7.76N 16.01 E 5958100.75 N 278311.44 E 0.120 7.76 2942.35 0.740 345.440 2841.10 2942.08 8.94 N 15.57 E 5958101.95 N 278311.04 E 0.160 8.94 3038.58 0.750 348.000 2937.32 3038.30 10.16 N 15.29 E 5958103.18 N 278310.79 E 0.036 10.16 3133.90 0.790 341.620 3032.63 3133.61 11.40 N 14.95 E 5958104.42 N 278310.49 E 0.099 11.40 3229.44 0.690 346.080 3128.17 3229.15 12.58 N 14.60 E 5958105.61 N 278310.18 E 0.121 12.58 3325.10 0.720 340.190 3223.82 3324.80 13.70 N 14.26 E 5958106.75 N 278309.87 E 0.082 13.70 15 April, 2004 - 14:44 Page 2 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Exploration 2004 - Spark # 4 - Spark #4 Your Ref: API 501032048000 Job No. AKMW2910261, Surveyed: 11 April, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3420.29 0.590 341.340 3319.00 3419.98 14.73 N 13.90 E 5958107.78 N 278309.54 E 0.137 14.73 3515.84 0.550 346.220 3414.55 3515.53 15.64 N 13.64 E 5958108.70 N 278309.30 E 0.066 15.64 3611.12 0.640 331.990 3509.82 3610.80 16.56 N 13.28 E 5958109.63 N 278308.97 E 0.181 16.56 3706.87 1.350 237.510 3605.56 3706.54 16.42 N 12.07 E 5958109.53 N 278307.76 E 1.607 16.42 3802.41 1 .450 233.050 3701.07 3802.05 15.09 N 10.16 E 5958108.25 N 278305.81 E 0.155 15.09 e 3897.84 1.380 237.480 3796.48 3897.46 13.75 N 8.22 E 5958106.97 N 278303.84 E 0.136 13.75 3993.45 1.470 239.400 3892.06 3993.04 12.50 N 6.20E 5958105.79 N 278301.77 E 0.107 12.50 4089.04 1.460 237.950 3987.61 4088.59 11 .23 N 4.11 E 5958104.58 N 278299.65 E 0.040 11.23 4184.51 1.440 237.940 4083.05 4184.03 9.95 N 2.06 E 5958103.36 N 278297.57 E 0.021 9.95 4279.74 1.380 237.240 4178.25 4279.23 8.70 N 0.08 E 5958102.16 N 278295.55 E 0.066 8.70 4375.20 0.390 286.740 4273.70 4374.68 8.17 N 1.19W 5958101.67 N 278294.26 E 1.220 8.17 4470.57 0.390 290.260 4369.07 4470.05 8.37 N 1.81 W 5958101.89 N 278293.65 E 0.025 8.37 4566.42 0.660 2.560 4464.92 4565.90 9.04 N 2.09W 5958102.57 N 278293.39 E 0.685 9.04 4661.46 0.620 4.690 4559.95 4660.93 10.10 N 2.02W 5958103.62 N 278293.49 E 0.049 10.10 4756.45 0.550 336.250 4654.94 4755.92 11.03 N 2.16W 5958104.56 N 278293.37 E 0.311 11.03 4851.00 0.690 338.870 4749.48 4850.46 11.97 N 2.55W 5958105.51 N 278293.01 E 0.151 11.97 4947.44 0.660 298.080 4845.92 4946.90 12.78 N 3.25W 5958106.34 N 278292.34 E 0.489 12.78 5042.96 0.770 299.020 4941 .43 5042.41 13.35 N 4.30W 5958106.94 N 278291.31 E 0.116 13.35 5138.67 0.580 287.560 5037.13 5138.11 13.80 N 5.32W 5958107.43 N 278290.30 E 0.243 13.80 5234.13 0.560 276.740 5132.59 5233.57 14.01 N 6.25W 5958107.65 N 278289.38 E 0.115 14.01 5329.59 0.400 277.160 5228.04 5329.02 14.10 N 7.04W 5958107.77 N 278288.59 E 0.168 14.10 5424.84 0.410 249.570 5323.29 5424.27 14.02 N 7.69W 5958107.71 N 278287.94 E 0.203 14.02 e 5520.39 0.310 226.430 5418.84 5519.82 13.73 N 8.20W 5958107.43 N 278287.42 E 0.183 13.73 5615.67 0.280 230.000 5514.12 5615.10 13.40 N 8.56W 5958107.12 N 278287.05 E 0.037 13.40 5711.29 0.200 257.110 5609.74 5710.72 13.21 N 8.90W 5958106.94 N 278286.70 E 0.143 13.21 5804.75 0.000 0.000 5703.20 5804.18 13.18 N 9.06W 5958106.91 N 278286.54 E 0.214 13.18 5902.41 0.140 241.550 5800.86 5901.84 13.12 N 9.17W 5958106.85 N 278286.43 E 0.143 13.12 5997.90 0.200 58.890 5896.35 5997.33 13.15N 9.13W 5958106.88 N 278286.47 E 0.356 13.15 6093.51 0.660 99.280 5991.95 6092.93 13.15N 8.44 W 5958106.86 N 278287.16 E 0.548 13.15 6188.84 1.390 109.940 6087.27 6188.25 12.66 N 6.81 W 5958106.33 N 278288.77 E 0.788 12.66 6284.05 2.290 106.610 6182.43 6283.41 11.73 N 3.90W 5958105.31 N 278291.65 E 0.952 11.73 6379.22 1.890 92.430 6277.53 6378.51 11.12 N 0.51 W 5958104.60 N 278295.02 E 0.684 11.12 6474.89 2.080 84.140 6373.15 6474.13 11.23 N 2.79 E 5958104.61 N 278298.33 E 0.359 11.23 6570.43 1.100 71 .460 6468.65 6569.63 11.69 N 5.38 E 5958105.00 N 278300.94 E 1.084 11.69 6666.38 1.620 73.410 6564.57 6665.55 12.37 N 7.56 E 5958105.62 N 278303.13 E 0.544 12.37 15 April, 2004 . 14:44 Page 3 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Exploration 2004 - Spark # 4 - Spark #4 Your Ref: API 501032048000 Job No. AKMW2910261, Surveyed: 11 April, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6761.55 1.760 75.690 6659.70 6760.68 13.12 N 10.26 E 5958106.28 N 278305.85 E 0.163 13.12 6857.02 1.730 86.250 6755.13 6856.11 13.58 N 13.12 E 5958106.65 N 278308.72 E 0.338 13.58 6951.11 2.060 92.140 6849.17 6950.15 13.61 N 16.23 E 5958106.59 N 278311.83 E 0.407 13.61 7048.98 4.600 92.080 6946.86 7047.84 13.40 N 21.91 E 5958106.22 N 278317.50 E 2.595 13.40 7144.05 9.210 98.190 7041 .22 7142.20 12.18 N 33.25 E 5958104.66 N 278328.81 E 4.903 12.18 e 7239.85 11 .270 98.440 7135.49 7236.47 9.71 N 50.10 E 5958101.70N 278345.58 E 2.151 9.71 7335.46 9.530 96.990 7229.52 7330.50 7.37N 67.20 E 5958098.86 N 278362.60 E 1.840 7.37 7430.85 7.120 95.170 7323.90 7424.88 5.88 N 80.93 E 5958096.96 N 278376.28 E 2.541 5.88 7526.85 5.540 92.220 7419.31 7520.29 5.16 N 91.49 E 5958095.94 N 278386.81 E 1.680 5.16 7622.21 4.410 89.470 7514.31 7615.29 5.02 N 99.75 E 5958095.55 N 278395.07 E 1.211 5.02 7654.63 4.050 87.760 7546.64 7647.62 5.08N 102.14 E 5958095.53 N 278397.46 E 1.176 5.08 7726.41 3.730 88.360 7618.26 7719.24 5.24N 107.01 E 5958095.56 N 278402.33 E 0.449 5.24 7822.15 3.890 88.400 7713.79 7814.77 5.42 N 113.37 E 5958095.55 N 278408.69 E 0.167 5.42 7915.21 3.670 85.950 7806.64 7907.62 5.72 N 119.50 E 5958095.67 N 278414.82 E 0.293 5.72 '"'" 8005.00 3.670 85.950 7896.25 7997.23 6.13 N 125.23 E 5958095.90 N 278420.57 E 0.000 6.13 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB100.98' above MSL. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8005.00fl., The Bottom Hole Displacement is 125.38ft., in the Direction of 87.199° (True). e 15 April, 2004 - 14:44 Page 4 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Exploration 2004 - Spark # 4 - Spark #4 Your Ref: API 501032048000 Job No. AKMW2910261, Surveyed: 11 April, 2004 ConocoPhillips Exp North Slope Alaska Comments Measured Depth (ft) Station Coordinates rvD Northin9s Eastin9s (ft) (ft) (ft) Comment 8005.00 7997.23 6.13 N 125.23 E Projected Survey e Survey tool program for Spark # 4 - Spark #4 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 8005.00 7997.23 MWD Magnetic e 15 April, 2004 -14:44 Page 5 of 5 DrillQuest 3.03.06.002 Spark '4 WELL SCHEMATIC Actual P&A, 4/13/04 - ~. I-- III I e 16" 62.6# @ 117' MD Surface 15.7 ppg cmt plug down to 315' Surface csg. 9-5/8" 40# L-80 BTC @ 2663' MDfTVD Hydrocarbon zone = 2940'-3040' Downsqueeze 95 bbls of 12.0 ppg Arctic Crete cmt in 9-5/8" x 7" annulus down to 3240' 9.8 ppg mud .. 15.8 ppg Cmt plug thru retainer at 7550' to /05" lay in cmt on top of retainer to 7500' ... Top-set csg. 7" 26# L-80 BTC @ 7,710' MD 6-1/8" hole TD = 8005' MD/7997' TVD TAB 4/13/04 e 'REV I DATE I BY I CK I APP I DESCRlP110N 1 3/15/04 G.D. B.D. 18 ISSUED PER K03125ACS NOTES: 1. BASIS OF COORDINATES: ALPINE MONUMENT MON 19 AND LOUNSBURY AND ASSOCIATES MONUMENT "03-10-01". 2. COORDINATES ARE NAD 27. 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 3/14/04 4~~~~L~~_~I. AlpIne OfffcEI (907) 670-47.39 ~ Anchorage. Alaska (907) l73-1 B30 - Alpine Survey Office IREV DATE I BY I L) ..ð I Vicinity Map ::i::i ::):::> ¡jw ~ ..c. -- _"'" ~~\",............ ( \ \ \~~? .¿~\ ,-N--lici ........... ~ ~\ "'-\ \ \ 568 . :- ........... -~ ~ v-;,t \to ~ ~ ( ~. '%. --- --- ..-- .\ \ ~ ~ ...: \..-- ~~ ~ ___ ..-- \~ \ r --ýf \~ /'" ~ N Z. \ (" ,\GJ. /' _ :::.- . ~ \ œ SPARK 4 \ \.-- :..- -- fi3 ~ ~\~oQ R[STAKE \ \" (f) ò . \ v.>¡t..\~S_- .... o~ ~\ ~G ~~ ~ \'¡}.. ~\ ~---:/ ~ Q) ~Ù ...........0-;- ~ ........... r::.0 ± \ ........... ~O"f. :.t \.......- ........... ti" 10'0 H SEC. 23, T. 11 N., R. 1 E., U.M. SEC. 26. T. 11 N., R. 1 E. U.M. SCALE 1"=200' ConocriPhillips Alaska, Inc. I DRAWING NO: CADD fiLE NO. ..- ..... . CK I APP DESCRIPlI Q\ HARRISON BAY <, ...... ÇF¿LPINE ,CILl~ PROJECT ~~ SITE NUIQSUip¡ 'J Spark 4 Restake LOCATED 1JJTHIN PROTRACTED SECTION 23. T. 11 N.. R. 1 E. UMIAT MERIDIAN, AlASKA 882' FSL 568' PEL GND ELEV. = 81.8' BPNSL ICE PAD ELEV.=84.7· BPIlSL NAD27 natum N 70"17TIIU D1" Tf 151"47·4D.962- ASPC ZN4 (Y) 5,958,093.47 (x) 278,295.21 ./ ~~,_. ~~., ~~f:'. ~'49TH ~ ':r.~~ ·······..···..·····..·1 . ............ ........., i .. Bradley W. DellÌnø : 1 'f.~" LS-8412 .,~~ '-~~(\~~':'.#' \\\.,,"'~- SURVEYOR'S CERTIFICATE / I HEREBY CERTIFY lHAT I AM PROPERLY REGISTERED AND LICENSED TO PRAClICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND lHAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 14, 2004. MODULE: AP()(} UNIT: AP SPARK 4 RESTAKE EXPLORATORY WELL CONDUCTOR ASBUILT LOCAllON CE-APOO-1 01 0 I PART: 1 OF' 1 I REV: 1 ALPINE e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, Ké'tï1 4(z,;;lo+ DATE: P. I. Supervisor ~ April 18, 2004 FROM: Chuck Scheve, SUBJECT: Petroleum Inspector Surface Abandonment Spark #4 PDT#' 204...(}()8 Sunday. April 18.2004: I traveled to the Conoco Phillips Spark #4 exploratory location to inspect the casing cut off and abandonment of this well. Prior to my arrival all casing strings were cut off at approximately 4' below original ground level. Cement in the 7" casing was found at a depth of <30'. A ready mix truck was called to location and the 7" casing topped off with cement. The excess cement was then poured in the excavation around the well. I required the excess cement be removed prior to back filling the excavation. SUMMARY: I inspected the casing cut off depth, and the P&A marker plate on the Spark#4 well and found all to be in order with the exception off the excess cement in the excavation. Attachments: Spark #4 plate.JPG Spark#4 cut off.JPG Spark#4 excess cement.JPG e e Spark #4 (ConocoPhillips) Surface Abandonment Inspection Photos from AOGCC Inspector Chuck Scheve April 18, 2004 Casing cut 4 ft BGL Excess cement in excavation Marker plate . MN~I Laboratories, Inc. State of Alaska Oil and Gas Conservation Comm. 333 7th Ave. Anchorage, AK Chip Samples Conoeo-Phillips Spark #4 North Slope, AK Depths 7711-7804 93 feet c1~ Ifl ~fV 17 38 Y"r\: u~""~ )'1 (Q.\\L '- t ....vzp/\ sig:-~A ¡;-l - Omni Labs. Dave ster 6-8605 oW . RECEJ\JEO þ...~R 1 5 1004 . , ....n\\$S\on C' w¡¡ \.#()\"'" 0'\ &. ûa$ \,10 . M8$~a \ þ.ntt\Ot8\\e ;=1 {I) b J~'1'-~68 Fdt. n ¡. : I -:l , z J . . JOG t;(! (Y) Py SchlumbBPIBP ] ] ] !l l : J :1 ~~ ~ Jfff-oV Erx:.cL~~+CO N Fi OENTiJ1L CONOCOPHILLlPS FROM RESERVOIR TO RESULTS. Oil phase Sampling & Analysis Services 16068th St, Nisku, Alberta, Canada Tel:I-780-955-2800 Fax:I-780-955-2921 Field Operations Report BOROUGH: WELL: DATE: RIG: North Slope Spark #4 10 to 16 April 2004 Doyon 19 ,-..1- f Ct-'..; U ,1 ! ¿;] lil.. FORMATION PARAMETERS SAMPLED: Depth: 7728.0 ft MD Pressure: 3722.8 psia Temperature: 177.3 F o Synthetic Oil-based Mud System o Water-based Mud System "'0 00 "C::J ::2.0 (1)0 6)0 ~;9 -. C= a~ D) SAMPLING OPERATION PERSONNEL: Wellsite Client Rep.: Oilphase Personnel: MDT Personnel: Date submitted: Approved by: Date: Wayne Campaign Jennifer Harris Scot Shier Roger Lepine 14 April 2004 Colin Drever 6 May 04 © 2004 Oilphase-DBR Sampling Services - Sampling Report (Rev NAM 02). The data in this report remains the property of the client and may not be disclosed or reproduced without the client permission. On-site fluid analysis measurements made in the field may be subjectto further evaluation once a PVT study has been performed. Schlumberger Private 1 ~r ~. ¿ I Client: Job #: Date: n J . . ConocoPhillips CAL 069 10 - 16 April 04 Field: Well: Installation: lehlulDbepgep Exploration Spark #4 Doyon 19 Table of Contents n ] ¡ J : } J ,J . ~ ì j Su mma ry ............................................................ 1 Sequence of Events... ... ............ .................. ........... 2 MDT Sam pie Listing .................................................4 Chemical Rinse listing............................................. 5 © 2004 Oilphase-DBR Sampling Services - Sampling Report (Rev NAM 02). The data in this report remains the property of the client and may not be disclosed or reproduced without the client permission. On-site fluid analysis measurements made in the field may be subject to further evaluation once a PVT study has been performed. Schlumberger Private ii ~l . ~T ] . . Client: Job #: Date: ConocoPhillips CAL 069 10 -16 April 04 Field: Exploration Well: Spark #4 Installation: Doyon 19 Schlu_blPIIP Summary COIVf!/?~~1 Ut;v 17JlL n n n fJ Over the course of 11 to 12 Apri/2004, Schlumberger Wireline ran their Formations Dynamics Tester into the well Spark #4. The toolstring consisted of one 2 %gallon chamber, one 1 gallon chamber, three 450 cc MPSRs, and three 250 cc SPMCs. All sample chambers were filled atthe same depth in the Jurassic sand at 7728.0 ft MD. SPMC 059 failed to capture sample due to the internal rod firing close prematurely. Local procedures are being revised to prevent this from happening in the future. ! J I MPSR 1400, MPSR 1401, and MPSR 1402 were heated to reservoir temperature for two hours and transferred into Conventional Sample Bottles (CSBI atthe Schlumberger shop. MRSC 158 was pressurized, heated, and agitated for six hours and was transferred at 5,500 psi and at reservoir temperature into four SSBs. MRSC 292 was bled down onsite by the MDT Engineer as per client request. SPMC 117 and SPMC 204 were heated to reservoir temperature for two hours before being transferred into SSBs. The chambers were post-rinsed with Toluene for possible asphaltene analysis. 1 ¡ . j All pressurized hydrocarbon samples were sentto Oilphase-DBR's PVT laboratory in Houston, Texas. © 2004 Oilphase-DBR Sampling Services - Sampling Report (Rev NAM 021. The data in this report remains the property of the client and may not be disclosed or reproduced without the client permission. On-site fluid analysis measurements made in the field may be subjectto further evaluation once a PVT study has been performed. Schlumberger Private ''1. ! j . J' ] n n fI ¡ ] : J ,I Client: Job #: Date: ConocoPhillips CAL 069 10-16Apri104 . . Field: Well: Installation: Exploration Spark #4 Doyon 19 SchlumblPllP Sequence of Events GÂTE 11 ME 10 Apr 04 11 Apr 04 12 Apr 04 14:30 16:30 18:30 05:00 17:17 17:42 18:30 18:32 18:36 18:43 18:45 02:00 14:00 14:30 16:30 16:45 17:00 19:00 19:15 20:00 22:00 22:15 Oilphase-DBR personnel arrive on Doyon 19 Commenced priming SPMCs to 8,000 psi Completed priming SPMCs Commenced running in the hole with MDT Sampled MRSC 292 at 7728.0 ft MD Sampled MRSC 158 at 7728.0 ft MD Sampled MPSR 1400 at 7728.0 ft MD Sampled MPSR 1401 at 7728.0 ft MD Sampled MPSR 1402 at 7728.0 ft MD Sampled SPMC 117 at 7728.0 ft MD Sampled SPMC 204 at 7728.0 ft MD Pulled out of hole with MDT Obtained opening pressure on MRSC 158 (4,000 psi @ 69 F) Obtained opening pressure on MPSR 1400 (4,200 psi @ 69 F) Commenced transfer of MPSR 1400 (5,500 psi @ 180 F) Completed transfer of MPSR 1400 into CSB 7673-QA Obtained opening pressure on MPSR 1401 (4,200 psi @ 69 F) Commenced transfer of MPSR 1401 (5,500 psi @ 180 F) Completed transfer of MPSR 1401 into CSB 7721-QA Obtained opening pressure on MPSR 1402 (4,300 psi @69 F) Commenced transfer of MPSR 1402 (5,500 psi @ 180 F) Completed transfer of MPSR 1402 into CSB 7146-QA © 2004 Oilphase-DBR Sampling Services - Sampling Report (Rev NAM 02). The data in this report remains the property of the client and may not be disclosed or reproduced without the client permission. On-site fluid analysis measurements made in the field may be subject to further evaluation once a PVT study has been performed. Schlumberger Private 2 "'1 if . Client: ConocoPhillips Job #: CAL 069 Date: 10 -16 April 04 ~r n . . Field: Exploration Well: Spark #4 Installation: Doyon 19 SchlumbøPllP Sequence of Events n DATE 12 Apr 04 fl L n 13 Apr 04 fJ tl ¡ 1 J 14 Apr 04 '1 t i: ~ TIME 22:30 00:15 12:00 14:00 14:15 15:00 17:00 17:15 09:00 09:30 Commenced transfer of MRSC 158 (5,500 psi @ 170 F) Completed transfer of MRSC 158 into four CSBs Obtained opening pressure on SPMC 11714,500 @ 69 F) Commenced transfer of SPMC 117 (5,500 psi @ 180 F) Completed transfer of SPMC 117 into SSB 11607-QA Obtained opening pressure on SPMC 204 (4,500 psi @ 69 F) Commenced transfer of SPMC 204 (5,500 psi @ 180 F) Completed transfer of SPMC 204 into SSB 11876-QA Commenced post-rinse of chambers Completed post-rinse of chambers © 2004 Oilphase-DBR Sampling Services - Sampling Report (Rev NAM 02). The data in this report remains the property of the client and may not be disclosed or reproduced without the client permission. On-site fluid analysis measurements made in the field may be subjectto further evaluation once a PVT study has been performed. Schlumberger Private 3 ~~ ~ --- ~ '-' - ;-'''''] """·.·,··.,,...r:·,V·:'-~ -.-I ~. . ~ -- :::... .j " '~ -- Client: Job #: Date: ConocoPhillips CAL 069 10 - 16 April 04 Field: Well: Installation: Exploration Spark #4 Doyon 19 Sclllum_"lep CONFlOENTIAL MDT Sample Listing JURASSIC SAND SAMPLES: GAS . 7728.0 ft MD (TVD=7728.0'), 3722.8 psia @ 177.3 F POT =117 min, POV = 50 L,AP = 73 psi * 1.01 11/Apr/04 17.42 1 gal sub-samp MRSC 158 4,000 @ 69 5,500 @ 170 5,500 @ 68 SSB 11609-QA 650 cc MRSC 158 was heated and agitated for 6 hours 1.02 11/Apr/04 17.42 1 gal sub-samp MRSC 158 4,000 @ 69 5,500 @ 170 5.500 @ 68 SSB 11878-QA 650 cc prior to transfer into four CSBs . 1.03 11/Apr/04 17.42 1 gal sub-samp MRSC 158 4,000 @ 69 5,500 @ 170 5,500 @ 68 SSB 11527-QA 640 cc 1.04 11/ Apr/04 17.42 1 gal sub-samp MRSC 158 4,000 @ 69 5,500 @ 170 5,300 @ 68 SSB 11561-QA 660 cc 1.05 11/Apr/04 18.30 450 cc MPSR MPSR 1400 4,200 @ 69 5,500 @ 180 5,500 @ 69 CSB 7673-QA 380 cc 1.06 111Apr/04 18.32 450 cc MPSR MPSR 1401 4.200 @ 69 5,500 @ 180 5,500 @ 69 CSB 7721-QA 420 cc <- 1.07 11/Apr/04 18.36 450 cc MPSR MPSR 1402 4,300 @ 67 5,500 @ 180 5,500 @ 67 CSB 7746-QA 410 cc C 1.08 11/Apr/04 18.43 250 cc SPMC SPMC 117 4,500 @ 69 5,500 @ 180 5,500 @ 69 SSB 11607-QA 200 cc ".~.: 1.09 11/Apr/04 18.45 250 cc SPMC SPMC 204 4,500 @ 69 5,500 @ 180 5,500 @ 69 SSB 11876-QA 200 cc -J DRILLING FLUID SAMPLES c::: rr", -"-t.ùt .-;i~' 1.10 11/Apr/04 20.00 Waterbase mud n/a n/a n/a n/a Plastic bottle 1 Gal. From active pit. . NOTES: All samples listed above are being sent to the Oilphase DBR PVT Laboratory in Houston, Texas . POT is pump-out time in minutes, POV is pump-out volume in liters, and Ll.P is the difference between formation & ffowing pressure at the probe while pumping out (Le. drawdown). Schlumberger Private 4 l' . . :1" 11. CHent: Job #: Date: ConocoPhillips CAl069 10 -16 April 04 Field: Well: Installation: Exploration Spark #4 Doyon 19 Sc~IUlRbBl'gBI' n Chemical Rinse Listing 1f1 ~ Rinse Type: Post-rinse i:] i. CR1.01 CR1.02 CR1.03 CR1.04 MRSC 158 MPSR 1400 MPSR 1401 MPSR 1402 06.Sep.03 06.Sep.03 06.Sep.03 06.Sep.03 09.00 09.10 09:20 09:30 Toluene Toluene Toluene Toluene ~] .it. ~J ~1 . .. 't ~ . j * Sample/rinse volumes are approximately 300 cm3 for MPSR Mu/tisample 450 cm3 PVT Bott/es. * Sample/rinse volumes are approximately 900 cm3 for 1.0 & 2% Gallon MDT Sample Chambers. © 2004 Oilphase-DBR Sampling Services - Sampling Report (Rev NAM 02). The data in this report remains the property of the client and may not be disclosed or reproduced without the client permission. On-site fluid analysis measurements made in the field may be subjectto further evaluation once a PVT study has been performed. Schlumberger Private 6 . . ~ ConocoPhillips Alaska, Inc. Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage, AK 99510 phone 907.263.4859 TO: AOGCC 333 WEST 7TH ANCHORAGE, AK. 99510 DATE: April 13, 2004 AIRBILL: AirlLand 5271832 AFT#: CPBV04-04-13-01 CHARGE CODE: N/A OPERATOR: ConocoPhillips Alaska, Inc. SAMPLE TYPE: DRY DITCH NUMBER OF BOXES: 1 Bundle NAME: SPARK #4 SAMPLE DEPTH: ONE COMPLETE SET OF DRY CUTTING AS RECEIVED FROM THE RIG SPARK #4 120-8005 UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: RECEIVED BY: ~ ())jJ ConocoPhillips Alaska Inc. BAYVIEW GEOLOGIC FACILITY 619 E. Ship Creek Ave. ANCHORAGE, AK. 99510-0360 ATTN: D. L. Przywojski ABV-100 DATE: / '> fJ-p(l("'1 ~(M\( Cc: A. ANDREOU CPAI G. WILSON CPAI I' > (0 ;l ~ '1-~ lJ'8 F/I~ e . ~ Paul Mazzolini Exploration DrillingTeam Leader Drilling & Wells ConocóP't,illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 April 12, 2004 RECEIVED APR 1 2 2004 Alaska Oil & Gas Cons. Commission Anchorage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval on Spark #4 (204-008) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming operations to P&A the exploration well Spark #4. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, ?~fr¡~ P. Mazzolini Exploration Team Leader CPAI Drilling PM/skad ,ORIGINA·L · I» k'\ STATE OF ALASKA RECEIVEGb- lVJ ALASKA Oil AND GAS CONSERVATION COMMISSION x::Jc APPLICATION FOR SUNDRY APPROVAL APR 12 2004 ~~' 20 AAC 25.280 Alaska Oil & Ga~ons Gommi~!;ion~ Operational shutdown 0 Perforate 0 Variance AndhtraginnUlar Dispos.D Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 o e 1. Type of Request: o Repair well 0 o o Alter casing 0 o Abandon Suspend Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99515 7. KB Elevation (ft): 37' RKB 8. Property Designation: ALK 51661 ADL AA081821 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): 8005' 7997' Casing Length Size Structural Conductor 108' 16" Surface 2626' 9.625" Intermediate 7673' 7" Production Liner Perforation Depth MD (ft): N/A Packers and SSSV Type: Perforate New Pool Re-enter Suspended Well 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: V 204-008 6. API Number: Exploratory 0 Service 0 -/ 50-103-20480-00 9. Well Name and Number: Spark #4 10. Field/Pools(s): NPRA Exploration PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): MD TVD Burst Collapse 108' 108' 2663' 2663' 7710' 7710' Perforation Depth TVD (ft): N/A Packers and SSSV MD (ft): Tubing MD (ft): 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 4/12/2004 16. Verbal Approval: Date: 4/12/04 Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. none Printed Name, P. M~~~lini " Signature ?~ r' I~ Tubing Size: n/a Tubing Grade: none 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Contact Tim Billinasley @ 265-6531 Title Drilling Team Leader Phone 263-4603 COMMISSION USE ONLY Date ð4/,Z-. I z.oo4 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Sundry Number: ....3 éJ' ~ - / ').. 0 Location Clearance ~ ~L '-'\ \''-'-'~XC\c:,\ 'Q\:, ~\\-~ ç()\~('? 'V\v~ ~\~~( ~C)(,CC Y\-<;'~(C~,-ÇÖ\ (-.j-\ G~ \ ç. \~ \.- M t--,.Û \-. a \....... ~ \ \c, Other: Subsequent Form Required: \r--\ (; ~ Origina' SignØdN~ CAN sEAMOU ¡I Approved by: ;(C,I'{{!( nornJon ree used hl,f¥7j(2 I) I h a (/.. Þ,(1 r h C I k1{1h:... I;"-:r,.¡ I ~ t../t.?' f L ¡ Form 10-403 Revised 2/2003 ,) C COMMISSIONER BY ORDER OF THE COMMISSION OR\G\.N-AL Date: L, 'V ð& I firI1IIS8FL APi 152M SUBMIT IN DUPLICATE Spark. WELL SCHEMATIC Proposed P&A Retainer e 16" 62.6# @ 108' MD Surface 15.7 ppg cmt plug down to 300' Surface csg. 9-5/8" 40# L-80 BTC @ 2663' MOrrVO Hydrocarbon zone = 2940'-3040' Oownsqueeze 11.0 ppg Arctic Crete cmt in 9-5/8" x 7" annulus down to 3240' 9.8 ppg mud 15.8 ppg Cmt plug from 8005' to 7450' thru retainer at 7550' Top-set csg. 7" 26# L-80 BTC @ 7,710' MO 6-1/8" hole TO = 8005' MO/7997' TVO TAB 4/11/04 e Spark #4 P&A Procedure e CONFIDENTIAL for AOGCC and BLM 1. Spark #4 Well bore Status The Spark #4 well was drilled to a depth of 8005' MDn997' TVD. The 9-5/8" surface casing was set at 2663' and cemented back to surface. A 7" string was set and cemented at 7710' MD drilled out and a single coring run made. The rig drilled 6-1/8" hole to a TD of 8005' MD, ran E-line logs and the decision has been made to P&A the well. These procedures cover the proposed P&A plan. 2. Notify BLM/AOGCC 48 hours in advance of all well P&A operations. (Tim Billingsley talked to Tom Maunder and Stan Porhola on Saturday April 10.) Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 3. After all logging is completed, perform injectivity test into 6-1/8" open hole interval from 7710' to 8005' TD. Pressure up to a maximum of 3500 psi on the 7" casing and record injection rate. (Need a minimum of 2 bpm to proceed with retainer abandonment plan). If injection rate is not satisfactory «2 bpm), then an open hole plug will be laid in with 3-1/2" tbg stinger and the plug will have to be tagged and witnessed by BLM. 4. Mobilize and rig up D/S for well suspension operation. RIH with Baker cement retainer on 4" drill pipe. 5. Set retainer at 7550'. ../ 6. Establish injection into open hole below retainer. 7. Mix 15.8 ppg cement. Cement volume calculation = 8005' -7710' = 295' x .036 bbl/ft in 6-1/8" hole x 1.2 washout = 12.7 bbls 7710' - 7550' = 160' x .0382 bbl/ft in 7" 26# csg = 6.1 bbls Lay in 4 bbl of cement on top of retainer = 4/.0382 = 105', TOC = 7550' - 105' = 7450' appx . \/ Total cmt = 12.7 + 6.1 + 4 = 22.8 bbls 8. Pump cement down drill pipe, with appx 4 bbls of cement still above retainer; unsting and allow remaining 4 bbls to dump on top of retainer. 9. POOH approx. 3 stands, circulate until drill pipe is clean. POOH. 10. RU to pump down the 9-5/8" x 7" annulus. Pump 100 bbls of water to flush annulus and verify injectivity, note rate and pressures. Bullhead 91 bbls of ArcticCrete 12.0 ppg cement into the annulus. Hydrocarbon zone is present from 2940' to 3040'. Annulus cement volume calculations = Surface to 7" shoe at 2663' = 2663' x 0.0282 bbl/ft (7" x 9-5/8" 40#) = 75.1 bbls 2663' to 3240' (200' below hydrocarbons) = 577' x .023 bbllft for 8-1/2" x 7" x 1 .2 excess for washout = 15.9 bbls TAB 4/11/04 e Spark #4 P&A Procedure e CONFIDENTIAL for AOGCC and BLM Total annulus cmt = 91.0 bbls 11. POOH to 561' MD. Spot a 10 bbl high vise pill from 561' MD to 300' MD. Spot a 300' plug (11.5 bbl) of 15.7 ppg Arctic Set I cement plug from 300' to surface in the 7" 26# casing. 12. RD and move out rig. 13. Cut off wellhead and all casing strings at 3 feet below ground level. Verify cement is at surface in all strings. Send casing head with stub to Materials for repair/redressing. 14. Weld 14" thick cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top. Drill1/8" weep hole in cover plate. · Conoco Phillips Alaska, Inc. · Spark #4 · PTD# 204-008 · API# 50-103-20479-00 · SHL: 571' FSL, 232' FWL, Sec. 20, T11 N, R1 E 15. Remove cellar. Back fill cellar with gravel as needed. Clear ice pad location and demob all materials/equipment. TAB 4/11/04 ASP Coordinates for Spark #4, Scout #1, & Spark #8 . . Bob, per our discussion today the coordinates for the above wells in NAD 27 ASP4 should be as follows: * ).()I/OOflO Spa r k # 4 : * Scout #1: X=278,294 & Y=5,958,093 X=257,976 & Y=5,958,609 A PTD package for Spark #8 should be arriving shortly (if not already), and the coordinates in NAD 27 ASP4 should be as follows: * Spark #8: X=252,539 & Y=5,943,628 The legal descriptions in the permits remain as indicated. Thanks, Tom 265-6377 (w) 275-7352 (p) 265-1336 (f) 1 of 1 1/14/20047:44 AM · ~ íM J Lrù e J I I ? ¡ , i / i ! I I FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION / ¡ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 Re: NPRA Spark #4 ConocoPhillips (Alaska), Inc. Permit No: 204-008 Surface Location: 682' FSL, 569' FEL, Sec. 23, TllN- ROlE, UM Bottomhole Location: 682' FSL, 569' FEL, Sec. 23, TlIN- ROlE, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above exploration well. This permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10-403AD prior to the approval of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In your application, it is indicated that testing and stimulation of the productive intervals in the well may be performed. A Sundry Application (Form 403) detailing the planned activities should be submitted for approval. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) ofthe diverter function test and BOPE tests must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~....' //)~í f I ) / ;:¿/~L -{.--¿f~ , , C () --- Sarah Palin Chair BY ORDER OF THE COMMISSION DATED this 12th of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation wlo encI. P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 682' FSL, 569' FEL, Sec. 23, T11 N, R1 E, UM ' Top of Productive Horizon: 682' FSL, 569' FEL, Sec. 23, T11 N, R1 E, UM Total Depth: 682' FSL, 569' FEL, Sec. 23, T11 N, R1 E, UM . 4b. Location of Well (State Base Plane Coordinates): Surface: x- 772405 16. Deviated wells: Kickoff depth: 0 ft. 18. Casing Program Size 1a. Type of Work: Drill 0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Hole 24" 12.25" Casing 16" 9.625" 8.5" 7" 6.125" 4-1/2" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee (;2] Property Plat 0 e ~L<; e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RedrillU 1b. Current Well Class: Stratigraphic Test 0 Exploratory ~ Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone (;2] 5. Bond: [d Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 Spark #4 6. Proposed Depth: 12. Field/Pool(s): MD: 8200' TVD: 8200' NPRA Exploration 7. Property Designation: ALK 5166 8. Land Use Permit: 13. Approximate Spud Date: March 20, 2004 14. Distance to Nearest Property: 4598' at TD / ADL AA081821 9. Acres in Property: 5756 10. KB Elevation 15. Distance to Nearest y- 5959760 Zone- 5 GL 50' & 37' RKB Weft WIthin PooT: ~oose's TOoth C , 3 mi 17. Anticipated Pressure (see 20 MC 35.035) ,/ Maximum Hole Angle: 0° Max. Downhole Pressure: 2948 psig / Max. Surface Pressure: 3850 psig Setting Depth Quantity of Cement Specifications Top Bottom c. f. or sacks Weight Grade Coupling Length MD TVD MD TVD (including stage data) 63# B PEB 80' Surface Surface 117' 117' 200 sx AS I 40# L-80 BTC 2685' Surf. Surf. 2722' 2722' 350 sx AS III Lite & 170 sx Class G 26# L-80 BTC-M 7625' Surf. Surf. 7662' 7662' 180 sx Class G + additives 12.6# L-80 IBT-M 688' 7512' 7512' 8200' 8200' 130 sx Class G + additives PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD Length Size BOP SketchD Diverter Sketch 0 perfOration Depth TVD (ft): Drilling program(;2] Time v. Depth Plot Lcd Seabed Report 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis 0 20 AAC 25.050 requirements (;2] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Contact Tom Brassfield @ 265-6377 Title Drilling Team Leader Phone Date Signature P. Mazzolini 7~fJ1~ e)j 10 '6 ID4- Preoared bv SharQn AI/suo-Drake Commission Use Only Permit to Drill I I API Number: . I Permit Approval ./ ( Isee cover letter Number: Xl --{JOB 50- /(J:3 - 2ZY!£:{'}·_{)() Date: \ IZ)CJ'--f for other requirements Conditions of approval: Samples required -g Yes 0 No Mud log required ~et:flt'~ ~V~ D Hydrogen sulfide measures 0 Yes Q No Directional survey required 0 If~~ . .~ jLJ"" ... t. \ V\(,¡ ,Co" ()" Other: ~~~'.~~~~~\"\.~ ~ o."'~~~~~ ~'1 '-\Cs... '\'\ \..O\' \Ñ(J.\~;J ~ô,,~~~~~<§~~ 4~ 5()t:O~, \ ",\, c. \ '3'(;;)~ "",It~~ ~~C)O Ç>->\ \'J\.\~\ """~ "'" \~rtc;..~~ r . Alaska Oil & Gas Cons. Conmîs.sío 1 BY ORDER OF ' Original Signed By COMMISSIONER THE COMMISSION Date: Anchorage t 120L- Saràtl to»alin Approved by: Form 1 0-401 Revised 3/2003 . ORIGINAL Submit in duplicate e Conoco Phillips Alaska, e. Drill and Case Plan for Spark #4 General Procedure: 1. MIRU Doyon 19 over pre-installed 16" conductor casing with welded landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. / 3. Spud well and drill 12 1/4" hole to the surface casing point at 2722' MD/2722' 1VD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. . Employ lightweight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 V2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT (or FIT if gradient reaches 16 ppg equivalent) · Record results and fax to town ;/ .- 9. Drill 8V2" hole to top of Jurassic at approx. ±7662' MD/±7662' 1VD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Will trip to pick-up rotary BHA, placing GRfResistivity as close to bit as possible to assist in picking casing point. 10. Run 7" intermediate string to isolate potentially sensitive shales located just above the objective (est.@ 7662' MD /7662' 1VD). Cement casing to bring cement ±1000' above 7" shoe. 11. Make up 6 1/8" mill tooth bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment, circulate & condition mud, displace to coring fluid and TOOH. (LOT is not planned for this casing string - see attached explanation). 13. PU core barrel, RIH and core at least one 60' core. v TOOH, LD core barrel and PU 6-1/8" bit and drilling assembly and llH. ,/ 14. Drill 6 1/8" hole to ±8200' MD / ±8200' 1VD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. · Condition hole and mud for e-line logs. 15. Log 6-1/8" wellbore as necessary. v 16. Run and cement 4 V2" 12.6# L80 IBT-M Liner 17. Make a cleanout run with bit and scrapers · Displace to filtered seawater or brine- depending on formation pressure. · Pressure test well to 3000 psi for 30 minutes (perform low pressure test on liner lap). · Record results and fax to town 18. Run and land 3-1/2" or 4 V2" tubing with gas lift completion 19. Nipple down BOP's. Install production tree and pressure test same to 5000 psi.6 20. Secure well, release rig. ORIGINAL e Conoco Phillips Alaska, e. 21. MIRU well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or trucked to Kuparuk or Alpine production facilities. 22. Upon completion of testing or if the well is not completed, plug and abandon the well, or temporarily shutdown per applicable regulations. Thoroughly clean location and block off further ice road access to location. ORIGINAL _ Conoco Phillips Alaska, e. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Spark #4 Drilling Fluid Properties: Spud to surface casing point Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids 9.5 - 10.2 ppg 16 - 26 25 - 35 50 - 100 10 - 20 15 - 40 7 - 15 9.5 - 10 ± 10% Drill Out Intermediate hole 9.5 - 11.3 ppg 6 - 20 5 - 20 35 - 50 2-6 14 - 20 < 6 below 7000' 9.0 - 10 < 11% Production Hole (Intermediate shoe to TD) 9.7 - 9.8 ppg v 15 - 25 14 - 24 50 - 70 3-6 3-8 <10 9.0 - 12.0 <8% DrillinS! Fluid System: Equipment list for Doyon 19 should be on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 MC 25.033. Maximum Anticiøated Surface Pressure and Casing Desian: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size 16" 9-5/8" 7" 4-1/2'''' Casing Setting Depth 117' MD / 117' ND 2722' MD / 2722' ND 7662' MD / 7662' ND 8200' MD / 8200' ND Fracture Gradient 11.0 ppg 14.3 ppg 17.6 ppg 17.6 ppg Expected Maximum Mud Weights: Pore Pressure Gradient 8.33 8.33 9.4 ppg 9.0 ppg 12-1/4" surface hole to 2722' MD /2722' ND: 10.2 ppg Pore Pressure 51 1179 3745 3850 ,/ MASP Drilling NA 54 psi 1725 psi 2948 psi 8-1/2" Intermediate hole to 7662' MD /7662' ND: 11.3 ppg (for shale stabilization) y 6-1/8" Production Hole to 8200' MD / 8200'ND: 9.8 ppg . ORIGINAL _ Conoco Phillips Alaska, _. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) - 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.11 = Gas Gradient in psi/ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D = [(11.0 x 0.052) - 0.11] x 117' = 54 psi OR MASP = FPP - (0.11 x D) = 1179 - (0.11 x 2722') = 880 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(14.3 x 0.052) - 0.11] x 2722' MASP = 1725 psi OR MASP = FPP - (0.11 x D) = 3745 - (0.11 x 7662') = 2902 psi 3. Drilling below 7" Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(17.6 x 0.052) - 0.11] x 7662' MASP = 6169 psi OR MASP = FPP - (0.11 x D) = 3850 - (0.11 x.8200') = 2948 psi / ORIGINAL _ Conoco Phillips Alaska, e. Casing Design Performance Properties Size Weight Grade I Connection I 16" 63 ppf B PEB 9-5/8" 40 ppf L-80 BTC 7" 26 ppf L-80 BTC-M 4-1/2" 12.6 ppf L-80 BTC Internal I Yield Collapse Conductor Casing 5750 psi 3090 7240 psi 5410 8430 psi 7500 psi Tensile Strength Joint Body 979 M 916 M 667 M 519 M 304 M 267 M Casing Setting Depth Rational: 16" @ 117' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8" @ 2722' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8-1/2" hole to top of reservoir. 7" @ 7662' MD RKB Intermediate casing is set strictly to provide isolation of potentially troublesome shales. The shoe of this casing will be set immediately into the top of the objective with a planned core to be taken immediately below the 7" shoe. A LOT would require 20' of additional hole to be drilled and would jeopardize targeted core recovery. Bottom hole pressures are available from offset data in the area. Well Proximity Risks: None Drilling Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Spark #4 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached mud weight versus depth graph for the offset wells Lookout #1, Lookout #2, ARCO Spark #1, Rendezvous "A", Rendezvous #2, Mitre #1, and Moose's Tooth "C". Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The Spark #4 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. PAl may request approval to inject or dispose of fluids in the Spark #4 9-5/8" x 7" annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 AAC 25.080. ORIGINAL Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (55) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE. D5i 260 1185 1434 1582 1784 2583 2776 Geology: Permafrost K3 Sequence 97 Sequence 95 Sequence 93 Sequence 92 Base Ponded Turbidites Disturbed/Pebble Shale LCU Top Jurassic UJU/J4 Base J4 Silt TD . Conoco Phillips Alaska, e. 600' 2735' 3310' 3650' 4015' 5740' 6100' Absent 7235' 7575' 200' 200' 200' 200' 200' 200' 200' Possible Oil or Gas 7770' 200' 3328 200' Probable Oil and/or 3745 .- / Gas 200' 3810 ./ 3850 ./ 8113' Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 - Surface Casing setting depth) LWD: GR/Res 8-1/2" Intermediate Hole (Surface Casing setting depth to Top J4jUJU) LWD: GR/Res/Density/Neutron/PWD 6-1/8" Production Hole (7" Shoe to TO) LWD: GR/Res/Density/Neutron/PWD Wireline: GR/Res/Dipole Sonic/CMR/MDT (Contingency: PEX/MSCTjVSP) II. Coring Full Diameter 2.5" Core in Upper Jurassic (1 - 2,60' cores) Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful II. Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TO. Service most likely will include ROP on S' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Thirty to sixty-foot (30'-60') wet and dry samples will be collected from surface to surface casing setting depth. Thirty-foot (30') wet and dry samples will be collected from surface casing setting depth to well TO and ten-foot (10') wet and dry samples, or continuous, collected across any hydrocarbon intervals. ORIGINAL · Conoco Phillips Alaska, e. III. Flow Testing Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build-up. The flow period will be determined on-site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build-up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. ORIGINAL e Conoco Phillips Alaska, e. Spark #4 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) .12-1/4" Hole / 9-5/8" Casing Interval Event Gas Hydrates Risk Level Low Clay Balling Medium Abnormal Pressure in Surface Formations Lost Circulation Low Medium 8-1/2" &. 6-1/8" Hole Event Lost circulation Risk Level High Hole swabbing on trips Low Directional Control Medium Sloughing Shale, Tight Hole High Abnormal Reservoir Pressure Hydrogen Sulfide gas Low Low Mitigation Strategy Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Diverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled running speeds. Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- planned LCM pills, lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BHA design, on-sight geologic review and advisement of potential slump blocks. Increased mud density and fluid composition according to plan, controlled trip speeds, sweeps, ECD monitoring. Well control drills, increased mud weight, contingencies for top set casing string. H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGINAL TVD/M D o 1000' 2000' 3000' - 4000' - 5000' - 6000' - 7000' - 8000' - 9000' Well: Spark #4 e Field: NPRA Exploration Est. RKB Elevation @ 87' Permafrost@687' ~ 9-5/8" Csg Pt @ 2722' K3 @ 2822' ~ TD @ 8200' I o Vertical Section Sequence 97 @ 3397' Sequence 95 @ 3737' Sequence 93 @ 4102' Sequence 92 @ 5827' Base Turbidites @ 6187' LCU @ 7322' Top Jurassic & 7" Csg Pt @ 7662' { Base J4 Silt @ 7857' ORIGINAL e Estimated Surface Location: 682' FSL, 569' FEL Sec.23, T11 N,R1 E,UM " Spark #4 e WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 117'MD/RKB Base of permafrost 687' MD 9-5/8" Surface Casing at 2,722' MD Top of Cement at 6,662' MD 7" Intermediate Casing at 7,662' MD 4-1/2" Production Liner @ 7,512' MD to 8,200' MD I I J I I ~ I 1 8-1/2" Hole l'WH" e Conductor Casing Size 1 Hole Size Depth: Top 01 Cement Excess Calculated: 16" In 20' hole 117' MO RKB Surface 100% Volume Calculations: (11711) (0.7854 elm) (184 cl) 1(0.93 ellsx) Slurry Volume: 184 cf SIurryWei9ht 15.7ppg Slurry Yield 0.93 cf/sx (2.00) = 184 eI 200 sx or Arctic Set 1 200 sx rounded Surface Casing Stage 1: Volume excess 9-518' in 12-1/4" hole (4.50) = 968 eI (1.45) = 561 eI (68711) (1,23511) (1,529 cf) (80011) (363cl) (0.3132 ellll) (0.3132 ellIl) 1(4.44 ellsx) (0.3132 ellIl) 1(2.40 ellsx) Lead Tall shoe Joint vol 34 cf + 344 sx (1.45) = 363 eI 166sx System: Lead (Arctic Set 3 Ute cement + 9% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% S1 (Cae,,") + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tall (UteCrete @ 12.0 ppg) 12-114" Hole Lead Slurry Volume: 1,529 cl Slurry Weight 10.7 ppg Slurry Yield 4.44 ellsx Thickening Time 6.0+ hours Tall Slurry Volume: 363 cf Slurry Weight 12.0 ppg Slurry Yield 2.40 ellsx Thickening Time 3.5 ·4.5 hours or 170 sx Class G or 350 sx Arctic Set 3 Lite Intermediate Casing Size 1 Hole Size Depth: Top 01 Cement Excess Calculated: BHT (Static): 7" in 8-112" hole 7,662' 6,662' 50% 16()!! F 13()!! F BHT (Circ): excess Volume around 7 " (1,000 II) shoe joint vol 17 cl + (190 cf) (0.1268 ell!1) 1(1.17cf/sx) (1.50) = 190 eI 177 sx System: (Class G cement + 1% D800 + 0.2% 046 + 0.3% 065 Slurry Volume: 207 cf Slurry Weight 15.8 ppg Slurry Yield 1.17 cf/sx Thickening Time 3.5 - 4.5 hours or 180 sx Class G Production Casing Size 1 Hole Size Depth: Top of Cement Excess Calculated: BHT (Static): 4-112" in 6-118" hole 8,200' 7,450' 40% 16()!! F 130" F BHT (Circ): excess Volume around 4-112" (53811) (0.0942 cllll) (1.40) = 71 eI Vol. Between liner & Int. 20 sx shoe loint vol 7 cf+ (71 cl) 1(1.20 ellsx) 65 sx Volume 01 200' above liner 40 sx System: (Class G cement wlGasblok + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.75% 065 (disp) + 1 gps D135 + 2 gps D600 + 0.1 % 0800 (ret.) Slurry Volume: 130 cl Slurry Weight 15.8 ppg Slurry Yield 1.20 ellsx Thickening Time 3.5 - 4.5 hours or 130sx Class G Cement volumes and blends are estimates only and subject to change before pumping. 12/29/2003 ORIGINAL Spark #4 e Proposed Completion Schematic 16" 6S# H-40 @ +/-117'MD r¡¡ I ¡ I J I, I ~ ~ ~ I ! I I ~ i I j! I I I I Depths are based on est rig RKB Surface csg. 9-S/8" 40.0# L-80 BTC (+/- 2722' M D /2722' TVD) Intermediate csg. 7" 26.0# L-80 BTCM (+/- 7662' MD /7662' TVD) Production Liner 4-1/2" 12.6# L-80 IBT-M (+/- 8200' MD/8200' TVD) .. .. ... ..... r r r Iii I, L II I ! . I I I I r.. - 4-1/2" FMC Gen VTubing Hanger, 4-1/2" L-80 IBT-M pin down 4-1/2" 12.6# L-80 IBT-M Spaceout Pups as Required 4-1/2" 12.6# L-80 IBT-M Tubing to Surface 4-1/2" Cameo 'DB' nipple w/3.875" profile set at +/- SOO' MD. 4-1/2" x 6' L- 80 IBT-M pup installed above and below 4-1/2" 12.6# L-80 IBT-M tubing to landing nipple 4-1/2" x 1" Cameo 'KBG-2' mandrels w/ DV's and RK latch, 6' L-80 handling pups installed above and below. Spaced out w/4-1/2", 12.6#/ft L-80 EUE8rd tubing as needed. 4-1/2" x 1" Cameo 'KBG-2' mandrel w/latch & dummy, 6' L-80 handling pups installed above and below. 2joints 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" x 1" Cameo 'KBG-2' mandrel w/latch & dummy, 6' L-80 handling pups installed above and below. +- 1 joint 4-112" 12.6# L-80 IBT-M tubing 4-1/2" Halliburton "XN" nipple w/3.725" profile 1 jt 4-1/2" 12.6# L-80 IBT-M tubing Baker locator sub 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 4-112" L-80 IBT box up Liner Assembly (run on drillpipe). Baker 7" x 4-1/2" 'ZXP' Liner Top Isolation Packer with C-2 profile & 12' PBR Baker 7" x 4-1/2" 'HMC' Liner Hanger 4-112" 12.6# L-80 IBT-M liner as needed 4-1/2" Baker Landing Collar 1 jt 4-1/2" 12.6# L-80 IBT-M tubing 4-112" Baker Float Collar 2jts 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Baker Float Shoe 3_%" 9.3 ppf L-80 EUE rd may be substituted for the 4-~" ORIGINAL TJB 12/22/03, v1 Spud Well @ 0900 hrs 3/31/01 1000 2000 ¡::- W W IJ.. -- :t: .... a. w c c w a:: :J U) <t w ::E 3000 4000 5000 6000 7000 8000 9000 116" set @ 108' I DRILLING TIME AND MUD WEIGHT CURVE Lookout #1 ............ Depth Mud Weight o 1= I I I I _L_L_i___.1_L_L I I J I I - í -1- -I - ~ T í r _ L ..,.,.1_ _I _ _ _ .1 _ L _ 1- , I _:_ _ _.; _ ~ _ Slouging shales. Incr. MW I I ! from 11.3 ppg to 11.5 ppg to ::.... + - I :- control .} I I _J._L_L I I r-r I I I I I .1_L_ _I__I_..J .1__ I I ¡ I T-r---I--I-~ T---r-I- J. _ L__ _I__I_...J _ J. I J I I ) ~-T r---I-~-~-T r-I- ~ _ ¡Drill 12-,1/4" Hole 1_ _ I , -1_..1_.1 I ) ) I -I-ì-T-¡- 11.9 11.7 I I 1- f + - -!- c- 11.5 f-- 11. + - 'i- L_ I - __I - -- 11.1 I 1 -r--¡----¡--¡-1"-r- J.._L_L___I_.J_J.._L 1 i 1 I I I -r--r -J--¡-T-ï- 10.9 I I I 1 I 1 , I I I I I I- -r r - - -!~ ì - T - í- :¡:: L L_L _I_.J _.L L_ C) I I 1 1 1 10.7 ~ r - -1- ì T - í"':;-- .L _L_L _ _I_.J .L L_ 1 ! I , I 1 1 ! m-----r-Tm·"T-- 0 -i- _ J.-.-__ L ___ -I .}-~ 10.5 ;:) - To'/Make attempt @~ :E - DPC logs, run 2 pre- casing wiper trips to ~ 10.3 clean hole, run 7"/Cement/Run - GR/JB/USIT/MDT, 10.1 run 2000' of tbg and RDMO 9.9 I , _1- _,~ 9.7 o 30 45 60 10 15 25 Rig @ 0600 hrs 4/30/01 5/0701 I 2000 4000 6000 8000 10000 J__i__l.__ L_.J_ I I I I -T ---r-¡--,-- ---~-~--I--+ ---~-~--~- ___~_ J _L , , , , , L ..J__L_ , , - -1-- -j f- , ï-- I i 6" set @ i i 5'1 DRILLING TIME AND MUD WEIGHT CURVE Lookout #2 o I I I I I I __I__~ _1_ L____L_J__I__l.__ , - -1-- - -1- - + - -1- - r _-1_ I , I - ~- I T +- 1 , 1000 -T r--t--I- +--- ,__L_ __1_____ , , , , _c-_ , ,- , ~ - - r-~ , I _Î_ _ L 3000 +--r- --!-- [- -1- _ L_ , I I I I L_.l__L_.l , , ~ 5000 -1---1- - + - --- I- , , -¡-- I _1_ , 7000 I ¡--i--¡ !- -...¡. -1- -..¡.. 9000 1 j _I__L 1 , - T 1- - l - - r- ~ ì - I- - -1- _ - -J 1 I I -, 1 .L__ 1 -T- ,",j- - + -. , -T- __ J_ I - , __-1·__1_ I - -1-- o 10 5 Spud Well @ i 800 ............ 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I I I I I I --:--:--f-:-- --T--:--:-:----:-r-:-- i -~ -:-~ -r7-~- -~ -~-',--:-- --r-T--:--:'-- --:1Run ~1f¿· --:--qRlg Released .4I29/OOJ=- 8.6 __ J _ _,_ _1. _ J_ _ _ _.L i c- _L_J ____ L _.!__L _.L_ _ __L_ J __1__1. - - - _L _.1._..J_ _L__ - -'- _.L -....- ---- --'- - L -... - -'---- ---- -~- -'-- __ ~ _ _:_ _ ~ _ ~_ _ _,.. {i hole openEr runfi-·-~ _~ __ __~_ ~- -~ ...:.} ~- --~-{--:--~ -- - ~~-} --:-- ~:.- --:- -}- ~-:-~:.- - -:-- ~ -~_...::- - - - -:- -~ - {- -:..: -- 804 ___I,..-~-.-~-.,.--.-~-_~--I--~-+-~--~-... ____.__I-_~-.----~-...,.-I--~--,..-~-.-~--.--_-~-.-~--I-_---I--L-_I--~___~__·_·__~-· " " 1 I " " I I 'I I' 'I·" " I ., "".", I 'I 1 -' - _ _ ï -. -~- - ¡ -"'!- - - - ¡ --,- -ï-! - - -.-¡ - -.- -.-- ï -- -- r-T-,--¡ -- --ï-:¡--,- -¡-- --,--!,--,--!"- - - -,--¡- -~- -¡ - - -Y -!"-ï- -,- - - - -.- -¡ - ï - !- o 5 10 15 20. 25 TIME TO DRILL (DAYS) 30 35 40 " . . 12.0 11.8 11.6 11.4 11.2_ 11.0 10.8 10.6 10.4 l- x 10.2 æ ~ 10.0 Q :) 2 9.S 9.6 9.2_ 8.2 45 Jt 9199 --+-- Depth DRILLING TIME AND MUD WEIGHT Rendezvous "A" 11.4 11.2 11 10.8 ~ 1 1 0.4 ~ 52 IJJ ~ 0.2 c ::::> 2 Weight On I I I I , __L___ ~_ ___ _L ~_ __ __ _~ _____ ~_ L ____ ____ __ _____ L__ L __~_ I I I I I I --- r- j----- ---1- -j --ì-- ì ---r ------ r -- --r -¡---- __ _L_ ~___ ___~ ____L_ __ ___L L __ __ Drill 9-7/8' __ __~ __,- __ ___ ,___ ___ ~ ___~ _________ ~ _____ ~_ ~___ I I I I I , - 01' @ 16" set Hole e--- I I~ .- - - - I -1-- --+- 10 9.8 1 I I I I I 1--- 1-- --1- ~-- --r- ~ î ----- î- ~-- -- r --¡- î --~ L_ ~_ ~_ J __ L ___ _L_ _J_ 1 I I I I ¡-- ---I -- --I -r- 1-- -- --- r-- 4--- I I I I I I I I I I I I I I -ï ï -- ï- r-- --- -1- -- -r---- --I --¡- ~__ ___ ~ ___ __~ _L___ _L ___ __L __ _____L___ J__ I I I I I I I Î -- -I ì- -r r- --- r-- --- r ---I --- _~___ __ ~____ ~ L_ __ L __ L L__ ~____ \ I I I I I ~-- -~- I \- - ~. - - !- I I I I~ -1- I ~!- -1-- ---- -!- ---~ --l- I I I I [ ¡ I ( \ \ --- -~--- ~-- -r---- -r -r-- r -, ~- ____ ___ __J ___ ___ ~_ I , -~- ---- ____L ____ L___ - - - ;!;;- _ L_ m.. ---, -,- -1--- I I - I- e- -- --1-- '" 1; C" - ----~~~--- 1 -1- - I I - - -1- -1-- I Core 60'/recover 60' ---!- I I- l- I.. I 1-- I , - - - 1..-. ¡- -- ---- ---- I -I -r- __~_ L_ I ---- ï ___~ ___L_ ~__ 1 I -----r ---I I --, 1- - --) .j I -1-- -, I I '-- I ---l.- I - --i - 1-- 1·- - I H ' 000 2000 3000 4000 5000 6000 7000 8000 set @2661 5.9 ppg FIT - -, I - - -,- - ~ I 1---- to KCI/Gem I __ L_ I -r- --¡- L__ _-1_ I I --- r----i ---- I I , r--- .., ---- ____ ____ L __~ ___ , I I --- --, -'-1Dri ___ ____L __~_ 1 I I - I-~ - I -- , I- I - --{- ---- --~- ~ ----¡- -t-- -- --- ---- 20 by __--i__ :- - 1- 5 5 o 2000 3000 ¡:;- W W u.. - ::r:: 4000 I- 5000 6000 7000 8000 9000 116" set @ 115' 1 DRILLING TIME AND MUD WEIGHT CURVE Rendezvous #2 o I L ___...1____ I I r-- -, -=IDrilI12-1/4"Hole~'--= =_=_= = I -' - , , ____-1 ____!- ---- - _-'_ I -, ___..J_ __ ...J_ I - ----- ï- I ---r _ ...1__ , --I - - - -> -- , 1000 I I - --I -I-- I 19-5/8" set @2680' L 14.5 ppg FIT -1-- '- I I L. I ---- ----4-----1 _____ .J ____L I ____I- ___.J_ ------ - - ----ï , I I I - ì ------- I ___..1 _..1 , I - - ì--- --- -ì--- __ _~_ ___ ...1_ , ----,--- -I - -- --- I- I I ----r _ L.._ I r L.._ I - - --I --1- -1---- ¡--- - I I I 1-- ---1-----.-,-¡-- L_ _ _1__ __ I I -:;-=lMWD Failure I . - - ----1 I --1- -; - - , I ---1- --- -- I I 1-· ---f- I I --I -- -.....¡-----¡----- I I I I --;- - -¡-.-- ----- - ,= - = = _ ~ _ - =Ic~ntrol LC, Core 60'/reco~er 57' __ L ___ ___ ____ ____ ___ I I --1-- i-- I _..1_ I , - -'----- , ___L I -----r--- -- I _ _ _ _ _L_ I ---r---- ___L I ----1--- I -~ r I - -i- i- I- I --1-- I 1------ -- - ¡-- , ----f-- 1- _ , - - - 1- __L_ I I r- ---r- L _______ I ----,----- --. -- - - - ~~ 1-- -- >- - - - - - ì_ I -- r -- ---- ~------- I - - -1-- _~_..__L , - - - 1- .- - f- - --. --1--- ---I I I --+- Depth Mud Weight I ___L_ I , I -¡-- ____1____- _ I ---Î~-- -1--- -- - 1- _____L._____ ____L. _ ~--- ~- 1-~---~--~ I I I ~~ __~ I _L~___.J_ r- - ~L_ _ -1---- -r - I I - - -I- i-- - -- I --¡- --- I I , -" I ---I -1----- -1--- I , I I I-- - - - I -- - ¡-- ~-- I i_~_ _.1____ I ! ~r- -~ 4~ ~ ___L ~ _.1__ , I ~ r --~J-- I I I , --r-~--i-- ~ ~ L__ .J_ , I --r - ¡ ~ _____L__ .J~ I I l -----T-----m- --! - - -.- I I í-- - - --1 ----1·- -----I- I I -1---- I - - ~- ___~--M ___-------r-------""___n__ I I - 1- - - I - - - - -..¡ I -1-- -j-- I , -¡- ---- ¡---~ I I ----¡-- - - ---- _..1_ I I ~-¡--- 4---- _---1__ I ---' I I --- ~--- -1----- .. - - _ _ _ ~1TD/Run 7"/Cement/Run GR/J8JUSITNSP/Run Completion/Operational SD _~ ~_ L_ ____L _~L ~_-I o 5 10 DRILL Spud Well @ 1600 hrs 4/8/01 - - ~ ~- - - 15 Release @ 2400 hrs 4/23/01 prepared by WBL 5/701 11.4 11.2 11 10.8 10.6 10.4 ~ C) ~ 10.2 Q ::::) ::æ: 10 9.8 9.6 9.4 9 20 2000 3000 4000 5000 6000 10000 116" set @ 106,1 , I DRILLING TiME AND MUD WEIGHT CURVE Mitre #1 ............ Depth -Mud Weight o 1 ~- 7000 I --'- I I I .....J _L ....!_ I -, I I I 1- _ ... _ _1_ _ I " _1_ _ 1.. _1_ _ ¡... I -, - -1- + - -1- +- __1__1.__1_ L I 1 , I , 1- '-----1_ I - -1- ~ -j- - r _1_ _ L I -~r-----~^____¡_____r___-'·-r _.....J L _-1 , i --I - I - f-- - -j - f--- - -I - _1- I I I ¡ - ¡- _.l- I -¡- _L_ 1 -1- - -e-- ...¡----+ -j - f--- - _1__ i ~ - _1____ 1 _.1 __1 1 I 1000 I I i l- _ _1__ .!- - --!- i 1 f - -1- +--I--j- --1-- _I__L ~__ i I I I , _ 1- _ ...-1 I -- I - ~---j L _ _I_ I , I 1-- ; -- .1 _.1-_ 1 -T- +- I_ I J _ _ 1_ -, _ _ J I r I I J Jþ _ _.J _ _i- _1-_ _1___ _.J - - I I I 1 -r-T ---~--- ---j -~-+- --~--~- __J _J.._______I_ I ) I - I L_..J_ I i r-l- f----....¡- __L I I , J.__I__L_.J__ I I I -ï -r-¡-- -+ -I--+- -j-- I L J 1. J ) I ) - , 1 - - - - T - -, - - f--- -1-- -+--I--t- 1 1 -1-- 1 _J , _ l- __I 1 I T- -J. - 1 _ I , - ~ - , - - -I __J_ I ~- - I - - f-- - -i - _1- _ ~ I I I 8000 9000 1 1 .J__L 1 1 -, -1- I ~-I-- o 10 20 30 40 15 @ 1400 hrs 3/6/02 Rig @ 1800 hrs 4/11/02 12 11.8 11.6 11.4 - 11.2 11 10.8 I- ::I: 10.6 C) [j 3: - 10.4 c ::I ::æ 10.2 10 9.8 9.6 9.4 9.2 TJB 1000 2000 - 3000 DRILLING TIME AND MUD WEIGHT CURVE Moose's Tooth C o 1 . I Move in Doyon 141 3/23/01 from Randy A ~ , ..1 I -r- - - - - I ______ _~____ __I_- I I - ----- - 4 - - -,-- .......- De pth Mud Weight --.----- 1.___ __ I -1'- - - I --)- - I ----- - ---- ,- - -; I I ----- - I I,," I 1- - -- - - _I__ I - -I- I r- - -..- I - -,-- -- - - -!.- , - -- I ì - -- , I I ~I- -- I -- -r _____1____- , I - - - -1'- J ^ I__ I I 1 -T- I --¡ - - ~ -- -1-- __ _I I - - - - -1 - - - - ~I- __1__- , ---- - - ---------- ------ , , ---- - - --- -- - - __I- I ----- I- I - - - ~ 5000 -~ 6000 7000 8000 9000 _~mm_ I - - "[ _1 I i--- I I - --, , -1---- I -----, I , -.1--- I -¡- - -- ------ ï-------!- --- ---- - ---- .---- I -1-- f- I ,_. I T-- , -,- -- - - - -I.· - -1-- _1- ~ I , - ---- - -,- - -¡ -- - - - -.{ I I _--1__ ·1- I I _ _1_ _, _ _ _ _ , [J-==~=--~=~=--=~-==- I I _---J__ - - - - "I , -- -- 1-- - --1-- ----~-- --~ I -----T·---- I I - -I -- --I-- I - - -I- I I - - -,- - _L _ _ _ I T--- , -------- , -T--- --- ___1._____ I _ _1_ _ , -+ + - - - I - - - ~ T _1.____ ___ I -1-- - I I ------- , . , , j T A weUfor MT -CA sidetrack, RDMO ---- T- ______1__ I 12.0 11.8 11.6 11.4 11.2 11.0 10.8 I- :t: 10.6 G ¡¡¡ == 10.4 § ::æ: 10.2 10.0 9.8 - -, 9.4 wbl 6101 l I J1 it;"- , I I r 're " - l < ! o --- " .1 ~ ~ ¡-'''¡' Feet 1 pas d e e Conoc~illips Box 100360 Alaska 99510-0360 December 30,2003 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Target Location: Bottom Hole Location: Spark #4 (Exploratory Test) 682' FSL, 569' FEL, Sec 23, TllN-R1E X=772405, Y=5959760 ASP5 NAD27 682' FSL, 569' FEL, Sec 23, TllN-R1E 682' FSL, 569' FEL, Sec 23, TllN-R1E Re: Application for Permit to Drill: Surface Location: Dear Commissioner: PHILLIPS Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test ./ well from the referenced location in the National Petroleum Reserve - Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling an 8-1/2" well bore to the top of the objective with a LWD logging suite for evaluation. A 7" intermediate casing will be run in order to case off potentially sensitive shales and drilled out with a 6-1/8" bit. Only a minimal amount of hole ( < 1 ') will be drilled before POOH to pick-up a coring assembly. At least one 60' core will be cut through the objective zone beginning immediately below the 7" shoe. The well will then be drilled to TO and depending on the logs either a 4-1/2" liner will be run and the well will be tested, post-rig or the well will be P&A'd. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" intermediate casing, a 4-1/2" production liner and either 4-1/2" or 3-1/2" tubing. Please find attached information as required by 20 MC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) 2) 3) Form 10-401 Application for Permit to Drill per 20 MC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 MC 25.005 (c) (1). / A directional plat showing the surface and bottom hole locations Propo~E. . . .. . for the well per 20 MC 25.005 (c) (2)- straight hole. t'( CEIVED JAN 0 8 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGiNAL e e 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 19) as required by 20 AAC 25.035 (a) (1) and (b) have been submitted previously. 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a). (Previously submitted-on record) 8) PHILUPS does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. ,/ 9) Complete logging, coring, and mud logging operations are planned and descriptions are attached. The following are Conoco Phillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs (20 AAC 25.071) Greg Wilson, Geologist 263-4748 The anticipated spud date for this well is March 20, 2004. If you have any questions or require further information, please contact Tom Brassfield at (907) 265-6377 or Paul Mazzolini at (907) 263-4603 Sincerely, Tom Brassfield Senior Drilling E gineer cc: CONFIDENTIAL - Spark #4 Well File Paul Mazzolini ATO-1570 Andy Bond ATO-Bl0 RECEIVED JAN 0 8 2004 üR\G\NAL Alaska Oil & Gas Cons. CommÎssion Anchorage e e ~(J~.'f:'\) ð.. """ I)~~~ ~ ~ % l- <~<:.~\Ç)~ ~tr~ <VÇ)~ Ç¡~~<:" ('-'/)<:' \\~ <6. v ~Ç)\~~~ ~~~~ ~\\~ · e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER c/ WELL NAME ~ P,-,'-. PTD# z¿; t/q X)~, <Li--~\C>~~"\O~ CHECK WBA T ADD-ONS APPLIES (OPTIONS) MULTI LATERAL J' Rev: 07/] 0/02 C\jody\templates (If API number last two (2) digits are between 60-69) Pll..OT (PH) "CLUE" The permit is for a new well bore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals througb target zones. D D Well bore seg Annular Disposal On Program EXP On/Off Shore Unit Well Name: SPARK 4 EXP / PEND GeoArea 890 ExptoratQfY wel -2.5miJe.sJn)mMo.osEf~ To.oth.C exptorato.fY wel Vertjcal wel e Yes .Yes Yes NA Yes Yes Yes NA. Yes Yes Yes Yes Yes NA NA. NA. N.o Initial ClasslType Field & Pool CONOCOPHILLlPS ALASKA INC Permit fee attached Company Lease nUmber approPJiate .U.ni~ue welln.ame .aod Iwmber .Io.cated located proper distance.from. driJling unit from. QtheJ wells ina. detil1ed pool We.1 Well Well boul1dary . lo.cated proper distance. .SIJtficiel1t ~ Jf .deviatec in.drilJing. unit included ...creag.e .ayailable 2 3 4 5 6 7 8 9 PTD#: 2040080 Administration is weJI bOJe plat onJy. affected party has .appropriate. b.ond in JQrce. Permìl.c.ao be ì$sued without Permil.cao be i$su.ed without Can permit be approved before WeJI1n......,...ðd ur:·u....:n ..,....ð""¡ ......,... C!'.... All w reyiew ideot[fìed (for:. s.ervice welJ onlï) Pre.-¡ of pre-production less. than 3 months (for conservation order administrativ.e.approvaJ in.commeots).(fQr 10# ojection Order # (put 15-day wait 'v.....".'.,." "''-'' ''', .... "'... ......" v,, ata authQri~ed by. Qnly) seryiçe well 10 11 12 13 14 15 16 17 Operator Operator Date Appr SFD 1/9/2004 SpaJk #4.SFD. Kaye .Laughlin~ ÆO: NQ reyiew was requ.ired tor JYD.in Moose's Tooth C çalculate >1.0,000 ppm..Seeatso "Sh.alJow. from Arcodated 3/2l2001 in wel sm in area (aquifers <3175' the NPAA Area" letter Jeport NQ USDWs expected Salioities.in AnnIJlar fJle 2Q1~003) may be r.eque$ted disp.osaJ Drilling. wa.stelo disposal welJs. Qr approved annul No reseJ\l.e.pit plaone.d Rig jse.quippedwith steel pits. Nearest welUs ab.out 3. miles .away.. .No.PJQximity proþlems. aITD, Planoed.MW .9.7-9,8, Hig.her wejg.ht planned in 8-112" .hole .due to.shales, Expected. BHF' 9.0 EMW e 35.00 psi appropriate, CPA!. usually testslo 5QOO psi CalcuJate.dMASP. 29<t8 p~i Yes Yes Yes No. Yes Yes Yes NA. Yes Yes Yes Yes Yes Yes Yes No. NA ACMP.F.in.dingof CQnsisteocy.has been jssued.forlhis proiect .Cooduçtor Surfacecas.ing.prQtec!s. al strjngprQvided 8 19 20 Engineering & SUJf.csg tie-in known pro.ductiye horilon$ lan..~·a 'M C,.T~ B .&.p.ermafrost pit. . . 1 ¡ba.ndonment known USDWs .CMTvotadequ.ate to circulate.oncond.uctor. to.Surf çs~ CMT will cover al - - - - - - - - .Casiog de.signs aa:v.,......."". "". Adequate .tanJç.age. OJ beeo apprQved Jfare-drilt has a Adequate wellbore. ~eparatjon propo~ed t m.eel. reguJa.lions Jist Jf .diverteJ require.d, do.es .adequate .DrilJiog. fluid. program sc.hematic& equip BOPEs,do they m.eetreguJa.tion PSig in .comments) .(put (May 64) test to Choke.ma.nifold cQmpJies w/.APLRF'-53 WOJk will occur without ratiog appropriate; BOPEpre.ss .operation .sbutdown 21 22 23 24 25 26 27 28 29 30 31 32 33 34 long striog .CMTvoladequate to Date 1/9/2004 Appr TEM Js. presence oJ H2S gas. pJob.able Meçha.nical condjtion of. wells withjn A08. yerified. (For service well only) .thi~ sectio.nJn any.offse.t wel Nooe ha$ .been. s.een in 1:128. wasn.ot Qb$erved io the nearby. MQo.se's Too.th C wel Seecommeots Þox~ below. CPAI Yes Yes Yes NA. Yes PelJ11il.cao be i$su.ed wlo hydr.ogensulfide measures 35 36 37 38 39 Geology Appr SFD sm inshaltow portions.of this.3D.dataset.. 1/5/04: .Noobviou.s~as indicators Greg WilSQn~ .Data.presented on pote.ntial overpres.sure ~ones (it off:-~hore) nam.elphoneJorweekly progre~s.reports [e2Cploratory .ooly] Seismic.analysis.oJ shaJlow gas.zones Seabed .condition survey Contaçt. Date 1/9/2004 T Qm Brass.field ,.9.07-265-63.77 H2S was not observed in the nearby «3 miles) Moose's Tooth C well. Spark 4 will be mudlogged, and H2S sensors will be utilized during drilling operations. Shallow hazards information presented in report contained in Carbon 1 well file (203-218). Shallow velocity data indicate slightly elevated pore pressures may exist below permafrost, but gradients should drop back to 9 ppg by 3800'. Pressure will rise again from normal at 6300' to 11.0 - 11.4 ppg between 7000' and TD. Nearby Moose's Tooth C was drilled with max mud wt of 11.0 ooa. Public ~ Date Commissioner~) .---- /' .. c... /' (_ "" ,/ ",.;~ Date Engineering Commissioner: Date: I/J2.(i Geologic Commissioner DTS e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . . ¡tJc;~ I---·-"--~'_"·m~_,,~._ . r·:"' 'T\." , ,", -'~._,..,....-. · l-Ul~F1DENT1AL CORE ANALYSIS REPORT ;20 Lj - 0 a 8 ConocoPhillips, Alaska Spark No.4 Well North Slope, Alaska FINAL REPORT Conventional Core Analysis Performed for: ConocoPhillips, Alaska 700 G Street Anchorage, Alaska 99501 Report issued: September 7, 2004 Performed by: OMNI LABORATORIES, INC. 8845 Fallbrook Drive Houston, Texas 77064 File: A-87001 The interpretations or opinions expressed represent the best judgment of OMNI Laboratories, Inc. and assumes no responsibility and makes no warranty or representations, as to the productivity, proper operation, or profitableness of any oil, gas or any other mineral well. These analyses, opinions or interpretations are based on observations and materials supplied by the client for whom this report is made. . . . ......--., /iJÈlvliii¡ September 7,2004 Mr. Andreas Andreou ConocoPhillips, Alaska 700 G Street Anchorage, Alaska 99501 Subject: Conventional Core Analysis Report Spark NO.4 North Slope, Alaska File: A-87001 Dear Mr. Andreou: Final results of the conventional core analyses measurements are presented herein. Preliminary data were provided as available throughout the course of the study and posted to the web site. Introduction Approximately 90 feet of conventional core was cut from the Spark No. 4 well in North Slope, Alaska. The core was preserved and transported from well site by a ConocoPhillips crew. Personnel from OMNI Laboratories Anchorage facility took possession of the core in Anchorage, Alaska. On April 10, 2004, a core gamma log was performed on the entire length of the core. The core was then extruded from the aluminum core barrel and striped and marked for orientation. The core was slabbed into 1/3 and 2/3 sections. All shale sections of the core were sprayed and preserved with mineral oil. The 1/3 section of the core was cleaned and placed in slab boxes for white light and ultraviolet light photography. Each three-foot butt section was cut into three one-foot lengths. The top three inches of each one-foot section was cut from the slab and one horizontal and one vertical plug was drilled with liquid nitrogen. All plugs were trimmed to right cylinders with a dry saw. The routine core plugs were preserved and prepared for transport by coating with mineral oil, wrapping with Saran Wrap® and aluminum foil, and sealing inside labeled Protec Core Bags. Eighty-six horizontal plug samples and eighty-four vertical plugs were sent to OMNI Labs Houston facility for analysis. The remaining nine inches of each butt section was preserved by wrapping in Saran Wrap® and aluminum foil and dipping in Core Seal. Extraction, Cleaning and Drying Methods All horizontal and vertical plug samples were subjected to Dean Stark extraction to determine in-situ saturations. Every other vertical plug was designated as a tracer sample. The samples were cleaned by an azeotrope extraction method using chloroform and leached of salts with methanol (the tracer samples were not leached). All samples were dried to a constant weight in a convection oven at 180°F. Routine Properties Measurement Methods Grain volumes of plug samples were measured by helium expansion using the Boyle's Law method. The equipment was calibrated with known volume steel disks. Berea, titanium and lead check standards were measured before each run. The samples were kept in a desiccator until ready for grain volume measurement. The Berea check plug was measured every 5th sample, and the grain volume measurement for every 5th sample was repeated to ensure continued equipment calibration. Grain densities (gm/cc) were calculated using the dry sample weight (gm) and grain volume data (cc) using the formula: Page 2 . ConocoPhillips, Alaska Spark NO.4 Well North Slope, Alaska File: A-87001 DW GV where: GD = Grain Density, grams/cc DW = Dry weight, grams GV = Grain Volume, cc Boyle's law helium pore volumes and steady state permeabilities were determined at 800 psi and 2600 psi net confining stress on all samples using the Frank Jones Steady-State Porosimeter/Permeameter. Porosities were calculated using the following equation: GD = ø = (PV)/(GV+PV) * 100 where: ø = Porosity, percent PV = Pore Volume, cc GV = Helium Grain Volume, cc The tracer sample analyses is still in progress and will be presented under separate cover. The routine core analysis results are presented in tabular and graphic formats at the end of this discussion. OMNI Laboratories, Inc. appreciates the opportunity to have been of service to ConocoPhillips, Alaska. If you have any questions, or if we may be of any further assistance, please contact me at 832-237-4000. . Very truly yours, ~~~~ Melanie F. Dunn Special Core Analyses Manager . Page 3 Laboratories, Inc. ConocoPhi!lips Spark NO.4 Well 100 80 c (]) (.) '- (]) Q. c: o ~ '- :::¡ m (J) 60~---~ ~...__._----"~_..__. '- (]) -- ro $: 40 ro (.) :¡::; '- (]) > ._-----._--_....~ 20 o o I AND HORIZONTAL SATURATION CROSSPLOTS Convection Dried at 180°F 100 2600 psi I 80 ~ ~~ c (]) (.) '- (]) 60 0.. ¿ .Q m '- :::¡ m (J) 0 ro 40 (.) t (]) > . . . . . -~- . . 20 . o 20 40 60 80 100 Horizontal Water Saturation, percent ~ 2600 psi o 20 40 Horizontal Oil Saturation, percent 6-8-04 North Slope, Alaska File: A-87001 60 80 100 I Laboratories, Inc. VERTICAL AND AND Convection Dried at 180°F ConocoPhillìps Spark No.4 Well 1000 C/) >. (.) I- ro :Q E ..: <{ .8 :2' :.õ ro (]) E '- (]) D... ro (.) :¡::; '- (]) > 0.001 100 1llllllfr1l11Hljlllllllllll IIIII 2600 psi ~~gs Are Different Lithologicallr ~------ 10 1 ~--~- ------ 0.1 0.01 0.0001 0.0001 0.001 0.01 0.1 1 Horizontal Permeability to Air, millidarcys ~----_.~-_._--'- ------~-- 10 100 1000 -- c (l) (.) '- (]) 0.. ¿:. ¡g 15 I- o D... ro J5 '- (l) > 30 I- 2600 psi I 25 I y ::: 1.041 20 10 5 o o 5 6-8-04 CROSSPlOTS North Slope, Alaska File: A-87001 - -~ 10 15 Horizontal 20 percent 25 30 ..- ~ #--~'~:d l\\; ."""~........,..,,,...ß"" ,,",ii;,.,..,'~~\' ,i """""'-~'.: ~r"-:n0 \:;\'\ \. \. \ .,." C()t,r~ 6-8-04 MNI Laboratories, Inc. . SUMMARY OF VERTICAL AND HORIZONTAL CORE ANALYSES Convection Dried at 180°F ConocoPhillips North Slope, Alaska Spark No.4 Well File: A-87001 Permeability at Porosity at Sample 2600 psi NCS 2600 psi Grain Water Oil Total Core Sample Depth, millidarcys NCS, Density, Saturation, Saturation, Saturation, Number Number feet Orientation to Air I Klinkenberg percent gm/cc percent percent percent 1 1-4 7714.10 Horizontal 0.080 0.045 17.1 2.77 63.9 13.9 77.8 1 1-4VT 7714.20 Vertical 0.045 0.023 18.3 2.78 54.2 17.1 76.1 1 1-7 7717.10 Horizontal 0.199 0.128 18.3 2.72 65.5 17.8 83.3 1 1-7V 7717.30 Vertical 0.159 0.099 21.6 2.72 54.5 12.6 75.6 1 1-9 7719.10 Horizontal 0.101 0.059 14.5 2.75 70.3 13.8 84.2 1 1-9V 7719.00 Vertical 0.112 0.066 17.2 2.72 63.2 14.8 48.1 1 1-10 7720.15 Horizontal 1.52 1.10 14.0 2.68 51.4 17.1 68.5 1 1-10VT 7720.00 Vertical 1.24 0.990 16.9 2.68 47.7 17.3 64.4 1 1-11 7721.10 Horizontal 0.222 0.145 10.6 2.92 54.1 17.4 71.6 1 1-11V 7721.60 Vertical 0.016 0.0065 8.5 2.86 38.8 24.3 67.1 1 1-12 7722.40 Horizontal 19.2 15.5 18.1 2.78 50.5 16.9 67.4 1 1-12VT 7722.50 Vertical 0.015 0.0059 12.2 2.98 41.1 16.0 73.3 . 1 1-13 7723.55 Horizontal 58.3 50.3 22.9 2.69 47.3 17.1 64.4 1 1-13V 7723.50 Vertical 2.98 2.37 20.1 2.71 56.1 18.4 87.5 1 1-14 7724.10 Horizontal 65.9 57.2 22.6 2.66 47.7 16.5 64.3 1 1-14VT 7724.00 Vertical 47.1 40.5 24.7 2.70 38.7 19.8 78.0 1 1-15 7725.10 Horizontal 70.1 61.1 23.2 2.72 39.9 18.4 58.3 1 1-15V 7725.00 Vertical 133. 119. 23.2 2.69 38.5 25.7 91.3 1 1-21 7731 .1 0 Horizontal 192. 174. 20.4 2.67 35.6 21.8 57.3 1 1-21VT 7731.00 Vertical 247. 226. 21.8 2.69 34.4 19.9 65.0 1 1-22 7732.10 Horizontal 33.7 28.3 21.5 2.74 35.9 21.6 57.6 1 1-22V 7732.00 Vertical 46.3 40.1 22.2 2.73 38.1 21.3 73.7 1 1-23 7733.10 Horizontal 79.0 69.2 22.8 2.70 38.7 20.7 59.4 1 1-23VT 7733.20 Vertical 29.1 24.8 22.3 2.72 38.6 20.8 63.1 1 1-24 7734.35 Horizontal 62.7 54.3 21.6 2.67 41.2 25.4 66.6 1 1-24V 7734.30 Vertical 32.1 27.4 20.9 2.68 42.5 20.0 100.0 1 1-25 7735.10 Horizontal 0.0051 0.0015 8.4 2.96 52.4 17.4 69.8 1 1-25VT 7735.20 Vertical 0.0068 0.0022 5.6 3.21 22.6 32.6 57.1 1 1-26 7736.10 Horizontal 0.012 0.0046 10.5 2.70 43.0 25.8 68.8 1 1-26V 7736.20 Vertical 0.0032 0.0008 10.2 2.69 46.5 36.3 75.1 1 1-27 7737.10 Horizontal 0.021 0.0091 11.9 2.69 36.5 25.8 62.3 1 1-27VT 7737.20 Vertical 0.0059 0.0018 12.3 2.69 35.3 19.0 74.5 1 1-28 7738.40 Horizontal 0.0086 0.0029 9.0 2.69 56.9 20.8 77.8 1 1-28V 7738.20 Vertical 0.0046 0.0013 10.0 2.69 47.5 34.3 68.1 1 1-29 7739.10 Horizontal 0.0077 0.0025 11.7 2.71 38.4 23.3 61.7 1 1-29VT 7739.30 Vertical 0.0092 0.0032 10.8 2.69 41.6 21.3 58.5 1 1-30 7740.10 Horizontal 0.027 0.012 12.7 2.68 34.6 23.8 58.3 1 1-30V 7740.20 Vertical 0.030 0.014 13.6 2.69 33.4 27.0 76.5 . 1 1-31 7741.10 Horizontal 0.047 0.024 12.7 2.72 30.7 19.7 50.3 1 1-31VT 7741.20 Vertical 0.013 0.0049 14.5 2.80 15.4 19.0 64.2 1 1-34 7744.30 Horizontal 0.056 0.029 14.0 2.67 28.1 21.6 49.8 1 1-34V 7744.40 Vertical 0.014 0.0050 15.5 2.68 25.7 24.3 70.3 1 1-35 7745.10 Horizontal 0.045 0.023 14.0 2.68 27.7 17.8 45.5 6-8-04 MNI Laboratories, Inc. . SUMMARY OF VERTICAL AND HORIZONTAL CORE ANALYSES Convection Dried at 180°F ConocoPhillips North Slope, Alaska Spark NO.4 Well File: A-87001 Permeability at Porosity at Sample 2600 psi NCS 2600 psi Grain Water Oil Total Core Sample Depth, millidarcys NCS, Density, Saturation, Saturation, Saturation, Number Number feet Orientation to Air I Klinkenberg percent gm/cc percent percent percent 1 1-35VT 7745.20 Vertical 0.017 0.0067 13.8 2.68 24.6 23.0 54.3 1 1-36 7746.10 Horizontal 0.035 0.017 13.2 2.67 29.0 21.7 50.7 1 1-36V 7746.20 Vertical 0.019 0.0080 13.7 2.69 30.7 16.9 70.0 1 1-37 7747.10 Horizontal 0.018 0.0077 11.9 2.68 36.5 22.3 58.8 1 1-37VT 7747.20 Vertical 0.018 0.0074 14.1 2.68 23.2 22.6 59.5 1 1-38 7748.10 Horizontal 0.019 0.0078 12.5 2.68 31.7 25.4 57.1 1 1-38V 7748.20 Vertical 0.006 0.0019 11.3 2.68 40.8 27.7 77.1 1 1-39 7749.10 Horizontal 0.013 0.0051 11.7 2.68 30.3 29.5 59.8 1 1-39VT 7749.20 Vertical 0.0053 0.0015 12.0 2.67 28.5 26.8 59.4 1 1-40 7750.10 Horizontal 0.024 0.011 12.9 2.68 33.6 22.0 55.6 1 1-40V 7750.20 Vertical 0.027 0.012 13.0 2.69 31.7 24.1 66.1 1 1-41 7751.10 Horizontal 0.019 0.0077 13.1 2.68 32.6 18.9 51.5 1 1-41VT 7751.20 Vertical 0.0051 0.0015 11.4 2.68 33.4 25.6 62.4 . 1 1-42 7752.10 Horizontal 0.027 0.012 12.3 2.68 31.6 23.5 55.1 1 1-42V 7752.20 Vertical 0.0039 0.0011 11.0 2.69 39.1 31.6 73.7 1 1-43 7753.10 Horizontal 0.0088 0.003 10.6 2.68 42.8 21.6 64.3 1 1-43VT 7753.20 Vertical 0.0056 0.0017 11.3 2.68 33.2 21.1 55.2 1 1-44 7754.10 Horizontal 0.010 0.0036 12.1 2.69 33.6 25.6 59.2 1 1-44V 7754.20 Vertical 0.002 0.0004 10.8 2.68 39.4 36.5 70.8 1 1-45 7755.10 Horizontal 0.0064 0.0020 11.0 2.68 36.5 26.7 63.2 1 1-45VT 7755.20 Vertical 0.0045 0.0012 9.6 2.69 34.6 31.6 82.8 1 1-46 7756.05 Horizontal 0.0078 0.0026 11.8 2.69 33.7 26.0 59.7 1 1-46V 7756.20 Vertical 0.007 0.0022 10.7 2.68 38.8 35.6 66.4 1 1-47 7757.15 Horizontal 0.012 0.0043 11.8 2.68 34.1 23.6 57.7 1 1-47VT 7757.20 Vertical 0.010 0.0034 12.4 2.68 24.4 32.6 54.3 1 1-48 7758.10 Horizontal 0.0061 0.0019 12.6 2.70 33.5 21.5 55.0 1 1-48V 7758.20 Vertical 0.0047 0.0013 11.4 2.69 29.1 40.7 67.0 1 1-49 7759.10 Horizontal 0.016 0.0065 11.5 2.68 40.2 22.6 62.8 1 1-49VT 7759.20 Vertical 0.014 0.0052 12.3 2.69 31.7 22.3 81.8 1 1-50 7760.20 Horizontal 0.027 0.012 11.4 2.69 36.0 26.1 62.1 1 1-50V 7760.30 Vertical 0.0055 0.0016 11.6 2.70 27.5 27.0 86.3 1 1-51 7761.10 Horizontal 0.0051 0.0015 10.4 2.66 41.0 24.6 65.6 1 1-51VT 7761.20 Vertical 0.0091 0.0032 11.3 2.69 31.9 24.0 62.8 1 1-52 7762.10 Horizontal 0.0048 0.0014 10.1 2.69 49.2 23.1 72.3 1 1-52V 7762.20 Vertical 0.0042 0.0011 10.0 2.69 49.7 18.9 66.5 1 1-53 7763.10 Horizontal 0.0092 0.0032 10.4 2.69 47.8 21.8 69.6 1 1-53VT 7763.20 Vertical 0.012 0.0042 10.5 2.69 37.4 27.8 60.4 1 1-54 7764.10 Horizontal 0.020 0.0083 10.5 2.69 48.5 20.6 69.1 1 1-54V 7764.20 Vertical 0.0054 0.0016 10.6 2.70 42.2 33.4 70.6 . 1 1-55 7765.10 Horizontal 0.0083 0.0028 9.8 2.69 55.5 20.2 75.6 1 1-55VT 7765.20 Vertical 0.0077 0.0026 9.5 2.70 48.1 0.0 34.5 1 1-56 7766.10 Horizontal 0.010 0.0034 9.7 2.69 49.7 38.2 87.9 1 1-56V 7766.20 Vertical 0.021 0.0089 12.8 2.69 39.6 24.8 67.2 1 1-57 7767.10 Horizontal 0.0031 0.0008 9.7 2.71 54.3 24.4 78.7 6-8-04 MNI - Laboratories, Inc. . SUMMARY OF VERTICAL AND HORIZONTAL CORE ANALYSES Convection Dried at 180°F ConocoPhillips North Slope, Alaska Spark NO.4 Well File: A-87001 Permeability at Porosity at Sample 2600 psi NCS 2600 psi Grain Water Oil Total Core Sample Depth, millidarcys NCS, Density, Saturation, Saturation, Saturation, Number Number feet Orientation to Air I Klinkenberg percent gm/cc percent percent percent 1 1-57VT 7767.20 Vertical 0.0042 0.0012 8.2 2.67 60.1 27.4 50.1 1 1-58 7768.10 Horizontal 0.077 0.043 9.0 2.69 60.0 25.8 85.8 1 1-58V 7768.20 Vertical 0.022 0.0096 9.3 2.68 65.3 26.1 72.4 1 1-59 7769.10 Horizontal 0.0043 0.0012 9.8 2.68 51.3 26.6 77.9 1 1-59VT 7769.20 Vertical 0.0041 0.0011 9.8 2.68 46.5 27.2 47.6 1 1-60 7770.10 Horizontal 0.015 0.0058 10.0 2.69 54.2 23.7 77.9 1 1-60V 7770.20 Vertical 0.0083 0.0028 8.9 2.70 72.4 27.7 75.8 1 1-61 7771.10 Horizontal 0.004 0.001 9.8 2.70 50.8 23.4 74.2 1 1-61VT 7771.20 Vertical 0.0024 0.0006 9.3 2.69 50.1 25.0 47.6 1 1-62 7772.15 Horizontal 0.012 0.0045 9.9 2.70 52.9 23.0 75.9 1 1-62V 7772.50 Vertical 0.010 0.0036 11.4 2.70 42.2 25.9 97.0 1 1-63 7773.45 Horizontal 0.0073 0.0024 9.5 2.68 56.4 16.4 72.8 1 1-63VT 7773.50 Vertical 0.0087 0.0030 9.4 2.69 48.3 28.2 45.8 . 1 1-64 7774.10 Horizontal 0.0071 0.0023 9.2 2.69 55.2 21.5 76.6 1 1-64V 7774.20 Vertical 0.0093 0.0032 11.5 2.70 40.7 29.6 76.8 1 1-65 7775.10 Horizontal 0.020 0.0087 8.7 2.70 66.6 17.3 83.9 1 1-65VT 7775.20 Vertical 0.0048 0.0014 10.7 2.69 48.8 21.1 68.5 1 1-66 7776.10 Horizontal 0.0076 0.0025 9.3 2.70 71.7 19.2 90.9 1 1-66V 7776.20 Vertical 0.0059 0.0018 10.6 2.70 51.3 25.9 81.2 1 1-67 7777.10 Horizontal 0.0046 0.0013 8.6 2.69 63.6 22.2 85.8 1 1-67VT 7777.20 Vertical 0.0043 0.0012 10.4 2.69 44.1 22.1 55.3 1 1-68 7778.10 Horizontal 0.0044 0.0012 9.4 2.70 53.8 24.8 78.6 1 1-68V 7778.20 Vertical 0.010 0.0035 11.0 2.69 54.0 19.8 74.9 1 1-69 7779.10 Horizontal 0.006 0.0018 9.3 2.69 58.6 22.8 81.4 1 1-69VT 7779.20 Vertical 0.011 0.0040 10.3 2.69 50.4 20.4 55.7 1 1-70 7780.10 Horizontal 0.0046 0.0013 9.1 2.69 58.3 24.5 82.8 1 1-70V 7780.20 Vertical 0.0067 0.0021 11.5 2.69 47.9 18.6 78.0 1 1-71 7781.10 Horizontal 0.008 0.0027 8.8 2.68 63.1 22.5 85.6 1 1-71VT 7781.20 Vertical 0.0072 0.0023 10.4 2.68 42.7 24.4 59.0 1 1-72 7782.10 Horizontal 0.0077 0.0025 9.5 2.68 60.5 29.2 89.6 1 1-72V 7782.20 Vertical 0.0077 0.0025 9.3 2.69 57.5 28.8 66.6 1 1-73 7783.10 Horizontal 0.014 0.0055 9.1 2.69 54.1 27.4 81.5 1 1-73VT 7783.20 Vertical 0.0015 0.0003 10.4 2.68 45.0 21.5 70.8 1 1-74 7784.10 Horizontal 0.014 0.0054 9.3 2.68 62.4 23.3 85.7 1 1-74V 7784.20 Vertical 0.0075 0.0025 10.9 2.69 41.2 29.4 82.5 1 1-75 7785.10 Horizontal 0.014 0.0052 8.8 2.66 61.4 20.6 82.0 1 1-75VT 7785.20 Vertical 0.010 0.0034 10.7 2.68 40.8 26.5 54.3 1 1-76 7786.10 Horizontal 0.0048 0.0014 9.2 2.69 54.3 28.4 82.7 1 1-76V 7786.20 Vertical 0.010 0.0034 10.7 2.70 44.7 27.6 88.9 . 1 1-77 7787.10 Horizontal 0.012 0.0043 9.2 2.69 69.3 26.1 95.4 1 1-77VT 7787.20 Vertical 0.016 0.0065 9.9 2.69 48.6 27.3 75.9 1 1-78 7788.10 Horizontal 0.0098 0.0035 8.9 2.69 63.1 27.0 90.1 1 1-78V 7788.20 Vertical 0.0061 0.0019 8.7 2.69 62.7 34.3 95.5 1 1-79 7789.35 Horizontal 0.006 0.0018 9.1 2.76 62.2 29.9 92.1 6-8-04 . SUMMARY OF VERTICAL AND HORIZONTAL CORE ANALYSES Convection Dried at 180°F ConocoPhillips North Slope, Alaska Spark NO.4 Well File: A-87001 Permeability at Porosity at Sample 2600 psi NCS 2600 psi Grain Water Oil Total Core Sample Depth, millidarcys NCS, Density, Saturation, Saturation, Saturation, Number Number feet Orientation to Air I Klinkenberg percent gm/cc percent percent percent 1 1-79VT 7789.20 Vertical 0.011 0.0040 9.6 2.70 51.3 25.5 66.2 1 1-80 7790.10 Horizontal 0.0043 0.0012 8.1 2.69 66.1 31.3 97.4 1 1-80V 7790.20 Vertical 0.0069 0.0022 9.8 2.70 50.5 30.7 81.6 1 1-81 7791 .1 0 Horizontal 0.019 0.0080 8.0 2.69 74.6 20.4 95.0 1 1-81VT 7791.20 Vertical 0.0024 0.0005 9.3 2.71 53.4 21.5 74.5 1 1-82 7792.10 Horizontal 0.0092 0.0032 8.1 2.70 79.9 18.5 98.3 1 1-82V 7792.20 Vertical 0.0061 0.0019 9.8 2.74 51.9 26.1 79.0 1 1-83 7793.10 Horizontal 0.011 0.0039 6.7 2.71 1 00.2 0.0 100.2 1 1-83VT 7793.20 Vertical 0.0035 0.0009 10.4 2.69 48.7 17.9 57.0 1 1-84 7794.10 Horizontal 0.021 0.0092 8.1 2.81 71.4 20.4 91.7 1 1-84V 7794.20 Vertical 0.011 0.0041 9.4 2.69 63.7 18.9 81.2 1 1-85 7795.10 Horizontal 0.115 0.068 8.1 2.69 96.5 11.5 108.0 1 1-85VT 7795.20 Vertical 0.0013 0.0002 8.2 2.69 77.8 11.1 69.8 . 1 1-86 7796.10 Horizontal 0.032 0.015 7.9 2.68 91.2 14.4 105.6 1 1-86V 7796.20 Vertical 0.0025 0.0006 8.2 2.69 77.3 18.2 92.1 1 1-87 7797.10 Horizontal 0.083 0.047 8.6 2.69 87.1 17.0 104.1 1 1-87VT 7797.20 Vertical 0.002 0.0004 8.4 2.68 50.9 30.6 54.0 1 1-88 7798.10 Horizontal 0.011 0.0041 8.0 2.69 60.2 29.5 89.7 1 1-88V 7798.20 Vertical 0.011 0.0039 9.2 2.70 64.2 14.8 96.9 1 1-89 7799.10 Horizontal 0.0077 0.0026 8.0 2.72 102.0 0.0 102.0 1 1-89VT 7799.20 Vertical 0.002 0.0004 8.3 2.71 52.3 29.0 54.5 1 1-90 7800.10 Horizontal 0.011 0.0040 7.8 2.70 71.5 20.8 92.3 1 1-90V 7800.20 Vertical 0.0062 0.0019 8.3 2.70 69.5 22.6 90.0 1 1-91 7801.20 Horizontal 0.0096 0.0034 7.0 2.69 98.5 10.7 109.2 1 1-91VT 7801.20 Vertical 0.0010 0.0002 7.6 2.70 74.2 22.7 55.9 1 1-92 7802.10 Horizontal 0.017 0.0071 7.5 2.71 85.3 17.3 102.6 1 1-92V 7802.20 Vertical 0.0075 0.0025 8.5 2.73 75.7 14.2 69.1 1 1-93 7803.10 Horizontal 0.0081 0.0027 7.3 2.73 90.2 15.4 105.6 1 1-93VT 7803.20 Vertical 0.0020 0.0004 10.2 2.70 58.0 11.2 68.6 1 1-94 7804.10 Horizontal 0.011 0.0042 7.5 2.68 87.0 18.5 105.5 1 1-94V 7804.20 Vertical 0.0009 0.0001 7.4 2.67 86.2 23.6 109.8 . ConocoPhillips Spark NO.4 Well (j) >- (.) '- ro :2 E (J) (f) :J '- <i: .8 £ ..a ro (1) E '- (]) 0.. 0.001 I Laboratories; Inc. 6-8-04 PERMEABILITY CROSSPlOTS Convection Dried at 180°F All Samples 1000 I 1IIII11i I I ¡ II 100 = Horizontal 800 psi ~ . Horizontal 2600 psi ~ . Vertical 800 psi = Vertical 2600 psi I ill = 0.91 10 1 _._._~~-~-~ ----_._---_.._.~~ 0.1 --------_.~~- II 0.01 y 1111111111111111 ¡ I 0.0001 0.0001 0.001 0.01 0.1 10 100 1000 Permeability to Air SS, millidarcys 1000 (j) >- (.) '- ro :2 E (J) (J) :J >- :!::: :ö ro (]) E '- (]) 0.. OJ '- (]) ..a c: (]) ..:.::: ,!; s::: 0.001 North Slope, Alaska File: A-87001 ¡ ~ lit i III I j ¡It i I t 1 1 I 100 Horizontal 800 psi _ . Horizontal 2600 psi Vertical 800 psi =, Vertical 2600 psi 10 ---~.~ 0.1 0.01 0.0001 0.0001 0.001 0.01 0.1 1 10 100 1000 Klinkenberg Permeability SS, millidarcys I Laboratories, Inc. PERMEABILITY AND POROSITY CROSSPLOTS Convection Dried at 180°F All Samples ConocoPhillips Spark NO.4 Well 1000 100 (J) >- (.) '- ro 32 E 10 ïi5 0.. o o (!) C'\! m '- <ë .8 £ ..Q ro (]) E '- (]) 0.. -_.._,--~- ~-~._~_.~, -~- 0.1 ~___ 0.01 ---- Horizontal . Vertical 0.001 0.0001 0.0001 0_001 0.01 1 10 0.1 Permeability to AÎr at 800 psi, millidarcys --.---- ----~ 100 1000 __ 20 c: (]) (.) '- (!) 0.. ïñ 0.. g 15 (!) C'\! ro >- -- 'ø o '- o a.. 10 30 25 5 o o 5 10 15 Porosity at 800 6-8-04 North Slope, Alaska File: A-87001 I Horizontal I Vertical 20 percent 25 30 SATURATIONS VERSUS POROSITY Convection Dried at 180°F Vertical Samples (]) 80 ~ (.) ro 0.. . 10 (/) . -"_.. (]) '- 0 (/) 0.. >. C . (.) '- (]) ro (.) 60 ~_. 32 '- (]) 0.. . E ëii . . ¿: ~._.- 0.. 0 .Q 0 . ro 0.1 <0 (]) ------- N E m 40 '- (]) c: Q.. 0 :¡::; ro . '- 0.01 :::¡ m (J) :::: 32 :::¡ . ü: 20 0.001 -----~ -~ 0.0001 0 0 5 10 15 20 25 30 0 5 10 15 20 25 30 Porosity, percent Porosity at 2600 percent I Laboratories, Inc. ConocoPhillips Spark NO.4 Well AND 1000 100 I i . 800 psi 2600 psi 100 6-8-04 North Slope, Alaska File: A-87001 SATURATIONS VERSUS POROSITY Convection Dried at 180°F Horizontal Samples I AND 1000 ConocoPhillips Spark NO.4 Well 100 I . 800 psi 10 2600 psi (jJ >. (.) '- ro :g 'Ë >. ~ :.0 ro 0.1 (]) ¡:: 1:: (]) 0... 0.01 0.001 0.0001 -- -'"._--~ o 5 10 15 20 Porosity, percent 25 30 6-8-04 North Slope, Alaska File: A-87001 100 . - Water ~ . Oil (]) 80 ---.- (.) ro 0.. . (jJ (]) .- '- . 0 0.. .- . c (]) (.) 60 ~-- '- (]) 0.. . ë¡¡ 0.. 0 0 {O N m 40 c: .Q .- m '- :::¡ m (J) :g :::¡ ¡:¡: 20 o o 5 10 15 20 Porosity at 2600 psi, percent 25 30 . . . (ÐMNI 6-8-04 :\¡'¡:,',!\,\:.'!lI '¡%:!';:;,i~,'"",,',:: laboratories, Inc. SUMMARY OF ROUTINE CORE ANALYSES RESULTS Convection Dried at 180°F Vertical Samples ConocoPhillips North Slope, Alaska Spark NO.4 Well File: A-87001 millidarcys Fluid Sample to Air Klinkenberg Porosity, Grain Saturations at NCS, Core Sample Depth, I 800 psi I 2600 psi 800 psi I 2600 psi Percent Density, percent Number Number feet SS I uss ss I uss ss I uss ss I USS Ambient I 800 psi 12600 psi gm/cc Water I Oil I Total 1 1-2VT 7712.10 0.058 0.088 0.026 0.044 0.030 0.047 0.012 0.021 15.3 15.3 14.9 2.71 66.2 19.7 85.9 1 1-3V 7713.00 0.040 0.023 0.026 0.011 0.019 0.009 0.011 0.0042 15.1 15.0 14.7 2.85 60.8 15.3 76.1 1 1-4VT 7714.20 0.097 0.125 0.045 0.080 0.056 0.069 0.023 0.041 18.8 18.7 18.3 2.78 54.2 17.1 71.3 1 1-7V 7717.30 0.480 0.524 0.159 0.318 0.346 0.362 0.099 0.202 22.0 21.9 21.6 2.72 54.5 12.6 67.1 1 1-8VT 7718.20 0.131 0.165 0.054 0.088 0.079 0.096 0.028 0.047 11.4 11.2 11.0 2.94 59.9 13.4 73.3 1 1-9V 7719.00 0.273 0.389 0.112 0.196 0.183 0.256 0.066 0.115 17.8 17.7 17.2 2.72 63.2 14.8 78.0 1 1-10VT 7720.00 1.57 1.95 1.24 1.64 1.26 1.54 0.990 1.28 17.5 17.4 16.9 2.68 47.7 17.3 65.0 1 1-11V 7721.60 0.030 0.012 0.016 0.0062 0.014 0.0048 0.0065 0.0021 8.8 8.7 8.5 2.86 38.8 24.3 63.1 1 1-12VT 7722.50 0.020 0.031 0.015 0.021 0.009 0.014 0.0059 0.0086 12.6 12.5 12.2 2.98 41.1 16.0 57.1 1 1-13V 7723.50 4.08 4.04 2.98 3.30 3.26 3.38 2.37 2.72 20.7 20.6 20.1 2.71 56.1 18.4 74.5 1 1-14VT 7724.00 51.2 55.3 47.1 52.0 44.2 52.5 40.5 49.3 25.2 25.2 24.7 2.70 38.7 19.8 58.5 1 1-15V 7725.00 142. 147. 133. 140. 128. 142. 119. 134. 23.7 23.6 23.2 2.69 38.5 25.7 64.2 1 1-21VT 7731.00 269. 270. 247. 264. 248. 263. 226. 257. 22.1 22.0 21.8 2.69 34.4 19.9 54.3 1 1-22V 7732.00 49.5 50.4 46.3 48.8 42.9 47.7 40.1 46.3 22.8 22.7 22.2 2.73 38.1 21.3 59.5 1 1-23VT 7733.20 32.9 34.5 29.1 32.5 28.1 32.4 24.8 30.5 22.6 22.5 22.3 2.72 38.6 20.8 59.4 1 1-24V 7734.30 37.3 40.4 32.1 38.2 32.0 38.0 27.4 35.9 21.5 21.4 20.9 2.68 42.5 20.0 62.4 1 1-25VT 7735.20 0.032 0.0019 0.0068 0.0009 0.015 0.0005 0.0022 0.0002 5.8 5.7 5.6 3.21 22.6 32.6 55.2 1 1-26V 7736.20 0.014 0.0091 0.0032 0.0041 0.0056 0.0031 0.0008 0.0012 10.5 10.5 10.2 2.69 46.5 36.3 82.8 1 1-27VT 7737.20 0.036 0.0066 0.0059 0.0024 0.017 0.0022 0.0018 0.0007 12.6 12.5 12.3 2.69 35.3 19.0 54.3 1 1-28V 7738.20 0.010 0.0051 0.0046 0.0023 0.0037 0.0018 0.0013 0.0007 10.5 10.4 10.0 2.69 47.5 34.3 81.8 1 1-29VT 7739.30 0.018 0.0074 0.0092 0.0033 0.0072 0.0025 0.0032 0.0009 11.0 10.9 10.8 2.69 41.6 21.3 62.8 1 1-30V 7740.20 0.049 0.072 0.030 0.045 0.025 0.037 0.014 0.022 14.2 14.1 13.6 2.69 33.4 27.0 60.4 1 1-31VT 7741.20 0.037 0.029 0.013 0.021 0.018 0.013 0.0049 0.0087 14.8 14.7 14.5 2.80 15.4 19.0 34.5 1 1-34V 7744.40 0.060 0.066 0.014 0.044 0.032 0.033 0.005 0.021 15.9 15.8 15.5 2.68 25.7 24.3 50.1 1 1-35VT 7745.20 0.022 0.037 0.017 0.021 0.0094 0.017 0.0067 0.0090 14.3 14.1 13.8 2.68 24.6 23.0 47.6 1 1-36V 7746.20 0.042 0.053 0.019 0.032 0.021 0.026 0.008 0.015 14.3 14.2 13.7 2.69 30.7 16.9 47.6 1 1-37VT 7747.20 0.028 0.040 0.018 0.018 0.013 0.027 0.0074 0.012 14.5 14.5 14.1 2.68 23.2 22.6 45.8 1 1-38V 7748.20 0.021 0.028 0.0060 0.013 0.0089 0.012 0.0019 0.0050 11.8 11.8 11.3 2.68 40.8 27.7 68.5 1 1-39VT 7749.20 0.013 0.016 0.0053 0.0094 0.0050 0.0065 0.0015 0.0033 12.2 12.2 12.0 2.67 28.5 26.8 55.3 1 1-40V 7750.20 0.043 0.032 0.027 0.017 0.021 0.014 0.012 0.0067 13.6 13.5 13.0 2.69 31.7 24.1 55.7 1 1-41VT 7751.20 0.011 0.015 0.0051 0.0038 0.0060 0.0015 11.8 11.6 11.4 2.68 33.4 25.6 59.0 1 1-42V 7752.20 0.011 0.016 0.0039 0.0041 0.0063 0.0011 11.4 11.4 11.0 2.69 39.1 31.6 70.8 1 1-43VT 7753.20 0.010 0.015 0.0056 0.0046 0.0038 0.0056 0.0017 0.0015 11.8 11.6 11.3 2.68 33.2 21.1 54.3 1 1-44V 7754.20 0.010 0.011 0.0020 0.0036 0.0036 0.0040 0.0004 0.0011 11.1 11.1 10.8 2.68 39.4 36.5 75.9 1 1-45VT 7755.20 0.011 0.0065 0.0045 0.0026 0.0042 0.0021 0.0012 0.0007 10.0 9.9 9.6 2.69 34.6 31.6 66.2 1 1-46V 7756.20 0.016 0.015 0.0070 0.0040 0.0066 0.0059 0.0022 0.0013 11.1 11.0 10.7 2.68 38.8 35.6 74.5 . . . ;:i~MNI 6-8-04 ,.". 'I' Laboratories, Inc. SUMMARY OF ROUTINE CORE ANALYSES RESULTS Convection Dried at 180°F Vertical Samples ConocoPhillips North Slope, Alaska Spark NO.4 Well File: A-87001 Permeability, millidarcys Fluid Sample to Air Klinkenberg Porosity, Grain Saturations at NCS, Core Sample DePth, 800 psi I 2600 psi 800 psi I 2600 psi Percent Density, percent Number Number feet SS I uss ss I uss ss I uss ss I USS Ambient I 800 psi 12600 psi gm/cc Water I Oil I Total 1 1-47VT 7757.20 0.015 0.017 0.010 0.0093 0.0058 0.0064 0.0034 0.0032 12.6 12.6 12.4 2.68 24.4 32.6 57.0 1 1-48V 7758.20 0.013 0.018 0.0047 0.0087 0.0049 0.0073 0.0013 0.0030 11.8 11.7 11.4 2.69 29.1 40.7 69.8 1 1-49VT 7759.20 0.036 0.0091 0.014 0.0032 0.017 0.0033 0.0052 0.0010 12.5 12.4 12.3 2.69 31.7 22.3 54.0 1 1-50V 7760.30 0.011 0.021 0.0055 0.0097 0.0040 0.0084 0.0016 0.0034 12.2 12.1 11.6 2.70 27.5 27.0 54.5 1 1-51VT 7761.20 0.014 0.016 0.0091 0.0027 0.0053 0.0060 0.0032 0.0008 11.6 11.5 11.3 2.69 31.9 24.0 55.9 1 1-52V 7762.20 0.0056 0.010 0.0042 0.0034 0.0017 0.0035 0.0011 0.0010 10.5 10.4 10.0 2.69 49.7 18.9 68.6 1 1-53VT 7763.20 0.030 0.0037 0.012 0.0013 0.014 0.0011 0.0042 0.0003 10.8 10.7 10.5 2.69 37.4 27.8 65.2 1 1-54V 7764.20 0.0087 0.0086 0.0054 0.0024 0.0030 0.0030 0.0016 0.0007 11.1 11.0 10.6 2.70 42.2 33.4 75.6 1 1-55VT 7765.20 0.025 0.0026 0.0077 0.0006 0.011 0.0008 0.0026 0.0001 9.8 9.7 9.5 2.70 48.1 0.0 48.1 1 1-56V 7766.20 0.035 0.010 0.021 0.0023 0.017 0.0036 0.0089 0.0007 13.3 13.2 12.8 2.69 39.6 24.8 64.4 1 1-57VT 7767.20 0.0053 0.0016 0.0042 0.0016 0.0004 0.0012 8.5 8.5 8.2 2.67 60.1 27.4 87.5 1 1-58V 7768.20 0.042 0.025 0.022 0.021 0.011 0.0096 9.7 9.6 9.3 2.68 65.3 26.1 91.3 1 1-59VT 7769.20 0.011 0.0034 0.0041 0.0012 0.0039 0.0011 0.0011 0.0003 10.0 9.9 9.8 2.68 46.5 27.2 73.7 1 1-60V 7770.20 0.023 0.0083 0.010 0.0028 9.5 9.4 8.9 2.70 72.4 27.7 100.0 1 1-61VT 7771.20 0.011 0.0032 0.0024 0.0008 0.0038 0.0009 0.0006 0.0002 9.6 9.5 9.3 2.69 50.1 25.0 75.1 1 1-62V 7772.50 0.028 0.0043 0.010 0.0015 0.013 0.0014 0.0036 0.0004 12.0 11.9 11.4 2.70 42.2 25.9 68.1 1 1-63VT 7773.50 0.025 0.0033 0.0087 0.011 0.0010 0.0030 9.7 9.7 9.4 2.69 48.3 28.2 76.5 1 1-64V 7774.20 0.030 0.0055 0.0093 0.0017 0.014 0.0018 0.0032 0.0004 11.9 11.9 11.5 2.70 40.7 29.6 70.3 1 1-65VT 7775.20 0.014 0.0026 0.0048 0.0010 0.0054 0.0008 0.0014 0.0002 11.0 10.9 10.7 2.69 48.8 21.1 70.0 1 1-66V 7776.20 0.026 0.0042 0.0059 0.0020 0.012 0.0014 0.0018 0.0005 11.0 11.0 10.6 2.70 51.3 25.9 77.1 1 1-67VT 7777 .20 0.011 0.0028 0.0043 0.0009 0.0039 0.0010 0.0012 0.0002 10.7 10.6 10.4 2.69 44.1 22.1 66.1 1 1-68V 7778.20 0.027 0.0014 0.010 0.0015 0.012 0.0010 0.0035 0.0004 11.5 11.4 11.0 2.69 54.0 19.8 73.7 1 1-69VT 7779.20 0.024 0.0024 0.011 0.011 0.0007 0.0040 10.5 10.5 10.3 2.69 50.4 20.4 70.8 1 1-70V 7780.20 0.028 0.014 0.0067 0.0015 0.013 0.0046 0.0021 0.0004 11.9 11.8 11.5 2.69 47.9 18.6 66.4 1 1-71VT 7781.20 0.023 0.0034 0.0072 0.0010 0.010 0.0011 0.0023 0.0003 10.7 10.7 10.4 2.68 42.7 24.4 67.0 1 1-72V 7782.20 0.021 0.011 0.0077 0.0027 0.009 0.0043 0.0025 0.0008 9.6 9.5 9.3 2.69 57.5 28.8 86.3 1 1-73VT 7783.20 0.0030 0.0023 0.0015 0.0008 0.0007 0.0003 10.7 10.6 10.4 2.68 45.0 21.5 66.5 1 1-74V 7784.20 0.026 0.0075 0.012 0.0025 11.4 11.3 10.9 2.69 41.2 29.4 70.6 1 1-75VT 7785.20 0.025 0.0035 0.010 0.0010 0.011 0.0011 0.0034 0.0003 10.9 10.9 10.7 2.68 40.8 26.5 67.2 1 1-76V 7786.20 0.030 0.0045 0.010 0.0017 0.014 0.0015 0.0034 0.0005 11.2 11.1 10.7 2.70 44.7 27.6 72.4 1 1-77VT 7787.20 0.042 0.0024 0.016 0.021 0.0007 0.0065 10.2 10.1 9.9 2.69 48.6 27.3 75.8 1 1-78V 7788.20 0.019 0.011 0.0061 0.0027 0.0079 0.0038 0.0019 0.0008 9.2 9.1 8.7 2.69 62.7 34.3 97.0 1 1-79VT 7789.20 0.036 0.0023 0.011 0.017 0.0007 0.0040 9.9 9.9 9.6 2.70 51.3 25.5 76.8 1 1-80V 7790.20 0.020 0.0038 0.0069 0.0010 0.0083 0.0012 0.0022 0.0002 10.5 10.4 9.8 2.70 50.5 30.7 81.2 1 1-81VT 7791.20 0.0042 0.0022 0.0024 0.0011 0.0006 0.0005 9.7 9.7 9.3 2.71 53.4 21.5 74.9 1 1-82V 7792.20 0.016 0.0032 0.0061 0.0007 0.0066 0.0009 0.0019 0.0001 10.2 10.1 9.8 2.74 51.9 26.1 78.0 . . . ",®MNI 6-8-04 :,i¡i:¡!,i:i': '",;::: '" Laboratories, Inc. SUMMARY OF ROUTINE CORE ANALYSES RESULTS Convection Dried at 180°F Vertical Samples ConocoPhillips North Slope, Alaska Spark NO.4 Well File: A-87001 Permeability, millidarcys Fluid Sample to Air Klinkenberg Porosity, Grain Saturations at NCS, Core Sample Depth, I 800 psi I 2600 psi 800 psi I 2600 psi Percent Density, percent Number Number feet SS I USS SS I USS SS 1 USS SS I USS Ambient I 800 psi 12600 psi gmlcc Water I Oil I Total 1-83VT 7793.20 0.0048 0.0018 0.0035 0.0006 0.0014 0.0005 0.0009 0.0001 10.7 10.6 10.4 2.69 48.7 17.9 66.6 1-84V 7794.20 0.030 0.0022 0.011 0.014 0.0006 0.0041 10.0 10.0 9.4 2.69 63.7 18.9 82.5 1-85VT 7795.20 0.0028 0.0012 0.0013 0.0004 0.0007 0.0003 0.0002 0.0001 8.5 8.4 8.2 2.69 77.8 11.1 88.9 1-86V 7796.20 0.0050 0.0036 0.0025 0.0006 0.0014 0.0011 0.0006 0.0001 8.6 8.5 8.2 2.69 77.3 18.2 95.5 1-87VT 7797.20 0.0041 0.0016 0.0020 0.0011 0.0004 0.0004 8.7 8.7 8.4 2.68 50.9 30.6 81.6 1-88V 7798.20 0.022 0.0057 0.011 0.0012 0.0094 0.0019 0.0039 0.0003 9.7 9.6 9.2 2.70 64.2 14.8 79.0 1-89VT 7799.20 0.0041 0.0011 0.0020 0.0011 0.0003 0.0004 8.6 8.5 8.3 2.71 52.3 29.0 81.2 1-90V 7800.20 0.012 0.0018 0.0062 0.0006 0.0046 0.0005 0.0019 0.0001 8.7 8.7 8.3 2.70 69.5 22.6 92.1 1-91 VT 7801.20 0.0019 0.0008 0.0010 0.0004 0.0002 0.0002 8.0 7.9 7.6 2.70 74.2 22.7 96.9 1-92V 7802.20 0.020 0.0021 0.0075 0.0086 0.0006 0.0025 8.9 8.8 8.5 2.73 75.7 14.2 90.0 1-93VT 7803.20 0.0044 0.0020 0.0012 0.0004 10.7 10.6 10.2 2.70 58.0 11.2 69.1 1-94V 7804.20 0.0032 0.0017 0.0009 0.0003 0.0008 0.0004 0.0001 7.7 7.6 7.4 2.67 86.2 23.6 109.8 7.02 7.48 6.43 8.81 6.30 7.18 5.73 8.58 12.3 12.3 12.0 2.71 46.6 23.7 70.2 . . . i@ ',:"i:i""ii¡ MNI :i¡i¡iii!¡::!:",,_J!: '" Laboratories, Inc. '!j;",~ SU7ARY OF ROUTINE CORE ANALYSES RESULTS . Convection Dried at 180°F '-, .L Horizontal Samples ConocoPhillips Spark No.4 Well Permeability, millidarcys I Sample to Air Klinkenberg Porosity, Grain Core Sample Depth, I 800 psi I 2600 psi 800 psi I 2600 psi Percent Density, Number Number feet SS I uss ss I USS ss I uss ss I USS Ambient I 800 psi I 2600 psi gm/cc 1 1-4 7714.10 0.177 0.212 0.080 0.124 0.112 0.122 0.045 0.065 17.5 17.5 17.1 2.77 1 1-7 7717.10 0.448 0.490 0.199 0.303 0.321 0.324 0.128 0.187 18.9 18.8 18.3 2.72 1 1-8 7718.10 + 18.7 3.22 1 1-9 7719.10 0.285 0.3569 0.101 0.181 0.192 0.2192 0.059 0.1017 14.8 14.7 14.5 2.75 1 1-10 7720.15 1.72 1.43 1.52 1.30 1.24 1.04 1.10 0.982 14.5 14.5 14.0 2.68 1 1-11 7721.10 0.264 0.244 0.222 0.208 0.176 0.146 0.145 0.127 11.0 11.0 10.6 2.92 1 1-12 7722.40 19.8 21.2 19.2 20.2 16.0 19.6 15.5 18.6 18.9 18.8 18.1 2.78 1 1-13 7723.55 61.0 61.3 58.3 59.3 52.8 58.2 50.3 56.3 23.4 23.3 22.9 2.69 1 1-14 7724.10 69.8 72.1 65.9 69.6 60.8 68.8 57.2 66.2 23.1 23.0 22.6 2.66 1 1-15 7725.10 72.3 78.2 70.1 77.1 63.1 74.5 61.1 73.5 23.9 23.9 23.2 2.72 1 1-17 7727.50 49.4 53.9 46.0 51.8 42.2 50.9 39.2 49.0 22.7 22.7 22.1 2.76 1 1-19 7729.55 51.7 55.4 48.1 54.0 44.4 52.5 41.1 51.3 22.3 22.3 21.7 2.69 1 1-20 7730.20 124. 124. 109. 120. 111. 120. 97.0 115. 21.7 21.6 21.4 2.65 1 1-21 7731.10 205. 216. 192. 212. 187. 209. 174. 205. 20.8 20.8 20.4 2.67 1 1-22 7732.10 43.9 41.6 33.7 40.1 37.4 39.2 28.3 37.7 22.0 21.9 21.5 2.74 1 1-23 7733.10 86.7 90.3 79.0 88.1 76.3 86.2 69.2 83.9 23.2 23.1 22.8 2.70 1 1-24 7734.35 72.4 70.4 62.7 66.9 63.2 67.0 54.3 63.3 21.8 21.7 21.6 2.67 1 1-25 7735.10 0.011 0.014 0.0051 0.0070 0.0038 0.0048 0.0015 0.0022 8.6 8.6 8.4 2.96 1 1-26 7736.1 0 0.026 0.024 0.012 0.012 0.011 0.0094 0.0046 0.0038 11.0 10.9 10.5 2.70 1 1-27 7737.10 0.024 0.035 0.021 0.021 0.011 0.015 0.0091 0.0076 12.3 12.2 11.9 2.69 1 1-28 7738.40 0.025 0.019 0.0086 0.0081 0.011 0.0072 0.0029 0.0025 9.5 9.4 9.0 2.69 It" -. 1 1-29 7739.10 0.020 0.033 0.0077 0.019 0.008 0.013 0.0025 0.0070 12.4 12.3 11.7 2.71 (i..·' ~.1. 1-30 7740.10 0.046 0.071 0.027 0.046 0.023 0.034 0.012 0.020 13.2 13.1 12.7 2.68 ~ :. ,1 '" 1-31 7741.10 0.074 0.101 0.047 0.072 0.041 0.052 0.024 0.035 13.3 13.2 12.7 2.72 V:¡ f 1[ '1-32 7742.25 0.382 0.461 0.304 0.405 0.266 0.305 0.206 0.268 15.8 15.7 15.5 2.67 :¡, '.t. "1-;34 7744.30 0.082 0.119 0.056 0.089 0.046 0.062 0.029 0.045 14.6 14.5 14.0 2.67 ~"1-35' .,7745.10 0.064 0.102 0.045 0.071 0.034 0.053 0.023 0.034 14.5 14.5 14.0 2.68 ~~~"OO54 0.078 0.035 0.056 0.028 0.037 0.017 0.025 13.4 13.3 13.2 2.67 1~ ~ ~ÀOW 0.056 0.018 0.035 0.014 0.026 0.0077 0.015 12.3 12.3 11.9 2.68 1-38 7 0.038 0.055 0.019 0.034 0.019 0.024 0.0078 0.014 12.7 12.7 12.5 2.68 1-39 7749. 0.029 0.046 0.013 0.027 0.013 0.020 0.0051 0.010 11.9 11.9 11.7 2.68 1-40 7750.10 0.042 0.055 0.024 0.033 0.021 0.024 0.011 0.013 13.5 13.4 12.9 2.68 1-41 7751.10 0.036 0.058 0.019 0.033 0.017 0.027 0.0077 0.013 13.5 13.4 13.1 2.68 1-42 7752.10 0.048 0.068 0.027 0.037 0.025 0.032 0.012 0.015 12.8 12.7 12.3 2.68 1-43 7753.10 0.027 0.034 0.0088 0.016 0.012 0.014 0.0030 0.0055 10.9 10.9 10.6 2.68 . . . "~ ':',ii!iiii!ll MNI :Ii!:!:!,:::!;::',,':':::,'. laboratories, Inc. SUMMARY OF ROUTINE CORE ANALYSES RESULTS Convection Dried at 180°F Horizontal Samples ConocoPhillips Spark No.4 Well Permeability, millidarcys I Sample to Air Klinkenberg Porosity, Grain Core Sample Depth, I 800 psi I 2600 psi 800 psi I 2600 psi Percent Density, Number Number feet SS I USS SS I USS SS I USS SS I USS Ambient I 800 psi I 2600 psi gm/cc 1 1-44 7754.10 0.019 0.029 0.010 0.015 0.0078 0.012 0.0036 0.0051 12.4 12.4 12.1 2.69 1 1-45 7755.10 0.015 0.020 0.0064 0.012 0.0057 0.0069 0.0020 0.0036 11.4 11.3 11.0 2.68 1 1-46 7756.05 0.017 0.039 0.0078 0.021 0.0070 0.016 0.0026 0.0080 12.0 12.0 11.8 2.69 1 1-47 7757.15 0.020 0.033 0.012 0.019 0.0085 0.013 0.0043 0.0068 12.0 12.0 11.8 2.68 1 1-48 7758.10 0.025 0.045 0.0061 0.028 0.0110 0.020 0.0019 0.011 12.8 12.7 12.6 2.70 1 1-49 7759.10 0.039 0.044 0.016 0.021 0.019 0.019 0.0065 0.0081 12.0 11.9 11.5 2.68 1 1-50 7760.20 0.037 0.024 0.027 0.013 0.018 0.0090 0.012 0.0045 11.8 11.7 11.4 2.69 1 1-51 7761.10 0.014 0.029 0.0051 0.018 0.0055 0.012 0.0015 0.0064 11.0 11.0 10.4 2.66 1 1-52 7762.10 0.014 0.020 0.0048 0.0066 0.0054 0.0074 0.0014 0.0020 10.4 10.3 10.1 2.69 1 1-53 7763.10 0.024 0.026 0.0092 0.012 0.010 0.010 0.0032 0.0038 10.7 10.7 10.4 2.69 1 1-54 7764.10 0.031 0.022 0.020 0.0098 0.015 0.0082 0.0083 0.0031 10.8 10.7 10.5 2.69 1 1-55 7765.10 0.021 0.018 0.0083 0.0028 0.0091 0.0064 0.0028 0.0007 10.1 10.1 9.8 2.69 1 1-56 7766.10 0.012 0.018 0.010 0.0074 0.0046 0.0067 0.0034 0.0022 10.2 10.2 9.7 2.69 1 1-57 7767.10 0.014 0.020 0.0031 0.0052 0.0073 0.0008 9.9 9.8 9.7 2.71 1 1-58 7768.10 0.168 0.172 0.077 0.0089 0.105 0.075 0.043 0.0028 9.6 9.5 9.0 2.69 1 1-59 7769.10 0.0076 0.015 0.0043 0.0032 0.0025 0.0052 0.0012 0.0008 10.2 10.1 9.8 2.68 1 1-60 7770.10 0.023 0.017 0.015 0.0076 0.010 0.0064 0.0058 0.0022 10.4 10.3 10.0 2.69 1 1-61 7771.10 0.011 0.015 0.0040 0.0066 0.0040 0.0055 0.0010 0.0019 10.3 10.2 9.8 2.70 1 1-62 7772.15 0.023 0.019 0.012 0.0074 0.010 0.0072 0.0045 0.0022 10.3 10.2 9.9 2.70 1 1-63 7773.45 0.014 0.015 0.0073 0.0052 0.0053 0.0055 0.0024 0.0014 9.8 9.7 9.5 2.68 1 1-64 7774.10 0.010 0.019 0.0071 0.0082 0.0036 0.0072 0.0023 0.0025 9.6 9.6 9.2 2.69 1 1-65 7775.10 0.038 0.016 0.020 0.0054 0.019 0.0057 0.0087 0.0015 9.2 9.2 8.7 2.70 1 1-66 7776.10 0.027 0.021 0.0076 0.0053 0.012 0.0079 0.0025 0.0015 9.5 9.5 9.3 2.70 1 1-67 7777.10 0.012 0.014 0.0046 0.0051 0.0045 0.0049 0.0013 0.0014 9.1 9.0 8.6 2.69 1 1-68 7778.10 0.016 0.018 0.0044 0.0063 0.0063 0.0067 0.0012 0.0018 10.0 9.9 9.4 2.70 1 1-69 7779.10 0.016 0.020 0.0060 0.0083 0.0066 0.0078 0.0018 0.0025 9.9 9.9 9.3 2.69 1 1-70 7780.10 0.012 0.017 0.0046 0.0067 0.0044 0.0065 0.0013 0.0019 9.5 9.5 9.1 2.69 1 1-71 7781.10 0.020 0.022 0.0080 0.0082 0.0084 0.0086 0.0027 0.0025 9.2 9.2 8.8 2.68 1 1-72 7782.10 0.021 0.022 0.0077 0.0088 0.0088 0.0084 0.0025 0.0027 9.8 9.8 9.5 2.68 1 1-73 7783.10 0.021 0.015 0.014 0.0025 0.0089 0.0052 0.0055 0.0006 9.5 9.5 9.1 2.69 1 1-74 7784.10 0.024 0.019 0.014 0.0055 0.011 0.0072 0.0054 0.0015 9.9 9.8 9.3 2.68 1 1-75 7785.10 0.022 0.018 0.014 0.0058 0.0093 0.0068 0.0052 0.0016 9.1 9.0 8.8 2.66 1 1-76 7786.10 0.011 0.013 0.0048 0.0035 0.0040 0.0046 0.0014 0.0009 9.6 9.6 9.2 2.69 1 1-77 7787.10 0.041 0.019 0.012 0.0050 0.020 0.0069 0.0043 0.0014 9.5 9.5 9.2 2.69 1 1-78 7788.10 0.017 0.014 0.0098 0.0067 0.0050 0.0035 9.5 9.4 8.9 2.69 . . . "@ ",i!'!!!! MNI ',!,II¡:;:,':\: ' Labo..'o,'''. Inc. SUMMARY OF ROUTINE CORE ANALYSES RESULTS Convection Dried at 180°F Horizontal Samples ConocoPhillips Spark NO.4 Well Permeability, millidarcys I Sample to Air Klinkenberg Porosity, Grain Core Sample Depth, I 800 psi I 2600 psi 800 psi I 2600 psi Percent Density, Number Number feet SS I USS SS I USS SS I USS SS I USS Ambient I 800 psi I 2600 psi gm/cc 1 1-79 7789.35 0.016 0.011 0.0060 0.0014 0.0064 0.0036 0.0018 0.0003 9.4 9.4 9.1 2.76 1 1-80 7790.10 0.014 0.012 0.0043 0.0013 0.0053 0.0039 0.0012 0.0003 8.5 8.4 8.1 2.69 1 1-81 7791.10 0.056 0.022 0.019 0.0043 0.029 0.0082 0.0080 0.0012 8.3 8.3 8.0 2.69 1 1-82 7792.10 0.029 0.014 0.0092 0.0025 0.013 0.0051 0.0032 0.0006 8.5 8.4 8.1 2.70 1 1-83 7793.10 0.028 0.016 0.011 0.0020 0.013 0.0056 0.0039 0.0005 7.0 6.9 6.7 2.71 1 1-84 7794.10 0.056 0.036 0.021 0.010 0.029 0.015 0.0092 0.0033 8.3 8.3 8.1 2.81 1 1-85 7795.10 0.240 0.115 0.158 0.068 8.3 8.3 8.1 2.69 1 1-86 7796.10 0.106 0.044 0.032 0.014 0.062 0.020 0.015 0.0046 8.1 8.0 7.9 2.68 1 1-87 7797.10 0.181 0.087 0.083 0.021 0.115 0.044 0.047 0.0079 8.8 8.8 8.6 2.69 1 1-88 7798.10 0.024 0.0082 0.011 0.0010 0.011 0.0025 0.0041 0.0002 8.4 8.4 8.0 2.69 1 1-89 7799.10 0.024 0.019 0.0077 0.011 0.0069 0.0026 8.2 8.2 8.0 2.72 1 1-90 7800.10 0.034 0.029 0.011 0.0034 0.016 0.0116 0.0040 0.0009 8.0 7.9 7.8 2.70 1 1-91 7801.20 0.026 0.010 0.0096 0.0009 0.011 0.0032 0.0034 0.0002 7.4 7.3 7.0 2.69 1 1-92 7802.10 0.044 0.014 0.017 0.0020 0.022 0.0051 0.0071 0.0004 8.0 7.9 7.5 2.71 1 1-93 7803.10 0.021 0.014 0.0081 0.0018 0.0090 0.0048 0.0027 0.0004 7.9 7.8 7.3 2.73 1 1-94 7804.10 0.023 0.0080 0.011 0.010 0.0025 0.0042 8.0 8.0 7.5 2.68 10.14 10.59 9.27 10.78 8.91 10.11 8.11 10.27 12.3 12.2 11.8 2.71 ConocÓPhillips Spark 4 Omni Core Labs UV and White Light Core Photos 7711-7804' md 4/08/2005 Confidential Data ~u-f-(;Og CONFIDENTiAL s o . . . Approved by: /f()~t ¿ rnv./ tf- zOZ/-oð/ óPh~/ _II- Conce .!.¡ ... ·.1 IPS FINAL WELL REPORT SPARK # 4 CONOCOPHILLlPS ALASKA INC. ï 1 I ",'.'" L' ¡' Íi j i~ !..:..lÎ Compiled by: Andrew Buchanan Mindaugas Kuzminskas Date: 04/10/1200 · · · .~<.. ConocoPhillips SPARK #4 TABLE OF CONTENTS 1 EQUIP M ENT AN D CREW .................... ........ ......... ............................. .......................................... ............... 2 1.1 Equ ipment Summa ry ......................... ......... ...................................................... ............ ............. ..... 2 1.2 Crew............. .......................................... ............................................. .......... ................................ .... 2 G EN ERAL WELL DETAILS ............. .............. .................. .................................................. ........ .......... ....... 3 2.1 Objectives ............... ................................ ............. ............... ................. ............ ....... ........ ................. 3 2.2 Well Summa ry . .......... ......... ....... ....... ....................................... ......... .......... ........................... ..... ...... 3 GEOLOGICAL DATA ................................. .... .................................................... ........ .................................. 4 3.1 Lithostratig rap hy ........................................... .............................................................. ....... ............ 4 3.2 Offset Wells Referenced ..... ...................... ...... .................................. ................. .......... .................. 4 3.3 Mud log Summa ry ....... ...... ....... ........ ............................ ............... .............. ....................................... 5 3.4 Gas Samples........... ...................................... ........................... ...... ........... ....................................... 9 3.5 Gas Pea ks ....... .................................... ...... .......... ............................................. ....... .................. ..... 1 0 3.6 Connection Gas................................................... ..... ........................... ...... ........... .......... ............... 1 0 3.7 Sampling Program J Sample Dispatch........................................................................................11 PRESSURE J FORMATION STRENGTH .................................................................................................12 4.1 Formation Integrity J Leak Off Tests ..........................................................................................12 4.2 Pore Pressure Evaluation Introduction .....................................................................................12 4.3 Pore Pressure Summary .............................................................................................................. 13 DRILLING DATA ..... ......................... ................ ............ ....................................... ........... ............................ 14 5.1 5.2 5.3 2 3 4 5 S~ rvey Data .......... ..... ............ .................................. ..........-F~;~ii¡;·i:1\.:·!~:~:~;~; ·y;;l·~::;;;;~V;:~.::~;~~~·;~;~m14 Bit Record . .................. .............. ........................................ t ·"'...~·j\"í·.¡¡..·t·~·..·~· ......,....i!..,¡;.,!"... 1...· F , .... . -p ~,w'.L '! Ji. l..ikkJ ! Mud Record ...................................................... .................................................... ..........................~ 7 Enclosures 2"/100' Formation Log 2"/100' Scale Drilling Dynamics Log 2"/100' Scale LWD / Lithology Log 2"/100' Gas Ratio Log [:I EPOCH 1 ,,~,p., >",~.., ...,.ø...f.<.. ~. \Ö " 1 EQUIPMENT AND CREW 1.1 Equipment Summary Parameter Ditch gas Rate of penetration (ROP) Pump stroke counter (SPM) Hook Load (HL) I Weight on bit (WOB) Drillstring torque (TRQ) Top drive rotary (RPM) Pump Pressure (PP) Mud flow in (MFI) Mud flow out (MFa) MUdlogging unit computer system 1.2 Crew Unit Number :ML015 Mudloggers Andrew Buchanan Mindaugas Kuzminskas Years" 8 1 eonocò'Phillips SPARK #4 Equipment Type I Position QGM Degasser (upstream flowline position) Flame ionisation total & chromatograph detector Primary draworks block position indicator Magnetic proximity sensor Hydraulic pressure cell Witts feed from Totco Witts feed from T otco Witts feed from T otco Calculated from stroke counters Witts feed from Totco Compaq 486/340 Mb PC Days "l 19 19 Sample Catchers Jon Mowery Kevin Hardy Days 17 16 "1 Years experience Mudlogger *2 Days at wellsite between spud and total depth of well Additional Comments . [=I EPOCH . Total Downtime Technician Pete Ramsey Comments Occasional degasser intake plugging from large clay cuttings. Days 3 2 . "../ ConocoPhiUips SPARK #4 · 2 GENERAL WELL DETAILS 2.1 Obiectives The Spark # 4 well was planned as an exploration test of the Upper Jurassic Alpine equivalent Sandstone 2.2 Well Summary Company: ConocoPhillips Alaska Pñmary Target: Alpine Equivalent Sands Well: Spark # 4 Spud Date: 03/26/04 Field: Exploration TD Depth: 8005' Region: NPRA TD Date: 04/101104 County, State: North Slope Borough, Alaska Completion Plugged and Abandoned Status: Classification Exploration Dñlling Days: 16 Location: Sec 23, T 11 N, R 1 E, UM Days Testing: 4 Coordinates: 682' FSL, 568' FEL UM Company Don Lutrick, Zane Kuenzler Representative: Elevation: Ground:61.8' AMSL Wellsite Dick Owens, Dave Boyer · RKB 101' AMSL Geologist: API Index: 50-103-20480-00 MWD Company: Sperry-Sun AFE No. WCD.E02.x051 Mud Company: MI Drilling Fluids RiglType: Doyon 191 Arctic Triple Maximum Mud Shoe Depth Hole Depth TD Weigh Deviatio Casingl FIT Section MDR TVDS Fonnation t n Coring Liner MDRT TVDS (ppg) T (ft) S (ft) (ppg) (oinc) (ft) S (ft) 20" 117' -16' 16" 117' -16' 12 %" 2673' -2572' Colville Group 10.0 0.25 9 5/8" 2663' -2562' 14.5 8%" 7710' -7602' Alpine Equiv 9.8- 1.7 7" 7702' -7594' Sands 11.3 6 1/8" 8005' 7807' Kingak Shale 9.8 3.7 7711'- 7805' · n EPOCH 3 ..... ConocoPhillips SPARK #4 3 GEOLOGICAL DATA 3.1 Lithostratigraphv Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geolo9ist. PROGNOSED DRILLING PICK MDRT(ft) TVDSS(ft) MDRT(ft) TVDSS(ft) 887' -800' 813' -712' 2822' -2735' 2880' -2779' 3397' -3310' 3430' -3329' 3737' -3650' 3825' -3724' 4102' -4015' 4007' -3906' 5827' -5740' 5750' -5649' 6187' -6100' FORMATION Base Permafrost (K-3) Seq 97 Seq 95 Seq 93 Seq 92 Base Bonded Turbidites HIGH/LOW (ft) 88'H 44'L 19' L 74'L 109'H 91' H Pebble Shale Disturbed Zone Not Present Top HRZ 7237' -7150' 7298' 7190' 40'L Base HRZlMiluveach (LCU) 7322' -7235' 7310' 7202' 33'L UJU/Alpine Equivalent Sands 7662' -7575' 7689' 7581' 6'L Base J4 Silt 7857' -7770' 7860' 7753' 17' H Total Depth (-250' MD Below J4) 8107' -8020' 8005' 7896 3.2 Offset Wells Referenced The offset wells listed below were selected due to their proximity to the Spark 4 drill location Fish Creek Test 1 Mooses Tooth C Mitre 1 Rendezvous 2 2.5 miles NW of Spark 4 Lookout 1 & 2 3 miles SW of Spark 4 Spark 1 & 1A 10 miles ESE of Spark 4 Rendezvous A 8.5 miles S of Spark 4 Hunter A 7 miles E of Spark 4 4.5 miles SE of Spark 4 5.5 miles S of Spark 4 16 miles SW of Spark 4 . ~ EPOCH . 4 . . . . ..... ConocoPhillips SPARK #4 3.3 Mudloq Summary The following text provides a brief summary of the defining lithological and drilling characteristics for that part of the well over which drill cuttings were collected. For more detail the reader is referred to the Lithology and Remarks section. TERT~RY-CREATACEOUS Colville Group First Returns 118' to 2880' MDRT (118' to -2779' TVOSS) The upper section (118' to 810' MORT, -17' to -709' TVOSS) consists of interbedded lower very fine to upper medium with occasional coarser unconsolidated Sand; very light greenish gray very soluble Claystone, and very light gray quartzose Siltstone. Abundant Tuff/Ash-Tuffaceous Claystone laminations and layers of Carbonaceous Material are notably present in the upper part of the section. Maximum 245 Drill Rate (ftIhr) I Min~~um I Average 2 Total Gas (Units' I Mini~um Average 119 Maximum 5 The lower section (810' MORT, -709' TVDSS to 2663' MORT, -2562' TVOSS) is comprised predominantly of light brownish gray to light greenish gray very soluble Claystone with abundant siltstone and sandstone beds. Occasional thick Sandstone and Siltstone accumulations show elevated gas readings. Throughout the section are common to abundant Tuff/Ash- Tuffaceous Claystone laminations locally reaching 20% of samples. Higher concentrations of Carbonaceous Material are present in the middle and lower part of the section. The base of the Permafrost was picked at 813' MORT (-712 TVOSS). Some minor gas zones were observed below 980' MROT (-893' TVOSS). The largest gas accumulations, between 2150' MROT (-2063' TVDSS) and 2663' (-2576' TVOSS) showed a maximum of 162 units of gas with chromatographic readings showing 33013 ppm Methane, 418 ppm Ethane, 110 ppm Propane and 3 ppm Butane. Maximum 222 Drill Rate (ftIhr) I Mini;num I Average 68 Total Gas (Units' I Mini~um Average 132 Maximum 162 Nanushuk Group 2880' - 3430' MORT (-2779'- 3329' TVOSS) The section is comprised predominantly of very light to light gray firm Claystone and Siltstone with hydrocarbon bearing very light gray very fine, well sorted, commonly grading to Siltstone Sand beds in the middle of the section. The significant gas accumulations observed throughout the whole lower part of the zone, starting from 2905' MRDT (-2804' TVOSS) and 3230' (-3129' TVOSS) and showed a maximum of 850 units of gas, with following chromatography: 124748 ppm Methane, 10623 ppm Ethane, 4049 ppm Propane, 2354 ppm Butane and 817 ppm Pentane. Throughout the section starting 2945' MROT (-2844' TVOSS) and ending 3025' MROT (-2924) was observed trace amounts of free oil. Maximum 185 Drill Rate (ftIhr) I Min~~um I Average 136 Total Gas (Units' I Mini~um Average 133 Maximum 850 n EPOCH 5 · · · ''',../ ConocoPhiUips SPARK #4 Torok Group 3430' to 7298' MORT (-3329' to -7190' TVOSS) Light brownish gray soluble Claystone with up to 50% light gray Siltstone that grades to very fine Sandstone in part. Included in this section are grading upward packages with very fine lower to occasional lower medium moderately consolidated, grain and matrix supported Sandstone with very poor, predominantly clay ¡nfilled porosity. White to very light gray Tuffaceous Claystone laminations are generally rare to localized abundant. Three significant gas accumulations were observed throughout this section of the well. The first one was observed in the sequence ofthin sands at 3740' - 3780'MORT (-3639'- 3679' TVOSS) and 3830' 3860' MORT (-3729' - 3759' TVDSS). The Sandstones in this interval consists of a very light to whitish gray, very fine lower to fine upper predominantly quartz sandstone. Both Sandstones are moderately consolidated and have very poor to occasional fair intergranular porosity and are partly infllled with clay matrix. In the first interval gas peeks at 427 units with a chromatographic break down of 61 ,311 ppm Methane, 1391 ppm Ethane, 691 ppm Propane, 1107 ppm Butane and 836 ppm Pentane. Second interval shows lesser gas and peaks at 170 units with a chromatographic breakdown of 20,631 ppm Methane, 478 ppm Ethane, 198 ppm Propane, 330 ppm Butane and 312 ppm Pentane. Sands in this interval shows medium to strong fluorescence and have intense yellowish white cut. The next significant accumulation occurs from 5040' (-4939' TVOSS) to 5120' (5019' TVOSS). This thin Sandstone interval consists of lower to upper very fine predominantly quartz sand. The maximum gas reading was 255 units with following Chromatography: 33,714 ppm Methane, 2197 ppm Ethane, 1732 ppm Propane, 838 ppm Butane, 275 ppm pentane. Analysis of the Sandstone in this interval indicates trace of light brown shows with very poor to trace fair commonly clay infilled intergranular porosity with light yellow fluorescence and a very slow, very weak, pale greenish-yellow fluorescent cut. The third gas accumulation in this interval occurs from 5760' (-5659'TVDSS) to 5820' MORT (-5719' TVOSS). The Sandstone of this interval consists of a very light gray to whitish gray with occasional salt and pepper appearance, lower to upper with occasional fine, predominantly quartz and lithic sand. The maximum gas was 422 units with the chromatographic breakdown: 67823 ppm Methane, 5083 ppm Ethane, 2725 ppm Propane, 948 ppm Butane, 237 Pentane. Inspection of the sandstone shows very poor to trace fair predominantly matrix infllled intergranular porosity with occasional very rare trace of light brown oil staining shows, dull yellow-orange to pale yellow fluorescence with a very weak, very slow, pale, milky yellow fluorescence cut. Maximum 144 Drill Rate (ftIhr) I Min:um I Average 273 Total Gas (Units' I Minimum ., 61 Average 117 Maximum 422 Hiahlv Radioactive Zone (HRZ) 7298' to 7310' MORT (-7190' to -7202' TVOSS) In this thin zone is present and dominates dark brown to brownish black Carbonaceous Shale with the content of carbonaceous material up to 30% and contains abundant disseminated pyrite and occasional glauconite in the lower part of the zone. Throughout this entity minor visible gas bleeding was observed. No significant sand accumulations were observed in this unit. Maximum 60 Drill Rate (ftIhr) Mini;,um I Average 39 Total Gas (Units' I Minimum 25 Average 47 Maximum 46 ~ EPOCH 6 . . . .,...... ConocoPhillips SPARK #4 Miluveach ( LeU) 7310' to 7689' MDRT (-7202' to -7581' TVDSS) Interval consists of a medium to dark brown, firm to hard Shale with occasional disseminated and rare granular pyrite. Carbonaceous material has tendency to decrease with the depth in this zone. Drill Rate (ftIhrr Maximum Minimum 90 9 Total Gas (Units) Maximum I Minimum 156 18 I Average 50 I Average 57 Alpine Equivalent Sandstone/J4 Silt 7689' to 7860' MDRT (-7581' to -7753' TVDSS) The Alpine Equivalent Sand was cored and this summary is based on drill cuttings obtained during the coring. Immediately below the unconformity and overlying the reservoir sands is clayey sandy shale. This shale has common lower very fine to lower fine glauconite rich sand and grades to silty sand in part. The reservoir sands can be broken into two units. The upper sandstone unit (7689' - 7765' MDRT; -7581' - -7657' TVDSS) consists of lower very fine to lower fine, very angular, moderately sorted sand composed of predominantly quartz with trace to glauconite. Recovered samples revealed that sandstone in this part of the zone is grain and matrix supported with common clay matrix infilled porosity. The sandstone has occasional faint residual oil staining showing very faint, dull orange fluorescence associated with very slow, weak milky whitish-green fluorescence cut. The ditch gas over this interval maxed at 1732 units at 7730'and the chromatographic distribution of the peak gas of: 225409 ppm Methane; 33396 ppm Ethane; 15940 ppm Propane; 6349 ppm Butane and 2196 ppm Pentane. The Lower Sandstone unit (7765' - 7860' MDRT; -7657' - 7753' TVDSS) observed to be much more silty and consists of a lower very fine to upper very fine, angular to subrounded, moderately to well sorted quartz sand with common glauconite (decreasing with depth) and pyrite Oncreasing with depth). Majority of consolidated samples are claylsilt matrix supported. The sandstone of this unit shows common very faint whitish-yellow fluorescence associated with slow, weak, milky whitish-green fluorescence cut. The ditch gas for this interval was decreasing with depth from 1000 units at the upper part to below 100 in the lower part. Maximum 342 Drill Rate (ftIhr) I Mini;,um I Average 540 Total Gas (%) I Mini~um I Average 41 Maximum 1732 Lower part of this interval interval consists of predominantly siltstone with common sandstone and partially ashy claystone interbedding. Some consolidated sandstone grains recovered from thin sandstone beds disclose high content of clay matrix and ditch gases peaked at 117 units with chromatographic distribution of the gas peak follows: 14980 ppm Methane; 2276 ppm Ethane; 1041 ppm Propane; 409 ppm Butane, and 166 ppm Pentane ~ EPOCH 7 . . . ../ ConocoPhillips SPARK #4 Kinqak Shale 7860' to 8005' MDRT (-7753' to -7896' rvDSS) This formation consists predominantly of a medium to dark brown hard blocky shale. The shale contains common to abundant disseminated and fracture filling pyrite and common carbonaceous material. It is commonly interbedded with siltstone and claystone and grades to siltstone in part. There were no significant gas or sandstone accumulations through out this interval. Maximum 122 Drill Rate (ftIhr) I Mini:;,um [ Average 39 Total Gas (%) I Min~~um I Maximum 117 [:I EPOCH Average 59 8 ........ ConocoPhiUips SPARK #4 . 3.4 Gas Samples No. Depth Background Units C1 C2 C3 C4 C5 1 535 3 3 75 0 0 0 0 2 750 3 3 618 0 0 0 0 3 1000 12 17 4176 0 0 0 0 4 1250 48 53 10424 0 0 0 0 5 1500' 50 94 17819 TR 0 0 0 6 1761' 60 67 12788 TR 0 0 0 7 2000' 40 52 9658 TR 0 0 0 8 2250' 80 106 19812 162 59 41 0 9 2500' 85 105 19384 213 66 TR 0 10 2750' 30 31 5491 33 0 0 0 11 2917' 35 450 72307 5547 923 199 TR 12 2966' 120 650 93575 7857 3180 2162 871 13 3300' 95 118 20672 399 74 85 64 14 3500' 96 110 20706 159 16 20 0 15 3750' 75 298 41838 1025 526 300 553 16 4000' 78 84 13004 305 128 40 75 17 4250' 55 59 9269 372 135 41 0 18 4550' 50 51 7765 383 146 29 0 19 4750' 50 73 10866 630 350 152 15 20 5000' 70 77 10966 704 481 200 38 21 5250' 90 124 15679 1287 1038 161 395 22 5500' 60 64 7553 579 446 73 198 23 5750' 65 69 10794 865 425 162 33 . 24 5781' 100 411 65254 4901 2635 915 222 25 6000' 65 69 8185 792 495 288 156 26 6250' 45 51 8045 554 220 39 65 27 6500' 50 52 8292 460 138 27 30 28 6750' 20 22 2940 167 67 13 15 29 7000' 35 39 6486 364 130 49 0 30 7250' 25 29 7410 331 143 24 34 31 7500' 65 70 11339 1228 607 129 159 32 7629 50 90 13854 1689 715 123 178 33 7720 20 373 17391 2205 997 392 117 34 7730 1700 1732 225409 33396 15940 6349 2196 35 7740 1620 1640 228163 37797 18785 7243 2474 36 7753 1400 1430 194491 30269 15262 2043 3766 37 7760 1330 1330 181573 26697 12842 1699 3194 38 7771 570 560 65394 9635 4806 655 1258 39 7780 390 370 43392 6829 3266 428 854 40 7790 220 218 24311 4093 2008 264 548 41 7800 130 124 14181 2353 1140 152 326 42 7822 85 306 27987 4835 2383 841 256 43 8000 35 37 3625 538 419 66 151 . ~ EPOCH 9 ... .' ConocoPhiUips SPARK #4 . 3.5 Gas Peaks Depth Background Units C1 C2 C3 C4 C5 2917 60 466 72307 5547 923 198 0 2964 60 665 91138 7453 2977 2026 813 2995 60 850 124747 10623 4049 2354 817 3024 60 599 94772 8056 2504 996 254 3756 55 427 61311 1391 691 1107 836 5072 90 254 33714 2197 1732 838 275 5226 90 166 21718 1710 1460 212 506 5779 65 422 67823 5083 2725 948 237 7629 50 90 13854 1689 715 123 178 7730 34 1732 225409 33396 15940 6349 2196 7823 85 304 36420 6433 3203 379 751 3.6 Connection Gas None observed in this well. . . ~ EPOCH 10 eonocò'Phillips SPARK #4 3.7 Samplinq Proqram I Sample Dispatch Set Type I Purpose Interval Frequency Dispatched to ConocoPhillips Inc. A Unwashed 120' - 7000' 30' Bayview Warehouse Biostratigraphy 7000' - T.D. 10' 619 East Ship Creek Ave. Anchorage, AK 99510 B Unwashed 120' - 7000' 30' Anadarko Petroleum Co. Biostratigraphy 7000' - T.D. 10' ConocoPhillips Inc. C Washed, screened & dried 120' - 7000' 30' Bayview Warehouse Reference Samples 7000' - T.D. 10' 619 East Ship Creek Ave. Anchorage, AK 99510 ConocoPhillips Inc. D Washed, screened & dried 120' - 7000' 30' Bayview Warehouse Reference Samples 7000' - T.D. 10' 619 East Ship Creek Ave. Anchorage, AK 99510 Washed, screened & dried 120' - 7000' 30' Anadarko Petroleum Company E Reference Samples 7000'- T.D. 10' 1201 Lake Robbins Dr. The Woodlands Tx 77380 F Washed, screened & dried 120' - 7000' 30' AOGCC Reference Samples 7000' - T.D. 10' G Washed, screened & dried 120' - 7000' 30' Bureau of Land Management Reference Samples 7000'- T.D. 10' H Gas Sample Bags 250' - T. D. 250'and Isotech Laboratories significant peaks Tom Lorenson Unwashed Geochemistry 180' - 3000' 60' U. S. Geological Survey Samples 345 Middlefield Road, MS-999 Menlo Park, CA 94025 J Washed Reference Samples 120' - 7000' 30' For on site geological examination Samplex Samples 7000' - T.D. ConocoPhillips Inc. K Core interval mud samples 7795' - 7885' 15' Bayview Warehouse 619 East Ship Creek Ave. Anchorage, AK 99510 Sample frequency was locally altered according to drillrate constraints. . U EPOCH . 11 . C~illips SPARK #4 · 4 PRESSURE I FORMATION STRENGTH 4.1 Formation Inteqritv I Leak Off Tests MDRT(ft) TVDSS(ft) LOT /FIT(ppg FORMATION EMW) 2695' -2620.7' 14.5 Lower CoMlle Group 4.2 Pore Pressure Evaluation Introduction The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of this well; Background Gas (BG) Mud Weight (MW) Pressure Tests (RFn Connection Gas (CG) Hole Conditions (HC) Trip Gas (TG) Resistivity (RES) Quantitative Methods During the well quantitative estimation was limited to the following parameters; Corrected D exponent (DXC) Pressure Tests (MDn Sonic (SON) CMR VSP · Pressure tests provide the most definitive data. However, it is considered that estimates derived using Eaton Method calculations on corrected D exponent and Sonic data are also representative at certain levels. However, factors such as controlled drill rates, hole inclination, and absence of clean shale baselines to establish compaction trends preclude reliable estimation. Results Summary Final wellsite derived pore pressure evaluation is summarized in table form (Section 4.4) and graphical format (Figure *). Certain abbreviations have been used, all of which are outlined either above or below. HYD = Hydrostatic pressure SST = Sandstone EXTRAP = Extrapolated SHL = Shale CLST = Claystone SL TST = Siltstone · n EPOCH 12 ......./ ConocoPhillips SPARK #4 · 4.3 Pore Pressure Summary Equivalent mud weight (EMW) is calculated from rotary table (RT). Formation Interval Primary Lithology Interval Tops MDRT TVDSS (ft) (ft) Pore Pressure (EMW) Min Max Trend (ppg) (ppg) Trend Indicators Source of Quantitative Estimate Base Permafrost CLST 813' -712' 8.4 8.4 BG HYD Nanushuk Topset CLST/SST 2915' -28149' 8.2 8.5 +ve BG MDT Sands Seq.97 SST/SL TST 3430' -3329' 8.4 8.5 BG MW Seq.95 SSTISL TST 3825' -3724' 8.4 8.5 BG MW Seq.93 SSTISL TST 4007' -3906' 8.7 8.9 +ve BG MW Seq.92 SSTISL TST 5750' -5649' 8.7 8.9 +ve BG MW HRZ SHL 7298' -7190 8.7 8.9 BG MW Miluveach Shale SHL 7310' -7202' 9.0 9.2 +ve BG MW (LCU) UJUI Alpine SST 7689' -7581' 9.2 9.4 +ve BG,TG, MDT Equivalent Sands MDT Base J4 Silt SLTST 7860 -7753' 9.0 9.3 -ve BG MW Total Depth SHUCLST 8005' -7896 Refer to Section 4.3 for explanation of abbreviations used. · The following text highlights key details of the final wellsite assessment of the pore pressure profile Normal pore pressures (8.4ppg to 9.0ppg EMW) are maintained until approximately 7321 ft MDRT at which point levels of background gas incur a slight increase. Unfortunately the inabililyto construct normal compaction trends for DXC, does not permit the quantitative estimation of pore pressure. A pressure of 8.5 ppg was obtained for the Nanushuk using MDT. Pore pressure is seen to trend upwards from Sequence 93 through the Miluveach Shale based on the increase of background gas along with the increase mud weight. Pore pressure for the Alpine Equivalent Sands was obtained MDT. A value of 9.4 ppg was obtained for this formation. A subsequent negative trend in pore pressure is observed to total depth based on the lack of connection gas and decreasing background gas. · ~ EPOCH 13 .../ ConocoPhillips SPARK #4 . 5 DRILLING DATA 5.1 Survey Data Survey Survey Survey TVD N/S EIW Vertical DogLeg Depth Inclination Azimuth (ft) Departure Departure Section Severity (ft) (deg) (deg) (ft) (ft) (ft) (°/100') 191.28 0.22 56.36 191.28 0.21 0.31 0.21 0.12 286.30 0.25 56.10 286.30 0.43 0.64 0.43 0.03 376.68 0.33 80.43 376.68 0.58 1.06 0.58 0.16 465.59 0.61 77.37 465.58 0.73 1.78 0.73 0.31 556.80 0.78 89.06 556.79 0.84 2.87 0.84 0.24 645.66 0.97 97.84 645.64 0.75 4.22 0.75 0.26 734.64 1.15 101.13 734.60 0.48 5.84 0.48 0.22 823.53 1.15 99.6 823.47 0.15 7.60 0.15 0.04 912.37 1.05 103.66 912.30 -0.19 9.26 -0.19 0.14 1007.25 1.00 104.10 1007.16 -0.59 10.91 -0.59 0.06 1102.07 1.02 106.83 1101.97 -1.04 12.51 -1.04 0.06 1197.20 0.99 110.33 1197.08 -1.57 14.09 -1.57 0.07 1292.56 1.08 105.98 1292.43 -2.10 15.73 -2.10 0.13 1388.08 1.09 101.98 1387.93 -2.54 17.49 -2.54 0.08 . 1483.42 1.10 101.23 1483.25 -2.91 19.28 -2.91 0.02 1577 .59 1.05 104.97 1577.41 -3.31 21.00 -3.31 0.09 1673.52 0.28 37.46 1673.33 -3.35 21.99 -3.35 1.02 1768.90 0.64 334.31 1768.71 -2.69 21.9 -2.69 0.59 1864.21 0.53 339.16 1864.01 -1.80 21.52 -1.80 0.12 1959.28 0.61 340.35 1959.08 -0.92 21.19 -0.92 0.08 2053.51 0.56 334.79 2053.3 -0.03 20.81 -0.03 0.08 2149.12 0.58 338.67 2148.91 0.84 20.45 0.84 0.05 2244.14 0.61 322.23 2243.92 1.69 19.97 1.69 0.18 2339.20 0.70 333.59 2338.98 2.62 19.4 2.62 0.17 2434.41 0.77 325.96 2434.18 3.67 18.78 3.67 0.13 2529.39 0.62 324.04 2529.15 4.62 18.12 4.62 0.17 2604.17 0.62 320.32 2603.93 5.25 17.62 5.25 0.05 2751.93 0.72 327.80 2751.68 6.65 16.62 6.65 0.09 2847.52 0.79 334.7 2847.26 7.76 16.02 7.76 0.12 2942.35 0.74 345.44 2942.08 8.94 15.58 8.94 0.16 3038.58 0.75 348.00 3038.30 10.16 15.30 10.16 0.03 3133.90 0.79 341.62 3133.61 11.39 14.96 11.39 0.10 3229.44 0.69 346.08 3229.15 12.57 14.62 12.57 0.12 3325.10 0.72 340.19 3324.8 13.69 14.27 13.69 0.08 3420.29 0.59 341.34 3419.98 14.71 13.92 14.71 0.14 . ~ EPOCH 14 ....'. ConocoPhillips SPARK #4 . Survey Survey Survey TVD N/S EIW Vertical DogLeg Depth Inclination Azimuth (ft) Departure Departure Section Severity (ft) (deg) (deg) (ft) (ft) (ft) (°/100') 3515.84 0.55 346.22 3515.53 15.62 13.65 15.62 0.06 3611.12 0.64 331.99 3610.80 16.54 13.29 16.54 0.18 3706.87 1.35 237.51 3706.54 16.41 12.09 16.41 1.61 3802.41 1.45 233.05 3802.05 15.09 10.17 15.09 0.15 3897.84 1.38 237.48 3897.46 13.74 8.24 13.74 0.13 3993.45 1.47 239.40 3993.04 12.50 6.22 12.50 0.10 4089.04 1.46 237.95 4088.59 11 .23 4.13 11 .23 0.04 4184.51 1.44 237.94 4184.03 9.95 2.08 9.95 0.02 4279.74 1.38 237.24 4279.24 8.69 0.10 8.69 0.06 4375.20 0.39 286.74 4374.68 8.16 -1.18 8.16 1.22 4470.57 0.39 290.26 4470.05 8.37 -1 .79 8.37 0.03 4566.42 0.66 2.56 4565.90 9.04 -2.07 9.04 0.69 4661.46 0.62 4.69 4660.93 10.10 -2.01 10.10 0.06 4756.45 0.55 336.25 4755.92 11.03 -2.15 11.03 0.31 4851.00 0.69 338.87 4850.46 11.98 -2.54 11.98 0.15 4947.44 0.66 298.08 4946.90 12.78 -3.24 12.78 0.49 5042.96 0.77 299.02 5042.41 13.35 -4.28 13.35 0.12 . 5138.67 0.58 287.56 5138.11 13.81 -5.31 13.81 0.24 5234.13 0.56 276.74 5233.57 14.01 -6.24 14.01 0.12 5329.59 0.40 277.16 5329.02 14.11 -7.03 14.11 0.17 5424.84 0.41 249.57 5424.27 14.03 -7.67 14.03 0.20 5520.39 0.31 226.43 5519.82 13.72 -8.19 13.72 0.18 5615.67 0.28 230.00 5615.10 13.40 -8.55 13.40 0.04 5711.29 0.20 257.11 5710.72 13.21 -8.89 13.21 0.14 5804.75 0.00 328.91 5804.18 13.18 -9.04 13.18 0.21 5902.41 0.14 241.55 5901.84 13.12 -9.17 13.12 0.14 5997.90 0.20 58.89 5997.33 13.15 -9.11 13.15 0.35 6093.51 0.66 99.28 6092.93 13.15 -8.43 13.15 0.55 6188.84 1.39 109.94 6188.25 12.66 -6.80 12.66 0.79 6284.05 2.29 106.61 6283.41 11 .72 -3.89 11.72 0.95 6379.22 1.89 92.43 6378.52 11.11 -0.49 11.11 0.68 6474.89 2.08 84.14 6474.13 11.22 2.81 11.22 0.36 6570.43 1.10 71.46 6569.63 11.69 5.40 11.69 1.08 6666.38 1.62 73.41 6665.55 12.37 7.58 12.37 0.55 6761.55 1.76 75.69 6760.68 13.12 10.28 13.12 0.16 6857.02 1.73 86.25 6856.11 13.57 13.12 13.57 0.34 6951.11 2.06 92.14 6950.15 13.60 16.24 13.60 0.40 7048.98 4.60 92.08 7047.84 13.39 21.92 13.39 2.60 7144.05 9.21 98.19 7142.20 12.17 33.27 12.17 4.90 . 7239.85 11 .27 98.44 7236.47 9.70 50.12 9.70 2.15 n EPOCH 15 eonoco"Phillips SPARK #4 · Survey Survey Survey TVD N/S EIW Vertical DogLeg Depth Inclination Azimuth (ft) Departure Departure Section Severity (ft) (deg) (deg) (ft) (ft) (ft) (°/100') 7335.46 9.53 96.99 7330.5 7.37 67.21 7.37 1.84 7430.85 7.12 95.17 7424.88 5.87 80.93 5.87 2.54 7526.85 5.54 92.22 7520.30 5.16 91.49 5.16 1.68 7622.21 4.41 89.47 7615.29 5.01 99.75 5.01 1.20 7654.63 4.05 87.76 7647.63 5.07 102.14 5.07 1.19 7726.41 3.73 88.36 7719.24 5.24 107.01 5.24 0.45 7822.15 3.89 88.40 7814.77 5.41 113.37 5.41 0.17 7915.21 3.67 85.95 7907.63 5.71 119.49 5.71 0.3 8005.00 3.67 85.95 7997.23 6.12 125.23 6.12 0.00 · · [:I EPOCH 16 .....- ConocoPhillips SPARK #4 5.2 Bit Record Bit Make Type Jets / TFA Depth Total Bit Av.ROP WOB RPM SPP Wear /Run In(ft) Footage Hrs (ftIhr) (klbs) (psi) 1 HC MX-C1 1x12,3x18/0.856 117 2556 22.8 112.1 10-15 60 1-2-WT -G-E-I-NO- TD 2 HC HCM605 5x16/0.982 2673 4345 42.0 101.3 O-O-NO-A-X-I-ER-BHA 2RR HC HCM605 5X16/0.982 7018 684 14.9 46 0-1-WT -N-X-I-ER- TO 3 HC STX-1 3x18/0.746 7702 9 0.25 36 1-1-WT -A-E-I-NO-CP 4 HC ARC-425 6X12/0.663 7711 94 6.75 14 1-1-WT -A-O-I-NO-BHA 5 HC HCM605 6X11/0.557 7805 200 7.99 43 5.9 1-1-WT -A-X-I-PN- TO 5.3 Mud Record Contractor MI Orilling Fluids Mud Type KCI Flow Pro DATE DEPTH MW ECD VIS PV YP Gels WL Fe Sols OIW Sd MBT pH TotCI Hard (ppg) (ppg) (s/qt) (cc) (%) Ratio (%) (#/gal) (mg/L) Ca++ 03/26/04 617 10.1 10.4 75 14 39 14/22/24 5.1 1/N/A 8.5 192 1 1 9.5 36000 240 03/27/04 2430 10.0 90 14 50 24/37/40 5.8 1/N/A 8.5 192 0.75 2.75 9.0 33000 280 03/28104 2673 10.0 54 12 29 13/17/18 6.4 1/N/A 9.0 191 0.75 2.0 9.3 37000 240 03/29104 2673 10.0 57 12 29 13/17/18 6.2 1/N/A 9.0 191 0.75 2.0 9.2 37000 200 03/30/04 3533 9.6 10.16 50 11 31 14/22/27 6.8 1/N/A 7.5 1/92 0.25 3.5 9.0 29000 200 04/31/04 5118 9.7 10.41 51 14 39 22/35/40 9.6 1/N/A 9.0 1/90 0.15 7.5 8.5 28000 280 04/01104 6254 11.1 11.73 51 19 38 15/28/30 10 2/N/A 14.5 1/85 0.2 8.5 8.5 31250 180 04/02/04 7018 11.2 11.30 45 23 32 10/18/21 6.8 2/N/A 14.5 1/85 0.15 10.0 8.8 28000 120 04/03/04 7018 11.2 63 23 29 9/14117 6.2 1/N/A 14.5 1/85 0.10 10.0 8.8 25000 120 04/04/04 7368 11.2 56 28 35 11/19/22 5.4 2/N/A 14.5 1/85 0.25 9.5 9.2 29000 180 04/05/04 7702 11.3 11.78 52 28 30 1 0/20/23 5.8 2/N/A 15.0 1/84 0.25 10.0 9.0 28000 120 04/06/04 7702 11.3 11.3 60 23 21 5/1 0/12 5.0 2/N/A 15.0 1/84 0.25 9.0 9.1 22000 120 04/07/04 7702 11.3 86 22 28 9/19125 5.2 2/N/A 14.5 1/85 0.10 9.5 9.0 27000 100 04/08/04 7788 9.8 11.16 102 32 28 6/13117 4.8 1/1 10 1/90 0.1 8.75 8.5 32000 100 04/09/04 7815 9.8 11 .43 135 32 29 6/12/15 4.6 1/1 10 1/90 0.1 9 8.5 32000 100 04/1 0104 8005 9.8 64 24 19 5/8/11 5.0 1/1 10.5 1/89 0.1 9 8.4 33000 100 Abbreviations MW = Mud Weight Gels = 30 sec & 30 minute Sd = Sand content ECO = Effective Circulating Density WL = Water or Filtrate Loss VIS = Funnel Viscosity FC = Filter Cake Tot CI = Total Chlorides PV = Plastic Viscosity Sols = Solids YP = Yield Point OIW = Oil to Water ratio . n E110CH . 17 . I I I I I I I I I I I I I I I I I I I Schlumberger Fluid Analysis on MDT Samples ConocoPhillips Field: Exploration I"··'·..··.'..·..'·'·'. W. ê.l.I:.S·a t k"#4...·.. ........"-.....~..- ..-., {~{\'\J ~:;ni't~'\,rr ~ /.¡"~ I , \.,- V 1 ~.l .UJ i;...Ü:~ .Llf.U..J I PVT Study Report Prepared for Dennis Wegener ConocoPhillips Standard Conditions Used: Pressure: 14.696 psia Temperature: 60°F Prepared by: Meisong Yan Reviewed by: Dennis D'Cruz Schlumberger WCP Oilphase-DBR 2315 Schlumberger Street, Building 15 Houston, Texas, 77023 (713) 921-9500 Date: 11/30/2004 Aoøt~-.¡.... R!/JuA. 2oif-008 Report #200400111 I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 1 9 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger I Table of Contents I List of Figures ...... ......... ..... ListofTables .......... ...... ......... .................. ........................ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . I EXECUTIVE SUMMARY.. ................ ................................... ................. I Objective ........ ....... .. ..... .......... ... .... ...... ........ ................ ........... ...................... Introduction ............. .... ............ .............. ............... ......... Scope of Work. ........ . ................ ..................... .................................. .. ................................ Results ................ ........ ........ ..... ........ ...... .......... ........... ............... ... ... ......... Sequence of Events ............... . ... ... .. .................................. Chain of Sample Custody .................... .......... ........................ I RESULTS AND DISCUSSIONS.. . . . . . . . . . . . . . . . . . . . . . . . ................................................................... I I Fluids Preparation and Analysis... ............... Reservoir Fluid Analysis. . . . . . .. ........................... ................................ .............. ....................... PVT Analysis on.Sample1.08;.Cylinder.SSB 1160170A;. Depth .7128 ft. MD.... ConstantComposition.ExpansiDnat.Tr.es. ........ ...... .... . ...... .............. ............... PVT Analysis on Sample 1.09; Cylinder SSB.1.187670A;. Depth 7128 .ft. MD. Constant Composition .ExpansiDn at. Tr.es .. ............. ....................... ..................... .................... I Appendix A: Nomenclatur.e..and.DefinitioDS. ... .................................................................... . Appendix B: Molecular.Weightsand Densitie.s. Used.... Appendix C: EQUiPMENT..... ..... ................... ........................................................... Fluid Preparation and. Validation ..................... ............................ ....................... Fluid Volumetric (PVT). and Viscosity Equipment ............. Appendix D: PRo.CEDURE. .............. .............. .................. Fluids Preparationand.Validation..... .... ............. . ......... Constant Composition Expansion PrDcedure. . . . . . . . . . . .. .......... Differential Vaporization. Procedure. .................................. Multi-Stage Separation Test ... ............... ..... ... ....... .......... ...... ..... ........................ .... ......... ....... Liquid Phase Viscosity and.Density Measurements. During .DV.Step . ..... . ..... . ...... Stock- Tank Oil (S.TO). Viscosity and Density Measurements.. Asphaltene, Wax andSul/ur Content Measurements ............................. .. SAR(P)AAnalysis ..... .... ............ ................. .............. High-Temperature. High7Pressure.Filtr.atiDn. Test. ............. I I ........................ .............. I I ............. . . . . . . . . . . . . . . . I ................. I I I I I WCP Oilphase-DBR 2 3 4 4 4 4 4 5 5 6 6 6 16 16 22 22 27 28 29 29 29 32 32 32 32 33 33 33 34 34 34 Job #: 200400111 I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger I List of Figures I I Figure 1: Stock Iank.Oil.ChrolDBtogram(SampJe.1..08}.... .. ........... Figure 2: k-Plot for Equilibrium.Check(Sample .1.081...... ... ... . ............. Figure 3: Stock Iaok.Oil.Chromatogram(SampJe.l.09} ...................... Figure 4: k-Plotfor. Equilibrium.Check(Sample .1.091.......... . . . ....... ................... Figure 5: Constant Composition Expansion at.17rf.c .ReJative Volume. (Sample.1..08} Figure 6: Constant .Composition Expansion at.17rf .cRetrograde liquid Oeposit (Sample. 1.081.. Figure 7: Constant .Composition Expansion at.17rf.c .Reservojr fluid Density (SampJe.1..08} Figure 8: Constant Composition Expansion at.17rf.c Z factor (SampJe.1..08}. ........ . ........ ... Figure 9: Constant .Composition Expansion at.1.71°f.c .ReJative Volume. (SampJe.1..09}.. Figure 10: Constant. Composition. Expansion. at .117.°F" Retrograde. Liqujd.Deposit.(Sample.1.09J.. Figure 11: Constant. Composition. Expansion. at .117.°F.". Reservoir. flujd. Densjty.(Sample .1.091 ......... . ..... Figure 12: Constant. Composition. Expansion. at .117.°F" Z.Factor.(Sample .1.091... .. ............ 11 11 14 14 17 18 19 20 23 24 25 26 I I I I I I I I I I I I I I I WCP Oilphase-DBR 2 Job #: 200400111 I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger I I List of Tables I I Table 1: Well and.SampLe.ldentificatiOß......................................................................................... Table 2: Sampling and Transfer Swnmaq.. . . . . . . . . . . . ..... . . . . . . . . . . . . . . . ............. ... . .. . . . . . . ................. .. . . . . ...... Table 3: Reservoir fluid Properties. . . . . .... . . . .. . . . . . . . . . .... . . . ... . . . . . . . . .. . ..... . ........ .. . . .. . ............ .. . . . . . . . . . . . . . ... Table 4: Stock-Tank.OiJ.P.roperties............................................................................................... Table 5: C30+ Composition. GOR. .oAPI. .b.y.Zero-.Flash (SampJe.1..D8) ................... .................... Table 6: Calculated Fluid Properties ..... .............. ..... Table 7: C30+ Composition. GOR. °API. .b.y.Zero-Flash (SampJe.1..D9) Table 8: Calculated Fluid Properties.. Table 9: Summary. of Results of. Sample .1.08. ............ Table 10: Constant Composition. Expansion.at.1 17.0F. (SampJe.1.D8).. Table 11: Summaryo.tResuLts.of Sample .1.09 ................................. Table 12: Constant Composition. Expansion. at .117.°F. (SampJe.1..D9I.... .............. 7 7 8 8 9 10 12 13 15 16 21 22 .. . ... ................ .... ....... ............. I I I .................. ...................... I I I I I I I I I I I WCP Oilphase-DBR 3 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger 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-DBR has conducted a fluid analysis study on bottomhole fluid samples collected during the Modular Formation Dynamics Testing of Well Spark #4 drilled during the Exploration. Scope of Work . Homogenize bottomhole hydrocarbon fluid samples at 177°F and 8000 psi with rocking for three days. · Conduct preliminary evaluation on bottomhole hydrocarbon samples that includes single-stage flash Gas· Oil Ratio (GOR). reservoir fluid composition, stock-tank oil (STO) and monophasic fluid properties. · Select representative samples for the PVT study. · Conduct a Constant Composition Expansion (CCE) test at the reservoir temperature. Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon samples: · Two bottomhole samples were used for validation purposes. They were homogenized at 17JDF and 8000 psi for three days. · The zero flash GOR was determined to be from 28.482 - 34,584 SCF/STB, and the STO density to be from 0.782 - 0.791 g/cc. · Select representative samples 1.08 and 1.09 for the PVT study. · The dew point of the sample 1.08 at Tres is 4395.7 psia. · The dew point of the sample 1.09 at Tres is 4333.7 psia. · Although the dew points of both samples 1.08 and 1.09 are above the measured reservoir pressure (3723 psia at 177 of). these dew points are believed to be representative of the fluid samples present in the sample chambers. The explanation as to why the captured samples had dew points higher than the reservoir pressure is believed to be linked to the suspected presence of a relic oil saturation. While this relic oil saturation will be immobile under most production scenarios, it is speculated that phase behavior processes near the well bore during MDT sampling serves to mobilize this relic oil which leads to measured dew points higher than the reservoir pressure. WCP Oilphase-DBR 4 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: Field: Sand: Job#: Schlumberger Exploration JURASSIC 200400111 ConocoPhillips Spark #4 Doyon 19 Sequence of Events 05/17/04 Sample arrived and clinet was informed. 09/24/04 Project work scope discussed. 09/24/04 Work agreement approved. 10/07/04 Sample PVT prelim results sent via e-mail. 11/05/04 Sample PVT results sent via e-mail. 11/19/04 Invoice for the prelim and CCE study were generated. Invoice#: 9091302948. Chain of Sample Custody The samples collected from the well of Spark #4 were sent to Oilphase-DBR in Houston, Texas. The samples were used for 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 Job #: 200400111 5 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger RESUL 1S AND DISCUSSIONS Fluids Preparation and Analysis Two bottomhole samples 1.08 and 1.09 collected during the Modular Formation Dynamics Testing 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 bottom hole samples was conducted and the results are summarized in Table 2. After three days of homogenization, sample validation tests were conducted to evaluate the validity of the samples, and both samples were good candidates for PVT analysis. Based on the preliminary results, sample 1.08 and 1.09 were 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 (GOR) to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Tables 5 and 7. The molecular weight of the stock-tank oil (STO) was measured. Other properties such as the plus fraction properties and heat content for the flashed gas were calculated from the compositions and are listed in Tables 6 and 8. Only water-based mud was used for this well. WCP Oilphase-DBR 6 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: ConoeoPhillips Field: Exploration Schlumberger Well: Spark #4 Sand: JURASSIC Installation: Doyon 19 Job#: 200400111 Table 1: Well and Sample Identification Client: ConoeoPhillips Job# 200400111 Field: Exploration Well: Spark #4 Sample ID Chamber # Chamber Sampling Date Opening Condo Reservoir Conditions Volume in the field Pressure Temperature Depth (ee) (psia/oF) (psia) (OF) (ft) 1.08 SPMC 117 250 4/11/2004 4515/69 3)23 177 7728 1.09 SPMC 204 250 4/11/2004 4515/69 3)23 177 7728 Table 2: Sampling and Transfer Summary Opening Transfer Closing Opening Initial Sample ID Chamber # conditions Cylinder conditions conditions FS&W Sample in the field ID in the field in the Lab Volume (psiarF) (psia;oF) (psiarF) (ee) (ee) 1.08 SPMC 117 4515/69 SSB 11607 -QA 5515/69 5115/72 2 200 1.09 SPMC 204 4515/69 SSB 11876-QA 5515/69 5015/72 2 200 WCP Oilphase-DBR 7 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConoeoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Sample ID Cylinder # Table 3: Reservoir Fluid Properties Zero Flash Dew Depth GOR* Bo** Point at Tres (ft) (sef/bbl) (psia) SSB 11607 -QA SSB 11876-QA 1.08 1.09 7)28 7.728 34,584 28,482 4396 4334 * Flashed gas volume (scf) per barrel of stoek tank liquid @ 60°F ** Volume of live oil at its bubble point pressure per flashed stoek tank liquid volume @ 60°F Table 4: Stock-Tank Oil Properties STO Properties Sample ID Cylinder # Depth Molar Mass Density API (ft) (glee) 1.08 SSB 11607-QA 7)28 144.3 0.791 47.4 1.09 SSB 11876-QA 7)28 134.2 0.782 49.4 WCP Oilphase-DBR 8 Schlumberger Molar Mass of monophasic fluid 23.7 24.1 Job #: 200400111 I Client: ConocoPhillips field: Exploration Schlumberger Well: Spark #4 Sand: JURASSIC I Table 5: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.08) I Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD Component MW flashed Gas flashed Liquid Monophasic fluid (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % I Carbon Dioxide 44.01 1.76 0.85 0.00 0.00 1.54 0.83 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.26 0.20 0.00 0.00 0.23 0.20 I Methane 16.04 59.71 78.87 0.00 0.00 52.21 77.24 Ethane 30.07 15.66 11.04 0.00 0.00 13.69 10.81 Propane 44.10 11.17 5.37 0.00 0.01 9.77 5.26 I I - Butane 58.12 2.08 0.76 0.01 0.02 1.82 0.74 N - Butane 58.12 4.06 1.48 0.04 0.11 3.56 1.45 I - Pentane 72.15 1.59 0.47 0.12 0.24 1.40 0.46 I N - Pentane 72.15 1.56 0.46 0.21 0.42 1.39 0.46 C6 84.00 0.68 0.17 1.24 2.13 0.75 0.21 M-C-Pentane 84.16 0.31 0.08 0.45 0.76 0.33 0.09 I Benzene 78.11 0.07 0.02 0.09 0.17 0.07 0.02 Cyclohexane 84.16 0.32 0.08 0.74 1.27 0.37 0.10 C7 96.00 0.24 0.05 3.82 5.74 0.69 0.17 M-C-Hexane 98.19 0.34 0.07 2.90 4.26 0.66 0.16 I Toluene 92.14 0.10 0.02 1.57 2.45 0.28 0.07 C8 107.00 0.05 0.01 8.82 11.89 1.15 0.26 E-Benzene 106.17 0.00 0.00 0.32 0.44 0.04 0.01 I M/P-Xylene 106.17 0.01 0.00 2.53 3.44 0.32 0.07 a-Xylene 106.17 0.00 0.00 0.72 0.98 0.09 0.02 C9 121.00 0.00 0.00 10.26 12.23 1.29 0.25 I Cl0 134.00 0.01 0.00 12.37 13.32 1.56 0.28 Cll 147.00 0.00 0.00 9.73 9.55 1.22 0.20 C12 161.00 0.00 0.00 7.78 6.97 0.98 0.14 I C13 175.00 0.00 0.00 7.02 5.79 0.88 0.12 C14 190.00 0.00 0.00 5.64 4.28 0.71 0.09 C15 206.00 0.00 0.00 4.89 3.42 0.61 0.07 I C16 222.00 3.67 2.38 0.46 0.05 C17 237.00 2.87 1.75 0.36 0.04 C18 251.00 2.55 1.46 0.32 0.03 I C19 263.00 1.97 1.08 0.25 0.02 C20 275.00 1.50 0.79 0.19 0.02 C21 291.00 1.22 0.60 0.15 0.01 C22 300.00 0.96 0.46 0.12 0.01 I C23 312.00 0.79 0.36 0.10 0.01 C24 324.00 0.62 0.28 0.08 0.01 C25 337.00 0.50 0.21 0.06 0.00 I C26 349.00 0.43 0.18 0.05 0.00 C27 360.00 0.37 0.15 0.05 0.00 C28 372.00 0.32 0.13 0.04 0.00 I C29 382.00 0.23 0.09 0.03 0.00 C30+ 580.00 0.73 0.18 0.09 0.00 Total 100.00 100.00 100.00 100.00 100.00 100.00 I MW 21.19 144.26 23.73 MOLE RATIO 0.9793 0.0207 I WCP Oilphase-DBR 9 Job #: 200400111 I Client: ConocoPhillips Field: Exploration Schlumberger Well: Spark #4 Sand: JURASSIC I Table 6: Calculated Fluid Properties I Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid I Cn+ Composition Mass % Mole% Mass % Mole% Mass % Mole% C7+ 1.46 0.34 98.37 97.07 13.63 2.34 C12+ 0.00 0.00 44.05 30.56 5.53 0.63 I C20+ 7.67 3.43 0.96 0.07 C30+ 0.73 0.18 0.09 0.00 I Molar Mass C7+ 90.43 146.20 138.21 C12+ 207.94 207.94 I C20+ 323.01 323.01 C30+ 580.00 580.00 I Density C7+ 0.7939 C12+ 0.8185 0.8185 C20+ I C30+ Fluid at 60°F 0.7911 I Gas Gravity (Air = 1) 0.732 Dry Gross Heat Content (BTU/scf) 1 1,263 I Wet Gross Heat Content (BTU/scf) 1,241 Water-based Mud Contamination level (wt%) ISTO Basis I Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties I MW 1 144.26 I 580.00 I Density (g/cm3) 0.791 I Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 34584 1 I STO Density (g/cm3) 0.7911 STO API Gravity 47.4 I OBM Density (g/cm3) @60°F I I I WCP Oilphase-DBR 10 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Well: Spark #4 Field: Exploration Sand: JURASSIC Figure 1: Stock Tank Oil Chromatogram (Sample 1.08) 1.08; SSB 11607-QA; 7728 ft. MD FID1~, - pA : 1800 - 1600 - 1400 - lD 1200 - 0 I 0 '1000 - (j :>, 800 - :;¡ 600 - 400- 200 - 0 0 10 o \"" o ,.. ,.. o (\1 ,.. o (Ï) \"" o '1 \"" 01.[1 ,.. OlD ,..,,- O,..CO 0,..0)0 0'" N\""r~(Ï) o 0 r'l r'~ N '1l.[1lD"-COo) Ooo~jr~Nr~NN 000000 20 I 30 1 40 min I 50 Figure 2: k-Plot for Equilibrium Check (Sample 1.08) Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD 5.00 4.00 + C3 3.00 + iC4 + nC4 ë>. 2.00 ... -= <::I .. .... 100 0.00 . C6 ." C7 -100 .-et-- -2.00 -4.00 -3.00 -2.00 -1.00 000 100 2.00 3.00 F WCP Oilphase-DBR 11 Job #: 200400111 I Client: ConocoPhillips Field: Exploration Schlumberger Well: Spark #4 Sand: JURASSIC I Table 7: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.09) I Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % I Carbon Dioxide 44.01 1.78 0.86 0.00 0.00 1.52 0.83 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.25 0.19 0.00 0.00 0.21 0.18 I Methane 16.04 59.89 78.93 0.00 0.00 51.07 76.84 Ethane 30.07 15.71 11.05 0.00 0.00 13.40 10.76 Propane 44.10 11.20 5.37 0.10 0.29 9.56 5.24 I I - Butane 58.12 2.07 0.75 0.08 0.19 1.78 0.74 N - Butane 58.12 4.05 1.47 0.30 0.70 3.50 1.45 I - Pentane 72.15 1.57 0.46 0.43 0.80 1.40 0.47 I N - Pentane 72.15 1.55 0.45 0.65 1.22 1.42 0.47 C6 84.00 0.64 0.16 2.77 4.42 0.96 0.27 M-C-Pentane 84.16 0.29 0.07 0.90 1.43 0.38 0.11 I Benzene 78.11 0.07 0.02 0.19 0.32 0.08 0.03 Cyclohexane 84.16 0.29 0.07 1.34 2.14 0.44 0.13 C7 96.00 0.19 0.04 5.97 8.34 1.04 0.26 M-C-Hexane 98.19 0.27 0.06 4.14 5.66 0.84 0.21 I Toluene 92.14 0.12 0.03 2.11 3.08 0.41 0.11 C8 107.00 0.04 0.01 10.31 12.93 1.55 0.35 E-Benzene 106.17 0.00 0.00 0.34 0.43 0.05 0.01 I M/P-Xylene 106.17 0.01 0.00 2.58 3.26 0.39 0.09 O-Xylene 106.17 0.00 0.00 0.71 0.90 0.11 0.02 C9 121.00 0.00 0.00 10.03 11.12 1.48 0.30 I C10 134.00 0.01 0.00 11.00 11.02 1.63 0.29 C11 147.00 0.00 0.00 8.30 7.58 1.22 0.20 C12 161.00 0.00 0.00 6.54 5.45 0.96 0.14 I C13 175.00 0.00 0.00 5.90 4.52 0.87 0.12 C14 190.00 0.00 0.00 4.76 3.36 0.70 0.09 C15 206.00 0.00 0.00 4.13 2.69 0.61 0.07 I C16 222.00 3.10 1.87 0.46 0.05 C17 237.00 2.44 1.38 0.36 0.04 C18 251.00 2.17 1.16 0.32 0.03 I C19 263. 00 1.69 0.86 0.25 0.02 C20 275.00 1.29 0.63 0.19 0.02 C21 291.00 1.04 0.48 0.15 0.01 C22 300.00 0.83 0.37 0.12 0.01 I C23 312.00 0.68 0.29 0.10 0.01 C24 324.00 0.54 0.22 0.08 0.01 C25 337.00 0.46 0.18 0.07 0.00 I C26 349.00 0.39 0.15 0.06 0.00 C27 360.00 0.43 0.16 0.06 0.00 C28 372. 00 0.37 0.13 0.06 0.00 I C29 382.00 0.22 0.08 0.03 0.00 C3O+ 580.00 0.75 0.17 0.11 0.00 Total 100.00 100.00 100.00 100.00 100.00 100.00 I MW 21.14 134.16 24.14 MOLE RATIO 0.9735 0.0265 I WCP Oilphase-DBR 12 Job #: 200400111 I Client: ConocoPhillips Field: Exploration Schlumberger Well: Spark #4 Sand: JURASSIC I Table 8: Calculated Fluid Properties I Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid I Cn+ Composition Mass % Mole% Mass % Mole% Mass % Mole% C7+ 1.29 0.30 95.66 92.37 15.19 2.74 C12+ 0.00 0.00 37.73 24.17 5.56 0.64 I C2o+ 7.01 2.88 1.03 0.08 C3O+ 0.75 0.17 0.11 0.00 I Molar Mass C7+ 89.93 138.94 133.67 C12+ 209.42 209.42 I C2o+ 326.94 326.94 C3O+ 580.00 580.00 I Density C7+ 0.7900 C12+ 0.8210 0.8210 C2O+ I C3O+ Fluid at 6o°F 0.7821 I Gas Gravity (Air = 1) 0.730 Dry Gross Heat Content (BTU/scf) I 1,261 I Wet Gross Heat Content (BTU/scf) 1,239 Water-based Mud Contamination level (wt%) ISTO Basis I Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properti es I MW I 134.16 I 580.00 I Density (g/cm3) 0.782 I Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 28482 I I STO Density (g/cm3) 0.7821 STO API Gravity 49.4 I OBM Density (g/cm3) @6o°F I I I WCP Oilphase-DBR 13 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: ConocoPhíllips Well: Spark #4 Field: Exploration Sand: JURASSIC figure 3: Stock Tank Oil Chromatogram (Sample 1.(9) Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD - pA: 1800 - to o 1600 - , o Q)Oì (J cO ::-, () (J - ¿: OJ::-' to () 0 X o c: ' CtO t-. () .~ roO J "'.! Lj') '), õ E o "j'o f- 800 - 'a¡j c (3::-, '~G0 600 - \>, c;¿ tfl 400 - i la ~:I~ , I la 200 - ._ I 1400- o ,.. o ,.. ,.. ü 1200 - 1000 - rnín [I Œ C c[I Œ- ~ >, cX Œ ' [0 (! C o o I 20 I 40 I 50 30 figure 4: k-Plot for Equilibrium Check (Sample 1.(9) Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD 3.00 2.50 2.00 1.50 Q. 1.00 ..:.:: c; <:> 0.50 ..... 000 -0.50 -100 -1.50 -4.00 -3.00 .. C3 ,. iC4 .ttC-4 ~ .. C6 C7 .. C8 -2.00 -100 000 100 2.00 3.00 f WCP Oilphase-DBR 14 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: WCP Oilphase-DBR ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Table 9: Summary of Results of Sample 1.08 Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD Reservoir Conditions: Pressure: 3723 177 Temperature: Dew Point Pressure At T res Gas-Oil Ratio Single-stage Flash: Total Differential Liberation: Total Separator Flash (1): Total Separator Flash (2): Properties at 60°F Single-stage STO: Differential Liberation STO: Separator STO (1): Separator STO (2): Properties at Tres and Reservoir Pressure Viscosity: Compressibillity (Co): Density: Properties at Tres and Psat Viscosity: Compressibillity (Co): Density: Formation Volume Factor Single-stage Flash: Total Differential Liberation: Total Separator Flash (1): Total Separator Flash (2): Note: Standard conditions are 14.696 psia and 60°F 4.396 34584 STO ° API 47.4 @Pres & Tres 15 pSla of pSla scf!stb scf I stb scf/stb scf!stb Gas Gravity (Average) 0.732 cP 106¡psi g/cc CP 1O-6/psi g/cc @Psat & Tres Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: ConoeoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger PVT Analysis on Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. 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 177°F and 10015 psia pressure. The CCE measurements are presented in Table 10. The measured dew point pressure was 4395.7 psia. Other parameters such as the gas deviation factor, monophasic density and % liquid deposit were also measured at the reservoir temperature are reported in Table 10. The analysis result showed the dew point of sample 1.08 at the reservoir temperature is about 673 psi higher than the reservoir pressure. This observation was reported to the client and further discussion was listed in the result section. Table 10: Constant Composition Expansion at 177°F (Sample 1.08) Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD Pressure Relative RLD Density Z Volume (psia) (% of vol at Pd) (glee) 10015 0.7386 0.388 1.437 9016 0.7601 0.377 1.331 8516 0.7725 0.371 1.278 8017 0.7874 0.364 1.226 7518 0.8058 0.356 1.177 7019 0.8230 0.348 1.122 6520 0.8449 0.339 1.070 6018 0.8697 0.329 1.017 5718 0.8887 0.322 0.987 5618 0.8939 0.320 0.976 5519 0.9009 0.318 0.966 5020 0.9384 0.305 0.915 4920 0.9462 0.303 0.904 4820 0.9562 0.300 0.895 4720 0.9657 0.297 0.885 4621 0.9754 0.294 0.876 4520 0.9853 0.291 0.865 4420 0.9967 0.287 0.856 Pd 4396 1.0000 0.00 0.286 0.854 4319 1.0087 0.01 4221 1.0217 0.02 4135 1.0325 0.03 4017 1.0490 0.05 3905 1.0662 0.06 3730 1.0960 0.11 3528 1.1357 0.52 3319 1.1863 1.28 3118 1.2444 2.21 2826 1.3541 3.62 2423 1.5669 5.78 2027 1.8913 8.08 1820 2.1271 8.12 Note: The dew point of sample 1.08 at the reservoir temperature is about 673 psi higher than the reservoir pressure. WCP Oilphase-DBR 16 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: 2.40 2.00 CI) 1.60 E -= c > CI) > ''¡::::: = 'ii a:: 1.20 0.80 0.40 1000 WCP Oilphase-DBR ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Figure 5: Constant Composition Expansion at 177°F - Relative Volume (Sample 1.08) Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD ~._._ __ __ u_______ --------,.._------, 3000 5000 7000 9000 11000 Pressure (psial 17 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Figure 6: Constant Composition Expansion at 177°F - Retrograde Liquid Deposit (Sample 1.08) Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD 10.00 8.00 - =ë 6.00 a.. @ c; > - CI -::J!. ~ CI ...I 4.00 -- cc: 2.00 -- 0.00 1000 2000 3000 4000 5000 Pressure (psia) WCP Oilphase-DBR 18 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Figure 7: Constant Composition Expansion at 177°F - Reservoir Fluid Density (Sample 1.08) Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD 0.40 0.35 c:;- ..g ~ ~ ïñ c I\) C LL. a:: 0.30 0.25 4000 WCP Oilphase-DBR 6000 8000 Pressure (psia) 19 10000 12000 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: WCP Oilphase-DBR ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Figure 8: Constant Composition Expansion at 177°F - Z Factor (Sample 1.08) Sample 1.08; Cylinder SSB 11607-QA; Depth 7728 ft. MD 1.50 1.25 !:::!. .. Q - U CI 1.1- C Q '~ CI 'S: Q) CI en CI (::J 1.00 _u 0.75 4000 6000 8000 10000 12000 Pressure (psia) 20 Job #: 200400111 I Client: Well: I I I I I I I I I I I I I I I I I I WCP Oilphase-DBR ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Table 11: Summary of Results of Sample 1.09 Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD Reservoir Conditions: Pressure: Temperature: Dew Point Pressure AtTres Gas-Oil Ratio Single-stage Flash: Total Differential Liberation: Total Separator Flash (1): Total Separator Flash (2): Properties at 60°F Single-stage STO: Differential Liberation STO: Separator STO (1 ): Separator STO (2): Properties at Tres and Reservoir Pressure Viscosity: Compressibillity (Co): Density: Properties at Tres and Psat Viscosity: Compressibillity (Co): Density: Formation Volume Factor @Pres & Tres Single-stage Flash: Total Differential Liberation: 3723 177 4,334 28482 STO ° API 49.4 Total Separator Flash (1): Total Separator Flash (2): Note: Standard conditions are 14.696 psia and 60°F 21 pSla of pSla scf/stb scf/stb scf I stb scf/stb Gas Gravity (Average) 0.730 CP 1O-6/psi g/cc CP 1O-6/psi g/cc @Psat & Tres Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: ConoeoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger PVT Analysis on Sample 1.09; Cylinder SSB 11876-0A; Depth 7728 ft. 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 the specified reservoir temperature and at 10033 psia pressure. The constant composition expansions was conducted at the reservoir temperature of 177.3°F. The CCE measurements are presented in Table 12. The measured dew point pressure was 4333.7 psia. Other parameters such as the gas deviation factor, monophasic density and % liquid deposit were also measured at the reservoir temperature are reported in Table 12. The analysis result showed the dew point of sample 1.09 at the reservoir temperature is about 611 psi higher than the reservoir pressure. This observation was reported to the client and further discussion was listed in the result section. Table 12: Constant Composition Expansion at 177°F (Sample 1.09) Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD Pressure Relative RLD Density Z Volume (psia) (% of vol at Pd) (glee) 10033 0.7315 0.387 1.469 9018 0.7536 0.375 1.360 8520 0.7666 0.369 1.307 8020 0.7808 0.362 1.253 7515 0.7975 0.355 1.199 7019 0.8157 0.347 1.146 6519 0.8368 0.338 1.092 6018 0.8620 0.328 1.038 5518 0.8928 0.317 0.986 5017 0.9299 0.304 0.934 4817 0.9474 0.299 0.913 4717 0.9573 0.296 0.904 4616 0.9675 0.292 0.894 4546 0.9753 0.290 0.887 4415 0.9892 0.286 0.874 Pd 4334 1.0000 0.00 0.283 0.861 4199 1.0133 0.01 4095 1.0239 0.02 4015 1.0352 0.03 3915 1.0507 0.06 3721 1.0832 0.30 3520 1.1241 0.80 3326 1.1716 1.61 3024 1.2618 2.85 2724 1.3826 4.14 2421 1.5559 5.71 2047 1.8588 7.78 1846 2.0802 7.97 Note: The dew point of sample 1.09 at the reservoir temperature is about 611 psi higher than the reservoir pressure. WCP Oilphase-DBR 22 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: 2AO 2.00 m 1.60 E = ã > m > ''¡:¡ ..!!! m cc 1.20 0.80 OAO 1000 WCP Oilphase-DBR ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Figure 9: Constant Composition Expansion at 177°F - Relative Volume (Sample 1.09) Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD 3000 5000 7000 9000 11000 Pressure (psia) 23 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Figure 10: Constant Composition Expansion at 177°F - Retrograde Liquid Deposit (Sample 1.09) Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD 10.00 8.00 ~ 6.00 a.. @ ë; > - CI .,¡¿ ~ Q .... 4.00 a:: 2.00 0.00 1500 2000 2500 3000 3500 0-0-0 4000 4500 5000 Pressure (psia) WCP Oilphase-DBR 24 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Figure 11: Constant Composition Expansion at 177°F - Reservoir Fluid Density (Sample 1.09) Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD 0.40 0.35 u ~ .s ~ '¡;¡ c II) CI u.. CIC 0.30 0.25 3000 5000 7000 9000 11000 Pressure (psia) WCP Oilphase-DBR 25 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: ConocoPhillips Spark #4 Field: Sand: Exploration JURASSIC Schlumberger Figure 12: Constant Composition Expansion at 177°F - Z Factor (Sample 1.09) Sample 1.09; Cylinder SSB 11876-QA; Depth 7728 ft. MD 1.50 1.25 8 ... Q - U III LL. = Q ',¡:: III 'S: Q) Q en III c.:J 1.00 - 0.75 3000 5000 7000 9000 11000 Pressure (psial WCP Oilphase-DBR 26 Job #: 200400111 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 %,w/w Z ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger 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 the 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= 1). 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 27 Job #: 200400111 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 Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger 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 Cl 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 a-XYLENE C9 Cl0 Cll 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 28 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Schlumberger Field: Sand: Job#: Exploration JURASSIC 200400111 Appendix C: EQUIPMENT Ruid 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 a water-glycol mixture at the bottomside of the piston cylinder. A 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 analyses 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 and 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 Llhr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 psia) and the operating temperature ranges 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 the 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, 530um 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 °C to 400°C. Over this temperature range, the components eluted are from C, 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 using an 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, allows for the correct separation and analysis of the injected gas. WCP Oilphase-DBR 29 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger Fluid Volumetric (PVT) and Viscosity Equipment The preliminary saturation pressure, constant composition expansion (CCE), differential vaporization (OV) and 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. A specially designed floating piston and a magnetically coupled impeller rnixer are mounted inside the Pyrex cylinder to allow for rnercury-free operation. The bottorn 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, rnounted on the bottom end cap of the PVT cell, allows quick equilibration of the hydrocarbon fluid. The effective volurne of the cell is approxirnately 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. 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 3600. 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 (RTD) and displayed on a digital indicator with an accuracy of 0.20.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 (1820.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 a 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 1900.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 allows 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 30 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: ConocoPhillips Field: Exploration S hi b Well: Spark #4 Sand: JURASSIC C um eruer Installation: Doyon 19 Job #: 200400111 The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onset 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). 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-DBR 31 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 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 and at reservoir temperature into an atmospheric Gasometer, 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 the 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 achieves 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 corresponds 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, allows 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. WCP Oilphase-DBR 32 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumberger Multi-Stage Separation Test 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, allows 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 is then reduced to the first-stage separation test temperature allowing 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. · 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 a sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upward 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 compare very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock-Tank Oil (STO) 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. WCP Oilphase-DBR 33 Job #: 200400111 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: ConocoPhillips Spark #4 Doyon 19 Field: Sand: Job#: Exploration JURASSIC 200400111 Schlumbepgep 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 the UOP (Universal Oil Product) 46-64 procedure. The sulfur content of the STO is measured using the ASTM D 2494 procedure. All other STO analyses are measured according to industry standards. SAR(P)A Analysis A spinning band distillation is carried out on the original sample to establish two fractions. The initial boiling point to 300°C fraction is then analyzed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300°C fraction is 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 are added to precipitate the insoluble portion of the sample. The precipitate is filtered, dried and weighed. The solvent is removed from the soluble portion of the sample, which is referred to as the maltenes. The maltenes are then redissolved in pentane and are chromatographically separated into saturates, aromatics and resins (polars) fractions by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents are then removed from each fraction and the amount of material weighed. The data from the three methods are 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 {¡Itration 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 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 34 Job #: 200400111