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205-157
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6274' feet Surface, 2038', 3055', 3621', 4191', 4756', 5230', 5794' feet true vertical 3780' feet None feet Effective Depth measured 2200'feet None feet true vertical 1979' feet None feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 2133' MD 1935' TVD Packers and SSSV (type, measured and true vertical depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool- SUSPENDED 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 2373' 2078' Burst Collapse Production Liner Casing 2342' 110'Conductor Surface Intermediate 20" 10-3/4" 80' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-157 50-029-23283-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025630 Kuparuk River Field/ West Sak Oil Pool KRU 3J-101 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 110' ~~~ SUSPENDED ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A None Dusty Freeborn Dusty.Freeborn@conocophillips.com 907-659-7224Staff Well Integrity Engineer 12136-12166' 5939-5960' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:11 am, Sep 26, 2025 Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU= Well Integrity and Intervention, E=Dusty.Freeborn@ conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:22:06-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn J.Lau 11/5/25 RBDMS JSB 100225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 9, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit West Sak 3J-101 (PTD 205-157) Dear Commissioner Chmielowski: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit West Sak well 3J-101 (PTD 205-157). The following documents are attached: - 10-404 Sundry - Suspended Well Inspection - Wellbore Schematic - Location Plot Plan - Photographs The well is being held for future West Sak development. Please call me at (907) 265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU=Well Integrity and Intervention, E =Dusty.Freeborn@conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:23:16-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party isprohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/29/2025 InspectNo:susSTS250908142726 Well Pressures (psi): Date Inspected:9/6/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:12/17/2005 #305-379 Tubing:0 IA:0 OA: Operator:ConocoPhillips Alaska, Inc. Operator Rep:Matt Miller Date AOGCC Notified:9/3/2025 Type of Inspection:Subsequent Well Name:KUPARUK RIV U WSAK 3J-101 Permit Number:2051570 Wellhead Condition Well head shows normal corrosion for being out in the open. No signs of leaks, valves turned easily and wellhead was disconnected from any flowlines. Surrounding Surface Condition clean gravel, no subsidence Condition of Cellar 1 inch of mucky water in the bottom, no sheen, no trash Comments This is a monobore well. Wellhead is protected by a steel corral, Gauges were accurate and verified by calibrated digital gauge. Location was verified by plot map. Supervisor Comments Photos (4) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Wednesday, October 29, 2025 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/29/2025 InspectNo:susSTS250908142726 Well Pressures (psi): Date Inspected:9/6/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:12/17/2005 #305-379 Tubing:0 IA:0 OA: Operator:ConocoPhillips Alaska, Inc. Operator Rep:Matt Miller Date AOGCC Notified:9/3/2025 Type of Inspection:Subsequent Well Name:KUPARUK RIV U WSAK 3J-101 Permit Number:2051570 Wellhead Condition Well head shows normal corrosion for being out in the open. No signs of leaks, valves turned easily and wellhead was disconnected from any flowlines. Surrounding Surface Condition clean gravel, no subsidence Condition of Cellar 1 inch of mucky water in the bottom, no sheen, no trash Comments This is a monobore well. Wellhead is protected by a steel corral, Gauges were accurate and verified by calibrated digital gauge. Location was verified by plot map. Supervisor Comments Photos (4) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Wednesday, October 29, 2025 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): Casing Collapse Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Perforation Depth MD (ft): TVD BurstMDLength Size Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): approval: Notify Commission so that a representative may witness Sundry Number: BOP TestMechanical Integrity Test Location Clearanc e ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: COMMISSION USE ONLY Contact Name: Contact Email: Contact Phone: Date: e: certify that the foregoing is true and the procedure approved herein will not rom without prior written approval. gnature: me: Date for 15.W ell Status after proposed work: Operations:OILWINJ W DSPL Suspended proval:Date:GASWAGGSTOR SPLUG Representative:GINJ Op Shutdown Abandoned nts: Proposal Summary Wellbore schematic13.W ell Class after proposed work: ations Program BOP SketchExploratory Stratigraphic Development Service quest: Abandon Plug Perforations Fracture Stimulate Repair We Operations shutdownpair Well Suspend Perforate Other Stimulate Pull Tub Change Approved Programll Tubing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___er Casing ________________ __ ame:4.Current Well Class:5.Permit to Drill Number: Exploratory Development Stratigraphic Service 6.API Number: g:8.W ell Name and Number: ation or Conservation Order governs well spacing in this pool? perforations require a spacing exception?Yes No esignation (Lease Number):10.Field/Pool(s): D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): g Collapse SSSV Type:Packers and SSSV MD (ft) and TVD (ft): pth MD (ft): TVD BurstMDLengthSize Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY Tubing Grade:Tubing MD (ft): Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 205-157 50-029-23283-00 n/a KRU WSak 3J-101 ADL 25630 Kuparuk River Field/West Sak Oil Pool 6274 3780 2200 1979 2233, 2974 n/a Conductor 80 20" 110 110 Surface 2342 10-3/4" 2373 2078 n/a n/a 3-1/2"L-80 2133 n/a n/a 12/17/2005 Stephanie Pilch Well Integrity & Compliance Specialist Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-10-10 16:37:03 Foxit PhantomPDF Version: 10.0.0 Stephanie Pilch 10/10/20 Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907)440-6290 ✔Suspension Renewal ✔ ✔ ✔ ✔✔ ✔ By Samantha Carlisle at 6:12 pm, Oct 11, 2020 320-434 SFD 10/12/2020 DSR-10/12/2020 None 12/17/2005 SFD 10/12/2020 -00 X VTL 11/02/20 Comm. 11/3/2020 dts 11/3/2020 JLC 11/3/2020 RBDMS HEW 11/12/2020 ! "##$ %& %' ( )* " ( %+ ) ,-./ $) $ 0 / & -( 12, -103 4 '' ( '" ( %+ ) ,-./ $) $ 0( $2 2. 3(53 6 ) * *2.' )* '2 -'!& ).('2 ).( !2 ).(2 -14 ' ( !'' (2 - 6$#) 6'3 34 2 3 (- 1!37 ( ( -( 12 Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-10-10 16:37:22 Foxit PhantomPDF Version: 10.0.0 Stephanie Pilch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igitally signed by Sara Carlisle DN: OU=Drilling & Wells, O=ConocoPhillips Alaska, CN=Sara Carlisle, E=sara.e.carlisle@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-06-13 08:54:57 Foxit PhantomPDF Version: 9.7.0 Sara Carlisle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y Samantha Carlisle at 9:44 am, Jun 15, 2020 Digitally signed by Sara Carlisle DN: OU=Drilling & Wells, O=ConocoPhillips Alaska, CN=Sara Carlisle, E=sara.e.carlisle@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-06-13 08:54:57 Foxit PhantomPDF Version: 9.7.0 Sara Carlisle SFD 6/17/2020DSR-6/15/2020 RBDMS HEW 6/15/2020 -00 VTL 7/27/20 Suspended Well Inspection Review Report InspectNo: susBDB200518050730� Date Inspected: 5/16/2020 Inspector: Brian Bixby Type of Inspection: Subsequent Well Name: KUPARUK RIV U WSAK 31-101 Permit Number: 2051570 Suspension Approval: Sundry 305-379 " Suspension Date: 12/17/2005 Location Verified? W If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi) Tubing: 0 IA: 01 OA: Date AOGCC Notified: 4/27/2020 Operator: ConocoPhillips Alaska, Inc. Operator Rep: Roger Winter Wellbore Diagram Avail? ❑� Photos Taken? ❑� Fluid in Cellar? ❑ BPV Installed? ❑ VR Plug(s) Installed? ❑ Wellhead Condition The wellhead looked to be in good condition and all the valves worked properly and had gauges on them. Condition of Cellar Full of snow Surrounding Surface Condition No wellhouse. The surrounding area covered with snow. Comments Location verified by as -built pad map. Monobore Completion so there is no OA. Supervisor Comments Location should be clear of snow and ice before performing suspended well inspection. Photo (1). Friday, June 5, 2020 Suspended Well Inspection - KRU 3.1-101 PTD 2051570 Photo by AOGCC Inspector B. Bixby 5/16/2020 C0 oPhillips ",, WEN UM 3J -I31 WAW. 50-029-'725300-0: m ni�I 3v. tmlW 40,9 FML 4114' FF- Sa. 4.1124, Rif, A 2020-0516 Suspend_KRU 3J-101_bb.docx Page 1 of 1 STATE OF ALASKA AL,.AKA OIL AND GAS CONSERVATION COM....dSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate Alter Casing 9 r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Suspend Well Inspect 147 2.Operator Name: 4.Well Class Before Work 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 205-157 3 Address 6.API Number Stratigraphic r Service I- P. O. Box 100360,Anchorage,Alaska 99510 50-029-23283-00 7.Property Designation(Lease Number): 8 Well Name and Number ADL 25630 KRU West Sak 3J-101 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary. Total Depth measured 6274 feet Plugs(measured) CMT RETAINER-2233'-2743' CEMENT PLUG-2974'-6274' true vertical 3780 feet Junk(measured) None Effective Depth measured 2200 feet Packer(measured) NA true vertical 1979 feet (true vertical) NA Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 110 110 1530 520 SURFACE 2342 10 75 2372 2078 5210 2470 RECEIVED sCAMNIE ..ii_JL J. `E G 015 Perforation depth: Measured depth. None JUN 3 0 2015 True Vertical Depth: None A0G0C Tubing(size,grade,MD,and TVD) None Packers&SSSV(type,MD,and TVD) 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work. Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16 Well Status after work Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt NA Contact MI Loveland/Martin Walters Email N1878conocophillips.com Printed Name MJ Loveland Title WI Proj Supervisor Signaturei i /✓one 659-7043 Date 6/ 1-9 /e----- YTS 71905— c7114,-- RBDMSJ JUL - 1 2015 Form 10-404 Revised/01 201 Submit Original Only ✓ RECEIVED ConocoPhillips JUN 3 0 2015 Alaska P.O. BOX 100360 A G CC ANCHORAGE,ALASKA 99510-0360 June 29, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit West Sak 3J-101 (PTD 205-157) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit West Sak well 3J-101 (PTD 205-157). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well is being held for future West Sak development. Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor —Tree: (2)Vetco 4-118 x 5ksi valves 3J-101 Surface Location: Eslina;519,545 Tubing Hanger:Vetco,with 3- Norininga:6.002,897 '//',EUE 8rd box down. Pati Elt+vali6n: 44'AMSL Wellhead: Vetco M13228 Nordic Rig 3 Floor @ 30' Lower Bowl Elevation:74'AMSL Conductor:20"Cemented to 110'MD Fluid: Diesel in tubing and annulus 3'/3',9.3#,L80 EUE 8rd Mod Tubing @+/-2133'MD TD 13?/:"hole of 10-%",45.5#,L-B0 BTC Casing '.. Va. 2373'MD,2078'TVD Cement retainer set at approx.2283' :-•,r; ':, MD with enough cement pumped to fill • ''•' xi";7.C'-4 to 2473'MD and 50'dumped on top is i • • %^;:i;•: Cement Plug(s)across Fuld: Drilling mud x:??:?< hydrocarbon bearing zones from TD to 3B8 above Ugnu rail.*1-.9.0 ppg y:w;,,>;;:.'•:-•:-a:;:,i:#.. 13 West Fault Est.TOC[?a 29741.MD.Six 550'lifts. (4 TD 8-I12"hole a%;` i-`'' tc 6274'MD, 3,780'TVD ConocOPh1IIips 3J-'I 07 P&A sneel 1 or We ❑LSI Cl 12/9/2005 29/modified 0 Alaska g �2�?o05a5 • m Q Vii Z �.— 11 sr JZWo iFliQmQO O K a 0 Z Q epi ci_ I I a o Lal Q\ M J a tlti in in — —i— \ o 00+9L N + -{- -- -f- I o ) V) Lo Zi ) o � Q 1 LJ o ._T_,. w M J O z O J W V o0 0 0 Q 381 C Ln OO+NL N ±+ 4 .�N 0 LILY,, cy ° -T _is,,, U o II --+-�p{8{< z z I ---„Qg0 1 itei 1 I!= O +--L-38f N 01 i-, ,-,T.., .„,...,,,0 f*-1,I– 1111 ___0_24).0 ro LLJ 0 N• Co+00 N 59 -+- LO I I W wi d v- T -� o `.....p...1. ,\,.... 4.11-r -----t--itetWr'r f- z O W U III .. — � I I o - Q� Ng N O JJ n lisp .......�—. - - '^ z O a. – 8 '° o o 00+ZZ N + LiLTL--._—,,.-0 El t0 ± \\ T d1 % o' �1 0 3 8 n . I C U N _ o cc1coO. M g g I 1 T i Z m I CI m w w w o a 0 3 rn v si � E. il ffi E 0. o W • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT WSAK 3J-101 Field/Pool: KUPARUK RIVER/WEST SAK Permit#(PTD): 205-157 Sundry 305-379 API Number: 50-029-23283-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 12/17/2005 Surface Location: 1205' FSL, 565' FWL Section: 3 Township: 12N Range: 9E Nearest active pad or road: KRU DS3J Meridian: UMIAT Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: good Pad or location surface: good Location cleanup needed: none Pits condition: backfilled Surrounding area condition: good Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: NA Samples taken: NA Access road condition: Good Photographs taken (#and description): 3 photos of well and area around well Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: good Cellar description, condition, fluids: good Rat Hole: na Wellhouse or protective barriers: yes Well identification sign: yes Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: IA- 0 PSI Wellhead Photos taken (#and description): 3 of well and area Work Required: none Operator Rep (name and signature): Perry Greenwood AOGCC Inspector: Johnnie Hill Other Observers: MJ Loveland Inspection Date: 6/27/2015 AOGCC Notice Date: 6/25/2015 Time of arrival: 1330 Time of Departure: 1335 Site access method: Truck • y.'�.. 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LAT I LONG Onshore/Offshore: Onshore Suspension Date: 12/17/05 • Date AOGCC Notified: 06/25/15 - Sundry No.: 305-379 Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 " OA 0 SCONED AUG 1 9 2015 Condition of Wellhead: good and clean-no well house Condition of Surrounding Surface Location: good clean gravel/celler little water - Follow Up Actions Needed: none Comments: none Attachments: Photos(2) REVIEWED BY: Insp.Supry 31 - 7/Z4Jr Comm PLB 06/2014 2015-0627_Suspend_KRU_3J-101jh.xlsx ir tit i r r 7E is f yya � • f • •.' < I . AO E; la .., 1 -._ -., i 2 i s# 1 1 ' fS. ee :.. •, .1 ( . M. <. cr:• Ir � 1 '' i M •—, ' li I ' . , • 0 0 I.—; O 4-. . . ' • • ti _Cu _ Uo • 0N `�' N V:::! o O VI Q O r CA• O• � a 205- Schiumberger Analysis of MDT Fluid Samples ConocoPhillips Field:West Sak Well:3J-101 Black Oil PVT Study Report Prepared for Dennis Wegener ConocoPhillips Standard Conditions Used: Pressure: 14.696 psia Temperature:60°F SCANNED UIQ 4��3 4 "201;:"201;: Prepared by:Stefan Smuk Schlumberger Oilphase-DBR 16115 Park Row,Suite 150 Houston,Texas,77084 +1 281 285 6370 Date:08/25/2006 Report#200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job 11: 200500215 Table of Contents List of Figures 2 List of Tables 3 EXECUTIVE SUMMARY 4 Objective 4 Introduction 4 Scope of Work 4 Results 4 PVT Summary-Sample RSS 11.01+1.02);Cylinder CSI 4832-1A;Depth 5697!IMO,B Sand 5 PVT Summary-Sample RSS(1.11+1.12+1.13);Cylinder CSB 4881-IA;Depth 5553 ft MD,D Sand 5 Sequence of Events 7 Chain of Sample Custody 7 RESULTS AND DISCUSSIONS 8 Fluids Preparation and Analysis 8 Reservoir Fluid Analysis 8 PVT Analysis on Sample RSS(1.01+1.02);Cylinder CSB 9832-1A;Depth 5697 ft MD,B Sand 47 Constant Composition Expansion at Tres 47 Reservoir Oil Viscosity at Tres 49 Multi-Stage Separation Test 51 PVT Analysis on Sample RSS(1.11+1.12+1.13);Cylinder CSB 4881-IA;Depth 5553 ft.MD,D Sand 61 Constant Composition Expansion at 100'F 61 Reservoir Oil Viscosity at Tres 63 Multi-Stage Separation Test 65 Appendix A:Nomenclature and Definitions 69 Appendix B:Molecular Weights and Densities Used 70 Appendix C:EQUIPMENT 71 Fluid Preparation and Validation 71 Fluid Volumetric(PVT)and Viscosity Equipment 71 Appendix D:PROCEDURE 74 Fluids Preparation and Validation 74 Constant Composition Expansion Procedure 74 Differential Vaporization Procedure 74 Multi-Stage Separation Test 74 Liquid Phase Viscosity and DensityMeasurements During DV Step 75 Stock-Tank Oil1STO)Viscosity and Density Measurements 75 Asphaltene,Wax and Sulfur Content Measurements 75 SAR(P)A Analysis 76 High-Temperature High Pressure Filtration Test 76 011phase-DBR 2 Fila 200500215 r Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job If: 200500215 List of Figures Figure 1:Stock Tank Oil Chromatogram(Sample 1.04) 16 Figure 2:k-Plot for Equilibrium Check(Sample 1.04) 16 Figure 3:Stock Tank Oil Chromatogram(Sample 1.08) 19 Figure 4:k-Plot for Equilibrium Check(Sample 1.08) 19 Figure 5:Stock Iank Oil Chromatogram(Sample 1.09) 22 Figure 6:k-Plot for Equilibrium Check(Sample 1.09) 22 Figure 7:Stock Tank Oil Chromatogram(Sample 1.10) 25 Figure 8:k-Plot for Equilibrium Check(Sample 1.10) 25 Figure 9:Stock Tank Oil Chromatogram(Sample 114) 28 Figure 10:k-Plot for Equilibrium Check(Sample 1.14) 28 Figure 11:Stock Tank Oil Chromatogram(Sample 1.18) 31 Figure 12:k-Plot for Equilibrium Check(Sample 1.18) 31 Figure 13:Stock Tank Oil Chromatogram(Sample 1.19) 34 Figure 14:k-Plot for Equilibrium Check(Sample 1.19) 34 Figure 15:Stock Tank Oil Chromatogram(Sample 1.20) 37 Figure 16:k-Plot for Equilibrium Check(Sample 120) 37 Figure 17:Stock Tank Oil Chromatogram(Sample 1.01&1.02) 40 Figure 18:k-Plot for Equilibrium Check(Sample 1.01&1.02) 40 Figure 19:De-emulsifier Oil Chromatogram 41 Figure 20:Stock Tank Oil Chromatogram(Sample 1.01&1.02) 44 Figure 21:k-Plot for Equilibrium Check(Sample 1.01&1.02) 44 Figure 22:Constant Composition Expansion at 70.0°F-Relative Volume 48 Figure 23:Reservoir Fluid Viscosity 70°F 50 Figure 24:Stock Tank Oil Chromatogram(Sample 1.11,1.12&1.13) 57 Figure 25:k-Plot for Equilibrium Check(Sample 1.11,1.12&1.13) 57 Figure 26:Constant Composition Expansion at 100°F-Relative Volume 62 Figure 27:Reservoir Fluid Viscosity 69°F 64 011phase-DBR 3 File 200500215 i r Client: ConocoPhillips Field: WestSak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job#: 200500215 List of Tables Table 1:Well and Sample Identification 10 Table 2:Well Position Data 10 Table 3:Sampling.and.Transfer Summary 11 Table 4:Reservoir.Fluid.Properties. 12 Table 5:Stock-Tank Oil Properties 13 Table 6:C30+Composition,GOR,'API,by Zero-Flash(Sample 1.04) 14 Table 7:Calculated Fluid Properties 15 Table 8:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.08) 17 Table 9:Calculated Fluid Properties 18 Table 10:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.09) 20 Table 11:Calculated Fluid Properties 21 Table 12:C30+Composition,GOA,°API,by Zero-Flash(Sample 1.10) 23 Table 13:Calculated Fluid Properties 24 Table 14:C30+Composition,GOR,'API.by Zero-Flash(Sample 1.14) 26 Table 15:Calculated Fluid Properties 27 Table 16:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.18) 29 Table 17:Calculated Fluid Properties 30 Table 18:C30+Composition,GOB,°API,by Zero-Flash(Sample 1.19) 32 Table 19:Calculated Fluid Properties 33 Table 20:C30+Composition,GOA,°API,by Zero-Flash(Sample 1.20) 35 Table 21:Calculated Fluid Properties 36 Table 22:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.01&1.02) 38 Table 23:Calculated Fluid Properties 39 Table 24:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.01&1.02) 42 Table 25:Calculated Fluid Properties 43 Table 26:Composition of Synthetic Recombination Gas for Sample(1.01&1.02) 45 Table 27:Summary of Results of Sample ASS(1.01+1.02) 46 Table 28:Constant Composition Expansion at 70.0'F(Sample 1.01&1.02 RSS) 47 Table 29:Reservoir Fluid Viscosity 70'F 49 Table 30:Multi-Stage Separation Test Vapor&Liquid Properties 52 Table 31:Multi-Stage Separator Test Vapor Composition(mol%) 53 Table 32:Multi-Stage Separator Test Residual Liquid Composition(mal%) 54 Table 33:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.11,1.12&1.13) 55 Table 34:Calculated Fluid Properties 56 Table 35:C12+Composition of Synthetic Recombination Gas for Sample(1.11,1.12&1.13) 58 Table 36:Summary of Results of Sample ASS(1.11+1.12+1.13) 59 Table 37:Constant Composition Expansion at 100'F(Sample RSS 1.11+1.12+1.13) 60 Table 38:Simulated Constant Composition Expansion at 69°F(Sample RSS 1.11+1.12+1.13) 61 Table 39:Reservoir Fluid Viscosity 69°F 63 Table 40:Multi-Stage Separation Test Vapor&Liquid Properties 66 Table 41:Multi-Stage Separator Test Vapor Composition(moi%) 67 Table 42:Multi-Stage Separator Test Residual Liquid Composition(mal%) 68 011phase-DBR 4 Fila 200500215 i r Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job#: 200500215 EXECUTIVE SUMMARY Objective To evaluate the composition and phase behavior of bottomhole fluid samples collected during modular formation dynamics testing(MDT). Introduction At the request of ConocoPhillips, Oilphase-DBR conducted a fluid analysis study of bottomhole reservoir-fluid samples collected during the modular formation dynamics testing(MDT)of Well 3J-101 drilled in the field West Sak. Scope of Work • Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for one • Heat the samples for another day without rocking in vertical position. • Conduct preliminary evaluation on bottomhole hydrocarbon samples, including single-stage flash Gas- Oil Ratio(GOR),reservoir fluid composition,stock-tank oil(STO)and monophasic fluid properties. • Reconstitute representative formation-fluid blends using demulsification and recombination with synthetic gas,for each sampled depth. For each of the two recombined samples: • Conduct a Constant Composition Expansion(CCE)test at the reservoir temperature. • Conduct a multi-stage separation test at the specified conditions. • Conduct viscosity measurements of the oil at the reservoir temperature. Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon-fluid samples: • Eight bottomhole samples were used for validation purposes.They were homogenized at the reservoir conditions for one day and were settled in a vertical position,under heating,heated for one additional day. • The 'zero flash' GOR was determined to be from 75 - 158 SCF/STB, and the STO density to be from 0.950-0.968 g/cc. • To account for apparent undersaturation of the sampled fluids, two sets of samples (1.01 and 1.02, 5697' MD and 1.11 + 1.12 + 1.13, 5553' MD) were blended and recombined with synthetic gas mixtures,after demulsification. This process was intended to create test-fluid samples that would be representative of the native formation-fluid. The synthetic-gas compositions were determined using an equation-of-state model to predict the composition of gas that would have been evolved and separated from the sample during sampling,given an assumed saturation pressure. • The two sets of recombined samples(1.01 and 1.02,5697' MD and 1.11 +1.12+1.13,5553' MD)each underwent PVT analysis The measured PVT Data are summarized in the tables following. 011phase-DBR 5 File 200500215 , T Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job IM 200500215 EXECUTIVE SUMMARY(CONTINUED) PVT Summary-Sample RSS(1.01+1.02);Cylinder CSB 4832-IA;Depth 5697 It MD,B Sand FLASHING CUMULATIVE API Gas Relative FVF FVF OPERATION GOR(scf/stb) GRAVITY Density(air=1) at Pres/Tres at Psat/Tres Zero Flash 158 16.9 0 584 1 033 1 035 DL Flash @ Tres - - - - - SeparatorTest 150 17.1 0.571 1 039 1.041 PVT Summary-Sample RSS(1.11+1.12+1.13);Cylinder CSB 4881-IA;Depth 5553 It MD,D Sand FLASHING CUMULATIVE API Gas Relative FVF FVF OPERATION GOR(scf/stb) GRAVITY Density(air=1) at Pres/Tres at Psat/100°F Zero Flash 156 16 2 0 582 - 1 068 DL Flash CO Tres - - - - - Separator Test 156 16 3 0.572 - 1 063 011phasa-0136 6 Fila 200500215 I T I Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job# 200500215 Quality Assurance Process Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottom hole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry This objective requires persistent innovation and ongoing development of state-of-the-art technologies and equipment A rigorous quality assurance program,continuous employee training and enforcement of strict safety standards maintain our compliance with Quality,Health, Safety and Environment IOHSE)requirements Proactive integration of OHSE objectives and management goals at every level supports the communication and implementation of OHSE policies and standards Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures Details of these programs are available upon request The lab-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results a) Establish quality of measurement during data generation b) Establish quality of processed data as per checklist during data processing by Data Quality Engineer cl Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency d) The responsible Project Engineer confirms consistency of reported data e) Engineering Project Manager review the results/report for overall consistency Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established Quality checklists designed for each operation and based on the level of complexity All property measurements and calculation procedures are maintained in company archives for a period of 1 year This information is available for review by clients upon request The file and laboratory records information are listed below to provide access reference to all records related to this project For any questions,please do not hesitate to contact the undersigned Project Engineer File No.:200500215 Laboratory Records:200500215 Data Quality Data Reporting Suyu Ye Stefan Smuk Data Quality Engineer Fluids Analysis Support Engineer Overall Report Quality Clay Young Oilphase-DBR Operation Manager,NGC 011phase-DBR 7 File 200500215 \ T Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job#: 200500215 Sequence of Events 12/21/05 Samples arrived and client was updated. 01/03/06 Project work scope discussed. 01/04/06 Work agreement approved. 01/04/06 Prelim PVT tests request for eight samples issued. 01/10/06 STO density and water content results sent via e-mail. 01/20/06 Sample PVT prelim results sent via e-mail. 08/25/06 Final PVT report issued to client. Chain of Sample Custody The samples collected from the well 3J-101 were sent to Oilphase-DBR in Houston,Texas. The samples were used to preliminary measurements and subsequent PVT studies. The measurement details are in the following text. Samples remaining after measurements are stored in Oilphase-DBR storage unless otherwise instructed. 011phase-DBR a Me 200500215 t r Client: ConocoPhiltips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job it: 200500215 RESULTS AND DISCUSSIONS Fluids Preparation and Analysis Eight bottomhole samples collected during MDT operations were transferred to Oilphase-DBR The well and formation data,with the respective reservoir conditions of the bottomhole samples,are summarized in Table 1 Quality checks of the bottomhole samples were conducted,and the results are summarized in Table 2 After one day of homogenization,sample validation testing was conducted to evaluate the validity of the samples Based on the preliminary results, representative samples 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 phases recovered from single-stage flashing were subjected to chromatography and their compositions were determined These compositions were recombined mathematically according to the single-stage flash Gas-Oil Ratio(GOR)to calculate the reservoir fluid composition The reservoir fluid analysis is summarized in Table 5,7,9,11,13,15,17 and 19 The molecular weight of the stock-tank oil(STO)was measured Other properties such as the plus fraction properties and heat content for the flash gas were calculated from the compositions and are listed in Table 6,8,10,12,14,16,18 and 20. In order to capture enough sample for the de-emulsification and the testing,samples 1 01 through 1.03 and 1 11 through 1 13 were selected to undergo free-water and sediment checks 60 cc water was recovered from sample 1.01, 70 cc water from 1.02,350 cc mud for sample 1 03, 50 cc water from 1.11,50 cc water from 1.12,and 50 cc water from 1 13 Thus,it was decided to transfer 250 cc oil from each of 1.01 and 1.02 to a new cylinder for de-emulsification Approximately 200 cc of oil from each of 1 11,1.12 and 1.13 were transferred to a single cylinder for de-emulsification After the de-emulsification,75 cc water was recovered from the mixed sample(1.11,1.12,1.13)and 30 cc water from the mixed sample (1 01,1 02). Both blends were then flashed to obtain GOR,API and compositional data The reservoir fluid analyses are summarized in Tables 21 and 26 Other properties,such as the plus-fraction properties and heat contents of flashed gases,were calculated from the compositions and are listed in Tables 22 and 27 The blended sample(1.01, 1 02)showed slight contamination from the demulsifier(Figure 20), indicating a slight surplus of injection The de-emulsifier free composition appears in Table 23 Per client instruction,another 400 cc sample(200 cc each from 1 01 and 1 02)was transferred to a new cylinder,CSB 4832-IA,for a secondary demulsification using a lower additive ratio 10 cc of free water was subsequently recovered from bottom of the cylinder, while close to zero BS&W was observed in the supernatant oil Compositional analysis showed no contamination from the demulsifier A saturation-point check of the blended sample(1 11, 1 12, 1.13)was conducted at room temperature,revealing a bubble point of 440 psia This was consistent with the available reservoir-pressure and drawdown data An equation-of-state simulation was conducted to determine an appropriate synthetic-gas composition for recombination to the desired saturation point of approximately 1400 psia In this process,a differential liberation at reservoir temperature was simulated,and the'first-step"gas composition was inferred to represent the approximate composition of the gas that had been depleted from the sampled oil during acquisition This gas was synthesized and physical recombination was carried out Sample(1.01,1 02)was also recombined with a synthetic gas. The planning and execution of the(1 01,1.02)recombination was analogous to that done for sample(1.11,1 12,1 13). 011phass-DBR 9 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job#: 200500215 After recombination and analysis of sample(1 11,1 12,1 13),it was discovered that the sample appeared to have excess solution gas It was inferred that stabilization had not occurred in the experimental system, due to severe density and viscosity conditions at the reservoir temperature of 69°F It was decided to re-stabilise the fluid at 100°F and 1600 psia,which was predicted to be equivalent to a bubble point of 1450 psia at 69°F,and push off the excess gas. The elevated temperature was chosen to in order to ensure that good- quality phase behavior data would be acquired for modelling purposes. The CCE and the first stage of the separator test were conducted at 100°F, the reported saturation point and property data reflect properties measured at 100°F The first-stage properties of the separator test also reflect 100°F data. A simulation is provided,based on a tuned equation-of-state model,for a CCE experiment at the actual reservoir temperature of 69°F The viscosity data for the 0 Sand,measured at actual reservoir temperature(69°F),are considered to be unusually high for the fluid type However,the values were confirmed through duplicate testing,and are considered to be analytically valid 011phase-DBR 10 File 200500215 I Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job*: 200500215 Table 1:Well and Sample Identification Client: ConocoPhillips Job* 200500215 Field: West Sak Well: 3J-101 Sample ID Chamber* Zone Sampling Date Opening Pres. Reservoir Conditions in the field Pressure Temperature Depth (psia/°F) (psia) (°F) (ft) 1 04 MRSC 226 B Sand 12/11/05 4,615/66 1,505 70 5697 1 08 MPSR 1399 B Sand 12/11/05 4,515/66 1,505 70 5697 1 09 SPMC 254 B Sand 12/11/05 5,015/66 1,505 70 5697 1 10 SPMC 001 B Sand 12/11/05 5,515/66 1,505 70 5697 1 14 MRSC 297 D Sand 12/11/05 4,515/66 1,465 69 5553 1 18 MPSR 1398 D Sand 12/11/05 4,515/66 1,465 69 5553 1 19 SPMC 034 D Sand 12/11/05 5,515/66 1,465 69 5553 1 20 SPMC 162 D Sand 12/11/05 5,415/66 1,465 69 5553 Table 2:Well Position Data Well Name Strat Name Latitude Longitude X Loc Y Loc 3J-101 SURFACE 70 418759950 -149.843912902 165957711 6002638 65 3J-101 WEST SAK D 70 418255274 -149 823901590 1662034.38 6002460 53 3J-101 WEST SAK B 70 418149411 -149 821817091 1662290.13 6002423.35 3J-101 WEST SAK A3 70 417917933 -149 811758736 1663524.57 6002342 27 3J-101 WEST SAK A2 70 417917349 -149 811196663 1663594.18 6002342.22 3J-101 WEST SAK D 70 417938810 -149 813452924 1663316.95 6002348.85 3J-101 WEST SAK B 70 417926949 -149 812548820 1663428 05 6002344.74 011phase-DBR 11 File 200500215 r Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job#: 200500215 Table 3:Sampling and Transfer Summary Opening Transfer Closing Opening Water Transferred Sample ID Chamber# conditions Cylinder conditions conditions Content Sample in the field ID in the field in the Lab from Top Volume i (psia/°F) (psia/°F) (psia/°F) (wt%) (cc) 1.04 MRSC 226 4,615/66 CSB 8629-QA 115/66 315/71 1 98 600 1 08 MPSR 1399 4,515/66 CSB 14309-QA 115/66 660/71 3.56 410 1.09 SPMC 254 5,015/66 SSB 18528-QA 6,015/66 6215/71 5 25 240 1.10 SPMC 001 5,515/66 SSB 18136-0A 6,015/66 6132/71 1 48 240 1.14 MRSC 297 4,515/66 CSB 14308-0A 115/66 289/71 1.19 600 1.18 MPSR 1398 4,515/66 CSB 14311-QA 115/66 568/71 6.23 410 1 19 SPMC 034 5,515/66 SSB 18539-0A 6,015/66 6215/71 8 73 240 1.20 SPMC 162 5,415/66 SSB 18530-QA 6,015/66 6015/71 6.24 240 1 01 &1.02 Multiple - CSB 4854-IA - - Nil 500 1.01 &1 02 Multiple - CSB 4832-IA Nil 400 1 11,1 12&1 13 Multiple - CSB 4881-IA - - Nil 600 1 011phase-DBR 12 File 200500215 1 1 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job#: 200500215 Table 4:Reservoir Fluid Properties Zero Flash Saturation Molar Mass of Monophasic Sample ID Cylinder# Depth GOR* Bo** Pressure monophasic fluid*** at Tres fluid contamination (ft) (scf/stb) (psia) %(w/w) 1 04 CSB 8629-QA 5,697 88 325 9 - 1 08 CSB 14309-GA 5,697 95 318 5 - 1.09 SSB 18528-QA 5,697 83 336.5 - 1 10 SSB 18136-QA 5,697 92 320.9 - 1.14 CSB 14308-GA 5,553 87 326.5 - 1 18 CSB 14311-QA 5,553 76 3464 - 1.19 SSB 18539-QA 5,553 76 350.2 - 1 20 SSB 18530-GA 5,553 75 344.3 - 1.01 &1 02 CSB 4854-IA 5,697 91 320.1 1 7 1.01 &1 02 CSB 4832-IA 5,697 158 1.035 1304 263 7 - 1 11,1 12&1 13 CSB 4881-IA 5,553 156 1.041 t 1574# 275.3 - * Flashed gas volume lscf)per barrel of stock tank liquid©60°F ** Volume of live oil at bubble point pressure,per unit equivalent volume of flashed stock tank liquid CO 60°F *** Refers to contamination by demulsifier Calculated from contamination level in STO determined from compositional analysis t Based on predicted saturation pressure at reservoir temperature t Bubble point at measurement temperature at 100°F Pb at 72°F,prior to recombination with synthetic gas,was 440 psia 011phase-DBR 13 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B&D Schlumberger Installation: - Job#: 200500215 Table 5:Stock-Tank Oil Properties STO Properties Sample ID Cylinder# Depth Molar Mass Density API' Contamination (ft) (9/cc) %(w/w) 1 04 CSB 8629-QA 5,697 414.2 0 9548 16.7 - 1 08 CSB 14309-QA 5,697 411 1 0 9585 16.1 - 1 09 SSB 18528-QA 5,697 424 9 0 9599 15.9 - 1 1.10 SSB 18136-QA 5,697 412 6 0.9513 17 2 - 1.14 CSB 14308-QA 5,553 413.5 0 9594 16 0 - 1.18 CSB 14311-0A 5,553 430.4 0 9622 15 6 - 1 19 SSB 18539-0A 5,553 436 0 0 9682 14.6 - 1 20 SSB 18530-QA 5,553 425 6 0 9645 15.2 - 1 01 &1 02 CSB 4854-IA 5,697 409 6 0.9515 17.2 1 7 1 01 &1 02 CSB 4832-IA 5,697 392.6 0.9503 17.4 - 1.11,1.12&1 13 CSB 4881-IA 5,553 402 5 0 9581 16 2 - • API=141 5/Density-131 5 011phese-DBR 14 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 6:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.04) Sample 1.04;Cylinder CSB 8629-QA;Depth 5697.1 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 7.08 2.82 0.00 0.00 0.08 0.63 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.89 1.18 0.00 0.00 0.02 0.26 Methane 16.04 86.44 94.35 0.00 0.00 1.03 21.00 Ethane 30.07 1.06 0.62 0.00 0.00 0.01 0.14 Propane 44.10 0.91 0.36 0.01 0.13 0.02 0.18 I-Butane 58.12 0.81 0.24 0.02 0.11 0.02 0.14 N-Butane 58.12 0.45 0.14 0.01 0.08 0.02 0.09 I-Pentane 72.15 0.58 0.14 0.04 0.20 0.04 0.19 N-Pentane 72.15 0.12 0.03 0.01 0.04 0.01 0.04 C6 84.00 0.28 0.06 0.08 0.38 0.08 0.31 M-C-Pentane 84.16 0.03 0.01 0.00 0.02 0.00 0.02 Benzene 78.11 0.01 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.01 0.00 0.00 0.02 0.00 0.02 C7 96.00 0.11 0.02 0.15 0.63 0.15 0.50 M-C-Hexane 98.19 0.03 0.01 0.00 0.02 0.00 0.02 Toluene 92.14 0.02 0.00 0.00 0.01 0.00 0.01 C8 107.00 0.09 0.01 0.15 0.56 0.15 0.44 E-Benzene 106.17 0.01 0.00 0.00 0.02 0.00 0.01 M/P-Xylene 106.17 0.01 0.00 0.00 0.01 0.00 0.00 O-Xylene 106.17 0.00 0.00 0.00 0.02 0.00 0.01 C9 121.00 0.06 0.01 0.30 1.01 0.29 0.79 010 134.00 0.04 0.01 0.56 1.74 0.56 1.36 C11 147.00 0.01 0.00 0.92 2.60 0.91 2.02 C12 161.00 0.00 0.00 1.39 3.57 1.37 2.78 C13 175.00 0.00 0.00 1.92 4.54 1.90 3.53 C14 190.00 0.00 0.00 2.23 4.86 2.20 3.78 C15 206.00 0.00 0.00 2.62 5.27 2.59 4.10 C16 222.00 2.55 4.75 2.51 3.69 C17 237.00 2.64 4.62 2.61 3.59 C18 251.00 2.75 4.53 2.71 3.52 C19 263.00 2.68 4.22 2.65 3.28 C20 275.00 2.58 3.88 2.55 3.02 C21 291.00 2.61 3.71 2.58 2.88 C22 300.00 2.42 3.34 2.39 2.60 C23 312.00 2.25 2.99 2.23 2.33 C24 324.00 2.05 2.62 2.02 2.04 C25 337.00 1.93 2.37 1.91 1.84 C26 349.00 1.86 2.21 1.84 1.71 C27 360.00 1.90 2.18 1.88 1.70 C28 372.00 1.85 2.06 1.83 1.60 C29 382.00 1.68 1.82 1.66 1.42 C30 394.00 1.73 1.82 1.71 1.42 031 404.00 1.53 1.57 1.52 1.22 C32 415.00 1.44 1.44 1.42 1.12 C33 426.00 1.26 1.23 1.25 0.95 C34 437.00 1.24 1.17 1.22 0.91 C35 445.00 0.89 0.83 0.88 0.65 C36+ 992.00 49.74 20.77 49.15 16.15 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.51 414.20 325.92 MOLE RATIO 0.2225 0.7775 011phase-DBR 15 File 200500215 1 Y Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 7:Calculated Fluid Properties Sample 1.04;Cylinder CSB 8629-QA; Depth 5697.1 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.40 0.07 99.84 99.06 98.65 77.03 C12+ 0.00 0.00 97.74 92.39 96.57 71.83 C20+ - - 78.97 56.02 78.02 43.55 C30+ - - 57.84 28.83 57.15 22.41 - C36+ - - 49.74 20.77 49.15 16.15 Molar Mass C7+ 103.85 417.45 417.39 C12+ 166.86 438.18 438.18 _ C20+ - 583.84 583.84 C30+ - 830.99 830.99 C36+ - 992.00 992.00 Density C7+ - 0.9556 - C 12+ - 0.9604 0.9604 C20+ - 0.9945 0.9945 C30+ 1.0421 1.0421 C36+ 1.0659 1.0659 Fluid at 60°F 0.9548 Gas Gravity(Air=1) 0.605 Dry Gross Heat Content(BTU/scf) 1,001 Wet Gross Heat Content(BTU/scf 983 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 414.20 414.20 992.00 Density(g/cm3) 0.9548 - 1.0659 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 88 - STO Density(g/cm3) 0.9548 - STO API Gravity 16.7 - OBM Density(g/cm3)©60°F - 011phase-DBR 16 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Figure 1:Stock Tank Oil Chromatogram(Sample 1.04) Sample 1.04;Cylinder CSB 8629-QA, Depth 5697.1 ft.MD 'I21 A,(E'l1PCHEl1 ATA100500215\CY:i29 C;) Norm 250 JOB 200500215 CONOCO PHILIPS 1.04 CSB 8629-QA RF FLASH CYLINDER 200 150- 100- of t`m od) W NNNryNNNITIM N U U U 0 UUUUJ • Uc0o m }4 UUU CCccccccCCCCCCCCCCC .4; u>, Uc wW11110111111 +Q ( 11y 11111 1 11111T177777- , • 0 5 10 15 20 25 30 35 mm Figure 2:k-Plot for Equilibrium Check(Sample 1.04) Sample 1.04;Cylinder CSB 8629-QA;Depth 5697.1 ft.MD 2 1.5 •ntdC1 •C3 1 •eqg 5 0.5 •C6 -a - 0 3 •C8 •C7 -0.5 •C9 -1 •C10 -1.5 -2 -4 -3 -2 -1 0 1 2 3 F 011phase-DBR 17 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger j Table 8:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.08) Sample 1.08;Cylinder CSB 14309-QA;Depth 5697.1 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1.62 0.62 0.00 0.00 0.02 0.15 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.34 0.81 0.00 0.00 0.02 0.19 Methane 16.04 91.58 96.72 0.00 0.00 1.14 22.72 Ethane 30.07 1.12 0.63 0.00 0.00 0.01 0.15 Propane 44.10 1.05 0.40 0.01 0.09 0.02 0.16 I-Butane 58.12 1.00 0.29 0.01 0.09 0.02 0.13 N-Butane 58.12 0.55 0.16 0.01 0.07 0.02 0.09 I-Pentane 72.15 0.71 0.17 0.04 0.20 0.04 0.19 N-Pentane 72.15 0.16 0.04 0.01 0.04 0.01 0.04 C6 84.00 0.35 0.07 0.06 0.31 0.07 0.26 M-C-Pentane 84.16 0.04 0.01 0.00 0.02 0.00 0.01 Benzene 78.11 0.01 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.01 0.00 0.00 0.02 0.00 0.02 C7 96.00 0.16 0.03 0.12 0.52 0.12 0.40 M-C-Hexane 98.19 0.03 0.01 0.01 0.02 0.01 0.02 Toluene 92.14 0.03 0.01 0.00 0.01 0.00 0.01 C8 107.00 0.12 0.02 0.18 0.69 0.18 0.53 E-Benzene 106.17 0.01 0.00 0.01 0.02 0.01 0.02 M/P-Xylene 106.17 0.01 0.00 0.00 0.02 0.00 0.01 O-Xylene 106.17 0.00 0.00 0.01 0.02 0.01 0.02 C9 121.00 0.06 0.01 0.31 1.04 0.30 0.80 C10 134.00 0.05 0.01 0.59 1.81 0.58 1.38 C11 147.00 0.01 0.00 0.95 2.65 0.93 2.02 C12 161.00 0.00 0.00 1.41 3.59 1.39 2.75 C13 175.00 0.00 0.00 1.93 4.52 1.90 3.46 C14 190.00 0.00 0.00 2.16 4.68 2.14 3.58 C15 206.00 0.00 0.00 2.68 5.35 2.65 4.10 C16 222.00 2.58 4.78 2.55 3.66 C17 237.00 2.71 4.70 2.68 3.60 C18 251.00 2.65 4.35 2.62 3.33 C19 263.00 2.67 4.17 2.64 3.19 C20 275.00 2.58 3.85 2.55 2.95 C21 291.00 2.50 3.53 2.47 2.70 C22 300.00 2.40 3.28 2.37 2.51 C23 312.00 2.16 2.84 2.13 2.18 C24 324.00 2.19 2.78 2.16 2.13 j C25 337.00 2.04 2.49 2.02 1.91 C26 349.00 2.05 2.41 2.02 1.84 C27 360.00 1.99 2.27 1.96 1.74 C28 372.00 1.79 1.98 1.77 1.51 C29 382.00 1.77 1.91 1.75 1.46 C30 394.00 1.72 1.80 1.70 1.38 C31 404.00 1.63 1.65 1.61 1.27 C32 415.00 1.44 1.43 1.42 1.09 C33 426.00 1.29 1.24 1.27 0.95 C34 437.00 1.24 1.16 1.22 0.89 C35 445.00 1.09 1.01 1.08 0.77 C36+ 980.00 49.02 20.56 48.41 15.73 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.94 411.11 318.50 MOLE RATIO 0.2349 0.7651 011phase-DBR 18 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 9:Calculated Fluid Properties Sample 1.08;Cylinder CSB 14309-QA; Depth 5697.1 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole C7+ 0.53 0.09 99.86 99.20 98.62 75.92 C12+ 0.00 0.00 97.69 92.37 96.47 70.67 C20+ - - 78.89 56.21 77.91 43.01 C30+ - - 57.43 28.86 56.71 22.08 C36+ - - 49.02 20.56 48.41 15.73 Molar Mass C7+ 102.91 413.84 413.75 C12+ 165.02 434.80 434.80 C20+ - 576.99 576.99 C30+ - 818.03 818.03 C36+ - 980.00 980.00 Density C7+ - 0.9592 - C12+ - _ 0.9643 0.9643 C20+ - 0.9997 0.9997 C30+ 1.0510 1.0510 C36+ 1.0780 1.0780 Fluid at 60°F 0.9585 Gas Gravity(Air=1) 0.585 Dry Gross Heat Content(BTU/scf) 1,031 _ Wet Gross Heat Content(BTU/scf 1,013 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 411.11 411.11 980.00 Density(g/cm3) 0.9585 - 1.0780 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 95 - STO Density(g/cm3) 0.9585 - STO API Gravity 16.1 - OBM Density(g/cm3)@60°F - 011phase-DBR 19 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Figure 3:Stock Tank Oil Chromatogram(Sample 1.08) Sample 1.08;Cylinder CSB 14309-QA;Depth 5697.1 ft. MD FID1 A.(E:UIPCHECDATAr00500215\,CY143C0.D) Norm. 2s- — JOB 200500215 CONOCO PHILIPS 1.08 CSB 14309-QA RF FLASH CYLINDER 200- . 150- 100- co 50- - cI Ln nao 0)o�Nmal17I.ChCO m �� �NNNNNNN'VN 0(Oj U U U U U U c c c c cc cccccccccc cc c cccc ` `.-..._`. `. . rarou Nil l IIIlllal IIMIII Ill.111111 IIIIIN II 0 5 10 15 20 26 30 35 mir Figure 4:k-Plot for Equilibrium Check(Sample 1.08) Sample 1.08;Cylinder CSB 14309-QA; Depth 5697.1 ft. MD 2 •C3 •iC4 1.5 a nCd 1 •liek5 -a 0.5 •C6 3; 0 •C7 •C8 -0.5 •C9 -1 •C10 -1.5 -4 -3 -2 -1 0 1 2 3 F 011phase-DBR 20 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 10:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.09) Sample 1.09;Cylinder SSB 18528-QA; Depth 5697.1 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% Wr°k MOLE% Carbon Dioxide 44.01 0.62 0.23 0.00 0.00 0.01 0.05 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.68 0.98 0.00 0.00 0.02 0.21 Methane 16.04 95.61 97.96 0.00 0.00 1.01 21.20 Ethane 30.07 0.85 0.46 0.00 0.00 0.01 0.10 Propane 44.10 0.46 0.17 0.02 0.16 0.02 0.16 I-Butane 58.12 0.30 0.09 0.02 0.14 0.02 0.13 N-Butane 58.12 0.13 0.04 0.01 0.10 0.01 0.08 I-Pentane 72.15 0.11 0.03 0.04 0.24 0.04 0.19 N-Pentane 72.15 0.03 0.01 0.01 0.05 0.01 0.04 C6 84.00 0.05 0.01 0.07 0.33 0.07 0.26 M-C-Pentane 84.16 0.01 0.00 0.00 0.02 0.00 0.02 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.03 0.00 0.02 C7 96.00 0.02 0.00 0.18 0.78 0.18 0.61 M-C-Hexane 98.19 0.02 0.00 0.01 0.03 0.01 0.02 Toluene 92.14 0.01 0.00 0.00 0.02 0.00 0.01 C8 107.00 0.03 0.01 0.15 0.58 0.14 0.45 E-Benzene 106.17 0.00 0.00 0.00 0.02 0.00 0.02 M/P-Xylene 106.17 0.01 0.00 0.00 0.01 0.00 0.01 O-Xylene 106.17 0.00 0.00 0.01 0.02 0.01 0.02 C9 121.00 0.03 0.00 0.28 0.99 0.28 0.78 C10 134.00 0.02 0.00 0.54 1.72 0.54 1.35 C11 147.00 0.00 0.00 0.87 2.51 0.86 1.97 C12 161.00 0.00 0.00 1.33 3.50 1.31 2.74 C13 175.00 0.00 0.00 1.83 4.44 1.81 3.48 C14 190.00 0.00 0.00 2.07 4.62 2.05 3.62 C15 206.00 0.00 0.00 2.56 5.28 2.53 4.14 C16 222.00 2.43 4.65 2.40 3.64 C17 237.00 2.51 4.50 2.49 3.53 C18 251.00 2.62 4.44 2.59 3.48 C19 263.00 2.58 4.17 2.55 3.26 C20 275.00 2.44 3.76 2.41 2.95 C21 291.00 2.49 3.63 2.46 2.85 C22 300.00 2.30 3.26 2.28 2.55 C23 312.00 2.26 3.08 2.24 2.42 C24 324.00 2.21 2.90 2.19 2.27 C25 337.00 1.80 2.27 1.78 1.78 C26 349.00 1.78 2.17 1.76 1.70 C27 360.00 1.79 2.11 1.77 1.65 C28 372.00 1.77 2.02 1.75 1.59 C29 382.00 1.75 1.95 1.73 1.53 C30 394.00 1.61 1.74 1.60 1.36 C31 404.00 1.45 1.53 1.43 1.20 C32 415.00 1.39 1.42 1.38 1.12 C33 426.00 1.33 1.33 1.32 1.04 C34 437.00 1.19 1.16 1.18 0.91 C35 445.00 1.21 1.15 1.19 0.90 C36+ 1024.90 51.10 21.19 50.56 16.60 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.44 424.94 336.55 MOLE RATIO 0.2164 0.7836 011phase-DBR 21 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 11:Calculated Fluid Properties Sample 1.09;Cylinder SSB 18528-QA; Depth 5697.1 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.16 0.03 99.84 _ 98.98 98.78 77.57 C12+ 0.00 0.00 _ 97.79 92.26 96.76 72.30 C20+ - - _ 79.87 56.67 79.03 44.41 C30+ - - 59.29 29.52 58.66 23.13 C36+ - - 51.10 21.19 50.56 16.60 Molar Mass C7+ 106.63 428.62 428.60 C12+ 164.65 450.40 450.40 C20+ - 598.93 598.93 C30+ - _ 853.55 853.55 C36+ 1024.90 1024.90 Density C7+ - _ 0.9608 - C12+ - 0.9657 0.9657 20+ - 0.9994 0.9994 C30+ _ 1.0468 _ 1.0468 C36+ 1.0710 1.0710 Fluid at 60°F 0.9599 Gas Gravity(Air=1) 0.568 Dry Gross Heat Content(BTU/scf) 1,011 Wet Gross Heat Content(BTU/scf 994 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 424.94 424.94 1024.90 _ Density(g/cm3) 0.9599 - 1.0710 Single Stage Flash Data Original STO De-Contaminated GOO(scf/stb) 83 - STO Density(g/cm3) 0.9599 - STO API Gravity 15.9 - OBM Density(g/cm3)@60°F - 011phase-DBR 22 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 10:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.09) Sample 1.09;Cylinder SSB 18528-QA;Depth 5697.1 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid - (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.62 0.23 0.00 0.00 0.01 0.05 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.68 0.98 0.00 0.00 0.02 0.21 Methane 16.04 95.61 97.96 0.00 0.00 1.01 21.20 Ethane 30.07 0.85 0.46 0.00 0.00 0.01 0.10 Propane 44.10 0.46 0.17 0.02 0.16 0.02 0.16 I-Butane 58.12 0.30 0.09 0.02 0.14 0.02 0.13 N-Butane _ 58.12 0.13 0.04 0.01 0.10 0.01 0.08 I-Pentane 72.15 0.11 0.03 0.04 0.24 0.04 0.19 N-Pentane 72.15 0.03 0.01 0.01 0.05 0.01 0.04 C6 84.00 0.05 0.01 0.07 0.33 0.07 0.26 M-C-Pentane 84.16 0.01 0.00 0.00 0.02 0.00 0.02 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.03 0.00 0.02 C7 96.00 0.02 0.00 0.18 0.78 0.18 0.61 M-C-Hexane 98.19 0.02 0.00 0.01 0.03 0.01 0.02 Toluene _ 92.14 0.01 0.00 0.00 0.02 0.00 0.01 C8 107.00 0.03 0.01 0.15 0.58 0.14 0.45 E-Benzene 106.17 0.00 0.00 0.00 0.02 0.00 0.02 M/P-Xylene 106.17 0.01 0.00 0.00 0.01 0.00 0.01 O-Xylene _ 106.17 0.00 0.00 0.01 0.02 0.01 0.02 C9 121.00 0.03 0.00 0.28 0.99 0.28 0.78 C10 134.00 0.02 0.00 0.54 1.72 0.54 1.35 C11 147.00 0.00 0.00 0.87 2.51 0.86 1.97 C12 161.00 0.00 0.00 1.33 3.50 1.31 2.74 C13 175.00 0.00 0.00 1.83 4.44 1.81 3.48 C14 190.00 0.00 0.00 2.07 4.62 2.05 3.62 C15 206.00 0.00 0.00 2.56 5.28 2.53 4.14 C16 222.00 2.43 4.65 2.40 3.64 C17 237.00 2.51 4.50 2.49 3.53 C18 251.00 2.62 4.44 2.59 3.48 C19 263.00 2.58 4.17 2.55 3.26 C20 275.00 2.44 3.76 2.41 2.95 C21 291.00 2.49 3.63 2.46 2.85 C22 300.00 2.30 3.26 2.28 2.55 C23 312.00 2.26 3.08 2.24 2.42 C24 324.00 2.21 2.90 2.19 2.27 C25 337.00 1.80 2.27 1.78 1.78 C26 349.00 1.78 2.17 1.76 1.70 C27 360.00 1.79 2.11 1.77 1.65 C28 372.00 1.77 2.02 1.75 1.59 C29 382.00 1.75 1.95 1.73 1.53 C30 394.00 1.61 1.74 1.60 1.36 C31 404.00 1.45 1.53 1.43 _1.20 C32 415.00 1.39 1.42 1.38 1.12 C33 426.00 1.33 1.33 1.32 1.04 C34 437.00 1.19 1.16 1.18 0.91 C35 445.00 1.21 1.15 1.19 0.90 C36+ 1024.90 51.10 21.19 50.56 16.60 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.44 424.94 336.55 MOLE RATIO 0.2164 0.7836 011phase-DBR 21 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Figure 5:Stock Tank Oil Chromatogram(Sample 1.09) Sample 1.09;Cylinder SSB 18528-QA;Depth 5697.1 ft.MD FID1 A.(E 1HPCHE411iIDATr1005002'5,Y1652E Norm. • o 250- • JOB 200500215 CONOCO PHILIPS 200- 1.09 SSB 18528-0A RF FLASH CYLINDER 150- • 100- . N (0 (1443 � o c N �m��NNNcf50- C,61) o ccccccc� . U CC cccCCm U°Tbx , ., c c II I L -----_ — 0 5 10 15 20 25 30 35 mir Figure 6:k-Plot for Equilibrium Check(Sample 1.09) Sample 1.09;Cylinder SSB 18528-QA; Depth 5697.1 ft.MD 1.5 •C3 1 •IC4 •nC4 0.5 • 5 01 0 O •C6 -0.5 •C8 •C7 -1 •C9 -1.5 -4 -3 -2 -1 0 1 2 3 F 011phase-DBR 23 File 200500215 1 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 12:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.10) Sample 1.10;Cylinder SSB 18136-QA; Depth 5697.1 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.48 0.18 0.00 0.00 0.01 0.04 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.83 1.07 0.00 0.00 0.02 0.25 Methane 16.04 95.80 97.98 0.00 0.00 1.13 22.67 Ethane 30.07 0.82 0.45 0.00 0.00 0.01 0.10 Propane 44.10 0.44 0.16 0.02 0.16 0.02 0.16 I-Butane 58.12 0.29 0.08 0.02 0.13 0.02 0.12 N-Butane 58.12 0.12 0.03 0.01 0.10 0.01 0.08 I-Pentane 72.15 0.10 0.02 0.04 0.22 0.04 0.18 N-Pentane 72.15 0.03 0.01 0.01 0.06 0.01 0.05 C6 84.00 0.04 0.01 0.10 0.50 0.10 0.39 M-C-Pentane 84.16 0.00 0.00 0.00 0.02 0.00 0.02 Benzene 78.11 0.00 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.00 0.00 0.01 0.03 0.01 0.02 C7 96.00 0.02 0.00 0.18 0.78 0.18 0.60 M-C-Hexane 98.19 0.00 0.00 0.01 0.03 0.01 0.02 Toluene 92.14 0.00 0.00 0.00 0.01 0.00 0.01 C8 107.00 0.01 0.00 0.16 0.61 0.16 0.47 E-Benzene 106.17 0.00 0.00 0.00 0.02 0.00 0.01 M/P-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 0-Xylene 106.17 0.00 0.00 0.01 0.03 0.01 0.02 C9 121.00 0.01 0.00 0.30 1.02 0.30 0.79 010 134.00 0.00 0.00 0.57 1.77 0.57 1.36 C11 147.00 0.00 0.00 0.94 2.64 0.93 2.03 C12 161.00 0.00 0.00 1.40 3.59 1.39 2.76 C13 175.00 0.00 0.00 1.94 4.56 1.91 3.51 C14 190.00 0.00 0.00 2.18 4.74 2.16 3.64 C15 206.00 0.00 0.00 2.71 5.43 2.68 4.17 C16 222.00 2.77 5.15 2.74 3.96 C17 237.00 2.56 4.45 2.53 3.42 C18 251.00 2.66 4.37 2.63 3.36 C19 263.00 2.70 4.24 2.67 3.26 C20 275.00 2.55 3.83 2.52 2.94 C21 291.00 2.57 3.64 2.53 2.80 C22 300.00 2.44 3.36 2.41 2.58 C23 312.00 2.30 3.04 2.27 2.33 C24 324.00 2.13 2.71 2.10 2.08 C25 337.00 2.05 2.51 2.03 1.93 C26 349.00 2.01 2.38 1.99 1.83 C27 360.00 1.65 1.89 1.63 1.45 C28 372.00 1.90 2.11 1.88 1.62 C29 382.00 1.95 2.11 1.93 1.62 C30 394.00 1.40 1.47 1.38 1.13 C31 404.00 1.63 1.67 1.61 1.28 C32 415.00 1.17 1.16 1.15 0.89 C33 426.00 1.24 1.20 1.23 0.92 C34 437.00 1.17 1.10 1.16 0.85 C35 445.00 0.16 0.15 0.16 0.11 036+ 989.70 50.37 21.00 49.77 16.14 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.41 412.59 320.90 MOLE RATIO 0.2314 0.7686 011phase-DBR 24 Rle 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 13:Calculated Fluid Properties Sample 1.10; Cylinder SSB 18136-QA; Depth 5697.1 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole To C7+ 0.05 0.01 99.80 98.84 98.62 75.96 C12+ 0.00 0.00 97.61 91.85 _ 96.45 70.59 C20+ - - 78.69 55.31 77.76 42.51 C30+ - - 57.14 27.75 56.46 21.33 C36+ - - 50.37 21.00 49.77 16.14 Molar Mass C7+ 105.31 416.62 416.61 C12+ 168.00 438.45 438.45 C20+ - 586.96 _ _ 586.96 C30+ - 849.65 _ 849.65 C36+ - 989.70 989.70 Density C7+ - 0.9523 - C12+ - 0.9573 0.9573 C20+ - _ 0.9907 _ 0.9907 C30+ _ 1.0379 _ 1.0379 C36+ 1.0571 1.0571 Fluid at 60°F 0.9513 Gas Gravity(Air=1) 0.566 Dry Gross Heat Content(BTU/scf) 1,009 Wet Gross Heat Content(BTU/scf 992 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 412.59 412.59 989.70 Density(g/cm3) 0.9513 - 1.0571 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) _ 92 - STO Density(g/cm3) 0.9513 - STO API Gravity 17.2 - OBM Density(g/cm3)@60°F - Ol l phase-D BR 25 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Figure 7:Stock Tank Oil Chromatogram(Sample 1.10) Sample 1.10;Cylinder SSB 18136-QA; Depth 5697.1 ft.MD FID1 A,(E:1HPCHEM2 DATA+VJ5O02151CY18138,D) Nam. 0 x ° 250- I • 240- JOB 200500215 CONOCO PHILIPS 1.10 SSB 18136-QA RF FLASH CYLINDER 150- • 100- . Dl ID 50- 0 C q N ID � t-NryNNNN � .0 U0 .) 0 N m r r UU(UUUUUUUW Y0 °iL 5co co0 � U U U 0 C ccCcccccccCCCCccccc c ,....M.raYlRllllf �HU..., T.. D Mr- 5 10 15 20 25 30 35 mir Figure 8:k-Plot for Equilibrium Check(Sample 1.10) Sample 1.10;Cylinder SSB 18136-QA;Depth 5697.1 ft. MD 1.5 •C3 1 •1U4 •nC4 0.5 •sCIE5 0 -0.5 •C6 -1 -4 -3 -2 -1 0 1 2 3 F 011phase-DBR 26 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 14:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.14) Sample 1.14;Cylinder CSB 14308-QA;Depth 5553 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 4.62 1.77 0.00 0.00 0.05 0.39 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.73 1.04 0.00 0.00 0.02 0.23 Methane 16.04 91.81 96.50 0.00 0.00 1.04 21.15 Ethane 30.07 0.82 0.46 0.00 0.00 0.01 0.10 Propane 44.10 0.17 0.07 0.01 0.08 0.01 0.08 I-Butane 58.12 0.11 0.03 0.00 0.02 0.00 0.02 N-Butane 58.12 0.05 0.01 0.00 0.00 0.00 0.01 I-Pentane 72.15 0.03 0.01 0.00 0.01 0.00 0.01 N-Pentane 72.15 0.05 0.01 0.00 0.01 0.00 0.01 C6 84.00 0.06 0.01 0.01 0.03 0.01 0.02 M-C-Pentane 84.16 0.03 0.01 0.00 0.00 0.00 0.00 Benzene 78.11 0.01 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.01 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.07 0.01 0.10 0.41 0.09 0.32 M-C-Hexane 98.19 0.05 0.01 0.00 0.00 0.00 0.00 Toluene 92.14 0.03 0.01 0.00 0.00 0.00 0.00 C8 107.00 0.10 0.02 0.00 0.00 0.00 0.00 E-Benzene 106.17 0.01 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.02 0.00 0.00 0.00 0.00 0.00 0-Xylene 106.17 0.01 0.00 0.00 0.00 0.00 0.00 C9 121.00 0.10 0.01 0.00 0.00 0.00 0.00 010 134.00 0.08 0.01 0.03 0.10 0.03 0.08 C11 147.00 0.01 0.00 0.32 0.91 0.32 0.71 C12 161.00 0.00 0.00 0.81 2.07 0.80 1.62 C13 175.00 0.00 0.00 1.68 3.97 1.66 3.10 C14 190.00 0.00 0.00 2.02 4.40 2.00 3.43 C15 206.00 0.00 0.00 2.49 4.99 2.46 3.90 C16 222.00 2.63 4.91 2.60 3.83 C17 237.00 2.74 4.78 2.71 3.73 C18 251.00 2.89 4.76 2.85 3.71 C19 263.00 3.07 4.83 3.04 3.77 C20 275.00 2.94 4.42 2.91 3.45 C21 291.00 2.95 4.20 2.92 3.28 C22 300.00 2.88 3.97 2.85 3.10 C23 312.00 2.86 3.79 2.83 2.96 C24 324.00 2.80 3.57 2.77 2.79 C25 337.00 2.75 3.38 2.72 2.64 C26 349.00 2.70 3.20 2.67 2.50 C27 360.00 2.67 3.07 2.64 2.39 C28 372.00 2.59 2.88 2.56 2.25 C29 382.00 2.50 2.70 2.47 2.11 C30 394.00 2.29 2.40 2.26 1.88 C31 404.00 2.15 2.20 2.13 1.72 C32 415.00 2.07 2.06 2.05 1.61 C33 426.00 1.87 1.81 1.85 1.42 C34 437.00 1.73 1.64 1.71 1.28 C35 445.00 1.66 1.54 1.64 1.20 C36+ 1023.00 41.78 16.89 41.31 13.19 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.86 413.46 326.54 MOLE RATIO 0.2191 0.7809 011phase-DBR 27 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 15:Calculated Fluid Properties Sample 1.14;Cylinder CSB 14308-QA;Depth 5553 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.54 0.09 99.98 99.85 98.85 77.99 C12+ 0.00 0.00 99.53 _ 98.43 _ 98.40 76.86 C20+ - - 81.20 63.72 80.28 49.76 C30+ - - 53.55 28.55 52.95 22.29 C36+ - - 41.78 16.89 41.31 13.19 Molar Mass C7+ 106.64 413.99 413.92 C12+ 164.83 418.07 418.07 C20+ - 526.83 526.83 C30+ - 775.61 _ 775.61 - C36+ - 1023.00 1023.00 Density C7+ - 0.9595 - C12+ - 0.9606 0.9606 C20+ - 0.9922 0.9922 C30+ 1.0585 1.0585 C36+ 1.1065 1.1065 Fluid at 60°F 0.9594 Gas Gravity(Air=1) 0.582 Dry Gross Heat Content(BTU/scf) 994 Wet Gross Heat Content(BTU/scf 977 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties __ MW 413.46 413.46 1023.00 Density(g/cm3) 0.9594 - 1.1065 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 87 - STO Density(g/cm3) _ 0.9594 _ - STO API Gravity 16.0 - OBM Density(g/cm3)@60°F - 011phase-DBR 28 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Figure 9:Stock Tank Oil Chromatogram(Sample 1.14) Sample 1.14;Cylinder CSB 14308-QA; Depth 5553 ft.MD FI01A(EWPCHE1121DATA005002151CY14308.D) Norm. JOB 200500215 CONOCO PHILIPS 1.14 CSB 14308-QA — RF FLASH CYLINDER .QG- inn K~m010�NP1�47(Dr 50 NN N m N N �NNNNN UUUUWUW U p U U ++rrc c c+c icccccccccccc cccc C._. �.Cwll C Ilr II MII ll ■in 0 5 10 15 20 25 30 35 mir Figure 10:k-Plot for Equilibrium Check(Sample 1.14) Sample 1.14;Cylinder CSB 14308-QA;Depth 5553 ft.MD 2 •nC4 1.5 - •n'5 •iC4 1 •iC5 •C3 -Y •C6 1 J n l •C10 •C/ ^ I -3 -2 -1 0 1 2 3 F 011phase-DBR 29 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 16:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.18) Sample 1.18;Cylinder CSB 14311-QA;Depth 5553 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE T. WT% MOLE% Carbon Dioxide 44.01 2.84 1.07 0.00 0.00 0.03 0.22 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 2.11 1.25 0.00 0.00 0.02 0.25 Methane 16.04 94.25 97.31 0.00 0.00 0.91 19.75 Ethane 30.07 0.60 0.33 0.00 0.00 0.01 0.07 Propane 44.10 0.06 0.02 0.01 0.08 0.01 0.07 I-Butane 58.12 0.04 0.01 0.00 0.03 0.00 0.02 N-Butane 58.12 0.00 0.00 0.00 0.00 0.00 0.00 I-Pentane 72.15 0.00 0.00 0.00 0.02 0.00 0.01 N-Pentane 72.15 0.01 0.00 0.01 0.04 0.01 0.03 C6 84.00 0.01 0.00 0.07 0.36 0.07 0.29 M-C-Pentane 84.16 0.00 0.00 0.01 0.03 0.01 0.03 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.02 0.00 0.09 0.39 0.09 0.31 M-C-Hexane 98.19 0.00 0.00 0.00 0.00 0.00 0.00 Toluene 92.14 0.00 0.00 0.00 0.00 0.00 0.00 C8 107.00 0.01 0.00 0.00 0.00 0.00 0.00 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 O-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 C9 121.00 0.01 0.00 0.00 0.00 0.00 0.00 C10 134.00 0.02 0.00 0.01 0.03 _ 0.01 0.02 C11 147.00 0.01 0.00 0.30 0.89 0.30 0.71 C12 161.00 0.00 0.00 0.77 2.06 0.76 1.65 C13 175.00 0.00 0.00 1.46 3.60 1.45 2.87 C14 190.00 0.00 0.00 2.01 4.55 1.99 3.62 C15 206.00 0.00 0.00 2.24 4.69 2.22 3.74 C16 222.00 2.44 4.73 2.41 3.77 C17 237.00 2.69 4.89 2.67 3.90 C18 251.00 2.73 4.68 _ 2.70 3.73 C19 263.00 2.73 4.47 2.71 3.57 C20 275.00 2.85 4.46 2.82 3.56 C21 291.00 2.77 4.09 2.74 3.26 C22 300.00 2.73 3.91 2.70 3.12 C23 312.00 2.68 3.69 - 2.65 2.94 C24 324.00 2.61 3.46 2.58 2.76 C25 337.00 2.64 3.37 2.61 2.69 C26 349.00 2.52 3.10 2.49 2.47 C27 360.00 _ 2.54 3.03 2.51 2.42 C28 372.00 2.42 2.80 2.40 2.23 C29 382.00 2.40 2.71 2.38 2.16 C30 394.00 1.92 2.10 _ 1.90 1.67 C31 404.00 1.87 1.99 _ 1.85 1.59 C32 415.00 1.88 1.95 1.86 1.56 C33 426.00 1.92 1.94 1.90 1.55 C34 437.00 1.70 1.67 1.68 1.33 C35 445.00 1.44 1.39 1.43 1.11 C36+ 1045.00 45.53 18.75 45.08 14.94 Total 100.00 100.00 100.00 100.00 - 100.00 100.00 MW 16.56 430.40 346.39 MOLE RATIO 0.2030 0.7970 011phase-DBR 30 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 17:Calculated Fluid Properties Sample 1.18; Cylinder CSB 14311-QA; Depth 5553 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.08 0.01 99.91 99.48 98.94 79.28 C12+ 0.00 0.00 99.50 98.13 98.53 78.21 C20+ - - 82.41 64.45 81.61 51.37 C30+ - - 56.26 29.81 55.72 23.75 C36+ - - 45.53 18.75 45.08 14.94 Molar Mass C7+ 113.91 432.27 432.26 C12+ 166.36 436.41 436.41 C20+ - 550.38 550.38 C30+ - 812.47 812.47 C36+ - 1045.00 1045.00 Density C7+ - 0.9627 - C 12+ - 0.9637 0.9637 C20+ - 0.9935 0.9935 C30+ 1.0536 1.0536 C36+ 1.0918 1.0918 Fluid at 60°F 0.9622 Gas Gravity(Air=1) 0.572 Dry Gross Heat Content(BTU/scf) 993 Wet Gross Heat Content(BTU/scf 975 OBM Contamination Level(wt"/o) _ - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 430.40 430.40 1045.00 Density(g/cm3) 0.9622 - 1.0918 Single Stage Flash Data Original STO De-Contaminated GOA(scf/stb) 76 - STO Density(g/cm3) i i 0.9622 - STO API Gravity 15.6 - OBM Density(g/cm3)©60°F - 011phase-DBR 31 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Figure 11:Stock Tank Oil Chromatogram(Sample 1.18) Sample 1.18;Cylinder CSB 14311-QA; Depth 5553 ft.MD FID1 A,(E:IHPCHEMl2kDATA1005002151CY14311D) - Now U • n e 250- I • JOB 200500215 CONOCO PHILIPS 200- 1.18 CSB 14311-QA RF FLASH CYLINDER 150- 100- . ryma471l�`a� N 50- CY Cr) N CO h m,NNryNNNr`U rbi t` V U C C C C C C CCCCCCCCCCcc C U U c c c t►III�t����ir�l� ll� III 11itt �><- o ,-- 0 5 10 15 20 25 30 35 mir Figure 12:k-Plot for Equilibrium Check(Sample 1.18) Sample 1.18;Cylinder CSB 14311-QA;Depth 5553 ft.MD 0.6 •+r.4 •C3 0.6 a 0.4 OI 0.2 0 •iC5 -0.2 •nC5 -0.4 -4 -3 -2 -1 0 1 2 3 111 F 011phase-DBR 32 Flo 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 18:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.19) Sample 1.19;Cylinder SSB 18539-OA; Depth 5553 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1.25 0.47 0.00 0.00 0.01 0.10 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.65 0.97 0.00 0.00 0.02 0.20 Methane 16.04 95.66 97.95 0.00 0.00 0.92 20.02 Ethane 30.07 0.84 0.46 0.00 0.00 0.01 0.09 Propane 44.10 0.15 0.05 0.01 0.06 0.01 0.06 I-Butane 58.12 0.13 0.04 0.00 0.03 0.00 0.03 N-Butane 58.12 0.03 0.01 0.00 0.00 0.00 0.00 I-Pentane 72.15 0.03 0.01 0.01 0.06 0.01 0.05 N-Pentane 72.15 0.10 0.02 0.01 0.04 0.01 0.04 C6 84.00 0.05 0.01 0.10 0.50 0.10 0.40 ' M-C-Pentane 84.16 0.00 0.00 0.00 0.00 0.00 0.00 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.02 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.05 0.01 0.09 0.41 0.09 0.33 M-C-Hexane 98.19 0.01 0.00 0.00 0.00 0.00 0.00 Toluene 92.14 0.00 0.00 0.00 0.00 0.00 0.00 C8 107.00 0.01 0.00 0.00 0.00 0.00 0.00 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 0-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 C9 121.00 0.01 0.00 0.00 0.00 0.00 0.00 C10 134.00 0.01 0.00 0.01 0.02 0.01 0.02 C11 147.00 0.01 0.00 0.21 0.62 0.21 0.49 C12 161.00 0.00 0.00 0.69 1.87 0.68 1.48 C13 175.00 0.00 0.00 1.47 3.67 1.46 2.92 C14 190.00 0.00 0.00 1.99 4.57 1.97 3.64 C15 206.00 0.00 0.00 2.49 5.27 2.47 4.19 C16 222.00 2.37 4.66 2.35 3.71 C17 237.00 2.54 4.68 2.52 3.72 C18 251.00 2.71 4.71 2.68 3.74 C19 263.00 2.84 4.71 2.81 3.75 C20 275.00 2.80 4.43 2.77 3.53 C21 291.00 2.64 3.95 2.61 3.15 C22 300.00 2.64 3.83 2.61 3.05 C23 312.00 2.70 3.78 2.68 3.01 C24 324.00 2.63 3.54 2.61 2.82 C25 337.00 2.51 3.25 2.49 2.58 C26 349.00 2.45 3.07 2.43 2.44 C27 360.00 2.40 2.90 2.37 2.31 C28 372.00 2.40 2.82 2.38 2.24 C29 382.00 2.39 2.73 2.36 2.17 C30 394.00 1.89 2.09 1.87 1.66 C31 404.00 1.90 2.05 1.88 1.63 C32 415.00 1.70 1.78 1.68 1.42 C33 426.00 1.60 1.64 1.59 1.31 C34 437.00 1.57 1.56 1.55 1.24 C35 445.00 1.52 1.49 1.50 1.18 C36+ 1060.00 46.73 19.22 46.28 15.29 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.43 436.02 350.25 MOLE RATIO 0.2044 0.7956 011phase-DBR 33 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand Table 19:Calculated Fluid Properties Sample 1.19;Cylinder SSB 18539-QA; Depth 5553 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.12 0.02 99.88 99.32 98.92 79.02 C12+ 0.00 0.00 99.57 98.26 98.62 78.18 C20+ - - 82.47 64.14 81.67 51.03 C30+ - - 56.90 29.84 56.36 23.74 C36+ - - 46.73 19.22 46.28 15.29 Molar Mass C7+ 102.14 _ 438.48 438.46 C12+ 166.44 441.82 441.82 C20+ - 560.60 560.60 C30+ 831.57 831.57 C36+ - 1060.00 1060.00 Density C7+ - 0.9688 - C12+ - 0.9696 0.9696 C20+ - 1.0011 1.0011 C30+ 1.0639 1.0639 C36+ 1.1021 1.1021 Fluid at 60°F 0.9682 Gas Gravity(Air=1) 0.567 Dry Gross Heat Content(BTU/scf) 1,005 Wet Gross Heat Content(BTU/scf 987 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 436.02 _ 436.02 1060.00 Density(g/cm3) 0.9682 - 1.1021 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 76 - STO Density(g/cm3) 0.9682 - STO API Gravity 14.6 - OBM Density(g/cm3)@60°F - 011phase-DBR 34 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Figure 13:Stock Tank Oil Chromatogram(Sample 1.19) Sample 1.19;Cylinder SSB 18539-QA;Depth 5553 ft.MD FID1 A,(E,UIPCHEIRlDATA005002151CY18538.D) Norm. c 0 • I 250- . • JOB 200500215 CONOCO PHILIPS • 1.19 SSB 18539-QA 200- RF FLASH CYLINDER 150- 100- . m NtnILAO, �. [ N m �] T:t° "NNNNNN �°°°°ccccc UUUU cc • �. ;MINA S II lltiiiui ► Trim-rim — 0 5 10 15 20 25 30 35 mir Figure 14:k-Plot for Equilibrium Check(Sample 1.19) Sample 1.19;Cylinder SSB 18539-QA;Depth 5553 ft.MD 1.5 •iC4 •C3 1 •nL5 0.5 Y •iC5 0 - •C7 -0.5 •C6 -1 -4 -3 -2 -1 0 1 2 3 F 011phase-DBR 35 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 20:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.20) Sample 1.20;Cylinder SSB 18530-QA;Depth 5553 ft.MD Component MW j Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1.19 0.44 0.00 0.00 0.01 0.09 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 2.17 1.27 0.00 0.00 0.02 0.25 Methane 16.04 95.87 97.91 0.00 0.00 0.91 19.44 Ethane 30.07 0.62 0.34 0.00 0.00 0.01 0.07 Propane 44.10 0.07 0.02 0.01 0.10 0.01 0.09 I-Butane 58.12 0.04 0.01 0.00 0.03 0.00 0.03 N-Butane 58.12 0.00 0.00 0.00 0.01 0.00 0.01 I-Pentane 72.15 0.00 0.00 0.00 0.02 0.00 0.01 N-Pentane 72.15 0.01 0.00 0.01 0.06 0.01 0.05 C6 84.00 0.00 0.00 0.01 0.06 0.01 0.05 M-C-Pentane 84.16 0.00 0.00 0.00 0.00 0.00 0.00 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.00 0.00 0.11 0.49 0.11 0.39 M-C-Hexane 98.19 0.00 0.00 0.00 0.01 0.00 0.01 Toluene 92.14 0.00 0.00 0.00 0.00 0.00 0.00 C8 107.00 0.00 0.00 0.00 0.02 0.00 0.01 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 O-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 C9 121.00 0.00 0.00 0.00 0.01 0.00 0.01 C10 134.00 0.00 0.00 0.04 0.14 0.04 0.11 C11 147.00 0.00 0.00 0.31 0.89 0.30 0.71 C12 161.00 0.00 0.00 0.83 2.19 0.82 1.76 C13 175.00 0.00 0.00 1.56 3.78 1.54 3.03 C14 190.00 0.00 0.00 1.94 4.36 1.93 3.49 C15 206.00 0.00 0.00 2.53 5.23 2.51 4.19 C16 222.00 2.47 4.74 2.45 3.80 C17 237.00 2.63 4.72 2.60 3.78 C18 251.00 2.85 4.84 2.83 3.88 C19 263.00 2.91 4.71 2.88 3.78 C20 275.00 2.72 4.22 2.70 3.38 C21 291.00 2.85 4.16 2.82 3.34 C22 300.00 2.73 3.88 2.71 3.11 C23 312.00 2.82 3.84 2.79 3.08 1 C24 324.00 2.77 3.64 2.75 2.92 C15 337.00 2.67 3.37 2.64 2.70 C26 349.00 2.51 3.07 2.49 2.46 C27 360.00 2.42 2.87 2.40 2.30 C28 372.00 2.37 2.71 2.34 2.17 C29 382.00 2.38 2.65 2.36 2.13 1 C30 394.00 2.16 2.33 2.14 1.87 C31 404.00 2.11 2.23 2.09 1.78 C32 415.00 1.63 1.67 1.61 1.34 C33 426.00 1.65 1.65 1.63 1.32 C34 437.00 1.57 1.53 1.55 1.22 C35 445.00 1.57 1.50 1.55 1.20 C36+ 1043.00 44.83 18.29 44.41 14.66 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.38 425.59 344.35 MOLE RATIO 0.1985 0.8015 011phase-DBR 36 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 21:Calculated Fluid Properties Sample 1.20;Cylinder SSB 18530-QA; Depth 5553 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.02 0.00 99.96 99.72 99.01 79.92 C12+ 0.00 0.00 99.49 98.17 98.55 78.68 C20+ - - 81.76 63.59 80.99 50.97 C30+ - - 55.51 29.19 54.99 23.39 C36+ - - 44.83 18.29 44.41 14.66 Molar Mass C7+ 120.70 426.62 426.62 C12+ 163.09 431.32 431.32 C20+ - _ 547.18 547.18 C30+ - 809.39 809.39 C36+ - 1043.00 1043.00 Density C7+ - 0.9648 - C 12+ - 0.9659 0.9659 C20+ _ 0.9979 0.9979 C30+ 1.0620 1.0620 C36+ 1.1035 1.1035 Fluid at 60°F 0.9645 Gas Gravity(Air=1) 0.566 Dry Gross Heat Content(BTU/scf) 998 Wet Gross Heat Content(BTU/scf 981 OBM Contamination Level(wt°7°) _ - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 425.59 425.59 1043.00 Density(g/cm3) 0.9645 - 1.1035 Single Stage Flash Data Original STO De-Contaminated GOP(scf/stb( 75 - STO Density(g/cm3) _ 0.9645 - STO API Gravity 15.2 - OBM Density(g/cm3)©60°F - 011phase-DBR 37 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Figure 15:Stock Tank Oil Chromatogram(Sample 1.20) Sample 1.20;Cylinder SSB 18530-CA;Depth 5553 ft.MD FID1 A,(E:IHPCHEM2 ATA0105002151CY18530,D) Norm. 250- JOB 200500215 CONOCO PHILIPS 1.20 SSB 18530-QA RF FLASH CYLINDER 200- 150- 100 50D r,m�p10NFVNNNNNNNNIAL nm N t'1 41 N � ccccccccccccccecccc U • 0 5 10 15 20 25 30 35 mir Figure 16:k-Plot for Equilibrium Check(Sample 1.20) Sample 1.20;Cylinder SSB 18530-0.A;Depth 5553 ft.MD 1 0.8 •iC4 0.6 •C3 Ts. o, 0.4 0 •nC4 0.2 0 •iC5 •nC5 -0.2 -4 -3 -2 -1 0 1 2 3 F 011phase-DBR 38 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Contam.wt% 1.72 STO(Demulsifier) Table 22:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.01&1.02) Sample 1.01 &1.02;Cylinder CSB 4854-IA Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1.57 0.60 0.00 0.00 0.02 0.14 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.50 0.89 0.00 0.00 0.02 0.20 Methane 16.04 93.42 97.18 0.00 0.00 1.11 22.13 Ethane 30.07 1.08 0.60 0.00 0.00 0.01 0.14 Propane 44.10 0.81 0.31 0.02 0.16 0.03 0.19 I-Butane 58.12 0.70 0.20 0.01 0.09 0.02 0.11 N-Butane 58.12 0.36 0.10 0.01 0.08 0.02 0.09 I-Pentane 72.15 0.43 0.10 0.03 0.17 0.04 0.16 N-Pentane 72.15 0.04 0.01 0.00 0.02 0.00 0.02 C6 84.00 0.01 0.00 0.04 0.21 0.04 0.16 M-C-Pentane 84.16 0.00 0.00 0.00 0.02 0.00 0.01 Benzene 78.11 0.00 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.00 0.00 0.00 0.02 0.00 0.02 C7 96.00 0.00 0.00 0.10 0.43 0.10 0.34 M-C-Hexane 98.19 0.00 0.00 0.01 0.02 0.01 0.02 Toluene 92.14 0.01 0.00 0.03 0.13 0.03 0.10 C8 107.00 0.01 0.00 0.14 0.54 0.14 0.42 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.01 0.03 0.01 0.03 O-Xylene 106.17 0.00 0.00 0.06 0.23 0.06 0.18 C9 121.00 0.01 0.00 0.25 0.83 0.24 0.64 C10 134.00 0.02 0.00 1.12 3.42 1.11 2.64 C11 147.00 0.00 0.00 1.83 5.09 1.81 3.93 C12 161.00 0.00 0.00 1.41 3.59 1.39 2.77 C13 175.00 0.00 0.00 1.82 4.25 1.80 3.28 C14 190.00 0.00 0.00 2.12 4.58 2.10 3.53 C15 206.00 0.00 0.00 2.55 5.07 2.52 3.91 C16 222.00 2.33 4.31 2.31 3.33 C17 237.00 2.43 4.20 2.40 3.24 C18 251.00 2.59 4.23 2.56 3.26 C19 263.00 2.64 4.11 2.60 3.17 C20 275.00 2.35 3.50 2.32 2.70 C21 291.00 2.29 3.22 2.26 2.49 C22 300.00 2.36 3.23 2.34 2.49 C23 312.00 2.12 2.78 2.09 2.15 C24 324.00 1.94 2.46 1.92 1.90 C25 337.00 1.97 2.40 1.95 1.85 C26 349.00 1.92 2.26 1.90 1.74 C27 360.00 1.78 2.02 1.76 1.56 C28 372.00 1.78 1.96 1.76 1.51 C29 382.00 1.79 1.91 1.76 1.48 C30 394.00 1.72 1.79 1.70 1.38 C31 404.00 1.29 1.31 1.28 1.01 C32 415.00 1.55 1.53 1.53 1.18 C33 426.00 0.84 0.81 0.83 0.62 C34 437.00 1.18 1.10 1.16 0.85 C35 445.00 1.05 0.96 1.03 0.74 C36+ 990.00 50.51 20.90 49,91 16.14 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.69 409.60 320.11 MOLE RATIO 0.2278 0.7722 011phase-DBR 39 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand Contam.wt% 1.72 STO(Demulsifier) Table 23:Calculated Fluid Properties Sample 1.01 &1.02;Cylinder CSB 4854-IA Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.08 0.01 99.88 99.27 98.70 76.66 C12+ 0.00 0.00 96.33 88.46 95.18 68.31 C20+ - - 78.44 54.13 77.51 41.80 C30+ - - 58.13 28.40 _ 57.44 21.93 C36+ - - 50.51 20.90 49.91 16.14 Molar Mass C7+ 107.49 412.12 412.11 C12+ 166.70 446.03 446.03 C20+ - 593.48 593.48 C30+ - 838.56 838.56 C36+ - 990.00 990.00 Density C7+ - 0.9521 - C12+ - 0.9597 0.9597 C20+ - 0.9922 0.9922 C30+ 1.0363 1.0363 C36+ 1.0571 1.0571 Fluid at 60°F 0.9515 Gas Gravity(Air=1) 0.576 Dry Gross Heat Content(BTU/scf) 1,017 Wet Gross Heat Content(BTU/scf 999 Demusifier Contamination Level(wt%) 1.7 STO Basis 1.7 Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 374.81 409.60 990.00 Density(g/cm3) 0.9515 0.9030 1.0571 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 91 93 STO Density(g/cm3) 0.9515 0.9565 STO API Gravity 17.2 16.4 De-emuslfier Density(g/cm3)@6 0.7340 011phase-DBR 40 Fle 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand Contam.wt% 1.72 STO(Demulsifier) Figure 17:Stock Tank Oil Chromatogram(Sample 1.01&1.02) Sample 1.01 &1.02;Cylinder CSB 4854-IA FIDI A (E,41PCHEtIl21DATP005002151CY8829.D) Non.- 250 JOB 200500215 CONOCO PHILIPS 1.04 CSB 8629-QA RF FLASH CYLINDER 200 150 100 t0 50 N ID m NNNNNNNiNNTrIl L N m U UUUUU�UUUUU J .X)• U ccccccccccccccccc c c c .>' Ux ` c _ I :I. TSITTrrr 0 5 10 15 20 25 30 35 miq Figure 18:k-Plot for Equilibrium Check(Sample 1.01&1.02) Sample 1.01 &1.02;Cylinder CSB 4854-IA 1.6 •iC4 •C3 1.4 - •nC4 1.2 - 1 - a •iC5 o, 0.8 0 •nC5 0.6 0.4 0.2 0 -4 -3 -2 -1 0 1 2 3 F 011phase-DBR 41 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand Contam.wt% 1.72 STO(Demulsifier( Figure 19:De-emulsifier Oil Chromatogram De-emulsifier F:61 u.M L DATA005002f[ - pA DEEMULSIFIER 140- CHROMATOGRAM 120- 100- BO- I 6 nC10 43- 1-111. 5 10 15 20 25 mir 011phase-DBR 42 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 24:C36+Composition,GOR,°API,by Zero-Hash(Sample 1.01&1.02) Sample 1.01 &1.02;Cylinder CSB 4832-IA Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1.31 0.50 0.00 0.00 0.03 0.16 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.96 0.58 0.00 0.00 0.02 0.19 Methane 16.04 91.78 96.84 0.00 0.00 1.90 31.22 Ethane 30.07 1.22 0.68 0.00 0.00 0.03 0.22 Propane 44.10 1.69 0.65 0.02 0.16 0.05 0.32 I-Butane 58.12 0.83 0.24 0.01 0.09 0.03 0.14 N-Butane 58.12 0.50 0.15 0.01 0.08 0.02 0.10 I-Pentane 72.15 0.64 0.15 0.04 0.20 0.05 0.19 N-Pentane 72.15 0.18 0.04 0.01 0.05 0.01 0.04 C6 84.00 0.33 0.07 0.09 0.41 0.09 0.30 M-C-Pentane 84.16 0.03 0.01 0.00 0.02 0.01 0.02 Benzene 78.11 0.01 0.00 0.00 0.02 0.00 0.01 Cyclohexane 84.16 0.04 0.01 0.01 0.03 0.01 0.02 C7 96.00 0.31 0.05 0.14 0.54 0.14 0.38 M-C-Hexane 98.19 0.03 0.00 0.01 0.02 0.01 0.02 Toluene 92.14 0.03 0.00 0.04 0.16 0.04 0.11 C8 107.00 0.05 0.01 0.18 0.62 0.17 0.43 E-Benzene 106.17 0.00 0.00 0.04 0.16 0.04 0.11 M/P-Xylene 106.17 0.010.00 0.01 0.04 0.01 0.03 O-Xylene 106.17 0.01 0.00 0.01 0.03 0.01 0.02 C9 121.00 0.02 0.00 0.29 0.93 0.29 0.63 C10 134.00 0.010.00__ 0.54 1.55 0.53 1.05 C11 147.00 0.01 0.00 0.92 2.39 0.90 1.62 C12 161.00 0.01 0.00 1.50 3.54 1.46 2.40 C13 175.00 0.00 0.00 1.98 4.31 1.94 2.92 C14 190.00 0.00 0.00 2.46 4.93 2.41 3.34 C15 206.00 0.00 0.00 2.81 5.20 2.75 3.53 C16 222.00 2.87 4.93 2.81 3.34 C17 237.00 2.84 4.56 2.78 3.09 C18 251.00 3.03 4.60 2.96 3.12 C19 263.00 2.87 4.16 2.81 2.82 C20 275.00 2.89 4.00 2.83 2.71 C21 291.00 2.89 3.78 2.83 2.56 C22 300.00 2.70 3.43 2.64 2.32 C23 312.00 2.66 3.25 2.61 2.20 C24 324.00 2.37 2.79 2.32 1.89 C25 337.00 2.37 2.68 2.32 1.82 I C26 349.00 2.13 2.32 2.08 1.57 C27 360.00 2.29 2.42 2.24 1.64 C28 372.00 2.55 2.61 2.49 1.77 C29 382.00 1.94 1.94 1.90 1.31 C30 394.00 1.91 1.84 1.87 1.25 C31 404.00 1.91 1.80 1.87 1.22 C32 415.00 1.75 1.60 1.71 1.09 C33 426.00 1.40 1.26 1.38 0.85 C34 437.00 1.14 0.99 1.11 0.67 C35 445.00 0.99 0.85 0.97 0.57 C36+ 884.70 43.40 18.70 42.51 12.67 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.93 381.17 263.74 MOLE RATIO 0.3224 0.6776 011phase-DBR 43 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 25:Calculated Fluid Properties Sample 1.01 &1.02;Cylinder CSB 4832-IA Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.56 0.10 99.82 99.01 97.76 67.12 C12+ 0.01 0.00 97.63 92.51 95.61 62.69 C20+ - - 77.27 56.27 75.67 38.13 C30+ - - 52.50 27.05 51.41 18.33 C36+ - - 43.40 18.70 42.51 12.67 Molar Mass C7+ 97.27 384.28 384.15 C12+ 161.00 402.26 402.26 C20+ - 523.45 523.45 C30+ - 739.82 739.82 C36+ - 884.70 884.70 Density C7+ - _ 0.9542 - C12+ - 0.9591 0.9591 C20+ - 0.9964 0.9964 C30+ 1.0598 _ 1.0598 C36+ 1.0958 1.0958 Fluid at 60°F 0.9533 Gas Gravity(Air=1) 0.584 Dry Gross Heat Content(BTU/scf) 1,037 Wet Gross Heat Content(BTU/scf 1,019 De-emuslfier Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW - 381.17 884.70 Density(g/cm3) 0.9533 0.9533 1.0958 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 158 STO Density(g/cm3) 0.9533 STO API Gravity 16.9 De-emuslfier Density(g/cm3)@6 - 011phase-DBR 44 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Figure 20:Stock Tank Oil Chromatogram(Sample 1.01 &1.02) Sample 1.01 &1.02;Cylinder CSB 4832-IA Fi[i 'F'2AkTA20051A0500215 Cr4832 Dl Norm- g� 180- 0° 160- 140 7 JOB 200500215 CONOCO PHILLIPS 1.01,1.02 CSB 4832-IA 120- RF FLASH CYLINDER 100- 80- 80- 1�N U N.m0)ONMT1411.0 .•M to I9 ��NNNNNNNNN W+� 4�eMo m rte N m U U O UUUUUU00000 �! T01 O U U c c c cc Cccccc cccc 0 5 10 16 20 25 30 35 mir Figure 21:k-Plot for Equilibrium Check(Sample 1.01 &1.02) Sample 1.01 &1.02;Cylinder CSB 4832-IA 2 •C3 1.5 •1C4 •nC4 1 •2C5 0.5 •C6 •C7 0 -0.5 - •-CB -1 -4 -3 -2 -1 0 1 2 3 011phase-DBR 95 File 200500215 r s Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand Table 26:Composition of Synthetic Recombination Gas for Sample(1.01&1.02) Sample 1.01 &1.02;Cylinder CSB 4832-IA Component MW Synthetic Gas wt% mol% CO2 44.01 0.928 0.352 H2S 34.08 0.000 0.000 N2 28.01 6.817 4.057 Cl 16.04 91.794 95.397 C2 30.07 0.208 0.115 C3 44.10 0.112 0.043 i-C4 58.12 0.055 0.016 n-C4 58.12 0.028 0.008 i-05 72.15 0.032 0.007 n-05 72.15 0.005 0.001 C6 84.00 0.019 0.004 Mcyclo-05 84.16 0.000 0.000 Benzene 78.11 0.000 0.000 Cyclo-C6 84.16 0.000 0.000 C7 96.00 0.000 0.000 Mcyclo-C6 98.19 0.000 0.000 Toluene 92.14 0.000 0.000 C8 107.00 0.000 0.000 C2-Benzene 106.17 0.000 0.000 m&p-Xylene 106.17 0.000 0.000 o-Xylene 106.17 0.000 0.000 C9 121.00 0.000 0.000 C10 134.00 0.000 0.000 C11 147.00 0.000 0.000 C12 161.00 0.000 0.000 Calculated MW g/mol 16.67 Gas Gravity Air=1 0.575 011phase-DBR 46 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 27:Summary of Results of Sample RSS(1.01 +1.02) Sample RSS(1.01 +1.02);Cylinder CSB 4832-IA;Depth 5697 ft MD Reservoir Conditions: Pressure: 1490 psia Temperature: 70 °F Summary of Fluid Properties: OBM Contamination: - Wt%STO Basis OBM Contamination: - Wt%RF Basis Bubble Point Pressure At Tres 1,304 psia At 130°F psia At 100°F - psia Gas-Oil Ratio Single-stage Flash: 158 scf/stb Total Differential Liberation: - scf/stb Total Separator Flash: 150 scf/stb Properties at 60°F STO°API Gas Gravity(Average) Single-stage STO: 16.9 0.584 Differential Liberation STO: - - Separator STO: 17.1 0.571 Properties at Reservoir Conditions Viscosity: 243.8 cP Compressibillity(Co): 7.74 10-6/psi Density: 0.9347 g/cc Properties at Saturation Conditions Viscosity: 239.4 cP Compressibillity(Co): 7.80 10-6/psi Density: 0.9327 g/cc Formation Volume Factor @Pres&Tres @Psat&Tres Single-stage Flash: 1.033 1.035 Total Differential Liberation: - - Total Separator Flash: 1.039 1.041 Note:Standard conditions are 14.696 psia and 60°F 011phase-DBR 47 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger PVT Analysis on Sample RSS(1.01 +1.02);Cylinder CSB 4832-IA; Depth 5697 ft MD,B Sand Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 70.0°F and at a pressure of 5,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 28. The pressure-volume (P-V)plots of the CCE data are presented in Figure 22.The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,304 psia at the reservoir temperature of 70.0°F.Also,calculated relative volume and oil compressibility is presented in Table 28.As seen in the table,the compressibility of this oil is 7.8 x 10e-6 1/psia at the saturation pressure. Table 28:Constant Composition Expansion at 70.0°F(Sample 1.01&1.02 RSS) Sample RSS(1.01 +1.02);Cylinder CSB 4832-IA;Depth 5697 ft MD Date:08/25/2001 Pressure Relative Vol %Liquid %Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VI/Vsat) (Vl/Vtotal) (g/cm3) (104/psia) 1 5015 0.9740 100.0 97.4 0.9586 6.66 2 4020 0.9800 100.0 98.0 0.9523 6.95 3 3017 0.9870 100.0 98.7 0.9454 7.25 4 2019 0.9950 100.0 99.5 0.9383 7.57 5 1716 0.9970 100.0 99.7 0.9363 7.66 6 1510 0.9980 100.0 99.8 0.9348 7.73 Pi 1490 0.9980 100.0 99.9 0.9347 7.74 Pb 1304 1.0000 100.0 100.0 0.9333 7.80 9 1185 1.0190 98.1 99.9 5.3 10 1090 1.0390 96.1 99.8 5.1 11 1010 1.0600 94.1 99.7 4.9 12 919 1.0880 91.5 99.6 4.7 13 871 1.1070 89.9 99.6 4.6 14 793 1.1440 86.9 99.5 4.5 15 680 1.2100 82.1 99.3 4.4 16 540 1.3300 74.6 99.2 4.3 17 375 1.5830 62.5 99.0 4.3 18 260 1.9530 50.6 98.9 4.2 011phase-DBR 48 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Figure 22:Constant Composition Expansion at 70.0°F-Relative Volume Sample ASS(1.01 +1.02);Cylinder CSB 4832-IA; Depth 5697 ft MD 2.2 2.0 0 1.8 a d 5 1.6 • E 0 .W 1.4 0 're • 1.2 • • • • • • 1.0 •• • • • O .. 0.8 0 1000 2000 3000 4000 5000 6000 Pressure(psis) 011phase-DBR 49 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 70°F.These values as a function of selected pressure steps are summarized in Table 29.The liquid phase viscosity values are graphically presented in Figure 23. As seen in the figures and as expected,the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 29:Reservoir Fluid Viscosity 70°F Sample RSS(1.01 +1.02);Cylinder CSB 4832-IA; Depth 5697 ft MD Pressure Viscosity @ Tres (psia) (cP) 1 9915.7 1168.7 2 9042.7 996.9 3 8013.7 815.5 4 7010.7 685.0 5 6024.7 580.1 6 5029.7 486.1 7 4028.7 403.6 8 3518.7 371.7 9 3015.7 341.2 10 2527.7 305.7 11 2029.7 278.8 12 1528.7 250.4 Pb 1304.0 239.4 14 1161.7 273.7 15 1095.7 287.9 16 1020.7 309.6 17 937.7 333.9 18 831.7 359.8 19 712.7 389.8 20 639.7 428.0 STO 14.7 1325.0 011phase-DBR 50 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand Figure 23:Reservoir Fluid Viscosity 70°F Sample RSS(1.01 +1.02);Cylinder CSB 4832-IA; Depth 5697 ft MD 1400 - I 1200 1000 • 800 • •e • 600 • • 400 • • • • • • - • • 54 • 2 •• 00 0.0 2000.0 4000.0 6000.0 8000.0 10000.0 12000.0 Pressure(psia) 011phase-DBR 51 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 30 - 32. The fluid properties(i.e., GOR, density and oil formation volume factor)are presented in Table 30. Multi-stage separation test conditions are: STAGE Pb 1304 psia 70 °F STAGE 1 105 psia 125 °F STAGE 2 75 psia 185 °F STAGE STO 15 psia 60 °F As seen in Table 30,the GOR value obtained from the multi-stage separation test is 150 SCF/STB and the formation volume factor is 1.041. The compositional analyses of separator gas and tank gas are summarized in Table 31 and the composition of tank liquid is tabulated in Table 32.The total dry gross heat content of the separation gases is calculated to be 1,017 BTU/scf whereas the total wet gross heat content is calculated to be 1027 BTU/scf. 011phase-DBR 52 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 30:Multi-Stage Separation Test Vapor&Liquid Properties Sample RSS(1.01 +1.02);Cylinder CSB 4832-IA; Depth 5697 ft MD PROPERTY STAGE Pb STAGE 1 STAGE 2 STAGE STO Pressure(psia) 1304 105 75 14.7 Temperature(°F) 70 125 185 60 Liquid Density(g/cm3) 0.9333 0.9501 0.9489 0.9525 Vap.Gravity' 0.570 0.579 0.599 Vap.M„,,, 16.52 16.75 17.34 Vap Heat Val." 1016 1029 1034 GOR` 140 3 6 GORd 140 3 6 Sep.FVF° 1.041 1.004 1.005 1.000 a)Calculated,at 60°F(air=1) b)Calculated,Dry basis BTU/scf c)scf gas/bbl of oil at STD conditions d)scf gas/bbl of oil at separator conditions e)fluid volume at sep conditions/fluid volume at STD conditions Residual oil density at standard conditions 0.9525 g/cc Sep gas gravity(average) Sa=ERjSgj/ER 0.571 Where: R:GOR(scf gas/bbl of oil at STD conditions), j:separator stages Sep gas gross heating value ILS=ERi*Lci/ERi 1017 BTU/scf(dry basis) Where: R:GOR(scf gas/bbl of oil at STD conditions), j:separator stages SEPARATION TEST SUMMARY °Total Separation Test GOR 150 Separation Test STO Gravity 17.1 bSeparation Test FVF 1.041 a)scf gas/bbl of condensate at STD conditions b)Fluid volume at Psat&Tres/Fluid volume at STD 011phase-DBR 53 File 200500215 L . Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger Table 31:Multi-Stage Separator Test Vapor Composition(mol%) Sample RSS(1.01 +1.02); Cylinder CSB 4832-IA;Depth 5697 ft MD Component MW Mole% (g/mol) STAGE Pb STAGE 1 STAGE 2 STAGE STO Carbon Dioxide 44.01 0.48 0.49 0.86 Hydrogen Sulfide 34.08 0.00 0.00 0.00 Nitrogen 28.01 0.55 0.51 1.55 Methane 16.04 97.91 97.12 95.58 Ethane 30.07 0.64 0.89 0.81 Propane 44.10 0.18 0.56 0.47 I-Butane 58.12 0.06 0.15 0.08 N-Butane 58.12 0.03 0.09 0.09 I-Pentane 72.15 0.03 0.08 0.04 N-Pentane 72.15 0.03 0.02 0.09 C6 84.00 0.03 0.04 0.05 M-C-Pentane 64.16 0.00 0.00 0.00 Benzene 78.11 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 C7 96.00 0.01 0.00 0.01 M-C-Hexane 98.19 0.00 0.00 0.00 Toluene 92.14 0.03 0.00 0.03 C8 107.00 0.00 0.00 0.01 E-Benzene 106.17 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.01 0.04 0-Xylene 106.17 0.00 0.01 0.01 C9 121.00 0.00 0.01 0.02 C10 134.00 0.00 0 00 0.02 C11 147.00 0.00 0.00 0.12 C12 161.00 0.00 0.00 0.10 C13 175.00 0.00 0.00 0.01 C14 190.00 0.00 0.00 0.00 C15 206.00 0.00 0.00 0.00 C16 222.00 0.00 0.00 0.00 C17 237.00 0.00 0.00 0.00 C18 251.00 0.00 0.00 0.00 C19 263.00 0.00 0.00 0.00 C20 275.00 0.00 0.00 0.00 C21 291.00 0.00 0.00 0.00 C22 300.00 0.00 0.00 0.00 C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 0.00 C25 337.00 0.00 0.00 0.00 C26 349.00 0.00 0.00 0.00 C27 360.00 0.00 0.00 0.00 C28 372.00 0.00 0.00 0.00 C30 394.00 0.00 0.00 0.00 C31 404.00 0.00 0.00 0.00 C32 415.00 0.00 0.00 0.00 C33 426.00 0.00 0.00 0.00 C34 437.00 0.00 0.00 0.00 C35 445.00 0.00 0.00 0.00 C36+ 884.70 0.00 0.00 0.00 Total 100.00 100.00 100.00 MW 16.52 16.75 17.34 Relative Density(air=1l 0.570 0.579 0.599 Dry Gross Heat Content(BTU/scf) 1016 1029 1034 011phase-DBR 54 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand Table 32:Multi-Stage Separator Test Residual Liquid Composition(mol%) Sample RSS(1.01 +1.02);Cylinder CSB 4832-IA;Depth 5697 ft MD COMPONENT MW Residual Liq. (g/moll Imo!%) Methane 16.04 0.00 Ethane 30.07 0.00 Propane 44.10 0.44 I-Butane 58.12 0.14 N-Butane 58.12 0.11 I-Pentane 72.15 0.24 N-Pentane 72.15 0.09 C6 84.00 0.44 M-C-Pentane 84.16 0.05 Benzene 78.11 0.04 Cyclohexane 84.16 0.06 C7 96.00 1.05 M-C-Hexane 98.19 0.02 Toluene 92.14 0.28 C8 107.00 0.62 E-Benzene 106.17 0.06 M/P-Xylene 106.17 0.02 O-Xylene 106.17 0.05 C9 121.00 0.95 C10 134.00 1.86 C11 147.00 2.77 C12 161.00 3.98 C13 175.00 4.86 C14 190.00 5.24 C15 206.00 5.79 C16 222.00 4.94 C17 237.00 4.76 C18 251.00 4.79 C19 263.00 4.58 C20 275.00 3.84 C21 291.00 3.72 C22 300.00 3.35 C23 312.00 2.84 C24 324.00 2.57 C25 337.00 2.25 C26 349.00 2.10 C27 360.00 2.09 C28 372.00 1.87 C29 382.00 1.63 C30 394.00 1.56 C31 404.00 1.25 C32 415.00 0.93 C33 426.00 0.81 C34 437.00 0.77 C35 445.00 0.61 C36+ 884.70 19.60 Total 100.00 MW 376.14 011phase-DBR 55 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 33:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.11,1.12&1.13) Sample 1.11, 1.12&1.13;Cylinder CSB 4881-IA Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1.31 0.50 0.00 0.00 0.03 0.17 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 2.91 1.75 0.00 0.00 0.06 0.58 Methane 16.04 92.09 96.78 0.00 0.00 1.86 31.92 Ethane 30.07 0.61 0.34 0.00 0.00 0.01 0.11 Propane 44.10 0.44 0.17 0.01 0.13 0.02 0.14 I-Butane 58.12 0.11 0.03 0.00 0.02 0.00 0.02 N-Butane 58.12 0.09 0.03 0.00 0.01 0.00 0.01 I-Pentane 72.15 0.07 0.02 0.00 0.01 0.00 0.01 N-Pentane 72.15 0.27 0.06 0.00 0.01 0.01 0.03 C6 84.00 0.11 0.02 0.06 0.31 0.07 0.21 M-C-Pentane 84.16 0.01 0.00 0.01 0.05 0.01 0.04 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.00 0.00 0.00 0.02 0.00 0.01 C7 96.00 0.09 0.02 0.22 0.94 0.22 0.64 M-C-Hexane 98.19 0.02 0.00 0.01 0.02 0.01 0.02 Toluene 92.14 0.28 0.05 0.00 0.01 0.01 0.02 C8 107.00 0.07 0.01 0.06 0.24 0.06 0.16 E-Benzene 106.17 0.01 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.66 0.11 0.00 0.01 0.02 0.04 O-Xylene 106.17 0.09 0.02 0.00 0.02 0.01 0.02 C9 121.00 0.41 0.06 0.05 0.16 0.06 0.13 010 134.00 0.18 0.02 0.10 0.30 0.10 0.21 C11 147.00 0.11 0.01 0.42 1.16 0.42 0.78 C12 161.00 0.03 0.00 0.98 2.44 0.96 1.63 C13 175.00 0.00 0.00 1.80 4.13 1.76 2.77 C14 190.00 0.01 0.00 2.19 4.64 2.15 3.11 C15 206.00 0.00 0.00 2.50 4.89 2.45 3.27 C16 222.00 0.00 0.00 2.59 4.69 2.53 3.14 C17 237.00 0.00 0.00 2.98 5.06 2.92 3.39 C18 251.00 0.00 0.00 2.99 4.79 2.93 3.21 C19 263.00 0.00 0.00 2.88 4.40 2.82 2.95 C20 275.00 0.00 0.00 3.10 4.54 3.04 3.04 C21 291.00 0.00 0.00 2.94 4.07 2.88 2.73 C22 300.00 0.00 0.00 2.98 4.00 2.92 2.68 C23 312.00 0.00 0.00 3.05 3.93 2.98 2.63 C24 324.00 0.00 0.00 2.68 3.33 2.62 2.23 C25 337.00 0.00 0.00 2.91 3.48 2.85 2.33 C26 349.00 0.00 0.00 2.23 2.57 2.18 1.72 C27 360.00 0.00 0.00 2.73 3.05 2.67 2.04 C28 372.00 0.00 0.00 2.58 2.80 2.53 1.87 C29 382.00 0.00 0.00 2.76 2.91 2.70 1.95 C30 394.00 0.00 0.00 1.79 1.82 1.75 1.22 C31 404.00 0.00 0.00 2.16 2.16 2.12 1.45 C32 415.00 0.00 0.00 1.63 1.59 1.60 1.06 C33 426.00 0.00 0.00 1.23 1.16 1.20 0.78 C34 437.00 0.00 0.00 1.49 1.37 1.46 0.92 C35 445.00 0.00 0.00 1.53 1.38 1.50 0.93 C36+ 978.00 0.00 0.00 42.37 17.44 41.51 11.69 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.85 402.51 275.30 MOLE RATIO 32.9870 67.0130 011phase-DBR 56 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 34:Calculated Fluid Properties Sample 1.11, 1.12&1.13; Cylinder CSB 4881-IA •Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole°A° C7+ 2.00 0.31 99.92 99.53 97.94 66.80 C12+ 0.04 0.00 99.03 96.59 97.03 64.73 C20+ - - 80.14 61.56 78.52 41.26 C30+ - - 52.20 26.91 51.14 18.04 C36+ - - 42.37 17.44 41.51 11.69 Molar Mass C7+ 110.72 404.38 403.94 C12+ 168.86 412.67 412.67 .C20+ - _ 523.98 523.98 C30+ 780.62 780.62 C36+ - 978.00 978.00 Density C7+ - 0.9030 0.903 C12+ - 0.9044 0.9044 C20+ - 0.9198 0.9198 C30+ 0.9365 0.9365 C36+ 0.9410 0.9410 Fluid at 60°F 0.9581 Gas Gravity(Air=1) 0.582 Dry Gross Heat Content(BTU/scf) 1,014 Wet Gross Heat Content(BTU/scf 996 OBM Contamination Level(wt%) - STD Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 402.51 978.00 Density(g/cm3) 0.9580 0.9020 0.9410 Single Stage Flash Data Original STO De-Contaminated GOA(scf/stb) 156 _ - STO Density(g/cm3) _ 0.9581 - STO API Gravity 16.2 - OBM Density(g/cm3)©60°F - 011phase-DBR 57 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Figure 24:Stock Tank Oil Chromatogram(Sample 1.11,1.12&1.13) Sample 1.11,1.12&1.13;Cylinder CSB 4881-IA FID1 A, E OCHEMATA100500215iCY8020.D) Nom. ti 250 JOB 200500215 CONOCO PHILIPS 1.04 CSB 8629-QA RF FLASH CYLINDER 200- 150- . • 100- , Q113. Ul _ Nrpo 50- (. N W N N N NryN NNCITri 1 coo U U n00000cccc 00000ccccccoun }v 0) c U U c c c c tett °), U X0 U U c c I 5 10 15 20 25 30 35 mir Figure 25:k-Plot for Equilibrium Check(Sample 1.11,1.12&1.13) Sample 1.11, 1.12&1.13;Cylinder CSB 4881-IA Ii 2.5 2 - •nC5 •nC4 •iC5 1.5 •tC4 •C3 a 1 Y • OJ 0.5 - •CB 0 •C6 -0.5 - •C7 -1 -2 -1.5 -1 -0.5 0 0.5 1 1.5 2 2.5 3 F 011phase-DBR 58 File 200500215 e Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 35:C12+Composition of Synthetic Recombination Gas for Sample(1.11,1.12&1.13) Sample 1.11, 1.12&1.13;Cylinder CSB 4881-IA Component MW Synthetic Gas wt% mol% CO2 44.01 0.652 0.246 H2S 34.08 0.000 0.000 N2 28.01 7.073 4.201 Cl 16.04 92.001 95.422 C2 30.07 0.168 0.093 C3 44.10 0.083 0.031 i-C4 58.12 0.009 0.003 n-C4 58.12 0.003 0.001 i-05 72.15 0.002 0.000 n-05 72.15 0.001 0.000 C6 84.00 0.007 0.001 Mcyclo-05 84.16 0.000 0.000 Benzene 78.11 0.000 0.000 Cyclo-C6 84.16 0.000 0.000 C7 96.00 0.000 0.000 Mcyclo-C6 98.19 0.000 0.000 Toluene 92.14 0.000 0.000 C8 107.00 0.000 0.000 C2-Benzene 106.17 0.000 0.000 m&p-Xylene 106.17 0.000 0.000 o-Xylene 106.17 0.000 0.000 C9 121.00 0.000 0.000 C10 134.00 0.000 0.000 C11 147.00 0.000 0.000 C12 161.00 0.000 0.000 Calculated MW g/mol 16.64 Gas Gravity Air=1 0.574 011phase-DBR 59 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 36:Summary of Results of Sample RSS(1.11 +1.12+1.13) Sample RSS(1.11 +1.12+1.13);Cylinder CSB 4881-IA;Depth 5553 ft.MD Reservoir Conditions: Pressure: 1450 psia Temperature: • 69 °F Summary of Fluid Properties: OBM Contamination: - Wt%STO Basis • OBM Contamination: - Wt%RF Basis Bubble Point Pressure At Tres - psia At 130°F - psia At 100°F 1,574 psia Gas-Oil Ratio Single-stage Flash: 156 scf/stb Total Differential Liberation: - scf/stb Total Separator Flash: 156 scf/stb Properties at 60°F STO°API Gas Gravity(Average) Single-stage STO: 16.1 0.582 Differential Liberation STO: - - Separator STO: 16.3 0.572 Properties at Reservoir Conditions Viscosity: - cP Compressibillity(Co): - 10-6/psi Density: - g/cc Properties at Saturation Conditions Viscosity(69°F): 536.3 cP Compressibillity(100°Fl: 6.02 10-6/psi Density(100°F): 0.9186 g/cc Formation Volume Factor @Pres&Tres @Psat&100°F Single-stage Flash: - 1.068 Total Differential Liberation: - - Total Separator Flash: - 1.063 Note:Standard conditions are 14.696 psia and 60°F. Reported FVF values are on abasis of 100°F. 011phase-DBR 60 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger PVT Analysis on Sample RSS(1.11 +1.12+1.13);Cylinder CSB 4881-1k Depth 5553 ft.MD,D Sand Constant Composition Expansion at 100°F The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a special test temperature of 100°F and at a pressure of 5,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 37.The pressure-volume (P-V)plots of the CCE data are presented in Figure 26.The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid,the bubblepoint was determined to be 1,574 psia at the measurement temperature of 100°F. Table 37:Constant Composition Expansion at 100°F(Sample RSS 1.11+1.12+1.13) Sample RSS(1.11 +1.12+1.13);Cylinder CSB 4881-IA; Depth 5553 ft. MD Pressure Relative Vol %Liquid %Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VINsat) (VlNtotal) (g/cm3) (10°/psia) 1 5015 0.9820 100.0 98.18 0.9356 4.69 2 4513 0.9840 100.0 98.42 0.9334 4.87 3 4013 0.9870 100.0 98.66 0.9311 5.05 4 3515 0.9890 100.0 98.92 0.9287 5.23 5 3016 0.9920 100.0 99.18 0.9262 5.42 6 2515 0.9950 100.0 99.45 0.9237 5.62 7 2012 0.9970 100.0 99.74 0.9210 5.83 8 1913 0.9980 100.0 99.80 0.9205 5.87 9 1815 0.9990 100.0 99.86 0.9199 5.91 10 1731 0.9990 100.0 99.91 0.9195 5.95 11 1623 1.0000 100.0 99.97 0.9189 6.00 Pb 1574 1.0000 100.0 100.00 0.9186 6.02 13 1451 1.0120 98.8 100.00 7.0 14 1373 1.0220 97.9 99.99 6.8 15 1287 1.0340 96.6 99.91 6.5 16 1182 1.0540 94.8 99.85 6.2 17 1071 1.0800 92.4 99.76 5.9 18 833 1.1680 85.3 99.55 5.3 19 622 1.3190 75.4 99.39 4.8 20 414 1.6240 61.1 99.25 4.5 21 228 2.3650 41.9 99.13 4.3 011phase-DBR 61 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 38:Simulated Constant Composition Expansion at 69°F(Sample RSS 1.11+1.12+1.13) Sample RSS(1.11 +1.12+1.13);Cylinder CSB 4881-IA;Depth 5553 ft. MD Pressure Relative Vol %Liquid %Liquid Liquid Density Y Function Compressibility (psia) (Vr=V/Vsat) (VlNsat) (VI/Vtotal) (9/cm3) (108/psia) 1 5015 0.9913 99.1 100.00 0.9332 2.03 2 4513 0.9923 99.2 100.00 0.9323 2.13 3 4013 0.9934 99.3 100.00 0.9312 2.23 4 3515 0.9945 99.5 100.00 0.9302 2.34 5 3016 0.9957 99.6 100.00 0.9291 2.46 6 2515 0.9970 99.7 100.00 0.9279 2.59 7 2012 0.9983 99.8 100.00 0.9267 2.73 8 1913 0.9986 99.9 100.00 0.9264 2.76 9 1815 0.9988 99.9 100.00 0.9262 2.79 10 1731 0.9991 99.9 100.00 0.9259 2.82 11 1623 0.9994 99.9 100.00 0.9257 2.85 12 1574 0.9995 100.0 100.00 0.9255 2.87 13 1451 0.9999 100.0 100.00 0.9252 2.91 Pb 1407 1.0000 100.0 100.00 0.9251 2.92 15 1373 1.0043 99.9 99.47 5.8 16 1287 1.0167 99.6 97.97 5.6 17 1182 1.0356 99.2 95.83 5.3 18 1071 1.0613 98.8 93.13 5.1 19 833 1.1473 98.0 85.39 4.7 20 622 1.2905 97.2 75.31 4.3 21 414 1.5908 96.4 60.60 4.1 011phase-DBR 62 File 200500215 i Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Figure 26:Constant Composition Expansion at 100°F-Relative Volume Sample RSS(1.11 +1.12+1.13);Cylinder CSB 4881-IA;Depth 5553 ft.MD 2.6 2.4 • 2.2 2.0 g 1.8 0 0 1.6 • • G 1.4 • 1.2 • • •• • 0.8 0 1000 2000 3000 4000 5000 6000 Pressure 1psia) 011phase-DBR 63 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 69°F.These values as a function of selected pressure steps are summarized in Table 39.The liquid phase viscosity values are graphically presented in Figure 27. As seen in the figures and as expected,the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 39:Reservoir Fluid Viscosity 69°F Sample RSS(1.11 +1.12+1.13);Cylinder CSB 4881-IA;Depth 5553 ft.MD Pressure Viscosity @ Tres (psia) (cP) 1 4724 1131.1 2 3655 887.7 3 2605 694.2 4 1539 550.0 Pb* 1392 536.3 7 1085 591.3 8 855 681.2 9 696 783.1 10 590 894.4 11 468 1011.1 STO 15 3210.1 * Approximation to actual saturation point. 011phase-DBR 64 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Figure 27:Reservoir Fluid Viscosity 69°F Sample BSS(1.11 +1.12+1.13); Cylinder CSB 4881-IA; Depth 5553 ft. MD 3400 - • 2900 2400 1900 0 1400 • • 900 `• • • • • • • 400 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 Pressure 1psia) 011phase-DBR 65 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 40 -42. The fluid properties (i.e., GOR, density and oil formation volume factor)are presented in Table 40.Multi-stage separation test conditions are: STAGE Pb 1574 psia 100 °F STAGE 1 105 psia 125 °F STAGE 2 75 psia 185 °F STAGE STO 15 psia 60 °F As seen in Table 40,the GOR value obtained from the multi-stage separation test is 156 SCF/STB,and the formation volume factor is 1.063,relative to initial saturated volume at 100°F.The compositional analyses of separator gas and tank gas are summarized in Table 41 and the composition of tank liquid is tabulated in Table 42.The total dry gross heat content of the separation gases is calculated to be 1,000 BTU/scf. 011phase-DBR 66 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 40:Multi-Stage Separation Test Vapor&Liquid Properties Sample ASS(1.11 +1.12+1.13);Cylinder CSB 4881-IA; Depth 5553 ft.MD PROPERTY STAGE Pb STAGE 1 STAGE 2 STAGE STO Pressure(psi. 1574 105 75 14.7 Temperature I 100 125 185 60 Liquid Density(g/cm3) 0.9186 0.9447 0.9360 0.9573 Vap.Gravity' 0.571 0.573 0.594 Vap.M,,,,, 16.54 16.60 17.20 Vap Heat Val." 998 1010 1046 GOR` 0 147 5 4 GOR° 0 144 5 4 Sep.FVF° 1.063 1.015 1.023 1.000 a)Calculated,at 60°F(air=1) b)Calculated,Dry basis BTU/scf c)scf gas/bbl of oil at STD conditions d)scf gas/bbl of oil at separator conditions e)fluid volume at sep conditions/fluid volume at STD conditions Residual oil density at standard conditions 0.9573 g/cc Sep gas gravity(average) Sg=ERjSgj/ER 0.572 Where: A:GOR(scf gas/bbl of oil at STD conditions), j:separator stages Sep gas gross heating value IL,=ERi*Lci/ERi 1000 BTU/scf(dry basis) Where: R:GOR(scf gas/bbl of oil at STD conditions), j:separator stages SEPARATION TEST SUMMARY 'Total Separation Test GOR 156 Separation Test STO Gravity 16.31 'Separation Test FVF 1.063 a)scf gas/bbl of condensate at STD conditions b)Fluid volume at Psat&Tres/Fluid volume at STD 011phase-DBR 67 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 41:Multi-Stage Separator Test Vapor Composition(mol%) Sample RSS(1.11 +1.12+1.13);Cylinder CSB 4881-IA;Depth 5553 ft.MD Component MW Mole% (g/mol) STAGE Pb STAGE 1 STAGE 2 STAGE STO Carbon Dioxide 44.01 0.45 0.66 0.86 Hydrogen Sulfide 34.08 0.00 0.00 0.00 Nitrogen 28.01 1.78 0.91 0.40 Methane 16.04 97.24 97.44 96.73 Ethane 30.07 0.29 0.54 0.81 Propane 44.10 0.11 0.26 0.47 I-Butane 58.12 0.02 0.04 0.08 N-Butane 58.12 0.02 0.05 0.09 I-Pentane 72.15 0.01 0.02 0.04 N-Pentane 72.15 0.01 0.02 0.09 C6 84.00 0.01 0.02 0.05 M-C-Pentane 84.16 0.00 0.00 0.00 Benzene 78.11 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 C7 96.00 0.01 0.01 0.01 M-C-Hexane 98.19 0.00 0.00 0.00 Toluene 92.14 0.00 0.00 0.03 C8 107.00 0.01 0.01 0.01 E-Benzene 106.17 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.04 0-Xylene 106.17 0.00 0.00 0.01 C9 121.00 0.01 0.00 0.02 C10 134.00 0.00 0.00 0.02 C11 147.00 0.00 0.00 0.12 C12 161.00 0.00 0.00 0.10 C13 175.00 0.00 0.00 0.01 C14 190.00 0.00 0.00 0.00 C15 206.00 0.00 0.00 0.00 C16 222.00 0.00 0.00 0.00 C17 237.00 0.00 0.00 0.00 C18 251.00 0.00 0.00 0.00 C19 263.00 0.00 0.00 0.00 C20 275.00 0.00 0.00 0.00 C21 291.00 0.00 0.00 0.00 C22 300.00 0.00 0.00 0.00 C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 0.00 C25 337.00 0.00 0.00 0.00 C26 349.00 0.00 0.00 0.00 C27 360.00 0.00 0.00 0.00 C28 372.00 0.00 0.00 0.00 C30 382.00 0.00 0.00 0.00 C30 394.00 0.00 0.00 0.00 C31 404.00 0.00 0.00 0.00 C32 415.00 0.00 0.00 0.00 C33 426.00 0.00 0.00 0.00 C34 437.00 0.00 0.00 0.00 C35 445.00 0.00 0.00 0.00 C36+ 978.00 0.00 0.00 0 00 Total 100.00 100.00 100.00 MW 16 54 16.60 1720 Relative Density(air=1) 0 571 0.573 0.594 Dry Gross Heat Content(BTU/scf) 998 1010 1046 011phasa-DBR 68 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger Table 42:Multi-Stage Separator Test Residual Liquid Composition(mol%) Sample RSS(1.11 +1.12+1.13);Cylinder CSB 4881-IA; Depth 5553 ft.MD COMPONENT MW Residual Lig. (g/mol) (moi%) Carbon Dioxide 44.01 0.00 Hydrogen Sulfide 34.08 0.00 Nitrogen 28.01 0.00 Methane 16.04 0.00 Ethane 30.07 0.00 Propane 44.10 0.10 1-Butane 58.12 0.02 N-Butane 58.12 0.01 I-Pentane 72.15 0.01 N-Pentane 72.15 0.01 C6 84.00 0.21 M-C-Pentane 84.16 0.03 Benzene 78.11 0.00 Cyclohexane 84.16 0.00 C7 96.00 0.58 M-C-Hexane 9819 0.00 Toluene 92.14 0.00 08 107.00 0.08 E-Benzene 106.17 0.00 M/P-Xylene 106.17 0.00 0-Xylene 106.17 0.01 C9 121.00 0.07 C10 134.00 0.27 011 147.00 1.11 C12 161.00 2.42 C13 175.00 4.16 C14 190.00 4.67 015 206.00 4.97 216 222.00 5.14 217 237.00 4.78 C18 251.00 4.53 219 263.00 4.68 220 275.00 4.52 221 291.00 4.05 222 300.00 4.07 223 312.00 3.86 224 324.00 3.17 225 337.00 3.69 226 349.00 2.66 227 360.00 3.10 :28 372.00 2.89 229 382.00 3.00 230 394.00 1.91 231 404.00 2.25 232 415.00 1.88 C33 426.00 1.38 234 437.00 1.41 335 445.00 1.21 236+ 978.00 17.06 Total 100.00 W 402.28 011phase-DBR 69 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: Schlumberger Installation: - Job#: 200500215 Appendix A: Nomenclature and Definitions API Gravity American Petroleum Institute gravity Bg Gas formation volume factor Bo Oil formation volume factor CCE Constant composition Expansion DV Differential Vaporization GLR Gas Liquid Ratio GOR Gas Oil Ratio LO Live Oil n Number of moles OBM Oil Based Mud P Absolute pressure Pb Bubble point pressure PV Pressure-Volume Method Pi Initial Reservoir Pressure R Universal gas constant Rs Solution gas oil ratio T Temperature V Volume Vr Relative volume STL Stock Tank Liquid STO Stock Tank Oil %,w/w Weight Percent Z Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid.Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses, densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems"by M.B.Standing Compressibility in constant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation(Gas deviation factor,1=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. 011phase-DBR 70 File 200500215 p Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: Schlumberger Installation: - Job#: 200500215 Appendix B: Molecular Weights and Densities Used Components MW Density (g/cc) CO2 44.01 0.827 H2S 34.08 0.993 N2 28.013 0.808 Cl 16.043 0.300 C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 N-C4 58.124 0.586 I-05 72.151 0.625 N-05 72.151 0.631 C6 84 0.660 MCYC-05 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0.781 C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 CB 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 0-XYLENE 106.17 0.884 C9 121 0.768 C10 134 0.782 C11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 C15 206 0.836 C16 222 0.843 C17 237 0.851 C18 251 0.856 C19 263 0.861 C20 275 0.866 C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0.885 C25 337 0.888 C26 349 0.892 C27 360 0.896 C28 372 0.899 C29 382 0.902 011phase-DBB 71 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: Schlumberger Installation: - Job#: 200500215 Appendix C: EQUIPMENT Fluid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently,the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder.Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature.The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies.A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer.This unit in conjunction with GC analysis(see below)provides the full fluid compositional analysis,GOR,density at sampling P&T corrected to standard conditions.The JEFRI gasometer consists of a motor-driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure.Piston motion is tracked by a linear encoder,which is subsequently,converted to measure the gas volume in the cylinder.The total Gasometer volume is 10 L.The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr.The operating pressure of the Gasometer is ambient pressure(up to a maximum of 40 psia)and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer,compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography(GC). Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector(FID). In this system,separation of individual components is carried out in a 30m long,530mm diameter"Megabore"capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase.The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range,the components eluted are from C1 to C36 along with naphthenes and aromatics components.Based on the physical properties,these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas(helium)through the column.With prior knowledge of the amount of"retention"for known compounds contained in calibration standards,the same compounds can be identified in the unknown hydrocarbon sample by matching"retention" times.The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns.The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas.The molecular sieve is used to achieve separation of the light gaseous components(nitrogen,oxygen,and methane)while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis.This column is capable of achieving separation of components up to Cep+, along with the associated naphthenes and aromatics that are lumped into the C6. fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector(TCD)while the C5,components are analyzed for using a FID detector.The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns,and hence,allowing for the correct separation and analysis of the injected gas. Fluid Volumetric(PVT)and Viscosity Equipment 011phase-DBR 72 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: - Schlumberger Installation: - Job#: 200500215 The preliminary saturation pressure,constant composition expansion(CCE),differential vaporization(DV), multi-stage separation tests (MSST)are measured using a pressure-volume-temperature(PVT)apparatus.The PVT apparatus consists of a variable volume,visual JEFRI PVT cell.The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm.An especially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury free operation.The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content.The piston allows liquid level measurements as small as 0.005 cc.The magnetically coupled impeller mixer,mounted on the bottom end cap of the PVT cell,allow quick equilibration of the hydrocarbon fluid.The effective volume of the cell is approximately 120 cc.The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. A variable volume JEFRI displacement pump controls the volume,and hence,the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell.The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder.The PVT cell is mounted on a special bracket,which can be rotated 360°.The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven.The cell temperature is measured with a platinum resistance thermal detector(RTD)and displayed on a digital indicator with an accuracy of 0.2°F.The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to± 0.1%of full scale.The temperature and pressure ratings of this PVT system are 15,000 psi(103 MPa)and 360°F(182°C). The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm.The cathetometer is equipped with a high-resolution video camera that minimizes parallax in readings and uses a high-resolution encoder producing both linear and volumetric readings.The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test. The floating piston is designed in the shape of a truncated cone with gradually tapered sides, which allows measurement of extremely small volumes of liquid(0.005 cc)corresponding to roughly 0.01%of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer,which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston.Viscosity is measured by the motion of the piston,which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall.Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity.The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe.The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig.The accuracy is±1.5%of full scale for each individual piston range.The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell(carrier chamber)with a maximum internal volume of 25 mL is attached at the top of the viscometer.The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer.The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber.The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. 011phase-DBR 73 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: - Schlumberger Installation: - Job#: 200500215 The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation (OHSP)due to changes in the temperature,pressure and/or composition.These fiber optic probes are mounted across the windows of the visual cell.The principle behind the measurement is based on the transmittance of a laser light in the near infra red(NIR)wavelength through the test fluid undergoing temperature, pressure or the fluid composition changes. In this system, a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation, isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies.The process variables(i.e.,temperature,pressure,solvent volume,time and transmitted light power level)are recorded and displayed from the detector.The fiber optic light transmittance system referred to here that detects the conditions of OHSP is termed as the light scattering system(LSS). 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. 011phese-DBR 74 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: - Schlumberger Installation: - Job St: 200500215 Appendix D:PROCEDURE Fluids Preparation and Validation After homogenizing,a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio(GOR).The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid.The atmospheric flash also provides parameters such as GOR and stock tank oil density.The flashed fluids(gas and liquid) are then subjected to compositional analysis using gas chromatographic technique.Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values.In addition,a sub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently,a quick P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature.The CCE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps.At each pressure step,the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium.Total fluid volume(with visual observation of a single or two phase condition in the cell)is measured at each pressure stage,and subsequently,a pressure-volume(P-V)plot is created identifying the phase state at each P-V condition.The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute live oil compressibility above the bubblepoint pressure and relative oil volumes over the entire pressure range. Differential Vaporization Procedure Subsequent to the completion of the CCE experiment,another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions.A differential vaporization(DV)experiment is then conducted by incrementally reducing the pressure in the PVT cell in discrete steps.In these steps,the pressure is reduced below the saturation pressure,and hence,allowing the gas phase to evolve.A typical pressure stage in a DV 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 DV test. • The pressure of the fluid is then reduced to the first pressure stage(below the bubblepoint pressure)of the DV test allowing free gas to evolve.The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. • The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure(see Fluid Analysis Equipment Section) • The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. Multi-Stage Separation Test 011phase-DBR 75 File 200500215 -0 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: - Schlumberger Installation: - Job#: 200500215 Subsequent to the completion of the DV experiment,another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions.A multi-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps.In these steps,the pressure is reduced below the saturation pressure,and hence,allowing the gas phase to evolve.A typical pressure stage in a separation test is described below: • The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil.This is the starting point of the separation test. • The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate.The pressure of the fluid is then reduced to the first pressure stage(below the bubblepoint pressure)of the separation test allowing free gas to evolve.The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. • The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure(see Fluid Analysis Equipment Section) The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity,a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. A portion of the live reservoir fluid used in the DV test is then transferred into a high-pressure high-temperature electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer,flashing of oil takes place,and hence,the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken.Subsequent to transfer of live reservoir fluid into the viscometer,the fluid system is allowed to achieve thermal and pressure equilibration.Then,the viscosity reading is taken.Following the viscosity reading,incremental pressure reduction steps are repeated as those used in DV steps.At each pressure point,the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration.The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock-Tank 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. Asphaltene, Wax and Sulfur Content Measurements 011phaaa-DBR 76 File 200500215 F , y Client: ConocoPhillips Field: West Sok Well: 3J-101 Sand: - Schlumberger Installation: - Job#: 200500215 Asphaltene content of stock-tank oil samples is conducted using the IP-143(French Institute of Petroleum)procedure.In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil.Wax content of the STO is measured using UOP (Universal Oil Product)46-64 procedure.The sulfur content of the STO is measured using ASTM D 2494 procedure. .All other STO analysis were measured according to industrial standards. SAR(P)A Analysis A spinning band distillation was carried out on the original sample to establish two fractions.The initial boiling point to 300°C fraction was then analysed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes).This method dissolves the fraction in an equal weight of toluene,then 40 volumes of pentane were added to precipitate the insoluble portion of the sample.The precipitate was filtered,dried and weighed.The solvent was removed from the soluble portion of the sample,which was referred to as the maltenes.The maltenes were then redissolved in pentane and were chromatographically separated into saturates,aromatics and resins(polars)fraction by elution from a column filled with activated alumina, using various solvents and solvent mixtures.The solvents were then removed from each fraction and the amount of material weighed. The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High-Temperature High Pressure filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence,high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. 011phase-DBR 77 File 200500215 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ©s- 1 ,~ ~ Well History File Identifier Organizing (done) ^ Two-sided III II~III II III II III ^ Rescan Needed RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~skettes, No. I ^ Maps: ~Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: NOTES Logs of various kinds: h O : er:: ^ t BY: Maria Date: ~ D g /s/ Project Proofing III IIIIIIIIIII IIIII BY: Maria Date: ~D D U lsl Scanning Preparation ~_ x 30 = ~ O ~ + ~ _ =TOTAL PAGES~d--' BY: Maria Date: ~~ / ~ $ (Count does not include cover sheet) /s/ Production Scanning Stage 1 Page Count from Scanned File: -~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~~~D~Q ~ lsl !M`~ ~ • `1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II I) II I II II I I III ReScanned III IIIIIIIIIII IIIN BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III IIII III P 10/6/2005 Well History File Cover Page.doc I ' • • cllal 0[F tata[KKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 3J -101 Sundry Number: 310 -423 e `Ulut w ore) AlA Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, f Daniel T. Seamount, Jr. Chair DATED this day of January, 2011. Encl. . • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 DEC 1 4 2010 Alaska Cii & Gas Cons. Commission December 11, 2010 Anchorage Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of Suspended Well 10 -403 Status Kuparuk River West Sak 3J -101 (PTD 205 -157) Dear Commissioner Seamount: ConocoPhillips Alaska Inc. (CPAI) hereby submits a request for renewal of the suspension status of Kuparuk River Unit well Kuparuk River West Sak 3J -101 (PTD 205 -157) per 20 AAC 25.110. The well was visually inspected September 29, 2010 and the results submitted on a 10 -404. The condition of the well is noted on an attached schematic and 10 -403 form. Please note the following: - The well bore is not perforated - The well has a cement retainer and cement plug in well bore - The well is on an active pad. CPAI request the renewal of the suspension because the well is being held for future West Sak development. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, q ✓ / ,f� v MJ Loveland ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA * ice ALAS IL AND GAS CONSERVATION COMMISSO \.�'� ` A' ` APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 aa00 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r ;I- \, Suspend Plug FFrforations r Perforate r Pull Tubing r Time Extension , Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r 2. Operator Name: 4. Current Well Class: 5. Permit to drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r. • 205 -157 • 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23283 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 3J -101 9. Property Designation: 10. Field /Pool(s): ADL 25630 • Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6274 • 3780 • 2200' • 1979' 2249' & 3530 -6274 NONE Casing Length Size MD ND Burst Collapse CONDUCTOR 110 20 140' 110' SURFACE 2342 10.75 2372' 2078' 3580 2090 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE NONE 3.5 L -80 1917' Packers and SSSV Type: None Packers and SSSV MD (ft) and ND (ft) NONE NONE 12. Attachments: Description Summary of Proposal r/ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service E 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: NA Oil r Gas r WDSPL r Suspended P. 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Lovland /Perry Klein Printed Name MJ Loveland /Perry Klein Title: Well Integrity Supervisor Signatur / 8 Phone: 659 -7043 Date f /- /d Commission Use Only Sundry Number: 4) 0 -Lid, `!S Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED Other: DEC 14 2010 Subsequent Form Required: N6 he etiF - 4 --AOT G iaska IA & Gas Cans. Co missi)n Anchorage APPROVED BY ���� Approved by: )4 ‘ COMMISSIONER THE COMMISSION Date: /� d "+ws AN oe ;iI ORIGINAL f 1> /2. ; , Form 10 -403 Revised 1/2010 Submit in Duplicate • • • Tree: (2) Vetco 4 -118 x 5ksi valves 3J -707 Surface Location: Fading: 519,545 Tubing Hanger: Vetco, with 3- Norlhinga: 6.002,8e7 '/x ", EUP 8rd box down. Pad Elavalian: 44'AMSL Wellhead: Vetco MB228 Nordic Rig 3 Floor is 30' Lower Bowl Elevation: 74' AMSL Conductor: 20" Cemented to 110' MD Fluid: Diesel in tubing and annulus 3-W, 9 -3 #, L80 EUE Ord Mod Tubing (4 +/ -2133' MD TO 13 -W hole ivy Shoe of 10-W, 45.5#, L -80 BTC Casing la 2373' MO, 2078' TVD Cement retainer set at approx. 2283' MD with enough cement pumped to fill to 2473' MD and 50' dumped on top Cement Plug(s) across Fluid: Drilling mud . hydrocarbon bearing zones *I- 9.0 ppg from TD to 388' above Ugnu B West Fault Est. TOC (c 2974' MD. Six 550' lifts. \ ■ N \ ;; TD 84/2" hole 6274' MD, 3,790' TVD Conoc 3J�'10'1 P &A fi ed mod!ed by rra (! by PJB Alaska Well Design 9005 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/29/10 Inspector: Bob Noble Operator: CPA • Well Name: KRU 3J-101 - Oper.Rep: Ian Ives PTD No.: 205-157 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified,How? ier(specify in commei Onshore/Offshore: Onshore Suspension Date: 12/17/05 Date AOGCC Notified: 08/28/10 ' Sundry No.: 305-379 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA None . SCANNED AUG 1 4 2015 Condition of Wellhead: Wellhead location was verified with the use of a plot plan.Wellhead looked to be in good working condition.The well is a mono-bore - Wellhead has 2 master valves. IA line is blinded with gauge.Wellhead has a guard around it. Well has a welded sealed steel cellar box with what looked like 10.5"of clean water. - Condition of Surrounding Surface The location condition looked good with no oil stains. Location: Follow Up Actions None Needed: Attachments: Photos(3) REVIEWED BY: Insp.Supry Comm PLB 08/2010 2010-0829_Suspend_KRU_3J-101_bn.xlsx ¢/r• r !♦fid 1 j,'. , ( 1 '•• •', .•114�!r ff I 14 • ;Vi". '" rr1r{r� 06F! s a,Ajt 7's�r Fi err ; K'�ryY t t 1• • A V + • Lr t P pv e 1 cki ° � b O h, +r r o co 4 fy y • s M q t .. � Urh•� v • b g:yi sZ r•`p,. 4 $r X69 ,.�:. r Q f k S ` ,b rs* 0. clJ N O N i t Y , ,!! , o L/� a a 00 t N Pr ,M � 4 4 = +fir , ", 1z 7 , .1i 01 1 op. 1)-70...-1.:. .. . ._ ... , , :, .,t s . , _ _ , . , ,. . . , .. ‘,-• ' U fit, A e b O rn p r 4. 0I � w CO el } t pCD ` a ConocoPhillips Alaska, Inc. Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage, AK 99510 phone 907.263.4859 TRANSMITTAL TO: AOGCC 333 W 7T" AVE Anchorage, AK 99501 OPERATOR: CPAI SAMPLE TYPE: DRIES DATE: 12-27-05 AIRBILL: 5325460 CPBV 05-12-27-03 CHARGE CODE#: 10096698 WELL: 3J-101 NUMBER OF BOXES: 1 Bundle (6 bxs) SAMPLES SENT: 3J-101 ~~ Dries 90-6274 ~~ SENT BY: Mike McCracken UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ConocoPhillips Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Dan Przywojski 1 RECEIVED BY: DATE: ~ ~ ~~~ ~®0 ~ ,~~~ MAC ~ 20~~ ~o~ - ~~ 7 f ~ ~~ ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051570 Well Name/No. KUPARUK RIV U WSAK 3J-101 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23283-00-00 MD 6274 TVD 3779 Completion Date 12/17/2005 Completion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu, FMI/DSI/SWC + TLC MDT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name g 13916 Formation Micro Ima D Pdf Directional Survey '~ 13916 Sample I ~ 13916 Formation Tester ~~ C Pds 13916 See Notes (F~ C ~~t, 13941 Induction/Resistivity 13941 Induction/Resistivity ~I ICY C Pdf 13941 Induction/Resistivity ~ 13941 Neutron ~'~ l~ C Pdf 13941 Neutron 13941 Induction/Resistivity 7 1f (7 --LSD C Pdf 13941 Induction/Resistivity 13941 Neutron ]` <= t~ ',~ C Pdf 13941 Neutron '~ Wrd 13947 Report: Final Well R ', QED" C Wrd 13947 Report: Final Well R (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 5 Col 1 2372 6000 Case 5/15/2006 Field Print 10-Dec-2005 0 0 1/17/2006 DEFINITIVE SURVEY 5 Blu 1 3470 5922 Case 5/15/2006 Sidewall Cores CST-GR 10-Dec-2005 Col 2 3470 5568 Case 5/15/2006 MDT/GR 11-DEC-2005 1, 2 0 0 Case 5/15/2006 MDT/GR, Sidewall Cores CST-GR, Formatation Tester Field Print 10-Dec- 2006 0-2 110 6218 6/8/2006 ROP, GR, RHOB, NPHI, NCNT 2 Col 1-2 222 6274 6/8/2006 ROP, DGR, EWR 1-Dec- 2005 2 1-2 222 6274 6/8/2006 ROP, DGR, EWR 1-Dec- 2005 5 Col 1-2 222 6274 6/8/2006 DGR, CTN, ALD 5 1-2 222 6274 6/8/2006 DGR, CTN, ALD 2 CoI 1-2 222 3779 6/8/2006 DGR, EWR 1-DEG-2005 '~ 2 1-2 222 3779 6/8/2006 DGR, EWR 1-DEC-2005 ! 2 Col 1-2 222 3779 6/8/2006 DGR, CTN, ALD 1-DEC- 2005 ' 2 1-2 222 3779 6/8/2006 DGR, CTN, ALD 1-DEC- 2005 0 0 6/9/2006 Final Report, w/Mud Logs 15-Dec-2005 I 0 0 6/9/2006 Final Report, w/Mud Logs 15-Dec-2005 DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051570 Well Name/No. KUPARUK RIV U WSAK 3J-101 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23283-00-00 MD 6274 TVD 3779 ~g _ - 13947 Mud Log Iz$~~ C Pdf 13947 Mud Log '~ 13947 Mud Log I~ C Pdf 13947 Mud Log C~ 13947 Mud Log .~ C Pdf 13947 Mud Log ~~~ ~ 13947 Mud Log ICI ~ C Pdf 13947 Mud Log LL~~ 13947 Mud Log ~D C Pdf 13947 Mud Log I! S 1 tt g 3947 Mud Log ;,jzb C Pdf 13947 Mud Log I~ 139 7 d M L 4 u og j ~tD C Pdf 13947 Mud Log ~~bg 13947 Mud Log IUD C. Pdf 13947 Mud Log 14343 See Notes Completion Date 12/17/2005 Completion Status SUSP Current Status SUSP UIC N Col 110 6274 6/9/2006 Formation Log, MD 1-Dec- 2005 j Col 110 6274 6/9/2006 Formation Log, MD 1-Dec- i 2005 Col 110 3780 6/9/2006 Formation Log, TVD 1-Dec- 2005 Col 110 3780 6/9/2006 Formation Log, TVD 1-Dec- 2005 Col 110 6274 6/9/2006 Drilling Dynamics, MD 1- Dec-2005 j Col 110 6274 6/9/2006 Drilling Dynamics, MD 1- Dec-2005 II Col 110 3780 6!9!2006 Drilling Dynamics, TVD 1- Dec-2005 i Col 110 3780 6/9/2006 Drilling Dynamics, TVD 1- Dec-2005 Col 110 6274 6/9/2006 Combo Log, MD 1-Dec- 2005 Col 110 6274 6/9/2006 Combo Log, MD 1-Dec- 2005 Col 110 3780 6/9/2006 Combo Log, TVD 1-Dec- 2005 Col 110 3780. 6/9/2006 Combo Log, TVD 1-Dec- 2005 Col 110 6274 6/9/2006 Gas Ratio, MD 1-Dec-2005 Col 110 6274 6/9/2006 Gas Ratio, MD 1-Dec-2005 Col 110 3780 6/9/2006 Gas Ratio TVD 1-Dec-2005 Col 110 3780 6/9/2006 Gas Ratio TVD 1-Dec-2005 0 0 Case 1!22!2007 Anal of MDT Fluid Samples: Black Oil PVT Study Report 0 0 Gase 1/22/2007 Anal of MDT Fluid Samples: Black Oil PVT I Study Report ~C Pdf 14343 See Notes Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ~J DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051570 Well Name/No. KUPARUK RIV U WSAK 3J-101 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23283-00-00 MD 6274 TVD 3779 Completion Date 12/17/2005 Completion Status SUSP Current Status SUSP UIC N ADDITIONAL INFORMATION C Well Cored? Y / N J ~ ~- Chips Received? -~-PF-- Analysis ~/ N ~~ (~~,~ ~,~,,~,~ c: } Received? Comments: Compliance Reviewed By: _ __ _. Daily History Received? Y / N Formation Tops V/ N - - l -- -- - - Date t ~C _ 2~,~-U -~?_ • '"` ~C~n~c~P'h~~lli TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`h avenue, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: North East West Sak (NEWS) wells -PVT and API gravity oil analysis summaries DATE: 1 /17/2007 Hand del West Sak 3J-101 LO/NS~4`S-~,30~,~ CD &Hardcopy report ~~-~ 5- ~ ~~ 3C~3 vSchlumberger-Analysis of MDT Fluid Samples -Black Oil PVT Study Report; report 200500215; 8/25/2006; Disk(contains all 5 wells) and &Hardcopy report V Kuparuk Labs Report of Analysis; DS 3J-1011 Produced oil ;report and spreadsheet ~ West Sak 1 Q-101 LO/NS 083-135 CD &Hardcopy report aO5 - (ate Schlumberger-Analysis of MDT Fluid Samples -Black Oil PVT Study Report; report 200500199; 3/29/2006; isk(contains all 5 wells) and &Hardcopy report Kuparuk Labs Report of Analysis; DS 1Q-101 Produced oil ;report and spreadsheet IWest Sak 1 R-East LO/NS 05-026 CD &Hardcopy report 2 b s-all ~- I ~/3 ~iC r _Schlumberger-Analysis of MDT Fluid Samples -Black Oil PVT Study Report; report 200600071; 5/23/2006; ~ Disk(contains all 5 wells) and &Hardcopy report _ Kuparuk Labs Report of Analysis; DS 1 R-East Produced oil ;report and spreadsheet I West Sak 1 H-South LO/NS 05-026 CD &Hardcopy report .a aS_ a t a ~ /u 3~-(b Schlumberger-Analysis of MDT Fluid Samples -Black Oil PVT Study Report; report 200600089 6/30/2006; Disk(contains all 5 wells) and &Hardcopy report ~uparuk Labs Report of Analysis; DS 1 H-South Produced oil ;report and spreadsheet West Sak 1 H-North LO/NS 05-026 r ,BCD &Hardcopy report ~ 6 ~ _ ~~ ~ jC.(3C~ j t1 Schlumberger-Analysis of MDT Fluid Samples -Black Oil PVT Study Report; report 200600050; 6/20//2006; Qisk(contains all 5 wells) and &Hardcopy report Kuparuk Labs Report of Analysis; DS 10-101 Produced oil ;report and spreadsheet Please check off each item as received, promptly sign and return the transmittal to address below. /Ill dales i.~ confidential r~ntil .=fate nf'~ ~ c~%G;'t.; re%a,~e dale o al! data recipient.: - ~ `' CC: Andy gndre u, PAI Geologist ~~~~ ,~ j, ~n~.~ Receipt: C/~ ~~ ~-a~°~°'-`- Date: 1Q;v`:wt:~~ill~'lRd~~~(''' ,!°° ~'s91a~~r~ir~!~3w I _ ~ ~ GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 Sandra. D. LemkeC~Conocophillips. com • Kuparuk Laboratory Report of Analysis • RECEIVED Report Date: December 20, 2005 To: Andy Andreou JAN 2 2 200 ;Qii& G°mrr-iss-or€ Lab ID AB06847 AB06848 AB06849 AB06850 Sample Descri tion DS 3J Produced Oil DS 3J Produced Oil DS 37 Produced Water DS 3J Produced Water We11Num 101 101 101 101 Date 12/11/05 12/11/05 12/11/05 12/11/05 Time 16:34 20:41 16:34 20:41 LocDescri for MRSC 226 MRSC 297 MRSC 226 MRSC 297 Anal sis Unit Result Result Result Result Chloride m 1 --- --- 11800 11600 API at 60 degrees F DRY Degrees API 16.2 16.1 --- --- Water Cut Vol % 32.1 18.4 --- --- If there are any questions regarding this data, please call KLS at 659-7214. Completed By:_MG Reviewed By:_MA a~3 -~, ' ~o~ l~~- '~ ~~13`l~ • • Sample_ID Well Sand Depth Type API GCMS-Global Curve GC-Global Cuuve Comment US136779 3J-101 UgnuB 3355 SWC 9.5 n.a. US136781 3J-101 UgnuB 3375 SWC 8.7 n.a. U5136786 3J-101 UgnuB 3425 SWC 8.3 n.a. US136789 3J-101 UgnuB 3455 SWC 8.1 n.a. US136796 3J-101 UgnuB 3525 SWC 7.9 n.a. US136801 3J-101 UgnuB 3575 SWC contaminated n.a. U5136804 3J-101 UgnuB 3605 SWC 8.3 n.a. Average 3J-401 IlgisuB SWC n.a. 8.5 n.a. n.a. n,a. US136813 3J-101 UgnuA 3695 SWC 6.7 n.a. US136815 3J-101 UgnuA 3715 SWC 7.1 n.a. Average 3j-1D4 ilgmaA SWC n.a. 7.7 n.a. n.a. n.a. US136818 3J-101 N 3860 SWC 6.58 n.a. Average $J-101 N SWC n.a. 6.6 n.a. n.a, n.a, high uncertainty US136823 3J-101 DW 4226 SWC 13.1 n.a. US136826 3J-101 DW 4243 SWC 13.5 n.a. US136830 3J-101 DW 4275 SWC 14.7 n.a. US136831 3J-101 DW 4304 SWC 14 n.a. Average 3J-104 DW SWC n.a. 13.8 n.a. n.a. n.a. U5136835 3j-101 N 5144 SWC 12.1 n.a. Average 3J-101 N SWC n.a. 12.1 n.a. n.a. n.a. US136837 3J-101 DE 5550 SWC 13.3 n.a. US136839 3J-101 DE 5553 SWC 14.4 n.a. US136842 3J-101 DE 5565 SWC 15.7 n.a. US136846 3J-101 DE 5604 SWC 19.3 n.a. Average 3J-101 DE SWG 15.9 45.7 0.2 n.a. n.a. US136850 3J-101 BE 5673 SWC 14.3 n.a. US136852 3J-101 BE 5691 SWC 15.7 n.a. US136853 3J-101 BE 5696 SWC 15.6 n.a. US136855 3J-101 BE 5717 SWC 17 n.a. Average 3J-101 BE SWC 16.7 15.7 1.2 n.a. n.a. US136857 3J-101 A3E 5846 SWC 18.2 n.a. Average 3J-102 A3E SWC n.a. 18.2 n:a, n.a. n.a. US136860 3J-101 A2E 5916 SWC 19.2 n.a. US136861 3J-101 A2E 5922 SWC 20.9 n.a, Average 3J-1D2 A2E SWC n.a. 20.1 n.a. n.a. n,a. ~~~.«~ # ._ . ~_ _.. l ~..:. .~ ~,.-~ Cor~~rco~h~ps FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O.Box 100360 Anchorage AK 99510-0360 RE: 3J-101 DATE: 6/6/2006 11/ TRANSMITTAL Jl)N ~ 9 2006 CONFIDENTIAL DATA rw}il & Gas Cats. Calm TO: Librarian '~ AOGCC 333 W. 7"' Ave., Suite 100 Anchorage, Alaska 99501 del West Sak 3J-101 500292328300 IHardcopy report and CDROM digital log images Final Well Report-Mudlogging data, 3J-101, Brian O'Fallon/ Lees Browne, 12/15/2005; well details, geological data, pressure/formation data; drilling data, morning reports; well logs; Formation Log MD, 2"=100'; Formation Log TVD, 2"=100'; Drilling Dynamics md, 2"=100'; Drilling Dynamics log, 1 "=200'; Combo Log MD; 1 "=200" Combo Log TVD, 1 "=200'; Gas Ratio MD, Gas Ratio TVD CDROM contains DML database, final and morning reports, LAS files; log pdf image files and lithology remarks files. (Please check off each item as received, promptly sign and return the transmittal to address below. To all data recipients: All data is confidential until State of Alaska desi Hated AOGCC release date CC: Andy Andreo CAI Geologist Receipt: i~~~ Date: Q~ ="-w~~~~~~i~r`,, GIS-Technical Data Management ~;ConocoPhillips ~ Anchorage, Alaska ~ Ph: 907.265.6947 Sandra. D. Lemke(o~Conocophillips com ~aS- r S~ ¢ ~ 39 y ~- • • WELL LOG TRANSMITTAL To: State of Alaska May 30, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3J-101, AK-MW-4081380 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3J-101: Digital Log Images 50-029-23283-00 ~~ ,~v~ cop`r`a' ~~~asc~x~ ~~ 1 CD Rom ~5 = l5 ~ ~ ~39Y~ 05/09/06 i~ 9~.,5'~~ ch~u~berger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 3796 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3J-101 10987553 CST 12/10/05 1 3J-101 10987553 FMI 12/10/05 1 3J-101 10987553 MDT 12/10/05 1 3J-101 10987553 FIELD PDS/DLIS & FINAL LDWG TIF FILE 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ConocoPhillips April 3, 2006 Randy Thomas Kuparuk Drilling Team Leader Drilling 8 wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ,~, . v ~Y.a Commissioner " . ~~F ~.' ~`~ ~ ~' State of Alaska Alaska Oil & Gas Conservation Commission ~~ ~ I' c.R ~ ' ' 333 West 7th Avenue Suite 100 ~ ;,~ ,~ ~~~,,~~ Anchorage, Alaska 99501 ~ ~~ ~ _ a Subject: Well Completion Report for 3J-101 (APD 205-157 / 305-379) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3J-101. If you have any questions regarding this matter, please contact me at 265-6830 or Tom Brassfield at 265-6377. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA APR ®~ ZOO6 ALASKA OIL AND GAS CONSERVATION COMM~ION WELL COMPLETION OR RECOMPLETION REPC~~~ ~~~~1~~~omfnissian 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended ~ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other_ 1b. Well Class: Development ^ Exploratory Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 17, 2005 ~ 12. Permit to Drill Number: 205-157 / 305-379 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 1, 2005 ~ 13. API Number: 50-029-23283-00 4a. Location of Well (Governmental Section): Surface: 1205' FSL, 565' FWL, Sec. 3, T12N, R9E, UM - 7. Date TD Reached: December 9, 2005 14. Well Name and Number: 3J-101 At Top Productive Horizon: 904' FSL, 975' FEL, Sec. 3, T12N, R9E, UM 8. KB Elevation (ft): 30' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 881' FSL, 502' FEL, Sec. 3, T12N, R9E, UM 9. Plug Back Depth (MD + ND): 2200' MD / 1979' TVD West Sak Oil Pool -Exploratory ° 4b. Location of Well (State Base Plane Coordinates): Surface: x- 519544 ` y- 6002888 • Zone- 4 10. Total Depth (MD + ND): • 6274' MD / 3779' ND 16. Property Designation: ADL 25630 TPI: x- 523285 y- 6002597 Zone- 4 Total Depth: x- 523759 ' - 6002576 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: LE931805 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1775' MD 21. Logs Run: GR/Res, DenslNeu, FMI/DSI/SWC + TLC MDT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.5# H-40 30' 110' 30' 110' 40" 35o sx AS1 10.75" 45.5# L-80 30' 2372' 30' 2078' 13.5" 53o sx AS Lite, 330 sx AS I cement retainer @ 2249' 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 1917' none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement retainer @ 2249' 30 bbls 3530'-6274' (6 plugs) 288 bbls 26. PRODUCTION TEST Date First Production not applicable Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". , J ; "s '+ Z2 f ~~. APR ~ 9 2006 t t e J NONE • v;,f Form 10-407 Revised 12/2003 ~ ~ ~ , ~ ( ~ ~ CONTINUED ON REVERSE /°:..~`+,~ ,~j~ ./ ~~'„Db t ~ Y~ /~~ 1~~~~~~ (~ APR-11-2006 15 27 PHILLIPS RK INC 907 265 6224 P.02 28. 29. GEOLQGIC MARKERS FORMATION TESTS NAME MD ND Include and briefry summarize #es# results. list intervals tested, and atiaCh detailed SupAOrting data as necessary. it no tests were conducted, state "None". 3J-101 Tpp West Sak 4220' 2989' Base West Sak 6155' 3677' NIA 30. LIST Of AT'i'ACHMlrNTS Summary of Daily Operations, pirectipnel Survey 31. 1 h¢rBby terrify that thB foregoing is true and correct to the best Of my knowletlge, Contact: Torn Brasfield ~ 265-6377 Printetl Na Rand Thomas Tltie: CGreater Kuaaruk Area Drillino Team Leader . Y ~ ~li~ 6 t ~ ,~~ ~ ~ ~~ Da a signature aae , INSTRUCTIONS PrcpareG py snaron Allsup-Drake t^,enerai: This fprm is designed for submitting a complete and ~cprrett weH Completion report and log on all types of lands and leases in Alaska. ' ' Item 7a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Ga5 Injection, salt water disposal, water supply for injection, observation, or Other. Multiple coinplstion 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 gib: TPI (Top of PrpduCing Interval). Item 8:.the Kelly Bushing elevation in feet about mean low Iew water. Use same as reference for depth measurements given in other spaces on this form and in dny attachmenfs_ Item 13. The API number reported to AOGCC must be is digits (ex. 50.029-20123-00-Op). item 2D: True vertical thickness. Item 22: Attactled Supplemental rewrds for this well Shpukl Show the details of any multiple Stage Cementing and the location of the Cementing loaf. Item 23; If this well is Completed for separate productipn from mote than one interval (multiple completion), so state in item 1, and in item 2$ show the producing intervals far only the interval reported in item 26. (Submit a separate form for each additignal intBrval t0 be separately produced, shpwing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gds Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas InjBGtipn, Shut-in, ether (explain). Item 27. If h0 Cores taken, indicate "none". Item 29: List all test infprmatign, if Hens, Stale "None". Form 10-407 Revised 1212p03 r TOTAL P.02 ~b s~~/o~ APR-11-2006 15 27 PHILLIPS AK INC 907 265 6224 P.01 ConQCOPhiIli s Ataska , ~ 70Q G Sfree~, ~ Anchorage,. AK 99501 FAX ~~ f ~A e~ ~ .8 ~~U~ t.0t"t3,~"s'~~ ~£.~n, a ~:r: Fh~one: 1~'ax phone: cc: ~o ~~ ~-~~ r. ~jU4°SJlO1'~S~ ~"`4T~ RE,tV~A,RKS: ^ Crrgent [~ For your review ^ Reply ASAF ^ Flease Comment S~~ ~~~~~ Number of pages including cpvcr shoot: ,~ FYolm: /~ F13one: ~~ ~ ~ ~j ~ ~. Fax pl~one_ 265 6224 ATQ 1529 z-1 ~« of ~- ,~df ~~ ~~~ ~ Q~ 4~ l~ ~ s' ,-~ ConocoPhiilips.Alaska Operations Summary Report Legal Well Name: 3J-101 Common Well Name: 3J-101 Event Name: ROT -DRILLING Start: 11/28/2005 Contractor Name: n1433@conocophillips.com Rig Release: 12/17/2005 Rig Name: Nordic 3 Rig Number: 3 Date 11 /29/2005 11 /30/2005 12/1 /2005 12/2/2005 100:00 - 12:00 ( Code 2.00 MOVE DMOB MOVE RD rig preparing to move rig off well 0.50 MOVE MOVE ~ i MOVE Moved rig off well 1.25 MOVE ~ OTHR ' MOVE Cleaned up around well cellar and removed diverter stack from cellar 2.75 WAITONj OTHR ~ MOVE Rig Move was delayed by security due to activities in the field not allowing rig onto road 4.00 MOVE MOVE MOVE Moved rig from 10 pad 4.1 miles to 3J pad and spotted rig on pad 1.50 MOVE OTHR MOVE Moved both rig camps from 1 O pad and set up on 3J pad 1.50 MOVE MOVE ~ MOVE ~ Lay out herculite and set matting boards for rig, 0.501 MOVE ~ POSN SURFAC Move rig over well and level same, Accepted Rig @ 20:00 hrs 11-29-2005. Accepted rig 3 hrs prior to begin nippling up due to security having road closed not allowing rig to move 4.00 WELCT NUND ; SURFAC Set Diverter on well and begin nippling up, install shaker in cuttings box. 7.00 WELCTI' NUND SURFAC Fin NU 21 1/4" 2M diverter, 16" line and riser 6.50 DRILL j OTHR SURFAC Spotted MI, Epoch and MWD shacks and hooked up same, loaded 87 i jts of 5" DP in pipe shed and strapped same, loaded Sperry Sun's ,MWD and directional toots in pipe shed, offloaded 10 3/4" surface csg 3.50 DRILL PULD SURFAC I PU and stood back 20 stds of 5" DP, torqued pipe up while standing ~ back 1.00 WELCT BOPE SURFAC it and tested ok, Function tested diverter, safety alarms and koome i ~ Note: Lou Grimaldi with AOGCC witnessed test 1.50 DRILL PULD SURFAC PU and stood back 9 stds of 5" DP 1.50 DRILL OTHR 1 SURFAC ' Fin loading 5" DP into pipe shed and strapped same 3.00 DRILL ~ PULD I SURFAC PU and stood back 16 stds of 5" DP 3.00, DRILL PULD SURFAC Fin PU and standing back 5" DP, stood back 16 stds for a total of 61 stds in derrick 1.50 DRILL OTHR SURFAC ' Loaded pipe shed with 5" HWDP and jars, strapped same 1.50 DRILL 1 PULD ' SURFAC PU and stood back 5 stds of HWDP and jars 1.00 RIGMNT RSRV SURFAC Slipped and cut 50' of drlg Tine and serviced top drive, began loading pipe shed with 10 3/4" csg 5.00 DRILL DRLG ~ SURFAC Fin loading pipe shed with 10 3/4" csg and strapped same, loaded 65 I jts into pipe shed 2.50 DRILL ~ PULD SURFAC MU 13 1/2" bit #1 RR2 (RR F/10-101) on 8" motor with 1.83 deg bend flt sub and stab, RIH to 40', NOTE Rig and Camp went on highline at 0.50 DRILL OTHR j SURFAC 14:00 hrs. Pressure tested surface lines to 2,000 psi and ck ok, flooded conductor with water checking for leaks and ck ok 0.50 DRILL CIRC SURFAC RIH from 40' and tagged cement inside conductor at 95', cleaned out to I btm of conductor at 110' 1.50 ~ DRILL DRLG SURFAC Spudded well at 15:30 hrs drilling 13 1/2" hole from 110' to 220', (110') I ADT 1.5 hrs, 5-10K wob, 40 rpm's, 343 gpm at 450 psi ' 0.50 DRILL TRIP SURFAC ~ POOH 2 stds to motor at 40 3.50 DRILL I PULD SURFAC j Fin MU BHA #1, PU and MU MWD with DGR & EWR, oriented MWD and uploaded, PU 3-NMFDC's RIH to 220', RU Sperry Suns Gyro 3.00 DRILL DRLG ~ SURFAC Directionally drilled and survey 13 1/2" hole F/220' to 358', ART=1.94 j ~ hrs., 10-15K wob, 45 rpm's, 130 spm 385 gpm, 650 psi. 385 gpm=96 1 rpm mtr, Up wt 48k, Dn wt 48k. No torque, drag, 12.00 DRILL j DRLG SURFAC Directionally drilled 13 1/2" hole per directional plan from 358' to 1,010' MD/998' TVD (652'), ART 1.76 hrs, AST 5.87 hrs, 20-25K wob, 45 j rpm's, 136 spm, 405 gpm, off btm pressure 700 psi, on btm 900 psi, off ! ~ btm torque 1,800 ft-Ibs, on btm 2,200 ft-Ibs, rot wt 65K, up wt 65K, do ~ i wt 65K, ave 9.3 ppg MW, ran a total of 7 gyro's, ave 20 min. each, RD I I i 9yro after 819'. Page 1 of 8 Spud Date: 12/1/2005 End: 12/17/2005 Group: From - To Hours Code Sub ~ Phase Description of Operations 06:00 - 08:00 08:00 - 08:30 08:30 - 09:45 09:45 - 12:30 12:30 - 16:30 16:30 - 18:00 18:00 - 19:30 19:30 - 20:00 20:00 - 00:00 00:00 - 07:00 07:00 - 13:30 13:30 - 17:00 17:00 - 18:00 18:00 - 19:30 19:30 - 21:00 21:00 - 00:00 00:00 - 03:00 03:00 - 04:30 04:30 - 06:00 06:00 - 07:00 07:00 - 12:00 12:00 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 17:00 17:00 - 17:30 17:30 - 21:00 21:00 - 00:00 Printed: 3/30/2006 4:24:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3J-101 3J-101 ROT -DRILLING Start: 11/28/2005 n1433@conocophillips.com Rig Release: 12/17/2005 Nordic 3 Rig Number: 3 Date From - To Hours I Code ' Sub Code 12/2/2005 12:00 - 00:00 12.00 I DRILL ~ I I DRLG 12/3/2005 ~ i 00:00 - 04:30 4.50 DRILL ; DRLG I 04:30 - 05:00 0.50 i DRILL CIRC 05:00 - 05:40 0.67 DRILL ; DRLG ~ 05:40 - 07:15 I 1.581 I DRILL CIRC 07:15 - 09:00 09:00 - 10:00 10:00 - 10:15 10:15 - 11:45 1.751 DRILL I WIPR 1.00 DRILL WIPR 0.25 DRILL REAM 1.50 DRILL ~ CIRC 11:45 - 12:00 12:00 - 15:30 15:30 - 19:00 19:00 - 20:00 20:00 - 23:00 23:00 - 00:00 12/4/2005 00:00 - 04:30 I 04:30 - 05:15 05:15 - 05:45 .05:45 - 08:00 0.25 DRILL ' OBSV 3.50 DRILL TRIP 3.50 DRILL PULD 1.00 CASE IOTHR 3.00 CASE RURD 1.001 CASE RUNC I 4.50 CASE ;RUNC 0.751 CEMENlf CIRC 0.50 CEMEN RURD 2.25 CEMEN CIRC Page 2 of 8 Spud Date: 12/1/2005 End: 12/17/2005 Group: Phase '' Description of Operations -.-' _- SURFAC i Directionally drilled 13 1/2" hole per directional plan from 1,010' to 1924'MD / 1,804' TVD (914') ,ART 3.51 hrs AST 5.48 hrs, 20-25K wob, 45 rpm's, 150 spm, 450 gpm, off btm pressure 870 psi, on btm 1000 psi, off btm torque 3200 ft-Ibs, on btm 3900ft-Ibs, rot wt 65K, up wt 85K, do wt 77K, ave 9.3 ppg MW SURFAC ~ Directionally drilled 13 1/2" hole per directional plan from 1924' to 2,340' i MD / 2,060' TVD (416') ,ART 1.95 hrs AST 1.01 hrs, 15-25K wob, 45 rpm's, 175 spm, 520 gpm, off btm pressure 1,400 psi, on btm 1,590 psi, off btm torque 3,700 ft-Ibs, on btm 4,500ft-tbs, rot wt 80K, up wt 90K, do wt 70K, ave 9.5 ppg MW SURFAC !Circ btms up for sample and geologist SURFAC i Directionally drilled 13 1/2" hole per directional plan from 2,340' to 2,381' MD / 2,081' TVD (41') ,ART .20 hrs AST .20 hrs, (10 3/4" Csg Pt.) SURFAC Pumped 35 bbl weighted hi vis sweep (2# over MW) and Circ out of i hole, had no increase in cuttings back from sweep, circ 2 1/2X btms up and was clean at the shakers, circ at 175 spm, 520 gpm at 1,300 psi and 70 rpm's with 4,400 ft-Ibs torque. SURFAC Monitored well-static, POOH wet on elevators from 2,381' to 541', pulled out 1st std of HWDP to 541', no problems POOH SURFAC I RIH from 541' to 2,340' with no problems or fill. SURFAC ;Est circ and washed down 41' to btm at 2,381' with no fill or problems SURFAC Pumped 2nd weighted hiv vis sweep and circ hole clean, saw slight increase in cuttings back from sweep and circ a total of 3X btms up and was clean at shakers, 9.5 ppg MW in and out, circ at 185 spm, 550 gpm at 1,360 psi, 65 rpm's with 4,400 ft-Ibs torque, max trip gas was 25 units. SURFAC i Monitored well-static, blew down top drive and dropped ESS survey tool SURFAC ~ POOH wet on elevators from 2,381' to BHA at 632', stood back HWDP and jars POOH to 178 SURFAC POOH from 178' LD 3-NMFDC's, downloaded MWD then LD MWD and motor, cleared rig floor SURFAC ;; PU Vetco gray 10 3/4" hanger and landing jt. and drift to landing 'shoulder and lay down same SURFAC Rig up GBR 10 3/4" csg running equipment with Franks fill up tool. SURFAC M/U 10 314" shoe tract Jts #1 through #3 and circ and check floats, RIH to 125'. SURFAC i Cont RIH with 10 3!4" csg to 2,336' with no problems and good pipe displacement, st wt up 125K, do wt 65K, MU hanger and landed csg with float shoe at 2,372.56' MD/ 2,078' TVD and float collar at 2,293', no problems RIH, Ran a total of 58 jts (2,333') of 45.5#, L-80, BTC csg, ,total csg, float equip and hanger, 2,340.1', ran 13 bow spring ,centralizers and 3 stop rings per well plan (1st 13 jts) SURFAC Circ btms up thru fill up tool and began cond mud for cementing, staged pump rate up to 7 bpm at 350 psi, st wt up 135K, do wt 85K, reciprocating pipe with full returns SURFAC RD Franks fill up tool and RU Dowell cement head SURFAC ~ Fin circ and conditioning mud for cementing, conditioned mud in to 9.6 I ppg, 58 vis, PV 31 and YP of 15, mud out at 9.6 ppg, 65 vis, 33 PV and 17 YP, circ at 7 bpm at 350 psi, st wt up 135K do wt 85K, removed Sperry Sun's 8" tools from pipe shed and held PJSM with Dowell, ASRC vac truck drivers, MI mud eng. and rig crew on cementing operations while circ. Printed: 3!30/2006 4:24:41 PM ConocoPhillips Alaska Operations Summary Report Page 3 of 8 Legal Well Name: 3J-101 Common Well Name: 3J-101 Spud Date: 12/1/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/17/2005 Contractor Name: n1433@conocophillips.com Rig Release: 12/17/2005 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours ; Code ~'~ Sub Code ___~- 12/4/2005 08:00 - 10:00 ~ 2.00 CEMENT PUMP 10:00 - 10:45 0.75 10:45 - 14:30 ~ 3.75 14:30 - 20:00 ~ 5.50 20:00 - 23:00 3.00 23:00 - 00:00 12/5/2005 00:00 - 00:30 00:30 - 05:30 05:30 - 10:30 10:30 - 11:30 11:30 - 12:00 12:00 - 18:00 Phase SURFAC CEMENl~DISP SURFAC CEMEN RURD SURFAC WELCTL, NUND ~ SURFAC i WELCTL~ NUND SURFAC 1.00 WELCTu NUND SURFAC 0.50 WELCT NUND 'SURFAC 5.00 WELCT NUND SURFAC 5.00 WELCT ROPE SURFAC 1.00 DRILL PULD SURFAC 0.50 RIGMNT~ RSRV ~ SURFAC 6.001 DRILL ~ PULD SURFAC 18:00 - 19:00 1.00 j 19:00 - 20:30 1.50 20:30 - 22:00 i 1.50 22:00 - 23:00 1.00 23:00 - 23:45 0.75 23:45 - 00:00 0.25 12/6/2005 j I 00:00 - 01:30 ~ 1.50 ~ 01:30 - 03:15 1.75 RIGMNTI RSRV I SURFAC DRILL (TRIP iSURFAC DRILL ~ SFTY ~ SURFAC DRILL !TRIP SURFAC DRILL ~CIRC SURFAC CASE DEOT iSURFAC CASE DEOT iSURFAC DRILL I OTHR I SURFAC 03:15 - 03:30 I 0.251 DRILL I DRLG f SURFAC Description of Operations -- _.w_.. ~ Turned over to Dowell and cemented 10 3/4" csg, pumped 5 bbls of water, pressure tested lines to 3,500 psi, then pumped 50 bbls of CW x,100 at 8.3 ppg, then pumped 48.5 bbls of 10.5 ppg mudpush, ave 4 bpm at 150 psi, dropped btm plug, began mixing and pumping Arcticset life lead slurry, pumped 420 t~-fs ( sxs) o! lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.8 bpm at 200 psi, followed with 55't~bte (33t) axs) of Arc~ieset 1 tail cmt at 15.7 ppg and .93yield with add., ave 6.5 bpm at 350 psi, re ' ~9 ur~108:50<hrs and j with 20 bbis of tail left to go and mudpush at surface, csg stuck 1 1/2 - 12" off of landing ring, dropped plug and attempted to land hanger while displacing cement with no success. Checked with Vetco Gray rep and confirmed the hanger was ok located as is, fluted portion of hanger should be started into landing ring and will only raise tree 1 1/2" - 2". Float shoe landed at 2,372' ;Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 201 bbls of 9.6 ppg mud, displaced cmt at 7 bpm, initial circ pressure 325 psi, max pressure 660 psi, slowed rate to 3.5 bpm and bumped plug on calc displacement, pressured up to 1,500 ,psi, checked floats and held, CtP ~ 10:30 firs, had firq returns during ';job and-had 200 Dbls of 10.7 ppg t~# Lack to surface... j Flushed out stack and RD cement head, LD landing jt and csg equipment ND 16" diverter line and 21 1/4" diverter stack, ND 21 1/4" x 48" Spool and set out of cellar Clean up wellhead and inspect hanger landing ring, found landing ring was not level on hanger but hanger was level. Began to install vetco gray wellhead i Fin NU Vetco Gray MB 228 11" x 5M Tbg Head NU 11" x 5M BOP stack and riser ' RU and tested BUPE, tested valves, rams, manifold and annular to 250 psi low and 3,000 psi high with no problems, RD test tools LD 3 stds of 5" HWDP out of derrick Serviced top drive and blocks ',Held PJSM then PU and MU 8 1/2" BHA #2 with bit #2, RIH to 385', MU it l" motor with 1.5 deg bend, MPT, w/DGR, EWR, PWD, MWD w/ALD, CTN and ACAL, oriented MWD and uploaded same, held PJSM and loaded radioactive sources, RIH PU 3-NMFDC's to 199'. Performed shallow pulse test, blew down top drive and cunt RIH with 5" HWDP and jars from derrick to 385'. ~ Changed out pipe spinners on rig floor per MODUSPEC recommendation RIH with BHA #2 from 385' to 1,680' Held stripping drill with rig crew RIH from 1,680' to 2,220' and washed down to 2,270' Circ hole clean evening MW in and out at 9.3 ppg, circ at 120 spm, 350 ,'gpm at 850 psi Began to RU to test csg Rig up and. perform cog intsgritytest to 3000 psi. for 30 minutes (good test) Drill out shoe tract Float collar@2293'MD, Csg shoe @ 2372' MD , ;Clean out rat hole to 2381' j 343 gpm. 920 psi. 40 rpm top drive, mfr 113 rpm. Drill F/2381' to 2401' 343 gpm, 920 psi. 40 rpm topdrive , 113 rpm Printed: 3/30/2006 4:24:41 PM ' ConocoPhillips Alaska Page 4 of'8 Operations Summary Report Legal Well Name: 3J-101 Common Well Name: 3J-101 Spud Date: 12/1/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/17/2005 Contractor Name: n1433@conocophillips.com Rig Release: 12/17/2005 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code ' Sub' Phase ! Description of Operations __ Code _-_. 12/6/2005 03:15 - 03:30 0.25 DRILL I DRLG SURFAC motor ~ 03:30 - 04:00 0.50 DRILL 'CIRC SURFAC Circ and condition mud for LOT. 418 gpm, 1250 psi, MW in 9.4 out 9.4 04:00 - 06:45 !; 2.75 j DRILL LOT SURFAC RU and pe L©T to 14.0 {~ EMW, 500 psi at 2081'TVD with 9.4 j ppg MW ,Rig down test equipment and blow down same. 06:45 - 08:00 1.25 DRILL ~ CIRC PROD Displace wellbore with 9.0 ppg Flo-Pro mud 08:00 - 11:15 3.25 DRILL OTHR PROD Clean pits and lines 11:15 - 11:45 ! 0.501 DRILL CIRC PROD ~ Continue to bring on remaining Flo-Pro in to active system. 11:45 - 12:00 ' 0.25 DRILL CIRC PROD Get clean hole ECD @ 500 gpm = 9.52 12:00 - 00:00 12.00 DRILL ;DRLG PROD Directionally drilll 8 1/2" hole ahead and survey F/2401' to 3375' j (ART=4.9hrs. AST=3.3 hrs) 12/7/2005 00:00 - 05:15 ~ 5.25 j DRILL DRLG PROD ~ Directionally drilll 8 1 /2" hole ahead and survey F/ 3375' to j ' 3828'(ART=hrs. AST= hrs) 05:15 - 05:30 0.251 DRILL ' OBSV PROD Flow check, (Instrumentation showed a gain) flow check showed well 1 ~ ,static. 05:30 - 05:45 i 0.25' DRILL DRLG PROD Directionally drill 8 1/2" hole ahead and survey F/3828' to 3851' (ART=hrs. AST=hrs)pitsshowing gain in volume., flow line percentage i showed no change. 05:45 - 06:00 0.25 DRILL ~ OBSV ! PROD Flow check well f9owing SHghUy, (pity a 6-bb1, ga~ir~ shut annular '; j prevsntor 20 psi in 5 minutes pressure static) j 06:00 - 07:15 1.25 WELCTL KILL PROD Pump bottoms up through choke with the drillers method,( noted no ' ~ influx on bottoms up 4 bpm,500 psi. on dp and holding 70 psi on choke) " ' ' 07:15 - 08:00 0.75! DRILL DRLG PROD Directionally drill 8 1/2 hole ahead and survey F/3851 to 3902 ~ (ART=hrs AST=hrs) 08:00 - 10:00 2.00 DRILL ~ CIRC PROD Circ and condition mud per mud engineer { 10:00 - 12:45 2.75 DRILL DRLG PROD ~ Directionally drill 8 112" hole ahead and survey F/3902' to 4127' ' (ART=hrs AST=hrs) 12:45 - 13:45 1.00 DRILL CIRC PROD Circ and condition mud for wiper trip 13:45 - 14:00 0.25 DRILL ~ OBSV PROD Flow check well ~ 14:00 - 17:00 j 3.00 DRILL WIPR PROD ; Wiper trip to csg shoe @ 412T (tight spot @ 3160' rest of hole 10-15k I ' avg drag over normal 17:00 - 18:30 1.50 RIGMNT RSRV , PROD Service top drive and rig j 18:30 - 20:15 I 1.75 DRILL WIPR PROD Wiper trip in hole to 4080 'tag fill (normal down drag for the wellbore ~ ! , geometry ) 20:15 - 00:00 3.75 DRILL REAM PROD ! Wash and ream to Fl4080' to 4127 Run sweeps and Chg well bore fluids over to new Flo-Pro fluids 12!8/2005 ~ 00:00 - 01:50 1.83 DRILL CIRC PROD j Circ and cond chg over Flo-Pro ~ 01:50 - 00:00 , 22.17 ~~ DRILL DRLG PROD Directionally Drill! ahead 8 1 /2" hole F/412T to 5731' (AST=9.33hrs ART= 2.97hrs) 12/9/2005 ; 00:00 - 09:30 9.50; DRILL DRLG PROD ! Directionally drill ahead 8 112" hole F/5731' to 6274' (ART=3.04hrs.AST=2.65hrs) Bit wt. 5-15k,477 gal per minute, 1650 psi, 09:30 - 11:00 1.50 DRILL i CIRC ~ PROD Circ Hi-Vis sweep around, 477gpm, 1550 psi. 170k up, 105 k rot, 65 !, ~ rpm's, tq 9800 on bottom ,off bottom 10600 ft/Ib. 11:00 - 11:15 ~ 0.25 DRILL , OBSV , PROD Flow check ~ 11:15 - 16:00 4.75 DRILL j WIPR PROD Wiper TOH to csg @ 2372' MD, tight at 4766' , 3728' seen a slight more i than normal overdrag did not pump or rotate out of wellbore ~~ 16:00 - 18:30 ' 2.50 DRILL ; WIPR ! PROD Wiper TIH to 6274' no noticeable fill on botttom, Down drag at spots 18:30 - 21:00 .2.50 DRILL CIRC j PROD ' went down to 45k at times. Circ Hi-Vis sweep around @ 507 gpm, 1750 psi, 170k up 105 k rot 75k ~I 21:00 - 21:15 I 0.25 DRILL : OBSV PROD rt, 65 rpm's Flow check Printed: 3/30/2006 4:24:41 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 3J-101 Common Well Name: 3J-101 Event Name: ROT -DRILLING Contractor Name: n1433@conocophillips.com Rig Name: Nordic 3 Date I 1=rom''- To '' Hours ' Code !Code ~_ 12/9/2005 121:15 - 00:00 2.75 ~ DRILL TRIP 12/10/2005 00:00 - 03:30 3.501 DRILL ~ TRIP 03:30 - 05:30 2.00 DRILL PULD 1 05:30 - 07:30 2.00 DRILL PULD 07:30 - 08:30 1.00 LOG , PULD 08:30 - 12:00 ! 3.50 i LOG I ELOG 12:00 - 13:00 1.00 RIGMNT~ RSRV 13:00 - 13:30 i 0.50 I LOG j RURD 13:30 -14:00 0.50 LOG DLOG 14:00 - 16:00 2.00 LOG ~ PULD 16:00 - 23:00 7.00 LOG i DLOG 23:00 - 00:00 12/11 /2005 ~ 00:00 - 00:30 00:30 - 01:00 01:00 - 08:30 1.00 I LOG I ELOG 0.50 ~ LOG ' SFTY 0.50 LOG OTHR 7.50 LOG , DLOG 08:30 - 00:00 ! 15.50 ! LOG I DLOG 12/12/2005 00:00 - 01:30 1.50 LOG i DLOG 01:30 - 05:00 3.50 LOG DLOG 05:00 - 06:00 1.00 ~ LOG DLOG 06:00 -06:30 0.50 { LOG i DLOG 06:30 - 07:30 1.00 LOG j DLOG 07:30 - 09:00 1.50 LOG . DLOG i 09:00 - 11:00 2.00' LOG DLOG 11:00 - 12:30 ~ 1.50 LOG DLOG 12:30 - 15:30 3.00 LOG DLOG 15:30 - 16:00 0.50 LOG ' DLOG 16:00 - 17:00 1.00 ! LOG DLOG Phase Page5of8 Spud Date: 12/1/2005 Start: 11/28/2005 End: 12/17/2005 Rig Release: 12/17/2005 Group: Rig Number: 3 Description of Operations PROD POOH, for LOGS, Drop HOWCO E.M.S. @ 4553' Cont to POOH to 3880' MD. PROD I Continue POOH F/3880' to MWD Tools PROD UD 1-NMFDC and Download MWD data PROD Continue to UD Bha #2 PROD PJSM: R/U and P/U SWS FMI/DSI/Gr tool and test same PROD RIH to 3800' and Log out with FMI/DSUGR/ tools to 2415', POOH and R/D SWS tools PROD ', Service Dwks, Top drive and all pipe handling equipment PROD ~ Remove Sperry sun Tools from pipe shed PROD PJSM: Operational and Safety meeting SWS employees PROD P/U and M/U MDT loggging tools PROD 'RIH W/ MDT logging tools to 2372' ,Break circ. 3 bpm, Cont to RIH W/ MDT logging tools @ 23' min Breaking circ every 5-stds to 4147' PROD 'I PJSMS: Hang SWS sheve, RIH with E-line and docking tool, circ down @ 1 bpm PROD PJSM :Double Check equipment @ 4147' PROD RIH with E-line and docking tool, circ down at 1 bpm and set latch PROD RIH F/ 4147' to 5931' Run G/R and taking formation pressure readings !while RIH Took 12 attempts with only 8 successful pressure readings @ F/ 4281' MD, 2936 SSTVD, to 5925 MD 3409' SSTVD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD 17:00 - 18:00 1.00 LOG DLOG 'I PROD 18:00 - 19:00 1.00 LOG ~, DLOG 'PROD POOH taking formation samples, Attempted MDT samples @ 5568' MD, 5553' and 5571' without success, Collected MDT sample @ 5697' , and second try got successful sample 5553' (120k up, 65k dn.) (No wellbore problems recognized) POOH F/ 5553 to 4621' POOH Logging F/ 4621' to 4240' continue logging. POOH to SES @ 4147' attemp to pull docking tool from latch unable Rig up to circ & Circ @ 252 gpm, 450 psi. Pull out of latch and POOH with E-line docking tool (Laid do SES) POOH F/ 4147 to 3109' Rehead E-line rope socket Install SES and RIH with E-line docking tool and test same RIH to 3371' & log POOH to 3369' and log, RIH to 3602' POOH F/ 3602' to 3360' Attemp to get sample @ (Not successful) Tried to get test 3365' Seal failure , 3363' seal failure, 3360' Seal failure 3450' Could not figure out what was going on(was tite) 3596' tite, 3365' attempted pressures with pkr Tite, These were formation test pertormed in (UGNU) POOH F/ 3365' to 3109' R/D SES and pooh with E-line docking tool Printed: 3/30/2006 4:24:41 PM C'onocoPhillips Alaska Page 6 of 8 Operations Summary''Report Legal Weli Name: 3 J-101 Common W ell Name: 3 J-101 Spud Date: 12/1/2005 Event Nam e: ROT -D RILLING Start: 11/28/2005 End: 12/17/2005 Contractor Name: n 1433@ conocop hillips. com Rig Release: 12/17/2005 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hoclrs ' Code Code Phase Description of Operations 12/12!2005 19:00 - 20:15 1.25 ~ LOG ~ CIRC PROD ~ Precautionary circulate 1 1/2 times bottoms up and check mud @ 250 ' gpm, 170 psi ' 20:15 - 00:00 3.75 LOG DLOG PROD POOH with DP Conveyed logging tools F/ 3109' to 358' 12/13/2005 00:00 - 00:45 ; 0.75 LOG DLOG ~ PROD ~ Cont POOH with DP Conveyed logging tools F/ 358' at 30-35'/min with no problems in open hole. 00:45 - 01:00 0.25, LOG ' SFTY PROD ' Held PJSM with SWS and rig crew on LD logging string. 01:00 - 03:00 2.00; LOG PULD PROD POOH LD MDT logging tools, tools sent to SWS shop to check sample ' recovery. 03:00 - 03:15 ~ 0.25 LOG SFTY PROD Held PJSM with SWS and rig crew on PU of sidewall coring tool. 03:15 - 05:45 i 2.50 LOG DLOG i PROD , MU Core Tool and xo, RIH on 5" DP to 2,360'. 05:45 - 06:15 0.50 LOG ~ CIRC PROD ' RU and est circ at 42 spm, 3 bpm and 80 psi, circ to clean out docking head. 06:15 - 08:00 1.75 ~ LOG DLOG PROD Cont RIH from 2,360' to 4,040', broke circ every 5 stnds while RIH, RIH at 23'/min, no problems RIH. 08:00 - 09:30 1.50 LOG OTHR ! PROD , RU sheave and sidedoor entry sub, RIH with docking tool, circ dwn at 7 ~ ;, bpm, 300 psi and latched into docking tool, tested hookup and ck OK, ~ ' installed cable clamp. 09:30 - 12:15 2.75: LOG DLOG PROD Cont RIH on 5" DP from 4,040' to 5,935'. 12:15 - 12:30 0.25 LOG SFTY PROD Monitor well (well static). 12:30 - 13:30 i 1.00 LOG DLOG PROD I POOH taking sidewall cores, from 5,922' to 5,694'. 13:30 - 15:45 2.25 LOG OTHR ~ PROD I DC power supply failed in logging unit. Replaced and tested unit. 15:45 - 18:30 2,75 LOG ~ DLOG ~ PROD ' Cont POOH taking sidewall cores from 5,694' to 4,223' for a total of 45 shots in the West Sak, POOH to 4,039' (SES). 18:30 - 19:30 ~ 1.00 LOG OTHR PROD ~ Unlatched docking head at 4,039' and POOH with E-line, LD side entry ' sub and RD sheave. 19:30 - 23:30 ~ 4.00 LOG DLOG ' PROD ~~ Cont POOH from 4,039' to 31'. 23:30 - 00:00 0.50 i LOG ' OTHR PROD POOH LD sidewall coring tools. 41 of 45 shots fired and recovered. 4 I ~ shots unfired and recovered in gun section. 12/14/2005 00:00 - 01:30 ; 1.50 LOG PULD PROD RU sheave, prep rig floor and tools for SWC on a-line. 01:30 - 02:00 ' 0.50 LOG ELOG PROD !. RIH on a-line to 2,780', could not get tools past 2,780'. 02:00 - 02:30 0.50 LOG i ELOG ~ PROD POOH from 2,780' with SWC tools on a-line. 02:30 - 02:45 0.25 LOG ~ SFTY PROD PJSM with SWS and rig crew on LD live core gun. 02:45 - 04:00 1.25 LOG RURD. PROD Rig down wire line sheave-Pick up tools to RIH on 5" DP. 04:00 - 06:00 2.00 LOG TRIP PROD . Run in hole to 2,360'. , 06:00 - 07:00 ' 1.00 LOG CIRC i PROD ! CBU @ 4 bpm with 90 psi, up wt 75k do wt 60k. 07:00 - 08:00 1.00 LOG i TRIP PROD Run in hole f! 2,360' to 3,090'. 08:00 - 08:30 0.50 LOG ' RURD PROD ~ Rig up wire line sheave &SES. 08:30 - 09:45 1.25 ! LOG ELOG PROD Run in hole w/ wire line-pump @ 7bpm 230 psi to set latch. 09:45 - 10:00 ! 0.251 LOG TRIP PROD Run in hole w/drill pipe f/ 3,090' to 3,977 up wt 100K do wt 65K. 10:00 - 12:00 ~ 2.00 LOG i DLOG ~; PROD ; Tie in-POOH retrieving SWC to 3,090' W SES. 12:00 - 13:00 1.00 LOG !, ELOG PROD ~ POOH w/ E-line. Rig down SES & sheave in derrick. 13:00 - 14:00 1.00 ~ LOG ; CIRC PROD CBU at 84 spm, 175 psi, up wt 82K do wt 63K, check for flow (well j static). i 14:00 - 17:30 3.50 LOG DLOG . PROD POOH from 3,093' LD HWDP. 17:30 - 18:30 1.00 LOG PULD i PROD i LD core tools, unload samples, RD a-line equipment. 18:30 - 20:00 1.50 LOG i RURD PROD ' Off load HWDP from shed, RU floor and handling equipment to run 3 ; ~ 1/2" tubing/cement string. 20:00 - 21:00 1.00 ~ ABAND PULD i PROD MU muleshoe on first jnt, broke tong die retaining pin on ECKLE tubing tongs, repair pin while performing rig service. 21:00 - 22:30 1 1.50 ABAND TRIP PROD i PU RIH to 1,316', with 42 jnts 3 1/2" EUE tubing from pipeshed. 22:30 - 23:00 ~ 0.50 ABANDN RURD PROD ~ RU floor and handling equipment to run 5" DP from derrick. 123:00 - 00:00 1.00 ~ i ABANDIy TRIP PROD RIH with cmt string on 5" DP from 1,316' to 2,742', up wt 58K do wt ~ ' ~~ ; 50K. Printed: 3/30/2006 4:24:41 PM -ConocoPhillips'Alaska Page 7 of 8 Operations Summary Report Legal Well Name: 3J-101 Common Well Name: 3J-101 Spud Date: 12/1/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/17/2005 Contractor Name: n1433@conocophillips.com Rig Release: 12/17/2005 Group: Rig Name: Nordic 3 Rig Number: 3 Date 12/15/2005 12/16/2005 From - To Hours i Code ; Phase Description of Operations ;Code 00:00 - 02:00 j 2.00 } CEMEN ~ TRIP I~ SUSPEN ~ RIH w/ 3 5" stinger & 5" dp. 02:00 - 03:15 ~ 1.25 ~ CEMEN~CIRC , SUSPEN Circ. @ 100 spm 400# Rotate & reciprocate 20 rpm up wt. 130k do 68k rot 85k. 03:15 - 03:45 0.50 CEMEN'>f SFTY SUSPEN PJSM=du to cement-test lines to 3500# 03:45 - 04:15 0.50 CEMENT PUMP i SUSPEN ;Pump 10 bbl. water ahead of 48 bbls. cement-3 bbl. water behind i followed w/ 87 bbl. mud. 04:15 - 05:00 0.75 CEMENTTRIP SUSPEN Rig down circ. head POH 6 stands dp from 6269 to 5705. 05:00 - 06:30 1.50 CEMEN i CIRC SUSPEN CBU @ 6 bpm clean returns. 06:30 - 07:00 0.50 CEMENT PUMP SUSPEN Pump plug #2 10 bbl. water 48 bbl. cement 3 bbl. water followed w! 80 ~ bbl. mud. 07:00 - 08:00 1.00 CEMEN TRIP ~ SUSPEN POH from 5705 to 5231. 08:00 - 08:45 0.75 CEMEN CIRC SUSPEN CBU @ 10 bpm- bottoms up 8 bbl. contaminated mud. 08:45 - 09:15 , 0.50 CEMENT PUMP SUSPEN Pump plug 3# 10 bbl. water 48 bbl. cement 3 bbl. water followed w/ 70 ~ I ~ bbl. mud. 09:15 - 10:00 0.75 CEMEN"tETRIP ~ SUSPEN POH from 5231 to 4666. 10:00 - 11:00 1.00 CEMENTf CIRC SUSPEN CBU @ 7 bpm. clean returns. 11:00 - 12:00 1.00 CEMENT PUMP SUSPEN i Pump plug #4 10 bbl. water 48 bbl. cement 3 bbl. water followed w/ 59 ~ ' ' ~ bbl. mud. 12:00 - 12:30 0.50 ~ TRIP ; CEMEN SUSPEN ' POH from 4666 to 4096. 12:30 - 13:30 1.00 CEMEN~CIRC SUSPEN CBU @ 7 bpm clean returns. 13:30 - 14:00 0.50 CEMEN ;PUMP SUSPEN Pump plug #5 10 bbl. water 48 bbl. cement 3 bbl. water followed w150 ' ~ ~ bbl. mud. 14:00 - 14:30 0.50 CEMENTTRIP ~ SUSPEN POH from 4096 to 3530. 14:30 - 15:00 0.50 CEMEN ~ CIRC ~ SUSPEN CBU @ 7 bpm. clean returns. 15:00 - 15:30 0.50 ~ CEMENTPUMP SUSPEN Pump plug #6 10 bbl. water 48 bbl. cement 3 bbl. water foNowed w/ 40 bbl. mud. 15:30 - 16:30 1.00 CEMENTTRIP ; SUSPEN POOH from 3,530' to 2,489'. 16:30 - 17:00 0.50 CEMENTCIRC SUSPEN Drop wiper dart and circ 1 1/2 bolt up at 98 spm with 175 psi. with no i contaminated mud 17:00 - 19:00 2.00 DRILL PULD SUSPEN 'POOH LD 37 juts 5" DP. 19:00 - 19:30 0.50 DRILL RIRD ~ SUSPEN ' RD 5" handling tools and RU 3 1/2" tools. 19:30 - 21:00 1.50 CEMEN TRIP SUSPEN POOH from 1,316' and stood back 14 studs of 3 1/2" cement stinger. 21:00 - 21:30 4 0.50 CEMENT KURD SUSPEN RD 3 1/2" handling tools and RU 5" tools. 21:30 - 21:45 0.25 ~ SFTY CEMEN SUSPEN I Held PJSM with crew and HES tool supervisor on MU of retainer. 21:45 - 23:30 1.75 ~ CEMEN TRIP SUSPEN ~ MU Haliburton 10 3/4" csg EZSV cement retainer and RIH to 2,249' on i 5" DP. 23:30 - 00:00 ' 0.50 CEMENT OTHR SUSPEN Set EZSV retainer at 2,249' with btm of retainer at 2,252' and set 25K !.down on retainer, st wt up 68K, do wt 57K, shear and PU out of j retainer, sting in RU and test retainer/casing at 1,500 psi for 10 min. Test OK. 00:00 - 00:30 0.50 CEMEN OTHR SUSPEN Perform injection test @ 2 bpm 700#. 00:30 - 01:30 1.00 CEMENI~ PLUG SUSPEN ~ Pump 10 bbl. water 30 bbl. cement followed w/ 30 bbl. mud. left 5 bbl. cement on top of retainer. 01:30 - 01:45 0.25 CEMENTTRIP SUSPEN POH lay down 4 jts. 5" dp. 01:45 - 02:30 ' 0.75 ~ CEMEN CIRC SUSPEN CBU @ 6 bpm 200#. 02:30 - 03:30 1.00 CEMEN~CIRC SUSPEN Reverse circ rinsate @ 5 bpm 370#. 03:30 - 05:00 1.50 CEMEN OTHR SUSPEN PJSM-slip & cut drlg. line. 05:00 - 06:30 , 1.50 CEMENl1CIRC SUSPEN Rig up & reverse circ. seawater @ 5 bpm 260#. 06:30 - 07:00 ` 0.50 CEMENTOTHR SUSPEN Break down kill line & fill trip tank. 07:00 - 09:30 2.50 CEMENI~TRIP ~ ~ SUSPEN POH laying down dp & running tool 09:30 - 10:15 0.75 CEMEN~I{}TRIP SUSPEN RIH w/ 20 stands 5" dp 10:15 - 12:00 ~ 1.75 CEMENlj PULD SUSPEN Lay down 20 stands 5" dp. 12:00 - 13:00 1.00, CEMENI'i PULD SUSPEN ~ RIH wl 4 stds. 5" dp & lay down same. Printed: 3/30!2006 4:24:41 PM ConocoPhillips Afaska Page 8 of 8 Operations Summary Report Legal Well Name: 3J-101 Common Well Name: 3J-101 Spud Date: 12/1/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12117!2005 Contractor Name: n1433@conocophillips .com Rig Release: 12/17/2005 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To ' Hours 'Code Code _ _ ~ Phase Description of Operations _. 12/16/2005 i 13:00 - 15:00 _ _ 2.00 ABAND _. TRIP __ SUSPEN ; _____ Rig up & run 3.5" tbg. to 1879. 15:00 -16:00 ~ 1.00 i ABAND TRIP j SUSPEN ~ Make up Vetco Grey 4 1/2" x 3 1/2" tbg hanger & land circ string at ' 16:00 - 16:30 III 0.50 ABAND I OTHR SUSPEN 1,91 T. Run in lock down screws & lay down landing jt. 16:30 - 21:00 4.50 i WELCT NUND SUSPEN ;PJSM-Nipple down 11" BOP, rack and secure for rig move: 21:00 - 22:30 ~~ 1.50 WELCTL NUND SUSPEN NU Vetco Grey MB 228 11" 5M tree with multi-bowl removed, test tree i to 5,000 psi for 15 min. Test OK. 22:30 - 23:30 II 1.00 I, CMPLTN FRZP ~ SUSPEN RU Little Red for frz protect, pull TWC, press test circ lines. : 23:30 - 00:00, 0.50 ~ CMPLTN FRZP ~ SUSPEN 'Start pumping diesel dwn annulus at 5 bpm, 675 psi, taking returns to 12/17/2005 ` 00:00 - 00:15 ~ 0.25 CMPLTN FRZP SUSPEN rockwasher/cuttings box. Cont freeze protecting with Little Red at 5 bpm 675 psi. 00:15 - 01:15 I 1.00! . CMPLTN OTHR SUSPEN !Blow dwn and RD all circ lines, install flange on annulus valve, RD ~ i ~ ~ ~ handy berm around cellar. 01:15 - 02:15 1.00 WELCT EQRP SUSPEN RU lubricator and installed BPV, RD lubricator and secured well. 02:15 - 04:45 2.50 1 ABAND OTHR SUSPEN ~ Clean up cuttings box, unplug and skid mud shack, prep cellar and I .tarps for move, call DSO and held PJSM for rig move. ' 04:45 - 06:00 '~ 1.25 MOVE ,MOVE MOVE Moved rig ofF well, secured cellar doors, clean around well site. Realeased rig at 06:00 hrs i2-17-05. Printed: 3/30/2006 4:24:41 PM DEFINITIVE Halliburton Sperry-Sun Western North Slope ConocoPhllips. Kuparuk 3J `', 3J-101 Job No. AK-MW-0004081380, Surveyed: 9 December, 2005 Survey Report 29 December, 2005 _ Your Ref: AP1500292328300 Surface Coordinates: 6002887.06 N, 519545.34E (70° 25' 08.5883" N, 149° 50' 26.8124" ~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1002887.06 N, 19545.34E (Grid) Surface Coordinates relative to Structure: 464.42 N, 1.96E (True) Kelly Bushing Elevation: 73.85ft above Mean Sea Level Kelly Bushing Elevation: 73.85ff above Project V Reference Kelly Bushing Elevation: 73.85ft above Structure ~ ~ ~ ~'" t"' ~ ~ ~ ~ ~ ~ ~ E E s Survey Ref.• svy2247 A Halliburton Company • • + Halliburton Sperry-,Sun Survey Report for Kuparuk 3J - 3J-101 Your Ref: APf 500292328300 Job No. AK-MW-0004081380, Surveyed: 9 December, 2005 ConocoPhillips Wesfern North Slope 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) f(ft) (ft) (°/100ft) 0.00 0.000 0.000 -73.85 0.00 0.00 N 0.00 E -- 6002887.06 N - 519545.34E 0.00 CB-SS-Gyro 100.00 0.790 238.460 26.15 100.00 0.36 S 0.59 W 6002886.70 N 519544.75E 0.790 -0.56 200.00 1.310 228.940 126.13 199.98 1.47 S 2.04 W 6002885.58 N 519543.31E 0.547 -1.92 263.00 1.750 233:480 189.11 262.96 2.52 S 3.35 W 6002884.53 N 519541:99 E 0.724 -3.15 360.00 1.310 241.580 286.07 359.92 3.93 S 5.52 W 6002883.12 N 519539.83E 0.504 -5.19 443.00 0.720 228.900 369.06 442.91 4.72 S 6.75 W 6002882.32 N 519538.61E 0.756 -6.35 533.00 0.700 109.950 459.06 532.91 5.28 S 6.66 W 6002881.76 N 519538.70E 1.359 -6.22 628.00 2.860 84.610 554.01 627.86 5.26 S 3.75 W 6002881.79 N 519541.60E 2.366 -3.33 720.00 8.110 96.950 645.55 719.40 5.83 S 4.98.E 6002881.25 N 519550.34E 5.816 5.42 MWD+SAG 752.74 10.400 96.590 677.87 751.72 6.44 S 10.21E 6002880.64 N 519555.57E 6.997 10.69 847.86 16.300 97.770 770.37 844.22 9.24 S 31.99E 6002877.91 N 519577.35E 6.209 32.61 943.27 17.410 99.030 861.69 935.54: 13.29 S 59.35E 6002873.93 N 519604.72E 1.225 60.21 1038.48 18.610 98.680 952.23 1026.08 17.82 S 88.44E 6002869.48 N 519633.82E 1.265 89.56 1133.00 21.240 99.980 1041.08 1114.93 23.06 S 120.21E 6002864.31 N 519665.61E 2.822 121.65 1228.84 25.710 94.610 1128.98 1202.83 27.74 S 158.06E 6002859.73 N 519703.47E 5.166 159.74 1324.12 27.570 93.340 1214.14 1287.99 30.69 S 200.67E 6002856.90 N 519746.09E 2.041 202.46 1418.64 27.690 95.050 1297.88 1371.73 33.90 S 244:38 E 6002853.80 N 519789.81E 0.849 246.29 1513.86. 28.170 96.440 1382.01 1455.86 38.36 S 288.76E 6002849.45 N 519834.20E 0.849 290.88 1609.00 26.960 95.450 1466.35 1540.20 42.93 S 332.54E 6002845.00 N 519878.00E 1.360 334.89 1704.20 28.950 95.650 1550.44 1624.29 47.25 S 376.96E 6002840.80 N 519922.42E 2.093 379.51 1800.07 34.510 94.960 1631.95 1705.80 51.89 S 427.15E 6002836.29 N 519972.62E 5.812 429.90 1894.20 43.010 94.180 1705.28 1779.13 56.54 S 485.84E 6002831.79 N 520031.32E 9.045 488.78 1988.41 47.430 93.840 1771.63 1845.48 61.21 S 552.53E 6002827.30 N 520098.03E 4.699 555.63 2083.36 51.330 94.440 1833.43 1907.28 66.42 S 624.40E 6002822.27 N 520169.91E .4.135 627.68 2178.32 52.400 95.020 1892.07 1965.92 72.58 S 698.83E 6002816.31 N 520244.36E 1.225 702.37 2272.72 54.920 96.800 1948.01 2021.86 80.43 S 774.46.E 6002808.66 N 520320.00E 3.071 778.38 2314.11 54.990 95.670 1971.77 2045.62 84.11 S 808.14E 6002805.07 N 520353.70E 2.242 812.25 2402.90 56.300 95.520 2021.88 2095.73 91.26 S 881.09E 6002798.11 N 520426.67E 1.482 885.53 2491.33 54.740 95.080 2071.94 2145.79 97.99 S 953.67E 6002791.57 N 520499.26E 1.811 958.42 2589.42 55.920 95.740 2127.74 2201.59 105.60 S 1033.98E 6002784.17 N 520579.60E 1.324 1039.08 2684.05 55.120 95.000 2181.31 2255.16 112.90 S 1111.64E 6002777.07 N 520657.28E 1.063 1117.08 2774.31 58.190 93.220 2230.92 2304.77 118.29 S 1186.84E 6002771.88 N 520732.48E 3.779 1192.46 2865.04 59.860 90.500 2277.62 2351.47 120.79 S 1264.58E 6002769.58 N 520810.23E 3.161 1270.15 2968.44 . 58.530 91.840 2330.57 2404.42 122.60 S 1353.36E 6002768.00 N 520899.02E 1.701 1358.81 3063.23 59.720 94.420 .2379.22 2453.07 127.05 S 1434.59E 6002763.76 N 520980.26E 2.652 1440.13. • • 29 December, 2005 - 14:37 Page 2 of 4 DrillQuest 3.03.06:008 Ha/liburton Sperry-Sun Survey Report for Kuparuk 3J - 3J-101 Your Ref.• AP1500292328300 Job No. AK-MW-0004081380, Surveyed: 9 December, 2005 Western North Slope Measured True Sub-Sea Vertical LocaLCOOrdinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 3158.29 62.410 95.560 °2425.21 2499.06 134.30 S 1517.46E 6002756.73 N 521063.14 E 3252.87 64.340 94.810 2467.60 2541.45 141.94 S 1601.66E 6002749.32 N 521147.36 E 3347.97 64.540 92.320 2508.63 2582.48 147.27 S 1687.27E 6002744.21 N 521232.99 E 3442.97 65.360 92.290 2548.86 2622.71 150.73 S 1773.27E 6002740.97 N 521319.00 E 3537.93 64.780 92.670 2588.88 2662.73 154.45 S 1859.30E 6002737.47 N 521405.04 E 3633.17 64.320 92.790 2629.81 2703.66 158.55 S 1945.20E 6002733.60 N 521490.95 E 3728.39 62.770 92.350 2672.23 2746.08 162.38 S 2030.36E 6002730.00 N 521576.12 E 3823.71 61.000 91.720 2717.15 2791.00 165.36 S 2114.37E 6002727.23 N 521660.14 E 3915.77 58.760 90.820 2763.34 2837.19 167.14 S 2193.98E 6002725.67 N 521739.75 E 4011.06 57.950• 93.830 2813.34 2887.19 170.42 S 2275.02E 6002722.60 N 521820.80 E 4104.97 59.030 94.270 2862.42 2936.27 176.07 S 2354.88E 6002717.15 N 521900.67 E 4199.49 65.230 94.790 2906.59 2980.44 182.68 S 2438.13E 6002710.76 N 521983.94 E 4293.15 73.490 99.810 2939.59 3013.44 193.91 S 2524.95E 6002699.76 N 522070.79 E 4388.46 76.150 98.280 2964.55 3038.40 208.36 S 2615.78E 6002685.55 N 522161.65 E 4483.38 81.580 98.110 2982.87 3056.72 221.63 S 2707.93E 6002672.52 N 522253.84 E 4576.86 83.570 93.010 2994.96 3068.81 230.60 S 2800.15E 6002663.80 N 522346.08. E 4671.82 80.890 93.400 3007.80 3081.65 235.85 S 2894.08E 6002658.78 N 522440.03 E 4766.70 81.590 96.260 3022.25 3096.10 243.75 S 2987.51E 6002651.13 N 522533.48 E 4861.07 84.750 96.330 3033.47 3107.32 254.02 S 3080.64E 6002641.10 N 522626.63 E 4954.00: 87.410 95.830 3039.82 3113.67 263.84 S 3172.82E 6002631.53 N 522718.84 E 5048.90 86.860 96.050 3044.57 3118.42 273.65 S 3267.09E 6002621.96 N 522813.14 E 5142.14 83.760 93.490 3052.19 3126.04 281.38 S 3359.68E 6002614.48 N 522905.74 E 5236.07 79.380 92.060 ' 3065.96 3139.81 285.89 S 3452.46E 6002610.21 N 522998.53 E 5326.76 74.830 90.870 3086.19 3160.04 288.15 S 3540.81E 6002608.18 N 523086.89 E 5424.70 69.330 94.920 3116.33 3190.18 292.81 S 3633.82E 6002603.77 N 523179.91 E 5520.09 64.250 92.620 3153.91 3227.76 298.60 S 3721.26E 6002598.20 N 523267.37 E 5615.21 58.420 92.100 3199.52 3273.37 302.05 S 3804.62E 6002594.97 N 523350.73 E 5709.26 51.200 92.420 3253.69 3327.54 305.07 S 3881.37E 6002592.16 N 523427.49 E 5802.76 44.740. 89.810 3316.26 3390.11 306.50 S 3950.76E 6002590.91 N 523496.88 E 5895.15 38.460 90.590 3385.31 3459.16 306.69 S 4012.06E 6002590.88 N 523558.19 E 5987.73 32.300 94.440 3460.77 3534.62 308.90 S 4065.57E 6002588.81 N 523611.71 E 6083.12 31.380 95.220 3541.81 3615.66 313.13 S 4115.72E 6002584.70 N 523661.86 E 6176.71 30.430 95.220 3622.11 3695.96 317.51 S 4163.58E 6002580.46 N 523709.74 E 6206.00 30.360 95.090 3647.37 3721.22 318.84 S 4178.34E 6002579.16 N 523724.50 E '° 6274.00 30.360 .95.090 3706.05 3779.90 - 321.89 S 4212.58E • 6002576.20 N 523758.75E , All data is in Feet (US Su rvey) unless otherwise stated. Directions and coordinates are relative to True North. ConocoPhillips Dogleg Vertical Rate (°/100ft) 3.018 2.160 2.371 0.864 0.710 0.496 1.680 1.946 2.576 2.820 1.217 6.577 10.143 3.192 5.723 5.813 2.851 3.069 3.349 2.912 0.624 4.306 4.900 5.177 6.856 5.768 6.148 7.682 7.212 6.820 7.073 1.057 1.015 0.328 0.000 Section Comment 1523.31 1607.85 1693.63 1779.63 1865.68 1951.64 2036.84 2120.83 2200.33 2281.38 2361.43 2444.95 2532.38 2624.06 2716.97 2809.61 2903.67 2997.43 3091.07 3183.74 3278.49. 3371.40 3464.25 3552.50 3645.59 3733.22 3816.59 3893.34 3962.62 4023.76 4077.28 4127.60 4175.66 4190.48 4224.85 Projected Survey • • 29 December, 2005 - 14:37 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 3J - 3J-109 Your Ref: API 500292328300 Job No. AK-MW-0004087380, Surveyed: 9 December, 2005 Wesfern North Slope ConocoPhillips Vertical depths are relative to Well. 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 94.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6274.OOft., The Bottom Hoie Displacement is 4224.86ft., in the Direction of 94.370° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 6274.00 3779.90 321.89 S 4212.58E Projected Survey Survey tool program for 3J-101 Fro m To Measured Vertical Measured Vertical Depth .Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 720.00 .719.40 CB-SS-Gyro 720.00 719.40 6274.00 3779.90 MWD+SAG r • 29 December, 2005 - 14:37 Page 4 of 4 DrillQuesf 3.03.06.008 t • 0.00' MD 13-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey C ata for Well 3J-101 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey Projected Survey: • ~b~ - I ~"7 0.00' MD (if applicable) 6,274.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ ~ 3J-101 Well Status Report- 12/21/05 FINAL ~~S- t s'~ Spud 3J-101 at 1530 hrs 12/1/05. Directionally drilled 13-1/2" hole to 2381' MD/2081' TVD. Ran & cemented 10-3/4" 45.5 ppf L-80 BTC casing to 2373' MD/2078' TVD with 420 bbls (530 sx) of ARCTICSET Lite lead slurry plus 55 bbls (330 sx) ARCTICSET 1 of tail slurry. Full returns during the job, reciprocated pipe during first part of the job, and had 200 bbls of 10.7 ppg slurry back to surface. Casing set 1.5 to 2 inches off landing ring- unable to work lower. ND diverter NU 11" 5000 psi BOPE stack. Tested to 250 psi low and 3000 psi high. PU 8-1/2" BHA, RIH to 2270' MD, tested casing to 3000 psi-OK. Drilled out shoe track, drilled 20' of new hole to 2401' MD, circulated and conditioned mud, performed LOT to 14.0 ppg EMW. Changed over to 9.0 ppg Flo-Pro mud system and drilled to 3851' MD. Flow check, SI well (0 SICP & 0 SITP) and circulated thru choke-confirmed no influx. Drilled ahead to approx. 4127' MD and currently making a wiper trip to the shoe. Directionally drilled 8-1/2" hole to 6274' MD, made short trip to shoe, made trip back to bottom, C&C'd, POOH for logs. RU SWS. Ran FMI. RU TLC MDT. Ran to bottom taking 12 pressure readings (8 successful) in the Ugnu/West Sak. Made 10 attempts at fluid recovery in the West Sak/Ugnu with one successful recovery in the "B" sands East fault and one in the "D" sands East fault. POOH and RU to obtain Drill pipe conveyed sidewall cores. RIH. Recovered 41 of 45 cores. RU SWS e-line and RIH to get sidewall cores in Ugnu. Could not get past 2780' MD. POOH. RU SWS DP conveyed sidewall coring tools. RIH and obtained 44 of 45 shots. RIH with 3-1/2" cement stinger to set P&A plugs. As of 1600 hrs 12/15/05, all six cement plugs pumped and circulating to clean-up BHA- no operational issues with cementing operations. Dropped DP wiper dart, C&C hole, POOH to PU EZSV. Set retainer at 2252', set 25K down-OK, shear out & tested casing & retainer to 1500 psi-OK. Pumped 25 bbl of slurry below retainer, dumping 5 bbl on top. POOH LD. RIH & land 3-1/2" circulating string at 1879' MD. ND BOPE & NU dry hole tree, tested to 5000 psi-OK. Freeze protected tubing and casing with diesel. Installed BPV and released Nordic #3 at 0600 hrs 12/17/05. ~ ~~ ~ , a FRANK H. MURKOWSK/, GOVERNOR Lail[1-7ia[~ O~ ~1`L u0-7 A~. 333 W. T" AVENUE, SUITE 100 CO1~T5ERQATI011T CO1rII~II5SIOI~T ANCHORAGE, ALASKA 99501-3539 '~ PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: KRU West Sak 3J-101 Sundry Number: 305-379 Dear Mr. Thomas: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or .such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~day of December, 2005 Encl. Chairman • . • • • ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 December 12, 2005 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry approval to Suspend Conoco Phillips 3J-101 Surface Location: 1205' FSL, 566' FWL, Sec. 3, T12N, R9E, UM or ASP4, NAD 27 coordinates of X=519,545 & Y=6,002,887 Target Location: 989' FSL, 3079' FWL, Sec. 3, T12N, R9E, UM BHL: 890' FSL, 565' FEL, Sec. 3, T12N, R9E, UM CONFIDENTIAL Dear Commissioner: ConocoPhillips Alaska, Inc. would like to suspend the 3J-101 West Sak wellbore, located in the Kuparuk River Field/West Sak Oil Pool. Nordic 3 spud this well on 12/1/05 and TD'd the well on 12/9/05. The attached Sundry and back-up information describes the suspension procedure for the existing wellbore. If you have any questions or require any further information, please contact me at 265-6377 or Randy Thomas at 265-6830 Si cerel ~~ Tom Brassfiel Staff Drilling ngineer ' STATE OF ALASKA ~'l't3'9~ RECEIVE D ALA~OIL AND GAS CONSERVATION COMMI~N ~'~_ ~EC APPLICATION FOR SUNDRY APPROVALS ~1~-- 1 2 20D5 20 AAC 2s.2so ~S ~ ~ ~~, S Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon Suspend ~ Operational shutdown Pertorate Waiver ther Anchorage Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^~ 205-157 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-029-23283-00 7. KB Elevation (ft): 9. Well Name and Number. 30' RKB + 44' to top of pad 3J-101 8. Property Designation: 10. Field/Pools(s): ADL 25630 Kuparuk River FieldM/est Sak Oil Pool- Exploration 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6274' 3779' Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 140' MD 140' ND 3060+ 1500+ Surface 2342' 10-3/4" 2372' MD 2078' ND 3580 2090 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 3-1 /2" L-80 2133' Packers and SSSV Type: None Packers and SSSV MD (ft): None 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/13/2005 Oil ^ Gas ^ Plugged Q Abandoned ^ 16. Verbal Approval: Date: 12/12/2005 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brasfield Printed Nam andy Thomas Title GKA Drilling Team Leader ' ~ Signatur hone 265-6830 Date 12/12/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (.i '~ ~~ ~" ~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~Oh~C`~' ~ ti~sj t7 ~'i"V C ~ ~~~ ~~c_SS ~c.~G~ '1~~ s~~~ ~~ ~C~C C'~~ ~ r0 v.34r p ` v wt:,`tiv~ SO ~ ~ ~~ CAS hU O [~CL~.C1.'T~ C~ l~C,.` {7 ~'O~ ~~ h~~ J i `-~ T C ~~ l~F~ ~ Subsequent Form Re 'red: "~ ~ ~~'~ r1F _ ' ~ , ~~Q~ APPROVED BY Approved COMMISSIONER THE COMMISSION Date: /~ ~ 3/' v vv Form 10-403 Revised 07/2005 ORi61NAL Submit in Duplicate 3J-101 Final Suspension Revised 12/12/05 by TJB Summary: 3J-101 well was spudded 1530 hrs on 12/1/05 and TD'd on 12/9/05. After running a-line logs, drill pipe conveyed MDT's and possibly percussion sidewall cores the wellbore will be P&A'd and the surface casing suspended for future utility as a West Sak producer/injector. Please see the attached wellbore schematic for details. 1. Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Mobilize and rig up D/S for well P&A operation. 3. Spot balanced cement plugs from TD @ 6274' MD to 2974'MD (approx. 368' above top of the Ugnu B (West Fault) @ 3342' MD). These plugs will be laid in six 550' intervals. Total cemented interval is approx. 3300' in length. Cement volumes will be based on 8-1/2" hole diameter plus 25%. Total volume is approximately 1627 cu ft or 1391 sx of slurry. This will cover the West Sak-East Fault interval from TD to the top of the Ugnu B in the West Fault. Note: not required to tag plugs ( etting from TD) as long as the cementing operations go "as planned", ~{~~'~V~~-~ ~ ~ 4. By the down squeeze method through a retainer set 90' above the shoe. (or approx. 2283' MD) pump cement plug #2 as per AOGCC regulations. Pump sufficient cement through the retainer to extend 190' below (90' of casing volume plus 100' of open hole) and lay a 50' cement cap on top of the retainer. Cement volume in open hole will be based on 8-1/2" hole diameter plus 25%. Total volume is approximately 125 cu ft or 134 sx of slurry. Weight test retainer before pumping cement. Not required to tag the plug. Leave 9.0 ppg mud below the plug.(Weight of mud needed to TD the hole). Circulate seawater into the surface casing before POOH. NOTE: Contact AOGCC inspector for option to witness setting the retainer. 5. POOH standing back 3-1/2" stringer (to be used for circulating string) and laying down 5" DP. 6. RU and run/land a 3-1/2" circulating string to approx 100' above TOC (or approximately 2133" MD) inside the 10-3/4" surface casing. A VETCOgray 4-1/2" tubing hanger crossed-over to 3-1/2" EUE 8rd will be used to land the circulating string. 7. ND BOPEs. Install a 4-1/2" VETCOgray dry hole tree as shown in the schematic and pressure test to 3000 psi. This wellbore will be utilized in the future as a West Sak producer/injector. Freeze protect the tubing and annulus with diesel. 8. Secure well and release rig. TJB 12/12/05 File: 3J-101 Tom Brassfield Staff Drilling Engin r TJB 12/12/05 • `~ Tree: (2) Vetco 4-1/8 x 5ksi valves 3J-101Surface Location: ~ Eastings: 519,545 ~~ Tubing Hanger: Vetco, with 3- Nortnings: a,oo2,a8~ '/z ', EUE 8rd box down. Pad Elevation: aa' AMSL Wellhead: Vetco M6228 Nordic Rig 3 Floor @ 30' Lower Bowl Elevation: 74' AMSL Conductor: 20" Cemented to 110' MD Fluid: Diesel in tubing and annulus 3'/:", 9.3#, L80 EUE 8rd ~- Mod Tubing @ +l- 2133' MD TD 13'/=" hole Shoe of 10 3/<'", 45.5#, L-80 BTC Casing @ 2373' MD, 2078' TVD ~ Cement retainer set at approx. 2283' ------ MD with enough cement pumped to fill to 2473' MD and 50' dumped on top Fluid: Drilling mud Cement Plug(s) across hydrocarbon bearing zones from TD to 368' above Ugnu ' ~ B West Fault Est. TOC @ 2974' MD. Six 550' lifts. ~`~=: TD 8-112" hole @ 6274' MD, 3,780' TVD ConocoPhillips 3J-101 P&A Sheetlofl Alaska Well Design modified byTJB 12/9/2005 RE: 3J-101 (205-157) Nordic 3 BOPE Waiver SubJeet: RE: 33-101 (205-157) Noy°die 3 BOPE Waiver From: "Brassfield, Tom J" <TUM..T.Brassfield@conocophillips.c~~m= Date: Mon, 12 Dcc ?OOS 15:22:11 -~0~00 To: I~hom~~s R~launder<tom r~~aunder("u ~idmin.stat~.~~k.us-> Tom, thanks! Tom -----Original Message----- From: Thomas Maunder [mail~~toaom_maunder@admin.state.ak.us] Sent: Monday, December 12, 2005 2:30 PM To: Brassfield, Tom J Cc: Nordic 3 Company Man; Thomas, Randy L Subject: Re: 3]-101 (205-157) Nordic 3 BOPE Waiver Tom, et al, Waiving the upcoming BOP test is acceptable to accomplish the DP conveyed SWC run. If all goes according to plan, the next operation would be to plug the open hole. If problems are encountered getting the SWC, please let me know. Call or message with any questions. Tom Maunder, PE AOGCC Brassfield, Tom J wrote, On 12/12/2005 9:56 AM: Tom, per our telephone conversation this morning; CPAI would like to request a waiver on the 7 day BOPS test conducted 12/5/05. The current status of the well is in the hole with DP conveyed MDT logging tools attempting to obtain samples form the Ugnu formation on the West side of the fault. The next step is to RIH with DP conveyed percussion sidewall coring tools and obtain samples from both sides of the fault. The plan would be to TIH with the P&A BHA after completing the logging run. My understanding is that if we were to decide to make a clean-out run at this time (after POOH with the TLC MDT toots) a BOPE test would be required? Thanks, Tom 1 of 1 12/12/2005 3:46 PM 3J-101 Well Status Report- 12/7/05 ~s=~~~ Spud 31-101 at 1530 hrs 1211/05. Directionally drilled 13-1i2" hole to 2381' MD/2081' TVD. Ran & cemented 10-3/4" 45.5 ppf L-80 BTC casing to 2373' MD12078' TVD with 420 bbls (530 sx) of ARCTICSET Lite lead slurry plus 55 bbls (330 sx) ARCTICSET 1 of tail slurry. Full returns during the job, reciprocated pipe during first part of the job, and had 200 bbls of 10.7 ppg slurry back to surface. Casing set 1.5 to 2 inches off landing ring- unable to work lower. ND diverter NU 11" 5000 psi BOPE stack. Tested to 250 psi low and 3000 psi high. PU 8-1/2" BHA, RIH to 2270' MD, tested casing to 3000 psi-OK. Drilled out shoe track, drilled 20' of new hole to 2401' MD, circulated and conditioned mud, performed LOT to 14.0 ppg EMW. Changed over to 9.0 ppg Flo-Pro mud system and drilled to 3$51' MD. Flow check, SI well (0 SICP & 0 SITP) and circulated thru choke-confirmed no influx. Drilled ahead to approx. 4127' MD and currently making a wiper trip to the shoe. Re: Diverter Arrangement - Nordic 3 (KRU 31-101) Subject: Re: Diverter Arrangement -Nordic 3 (KRU 3J-101} F~•om: Thomas Maunder<tom_maunder@,admin.state.ak.us> Date: Thu, Ol Dec 2005 1f~:16:21 -0900 To: James R~ ~~' ~~ jim_rc~r~~~r a<lri~in.state.<~k.u~=~- LJ Diverter line layout when a rig goes back to a pad is always a problem. Lou's drawing doesn't show the diverter "tank" which it appears is where they have the line going to contain any solids/liquids. In the PTD application, I don't remember anything being mentioned on "layout", just that they would be using the diverter. Maybe this is a subject we should take up in a meeting like we had with Jerry and MJ. Not sure which is worst, pointing toward the camp or directly at flowlines and electric cables. Tom James Regg wrote, On 12/1/2005 3:16 PM: Lou came across an interesting one yesterday at Nordic 3 (ICRU 3J-101). I've attached both operator's and Lou's reports. Diverter functioned properly; line placement is concern here (details on Lou's report). Guess we do not dictate any requirements for layout; seems that layout should be something that could easily be addressed in PTD. The way it is arranged on 3J-101, they might just as well have asked for a waiver from requirements (except my understanding is BP and CPAI have determined a diverter waiver to be an unnecessary risk - go figure!). Another one of those personnel safety risk issues that are a gray area for us. Jim 1 of 1 12/13/2005 2:13 PM ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems inspection Report Submit to: ~ir~zvL~adr^in.st<;tr_..s.K.:~ i30a`~i:~j.7'i:Qi`.tiP41v`:2v~;adn ttn.~ataiC,3b'. v^~ h:~h_fEec~Pnstei>; ~N;adr::n.state.a~:..:,. Operation Drlg Contractor: Nordic Rig No. Operator: Conoco Phillips Oper. Rep Field/Unit & Well No.: KRU / 3J-101 Rig Rep. Location: Sec. 3 T. 12N R. 9E Date: 30-Nov-05 Development Exploratory: X 3 PTD # 205-157 Rig Ph. # 659-7446 Pete Wilson/Larry Myers Ron Rice Merdian 1205FSL.565FWL ....... ..... .. .. ........ ..... .. .......... MISC. INSPECTIONS: Location Gen.: Good Wel! Sign: Yes Housekeeping: Good (Gen.) Drlg. Rig: Yes Reserve Pit: N/A Flare Pit: N/A DIVERTER SYSTEM INSPECTION: Diverter Size: 21 1/4" in. ',Divert Valves} Full Opening: Yes '.Valve(s) Auto & Simultaneous: Yes Vent Line(s) Size: 16" in. Vent Line(s) Length: 105 ft. .Line(s) Bifurcated: No 'Line(s) Down Wind: N/A Line(s) Anchored: Yes Turns Targeted /Long Radius: N/A GAS DETECTORS: Methane Hydrogen Sulfide: 2900 psig 1600 psig min 31 sec. 2 min 25 sec. 2025 psig Light Alarm No Yes No Yes No Yes Light Alarm Red Yes Yellow Yes ~E\!I*R . ~ . H t G. ::::::::::::::::::::: i:;::::::::::::::::::::::::::::::::..................................~..- f..............:.....:.....:...:.....:.....:...:.........:.:...:...:.:...:.....:...:.....:.:.:...........:...:.:...:.:.:.:...:.:. -= - N Remarks: Items 0 Repair Items Within Day (s) And contact the Inspector @ 659-3607 AOGCC REP.: LOU Grlmaldl ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 4 bottles MUD SYSTEM INSPEGTION: Trip Tank: Mud Pits: Flow Monitor: OPERATOR REP.: Pete Wilson Diverter Test (for rigs) BFL 05/29/03 2005-1130 Diverter Nordic3 KRU 3J-101.x1s MEMORANDUM TO: Jim Regg P.I. Supervisor THRU: FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oi{ and Gas Conservation Commission DATE: November 30, 2005 SUBJECT: Diverter Function Test Nordic 3 Conoco Phillips 3J-101 205-157 Kuparuk River Field, West Sak Pool Operator Rep.: Pete Wilson Op. phone: Contractor Rep.: RiceM/edin Rig phone: MISC. INSPECTIONS: Location Gen.: P Well Sign: P Housekeeping: P (Gen.) Drlg. Rig: P Reserve Pit: NJA Flare Pit: N/A MUD SYSTEM INSPECTION: Light Alarm Trip Tank: P P Mud Pits: P P Flow Monitor: P P GAS DETECTORS: Light Alarm Methane P P HzS: P P Op. E-Mail: Rig E-Mail: ACCUMULATOR SYSTEM: P1F Systems Pressure: 2900 psig P Pressure After Closure: 1600 psig P 200 psi Recharge Time: :31 min:sec P FuIlRecharge Time: 2:25 min:sec P Nitrogen Bottles: 4 X 2025 PSI DIVERTER SYSTEM INSPECTION: Diverter Size: 21 1/4 in. Divert Valve(s) Full Opening: P Valve(s) Auto & Simultaneous: P Vent Lines} Size: 16 in. Vent Line(s) Length: 90 ft. Line(s) Bifurcated: N/A Line(s) Down Wind: F Line(s) Anchored: P Turns Targeted /Long Radius: N/A Access Road Cam Cam ^ ^ ^ a ^ o ^ o ^ ^ ^ ^ ^ ^ o Manifold Building Wind Direction Test's Details The Diverter function test went very well with the 16" knife valve opening (24 seconds) before the 21 1/4" Annular closed fully (55 seconds). The recharge on the accumulator was well within acceptable time limits. The gas detectors were being calibrated during the test. The Vent line layout was the major drawback in this setup. The line was pointed in the direction of the rig camp and directly at the only access and egress from this pad. The prevailing winds tended to only intensify this poor choice of direction. I inquired as to why the vent line did not exit the sub from the front and point towards empty tundra I was told that the doors that it would have to go through were too big and would be hard to keep the sub warm. I think a little plywood may have helped. I discussed this with Pete Wilson and Bobby Morrison who felt the risk was minimal and did not seem inclined to move the vent line. Total Test Time: 3 hours Number of failures: 2 cc: Attachments: 2005-1130_D iverter_N ordic3_K R U_3J-101 _Ig.xls ~~Q~[~ 0~ G~~w~~31~ AL~58A OII, A1QD tz~-,S CO1~T5ER~~TIO1~T CO1~II-'ii5SIO1~T Randy Thomas GKA Drilling Team Leader Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: KRU West Sak 3J-101 FRANK H. MURKOWSKI, GOVERNOR Conoco Phillips Alaska, Inc. Permit No: 205-157 Surface Location: 1205' FSL, 565' FWL, Sec. 3, T12N, R9E Bottomhole Location: 890' FSL, 565' FEL, Sec. 3, T12N, R9E Dear Mr. Thomas: 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this~~day of October, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas~conocophillips.com October 19, 2005 . Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Suite 100 Anchorage, Alaska 99501 ~.. ,.® ~ask~ l~i~ ~ ~ ~u, ~~-~~~~s~r; 1~~$~~9~~~?~: Re: Applications for Permit to Drill, West Sak Exploration Well 3J-101 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill an onshore exploration well thru the West Sak sands. This well will be designated 3J-101. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. The expected spud date of 3J-101 is November 25th, 2005. If you have any questions or require any further information, please contact Tom Brassfield at 265-6377. Sincerely, `.~.. ~-- Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMf4 .ION PERMIT TO DRILL 20 AAC 25.005 ~i.J~~ V ~C~ ~ ~ ~~~~ ~o~~ tae Type of Work: Drill ~ Redrill Re-entry ~ 1b. Current Well Class: Exploratory ~ Devel ' 1 Stratigraphic Test ~ Service ~ Development Gas one 0 2. Operator Name: ~1s ~a°: J.ms' Cono~ Phi~ps Alaska, Inc. 5. Bond: Blanket ~ Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 3J-101 3. Address: PO Box 100360, Anchorage, AK, 99510-0360 6. Proposed Depth: MD: 6,209' ~ TvD: 3,787' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1205'FSL,565' FWL,Sec 3,T12N,R9E ~ 7. Property Designation: ADL 25630' West Sak Oil Pool- Exploration Top of Productive Horizon: 989'FSL,3079'FWL,Sec 3,T12N,R9E 8. Land Use Permit: LE 931805 13. Approximate Spud Date: 25-Nov-05 Total Depth: 890'FSL,565'FEL,Sec 3, T12N,R9E ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: ~' `"` 3s1.ufC5. 4b. Location of Well (State Base Plane Coordinates): Surface:x- 519544 ' y- 6,002,888 Zone- 4 10. KB Elevation (Height above GL): 30 feet 15. Distance to Nearest Wellfoz Within Pool: None 16. Deviated wells: Kickoff depth: 500 feet ' Maximum Hole Angle: 86 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1570 Surface: 1186 ~ 18. Casing Program: Size Specifications Setting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 94 K-55 Welded 80' 30' 30' 110' 110' ~ 260 cf ArcticCRETE 13-1(2" 10-3/4" 45.5 L-80 BTC 2259' 30' 30' 2289' ' 2058' ~ 520 sxASLite+ 110 sx DeepCRETE 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat [] Diverter Sketch 0 Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 10!19!2005 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfield@265-6377 Printed Name Randy Thomas Title GKA Drilling Team Leader Signature ~ ~ `s~~'^ Phone 265-6830 Date 10/19/2005 Commission Use Only Permit to Drill Number: ~Q~ /~~ API Number: 50- d~`~~ Z3 ~~ `~ Permit Approval Date: .. See cover letter for other requirements. c~ Conditions of approval : '~~, ~3o~c.~,i~~tsv l't3~-~G~W~~ ~~ S~~ ~~ ~9~ ~tCC~?~~~ ~ ~ c~-~ Rr~.~~~03 S(„1~~ Sample equired Yes ~] No ~ Mud log required Yes ~ No Hydr a sulfide measures Yes ~ N~op ~ Directional survey req~.uirAed~ Yes ~ No Other: ~ y 'Q • i r~~: C~w~ , ~ j ~~ ~G~E ``v~~~. C~ CJ.~1'~~~ ~J ~ ~~ APPPpVED BY Approved b , THE COMMISSION Date: ~ ~-~ c~$" ~I v - t,, .-' Form 10-401 Revised 0612004 ~ D ~ ~ ~ ~ ~ ~ Submit inDuplicate ~tion for Permit to Drill, Well 3J-101 Revision No.O Saved: 18-Oct-05 Permit It -West Sak Well #3J-101 App/ication for Permit to Drill Document M a x i m i x E 1411 VGlue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..........................................................................:....................... 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 3J-101 PERMIT lT 10 18 05.doc Page 1 of 7 Printed: 18-Oct-05 ORIGINAL • ~tion for Permit to Drill, Well 3J-101 Revision No.O Saved: 18-Oct-05 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 7 Attachment 1 Nordic 3 West Sak Diverter & 3ksi BOP Configuration .................................................. 7 Attachment 2 Directional Plan ............................................................................................................... 7 Attachment 3 Drilling Hazards Summary .............................................................................................. 7 Attachment 4 Cement Data ................................................................................................................... 7 Attachment 5 WeII Schematic ............................................................................................................... 7 1. WeII Name Requirements of 20 AAC 25.005 (f) Each we// must be identified by a unique name designated by the operator and a unique API number assigned by the commission under Zt1 AAC25.040(b). For a we/! with mu/tiple we//branches, each branch must Simi<ar(y be identited by a unique name andAPl number by adding a suffix to the name designated for the wel/ by the operator and to the number assigned to the weff by the commission. The well for which this Application is submitted will be designated as 3J-101. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application far a Permit to Driil must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application: (Z) a plat identifying the property and the property`s owners and showing (A)the coordinates of the proposed iocation of the we// at the surface, at the top of each objective formation, and at tota/depth, referenced to governmental section /fines (8) the coordinates of the proposed location of the well at the surface, referenced to the state p/ane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (G) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1205' FSL, 565' FWL Section 3, T12N, R9E ASPZone 4 NADUCoordinates RKB E/evation 73' AMSL Northings; 6,DOZ,888 Eastings; 519,544 Pad Elevation 43' AMSL Location at Top of Productive Interval West Sak 989' FSL, 3079' FWL, Section 3, T12N, R9E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.' 4, 310 Northings; 6,002,678 Eastings: 522,059 Tota/ ~erticalDe th, RKB; 3,017 Total ~ertica! De th SS.• 2 944 Location at Totaf De th 890' FSL, 565' FEL, Section 3, T12N, R9E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB; 6,209 ` Northings; 6,002,584 Eastings.• 523,695 Tota/ Vertical De th RKB.• 3 787 Tota/ t/ertical De th, SS.• 3 714 and (D) other information required by 20.4AC25.050(b); 3J-101 PERMIT lT 10 18 05.doc Page 2 of 7 Printed: 18-Oct-05 ORIGINAL lion for Permit to Drill, well 3J-101 Revision No.O Saved: 18-Oct-05 Requirements of 20 AAC 25.050(b) Ifs well is to be intentions//y deviated, the application for a Permit to Orill (Form ZD-40.1) must (1) include a p/at, drawn to a suitab/e sca/e, showing the path of the proposed wellbore, including al/adjacent weflbares within 201T feet ofany portion of the proposed we/!; Please see Attachment 1: Directional Plan and (2) for all wet/s within 200 feet of the proposed wetJbore (A) list the names of the operators of those wells, to the extent that Chase names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certr`fred mail; or (B) state that the app/icant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on fi/2 with the commission and identified in the application; (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 AACZ5.035, ZO AAC 25.036, ar ZO AAC Z5. D.37, as applicab/e; An API :ll" x 5,000 psi BOP stack (RSRRA) will be utilized to drill well iQ-101. For all operations the stack will be equipped with 2-7/8" to 5" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 5" DP rams in the lowermost cavity. See attached diagram entitled °Nordic 3 BOP Configuration" for clarification. Due to the formation pressures being far less than the rating of the BOPE, CPAI requests that the stack be operated under the 3000 psi BOP guidelines. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ica!ion for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the cammissia,~ and identified in the application; (4) information an drilling hazards, including (A) the maximum downhale pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based an a methane gradient; The expected reservoir pressures in the West Sak sands in the iQ-101 area vary from 0.43 to 0.45 psi/ft, ~ or 8.3 to 8.6 ppg EMW (equivalent mud weight). f The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11} and the deepest planned vertical depth of the West Sak A2 sand formation is 3,489 feet giving a MPSP of 1,186 psi, calculated thusly: MPSP = (3,489 ft)*(0.45 - 0.11 psi/ft) = 1,186 psi ' (B) data on potential gas zanes; The well bore is not expected to penetrate any gas zones. r and (C) data concerning potentia/causes of ho% prob/ems such as abnarma(!y geo pressured strata, lost circulation zones, and zanes that have a i~ropensity for differential sticking; Please see Attachment 2: iQ-101 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on fi/e with the commission and identified in the application.• (S) a descripa ion of the procedure for conducting formation integrity tests, as required under 20 AAC25.030(f); 3J-101 PERMIT IT 1018 05.doc Page 3 of 7 Printed: 18-Oct-05 ORIGINAL i~tion for Permit to Drill, Well 3J-101 Revision No.O Saved: 18-Oct-05 3J-101 will be not be completed ,but is being planned as a "keeper" well for future utility as a West Sak wellbore. The 10-3/4"shoe track will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.OD5(c)(6) Rn application for a Permit to Dri// must be accompanied by each of the fo/%wing items, except far an item already on file with the commission and identified in the application,• (6) a complate proposed casing and cementing program as required by 20 ARC 25.03fl, and a description of any slotted finer, pre- pen`orated liner, or sateen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Ho% Top etm Csy/Tbg Size Weight Length MDITVD MD/TVD OD in in lblft Grade Connection ft ft ft Cement Pro ram 20" 40"" 94 K55 Welded 80 30 / 30 110 / 110 Cemented to surface with 260 cf ArcticCRETE 10-3/4" 13-1/2" 45.5 L-80 BTC 2259 30 / 30 2289 /2058 Cemented to Surface w/ 520 sx ASLite Lead 110 sx Dee CRETE Tail 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) Rn application far a Permit to Dri!! must be accompanied by each of the fo/lowing items, except for an item a/ready on file with tfie commission and identified in the application: (7) a diagram and description of the diuerter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 2D AAC 25.035(h)(2); See attached schematic. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Pem~it to DriJ! must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,• Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (LSND) Surface to 10-3/4"Casin Point Mud Properties Density (ppg) 9.2 - 9.5 ~ Funnel Viscosity (seconds) 150-250 Yield Point (cP) 30 - 45 APl Filtrate (cc / 30 min)) 4 - 6 Chlorides (mg/l) <600 pH 9.0 - 9.5 3J-101 PERMIT lT 10 18 05.doc Page 4 of 7 Printed: 18-Oct-05 ORIGINAL • Production Hole Mud Program (FLOPRO NT Drill-in Fluid) ~tion for Permit to Drill, Well 3J-101 Revision No.O Saved: 18-Oct-05 IO-3/4"Casin Point to TD Mud Properties Density (ppg) 9.0 - 9.2 ~ Plastic Viscosity 10 Yield Point (cP) 28-30 - 45 APl Filtrate (cc 130 min)) 4 - 6 Chlorides (mg/l) 15,000-17000 pH 9.0 - 9.5 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nordic #3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application far a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication: (9) for an exp/oratory or stratigraphic test we!/, a tabu/ation setting aut the depths of predicted abnormal/y geo pressured strata as required by ZO AAC ZS.033(f); Not applicable: Well is being drilled from an existing producing Kuparuk pad with known formation pressures. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item aiready on fi/e with the commission and identified in the application: (1 D) for an exploratory ar stratigraphic test we/% a seismic refraction or reflection analysis as required lay ZO AAC25. t161(a); Not applicable: Well is being drilled from an existing producing Kuparuk pad with known formation pressures. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Dri// must be accompanied by each of the fo/lowing items, except far an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or t7oating drilling vessel, an analysis ofseabed conditions as required by ZO AAC25.061(b),~ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application For a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of ZO AAC 25. ©25 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. ORIGINAL 3J-101 PERMIT IT 10 18 05.doc Page 5 of 7 Printed: 18-Oct-05 • ~tion for Permit to Drill, We11 3J-101 Revision No.O Saved: 18-Oct-05 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dri11 must be accompanied by each of the fol/owing items, except for an item a/ready on ft/e with the commission and identified in the application: The proposed drilling program for 37-101 is listed below. 1. Excavate cellar, install cetlar box, set and cement 20" x 34" insulated conductor to +/-110' RKB (2 joints). Install landing ring on conductor. 2. .Move in /rig up Nordic #3. Install. 21-1/4" Annular with 16" diverter line and function test. Notify AOGCC 24 hours prior to test. , ~ 3. Spud and directionally drill 13-1/2" hole to casing point at +/_ 2289' MD /2058' TVD as per directional plan. Run MWD/LWD (GR/RES)tools as required for directional monitoring. Mud log from base of the surface conductor to TD r 4. Run and cement 10-3/4", 45.5 ppf, L-80, BTC casing to surface. Displace cement with water base mud and, pressure test casing to 3000 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 11" x 5,000 psi BOP's and test to 3000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. s 6. PU 8-1/2" bit and drilling assembly, with MWD &LWD (GR/Res/Neutron/Density). RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak- off (or FIT if gradient reaches 16 ppg equivglent) recording results. Change over to the FLOPRO drill-in fluid. 8. Directionally drill to TD at 6209' MD / 3787' TVD. Make short trip and condition hole/mud for E- line logs. 9. RU & run E-line logs per program. Currently planned are 1) a drill pipe conveyed MDT, 2) E-line conveyed Dipole SoniclFMl and 3) percussion sidewall cores. 10. PU P&A BHA, TIO and lay open hole cement plugs across hydrocarbon bearing zones as discussed with AOGCC. 11. Set cement retainer at 10-3/4" casing shoe and pump cement below and above the retainer per AOGCC regulations. 12. Run and land 3-1/2" circulation string inside the surface casing string leaving diesel as a freeze protect fluid in the tubing and annulus. 13. Nipple down the BOPE's. Install a dry hole tree for future utility and pressure test to 3000 psi. 14. Secure well and release rig. 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill musts be accompanied by each of the following items, except for an item already on file with the commission and identified m the app/ication: (14) a genera! description of haw the operator plans to dispose of dri/ling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annu/ar dispose/operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. At some future time, CPAI may request authorization for the disposal of drilling waste via the annulus on 37-101 by filing with the AOGCC a 10-403 supplement with additional information as required under 20 AAC 25.080. 3J-101 PERMIT /T 10 18 05.doc Page 6 of 7 Printed: 18-Oct-05 ORIGINAL • 15.Attachments Attachment 7 Nordic 3 West Sak Diverter & 3ksi BOP Configuration Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Cement Data Atfachment 5 Well Schematic ~tion for Permit to Drill, Well 3J-101 Revision No.O Saved: 18-Oct-05 3J-101 PERMIT /T 10 18 05.doc Page 7 of 7 Printed: 18-Oct-05 • • Diverter System Schematic West Sak Exploration Wells, Vetco Gray Wellhead System, Nordic Rig 3 ----- Open--- 5 ~ ------- To Accumulator I Closed '- ~ E---------f ~- I I _ _ _ From ~ ~ ~ Accumulator I I I 1 I I I I I 1 I I Closed i ~ I I J I ---~ Open ~--~' 4 3 Top of Wellhead 2 .- 6 Pad Level 20° ~ 0.00 ft. n 4--(d en er ine o ~•' 16" Diverter Line Bottom of Diverter x.xx ft. (xx in) KEY: 1. .Conductor Casing: 20" 2. Landing Ring: 20" 2000 psi slip-on 3.Starting Head Adapter: 20" Vetco Gray Quick Connect Bottom x AP121-1/4" 2000 psi Flange. Up, Vetco Gray. f1C. r....L.... Q......1. 7A ~ /Aa ~ntln .....: a....-. .......1 L. ,.al...,.,....:aL dCn ..:.J-. -..al-a 5. Annular Preventer: Hydril MSP 2,000 psi annular -Nordic 7. Knife Valve: ANSI 16"-150# RF: The valve opens automatically upon closure ofi annular preventer -Nordic 8. Diverter Line: 16" -Nordic ----~ ~~ ~~~ i TJB 10/14/05 11-5 BOP System Schematic West Sak Exploration Wells, Vetco Gray Wellhead System, Nordic Rig 3 Top of We vel t. ~ v 1. Landing Ring, 20" x 10-3/4", Vetco Gray 2.Vetco Gray Wellhead system w/API 11" " 5000 psi flange up 3. Double Studded Adapter, 11" 5000 psi down x 11" 5000 psi up 4. Single Ram BOP, 11" x 5000 psi, with pipe rams, Nordic 5. Drilling Spool, 11" x 5000 psi, w! 2 Side Outlets, Nordic 6. Double Ram BOP, 11" x 5000 psi, with variable Pipe Rams on Top and Blind Rams on Bottom, Nordic 7. Annular BOP, 11" x 5000 psi, Hydril GK, Nordic 8. Choke Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nordic 9. Choke Line Valve, Hydraulically Operated, 3-1 /8"" x 5,000 psi, Nordic 10. Kill Line Valve, Manual Operation, 2-116" x 5,000 psi, Nordic 11. Kill Line Valve, Manual Operation, 2-1/16"" x 5,000 psi, Nordic prepared by Tom Brassfie/d 10h4l05 • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 3J Pad Plan: 3J-101 (wp07) Proposal Report 05 October, 2005 HALL.IE3LIRTON Sperry Qrilling Services ORIGINAL o~ ~ Proposed SHL @ 1205ft FSL & 565ft FWL -Sec 3 - T12N - R09E1 KOP @ 500ft MD, 500ft ND -Build @ 2.5°/100 soo o^ 750 10° loon 20- 1250 . -_^ E3 aSe Of Perm. 30 2 nso a O ~ 2000 r ~ 2250 Continue Build @ 3°/100ft , 700ft MD, 700ft TVD Sail @ 37.39° Inc : 1780ft MD, 1693ft ND ~' ConocoPhillips Ak~ska Build @ 4°/100ft to 65 Inc - 1880ft MD, 1772ft N~ ® 0 10 3/4" CSG @ 2289ft MD, 2058ft ND : 1145ft FSL & 1308ft FWL -Sec 3 - T12N - R09E ~u C yo eo Sail @ 62° Inc : 2495ft MD, 2168ft N] CASING DETAILS No ND MD Name Size 1 2058.00 2288.93 10 3/4" 10-314 FORMATION TOP DETAILS No. NDPath MDPath Formation 1 1693.00 1779.62 Base of Perm 2 2058.00 2288.93 T3 + 800 3 2197.00 2557.90 Ugnu C 4 2561.00 3333.36 Ugnu B 5 2868.00 3987.40 K-13 6 3017.00 4309.55 WSAK D (W FLT) 7 3095.00 4536.85 WSAK B (W FLT) 8 3261.00 5437.83 WSAK D (E FLT) 9 3330.00 5582.04 WSAK B (E FLT) 10 3489.00 5837.45 WSAK A2 11 3702.00 6109.22 Base WSAK HALLIBU RTON SWn'II Drt11I~y S~nla~s Project: Kuparuk River Unit Site: Kuparuk 3J Pad Well: Plan 3J (40' N of 16) Wellbore: Plan 3J (40' N of 16) Plan: 3J-101 (wp07) Build @ 4°/100ft to 86.34° Inc - 4225ft MD, 2980ft ND~ Sail @ 86.34° Inc : 4835ft MD, 3145ft ND ~Ory--- Drop @ 5°/100ft : 5011ft MD, 3156ft ND 3J-101 (Top WSAK W of Fk) (wp07) 8 -- - o _-- .__ ^o - - m° --------------------------------------- ---- ---------------------------------- Prognosed Fault Crossing : 5011ft MD, 3156ft ND ao 3J-101 T2 (Top WSAK E of Flt) (wp07) ease wsn-c TD @ 6209ft MD, 3787ft ND :890 ftFSL & 565 ft FEL -Sec 3 - T12N - R09E -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 Vertical Section at 94.50° (500 Win) 1 c 0 0 L r O Z t 3 O -1 _1 0 Project: Kuparuk River Unlt ~t~?$ Site: Kuparuk 3J Pad pig WeIL• Plan 3J (40' N of 16) Wellbore: plan 3J (40' N of 16) Plan: 3J-101 (wp07) HALL.IiBUFtT©!V Sperry Ddllinq Sewicss Proposed SHL @ 1205ft FSL & 565ft FWL -Sec 3 - T12N - R09E ' r ,' KOP @ 500ft MD, 500ft ND -Build @ 2.5°/100ft TD @ 6209ft MD, 3787ft TVD :890 ftFSL & 565 ft FEL -Sec 3 - T12N - R09E ,' ,~ Continue Build @ 3°/100ft , 700ft MD, 700ft ND ~~ ~~ Sail @ 37.39° Inc : 1780ft MD, 1693ft ND ` ~~ ,' ,' Prognosed Fault Crossing : 5011ft MD, 3156ft ND ` '~ 3J-101 (Top WSAK W of Flt) (wp07) 3J-101 T2 (Top WSAK E of Flt) (wp07) ~~ ~ ~ ~ ~ ~ ` ~ ~ ~~ ~ ~ ~ i ` ~ ~ ~ ~ ~ i i ~ i ~ i ~ , i ~ ~ i ~ ~ i ~ ~ ~ ~ ~ ~ i ` ~ ~ ` ~ i ~ ~ i ~ ~ ~ i ~~ ~ i ~ ~ Drop @ 5°/100ft : 5011ft MD, 3156ft ND ~~ 1~ Sail @ 86.34° Inc : 4835ft MD, 3145ft ND ', ~~ '~ ~~ Build @ 4°/100ft to 86.34° InC - 4225ft MD, 2980ft ND T M4zimuths to True Noi Magnetic North: 24.2 ~ \~ Magnetic Fie Build 4°/100ft to 65 Inc - 1880ft MD 1772ft ND ~ Sail @ 62° Inc : 2495ft MD, 2168ft ND Strength: 57556.91 @ ~ Dip Angle: 80.8 `~ Date: 9/20/201 ~ Model: BGGM20 10 3/4" CSG @ 2289ft MD, 2058ft ND : 1145ft FSL & 1308ft FWL -Sec 3 - T12N - R09E -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 West(-)/East(+) (500 ft/in) ~ ~ / ' Halliburton Company HALi.IBL,RTON ©n~C4 1~~~ ~p 5 ~ Planning Report -Geographic ~ ~ ~ ~~ ~~ ~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 3J (40' N of 16) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 73.OOft ((45+28)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 73.OOft ((45+28)) Ske: Kuparuk 3J Pad North Reference: True Well: Plan 3J (40' N of 16} Survey Calculation Method: Minimum Curvature Wellbore: Plan 3J (40' N of 1`6) Design: 3J-101 (wp07) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (F~cact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor -- - -- --- Well Plan 3J (40' N of 16) Well Position +N/S 0.00 ft Northing: 6,002,887.50 ft Latitude: 70° 25' 08.593" N +E/-W 0.00 ft Easting: 519,544.00 ft Longitude: 149° 50' 26.852" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 45.OOft - , Wellbore Plan 3J (40' N of 16) - - -- Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 9I20t2005 24.24 80.83 57,557 Design 3J-101 (wp07) - - - Audit Notes: Version: Phase: PLAN Tie On Depth: 45.00 'Vertical Section: Depth From (TVD) +N/-S +E!-W Direction (ft) (ft) (ft) (°) 45.00 0.00 0.00 94.50 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI_S +E/_yy Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 45.00 0.00 0.00 45.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 700.25 5.01 94.57 700.00 -0.70 8.72 2.50 2.50 0.00 94.57 1,779.62 37.39 94.57 1,693.00 -31.38 392.59 3.00 3.00 0.00 0.00 1,879.62 37.39 94.57 1,772.45 -36.22 453.11 0.00 0.00 0.00 0.00 2,495.12 62.00 95.03 2,167.53 -75.54 917.24 4.00 4.00 0.07 0.98 4,225.14 62.00 95.03 2,979.60 -209.49 2,438.95 0.00 0.00 0.00 0.00 4,300.02 65.00 95.03 3,013.00 -215.36 2,505.69 4.00 4.00 0.00 -0.01 4,835.43 86.34 93.15 3,144.76 -251.74 3,020.14 4.00 3.99 -0.35 -5.14 5,011.03 86.34 93.15 3,155.97 -261.37 3,195.12 0.00 0.00 0.00 0.00 5,437.83 65.00 93.15 3,261.00 -283.97 3,605.63 5.00 -5.00 0.00 -180.00 6,109.22 31.43 93.15 3,702.00 -311.09 4,098.38 5.00 -5.00 0.00 -180.00 6,209.22 31.43 93.15 3,787.33 -313.95 4,150.45 0.00 0.00 0.00 0.00 10/5/'1005 5:57:49PM Page 2 of 6 COMPASS 2003.11 Build 48 ~~~G1NAL ~/ ~ Halliburton Company ~ ~ AT N MALI. BU A COnoc4f'hiff~ Planning Report -Geographic - - Sperry Orillieg Senesces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 3J (40' N of 16) Company: ConocoPhillips Alaska_(Kuparuk) TVD Reference: Planned RKB @ 73.OOft ((45+28)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 73.OOft ((45+28)) Site: Kuparuk 3J Pad. North Reference: True Well: Plan 3J (40' N'of 16) Survey Calculation Method: Minimum Curvature Wellbore: Plan 3J (40' N of 16) Design: 3J-101 (wp07) Planned Survey 3J-101 (wp07) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting pLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) lft) (ft} (ft) (°/100ft) (ft) 5,418.55 65.96 93.15 3,253.00 3,180.00 -283.00 3,588.11 6,002,613.92 523,132.49 5.01 3,599.26 5,437.83 65.00 93.15 3,261.00 3,188.00 -283.97 3,605.63 6,002,613.00 523,150.00 5.00 3,616.79 WSAK D (E F LT) - 3J-101 T2 (Top WSAK E of Fk) (wp07) 5,442.54 64.76 93.15 3,263.00 3,190.00 -284.20 3,609.89 6,002,612.78 523,154.26 5.00 3,621.06 5,500.00 61.89 93.15 3,288.79 3,215.79 -287.02 3,661.15 6,002,610.09 523,205.53 5.00 3,672.39 5,582.04 57.79 93.15 3,330.00 3,257.00 -290.92 3,731.96 6,002,606.38 523,276.34 5.00 3,743.28 WSAK B (E F LT) 5,600.00 56.89 93.15 3,339.69 3,266.69 -291.75 3,747.06 6,002,605.59 523,291.44 4.99 3,758.40 5,700.00 51.89 93.15 3,397.90 3,324.90 -296.22 3,828.21 6,002,601.33 523,372.60 5.00 3,839.65 5,800.00 46.89 93.15 3,462.97 3,389.97 -300.39 3,903.99 6,002,597.36 523,448.38 5.00 3,915.53 5,837.45 45.02 93.15 3,489.00 3,416.00 -301.87 3,930.87 6,002,595.95 523,475.25 5.00 3,942.43 WSAK A2 5,900.00 41.89 93.15 3,534.40 3,461.40 -304.23 3,973.82 6,002,593.70 523,518.21 5.00 3,985.44 6,000.00 36.89 93.15 3,611.66 3,538.66 -307.72 4,037.17 6,002,590.38 523,581.56 5.00. 4,048.86 6,100.00 31.89 93.15 3,694.15 3,621.15 -310.82 4,093.55 6,002,587.43 523,637.94 5.00 4,105.31 6,109.22 31.43 93.15 3,702.00 3,629.00 -311.09 4,098.38 6,002,587.18 523,642.77 5.00 4,110.15 Base WSAK 6,200.00 31.43 93.15 3,779.46 3,706.46 -313.69 4,145.65 6,002,584.70 523,690.04 0.00 4,157.48 6,209.22 31.43 93.15 3,787.33 3,714.33 -313.95 4,150.45 6,002,584.45 523,694.84 0.00 4,162.28 TD ~ 6209ft MD, 3787ft TVD :890 ftFSL & 565 ft FEL -Sec 3 - T12N - R09E .- 10/52005 5:57:49PM Page 5 of 6 COMPASS 2003.118ui1d 48 ~0~1~ ~ •-' Halliburton Company HAL.LiBURTON C0110C~ ~11~~1 S p Planning Report -Geographic - -- - ~ -- Alaska S~s^r!r Drifting Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 3J (40' N of 16) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 73.OOft ((45+28)) Pro}ect: Kuparuk River Unit MD Reference: Planned RKB @ 73.OOft ((45+28)) Site: Kuparuk 3J Pad North Reference: True Well: Plan 3J (40' N oY16) Survey Calculation Method: Minimum Curvature Wellbore: Plan 3J (40' N of 16) Design: 3J-101 (wp07) Geologic Targets Plan 3J (40' N of 16) TVD Target Name +NI-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,156.00 3J-101 Fault Intersection -260.90 3,199.65 6,002,635.00 522,744.00 - Point 3,261.00 3J-101 T2 (Top WSAK E of Flt) (wp07) -283.97 3,605.63 6,002,613.00 523,150.00 - Point 3,013.00 3J-101 (Top WSAK W of Flt) (wp07) -215.36 2,505.69 6,002,678.72 522,050.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diamet®r (ft) (ft) (°) ('~) 2,288.93 2,058.00 10-3/4 13-1/2 Prognosed Formation intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) (ft) (ft) (ft) Name 1,779.62 37.39 94.57 1,693.00 -31.38 392.59 Base of Perm 2,288.93 53.76 94.91 2,058.00 -60.41 743.42 T3 + 800 2,557.90 62.00 95.03 2,197.00 -80.40 972.46 Ugnu C 3,333.36 62.00 95.03 2,561.00 -140.44 1,654.55 Ugnu B 3,987.40 62.00 95.03 2,868.00 -191.08 2,229.83 K-13 4,309.55 65.38 94.99 3,017.00 -216.12 2,514.31 WSAK D (W FLT) 4,536.85 74.44 94.15 3,095.00 -233.07 2,726.88 WSAK B (W FLT) 5,437.83 65.00 93.15 3,261.00 -283.97 3,605.63 WSAK D (E FLT) 5,582.04 57.79 93.15 3,330.00 -290.92 3,731.96 WSAK B (E FLT) 5,837.45 45.02 93.15 3,489.00 -301.87 3,930.87 WSAK A2 6,109.22 31.43 93.15 3,702.00 -311.09 4,098.38 Base WSAK 10/52005 5:57:49PM Page 6 of 6 COMPASS 2003.11 Build 48 ORIGINAL • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 3J Pad Plan 3J -101 (wp07) Anticollision Summary 05 October, 2005 HAL.L.1E'~UF~Tt31V Sperry Drilling Services 3.1-16 3J-15 3J-19 3J-14 270 3J-13 3J-12 3J-11 3J-10 3J-09 C SURVEY PROGRAM Dale: 200510-IK'1'011:INF.00 Validated: Ycs Version: Dgih Fmm Depth To Suney/Plan Trpl 4CW iN1U.W 3J-101 (wp07) MND 900.011 6AY.22 3J-101 (x~p07) MWD 0 so From Colour To MD 45 250 500 750 250 500 750 1000 1250 1500 - 1750 2000 2500 3000 3500 5000 -- 6500 8000 9500 11000 12500 180 1000 1250 1500 1750 Travelling Cylinder Azimuth (TFO+AI.1) ~°~ vs Centre to Centre Separation X250 ft/in k 2000 2500 3000 3500 5000 6500 REFERENCEINFORMATION 8000 Coortlinate (WE) Reference: Well Plan 3J (40' N of 16), True North 9500 Vertical (ND) Reference: Planned RKB ~ 73.OOR ((45+28)) 11000 Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Planned RKB @ 73.00(1 ((45+28)) Calculation Method: Minimum Curvature NAD 27 ASP Zone 4 : WELL DETAILS: Plan 3J (40' N of 16) ANTI-COLLISION SETi1NGS Grountl Level: 45.00 Interpolation Method: MD Interval: 50Stalions +WS +EI-W Northing Easting Latitude Longitude Depth Range From: 45.00 To 6209.22 0.00 0.00 6002887.50 519544.00 70°25'8.593N 149°50'26.852W Maximun Range:1337.55417427165 Reference: Plan: 3J-101 (wp07) 0 180 Travelling Cylinder Azimuth (rFO~A7.1) I°~ vs Centre to Cenfre Separafion ~ IS ft/ink 90 Sec MD Inc Azi TVD +W-S +EI-W DLeg TFace VSec Target 1 45.00 0.00 0.00 45.00 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 3 700.25 5.01 94.57 700.00 -0.70 8.72 2.50 94.57 8.74 4 1779.62 37.39 94.57 1693.00 -31.38 392.59 3.00 0.00 393.84 5 1879.62 37.39 84.57 1772.45 -36.22 453.11 0.00 0.00 454.56 6 2495.12 62.00 95.03 2167.53 -75.54 917.24 4.00 0.98 920.34 7 4225.14 62.00 95.03 2979.60 -209.49 2438.95 0.00 0.00 2447.87 8 4300.02 65.00 95.03 3013.00 -215.36 2505.69 4.00 -0.01 2514.87 3J-101 (Top WSAK W of FR)(K 9 4835.43 86.34 93.15 3144.76 -251.74 3020.14 4.00 -5.14 3030.58 10 5011.03 86.34 93.15 3155.97 -261.37 3195.12 0.00 0.00 3205.77 11 5437.83 65.00 93.15 3261.00 •283.97 3605.63 5.00 -180.00 3616.79 3J•101 T2 (Top WSAK E of Fk) 12 6109.22 31.43 93.15 3702.00 -311.09 4098.36 5.00.180.00 4110.15 13 6209.22 31.43 93.15 3787.33 -313.95 4150.45 0.00 0.00 4162.28 ConocoPhillips AWSka (Kuparuk) Engineering Slot West Sak Calcuation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 'b-' Conoco~illips Alaska Company; ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit. Reference Site: Kuparuk 3J Pad Site Error: 0 OOft Reference Well: Plan 3J (40' N of 16} Well Error: O.OOft Reference Wellbore Plan 3J (40'N of 16) Reference Design: 3J-101 (wp07) Halliburton Company Anticollision Report Local Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • HA~usu>Amnll Spsr-Y Drilliin~ Sefvicars Well Plan 3J (40' N of 16) Planned RKB @ 73.OOft ((45+28)) Planned RKB @ 73.OOft ((45+28)) True Minimum Curvature 2.00 sigma EDM 2003.11. Single User Db Reference Datum Reference 3J-101 (wp07) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,337.55ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 10!5/2005 From To (ft) (ft) Survey (Wellbore) Tool Name Description 45.00 800.00 3J-101 (wp07) (Plan 3J (40' N of 16)) MWD MWD -Standard 800.00 6,209.22 3J-101 (wp07) (Plan 3J (40' N of 16)) MWD MWD -Standard Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 3J Pad 3J-08 - 3J-08 - 3J-08 892.52 900.00 288.89 16.23 272.66 Pass -Major Risk 3J-09 - 3J-09 - 3J-09 897.65 900.00 213.93 15.20 198.73 Pass -Major Risk 3J-10 - 3J-10 - 3J-10 897.78 900.00 187.24 15.93 171.31 Pass -Major Risk 3J-11 - 3J-11 - 3J-11 848.14 850.00 164.31 12.99 151.31 Pass -Major Risk 3J-12 - 3J-12 - 3J-12 799.39 800.00 142.45 14.91 127.55 Pass -Major Risk 3J-13 - 3J-13 - 3J-13 847.71 850.00 117.20 13.32 103.87 Pass -Major Risk 3J-14 - 3J-14 - 3J-14 798.25 800.00 88.70 12.63 76.07 Pass -Major Risk 3J-15 - 3J-15 - 3J-15 797.94 800.00 65.01 15.32 49.69 Pass -Major Risk 3J-16 - 3J-16 - 3J-16 697.18 700.00 39.18 12.03 27.15 Pass -Major Risk 3J-19 - 3J-19 - 3J-19 954.92 1,000.00 249.33 17.55 231.78 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 10/52005 6:24:42PM Page 2 of 2 COMPASS 2003.11 Build 48 ORIGINAL ConocoPhillips Alaska lnc. (West Sak) Alaska State Planes 4 Well: 3J-101 (wpU7) Date: 5-Oct-US Nad 27 Coordinates Vsec Plane 94.5° SVY MD lnc Azim SSTVD TVD N/S E/W % Y DLS V.S. . Comments # (k) (Deg) (Deg) (ft) (ft) (fq (R) (ft) (R) °/100tt (fy Tie-On u 0.00 0.00 -73.00 0.00 0.00 N 0.00E 519544.000E 6002887.500 N -- 0.00 0.00 Proposed SHL @ 1205ft FSL & 565ft FWL -Sec 3 - 1 100 0.00 0.00 27.00 100.00 0.00 N 0.00E 519544.000E 6002882500 N 0.00 0.00 2 200 0.00 0,00 127.00 200.00 0.00 N 0.00E 519544.000E 6002887.500 N 0.00 0,00 3 300 _ 0.00 Q00 227.00 300.00 0.00 N . 0.00E 519544.000E 6002887.500 N 0.00 0.00 4 400 0.00 0.00 327.00 . 400,00 0.00 N 0.00E 519544.000E 6002887.500 N 0.00 0.00 5 500 0.00 0.00 427.00 500 00 0.00 N 0.00E 519544.000 E 6002887.500 N 0 00 000 KOP SOOft MD, SOOft TVD - Bui1~2.5°/100ft 6 600 2.50 94.57 526.97 599 97 0.17 S 2-17 E 519546.175E 6002887.332 N ^_.50 3.18 7 - 700 5.01 94.57 627.00 700.00 0.70 S 8.72E 519552.716E 6002886.826 N '_50 8,74 Continue Build @ 3°/100£1, 700ft MD, 700ft TVD 8 $00 8.00 94.57 726.09 799.09 1.60 S 19.97E 519563.976E 6002885.956 N 3.00 20.04 9 90~ 11.00 94.57 824.71 897,71 2.91 S 36.42E 5195$0.426 E 6002884.684 N 3.OG 3654 l0 IOC 14.00 94.57 922.33 995.33 4.64 S 57.99E 519601.998E 6002883.017 N 3.00 58.1$ 11 t 100 17.00 94:57 101$.68 1091.68 6.76 S 84.63E 519628.634E 6002880.958 N 3.00 84.90 12 1200 20.00 94.57 11 L3.50 ] 186.50 9.29 S 116.25 E 519660.261 E 6002878.513 N 3.00 L 16.62 13 1300 23.00 94.57 1206.53 1279.53 12.21 S 152.78E 519696.792E 6002875.690 N 3.00 .153.26 14 1400 26.00 94.57 1297.52 1370.52 15.52 S 194.11 E 519738.127 E 6002872.495 N 3.00 194.'73 15 1500 29.00 94.57 1386 21 1459 21 _ _ 19.19 S 240. L3 E 519784.152 E 6002868.937 N 3.00 240.89 16 1600 32.00 94.57 1472.36 1545.3fi 23.24 S 290.71 F 519834.742E 6002865.02"7 1I 3.00 291.£x1 17 17(Xt 35.00 94.57 1555.74 1628.74 27.63 S 345.72E 519889.757E 6002860.7J4 ?~{ 3.00 346.82 18 .1780 37.39 94.57 1620.00 1693.00 _ _ 31.38 S 392.59E 519936.629E 6092857.151 3.00 393.84 Sail @ 37.39° Inc : 1780ft MD, 1693ft TVD -Base o 19 1800 37.39 94.57 1636.19 1709.14 32.37 S ' 4&1.92 E 519948.962 E 6002856.198 N 0.00 40621 20 1880 37.39 9457 L699.45 1772.45 36.22 S 453.1 I E 519997.163E 6002852.472 N 0.00 45456 Build a~4°/100ft [0 65 Inc - 1880ft MD, 1772ft TVI 21 1900 38.20 94.59 1715.55 .17$8.55 37.22 S - 465.56 B 520009.609E 600285 L 507 N 4 00 467.04 22 2000' 42.20 94.69 1791.92 1864.92 42.44 S 534_$8 E 520073.939E 6002846.451 iQ 4.00 531.58 23 21'00 46.20 94.78 1863.59 i936.S3 48.20 S 599.35E _520143.413 E 6002840.878 N 4.00 601.28 _ _ 24 22(10. 50.20 94.85 1930.23 2003 23 54.45 S 673.62E 520217.692E 6002834.816 N 4.00 675.8E 25 2284 53.76 9A.91 1985.00 2058.00 60.41 S 743A~ E 520287.499 E 6002839.038 N 4.00 745.$7 10 3/4" CSG @ 2289ft MD, 2058ft TVD : 1145ft FS 26 2300 54.20 .. 94.92 1991.51 2064.51 61.18 S 752.33E 520296.414 E 6002828_.295 N 4.00 754:$1 27 ..2400 58.20 94.98 2047.12 2120.12 68.35 S 835.}0 E _ 520379.196E 6002821.345 N 4.00 837.89 28 2495 62.00 95.03 2094.53 2167.53 75.54 S 917.24E 520461.346E 6002814.368 N 4.00 920.34 Sail @ 62° [nc : 2495ft MD, 2168ft TVD 29 2500 62.00 ..:95.03 2096.82 2169.82 75.92 S 921:33 E 520465.630 I[ 6002814.002 N 0.00 924.64 30 255$ 62.00 95 03 2114.00 2197 00 $0.40 S 972.46E 520516.573E 6002809.652 N 0.00 975.77 Ugnu C 31 2600 62.00 95.03 2143.76 2216.76 83.66 S 1009.48 E 520553.600E 6002806A91 N 0.00 101294 32 2700 62.00 95.03 2190.70 2263.70 91.40 S 1097.44 E 520641.569E 6002798.979 N 0.00 L 101.23 33 2800 62.00 45.03 2237.64 2310 64 99.15 S 1185.40 E 520729.539 E 6002791.468 N 0.00 1189.53 34 2900 62.00 95.03 2284.58 2357.58 106.89 S 1273.36E 520817.509 E 6002783 957 N 0.00 1277.82 35 3000 62.00 95.03 2331.51 2404.51 114.63 S 1361.33E 520905.478 E ti002776.445 N 0.00 1366.12 36 3100 _ 62.00 95.03 2378 45 2451.45 122.37 S ] d4928 E 520993.448E 6002768.934 N 0 00 1454.41 37 3200 62.00 95.03 2425.39 249839 13011 S 1537.23E 521081.417 E ti002761.423 N 0.00 1542]0 38 3300 62.00 95.03 24'P_.33 2545.33 137.86 5 1625.19E 521169.387E 6002753.911 N 0.00 1631.00 39 3333 62.00 95.03 2488.00 2561.00 140.44 S 1654.55E 521198.749 E 6002751.404 N 0 00 1660.47 Ugnu B 40 3400 62.00 95.03 2519.27 2592 27 145.60 S t 713_ I S E 521257.356 E ti002746.400 N 0.00 1719.29 41 3500 62.00 95.03 2566.21 26393E 153.34 S 1801.11 E 521345.326E 6002738.889 N 0.00 1807.59 42 3600 62.00 95.03 2613.15 . 2686.15 161.08 S 1889.07E 521433.295 E ti00273L377 N 0.00 1895.88 43 3700 62.00 95.03 2660.09 2733.09 L68.83 S L977.03 E 521521.265E 6002723.866 N 0.00 1984.18 44 3800 62.00 95.03 2707.03 2780.03 176.57 S .2064.99E 521609.235E 6002716.355 N 0.00 2072.47 45 3900 62.00 95.03 2753.97 2826.97 184.31 S 2152.94E 521697.204E 6002708.843 N 0.00 2160.77 46 3987 62.00 95.03 2795.00 2868.00 191.08 S 2229.83 F 521774.101E 6002702.378 N 0.00 223295 K-13 47 4(700 62.00 95.03 2800.91 2873.91 192.05 S 2340.90E 521785.]74 E 6002701.332 N O.OU 2249.06 48 4100 62.00 9~ 03 2847.85 2920.85 199.80 S 2328.86E 521873.143E 6002693.821 N 0.00 2337.36 49 4200 62.00 95.03 2894.79 2967.79 207.54 S 2416.82E 521961.113E 6002686.309 N U_OU 2425.65 50 42?5 62.00 95.03 2906.60 2979.60 209.49 S 2418.95E 521983.246E 6002684.420 N O OD 2447.87 Build 4%100$ to 86.34° Inc - 4225$ MD, 2980ft 51 4300 65.00 95.03 2940.00 3013.00 215.36 S 2505 69 F 522050.000E 6002678.720 N 4 00 2514.87 3J-101 (Top WSAK W of Flt) (wp07) 52 4310 65.38 94.99 2944.00 3017.00 216.12 S 2514.31E 522058.621E 6002677.987 N 4.00 2533.52 WSAK D (W FLT) 53 4334 66.35 94.90 2954.00 302200 218.04 S 2536.55E 522080.861 E 6002676.121 N 4.00 2545.84 54 __ 4400 68.98 94.65 2979.06 3052.06 223.12 S 2597.36E 522141.675E 6002671.207 N 4 00 2606.86 55 4475 71.96 94.37 3004.00 3077.00 228.64 S 2667.44E 522211.760E 6002665.865 N 4.00 267215 56 4500 72.97 9428 3011.66 3084.66 230.47 S 269L59 E 522235.916E 6002664J00 N 4.00 270].38 57 4537 74.44 94.15 3022.00 3095.00 233.07 S 2726.88E 522271.206E 6(102661.591 N 4.00 2736.76 WSAK B (W FLT) 58 4600 76.95 93.93 3037.60 3110.60 237.38 S 2787.90E 522332.231E 6002652438 N 4.00 2797.93 59 4700 80.94 93,60 3056.77 3129.77 243.83 S 2885.81E 522430.151 F 600265L253 N 4.00 2896,04 60 4800 84.93 93.27 3069.07 3142.07 249.76 S 2984.85E 522529.198E (002645.576 N 4.00 2995.25 61 4835 86.34 93.15 3071.76 3144.76 251.74 S 3020.14E 522564.48$ E (002643.690 N 4.00 3030.58 Sail @ 86.34° Inc : 4835ft MD, 3145ft TVD I'12N - R09E Perm L&1308ftFWL-Seca-T12N-R09E-T3+800-103/4" TVD • Page 1 of 2 /V r ~~ ~~ .~+"^'_ SVY MD [nc Azim. SS'I1'D TVD N/S E(1Y' .l' Y DLS Y.S. Comments . # (ft) (Deg) (Deg) (Ct) (ft) (fq (R) (ft) (ft) - °/100ft (ft) 62 -- 4900 86.'4 - 9315 3075.88 3148.88 255.28 S -- 3084 a6 E 532628.814E ___ - 6002640.318 N u.00 __ 3094.98 63 5000 86.34 93.15 3082_'7 315527 260.77 S 3184.11 E 522728.463E 6002635 094 N O Ou 3194.75 64 5011 86.34 93.15 308° 97 3155.97 261.37 S 3195.12E 522739.472E 6002634517 N 0.00 3205.77 Drop @ 5°/100ft : SO11ftMD, 3156ft TVD 65 SOLI. 86.32 93.15 3083.00 3156.00 261.40 S 3195.52E 522739.877E 6002634.496 N i0U 3206. L8 Prognosed Fault Crossing : 5011ft MD, 3156fr TVD 66 5100 81.89 93.15 3092.09 3165,09 266.24 S 3283A4 E 522827.803 F 6f)02629.887 N 5.00 3294.21 67 .5200 76.89 9315 3110.49 3183.49 27L64 S 3381.55E 522925.918E 6002634.744 N 5.00 3392,44 _ 68_ .5300 7L89 93.15 _ 3137.39 3210.39 276.93 S 3477,69E 523022.058E 6002619]05 N 5.00 _ 3488.70 69 5400 66.89 93.15 3172.57 324557 282.07 S 357 L 12 E 523115.492 E 6002614.809 N 5 nn "158224 70 5419 65.96 9315 3180.00 3253.00 283.00 S 3588.11 E 523132.486E 6002613.918 N 5.00 359926 71 5438 65.00 93.15 3188.00 326L00 283.97 S 3605.63E 523150.000E 6002613.00 N 5 n0 3616.79 WSAK D (E FLT) - 3J-]01 T2 (Top WSAK E of Flt; 72 5443 64.76 93.15 3190.00 326300 284.20 S 3609.89E 523154260E 6002673977 N 5 UO 3621.06 73 5500 61.89 93.15 3215.78 3288]8 287.02 S 3661.13E 523205.508E 6002610.091 N 5.00 3672.37 74 5582 57.79 93.13 3257.00 3330.00 290.92 S 3731.96E 523276.341E 6002606.379 N _ S.OQ 374338 WSAK B (E FLT) 75 56CK~ 56.89 93.15 3266.68 333868 291.75 S 3747.04E 523291.421 L 6003605.588 N 5 00 3758.38 76 5700 51.89 93.15 3324.88 3397:88 296.22 S 3828.20E 523372.578E 6002601.335 N 5.00 3839.6-1 ~ 77 5800 46.89 ' 93.15 3389.95 3462.95' 300.39 S 390398E 523448.360 E 6003597.364 N 5.00 3915.S1 78 5%37 45.02 93 l5 3416.00 3459.00 301.87 S 3930.87E 523475.253E 6002595.954 N 5.00 :3942'.43 WSAK A2 79 5900 41.89 93:15 3461.38 3534.38 304.23 S 3973.80E 523518.192E 6002593.704 N 5.00 3985.42 80 6000 36.89 93.15 3538.64 3611.64 307.72 S 4037.15E 523581.541E 6002590.354 N 5.00 4048.55 81 6109 31.43 93.15 3629.00 370200 311.09 S 4098.38E 523642.770E 6002587.175 N 5.00 4110.15 Base WSAK 82 6209 31.43 93:15 3714.33 3787 33 313.95 S 4150.45E 523694.839E 6002584.446 N 0.00 4162.28 TD @ 6209ft MD, 3787£[ TVD :890 ftFSL & 565 fl 3J-101 Fault Intersection ~wP07) FEL -Sec 3 - T12N - 809E • • Page 2 of 2 • • 3J-101 Drilling Hazards Summary 13 1/2" Oaen Hole / 10 3/4" Casinq,Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low ,- Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets , um in out 8-1/2" Ogen Hole to TD Hazard Risk Level Miti ation Strate Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Stuck Pipe Low Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure r wei ht. Lost circulation Low Reduced um rates, mud rheolo LCM Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets , um in out 3J-101 Drilling Hazards Summary prepared by TJB 10/18f05 ORIGINAL CemCADE Preliminary Job Design 10 3/4" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 10/18/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2634207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 120' MD < Base of Permafrost at 1,780' MD (1,693' TVD) Scl~r~~ Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 30% excess below the permafrost. The top of the tail slurry is designed to be at 1,800' MD. Lead Slurry Minimum pump time: 195 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (120') x 1.00 (no excess) = 163.7 ft3 0.3637 ft3/ft x (1780' - 120') x 3.50 (250% excess) = 2113.1 ft3 0.3637 ft3/ft x (1800' - 1780') x 1.30 (30% excess) = 9.5 ft3 163.7 ft3 + 2113.1 ft3+ 9.5 ft3 = 2286.3 ft3 2286.3 ft3 / 4.45 ft3/sk = 513.8 sks Round up to 520 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 135 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3637 ft3/ft x (2289' - 1800') x 1.30 (30% excess) = 231.2 ft3 0.5400 ft3/ft x 80' 3(Shoe Joint) = 43.2 ft3 231.2 ft3 + 43.2 ft = 274.4 ft3 274.4 ft3/ 2.52 ft3/sk = 108.9 sks Round up to 110 sks BHST = 39°F, Estimated BHCT = 60°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 1,800' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,289' MD (2,058' TVD) Mark of Schlumberger CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 40 8.0 20.0 Drop bottom plug 5.0 25.0 MudPUSH II 5 50 10.0 35.0 Lead Slurry 7 407 58.1 93.1 Tail Slurry 5 49 9.8 102.9 Drop Top Plug 5.0 107.9 Displacement 7 197 28.1 136.0 Slow Rate 3 15 5.0 140.0 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL ,~ Tree: (2) Vetco 4-1 /8 x 5ksi valves Tubing Hanger: Vetco, with 3- '/Z", EUE 8rd box down. Wellhead: Vetco MB228 Lower Bowl 3J-101 Proposed Surface Location: Eastings:519,544 Northings:6,002,888 - Pad Elevation: 43' AMSL Nordic Rig 3 Floor @ 0' Elevation: 73' AMSL Conductor: 20" x 34" Insulated, set at 110' Fluid: Diesel in tubing and annulus Fluid: Drilling mud TD 8-1/2" hole @ 6,209' MD, 3,787' TVD Cement Plug(s) across hydrocarbon bearing zones Cono~oPhilli 5 3J-101 FEL 3 Sheet1of1 p We I I Design modified by TJB Alaska _ _ , 1oilar~oo5 .. . 3'/2', 9.3#, L80 EUE 8rd Mod Tubing @ +/- 2000' MD TD 13 '/Z" hole Shoe of 10 '/<", 45.5#, L-80 BTC Casing @ 2289' MD, 2058' TVD d •• •• SHARON K. ALLSUP-DRAKE 1115 CONOCOPHILLIPS AT0 1530 ~fQ~ ~fQ~ 700 G ST. DATE ~ "`~ "" `R-~ fip-14/311 ANCHORAGEcA/~K~ 991501 PAY TO THE 1 ~"~V~ ©G f't L-Tf ~Yyf 1~^(~,~ ~ j~~ ~.l .ORDER OF ! F1 ti l lJ~( W ~~ `-~QT~ `~~ ~~ ~-~~DOLLARS LJ ~~a„` ' CHASE Chase Manhattan Bank USA, N.A. Valid Up TO 0 DOllafs 1 r ^v_ C 2[I<! White Clay Center Or.. 4ewark. DE 19)11 ,h / 1 ~~ G i MEMO ~. ~:031L00L44~:21847L907927611'LL15 `: - _ __ i~ s a •• •• TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /~~~~ ~~ ~" /tea ~ PTD# ~'~~ ~ ~ ~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of .the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC Z5.005(f), al! (per records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and groduce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL -490150 -Well Name: KUPARUK RIV U WSAK 3J-101 Program EXP Well bore seg ^ PTD#:2051570 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type EXP! PEND GeoArea Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mit_fee attached- eS 2 Lease number appropriate _______________________________________ Yes_ --_- 3 Unique well-name andnumber_----________________________________ Yes_ ____-__--__--__- ---------------------------------------------------------- 4 Well located in a_defined-pool- Yes _ _ - _ _ - - KUPARUK RIVER,_WEST SAK OIL - 490150; this is a West $akde1ineation-well.- - _ 5 Well located proper distance from drilling unit_boundary_ Yes - - . - . - No spacing restrictions ether than a 500' set-back from external _ro ert lines.- - p p Y 6 Well located proper distance-fro_m_ other wells- . - . - - _ - - - - . Yes Well is located about 3 miles from KR_U_extern_al boundary. - _ - _ - - - - - . - - - 7 Suffcientacreageavailablen,dril_lingunit_______________ ________________ Yes_ _-__ ..-. 8 If_deyiated,is.wellboreplat_included ________________.____-_-----._-. Yes- _--_-..-___ - - 9 Operatoronlyaffectedparty_____ __________________________________ Yes_ --..-.-- 10 Ope[atorhas_appropriate-bond in force___--___ ....................... Yes_ _-____-_--___-__.-_ ------------------------------------------------------- 11 Permit can be issued without conservation order Yes Appr Date. 12 Pe[mitcanbeissuedwithoutadministrative-appr_oval_____ ___________________ Yes_ _________ __- _______________________________________ SFD 10124!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized bylnjectionOrder#(put_1O#in_comments)(FQr_ NA_- _-__-_--.--_-_--__-_-_______________________________________________-- 15 All wells-within 114-mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ - ( 16 Pre-produced injector; duration of preproduction less than-3 months_(Forservice well only) - - NA- - - - - - - - - - - - - - - - - - 17 ACMP Finding of Gonsistency_has been issued-for-this project _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ Well drilled from exisiting pad. _ _ _ _ _ _ _ _ _ _ - - _ - _ _ _ _ _ _ _ _ _ _ _ - . _ _ - - - - - . _ - _ Engineering ~I 18 Conductor string-provided Yes 1 19 Surface casingprotects all_known U$DWs - - ------- - - -- - - - - - - - - - - - NA_ All aquifers exempted, 40 CFR-147.102_(b)(3). - . - - - ~'i 20 CMT-vol-adequate_to circul_ale_on conductor& su_rf_csg - - - - - - -- - --- - - - -- - - - - - - Yes . - - . ... - - - 21 CMT-vol-adequate_to tie-in long string tosurf csg- - - - - - - - - - - - - No_ 8-112" hole_section is_ planned to be plugged.- Wel_I proposed to-be suspended.- - . 22 CMT_willcoverallknown-productiyehorizons_______ ______________________ Yes- __----.--.-.--.----__--______-__--_-_-______-______-____________________-- 23 Casing designs adequatefo[G,T,B&-pe[mafrost---- ---------------------- Yes- ------ ------- ----------------------------------------------------------- 24 Adequate tankage-or reserve pit Yes - . - - - -Rig is-equipped with steel pits.. No reserre_pitplanned, All waste to approved disposal_wells.- - 25 If a-re-drill, has_a_ 10-4.03 for abandonment been approved - NA_ 26 Adequate wellbore separation-proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ Yes - - - - - - -Proximity analysis performed, Traveling cylinder path calculated, Gyros possible, - - . - _ - - _ _ _ _ _ _ - - _ _ - 27 If_diverterrequired,doesitmeetregulations___ __________________________ Yes_ ______ Appr Date 28 Drilling fluid program schematic & equip list adequate- Yes Maximum expected formation pressure 8.6 EMW._ MW planned up to 9,5_ppg._ TEM 10125/2005 29 _B_OPEs,-do they meet regulation _ .. - - .. - Yes - - - - - - 3K confguraticn proposed with-1. s-e# VBRs and 1 set.fxed DP tams, - - _ _ - _ - . 30 B_OPE_press rating appropriate; test to.(P-ut psig in comments)- Yes MASP calculated at 11.86 psi. 3000_psi-BOP testproposed.- 31 Choke-manifoldcomp_lieswlAPIRP-53(May84)____________________________ Yes_ ____________________-___--__--_-_-__-______-__-_-----_.-_.------_---__ _ 32 Work willoccurwithoutoperationshutdown--- ----------------------- --- Yes_ ______________________-__-------__-___-_-_--__--_--------__--__--__.___ ( 33 Ispresence_ofH2Sgas_probable_____------------------___----- __- No__ ____-_W$hasnotbeen_activeat 3J pad.-------__- ---_--------_--- --_-.._.-________ 34 Mechanical condition gf wells within AOR yeri_fied (FOr_senrice well on_ly~ NA_ Geology 35 Permit_can be issued w/o hyd[ogen sulfide measures - - - - - - - - - - Yes West Sak pool has_not been produced cr_received injection at 3J-Pad. 36 Data_presented on potential overpressure zones- - - - - - - - - - - - - - - - - - - Yes Expected resen!oirpressure is 8,3 to 8.6 Peg EMW, will be drilled with.9.Q, 9.2 peg mud, - - - - _ _ _ Appr Date 37 Seismic_analysis ofshallow gas_zones_ N_A- Ei hteen wells have been-drilled from_KRU_ 3J-Pad, _ 9 SFD 10/24!2005 '38 Seabed conditionsurvey_(ifoff-shore)_ _________________-_--_--------. NA-- _--------,-_-- 39 .Contact name/phone for weekly progress.reports [exploratory only]- - Yes Tom Brasfield - 907-265-6377. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date D`~~~ ! ~ ~ ~~' ~ ~~rv ~a- zs~s • • • • Well History Fife 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 chronologica((y organize this category of information. RECEIVED -JUN 0 9 2006 ~iaelca OA 8~ Gas Cons. cortunis~ Ancfiaa9e ConocoPh i I I i ps Alaska, Inc. ~~~ FINAL WELL EPORT MUDLOGGIN DATA . ~~~ i .~ ~~- ~"'"...~~........ ~'~t ~.4 I 3J-a .~~. Provided by: ~s-~s~- ~~ 3~y~ Compiled by: Brian O'Fallon Lees Browne Date: 12/15/05 RECEIVED JUN 0 9 2006 ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA 3J-101 i Provided by: [~ EPOCH Approved by: Bryn Clark Compiled by: Brian O'Fa11on Lees Browne Distribution: • Date: 12/15/05 SOS-iS~ '~ !3~'Y~ '~'1~~~I~S 3J-101 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT &CREW----•• ...........................................•--.....................---------.................. ..2 1.1 Equipment Summary .................................•-•---......................------••---.......................................------..... ..2 1.2 Crew .................................................................................................................................................... .. 4 2 WELL DETAILS .......................................................................................................................................... ..5 2.1 Well Summary .................................................................................................................................... ..5 2.2 Hole Data ..............................................•---------..........................-------...........................----..........----...... ..5 3 GEOLOGICAL DATA .............................................••---•----•-•--.........-•------------•--.....................-•---......-----••---• -.6 3.1 Lithostratigraphy .................................................................................................................................. ..6 3.2 Mudlog Summary ............................................................................................................................... ..7 3.3 Gas Samples ...................................................................................................................................... 17 3.4 Connection Gases .............................................................................................................................. 17 3.5 Sampling Program /Sample Dispatch .............................................................................................. 18 4 PRESSURE /FORMATION STRENGTH DATA ...................................................................................... 19 4.1 Formation Integrity/Leak Off Tests ..............•-----................................................................................. 19 4.2 Wire line Formation Tests .............................................................................•-•-•----............................ 19 4.3 Pore Pressure Evaluation Introduction .............................................................................................. 19 4.4 Pore Pressure Evaluation Conclusions ............................................................................................. 19 4.5 Pore pressure evaluation .................................................................................................................... 23 5 DRILLING DATA --• ...........................................................................................•---...................................... 24 5.1 Survey Data ................••-•-----•---..............................................................................--•-----...................... 24 5.2 Bit Record .............................................................................................•--............................................ 27 5.3 Mud Record ......................................................................................................................................... 28 6 MORNING REPORTS ................................................................................................................................ 29 Enclosures 2"/100' Formation Log (MD) 2"/100' Drilling Dynamics Log 2"/100' Gas Ratio Log Z"/100' LWD / Lithology Log • ~~~~~ • • ~ MUDLOGGING EQUIPMENT ~ CREW 1.1 Equipment Summary ~~~'~~~~`~ 3J-101 Parameter Equipment Type /Position Total Comments Downtime QGM Agitator (Mounted in possum belly) Ditch gas Flame ionization total gas & chromatography. 0 WITS feed to QUADCO: Spud -TD Insulated umbilical with three of low lines. Effective Circulatin Dens' ECD From S err -Sun 0 Be in ECD data after FIT: 2401'-TD Hook Load / Wei ht on bit H draulic ressure transducer 0 No roblems no missin data Rate of penetration Primary draw-works block position indicator 0 No problems, no missing data O tical encoder on draw-works Mudlo in unit com uter s stem HP Coma Pentium 4 X2 DML & Ri watch 0 On UPS should ower shut down on ri Mudlo in unit DAC box In-unit data collection/distribution center 0 On UPS should ower shut down on ri Mud Flow In Derived from Strokes/Minute and Pum Out ut 0 see um stroke counters below Pum stroke counters 2 um s Ma netic roximi sensors 0 No roblems, no missin data Quadco Well Monitorin Com onents QUADCO Com uter in Mudlo in Unit 0 On UPS should ower shut down on ri Mud Flow Out From QUADCO 5 hours 3228-3562' WITS feed from QUADCO: Spud -TD 5 hours Pit Volumes, Pk Gain/Loss From QUADCO 3228-3562' WITS feed from QUADCO: Spud -TD Pump Pressure From QUADCO 5 hours 3228-3562' WITS feed from QUADCO: Spud -TD RPM From QUADCO 5 hours ' WITS feed from QUADCO: Spud -TD 3228-3562 Torque From QUADCO 5 hours 3228-3562' WITS feed from QUADCO: Spud -TD QUADCO computer and IP phone were ready online in Epoch unit prior to spud of well, and WITS communication between QUADCO and Epoch Rigwatch Computer established. Epoch WITS output to QUADCO included ditch gas only, and input from QUADCO included flow out, total mud volume, trip tank, gain- loss, pump pressure, and top drive rpm and torque. The QUADCO system was down for 5 hours following a power outage, and no data was recorded from 3228' to 3562'. Values for RPM, provided by the driller, were entered for DX calculations. ECD data was acquired from Sperry Sun for DX calculations. Pore pressure charts and estimated pore pressure is evaluated in section 4 of this report. Sperry Sun did not measure ECD for the surface hole. EP+DCH 2 • • • ~,. ~C1t"iOC0~11~~1~'35 3J-101 Gas values for the surface hole were difficult to measure, as rig crews had problems with excessive cuttings, but gas recording for the 8'/" hole went well. Mud flow into the possum belly where the gas trap was set often had restricted flow and no flow at all due to the excessive cuttings in the surface hole. The base plate on the gas trap, with a two inch diameter hole covered with a'/e" mesh screen, had to be removed as the screen would be continuously plugged from clay cuttings and a hi vis mud. To remove only the screen and not the base plate would trap rocks inside the barrel which would likely break the prongs on the agitator. Removing the base plate allowed rocks to flow freely in and out of the bottom of the trap. However, removing the base plate made the trap more sensitive to the mud level in the possum belly. The base plate with screen was replaced after surface hole, with no problems encountered while drilling the 8'/z" hole. Occasionally the trap would be washed out as a preventive measure to help ensure reliable gas readings during shows. Also, two spare polyflow gas lines were utilized should freezing or plugging occur. One spare was rigged up to rig air to blowback lines to keep free of moisture and drilling mud. The second spare was kept as a back up gas line. EPCJCH 3 • • • 1.2 Crew Unit Type Arctic Series 10 Skid Unit Number ~ ML012 ,,... ~C)f1©Ci7~11~~1~1S 3J-101 Mudloggers Years Da~s Sample Catchers Years Days Technician Days Trainees Days Brian O'Fallon 18 9 Jeff Porcianko <1 9 None re uired Lees F. Browne Jr. 24 9 Todd Baham 2 9 ' Years experience as Mudlogger .2 Days at well site between spud and total depth of well Additional Comments Technician required to work on DAC box. ~ EPOCH 4 ~~~~~~~~~~ 3J-101 2 WELL DETAILS 2.1 Well Summary C: • Well: 3J-101 API Index #: 029-23283-00 Lat: 70d25'7.53"N Field: West Sak Surtace Co-Ordinates: Long:149d 50'38.08"W SEC 3 T 12N R9E 4075.5' FNL 566' FWL Borough: North Slope Primary Target Depth: 4220' MD State: Alaska TD De the P 6274' MD 3780'TVD Rig Name /Type: Nordic Calista #3 /Arctic Suspensron Date: 12/15!05 Triple Primary Target: West Sak "D" and "B" License: 205-157 Spud Date: 12!1/05 Ground Elevation: 43' Completion Date: 12/15/05 RT Elevation: 73.85' Completion Status: Cement Plug Secondary Target Ugnu B: 3342'MD De the Classification: Exploration TD Date: 12/9/05 TD Formation: West Sak Days Testing: NONE Days Drilling: 9 2.2 Hole Data Maximum De th Mud Shoe De h FIT Hole Section MD ft TVDSS ft TD Formation IlYeight tPPg) Deviation (°inc) Coring Casing/ Liner MD ~ TYDSS g (ppg) Conductor 110 -36 Colville Gr NA 0 20" - NA 13 112° 2381 -2010 Colville Gr 9.3 56.00 - 10'f." 2372' -2004 14.0 8112" 6274 -3706 Cotvi~ Gr 9.0 30.36 NA NA NA NA Additional Comments A 13'/2" surface hate was directionally drilled to 2381' with 9.3 spud mud with no problems and directional survey's every stand. No connection gases noted with 25 units of Wiper Gas at casing point. The 8 '/2" hole section was drilled to 6274'. Slides were necessary for directional hole. Each stand was back reamed prior to each connection. Mud weight was maintained from 9.2 to 9.4, and no connection gases were recorded. A wiper trip at 4127' was made to displace the mud in the hole and replace the mud in the pits, a total of 580 bbls of new mud. At 3853', after a 6 bbl increase while drilling, a flaw check revealed the well was flowing with the pumps off. It was determined the well was breathing due to high ECD. There was no downtime gas lagged out from the flow check or later connections. The wiper trip was made in anticipation of drilling into the West Sak targetzones, to provide a better mud for improved log quality and more accurate hole analysis for logs run after total depth. Logging was commenced after a wiper trip. Five logging runs were performed, a combo run, a drill pipe conveyed pressure run, a drill pipe conveyed sidewall coring run, a wireline sidewall coring run, and a second drill pipe conveyed coring run after the wireline failed to go to bottom. Forty-five cores were attempted on each sidewall coring run. Pressure results are shown in section 4,. C~ F,PC~C,,T-T R~Of1t~C0~"tl~~lp5 3J-101 3 GEOLOGICAL DATA 3.1 Lithostratigraahy • Drilling picks ~ actual wire line tops refer to provisional picks provided by the well site Geologist. PROGNOSED ACTUAL WIRELINE PICK HIGH/LOW FORMATION MDRT ft TVDSS ft MDRT ft TVDSS ft (ft) Permafrost surface T3 na -1185 1260 -1157 28 Base Permafrost 1780 -1620 1775 -1611 9 Casing Point (T3+800'TVD) 2289 -1985 2381 -2007 -22 Ugnu C 2558 -2124 2664 -2170 -46 Ugnu B 3333 -2488 3342 -2505 -17 Ugnu A na na 3736 -2675 Na K13 Marker 3987 -2795 3958 -2785 10 West Sak D Sand 4310 -2944 4220 -2915 29 West Sak C Shale na na 4318 -2946 Na West Sak B Sand 4537 -3022 4488 -2983 39 Fault Crossing 5011 -3083 4866 -3034 49 K13 Marker na na 5752 -3053 Na West Sak D Sand 5438 -3188 5540 -3163 25 West Sak C Shale na na 5611 -3197 Na West Sak B Sand 5582 -3257 5670 -3230 27 West Sak A4 Sand na na 5737 -3271 Na West Sak A3 Sand 5726 -3341 5797 -3342 29 West Sak A2 Sand 5837 -3416 5902 -3391 25 West Sak Al Sand na na 6008 -3478 Na Base West Sak 6110 -3630 6155 -3603 27 TD 6209 -3714 6274 -3706 8 F,PC~C',N CC>~+C~11~~IpS 3J-101 t 3.2 Mudlog Summary Permafrost to T3 First Returns 110' to 1278' MD (-36' to -1173` TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 336 10.3 98.5 44 0 3 The permafrost zone above the T3 includes mostly sand and pea gravel with some interbedded claystone down to 640', a massive claystane from 640' to 850', and again mostly sand and pea gravel with some interbedded claystone to the top of the T3. The sands from 115' to 640', were medium gray to medium dark gray overall, and ranged from moderatelywell sorted medium to fine grained sands with scattered coarse grains and pebbles, to conglomeratic sands with increasing pebbles and granules (up to 15 mm), to poorly sorted sandy conglomerates with increasing clay matrix and relative percentages of coarser fraction. Grains were angular to subangular, especially in the finer fraction, with some rounded coarse and predominantly rounded pebbles and fragments. Rounded pebbles and granules were spheroidal to elongate. Composition of the finer fraction was approximately 60% clear to translucent quartz, and 40% silicates, including chert and siliceous lithics, minor volcaniclastics, some lithic clasts, including coal and carbonaceous clasts, and slight pyrite. This fraction down to 150 feet was more varicolored and of possible different sources than sands that followed. The non quartz finer fraction below 150' was dominantly gray to dark gray to dark brown to black. The coarse to granule fraction was predominantly silicates, of dominant composition as in the finer fraction, but with some white rounded silica grains, occasional angular quartz, locally scattered shell fragments, and scattered varicolored silicates, and igneous and volcanic clasts. Clay or Claystone was medium gray to gray, to rare brownish gray due to weathered carbonaceous matter, or locally with occasional streaks of grayish brown organic clays. Clays were mostly amorphous and solub{e washed to a mushy paste in sample, but locally w~h clayey to slightly silty texture, slightly sparkly luster with slight disseminated fine silt sized mica flakes, and very slight to slight carbonaceous silts, fines, and flakes. Sight loose si{t to very fine sand persists throughout in samples, and locally floating fine to medium silicate sand grains were observed in preserved claystone. Claystone is probably massive, to interbedded orgrading to, and as a matrix in, sands and conglomerates. The sands from 850' to 1278' were medium dark gray to medium gray overall. Grain sizes ranged from very fine to coarse, with scattered to abundant pebbles and granules up to 10 mm diameter or 20 mm in length. Grains were angular to subrounded, to mostly rounded pebbles and granules, and some rounded coarse grains. Sands were moderately well to poorly sorted, mostly grain supported, but grading conglomerate and claystone. Overall compositions were 65% clear to translucent quartz, and 35% dark brown to amber to black to gray silicates, including chert, siliceous lithics, and trace mica, and scattered pyrite clusters. Pyrite also occasionally occurred as accretions spattered on grains. Quartz was more dominant in the finer fraction, and only about 20°l0 of the coarse fraction. Top T3 to Casing Point 1278' to 2381' MD (-1173' to -2010' NDSS) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 273 19.3 139 33 1 4 The base of the Permafrost is included in this section and was encountered at an estimated 1775'MD, as lower resisfivity in sands below this point probably reflects a transition from ice to water {Section 4.4 : Pore Pressure ~~~~.~ 7 r..' ~t?f1t)CQ~'11~~1~lS 3J-101 • Evaluation Conclusions). Casing point was anticipated to be below the permafrost in a clayey interval approximately 800'(lVD) below the T3. The pick was a little deeper at 2381' (T3+837'TVD), as the anticipated pick appeared to be sandy. This section included interbedded sand, ctaystone, conglomeratic sand, and some conglomerate. The T3 appeared to be sand and conglomeratic sand at the top, with mostly sand and claystone to the base of the permafrost. Conglomeratic sands and conglomerate were quite common below the permafrost overall increasing downward to casing point. Compositions were similar to sands above the T3 although with less pyrite, and overall 50% clear to translucent quartz and 50% mostly dark silicates and minor organic clasts. claystone was of similar composition as well except rare grading siltstone, and minor but sl~ghtiy more common brownish organic claystones and associated carbonaceous flakes and matter. Surface Casing to Ugnu C 2381' to 2664' MD (-2010' to -2169' TVDSS) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Ma~amum Minimum Avera e 387 23 151 24 3 15 The interval includes mostly sand, some conglomeratic, and some interbedded siltstone and clay. Sands are medium to light gray. Grain sizes were coarse to fine, especially in the coarse lower to medium range, and scattered to locally common pebbles and granules. Angularity was mostly subangularto angular. Some coarse grains and pebbles were rounded. Sorting varied from well sorted with slight clay matrix and grains dominantly in the medium to coarse range, to moderately and poorly sorted with increased matrnc and grading to silistone, claystone, or conglomerate. Samples from 2580' to 2664' were conglomeratic. Compositionwas 40-65°~6 clear to translucent quartz, with more quartz prevalent in finer fractions, and 60-35% varicolored grains, mostly silicates (some chert), some siliceous lithics, lithics, and trace volcanic tuff. Noted grain colors are medium to dark gray, green (possible chorfization in part}, black, amber to brown, and minor red. Traces of "woody" matter and localty minor coal ciasts or thinly bedded coal were also noted. Locally minor calate, and minor hard silica cemented fine to medium grain supported sandstone, was noted. claystone was mostly medium gray to medium light gray, some with brownish hues as s{kPubty organic, to locally very organic and grading carbonaceous shale. Textures were slightly silly to silty often grading to siltstone. Very slight silts and fines of mica produced a slightly sparkly luster. Slight to very slight silts and fines of carbonaceous matter were prevalent throughout, with some occasional flakes and partings and occasional streaks and lamina of organic clay from weathered carbonaceous matter. From 2405 to 2465' ctaystone often graded to organic claystone and carbonaceous shale, with some minor coal. Siltstone was overall less organic than ctaystone, but typically very clayey, and often graded to clayey very fine to fine grained sandstone. Silt grains were mostly quartz, with an increase in non quartz grains in the fine sands, notably some green (chlorite) silicate grains. Top Ugnu C to Ugnu B 2664' to 3281' MD (-2169' to -2480' TVDSS) Drill Rate ftlhr Total Gas units Ma~amum Minimum Avera a Mabmum Minimum Avera e 624 13.9 156 31 2 15 This section includes sand, conglomeratic sand and conglomerate, claystone, siltstone, same carbonaceous shale and coal. Sands were medium gray to light gray, fine to coarse grained, especially medium, with slightly scattered ~1 ~,PO~H rte,' ~10C0~11~~I~S 3J-101 pebbles in the Ugnu "C°, and mostly conglomeratic from 2664' to just above a coal at 2770'. Grains were angular to subangular, except often rounded in the pebble fraction. Sorting was well to moderate with a slight clay matrix in the sands, to poorly sorted with increased matruc and grading to siltstone, claystone, and conglomerate. Composfion of the grains included 55-60% clear to translucent quartz, and 45-40% chert and other silicates, siliceous lithics, and minor mostly coal and carbonaceous lithics. Grain colors noted, including lithic clasts, were gray, amber to brown, black, green, and trace red and white. Again, non quartz grains were more prevalent in the coarse to conglomerate fraction, with the quartz grains increasingly prominent in the finer fraction. Traces of volcanics at 2950'. claystone and siltstone were light gray to white to medium gray, some slightly organic with brownish hues, to locally variably organic and grading grayish brown organic claystone and carbonaceous shale. Traces to slight mica silts and fines contributed to a slightly sparkly luster overall, to sometimes velvety luster in siltstone. Traces to slight carbonaceous silts and fines prevailed throughout, to occasional flakes and partings, especially in variably organic clays and grading to carbonaceous shale. The lighter colored grays appearto be of ashy origin in part, and locally grading tuffaceous claystone and ash fall tuff. Also noted was some incipient fissility especially in the siltstone, locally some firm calcareous silistone. Carbonaceous clay and silts were noted at 2760' to 2805', and a small carbonaceous shale and coal at 3270' the carbonaceous shale/coal was brownish black to black, lignite to very carbonaceous shale striated to gritty texture with subblocky to hackly fracture. Top Ugnu B to Ugnu A 3281' to 3641' MD 1-2480' to -2632' TVDSS) • Drill Rate ft/hr Total Gas units Ma~amum Minimum Avera a Maximum Minimum Avera e 191 57.2 135 243 1 108 The Ugnu 8 is noted by a massive unconsolidated sand body with distinct increases in background gas and abundant oil and oil tar in the drilling mud and samples. Minor matroc clay and slight carbonaceous material noted in samples, especiaNy towards the lower sections of the formation.. Sand from 3300'-3390' was gradational clay and sands with increasing to a majority of sand by 3350'. Sands were very light gray with clayt size ranging from medium tower to fine lower with subround and moderate to well developed spheriaty with moderate to well sorting and polished to slightly pitted textures. Sands were unconsolidated with no visible cementing and composed of predominantly quartz grains with fair porosity ftom 3281' to 3350' and increasing to fair to good porosity by 3390'. Sands were both grain and matrix supported in the first fifty feet of the section and became grain supported by 3390'. Rig crews working on the shale shakers {changing screens) prevented some gas readings from being noted {at the top 40' of the formation) but generally showed a upward trend of background gas from 20 units at the top (3281 ~ to a reading of 84 units by 3350'. As the sand became cleaner the background gases increased to reflect this. By 3320' samples had common to abundant dark brown oi{ with very slight oil staining as the cleaner sands appeared to be "flushed°. Samples under UV light displayed 90% moderate even orange fluorescence with a very slight petroleum odor with instant milky white oil cuts leaving a strong brown hued reskiue stain. Sands from 3350' to 3545' displayed better porosity and an overall cleanliness with very light gray colors with clast size increasing slightly to medium upper to fine upper, subraund with moderate to well developed sphericity, moderate sorting with polished to pitted textures. Sands continued with being unconsolidated with no visible cements and still composed predominantly of quartz with secondary chert and volcanic fragments and a trace of epidote. Samples were dominantly grain supported with fair to good estimated porosity and permeability showing a vast improvement over the first seventy feet of the formation, with continued common to abundant free oil in the drilling mud and samples with a very slight petroleum odor and very slight oil stain. Most, if not alt ~ EPflCH 9 ~011[3CO~11~~Ip5 3J-101 oil appears to be flushed into the mud system and occurs as °pops", "blebs° or as a sheen. Samples displayed 90% moderate orange sample fluorescence with immediate blue white milky oil cuts with increasing tar in the drilling mud noted at 3450'. All samples showed a strong dark browned hued residue stain. • Sands from 3535' to the base of the formation (3641'} showed a slight increase of clay content with slight losses of sample fluorescence and oil cuts. Samples of sand still remained very light graywith clast sizes ranging from medium upper to medium lower occasionally fine upper, subround occasionally subangular and moderate to well sorted with moderate developed sphericity. Sands exhibited no visible cement and were still unconsolidated with dominant grain support wrth sl'~ght increasing clay matrix. Sands were composed of 90% quartz with 10% chert, volcanics and various I"rthic fragments. Samples displayed fair to good porosity and permeability with the increase of clay matrix. Continued common dark brown oil blebs in the samples with a very slight petroleum odor with very slight oil staining of the samples with a sl"~ght decrease in sample fluorescence to 80% moderate even orange with an instant bright blue white milky fluorescence cut and a strong brown hued residue ring. At this point samples were hard to dry with the amount of oil and tar found in the samples (even after washing them). Background gas slowly increased from 20 units at the top (3281 ~ to averaging 120 units to a maximum of 243 units (3488 from 3390' to 3630' with slight amounts of C2 (ethane) towards the middle and lower sections (5- 20 ppm}. Claystone noted was either matrix material or thin to thick beds (especially towards the bottom of the formation [3545'-3565']) being light brownish gray in color and very soft. Consistency ranged from lumpy to clumpy, clustered to clotted and gelatinous in parts with having no cohesiveness and adhesiveness to having slight amounts with most being very hydrophilic and going into solution. Clay fractures and habits were amorphous to earthy and displaying a uniform earthy luster. Textures were ashy to colloidal and some thin silt sections. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 3350 84 16503 3488 243 47278 20 3583 146 27603 9 Top Ugnu A to West Sak D Sand 3641' to 4221' MD (-2632' to -2916' TWSS~ Drill Rate ftJhr Total Gas units Maximum Minimum Avera a Mabmum Minimum Avera e 224 29.4 117 112 7 33 The Ugnu A shows a decrease in clean sand with an increase of siltstone and claystone displaying a fairly uniform balance of silt; clay and sand. The middle of the formation (3810'-4020 has a coarse section with sand size increasing to coarse grains (10-15%} with some sandstones and minor conglomerate sand (10%). Background gas shows a slow decrease through the formation from 75 units at the top to 25 units at the base reflecting the increase in clay and silt and the loss of sand. The upper sands of the Ugnu A from 3641' to 3780' are very reminiscent of the lower Ugnu B displaying very light gray color with clast size ranging from medium upper to fine upper, subround to subangular with moderate sphericity and moderate to well sorting. No visible cementing noted with unconsolidated grains and dominant grain support. A slight clay matrnc is noted with sand composed of 90% quartz and 10% chert, volcanics and various lithic fragments with fair to good estimated porosity with continued common dark brown oil blebswith a very slight petroleum odor and very light staining. Samples displayed an 80% moderate even orange sample fluorescence with instant bright blue white milky fluorescent cut and a strong browned hue residue ring. Sands by 3730' have decreased to only 10-30% of the samples as clay and silt have taken over thus reducing the background gases and oil in the samples. Sands from 3810' to 3900' show an increase in size to coarse ~l ~~'~ 10 ,~,,,, ~fJI7p[itf~11~~1~?S 3J-101 with a fine lower end. Scattered very coarse and pebbles are noted in parts. Sands are medium gray with a brownish hue and subround to subangular. The finer fraction is 60% quartz and 40% dark gray to bladcto gray to trace yellow, including silicates and minor carbonaceous and volcanic. The coarser fraction includes mostly dark cherts and some angular quartz (some trace fight brown calcite} with mostly matrix supported with a continued 60-70% dull to moderate even fluorescence on clay and sand with continued free oil and spotty tar with decreasing oil shows to the top of the West Sak D. Siltstones below the K13 marker (3958 increase from 25% to over 50% of the samples at the top of the West Sak D. Colors are medium gray to medium light gray with gradational aspects from very clayey to silly claywith most coarse silt grading to very fine lower sized sand. Same floating mostly fine silicate sand grains with slight overact black silts and fines with carbonaceous matter. Most other silts are clear to translucent quartz to slight silicates and green chlorite with occasional increasing black to dark reddish brown carbonaceous matter and micro partings. Claystones compose roughly 40% of the samples throughout the Ugnu A and are gradational to siltstones. The clays are medium gray to medium light gray and very soft with various consistences: lumpyto dumpy clustered to clotted, gelatinous in parts, mushy to pasty with non to very slight cohesiveness and slight to moderate adhesiveness. Samples display earthy to amorphous fractures and habits with a moderate earthy luster and a colloidal to ashy texture. Most of the clays are gradational composed roughly of 50% clay, 50% siltwith pin point oil in the samples and a 10% moderate orange sample fluorescence which is probably slough from the base of the Ugnu B or the top of the Ugnu A. The well was shut in at 3853' as it noted a 6 BBI gain. The well was flowing and it was pumped out through the choke at 54 SPM (162 GPM) with no volume increase while pumping. There was no Down Time Gas associated with this flow check. A Wiper Trip was conducted at 4127' for new drilling mud and displacng the hole (580 BBLS). Wiper gas recorded was 95 units. DEPTH GAS units C1 m CZ m C3 m C4 m C5 m 3701 112 21395 6 Top West Sak D Sand to West Sak C Shale 4221' to 4317' MD (-2916' to -2946' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 184 6.9 109 270 28 159 The first West Sak "D" sand (west of the fault) was readily identified by an abrupt gas show of 122 units over 25 with slight amounts of C-2 with a 90% even moderate orange sample fluorescence with no odorwith pin pointto common dark brown oil in the samples and a instant bright blue white milky cut and a strong brown hued residue stain. Sample fluorescence changed to a yellow orange at 4240' and to a uniform yellow by 4250'to the base of the "D" sand at 4317' The West Sak "D" sands are very light gray overall, medium upper to fine Tower grains and scattered medium lower to very fine in the lower section, subrounded, moderate sorting with slightly poor sorting at the base, matrix supported, and friable with clay and silt matrix, to gradationally poorly sorted with increasing silt and clay matrix, while occasionally grading to siltstone or claystone. Traces of sandstone were firm with a calcareous clay matruc, and specks and partings of organic matter oriented along laminar contacts were common especially in silts and clays. Compositions are 70-90% quartz, and 30-10% undifferentiated cherts, lithics, and various volcaniclastics and silicates, including common green grains from possible chlori6zation. Porosity appears to be fair to poor, but typical of oil producing West Sak Sands. The samples had no odor with pin point to common dark brown free oil in the samples. Fluorescence is 90% orange-at 4221' and becoming yellow ~~~~~ 11 r. ~(~1'1OC0~11~~IpS 3J-101 • orange to yellow at 4250'. Samples have an instant bright blue white milky flourescence cut with strong brown hued residue stains. Background gas remained between 100 to 200 units throughout the entire zone and decreasing to 40-50 units once into the West Sak "C" silts with continued bleed off of oil in drilling mud. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 4220 122 26435 14 4246 27D 57436 32 7 4278 210 44272 23 Top West Sak C Shale to West Sak B Sand 4317' to 4490' MD 1-2946' to -2984' TVDSS~ Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 197 16.5 109 171 21 59 The West Sak "C" siltstone (70%) was pate yellowish brown to light brownish gray becoming medium gray to medium fight gray towards the base. very poor to poor induration with many amorphous soluble cuttings, grading to a silty claystone in parts in the tower sections. 0-15% very fine grain sand noted. Sample fluorescence was 40% and diminishing with depth with continued pin point to common oil in cuttings and mud system. DEPTH GAS units C1 m C2 m C3 C4 m C5 m 4335 171 37132 24 Top West Sak B Sand to Fault 4490' to 4910' MD -2984' to -3036' TVDSS Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 250 12.3 123 114 21 54 The West Sak B is primarily sand but mostly poorly developed and often grading siltstone to silty claystone. Maximum gas in this zone was only 114 units, and low resistivity except through t~ht calcareous sandstone or sandy calcareous tuff, indicates a low probability of hydrocarbon production. Sample fluorescence, however, persisted, ranging from 20-60% of the samples, from a faint orange to a dull to moderate yellow orange. There was scattered oil staining on the clays, but no reported free oil. Bulk cuts were an instant milky white and slow streaming from the clays. Sands and sandstone were medium light gray to medium gray, with very fine to medium and scattered coarse grains. Grains were angular to subrounded. Sandstone persisted in 20-30% ofthe samples, was veryfine to fine grained, soft to friable, and matroc and grain supported in a mostly non to sl'~ghtty calcareous day and silt matruc. Occasional streaks were hard and calcareous as mentioned earlier. A fine to coarse unconsolidated fraction persisted as 20-30% of the samples at the top of the B to mostly 10-20% approaching the fault, and also occurred as scattered floating grains in the finer sandstone. The coarser sands are estimated to be friable, mostly grain supported, and grading to moderately well sorted with some fair to good porosity. Overa{{ composition of the sands and sandstone was 60% clear to translucent quartz, 35% dark brown to black to amber to gray to green silicates, siliceous lithics, and (mostly carbon) lithics, and 5% white to light brown calcte. The calcite is possibly localized to calcite concretions and not persistent in the sands. Siltstone and claystone was medium gray to medium light gray, and often with a faint brownish hue probably at least in part due to oil staining from mud in the oil. Cuttings were soft to moderately soft and overall slrcthtly calcareous. Locally tightly scattered calcite flakes indicated thin lamina or fracture fill. ~P~~~ 12 'CttO~'11~~~tpS 3J-101 • DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 4602 114 22867 11 Fault to West Sak D Sand 4910' to 5548` MD (-3036' to -3166' TVDSSI Driii Rate fflhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 301 11.8 114 200 11 64 The fault zone is curiously identified with the sudden appearance of iso-butane, occurring in signficant amounts relative to ethane and propane. Oil fluorescence increased, but possibly at least in part due to oil in mud not absorbed into clays through the sandy section. Samples in an upper sandy section, below the fault contact at 4910', had 70% dull to moderate orange fluorescence with scattered spots of free oil, but gas peaked at only 75 units. Fluorescence and gas decreased gradually to 50%, until a second sand at 5130' which peaked with 200 units of gas and a slight increase in free oil in samples. Samples had 60-80% fluorescence from 5130'to 5280', from a faint orange to a moderate yellow orange. With only unconsolidated sands and lumps of sandy clay to test, bulk cuts were an instant milky white, and moderate stream from the sandy clays. Sands were medium gray to medium dark gray, medium to very fined grained, especially medium to fine, and with scattered coarse. Grains were angu{ar to subrounded with moderate to high sphericity. The sands were estimated to be mostly grain supported, friable, and well to moderate{y sorted with a c{ay matrix; Compositions were 60% clear to translucent quartz, and 40% dark gray to gray to dark brown to black to green and trace red grains, including silicates, siliceous lithics, and minor lithics and chlorite. Porosfies are estimated as fairto good. After 5350' samples changed from predominantly sand to predominantly siltstone, comprising roughly 75% of the caught samples. Background gas also reflected this change showing a gradual decrease in gas readings from 120 units at 5350' to averaging 50 units just above the top of the West Sak D. Siltstones comprised of light brownish gray to pale yellowish brown colors with very poor to poor induration with various consistences: lumpy to clumpy, clustered to clotted, mushy to pasty, slightly tackyto rare slimy in parts. Sifts displayed non to slight cohesiveness to slight to moderate adhesiveness with amorphous to earthy fracture and habits. Moderate earthy lusters with an ashy to colloidal texture of massive gradational silts composed of 80°!o silt and 20% clay with trace shell fragments and various trace detrital materials. The sifts still gave off a 50% dull even orange yellow sample fluorescence with instant hazy to cloudy moderate streaming cuts with straw to pale straw residue stains decreasing to the top of the West Sak D. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 5153 185 34404 28 15 97 0 Top West Sak D Sand to West Sak C Shale 5548' to 5610' MD (-3166' to -3196' TVDSSI Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 258 25.0 126 634 88 210 The West Sak D was marked an abrupt gas kick from 45 units to a maximum of 291 units followed by two other kicks with peaks of 634 units @ 5564' and 178 units at 5597'. All gas kicks were marked by sands compromising no more than 40% and no less than 20°!0 of the samples. The West Sak D sands were very light gray with cast size ranges from fine lower to very fine with some ~P~~~ 13 CO~'11~~IpS 3J-101 gradation to silt. Clasts were subrounded with moderate to well develaped sphericity and moderate to poor sorting with no visible cement, unconsolidated with traces of calcite. Sands had a dominant silt and clay structured (loosely attached) matrix support with possible secondary grain support in cleaner parts. The sands were composed of predominantly quartz with minor chert and various lithic fragments with porosity and permeability noted at fair to poor on average. Sample fluorescence was noted at 60% even yellowgreen atthe first gas kick @ 5547' and increasing to 80% at the second gas kick at 5564'. Pin point to common brown oil in the samples and drilling mud with no odor or stain giving off an instant bright blue white milky fluorescence oil cut with a straw hued residue stain. Samples of the third gas kick at 5597' displayed a slightly less oil cut than the other two kicks showing an instant cut but only cloudy to hazy blue white cuts with a faint straw residue stain. Siltstones of the section are light brownish gray to pale yellowish brown with very poor to poor induration. Consistency was lumpy to clumpy, clustered to clotted, mushy to pasty, slightly tacky to some being slimy in parts. Silts displayed very slight cohesiveness to slight to moderate adhesiveness with an amorphous to earthy fracture and habit, moderate earthy luster with an ashy to colloidal texture. These silts were composed of 80°k silt, 20% clay and moderately hydrophilic. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 5547 291 49141 158 30 36 6 5564 634 103038 465 134 84 9 5597 178 28295 105 35 30 5 Top West Sak C Shale to West Sak B Sand 5610' t~ 5671' MD (-3196' to -3231' TVDSSI • Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 211 40.9 135 178 92 126 The West Sak C was fairly uniform in samples, gas and oil shows (61 ~, with samples generally composed of 70-80% silt and 20-30% sand. Background gas averaged 126 unifis with a maximum of 178 units giving a very calm background gas throughout the zone. Sand was very light gray with clast sizes ranging from fine lower to very fine, being subrounded with moderate to well developed sphericity and displaying moderate to poor sorting with pitted textures and no visible cement being freely unconsolidated. Dominant {oosely attached sift matrix was noted with dominant matrix support with some possible secondary grain support possible in parts. Sands were composed of predominantly quartz with minor chert and trace various lithic fragments. Porosity and permeabilitywere estimated atfairto poor. Samples had 80% moderate to bright even yellow green sample fluorescence with pin point to scattered oil in the samples and mud giving off no odor or stain. Oil cuts were instantaneous cloudy to hazy blue white with a faint straw residue ring. Siltstones were light brownish gray with very poor to poor induration. Consistencies varied from lumpy to clumpy, clustered to clotted, mushy to pasty with non to slight cohesiveness and moderate adhesiveness. Sills displayed an amorphous to earthy fracture and habit with a moderate earthy luster and ashy to silty with some colloidal textures. Generally massive silt with gradtionat beds of very fine sands. DEPTH GAS units C1 C2 m C3 m C4 m C5 m 5656 126 20423 62 25 Z6 5 Top West Sak B Sand to West Sak A4 5671' to 5737' MD -3231' to -3272' TVDSS Drill Rate (ft/hr) Total Gas (units) ~,,PC~CH 14 t]~'11~~1~75 3J-101 • • Maximum Minimum Avera a Maximum Minimum Avera e 219 9.2 140 482 166 327 The West Sak "B sand was marked by a increase in background gas from 150 units with two peaks of 435 units {5674') and 482 un'~ts (5689') and having a constant background of 200-400 units marked by disfinctincreases of C-5 {Pentane). Sands were very light gray with clayt size ranges from fine to very fine being subround with moderate developed sphericity. Moderate to poor sorting with a dominant loosely packed silt and clay matruc support exhibiting 90°lo moderate to bright yellow green with some spotty orange hued even sample fluorescence with no odor and common brown oil in the samples and drilling mud. Samples yielded an instant milky blue white oil cut with moderate to strong brown hued residue stain. Sample cuts of oil marked a large increase of "show" compared to the West Sak C with background gastripling in value and the quality of oil shows giving a distinct change on the mud log from a "2" rating (average) to a "4" rating excellent. Siltstones of the West Sak B formation mirror the silts in the West Sak C with very little difference. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 5674 435 68953 297 217 284 108 5689 482 75975 348 279 318 117 Top West Sak A4 to West Sak Al 5737' to 6030' MD -3272' to -3496' TVDSS Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 192 20.3 102 313 46 137 This section combines the West Sak A4 and West Sak A3 as both intervals are of similar composition. This section includes intebedded siltstone and sand. The A4 and A3 sands are moderately to poorly sorted with a clay and silt matrix and poor to fair esfimated porosity, developed primarily over the intervals 5745-5777" forthe A4, and 5840- 5870' for the A3, as is indicated by good show gas and oil shows. Relative amounts of pentane continue to increase through this section. The A4 sand was very light gray with clayt size ranges from fine to very fine showing subround to subangular features with moderate developed sphericity. Sorting was moderate to poor with impacted textures and no visible cement with traces of calcite. A dominant matrix supported sand with loosely attached clay and trace amounts of pyrite and mica. Porosity and permeability was estimated at poor to fair with pin point to scattered brown oil in the mud. Samples showed an even yellow green fluorescence with no odor and a instant bright hazy to cloudy blue white oil cut and a straw residue stain. The A3 was noted for good gas and oil shows with sand being very light gray and a clast size range from fine lower to very fine grading to silt in parts. Clasts were subround to subangular with moderate developed sphericity and moderate to poor sorting. and composed of predominantly quartz with fair to poor estimated porosity and permeability. Samples exhibited a 80°/o moderate yellow green even sample fluorescence with pin point to scattered brown oil with instant bright blue white milky cuts and a strong straw residue. Siltstones are brownish gray to light brownish gray with medium gray to light gray and offwhite secondary hues. The clays are soft and soluble for the most part, but occasional firmer cuttings sometimes exhibit incipient fissility. Brownish color is due to organic clays from reworked carbonaceous matter. Slight carbonaceous silts, fines, and flakes overall, sometimes oriented along planar bedding where structure is preserved. Textures are silty to clayey with slight to locally abundant very fine and fine sand grains as grades to clayey sand. i ~POC~ 15 ~OI"10Ct1~'11~~IpS 3J-101 • DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 5758 310 48237 227 198 273 108 5844 229 34048 212 291 576 289 5921 254 35256 236 239 805 583 Top West Sak Al Sand to Total Depth 6030' to 6274' MD 1-3496' to -3706' NDSS1 Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 192 35.6 115 374 50 114 Relative amounts of pentane began to decline in the West Sak "A1 "where gas peaked in a basal sand at 308 units, and continued to decline in sands below the West Sak Base, where gas peaked at 374units. Fluorescence had declined in the "clayey" section above the basal sand to 20-30% faint orange and a trace of free oil, to increase again in the high gas sands. Samples from 6120' to total depth (6274' had 50-80% even faint orange to moderate yellow orange fluorescence with spots of medium to dark brown free oil, and orange yellow fluorescence and brown oil stain on rare scattered clusters of consolidated sandstone. A bulk cut produced an instant milky to moderately streaming white fluorescence, and the sandstone a slight instant to slow blooming white fluorescence. Sand and sandstone was medium gray overall, and fine to very fine with lightly scattered medium lower grains. Grains were angular to subrounded, subangular overall, with moderate to high sphericdy. Composition of the grains was 75% clear to translucent quartz, and 25% black to gray to dark brown to green silicates or siliceous lithics and minor chlorite. A high gamma response in gaseous zones could indicate grains are perhaps reworked volcanics in part. The sands were estimated to be mostly grain supported and friable, and moderately • to well sorted with a clay matrix. The sandstone was poorly to moderately consolidated with a siliceous cement. Porosities in the high gas sands are estimated to be fair to good, and in the sandstone poor. Some very fine to fine grained slightly argillaceous sandstone below the basal West Sak was dense and calcareous. Siltstone and claystone was medium gray overall, and gradational from slightly silly claystone to clayey siltstone grading to clayey very fine grained silty sandstone. Trace to slight carbon sifts and fines pers~stthroughout, with locally minor micropartings and clasts in the A1. Cuttings were moderately soft and soluble and non to occasionally slightly calcareous, to rare firm and calcareous. Traces of micropartings of oil were also observed in the A1. • Ash fall tuff occurred in slight amounts in the samples, occurring as light gray with a greasy luster, non calcareous, and smooth to slightly sandy/silty. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 6141 308 39422 553 125 289 400 6175 374 58706 824 150 284 284 6254 159 26329 275 43 71 74 ~[)11'1GE0~1t~~1~]S 3J-101 3.3 Gas Samples 1 unit c A_05% Methane Eauivalent • r~ LJ Sam le De th Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=0.05°t° M.E. (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) 1 2500 24 4990 2 2750 12 2417 3 3000 18 3316 4 3250 10 1661 5 3340 75 16021 6 3491 221 47107 19 7 3750 43 8760 8 4000 22 4391 9 4212 122 26435 tr 10 4505 53 10129 5 11 4750 24 4434 2 12 5000 34 6703 3 13 5145 185 33666 27 12 78 8 14 5250 137 24687 14 9 88 13 17 15 5500 41 5216 8 2 11 1 6 16 5750 220 34231 157 131 130 69 74 17 5945 208 26748 1$5 269 270 369 265 277 18 6138 300 45692 527 115 167 113 246 115 19 6177 370 56240 828 146 175 96 259 136 20 6250 148 24272 261 39 43 25 43 18 3.4 Connection Gases 1 unit = 0.05% Methane Eauivalent De th Units C1 C2 C3 C4 C5 feet m m m m m None Recorded ~,POCH 17 O~t~{~IpS 3J-101 • • 3.5 Samptinq Pro4ram f Samale Disaatch Set T / Pu ase Fre uenc Interval Dis etched to ~~^'1ew warehouse Unwashed Biostratigraphy 60' ' 110' -1770` MD ' ' ConocoPnilrrps Alaska, Inc. ABV 100 A 30 - 6274 MD 1770 8105 Eleusis Drive Set owner: CPAI + 10 Shows A AK 99502 ttnhDaPe .McCracken A Bayvievu Warehouse Unwashed Biostratigraphy 60' ' 110' - 1770` MD ' ' Cor~oPniNips Alaska, Inc. ABV 100 B 30 - 6274 MD 1770 8105 Eleusis Drnte Set owner: BP 10' Shows Anchorage, AK 99502 Attn: D. P ~ kitM. McCracken Bayview Warehouse Washed, screened & dried 60' 110' -1770` MD cormcoPniuips Alaska, lnc. ABV 100 C Reference Samples 30' 1770' - 6274' MD 8105 Eleusis Drive Set owner: CPA{ 10' Shows Anon°rage, AK ssso2 Attn: D. P 'ski/M. McCracken 110' -1770` MD ~Y~+r Warehou~ Washed, screened & dried 60' 1770' - 6274' MD ConocoPhillips Alaska, Inc. ABV 100 D Reference Samples 30' Shows 8105 Eleusis Drive Set owner: BP 10' Anchorage, AK 99502 Attn: D. P 'skilM. McCracken 110' -1770` MD Bayview warehouse Washed, screened & dried 60' 1770' - 6274' MD ConocoPhillips Alaska, Inc. ABV 100 E Reference Samples 30' Shows $105 Eleusis Drnre Set owner: Unocal 10' Anchorage, AK 99502 Attn: D. P .McCracken 110' -1770` MD B Washed, screened & dried 60' 1770' - 6274' MD ~ ~Pni>lips ,A asks, tnc. ABV 100 F Reference Samples 30' ShO~ 8105 Eleusis Drive Set owner: AOGCC 10' Anchorage, AK 99502 Attn: D. P ~ski1M. McCracken Isotube gas samples 250' Routine intervals and Isotech Laboratories, Inc. G and spots of 2500' -6250` MD 13~ Parkland Court si nificant eaks above g p interest Champaign, IL 61821 bac round USGS 345 Middlefiekt Road, MS 999 H USGS gas hydrates 60' 150-3270' Menlo Park,. CA 94025 Attn: T. Lorenson 650-329-4186 • Sample frequency was locally altered according to drill rate constraints and zones of interest. ~ ~~oc~ 18 '~L3r1UCt~11~~Ip5 3J-101 • • • 4 PRESSURE /FORMATION STRENGTH DATA 4.1 Formation Integrity/Leak Off Tests MD TVDSS FIT /LOT FORMATION (tt} (ft {P Ennwl 2401' -2021 14.0 U nu C E uivalent mud wet ht EM is calculated from rota table. LOT (Leak Off Test) in bold italics. 4.2 Wire line Formation Tests HYDROSTATIC DEPTH ND NDSS Before After F Press Mobil' PPG Calc Formation 4226.1 2917.23 1479.11 1466 1406 1.6 9.26854 West Sak D 4240.16 2922.47 1504 1487.5 1367.88 26.5 9.001079 West Sak D 4615.2 2999.71 1465 1468 1345 236.5 8.622628 West Sak B 5553.1 3168.78 1657.24 1638.8 1449.9 25.1 8.799188 West Sak D 5568 3175.83 1666.4 1640 1439.28 27 8.715347 West Sak D 5600.3 3191.8 1674.69 1657 1486.05 6.6 8.953532 West Sak B 5676.2 3233.53 1696 1676 1494.5 14.6 8.888238 West Sak B 5697.2 3246.15 1703.73 1685.22 1490 47.1 8.827025 West Sak B 5917.3 3402.78 1787.6 1772.8 1568.31 9.2 8.863285 West Sak A3 4.3 Pore Pressure Evaluation Introduction Trend indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of a well; Background Gas (BG) Trip Gas (TG) Corrected D exponent (DXC} Resistivity (RES} Mud Weight (MW) Equivalent Circulafing Density (ECD) Hole Conditions (HC) Connection Gas (CG) Pressure Test Wire tine (PT) Quantitative Methods The primary indicators used for pore pressure evaluation were gas trends and wire line testing. Shales do not appear to be over compacted, and DXC plots do not appear to be of much use. Factors such as controlled drill rates, alternate sliding and rotating intervals, variations in angle building while sliding, PDC bits, and the absence of clean shale baselines to establish compaction trends, precluded reliable estimation. RES plots appear to be reliable in determining a permafrost base and suggesting compaction trends with depth, although the presence of hydrocarbons skews this data. However, generally, low RES and low gas indicate shaliness. 4.4 Pore Pressure Evaluation Conclusions 1) Surface Hole -13 1/2" (110' to 2381') Pore pressure throughout the surface hole probably maintained a constant at approbmately 8.6 ppg. DXC ~I'(~CH 19 COI'lOCO~'U~~IpS 3J-101 • vs TVD was not plotted, as there was no ECD measurement provided for this interval. Resistivity values for sand trails off after 1790' (1700' TVD), below the base of the permafrost. Gas remained low below the permafrost, suggesting no change in pore pressure. RES AND GAS VS ND -13.5" loooo looo 100 10 • 2) 8'/s" hole (2381' to 6724', Total Depth) •RES x GAS Pore pressure measured from wire line varied from between 8.62 ppg to 9.00 ppg in the West Sak, except fora 9.26 reading from a tight sand likely supercharged with mud filtration. MW was maintained at 9.2 to 9.4 while drilling this section and ECD varied from 9.6 to 10.6, fluctuating but overall increasing with depth. ECD data was measured down hole, continuously while drilling (MWD), and provided by Sperry-Sun. The DXC data is quite random. A sharp up trend in DXC from 3000-3200' is primarily the result of turning angle approximately 4 degrees per stand to near vertical in the D sand, with some hard calcareous concretions complicating the results as well. As the angle dropped drilling improved, and DXC also dropped. RES is a better pore pressure indicator. The steady downward tangent with depth reflected on low resistivity, low gas (shale) data, supports normal compaction trends. The lack of connection gases, or downtime gas after flow was checked and the hole appeared to be breathing, suggest pore pressure remained significantly under the 9.2-9.4 MW. A normal to slight upward trend in PP, ranging 8.6 to 9.0 ppg, as suggested by RES and wireline data, is concluded. • ~~ EPOCH 20 0 500 1000 1500 2000 2500 COI'1000~'ll~~lp5 3J-101 • r i• DXC VS ND - 8.5" 2.5 0.5 2000.0 2200.0 2400.0 2600.0 2800.0 3000.0 3200.0 3400.0 3600.0 3800.0 4000.0 • ~ • ~• • Z H ~ • • • • •• • • w ~ •~ ~; • • • i M S • - ~ ~ s = ~ ,; ~~ • • * s • ~• • • •~ : ts• _ • • ~ ) il'Cf Rti f) • 2.3 2.1 1.9 1.7 1.5 1.3 1.1 0.9 0.7 DXC AND GAS VS ND - 8.5" 2.5 2.3 2.1 1.9 1.7 1.5 1.3 1.1 0.9 0.7 E~ EPOCH •DXC •DXC z GAS 21 0.5 2000.0 2200.0 2400.0 2600.0 2800.0 3000.0 3200.0 3400.0 3600.0 3800.0 4000.0 • • i• loooo looo 100 10 loooo loon 100 10 C011000~'11~~Ip5 3J-101 RES VS ND - 8.5" RES AND GAS VS ND - 8.5" ~~ EPnC;H • RES • RES X GAS 22 1 2000.0 2200.0 2400.0 2600.0 2800.0 3000.0 3200.0 3400.0 36DD.0 3800.0 4000.0 1 2000.0 2200.0 2400.0 2600.0 2800.0 3000.0 3200.0 3400.0 3600.0 3800.0 4000.0 • 4.5 Pore pressure evaluation ~~ COt'tt~C0~11~~~p5 3J-101 F Primary Secondary Interval To s Pore Pressure EMW T d Source of ormation Interval Lithology (%) Lithology (%) MD ft TVDSS ft Min Max Trend ren Indicators 4uantitative Estimate Permafrost Sd 60°I° CI st 30°I° 110 -36 8.6 8.7 Flat BG RES Base Permafrost Sd 70% CI st 30% 1790 -1626 8.6 8.7 Flat BG RES To U nu "C» Sd 40% CI st 30% 2664 -2169 8.6 8.8 Flat BG RES, DXC To West Sak Sltst 40% Sd 30% 4221 -2916 8.6 9.0 Sli ht U BG RES,DXC,PT Fault Sltst 50% Sd 30% 4910 -3036 8.7 9.0 Flat BG RES,DXC,PT Base West Sak Sd 40% CI st 30% 6156 -3603 8.8 9.0 Flat BG RES, DXC Total De th 6274 -3706 8.8 9.0 Flat BG RES, DXC NOTE: Clyst = Claystone/Clay, Sd =Sand, Sltst = Siltstone, Sh =Shale, Sst =Sandstone ~1~~~~ 23 C~'11~~Ip5 3J-101 • 5 DRILLING DATA 5.1 Survey Data • • Measured Deft, h Incl. (°) Azim. (°) Tree Vertical Depth ft Latitude (ft~ Departure (ftl Dogleg Rate (°/100ft) Vertical Section (ft) 0.00 0.00 0.00 0.00 O.OON 0.00E 0.00 0.00 100.00 0.79 238.46 100.00 0.25S 0.41 W 1.13 -0.39 200.00 1.31 228.94 199.98 1.36S 1.86W 0.55 -1.75 263.00 1.75 233.48 262.96 2.41 S 3.18W 0.72 -2.98 360.00 1.31 241.58 359.92 3.825 5.34W 0.50 -5.03 443.00 0.72 228.90 442.91 4.61 S 6.57W 0.76 -6.19 533.00 0.70 109.95 532.91 5.175 6.48W 1.36 -6.05 720.00 8.11 96.95 719.23 7.16S 7.71E 3.97 8.25 752.74 10.40 96.59 751.54 7.78S 12.94E 7.00 13.51 847.86 16.30 97.77 844.05 10.57S 34.71E 6.21 35.43 943.27 17.41 99.03 935.36 14.62S 62.08E 1.23 63.03 1038.48 18.61 98.68 1025.90 19.15S 91.16E 1.27 92.38 1133.00 21.24 99.98 1114.75 24.39S 122.94E 2.82 124.47 1228.84 25.71 94.61 1202.65 29.08S 160.78E 5.17 162.57 1260.00 26.32 94.18 1230.65 30.125 174.41E 2.04 176.23 1324.12 27.57 93.34 1287.81 32.02S 203.40E 2.04 205.28 1418.64 27.69 95.05 1371.55 35.23S 247.11E 0.85 249.11 1440.00 27.80 95.37 1390.46 36.135 257.01E 0.85 259.05 1513.86 28.17 96.44 1455.68 39.70S 291.48E 0.85 293.70 1609.00 26.96 95.45 1540.02 44.27S 335.27E 1.36 337.71 1704.20 28.95 95.65 1624.11 48.58S 379.69E 2.09 382.33 1775.00 33.06 95.12 1684.78 52.OOS 415.99E 5.81 418.78 1800.07 34.51 94.96 1705.62 5322S 429.87E 5.81 432.72 1894.20 43.01 94.18 1778.95 57.885 4$8.56E 9.05 491.60 1988.41 47.43 93.84 1845.30 62.54S 555.25E 4.70 558.45 2083.36 51.33 94.44 1907.10 67.76S 627.12E 4.14 630.51 2178.32 52.40 95.02 1965.74 73.92S 701.56E 1.23 705.19 2272.72 54.92 96.80 2021.68 81.76S 777.18E 3.07 781.20 2314.11 54.99 95.67 2045.45 85.445 810.87E 2.24 815.07 2402.90 56.30 95.52 2095.55 92.59S 883.82E 1.48 888.36 2491.33 54.74 95.08 2145.61 99.33S 956.40E 1.81 961.24 2589.42 55.92 95.74 2201.41 106.945 1036.71E 1.32 1041.90 2664.00 55.29 95.16 2243.54 112.78S 1097.97E 1.06 1103.43 2684.05 55.12 95.00 2254.98 114.24S 1114.37E 1.06 1119.90 2774.31 58.19 93.22 2304.59 119.625 1189.56E 3.78 i 195.28 2865.04 59.86 90.50 2351.29 122.13S 1267.30E 3.16 1272.98 2968.44 58.53 91.84 2404.25 123.93S 1356.09E 1.70 1361.63 3063.23 59.72 94.42 2452.89 128.39S 1437.31E 2.65 1442.96 ~1 ~P~~H 24 rP.. 0~7~~tIpS 3J-101 • • Measured D(ft) h Incl. tom) l4zim. (~~ Verti al Depth ft Latitude (ftl Departure ~ftl Dogleg Rate (°/100ft1 Vertical Section (ft1 3158.29 62.41 95.56 2498.88 135.63S 1520.18E 3.02 1526.14 3252.87 64.34 94.81 2541.27 143.27S 1604.38E 2.16 1610.68 3342.00 64.53 92.48 2579.74 148.38S 1684.61E 2.37 1691.06 3347.97 64.54 92.32 2582.30 148.60S 1690.00E 2.37 1696.45 3442.97 65.36 92.29 2622.53 152.06S 1775.99E 0.86 1782.45 3537.93 64.78 92.67 2662.55 155.79S 1862.02E 0.71 1868.51 3633.17 64.32 92.79 2703.48 159.89S 1947.92E 0.50 1954.46 3728.39 62.77 92.35 2745.90 163.71 S 2033.08E 1.68 2039.66 3736.00 62.63 92.30 2749.39 163.98S 2039.84E 1.95 2046.42 3823.71 61.00 91.72 2790.82 166.70S 2117.10E 1.95 2123.65 3915.77 58.76 90.82 2837.01 168.47S 2196.70E 2.58 2203.15 3958.00 58.39 92.15 2859.03 169.40S 2232.73E 2.82 2239.13 4011.06 57.95 93.83 2887.01 171.75S 2277.74E 2.82 2284.20 4104.97 59.03 94.27 2936.09 177.41 S 2357.60E 1.22 2364.26 4199.49 65.23 94.79 2980.26 184.01 S 2440.86E 6.58 2447.77 4220.00 67.03 95.94 2988.56 185.775 2459.53E 10.14 2466.52 4293.15 73.49 99.81 3013.26 195.245 2527.67E 10.14 2535.20 4318.00 74.18 99.41 3020.18 199.23S 2551.21E 3.19 2558.97 4388.46 76.15 98.28 3038.22 209.69S 2618.50E 3.19 2626.88 4483.38 81.58 98.11 3056.54 222.96S 2710.65E 5.72 2719.79 4488.00 81.68 97.86 3057.22 223.60S 2715.18E 5.81 2724.35 4576.86 83.57 93.01 3068.63 231.93S 2802.88E 5.81 2812.43 4671.82 80.89 93.40 3081.47 237.19S 2896.81E 2.85 2906.49 4753.00 81.49 95.85 3093.90 243.665 2976.76E 3.07 2986.70 4766.70 81.59 96.26 3095.92 245.09S 299024E 3.07 3000.25 4861.07 84.75 96.33 3107.14 255.36S 3083.36E 3.35 3093.89 4866.00 84.89 96.30 3107.59 255.90S 3088.24E 2.91 3098.80 4954.00 87.41 95.83 3113.49 265.18S 3175.54E 2.91 3186.56 5048.90 86.86 96.05 3118.24 274.99S 3269.82E 0.62 3281.31 5142.14 83.76 93.49 3125.86 282.72S 3362.40E 4.31 3374.22 5152.00 83.30 93.34 3126.97 283.30S 3372.18E 4.90 3384.01 5236.07 79.38 92.06 3139.63 287.22S 3455.18E 4.90 3467.07 5326.76 74.83 90.87 3159.86 289.49S 3543.53E 5.18 3555.32 5424.70 69.33 94.92 3190.00 294.14S 3636.55E 6.86 364$.41 5520.09 64.25 92.62 3227.58 299.945 3723.99E 5.77 3736.04 5540.00 63.03 92.52 3236.42 300.74S 3741.81E 6.15 3753.87 5611.00 58.68 92.12 3271.00 303.255 3803.75E 6.15 3815.82 5615.21 58.42 92.10 3273.19 303.38S 3807.34E 6.15 3819.41 5670.00 54.21 92.28 3303.57 305.12S 3852.89E 7.68 3864.95 5709.26 51.20 92.42 3327.36 306.40S 3884.09E 7.68 3896.16 5737.00 49.28 91.70 3345.10 307.17S 3905.40E 7.21 3917.46 5797.00 45.14 89.99 3385.85 307.84S 3949.41E 7.21 3961.39 ~P~CH 25 ~: f..~01'1~000~1t~~IpS 3J-101 • C~ Measured Depth (ft) Incl. (°) Azim. (°) Tree Vertical Defptth Latitude (ft) Departure (ft) Dogleg Rate (°/100ft) Vertical Section (ft) 5802.76 44.74 89.81 3389.93 307.83S 3953.48E 7.21 3965.45 5895.15 38.46 90.59 3458.98 308.02S 4014.79E 6.82 4026.58 5902.00 38.00 90.84 3464.37 308.075 4019.03E 7.07 4030.81 5987.73 32.30 94.44 3534.44 310.23S 4068.30E 7.07 4080.10 6008.00 32.10 94.60 3551.59 311.09S 4079.07E 1.06 4090.90 6083.12 31.38 95.22 3615.48 314.47S 4118.44E 1.06 4130.42 6155.00 30.65 95.22 3677.08 317.845 4155.32E 1.02 4167.45 6176.71 30.43 95.22 3695.78 318.84S 4166.31E 1.02 4178.48 6206.00 30.36 95.09 3721.04 320.17S 4181.07E 0.33 4193.30 6274.00 30.36 95.09 3779.72 323.22S 4215.30E 0.00 4227.67 ~,PC)CH 26 5.2 Bit Record ~, • • Ct?t'1OCl~'tl~~lp5 3J-101 Depth In Total Bit Aug' WOB PP Bit Make Type Jets / TFA MD / TVDSS Footage Hrs ROP (Klbsj RPM lpSi) Wear BHA ft ft/hr 131/2" Hole 1rr2 HTC MX-1 3X20 1X13 110' 2271' 19.2 118 17 29 933 2-3-WT-A-E-I-ER- , TD 8.5" Hole 2 HTC HCM605 5X15 2381' 3892 36.81 115 23 32 1439 4-6-BT-A-RA-1-- TD ET'OCH 27 ~.: 'COtlC1G0~11~~IrJS 3J-101 5.3 Mud Record Contractor :MI Mud Tvpe :Spud Mud in Surface. FLOPRO NT from 2381' (after LOT) to TD Date Depth MW ECD VIS s~ t PV YP Gels FL cc FC Sols % O/VN Ratio Sd % pH CI ml/I Ca ml/I 13'/x" sec tion 12/2/05 1866 9.3 9.63 185 30 41 39/84/86 9.6 2/ 7 /93 1 9.2 600 40 1213/05 2381 9.5 9.5 175 37 32 14/33/36 5.6 2/ 8.5 192 0.75 9.2 600 40 12/4/05 2381 9.5 48 19 7 3/4/6 6 2/ 8 /92 0.75 9.0 600 40 12/5105 2381 9.3 9.3 52 24 12 3!8!10 6.6 21 7 193 0.75 9.2 600 40 8'/z" sect ion 12/6105 3320 9.1 10.74 75 6 46 21 /24/25 5.6 1 / 4.5 /96 1 9.3 24000 140 12J'7/OS 4127 9.0 10.32 70 10 30 10/12/14 5 1/ 2 /98 0.6 9.0 19000 120 12!8!05 5681 9.0 10.43 56 8 35 12/12/13 6 1 / 5 tr/95 0.4 9.0 16500 140 1219/05 B254 9.0 10.92 75 10 44 14!16117 5 11 5 tr/95 0.25 9.7 17000 120 12/10!05 6274 9.0 9 65 9 35 10/14/15 5.4 1 / 5 td95 0.2 9.5 17000 120 12/11/05 6274 9.0 9 48 10 30 8/10/12 5.8 1! 5 tr/95 0.2 9.7 16000 120 12/12/05 6274 9.1 9.1 57 13 32 12/14/18 5.8 1 / 5 tr/95 0.45 9.3 16000 120 12/13/05 6274 9.0 51 10 28 6/8/9 5.8 1 / 5 tr/95 0.3 9.5 15000 100 Abbreviations MW =Mud Weight Gels =Gel Strength Sd =Sand content WL = Water or Filtrate Loss CI =Chlorides VIS =Funnel Viscosity Ca =Hardness Calcium PV =Plastic Viscosity Sols =Solids YP =Yield Point ECD =Effective Circulating Density FC =Filter Cake O/W =Oil to Water ratio ~1 ~Pt~+~H 28 ~~~~~~~ 3J-101 n U MORNING REPORTS ~~~~~ 29 ConocoPhillips Alaska Inc. Exploration Well 3J-101 Report for: Larry Meyers Geologist: Curt Date: 12!2/05 Time: 03:30 Current Depth: 540 Yesterdays Depth: 110 24 hr Footage: 430 rlrillinn Dcramafcrc Operation: DRILU SLIDE ROP: Current: 60 Max: 336 Torque: Current: 0 Max: 1332 WOB: Current 10 Max: 17 RPM: Current: 0 Max: 45 PP: Current: 722 Max: 740 Lag: Strokes: 669 Time: 5:15 Circulation: Strokes: 5259 Time: 39 ECD: Current: 9.88 Max: ~A~~r~ Drnnorfioc 7 MW: 9.3 FV: 170 PV: 25 YP: 50 FL: NA Gels: 35/48/52 Sol: 6 H: 9.2 CI- 400 Ca++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 10.1 De the 525 (`_~c Gvcn+c Trip Gas Depth TG C1 C2 C3 C41 C4N C51 GSN NONE Connection Gas De th TG C1 C2 C3 G41 C4N C51 C5N NONE Poakc Depth TG C1 C2 C3 C41 C4N C51 C5N 527 10.1 2089 3as Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 90% SAND, 10% CLAY Last 24 hrs: Opperational Summary: DRILL AHEAD AS PER DIRECTIONAL PLAN, SLIDE AND GYRO @ CNX Calibrations: Failures: • ConocoPhillips Alaska Inc. Exploration Well 3J-101 Report for: Larry Meyers Geologist: Curt Goddard Date: 12/3/05 Time: 05:00 Current Depth: 2340 Yesterdays Depth: 540 24 hr Footage: 1800 Operation: DRILU SLIDE rlrillinn Pcr~mctcrc • ROP: Current: 121 Max: 273 Torque: Current: 4071 Max: 5652 WOB: Current 14 Max: 33 RPM: Current: 40 Max: 300 PP: Current; 1527 Max 1703 La Strokes: 2352 Time: 5:15 Circulation: Strokes: 9385 Time: 29.4 ECD: Current; 9.88 Max: Muni PrnnPrtiPc MW: 9.3 FV: 185 PV: 30 YP: 41 FL: 9.6 Gels: 39/84/86 Sol: 7 H: 9.2 Cf 600 Ca++ 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 2 Max: 44 De the 802 (`_~c Fvnn4c Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N NONE Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE Paakc Depth TG C1 C2 C3 C41 C4N C51 C5N 802 44 8809 gas Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 90% SAND, 10% CLAY Last 24 hrs: Sand, Clay Opperational Summary: DRILL AHEAD AS PER DIRECTIONAL PLAN, SLIDE AND GYRO @ CNX Calibrations: Failures: ConocoPhillips Alaska Inc. Exploration Well 3J-101 Report for: Larry Meyers Geologist: Curt Goddard Date: 12/4/05 Time: 05:00 Current Depth: 2382 Operation: Run 10.75" csg Yesterdays Depth: 2340 24 hr Footage: 42' rlrillinn Pnrarr~ctprc ROP: Current: 0 Max: 195 Torque: Current: 0 Max: 6189 WOB: Current 0 Max: 23 RPM: Current: 0 Max: 51 PP: Current: 0 Max: 1623 La Strokes: 2412 Time: 16 Circulation: Strokes: 3000 Time: ECD: Current: Max: Mud Properties MW: FV: PV: YP: FL: Gels: Sol: H: Cf~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 4 Max: 10 De the 2382 (`_~c Gvcn4c Tri Gas Depth WG C1 C2 C3 C41 C4N C51 CSN 2382' 25 5129 Connection Gas De th TG C1 C2 C3 C41 C4N C51 CSN NONE Pcakc Depth BG C1 CZ C3 C41 C4N C51 C5N 2382 5 1020 .as Sam les No. Depth TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 90% SAND, 10% CLAY Last 24 hrs: Sand, Clay DRILL AHEAD TO 2382', CIRCULATE HOLE, WIPER TRIP TO THE SHOE Opperational Summary: =WG 25 UNITS, TRIP TO BOTTOM CIRCULATE HOLE, POOH R/U AND RUN 10.75" CSG TO BOTTOM. TG = 10 UNITS Calibrations: • Failures: ConocoPhillips Alaska Inc. Exploration Well 3J-101 Report far: Larry Meyers Geologist: Curt Goddard Date: 12/5/05 Time: 05:00 Current Depth: 2381 Operation: Work on Wellhead Yesterdays Depth: 2381 24 hr Footage: 0' rlrillinn Ppramatarc • .J ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: ECD: Current: Max: Maui Prnnarticc MW: 9.5 FV: 48 PV: 19 YP: 7 FL: 6 Gels: 3/4/6 Sol: 8 H: 9.0 Cf~ 600 Ca++~ 40 MW Change: Depth: 2381 From: 9.3 To: 9.5 Reason: 8.5 Hole Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 0 De th: 2381 C~ac Fvcntc Trip Gas Depth TG C1 CZ C3 C41 C4N C51 C5N ' 10 2033 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE PPakc Depth BG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 CSN Lithologies: Current: 90% SAND, 10% CLAY Last 24 hrs: Sand, Clay RUN 10.75" CSG TO 2372' (SHOE). Circulate and condition mud. Pumped Opperational Summary: cement and displaced with mud. Bumped the plug and had cement returns to the surface. Working on the well head at present time. Calibrations: Failures: ConocoPhillips Alaska Inc. Exploration Well 3J-101 • .J • Report for: Larry Meyers Geologist: Curt Goddard Date: 12/6/05 Time: 05:00 Current Depth: 2401 Operation: LOT Yesterdays Depth: 2381 24 hr Footage: 20' Ilrillinn Porama+arc ROP: Current: 0 Max: 184 Tor ue: Current: 0 Max: 5496 WOB: Current 0 Max: 29 RPM: Current: 0 Max: 50 PP: Current: 0 Max: 1623 La Strokes: 2362 Time: 17 Circulation: Strokes: 2900 Time: 21 ECD: Current: 9.3 Max: 9.3 Marl Prnnarticc MW: 9.3 FV: 52 PV: 24 YP: 12 FL: 6.6 Gels: 3/8/10 Sol: 7 H: 9.2 CI" 600 Ca++ 40 MW Change: Depth: From: Mud Loss event: Depth: Volume: Ta: Reason: Gas Data Ditch Gas: Current: 0 Max: 4 De the 2401 Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N ' 0 0 Connection Gas De th TG C1 C2 C3 C41 C4N C51 CSN NONE Paakc Depth BG C1 C2 C3 C41 C4N C51 C5N Gas Sam ples No. Depth TG C1 CZ C3 C41 C4N C51 C5N Lithofogies: Current: 90% SAND, 10% CLAY Last 24 hrs: Sand, Clay FINISH INSTALLING WELL HEAD, TEST BOPE, P/U 8.5" BIT AND BHA, RIH Opperationa{ Summary: TO 2100', CIRCULATE AND CONDITION THE MUD TO 9.3 PPG, TEST CASG TO 3000 PSI, DRILL OUT FLOAT EQUIPMENT AND 20' OF NEW HOLE, PERFORM LOT AT PRESENT. Calibrations: EQUIPMENT CALIBRATED TODAY Failures: NONE ConocoPhillips Alaska Inc. Exploration Well 3J-101 Report for: Larry Meyers Geologist: Curt Goddard Date: 12/7105 Time: 05:00 Current Depth: 3753 Yesterdays Depth: 2401 24 hr Footage: 1352 rlrillinn Poramaficarc • ROP: Current: 138 Max: 624 Tor ue: Current: 5746 Max: 7063 WOB: Current 10 Max: 35 RPM: Current: 75 Mau: 78 PP: Current: 1389 Max: 1784 La Strokes: 3238 Time: 18 Circulation: Strokes: 11718 Time: 65 ECD: Current: 10.74 Max: 10.74 Marl Drnncrfiinc MW: 9.1 FV: 75 PV: 6 YP: 46 FL: 5.6 Gels: 21/24/25 Sol: 4.5 H: 9.3 Cf 24000 Ca++~ 140 MW Change: Depth: 3320 From: 9.3 Ta: 9.1 Reason: WELL PLAN Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 43 Max: 243 De the 3488 gas Events Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N ' 0 0 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE P as ke De th BG C1 CZ C3 C41 C4N C51 C5N 3488 243 46995 13 C:ac Samples No. Depth TG C1 C2 C3 C41 C4N C51 C5N 4 3250 10 1661 5 3320 70 16021 6 3500 221 47107 9 7 3750 40 8760 Lithologies: Current: 60°!o SAND, 30% CLAY, 10%SILT Last 24 hrs: Sand, Clay FINISH LOT AND DRILL OUT CEMENT PLUS 20' OF NEW HOLE, PREFORM FIT FAILED, CIRCULATE HOLE AND RETRY. PASSED. GOOD Opperational Summary: FOR 14.0 PPG EMW, RIG UP AND DISPLACE HOLE, CLEANED OUT LINES AND MUD PITS WITH WATER, TOOK ON NEW FLO PRO FROM TRUCKS AND DRILLED AHEAD. Operation: DRILLING Calibrations: ConocoPhillips Alaska Inc. Exploration Well 3J-101 Report for: Lar Me ers Geologist: Tony Hild. Date: 12!8/05 Time: 05:00 Current Depth: 4359 Yesterdays Depth: 3753 24 hr Footage: 606 rlrillinn Pcr~mctcrc • ROP:v Current: 119 Max: 224 Torque: Current: 5325 Max: 6772 WOB: Current 30 Max: 60 RPM: Current: 60 Max: 77 PP: Current: 1380 Max: 1544 La Strokes: 3628 Time: 24 Circulation: Strokes: 9300 Time: 58 ECD: Current: 10.32 Max: 10.32 Marl PrnnarFias MW: 9.0 FV: 70 PV: 10 YP: 30 FL: 5 Gels: 10/12/14 Sol: 2 H: 9.0 Cf 19000 Ca++ 120 Ditch Gas: Current: 53 Max: 269 De the 4246 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 3828 Volume: 35 bbls Gas Data 3as Events Trip Gas Depth WG C1 C2 C3 C41 C4N C51 C5N 4127 95 20883 Connection Gas De th TG C1 C2 C3 C41 C4N C51 CSN NONE vo~~~ Depth BG C1 C2 C3 C41 C4N C51 CSN 4246 269 51436 24 Comas s;amnlac No. Depth TG C1 C2 C3 C41 C4N C51 C5N 8 4000 22 4391 9 4218 122 26435 TR Lithologies: Current: 70% SILT, 30% CLAY Last 24 hrs: Sand, Clay, SILT DRILL TO 3828, OBSERVED 35 BBL GAIN, SHUT DOWN FOR FLOW Opperational Summary: CHECK, NO GAIN, DRILLED TO 3851 OBSERVED A 6 BBL GAIN IN PIT, SHUT IN AND CHECK FLOW NO GAIN, DRILLED TO 4127 POOH SHORT TRIP WG = 95 UNITS, DISPLACE HOLE WITH NEW MUD.. Calibrations: Failures: NONE Operation: DRILLING GonocoPhillips Alaska Inc. Exploration Well 3J-101 ny Hild. 5:00 Current Depth: 5951 Yesterdays Depth: 4359 24 hr Footage: 1592 Operation: DRILLING ROP: Current: 99 Max: 300 Torque: Current: 9102 Max: 9385 WOB: Current 1 Max: 73 RPM: Current: 62 Max: 68 PP: Current: 1520 Max: 1712 La : Strokes: 4656 Time: 29 Circulation: Strokes: 10746 Time: 67 ECD: Current: 10.32 Max: 10.32 Mutt Prnn~+rtios Report tar: Larry Meyers Geologist: To Date: 12/9105 Time: 0 r)rillinn ParamatPr~ MW: 9.0 FV: 56 PV: 8 YP: 35 FL: 6 Gels: 12/12/13 Sol: 5 H: 9.0 CI- 16500 Ca+' 140 Ditch Gas: Current: 92 Max: 634 De the 5564 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Trip Gas Depth WG C1 C2 G3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE Paaks Depth BG C1 C2 C3 C41 C4N C51 CSN 5564 634 103038 465 134 134 100 9 (,ac Samnlac No. De th TG C1 C2 C3 C41 C4N C51 C5N 14 5250 137 24687 14 9 101 17 15 5500 41 5216 8 15 6 16 5750 220 34231 157 131 130 69 112 17 5945 208 26454 285 1079 356 500 245 115 Lithologies: Current: 90% SILT, 10% SAND Last 24 hrs: SILT, VFGR SAND Opperationai Summary: DRILLING THE LAST 24 HRS. Calibrations: CALIBRATED INSTRUMENTS BEFORE WEST SAK Failures: NONE • ConocoPhillips Alaska fnc. Exploration Well 3J-101 ny Hild. 05:00 Current Depth: 6273 Operation: POOH to E-Log Yesterdays Depth: 5951 24 hr Footage: 322 ROP:+ Current: 0 Max: 192 Tor ue: Current: 0 Max: 10840 WOB: Current 0 Max: 40 RPM: Current: 0 Max: 67 PP: Current: 0 Max; 1817 La Strokes: 4865 Time: 29 Circulation: Strokes: 10829 Time: 69 ECD: Current: 10.92 Max: 10.92 Mori PrnnPrtiac Report for: Larry Meyers Geologist: To Date: 12110/05 Time: r)rillinn Ppramotarc U i MW: 9.0 FV: 75 PV: 10 YP: 44 FL: 5 Gets: 14/16/17 Sol: 5 pH: 9.7 Cf 17000 Ca" 120 Ditch Gas: Current: 0 Max: 374 De the 6175 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data 3as Events Trip Gas Depth WG C1 C2 C3 C41 C4N C51 C5N 6273 274 43647 216 87 120 88 204 97 Connection Gas De th TG C1 C2 C3 C41 C4N C51 CSN NONE Paalrc Depth BG C1 C2 C3 C41 C4N C51 C5N 6175 374 58706 823 149 175 95 259 136 C;ac Samnlas No. Depth TG C1 C2 C3 C41 C4N C51 CSN 18 6138 300 45692 527 115 167 113 246 115 19 6177 370 56240 828 146 175 96 259 136 20 6250 148 24272 261 39 43 25 43 18 Lithologies: Current: 6273' (TD) sandstone 10%,sand 20%, siftstone 40%, clay 30% Last 24 hrs: SILT, VFGR SAND, SANDSTONE, CLAY, DRILL TO 6274' (TD) / 3779' (TVD), PUMPED A HIGH V1S SWEEP AND Opperationat Summary: CIRCULATED OUT THE HOLE, POOH TO 2360' (TIGHT @ 4795'), TIH TO BOTTOM AND PUMP A HIGH VIS SWEEP (WG = 274 units), CIRCULATE OUT 3x AND BEGIN TO POOH FOR LOGS.. Calibrations: Failures: NONE ConocoPhillips Alaska Inc. Exploration Well 3J-101 ' ~ Report for: Larry Meyers Geologist: Tony Hild. ' Date: 12/11/05 Time: 05:00 Current Depth: 6273 Operafion: MDT Logging Yesterdays Depth: 6273 24 hr Footage: 0 f~rillinn PPramPtars • ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4865 Time: 29 Circulation: Strokes: 10829 Time: 69 ECD; Current: 10.92 Max: 10.92 Miirl Prnnc+rFicc MW: 9.0 FV: 65 PV: 9 YP: 35 FL: 5.4 Gels: 10/14/15 Sol: 5 pH: 9.5 CI- 17000 Ca++ 120 Ditch Gas: Current: 0 Max: 0 De the 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data gas Events Trip Gas Depth WG C1 C2 C3 C4{ C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE Ppakc Depth BG C1 C2 C3 C41 C4N C51 C5N 0 0 0 0 0 0 0 0 0 gas 5ampies No. Depth TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 6273' (TD) sandstone 10%,sand 20%, siltstone 40%, clay 30% Last 24 hrs: SILT, VFGR SAND, SANDSTONE, CLAY, POOH and lay down BHA and R/U for wire line logging. RIH with wire line and Opperational Summary: complete required logs with no problems. P/U and run MDT logging tools, side entry sub installed at 4147.. Calibrations: • Failures: NONE ConocoPhillips Alaska Inc. Exploration Well 3J-101 ny Hild. 05:00 Current Depth: 6273 Operation: MDT Logging Yesterdays Depth: 6273 24 hr Footage: 0 ROP:v Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4865 Time: 29 Circulation: Strokes: Time: ECD: Current: 10.92 Max: 10.92 Aniirl Drnncrticc Report for: Larry Meyers Geologist: To Date: 12/12/05 Time: rlrillinn Paramc4orc MW: 9.0 FV: 48 PV: 10 YP: 30 FL: 5.8 Gels: 8/10/12 Sol: 5 H: 9.7 CI" 16000 Ca++ 120 ditch Gas: Current: 0 Max: 0 De the 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Trip Gas De th WG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C4l C4N C51 C5N NONE Pcakc Depth BG C1 C2 C3 C4{ C4N C51 C5N 0 0 0 o a o 0 0 0 3as Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 6273' I?D) sandstone 10%,sand 20%, siltstone 40%, clay 30% Last 24 hrs: SILT, VFGR SAND, SANDSTONE, CLAY, Opperational Summary: Continue MDT logging with no problems. Calibrations: Failures: NONE ConocoPhillips Alaska Inc. Exploration Well 3J-101 ' • Report for: Larry Meyers Geologist: Tony Hild. Date: 12/13/05 Time: 05:00 Current Depth: 6273 Operation: MU DP SWC RIH Yesterdays Depth: 6273 24 hr Footage: 0 r)rillinn Paramatar_c • ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current fl Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4865 Time: 29 Circulation: Strokes: Time: ECD: Current: 10.92 Max: 10.92 flAiirl Prnnartioc MW: 9.0 FV: 48 PV: 10 YP: 30 FL: 5.8 Gels: 8110112 Sol: 5 H: 9.7 CI" 16000 Ca+' 120 Ditch Gas: Current: 0 Max: 0 De the 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data as Events Trip Gas Depth WG C1 C2 C3 C41 C4N C51 C5N 3000 68 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE Paakc Depth BG C1 C2 C3 C41 C4N C51 C5N 0 0 0 0 0 0 0 0 0 as Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 6273' (TD) sandstone 10%,sand 20%, siltstone 40%, clay 30% Last 24 hrs: SILT, VFGR SAND, SANDSTONE, CLAY, .FINISH MDT LOGGING, POOH WITH LOGGING TOOLS ON DP, UD Opperational Summary: LOGGING TOOLS M/U AND BEGIN TO RIH WITH SWC. Calibrations: Failures: NONE i ConocoPhillips Alaska Inc. Exploration Well 3J-101 Report for: Larry Meyers Geologist: Tony Hild. Date: 12/14/05 Time: 05:00 Current Depth: 6273 Operation: R/D DP SWC TOOL Yesterdays Depth: 6273 24 hr Footage: r~rillinn PPramPtarc ROP:v Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4865 Time: 29 Circulation: Strokes: Time: ECD: Current: 10.92 Max: 10.92 Merl Prnnnrtiac • MW: 9.0 FV: 51 PV: 10 YP: 28 FL: 5.8 Gels: 6/8/9 Sal: 5 pH: 9.5 CI-~ 15000 Ca++ 100 Ditch Gas: Current: 0 Max: 0 De the 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data as Events Trip Gas Depth BG C1 C2 C3 C41 C4N C51 C5N 5935 10 1875 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE Paakc Depth BG C1 C2 C3 C41 C4N CS{ C5N 5935 10 1875 0 0 0 0 0 0 as 5ampies No. Depth TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 6273' {TD) sandstone 10%,sand 20%, siltstone 40%, clay 30% Last 24 hrs: RIH WITH SWC TOOLS TO 5935', CIRCULATE AT SLOW RATE, AVE Opperational Summary: BACKGROUND CIRCULATION 7 UNITS (MAX 10),COMPLETE SIDE WALL CORES AND POOH WITH CORE SAMPLES. • Calibrations: Failures: NONE ~, Daily Cost: $2300.00 ConocoPhillips Alaska Inc. Exploration Well 3J-101 Report for: Larry Meyers Geologist: Tony Hiiiegeist. Date: 12/15/05 Time: 05:00 Current Depth: 6273 Operation: Cement Plug Yesterdays Depth: 6273 24 hr Footage: 0 • • rlrillinn Por~mc4crc ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4865 Time: 29 Circulation: Strokes: Time: ECD: Current: 10.92 Max: 10.92 Mnrl PrnnPrtiac MW: 9.0 FV: 51 PV: 10 YP: 28 FL: 5.8 Gels: 6!8/9 Sal: 5 H: 9.5 Cl~ 15000 Ca++~ 100 Ditch Gas: Current: Max: De the 0 4 units 0 units 9 units MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data 3as Events Trip Gas Depth BG C1 C2 C3 C41 C4N C51 CSN NA Connection Gas De th TG C1 CZ C3 C41 C4N C51 C5N NA PaakS Depth BG C1 C2 C3 C41 C4N C51 CSN Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 CSN Lithologies: Current: 6274' (TD} sandstone 10%,sand 20%, sittstone 40%, clay 30% Last 24 hrs: Opperational Summary: Calibrations: Failures: NONE Daily Cost: $2300.00 Rig down Epoch unit after core samples. WELL LOGS Analysis of MDT Fluid Samples ConocoPhillips Field: West Sak Well: 3J-101 Black Oil PVT Study Report Prepared for Dennis Wegener Schlum6erger ~•r~yAy ~~-~ ~~ ~~ ~y.~-w~ ~~ ~~ I -~ ~~ ~_,,..., ..._-. • Schlumberger Analysis of MDT Fluid Samples -~...,~4.. ~- ConocoPhillips ~° `- Field: West Sak °~:~; ; < ' Well: 3J-101 ~..d ... ~.,.. ; ~.... Black Oil PVT Study Report ~ ~~y"''~ Prepared for ~~~~ ~~ Dennis Wegener ConocoPhillips Standard Conditions Used: Pressure: 14.696 psia Temperature: 60°F ~~~^~~~`~ JAN 2 2 2007 Oii & Gas Cons. Anchorage Prepared by: Stefan Smuk Schlumberger Oilphase-DBR 16115 Park Row, Suite 150 Houston, Texas, 77084 + 1 281 285 6370 Date: 08/25/2006 Report #200500215 50 - o~°~ - ~3 2'45 3- °° ~ 1~13~~3 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: ~ B&D Schlumberger Installation: - Job #: 200500215 • Table of Contents List of Figures ........ . ........................................................................................................................................... ............................... List of Tables ..................................................................................................................... EXECUTIVE S.UMMARY ................................................................................................................................ Objective ............................. Introduction .................................................................................... . Scope of Work ................................................................................................... . .............................................. . Results _ .................................................................................................... PVT Summary -. Sample. RSS.(1.111. +.1.o2J,•. Cylinder. CSB.4832-1A;. Depth 569Z.ft MD,. B. Sand ...................................... PVT Summary -Sample RSS (1.11 + 1.12 + 1.13• Cylinder CSB 4881-1A; Depth 5553 ft MD, D Sand Sequence of Events..... _ .......................................................................................... _ ......................................... . ................................................. Chain of Sample.Gustody ......................... RESULTS AND..DISCU.SSI.ONS ........................................................................................................................ Fluids Preparation.andAnalysis ........................................................................................................................... Reservoir Fluid Analysis ...................................................................................................................................... PVT Analysis on .Sample. RSS. (1..01...+.1..A2-;.Cylinder. CS6.4832-.1A; D.epth.56S7.ft.M0, .B .Sand ........................................ Constant Composition.Expansinn.at.Tres ............................................................................................................... Reservoir Oil Viscosity. at.Tres .............................................................................................................................. Multi-Stage Separation..lest ................................................................ _ ............................................................ . • PVT Analysis on Sample RSS (1.11 + 1.12 + 1.131; Cylinder CSB 4881-IA; Depth 5553 ft. MD, D Sand Constant Composition.Expansion.at.il/0°f ............................................................................................................. Reservoir Oil Viscosity. at.Ties .............................................................................................................................. Multi-Stage Separation..Test ............................................................................................................................... Appendix A: Namenclatu.re.and.D.efinitians • Appendix B: Molecular Wei.ghts.and.Densities.Used ................... Appendix C: EQUIPMENT ............................................................. Fluid Preparation and .Validation ............................................................ Fluid Volumetric. (PYTJ.and.V.iscosityEquipmeot ...................................... Appendix D: PROCEDURE ................................................................. Fluids Preparation.and. Yalidati~n ........................................................... Constant Composition.Expansinn.Proceduce ............................................ Differential Vaporization.Procedure ........................................................ Multi-Stage Separation..Test .................................................................. Liquid Phase Viscosity. and Density. Measurements During. DY. Step .......... . Stock-Tank Oil.(STOJ.Viscosity.and.Density.Measurements ...................... Asphaltene, Wax. and Sulfur.Gontent.Measurements ................................ SAR(PJA Analysis .................................................................................. Nigh-Temperature.High. Pressure.Filtration.Test ....................................... Dllphase-DBR 1 z 3 4 4 4 4 4 5 5 7 7 s 8 47 47 49 51 61 61 63 65 ss 70 71 71 71 74 74 74 74 74 75 75 75 76 76 File 200500215 Client: ConocoPhillips Well: 3J-101 Field: Sand: West Sak B & D Schlumberger Installation: - Job #: 200500215 List of Figures Figure 1: Stock.Tank.Oil.Chromatogram.(Sample..1.04- ............................................................... ............................... 16 Figure 2: k-Plot.fnr.Equilibrium Gheck(Sample.].D4- .................................................................. ............................... 16 figure 3: Stock.Tank.Qil.Ghromatogram.(Sample1.08} ............................................................... ............................... ~9 Figure 4:k-Plot far.EquilibriumGheck(Sample.]..08) ................................................................. ............................... t9 Figure 5: Stock.Tank.Qil.C.hromatogram.(Sampla1.09- ............................................................... ............................... 22 Figure 6: k-Plot.for.Equilibrium.Check(Sample.]..D9) ................................................................. ............................... 22 Figure 7: Stock Tank.tlil.Chromatogram.(Sample1.101 ............................................................... ............................... 25 Figure 8: k-Plot.for.Equilibrium Gheck(Sampl.e.]..]0) ................................................................. ............................... 25 Figure 9: Stock.Tank.Dil.Chcomato.gram.SSample.1.14) .............................................................. ............................... 28 Figure 10: k-Plot.for.Equilibrium.Check.(Sample.1.1..4- ...............................................:................ ............................... 28 Figure 11: Stock.Tank.Dil.Chromatogram(Sample.L18) ............................................................. ............................... 31 Figure 12: k-Plat.for.Equilibrium.Check.(Sample.1.]81 ................................................................ ............................... 3t Figure 13: Stock.Tank.Oil.Chromatogram.(Sample.]..19- .............................................................. ............................... 34 Figure 14: k-Plot.forEquilib.rium.Che.ck.(Sample.l.]g) ................................................................ ............................... 34 Figure 15: Stock Tank.Dil.Chromatogram(Sample.1.20) ............................................................. ............................... 37 Figure 16: k-Plat for. Equilibrium.Check.(Sample .1.201 ................................. .. 37 figure l7: Stock Tank. Dil.Chromatogram(Sample.1..01&.1.02) .................................................... ............................... ao Figure 18: k-Plat.forEquilib.rium.Che.ck.(Sample.1.01.&.1.021 ...................................................... ............................._ 40 Figure 19: De-emulsifier.Oil.Cbromatagram .............................................................................. ............................... 4i Figure 20: Stock Tank. Dil:Chromatogram.(Sample.l..D1.&.1.02) .................................................... ............................... as Figure 21: k-Plot.for.Equilibrium.Che.ck.(Sample.1.01.&.1.02- ...................................................... ............................... 44 Figure 22: Constant.Composition Expansion at.7.0.0°F -. Relative.llolume ...................................... Figure 23: Reservoir.Fluid.Viscos.ity.70°F .................................................................................. ............................... 48 ............................... 50 Figure 24:Stock.Tank.Dil.Chromatogram.(Sample.1..11,.]..1213<.1.1.3) ............................. ~ . ~ ~.~ ~ ~ ~ ~~ ~ 57 Figure 25: k-Plat..for. Equilibrium.Che.ck.(Sample.i.].1,.1.1.2.& 1.13) .............................................. ................................ 57 Figure 26: Constant.Compositionl=xpaosionat.].00°F. -.Relative.Velum.e ...................................... ................................ 62 Figure 27: Reservoir.Fluid.V.iscosity.69°f ................................................................................. ................................ sa • Ollphase-DBR 2 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B & D Schlumberger Installation: - Job #: 200500215 List of Tables Table 1: Well and.Sample.tdentificaiian ................................................................. .............................. to Table 2: Well Position Data ........................................ . ....................................... .............................. to Table 3: Sampling and.TransferSummary ............................................................... .............................. tt Table 4: Reservoir.EluidProperlies ....................................................................... .............................. t2 Table 5: Stock-T.ank.Qil.P.roperties ....................................................................... .............................. t3 Table6:C30+Compositio.n,.GOR,.°APl,.by.Zero-Flash.(.S.ample.1.041 ....................................... ........................_.......... t4 Table 7: Calculated.Fluid.Properties ................................................................................... .................................... t5 Table8:C30+Comp.osition,.GOR,.°AP.I,.by.Zero-F.lash.(S.ample..1.08) ....................................... .................................... t~ Table 9: Calculated.Fluid.Properties ................................................................................... .................................... to Table 10: C30+Composition,.GQR, °API,.by.Zero-Elash.lSample.1.D9.) ...................................... .................................... 20 Table 11: Calculated.Fluid.P.ro.perties ................................................................................. .................................... 2t Ta61e 12: C30+ Camposition,.GOR, °AP.I,.by.Zero-.Flash.(Sample.1.10.- ...................................... .................................... 23 Table 13: Calculated.Eluid.P.ro.perties ................................................................................. .................................... 24 Table 14: C30+ Composition,.GQR, °API,.hy.Zero-.Flash.(Sample.1.14.) ...................................... .................................... 2s Table 15: Calculated.fluid.P.roperties ................................................................................. .................................... 2~ Table 16: C30+ Gomposition,.GQR.'API,.by.Zero-..Flash.(Sample.1.18) ...................................... .................................... 2s Table 17: Calculated.Fluid.P.roperties ................................................................................ ..................................... 30 Table 18: C30+ Compasition,.GOR, °API,.by.Zero-Flash.(Sample.1.19.) ..................................... .................................... 32 Table 19: Calculated.Eluidl?.roperties .............................................................................. ..................................... 33 Table 20: C30+ Composition,.GOR, °APl,.by.Zero-.Flash.ISample.1.20.) .................................... ..................................... 35 Table 21: Calculated.Fluid.P.roperties .................................................... _.......................... .......................:..... _...... 3s • Table 22:C36+Camposition,.GOR,'API,.by.Zero-Elash.(Sample.1.01.&.1.021 ........................... ..................... 38 Table 23: Calculated.Fluid.P.roperties ................................................................................ ..................................... 3s Table 24: C36+Composition,.GQR,'AP.I,.by.Zero-.Flash.(Sample.1.01.&.1.02- ........................... ..................................... 4z Table 25: Calculated.Fluid.P.roperties ................................................................................ ..................................... 43 Table 26: Composition.af.Syntheti.c.Recomhination.Gas.for.Sample.(1.01.&1.02) .................... ..................................... 45 Table 27: Summaryof.Results.of.Sample.RSS.(.1.01.t.1.02) .................................................... ..................................... 46 Table 28: Constant.Composition Expansion at.70.0°F. (Samp.le. t.01.&1..02 RSS.) ......................... ..................................... 47 Table 29: Reservoir.Fluid.Viscosity.7D°f ............................................................................. ..................................... 49 Table 30: Multi-Stage. Separation.Test.V.apor. & liquid. Properties ......................................... ..................................... 52 Table 3l:Multi-Stage.Separator.TestYapar.Gomposition(mol%.- ......................................... ............ .. 53 Table 32: Multi-Stage. Separator. Test Residual.liquid .Composition (mol %) ........................... ..................................... 54 Table 33: C36+ Compasition,.GQR, °API,.by.Zero-.Flash.(Sample.L.11..1...12 &.1.13) .................... ..................................... 55 Table 34: Calculated.Fluid.P.roperties ................................................................................ ..................................... 5s Table 35: C12+ Compasition.of. Synth.etic.Recomhinatian .Gas.far.Sample (.1.1.1,.1.12.&.1..13- ..... ..................................... 58 Table 36: Summary.af.Results.of.Sample.RSS.(.1.1.1.+.1.12.+.1.13- ........................................... ..................................... 59 Table 37: Constant.Composition .Expansion at,1.00°E.(.Sample. RSS.1..11..+.1...12 +.1.13) ............... ..................................... 60 Table 38: Simulated .Constant Composition. Expansion.at b9'F..(.Sample. RSS.1..11. +.1._12 +.1.13) . ..................................... 61 Table 39: Reservoir.Fluid.Viscos.ity.69°E ............................................................................. ..................................... 63 Table 40: Multi-Stage.Separati.on,Test.Vapor.&liquid.Properties ......................................... ..................................... 66 Table 41: Multi-Stage.SeparatorTestVapo.r.Composition ~.mal °fa.- ......................................... ..................................... s7 Table 42: Multi-Stage.SeparatorTest Residual.Liquid.Gomposition.(mol%.) ........................... ..................................... 68 • Ollphase-DBR 3 File 200500215 Client: ConocoPhillips Well: 3J-101 Installation: - Objective To evaluate the composition and phase behavior of bottomhole fluid samples collected during modular formation dynamics testing (MDT). Introduction At the request of ConocoPhillips, Oilphase-DBR conducted a fluid analysis study of bottomhole reservoir-fluid samples collected during the modular formation dynamics testing (MDT) of Well 3J-101 drilled in the field West Sak. Scope of Work Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for one day. Heat the samples for another day without rocking in vertical position. • Conduct preliminary evaluation on bottomhole hydrocarbon samples, including single-stage flash Gas- Oil Ratio (GOR), reservoir fluid composition, stock-tank oil (STO) and monophasic fluid properties. • Reconstitute representative formation-fluid blends using demulsification and recombination with synthetic gas, for each sampled depth. For each of the two recombined samples: Field: West Sak Sand: B & 0 Job #: 200500215 EXECUTIVE SUMMARY Schlumberger • Conduct a Constant Composition Expansion (CCE) test at the reservoir temperature. • Conduct amulti-stage separation test at the specified conditions. • Conduct viscosity measurements of the oil at the reservoir temperature. • Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon-fluid samples: • Eight bottomhole samples were used for validation purposes. They were homogenized at the reservoir conditions for one day and were settled in a vertical position, under heating, heated for one additional day. • The 'zero flash' GOR was determined to be from 75 - 158 SCF/STB, and the STO density to be from 0.950 - 0.968 g/cc. • To account for apparent undersaturation of the sampled fluids, two sets of samples (1.01 and 1.02, 5697' MD and 1.11 + 1.12 + 1.13, 5553' MD) were blended and recombined with synthetic gas mixtures, after demulsification. This process was intended to create test-fluid samples that would be representative of the native formation-fluid. The synthetic-gas compositions were determined using an equation-of-state model to predict the composition of gas that would have been evolved and separated from the sample during sampling, given an assumed saturation pressure. • The two sets of recombined samples (1.01 and 1.02, 5697' MD and 1.11 + 1.12 + 1.13, 5553' MD) each underwent PVT analysis. The measured PVT Data are summarized in the tables following. • Otlphase-DBR 4 File 200500215 • Client: ConocoPhillips Well: 3J-101 Installation: - Field: West Sak Sand:. B & D Job #: 200500215 Schlumberger EXECUTIVE SUMMARY (CONTiNUED- PVT Summary -Sample RSS (1.01 + 1.D2I; Gylinder CSB 4832-1A; Depth 5697 ff MD, B Sand FLASHING OPERATION CUMULATIVE GOR (scflstb) API GRAVITY Gas Relative Density (air=1) FVF at Pres(Tres FVF at Psat/Tres Zero Flash 158 16.9 0.584 1.033 1.035 Dt Flash @ Tres - - - - - SeparatorTest 150 17.1 0,571 1.039 1.041 PVT Summary -Sample RSS (1.11 + 1.12+ 1.13),• Cylinder CSB 4881-1A; Depth 5553 ff MD, D Sand FLASHING OPERATION CUMULATIVE GOR (scf/stb) API GRAVITY Gas Relative FVF Density (air=1- at Pres/Tres FVF at Psat/100°F Zero Flash 156 16.2 0.582 - 1.068 DL Flash @ Tres - - - - - SeparatorTest 156 16.3 0.572 - 1.063 :7 • Ollphase-DBR file 200500215 Client: ConocoPhifjips Well: 3J-101 Field: Sand: West Sak B & D Schlumberger Installation: - Job #: 200500215 Quality Assurance Process Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottom hole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality. Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry. This objective requires persistent innovation and ongoing development ofstate-of-the-art technologies and equipment. A rigorous quality assurance program, continuous employee training and enforcement of strict safety standards maintain our compliance with Quality, Health, Safety and Environment (QHSE} requirements. Proactive integration of OHSE objectives and management goals at every level supports the communication and implementation of OHSE policies and standards. Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data. Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures. Details of these programs are available upon request. The lab-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results a! Establish quality of measurement during data generation. bl Establish quality of processed data as per checklist during data processing by Data Quality Engineer. c) Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency dl The responsible Project Engineer confirms consistency of reported data e) Engineering Project Manager review the results/report for overall consistency Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established Quality checklists designed for each operation and based on the level of complexity. A(I property measurements and calculation procedures are maintained in company archives for a period of 1 year. This information is available for review by clients upon request. The file and laboratory records information are listed below to provide access reference to all records related to this project. For any questions, please do not hesitate to contact the undersigned Project Engineer, • Fi{e No.: 200500215 Laboratory Records: 200500215 Data Quality Suyu Ye Data Quality Engineer Overall Report duality Clay Young Oilphase-DBR Operation Manager, NGC • Data Reporting Stefan Smuk Fluids Analysis Support Engineer Ollphase-DBR 6 File 200500215 Client: ConocoPhiflips Well: 3J-101 Field: Sand: West Sak 6 & 6 Schlumberger Installation: - Job #: 200500215 • Sequence of Events 12/21/05 Samples arrived and client was updated. 01/03/06 Project work scope discussed. 01 /04/06 Work agreement approved. 01 /04/06 Prelim PVT tests request for eight samples issued. 01!10/06 STO density and water content results sent via e-mail. 01/20/06 Samp{e PVT pre{im results sent via e-mail. 08/25/06 Final PVT report issued to client. Chain of Sample Custody The samples collected from the well 3J-101 were sent to Oilphase-DBR in Houston, Texas. The samples were used to preliminary measurements and subsequent PVT studies. The measurement detai{s are in the following text. Samples remaining after measurements are stored in Oilphase-DBR storage unless otherwise instructed. • • Ollphase-DBR 7 fife 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B & D Schlumberger Installation: - Joh #: 200500215 • RESULTS AND DISCUSSIONS Fluids Preparation and Analysis Eight bottomhole samples collected during MDT operations were transferred to Oilphase-DBR. The well and formation data, with the respective reservoir conditions of the bottomhole samples, are summarized in Table 1. Quality checks of the bottomhole samples were conducted, and the results are summarized in Table 2. After one day of homogenization, sample validation testing was conducted to evaluate the validity of the samples. Based on the preliminary results, representative samples 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 phases recovered from single-stage flashing were subjected to chromatography and their compositions were determined. These compositions were recombined mathematically according to the single-stage flash Gas-Oil Ratio IGOR) to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Table 5, 7, 9, 11, 13, 15, 17 and 19. The molecular weight of the stock-tank oil (STO) was measured. Other properties such as the plus fraction properties and heat content for the flash gas were calculated from the compositions and are listed in Table 6, 8, 10, 12, 14, 16, 18 and 20. In order to capture enough sample for the de-emulsification and the testing, samples 1.01 through 1.03 and 1.11 through 1.13 were selected to undergo free-water and sediment checks. 60 cc water was recovered from sample 1.01, 70 cc water from 1.02, 350 cc mud for sample 1.03, 50 cc water from 1.11, 50 cc water from 1.12, and 50 cc water from 1.13. Thus, it was decided to transfer 250 cc oil from each of 1.01 and 1.02 to a new cylinder for de-emulsification. Approximately 200 cc of oil from each of 1.11, 1.12 and 1.13 were transferred to a single cylinder for de-emulsification. • After the de-emulsification, 75 cc water was recovered from the mixed sample {1.11, 1.12, 1.13) and 30 cc water from the mixed sample (1.01, 1.02). Both blends were then flashed to obtain GDR, API and compositional data. The reservoir fluid analyses are summarized in Tables 21 and 26. Other properties, such as the plus-fraction properties and heat contents of flashed gases, were calculated from the compositions and are listed in Tables 22 and 27. The blended sample (1.01, 1.D2) showed slight contamination from the demulsifier (Figure 20), indicating a slight surplus of injection. The de-emulsifier free composition appears in Table 23. Per client instruction, another 400 cc sample (200 cc each from 1.01 and 1.02) was transferred to a new cylinder, CSB 4832-IA, for a secondary demulsification using a lower additive ratio. 10 cc of free water was subsequently recovered from bottom of the cylinder, while close to zero BS&W was observed in the supernatant oil. Compositional analysis showed no contamination from the demulsifier. A saturation-point check of the blended sample 11.11, 1.12, 1.13) was conducted at room temperature, revealing a bubble point of 440 psia. This was consistent with the available reservoir-pressure and drawdawn data. An equation-of-state simulation was conducted to determine an appropriate synthetic-gas composition for recombination to the desired saturation point of approximately 1400 psia. In this process, a differential liberation at reservoir temperature was simulated, and the "first-step" gas composition was interred to represent the approximate composition of the gas that had been depleted from the sampled oil during acquisition. This gas was synthesized and physical recombination was carried out. Sample (1.01, 1.02) was also recombined with a synthetic gas. The planning and execution of the (1.01, 1.02) recombination was analogous to that done for sample (1.11, 1.12, 1.13). • (No Suggestions) 8 Fite 2005t102t5 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B & D Schlumberger Installation: - Job #: 200500215 • After recombination and analysis of sample (1.11, 1.12, 1.13, it was discovered that the sample appeared to have excess solution gas. It was inferred that stabilization had not occurred in the experimental system, due to severe density and viscosity conditions at the reservoir temperature of 69°F. It was decided to re-stabilise the fluid at 100°F and 1600 psia, which was predicted to be equivalent to a bubble point of 1450 psia at 69°F, and push off the excess gas. The elevated temperature was chosen to in order to ensure that good quality phase behavior data would be acquired for modelling purposes. The CCE and the first stage of the separator test were conducted at 100°F; the reported saturation point and property data reflect properties measured at 100°F, The first-stage properties of the separator test also reflect 100°F data. A simulation is provided, based on a tuned equation-of-state model, for a CCE experiment at the actual reservoir temperature of 69°F. The viscosity data for the D Sand, measured at actual reservoir temperature (69°F-, are considered to be unusually high for the fluid type. However, the values were confirmed through duplicate testing, and are considered to be analytically valid. • • INo Suggestions) 9 File 200500215 • Client: ConocoPhilfips Field: West Sak Well: 3J-101 Sand: B & D Schlumberger Installation: - Job #: 200500215 Table 1: Well and Sample Identification Client: ConocoPhillips Job# 200500215 Field: West Sak Well: 3J-101 Sample ID Chamber # Zone Sampling Date Opening Pres. Reservoir Conditions in the field Pressure Temperature Depth (psia/°F) {psia) (°Fy Ift1 1.04 MRSC 226 B Sand 12/11/05 4,615(66 1,505 70 5697 1.08 MPSR 1399 B Sand 12/11/05 4,515/66 1,5D5 70 5697 1.09 SPMC 254 B Sand 12/11/05 5,015/66 1,505 70 5697 1.10 SPMC 001 B Sand 12/11/05 5,515/66 1,505 70 5697 1.14 MRSC 297 D Sand 12/11/05 4,515/66 1,465 69 5553 1.18 MPSR 1398 D Sand 12/11(05 4,515/66 1,465 69 5553 1.19 SPMC 034 D Sand 12/11/05 5,515/66 1,465 69 5553 1.20 SPMC 162 D Sand 12/11/05 5,415/66 1,465 69 5553 Table 2: Well Position Data • • Well Name Strat Name Latitude Longitude X Loc Y Loc 3J-101 SURFACE 70.418759950 -149.643912902 1659577.11 6002638.65 3J-101 WEST SAK D 70.418255274 -149.823901590 1662034.38 6002460.53 3J-101 WEST SAK 6 70.418149411 -149.821817091 1662290.13 6002423.35 3J-101 WEST SAK A3 70.417917933 -149.811758736 1663524.57 6002342.27 3J-101 WEST SAK A2 70.417917349 -149.811196663 1663594.18 6002342.22 3J-101 WEST SAK D 70.417938810 -149.813452924 1663316.95 6002348.85 3J-101 WEST SAK B 70.417926949 -149.812548820 166342$.05 6002344.74 (No Suggestions) 10 file 200500215 • • Client: ConocoPhillips Well: 3J-101 Installation: - Field: West Sak Sand: B & D Job #: 200500215 Schlumberger Table 3: Sampling and Transfer Summary Opening Transfer Closing Opening Water Transferred Sample ID Chamber # conditions Cylinder conditions conditions Content Sample in the field ID in the field in the Lab from Top Volume (psial°F) (Psia/°FI IPsia/°F~ (wt%) lcc) 1.04 MRSC 226 4,615166 CSB 8629-QA 115/66 315/71 1.98 600 1.06 MPSR 1399 4,515/66 CSB 14309-QA 115/66 660/71 3.56 410 1.09 SPMC 254 5,015/66 SSB 18528-QA 6,015166 6215/71 5.25 240 1.10 SPMC 001 5,515/66 SSB 18136-QA 6,015166 6132/71 1.48 240 1.14 MRSC 297 4,515(66 CSB 14308-QA 115/66 289/71 1.19 600 1.18 MP5R 1398 4,515/66 CSB 14311-DA 115/66 568/71 6.23 410 1.19 SPMC 034 5,515166 SS818539-QA 6,015/66 6215/71 8.73 240 1.20 SPMC 162 5,415/66 SSB 18530-QA 6,015/66 6015/71 6.24 240 1.01 & 1.02 Multiple - CSB 4854-IA - - Nil 500 1.01 & 1.02 Multiple - CSB 4832-IA Nil 400 1.11,1.12 & 1.13 Multiple - CSB 4881-IA - - Nil 600 (No Suggestions) File 200500215 • • Client: ConacoPhillips Well: 3J-101 Insta{lation: - Field: West Sak Sand: B & D Job #: 200500215 Table 4: Reservoir fluid Properties Schlumberger Zero flash Saturation Molar Mass of Monophasic Sample ID Cy{finder # Depth GOR* Bo** Pressure monophasic fluid**~ at Tres fluid contamination (ft- (scf/stb- (psia} % -w/w) 1.04 CSB 8629-QA 5,697 88 325.9 - 1.08 CSB 14309-QA 5,697 95 318.5 - 1.09 SSB 18528-OA 5,697 83 336.5 - 1.10 SSB 18136-4A 5,697 92 320.9 - 1.14 CSB 14308-OA 5,553 87 326.5 - 1.18 CSB 14311-DA 5,553 7fi 346.4 - 1.19 SSB 18539-QA 5,553 76 350.2 - 1.20 SSB 18530-OA 5,553 75 344.3 - 1.01 & 1.02 CSB 4854-1A 5,697 91 320.1 1.7 1.01 & 1.02 CSB 4832-IA 5,697 158 1.035 1304 263.7 - 1.11, 1.12 & 1.13 CSB 4881-IA 5,553 156 1.041 t 1574 $ 275.3 - * Flashed gas volume (scfl per barrel of stock tank liquid Q 60°f. ** Volume of live oil at bubble point pressure, per unit equivalent volume of flashed stock tank liquid C~3 60°F. *** Refers to contamination by demulsifier. Calculated from contamination level in STO determined from compositional analysis. t Based on predicted saturation pressure at reservoir temperature. $ Bubble point at measurement temperature at 100°F. Pb at 72°F, prior to recombination with synthetic gas, was 440 psia. {No Suggestioas- t2 File 200500215 • Client: ConocoPhillips Well: 3J-101 Installation: - Field: West Sak Sand; B & D Job #: 200500215 Table 5: Stock-Tank Oil Properties Schiumberger STO Properties Sample ID Cylinder # Depth Molar Mass Density API* Contamination (ftl l9/cc) % lw/wl 1.04 CSB 8629-QA 5,697 414.2 0.9548 16.7 - 1.08 CSB 14309-QA 5,697 411.1 0.9585 16.1 - 1.09 SSB 18528-DA 5,697 424.9 0.9599 15.9 - 1.10 SSB 18136-QA 5,697 412.6 0.9513 17.2 - 1.14 CSB 14308-QA 5,553 413.5 0.9594 16.0 - 1.18 CSB 14311-QA 5,553 430.4 0.9622 15.6 - 1.19 SSB 18539-DA 5,553 436.0 0.9682 14.6 - 1.20 SSB 18530-DA 5,553 425.6 0.9645 15.2 - 1.01 & 1.02 CSB 4854-IA 5,697 409.6 0.9515 17.2 1.7 1.01 & 1.02 CSB 4832-1A 5,697 392.6 0.9503 17.4 - 1.11, 1.12 & 1.13 CSB 4881-IA 5,553 402.5 0.9581 16.2 - API =141.5/Density -131.5. • • (No Suggestions) 13 File 200500215 Client: ConocoPhillips field: West Sak Schfumberger Well: 3J-101 Sand: B Sand • Table 6: C30+ Composition, GOR, °API, by Zero-Flash Sample 1.04) Sample 1.04; Cylinder CSB 8629-QA; Depth 5697.1 ft. MD • Component MW Flashed Gas Flashed Liquid Monophasic Fluid Igimofel WT % MOLE °I° WT % MOLE % WT % MOLE Carbon Dioxide 44.01 7.08 2.82 0.00 0.00 0.08 0.63 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.89 1.18 0.00 0.00 0.02 0.26 Methane 16.04 86.44 94.35 0.00 0.00 1.03 21.00 Ethane 30.07 1.06 0.62 0.00 0.00 0.01 0.14 Propane 44.10 0.91 0.36 0.01 0.13 0.02 0.18 -Butane 58.12 0.81 0.24 0.02 0.11 D.D2 0.14 N -Butane 58.12 0.45 0.14 0.01 0.08 0.02 0.09 I -Pentane 72.15 0.58 0.14 0.04 O.ZD 0.04 0.19 N -Pentane 72.15 0.12 O.D3 0.01 0.04 0.01 0.04 C6 84.00 0.28 0.06 O.DB 0.38 0.06 0.31 M-C-Pentane 84.16 0.03 0.01 0.00 0.02 0.00 0.02 Benzene 78.11 0.01 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.1fi 0.01 0.00 0.00 0.02 0.00 0.02 C7 96.00 0.11 0.02 0.15 0.63 0.15 0.50 M-C-Hexane 98.19 0.03 0.01 0.00 0.02 O.OD 0.02 ToVuene 92.14 O.D2 0.00 0.00 0.01 0.00 0.01 C8 107.00 0.09 0.01 0.15 0.56 0.15 0.44 E-Benzene 106.17 0.01 0.00 0.00 0.02 0.00 0.01 M/P-Xylene 106.17 0.01 0.00 0.00 0.01 0.00 0.00 0-Xylene 106.17 0.00 0.00 0.00 0.02 0.00 0.01 C9 121.00 D.O6 0.01 0.30 1.01 0.29 0.79 C10 134.00 0.04 0.01 0.56 1.74 0.56 1.36 C11 147.00 0.01 0.00 0.92 2.60 0.91 2.02 C12 161.00 O.DO 0.00 1.39 3.57 1.37 2.78 C13 175.00 0.00 0.00 1.92 4.54 1.90 3.53 C14 190.00 0.00 0.00 223 4.86 2.20 3.78 C15 206.00 0.00 O.DO 2.62 5.27 2.59 4.10 C16 222.00 2.55 4.75 2.51 3.69 C17 237.00 2.64 4.62 2.61 3.59 C 18 251.00 2.75 4.53 2.71 3.52 C19 263.00 2.68 422 2.65 3.28 C2D 275.00 2.58 3.88 2.55 3.02 C21 291.00 2.fi1 3.71 2.58 2.88 C22 300.00 2.42 3.34 2.39 2.60 C23 312.00 2.25 2.99 2.23 2.33 C24 324 2.05 2.62 2.02 2.04 C25 337.00 1.93 2.37 1.91 1.84 C26 349.00 1.86 2.21 1.84 1.71 C27 360.00 1.90 2.18 1.88 1.70 C28 372.00 1.B5 2.06 1.83 1.60 C29 382.00 1.66 1.82 1.66 1.42 C30 394.00 1.73 1.82 1.71 1.42 C31 404.00 1.53 1.57 1.52 1.22 C32 415.00 1.44 1.44 1.42 1.12 C33 426.00 1.26 1.23 1.25 0.95 C34 437.00 1.24 1.17 1.22 0.91 C35 445.00 0.89 0.83 0.88 0.65 C36+ 992.00 49.74 20.77 49.15 16.15 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.51 414.20 325.92 MOLE RAT{0 0.2225 0.7775 Ollphase-DBR 14 File 200500215 r~ • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Tahle 7; Calculated Fluid Properties Schlumberger Sample 1.U4; Uylmder L;S~ df;'Ly-uA; Ueptn 5byi.l Ti. IVIU Properties Flashed Gas Flashed Liquid Monophasic fluid Cn+ Composition Mass % Mole °1o Mass % Male % Mass % Mole C7+ 0.40 0.07 99.84 99.06 98.65 77.03 C12+ 0.00 0.00 97.74 92.39 96.57 71.83 C20+ - - 78.97 56.02 78.02 43.55 C30+ - - 57.84 28.83 57.15 22.41 C36+ - - 49.74 20.77 49.15 16.15 Molar Mass C7+ 103.85 417.45 417.39 C 12+ 166.86 438.18 438.18 C20+ - 583.84 583.84 C30+ - 830.99 830.99 C36+ - 992.00 992.00 Density C7+ - 0.9556 - C12+ - 0.9604 0.9604 C20+ - 0.9945 0.9945 C30+ 1.0421 1.0421 C36+ 1.0659 1.0659 Fluid at 60°F 0.9548 Gas Gravity (Air =1) 0.605 Dry Gross Heat Content (BTU/scf) 1,001 Wet Gross Heat Content (BTU/scf) 983 OBM Contamination Level Iwt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 414.20 414.20 992.00 Density 19/cm3) 0.9548 - 1.0659 Single Stage Ftash Data Original STO De-Contaminated GOR (scf/stb) 66 - STO Density (g/cm3) 0.9548 - STOAPI Gravity 16.7 - OBM Density 19Jcm3) Q60°F - Ollphase-DBR 15 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand • Figure 1: Stock Tank Oil Chromatogram lSample 1.04) Samnla 1 f14~ Cvlinder CSR 8629-QA: Depth 5697.1 ft. MD FID1 A, (E: IHPOHEMI2''+DAtAV105002151CY88Z9.D) Noim. 2~0 JOB 200500215 CONOCO PHILIPS 1.04 CSB 8629-QA RF FLASH CYLINDER 200 150 100 61 ~ 1~0761Q- ~ NNNNry ~ ~ o c ,~ N~ NN;VfrX~l U1 (9 ~ ~ f N c c cc~ ~~ W a ~, ~ U cC C U U ~~ C C c o~, ~ X U U U c c C ~ ~~ I I,; ~ C i ~ I~ , b i ' C ~ C o C sl 1 i ; ; 4 ( Ij ~ ~„ f' ji i; ~ ~i ;ii 'i s I~ ~ i "i~ i I ~, ~ 0 0 5 10 15 20 25 30 35 mi • Figure 2: k-Plot for tquulurlum ~necK ~~ample ~.u4~ Sample 1.04; Cylinder CSB 8629-QA; Depth 5697.1 ft. MD Schlumberger z 1.5 1 D.5 o. '~ 0 rn J -0.5 -1 -1.5 -Z -4 -3 -2 -1 0 1 2 3 F ~ ' Ollphase-DBR 16 File 200500215 - _ _-- ~dCA-- ~ C3----------------- -_ ._ __ _._ ---- - __ _- ___ _ __ ~ -i n {{ I ~~`~-5------ - ~ _ • C6 -- -- --- --- - • C8 • C7 -- ----- ----- - _ ~ C9 • C10 -,-~ • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 8: C30+ Composition, GOR, °API, by Zera-Flash (Sample 1.08) Samp{e 1.08; Cy{inder CS814309-QA; Depth 5697.1 ft. MD Schlumberger Component MW Flashed Gas Flashed Liquid ManOphasic Fluid 19/mole) WT % MOLE °!° WT % MOLE % WT °/° MOLE Carbon Dioxide 44.01 1.62 0.62 0.00 0.00 0.02 0.15 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.34 0.81 0.00 0.00 0.02 0.19 Methane 16.04 91.58 96.72 0.00 0.00 1.14 22.72 Ethane 30.07 1.12 D.63 0.00 0.00 0.01 0.15 Propane 44.10 1.05 0.40 0.01 0.09 0.02 0.16 I -Butane 58.12 1.00 D29 0.01 0.09 0.02 0.13 N -Butane 58.12 0.55 0.16 0.01 0.07 0.02 0.09 I -Pentane 72.15 0.71 0.17 0.04 0.20 0.04 0.19 N -Pentane 72.15 0.16 0.04 0.01 0.04 0.01 D.D4 C6 B4.08 0.35 0.07 0.06 0.31 0.07 0.26 M-C-Pentane 84.16 0.04 0.01 0.00 0.02 0.00 0.01 Benzene 76.11 D.Ot 0.00 0.00 D.01 0.00 0.01 Cyclohexane 84.16 0.01 0.00 0.00 0.02 0.00 0.02 C7 96.00 0.16 0.03 0.12 0.52 0.12 0.40 M-C-Hexane 98.19 0.03 0.01 0.01 0.02 0.01 0.02 To{uene 92.14 0.03 0.01 O.DO 0.01 0.00 0.01 C8 107.00 0.12 O.OZ 0.18 0.69 0.18 0.53 E-Benzene 106.17 0.01 0.00 0.01 0.02 0.01 0.02 M/P-Xylene 106.17 0.01 0.00 0.00 O.D2 0.00 0.01 0-Xylene 106.17 0.00 O.DO D.01 0.02 0.01 0.02 C9 121.00 0.06 0.01 0.31 1.04 D.30 0.80 C10 134.00 0.05 0.01 0.59 1.81 0.58 1.38 C11 147.00 D.61 0.00 0.95 2.65 0.93 2.02 C12 161.00 0.00 0.00 1.41 3.59 1.39 2.75 C13 175.00 D.00 D.00 1.93 4.52 1.90 3.46 C 14 190.00 0.00 0.00 2.16 4.68 2.14 3.58 C15 206.00 0.00 0.00 2.68 5.35 2.65 4.10 C16 222.00 2.58 4.78 2.55 3.66 C17 237.00 2.71 4.70 2.68 3.60 G18 251.00 2.65 4.35 2.62 3.33 C19 263.00 2.67 4.17 2.64 3.19 C20 275.00 2.58 3.65 2.55 2.95 C21 291.00 2.50 3.53 2.41 2.70 C22 300.00 2.40 3.28 2.37 2.51 C23 312.00 2.16 2.84 2.13 2.18 C24 324.00 2.19 2.78 2.16 2.13 C25 337.00 2.04 2.49 2.02 1.91 C26 349.00 2.05 2.41 2.02 1.84 C27 360.00 1.99 2.27 1.96 1,74 C28 372.00 1.79 1.98 1.77 1.51 C29 382.00 1.77 7.91 1.75 1.46 C30 394.00 1.72 1.80 1.70 1.38 C31 404.00 1.63 1.65 1.61 1.27 C32 415.00 1.44 1.43 1.42 1.09 C33 426.00 1.29 1.24 1.27 0.95 C34 437.00 1.24 1.16 1.22 0.89 C35 445.00 1.09 1.01 1.08 0.77 C36+ 980.00 49.02 20.56 48.41 15.73 Total 100.00 10D.00 100.00 100.00 100.00 100.00 MW 16.94 411.11 318.50 MOLE RATIO 0.2349 0.7651 Ollphase-DSR 17 File 200500215 • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: 8 Sand Table 9: Calculated Fluid Properties Sample 1.08; Cviinder CSB 14309-QA; Depth 5697.1 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass °lo Mole °1° Mass % Mole °1° Mass °1° Mo4e C7+ 0.53 0.09 99.86 99,20 98.62 75.92 C 1 Z+ 0.00 0.00 97.69 92.37 96.47 70.67 C20+ - - 78.89 56.21 77.91 43.01 C30+ - - 57.43 28.86 56.71 22.08 C36+ - - 49.02 20.56 48.41 15.73 Molar Mass C7+ 102.91 413.84 413.75 C 12+ 165.02 434.80 434.80 C20+ - 576.99 576.99 C30+ - 818.03 818.03 C36+ - 980.00 980.D0 Density C7+ - 0.9592 - C12+ - 0.9643 0.9643 C20+ - 0.9997 0.9997 C30+ 1.0510 1.0510 C36+ 1.0780 1.0780 Fluid at 60°F D.9585 Gas Gravity (Air =1 } D.585 Dry Gross Heat Content (BTU/scf) 1,031 Wet Gross Neat Content (B7U/scf) 1,D13 OBM Contamination level (vut°Jo1 - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 411.11 411.11 980.00 Density 1g/cm3} 0.9585 - 1.0780 Single Stage Flash Data Original STD De-Contaminated GOR (scf/stbl 95 - STO Density ig/cm3) 0.9585 - STO APi Gravity 16.1 - OBM Density (g/cm3} Q60°F - Ollphase-DBR 18 Fite 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand • Figure 3: Stock Tank Oil Chromatogram (Sample 1.08) Sample 1.08: Cvlinder CSB 14309-QA; Depth 5697.1 ft. MD f ID1 A, (E:IHPCHEM1216ATA~A05002151C`(14309.Dj Norm. 250 JOB 200500215 CONOCO PHILIPS 1.08 CSB 14309-QA RF FLASH CYLINDER 200 150 100 50 U ~ ~ C ~0 ~N(0vU7t~0 Imtf1 N~ ~ O 0 ~ ~ N ~ i[~ ~N NNNNN(V.N CC " CC U ~ Q1 U U r ~ U ~ CC CC C C CC CCC~C ~ c ~ ~, U c U U C C c , , ~ y ~ I U c C ~. .'}+rd Itl C c ~ ~~ ~i w.W~01.'S'T1~~.1 I~, l,'f i,I' ,,1 i! ;i II ~~ I ~1Y1W.~- '~~~1"~-ru D 0 5 10 15 20 25 30 35 mi 7 Figure 4: k-Plot for Equilibrium GhecK iSample ~.uts- Sample 1.08; Cylinder CSB 14309-QA; Depth 5697.1 ft. MD • 2 1.5 1 a 0.5 x a o O J -0.5 -1 -1.5 -4 -3 -2 -1 0 1 2 3 F • C3 • iC4 _ _ ~ ~C4 ~ ~Ct~5 -- ~ 1- ---- -- _ _ -------- -- - - --- -- -- -- ~-C7--- --- -- --- -- • C8 i • C9 _ 1 • C10 Ollphase-DBR 19 File 200500215 • L • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 10: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.09) Sample 1.09; Cylinder SSB 18528-QA; Depth 5697.1 ft. MD Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/moles WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.62 0.23 0.00 0.00 0.01 0.05 Hydrogen Sulfide 34.08 0.00 0.00 0.00 O.DO 0.00 0.00 Nitrogen ZB.O1 1.68 0.98 0.00 0.00 0.02 0.21 Methane 16.04 95.61 97.96 0.00 0.00 1.01 21.20 Ethane 30.07 0.85 0.46 0.00 0.00 0.01 0.10 Propane 44.10 0.46 0.17 0.02 0.16 0.02 0.16 I -Butane 58.12 0.30 0.09 0.02 0.14 0.02 0.13 N -Butane 58.12 0.13 0.04 0.01 0.10 0.01 0.08 I -Pentane 72.15 0.11 0.03 0.04 0.24 0.04 0.19 N -Pentane 72.15 0.03 D.Ot 0.01 0.05 0.01 0.04 C6 84.00 0.05 0.01 0.07 0.33 0.07 0.26 M-C-Pentane 84.16 0.01 0.00 0.00 0.02 0.00 0.02 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.03 0.00 0.02 C7 96.00 0.02 0.00 0.18 0.76 0.18 0.61 M-C-Hexane 98.19 0.02 0.00 0.01 0.03 0.01 0.02 Toluene 92.14 0.01 0.00 0.00 0.02 0.00 0.01 C8 107.00 0.03 0.01 0.15 0.58 0.14 0.45 E-Benzene 106.17 0.00 0.00 0.00 0.02 0.00 0.02 M/P-Xylene 0-Xylene Cg 106.17 106.17 121.00 0.01 0.00 0.03 0.00 0.00 0.00 0.00 0.01 0.28 0.01 0.02 0.99 0.00 0.01 0.28 0.01 0.02 0.78 C10 134.00 0.02 0.00 0.54 1.72 0.54 1.35 Clt 147.00 0.00 0.00 0.67 2.51 0.86 1.97 C12 161.00 0.00 0.00 1.33 3.50 1.31 2.74 C13 175.00 0.00 0.00 1.83 4.44 1.81 3.48 C14 190.00 0.00 0.00 2.07 4.62 2.05 3.62 C15 206.00 0.00 0.00 2.56 5.28 2.53 4.14 Cl6 222.00 2.43 4.65 2.40 3.64 C17 237.00 2.51 4.50 2.49 3.53 C18 251.00 2.62 4.44 2.59 3.48 C19 263.00 2.58 4.17 2.55 3.26 C20 275.00 2.44 3.76 2.41 2.95 C21 291.00 2.49 3.63 2.46 2.65 C22 300.00 2.30 3.26 2.28 2.55 C23 312.00 2.26 3.08 2.24 2.42 C24 324.00 2.21 2.90 2.19 2.27 C25 337.00 1.60 2.27 1.78 1.76 C26 349.00 1.78 2.17 1.76 1.70 C27 360.00 1.79 2.11 1.77 1.65 C28 372.00 1.77 2.02 1.75 1.59 C29 382.00 1.75 1.95 1.73 1.53 C30 394.00 1.61 1.74 1.60 1.36 C31 404.00 1.45 1.53 1.43 1.20 C32 415.00 1.39 1.42 1.38 1.12 C33 426.00 1.33 1.33 1.32 1.04 C34 437.00 1.19 1.16 1.18 0.91 C35 445.00 1.21 1.15 t.i9 0.90 C36+ 1024.90 51.10 21.19 50.56 16.60 Total 100.00 100.00 100.00 100.00 100.00 100.00 M W 16.44 424.94 336.55 MOLE RATIO 0.2164 0.7836 Ollphase-DBR File 200500215 • Client. ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 11: Calculated Fluid Properties Sample 1.09: Cylinder SSB 18528-QA; Depth 5697.1 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass °(° Mole % Mass % Mole % Mass % Mole C7+ 0.16 0.03 99.84 98.98 98.78 77.57 C12+ 0.00 0.00 97.79 92.26 96.76 72.30 C20+ - - 79.87 56.67 79.03 44.41 C30+ - - 59.29 29.52 58.66 23.13 C36+ - - 51.10 21.19 50.56 16.60 Molar Mass C7+ 106.63 428.62 428.60 C12+ 164.65 450.40 450.40 C20+ - 598.93 598.93 C30+ - 853.55 853.55 C36+ - 1024.90 1024.90 Density C7+ - 0.9608 - C12+ - 0.9657 0.9657 C20+ - 0.9994 0.9994 C30+ 1.0468 1.0468 C36+ 1.0710 1.0710 Fluid at 60°F 0.9599 Gas Gravity (Air =1 ~ 0.568 Dry Gross Heat Content IBTU/scf) 1,011 Wet Gross Heat Content IBTU/scf) 994 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 424.94 424.94 1024.90 Density Ig/cm3) 0.9599 - 1.0710 Single Stage Flash Data Original STO De-Contaminated GOR Iscf/stb) 83 - STO Density (g/cm3) 0.9599 - STO API Gravity 15.9 - OBM Density Ig/cm3) C~36D°F - Ollphase-DBR 21 File 200500215 • Client: ConocoPhillips Field: West Sak Wetl: 3J-101 Sand: B Sand Figure 5: Stock Tank Oil Chromatogram (Sample 1.09) Sample 1.09; Cylinder SSB 18528-QA; Depth 5697.1 ft. MD PID1 A, (E; IHPCHEMt2lDATA~06002161CY1&62e.D) Norm, 260 JOB 200500215 CONOCO PHILIPS 200 1.09 SSB 18528-QA RF FLASH CYLINDER 160 100 (~9 U o1 N O O O ~ N frl~t ~fitD~CONry~7 NN 60 i ~ ~ C ~ In l9 ~ r ~ N N N NN NN OT (~1 ~ N m ~ ~ U U U U U UU UUUU~~J ~ C U CCCCCC ~ },61 ~ ~ ° U U U ~ C C C C C CC CCCC ~, I~ 0] U U C c u~ v U XU U c c ~ ~ ~ i ~~ i I ~,'~ I. ~ ~; t, 0 0 6 10 15 20 26 30 36 mi Schlumberger Figure 6: k-Plot for Equilibrium Check (Sample 1.09) Sample 1.09; Cylinder SSB 18528-QA; Depth 5697.1 ft. MD • 1.5 • C3 1 ----- -- -- ---- - -_ ~ i C4------- • nC4 -- 0.5 - --- - --- •'iCr~5 c Y O Q! __- - ~ I • C6 -0.5 ~ - -- ------- • C8 • C7 -1 - -- ~ C9 -1.5 -4 -3 -2 -1 0 1 2 3 F Ollphase-DBR 22 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand Table 12: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.10) Sample 1.10; Cylinder SSB 18136-QA; Depth 5697.1 ft. MD ~~ • Component MW Flashed Gas Flashed Liquid Monophasic Fluid Ig/motel WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.48 0.18 0.00 0.00 0.01 0.04 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.83 1.07 0.00 0.00 0.02 0.25 Methane 16.04 95.80 97.98 0.00 0.00 1.13 22.67 Ethane 30.07 0.82 0.45 0.00 0.00 0.01 0.10 Propane 44.10 0.44 0.16 0.02 0.16 0.02 0.16 I -Butane 58.12 0.29 0.08 0.02 0.13 0.02 0.12 N -Butane 58.12 0.12 0.03 0.01 0.10 0.01 0.08 I -Pentane 72.15 0.10 O.D2 0.04 0.22 0.04 0.18 N -Pentane 72.15 0.03 O.D1 0.01 0.06 0.01 0.05 C6 84.00 0.04 0.01 0.10 0.50 0.10 0.39 M-C-Pentane 84.16 0.00 0.00 0.00 0.02 0.00 0.02 Benzene 78.11 0.00 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.00 0.00 0.01 0.03 0.01 0.02 C7 96.00 0.02 0.00 0.16 0.78 0.18 0.60 M-C-Hexane 98.19 0.00 0.00 0.01 0.03 0.01 0.02 Toluene 92.14 0.00 0.00 0.00 0.01 O.DO 0.01 CB 107.00 0.01 0.00 0.16 0.61 0.16 0.47 E-Benzene 106.17 0.00 0.00 0.00 0.02 0.00 0.01 M/P-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 0-Xylene 106.17 0.00 0.00 0.01 0.03 0.01 0.02 C9 121.00 0.01 0.00 0.30 1.02 0.30 0.79 C10 134.00 0.00 0.00 0.57 1.77 0.57 1.36 C11 147.00 0.00 0.00 0.94 2.64 0.93 2.03 C12 161.00 0.00 0.00 1.40 3.59 1.39 2.76 C13 175.00 0.00 0.00 1.94 4.56 1.91 3.51 C14 190.00 0.00 0.00 2.18 4.74 2.16 3.64 C15 206.00 0.00 0.00 2.71 5.43 2.68 4.17 Cl6 222.00 2.77 5.15 2.74 3.96 C17 237.00 2.56 4.45 2.53 3.42 C18 251.00 2.66 4.37 2.63 3.36 C19 263.00 2.70 4.24 2.67 3.26 C20 275.00 2.55 3.83 2.52 2.94 C21 291.00 2.57 3.64 2.53 2.80 C22 300.00 2.44 3.36 2.41 2.58 C23 312.00 2.30 3.04 2.27 2.33 C24 324.00 2.13 2.71 2.10 2.08 C25 337.00 2.05 2.51 2.03 1.93 C26 349.00 2.01 2.38 1.99 1.83 C27 360.00 1.65 1.89 1.63 1.45 C26 372.00 1.90 2.11 1.88 1.62 C29 382.00 1.95 2.11 1.93 1.62 C30 394.00 1.40 1.47 1.38 1.13 C31 404.00 1.63 1.67 1.61 1.28 C32 415.00 1.17 1.16 1.15 0.89 C33 426.00 1.24 1.20 1.23 0.92 C34 437.00 1.17 1.10 1.16 0.85 C35 445.00 0.16 0.15 0.16 0.11 C36+ 989.70 50.37 21.00 49.77 16.14 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.41 412.59 320.90 MOLE RATIO 0.2314 0.7686 Ollphase-DBR v,~, File 200500215 • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 13: Calculated Fluid Properties Sample 1.10: Cylinder SSB 18136-QA; Depth 5697.1 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Male % Mass % Mole % Mass % Mole C7+ 0.05 0.01 99.80 98.84 98.62 75.96 C12+ 0.00 0.00 97.61 91.85 96.45 70.59 C20+ - - 78.69 55.31 77.76 42.51 C30+ - - 57.14 27.75 56.46 21.33 C36+ - - 50.37 21.00 49.77 16.14 Molar Mass C7+ 105.31 416.62 416.61 C12+ 168.00 438.45 438.45 C20+ - 586.96 586.96 C30+ - 849.65 849.65 C36+ - 989.70 989.70 Density C7+ - 0.9523 - C12+ - 0.9573 0.9573 C20+ - 0.9907 0.9907 C30+ 1.0379 1.0379 C36+ 1.0571 1.0571 Fluid at 60°F 0.9513 Gas Gravity (Air =1) 0.566 Dry Gross Neat Content (BTU/scf- 1,009 Wet Gross Heat Content IBTU/scf) 992 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 412.59 412.59 989.70 Density (g/cm3) 0.9513 - 1.0571 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 92 - STODensity (g/cm3) 0.9513 - STO APi Gravity 17.2 - OBM Density (g/cm3) C~60°F - 0(Iphase-DBR 24 File 200500215 • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand; B Sand Figure 7: Stock Tank Oil Chromatogram (Sample 1.10) Sample 1.10: Cvlinder SSB 18136-QA; Depth 5697.1 ft. MD FID1 A, (E: IHPGHEMI2iDATA1005002151CY18136,D~ Norm. 250 200 JOB 200500215 CONOCO PHILIPS 1.10 SSB 18136-QA RF FLASH CYLINDER 150 100 u1 m czo ~ ~, ~ m o o ~ N m a~oho~ 5O Q o C ~ l0 (9 ~ ~ ~ N N N N NNNNN UO U ~ e. ~ ~ U (~ ~C ~ CCW C ~ O CCCCCCC C U C ~u ~~ o] ~ ~ ~ ~ U C C uy,Cu ~ XU U U C ~ ~; ,I ii ; !j ;i ~ I;I;~i C C "" i I c~ C o ~ ~ i ~ 'I~~illi' !I l ili ~ Ili i a 0 5 10 15 20 25 30 35 mi Schlumberger Figure 8: k-Plot for Equilibrium Check (Sample 1.10) Sample 1.10; Cylinder SSB 18136-QA; Depth 5697.1 ft. MD • I i 1.5 • C3 - 1 - ii. • nC4 Y 0.5 t ----- -------- - • sC~S o i J O _ _-_ -____ -__ ___.- t -0.5 • C6 -1 i -4 -3 -2 -1 0 1 2 3 F Ollphase-DBR 25 File 200500215 • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 14: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.14- Sample 1.14; Cylinder CSB 14308-QA; Depth 5553 ft. MD Schlumherger Component MW Flashed Gas Flashed Liquid Monophasic Fluid ~g/male) WT % MOLE % WT °(° MOLE °(° WT % MOLE Carbon Dioxide 44.01 4.62 1.77 0.00 0.00 0.05 0.39 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 26.01 1.73 1.04 0.00 0.00 0.02 0.23 Methane 16.04 91.81 96.50 0.00 0.00 1.04 21.15 Ethane 30.07 0.82 0.46 0.00 0.00 0.01 0.10 Propane 44.10 0.17 0.07 0.01 0.08 0.01 0.08 I -Butane 56.12 0.11 0.03 0.00 0.02 0.00 0.02 N -Butane 58.12 0.05 0.01 0.00 0.00 0.00 0.01 I -Pentane 72.15 0.03 0.01 0.00 0.01 0.00 0.01 N -Pentane 72.15 0.05 0.01 0.00 0.01 0.00 0.01 C6 84.00 0.06 0.01 0.01 0.03 0.01 0.02 M-C-Pentane 84.16 0.03 0.01 0.00 0.00 0.00 0.00 Benzene 78.11 0.01 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.01 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.07 0.01 0.10 0.41 0.09 0.32 M-C-Hexane 98.19 0.05 0.01 0.00 0.00 0.00 0.00 Toluene 92.14 0.03 0.01 0.00 0.00 0.00 0.00 C8 107.00 0.1 D 0.02 0.00 0.00 0.00 0.00 E-Benzene 106.17 0.01 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 O.D2 0.00 0.00 0.00 0.00 0.00 0-Xylene 106.17 0.01 0.00 0.00 0.00 0.00 0.00 C9 121.00 0.10 0.01 0.00 0.00 0.00 0.00 C10 134.00 0.08 0.01 0.03 0.10 0.03 0.08 C11 147.00 0.01 0.00 0.32 0.91 0.32 0.71 C12 161.00 0.00 0.00 0.81 2.07 0.60 1.62 C13 175.00 0.00 0.00 1.68 3.97 1.66 3.10 C14 190.00 0.00 0.00 2.02 4.40 2.00 3.43 C15 206.00 0.00 0.00 2.49 4.99 2.46 3.90 C16 222.00 2.63 4.91 2.60 3.83 C17 237.00 2.74 4.78 2.71 3.73 C18 251.00 2.89 4.76 2.85 3.71 C19 263.00 3.07 4.63 3.04 3.77 C20 275.00 2.94 4.42 2.91 3.45 C21 291.00 2.95 4.20 2.92 3.26 C22 300.00 2.88 3.97 2.85 3.10 C23 312.00 2.86 3.79 2.83 2.96 C24 324.00 2.80 3.57 2.77 2.79 C25 337.00 2.75 3.38 2.72 2.64 C26 349.00 2.70 3.20 2.67 2.50 C27 360.00 2.67 3.07 2.64 2.39 C26 372.00 2.59 2.88 2.56 2.25 C29 362.00 2.50 2.70 2.47 2.11 C30 394.00 2.29 Z.40 2.26 1.88 C31 404.00 2.15 2.20 2.13 1.72 C3Z 415.00 2.07 2.06 2.05 1.61 C33 426.00 1.87 1.81 1.85 1.42 C34 437.00 1.73 1.64 1.71 1.28 C35 445.00 1.66 1.54 1.64 1.20 C36+ 1023.00 41.78 16.89 41.31 13.19 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.86 413.46 326.54 MOLE RATIO 0.2191 0.7809 Ollphase-DBR 26 file 200500215 • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 15: Calculated Fluid Properties Sample 1.14; Cylinder CSB 14308-OA; Depth 5553 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Move °lo Mass % Mole % Mass % Mole C7+ 0.54 0.09 99.98 99.85 98.85 77.99 C12+ 0.00 0.00 99.53 98.43 98.40 76.86 C20+ - - 81.20 63.72 80.28 49.76 C30+ - - 53.55 28.55 52.95 22.29 C36+ - - 41.78 16.89 41.31 13.19 Molar Mass C7+ 106.64 413.99 413.92 C 12+ 164.83 418.07 418.07 C20+ - 526.83 526.83 C30+ - 775.61 775.61 C36+ - 1023.00 1023.00 Density C7+ - 0.9595 - C12+ - 0.9606 0.9606 C20+ - 0.9922 0.9922 C30+ 1.0585 1.0585 C36+ 1.1065 1.1065 Fluid at 60°F 0.9594 Gas Gravity (Air =1) 0.582 Dry Grass Heat Content (BTU/scf) 994 Wet Gross Heat Content (BTU/scf) 977 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties M W 413.46 413.46 1023.00 Density (g/cm3) 0.9594 - 1.1065 Single Stage Flash Data Original STO De-Contaminated GOH (scf/stb) 87 - STO Density 19/cm3) 0.9594 - STOAPI Gravity 16.0 - OBM Density (g/cm3) Q60°F - Ollphase-DBR 17 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand Figure 9: Stock Tank Oil Chromatogram (Sample 1.14) Sample 1.14; Cylinder CSB 14308-QA; Depth 5553 ft. MD fID1A, (E:IHPCHEMl2tDATAVJ05002151CY14308.D} Norm. JOB 200500215 CONOCO PHILIPS 1.14 CSB 14308-QA 250 RF FLASH CYLINDER 200 150 100 61 O ~ N (ti-!'C~ f9h076~t1 50 ~ N CO ~~< N N N N NN NNN ~ ~' ~ N ~ ~ U U U U C C C C C C~ CW~C ~ U U ~ ~ ~ U Cc a ~~Cirtrtr'F*tr 'i~~ I ; ! ~ j ~ '. a : ~ !! ! I ' I i 0 0 5 10 /5 20 25 30 35 mi Figure 10: k-Plot for Equilibrium Check (Sample 1.14) Sample 1.14; Cylinder CSB 14308-QA; Depth 5553 ft. MD 2 • nC4 • C3 - ----~-iC5------- - °- • C6 o~ J 0.5 ~ - ----- - ----- - - - • C10 ~ 0 • 7 -0.5 ~-~ ' -4 -3 -2 -1 0 1 2 3 F Oltphase-DBR 28 File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 16: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.18) Sample 1.18; Cylinder CSB 14311-QA; Depth 5553 ft. MD Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 2.84 1.07 0.00 0.00 0.03 0.22 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 2.11 1.25 0.00 0.00 0.02 0.25 Methane 16.04 94.25 97.31 0.00 0.00 0.91 19.75 Ethane 30.07 0.60 0.33 0.00 0.00 0.01 0.07 Propane 44.10 0.06 0.02 0.01 0.06 0.01 0.07 I -Butane 58.12 0.04 0.01 0.00 0.03 0.00 0.02 N -Butane 58.12 0.00 0.00 0.00 0.00 0.00 0.00 I -Pentane 72.15 0.00 0.00 0.00 0.02 0.00 0.01 N -Pentane 72.15 0.01 0.00 0.01 0.04 0.01 0.03 C6 64.00 0.01 0.00 0.07 0.36 0.07 0.29 M-C-Pentane 84.16 0.00 0.00 0.01 0.03 0.01 0.03 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.02 0.00 0.09 0.39 0.09 0.31 M-C-Hexane 98.19 0.00 0.00 0.00 0.00 0.00 0.00 Toluene 92.14 0.00 0.00 0.00 0.00 0.00 0.00 CS 107.00 0.01 0.00 0.00 0.00 0.00 0.00 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 0-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 C9 121.00 0.01 0.00 0.00 0.00 0.00 0.00 C10 134.00 0.02 0.00 0.01 0.03 0.01 0.02 C11 147.00 0.01 0.00 0.30 0.89 0.30 0.71 C12 161.00 0.00 0.00 0.77 2.06 0.76 1.65 C13 175.00 0.00 0.00 1.46 3.60 1.45 2.87 C14 190.00 0.00 0.00 2.01 4.55 1.99 3.62 C15 206.00 0.00 0.00 2.24 4.69 2.22 3.74 C16 222.00 2.44 4.73 2.41 3.77 C17 237.00 2.69 4.89 2.67 3.90 C18 251.00 2.73 4.68 Z.70 3.73 C19 263.00 2.73 4.47 2.71 3.57 C20 275.00 2.85 4.46 2.82 3.56 CZ1 291.00 2.77 4.09 2.74 3.26 C22 300.00 2.73 3.91 2.70 3.12 C23 312.00 2.68 3.69 2.65 2.94 C24 324.00 Z.61 3.46 2.58 2.76 C25 337.00 2.64 3.37 Z.61 2.69 C26 349.00 2.52 3.10 Z.49 2.47 C27 360.00 2.54 3.03 2.51 2.42 C28 372.00 2.42 2.80 2.40 2.23 C29 382.00 2.40 2.71 2.38 2.16 C30 394.00 1.92 2.10 1.90 1.67 C31 404.00 1.87 1.99 1.85 1.59 C32 415.00 1.68 1.95 1.66 1.56 C33 426.00 1.92 1.94 1.90 1.55 C34 437.00 1.70 1.67 1.66 1.33 C35 445.00 1.44 1.39 1.43 1.11 C36+ 1045.00 45.53 18.75 45.08 14.94 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.56 430.40 346.39 MOLE RATIO 0.2030 0.7970 Ollphase-DBR 29 File 200500215 • • r~ ~. Client: ConocoPhitlips Field: West Sak Well: 3J-101 Sand: D Sand Table 17: Calculated Fluid Properties Sample 1.18; Cylinder CSB 14311-QA; Depth 5553 ft. MD Schlumberger Properties flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.08 0.01 99.91 99.48 98.94 79.28 C12+ 0.00 0.00 99.50 98.13 98.53 78.21 C20+ - - 82.41 64.45 81.61 51.37 C30+ - - 56.26 29.81 55.72 23.75 C36+ - - 45.53 18.75 45.08 14.94 Molar Mass C7+ 113.91 432.27 432.26 C 12+ 166.36 436.41 436.41 C20+ - 550.38 550.38 C30+ - 812.47 812.47 C36+ - 1045.00 1045.00 Density C7+ - 0.9627 - C 12+ - 0.9637 0.9637 C20+ - 0.9935 0.9935 C30+ 1.0536 1.0536 C36+ 1.0918 1.0918 Fluid at 60°F 0.9622 Gas Gravity (Air =1 ~ 0.572 Dry Gross Heat Content (BTU/scf~ 993 Wet Gross Heat Content (BTU/scf) 975 OBM Contamination Level (wt%) - STO Basis - Live Oif Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 430.40 430.40 1045.00 Density Ig/cm3) 0.9622 - 1.0918 Single Stage Flash Data Original STO De-Contaminated GOR Iscf/stbl 76 - STO Density Ig/cm3) 0.9622 - STO API Gravity 15.6 - OBM Density (g/cm3) @60°F - Ollphase-DBR T File 200500215 ~_ .] Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand Figure 11: Stock Tank Oil Chromatogram (Sample 1.18- Sample 1.18; Cylinder CSF3 1 431 1-11A; ueptn 555 tt. Ivlu FID1 A, (E:IHFCNEMI'lIDATAVl05002151CY14391.DJ Norm. 250 JOB 200500215 CONOCO PHILIPS 200 1.18 CSB 14311-QA RF FLASH CYLINDER I 150 I 100 (j ~ N ~ ~41(fl"u'~a'~ 50 0 ,~ l0 l9 ~ ~ ~ ~ N N N NNNUUUU(~,U UUUUUU p ~ ~ N m V U ~ ~ U<< C C C CCCCCCCCCCCC ~ ~ C U U [ [ C C _ ~~ ~ !~ ij ~ i li C C i III III '~ I i~ ! ~f III ii 0 ~ 0 5 10 15 20 25 30 35 Figure 12: k-Plot for EquiUbrium t:necK ~sampie ~. ia~ Sample 1.18; Cylinder CSB 14311-QA; Depth 5553 ft. MD • 1 - ~lC_4_- -- - 0.8 ---- --- - • C3 - 0.6 -- - - ---- Y Of J ~.2 ..._ - -___ -- _-.__ __- - -- __-__--_- __...- __.---....-._.- _..-._.._.--_- _- O -__ __ _- • iC5 -------- - ~ n~F -0.2 ---- -4 -3 -Z -1 0 1 2 3 ~ F Ollphase-DBR 31 File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 18: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.19) Sample 1.19; Cylinder SSB 18539-QA; Depth 5553 ft. MD Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid ~g/mole) Wl- % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 1.25 0.47 0.00 0.00 0.01 0.10 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.65 0.97 0.00 0.00 0.02 0.20 Methane 16.04 95.66 97.95 0.00 0.00 0.92 20.02 Ethane 30.07 0.84 0.46 0.00 0.00 0.01 0.09 Propane 44.10 0.15 O.D5 0.01 0.06 0.01 O.D6 I -Butane 58.12 0.13 0.04 0.00 0.03 0.00 0.03 N -Butane 58.12 0.03 0.01 0.00 0.00 0.00 0.00 I -Pentane 72.15 0.03 0.01 0.01 0.06 0.01 0.05 N -Pentane 72.15 0.10 0.02 0.01 0.04 0.01 0.04 C6 84.00 0.05 0.01 0.10 0.50 0.10 0.40 M-C-Pentane 84.16 O.DO 0.00 0.00 0.00 0.00 0.00 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.02 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.05 0.01 0.09 D.41 0.09 0.33 M-C-Hexane 98.19 0.01 0.00 0.00 0.00 0.00 0.00 Toluene 92.14 0.00 O.DO 0.00 0.00 0.00 0.00 CB 107.00 0.01 0.00 0.00 0.00 0.00 0.00 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 0-XyVene Cg 106.17 106.17 121.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 C10 134.00 0.01 0.00 O.Dt 0.02 0.01 0.02 C11 147.00 0.01 0.00 0.21 0.62 0.21 0.49 C12 161.00 0.00 0.00 0.69 1.87 0.68 1.48 C13 175.00 0.00 0.00 1.47 3.67 1.46 2.92 C14 190.00 0.00 0.00 1.99 4.57 1.97 3.64 C15 206.00 0.00 0.00 2.49 5.27 2.47 4.19 C16 222.00 2.37 4.66 2.35 3.71 C17 237.00 2.54 4.68 2.52 3.72 C18 251.00 2.71 4.71 2.68 3.74 C19 263.00 2.84 4.71 2.81 3.75 C2D 275.00 2.80 4.43 2.77 3.53 C21 291.00 2.64 3.95 2.61 3.15 C22 300.00 2.64 3.83 2.61 3.05 C23 312.00 2.70 3.78 2.68 3.01 C24 324.00 2.63 3.54 2.61 2.82 C25 337.00 2.51 3.25 2.49 2.58 C26 349.00 2.45 3.07 2.43 2.44 C27 360.00 2.40 2.90 2.37 2.31 C28 372.00 2.40 2.82 2.38 2.24 C29 382.00 2.39 2.73 2.36 Z.17 C30 394.00 1.89 2.09 1.87 1.66 C31 404.00 1.90 2.05 1.88 1.63 C32 415.00 1.70 1.78 1.68 1.42 C33 426.00 1.60 1.64 1.59 1.31 C34 437.00 1.57 1.56 1.55 1.24 C35 445.00 1.52 1.49 1.50 1.18 C36+ 1060.00 46.73 19.22 46.28 15.29 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.43 436.02 350.25 MOLE RATIO 0.2044 0.7956 Ollphase-DBR 32 File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 19: Calculated Fluid Properties Sample 1.19; Cylinder SSB 18539-QA; Depth 5553 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Male % Mass % Mole % Mass % Mole C7+ 0.12 0.02 99.88 99.32 98.92 79.02 C12+ 0.00 0.00 99.57 98.26 98.62 78.18 C20+ - - 82.47 64.14 81.67 51.03 C30+ - - 56.90 29.84 56.36 23.74 C36+ - - 46.73 19.22 46.28 15.29 Molar Mass C7+ 102.14 438.48 438.46 C12+ 166.44 441.82 441.82 C20+ - 560.60 560.60 C30+ - 831.57 831.57 C36+ - 1060.00 1060.00 Density C7+ - 0.9688 - C12+ - 0.9696 0.9696 C20+ - 1.0011 1.0011 C30+ 1.0639 1.0639 C36+ 1.1021 1.1021 Fluid at 60°F 0.9682 Gas Gravity (Air =1) 0.567 Dry Gross Heat Content (BTU/scf) 1,005 Wet Gross Heat Content (BTU/scf) 987 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 436.02 436.02 1060.00 Density (g/cm3) 0.9682 - 1.1021 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 76 - STO Density I9/cm3) 0.9682 - STO API Gravity 14.6 - OBM Density (g/cm3) C60°F - Ollphase-DBR 33 File 200500215 • • Client: ConocoPhil~ips Field: West Sak Well: 3J-101 Sand: D Sand Figure 13: Stock Tank Oil Chromatogram Sample 1.19) Sample 1.19; Cvlinder SSB 18539-QA; Depth 5553 ft. MD FID1 A, (Ea NFCHEM'i11DATAV305002151CY18539.D) Narm. 250 JOB 200500215 CONOCO PHILIPS 1.19 SSB 18539-QA 200 RF FLASH CYLINDER 150 100 50 ~ ~~p~Nt~~t171D I.n CO ~ ~ ~ N N N N NNN r~ UUW~~ ~ j ,- N m~ ~ ~ U UUUUUU U r' (~ C C U C C C C C C CCC CCCCCCCCC ~ C ~~ C C C ;; I; II; ~ II ~ ~ ;~ ~ 0 0 5 10 15 20 25 30 ~ m' Schlumberger Figure 14: k-Plot for Equilibrium Check (Sample 7.79- Sample 1.19; Cylinder SSB 18539-QA; Depth 5553 ft. MD • 1.5 • iC4 • C3 0.5 --- ---- ----- a o • iC5 J - - 0 _ _ ~ C7 --- ------ -0.5 -- -- ~ C i -1 ~ T -4 -3 -2 -1 0 1 2 3 F Ollphase-DBR 34 File 200500215 • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 20: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.20) Sample 1.20; Cylinder SSB 18530-QA; Depth 5553 ft. MD Schlumberger Component MW Flashed Gas Flashed Liquid Monaphasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 1.19 0.44 0.00 0.00 0.01 0.09 Hydrogen Sulfide 34.06 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 2.17 1.27 O.OD 0.00 0.02 0.25 Methane 16.04 95.87 97.91 0.00 0.00 0.91 19.44 Ethane 30.07 0.62 0.34 0.00 0.00 0.01 0.07 Propane 44.10 0.07 0.02 0.01 0.10 0.01 0.09 I -Butane 58.12 0.04 0.01 0.00 0.03 0.00 0.03 N -Butane 58.12 0.00 0.00 0.00 0.01 0.00 0.01 I -Pentane 72.15 0.00 0.00 0.00 0.02 0.00 0.01 N -Pentane 72.15 0.01 0.00 0.01 0.06 0.01 0.05 C6 84.00 0.00 0.00 0.01 0.06 0.01 0.05 M-C-Pentane 84.16 0.00 0.00 D.00 0.00 0.00 0.00 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.00 0.00 D.11 0.49 0.11 0.39 M-C-Hexane 98.19 0.00 0.00 0.00 0.01 0.00 0.01 Toluene 92.14 0.00 0.00 0.00 0.00 0.00 0.00 CS 107.00 0.00 0.00 0.00 0.02 0.00 0.01 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 0-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 C9 121.00 0.00 0.00 0.00 0.01 0.00 0.01 C10 134.00 0.00 0.00 0.04 0.14 0.04 0.11 C11 147.00 0.00 0.00 0.31 0.89 0.30 0.71 C12 161.00 0.00 0.00 0.83 2.19 0.82 1.76 C13 175.00 0.00 0.00 1.56 3.78 1.54 3.03 C14 190.00 0.00 0.00 1.94 4.36 1.93 3.49 C15 206.00 0.00 0.00 2.53 5.23 2.51 4.19 C16 222.00 2.47 4.74 2.45 3.80 C17 237.00 2.63 4.72 2.60 3.78 C18 251.OD 2.85 4.84 2.63 3.88 C19 263.00 2.91 4.71 2.88 3.78 C20 275.00 2.72 4.22 2.70 3.38 C21 291.00 2.85 4.16 2.82 3.34 C22 300.00 2.73 3.88 2.71 3.11 C23 312.00 2.82 3.84 2.79 3.08 C24 324.00 2.77 3.64 2.75 2.92 C15 337.00 Z.67 3.37 2.64 2.70 C26 349.00 2.51 3.07 2.49 2.46 C27 360.D0 2.42 2.87 2.40 2.30 C28 372.00 2.37 2.71 2.34 2.17 C29 382.00 2.38 2.65 2.36 2.13 C30 394.D0 2.16 2.33 2.14 1.67 C31 404.00 2.11 2.23 2.09 1.78 C32 415.00 1.63 1.67 1.61 1.34 C33 426.00 1.65 1.65 1.63 1.32 C34 437.00 1.57 1.53 1.55 1.Z2 C35 445.00 1.57 1.50 1.55 1.20 C36+ 1043.00 44.83 18.29 44.41 14.66 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.38 425.59 344.35 MOLE RATIO 0.1985 0.8015 Ollphase-DBR 35 File 200500215 • Client: ConocoPhillips Fieid: West Sak Well: 3J-101 Sand: D Sand Table 21: Calculated Fluid Properties Sample 1.20; Cylinder SSB 18530-QA; Depth 5553 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.02 0.00 99.96 99.72 99.01 79.92 C12+ 0.00 0.00 99.49 98.17 98.55 78.68 CZO+ - - 81.76 63.59 80.99 50.97 C30+ - - 55.51 29.19 54.99 23.39 C36+ - - 44.83 18.29 44.41 14.66 Molar Mass C7+ 120.70 426.62 426.62 C12+ 163.09 431.32 431.32 CZO+ - 547.18 547.18 C30+ - 809.39 809.39 C36+ - 1043.00 1043.00 Density C7+ - 0.9648 - C12+ - 0.9659 0.9659 C20+ - 0.9979 0.9979 C30+ 1.0620 1.0620 C36+ 1.1035 1.1035 Fluid at 60°F 0.9645 Gas Gravity (Air =1) 0.566 Dry Gross Heat Content (BTU/scf) 998 Wet Gross Heat Content (BTU/scf) 981 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 425.59 425.59 1043.00 Density (g/cm3) 0.9645 - 1.1035 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 75 - STO Density (g/cm31 0.9645 - STO API Gravity 15.2 - OBM Density (g/cm3) C~60°F - Ollphase-DBR 36 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand Figure 15: Stock Tank Oil Chromatogram (Sample 1.20) Sample I.~u; t;yunaer ~~~ 1~5.su-uH; uepm ~~~3 I~. Ivlu fID1,'a, (E:IHPCHE1~1121DA1At0U500215'sCY1S530.D) Narm. 250 JOB 200500215 CONOCO PHILIPS 1.20 SSB 18530-QA RF FLASH CYLINDER • 200 150 I 100 ~ ~ ~ 0 ~N(rj~!OtOt*.07~N(>~ 50 ~ N m~ 47 ~ ~ ~ ~ N N N N N NNNN~ ~ ~ U U UU C CCCCCCCCCCCv C~C~ `- U [ U U C C C ii ; ! ii Ij ;i: [ [ C i !;. ~ lip l l, I I~ i j l i :Ili ii ~ .:a I `'+i 'I Iil' ! i ll~ i t ! j;l ~ i ~~ G I D 0 5 10 15 20 25 30 35 Figure 16: k-Plot for Equilibrium GhecK ~5ample ~.zu- Sample 1.20; Cylinder SSB 18530-QA; Depth 5553 ft. MD • t - o.a --- --- . ic4 0.6 ------ -~ _--- ---_ ----- - _ - - -- - ----- --- -- -- . C3 4 0 -- --- -- ------------- _. . 0 J . nC4 - 0.2 --- - -- - 0 - - -- - ----------- • iC5 • nC5 -0.2 -4 -3 -2 -1 0 1 2 3 F Ollphase-DBR 37 File 200500215 • Client: ConocoPhillips Well: 3J-101 Contam. wt% 1.72 STO (Demulsifier) Field: West Sak Sand: B Sand Schlumherger Table 22: C36+ Composition, GOR, °API, by Zero-Flash (Sample 1.01 & 1.02) Sample 1.01 & 1.02; Cylinder CSB 4854-IA Component MW Flashed Gas Flashed Liquid Monophasic Fluid Ig/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 1.57 0.60 0.00 0.00 0.02 0.14 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.50 0.69 0.00 0.00 0.02 0.20 Methane 16.04 93.42 97.18 0.00 0.00 1.11 22.13 Ethane 30.07 1.08 0.60 0.00 0.00 0.01 0.14 Propane 44.10 0.81 0.31 0.02 0.16 0.03 0.19 I -Butane 58.12 0.70 0.20 0.01 0.09 0.02 0.11 N -Butane 58.12 0.36 0.10 0.01 0.08 0.02 0.09 I -Pentane 72.15 0.43 0.10 0.03 0.17 0.04 0.16 N -Pentane 72.15 0.04 0.01 0.00 0.02 0.00 0.02 C6 64.00 0.01 0.00 0.04 0.21 0.04 0.16 M-C-Pentane 84.16 0.00 0.00 0.00 0.02 0.00 0.01 Benzene 78.11 0.00 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.00 0.00 0.00 0.02 0.00 0.02 C7 96.00 0.00 0.00 0.10 0.43 0.10 0.34 M-C-Hexane 98.19 0.00 0.00 0.01 0.02 0.01 0.02 Toluene 92.14 0.01 0.00 0.03 0.13 0.03 0.10 C8 107.00 0.01 0.00 0.14 0.54 0.14 0.42 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.01 0.03 0.01 0.03 0-Xylene 106.17 0.00 0.00 0.06 0.23 0.06 0.16 C9 121.00 0.01 0.00 0.25 0.83 0.24 0.64 C10 134.00 0.02 0.00 1.12 3.42 1.11 2.64 C11 147.00 0.00 0.00 1.83 5.09 1.61 3.93 C12 161.00 0.00 0.00 1.41 3.59 1.39 2.77 C13 175.00 0.00 0.00 1.82 4.25 1.80 3.28 C 14 190.00 0.00 0.00 2.12 4.58 2.10 3.53 C15 206.00 0.00 0.00 2.55 5.07 2.52 3.91 C16 222.00 2.33 4.31 2.31 3.33 C17 237.00 2.43 4.20 2.40 3.24 C18 251.00 2.59 4.23 2.56 3.26 C19 263.00 2.64 4.11 2.60 3.17 C20 275.00 2.35 3.50 2.32 2.70 C21 291.00 2.29 3.22 2.26 2.49 C22 300.00 2.36 3.23 2.34 2.49 C23 312.00 2.12 2.78 2.09 2.15 C24 324.00 1.94 2.46 1.92 1.90 C25 337.00 1.97 2.40 1.95 1.85 C26 349.00 1.92 2.26 1.90 1.74 C27 360.00 1.78 2.02 1.76 1.56 C28 372.00 1.78 1.96 1.76 1.51 C29 382.00 1.79 1.91 1.76 1.48 C30 394.00 1.72 1.79 1.70 1.38 C31 404.00 1.29 1.31 1.28 1.01 C32 415.00 1.55 1.53 1.53 1.18 C33 426.00 0.84 0.81 0.83 0.62 C34 437.00 1.16 1.10 1.16 0.85 C35 445.00 1.05 0.96 1.03 0.74 C36+ 990.00 50.51 20.90 49.91 16.14 Total 100.00 100.00 100.00 100.00 100.00 100.00 MN/ 16.69 409.60 320.11 MOLE RATIO 0.2278 0.7722 Ollphase-DBR 38 File 200500215 • • Client; ConocoPhillips Well: 3J-101 Contam. wt% 1.72 STO (Demulsifier) Field: West Sak Sand: B Sand Schlumberger Table 23: Calculated Fluid Properties Sample 1.01 & 1.02; Cylinder CSB 4854-IA Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass °I° Mole C7+ 0.08 0.01 99.88 99.27 98.70 76.66 C12+ 0.00 0.00 96.33 88.46 95.18 68.31 C20+ - - 78.44 54.13 77.51 41.80 C30+ - - 58.13 28.40 57.44 21.93 C36+ - - 50.51 20.90 49.91 16.14 Molar Mass C7+ 107.49 412.12 41 Z.11 C 12+ 166.70 446.03 446.03 C20+ - 593.48 593.48 C30+ - 838.56 838.56 C36+ - 990.00 990.00 Density C7+ - 0.9521 - C 12+ - 0.9597 0.9597 C20+ - 0.9922 0.9922 C30+ 1.0363 1.0363 C36+ 1.0571 1.0571 Fluid at 60°F 0.9515 Gas Gravity (Air =1) 0.576 Dry Gross Heat Content (BTU/scf) 1,017 Wet Gross Heat Content (BTU/scf) 999 Demuslfier Contamination Level (wt°1°) 1.7 STO Basis 1.7 Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 374.81 409.60 990.00 Density (g(cm3) 0.9515 0.9030 1.0571 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 91 93 STD Density (g/cm3) 0.9515 0.9565 STO API Gravity 17.2 16.4 De-emuslfier Density (g/cm3) C~6 0.7340 Ollphase-DBR 39 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand Contam. wt% 1.72 STO (Demulsifier) • Figure 17: Stock Tank Oil Chromatogram (Sample 1.01 & 1.02) ~~~ , JdIII~Jie i.ul Ol i.uc, ~yniiuci IJJU `fUJ`t-I/'i fID1A, (EaHPCHEb1t2lUATAUJDSDD'2161CYC629.Dj Norm. ~ 250 ~ I JOB 200500215 CONOCO PHILIPS 1.04 CSB 8629-QA RF FLASH CYLINDER 200 150 10D ~ O 01 O ~ N fh~U1LDf`~OrN~'krifi ~ ~ Ul C9 ~ ~ ~ N N N NNNNNN~I('~1-j 5D ~ Uo ~ ~ N ~ U U U C ~ C C C C C~CCCUWWC U O XU U U U C i! I ;, ~ U C C C ~~ i!! i i i s I~ '~ ;: Iii i ~ i ~ i i C OC C C , j ~ I iI I'; I ''' Ii iii I Iji Ili II Ili !I D .,a....~..Aw 0 5 10 15 20 25 30 35 Figure 18: k-Plot for Equilibrium Check (sample i.u~ tk ~.uzl Sample 1.01 & 1.02; Cylinder CSB 4854-IA • 1.6 • iC4 • C3 ---- 1.4 -- -- ------- - - • nC4 - 1.2 - -- ---- - - - 1 - ------- - - - • iC5 c rn 0.8 - .__ - -- • nC5 J 0.6 - -- -- - --- - 0.4 --- 0.2 - - ----- O -4 -3 -2 -1 0 1 2 3 F Ollphase-DBR 40 File 200500215 • Client: ConocoPhillips Well: 3J-101 Contam. wt% 1.72 STO IDemulsifi Field: West Sak Sand: B Sand Figure 19: De-emulsifier Oil Chromatogram De-emulsifier Schlumberger rID I A, (H:121DATA100 5 0 02 1 51DM0~4800.D) pA DEEMULSIFIER CHROMATOGRAM 140 120 100 8D ao nC10 1 20 U c 0 5 10 15 20 25 mi Ollphase-DBR 41 File 200500215 • • ., Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 24: C36+ Composition, GOR, °API, by Zero-Flash (Sample 1.01 & 1.02) Sample 1.01 & 1,02; Cylinder CSB 4832-IA Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 1.31 0.50 0.00 0.00 0.03 0.16 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.96 0.56 O.OD 0.00 0.02 0.19 Methane 16.04 91.78 96.84 0.00 0.00 1.90 31.22 Ethane 30.07 1.22 0.68 0.00 0.00 0.03 0.22 Propane 44.10 1.69 0.65 0.02 0.16 0.05 0.32 I -Butane 58.12 0.63 0.24 0.01 0.09 0.03 0.14 N -Butane 58.12 0.50 0.15 0.01 0.08 0.02 0.10 I -Pentane 72.15 0.64 0.15 0.04 0.20 0.05 0.19 N -Pentane 72.15 0.16 0.04 0.01 0.05 0.01 0.04 C6 84.00 0.33 0.07 0.09 0.41 0.09 0.30 M-C-Pentane 84.16 O.D3 0.01 0.00 0.02 0.01 0.02 Benzene 78.11 0.01 0.00 0.00 0.02 0.00 0.01 Cyclohexane 84.16 0.04 0.01 0.01 0.03 0.01 0.02 C7 96.00 0.31 0.05 0.14 0.54 0.14 0.38 M-C-Hexane 98.19 0.03 0.00 0.01 0.02 0.01 0.02 Toluene 92.14 0.03 0.00 0.04 0.16 0.04 0.11 C8 107.00 0.05 0.01 0.18 0.62 0.17 0.43 E-Benzene 106.17 0.00 0.00 0.04 0.16 0.04 0.11 M/P-Xylene 106.17 0.01 0.00 O.D1 0.04 0.01 0.03 0-Xylene 106.17 0.01 0.00 0.01 0.03 0.01 0.02 C9 121.00 0.02 0.00 0.29 0.93 0.29 0.63 C10 134.00 0.01 0.00 0.54 1.55 0.53 1.05 C11 147.00 0.01 0.00 0.92 2.39 0.90 1.62 C12 161.00 0.01 0.00 1.50 3.54 1.46 2.40 C13 175.00 0.00 0.00 1.98 4.31 1.94 2.92 C14 190.00 0.00 0.00 2.46 4.93 2.41 3.34 C15 206.00 0.00 0.00 2.81 5.20 2.75 3.53 C16 222.00 2.67 4.93 2.81 3.34 C17 237.00 2.84 4.56 2.78 3.09 C18 251.00 3.03 4.60 2.96 3.12 C19 263.00 2.87 4.16 2.81 2.82 C20 275.00 2.89 4.00 2.83 2.71 C21 291.00 2.89 3.78 2.83 2.56 C22 300.00 2.70 3.43 2.64 2.32 C23 312.00 2.66 3.25 2.61 2.20 C24 324.00 2.37 2.79 2.32 1.89 C25 337.00 2.37 2.68 2.32 1.62 C26 349.00 2.13 2.32 2.08 1.57 C27 360.00 2.Z9 Z.42 2.24 1.64 C26 372.00 2.55 2.61 2.49 1.77 C29 382.00 1.94 1.94 1.90 1.31 C30 394.00 1.91 1.84 1.87 1.25 C31 404.00 1.91 1.80 1.87 1.22 C32 415.00 1.75 1.60 1.71 1.09 C33 426.00 1.40 1.26 1.38 0.65 C34 437.00 1.14 0.99 1.11 0.67 C35 445.00 0.99 0.85 0.97 0.57 C36+ 884.70 43.40 18.70 42.51 12.67 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.93 381.17 263.74 MOLE RATIO 0.3224 0.6776 Ollphase-DBR 42 File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 25: Calculated Fluid Properties Sample 1.01 & 1.02; Cylinder CSB 4832-IA Schlumherger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.56 0.10 99.82 99.01 97.76 67.12 C12+ 0.01 0.00 97.63 92.51 95.61 62.69 C20+ - - 77.27 56.27 75.67 38.13 C30+ - - 52.50 27.05 51.41 18.33 C36+ - - 43.40 18.70 42.51 12.67 Molar Mass C7+ 97.27 384.28 384.15 C12+ 161.00 402.26 402.26 C20+ - 523.45 523.45 C30+ - 739.82 739.82 C36+ - 884.70 884.70 Density C7+ - 0.9542 - C1 Z+ - 0.9591 0.9591 C20+ - 0.9964 0.9964 C30+ 1.0598 1.0598 C36+ 1.0958 1.0958 Fluid at 60°F 0.9533 Gas Gravity (Air =1) 0.584 Dry Gross Heat Content (BTU/scf) 1,037 Wet Gross Heat Content (BTU/scf) 1,019 De-emuslfier Contamination Levet (wt%- - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties M1/1/ - 381.17 884.70 Density (g/cm3) 0.9533 0.9533 1.0958 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 158 STO Density (g/cm3) 0.9533 STO API Gravity 16.9 De-emuslfier Density (g/cm3) Q6 - Ollphase-DBR 43 File 200500215 • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Figure 20: Stock Tank Oil Chromatogram (Sample 1.01 & 1.02- Sample 1.01 & 1.02; Cylinder CSB 4832-IA FID1 A, (F ;21 DATA12005t005002151CY4832.D) Noim. "~ 160 ~~ ~~. 180 1~ JOB 200500215 CONOCO PHILLIPS 1.01, 1.02 CSB 4832-IA 120 RF FLASH CYLINDER 100 80 80 ~ ~ ~ ~ ov ~ ~OYO~Nf~VUI(D~ U ZU m ~~ ,q 47 CO ~ ~NNNNNNNUU~ ~ C ~ --°~1~ ~ m ~ o ~ ~ m ~ U U ~ ~ c cc~cccccccccdc 20 c ,Li II ~~jl~ U° F U ~~ U C C C C '~'Ci' !i i !I~ i ~i~~ i' il I I 0 0 5 10 15 20 25 30 35 mi Schlumberger Figure 21: k-Plot for Equilibrium Check (Sample 1.01 & 1.02) Sample 1.01 & 1.02; Cylinder CSB 4832-IA • z • C3 • iC4 1.5 - _ _ - __ _ - - __ _ __--- - - • nCA 1 ~ ~ Iti5- _ _ _ _ __ - ~ - ~, 0.5 J ---- - --- - --- • C6 • C7 0 -- 1 i -1 i -4 -3 -2 -1 0 1 2 3 F Ollphase-DBR 44 File 200500215 • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 26: Composition of Synthetic Recombination Gas for Sample (1.01 & 1.02) Sample 1.01 & 1.02; Cylinder CSB 4832-IA Schlumherger Component MW Synthetic Gas wt% mol% C02 44.01 0.928 0.352 HZS 34.08 0.000 0.000 N2 28.01 6.817 4.057 C1 16.04 91.794 95.397 C2 30.07 0.208 0.115 C3 44.10 0.112 0.043 i-C4 58.12 0.055 0.016 n-C4 58.12 0.028 0.008 i-C5 72.15 0.032 0.007 n-C5 72.15 0.005 0.001 C6 84.00 0.019 0.004 Mcyclo-C5 84.16 0.000 0.000 Benzene 78.11 0.000 0.000 Cyclo-C6 84.16 0.000 0.000 C7 96.00 0.000 0.000 Mcyclo-C6 98.19 0.000 0.000 Toluene 92.14 0.000 0.000 Cg 107.00 0.000 0.000 C2-Benzene 106.17 0.000 0.000 m&p-Xylene 106.17 0.000 0.000 o-Xylene 106.17 0.000 0.000 Cg 121.00 0.000 0.000 C10 134.00 0.000 0.000 C11 147.00 0.000 0.000 C12 161.00 0.000 0.000 Calculated MW g/mol 16.67 Gas Gravity Air =1 0.575 Ollphase-DBR 45 File 200500215 • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 27: Summary of Results of Sample RSS (1.01 + 1.02) Sample RSS (1.01 + 1.02; Cylinder CSB 4832-IA; Depth 5697 ft MD Schlumberger Reservoir Conditions: Pressure: 1490 psia Temperature: 70 °F Summary of Fluid Properties: OBM Contamination: - Wt% STO Basis OBM Contamination: - Wt% RF Basis Bubble Point Pressure At Tres 1,304 psia At 130°F - psia At 100°F - psia Gas-Oil Ratio Single-stage Flash: 158 scf/stb Total Differential Liberation: - scf/stb Total Separator Flash: 150 scf/stb Properties at 60°F STO °API Gas Gravity (Average) Single-stage STO: 16.9 .0.584 Differential Liberation STO: - - Separator STO: 17.1 0.571 Properties at Reservoir Conditions Viscosity: 243.8 cP Compressibillity (Cod: 7.74 10-6/psi Density: 0.9347 g/cc Properties at Saturation Conditions Viscosity: 239.4 cP Compressibillity ~Co-: 7.80 10-6/psi Density: 0.9327 g/cc Formation Volume Factor @Pres & Tres @Psat & Tres Single-stage Flash: 1.033 1.035 Total Differential Liberation: - - Total Separator Flash: 1.039 1.041 Note: Standard conditions are 14.696 psia and 60°F • Ollphase-DBR 4ii File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand • PVT Analysis on Sample RSS (1.01 + 1.02-; Cylinder CSB 4832-IA; Depth 5697 ft MD, B Sand Constant Composition Expansion at Tres The CCE study was initiated bycharging asub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 70.0°F and at a pressure of 5,015 psis. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 28. The pressure-volume (P-V) plots of the CCE data are presented in Figure 22. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,304 psia at the reservoir temperature of 70.0 °F. Also, calculated relative volume and oil compressibility is presented in Table 28. As seen in the table, the compressibility of this oil is 7.8 x 10e-61/psia at the saturation pressure. Schlumberger Table 28: Constant Composition Expansion at 70.0°F Sample 1.01&1.02 RSS) S~mnle RSS 11.01 + 1.02): Cylinder CSB 4832-IA; Depth 5697 ft MD • • Date: 08/25/200f Pressure (psia) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % Liquid (VI/Vtotal) Liquid Density Ig/cm3} Y Function Compressibility 110'6/psia) 1 5015 0.9740 100.0 97.4 0.9586 6.66 2 4020 0.9800 100.0 98.0 0.9523 6.95 3 3017 0.9870 100.0 98.7 0.9454 7.25 4 2019 0.9950 100.0 99.5 0.9383 7.57 5 1716 0.9970 100.0 99.7 0.9363 7.66 6 1510 0.9980 100.0 99.8 0.9348 7.73 Pi 1490 0.9980 100.0 99.9 0.9347 7.74 Pb 1304 1.0000 100.0 100.0 0.9333 7.80 9 1185 1.0190 98.1 99.9 5.3 10 1090 1.0390 96.1 99.8 5.1 11 1010 1.0600 94.1 99.7 4.9 12 919 1.0880 91.5 99.6 4.7 13 871 1.1070 89.9 99.6 4.6 14 793 1.1440 86.9 99.5 4.5 15 680 1.2100 82.1 99.3 4.4 16 540 1.3300 74.6 99.2 4.3 17 375 1.5830 62.5 99.0 4.3 18 260 1.9530 50.6 98.9 4.2 Ollphase-DBR 47 File 200500215 Field: West Sak Sand: B Sand Schlumberger Client: ConocoPhillips Well: 3J-101 • Figure 22: Constant Composition Expansion at 70.0°F -Relative Volume Sample RSS (1.01 + 1.02-; Cylinder CSB 4832-IA; Depth 5697 ft MD z.z z.o 1.8 a ~ 1.6 d e 0 .? 1.4 R 1.2 1.0 r ~ L_J Ollphase-DBR o.a 0 1000 2000 3000 4000 5000 6000 Pressure~psia) 48 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand • Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 70°F. These values as a function of selected pressure steps are summarized in Table 29. The liquid phase viscosity values are graphically presented in Figure 23. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. • • Table 29: Reservoir Fluid Viscosity 70°F Sample RSS (1.01 + 1.02-; Cylinder CSB 4832-IA; Depth 5697 ft MD Pressure Viscosity @ Tres (psia) IcPI 1 9915.7 1168.7 2 9042.7 996.9 3 8013.7 815.5 4 7010.7 685.0 5 6024.7 580.1 6 5029.7 486.1 7 4028.7 403.6 8 3518.7 371.7 9 3015.7 341.2 10 2527.7 305.7 11 2029.7 278.8 12 1528.7 250.4 Pb 1304.0 239.4 14 1161.7 273.7 15 1095.7 287.9 16 1020.7 309.6 17 937.7 333.9 18 831.7 359.8 19 712.7 389.8 ZO 639.7 428.0 STO 14.7 1325.0 Ollphase-DBR 49 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand • Figure 23: Reservoir Fluid Viscosity 70°F Sample RSS (1.01 + 1.02; Cylinder CSB 4832-IA; Depth 5697 ft MD 1400 1200 1000 ~ 800 .y O U N > 600 400 • 200 • 0 ~ 0.0 2000.0 4000.0 6000.0 Pressurelpsia) 8000.0 10000.0 12000.0 Ollphase-DBR 50 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Schlumberger • Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 30 - 32. The fluid properties (i.e., GOR, density and oil formation volume factor) are presented in Table 30. Multi-stage separation test conditions are: STAGE Pb 1304 psia 70 °F STAGE 1 105 psia 125 °F STAGE 2 75 psia 185 °F STAGE STO 15 psia 60 °F As seen in Table 30, the GOR value obtained from the multi-stage separation test is 150 SCF/STB and the formation volume factor is 1.041. The compositional analyses of separator gas and tank gas are summarized in Table 31 and the composition of tank liquid is tabulated in Table 32. The total dry gross heat content of the separation gases is calculated to be 1,017 BTU/scf whereas the total wet gross heat content is calculated to be 1027 BTU/scf. Ollphase-DBR 51 File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 30: Multi-Stage Separation Test Vapor & Liquid Properties Sample RSS X1.01 + 1.02-; Cylinder CSB 4832-IA; Depth 5697 ft MD PROPERTY STAGE Pb STAGE 1 STAGE 2 STAGE STO Pressurelpsia- 1304 105 75 14.7 Temperature (°F) 70 125 185 60 Liquid Density (g/cm3) 0.9333 0.9501 0.9489 0.9525 Vap. Gravitya 0.570 0.579 0.599 Vap. M,,,,~ 16.52 16.75 17.34 Vap Heat Val.b 1016 1029 1034 GOR` 140 3 6 GORd 140 3 6 Sep. FVFe 1.041 1.004 1.005 1.000 a) Calculated, at 60°F fair=11 b) Galculateo, ury basis o i u/scr q scr gas/ooi or oii ai ~ ~ u ~ununwiis dj scf gas/bbl of oil at separator conditions e) fluid volume at sepconditions/fluid volume at STD conditions Residual oil density at standard conditions 0.9525 g/cc Sep gas gravity (average) S9 = ERjSgj/ERi 0.571 Where: R: GOR (scf gas/bbl of oil at STD conditionsj, j: separator stages Sep gas gross heating value I L~ =ERi*L~i/ERi 1017 BTU/scf (dry basin Where: R: GOR (scf gas/bbl of oil at STD conditionsl, j: separator stages SEPARATION TEST SUMMARY aTotal Separation Test GOR 150 Separation Test STO Gravity 17.1 bSeparation Test FVF 1.041 Schlumberger aj scf gas/bbl of condensate at STD conditions bj Fluid volume at Psat & Tres/Fluid volume at STD Ollphase-DBR 52 file 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: B Sand • Table 31: Multi-Stage Separator Test Vapor Composition (mol °1°- Sample RSS (1.01 + 1.02; Cylinder CSB 4832-IA; Depth 5697 ft MD • • Component MW (g/mol) Mole STAGE Pb STAGE 1 STAGE 2 STAGE STO Carbon Dioxide 44.01 0.48 0.49 0.86 Hydrogen Sulfide 34.08 0.00 0.00 O.DO Nitrogen 28.01 0.55 0.51 1.55 Methane 16.04 97.91 97.12 95.58 Ethane 30.07 0.64 0.89 0.81 Propane 44.10 0.16 0.56 0.47 I -Butane 58.12 0.06 0.1,5 0.08 N -Butane 58.12 0.03 0.09 0.09 I -Pentane 72.15 0.03 6.08 0.64 N -Pentane 72.15 0.03 0.02 0.09 C6 84.00 0.03 0.04 0.05 M-C-Pentane 84.16 0.00 0.00 0.00 Benzene 78.11 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 C7 96.00 0.01 0.00 0.01 M-C-Hexane 98.19 0.00 0.00 0.00 Toluene 92.14 0.03 0.00 0.03 CS 107.00 0.00 0.00 0.01 E-Benzene 106.17 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.01 0.04 0-Xylene C9 106.17 121.00 0.00 0.00 0.01 0.01 0.01 0.02 C10 134.00 0.00 0.00 0.02 c11 147.00 0.00 0.00 0.1 z C 12 161.00 0.00 0.00 0.10 C13 175.00 0.00 0.00 0.01 C14 190.00 0.00 0.00 0.00 C15 206.66 O.DO D.00 0.00 C16 222.00 0.00 0.00 0.00 C17 237.00 0.00 0.00 0.00 C18 251.00 0.00 0.00 D.00 C19 263.00 0.00 0.00 0.00 C20 275.00 0.00 0.00 0.00 C21 29100 0.00 0.00 0.00 C22 300.00 0.00 0.00 O.DO C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 0.00 C25 337.00 0.00 0.00 0.00 C26 349.00 0.00 0.00 0.00 C27 36D.00 0.00 0.00 0.00 C28 372.00 D.00 0.00 0.00 C30 394.00 0.00 0.00 D.00 C31 404.00 0.00 0.00 0.00 C32 415.00 0.00 0.00 O.DO C33 426.00 0.00 0.00 0.00 C34 437.00 0.00 0.00 0.00 C35 445.00 0.00 0.00 6.60 C36+ 884.70 0.00 0.00 0.00 Total 100.00 100.00 100.00 MW 16.52 16.75 17.34 Relative Density lair=l ~ Dry Gross Heat Content (8TU/scf~ 0.570 1016 0.579 1029 0.599 1034 Ollphase-DBR F~ File 200500215 ~J • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: B Sand Table 32: Multi-Stage Separator Test Residual Liquid Composition (mol %) Sample RSS (1.01 + 1.02; Cylinder CSB 4832-IA; Depth 5697 ft MD Schlamberger COMPONENT MW (g/mol) Residual Liq. (mol %) Methane 16.04 0.00 Ethane 30.07 0.00 Propane 44.10 0.44 I -Butane 58.12 0.14 N -Butane 58.12 0.11 I -Pentane 72.15 0.24 N -Pentane 72.15 0.09 C6 64.00 0.44 M-C-Pentane 84.16 0.05 Benzene 78.11 0.04 Cyclohexane 84.16 0.06 C7 96.00 1.05 M-C-Hexane 98.19 0.02 Toluene 92.14 0.28 CS 107.00 0.62 E-Benzene 106.17 0.06 M/P-Xylene 106.17 0.02 0-Xylene 106.17 0.05 C9 121.00 0.95 C10 134.00 1.86 C11 147.00 2.77 C12 161.00 3.98 C13 175.00 4.86 C14 190.00 5.24 C15 206.00 5.79 C16 222.00 4.94 C17 237.00 4.76 C18 251.00 4.79 C19 263.00 4.56 C20 275.00 3.84 C21 291.00 3.72 C22 300.00 3.35 C23 312.00 2.84 C24 324.00 2.57 C25 337.00 2.25 C26 349.00 2.10 C27 360.00 2.09 C28 372.00 1.87 C29 382.00 1.63 C30 394.00 1.56 C31 404.00 1.25 C32 415.00 0.93 C33 426.00 0.81 C34 437.00 0.77 C35 445.00 0.61 36+ 884.70 19.6 Total 100.00 -yl 376.14 Ollphase-DBR 54 File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 33: C36+ Composition, GOR, °API, by Zero-Flash (Sample 1.11,1.12 & 1.13) Sample 1.11, 1.12 & 1.13; Cylinder CSB 4881-IA Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 1.31 0.50 0.00 0.00 0.03 0.17 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 2.91 1.75 0.00 0.00 0.06 0.58 Methane 16.04 92.09 96.78 0.00 0.00 1.86 31.92 Ethane 30.07 0.61 0.34 0.00 0.00 0.01 0.11 Propane 44.10 0.44 0.17 0.01 0.13 0.02 0.14 I-Butane 58.12 0.11 0.03 0.00 0.02 0.00 0.02 N -Butane 58.12 O.D9 0.03 0.00 0.01 0.00 0.01 I -Pentane 72.15 0.07 0.02 O.DO 0.01 D.00 0.61 N -Pentane 72.15 0.27 0.06 0.00 0.01 0.01 0.03 C6 84.00 0.11 0.02 0.06 0.31 0.07 0.21 M-C-Pentane 84.16 O.Dt 0.00 0.01 0.05 0.01 0.04 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.00 0.00 0.00 0.02 0.00 0.01 C7 96.00 O.D9 0.02 0.22 0.94 0.22 0.64 M-C-Hexane 98.19 0.02 0.00 0.01 0.02 0.01 0.02 Toluene 92.14 0.28 D.05 0.00 0.01 0.01 0.02 C8 107.00 0.07 0.01 0.06 0.24 D.O6 0.16 E-Benzene 1D6.17 0.01 0.00 0.00 0.00 0.00 0.00 M/P-Xylene 106.17 0.66 0.11 0.00 0.01 0.02 0.04 0-Xylene Cg 106.17 121.00 0.09 0.41 0.02 0.06 0.00 0.05 0.02 0.16 0.01 0.06 0.02 0.13 C10 134.00 0.18 0.02 0.10 0.30 0.10 0.21 C11 147.00 0.11 0.01 0.42 1.16 0.42 0.78 C12 161.00 0.03 0.00 0.98 2.44 0.96 1.63 C13 175.00 0.00 0.00 1.80 4.13 1.76 2.77 C14 190.OD 0.01 0.00 2.19 4.64 2.15 3.11 C15 206.00 0.00 0.00 2.50 4.89 2.45 3.27 C16 222.00 0.00 0.00 2.59 4.69 2.53 3.14 C17 237.00 0.00 0.00 2.98 5.06 2.92 3.39 C18 251.00 0.00 0.00 2.99 4.79 2.93 3.21 C19 263.00 0.00 0.00 2.88 4.40 2.82 2.95 C20 275.00 0.00 0.00 3.10 4.54 3.04 3.04 C21 291.00 O.OD 0.00 2.94 4.07 2.88 2.73 C22 300.00 0.00 0.00 2.96 4.00 2.92 2.68 C23 312.00 0.00 0.00 3.05 3.93 2.98 2.63 C24 324.00 0.00 0.00 2.68 3.33 2.62 2.23 C25 337.00 0.00 0.00 2.91 3.48 2.85 2.33 C26 349.00 0.00 0.00 2.23 2.57 2.18 1.72 C27 360.00 0.00 0.00 2.73 3.05 2.67 2.04 C28 372.00 0.00 0.00 2.58 2.80 2.53 1.87 C29 382.00 0.00 0.00 2.76 2.91 2.70 1.95 C30 394.00 0.00 0.00 1.79 1.82 1.75 1.22 C31 404.00 0.00 0.00 2.16 2.16 2.12 1.45 C32 415.00 0.00 0.00 1.63 1.59 1.60 1.06 C33 426.00 0.00 0.00 1.23 1.16 1.20 0.78 C34 437.00 0.00 0.00 1.49 1.37 1.46 0.92 C35 445.00 0.00 0.00 1.53 1.38 1.50 0.93 C36+ 978.00 0.00 0.00 42.37 17.44 41.51 11.69 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.85 402.51 275.30 MOLE RATIO 32.9870 67.0130 Ollphase-DBR 55 File 200500215 • • • Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand Table 34: Calculated Fluid Properties Sample 1.11, 1.12 & 1.13; Cylinder CSB 4881-IA l; ~+ C12+ C20+ erties Composition Molar Mass C7+ C12+ C20+ C30+ C36+ Flashed Gas Mass % Mole 2.00 0.31 0.04 0.00 110.72 168.86 ~i+ C12+ - - C20+ - C30+ C36+ Fluid at 60°F Gas Gravity (Air =1 ~ 0.582 Dry Gross Heat Content (BTU/scf) 1,014 Wet Gross Heat Content (BTU/scf) 996 OBM Contamination Level (vut%) Stock Tank Oil Properties at Standard Conditions: Measured Calculated M~1/ 402.51 Density (g/cm3~ 0.9580 0.9020 Single Stage Flash Data Original STO GOR (scf/stb) 156 STO Density (g/cm3) 0.9581 STO API Gravity 16.2 OBM Density (g/cm3~ C~60°F - Flashed Liquid Mass % Mole 99.92 99.53 99.03 96.59 80.14 61.56 52.20 26.91 42.37 17.44 404.38 412.67 523.98 780.62 978.00 0.9030 0.9044 0.9198 0.9365 0.9410 0.9581 - STO Basis - Live Oil Basis C36+ Properties 978.00 0.9410 De-Contaminated Monophasic Fluid Mass % Mole 97.94 66.80 97.03 64.73 78.52 41.26 51.14 18.04 41.51 11.69 403.94 412.67 523.98 780.62 978.00 0.903 0.9044 0.9198 0.9365 0.9410 Oliphase-DSR 56 File 200504215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand • Figure 24: Stock Tank Oil Chromatogram (Sample 1.11,1.12 & 1.13) Sample I.11, I.IL~ i.i~;~yiinaert,~~4~u1-iH f l01 F, (E:IHPCHEIui'~110ATA~005002161GYB829.0) Norm. 260 JOB 200500215 CONOCO PHIL{PS 1.04 CSB 8629-QA RF FLASH CYLINDER 200 150 100 ~ v ~ ~ ~ o ~ N mv~n Igr~coo0-Nna~.n 50 _~ C ,~ U7 r4 ~ ~ ~ N N NN(yNNN~(~[~1 ~ ~ N ~ ~ U U U U C C C C C ~ C ~ ~UC}UJ~yj 0~ 7,~ ~- ~ ~ U C C C CCCC ~ ~ X U U ~ C<< '~ i:.l ! i i i! !; I iii i l i a C O C C a.,kyi+~?NA~I iii i ~I ~ i jj I ( u i i t Ir '' i I' ..L........a.....t,a..afn.4.r~.a..i .... i i~ ~ i; I I ~~ r i i; 0 5 10 15 20 25 30 I T 35 Figure 25: k-Plot for Equilibrium t:hecK (sample ~.n, i.lc « ~. ~s~ Sample 1.11, 1.12 & 1.13; Cylinder CSB 4881-IA 7 Ollphase-DBR 57 File 200500215 • • J Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 35: C12+ Composition of Synthetic Recombination Gas for Sample (1.11,1.12 & 1.13) Sample 1.11, 1.12 & 1.13; Cylinder CSB 4881-IA Schlumberger Component MW Synthetic Gas wt% mol% C02 44.01 0.652 0.246 H2S 34.08 0.000 0.000 NZ 28.01 7.073 4.201 C 1 16.04 92.001 95.422 C2 30.07 0.168 0.093 C3 44.10 0.083 0.031 i-C4 58.12 0.009 0.003 n-C4 58.12 0.003 0.001 i-C5 72.15 0.002 0.000 n-C5 72.15 0.001 0.000 C6 84.00 0.007 0.001 Mcyclo-C5 84.16 0.000 0.000 Benzene 78.11 0.000 0.000 Cyclo-C6 84.16 0.000 0.000 C7 96.00 0.000 0.000 Mcyclo-C6 98.19 0.000 0.000 Toluene 92.14 0.000 0.000 Cg 107.00 0.000 0.000 C2-Benzene 106.17 0.000 0.000 m&p-Xylene 106.17 0.000 0.000 o-Xylene 106.17 0.000 0.000 Cg 121.00 0.000 0.000 C10 134.00 0.000 0.000 C11 147.00 0.000 0.000 C12 161.00 0.000 0.000 Calculated MW g/mol 16.64 Gas Gravity Air =1 0.574 Ollphase-DBR 58 File 200500215 • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 36: Summary of Results of Sample RSS (1.11 + 1.12 + 1.13) Sample RSS X1.11 + 1.12 + 1.13-; Cylinder CSB 4881-IA; Depth 5553 ft. MD Schlumberger Reservoir Conditions: Pressure: 1450 psia Temperature: 69 °F Summary of Fluid Properties: OBM Contamination: - Wt% STO Basis OBM Contamination: - Wt% RF Basis Bubble Point Pressure At Tres - psia At 130°F - psia At 100°F 1,574 psia Gas-Oil Ratio Single-stage Flash: 156 scf/stb Total Differential Liberation: - scf/stb Total Separator Flash: 156 scf/stb Properties at 60°F STO °API Gas Gravity (Avera ge) Single-stage STO: 16.1 0.582 Differential Liberation STO: - - Separator STO: 16.3 0.572 Properties at Reservoir Conditions Viscosity: - cP Compressibi4lity (Co1: - 10-s(psi Density: - g/cc Properties at Saturation Conditions Viscosity (69°Fl:. 536.3 cP Compressibillity (100°F): 6.OZ 10-e/psi Density (100°Fl: 0.9186 g/cc Formation Volume Factor @Pres & Tres @Psat & 100°F Single-stage Flash: - 1.068 Total Differential Liberation: - - Total Separator Flash: - 1.063 Note: Standard conditions are 14.696 psia and 60°F. Reported FVF values are on abasis of 100°F. • Ollphase-DBR 59 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand • PVT Analysis on Sample RSS (1.11 + 1.12 + 1.13-; Cylinder CSB 4881-IA; Depth 5553 ft. MD, D Sand Constant Composition Expansion at 100 °F The CCE study was initiated by charging asub-sample of live reservoir fluid into the PVT cell at a special test temperature of 100°F and at a pressure of 5,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 37. The pressure-volume (P-V) plots of the CCE data are presented in Figure 26. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,574 psia at the measurement temperature of 100°F. Schlamberger Table 37: Constant Composition Expansion at 100°F (Sample RSS 1.11 + 1.12 + 1.13) Sample RSS (1.11 + 1.12 + 1.13-; Cylinder CSB 4881-IA; Depth 5553 ft. MD • • Pressure (psia) Relative Vol (Vr--V/Vsat) % Liquid (VI/Vsat) % Liquid (VlNtotal) Liquid Density (g/cm3) Y Function Compressibility (10~°/psia) 1 5015 0.9820 100.0 98.18 0.9356 4.69 2 4513 0.9840 100.0 98.42 0.9334 4.87 3 4013 0.9870 100.0 98.66 0.9311 5.05 4 3515 0.9890 100.0 98.92 0.9287 5.23 5 3016 0.9920 100.0 99.18 0.9262 5.42 6 2515 0.9950 100.0 99.45 0.9237 5.62 7 2012 0.9970 100.0 99.74 0.9210 5.83 8 1913 0.9980 100.0 99.80 0.9205 5.87 9 1815 0.9990 100.0 99.86 0.9199 5.91 10 1731 0.9990 100.0 99.91 0.9195 5.95 11 1623 1.0000 100.0 99.97 0.9189 6.00 Pb 1574 1.0000 100.0 100.00 0.9186 6.02 13 1451 1.0120 98.8 100.00 7.0 14 1373 1.0220 97.9 99.99 6.8 15 1287 1.0340 96.6 99.91 6.5 16 1182 1.0540 94.8 99.85 6.2 17 1071 1.0800 92.4 99.76 5.9 18 833 1.1680 85.3 99.55 5.3 19 622 1.3190 75.4 99.39 4.8 20 414 1.6240 61.1 99.25 4.5 21 228 2.3650 41.9 99.13 4.3 Ollphase-DBR File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 38: Simulated Constant Composition Expansion at 69°F Sample RSS 1.11 + 1.12 + 1.13) Sample RSS (1.11 + 1.12 + 1.13); Cylinder CSB 4881-IA; Depth 5553 ft. MD Schlamberger Pressure (psis) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % Liquid (VlNtotal) Liquid Density (g/cm3) Y Function Compressibility (10-a/psia) 1 5015 0.9913 99.1 100.00 0.9332 2.03 2 4513 0.9923 99.2 100.00 0.9323 2.13 3 4013 0.9934 99.3 100.00 0.9312 2.23 4 3515 0.9945 99.5 100.00 0.9302 2.34 5 3016 0.9957 99.6 100.00 0.9291 2.46 6 2515 0.9970 99.7 100.00 0.9279 2.59 7 2012 0.9983 99.8 100.00 0.9267 2.73 8 1913 0.9986 99.9 100.00 0.9264 2.76 9 1815 0.9988 99.9 100.00 0.9262 2.79 10 1731 0.9991 99.9 100.00 0.9259 2.82 11 1623 0.9994 99.9 100.00 0.9257 2.85 12 1574 0.9995 100.0 100.00 0.9255 2.87 13 1451 0.9999 100.0 100.00 0.9252 2.91 Pb 1407 1.0000 100.0 100.00 0.9251 2.92 15 1373 1.0043 99.9 99.47 5.8 16 1287 1.0167 99.6 97.97 5.6 17 1182 1.0356 992 95.83 5.3 18 1071 1.0613 98.8 93.13 5.1 19 833 1.1473 98.0 85.39 4.7 20 622 1.2905 97.2 75.31 4.3 21 414 1.5908 96.4 60.60 4.1 Ollphase-DBR 61 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand • Figure 26: Constant Composition Expansion at 100°F -Relative Volume Sample RSS (1.11 + 1.12 + 1.13); Cylinder CSB 4881-IA; Depth 5553 ft. MD • 2.6 2.4 2.2 2.0 a U~ 1.8 as E 0 ~ 1.6 .~ d 1.4 1.2 1.0 L_. \_. { _..._ _.. p_ ___. _. _.i _.. _.._ _ ___~_ _. ... 0.8 ~ 0 1000 2000 3000 4000 Pressure (psis) 5000 6000 Ollphase-DBR 62 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 69°F. These values as a function of selected pressure steps are summarized in Table 39. The liquid phase viscosity values are graphically presented in Figure 27. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 39: Reservoir Fluid Viscosity 69°F Sample RSS X1.11 + 1.12 + 1.13); Cylinder CSB 4881-IA; Depth 5553 ft. MD • • Pressure Viscosity @ Tres IPsia) 1cP1 1 4724 1131.1 2 3655 887.7 3 2605 694.2 4 1539 550.0 Pb * 1392 536.3 7 1085 591.3 8 855 681.2 9 696 783.1 10 590 894.4 11 468 1011.1 STO 15 3210.1 " Approximation to actual saturation point. Ollphase-DBR 63 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand • Figure 27: Reservoir Fluid Viscosity 69°F Sample RSS (1.11 + 1.12 + 1.13); Cylinder CSB 4881-IA; Depth 5553 ft. MD 3400 2900 2400 a a •y 1900 0 N_ 1400 • 900 • 400 ~ 0 5~0 1UU~ 1~~U ~~UU [S~J~ ,j~~U JJUU `fUVV YJVU Jllw Pressure~psial Ollphase-DBR 64 File 200500215 Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Schlumberger . Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 40 - 42. The fluid properties (i.e., GOR, density and oil formation volume factor) are presented in Table 40. Multi-stage separation test conditions are: STAGE Pb 1574 psia 100 °F STAGE 1 105 psia 125 °F STAGE 2 75 psia 185 °F STAGE STO 15 psia 60 °F As seen in Table 40, the GOR value obtained from the multi-stage separation test is 156 SCF/STB, and the formation volume factor is 1.063, relative to initial saturated volume at 100°F. The compositional analyses of separator gas and tank gas are summarized in Table 41 and the composition of tank liquid is tabulated in Table 42. The total dry gross heat content of the separation gases is calculated to be 1,000 BTU/scf. • • Ollphase-DBR 65 File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 40: Multi-Stage Separation Test Vapor & Liquid Properties Sample RSS (1.11 + 1.12 + 1.13; Cylinder C56 4881-IA; Depth 5553 ft. MD PROPERTY STAGE Pb STAGE 1 STAGE 2 STAGE STO Pressure (psi; 1574 105 75 14.7 Temperature I 100 125 185 60 Liquid Density (g/cm3) 0.9186 0.9447 0.9360 0.9573 Vap. Gravitya 0.571 0.573 0.594 Vap. M,,,,r 16.54 16.60 17.20 Vap Heat Val.° 998 1010 1046 GOR` 0 147 5 4 GORd 0 144 5 4 Sep. FlIFe 1.063 1.015 1.023 1.000 a) Calculated, at 60°F lair=1 i b) GalcWateo, Ury OASIS tS I U/SCT CI SCT gas/U01 UI uii a~ ~ i u cununwna dl scf gas/bbl of oil at separator conditions el fluid volume at sepconditions/fluid volume at STD conditions Residual oil density at standard conditions 0.9573 g/cc Sep gas gravity (average) Sg = ERjSgj/ER 0.572 Where: R: GOR scf gas/bbl of oil at STD contlitionsj, j'. separator stages Sep gas gross heating value (L~ =ERi*L~~Ri 1000 BTU/scf Idry basis) Where: R: GOR (scf gas/bbl of oil at STD conditionsl, j: separator stages SEPARATION TEST SUMMARY aTotal Separation Test GOR 156 Separation Test STO Gravity 16.31 bSeparation Test FVF 1.063 Schlumberger a) scf gas/bbl of condensate at STD conditions b) Fluid volume at Psat & Tres/Fluid volume at STD Ollphase-UBR 66 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: D Sand • Table 41: Multi-Stage Separator Test Vapor Composition (mol %) Sample RSS 11.11 + 1.12 + 1.131; Cylinder CSB 4881-IA; Depth 5553 ft. MD • • Component MW (g/moll Mole STAGE Pb STAGE t STAGE 2 STAGE STO Carbon Dioxide 44.01 0.45 0.66 0.66 Hydrogen Sulfide 34.08 0.00 0.00 0.00 Nitrogen 28.01 1.78 0.91 0.40 Methane 16.04 97.24 97.44 96.73 Ethane 30.07 0.29 0.54 0.81 Propane 44.10 0.11 0.26 0.47 I -Butane 56.12 0.02 0.04 0.08 N -Butane 58.12 0.02 0.05 0.09 I -Pentane 72.15 0.01 0.02 0.04 N -Pentane 72.15 0.01 0.02 0.09 C6 84.00 0.01 0.02 0.05 M-C-Pentane 84.16 0.00 0.00 0.00 Benzene 78.11 0.00 0.00 0.00 Cyclohexane C7 84.16 96.00 0.00 0.01 0.00 0.01 0.00 0.01 M-C-Hexane 98.19 0.00 0.00 0.00 Toluene 92.14 0.00 0.00 0.03 C8 107.00 0.01 0.01 0.01 E-Benzene 106.17 0.00 0.00 0.00 M/P-Xylene 0-Xylene C9 106.17 106.17 121.00 0.00 0.00 0.01 0.00 0.00 0.00 0.04 0.01 0.02 C10 134.00 0.00 0.00 0.02 C11 147.00 0.00 0.00 0.12 C12 161.00 0.00 0.00 0.10 C13 175.00 0.00 O.OD 0.01 C14 190.00 0.00 0.00 0.00 C15 206.00 0.00 0.00 0.00 C16 222.00 0.00 0.00 0.00 C17 237.00 0.00 0.00 0.00 C18 251.00 0.00 0.00 0.00 C19 263.00 0.00 0.00 0.00 C20 275.00 0.00 0.00 0.00 C21 291.00 0.00 0.00 0.00 C22 300.00 0.00 0.00 0.00 C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 0.00 C25 337.00 0.00 0.00 0.00 C26 349.00 0.00 0.00 0.00 C27 360.00 0.00 0.00 0.00 C28 372.00 O.DO 0.00 0.00 C30 382.00 0.00 D.OD 0.00 C30 394.00 0.00 0.00 0.00 C31 404.00 0.00 0.00 0.00 C32 415.00 0.00 0.00 0.00 C33 426.00 0.00 0.00 0.00 C34 437.00 0.00 0.00 0.00 C35 445.00 0.00 0.00 0.00 C36+ 978.00 0.00 0.00 0.00 Total 100.00 100.00 100.00 MW 16.54 16.60 17.20 Relative Density lair=l) Dry Gross Heat Content (BTU/scfl 0.571 998 0.573 1010 0.594 1046 Ollphase-DBR 67 File 200500215 • • • Client: ConocoPhillips Field: West Sak Well: 3J-101 Sand: D Sand Table 42: Multi-Stage Separator Test Residual Liquid Composition (mol %) Sample RSS (1.11 + 1.12 + 1.13); Cylinder CSB 4881-IA; Depth 5553 ft. MD Schlumherger COMPONENT MW 19/mol) Residual Liq. lmol %) Carbon Dioxide 44.01 0.00 Hydrogen Sulfide 34.08 0.00 Nitrogen 28.01 0.00 Methane 16.04 0.00 Ethane 30.07 0.00 Propane 44.10 0.10 I -Butane 58.12 0.02 N -Butane 58.12 0.01 I -Pentane 72.15 0.01 N -Pentane 72.15 0.01 C6 84.00 0.21 M-C-Pentane 84.16 0.03 Benzene 78.11 0.00 yclohexane 84.16 0.00 7 96.00 0.56 M-C-Hexane 98.19 0.00 oluene 92.14 0.00 Cg 1D7.D0 D.08 E-Benzene 106.17 0.00 /P-Xylene 106.17 0.00 -Xylene 106.17 0.01 g 121.00 0.07 10 134.00 0.27 C11 147.00 1.11 12 161.00 2.42 C13 175.00 4.16 C14 190.00 4.67 15 206.00 4.97 C16 222.00 5.14 C17 237.00 4.78 C18 251.00 4.53 C19 263.00 4.68 C20 275.00 4.52 C21 291.00 4.05 C22 300.00 4.07 C23 312.00 3.86 24 324.00 3.17 C25 337.00 3.69 C26 349.00 2.66 27 360.00 3.10 C28 372.00 2.89 C29 382.00 3.00 C30 394.00 1.91 31 404.00 2.25 32 415.00 1.88 C33 426.00 1.36 C34 437.00 1.41 C35 445.00 1.21 36+ 978.00 17.06 oral 100.00 Myy 402.28 Ollphase-DBR m File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: - Installation: - Job #: 200500215 Appendix A: Nomenclature and Definitions API Gravity American Petroleum Institute gravity Bg Gas formation volume factor Bo Oil formation volume factor CCE Constant composition Expansion DV Differential Vaporization GLR Gas Liquid Ratio GOR Gas Oil Ratio LO Live Oil n Number of moles OBM Oil Based Mud P Absolute pressure Pb Bubble point pressure PV Pressure-Volume Method Pi Initial Reservoir Pressure R Universal gas constant Rs Solution gas oil ratio T Temperature V Volume Ur Relative volume STL Stock Tank Liquid STO Stock Tank Oil %, w/w Weight Percent Z Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid. Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses, densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems" by M.B. Standing Compressibility inconstant 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. Ollphase-DBR 69 File 200500215 • • Client: Well: Installation: Ollphase-DBR ConocoPhillips Field: West Sak 3J-101 Sand: - - Job #: 200500215 Schlumberger ~endix B: Molecular Weights and Densities Used Components MW Density ~g/cc~ C02 44.01 0.827 H2 S 34.08 0.993 N2 28.013 0.808 C1 16.043 0.300 C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 N-C4 58.124 0.586 I-C5 72.151 0.625 N-C5 72.151 0.631 C6 84 0.660 MCYC-C5 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0.781 C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 C8 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 0-XYLENE 106.17 0.884 C9 121 0.768 C 10 134 0.782 C 11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 C15 206 0.836 C16 222 0.843 C17 237 0.851 C18 251 0.856 C19 263 0.861 C20 275 0.866 C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0.885 C25 337 0.888 C26 349 0.892 C27 360 0.896 C28 372 0.899 C79 382 0.902 10 bile 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: - Installation: - Job #: 200500215 __ Appendix C: EQUIPMENT F/uid Preparation and validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies. A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer. This unit in conjunction with GC analysis (see below provides the full fluid compositional analysis, GOR, density at sampling P&T corrected to standard conditions. The JEFRI gasometer consists of amotor-driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L. The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 Asia) and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography (GC). • Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FiD1. In this system, separation of individual components is carried out in a 30m Fong, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range, the components eluted are from 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 for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns, and hence, allowing for the correct separation and analysis of the injected gas. Fluid l/olumetiic (PVT) and Viscosity Equipment • Ollphase-DBR 71 File 200500215 Client: ConocoPhillips Field: West Sak Sehlumberger Well: 3J-101 Sand: - Installation: - Job #: 200500215 • The preliminary saturation pressure, constant composition expansion (CCE), differential vaporization (DVj, multi-stage separation tests (MSST) are measured using apressure-volume-temperature IPVT) apparatus. The PVT apparatus consists of a variable volume, visual JEFRI PVT cell. The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm. An especially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury- free operation. The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc. The magnetically coupled impeller mixer, mounted on the bottom end cap of the PVT cell, allow quick equilibration of the hydrocarbon fluid. The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. A variable volume JEFRI displacement pump controls the volume, and hence, the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell is mounted on a special bracket, which can be rotated 360°. The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum resistance thermal detector (RTDj and displayed on a digital indicator with an accuracy of 0.2°F. The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to ± 0.1 % of full scale. The temperature and pressure ratings of this PVT system are 15,000 psi (103 MPa) and 360°F (182°Cj. 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 ahigh-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 ccl corresponding to roughly 0.01 % of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer, which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston. Viscosity is measured by the motion of the piston, which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe. The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig. The accuracy is ±1.5% of full scale for each individual piston range. The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. • Ollphase-DBR 72 File 200500215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: - Installation: - Job #: 200500215 • The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation (OHSPI 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 (NIRI 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 (LSS1. 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. Ollphase-DBR 73 file 2005D0215 Client: ConocoPhillips Field: West Sak Schlumberger Well: 3J-101 Sand: - Installation: - Job #: 200500215 • Appendix D: PROCEDURE f/uids Preparation and !/alidation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio (GOR). The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid. The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids (gas and liquid) are then subjected to compositional analysis using gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values. In addition, asub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently, a quick P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The CCE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps. At each pressure step, the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium. Total fluid volume (with visual observation of a single or two phase condition in the cell) is measured at each pressure stage, and subsequently, apressure-volume IP-V) plot is created identifying the phase state at each P-V condition. The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute live oil compressibility above the bubblepoint pressure and relative oil volumes over the entire pressure range. • Differential f/apoiization 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 (DV) experiment is then conducted by incrementally reducing the pressure in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a DV 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 DV test. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the DV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. Multi=Stage Separation Test ^. Ollphase-DBR 74 File 200500215 Client: ConocoPhillips Field: West Sak Sehlumberger Well: 3J-101 Sand: - Installation: - Job #: 200500215 • Subsequent to the completion of the DV experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A multi-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a separation test is described below: The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the separation test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. 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 Outing 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 ahigh-pressure high-temperature electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer, flashing of oil takes place, and hence, the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps. At each pressure point, the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration. The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock-Tank Oil (STD/ Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. Asphaltene, Wax and Su/fur Content Measurements • Ollphase-DBR 75 File 200500215 Client: ConocoPhillips Field: West Sak Sehlumberger Well: 3J-101 Sand: - Installation: - Job #: 200500215 i Asphaltene content of stock-tank oil samples is conducted using the IP-143 jFrench Institute of Petroleum! procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oit. Wax content of the STO is measured using UOP (Universal Oil Product! 46-64 procedure. The sulfur content of the STO is measured using ASTM D 2494 procedure.. All other STO analysis were measured according to industrial standards. SAA(PlA Ana/ysis A spinning band distillation was carried out on the original sample to establish two fractions. The initial boiling point to 300°C fraction was then analysed using a supercritical fluid chromatographic ~ASTM 5186-91j method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes!. This method dissolves the fraction in an equal weight of toluene, then 40 volumes of pentane were added to precipitate the insoluble portion of the sample. The precipitate was filtered, dried and weighed. The solvent was removed from the soluble portion of the sample, which was referred to as the maltenes. The maltenes were then redissolved in pentane and were chromatographically separated into saturates, aromatics and resins (potars) fraction by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents were then removed from each fraction and the amount of material weighed. The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High-Temperature High Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. • • Ollphase-DBR 76 Fite 200500215 www.slb.com/oilfield WT_03_137_0 ©Schlumberger Schlumberger December 2003 *Mark of Schlumberger
