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205-156
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 5000'feet 1520'feet true vertical 3724' feet 1489' feet Effective Depth measured 1520'feet None feet true vertical 1489' feet None feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 1569' MD 1533' TVD Packers and SSSV (type, measured and true vertical depth) 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: 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 907-265-6218Staff Well Integrity Engineer None None 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 114' ~~~ SUSPENDED ~~ ~ measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-156 50-029-23282-00 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: ADL025641, ADL025634 Kuparuk River Field/ West Sak Oil Pool KRU 1Q-101 Plugs Junk measured Length Production Liner Casing 1790' 114'Conductor Surface Intermediate 20" 10-3/4" 70' 1824' 1746' Burst Collapse 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 8:41 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 11:08:38-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn RBDMS JSB 100225 J.Lau 11/5/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 8, 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 KRU 1Q-101 (PTD 205-156) Dear Commissioner Chmielowski: Enclosed please find the suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 1Q-101(PTD 205- 156). The following documents are attached: - 10-404 Sundry - Suspended Well Inspection - Wellbore Schematic - Location Plot Plan - Photographs 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 11:08:59-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn Casing Strings Casing Description CONDUCTOR String O... 20 String ID ... 19.124 Top (ftKB) 44.0 Set Depth (f... 114.0 Set Depth (TVD) ... 114.0 String Wt... 62.50 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 10 3/4 String ID ... 9.794 Top (ftKB) 33.6 Set Depth (f... 1,823.6 Set Depth (TVD) ... 1,745.7 String Wt... 45.50 String ... L-80 String Top Thrd BTC Tubing Strings Tubing Description Circulating Tubing String String O... 3 1/2 String ID ... 2.992 Top (ftKB) 29.1 Set Depth (f... 1,569.0 Set Depth (TVD) ... 1,532.9 String Wt... 9.30 String ... L-80 String Top Thrd EUE-MOD Completion Details Top (ftKB) Top Depth (TVD) (ftKB)Top Incl (°)Item Description Comment ID (in) 29.1 29.0 -0.07 HANGER VETCO TUBING HANGER 3.500 1,568.5 1,532.5 29.28 SHOE MULE SHOE/COLLAR 2.992 Cement Squeezes Top (ftKB) Btm (ftKB) Top Depth (TVD) (ftKB) Btm Depth (TVD) (ftKB)Description Start Date Comment 1,673.0 1,923.0 1,621.6 1,823.5 Cement Retainer W/ Cement Cap 11/28/2005 Held PJSM with crew and HES tool supervisor on MU of retainer MU Halliburton 10 3/4" csg EZSV cement retainer and RIH to 1,723' on 5" DP Set EZSV retainer at 1,723' with btm at 1,726' and set 25K wt down on retainer, st wt up 55K, dn wt 48K, PU out of retainer Pressure tested retainer and csg to 1,500 psi for 15 min, good test, held PJSM on cementing below retainer Stung back into retainer and est an injection rate at 1 bpm at 280 psi and 2 bpm at 380 psi, bled off pressure and PU out of retainer Dowell pumped 5 bbls water and pressure tested lines to 3,500 psi, mixed and pumped 25 bbls (150 sxs) of AS1 cement at 15.8 ppg, .93 yield and additives, followed with 1.5 bbls water, ave 3.5 bpm, held 200 psi back pressure on choke while spotting cement in DP, spotted to within 5 bbls of retainer, stung into retainer and rig fin displacing cement, rig pumped 25 bbls of 9.5 ppg mud placing 20 bbls of cement below retainer, shut down and PU laying 5 bbls (50') of cement on top of retainer, Est TOC at 1,673', CIP at 07:50 hrs. Calvin Timoty HES tool supervisor Jerry Culpepper cementer 4,000.0 4,500.0 3,059.5 3,383.6 Plug Back 11/27/2005 POOH slow 5 stds from 5,000' to 4,499' Circ btms up at 4,499', saw slight sign of cement contaminated mud at btms up, circ an add. btms up with 9.5 ppg MW in and out, circ at 185 spm, 550 gpm at 1,350 psi, st wt up 90K, dn wt 65K, circ 2X btms up Dowell pumped 10 bbls of water, then mixed and pumped 42.8 bbls (207 sxs) of 15.8, 1.16 yield cement with add., ave 3.8 bpm, initial pressure 210 psi, final pressure 185 psi, followed with 1.5 bbls water, turned over to rig and rig displaced cement with 64 bbls of 9.5 ppg mud to balance plug, ave 6 bpm at 170 psi, slowed to 3 bpm at 400 psi, CIP at 19:35 hrs, est TOC at 4,000', had full returns throughout job and reciprocated pipe throughout job, NOTE: Cement volume was calculated from 4 arm caliper ave 9" hole plus 10% excess and Chuck Scheve with AOGCC waived witnessing of cement plugs 4,500.0 5,000.0 3,383.6 3,723.8 11/27/2005 Circ hole clean for cement job evening MW in and out at 9.5 ppg, circ hole at 183 spm, 545 gpm at 1,300 psi, st wt up 95K, dn wt 70K, circ 2X btms up, held PJSM with rig crew, Dowell and ASRC vac truc drivers Turned over to Dowell and pumped 5 bbls water, pressure tested lines to 3,500 psi, cont to pump 5 add. bbls of water, mixed and pumped 43.2 bbls (209 sxs) of 15.8 ppg, 1.16 yield cement with additives, ave 4 bpm, initial pressure 250 psi, final 130 psi, followed with 1.3 bbls of water, turned over to rig and pumped 73 bbls of 9.5 ppg mud to balance plug, ave 6 bpm at 130 psi, slowed to 3 bpm at 300 psi, CIP at 17:25 hrs, est TOC at 4,500', had full returns during job and reciprocated pipe throughout job Notes: General & Safety End Date Annotation 11/29/2005 NOTE: DRILLING ON WELL SUSPENDED 11/29/2005 9/5/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: NONEWell Config: - 1Q-101, 9/5/2009 2:38:45 PM Schematic - Actual TD, 5,000 Abandonment Plug, 4,500 Abandonment Plug, 4,000 Suspension Plug, 1,673 SURFACE, 34-1,824 SHOE, 1,569 CONDUCTOR, 44-114 HANGER, 29 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: Build wellbore/casings, tag Last Mod By lmosbor End Date 9/5/2009 KUP KB-Grd (ft) Rig Release Date 11/29/2005 Annotation Last WO: End Date 1Q-101 H2S (ppm) Date... TD Act Btm (ftKB) 5,000.0 Well Attributes Wellbore API/UWI 500292328200 Field Name WEST SAK Well Status SUSPENDED Max Angle & MD Incl (°) 58.25 MD (ftKB) 2,565.45 “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.” “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:susSTS250908104706 Well Pressures (psi): Date Inspected:9/6/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:11/29/2005 #305-365 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 1Q-101 Permit Number:2051560 Wellhead Condition Clean, no sign of leaks, valves turned easily. Well head separated from flowline Surrounding Surface Condition clean pad, no subsidence Condition of Cellar Clear water in cellar clear/ no sheen, no trash in cellar Comments This well is a monobore well. The gauges on the tree were accurate and verified with digital gauges. Location verified by plot map. Supervisor Comments Photos (2) 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 2025-0906_Suspend_KRU_1Q-101_photos_ss Page 1 of 1 Suspended Well Inspection – KRU 1Q-101 PTD 2051560 AOGCC Inspection Rpt # susSTS250908104706 Photos by AOGCC Inspector S. Sullivan 9/6/2025 Suspended Well Inspection Review Report InspectNo: susBDB200518051320 Date Inspected: 5/16/2020 Inspector: Brian Bixby Type of Inspection Well Name: KUPARUK RIV U WSAK 1Q-101 - Permit Number: 2051560 Suspension Approval: Sundry 305-365 ' Suspension Date: 11/29/2005 Location Verified? W If Verified, How? Other (specify in comments) Offshore? ❑ Subsequent Date AOGCC Notified: 4/27/2020 Operator: ConocoPhillips Alaska, Inc. Operator Rep: Roger Winter Wellbore Diagram Avail? W Photos Taken? ❑4 Well Pressures (psi): Tubing: 0 Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ OA: 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 The surrounding area is covered with snow Comments Location verified by as -built pad map. Monobore completion so there is no OA. Supervisor Comments Location should be snow and ice free before performing suspended well inspection. Photo (1) Friday, June 5, 2020 Suspended Well Inspection — KRU 1Q-101 PTD 2051560 Photo by AOGCC Inspector B. Bixby 5/16/2020 1 ConocoPhillips Alaska Well Name. KRU WSAK IQ -191 API Number, 50-029-27282-00-00 PM 205-155 Off. WOW: 1574' FRL, 118P Fit, Sec. 28, T12M, RBE. UTA _ .. A,M 2020-0516 suspend_KRU_1Q-101_photo_bb.doex Page I of 1 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: Suspended Well Renewal 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.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?NA 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): 5000 Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Authorized Name: Jan Byrne Contact Name:Jan Byrne/Dusty Freeborn Authorized Title: Well Integrity Compliance Specialist Contact Email:N1617@conocophillips.com Contact Phone: 907-659-7224 Date:6/13/2020 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 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: NA 3.5 NA Perforation Depth MD (ft): NA NA 20 10.75 70 1790 114 1746 114 1824 L-80 TVD Burst 1569 MD 205-156 P.O. Box 100360, Anchorage, Alaska 99510 50-029-23282-00-00 ConocoPhillips Alaska, Inc Length Size KRU West Sak 1Q-101 Kuparuk River Field / West Sak Oil Pool 1673 1622 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 ADL 25641, 25634 3724 COMMISSION USE ONLY Tubing Grade:Tubing MD (ft): NA m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:22 am, Jun 15, 2020 320-258 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-06-13 08:55:07 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conoco phillips.com DLB 06/15/20 X 10-404 DSR-6/15/2020VTL 6/17/20 X Comm. 6/17/2020 dts 6/17/2020 JLC 6/17/2020 RBDMS HEW 6/18/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 13 June 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of Suspended Well 10-403 Status Kuparuk River Unit West Sak 1Q-101 (PTD 205-156) Dear Commissioner Chmielowski, ConocoPhillips Alaska Inc. (CPAI) hereby submits a request for renewal of the suspension status of Kuparuk River Unit West Sak well 1Q-101 (PTD 205-156) per 20 AAC 25.110. The well was visually inspected on May 16, 2020 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 wellbore is isolated with a cement plug. - The well is on an active pad. CPAI request the renewal of the suspension because the well is being held for future rotary development. Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-06-13 08:53:47 Foxit PhantomPDF Version: 9.7.0 jan.byrne@c onocophillips .com Casing Strings Casing Description CONDUCTOR String O... 20 String ID ... 19.124 Top (ftKB) 44.0 Set Depth (f... 114.0 Set Depth (TVD) ... 114.0 String Wt... 62.50 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 10 3/4 String ID ... 9.794 Top (ftKB) 33.6 Set Depth (f... 1,823.6 Set Depth (TVD) ... 1,745.7 String Wt... 45.50 String ... L-80 String Top Thrd BTC Tubing Strings Tubing Description Circulating Tubing String String O... 3 1/2 String ID ... 2.992 Top (ftKB) 29.1 Set Depth (f... 1,569.0 Set Depth (TVD) ... 1,532.9 String Wt... 9.30 String ... L-80 String Top Thrd EUE-MOD Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment ID (in) 29.1 29.0 -0.07 HANGER VETCO TUBING HANGER 3.500 1,568.5 1,532.5 29.28 SHOE MULE SHOE/COLLAR 2.992 Cement Squeezes Top (ftKB) Btm (ftKB) Top Depth (TVD) (ftKB) Btm Depth (TVD) (ftKB)Description Start Date Comment 1,673.0 1,923.0 1,621.6 1,823.5 Cement Retainer W/ Cement Cap 11/28/2005 Held PJSM with crew and HES tool supervisor on MU of retainer MU Halliburton 10 3/4" csg EZSV cement retainer and RIH to 1,723' on 5" DP Set EZSV retainer at 1,723' with btm at 1,726' and set 25K wt down on retainer, st wt up 55K, dn wt 48K, PU out of retainer Pressure tested retainer and csg to 1,500 psi for 15 min, good test, held PJSM on cementing below retainer Stung back into retainer and est an injection rate at 1 bpm at 280 psi and 2 bpm at 380 psi, bled off pressure and PU out of retainer Dowell pumped 5 bbls water and pressure tested lines to 3,500 psi, mixed and pumped 25 bbls (150 sxs) of AS1 cement at 15.8 ppg, .93 yield and additives, followed with 1.5 bbls water, ave 3.5 bpm, held 200 psi back pressure on choke while spotting cement in DP, spotted to within 5 bbls of retainer, stung into retainer and rig fin displacing cement, rig pumped 25 bbls of 9.5 ppg mud placing 20 bbls of cement below retainer, shut down and PU laying 5 bbls (50') of cement on top of retainer, Est TOC at 1,673', CIP at 07:50 hrs. Calvin Timoty HES tool supervisor Jerry Culpepper cementer 4,000.0 4,500.0 3,059.5 3,383.6 Plug Back 11/27/2005 POOH slow 5 stds from 5,000' to 4,499' Circ btms up at 4,499', saw slight sign of cement contaminated mud at btms up, circ an add. btms up with 9.5 ppg MW in and out, circ at 185 spm, 550 gpm at 1,350 psi, st wt up 90K, dn wt 65K, circ 2X btms up Dowell pumped 10 bbls of water, then mixed and pumped 42.8 bbls (207 sxs) of 15.8, 1.16 yield cement with add., ave 3.8 bpm, initial pressure 210 psi, final pressure 185 psi, followed with 1.5 bbls water, turned over to rig and rig displaced cement with 64 bbls of 9.5 ppg mud to balance plug, ave 6 bpm at 170 psi, slowed to 3 bpm at 400 psi, CIP at 19:35 hrs, est TOC at 4,000', had full returns throughout job and reciprocated pipe throughout job, NOTE: Cement volume was calculated from 4 arm caliper ave 9" hole plus 10% excess and Chuck Scheve with AOGCC waived witnessing of cement plugs 4,500.0 5,000.0 3,383.6 3,723.8 11/27/2005 Circ hole clean for cement job evening MW in and out at 9.5 ppg, circ hole at 183 spm, 545 gpm at 1,300 psi, st wt up 95K, dn wt 70K, circ 2X btms up, held PJSM with rig crew, Dowell and ASRC vac truc drivers Turned over to Dowell and pumped 5 bbls water, pressure tested lines to 3,500 psi, cont to pump 5 add. bbls of water, mixed and pumped 43.2 bbls (209 sxs) of 15.8 ppg, 1.16 yield cement with additives, ave 4 bpm, initial pressure 250 psi, final 130 psi, followed with 1.3 bbls of water, turned over to rig and pumped 73 bbls of 9.5 ppg mud to balance plug, ave 6 bpm at 130 psi, slowed to 3 bpm at 300 psi, CIP at 17:25 hrs, est TOC at 4,500', had full returns during job and reciprocated pipe throughout job Notes: General & Safety End Date Annotation 11/29/2005 NOTE: DRILLING ON WELL SUSPENDED 11/29/2005 9/5/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: NONEWell Config: - 1Q-101, 9/5/2009 2:38:45 PM Schematic - Actual TD, 5,000 Abandonment Plug, 4,500 Abandonment Plug, 4,000 Suspension Plug, 1,673 SURFACE, 34-1,824 SHOE, 1,569 CONDUCTOR, 44-114 HANGER, 29 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: Build wellbore/casings, tag Last Mod By lmosbor End Date 9/5/2009 KUP KB-Grd (ft) Rig Release Date 11/29/2005 Annotation Last WO: End Date 1Q-101 H2S (ppm) Date... TD Act Btm (ftKB) 5,000.0 Well Attributes Wellbore API/UWI 500292328200 Field Name WEST SAK Well Status SUSPENDED Max Angle & MD Incl (°) 58.25 MD (ft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igitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-05-19 16:47:57 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conocophillip s.com By Samantha Carlisle at 8:11 am, May 20, 2020 On beh alf of Stev e D (ste ve.d avie s@ alas ka.g ov) -00 On behalf of Steve D (steve.davies@ alaska.gov) SFD 5/21/2020 VTL 5/26/20 RBDMS HEW 5/22/2020 DSR-5/20/2020 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-05-19 16:47:26 Foxit PhantomPDF Version: 9.7.0 jan.byrne@c onocophillips. com # $$$ $$$ %&'( %&$$$ %" ($$$ $$$ $$$ ) # $$$ $$$ %&'( %&$$$ %" ($$$ $$$ $$$ ) * * # !"#$% &'"( &' % &' $$$ $$$ %&'( %&$$$ %" ($$$ $$$ $$$ ) ) + %&'( %" ( %&'( # %,( + # ++ % ( * + ,** ) + - %&'( +%&'( %" ( %&'( + %" ( %&'( # ++ -.-&%-%$ &- -.-&%$/ -#012)3 %4! -3$&0%55#6"/- 7 65 5&) 58 -%$ &- )$## (" %5& 9!6':+!-.-&% -%$ &- $&0,%5 ;5&91 -%:+ -%$ &- $% ;3 %4(%.$% ;$&0 6-%<3%053&5& -%$ &- 6%3%"/< 0&3% < 15"%58 -%$ &- 1 -66" -%-6%-0 -%$ &- $&0!6'%5 /6 85 . & '550%-6% 4-#012)5&!-.-&% &'(-#53 -%$ &- %"&'($!= &%5 -%$ &- $&0-6%$& &>-!% 5& $%-$% (/.$% /6 $&0(/.$% /6 (#-0588 / -66" -$&015"%58 -%$ &- 53-##/"./-0((#63$%- $&0/ -66" -%-6%-0 # &-6%5 /6 . ?-0$&0/"./-0((#6@ 6?6A58 !-.-&%$% //' B -#0$&0 $00 % 7-6 85##53-03 %4 ((#63$%- $7- (/. 4-#0 /6 ($!=/ -66" -5&!45=-34 #-6/5%% &' !-.-&% &1 6/5%%-0%53 %4 &((#658 -%$ &- 6%"&' &%5 -%$ &- $&0 '8 &0 6/#$! &'!-.-&% ' /"./-0((#658 //'."0/#$! &' ((#658 !-.-&%(-#53 -%$ &- 64"%053&$&01#$B &' ((#6@ ;A58!-.-&%5&%5/58 -%$ &- 6%$% ; ,1$% C 4 6 $#7 & .5%B%55#6"/- 7 65 2- B"#/-//- !-.-&%- 1#"' $!= 16#536%068 5. ;%5 ; !(%.6"/$% ; 6$36# '4%6 '&58!-.-&% !5&%$. &$%-0."0$%(%.6"/ ! !$&$00 (%.6"/ 3 %4 //') &$&05"% ! !$% 6/. 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r,oKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other.Suspend Well Inspect 2.Operator Name. 4 Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 205-156 3 Address. 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23282-00 7.Property Designation(Lease Number): 8 Well Name and Number: ADL 25641,25634 KRU West Sak 1 Q-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 5000 feet Plugs(measured) 1723 true vertical 3724 feet Junk(measured) none Effective Depth measured 1673 feet Packer(measured) None true vertical 1622 feet (true vertical) None Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 20 114 114 1640 630 SURFACE 1790 18 1824 1746 5210 2470 E° JUL '�� RECEIVED Perforation depth. Measured depth: None .J U N 3 0 2015 True Vertical Depth: None AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 1569 MD, 1533 TVD Packers&SSSV(type,MD,and TVD) None 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 p- 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 O.Exempt NA _ Contact MJ Loveland/Martin Walters Email N1878(c�conocophillips.com Printed Name MJ Loveland Title WI Project Supervisor Signature /Phone 659-7043 Date 6 of v/s......_ _,.._e,/ //17 vT1- 7`9015— RBDMS JUL - 1 2015 Form 10-404 Revised 5/2015 Submit Original Only I-' ConocoPhillips RECEIVED Alaska JUN 3 0 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC 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 1Q-101 (PTD 205-156) 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 1Q-101 (PTD 205-156). 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 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT/WSAK 1Q-101 Field/Pool: KUPARUK RIVER/WEST SAK Permit#(PTD): 205-156 Sundry 305-365 API Number: 50-029-23282-00-00 Operator. ConocoPhillips Alaska, Inc. Date Suspended: 11/29/2005 Surface Location: 1574' FNL, 1160' FEL Section: 26 Township: 12N Range: 9E Nearest active pad or road: KRU DS1Q 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: Good Surrounding area condition: Good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: water Samples taken: none Access road condition: good Photographs taken (#and description): 3 photos of well and area 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: water Rat Hole: NA Wellhouse or protective barriers: NA Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 PSI Annulus pressures: 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: 1345 Time of Departure: 1350 Site access method: Truck t KUP 1Q-101 ConocoPhillips i Well Attributes Max An le&MD TD Ala$ka i, Wellbore API/UWI Field Name Well Status [onomehilaps 500292328200 WEST SAK SUSPENDED 5,000.0 H25(ppm) Dote Annotation End Date KB-Grd(ft) Rig Release Date Well Confit:-10-101,9/"./20092:38:45 PM • LBSt WO: 11292005 Schematic•Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:Build wellbore/casings,tag Imosbor 9/5/2009 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 20 19.124 44.0 114.0 114.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(11KB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd SURFACE 103/4 9.794 33.6 1,823.6 1,745.7 45.50 L-80 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd Circulating Tubing 31/2 2.992 29.1 1,569.0 1,532.9 9.30 L-80 EUE-MOD String I Com k letion Details HANGER,29- Top Depth (TVD) Top Incl Top(ftKB) (ftKB) (") item Description Comment ID(in) ' - --- 29.1 29.0 -0.07 HANGER VETCO TUBING HANGER 3.500 1,568.5 1,532.5 29.28 SHOE MULE SHOE/COLLAR Cement S.ueezes Top Depth Btm Depth Description Start Date Comment 1 1,923.0 Cement Retainer 11/28/2005 Held PJSM with crew and HES tool supervisor on MU W/Cement Cap of retainer MU Halliburton 10 3/4"csg EZSV cement retainer and RIH to 1,723'on 5"DP Set EZSV retainer at 1,723'with btm at 1,726'and set 25K wt down on retainer,st wt up 55K,dn wt 48K, PU out of retainer Pressure tested retainer and csg to 1,500 psi for 15 min,good test,held PJSM on cementing below retainer Stung back into retainer and est an injection rate at 1 bpm at 280 psi and 2 bpm at 380 psi,bled off pressure and PU out of retainer Dowell pumped 5 bbls water and pressure tested lines to 3,500 psi,mixed and pumped 25 bbls(150 CONDUCTOR._ sxs)of AS1 cement at 15.8 ppg,.93 yield and as-t to additives,followed with 1.5 bbls water,ave 3.5 bpm, held 200 psi back pressure on choke while spotting cement in DP,spotted to within 5 bbls of retainer, stung into retainer and rig fin displacing cement,rig ■ pumped 25 bbls of 9.5 ppg mud placing 20 bbls of cement below retainer,shut down and PU laying 5 bbls(50)of cement on top of retainer,Est TOC at % 1,673',CIP at 07:50 hrs. SHOE t say - Calvin Timoty HES tool supervisor Jerry Culpepper cementer 4,000.0 4,500.0 i .Plug Back 11272005 POOH slow 5 stds from 5,000'to 4,499' Circ btms up at 4,499',saw slight sign of cement I contaminated mud at btms up,circ an add.btms up i with 9.5 ppg MW in and out,circ at 185 spm,550 gpm at 1,350 psi,st wt up 90K,do wt 65K,circ 2X btms up Dowell pumped 10 bbls of water,then mixed and pumped 42.8 bbls(207 sxs)of 15.8,1.16 yield cement with add.,ave 3.8 bpm,initial pressure 210 psi,final pressure 185 psi,followed with 1.5 bbls water,turned over to rig and rig displaced cement with 64 bbls of 9.5 ppg mud to balance plug,ave 6 bpm at 170 psi,slowed to 3 bpm at 400 psi,CIP at 19:35 hrs,est TOC at 4,000',had full returns throughout job and reciprocated pipe throughout job, NOTE:Cement volume was calculated from 4 arm caliper ave 9"hole plus 10%excess and Chuck Scheve with AOGCC waived witnessing of cement plugs 4,500.0 t t t i 11272005 Circ hole clean for cement job evening MW in and out at 9.5 ppg,circ hole at 183 spm,545 gpm at 1,300 psi,st wt up 95K,dn wt 70K,circ 2X btms up,held PJSM with rig crew,Dowell and ASRC vac truc drivers Turned over to Dowell and pumped 5 bbls water, pressure tested lines to 3,500 psi,cont to pump 5 add.bbls of water,mixed and pumped 43.2 bbls(209 SURFACE. soS 34-1.824 )of 15.8 ppg,1.16 yield cement with additives, ave 4 bpm,initial pressure 250 psi,final 130 psi, followed with 1.3 bbls of water,turned over to rig and pumped 73 bbls of 9.5 ppg mud to balance plug,ave 6 bpm at 130 psi,slowed to 3 bpm at 300 psi,CIP at Suspension 17:25 hrs,est TOC at 4,500',had full returns during Plug.1.673 job and reciprocated pipe throughout job Notes:General&Safety End Date Annotation 11/29/2005 NOTE:DRILLING ON WELL SUSPENDED 11/29/2005 9/5/2009 NOTE:VIEW SCHEMATIC w/Alaska Schemafic9.0 Abandonment Plug,4,000 Abandonment Plug,4,500 TD,5,000 ` +00+ZL N g + + + l4 a m 6j7O T1 Z ..- 3 r v_ O x Z wcJ i i i —\\ w J O.. m oa°~ 0 +OO+bI N + / \+/ \ + L, Z a O J I d H a a 0 in- V) z Go O t^o U z +00+91 N +0 -. .5 + s O.+ + d i. i Z —• co x Li O ¢ El!iIL_ • h Q O 0' V10x-0M O' 0 V o 0 181 1•—•a- mss'. 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Yes Oper. Email: If Verified,How? LAT/LONG • Onshore/Offshore: Onshore Suspension Date: 11/29/05 _ Date AOGCC Notified: 06/25/15 Sundry No.: 305-365 __ Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 - Photos Taken? Yes IA 0 OA 0 " (, Condition of S1r1'�1�"�© AUG 1 9 2015 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(3) — REVIEWED BY: Insp.Supry /z 7/z4//c Comm PLB 06/2014 2015-0627_Suspend_KRU_10-101Jh.xlsx Suspended Well Inspection—KRU 1Q-101 PTD 2051560 Photos by AOGCC Inspector J. Hill 6-27-2015 • Ar4,„; 11111•1114 u' p � t � ConocoPhiilips _ WR 1081888K -Ipl - no, soon 2#82-80-08 M soon - Bp.20.moan'M _ • a I"c r. x. 2015-0627_Suspend_KRU_1Q-101 photosjh.docx Page 1 of 2 tom___. IMPPINI olmilimisminal ommems..---.---w Conoco,-Phillips • rR 111A-Se - _ 2015-0627_Suspend_KRU_1 Q-101photos jh.docx 2 Page 2 of 2 205-�S�o Schiumberger Fluid Analysis on Bottomhole MDT Samples ConocoPhillips Field:West Sak Well:10-101 Black Oil PVT Study Report Prepared for Dennis Wegener ConocoPhillips Standard Conditions Used: Pressure: 14.696 psia Temperature:60°F SCANNED JUN 2 4 2015 Prepared by: Stefan Smuk Schlumberger WCP Oilphase-DBR 16115 Park Row,Suite 150 Houston,Texas,77084 (281)285-6370 Date:3/29/2006 Report#200500199 Client ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 Table of Contents List of Figures 2 List of Tables 3 EXECUTIVE SUMMARY 5 Objective 5 Introduction 5 Scope of Work 5 Results 5 PVT Study Data Quality Check Summary 7 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 1.06 C;.Cy.linder.CSB.1.17977QA;.Depth4293ft..MD 36 Constant Composition.Expansion at Tres 36 Reservoir Oil Viscosity at Tres 38 Single-Stage Separation Test 40 Viscosity Analysis on.Sample.1.06.0 44 Reservoir Oil Viscosity at Tres 44 Reservoir Oil Viscosity at 850°F 46 Reservoir Oil Viscosity at 90°F 48 Reservoir Oil Viscosityat 50°F 50 Density at Various Temperatures 52 Appendix A:Nomenclature and Definitions 55 Appendix B:Molecular Weights and.Densities Used 56 Appendix C:EQUIPMENT 57 Fluid Preparation and Validation 57 Fluid Volumetric.(PVT)and Viscosity Equipment 57 Appendix D:PROCEDURE 60 Fluids Preparation and Validation 60 Constant Composition Expansion Procedure 60 Differential Vaporization Procedure 60 Multi-Stage Separation Test 60 Liquid Phase Viscosity and.Density Measurements During DV Step 61 Stock-Tank Oil(STD)Viscosity.and.Density Measurements 61 Asphaltene,Wax and Sulfur Content Measurements 61 SAR(P/A Analysis .. 62 High-Temperature High Pressure.Filtration.Test 62 WCP Oilphase-DBR 1 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 List of Figures Figure 1:Stock Tank Oil Chromatogram(Sample 1.05) 15 Figure 2:k-Plot for Equilibrium.Check(Sample 1.05) 15 Figure 3:Stock Tank Oil.Chromatogram(Sample LOG) 18 Figure 4:k-Plot for Equilibrium Check(Sample 1.06) 18 Figure 5:Stock Tank.Oil Chromatogram(Sample 1.09) 21 Figure 6:k-Plot for Equilibrium Check(Sample 1.09) 21 Figure 7:Stock Tank Oil Chromatogram(Sample 1.10) 24 Figure 8:k-Plot for Equilibrium Check(Sample.1.10) 24 Figure 9:Stock Tank Oil Chromatogram(Sample 1.11) 27 Figure 10:k-Plot for Equilibrium Check(Sample.1.11) 27 Figure 11:Stock Tank.Oil Chromatogram(Sample 1.05 C) 31 Figure 12:k-Plot for Equilibrium Check(Sample.1.05 C) 31 Figure 13:Stock Tank Oil Chromatogram.(Sample 1.06 C) 34 Figure 14:k-Plot for Equilibrium Check(Sample 1.06 C) 34 Figure 15:Constant Composition.Expansion.at.67.0°.F.-.Relative.Volume 37 Figure 16:Reservoir Fluid Viscosity 67°F 39 Figure 17:Reservoir Fluid Viscosity 67°F 45 Figure 18:Reservoir Fluid Viscosity 150°F 47 Figure 19:Reservoir Fluid Viscosity 90°F 49 Figure 20:Reservoir Fluid Viscosity 50°F 51 Figure 21:STO Density vs.Temperature 53 Figure 22:Simulated Monophysical Density at.3000.pale.vs..Temperature 54 WCP Oilphase-DBR 2 Job#:200500199 2 i Client: ConocoPhillips Field: West Sak Well: 1 0-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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 12 Table 6:C30+Composition,GOR,°API,by Zero-Flash.(Sample.1.05) 13 Table 7:Calculated Fluid Properties 14 Table 8:C30+Composition,GOR,°API,by.Zero-Flash.(Sample 1.06) 16 Table 9:Calculated fluid Properties 17 Table 10:C30+Composition,GOR°API,by Zero-Flash.(Sample 1.09) 19 Table 11:Calculated.Fluid.Properties 20 Table 12:C30+Composition,6011,°API,by Zero-Flash.(Sample.1.1.0) 22 Table 13:Calculated FluLd Properties . ........ . .. . 23 Table 14:C30+Composition,.GOR.°API,by Zero-Flash.(Sample 1.11) 25 Table 15:Calculated.Fluid.Properties. 26 Table 16:Calculated Synthetic Gas.Composition 28 Table 17:Physical Composition.of the Syn.Gas Prepared.in.the Lab 28 Table 18:C30+Composition,.GDR,.°API,by Zero-Flash.(Sample 1.05.C) 29 Table 19:Calculated Fluid Properties-_. 30 Table 20:C30+Composition,.GDR,°API,by Zero-Flash.(Sample.1.06.C) 32 Table 21:Calculated Fluid Properties 33 Table 22:Summary.of.Results of Sample 1.06C. 35 Table 23:Constant Composition.Expansion.at67.0°.F.(Sample.1.06.C) 36 Table 24:Reservoir Fluid Viscosity 67°F 38 Table 25:Single-Stage Separation Test.Vapor&Liquid Properties 41 Table 26:Single-Stage Separator Test Vapor Composition.(mol.%) 42 Table 27:Single-Stage.Separator Test Residual.Liguid.Composition.(mol.%). 43 Table 28:Reservoir.Fluid Viscosity 67°F 44 Table 29:Reservoir Fluid Viscosity.150°F 46 Table 30:Reservoir Fluid Viscosity 90°F 48 Table 31:Reservoir Fluid Viscosity 50°F 50 Table 32:STO Density vs..Temperature 53 Table 33:Simulated Monaphysical Density at.3000.psia.vs..Temperature 54 WCP Oilphase-DBR 3 Job*200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 EXECUTIVE SUMMARY Objective To evaluate the composition and phase behavior of the bottomhole fluid samples collected during the modular formation dynamics testing(MDT). Introduction At the request of ConocoPhillips, Oilphase-DBR has conducted a fluid analysis study on bottomhole fluid samples collected during the modular formation dynamics testing(MDT)of Well 1Q-101 drilled in the field West Sak. Scope of Work • Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for one • Conduct the quick API check and water content check on the STO samples. • Conduct preliminary evaluation on bottomhole hydrocarbon samples that include single-stage flash Gas-Oil Ratio (GOR), reservoir fluid composition, stock-tank oil (STO) and monophasic fluid • Select a representative sample for de-emulsification. • Use de-emulsified sample for PVT study. • Transfer 200 cc de-emulsified sample to another cylinder and saturate it with syn gas. For this condittioned sample, • Conduct a Constant Composition Expansion(CCE)test at the reservoir temperature. • Conduct a single-stage separation test at the specified conditions. • Also conduct viscosity measurements of the oil at the reservoir temperature. Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon and water samples: • Six bottomhole samples were used for validation purposes. They were homogenized at the reservoir conditions for one day and heated for another day without rocking in vertical position. • Sample 1.01 was pushed out from the top of the cylinder and it was clear water-look without any trace of oil.We recommend to get the GWR and gas composition,water analysis if needed but should it be just filtrate,then blowdown. • For the quick API check, sample 1.05, 0.9440 @ 60 F, API: 18.4, water content: 1.0% from top; sample 1.09, 0.9475 @ 60 F, API: 17.8, water content: 1.9% from top; sample 1.10, 0.9476 @ 60 F, API: 17.8, water content: 1.7% from top; sample 1.11, 0.9485 @ 60 F, API: 17.8, water content: • The zero flash GOR of the hydrocarbon samples was determined to be from 117 - 133 SCF/STB,and the STO density to be from 0.945-0.948 g/cc. • Sample 1.10 was chosen for the de-emulsification. After the de-emulsification, lab collected 60 cc water and 30 cc mixture of sediment and oil from the bottom of the cylinder. Lab stopped draining out the sediment from the bottom since there is no clear cut between sediment and oil after that 30 cc push out. The BS&W from the top is 0.5%. The remaining sample volume isn't enough for the • Sample 1.05 was chosen for the de-emulsification. After the de-emulsification, lab collected 180 cc water and sediment from the cylinder bottom. The top sample was used for the testing but the Pb was 896 psia at 72°F. Apparently the sample lost some gas during the sampling due to the high WCP Oilphase-DBR 4 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 • Sample 1.05 was saturated with syn gas to reach a Pb close to the reservoir pressure. However,this conditioned sample was unfortunately contaminated at C10 and C11 residue from the transfer cylinder.That contamination may be the rinse solvent used by a 3rd party. • With client's approval, sample 1.06 was used to replace sample 1.05. The prelim testing the de- emulsification were conducted. 250 cc water and sediment were drained out from the bottom and the BSW from top is nil.Then we transferred 200 cc 1.06 from CSB 14332-QA to CSB 11797-QA and pushed out another 15 cc from the original cylinder. That 15 cc STO had no water and sediment. After that,we saturated that 200 cc in CSB 11797-QA with syn gas and re-verified the composition. The conditioned sample is valid for further PVT testing. • Subsequently,conditioned sample 1.06 was used for full PVT study. The following are the results of the reservoir fluids: The bubble point pressure at reservoir temperature was determined to be 1,399 psia. The reservoir fluid viscosity of conditioned sample 1.06 was measured to be 150.7 cP at bubblepoint pressure and 152.0 cP at the initial pressure. The stock tank oil viscosity at 67°F was measured as 708.9 cP. FLASHING CUMULATIVE API Gas Relative FVF FVF OPERATION GOR GRAVITY Density(air=1) at Pres/Tres at Psat/Tres Zero Flash 173 18.1 0.610 1.051 1.051 Separator Test 171 18.4 0.609 1.049 1.049 WCP Oilphase-DBR 5 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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(QHSE)requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE 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. c) Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency d) The responsible Project Engineer confirms consistency of reported data 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 pm-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.:200500199 Laboratory Records:200500199 Data Quality Data Reporting Suyu Ye Meisong Yan Data Quality Engineer Project Engineer Overall Report Quality Clay Young Clay Young Oilphase-DBR Operation Manager,NGC WCP Oilphase-DBR 6 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 Sequence of Events 12/06/05 Samples arrived and client was informed. 12/09/05 Project work scope discussed. 12/09/05 Work agreement approved. 12/09/05 Prelim PVT tests request for five samples issued. 12/12/05 Quick API check results were sent to client via e-mail. 12/29/05 Sample PVT prelim results sent via e-mail. 01/25/06 PVT testing scope approved by client 01/31/06 Pb result for sample 1.05 was reported to client 02/14/06 PVT testing postponed due the low Pb of the sample 1.05 03/08/06 Revised testing plan approved by client 03/29/06 PVT testing results sent to client Chain of Sample Custody The samples collected from the well 1Q-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. WCP Oilphase-DBR 7 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 RESULTS AND DISCUSSIONS Fluids Preparation and Analysis Six bottomhole samples collected during MDT operations were transferred to Oilphase-DBR. One sample from the D Sand of well 10-101 was recovered, along with five B-Sand samples. The well and formation data with their respective reservoir conditions for 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 1-day of homogenization, sample validation tests were conducted to evaluate the validity of the samples. Some sample-quality issues were observed, making the received fluids unrepresentative for use in PVT analysis as received. The reservoir fluid and stock-tank oil properties for all the samples are presented in Tables 4 and 5. Reservoir Fluid Analysis The gas and liquid from zero flash were subjected to chromatography and their compositions were determined. These compositions were recombined mathematically according to single-stage flash Gas-Oil Ratio (GOR) to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Table 6, 8, 10, 12 and 14. 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 7, 9, 11,13 and 15. Sample 1.01,when pushed out from the top of the cylinder,appeared clear,without any traces of oil. Sample 1.10 was chosen for the de-emulsification. After the de-emulsification, the laboratory collected 60 cc water and a 30-cc mixture of sediment and oil from the bottom of the cylinder. Drainage of sediment was stopped after 30 cc, because no progressive clarificaton of the oil was evident. The BS&W from the supernatant oil was 0.5%. Due to limited sample volume in sample 1.10, sample 1.05 was chosen for demulsification prior to continuing with PVT testing.After the demulsification, 180 cc of water and sediment were drained. The water content from the top of the cylinder was 0.2 wt%, while the water content from the bottom was 5.2 wt%. The top part of sample 1.05 was considered valid for the PVT testing. However, during the CCE testing on de-emulsified sample 1.05 at the field-report temperature (72 °F(, the saturation point was found to be 896 psia. This was close to the reported sampling pressure of 915 psia, which is inconsistent with expected saturation point of 1450 psia. Therefore, sample 1.05 may have been depleted during sampling and was in fact not representative for further testing. After discussing with client, an equation of state simulation was used to predict the composition of gas depleted from sample 1.05. A synthetic gas mixture was prepared. 200 cc of the supernatant from 1.05 was transferred to another cylinder, and the BS&W was measured. The BS&W was zero. The transferred liquid was 'saturated' with the synthetic gas to the specified reservoir pressure,for use in PVT analysis. The conditioned sample 1.05 had a bubble point of 1390 psia at 67°F. However,a compositional check revealed a possibility of contamination with C10 and C11,possibly from a solvent-rinse performed by a third party. WCP Oilphase-DBR 8 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 After discussion with the client, sample 1.05 was blown down and sample 1.06 was used to replace sample 1.05. De-emulsification was conducted. The laboratory drained out 250 cc water and sediment, and checked the water content from the top, which was nil. 200 cc was transferred and verified to contain zero water and sediment. Finally, as with sample 1.05, sample 1.06 was'saturated' with a synthetic gas at Tres &Pres. The bubble point of this revised fluid was measured to be 1399 psia. The composition of this revised fluid was measured and further PVT testing was conducted. WCP Oilphase-DBR 9 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 Table 1:Well and Sample Identification Client: ConocoPhillips Job# 200500199 Field: West Sak Well: 1Q-101 Sample ID Chamber# Zone Sampling Date Opening Pres. Reservoir Conditions in the field Pressure Temperature Depth (psia/°F) (psia) (°F) (ft) 1.01 MPSR 1399 D Sand 25/11/2005 6515/100 1,417 72 4188 1.05 MRSC 242 B Sand 26/11/2005 6515/100 1,450 67 4293 1.06 MRSC 242 B Sand 11/26/05 0:00 6515/100 1,450 67 4293 1.09 SPMC 255 B Sand 26/11/2005 6515/100 1,450 67 4293 1.10 SPMC 233 B Sand 26/11/2005 6515/100 1,450 67 4293 1.11 SPMC 162 B Sand 26/11/2005 6515/100 1,450 67 4293 Table 2:Well Position Data Well Name Strat Name Latitude Longitude X Loc Y Loc 10-101 SURFACE 70.367893064 -149.771816043 1668496.76 5984050.34 1Q-101 WEST SAK D 70.372893257 -149.761299336 1669783.72 5985884.93 1Q-101 WEST SAK B 70.373103083 -149.760874219 1669835.58 5985961.64 1 Q-101 WEST SAK A3 70.373307475 -149.760473542 1669885.31 5986037.09 1 Q-101 WEST SAK A2 70.373533681 -149.760040087 1669938.45 5986120.22 WCP Oilphase-DBR 10 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 Table 3:Sampling and Transfer Summary Opening Transfer Closing Opening Water Content Transferred Sample ID Chamber# conditions Cylinder conditions conditions Before Sample in the field ID in the field in the Lab De-emulsi. Volume (psia/°F) (psia/°F) (psia/°F) (wt%) (cc) 1.01 MPSR 1399 6515/100 CSB 14326-QA 15/61 415/73 N/A 420 1.05 MRSC 242 6515/100 CSB 14312-QA 215/61 1015/73 1.0 600 1.06 MRSC 242 6515/100 CSB14332-QA 215/61 1000/72 N/D 600 1.09 SPMC 255 6515/100 SSB 18140-QA 6015/61 6515/73 1.9 240 1.10 SPMC 233 6515/100 SSB 11281-MA 6015/61 6515/73 1.7 230 1.11 SPMC 162 6515/100 SSB 11878-QA 6015/61 6515/73 1.6 240 WCP Oilphase-DBR 11 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1C1-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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) 1.05 CSB 14312-QA 4,293 119 896 275.2 - 1.06 CSB 14332-QA 4,293 117 278.6 - 1.09 SSB 18140-QA 4,293 133 272.4 - 1.10 SSB 11281-MA 4,293 120 274.5 - 1.11 SSB 11878-0A 4,293 122 280.5 - 1.05 C**** CSB 7798-QA 4,293 175 1390 239.0 4.1 1.06 C**** CSB 11797-QA 4,293 173 1.051 1399 244.9 - *Flashed gas volume(scf)per barrel of stock tank liquid CO 60°F **Volume of live oil at it's bubble point pressure per flashed stock tank liquid volume CM 60°F ***Calculated from oil-based mud contamination in STO ****Conditioned sample.Saturated with syn gas. Table 5:Stock-Tank Oil Properties STO Properties Sample ID Cylinder# Depth Molar Mass Density API*** Unknown Contamination (ft) (g/cc) %(w/w) 1.05 CSB 14312-QA 4,293 364.3 0.9448 18.3 - 1.06 CSB 14332-QA 4,293 367.7 0.9469* 17.9 - 1.09 SSB 18140-QA 4,293 373.3 0.9472 17.9 - 1.10 SSB 11281-MA 4,293 364.2 0.9453* 18.2 - 1.11 SSB 11878-QA 4,293 376.3 0.9480 17.8 - 1.05 C** CSB 7798-QA 4,293 347.1 0.9404* 19.0 4.2 1.06 C** CSB 11797-QA 4,293 356.0 0.9458* 18.1 - *After the de-emulsification. **Conditioned sample.Saturated with syn gas. ***Qilphase-DBR's calculation is API=141.5/Density-131.5. WCP Oilphase-DBR 12 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 6:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.05) Sample 1.05;Cylinder CSB 14312-QA;Depth 4293 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.76 0.30 0.00 0.00 0.01 0.08 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.02 0.63 0.00 0.00 0.02 0.16 Methane 16.04 89.81 96.21 0.00 0.00 1.44 24.69 Ethane 30.07 1.84 1.05 0.00 0.00 0.03 0.27 Propane 44.10 1.26 0.49 0.02 0.13 0.04 0.22 I-Butane 58.12 1.62 0.48 0.03 0.19 0.06 0.27 N-Butane 58.12 0.77 0.23 0.02 0.16 0.04 0.17 I-Pentane 72.15 1.03 0.25 0.06 0.33 0.08 0.31 N-Pentane 72.15 0.36 0.09 0.02 0.12 0.03 0.11 C6 84.00 0.68 0.14 0.23 1.00 0.24 0.78 M-C-Pentane 84.16 0.09 0.02 0.03 0.12 0.03 0.09 Benzene 78.11 0.01 0.00 0.01 0.04 0.01 0.03 Cyclohexane 84.16 0.04 0.01 0.03 0.15 0.03 0.11 C7 96.00 0.26 0.05 0.39 1.47 0.39 1.11 M-C-Hexane 98.19 0.08 0.01 0.06 0.21 0.06 0.16 Toluene 92.14 0.02 0.00 0.03 0.13 0.03 0.10 C8 107.00 0.18 0.03 0.44 1.49 0.43 1.12 E-Benzene 106.17 0.01 0.00 0.03 0.10 0.03 0.07 M/P-Xylene 106.17 0.01 0.00 0.03 0.11 0.03 0.08 0-Xylene 106.17 0.00 0.00 0.03 0.12 0.03 0.09 C9 121.00 0.09 0.01 0.60 1.81 0.59 1.35 C10 134.00 0.05 0.01 1.02 2.77 1.01 2.06 C11 147.00 0.00 0.00 1.40 3.47 1.38 2.58 C12 161.00 0.00 0.00 1.95 4.42 1.92 3.29 C13 175.00 0.00 0.00 2.30 4.78 2.26 3.55 C14 190.00 0.00 0.00 3.07 5.89 3.02 4.38 C15 20600 0.00 0.00 2.76 4.87 2.71 3.62 C16 222.00 3.05 5.00 3.00 3.72 C17 23700 2.88 4.43 2.84 3.29 C18 251.00 2.99 4.34 2.94 3.22 C19 263.00 2.90 4.01 2.85 2.98 C20 275.00 2.67 3.54 2.63 2.63 C21 291.00 2.73 3.42 2.69 2.54 C22 300.00 2.69 3.27 2.65 2.43 C23 312.00 2.01 2.35 1.98 1.75 C24 324.00 2.18 2.45 2.14 1.82 C25 337.00 2.18 2.36 2.14 1.75 C26 349.00 1.77 1.85 1.75 1.38 C27 360.00 2.22 2.25 2.19 1.67 C28 372.00 1.94 1.90 1.91 1.41 C29 382.00 1.55 1.48 1.52 1.10 C30 394.00 1.72 1.59 1.69 1.18 C31 404.00 1.27 1.14 1.25 0.85 C32 415.00 1.43 1.26 1.41 0.93 C33 426.00 1.14 0.98 1.13 0.73 C34 437.00 0.91 0.76 0.89 0.56 C35 445.00 0.61 0.50 0.60 0.37 C36+ 940.00 44.60 17.28 43.88 12.85 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.19 364.31 275.22 MOLE RATIO 0.2566 0.7434 WCP Oilphase-DBR 13 Job#:200500199 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1Q-101 Sand: West Sak B Figure 1:Stock Tank Oil Chromatogram(Sample 1.05) Sample 1.05;Cylinder CSB 14312-GA;Depth 4293 ft.MD FID1 A.(F:t21DATAe05001881CY14312.D) Nom. 250^ • JOB 200500199 CONOCO PHILLIPS 200, 1.05 CSB 14312-QA RF FLASH CYLINDER • 150- 100- 1D aN _ t: m m YI l0 1` f�Y i Nry V i01Dr��`yv nT U c �ccU ccccccc 0 U c� � 4j U� o U fXU U U c c 5 10 15 20 25 30 35 mir Figure 2:k-Plot for Equilibrium Check(Sample 1.05) Sample 1.05;Cylinder CSB 14312-GA;Depth 4293 ft.MD 2 •C3 1.5 •iC..4 •nC4 1 •OC65 0.5 •C6 ac 0 Is 3 •C7 -0.5 •CS -1 .na -1.5 •C10 -2 -4 -3 -2 -1 0 1 2 3 F WCP Qilphase-DBR 15 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 7:Calculated Fluid Properties Sample 1.05;Cylinder CSB 14312-QA;Depth 4293 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.85 0.14 99.61 98.08 98.03 72.95 C12+ 0.00 0.00 95.51 86.11 93.98 64.01 C20+ - - 73.62 48.36 72.44 35.95 C30+ - - 51.67 23.50 50.84 17.47 C36+ - - 44.60 17.28 43.88 12.85 Molar Mass C7+ 100.45 369.99 369.85 , C12+ 167.18 404.09 404.09 C20+ - 554.57 554.57 C30+ - 800.91 _ 800.91 C36+ - 940.00 940.00 Density C7+ - 0.9466 - C12+ - 0.9559 _ 0.9559 C20+ - 0.9976 0.9976 C30+ 1.0553 1.0553 C36+ 1.0814 1.0814 Fluid at 60°F 0.9448 Gas Gravity(Air=1) .1 0.593 Dry Gross Heat Content(BTU/scf) 1,056 Wet Gross Heat Content IBTU/scf 1,037 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculates C36+Properties MW 364.31 364.31 940.00 Density(g/cm3) 0.9448 - 1.0814 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 119 - STO Density(g/cm3) 0.9448 - STO API Gravity 18.3 - OBM Density(g/cm3)@60°F WCP Oilphase-DBR 14 Job 4:200500199 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1Q-101 Sand: West Sak B Table 8:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.06) Sample 1.06;Cylinder CSB 14332-0A;Depth 1450 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% I WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1.28 0.49 0.00 0.00 0.02 0.13 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.51 0.92 0.00 0.00 0.02 0.23 Methane 16.04 91.17 96.61 0.00 0.00 1.41 24.57 Ethane 30.07 1.35 0.77 0.00 0.00 0.02 0.19 Propane 44.10 0.75 0.29 0.01 0.09 0.02 0.14 I-Butane 58.12 0.98 0.29 0.03 0.16 0.04 0.19 N-Butane 58.12 0.46 0.13 0.02 0.12 _ 0.03 0.12 I-Pentane 72.15 0.70 0.16 0.06 0.31 _ 0.07 0.27 N-Pentane 72.15 0.28 0.06 0.03 0.13 _ 0.03 0.11 C6 84.00 0.58 0.12 0.15 0.67 0.16 0.53 M-C-Pentane 84.16 0.08 0.02 0.02 0.08 0.02 0.07 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.04 0.01 0.03 0.11 0.03 0.09 C7 96.00 0.26 0.05 0.22 0.84 0.22 0.64 M-C-Hexane 98.19 0.08 0.01 0.06 0.23 0.06 0.18 Toluene 92.14 0.04 0.01 0.04 0.16 _ 0.04 0.12 C8 107.00 0.20 0.03 0.42 1.44 0.42 1.08 E-Benzene 106.17 0.01 0.00 _ 0.04 0.12 _ 0.04 0.09 M/P-Xylene 106.17 0.02 0.00 0.04 0.14 0.04 0.10 0-Xylene 106.17 0.01 0.00 _ 0.04 0.13 0.04 0.10 C9 121.00 0.11 0.02 _ 0.58 1.76 _ 0.57 1.32 C10 134.00 0.07 0.01 1.02 2.81 1.01 2.10 C11 147.00 0.01 0.00 1.36 3.40 1.34 2.53 C12 161.00 0.00 0.00 _ 1.86 4.24 _ 1.83 3.16 C13 175.00 0.00 0.00 _ 2.35 4.94 _ 2.31 3.68 C14 190.00 0.00 0.00 2.62 5.07 2.58 3.78 C15 206.00 0.00 0.00 3.05 5.44 3.00 4.06 C16 222.00 2.81 4.66 2.77 3.47 C17 237.00 3.06 4.75 3.01 3.54 C18 251.00 2.84 4.16 2.79 3.10 C19 263.00 3.00 4.19 2.95 3.12 C20 275.00 2.99 4.00 2.94 2.98 C21 291.00 2.70 3.41 2.66 2.54 C22 300.00 2.62 3.21 2.58 2.39 C23 312.00 2.33 2.75 2.30 2.05 C24 324.00 2.31 2.62 2.28 1.96 C25 337.00 _ 1.97 2.15 1.94 1.61 C26 349.00 _ 2.07 2.19 _ 2.04 1.63 C27 360.00 1.90 1.94 1.87 1.45 C28 372.00 1.95 1.93 1.92 1.44 C29 382.00 2.00 1.92 1.97 1.43 C30 394.00 1.61 1.51 1.59 1.12 C31 404.00 1.36 1.23 1.33 0.92 C32 415.00 1.30 1.15 1.28 0.86 C33 426.00 1.14 0.99 1.12 0.74 C34 437.00 0.96 0.80 0.94 0.60 C35 445.00 1.20 0.99 1.18 0.74 C36+ 948.00 43.84 17.01 43.16 12.68 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.00 367.75 I 278.55 MOLE RATIO 0.2543 0.7457 WCP Oilphase-DBR 16 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 9:Calculated Fluid Properties Sample 1.06;Cylinder CSB 14332-QA;Depth 1450 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.94 0.16 99.71 _ 98.52 98.17 73.51 C12+ _ 0.00 0.00 95.84 87.25 94.35 65.06 C20+ - - 74.26 49.80 73.10 37.14 C30+ - - 51.40 23.68 50.61 17.66 - C36+ - - 43.84 17.01 43.16 12.68 Molar Mass C7+ 101.55 372.18 _ 372.03 C12+ 171.64 _ 403.95 403.95 C20+ - _ 548.29 548.29 C30+ - 798.40 798.40 C36+ - 948.00 948.00 Density C7+ - 0.9483 - C12+ - 0.9568 0.9568 C20+ - 0.9978 0.9978 C30+ _ 1.0584 1.0584 C36+ 1.0872 1.0872 Fluid at 60°F 0.9469 Gas Gravity(Air=1) I 0.587 Dry Gross Heat Content(BTU/scf) 1,036 Wet Gross Heat Content(BTU/scf) 1,018 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 367.75 367.75 948.00 Density(g/cm3) 0.9469 - 1.0872 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 117 - STO Density(g/cm3) _ 0.9469 _ STO API Gravity 17.9 - OBM Density(g/cm3)@60°F I - WCP Oilphase-DBR 17 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 3:Stock Tank Oil Chromatogram(Sample 1.06) Sample 1.06;Cylinder CSB 14332-0A;Depth 1450 ft.MD FIDIA,(FO ATA1005001904CY143320) Nom,. JOB 200500199 CONOCO PHILLIPS 1.06 CSB 14332-QA 260- RF FLASH CYLINDER 200- • 150- 100- N 0 50 Loc�G oC c c N CmInRic(41cIANInucoUCCCCC u JPa, 0 UCCC 1.1'4 XU fir.% c cc I Pill- 0 5 10 15 20 25 30 35 mir Figure 4:k-Plot for Equilibrium Check(Sample 1.06) Sample 1.06;Cylinder CSB 14332-DA;Depth 1450 ft.MD 2 •C3 1.5 •nC4 1 •OCC5 0.5 •C6 6 - 0 •C7 s 0.5 •C8 •C9 -1 1.5 •C10 -2 -4 -3 -2 -1 0 1 2 3 F WCP Oilphase-DBR 18 Job It 200500199 r t Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 Q-101 Sand: West Sak B Table 10:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.09) Sample 1.09;Cylinder SSB 18140-QA;Depth 4293 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.48 0.19 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 2.32 1.42 0.00 0.00 0.04 0.40 Methane 16.04 89.42 95.76 0.00 0.00 1.60 27.13 Ethane 30.07 1.74 1.00 0.00 0.00 0.03 0.28 Propane 44.10 1.11 0.43 0.02 0.15 0.04 0.23 I-Butane 58.12 1.36 0.40 0.03 0.20 0.05 0.26 N-Butane 58.12 0.66 0.20 0.03 0.17 0.04 0.17 I-Pentane 72.15 0.92 0.22 0.07 0.34 0.08 0.30 N-Pentane 72.15 0.34 0.08 0.02 0.13 0.03 0.11 C6 84.00 0.70 0.14 0.24 1.07 0.25 0.81 M-C-Pentane 84.16 0.10 0.02 0.03 0.11 0.03 0.09 Benzene 78.11 0.01 0.00 0.01 0.04 0.01 0.03 Cyclohexane 84.16 0.04 0.01 0.03 0.15 0.03 0.11 C7 96.00 0.29 0.05 0.39 1.50 0.38 1.09 M-C-Hexane 98.19 0.09 0.02 0.05 0.21 0.05 0.15 Toluene 92.14 0.02 0.00 0.03 0.13 0.03 0.09 C8 107.00 0.20 0.03 0.43 1.51 0.43 1.09 E-Benzene 106.17 0.01 0.00 0.03 0.10 0.03 0.07 M/P-Xylene 106.17 0.01 0.00 0.03 0.11 0.03 0.08 0-Xylene 106.17 0.00 0.00 0.03 0.12 0.03 0.09 C9 121.00 0.10 0.01 0.61 1.87 0.60 1.35 C10 134.00 0.05 0.01 1.01 2.80 0.99 2.01 C11 147.00 0.00 0.00 1.37 3.49 1.35 2.50 C12 161.00 0.00 0.00 1.91 4.43 1.88 3.17 C13 175.00 0.00 0.00 2.38 5.09 2.34 3.64 C14 190.00 0.00 0.00 2.84 5.59 2.79 4.00 C15 206.00 0.00 0.00 2.68 4.85 2.63 3.48 C16 222.00 2.96 4.97 2.90 3.56 C17 237.00 2.82 4.44 2.77 3.18 C18 251.00 2.89 4.29 2.84 3.08 C19 263.00 2.80 3.98 2.75 2.85 020 275.00 2.71 3.68 2.67 2.64 C21 291.00 2.50 3.21 2.46 2.30 C22 300.00 2.58 3.22 2.54 2.30 C23 312.00 2.06 2.46 2.02 1.77 C24 324.00 1.98 2.28 1.94 1.63 C25 337.00 2.09 2.31 2.05 1.66 C26 349.00 1.76 1.89 1.73 1.35 C27 360.00 1.90 1.97 1.86 1.41 C28 372.00 1.77 1.77 1.74 1.27 C29 382.00 1.73 1.69 1.70 1.21 C30 394.00 1.19 1.13 1.17 0.81 C31 404.00 1.11 1.02 1.09 0.73 C32 415.00 1.23 1.11 1.21 0.80 C33 426.00 1.00 0.87 0.98 0.63 C34 437.00 0.62 0.53 0.61 0.38 C35 445.00 0.57 0.48 0.56 0.34 C36+ 955.00 47.45 18.55 46.61 13.29 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.18 373.27 272.39 MOLE RATIO 0.2833 0.7167 WCP Oilphase-DBR 19 Job t 200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 11:Calculated Fluid Properties Sample 1.09;Cylinder SSB 18140-0A;Depth 4293 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.93 0.16 99.60 97.95 97.83 70.25 C12+ 0.00 0.00 95.54 85.81 93.84 61.50 C20+ - - 74.26 48.17 72.93 34.53 C30+ - - 53.17 23.69 52.22 16.98 C36+ - - 47.45 18.55 46.61 13.29 Molar Mass C7+ 100.27 379.52 379.34 C12+ 168.51 415.58 415.58 C20+ _ - _ 575.38 575.38 C30+ - 837.85 837.85 C36+ - 955.00 955.00 Density C7+ - 0.9491 - C12+ - 0.9584 0.9584 C20+ - 0.9996 0.9996 C30+ 1.0545 1.0545 C36+ 1.0740 1.0740 Fluid at 60°F 0.9472 Gas Gravity(Air=1) 1 0.593 Dry Gross Heat Content(BTU/scf) 1,045 Wet Gross Heat Content(BTU/scf 1,027 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 373.27 373.27 955.00 Density(g/cm3) 0.9472 - 1.0740 Single Stage Flash Data Original STO De-Contaminated GDR(scf/stb) 133 - STO Density(g/cm3) 0.9472 - STO API Gravity 17.9 - OBM Density(g/cm3)©60°F I - WCP Oilphase-DBR 20 Job 9:200500199 Client: ConocoPhillips Field: West Sak Schlumberger Well: 10-101 Sand: West Sak B Figure 5:Stock Tank Oil Chromatogram(Sample 1.09) Sample 1.09;Cylinder SSB 18140-DA;Depth 4293 ft.MD FID1 A.(F12lDATA4005001991CY18140.D) Norm 2 250- 200- JOB 200500199 CONOCO PHILLIPS 1.09 SS 18140-QA 150- RF FLASH CYLINDER 00- ,r`n o L m ry 5D- Ll m ry m u c."-.)°�D�t2L2(2c2(2� ..cu a V c cccccc=ccc cccc cc 8 1DCU U c = c y� N 1 'Ll�i)l.r 1... n W _ �,. .,.�� �.iq.uiei�tlN'IA IIIr� ��411111111 D 5 10 15 20 25 30 35 mir Figure 6:k-Plot for Equilibrium Check(Sample 1.09) Sample 1.09;Cylinder SSB 18140-QA;Depth 4293 ft.MD 2 •C3 1.5 •IC4 •nC4 1 •FICi6S 0.5 •C6 g 0 •C7 -0.5 •C8 -1 •C9 -1.5 •C10 -2 -4 -3 -2 -1 0 1 2 3 F WCP Oilphase-DBR 21 Job it 200500199 Client: ConocoPhillips Field: West Sak Schlumberger Well: 10-101 Sand: West Sak 6 Table 12:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.10) Sample 1.10;Cylinder SSB 11281-MA;Depth 4293 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid Ig/mole) WT% MOLE% WT% MOLE% _ WT% MOLE% Carbon Dioxide 44.01 0.53 0.21 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 1.01 0.62 0.00 0.00 _ 0.02 0.16 Methane 16.04 90.07 96.37 0.00 0.00 1.46 24.93 Ethane 30.07 1.80 1.03 0.00 0.00 0.03 0.27 Propane 44.10 1.21 0.47 0.02 0.19 0.04 0.26 I-Butane 58.12 1.53 0.45 0.04 0.22 0.06 0.28 N-Butane 58.12 0.75 0.22 0.02 0.14 0.03 0.16 I-Pentane 72.15 1.00 0.24 0.07 0.35 _ 0.08 0.32 N-Pentane 72.15 0.37 0.09 0.03 0.14 _ 0.03 0.13 C6 84.00 0.69 0.14 0.21 0.89 0.21 0.70 M-C-Pentane 84.16 0.09 0.02 0.03 0.12 0.03 0.09 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.04 0.01 0.03 0.14 0.03 0.10 C7 96.00 0.28 0.05 0.32 1.22 0.32 0.92 M-C-Hexane 98.19 0.08 0.01 0.06 0.21 0.06 0.16 Toluene 92.14 0.02 0.00 0.02 0.06 _ 0.02 0.05 C8 107.00 0.19 0.03 0.37 1.28 0.37 0.95 E-Benzene 106.17 0.01 0.00 0.07 0.25 _ 0.07 0.19 M/P-Xylene 106.17 0.01 0.00 0.05 0.17 0.05 0.13 0-Xylene 106.17 0.00 0.00 0.02 0.07 0.02 0.05 C9 121.00 0.10 0.01 0.52 1.58 _ 0.52 1.17 C10 134.00 0.07 0.01 1.04 2.82 _ 1.02 2.09 C11 147.00 0.05 0.01 1.35 3.34 1.33 2.48 C12 161.00 0.09 0.01 1.86 4.21 1.83 3.13 C13 175.00 0.00 0.00 2.36 4.90 2.32 3.64 C14 190.00 0.00 0.00 2.69 5.16 2.65 3.82 C15 206.00 0.00 0.00 3.10 5.48 3.05 4.06 C16 222.00 3.09 5.06 _ 3.04 3.75 C17 237.00 2.91 4.47 2.86 3.31 C18 251.00 3.07 4.45 3.02 3.30 C19 263.00 2.93 4.06 _ 2.88 3.01 C20 275.00 2.91 3.85 2.86 2.85 C21 291.00 2.61 3.26 2.57 2.42 C22 300.00 2.81 3.41 2.77 2.53 C23 312.00 2.23 2.60 2.19 1.93 C24 324.00 2.35 2.64 2.31 1.96 C25 337.00 2.05 2.21 2.01 1.64 C26 349.00 1.90 1.98 1.87 1.47 C27 360.00 1.79 1.81 1.76 1.34 C28 372.00 1.96 1.92 1.93 1.42 C29 382.00 2.01 1.92 1.98 1.42 C30 394.00 1.44 1.33 1.41 0.99 C31 404.00 1.64 1.48 1.61 1.10 C32 415.00 1.23 1.08 1.21 0.80 C33 426.00 1.20 1.03 1.18 0.76 C34 437.00 1.08 0.90 1.06 0.67 C35 445.00 0.63 0.52 0.62 0.38 C36+ 939.00 43.89 17.03 43.18 12.62 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.16 364.24 274.47 MOLE RATIO 0.2587 0.7413 WCP Oilphase-DBR 22 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 13:Calculated Fluid Properties Sample 1.10;Cylinder SSB 11281-MA;Depth 4293 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 1.03 0.17 99.62 98.06 98.02 72.74 C12+ 0.09 0.01 95.73 86.77 94.18 64.33 C20+ - - 73.73 48.97 72.53 36.31 C30+ - - 51.11 23.36 50.29 17.32 C36+ - - 43.89 17.03 43.18 12.62 Molar Mass C7+ 105.71 370.02 369.86 C12+ 161.25 401.84 401.83 C20+ - 548.35 548.35 C30+ - 797.05 797.05 C36+ 939.00 939.00 Density C7+ - 0.9472 - C12+ - 0.9558 0.9558 C20+ - 0.9974 0.9974 C30+ 1.0576 1.0576 C36+ 1.0852 1.0852 Fluid at 60°F 0.9453 Gas Gravity(Air=11 I 0.593 Dry Gross Heat Content(BTU/scf) 1,057 Wet Gross Heat Content(BTU/scf) 1,038 OBM Contamination Level(wt%) STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 364.24 364.24 939.00 Density(g/cm3) 0.9453 - 1.0852 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 120 STO Density(g/cm3) 0.9453 - STO API Gravity 18.2 - OBM Density(g/cm3)@60°F I WCP Oilphase-DBR 23 Job#:200500199 Client ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 7:Stock Tank Oil Chromatogram(Sample 1.10) Sample 1.10;Cylinder SSB 11281-MA;Depth 4293 ft.MD F01 P.rE WP:4E0.:10AiAYl09)0,9?•R1122,f� Mom I 250- 700- JOB 200500199 CONOCO PHILLIPS 1.10 SSB 11281-MA RF FLASH CYLINDER 150- 100- 50- •io m C C O N 3 0 0] gj0N N r ? 0) , 5N m V ca, U C c ccc cc ccccc====== N. m fbXU .<9.; c c c c c c 2 c C t o c c c ........wh41'i9'r1 I'. '! -----.�..~n , .�d...e.dm.�•m�+gat+.*filmes'nI'L11ll.dJIJJ111-I.-.L_l:I. LJJ. 0 5 1015 20 75 30 35 Figure 8:k-Plot for Equilibrium Check(Sample 1.10) Sample 1.10;Cylinder SSB 11281-MA;Depth 4293 ft.MD 2 1.5 •nt4C4 •C3 1 •t1C5 0.5 •Ce 6 - 0 •C7 •C8 -0.5 1 •C9 •C10 -1.5 •C11 -4 -3 -2 -1 0 1 2 3 F WCP Oilphase-DBR 24 Job it:200500199 , t Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Table 14:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.11) Sample 1.11;Cylinder SSB 11878-0A;Depth 4293 ft.MD Component MW i Flashed Gas Flashed Liquid Monophasic Fluid Ig/mole) ; WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1 0.45 0.18 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 I, 1.05 0.65 0.00 0.00 0.02 0.17 Methane 16.04 89.50 96.19 0.00 0.00 1.47 25.69 Ethane 30.07 1.79 1.03 0.00 0.00 0.03 0.27 Propane 44.10 1.22 0.48 0.01 0.10 0.03 0.20 I-Butane 58.12 1.57 0.47 0.03 0.17 0.05 0.25 N-Butane 58.12 0.77 0.23 0.02 0.13 0.03 0.16 I-Pentane 72.15 _ 1.05 0.25 0.06 0.30 0.07 0.29 N-Pentane 72.15 0.88 0.21 0.06 0.30 0.07 0.28 C6 84.00 0.85 0.17 0.23 1.03 0.24 0.80 M-C-Pentane 84.16 0.09 0.02 0.02 0.10 0.02 0.08 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 _ 0.04 0.01 0.03 0.13 0.03 0.10 C7 96.00 0.27 0.05 0.32 1.27 0.32 0.94 M-C-Hexane 98.19 0.09 0.02 0.05 0.20 0.05 0.15 Toluene 92.14 0.02 0.00 0.03 0.14 0.03 0.10 C8 107.00 0.18 0.03 0.39 1.39 0.39 1.02 E-Benzene 106.17 0.01 0.00 0.03 0.09 0.03 0.07 M/P-Xylene 106.17 0.01 0.00 0.03 0.10 0.03 0.08 O-Xylene 106.17 0.00 0.00 0.03 0.11 0.03 0.08 C9 121.00 0.09 0.01 0.55 1.70 0.54 1.25 C10 134.00 0.05 0.01 0.93 2.62 0.92 1.92 C11 147.00 0.01 0.00 1.29 3.30 1.27 2.42 C12 161.00 0.00 0.00 1.80 4.22 1.77 3.09 C13 175.00 0.00 0.00 2.26 4.87 2.23 3.57 C14 190.00 _ 0.00 0.00 2.47 4.90 2.43 3.59 C15 206.00 0.00 0.00 2.83 5.18 2.79 3.79 C16 222.00 2.88 4.89 2.84 3.58 C17 237.00 2.76 4.39 2.72 3.22 C18 251.00 2.86 4.30 2.82 3.15 C19 263.00 2.80 4.00 2.75 2.93 C20 275.00 2.72 3.72 2.67 2.73 C21 291.00 2.53 3.27 2.49 2.40 C22 300.00 2.60 3.26 2.55 2.39 C23 312.00 2.12 2.55 2.08 1.87 C24 324.00 1.97 2.29 1.94 1.68 l C25 337.00 _ 213 2.38 2.10 1.75 C26 349.00 1.94 2.09 1.91 1.53 C27 360.00 2.03 2.12 1.99 1.55 • C28 372.00 1.99 2.01 1.96 1.47 C29 382.00 _ 1.99 1.96 1.96 1.44 C30 394.00 _ 1.42 1.36 1.40 1.00 C31 404.00 1.59 1.48 1.57 1.09 C32 415.00 1.22 1.11 1.20 0.81 C33 426.00 1.23 1.08 1.21 0.79 C34 437.00 0.96 0.83 0.95 0.61 C35 445.00 0.43 0.36 0.42 0.27 C36+ 960.00 46.33 18.16 45.57 13.31 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.24 376.34 280.45 MOLE RATIO 0.2670 0.7330 WCP Oilphase-DBR 25 Job k:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 15:Calculated Fluid Properties Sample 1.11;Cylinder SSB 11878-0A;Depth 4293 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.86 0.15 99.60 97.97 97.98 71.85 C12+ 0.00 0.00 95.88 86.77 94.30 63.60 C20+ - 75.20 50.04 73.96 36.68 C30+ - 53.19 24.39 52.32 17.88 C36+ 46.33 18.16 45.57 13.31 Molar Mass C7+ 100.09 382.60 382.45 C12+ 168 98 415.82 415.82 C20+ - 565.51 565.51 C30+ - 820.72 820.72 C36+ - 960.00 960.00 Density C7+ - 0.9499 - C12+ - 0.9584 0.9584 C20+ - 0.9976 0.9976 C30+ 1.0536 1.0536 C36+ 1.0776 1.0776 Fluid at 60°F 0 9480 Gas Gravity(Air=1) 0.595 Dry Gross Heat Content IBTU/scf) 1,061 Wet Gross Heat Content IBTU/scf 1,043 OBM Contamination Level(wt%) STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 376.34 376.34 960.00 Density(g/cm3) 0.9480 1.0776 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 122 - STO Density Ig/cm3) 0.9480 _ - STO API Gravity 17.8 - OBM Density(g/cm3)©60°F - I WCP Oilphase-DBR 26 Job#:200500199 Client ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 9:Stock Tank Oil Chromatogram(Sample 1.11) Sample 1.11;Cylinder SSB 11878-0A;Depth 4293 ft.MD . f em4TA00500,59V_' c,. Norm 250- 200- JOB 200500199 CONOCO PHILLIPS 1.11 SSB 11878-QA 150 RF FLASH CYLINDER 100- � U �a Ip 10 m §5RmAM O UCUCUCCC CC CC cit UCUc I II T ill- 0 25 30 mir Figure 10:k-Plot for Equilibrium Check(Sample 1.11) Sample 1.11;Cylinder SSB 11878-QA;Depth 4293 ft.MD 2 •C3 1.5 •iC4 •nC4 1 •O5 0.5 •C6 3 0 •C7 -0.5 •C8 -1 •C9 -1.5 •C10 -2 -4 -3 -2 -1 0 1 2 3 WCP Oilphase-DBR 27 Job a:200500199 Client: ConocoPhillips Field: West Sak Well: 11101 Sand: West Sak B Schlumberger Table 16:Calculated Synthetic Gas Composition Composition MOLE Carbon Dioxide 0.14 Hydrogen Sulfide Nitrogen 2.21 Methane 97.28 Ethane 0.23 Propane 0.06 I-Butane 0.04 N-Butane 0.02 I-Pentane 0.01 N-Pentane 0.00 C6 0.01 Total 100.00 Table 17:Physical Composition of the Syn Gas Prepared in the Lab Composition MOLE% Carbon Dioxide 0.17 Hydrogen Sulfide 0.00 Nitrogen 2.19 Methane 97.32 Ethane 0.25 Propane 0.03 I-Butane 0.02 N-Butane 0.00 I-Pentane 0.00 N-Pentane 0.00 C6 0.00 Total 100.00 WCP Oilphase-DBR 28 Job it:200500199 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1Q-101 Sand: West Sak B Contaminated 4.2 STO Basis,wt% Contaminated 4.1 RF Basis,wt% Table 18:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.05 C) Sample 1.05 C;Cylinder CSB 7798-QA;Depth 4293 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.92 0.35 0.00 0.00 0.02 0.12 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.05 0.63 0.00 0.00 0.02 0.21 Methane 16.04 91.68 96.84 0.00 0.00 2.13 31.71 Ethane 30.07 1.56 0.88 0.00 0.00 0.04 0.29 Propane 44.10 0.90 0.35 0.01 0.07 0.03 0.16 I-Butane 58.12 1.16 0.34 0.02 0.10 0.04 0.18 N-Butane 58.12 0.55 0.16 0.01 0.06 0.02 0.09 I-Pentane 72.15 0.75 0.18 0.04 0.19 0.06 0.18 N-Pentane 72.15 0.22 0.05 0.02 0.08 0.02 0.07 C6 84.00 0.52 0.10 0.19 0.77 0.20 0.56 M-C-Pentane 84.15 0.07 0.01 0.02 0.09 0.02 0.06 Benzene 78.11 0.01 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.03 0.01 0.03 0.11 0.03 0.07 C7 96.00 0.19 0.03 0.27 0.99 0.27 0.67 M-C-Hexane 98.19 0.06 0.01 0.05 0.17 0.05 0.11 Toluene 92.14 0.02 0.00 0.01 0.02 0.01 0.01 C8 107.00 0.12 0.02 0.37 1.20 0.36 0.81 E-Benzene 106.17 0.01 0.00 0.01 0.03 0.01 0.02 M/P-Xylene 106.17 0.01 0.00 0.01 0.02 0.01 0.02 O-Xylene 106.17 0.01 0.00 0.11 0.35 0.11 0.24 C9 121.00 0.07 0.01 0.66 1.88 0.64 1.27 C10 134.00 0.08 0.01 2.37 6.15 2.32 4.14 C11 147.00 0.03 0.00 3.99 9.43 3.90 6.34 C12 161.00 0.00 0.00 1.81 3.90 1.77 2.62 C13 175.00 0.00 0.00 2.19 4.35 2.14 2.92 C14 190.00 0.00 0.00 2.36 4.32 2.31 2.90 C15 206.00 0.00 0.00 2.73 4.59 2.66 3.09 C16 222.00 2.68 4.19 2.62 2.82 C17 237.00 2.59 3.80 2.53 2.55 C18 251.00 2.74 3.79 2.67 2.55 C19 263.00 2.63 3.47 2.57 2.34 C20 275.00 2.62 3.31 2.56 2.22 C21 291.00 2.43 2.90 2.38 1.95 C22 300.00 2.31 2.68 2.26 1.80 C23 312.00 2.11 2.35 2.06 1.58 C24 324.00 2.08 2.23 2.03 1.50 C25 337.00 1.96 2.02 1.91 1.36 C26 349.00 1.75 1.74 1.71 1.17 C27 360.00 1.71 1.65 1.67 1.11 C28 372.00 1.86 1.74 1.82 1.17 C29 382.00 1.80 1.63 1.75 1.10 C30 394.00 1.71 1.51 1.67 1.01 C31 404.00 1.56 1.34 1.52 0.90 C32 415.00 1.42 1.19 1.39 0.80 C33 426.00 1.26 1.02 1.23 0.69 C34 437.00 1.18 0.93 1.15 0.63 C35 445.00 1.16 0.90 1.13 0.61 C36+ 895.00 43.19 16.75 42.19 11.27 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.95 347.14 239.01 MOLE RATIO 0.3275 0.6725 WCP Oilphase-DBR 29 Job#:200500199 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1G-101 Sand: West Sak B Contaminated 4.2 STO Basis,wt% Contaminated 4.1 RF Basis,wt% Table 19:Calculated Fluid Properties Sample 1.05 C;Cylinder CSB 7798-DA;Depth 4293 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.70 0.12 99.72 98.72 97.42 66.43 C12+ 0.00 0.00 91.83 78.29 89.70 52.65 C20+ - _ - _ 72.10 45.89 70.43 30.86 C30+ - - 51.47 23.65 50.28 15.90 C36+ - 43.19 16.75 42.19 11.27 Molar Mass C7+ 102.53 350.65 350.51 C12+ 161.00 407.19 407.19 C20+ 545.47 545.47 C30+ - 755.55 755.55 _ C36+ 895.00 895.00 Density C7+ - 0.9417 C12+ 0.9584 0.9584 C20+ 0.9976 0.9976 C30+ 1.0518 1.0518 C36+ 1.0822 1.0822 Fluid at 60°F 0.9404 Gas Gravity(Air=1) I 0.585 1 Dry Gross Heat Content(BTU/scf) 1,041 Wet Gross Heat Content(BTU/scf 1,023 Contamination Level(wt%) 4.2 STO Basis 4.1 Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW _ 347.14 347.14 895.00 Density(g/cm3) 0.9404 1.082 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 175 N/D STO Density(g/cm3) 0.9404 - N/D STO API Gravity 19.0 N/D Contamination Density(g/cm3)©, N/D WCP Oilphase-DBR 30 Job ft:200500199 WClell: 1Q-10ConocoPhillips Field:nWest Sak Schlumberger Well: 10-101 Sand: West Sak B Contaminated 4.2 STO Basis,wt% Contaminated 4.1 RF Basis,wt% Figure 11:Stock Tank Oil Chromatogram(Sample 1.05 C) Sample 1.05 C;Cylinder CSB 7798-QA;Depth 4293 ft.MD P DiarE^.HP:NEtr2,Da•,a',05901991fE7798.D• Non 250- • I I 200- 150- 100- I4 U 2 c (D cm Oc n(`NN W M .11„2 )A ; U` ccI c '.T1 8 I 0 LC � c c M ` I II _III 0 5 10 15 20 _ 30 35 mir Figure 12:k-Plot for Equilibrium Check(Sample 1.05 C) Sample 1.05 C;Cylinder CSB 7798-QA;Depth 4293 ft.MD 2.5 2 •C3 1.5 •rt4C4 1 •ITC. 5 n 0.5 •C6 . 0 •C7 -0.5 •C8 -1 •C9 -1.5 •C10 -2 -4 -3 -2 -1 0 1 2 3 F WCP Oilphase-DBR 31 Job tt:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Table 20:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.06 C) Sample 1.06 C;Cylinder CSB 11797-QA;Depth 4293 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 1.79 0.72 0.00 0.00 0.04 0.24 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.86 0.54 0.00 0.00 0.02 0.18 Methane 16.04 86.22 94.92 0.00 0.00 2.04 31.16 Ethane 30.07 2.33 1.37 0.00 0.00 0.06 0.45 Propane 44.10 1.63 0.65 0.02 0.19 0.06 0.34 I-Butane 58.12 2.08 0.63 0.03 0.20 0.08 0.34 N-Butane 58.12 0.92 0.28 0.02 0.12 0.04 0.17 I-Pentane 72.15 1.27 0.31 0.07 0.33 0.09 0.32 N-Pentane 72.15 0.56 0.14 0.03 0.16 0.04 0.15 C6 84.00 0.94 0.20 0.16 0.66 0.17 0.51 M-C-Pentane 84.16 0.14 0.03 0.02 0.09 0.02 0.07 Benzene 78.11 0.02 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.06 0.01 0.03 0.11 0.03 0.08 C7 96.00 0.39 0.07 0.23 0.84 0.23 0.59 M-C-Hexane 98.19 0.13 0.02 0.06 0.22 0.06 0.16 Toluene 92.14 0.08 0.02 0.12 0.45 0.12 0.31 C8 107.00 0.27 0.05 0.42 1.41 0.42 0.96 E-Benzene 106.17 0.01 0.00 0.04 0.14 0.04 0.09 M/P-Xylene 106.17 0.02 0.00 0.03 0.11 0.03 0.07 O-Xylene 106.17 0.01 0.00 0.03 0.11 0.03 0.08 C9 121.00 0.16 0.02 0.57 1.67 0.56 1.13 C10 134.00 0.11 0.01 1.03 2.73 1.00 1.84 C11 147.00 0.01 0.00 1.38 3.34 1.34 2.24 C12 161.00 0.00 0.00 1.90 4.19 1.85 2.82 C13 175.00 0.00 0.00 2.41 4.90 2.35 3.29 C14 190.00 0.00 0.00 2.79 5.23 2.73 3.51 C15 206.00 0.00 0.00 3.05 5.27 2.98 3.54 C16 222.00 2.89 4.64 2.83 3.12 C17 237.00 3.17 4.76 3.09 3.20 C18 251.00 3.10 4.40 3.03 2.96 C19 263.00 3.07 4.16 3.00 2.79 C20 275.00 3.02 3.91 2.95 2.62 C21 291.00 2.99 3.65 2.91 2.45 C22 300.00 2.69 3.19 2.62 2.14 C23 312.00 2.52 2.87 2.46 1.93 C24 324.00 2.36 2.59 2.30 1.74 C25 337.00 2.20 2.32 2.15 1.56 C26 349.00 2.17 2.21 2.12 1.48 C27 360.00 2.15 2.13 2.10 1.43 C28 372.00 2.13 2.03 2.08 1.37 C29 382.00 2.13 1.98 2.07 1.33 C30 394.00 2.03 1.84 1.99 1.23 C31 404.00 1.55 1.36 1.51 0.92 C32 415.00 1.47 1.26 1.44 0.85 C33 426.00 1.36 1.14 1.33 0.76 C34 437.00 1.18 0.96 1.15 0.65 C35 445.00 1.06 0.84 1.03 0.57 C36+ 941.00 40.35 15.27 39.39 10.25 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.66 356.01 244.92 MOLE RATIO 0.3283 0.6717 WCP Oilphase-DBR 32 Job#:200500199 Client: ConocoPhillips Field: West Sak Schlumberger Well: 10-101 Sand: West Sak B Table 21:Calculated Fluid Properties Sample 1.06 C;Cylinder CSB 11797-QA;Depth 4293 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 1.41 0.25 99.67 98.34 97.34 66.13 C12+ 0.01 0.00 95.71 87.10 93.45 58.50 C20+ _ - - 73.34 49.56 71.60 33.29 C30+ - - 49.00 22.67 47.84 15.23 C36+ - - 40.35 15.27 39.39 10.25 Molar Mass C7+ 101.08 360.82 360.50 C12+ 169.31 391.19 391.19 C20+ - 526.77 526.77 C30+ - 769.42 769.42 C36+ - 941.00 941.00 Density C7+ - 0.9474 - C12+ - 0.9560 0.9560 C20+ - 0.9987 0.9987 C30+ 1.0675 _ 1.0675 C36+ 1.1065 1.1065 Fluid at 60°F 0.9458 Gas Gravity(Air=1) 0.610 Dry Gross Heat Content(BTU/scf) 1,072 Wet Gross Heat Content(BTU/scf 1,053 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 356.01 356.01 941.00 Density(g/cm3) 0.9458 - 1.1065 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 173 - STO Density(g/cm3) 0.9458 - STO API Gravity 18.1 - OBM Density(g/cm3)@60°F I - WCP Oilphase-DBR 33 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 13:Stock Tank Oil Chromatogram(Sample 1.06 C) Sample 1.06 C;Cylinder CSB 11797-CA;Depth 4293 ft.MD ,IDI A,(F:1210ATA60050019910E1t797R.D) Norm. JOB 200500199 CONOCO PHILLIPS 1.06(conditioned)SSB 11797-QA 250- RF FLASH CELL 200- 150- 00-150- 100- mm _ c c C� S C50- IO r 07ONc"crcWccci rcc c�c rrbl1 Xm N ( Q00000UUUU1NcmccrcCFm m9 U cc UEoc ',cc 5 10 15 20 25 30 35 mirl Figure 14:k-Plot for Equilibrium Check(Sample 1.06 C) Sample 1.06 C;Cylinder CSB 11797-CA;Depth 4293 ft.MD 2 •iC4 •C3 1.5 •nCi • 1 IICi 5 •C6 a 0.5 - •C7 0 0 •C8 -0.5 •C9 -1 •C10 -1.5 -4 -3 -2 -1 0 1 2 3 WCP Oilphase-DBR 34 Job 4:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 22:Summary of Results of Sample 1.06 C Sample 1.06 C;Cylinder CSB 11797-QA;Depth 4293 ft.MD Reservoir Conditions: Pressure: 1450 psia Temperature: 67 °F Summary of Fluid Properties: Bubble Point Pressure At Tres 1,399 psia Gas-Oil Ratio Single-stage Flash: 173 scf/stb Total Differential Liberation: scf/stb Total Separator Flash: 171 scf/stb Properties at 60°F STO°API Gas Gravity(Average) Single-stage STO: 18.1 0.610 Differential Liberation STO: Separator STO: 18.4 0.609 Properties at Reservoir Conditions Viscosity: 152.0 cP Compressibillity(Co): 6.0 106/psi Density: 0.9216 g/cc Properties at Saturation Conditions Viscosity: - cP Compressibillity(Co): 6.0 10-6/psi Density: 0.9213 g/cc Formation Volume Factor @Pres&Tres @Psat&Tres Single-stage Flash: 1.051 1.051 Total Differential Liberation: Total Separator Flash: 1.049 1.049 Note:Standard conditions are 14.696 psia and 60°F i WCP Oilphase-DBR 35 Job 0:200500199 Client ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger PVT Analysis on Sample 1.06 C;Cylinder CSB 11797-0A; Depth 4293 ft.MD Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of saturated or conditioned live reservoir fluid 1.06 into the PVT cell at a reservoir temperature of 67.0°F and at a pressure of 5,015 psia.Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 23.The pressure-volume(P-V)plots of the CCE data are presented in Figure 15. 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 1,399 psia at the reservoir temperature of 67.0°F.Also,calculated relative volume and oil compressibility is presented in Table 23.As seen in the table,the compressibility of this oil is 6.0 x 10e-6 1/psia at the saturation pressure. Table 23:Constant Composition Expansion at 67.0°F(Sample 1.06 C) Sample 1.06 C;Cylinder CSB 11797-0A;Depth 4293 ft.MD Pressure Relative Vol %Liquid %Liquid Liquid Density Y Function Compressibility (psis) (Vr=V/Vsat) (VI/Vsat) (VI/1/total) (g/cm3) (106/psia) 1 5015 0.9836 0.9367 3.3 2 4015 0.9872 0.9333 3.9 3 3015 0.9915 0.9293 4.6 4 2515 0.9939 0.9270 5.0 5 2015 0.9965 0.9246 5.5 6 1815 0.9976 0.9236 5.6 7 1715 0.9981 0.9230 5.7 8 1615 0.9987 0.9225 5.8 Pi 1450 0.9997 0.9216 6.0 Pb 1399 1.0000 100.0 100.0 0.9213 6.0 11 1386 1.0017 100.0 99.8 5.6 12 1352 1.0063 99.9 99.3 5.5 13 1276 1.0179 99.8 98.0 5.4 14 1148 1.0419 99.6 95.6 5.2 15 961 1.0921 99.3 90.9 5.0 16 696 1.2184 98.9 81.2 4.6 17 424 1.5324 98.5 64.3 4.3 18 231 2.2276 98.2 44.1 4.1 WCP 0ilphase-DBR 36 Job 4:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 15:Constant Composition Expansion at 67.0°F-Relative Volume Sample 1.06 C;Cylinder CSB 11797-QA;Depth 4293 ft.MD 2.4 0 2.2 2.0 1.8 a > E 1.6 0 > m io 1.4 1.2 1.0 OCD O' 0 0 0 0 0.8 0 1000 2000 3000 4000 5000 6000 Pressure(psia) WCP Oilphase-DBR 37 Job#:200500199 Client: ConocoPhillips Field: West Sak Schlumberger Well: 10-101 Sand: West Sak B Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 67°F. These values as a function of selected pressure steps are summarized in Table 24.The liquid phase viscosity values are graphically presented in Figure 16.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 24:Reservoir Fluid Viscosity 67°F Sample 1.06 C;Cylinder CSB 11797-QA;Depth 4293 ft.MD Pressure Viscosity @ Tres (pia) (cP) 1 5032 293.3 2 4495 267.5 3 4001 245.4 4 3533 225.4 5 3033 204.8 6 2505 186.3 7 2049 170.0 8 1868 164.5 9 1643 157.7 Pi 1450 152.0 Pb 1399 150.7 2 1183 165.1 3 1089 171.6 4 937 186.7 5 727 206.2 6 557 243.0 STO 14.696 788.6 WCP Oilphase-DBR 38 Job 4:200500199 Client ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Figure 16:Reservoir Fluid Viscosity 67°F Sample 1.06 C;Cylinder CSB 11797-0A;Depth 4293 ft.MD 900 800 • 700 600 500 y O 400 300 • • • • 200 • • 100 0 1000 2000 3000 4000 5000 6000 Pressure(psis) WCP Oilphase-DBR 39 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Single-Stage Separation Test Single-stage separation test results are presented in Tables 25 - 27. The fluid properties (i.e., GOR, density and oil formation volume factor)are presented in Table 25.Multi-stage separation test conditions are: STAGE 1 65 psia 150 °F STAGE STO 14.696 psia 60 °F As seen in Table 25, the GOR value obtained from the multi-stage separation test is 171 SCF/STB and the formation volume factor is 1.049.The compositional analyses of separator gas and tank gas are summarized in Table 26 and the composition of tank liquid is tabulated in Table 27.The total dry gross heat content of the separation gases is calculated to be 1,074 BTU/scf whereas the total wet gross heat content is calculated to be 1,055 BTU/scf. WCP Oilphase-DBR 40 Job#:200500199 Client ConocoPhillips Field: West Sak Schlumberger Well: 10-101 Sand: West Sak B Table 25:Single-Stage Separation Test Vapor&Liquid Properties Sample 1.06 C;Cylinder CSB 11797-QA;Depth 4293 ft.MD PROPERTY STAGE Pb STAGE 1 STAGE STO Pressure(psia) 1399 65 14.696 Temperature(°F) 67 150 60 -Lig.Den(g/cm3) 0.9214 0.9332 0.9438 Vap.Gravity° 0.610 0.594 Vap.M„„ 17.68 17.20 Vap HeatValb 1075 1057 GOR` 157 14 GORd 155 14 Sep.FVF° 1.049 1.013 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 0.9438 g/cc Sep gas gravity(average) Sg=ERjSgj/ERj 0.609 Where: R:GOR(scf gas/bbl of oil at STD conditions), j:separator stages Sep gas gross heating value(ai =ERi*L,1/ERi 1074 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 171 Separation Test STO Gravity 18.4 bSeparation Test FVF 1.049 a)scf gas/bbl of condensate at STD conditions b)Fluid volume at Psat&Tres/Fluid volume at STD WCP Oilphase-DBR 41 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 26:Single-Stage Separator Test Vapor Composition(mol%) Sample 1.06 C;Cylinder CSB 11797-QA;Depth 4293 ft.MD Component MW Mole°/0 (g/mol) STAGE 1 STAGE STO Carbon Dioxide 44.01 0.58 0.53 Hydrogen Sulfide 34.08 0.00 0.00 Nitrogen 28.01 0.62 0.23 Methane 16.04 94.77 96.60 Ethane 30.07 1.34 0.98 Propane 44.10 0.75 0.40 I-Butane 58.12 0.76 0.32 N-Butane 58.12 0.33 0.18 I-Pentane 72.15 0.34 0.17 N-Pentane 72.15 0.17 0.11 C6 84.00 0.17 0.16 M-C-Pentane 84.16 0.02 0.04 Benzene 78.11 0.00 0.01 Cyclohexane 84.16 0.01 0.02 C7 96.00 0.05 0.09 M-C-Hexane 98.19 0.02 0.03 Toluene 92.14 0.02 0.02 C8 107.00 0.03 0.05 E-Benzene 106.17 0.00 0.00 M/P-Xylene 106.17 0.00 0.01 0-Xylene 106.17 0.00 0.00 C9 121.00 0.01 0.02 C10 134.00 0.00 0.01 C11 147.00 0.00 0.00 C12 161.00 0.00 0.00 C13 175.00 0.00 0.00 C14 190.00 0.00 0.00 C15 206.00 0.00 0.00 C16 222.00 0.00 0.00 C17 237.00 0.00 0.00 C18 251.00 0.00 0.00 C19 263.00 0.00 0.00 C20 275.00 0.00 0.00 C21 291.00 0.00 0.00 C22 300.00 0.00 0.00 C23 312.00 0.00 0.00 C24 324.00 0.00 0.00 C25 337.00 0.00 0.00 C26 349.00 0.00 0.00 C27 360.00 0.00 0.00 C28 372.00 0.00 0.00 C29 382.00 0.00 0.00 C30 394.00 0.00 0.00 C31 404.00 0.00 0.00 C32 415.00 0.00 0.00 C33 426.00 0.00 0.00 C34 437.00 0.00 0.00 C35 445.00 0.00 0.00 C36+ 934.00 0.00 0.00 Total 100.00 100.00 MW 17.68 17.20 Relative Density(air=1) 0.610 0.594 Dry Gross Heat Content(BTU/scf) 1075 1057 WCP Oilphase-DBR 42 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Table 27:Single-Stage Separator Test Residual Liquid Composition(mol%) Sample 1.06 C;Cylinder CSB 11797-0A;Depth 4293 ft.MD COMPONENT MW Residual Liquid (g/mol) (mol%) 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 0.13 I-Butane 58.12 0.15 N-Butane 58.12 0.11 I-Pentane 72.15 0.28 N-Pentane 72.15 0.15 C6 84.00 0.67 M-C-Pentane 84.16 0.08 Benzene 78.11 0.02 Cyclohexane 84.16 0.11 C7 96.00 0.79 M-C-Hexane 98.19 0.21 Toluene 92.14 0.45 C8 107.00 1.41 E-Benzene 106.17 0.13 M/P-Xylene 106.17 0.11 0-Xylene 106.17 0.11 C9 121.00 1.71 C10 134.00 2.78 C11 147.00 3.38 C12 161.00 4.22 C13 175.00 4.91 C14 190.00 5.04 C15 206.00 5.44 C16 222.00 4.65 C17 237.00 4.77 C18 251.00 4.19 C19 263.00 4.36 C20 275.00 3.92 C21 291.00 3.44 C22 300.00 3.30 C23 312.00 3.17 C24 324.00 2.50 C25 337.00 2.15 C26 349.00 2.30 C27 360.00 2.08 C28 372.00 2.02 C29 382.00 1.88 C30 394.00 1.87 C31 404.00 1.42 C32 415.00 1.35 C33 426.00 1.16 C34 437.00 1.00 C35 445.00 1.00 _ _ C36+ 934.00 15.08 Total 100.00 MW 354.5 WCP Oilphase-DBR 43 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Viscosity Analysis on Sample 1.06 C Reservoir Oil Viscosity at Tres Per client's request, the monophysical liquid phase viscosity was repeated at the reservoir temperature of 67°F. These values as a function of selected pressure steps are summarized in Table 28. The liquid phase viscosity values are graphically presented in Figure 17.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 This time,the viscosity results were reduced but still within the measurement tolerance. The piston chosen for this viscosity testing ranges from 100 - 2000 cP. And based on the manufacturer, the error bar is about+/- 1% of the highest range.The dead oil viscosity at 67°F was also reduced but again it's within the measurement error. Table 28:Reservoir Fluid Viscosity 67°F Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft. MD Pressure Viscosity @ Tres (psia) (cP) 4011 227.7 3547 212.5 3041 195.8 2544 179.0 2050 161.6 15 759.8 WCP Oilphase-DBR 44 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 17:Reservoir Fluid Viscosity 67°F Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft.MD 800 0 700 600 500 •y 400 o . u 300 200 100 0 , 0 1000 2000 3000 4000 5000 Pressure(psia) WCP Oilphase-DBR 45 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Reservoir Oil Viscosity at 150°F The liquid phase viscosity was measured at the reservoir temperature of 150°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 18.As seen in the figures and as expected,the viscosity values decrease with decreasing pressure up to the bubblepoint,which cannot be just determined by this viscosity test. Table 29:Reservoir Fluid Viscosity 150°F Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft. MD Pressure Viscosity @ Tres (psia) (cP) 5524 27.0 4977 25.3 4492 24.0 3989 22.5 3523 21.1 3018 19.5 2518 18.3 15 44.5 WCP Oilphase-DBR 46 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 18:Reservoir Fluid Viscosity 150°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD 45 0 40 35 30 25 20 0 1000 2000 3000 4000 5000 6000 Pressure(psia) WCP Oilphase-DBR 47 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Reservoir Oil Viscosity at 90°F The liquid phase viscosity was measured at the reservoir temperature of 90°F. These values as a function of selected pressure steps are summarized in Table 30.The liquid phase viscosity values are graphically presented in Figure 19.As seen in the figures and as expected,the viscosity values decrease with decreasing pressure up to the bubblepoint,which cannot be just determined by this viscosity test. Table 30:Reservoir Fluid Viscosity 90°F Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft.MD Pressure Viscosity @ Tres (psia) (cP) 5461 123.2 4997 114.3 4504 105.6 4040 96.9 3526 88.4 3030 81.2 2519 73.7 2000 67.5 15 264.5 WCP Oilphase-DBR 48 Job#:200500199 l • Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 19:Reservoir Fluid Viscosity 90°F Sample 1.06 C;Cylinder CSB 11797-GA;Depth 4293 ft. MD 1000 0 1 ,00 - 10 . . . . . . . . 0 2000 4000 6000 8000 Pressure(psial WCP Oilphase-DBR 49 Job#:200500199 r A Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Reservoir Oil Viscosity at 50°F The liquid phase viscosity was measured at the temperature of 50°F. These values as a function of selected pressure steps are summarized in Table 31. The liquid phase viscosity values are graphically presented in Figure 20. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint,which cannot be just determined by this viscosity test. Table 31:Reservoir Fluid Viscosity 50°F Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft. MD Pressure Viscosity @ Tres (psia) (cP) 5560 500.5 4925 456.1 4576 433.5 4027 398.5 3530 366.8 3041 335.9 2524 307.1 2037 283.4 15 1650.0 WCP 0ilphase-DBR 50 Job#:200500199 • Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Figure 20:Reservoir Fluid Viscosity 50°F Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft.MD 1850 1650 O 1450 1250 1050 N t 850 650 450 250 0 1000 2000 3000 4000 5000 6000 Pressure(psia) WCP Oilphase-DBR 51 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Density at Various Temperatures The STO density was measure at four difference temperatures - 50°F, 67°F, 90°F and 150°F. The results were listed in Table 32. We also wanted to measure the monophysical density at 3000 psia and four difference temperatures -50°F, 67°F, 90°F and 150°F but ran out of sample volume. Hence, we combined the full PVT data from the reservoir temperature -67°F and our in-house simulation software -PVTPro to obtain the calculated monophysical densities at those temperatures.The results were listed in Table 33. Table 32:STO Density vs.Temperature Sample 1.06 C;Cylinder CSB 11797-OA; Depth 4293 ft.MD Temperature STO density 1°F) (g/cc) 50 0.9504 67 0.9444 90 0.9349 150 0.9115 WCP Oilphase-DBR 52 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1G-101 Sand: West Sak B Schlumberger Figure 21:STO Density vs.Temperature Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft. MD 0.955 0.950 0.945 - • 0.940 s 0.935 • C as 0.930 0 f. . co 0.925 0.920 0.915 • 0.910 0.905 0 20 40 60 80 100 120 140 160 Temperature(°F) WCP Oilphase-DBR 53 Job#:200500199 y � Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 33:Simulated Monophysical Density at 3000 psia vs.Temperature Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft. MD Temperature Monophysical density (°F) (g/cc) 50 0.9324 67 0.9293 90 0.9249 150 0.9129 Figure 22:Simulated Monophysical Density at 3000 psia vs.Temperature Sample 1.06 C;Cylinder CSB 11797-QA; Depth 4293 ft. MD 0 935 • 0.930 • Ts 0.925 • a H 0.920 0915 • 0 910 . . . 40 60 80 100 120 140 160 Temperature(°F) WCP Oilphase-DBR 54 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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,Z=1) The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. • A positive index indicates scaling tendencies. • A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. WCP Oilphase-DBR 55 Job#:200500199 . it Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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 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 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 WCP Oilphase-DBR 56 Job#:200500199 r - Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 Appendix C:EQUIPMENT Fluid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies.A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer.This unit in conjunction with GC analysis(see below) provides the full fluid compositional analysis, GOR, density at sampling P&T corrected to standard conditions. The JEFRI gasometer consists of a motor-driven piston in a stationary cylinder.The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L.The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr.The operating pressure of the Gasometer is ambient pressure(up to a maximum of 40 psia)and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography(GC). Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FID). In this system, separation of individual components is carried out in a 30m long, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range, the components eluted are from C1 to C36 along with naphthenes and aromatics components. Based on the physical properties, these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas(helium) through the column. With prior knowledge of the amount of "retention" for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching "retention"times.The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns.The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas.The molecular sieve is used to achieve separation of the light gaseous components (nitrogen, oxygen, and methane)while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides.The second column is a packed column as described previously in liquid analysis. This column is capable of achieving separation of components up to C12„ along with the associated naphthenes and aromatics that are lumped into the C6+ fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector (TCD) while the C5+ components are analyzed for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns,and hence,allowing for the correct separation Fluid Volumetric(PVT)and Viscosity Equipment WCP Oilphase-DBR 57 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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 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 A cylindrical piston cell (carrier chamber)with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. WCP Oilphase-DBR 58 Job#:200500199 P • Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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 High pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions. The filter manifold used is rated for 10,000 psia.The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. WCP Oilphase-DBR 59 Job#:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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 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 WCP Oilphase-DBR 60 Job#:200500199 t ' • Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 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 • 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 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 WCP Oilphase-DBR 61 Job#:200500199 _. Client: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Schlumberger Installation: - Job#: 200500199 SAH(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 The data from the three methods were combined to determine the amount of each component type in the original sample.Mass balances were calculated throughout the procedure to assure accurate data. High-Temperature High Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. WCP Oilphase-DBR 62 Job#:200500199 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 inspectio/nof the file. a(~~- 1 ~ ~J Well History File Identifier Organizing (done) RESCAN Color Items: ~Greyscale Items: ^ Poor Quality Originals: ~,.o.,aea iiiuiumiuiuu DI/G' ITAL DATA ,P`1 Diskettes, No. I V~ ^ Other, No/Type: ^ Rescan Needed III (IIIII II OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: Logs of various ki ds: NOTES: ^ Other:: BY: Maria Date: /s/ ProjectProofing IIIIIIIIIIIIII IIIII BY: Maria Date: tJ /s/ Scanning Preparation ~_ x 30 = ~ O O + ~ =TOTAL PAGES ~ ~~ ~~! ~/rte ~ (Count does not include cover sheet) , ^ A/(~ BY: Maria pate: /s/ V ~/' ~" 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: ~'~f ~~ /s/ ~~ 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. II I II II II I II II IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: !sl Comments about this file: a., , ne«,a iuumimiuuu 10/6!2005 Well History File Cover Page.doc • • 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 1Q -101 Oper. Rep: Ian Ives PTD No.: 205 -156 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? ier (specify in commei Onshore / Offshore: Onshore Suspension Date: 11/29/05 Date AOGCC Notified: 08/28/10 Sundry No.: 305 -365 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing ? Photos Taken? Yes IA 0 OA none Condition of Wellhead: Location veified by plot plan. Mono -bore well. Unable to get tubing pressure because there is a BPV in the tubing. Lines blinded with 28" of clean FI20 in cellar. Guard around wellhead. Condition of Surrounding Surface Pad looks good. No signs of any spills Location: Follow Up Actions None Needed: Attachments: Photos (3) REVIEWED BY: Insp. Supry jl' 10/4j, Comm PLB 08/2010 2010- 0828_Suspend_KRU_10- 101_bn.xls Suspended Well Inspection — KRU 1Q -101 PTD 2051560 Photos by AOGCC Inspector B. Noble 8 -28 -2010 O • i r km,„ �. 0 ■ a . { ! y , , t -o 4 # ` • �. ., - . -- k j t -4- --.....4- .............„:„,,,..„.. ...--„,....‘..e....... , N- . r ..,.. , , 4. 11111' i KRU 1Q -101 Suspended Well Inspection 8 -28 -10 bn 1 ,... . � � are, � x , ,i as . iii 1111111111 '' t a ) ! ! . ; ! .— NM°,,,. - - -- * t. 1 It . 1 f., 1 f i ., i t... . tiii 1,. ,. ., , -4.. - - ' _ i - 1 I, , -- re O 1., 3 j 4 p j 1 t j 1 1 () 1 s ! t. cn ! J ! ■ co '9; ;./ t 7 t f ! /' t 1 ! t t o i 7 p ! 4 # e 1 ! ' � co i s a ''f` f 1 f i s -!tf l f a$�c, V., j b x w', , ' - " � . 1 . • ' , ¢ ; 111 4.'" N • • • • • 0[F EtAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 506ANNED JAN 1 2U t MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1Q-101 Sundry Number: 310 -420 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, Daniel T. Seamount, Jr. Chair DATED this - day of January, 2011. Encl. • i Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 WED DEC % 4 Mil December 11, 2010 L L ;A ias Cans. Commission 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 1Q -101 (PTD 205 -156) 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 1Q -101 (PTD 205 -156) 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. n'Y Y Y q Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA OP lI < <, ALASAIL AND GAS CONSERVATION COMMISS 1 1 ,..,\ APPLICATION FOR SUNDRY APPROVALS \- 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r 1 7.94:f.;/ Suspend Plug Perforations E Perforate r Rill Tubing T Time Extension I Operational Shutdow n r Re -enter Susp. Well r Stimulate E Alter casing r Re,nm,,, S,.. S ;a. jr' I 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r , 205 -156 . 3. Address: 6. API Number: Stratigraphic r Service E P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23282 -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 • 1Q -101 • 9. Property Designation: 10. Field / Pool(s): ADL 25634 & 25641 Kuparuk River Field / West Sak Oil Pool - Exploratory 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 5000 3724 J 1673' • 1622' • 1723' NONE Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 20 114' 114' SURFACE 1790 10.75 1824' 1747' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE / NONE 3.5 L - 1569 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) NONE NONE 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development IT service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: NA Oil r Gas r WDSPL r Suspended r.- 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland /Perry Klein Printed Name MJ Loveland /Perry Klein Title: WELL INTEGRITY SUPERVISOR cam Signature , .. - - �� Phone: 659 - 7043 Date /..2 - // - /O Commission Use O Sundry Number61 0 '430 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: -� 1 \ID ` I / DEC 1. 4 2010 Subsequent Form Required: �0s. - .sir ` .� �� - • _ .. _ .:,as L0f1S. C01nnUUS 0 . Oft An ilorag APPROVED BY / Approved by: r , COMMISSIONER THE COMMISSION Date. AB Blom .JAN 4:4 201I N i l d•3 i Form 10 -403 Reved 1/2010 "` R I � I j� Submit in Duplicate jotei KU P 1 Q -101 ConocoPhiQIpS Well Attributes Max Angle & MD TD Alaska, Inc - Wellbore API /DWI Field Name Well Status Inc! (°) MD (ftKB) Act Bbn (ftKB) I. con000n.ltps 500292328200 WEST SAK SUSPENDED 58.25 2,565.45 5,000.0 Comment H23 (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Wail Coo: -10 -101, 91512009238:45 PM —SSSV: NONE Last WO: 11/29/2005 m Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: Build wellbore /casings, tag Imosbor 9/5/2009 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 44.0 114.0 114.0 62.50 H WELDED ;I111 Casing Description String O... String ID... Top (ftKB) Set Depth (L. Set Depth (TVD) ... String Wt... String... String Top Thrd SURFACE 103/4 9.794 33.6 1,823.6 1,745.7 45.50 L -80 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Circulating Tubing 3 1/2 2.992 29.1 1,569.0 1,532.9 9.30 L -80 EUE -MOD String Completion Details HANGER, 29 - - - - -� Top Depth (TVD) Top Inc! Top (ftKB) (81D3) (") Item Description Comment ID (In) r 29.1 29.0 -0.07 HANGER VETCO TUBING HANGER 3.500 _ 1,568.5 1,532.5 29.28 SHOE MULE SHOE/COLLAR 2.992 Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment 1,673.0 1,923.0 1,621.6 1,823.5 Cement Retainer 11/28/2005 Held PJSM with crew and HES tool supervisor on MU W/ Cement Cap of retainer MU Halliburton 103/4" csg EZSV cement retainer and RIH to 1,723' on 5' DP Set EZSV retainer at 1,723' with btm 811,726' and set 25K wt down on retainer, st wt up 55K, dn wt 48K, PU out of retainer Pressure tested retainer and csg to 1,500 psi for 15 min, good test, held PJSM on cementing below retainer Stung back into retainer and est an injection rate at 1 bpm at 280 psi and 2 bpm at 380 psi, bled off pressure and PU out of retainer Dowell pumped 5 bbls water and pressure tested lines to 3,500 psi, mixed and pumped 25 bbls (150 coNDU sxs) of AS1 cement at 15.8 ppg, .93 yield and 4 4.114 additives, followed with 1.5 bbls water, ave 3.5 bpm, held 200 psi back pressure on choke while spotting cement in DP, spotted to within 5 bbls of retainer, stung into retainer and rig fin displacing cement, dg pumped 25 bbls of 9.5 ppg mud placing 20 bds of 1 cement below retainer, shut down and PU laying 5 bbls (50') of cement on top of retainer, Est TOC at 1,673', CIP at 07:50 hrs. SHOE, 1.569 Calvin Timoty HES tool supervisor Jeny Culpepper cementer 4,000.0 4,500.0 3,059.5 3,383.6 Plug Back 11/27/2005 POOH slow 5 stds from 5,000' to 4,499' Circ btms up at 4,499', saw slight sign of cement m � contaminated mud at btms up, circ an add. btms s up with at MW i and out, circ 186 spm, gpm at 1,350 s 0 psi, st wt up, n wt add. citec 2X u btms up Dowell pumped 10 bbls of water, then mixed and pumped 42.8 bbls (207 sxs) of 15.8, 1.16 yield cement with add., ave 3.8 bpm, initial pressure 210 psi, final pressure 185 psi, followed with 1.5 bbls water, tumed over to 5g and rig displaced cement with 64 bbls of 9.5 ppg mud to balance plug, ave 6 bpm at 170 psi, slowed to 3 bpm at 400 psi, CIP at 19:35 hrs, est TOC at 4,000', had full returns throughout job and reciprocated pipe throughout job, NOTE: Cement volume was calculated from 4 arm caliper ave 9" hole plus 10% excess and Chuck Scheve with AOGCC waived witnessing of cement plugs ' 4,500.0 5,000.0 3,383.6 3,723.8 11/27/2005 Circ hole dean for cement job evening MW in and out at 9.5 ppg, dre hole at 183 spm, 545 gpm at 1,300 psi, st wt up 95K, dn wt 70K, circ 2X btms up, held PJSM with rig crew, Dowell and ASRC vac truc drivers Tumed over to Dowell and pumped 5 bbls water, pressure tested lines to 3,500 psi, coot to pump 5 add. bbls of water, mixed and pumped 43.2 bbls (209 SURFACE, 34 t ■824 - - -. sxs) of 15.8 ppg, 1.16 yield cement with additives, ave 4 bpm, initial pressure 250 psi, final 130 psi, followed with 1.3 bbls of water, fumed over to rig and suaPenamn \ 6 bp pumped bbls of 9.5 t 130 psi, slowed ppg mud o 3 bpm at balance 00 psi, IP at 17:25 hrs, est TOC at 4,500', had full retums during Plug, 1,673 job and reciprocated pipe throughout job Notes: General & Safety End Date Annotation 11/29/2005 NOTE: DRILLING ON WELL SUSPENDED 11/29/2005 9/52009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 Abandonment \ , Plug, 4,000 N. Abandonment \ Plug, 5,000 TD, 5,000 ■ ~ ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Shut-in Bottom Hole Pressure: 1Q-101 Run Date: 8/30/2009 September 10, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Q-101 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23282-00 s.j '~;~;'- • if:. .~_ . .. . ... ,,. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com Date: ~~~ -~~ ~ ~~~~J ~~"~ ~~~ ~~' l~ Signed: ~, ,~'~,i ~ ~~~~7 DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051560 Well Name/No. KUPARUK RIV U WSAK 1Q-101 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23282-00-00 MD 5000 TVD 3724 REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR / RES, DENS / NEU, FMI /DSI / SWC + TLC MDT Well Log Information: Log/ Electr Directional S ey Yes (data taken from Logs Portion of Master Well Data Maint Data Digital Dataset Log Log Run Interval OH ! Tye Med/Frmt Number Name Scale Media No Start Stop CH Received Comments +IrED D Lis 13771 ~ Induction/Resistivity J=ec,~ Formation Tester OTH Blu 1 ~^~D Asc Directional Survey (Rp/r 13771 LIS Verification Vr,eD C Lis 13772~Induction/Resistivity '~(~ Formation Tester ~~V1 t~ ~ ~~ ~0 ~ OTH Col 1 i FA C Pds 13852 wee Notes OTH 1 og Sample Blu 1 grog Sonic 25 Blu 1 ~g Sonic 2 Col C Pds 13851 JSonic 2 ~i(1.6g Formation Micro Ima 5 Col 1 Completion Date 11/29/2005 Completion Status SUSP Current Status SUSP UIC N 174 4963 Open 4/6/2006 GR EWR4 CNP SLD ROP ACAL VRI 3400 4866 12/21/2005 MODULAR FORMATION DYNAMICS TESTER 0 0 1/17/2006 DEFINITIVE SURVEY 174 4963 Open 4/6/2006 GR EWR4 CNP SLD ROP ACAL VRI 215 5000 Open 4/6/2006 ROP DGR EWR4 CTN ALD Plus Graphics 3400 4866 4/25/2006 MODULAR FORMATION DYNAMICS TESTER 24- 2005 3400 4866 4/25/2006 MODULAR FORMATION DYNAMICS TESTER, Diploe Sonic Imager DSI FMI GR and Chrono Sample Taker CST/GR 24- Nov-2005 3515 4630 4/20/2006 Chrono Sample Taker CST/GR 27-Nov-2005 1820 5000 4(25/2006 Dipole Sonic Imager DSI/FMI/GR 24-Nov-2005 0 0 4/25/2006 Geoframe Processed Interpretation Best DTI Final Result 24-Nov-05 0 0 4/25!2006 Geoframe Processed Interpretation Best DT" Final Result 24-Nov-05 1820 5000 Case 5/8/2006 Formation Micro-Imager nciicnnuno ~e ~i_., ~nnc DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051560 Well Name/No. KUPARUK RIV U WSAK 1Q-101 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23282-00-00 M 5000 TVD 3724 Completion Date 11/29/2005 Completion Status SUSP Current Status SUSP UIC N Rpt See Notes 0 0 __ 5/8/2006 -- Report: Mudlogging Equipement and Crew, Well Details, Geological Data, Pressure/Formation ', Strangth Data, Drilling ', Data, Morning Reports, Well Logs (on other Log ~'~~ / 13 N ~' Types"') 28-Nov-2006 ~ 870 otes See 0 0 5/8/2006 Report: Mudlogging ...~*~.- `'' Equipement and Crew, Well Details, Geological Data, Pressure/Formation ', Strangth Data, Drilling Data, Morning Reports, Well Logs (on other Log Types"') 28-Nov-2006 ~g Mud Log 2 Col 115 5000 c ~fs C e 5/8/2006 Formation Log ~g Mud Log 2 Col 115 5000 ~ ~ Cade 5/8/2006 Formation Log ,r !'cog ' Mud Log 2 Col 115 5000 c- C9FSe 5/8/2006 Drilling Dynamics wog Mud Log 2 Col 115 5000 5/8/2006 Drilling Dynamics 'wog Mud Log 2 Col 115 5000 5/8/2006 Combo Log wog Mud Log 2 Col 115 5000 C~~e 5!8!2006 Combo Log 0 0 og Gas Analysis 2 Col 115 5000 f`°~.. 5/8/2006 Gas Ratio og Gas Analysis 2 CoI 115 5000 ~ apse 5/8/2006 Gas Ratio I!,f~'` 14342 See Notes 0 0 Case 1/22/2007 Fluid Anal on Botton Hole Samples, Black Oil PVT Study C Pdf 14342 1See Notes 0 0 Case 1/22/2007 Fluid Anal on Botton Hole ', Samples, Black Oil PVT Study Well Cores/Samples Information: Sample Interval Set Name , Start Stop Sent Received Number Comments tti ngs u 120 5000 11/28/2005 1160 DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051560 Well NamelNo. KUPARUK RIV U WSAK 1Q-101 Operator CONOCOPHILLIPS ALASKA INC MD 5000 TVD 3724 ADDITIONAL INFORMATION Well Cored? Y // f~ Chips Received? c~''~ Analysis ~'-J-itl'~ Received? Completion Date 11/29/2005 Completion Status SUSP Daily History Received? Formation Tops Current Status SUSP Y/ ~Y N Comments: APf No. 50-029-23282-00-00 UIC N - --_ Compliance Reviewed By _ _ _ _ _ - ._ Date: __~__ u C7 • .. +C~r~c~rPl~illis 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 West Sak 3J-101 LO/NS 084-130 CD &Hardcopy report a 6 S = ~ ~ 5- °~ /mil 3~i3 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- )35 CD &Hardcopy report X05 -!ate ~ ~~w~ ~~~ /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 1 Q-101 Produced oil ;report and spreadsheet West Sak 1 R-East LO/NS 05-026 CD &Hardcopy report 2 p ~ _ 00 / ~ '~ / ~/ 3 yc / 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 West Sak 1 H-South LD/NS 05-026 CD &Hardcopy report ,a bS- a l a ~- ~~(3~-(,~ 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 ,BCD &Hardcopy report ~ b S - ~~ . ~jC(3~/S VSchlumberger-Analysis of MDT Fluid Samples -Black Oil PVT Study Report; report 200600050; 6/20//2006; (~,l~isk(contains all 5 wells) and &Hardcopy report Kuparuk Labs Report of Analysis; DS 1 Q-101 Produced oil ;report and spreadsheet Please check off each item as received, promptly sign and return the transmittal to address below. Tc~ ,=elf cla7 ~QCipient.~: All dafa <.s conr`identral t.~niil Ci~~te o~`~ .,~ c~ ~., __, "~'C re/Qase da/e~ CC: Andy ndre u, PAI Geologist ~'~~ ~ ~ ,(~~.~ Receipt: - Date: 1~ ~~";," ~~; ~.~ ~a.~t~ F,!1l.~Alal, C~~tNtft~i~~i~s~ w ,~~ 4~ ~~ GIS-Technical Data Management I ConocoPhillips ~ Anchorage, Alaska I Ph: 907.265.6947 Sandra. D. LemkeCa~Conocophillips. com R M i i Kuparuk Laboratory Report of Analysis Report Date: November 28, 2005 To: andreas.c.andreou@conocophillips.com Scott Redman Sample Description: DS 1Q Produced Oil JAN 2, 2 2007 Oil & C~as Cons. ~mmission ~J~ Sam le ID AB06288 Location Code D1Q0 WellNum 101 Collection Date 11/26/05 Collection Time 03:55 LocDescri for Anal sis Name Results Units API at 60 de ees F DRY 18.0 De ees API If there are any questions regarding this data, please call KLS at 659-7214. Completed By: BG Reviewed By: MA ~s - rs~ ~ ~<<3~a • • Sample_ID Well Sand Depth Type API GCMS-Global Curve GC-Global Curve Comment US136732 1Q-101 UgnuB 3515 SWC 14.9 n.a. Average 1Q-101 UgnnB SWC n.a. 14.9 n.a. n.a. n.a. high uncerhiinli~ US136733 1Q-101 UgnuA 3911 SWC 8.7 n.a. Average ]Q-101 UgnuA SWC n.a. 8.7 n.a. n.a. n.a. hi8h unrertaintq US136775 1Q-101 B NSA Oil 18.6 n.a, US136776 1Q-101 B NSA Oil 18.4 n.a. Average IQ-101 B OlL 18 18.5 OS ri.a. n.a. US136734 1Q-101 D 4158 SWC 13 n.a. US136737 1Q-101 D 4177 SWC 13.6 n.a. USi36739 1Q-101 D 4182 SWC 13.9 n.a. US136741 1Q-101 D 4184 SWC 13.6 n.a. US136742 1Q-101 D 4186 SWC 13.8 n.a. US136745 iQ-101 D 4190 SWC 13.4 n.a. US136748 1Q-101 D 4206 SWC 12.5 n.a. Average iQ-101 D SWC n.n. 13.4 n.a. n.a, n.a. U5136751 1Q-101 B 4220 SWC 18.5 n.a. US136752 1¢101 B 4278 SWC 16.4 n.a. U5136753 1Q-101 B 4280 SWC 18.1 n.a. US136754 1Q-101 B 4286 SWC 18.2 n.a. US136756 1Q-101 B 4286 SWC 17.9 n.a. US136760 1Q-101 B 4300 SWC 16.3 n.a. Average 1Q-101 B SWC 18 17.6 0.4 ~~.a. n.a. US136761 1Q-101 A4 4314 SWC 17.4 n.a. US136762 1Q-101 A4 4316 SWC 18 n.a. Average 1Q-101 A~4 SWC n.a. 17.7 n.a. n.a, n.a. US136763 1Q-101 A3 4367 SWC 20.8 n.a. USi36764 1Q-101 A3 4471 SWC SWC 20.4 a 6 n 20 n.a. n.a. n a Average US136767 iQ-101 1Q-101 A3 A2 4534 n.a. SWC . , . contminated . , n.a. US136768 1Q-101 A2 4556 SWC 20.9 n.a. US136769 1Q-101 A2 4561 SWC 21.2 n.a. USi36773 1Q-101 A2 4628 SWC 20.4 n.a. US136774 Average 1Q-101 1Q-]07 A2 A2 4630 SWC SWC n.a. 20.6 20.8 n.a. n.a. n.a. n.a. z ~--~ r TRANSMITTAL CONFIDENT/AL DATA ~ ~~5 °~~~ FROM: Sandra D. Lemke, AT01486 TO: Librarian ConocoPhillips Alaska, Inc. Alaska Oill and Gas Conservation Commission P.O. Box 100360 333 W. 7`h Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 1Q-101 Permit: 205-156 DATE: 5/4/2006 via mail I ransmltted: West Sak 1 Q-101 500292328200 Report and CDROM Epoch- Final Well Report Mudlogging Data; 11/28/2005; Brian O'Fallon and Fletcher England; includes color prints of Formation log 115-5000' MD &TVD 2"=100'; drilling dynamics MD &TVD; Combo Log MD & ND; Gas Ration log MD & TVD; CDROM contains DML Database, final well reports, morning reports, LAS files, LOG PDF image and lithology remarks files. Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska desi Hated AOGCC re/ease date CC: Andy An reou, CPAI Geolo~ist Receipt: ~~~.1~'V~/ Date: _'U`z ~C~~ .. _, - GIS-Technical Data Management ~ ConocoPhillips ~ Anchorage, Alaska ~ Ph: 907.265.6947 Sandra. D. LemkeC~Conocophillips, com Scbbnaberger Alaska Data $ Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ i,l~ a ~~ Log Description N0.3773 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Date BL Color CD 05/01 /O6 L-50 40012487 OH LDWG EDIT OF MWD/LWD 10/18/05 2 1 18-13 11225959 USIT 04/13/08 1 D.S.15-49A 11211378 SCMT 04/07/08 1 02-096 11258893 SGMT 04108106 1 P2-11A 11285928 SCMT 04120/06 1 PWDW2-1 10563132 TEMPERATURE LOG 02115/03 1 J-26 10550274 LDL 05/20103 1 W-29 10672333 LDL 10128/03 1 W-25 11072872 LDL 07114105 1 R-O6A 10572081 LDL 02/28103 1 N-21A 10703973 LDL 02115/04 1 PWDW2-1 10580235 LDL 03101/03 1 Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth • WELL LOG TRANSMITTAL To: State of Alaska March 22, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 I RE: MWD Formation Evaluation Logs 1Q-101, AK-MW-4046668 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 1 Q-101: Digital Log Images 50-029-23282-00 G QG 1 CD Rom G~~ d~'~1 s`~ • • WELL LOG TRANSMITTAL To: State of Alaska March Z1, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1Q-101, AK-MW-4046660 1 LDWG formatted Disc with verification listing. ~ ~ I API#: 50-029-23282-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ Signed: s~-ls~ e ConocoPhillips March 31, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 9951-0-0360 Phone: 907-265-6830 Subject: Well Completion Report for 1 Q-101 (APD 205-156 / 305-365) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 Q-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 MAR 3 ~. 2006 Alaska C6~ ~~ ~s ~c~-> . ~vu~°;~miss~r~ RT/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 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., or Aband.: November 29, 2005 ~ 12. Permit to Drill Number: 205-156 / 305-365 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 15, 2005 ~ 13. API Number: 50-029-23282-00 4a. Location of Well (Governmental Section): Surface: 1574' FNL, 1160' FEL, Sec. 26, T12N, R9E, UM ' 7. Date TD Reached: November 23, 2005 14. Well Name and Number: 10-101' At Top Productive Horizon: 255' FSL, 135' FWL, Sec. 24, T12N, R9E, UM 8. KB Elevation (ft): 30' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 4496' FNL, 4803' FEL, Sec. 24, T12N, R9E, UM 9. Plug Back Depth (MD + TVD): 1673' MD / 1622' TVD West Sak Oil Po01 -Exploratory 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528465 ' y- 5984299 Zone- 4 10. Total Depth (MD + TVD): 5000' MD / 3724' TVD 16. Property Designation: ADL 25641 & 25634 TPI: x- 529752 y- 5986133 Zone- 4 Total Depth: x- 530091 - 5986663 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 18. Directional Survey: Yes 0 No^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1666' MD 21. Logs Run: GR/Res, Dens/Neu, FMI/DSI/SWC + TLC MDT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# K-55 30' 115' 30' 115' 40" 26o cf ArcticCRETE 10.75" 45.5# L-80 30' 1823' 30' 1747' 13.5" 469 sx AS Lite, 280 sx AS I cement retainer @ 1723' 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 1583' none none . 25. ACID, FRACTURE, CEME EEZE, ETC. DEPTH INTERVAL (MD) ~ I F ATERIAL USED 4500'-5000' 209 sx Class G 4000'-4500' s 1673'-1923' 150 sx ASI - ~. e¢. 7~i r~A °. 4....: 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-MCF 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". y,.:,.; ':;I NONE ~ ,_LL~ 2. ```'' 1 ~f:%'~=~0 ~.__ Form 10-407 Revised 12/2003 ~ ~ @~ ar~ ~ ~O~pNTINUED ON REVERSE ~ ~~ ~` ~ ,, ~ ~'"(In r ~Upp ,~ ~,~/~ ze. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD InGude and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 10-101 Top West Sak 4153' 3156' Base West Sak 4883' 3641' ' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield @ 265-6377 Printed Nam Randv Thomas Title: Greater Kuaaruk Area Drillino Team Leader Signature ~ ~~n%~5.--~..r---.Wyy~e LL- ~ ~,-Z s ~j Date ~ l3 r ~f' INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Ketly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 11/13/2005 i 00:00 - 12:00 1 Q-101 1 Q-101 ROT -DRILLING n1433@conocophillips.com Nordic 3 Hours '' Code Code Phase -- -- 12.00 ~ RIGMNTI OTHR i RIGUP 12:00 - 00:00 12.00 RIGMNTI OTHR RIGUP 11/14/2005 00:00 - 12:00 12.00 RIGMNTI OTHR ~ RIGUP 12:00 - 13:00 1.00 RIGMNT OTHR RIGUP 13:00 - 13:30 0.50 RIGMNT, SFTY RIGUP 13:30 - 17:00 I 3.501 RIGMNTI OTHR I RIGUP 17:00 - 18:00 I 1.00 I WELCTLI BOPE I RIGUP 18:00 - 18:30 I 0.50 DRILL SFTY RIGUP 18:30 - 00:00 ! 5.50 DRILL PULD ;RIGUP 11/15/2005 00:00 - 05:30 5.501 DRILL PULD RIGUP 05:30 - 08:30 ; 3.001 DRILL ;PULD I RIGUP 08:30 - 11:00 1 2.50 DRILL OTHR RIGUP 11:00 - 13:00 ~ 2.00 (DRILL ~ PULD I SURFAC 13:00 - 14:00 I 1.00 DRILL CIRC SURFAC 14:00 - 14:30 ~ 0.50. DRILL ,DRLG .SURFAC 14:30 - 15:00 0.50 DRILL TRIP SURFAC 15:00 - 19:30 4.50 DRILL PULD SURFAC 19:30 - 00:00. 4.50. DRILL I DRLG I SURFAC 11/16!2005 100:00 - 12:00 I 12.00 ~ DRILL DRLG SURFAC 12:00 - 14:30 I 2.501 DRILL I DRLG I SURFAC Page 1 of 8 Spud Date: 11/15/2005 Start: 11/13/2005 End: 11/29/2005 Rig Release: 11/29/2005 Group: Rig Number: 3 Description of Operations Continue prepping motor room for painting, change out choke manifold pressure gauge, change gear oil in mud pump #2, check all pits for leaks and bad valves, perform top drive service. Clean and organize rig equipment, work on barrel warm-up shack, prep areas for painting, clean the camp generator room. Continue hook up (electrical) of service shacks. Off load smart tools from trucks. RIG on Standby last 24 Hrs. Continue cleaning, painting and performing rig maintenance. Rack & tally 14 jnts 5" HWDP and on-load BHA #1 in shed. Install CPAI computers in M-1 lab and Sperry unit. Continue wiring up Mongoose shaker on cuttings box. R/U EPOCH unit. Continue cleaning, painting and performing rig maintenance. Held pre-spud meeting with engineer, both rig crews, environmental rep, and assigned service reps. Install 4 1/2" IF saver sub on top drive. Set torque on top drive. R/U to P/U 5" DP from pipe shed. Perform diverter test with state rep John Crisp witness. Perform draw-down test, test pit alarms, flow alarm and gas alarms. All tested OK. ACCEPTED RIG at 18:00 Hrs 11/14/05 Hold PJSM with new crew on tour, on P/U DP from pipe shed. Start P/U of 5" DP from pipeshed, & M/U studs in mouse hole. Rack back in derrick. Fin PU and standing back 5" DP from pipeshed, stood back a total of 43 stds PU 5 stds of5" HWDP and jars from pipeshed, M/U in mouse hole and stood back in derrick. Modify mongoose shaker at cuttings chute for spud. Cont to condition and weight up to 9.2 ppg spud mud, and RU Sperry Sun's surface read out gyro. P/U 8" Sperry mud motor with 1.83 deg bend, M/U 13 1/2" bit #1 and 11 7/16" string stab. RIH and tagged fill inside conductor at 73' Cleaned out conductor from 73' to 145', circ at 350 gpm at 400 psi Spudded well at 14:00 hrs 11/15/05 and drilled 13 1!2" hole from 145' to 215'. POOH from 215' to mud motor at 30' Held PJSM and M/U 13 1/2" BHA #1 with MWD/LWD, oriented and uploaded MWD, P/U UBHO sub and 3 NMFDC's RIH to 215'. Drilled 13 1/2" hole per directional plan from 215' to 543' MD/541' TVD (328'). ART 1.72 hrs, AST .39 hrs, 2-20K wob, 45 rpm's, 135 spm, 405 gpm, 1,200 psi, rot wt 48K, up wt 48K, dwn wt 48K, on btm torque 888 ft/Ibs, off btm torque= 230 ft/Ibs, ran gyro survey's at 100', 173', 264', 354', and 445'. total survey time for 5 gyro's was 1 hr. Directionally drilled 13 1/2" hole from 543' to 1,188' MD/ 1,177' TVD, (645') ART 3.03 hrs, AST 3.83 hrs, 5-35K wob, 45 rpm's, 125 spm, 370. gpm, off btm pressure 1,200 psi, on btm pressure 1,400 psi, off btm torque 1,450ft/Ibs , on btm torque 1,850 ft/Ibs, rot wt 65K, up wt 65K, do wt 65K, RD Gyro at 820'. Directionally drilled 13 1/2" hole from 1,188' to 1,297' MD/ 1,283' TVD, (109') ART -0- hrs, AST 1.01 hrs, 25-35Kwob, -0- rpm's, 125 spm, 370 gpm, on btm pressure 1,200 psi, no rotation, rot wt 65K, up wt 65K, do wt 65K, unable to get desired build rate with 1.83 motor and decision was made to POOH and change to motor to a 2.3 deg bend. Printed: 3/88006 11:0821 AM ConocoPhillips Alaska Page 2 of 8 Operations Summary Report' k Legal Well Name: 1Q-101 Common Well Name: 1Q-101 Spud Date: 11/15/2005 Event Name: ROT -DRILLING Start: 11/13/2005 End: 11/29/2005 Contractor Name: n1433@conocophillips.com Rig Release: 11/29/2005 Group: Rig Name: Nordic 3 Rig Number: 3 Date .:.From - To Hours Code ', Code I Phase I Description of Operations 11/16!2005 14:30 - 18:00 3.50 DRILL , 18:00 - 19:00 1.00 DRILL 19:00 - 21:15 2.25 DRILL 21:15 - 23:30 ; 2.25 ~ DRILL 23:30 - 00:00 0.50; DRILL 11!17/2005 1 00:00 - 00:30 , 0.50 DRILL 00:30 - 02:30 ' 2.00 DRILL 02:30 - 06:30 4.00 DRILL i 06:30 - 07:30 1.00, DRILL ' 07:30 - 09:00 i 1.50 DRILL 09:00 - 10:30 1 i 1.50 DRILL 10:30 - 12:00 I 1.50 ~ DRILL 12:00 - 13:45 1.75 ~ DRILL 13:45 - 14:45 1.00 DRILL 14:45 - 15:45 1.00 DRILL 15:45 - 17:45 ; 2.001 DRILL 17:45 - 18:00 I 0.251 DRILL 18:00 - 19:00 1.00 RIGMP 19:00 - 22:00 3.00 DRILL 22:00 - 00:00 i 2.001 DRILL 11/18/2005 i 00:00 - 02:30 2.50 j DRILL 02:30 - 03:30 1.00 i CASE 03:30 - 07:15 ~ 3.75 I CASE 07:15 - 07:30 0.25 CASE 07:30 - 12:00 4.50. CASE TRIP SURFAC Blow down top drive and monitor well-static, POOH from 1,297 MD! 1,283' TVD. OTHR SURFAC 1 Change mud motor angle from 1.83 deg to 2.3 deg and oriented mud motor, cleaned rig floor. TRIP SURFAC RIH with BHA #2 to 1,297' with no ledges or fill. DRLG SURFAC ,Directionally drilled 13 1/2" hole from 1,297' to 1,442 MD/ 1,416' TVD, i (145') ART .24 hrs, AST 1.38 hrs, 30K wob, 30 rpm's, 191 spm, 569 gpm, off btm pressure 1,480 psi, on btm pressure 2,200 psi, off btm torque 1,650, on btm torque 2,600, rot wt 70K, up wt 70K, do wt 67K, rack and tally 10 3/4" casing. REAM SURFAC Circ hole while washing and reaming thru 12 deg dog leg at 1,442' MD DRLG SURFAC ~ Drilled 13 1/2" hole from 1,442' to 1,470', ART .43 hrs, AST -0-. REAM SURFAC Stood back 1 std and washed and reamed thru 12.7 deg dog leg at 1,355', RIH to btm at 1,470'. DRLG SURFAC i Directionally drilled 13 1/2" hole from 1,470' to 1,720' MD (250') ART 1.31 hrs, AST 1.02 hrs, 20-30K wob, 27 rpm's, drilled at 445 to 525 gpm, 1,250 psi to 1,500 psi, torque off btm 1,500 ft/Ibs, on btm 2,200 ft/Ibs, rot wt 65K, up wt 65K, do wt 65K. CIRC SURFAC Circ hole at reduced rate while changing out shaker screens on cuttings box shaker and waiting on super suckers to arrive at rig. DRLG S SURFAC Directionally drilled 13 1/2" hole from 1,720' to 1,830' MDl1,751' TVD, 10 3/4" Csg Pt. (110') ART 0.41 hrs, AST 0.29 hrs, 10-15K wob, 27 rpm's, drilled at 184 spm, 550 gpm off btm pressure 1,770 psi, on btm 1,810 psi, off btm torque1,350 ft/fbs, on btm 2,050 ft/Ibs, rot wt 73K, up wt 75K, do wt 75K. CIRC SURFAC Pumped 30 bbl weighted hi vis sweep (11b over MW) and circ out of hole, circ at 550 gpm, 2,000 psi and 30 rpm's, had no increase in i cuttings back from sweep. REAM SURFAC Backreamed out of hole 6 stds from 1,830' to 1,300', BROOH at 550 gpm at 1,950 psi and 30 rpm's, last 2 stds pulled at slower rate to get a btms up, no problems BROOH. WIPR SURFAC i POOH wet on elevators from 1,300' to BHA and HWDP at 634', no i problems POOH. WIPR SURFAC RIH from 634' to 1,770' with no problems. REAM SURFAC Washed down from 1,770' to 1,830'. Washed down with #2 rig pump, while working on #1 rig pump's "rod oiler" pump. CIRC ~ SURFAC i Pumped 30 bbl weighted hi vis sweep (21b over MW) and circ out of hole, had 10% increase in cuttings, cont to circ hole clean for trip out of hole, circ hole at 178 spm, 530 gpm, 1,980 psi, 30 rpm's, circ 3X btms up and was clean at shakers. OBSV ; SURFAC ~ Dropped Sperry Sun's ESS survey tool and monitored well-static, blow down top drive. RGRP SURFAC Removed top-drive grabber device for repair work. TRIP SURFAC POOH wet on elevators from 1,830', stood back HWDP POOH to NMFDC's, MWD/LWD at 181', no problems POOH PULD SURFAC I LD NMFDC's, UBHO sub and float sub. RU and plugged into and down loaded MWD. Clean rig floor. PULD SURFAC Fin downloading MWD and LD remaining BHA #2 OTHR ; SURFAC Made dummy run with Vetco Gray hanger and landing jt. RURD ! SURFAC , RU to run 10 3/4" csg, MU Franks fill up tool, changed out elevator bales and RU GBR's csg equipment. SFTY SURFAC Held PJSM with rig crew and tong operator on running of csg RUNC ,SURFAC MU 10 3/4" float shoe, 2 jts 10 3/4" 45.5# L-80, BTC csg, flt collar, Printed: 3/8/2006 11:08:21 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 Q-101 Common Well Name: 1Q-101 Event Name: ROT -DRILLING Start: 11/13/2005 Contractor Name: n1433@conocophillips.com Rig Release: 11/29/2005 Rig Name: Nordic 3 Rig Number: 3 Date 'From - To Hours I Code ~ Sub ~I phase ~' Code 11/18/2005 ~ 07:30 - 12:00 ~ 4.501 CASE RUNC SURFAC 12:00 - 12:30 12:30 - 14:15 14:15 - 15:15 15:15 - 16:45 0.50 CASE ~ RUNC j SURFAC 1.75 i CEMEN CIRC SURFAC 1.00 CEMEN I RURD ~ SURFAC 1.50 CEMEN CIRC SURFAC 16:45 - 19:00 19:00 - 19:30 2.251 CEMENlf PUMP I SURFAC 0.501 CEMENlf DISP !SURFAC 19:30 - 23:00 3.50 23:00 - 00:00 1.00 11/19/2005 I 00:00 - 02:30 I 2.50 02:30 - 07:30 5.00 (07:30 - 09:00 1.50 09:00 - 19:00 10.00 19:00 - 21:00 ! 2.00 21:00 - 00:00 3.00 PULD (SURFAC NUND I SURFAC NUND SURFAC NUND SURFAC NUND SURFAC I NUND ~ SURFAC NUND ;SURFAC BOPESURFAC Page 3 of 8 Spud Date: 11/15/2005 End: 11 /29/2005 Group: Description of Operations thread locked Conn below FC and circ thru shoe track, RIH with 10 3/4" csg to 1,786' with no problems and good pipe displacement, st up wt 85K, do wt 77K MU hanger and landed csg with float shoe at 1,823.56' MD/ 1,746' TVD and float collar at 1,739', no problems RIH, Ran a total of 44 jts (1,783') of 45.5#, L-80, BTC csg, total csg, float equip and hanger, 1,790', ran 13 bow spring centralizers and 3 stop rings per well plan Circ btms up thru fill up tool and began cond mud for cementing, staged pump rate up to 5.5 bpm at 250 psi, st wt up 85K, do wt 77K, initial MW out 10.0 ppg, 126 vis and 48 YP. RD Franks fill up tool, blew down top drive and MU Dowell's cement head Fin circ and conditioning mud for cementing, initial MW was 10.0 ppg and 126 vis and 48 YP, final MW out, 9.8 ppg, 55 vis, 26 PV and 14 YP, circ at 7 bpm at 300 psi, st wt up 100K do wt 83K, held PJSM with Dowell, ASRC vac truck drivers, MI mud eng's and rig crew on cementing operations while circ. Turned over to Dowell and cemented 10 3/4" csg, pumped 5 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 45 bbls of CW 100 (50 bbls total), then pumped 46 bbls of 10.5 ppg mudpush, ave 4 bpm at 140 psi, dropped btm plug, began mixing and pumping Arcticset lite lead slurry, pumped 372 bbfs (469 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.8 bpm at 100 psi, followed with 45 bbls (280 sxs) of Arcticset 1 tail cmt at 15.7 ppg and .93 yield with add., ave 6.8 bpm at 100 psi, reciprocated csg and had full returns, shut down and dropped top plug. Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 148 bbls of 9.9 ppg mud, displaced cmt at 7 bpm, initial circ pressure 275 psi, max pressure 445 psi, slowed rate to 4 bpm and bumped plug on talc displacement, pressured up to 1,500 psi, checked floats and held, CIP @ 19:30 hrs, had full returns during job and had 150 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 19:05 hrs, 20 bbls into displacement, stopped reciprocating pipe and landed hanger after having good 10.7 ppg cement back to surface. R/D cement head and hoses, R/D spiders, back out and L/D Vetco landing joint, R/U and flush diverter stack and gun barrel with rinsate truck. ND gun barrel and remove from cellar. Split gun barrel and clean out. Start cleaning mud pits. Fin ND diverter and 16" diverter line, cleaned out diverter box Removed riser and flushed out diverter, stood back same, removed Vetco Gray starting head and removed from cellar, set in wellhead. MU Vetco Gray threaded adapter flange and NU 11" 5M MB 228 tbg head, tested seals to 5,000 psi for 10 min and ck ok. PU & set 11" 5M BOP stack on wellhead & NU same While hand was attempting to undo a grayloc fitting, wire used to hold socket on impact wrench came loose striking his forearm causing a slight abrasion. First aid was given and ice applied to the arm, hand did not want to go to medic and returned to work. Changed out upper set of 3 1/2" pipe rams over to 5" DP RU and began testing BOP's, testing rams, valves and choke manifold to 250 psi low and 3,000 psi high, NOTE: John Spaulding W/AOGCC on location to witness test, having trouble getting blind rams to hold Printed: 3/8/2006 11:08:21 AM ConocoPhi(Lips Alaska Operations Summary .:Report Legal Well Name: 1 Q-101 Common Well Name: 1 Q-101 Event Name: ROT -DRILLING Contractor Name: n1433@conocophillips.com Rig Name: Nordic 3 Date From - To ~ Hours ~ Code Code ~' Phase 11/19/2005 21:00 00:00 3.00 WELCTL~BOPE SURFAC 11/20/2005 00:00 - 07:45 7.75. WELCT BOPE i SURFAC 07:45 - 09:00 1.25 DRILL RIRD SURFAC 09:00 - 09:15 0.25 DRILL SFTY SURFAC 09:15 - 17:15 8.00; DRILL PULD ;SURFAC 17:15 - 20:30 I 3.251, DRILL TRIP j SURFAC 20:30 - 22:00 1.50' DRILL SFTY SURFAC 22:00 - 22:15 0.25 DRILL TRIP SURFAC 22:15 - 23:00 0.75. i DRILL CIRC ~ SURFAC 23:00 - 00:00 i 1.00 ~ CASE DEQT SURFAC 11/21/2005 00:00 - 01:45 1.75 CASE 'DEQT SURFAC 01:45 - 02:15 0.50. CASE CIRC i SURFAC 02:15 - 03:30 f 1.25 CASE ~DEOT SURFAC 03:30 - 05:30 I 2.00 CEMEN DSHO SURFAC 05:30 - 06:00 I 0.501 DRILL I CIRC I SURFAC 06:00 - 07:30 1.501 DRILL I LOT SURFAC 07:30 - 08:45: 1.25; DRILL CIRC PROD 08:45 - 14:15 5.50 DRILL i OTHR PROD 14:15 - 15:30 '; 1.251 DRILL CIRC PROD 15:30 - 00:00 I 8.50 I DRILL i DRLG I PROD 11/22/2005 00:00 - 12:00 12.00 DRILL DRLG i PROD Page 4,of 8 Spud Date: 11/15/2005 Start: 11/13/2005 End: 11/29/2005 Rig Release: 11/29/2005 Group: Rig Number: 3 Description of Operations pressure. Fin. testing BOPE to 250 psi low and 3,000 psi high, blind rams failed ~ and changed out same, re-tested blind rams and checked ok, pulled test plug and RD test equipment, Note: John Spaulding W/AOGCC witnessed test PU elevators and bales then RU pipe spinners Held PJSM with rig crew and Sperry Sun reps on PU and MU BHA PU and MU 8 1/2" BHA with bit #2 RIH to 200', MU 7" motor with 1.5 ,deg bend, MPT, w/DGR, EWR, PWD, MWD w/ALD, CTN and ACAL, oriented MWD and uploaded same, had to steam CTN tool to get tool to work, held PJSM and loaded radioactive sources, RIH PU 3-NMFDC's to 200'. Performed shallow pulse test, blew dwn top drive, cont RIH with 5" HWDP and jars from derrick to 654'. PU 15 jts of 5" DP from pipeshed and RIH with 5 studs from derrick to 1,600' and Filled pipe. Performed strippig drill and well kill drill with drilling crew, CPAI reps and Tour pusher. Cont RIH from 1,600' to 1,710', just above float collar set at 1,739'. Dwn wt 65K, Up wt 75K. Circ hole at 1,710' for csg test, circ at 126 spm, 368 gpm at 1,100 psi, evened MW in and out at 9.8 ppg RU and began to test 10 3/4" surface casing to 3,000 psi and pressure bled down at 750 psi, trouble shooting pressure loss Attempted to test 10 3/4" csg, trouble shoot surface equip. Circ an additional btms up, MW in and out at 9.8 ppg, circ at 212 gpm at 800 psi RU and tested 10 3/4" csg to 3,000 psi for 30 min RIH from 1,710' and tagged cmt at 1,729' (FC @ 1,739'), drilled out float collar, shoe track and float shoe at 1,823', cleaned out to btm at ,1,830' then drilled 20' of new formation to 1,850' MD/1,768' TVD, drilled out with 4-8K wob, 115 spm, 342 gpm, at 1,200 psi, 2,800 ft-Ibs torque on btm, 2,500 ft-Ibs torque off btm. Circ hole clean for LOT, circ 2X btms up evening MW in and out at 9.8 ppg, circ at 490 gpm at 1,630 psi, rot wt 62K, up wt 62K, do wt 62 i RU and performed LOT to 12.4 ppg EMW, 240 psi at 1,741' TVD with 9.8 PP9 MW Pumped low vis sweep made from spud mud and followed with 35 bbl hi vis sweep made from 9.2 ppg Flo-Pro mud, then displaced hole over from 9.8 ppg spud mud to 9.2 ppg Flo-Pro, with Flo Pro back at surface shut down Cleaned around pollution pan, shakers and mud pits preparing to take on Flo-Pro mud. Circ hole with 9.2 ppg Flo- Pro mud to shear same and take into pits, circ hole and est clean hole ECD's, at 500 gpm, 60 rpm's, clean hole ECD was 9.7 ppg, at 525 gpm, 60 rpm's clean hole was 9.75 ppg Directionally drilled 8 1/2" hole per directional plan from 1,850' to 2,444' MD/ 2,181' TVD (594'), ART 2.47 hrs, AST 3.1 hrs, 2-12K wob, 60 rpm's, 175 spm, 521 gpm, off btm pressure 1,550 psi, on btm pressure 1,650 psi, off btm torque 4,214 ft-Ibs, on btm torque 4,750 ft-Ibs, rot wt 70K, up wt 75K, do wt 70k, 9.2 ppg Flo-Pro MW, ave ECD 10.14 ppg, ave BGG 15 units, max gas 30 units Directionally drilled 8 1!2" hole per directional plan from 2,444' to 3,234 MD/ 2,628' TVD (790'), ART 4.81 hrs, AST 1.69 hrs, 3-8K wob, 45-60 Printed: 3/8/2006 11:08:21 AM ConocoPhillips Alaska. Operations Summary Report Page 5 of 8 Legal Well Name: 1Q-101 Common Well Name: 1Q-101 Spud Date: 11/1.5/2005 Event Name: ROT -DRILLING Start: 11/13/2005 End: 11/29/2005 Contractor Name: n1433@conocophillips.com Rig Release: 11/29/2005 Group: Rig Name: Nordic 3 Rig Number: 3 Date 11 /22/2005 From - To ' Hours Code Co_de', Phase 00:00 - 12:00 12.00 ~ DRILL DRLG PROD 12:00 - 19:00 19:00 - 19:30 19:30 - 00:00 11 /23/2005 100:00 - 09:30 09:30 - 11:00 11:00 - 11:15 11:15 - 13:00 13:00 - 15:15 15:15 - 16:30 16:30 - 17:15 17:15 - 18:15 18:15 - 20:15 20:15 - 22:00 22:00 - 22:15 22:15 - 00:00 11 /24/2005 j 00:00 - 03:30 03:30 - 04:30 04:30 - 07:00 07:00 - 08:30 7.001 DRILL I DRLG I PROD 0.50 DRILL DRLG ;PROD 4.50 DRILL I DRLG .PROD 9.50 (DRILL i DRLG i PROD 1.501 DRILL I CIRC I PROD 0.25 I DRILL ~ OBSV I PROD 1.751 DRILL ';WIPR iPROD 2.25 I DRILL I REAM I PROD 1.251 DRILL I WIPR I PROD 0.751 DRILL (CIRC !PROD 1.00 RIGMNT RSRV PROD 2.00 DRILL WIPR PROD 1.751 DRILL i CIRC PROD 0.25 DRILL OBSV PROD 1.75 DRILL TRIP PROD 3.501 DRILL (TRIP ;PROD 1.00 DRILL !PULD PROD 2.501 DRILL PULD PROD 1.501 DRILL PULD PROD Description of Operations rpm's, 170 spm, 502 gpm, off btm pressure 1,450 psi, on btm pressure 1,550 psi, off btm torque 4,000 ft-Ibs, on btm torque 4,200 ft-Ibs, rot wt 76K, up wt 95K, do wt 65k, 9.3 ppg Flo-Pro MW, ave ECD 10.2 ppg, max ECD 10.44 ppg, ave BGG 15 units, max gas 30 units, est top of Ugnu C at 2,860' MD/ 2,378' TVD. Directionally drilled 8 1/2" hole per directional plan, from 3,234' to 3,668' MD/ 2,867' TVD (434'), ART 3.83 hrs, AST .88 hrs. Changed out swab on #2 rig pump. Directionally drilled 8 1/2" hole per directional plan from 3,668' to 4,239' MD/ 3,213' TVD {571'), ART 2.53 hrs, AST .34 hrs, 2-20K wob, 45-60 rpm's, 170 spm, 502 gpm, off btm pressure 1,500 psi, on btm pressure 1,610 psi, off btm torque 6,300 ft-Ibs, on btm torque 7,770 ft-Ibs, rot wt 85K, up wt 95K, do wt 80k, 9.2+ ppg Flo-Pro MW, ave ECD 10.3 ppg, max ECD 10.37 ppg, ave BGG 150 units, max gas 462 units, est top of West Sak "C" at 4,152' MD/ 3,156' TVD. Directionally drilled 8 1/2" hole per directional plan from 4,239' to 5,000' MD/ 3,724' TVD (761'), ART 5.71 hrs, AST .59 hrs, 5-20K wob, 70 rpm's, 170 spm, 506 gpm, off btm pressure 1,700 psi, on btm pressure 1,800 psi, off btm torque 6,900 ft-Ibs, on btm torque 8,200 ft-Ibs, rot wt 95K, up wt 140K, do wt 80k, 9.3 ppg Flo-Pro MW, ave ECD 10.6 ppg, max ECD 10.9 ppg, ave BGG 150 units, max gas 530 units from 4,865', est top of West Sak "D" at 4,159' MD! 3,158' TVD, "B" at 4,279' MD/3,239' TVD, "A2" at 4,534' MD/3,405' TVD Pumped 35 bbl hi vis sweep and circ out of hole, had 10% increase in cuttings back from sweep, circ a total of 3X btms up and was clean at shakers, circ hole at 190 spm, 564 gpm at 2,100 psi and 70 rpm's, BGG down to 60 units, took SPR's Monitored well-static POOH wet on elevators from 5,000' to 3,344' and began to see 20K drag in Ugnu Precautionary backreamed out of hole thru Ugnu from 3,344' to 2,730', with pumps off pulled 20K over at 3,166', cont to BROOH to 2,730', BROOH at 70 rpm's, 483 gpm at 1,600 psi Cont to wipe hole, POOH wet on elevators from 2,730' to 1,789' with no problems, (10 3/4" shoe at 1,823') Circ btms up at 1,789', circ at 134 spm, 400 gpm at 1,000 psi and 20 rpm's inside the shoe, blew down top drive. Serviced top drive and drawworks. RIH from 1,789' to 4,910' with no problems, dwn wt 70k. Washed last std down from 4,910' to 5,000' and had approx. 10' of fill on btm, pumped 30 bbl Hi-Vis sweep and circ 3X btms up and was clean at shakers, had no increase in cuttings back from sweep, circ at 184 spm, 549 gpm at 1,975 and 70 rpm's Monitored well for flow (well static), blew do top drive, dropped Sperry ESS tool. POOH 17 stnds, wet on elevators, from 4,910' to 3,297' up wt 145k, do wt 80k, and in the Ugnu up wt 110k, dwn wt 70k. hole taking calc fill. Cont POOH from 3,297' to BHA at 659' with no problems, SLM no corr. Stood back HWDP and jars, LD 2-NMFDC's, held safety mtg and removed radioactive sources LD 1-NMFDC and downloaded MWD Fin LD BHA #3, LD MWD/LWD and motor, cleared rig floor, calc fill on trip out 52 bbls, actual fill 58 bbls Printed: 3/8/2006 11:08:21 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 Q-101 Common Well Name: 1Q-101 Event Name: ROT -DRILLING Contractor Name: n1433@conocophillips.com Rig Name: Nordic 3 Date From - To ' Hours Code Code Phase 11!24/2005 ~ 08:30 - 08:45 0.25 i LOG ~ SFTY ~ PROD 08:45 - 10:00 1.25 10:00 - 11:00 ~ 1.00 11:00 - 14:45 3.75 14:45 - 16:00 I 1.25 16:00 - 18:00 ~ 2.00 18:00 - 18:15 0.25 18:15-21:00 2.75 21:00 - 23:45 2.75 23:45 - 00:00 ~ 0.25 11/25/2005 100:00 - 05:00 I 5.00 05:00 - 06:30 06:30 - 08:00 LOG jRURD PROD LOG PULD PROD LOG ELOG PROD LOG ; PULD ;PROD LOG ' OTHR ~PROD LOG SFTY PROD LOG DEOT PROD LOG IDLOG IPROD LOG i CIRC i PROD LOG I DLOG I PROD 1.50 ~ LOG RURD PROD 1.50' LOG OTHR PROD 08:00 - 16:30 8.501 LOG DLOG PROD 16:30 - 18:15 ; 1.75 I LOG I DLOG PROD 18:15 - 00:00 ( 5.75 ~ LOG ~ DLOG PROD 11/26/2005 100:00 - 07:45 I 7.751 LOG I DLOG I PROD 07:45 - 08:00 ' 0.25 I DRILL I OTHR I PROD 08:00 - 10:00 i 2.00 LOG DLOG PROD 10:00 - 11:30 1.50 LOG OTHR PROD 11:30 - 15:30 4.00, LOG DLOG ~ PROD I 15:30 - 15:45 ~' 0.25 ~ LOG SFTY PROD 15:45 - 18:30 ~ 2.75 LOG PULD PROD 18:30 - 19:30 1.00 LOG PULD i PROD 19:30 - 20:15 I 0.75' LOG ' TRIP ' PROD 20:15 - 21:00 ~ 0.75 LOG CIRC PROD I 21:00 - 21:45 0.75 LOG TRIP ~ PROD 21:45 - 22:30 0.75 LOG CIRC i PROD Start: 11 /13/2005 Rig Release: 11/29/2005 Rig Number: 3 Page 6 of 8 Spud Date: 11/15/2005 End: 11/29/2005 Group: Description of Operations Held PJSM with Schlumberger (SWS) on RU and upcoming wireline operations. RU SWS wireline (.46") and scheaves MU SWS FMI/ DSI/ Gr tool and RIH to 90' RIH with logging tools and tagged btm at 5,000' wireline measurements, logged up to 10 3/4" csg shoe at 1,823' with no problems, cont to POOH to 90' POOH & LD FMI/ DSI/ Gr tools Re-headed line for MDT tools and laid out toots Held PJSM on MU MDT tools and discussed RIH and Logging with DP MU MDT tool RIH to 136' and test same in rotary table, MU X/O from MDT to 5" DP. RIH with MDT tool on 5" DP to shoe at 1,823', RIH with a Running speed of 23 fpm. RU and est circ at 42 spm, 3 bpm and 60 psi, circ to clean out docking head. Up wt 57k, do wt 50k. Cont RIH with MDT logging tools on 5" Dp from 1,824' to 3,506', broke circ every 5 stds while RIH, RIH at 23'/min, no problems RIH. Held PJSM and RU SWS scheave and side door entry sub RIH with a-line and docking tool, circ down at 1 bpm and didn't latch on 1st attempt, increased rate to 283 gpm at 250 psi and latched into docking tool, tested hook up and ck ok, installed cable clamp RIH from 3,506' to 4,860' taking formation pressure readings while RIH, took 20 pressure readings from 3,716' MD/ 2,812' TVD to 4,860' MD/ 3,543' TVD. Up wt 110k, do wt 70k. POOH from 4,866' to 4,188'. Attempting to take formation samples with MDT tool at 4,188', 4,194' and back up at 4,178' with no success. Up wt 110k, do wt 70k. Cont to attempt to recover fluid sample with MDT logging tool at 4,178' with no oil recovered, RIH to 4,286' and made 1 failed attempt, RIH to 4,293' and had 1 sample recovery in the "B" sand, cont to RIH to 4,558' and 4,860' making 1 attempt at each pt with no oil recovery, was able to recover mud filtrate then the pressure would decrease and would have no flow to tool. Decision was made to abort MDT tool and POOH to run sidewall cores Switched rig and camp from highline power to rig generators in preperation for upcoming rig move. POOH with MDT logging tools on DP from 4,860' to 3,506', to side door entry sub Unlatched from logging tools and POOH with a-line, LD side door entry sub and RD scheave. Cont to POOH with MDT logging tools on DP from 3,506' to logging tools at 136', POOH at 30-35'/min with no problems in open hole. Held PJSM with SWS and rig crews on LD logging string POOH LD MDT logging tools, tools sent to SWS shop to check sample recovery MU 8 1/2" clean out BHA #4 &RIH with RR bit #2, bit sub, HWDP and jars to 456' RIH with 5" DP to 1,823' CBU at 112 spm, 305 psi, Up wt 65k, do wt 63k rot wt 62k, blow do top drive Cont RIH on 5" DP to 3,570', Kelly up CBU at 180 spm, 1,000 psi, Up wt 90k, do wt 70k, rot wt 70k, blow do Printed: 3/8/2006 11:08:21 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1Q-101 1 Q-101 ROT -DRILLING Start: 11/13/2005 n1433@conocophillips.com Rig Release: 11/29/2005 Nordic 3 Rig Number: 3 Page' 7 of 8 Spud Date: 11/15/2005 End: 11 /29/2005 Group: Date From - To Hours Gode Code , Phase ~ Description of Operations 11 /26/2005 '~ 21:45 - 22:30 22:30 - 23:15 23:15 - 00:00 11 /27/2005 00:00 - 00:15 100:15 - 02:30 ~ 02:30 - 05:45 05:45 - 06:00 06:00 - 06:30 06:30 - 09:00 09:00 - 10:00 _~__ _~ __ 0.75 LOG ~ CIRC PROD 0.75 LOG TRIP I PROD 0.75 ~ LOG CIRC ~ PROD , 0.25' LOG CIRC i PROD 2.251 LOG i CIRC ~ PROD 3.25 LOG TRIP PROD 0.251 LOG SFTY PROD 0.50 LOG ~ PULD PROD 2.50 LOG i ELOG PROD 1.00 LOG PULD PROD 10:00 - 11:00 1.00 CEMEN1 RURD SUSPEN 11:00 - 12:00 1.00 CEMEN PULD SUSPEN 12:00 - 13:00 1.00 I ~ CEMEN RURD SUSPEN 13:00 - 15:00 2.00 CEMENTi TRIP SUSPEN 15:00 - 15:30 0.50 CEMEN~ RURD SUSPEN 15:30 - 16:45 1.25 CEMEN CIRC SUSPEN 16:45 - 17:30 0.75 CEMENl~ PUMP !SUSPEN 17:30 - 18:00 0.501 CEMENl~TRIP `SUSPEN 18:00 - 19:00 ! 1.00 !CEMEN CIRC i SUSPEN 19:00 - 19:45 I 0.751 CEMENlf PUMP ;SUSPEN 19:45 - 20:15 I 0.501 CEMENTTRIP i SUSPEN top drive Cont RIH on 5" DP to 4,897', Kelly up Break circ and stage pumps to 184 spm, 1,300 psi, wash do from 4,897' to 4,985', bit took 3-5k at 4,985', cont wash do to 4,994', Up wt 145k, do wt 80k, rot wt 90k, 70 rpm with 6,400 ft-Ibs torque on btm Fin washing to btm from 4,994' to 5,000' Pumped hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ hole at 560 gpm, 1,300 psi, 70 rpm's with 6,400 ft-Ibs torque, rot wt 90K, up wt 145K, do wt 80K, circ 3X btms up with 9.5 ppg Flo-Pro mud in and out POOH and stood back HWDP and jars, talc fill on trip out 48 bbls, actual fill 53 bbls. No problems POOH, cleared rig floor Held PJSM with Schlumberger (SWS) on RU of wireline, scheaves and PU sidewall cores MU SWS sidewall coring tool and RIH to 23', (45 shots) RIH with sidewall coring logging tools to 4,630', POOH taking 43 cores in the West Sak up to 4,145', POOH to Ugnu and took 2 cores at 3,911' and 3,515', cont to POOH to logging tools at 23', no problems taking cores. POOH LD sidewall coring tools and RD wireline, recovered 43 of 45 ` cores taken, left 2 bullets in the hole, cores were approx 1 112" - 2" long and intact RD 5" handling tools & RU 3 1/2" handling tools PU &RIH with 33 jts of 3 1/2", 9.3#, L-80 EUE-Mod tbg for cement stinger to 1,035' RD 3 1/2" handling tools and RU 5" tools RIH with 3 1/2" cement stinger on 5" DP from 1,035' to btm at 5,000' MU pump in sub and cement line Circ hole clean for cement job evening MW in and out at 9.5 ppg, circ hole at 183 spm, 545 gpm at 1,300 psi, st wt up 95K, do wt 70K, circ 2X btms up, held PJSM with rig crew, Dowell and ASRC vac truc drivers Turned over to Dowell and pumped 5 bbls water, pressure tested lines to 3,500 psi, cont to pump 5 add. bbls of water, mixed and pumped 43.2 bbls (209 sxs) of 15.8 ppg, 1.16 yield cement with additives, ave 4 bpm, initial pressure 250 psi, final 130 psi, followed with 1.3 bbls of water, turned over to rig and pumped 73 bbls of 9.5 ppg mud to balance plug, ave 6 bpm at 130 psi, slowed to 3 bpm at 300 psi, CIP at 17:25 hrs, est TOC at 4,500', had foil retums during job and reaprocated pipe throughout job POOH slow 5 stds from 5,000' to 4,499' Circ btms up at 4,499', saw slight sign of cement contaminated mud at btms up, circ an add. btms up with 9.5 ppg MW in and out, circ at 185 spm, 550 gpm at 1,350 psi, st wt up 90K, do wt 65K, circ 2X btms up Dowell pumped 10 bbls of water, then mixed and pumped 42.8 bbls (207 sxs) of 15.8, 1.16 yield cement with add., ave 3.8 bpm, initial pressure 210 psi, final pressure 185 psi, followed with 1.5 bbls water, turned over to rig and rig displaced cement with 64 bbls of 9.5 ppg mud to balance plug, ave 6 bpm at 170 psi, slowed to 3 bpm at 400 psi, CIP at 19:35 hrs, est TOC at 4,000', had full returns throughout job and reciprocated pipe throughout job, NOTE: Cement volume was cslatisted from 4 ~cm ave g" he 1f#~t+ excess and Chuck Sche~e with AOGC~ vvaivesd ~ of cement plugs POOH slow 7 stds from 4,499' to 3,832' Printed: 3/8/2006 11:08:21 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1Q-101 Common Well Name: 1 Q-101 Event Name: ROT -DRILLING Start: 11/13/2005. Contractor Name: n1433@conocophillips.com Rig Release: 11/29/2005 Rig Name: Nordic 3 Rig Number: 3 Date 'From - To Hours Code 11/27/2005 120:15 - 21:00 ~ 0.751 CEME 21:00 - 00:00 3.00 DRILL 11128!2005 00:00 - 02:00 2.00 DRILL 02:00 - 02:30 0.50 DRILL 02:30 - 03:15 ~ 0.75 CEME 03:15 - 04:00 0.75 CEME 04:00 - 04:15 0.25 ~ CEME 1 04:15 - 06:00 1.75 i CEME 06:00 - 06:45 06:45 - 07:00 07:00 - 07:30 07:30 - 08:00 0.75 0.25 0.50 0.50 08:00 - 08:15 0.25 CEME 08:15 - 09:00 0.75. CEME 09:00 - 11:00 2.00 DRILL 11:00 - 12:30 I 1.50 DRILL 12:30 - 13:15 ' 75 0 ABANI 13:15 - 15:15 ~ . 2.00, ABANI 15:15 - 17:30 I 2.25 17:30 - 23:00 I 5.50 ' 23:00 - 00:00 1.00 11/29!2005 00:00 - 01:15 1.25 01:15 - 02:30 1.25 02:30 - 04:15 1.75 04:15 - 05:00 0.75 05:00 - 06:00 1.00 Sub I, Phase Code' _ CIRC SUSPEN PULD !SUSPEN PULD SUSPEN RIRD SUSPEN TRIP SUSPEN RURD SUSPEN SFTY SUSPEN TRIP ;SUSPEN OTHR SUSPEN OTHR SUSPEN CIRC I SUSPEN PUMP I SUSPEN TRIP SUSPEN CIRC SUSPEN PULD SUSPEN PULD SUSPEN RURD SUSPEN TRIP SUSPEN TRIP iSUSPEN WELCT NUND SUSPEN WELCT NUND SUSPEN WELCT I NUND SUSPEN CMPLTNI FRZP ~ SUSPEN ABANDI~ OTHR SUSPEN CMPLTNFRZP SUSPEN EORP !SUSPEN Page 3 of 8 Spud Date: 11!15/2005 End: 11/29/2005 Group: Description of Operations Dropped DP wiper dart and circ hole 1 1/2 bolt up, with no contaminated mud at 185 spm, 660 psi, 20 rpms on up-stroke, Up wt 80k, do wt 62k, blew do top drive and checked for flow (well static) POOH from 3,833' LD 5" DP, LD 56 jts POOH to 2,071' Cont to POOH LD 5" DP from 2,071' to 3 112" cement stinger at 1,035' RD 5" Handling tools and RU 3 1/2" tools POOH from 1,035' and stood back 11 stds of 3 1/2" cement stinger RD 3 1/2" handling tools and RU 5" tools Held PJSM with crew and HES tool supervisor on MU of retainer MU Halliburton 10 3/4" csg EZSV cement retainer and RIH to 1,723' on 5" DP Set EZSV rets~ir-ax' at 1,723' w~h bttn of alt 1,726' and set 25K wt down on retainer, at r~ up 55lC, do wt 4&K, PU out of Pressure tested retainerand ~ to 1,500 psi for 15 min, good test, held PJSAA ~ cementing below retainer Stung back into retainer and est an injection rate at 1 bpm at 280 psi and 2 bpm at 380 psi, bled off pressure and PU out of retainer Dowell pumped 5 bbls water and pressure tested lines to 3,500 psi, mixed and pumped 25 bbls (150 sxs) of AS1 cement at 15.8 ppg, .93 yield and additives, followed with 1.5 bbls water, ave 3.5 bpm,. held 200 psi back pressure on choke while spotting cement in DP, spotted to within 5 bbls of retainer, stung into retainer and rig fin displacing cement, rig pumped 25 bbls of 9.5 ppg mud placing 20 bbls of cement below retainer, shut down and PU laying 5 bbls (50') of cement on top of retainer, Est TOC at 1,673', CIP at 07:50 hrs. POOH from 1,723' LD 3 singles of 5" DP to 1,625' Circ 1 1/2 X btms up to clear DP at 1,625', at btms up had slight amount of cement contaminated mud then cleaned up, circ 9.5 ppg mud in & out, circ at 417 gpm at 200 psi, blew down top drive POOH from 1,625' LD 52 jts of 5" DP and HES running tool RIH with 5 stds of HWDP and jars, POOH LD same RD 5" handling tools and RU 3 1/2" tools PU &RIH with 11 stds of 3 112", 9.3 ppf, L-80 EUE-Srd -Mod tbg from derrick, then PU 16 jts from pipe shed and RIH to 1,536' Drained stack, MU Vetco Gray 4 1/2" x 3 1/2" tbg hanger and landed circ string at 1,569', RILDS, st wt up 30K, do wt 28K Pull riser and ND 11" BOP, rack and secure for rig move NU Vetco Gray MB 228 11" 5M tree with multi-bowl removed Fin NU Vetco Gray MB 228 11" 5M tree W/O multi bowl and tested same to 5,000 psi for 15 min, good test, pulled TWC RU Little Red and freeze protected well with 145 bbls diesel, circ at 5 bpm at 300 psi, with 145 bbls diesel (talc volume), still had Flo-Pro mud back, ordered out add. diesel, final pressure at 5 bpm 150 psi. Fin cleaning mud pits and shakers while waiting on diesel Fin freeze protect(ng weN ,after pumping 25 add. bbls had gocxl di~eserl' it ~ >aurface RU lubricator and installed BPV, RD lubricator and secured well, RELEASED RIG @ 06:00 Hrs 11/29/05 Printed: 3/8/2006 11:08:21 AM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 Q 1 Q-10.1 Job No. AK-MW-0004046668, Surveyed: 23 November, 2005 Survey Report 14 December, 2005 Your Ref: AP1500292328200 ~ Surface Coordinates: 5984298.70 N, 528464.21E (70° 22' 05.4759" N, 149° 46' 07.3324'' VV) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative fo Project H Reference: 984298.70 N, 28464.21E (Grid) Surface Coordinates relative to Structure: 379.21 S, 73.55E (True) Kelly Bushing Elevation: 81.80ft above Mean Sea Level Kelly Bushing. Elevation: 81.80ft above Project V Reference Kelly Bushing Elevation: 81.80ft above Structure 5plei'"~f'~-~t~~1 ©RILLING $ERV[GE'S A Halliburton Company ~` DEFIi~@aT1~fE • • Survey Ref: svy2236 Halliburton Sperry-Sun Survey Report for Kuparuk 1Q - 1Q-101 Your Ref: APf 500292328200 Job No, AK-MW-0004046668, Surveyed: 23 November, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000. 0.000 -81.80 0.00 0.00 N 0.00E 5984298.70 N 528464.21E 0.00 CB-SS-Gyro 100.00 0.340 346.260 18.20 100.00 0.29 N 0.07 W 5984298.99 N 528464.14E 0.340. 0.20 172.80 0.760 319.950 91.00 172.80 0.87 N 0.43 W 5984299.57 N 528463.77E 0.659 0.47 264.00 0.770 334.610 182.19 263.99 1.88 N 1.08 W 5984300.58 N 528463.12E 0.214 0.9,3 354.00 4.520 14.440 272.08 353.88 5.87 N 0.46 W 5984304.56 N 528463.73E 4.399 4.56 445.00 8.250 20.850 362.50 444.30 15.44 N 2.76E 5984314.15 N 528466.91E 4.167 14.26 535.00 7.510 21.070 451.65 533.45 26.97 N 7.17E 5984325.69 N 528471.28E 0.823 26.25 630.00 7.130 25.900 545.88 627.68 38.06 N 11.98E 5984336.81 N 528476.05E 0.761 38.11 719.00 8.120 38.050 634.09 715.89 47.98 N 18.27E 5984346.75 N 528482.29E 2.120 49.84 MWD Magnetic 752.71 8.960 38.450 667.43 749.23 51.91 N 21.37E 5984350.69 N 528485.38E 2.498 54.84 846.82 9.050 38.150 760.38 842.18 63.47 N 30.50E 5984362.29 N 528494.46E 0.108 69.54 941.42 9.360 39.400 853.76 935.56 75.27 N 39.98E 5984374.12 N 528503.90E 0.390 84.63 986.96 9.580 39.280 898.68 980.48 81.06 N 44.72E 5984379.93 N 528508.63E 0.485 92.10 1032:89 10.250. 41.040 943.93 1025.73 87.10 N 49.83E 5984385.99 N 528513.71E 1.601 99.97 1082.27 12.080 42.200 992.37 1074.17 94.25 N 56.18E 5984393.16 N 528520.03E 3.734 109.46 1126.27 12.780 43.330 1035.34 1117.14 101.20 N 62.62E 5984400.13 N 528526.44E 1.684 118.84 1169.45 12.540 43.620 1077.47 1159.27 108.06 N 69.13E 5984407.03 N 528532.93E 0.575 128.19 1220.94 12.450 44.410 1127.74 1209.54 116.08 N 76.87E 5984415.07 N 528540.64E 0.375 139.19 1264.60 13.830 .44.130 1170.25 4252.05 123.18 N 83.79E 5984422.20 N 528547.54E 3.164 148.98 1310.45 15.810 43.930 1214.58 1296.38 131.62 N 91.94E 5984430.66 N 528555.65E 4.320 160.55 1354.68 21.340 40.610 1256.49 1338.29 142.07 N 101.37E 5984441.16 N 528565.04E 12.725 174.51 1403.21 24.050 38.390 1301.26 1383.06 156.53 N 113.26E 5984455.66 N 528576..88E 5.856 193.17 1434.79 24.250 37.160 1330.07 1411.87 166.74 N 121.17E 5984465.90 N 528584.75E 1.715 206.07 1465.79 24.200 37.580 1358.34 1440.14 176.85 N 128.90E 5984476.04 N 528592.43E 0.579 218.78 1496.49 24.830 37.130 1386.27 1468.07 186.98 N 136.62E 5984486.20 N 528600.12E 2.140 231.50 1526.50 25.570 37.680 1413.43 1495.23 197.13 N 144.39E 5984496.37 N 528607.85E 2.586 244.27 1558.45 2$.060 36.070 1441.94 1523.74 208.66 N 153.03E 5984507.94 N 528616.44E 8.118 258.67 1590.48 30.600 36.190 1469.86 1551.66 221.33 N 162.28E 5984520.65 N 528625.64E 7.932 274.35 1623.05 32.550 36.120 1497.61 1579.41 235.10 N 172.34E 5984534.45 N 528635.65E 5.988 291.40 1686.30 31.860 37:680 1551.13 1632.93 262.06 N 192.57E 5984561.49 N 528655.78E 1.708 325.08 1717.36 32.740 37.440 1577.38 1659.18 275,21 N 202.69E 5984574.68 N 528665.85E 2.863 341.66 1761.30 35.260 37.490 1613.81 1695.61 294.71 N 217.63E 5984594.24 N 528680.72E 5.735 366.20 1860.00 37.930 38.310 1693.04 1774.84 341.13 N 253.79E 5984640.79 N 528716.70E 2.750 424.94 1902.38 .37.580 38.000 1726.55 1808.35 361.54 N 269.82E 5984661.26 N 528732.65E 0.939 450.84 1998.37 41.520 35.650 1800.56 1882.36 410.48 N 306.40E 5984710.34 N 528769.04E 4.390 511.91 14 December, 2005 - 11:10 Page 2 of 4 DrillQuest 3.03.06.008 v Hailburton Sperry-Sun Survey Report for Kuparuk 1 Q -1 Q-101 Your Ref: AP1500292328200 Job No. AK-MW-0004046668, Surveyed: 23 November, 2005 Western North, Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 2091.58 45.030 34.210 1868.41 1950.21 462.87 N 342.95E 5984762.87 N 528805.40 E 2186.70 47.780 33.000 1934.00 2015.80 520.24 N 381.06E 5984820.39 N 528843.29 E 2282.18 49.130 33.000 1997.32 2079.12 580.17 N 419.98E 5984880.47 N 528881.98 E 2377.26 51.300 .31.760 2058.16 2139.96 641.88 N 459.09E 5984942.32 N 528920.86 E ~ 2471.77 58.040 29.280 2112.79 2194.59 708.29 N 498.16.E 5985008.88 N 528959.68 E 2565.44 58.250 29.790 2162.22 2244.02 777.51 N 537.38E 5985078.25 N 528998.63 E 2660.31 56.920 29.060 2213.08 2294.88 847.26 N 576.73E 5985148.15 N 529037.72 E 2753:94 55.340 28.160 2265.26 2347.06 915.51 N 613.96E 5985216.53 N 529074.69 E 2847.82 54.500 32.780. 2319.23 2401.03 981.70 N 652.89E 5985282.88 N 529113.36 E 2942.04 . 53.530 34.210 2374.59 2456.39 1045.28 N 694.95E 5985346.61 N 529155.19 E 3037.59 53.620 35.520 2431.33 2513.13 1108.36 N 738.90E 5985409.86 N 529198.89 E 3133.60 56.060 37.190 2486.62 2568.42 1171.56 N 785.44E 5985473.23 N 529245.19 E 3223.84 54.530 36.980 2537.99 2619.79 1230.73 N 830.17E 5985532.58 N 529289.70 E 3321.31 56.660 38.240 2593.07 2674.87 1294.43 N 879.26E 5985596.46 N 529338.54 E 3418.67 56.440 37.500 2646.73 2728.53 1358.55 N 929.12E 5985660.78 N 529388.16 E 3508.99 55.140 37.170 2697.51 2779.31 1417.94 N 974.42E 5985720.33 N 529433.23 E 3608.82 57.180 39.660 2753.11 2834.91 1482.88 N 1025.95E 5985785.47 N 529484.52 E 3699.46 56.510 39.820 2802.68 2884.48 1.541.23 N 1074.46E 5985844.01 N 529532.81 E 3798.67 55.290 39.480 2858.30 2940.10 1604.49 N 1126.89E 5985907.46 N 529584.99 E 3893.96 53.730 38.300 2913.62 2995.42 1664.87 N 1175.60E 5985968.02 N 529633.47 E 3989.18 52.180 35.870 2970.99 3052.79 1725.48 N 1221.43E 5986028.81 N 529679.07 E 4086.58 50.380 34.290 3031.91 .3113.71 1787.65 N 1265.11E 5986091.15 N 529722.52 E 4179.77 49.630 34.330 3091.81 3173.61 1846.62 N 1305.36E 5986150.27 N 529762.54 E 4274.60 48.900 34.200 3153.69 3235.49 1906.01 N 1345.81E 5986209.81 N 529802.77 E 4370.29 49.810 33.230 3216.02 3297.82 1966.40 N 1386.11E 5986270.36 N 529842.83 E 4464.40 48.470 32.560 3277.59 3359.39 2026.16 N 1424.77E 5986330.26 N 529881.26 E 4557.06 49.300 33.240 3338.52 3420.32 2084.77 N 1462.69E 5986389.02 N 529918.96 E 4652.99 48.120 33.080 3401.82 .3483.62 2145.11 N 1502.11E 5986449.51 N 529958.16 E 4746.35 46.$00 32.480 3464.94 3546.74 2202.94 N 1539.36E 5986507.48 N 529995.18 E 4838.52 45.920 31.910 3528.55 3610.35 2259.38 N 1574.90E 5986564.06 N 530030.51 E 4932.88 45.120 30,960 3594.66 3676.46 2316.83 N 1610.01E 5986621.63 N 530065.40 E 5000.00 45.120 30.960 3642.02 ` 3723.82 2357.61 N 1634.48E 5986662.51 N 530089.71 E All data is in Feet (US Su rvey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical dept hs are relativ e to Well. N orthings and Eastings are re lative to Well. Global North ings and Eastings are rel ative to NAD27 Alaska State Planes, Zone 4. ConocoPhillips Dogleg Vertical Rate. Section Comment (°/100ft) 3.912 575.79 3.034 644.65 1.414 716.08 2.493 789.08 7.445 865.91 0.514 1.545 1.867 4.125 1.602 1.107 2.912 1.706 2.432 0.673 1.471 2.910 0.754 1.262 1.923 2.607 2.240 0.805 0.777 1.223 1.522 1.053 1.236 1.491 1.054 1.11.1 0.000 945.15 1024.89 1102.18 1178.76 1254.98 1331.86 1410.31 1484.43 1564.74 1645.85 1720.47 1803.20 1878.79 1960.64 2038.02 2113.94 2189.92 2261.31 2333.17 2405.76 2476.90 2546.67 2618.72 2687.47 2754.10 2821:31 2868.77 Projected Survey • • 14 December, 2005 - 11:10 Page 3 of 4 DriflQuest 3.03.06.008 x - Hal/iburton Sperry-Sun Survey Reporf for Kuparuk 1Q - 1 Q-101 Your Ref: AP1500292328200 Job No. AK-MW-0004046668, Surveyed:. 23 November, 2005 Western North Slope The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 34.733° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5000.OOft., The Bottom Hole Displacement is 2868.77ft., in the Direction of 34.733° (True). _, Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 5000.00 3723.82 2357.61 N 1634.48E Projected Survey Su-vey tool program for 1 Q-101 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) 1ft) 0.00 0.00 719.00 715.89 CB-SS-Gyro 719.00. 715.89 5000.00 3723.82 MWD Magnetic GonocoPhillips • • 14 December, 2005 - 11:10 Page 4 of 4 DrillQuest 3.03.06.008 • 0.00' MD 13-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 Q-101 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey Projected Survey • ~ 05 -- 15~ 0.00 ° MD (if applicable) 5,000.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALL{BURTON.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) 12/20/05 Schiumher~ger~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~C 2 1 20r,c G~i u. Gas Cans. Cvt;;+~.. _.....,. Af'C~laf'S~ NO. 3615 Company: Alaska Oil 8~ Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 1Y-19 11144040 PIEZO SONA TOOL 11/19/05 1 1Y-27 11072935 PRODUCTION PROFILE W/DEFT 11/22/05 1 2D-09 11072933 SBHP SURVEY 11/18/05 1 1R-15 11072932 SBHP SURVEY 11/18/05 1 3F-05 N/A PRODUCTION LOG 11/13/05 1 1L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE W/DEFT 09/10/05 1 1Q-16 11141232 PRODUCTION PROFILE W/DEFT 12/01/05 1 1E-33 N/A GLS & BHP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12/03/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1C-07 11141231 PRODUCTION PROFILE W/DEFT 11/30/05 1 1Q-09 11141233 INJECTION PROFILE 12/02/05 1 36-16 N/A INJECTION PROFILE 12/08/05 1 1Q-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1 1Q-101 - ~$ 11144044 MDT 11/24/05 1 SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • 1 Q-101 Well Status Report- 11 /3 0/OS .- ~,~ ~~ l 5 Spud 1Q-101 at 1400 hrs 11/15/O5. Directionally drilled 13-1/2" hole to 1830' MD/1751' TVD. Ran & cemented 10-3/4" 45.5 ppf L-80 BTC casing to 1823' MD/1746' TVD with 372 bbls (469 sx) of ARCTICSET Lite lead slurry plus 45 bbls (280 sx) ARCTICSET 1 of tail slurry. Full returns during the job, reciprocated pipe, and had 150 bbls of 10.7 ppg slurry back to surface. ND diverter NU 11" 5000 psi BOPE stack. Tested to 250 psi low and 3000 psi high, changed out blind rams- test witnessed by John Spaulding. PU 8-1/2" BHA, RIH to 1710' MD, tested casing to 3000 psi-OK. Drilled out shoe track, drilled 20' of new hole to 1850' MD, circulated and conditioned mud, performed LOT to 12.4 ppg EMW. Changed over to 9.2 ppg Flo-Pro mud system and currently drilling ahead at approx. 2900' MD. Directionally drilled 8-1/2" hole to 5000' MD, made short trip to shoe, made trip back to bottom, C&C'd, POOH for logs. RU SWS. Ran Dipole Sonic/FMI. RU TLC MDT. Ran to bottom taking 20 pressure readings in the Ugnu/West Sak. Made 8 attempts at fluid recovery in the West Sak with one successful recovery in the "B" sands. POOH and RD SWS. Made a conditioning trip to TD, POOH. RU SWS to obtain sidewall cores. Recovered 43 of 45 cores. RD SWS. RIH with 3-1/2" cement stinger. Set bottom plug on bottom (209 sx or 43.2 bbls of slurry) with est TOC @ 4500' MD. Circulated bottoms up with slight sign of cement contamination. Set 2"a 500' plug (207 sx or 42.8 bbls) with est TOC @ 4000' MD. No signs of cement contamination on bottoms-up. POOH LD DP. MU EZSV, RIH and set at 1726' MD. Set 25K down on retainer and pressure tested to 1500 psi- OK. Pumped 150 sx slurry, placing 20 bbls below retainer and dumping 5 bbls on top. POOH to 1625', circulated bottoms-up with slight amount of contamination. RIH with 3-1/2" circulating string and land with tail at 1569' +/-. RD BOPE stack and RU dry hole tree and pressure tested to 5000 psi. Freeze protected tubing and annulus with 170 bbls of diesel. Set BPV, secured well and released rig at 0600 hrs 11/29/05. Nordic 3 has moved to the next well 3J-101 and expected to spud 12/1/05. • ConocoPhillips Alaska, Inc. TO: AOGCC 333 W 7T" AVE Anchorage, AK 99501 OPERATOR: CPAI SAMPLE TYPE: DRIES SAMPLES SENT: TRANSMITTAL Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage, AK 99510 phone 907.263.4859 DATE: 11-28-05 AIRBILL: 5325455 CPBV 05-11-28-01 CHARGE CODE#: 10096061 WELL: 1 Q-101 NUMBER OF BOXES: 1 Bundle (4 bxs) 1 Q-101 ~) Dries 120-5000 / 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 RECEIVED BY: ©'~^~'~"""~ DATE: ~~~'o'`~ .:Uto t' ~ U ~~ - f~S'i6 ~ ~ ' 1 r ~ '1 ~ ,~ ~ ; ~,e, ~ ~ 9 ~~ .~ '~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~ ~ °~~ ~~ ~ i' ~' ~~ ~~ ~~ ~~rr *~ ~ 1~T~ ^ ~ c ~i4t>•-7~ Oai.r ~ ~ ~~' 333 W. 7"' AVENUE, SUITE 100 COI~TSERQA'rIO1~T COl~'II~IISSIOIQ ~ 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 gip; -1~Co Re: KRU 1 Q-101 Sundry Number: 305-365 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 ~~ay of November, 2005 Encl. C NOV-22-2005 14 ~ 50 D~ i WELLS ConocoPhillips PpsL OlfiCe E3ox 700360 Anchorage, Atdska 99510-0360 November 23, 2005 Commissioner State of Alaska Alaska Oil and Gas Conservation Commissipn 333 Wass 7t" Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 • 987 265 1336 P.02 Re: Application for Sundry approval to Suspend Conoco Phillips 1 Q-101 Surface Location_ 1574' FNL, 1961' FEL, Sea. 26, T12N, R9E, UM or ASP4, NAIL 27 caardinates of X=52$,464 & Y=5,984,299 Targe# Locations 270' FSL, 129' FWL, Sec. 24, T72N, R9E, UM BHL: 787' FSL, 489' FWL, SeC. 24, T72N, R9E, URA CgNFIDENTIAL Dear Commissioner: ConocaPhillips Alaska, Inc. would like to suspend the 1 Q-109 West Sak wellbore, located in the Kuparuk River Field/West Sak Oil Pool. Nardic 3 spud this well on 11/'[5/05 and TD'd the well on 11/23/05. 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 2ti5-6377 or Randy Thomas at 265-6380 Sincerely, ~~~ om Brasfield Staff Drilling Engi er NOV-22-2005 14~5~ D i WELLS ~ ~ 907 265'1~~6 P:t~4' ~~ ~~ ZS ,~/ ~ l H l t ur HLHtiftH ~ AL.A OIh AND GAS CONSERVATION COMMI N ~~~1 .. ~ . APPLICATION ~'OR SUNpRY APPROVALS ~"~ 1U AAG Z~.1tiU 1. Type of Request: Abandon After casing ^ Change approved program ^ Suspend ~ Operational shutdown Pertorate Waiver a =" her Repair well ^ P1ug Perfor8tiens ^ Stimulate ^ Time Extension ^ Pulf Tubing ^ Perforate New PSI © RE-enter Suspended Well ^ 2.Operator Namg: ConoCOPhillips Alaska, Inc. 4. CurrEnt Well ClaSS: Development ^ Exploratory ^~ S. Permit t0 Dti11 Number: 205-156 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 Stratigraphic ^ Service ^ t3. APl Number: 50-029-23282-00 7. KB E18vation (ft): 30' RKB + 52' to top of pad i3. WeII Name and Number: 1 Q-101 8. Property Designation: ADL 25841 ~ 25634 10. FiEId/POOIS(S): t{up2ruk River FieldlWest Sak Oil Pool- Exploration 11. PRESENT WELL C ONDITION SUMMARY To#al Depth MD (tt): Total Depth TVD (R): Effective Depth MD (ft): Effective DBpttt TVp (ft). Plugs (measured): Junk (measured): Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 145' MO 145' TVD 3060+ 1500+ Surtace 1793' 10-3/4" 1823' MD 1746"'fVD 3580 2090 Intermedia#e Production Liner Perforation Depth MD (R): None Perforation Depth TVD (ft): None i'ubing Size: 3-112" ~ Tubing Grade: L-$0 Tubing MD ($): 1583' Packers and SSSV Type: None Packers ana SSSV MD rftl: None De#ailed Operations Program ^ BOP Sketch ^ 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Date: Commission Representativ®: 17. 1 hereby certify that the foregoing is true and Correct to the b~ Printed Name Randy Th~nas Exploratory ^ Dev®lopment Q Service 15. Wel! Status after proposed work: ~ 7/25/2005 Oil ^ Gas ^ PluggEd Q Abandoned ^ WAG ^ GIN,! ~] WINJ ^ WDSPL ^ rriy knowledge. GontaCt Tom Title GKA Drilling Team Leader litions of approval: Notify Gommission So tha# a representativ® may witness Sundry Number: `~~~ " ~ 5 Integrity ~ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ r Loc~~v c.~c' S. r.S E C_~ '~ ~ v.~ ~~ ~~~-S C~rc~.~ ~Cc~ S~~`c+~. ` T_US~~ ~.co ~~vS ~ca.~vCU so~o~G~ ©d@C~.~~ctrO\ PCOO`~MS equent For ~r ~~~ ~~~~ ~,. ~.:k ~ ,~ '1005 APPROVED BY ~vetl b . COMMISSIONER THE COMMISSION Dat$: ` Farm 10-403 Revised 07/2005 O n ~ ~ ~ [~' ~ ~ Subrrait in DupfiCBte NOV-22-2aD5 14 50 D~ i WELLS . 987 265 1336 1 Q-101 Final Suspension Revised 11/23/05 by TJB Summary: 1Q-101 well was spudded 1400 hrs on 11/75/05 andTD'd on 11/23/05. 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 aH pressure testing and well suspension operations. Hold pre jab meeting with all personnel to discuss objectives, as well es safety and environmental issues. 2. Mobilize and rig up 17/S for well P&A operation. Spot a balanced cement plug from TD @ 5000' MD to 4000'MD (approx. 159' above top of the West Sak Q sand @ 4159' MD). This plug wil! be laid in two 50Q' intervals. Total cemented interval is approx. 1000' in length. Cement volumes will be based on $-1/2" hole diameter plus 25%. Total volume is approximately 493 cu ft or 421 sx of slurry. This will cover the West Sak interval from the base to the top of the "D" sand. No hydrocarbons were encountered in the Ugnu interval. It will riot be necessary to tag tap of the plug (unless the cement job does not go as planned) as we are setting the plugs cn bottom. 4. By the down Squeeze method through a retainer set 90' above fhe shoe (or approx. 1733' MD) pump cement plug #2 as per AQGCC 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 capon top of the retainer. Cement volume in open hole will be based an $-1/2" hole diameter plus 25%. Total volume is approximately 725 cu ft or 134 sx of slurry, Weight test retainer before pumping cement. Not required to tag the plug. Leave 9.2 ppg mud above and below khe plug.(Weight of mud needed to TD the hole) NOTE: Cont~~ct AO C inspector far option to witness setting the retainer. 5. POOH standing back 3-1/2" stringer (#a be used for circulating string) and laying dawn 5" DP. 6. RU and run/land a 3-1/2" circulating string to approx 100' above TOC (or approximately 15$3" MD) inside the 1p-3/4" surface casing. A VETCOgray 4-1/2" tubing hanger crossed-over to 3-112" EUE 8rd wil! be used to land the circulating sling. 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 to 3J-101. i'Je 19/23/Q5 File: 94-149 Gt""'- ~~ /Z 7 /~ om 13rsssfie < d Staff Drilling Engineer P.03 ' ~, ~~~~~ TJB X1/23/05 NOV-22-2005 14 ~ 50 Dom[' i WELLS 907 265 1336 P.05 ~- Tree: (2) Vetco 4-918 x 5ksi valves 9Q-9095urface Lacatiara: ~ Eastings: 528,A64 ~_ Tubing Hanger: Vetco, with 3- North;ngs: 5,sa4,2sP '/z", EUE $rd box down. Paa ~i~vatwn: 52' anrts~ _ INelihead: Vetco M822$ Nordic Rig 3 Flaor ~ 30' Lower Bowl Elevation: 82' AMSL Cortductgr: 20" Driven to 145' MD Fluid: Diesel in tubing and annulus 3=/R", 9.3#, L80 EUE 8rd /~ Mod Tubing ~ +/-1583' MD TD 93=/s' hole Shoe of 90'/4', 45.5#, L-80 BTC Casing ~ f 9823' MD, 9746' TW Cement retainer set at approx. 1733' MD with enough cement pumped to fill to 9923' MD and 50' dumped on top Fluid: Drilling mud Cement Plug(s) across hydrgCarbOn bearing zones from tD to 900' above West Sak. Est. TbC (~ 4000' MD TD 8-9l2" hole @ 5000' MD, 3,675' TVD COC1 P~ 1II1 1 Q-1 Q1 P$cA Sheen o/7 0Cfa 1 ~S Afaska Wel! Design modified by TJB iil23naos TOTAL P.05 RE: 1Q-101 West Sak Status • Subject: RE: 1 Q-101 West Sak Status ~ ~ ~ : ~ `~ ~.n From: "Brassfield, Tom J" ~ ATOM.J.Brassfield@conocophillips.com> Date:-Tue, 22 Nov 2005 1 ? :-1 ~ : U9 =.0900 To: Thomas 1~laundtr °~~torn maundcr(~l~idmin.statc.ak.us-- Tom, it was to leak-off. Thanks, Tom -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, November 22, 2005 12:41 PM To: Brassfield, Tom J Subject: Re: 1Q-101 West Sak Status Thanks Tom. Operations look routine. One question, was the shoe test taken to leak off or just to a predetermined EMW value?? Tom Brassfield, Tom J wrote, On 11/22/2005 12:39 PM: Tom, here is the current weekly status of 1 Q-101 as requested in the PTD. Thanks, Tom ', «1 Q 101 Wells Status Report to AOGCC 11 22 05.doc» 1 of 1 11/22/2005 12:52 PM 1 Q-101 Well Status Report- 11 /22/05 ~~5~-l~~ Spud 1Q-101 at 1400 hrs 11/15/O5. Directionally drilled 13-1/2" hole to 1830' MD/1751' TVD. Ran & cemented 10-3/4" 45.5 ppf L-80 BTC casing to 1823' MD/1746' TVD with 372 bbls (469 sx) of ARCTICSET Lite lead slurry plus 45 bbls (280 sx) ARCTICSET 1 of tail slurry. Full returns during the job, reciprocated pipe, and had 150 bbls of 10.7 ppg slurry back to surface. ND diverter NU 11" 5000 psi BOPE stack. Tested to 250 psi low and 3000 psi high, changed out blind rams- test witnessed by John Spaulding. PU 8-1/2" BHA, RIH to 1710' MD, tested casing to 3000 psi-OK. Drilled out shoe track, drilled 20' of new hole to 1850' MD, circulated and conditioned mud, performed LOT to 12.4 ppg EMW. Changed over to 9.2 ppg Flo-Pro mud system and currently drilling ahead at approx. 2900' MD. a~~, ~ -~ ~ ; 9 ~ FRANK H. MURKOWSKI, GOVERNOR .~~ a~~ ~a7~ OI~ ~`L li~-7 333 W. 7TM AVENUE, SUITE 100 CO1~T5ER~A'rI011T COMlf'IISSIOIQ ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 27&7542 Randy Thomas GKA Drilling Team Leader Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: KRU West Sak 1 Q-101 Conoco Phillips Alaska, Inc. Permit No: 205-156 Surface Location: 1574' FNL, 1160' FEL, Sec. 26, T12N, R9E Bottomhole Location: 78T FSL, 489' FWL, Sec. 24, T12N, R9E Dear Mr. Thomas: 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). ~nairman DATED this~day of October, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Cono oPhillips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com October 18, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Dri11, West Sak Exploration Well 1Q-101 Dear Commissioners: ~~ 4~s :t G'a3 C~,. ~TICh01'i€~~, ...,.~~t~rli ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill an onshore exploration well thru the West Sak sands. The this well will be designated 1Q-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 iQ-101 is November 10th, 2005. ~ If you have any questions or require any further information, please contact Tom Brassfield at 265-6377. Sincerely, _.~M .~, i._.-,. Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA SKA OIL AND GAS CONSERVATION JIMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~~~ 1a. Type of Work: Drill ~ Redrill Re-entry ~ 1b. Current Well Class: Exploratory ~ Develo I a Stratigraphic Test ~ Service ~ Development Gas [~± Eone 0 2. Operator~Name: ..~~ Con o Phln p Alaska~~nc. 5. Bond: Blanket ~ Single Well Bond No. 59-52-180 11. Well Name and Number: 1Q-101 3. Address: PO Box 100360, Anchorage, AK, 99510-0360 6. Proposed Depth: MD: 4,955 TvD: 3,675' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1574'FNL,1160' FEL,Sec 26,T12N,R9E ~ 7. Property Designation: ADL 25641 & 25634 ~ West Sak Oil Pool- Exploration Top of Productive Horizon: 270'FSL,129'FWL,Sec24,T12N,R9E ~ 8. Land Use Permit: LE 931814 & 931809 13. Approximate Spud Date: 10-Nov-05 Total Depth: 78TFSL,489'FWL,Sec 24, T12N,R9E ~ 9. Acres in Property: 2560 14. Distance to Nearest j Property: ~ ~~ f 4b. Location of Well (State Base Plane Coordinates): Surface:x- 528465 ~ y- 5,984,299 Zone- ~ ~} 10. KB Elevation (Height above GL): 30 feet 15. Distance to Nearest Well. z~ Within Pool: None ~n 16. Deviated wells: Kickoff depth: 350 feet , Maximum Hole Angle: 56 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1400 Surface: 1152 ~ 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 1859' 30' 30' 1889' i 1784' 480 sxASLite+ 55 sx DeepCRETE 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) 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 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: .Date 10/18/2005 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfie/d@265-6377 Printed Name ~~~Randy Thomas Title GKA Drilling Team Leader Signature '" ~`~---_ Phone 265-6830 Date 10(18!2005 Commission Use Only Permit to Drill API Number: Number: ~~~ ~~~ 50- ~~~'' Z3~~-C~, Permit Approval Date: . ~ See cover letter for other requirements. Conditions of approval : '3 k ~~ ~ov~~~ ~afc;.~:a v~ ~: '?~0~7C7Qs. '3C`~~ t~S~ C>-«~~tG.~p~E ~ ~ ~ 5 ~U S (~l~ Sample equired Yes ~ No ~ Mud log required Yes ~ No i~ q Hydr en ulfid`e-measures Yes No ~ Directionallsurvey required` Yes ~ No Other: ` CX~. ~ ~1~C'vC~~ < ~~r~.~~C,~~ p~v S ~'~ Ca~°~~C'~ 'ZCC~ ~~~ ~®~, APPROVED BY Approved by. THE COMMISSION Date: ~ ~ d Form -401 Re ' 06/2004 ~ ~ ~ ~ ~ ~ ~ ~ Submit inDuplicate • .Application for Permit to Drill, Well 1Q-101 Revision No.O Saved: 17-Oct-05 Permit It - .West Sak Well #1 Q-101 •~~~~ r.~ -~i Application for Permit to Dri// Document, II~IaW+~ll M a x i m i z e Well VpIU~ Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 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 bentonife) .......................................................................... 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 1Q-101 PERMIT IT 10 1705.doc Page 1 of 7 Printed: 17-Oct-05 OR161NAL • Application for Permit to Drill, Well 1 Q-101 Revision No.O Saved: 17-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 Doyon 14 West Sak 2004 3ksi BOP Configuration ......................................................... 7 Attachment 2 Directional Plan ............................................................................................................... 7 Aftachment 3 Drilling Hazards Summary .............................................................................................. 7 Attachment 4 Cement Data ................................................................................................................... 7 Attachment 5 Well Schematic ............................................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005 (fl Each we// must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a welt with mu/6ple well branches, each branch must simi/arty be idenlrfred by a unique name and API number by adding a suffix to the name designated for the wel/ by the operator and to the number assigned to the wel/ by the commission. The well for which this Application is submitted will be designated as 1Q-101. ~ 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Dri// must be accompanied by each of the following items, except for an item a/ready on fr/e with the commission and identified in the app/ication: (2) a p/at identifying the property and the property's owners and showing (A)che coordinates of the proposed /ocation of the well at the sulfate, at the top of each ob, jective formation, and at Iota/depth, referenced to governmenta/section lines (B) the coordinates of the proposed /ocativn of the we// at the surface, referenced to the state p/one coordinate system for this state as maintained by the Nationa/ Geodetic Survey in the Nationa/ Oceanic and Atmospheric Administration; (C) the proposed depth of the we// at the top of each objective formation and at total depth; Location at Surface 1574' FNL 1160' FEL, Section 26, T12N R9E ~ ASPZone 4 NAD 27Coord/nates RKB Elevation 80.3' AMSL Northings 5,984,299 Eastings: 528,465 Pad Elevation 50.3' AMSL Location at Top of Productive Interval West Sak 270' FSL, 129' FWL, Section 24, T12N, R9E ' ASP Zone 4 NAD 27Coordinates Measured De th, RKB: 4 133 Northings: 5,986,148 Eastings: 529,745 Total ~ertica/ De th RKB,• 3,146 Total 1/ertica! De th SS.• 3 066 Location at Total De th 787' FSL, 489' FWL, Section 24, T12N, R9E s ASPZone 4 NAD 27Coordinates Measured De th RKB: 4,955 Northings: 5,986,666 Eastings: 530,103 Total ~erticalDe th RKB,• 3 675 Total ~ertica/ De th, SS.• 3 594 and (D) other information required by 20 AAC1S.050(b); 1Q-101 PERMIT IT 101705.doc Page 2 of 7 O ('~ ~ n ~ ~ i /fj ` Printed: 17-Oct-05 Application for Permit to Drill, Well 1 Q-101 Revision No.O Saved: 17-Oct-05 Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviated, the application for a Permit to Ori// (form 10-401) must (1) include a p/at, drawn to a suitab/e scale, showing the path of the proposed we//bore, including a/!adjacent we//bores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for al/ we!/s within 200 feet of the proposed we//bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverab/e in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the app/ication; (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC25.035, 20 AAC25, 036, or 20 AAC 25.037, as applicable; An API li" x 5,000 psi BOP stack (RSRRA) will be utilized to drill well 1Q-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 o th'~e 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 application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1Q-101 area vary from 0.43 to 0.45 psi/ft, or 8.3 to 8.6 ppg EMW (equivalent mud weight). 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 3,388 feet giving a MPSP of 1,152 psi, calculated thusly: MPSP = (3,388 ft)*(0.45 - 0.11 psi/ft) = 1,152 psi (B) data on potenria/gas zones; The well bore is not expected to penetrate any gas zones. ~ and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circu/anon zones, and zones that have a propensity for differentia/sticking; Please see Attachment 2: 1Q-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 Ori/! must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application: (s) a description of the procedure for conducting formation integrity tests, as required under 20 AAC2s.030(f); 1Q-101 PERMIT IT 10 17 05.doc Page 3 of 7 Printed: 17-Oct-05 OR161NAL • Application for Permit to Drill, Well 1Q-101 Revision No.O Saved: 18-Oct-05 1Q-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 25.005(c)(6) An application for a Permit to Dri// must be accompanied by each of the tot/owing items, except for an item a/ready on fr/e with the commission and identified in the application; (6) a comp/ete proposed casing and cementing program as required by 20 A~4C 25.030, and a description of any slotted liner, pre- pen`oratedfiner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in in Ib/fE 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 1,859 30 / 30 1889 /1784 Cemented to Surface w/ 490 sxs ASLite Lead 60 sxs Dee CRETE Tail 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Dri!/ must be accompanied by each of the fo/(owing items, except for an item a/ready on file with the commission and identified in the app/ication; (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.D35(h)(2); See attached schematic. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An applcation for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item already on fife 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 AAC25.033; Drilling will be done with muds having the following properties over the fisted intervals: Surface Hole Mud Program (LSND) Surface to 10 -3/4"Casio Point Mud Properties Density (ppg) 9.2 - 9.5 ~ Funnel Viscosity (seconds) 150-250 Yield Point (cP) 30 - 45 API Filtrate (cc / 30 min)) 4 - 6 Chlorides (mg/l) <600 pH 9.0 - 9.5 1Q-101 PERMIT lT 10 17 05.doc Page 4 of 7 o ~ ~ ~ ~ N A ~.. Printed: 18-Oct-05 Production Hole Mud Program (FLOPRO NT Drill-in Fluid) Application for Permit to Drill, well 1 Q-101 Revision No.O Saved: 17-Oct-05 ZO-3/4ryCasin Point to TD Mud Properties Density (ppg) 9.0 - 9.2 i Plastic Viscosity 10 Yield Point (cP) 28-30 - 45 API Filtrate (cc / 30 min)) 4 - 6 Chlorides (mg/I) 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 for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item a/ready on fr/e with the commission and identified in the app/ication: (9) for an exploratory or stratigraphic test well, atabu/ation setting out the depths of predicted abnorma//y gea pressured strata as required by 20 AAC 25 033(t); 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)(1 D) An app/ication Far a Permit to Dri// must be accompanied by each of the fo/%wmg items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel% a seismic refraction or reflection ana/ysis as required by 20 AAC 25.061(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 application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commssion and identified in the application; (i1) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vess% an ana/ysis ofseabed conditions as required by 10 AAC 25.061(6); 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 foliowing items, except for an item a/ready on fr/e with the commission and identified in the application: (11) evidence showing that the requirements of20AAC25.0~5 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 1Q-101 PERMIT lT 10 17 05.doc Page 5 of 7 Printed: 17-Oct-05 ORIGINAL L~ Application for Permit to Drill, Well 1Q-101 Revision No.O Saved: 17-Oct-05 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dri// must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identfied in the application: The proposed drilling program for 1Q-101 is listed below. 1. Excavate cellar, install cellar 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 +/- 1889' MD /1748' 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 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. 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. f 8. Directionally drill to TD at 4955' MD / 3675' 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 Sonic/FMI 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 app/icatian for a Permit to Dri/! mustc be accompanied by each of the fo!/owing items, except For an item a/ready on fr/e with the commission and identified in the application: (14) a genera/ description ofhaw the operatorp/ans to dispose of dril/ing mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.OSp for an annular disposal operation in the we/%; 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 1Q-101 by filing with the AOGCC a 10-403 supplement with additional information as required under 20 AAC 25.080. 1Q-101 PERMIT IT 101705.doc Page 6 of 7 Printed: 17-Oct-05 • Application for Permit to Drill, Well 10-101 Revision No.O Saved: 17-Oct-05 15.Attachments Attachment 1 Nordic 3 West Sak Diverter & 3ksi BOP Configuration Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Cement Data Attachment 5 Well Schematic 1Q-101 PERMIT IT 10 17 05.doc Page 7 of 7 Printed: 17-Oct-05 • • Diverter System Schematic West Sak Exploration Wells, Vetco Gray Wellhead System, Nordic Rig 3 ----- Open--- 5 •r------- To Accumulator I Closed '~; F---------' L- I 1 II ~ ~ Accumulator I I I 1 I I I I I I I I Closed I 1 J I I _ _ _ ~ Open ~--- 4 V ~ A 3 Top of Wellhead 2 ~~' 6 Pad Level zo'~ ~ 0.00 ft. n ~'~~ en er Ine o ~~ 16" Diverter Line X.XX ft. (XX In) Bottom of Diverter KEY: 1. Conductor Casing; 20" 2. Landing Ring: 20" 2000 psi slip-on 3.Starting Head Adapter: 20" Vetco Gray Quick Connect Bottom x API 21-1/4" 2000 psi Flange Up, Vetco Gray. l1:..-..L-.. n.-~~/. ~lA A /All ~1/1A11 .-~: 1__ ~.-J L_ll ~.v .. :1L A/?II _'J_ _..11_1 5. Annular Preventer: Hydril MSP 2,000 psi annular -Nordic 7. Knife Valve: ANSI 16"-150# RF: The valve opens automatically upon closure of annular preventer -Nordic 8. Diverter Line: 16" -Nordic _._-~ ~~ ~i ~~~ ~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, 2-1/6" x 5,000 psi, Nordic 11. Kill Line Valve, Manual Operation, 2-1/16"" x 5,000 psi, Nordic prepared by Tom Brassfield 10/14/05 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 Q Pad Plan 1 Q-101 (20'E of 1 Q-06) Plan: 1 Q-101 (wp04) Proposal Report 14 October, 2005 HALLIBtJRTCiN Sperry Drilling Services -T-r SHL @ 1574ft FNL & 1160ft FEL -Sec 26 - T12N - R09E ~ COIIOCO~II~~IpS A~~ KOP @ 350ft MD, 350ft TVD -Build @ 2.50°/100ft o° ~o° loon Sail @ 32° Inc : 1630ft MD, 1564ft TVD zo° 1250 3~ 10 3/4" CSG @ 1175ft FNL 8 882ft FEL -Sec 26 - T12N - R09E, 1889ft MD, 1784ft TVD T8 + 385 (Surface CSt3) ~'~' 1o a~a^ ~ Build @ 4°/100ft to 56.33° Inc - 1910ft MD, 1802ft TVDJ Project: Kuparuk River Unit -- -- Site: Kuparuk 1Q Pad ,o Well: Plan 1Q-101 (20'E of 1Q-06) Sail @ 56.33° Inc : 2518ft MD, 2235ft TVD Wellbore: 1Q-West (NEWS 6 8~ 5) yo - Plan: 1Q-West (wp04) Ugnu C - - - - - - - - - - - - Drop @ 4°/100ft to 50° Inc, 3875ft MD, 2987ft TVD1 h~ j Sail @ 50°Inc & 34.92°Azi : 4033ft MD, 3082ft TVD Sporty DAlllny 3~nb~s -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 Vertical Section at 34.92° (500 ft/in) $ak D 1Q-101 T1 (Top WSAK) (wp03) ~BHL @ 787ft FSL & 489ft FWL -Sec 24 - T12N - R09E ==------------ yy~tSakA3 --------------------------------------- ------------- --- - y -- -- ----------------- a = _ - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - MALLIBURTON Project: Kuparuk River Unit NA~.I.IBURTOIV ~~~$ Site: Kuparuk 1Q Pad _ __ Well: Plan 1Q-101 (20'E of 1Q-06) $ ~ a""~"'s ~ Welibore: 1Q-West (NEWS 6 8~ 5) Plan: 1Q-West (wpiM) ~ , BHL @ 787ft FSL & 489ft FWL -Sec 24 - T12N - R09E 2100 1Q-101 T1 (Top WSAK) (wp03) "'S° 1925 1750 Top WSAK @ 270ft FSL & 129ft FWL -Sec 24 - T12N - R09E, 4133ft MD, 3146ft TVD - - - - - _ _ _ _ Sail @ 50°Inc & 34.92°Azi : 4033ft MD, 3082ft TVD 1575 `~ 0 ~~ ~~ ~~~_ ~ 1400 ~ `p Drop @ 4°/100ft to 50° Inc, 3875ft MD, 2987ft TVD o CASING DETAILS V~ ``~ v 1225 No TVD MD Name Size ~ ~ 1 1784.30 1889.20 10 3/4" 10-3/4 ~~a `''S° z° QO 1050 O Q~ Sail @ 56.33° Inc : 2518ft MD, 2235ft TVD o - ~ ,_ 875 - - - 700 SHL @ 1574ft FNL & 1160ft FEL -Sec 26 - T12N - R09E ~~ Build @ 4°/100ft to 56.33° Inc - 1910ft MD, 1802ft TVD . - ' ' , _ 10 3/4" CSG @ 1175ft FNL 8 882ft FEL -Sec 26 - T12N - R09E, 1889ft MD, 1784ft TVD -3S°--- - ------------ _____ Sail @ 32° Inc : 1630ft MD, 1564ft TVD _ _ KOP ae 350ft MD, 350ft TVD -Build @ 2.50°/100ft T M4zimuths to True North Magnetic North: 24.28° Magnetic Field Strength: 57556.1nT Dip Angle: 80.81 ° Date: 8/23/2005 Model: BGGM2005 -700 -525 -350 -175 0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 2450 West(-)/East(+) (350 ft/in) V ConocoPhillips Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1QPad Well: Plan 1Q-101 (20'E of 1 Q-06) Wellbore: 10-Wesf (NEWS 6 & 5) Design: 1 O-West (wp04) Halliburton Company HALLIBUi~T©N Planning Report -Geographic _._ .. ~... ,...~. sr,..ry orrrrr~ servres Local Co-ordinate Reference: Well Plan 1 Q-101 (20'E of 10-06) ND Reference: Original Plan RKB @ 80.30ft (Nordic 3) MD Reference: Original Plan RKB @ 80.30ft (Nordic 3) North Reference: True Survey Calculation Method: Minimum Curvature -- Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Pian 1Q-101 (20'E of 1Q-06) Well Position +N/S 0.00 ft Northing: 5,984,298.76 ft Latitude: 70° 22' 05.476" N +E/-W 0.00 ft Easting: 528,464.52 ft ~ Longitude: 149° 46' 07.323" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 52.30ft -- Wellbore 1 O-West (NEWS 6 & 5) --- Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 8/23/2005 24.28 80.81 57,556 - Design 1 O-West (wp04) -- -~ Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (ND) +N/-S +E/-W Directio n ~, (ft) (ft) (ft) (°) 28.00 0.00 0.00 34.92 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 1,630.00 32.00 34.92 1,564.49 285.55 199.35 2.50 2.50 0.00 34.92 1,910.00 32.00 34.92 1,801.94 407.21 284.28 0.00 0.00 0.00 0.00 2,518.20 56.33 34.92 2,234.96 752.06 525.02 4.00 4.00 0.00 -0.01 3,875.01 56.33 34.92 2,987.22 1,677.96 1,171.34 0.00 0.00 0.00 0.00 4,033.21 50.00 34.92 3,082.02 1,781.73 1,243.78 4.00 -4.00 0.00 179.98 4,133.21 50.00 34.92 3,146.30 1,844.54 1,287.63 0.00 0.00 0.00 0.00 4,855.06 50.00 34.92 3,610.30 2,297.95 1,604.17 0.00 0.00 0.00 0.00 4,955.06 50.00 34,92 3,674.58 2,360.76 1,648.02 0.00 0.00 0.00 0.00 10/14/2005 9:05:05AM Page 2 of 5 COMPASS 2003.11 Build 48 ~~1G~NQL `i ConocoPhillips Databas®: EDM 2003.11 Single User Db Company: ConocoPhillips,Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1Q Pad Well: Plan 1Q-101 (20'E of 1Q-06) Wellbore: 10-West (NEWS 6 & 5) Design: 10-West (wp04) Planned Survey 1 Q-West (wp04) Halliburton Company Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: MD Inclination Azimuth TVD SSTVD (ft) (°) (°) (ft) (ft) 28.00 0.00 0.00 28.00 -52.30 SHL ~ 1574ft FNL & 1160ft FEL - Sec 28 - T12N - R09E 100.00 0.00 0.00 100.00 19.70 200.00 0.00 0.00 200.00 119.70 300.00 0.00 0.00 300.00 219.70 350.00 0.00 0.00 350.00 269.70 KOP ~! 350ft MD, 350ft TVD - Build ~ 2.50°/100ft 400.00 1.25 34.92 400.00 319.70 500.00 3.75 34.92 499.89 419.59 600.00 6.25 34.92 599.50 519.20 700.00 8.75 34.92 698.64 618.34 800.00 11.25 34.92 797.11 716.81 900.00 13.75 34.92 894.74 814.44 1,000.00 16.25 34.92 991.32 911.02 1,100.00 18.75 34.92 1,086.68 1,006.38 1,200.00 21.25 34.92 1,180.65 1,100.35 1,300.00 23.75 34.92 1,273.03 1,192.73 1,400.00 26.25 34.92 1,363.65 1,283.35 1,500.00 28.75 34.92 1,452.35 1,372.05 1,600.00 31.25 34.92 1,538.94 1,458.64 1,630.00 32.00 34.92 1,564.49 1,484.19 Sail ~ 32° Inc : 1830ft MD, 1564ft TVD 1,662.80 32.00 34.92 1,592.30 1,512.00 Base Permafrost +N/-S +E/-W (ft) (ft) 0.00 0.00 HALt.tBtJF1TGN _v. ...,....... sp.-ry fa~u~ s.~cs Well Plan 1Q-101 (20'E of 10-06) Original Plan RKB @ 80.30ft (Nordic 3) Original Plan RKB @ 80.30ft (Nordic 3) True Minimum Curvature Map Map Northing Easting DLSEV Vert Section (ft) (ft) (°l100ft) (ft) 5,984,298.76 528,464.52 0.00 0.00 0.00 0.00 5,984,298.76 528,464.52 0.00 0.00 0.00 0.00 5,984,298.76 528,464.52 0.00 0.00 0.00 0.00 5,984,298.76 528,464.52 0.00 0.00 0.00 0.00 5,984,298.76 528,464.52 0.00 0.00 0.45 0.31 5,984,299.21 528,464.83 2.50 0.55 4.02 2.81 5,984,302.79 528,467.31 2.50 4.91 11.17 7.80 5,984,309.96 528,472.27 2.50 13.62 21.87 15.27 5,984,320.69 528,479.70 2.50 26.67 36.11 25.21 5,984,334.96 528,489.59 2.50 44.04 53.85 37.60 5,984,352.75 528,501.91 2.50 65.68 75.07 52.41 5,984,374.03 528,516.64 2.50 91.56 99.73 69.62 5,984,398.74 528,533.76 2.50 121.63 127.77 89.20 5,984,426.86 528,553.22 2.50 155.83 159.15 111.10 5,984,458.31 528,575.01 2.50 194.09 193.80 135.29 5,984,493.05 528,599.06 2.50 236.35 231.65 161.72 5,984,531.00 528,625.35 2.50 282.52 272.65 190.34 5,984,572.10 528,653.81 2.50 332.52 285.55 199.35 5,984,585.03 528,662.76 2.50 348.25 299.80 209.30 5,984,599.32 528,672.66 0.00 365.63 1,700.00 32.00 34.92 1,623.85 1,543.55 315.96 220.58 5,984,615.53 528,683.88 0.00 385.34 1,800.00 32.00 34.92 1,708.65 1,628.35 359.41 250.92 5,984,659.09 528,714.04 0.00 438.33 1,889.20 32.00 34.92 1,784.30 1,704.00 398.17 277.98 5,984,697.95 528,740.95 0.00 485.60 10314" CSG ~ 1175ft FNL & 882ft FEL -Sec 28 - T12N - R09E, 1889ft M D, 1784ft TVD - T3 + 385 (Surface CSG) -10 3/4" 1,900.00 32.00 34.92 1,793.46 1,713.16 402.86 281.25 5,984,702.65 528,744.21 0.00 491.33 1,910.00 32.00 34.92 1,801.94 1,721.64 407.21 284.28 5,984,707.01 528,747.23 0.00 496.63 Build ~ 4°/100ft to 58.33° Inc - 1 910ft MD, 1802ft TVD 2,000.00 35.60 34.92 1,876.72 1,796.42 448.25 312.94 5,984,748.16 528,775.72 4.00 546.68 2,100.00 39.60 34.92 1,955.93 1,875.63 498.27 347.86 5,984,798.30 528,810.45 4.00 607.69 2,200.00 43.60 34.92 2,030.69 1,950.39 552.70 385.85 5,984,852.87 528,848.23 4.00 674.07 2,300.00 47.60 34.92 2,100.64 2,020.34 611.28 426.74 5,984,911.59 528,888.89 4.00 745.50 2,400.00 51.60 34.92 2,165.44 2,085.14 673.71 470.32 5,984,974.18 528,932.23 4.00 821.64 2,500.00 55.60 34.92 2,224.77 2,144.47 739.69 516.39 5,985,040.34 528,978.04 4.00 902.11 2,518.20 56.33 34.92 2,234.96 2,154.66 752.06 525.02 5,985,052.74 528,986.62 4.00 917.19 Sail ~ 58.33° Inc : 2518ft MD, 2235ft TVD 2,600.00 56.33 34.92 2,280.31 2,200.01 807.88 563.98 5,985,108.70 529,025.37 0.00 985.27 2,700.00 56.33 34.92 2,335.76 2,255.46 876.12 611.62 5,985,177.12 529,072.74 0.00 1,068.49 2,800.00 56.33 34.92 2,391,20 2,310.90 944.36 659.26 5,985,245.53 529,120.11 0.00 1,151.71 2,893.97 56.33 34.92 2,443.30 2,363.00 1,008.49 704.02 5,985,309.82 529,164.63 0.00 1,229.91 Ugnu C 2,900.00 56.33 34.92 2,446.64 2,366.34 1,012.61 706.89 5,985,313.95 529,167.49 0.00 1,234.93 3,000.00 56.33 34.92 2,502,09 2,421.79 1,080.85 754.53 5,985,382.36 529,214.86 0.00 1,318.16 10/14/2005 9:05:05AM Page 3 of 5 COMPASS 2003.11 Build 48 ORIGINAL 7/ ~ Halliburton Company NALLIBLlFlTON COn~~~~~~ p~ Planning Report -Geographic ~~ p~~~ ~~~~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1Q-101 (20'E of 1Q-06) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Original Plan RKB @ 80.30ft (Nordic 3) Protect: Kuparuk River Unit MD Reference: Original Plan RKB @ 80.30ft (Nordic 3) Site: Kuparuk 1Q Pad North Reference: True Weil: Plan 1Q-101 (20'E of 1Q-06) Survey Calculation Method: Minimum Curvature Weltbore: 1 C,2-West (NEWS 6 & 5) Design: 1Q-West (wp04) Planned Survey 1 O-West (wp04) ~~ Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 3,100.00 56.33 34.92 2,557.53 2,477.23 1,149.09 802.16 5,985,450.78 529,262.23 0.00 1,401.38 3,200.00 56.33 34.92 2,612.98 2,532.68 1,217.33 849.80 5,985,519.19 529,309.60 0.00 1,484.60 3,300.00 56.33 34.92 2,668.42 2,588.12 1,285.57 897.43 5,985,587.61 529,356.97 0.00 1,567.83 3,400.00 56.33 34.92 2,723.86 2,643.56 1,353.81 945.07 5,985,656.02 529,404.34 0.00 1,651.05 3,472.93 56.33 34.92 2.764.30 2.684.00 1.403.58 979.81 5.985.705.92 529.438.89 0.00 1.711.74 Ugnu B 3,500.00 56.33 34.92 2,779.31 2,699.01 1,422.05 992.70 5,985,724.44 529,451.71 0.00 1,734.27 3,600.00 56.33 34.92 2,834.75 2,754.45 1,490.29 1,040.34 5,985,792.85 529,499.08 0.00 1,817.49 3,700.00 56.33 34.92 2,890.19 2,809.89 1,558.53 1,087.97 5,985,861.27 529,546.45 0.00 1,900.72 3,800.00 56.33 34.92 2,945.64 2,865.34 1,626.78 1,135.61 5,985,929.68 529,593.82 0.00 1,983.94 3,875.01 56.33 34.92 2,987.22 2,906.92 1,677.96 1,171.34 5,985,980.99 529,629.36 0.00 2,046.36 Drop ~ 4°HOOR to 50° Inc, 3875ft MD, 2987ft TVD 3,900.00 55.33 34.92 3,001.26 2,920.96 1,694.92 1,183.18 5,985,997.99 529,641.13 4.00. 2,067.04 3,943.08 53.60 34.92 3,026.30 2,946.00 1,723.66 1,203.24 5,986,026.81 529,661.08 4.00 2,102.10 K13 4,000.00 51.33 34.92 3,060.97 2,980.67 1,760.67 1,229.08 5,986,063.92 529,686.77 4.00 2,147.23 4,033.21 50.00 34.92 3,082.02 3,001.72 1,781.73 1,243.78 5,986,085.03 529,701.39 4.00 2,172.91 Sail ~ 50°Inc &34.92°Azi : 4033ft MD, 3082ft TVD 4,100.00 50.00 34.92 3,124.96 3,044.66 1,823.68 1,273.07 5,986,127.09 529,730.52 0.00 2,224.08 4,133.21 50.00 34.92 3,146.30 3,066.00 1,844.54 1,287.63 5,986,148.00 529,745.00 0.00 2,249.52 Top WSAK ~ 270ft FSL 8129ft FWL -Sec 24 - T12N - R09E, 4133ft MD, 3146ft TVD -West Sak D -1 Q-101 Ti (Top WSAK) (wp03) 4,200.00 50.00 34.92 3,189.23 3,108.93 1,886.50 1,316.92 5,986,190.06 529,774.13 0.00 2,300.68 4,246.77 50.00 34.92 3,219.30 3,139.00 1,915.87 1,337.43 5,986,219.52 529,794.52 0.00 2,336.51 West Sak B 4,300.00 50.00 34.92 3,253.51 3,173.21 1,949.31 1,360.77 5,986,253.03 529,817.73 0.00 2,377.29 4,383.68 50.00 34.92 3,307.30 3,227.00 2,001.87 1,397.46 5,986,305.73 529,854.22 0.00 2,441.39 West Sak A3 4,400.00 50.00 34.92 3,317.79 3,237.49 2,012.12 1,404.62 5,986,316.01 529,861.34 0.00 2,453.89 4,500.00 50.00 34.92 3,382.07 3,301.77 2,074.93 1,448.47 5,986,378.98 529,904.95 0.00 2,530.50 4,509.69 50.00 34.92 3,388.30 3,308.00 2,081.02 1,452.72 5,986,385.08 529,909.18 0.00 2,537.92 West Sak A2 4,600.00 50.00 34.92 3,446.35 3,366.05 2,137.74 1,492.32 5,986,441.95 529,948.56 0.00 2,607,10 4,700.00 50.00 34.92 3,510.63 3,430.33 2,200.56 1,536.17 5,986,504.92 529,992.16 0.00 2,683.71 4,800.00 50.00 34.92 3,574.91 3,494.61 2,263.37 1,580.02 5,986,567.89 530,035.77 0.00 2,760.31 4,855.06 50.00 34.92 3,610.30 3,530.00 2,297.95 1,604.17 5,986,602.57 530,059.78 0.00 2,802.49 Base West Sak 4,900.00 50.00 34.92 3,639.19 3,558.89 2,326.18 1,623.88 5,986,630.87 530,079.38 0.00 2,836.91 4,955.06 50.00 34.92 3,674.58 ~ 3,594.28 2,360.76 1,648.02 5,986,665.54 530,103.39 0.00 2,879.09 BHL ~ 787ft FSL & 489ft FWL -Sec 24 - T12N - R09E i 10/142005 9:05:05AM Page 4 of 5 COMPASS 2003.11 Build 48 ORIGINAL. ~-' ~ Halliburton Com any C011tK0~'11~~1p5 p HALiLIBUi~T~N --~ - , - - Pl i R hi rt G ann ng eograp epo - c A(aska Spsn'Y DritNng S•rv~ces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Ptan 10-101 (20'E of 1Q-06) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Original Plan RKB @ 80.30ft (Nordic 3) Project: Kuparuk River Unit MD Reference: Original Plan RKB @ 80.30ft (Nordic 3) Site: Kuparuk TQ Pad North Reference: True Well: Plan 1`Q-101 (20'E of 1Q-06) Survey Calculation Method: Minimum Curvature Wellbore: 1Q-West (NEWS 6 & 5) Design: 1 O-West (wp04) Geologic Targets 1 O-West (NEWS 6 & 5) TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,146.30 1Q-101 T1 (Top WSAK) (wp03) 1,844.54 1,287.63 5,986,148.00 529,745.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) f') ('7 1,889.20 1,784.30 10-3/4 13-112 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) (ft) (ftl (ft) Name 1,662.80 32.00 34.92 1,592.30 299.80 209.30 Base Permafrost 1,889.20 32.00 34.92 1,784.30 398.17 277.98 T3 + 385 (Surface CSG) 2,893.97 56.33 34.92 2,443.30 1,008.49 704.02 Ugnu C 3,472,93 56.33 34.92 2,764.30 1,403.58 979.81 Ugnu B 3,943.08 53.60 34.92 3,026.30 1,723.66 1,203.24 K73 4,133.21 50.00 34.92 3,146.30 1,844.54 1,287.63 West Sak D 4,246.77 50.00 34.92 3,219.30 1,915.87 1,337.43 West Sak B 4,383.68 50.00 34.92 3,307.30 2,001.87 1,397.46 West Sak A3 4,509.69 50.00 34.92 3,388.30 2,081.02 1,452.72 West Sak A2 4,855.06 50.00 34.92 3,610.30 2,297.95 1,604.17 Base West Sak 10/14/2005 9:05:05AM Page 5 of 5 COMPASS 2003.11 Build 48 r~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 Q Pad Plan 1 Q-101 (20'E of 1 Q-06) • Anticollision Summary 14 October, 2005 HA~L.I E~1.~1 i-'~'~'i~R1 Sperry Drilling Services ORIGINAL 1Q• 270 Date: 201L4141JTW:g1:IN1 Validated: Ycs Version: Depth Frum Depth To Sune~IPlan Tad 2&INI 981.00 1~Wed Ix 1>OJI l'B-GYRO-SS 8011.81 J955.116 IQ-West Ix~pot) MWD 1 Q-21 0 ConocoPhillips Alaska (Kuparuk) Engineering Slot West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Ertor Surtace: Elliptical COnic Warning Method: Rules Based 20 300 60 15 - t0 _~ 1 Q-03 \~~ 90 +n 1Q-0 240 \\___t\\s<~~~ 1 / / ~20 ~1Q-0~ 1 Q-26 1D-0~ 210 150 30 From Colour To MD 160 28 250 Travelling Cylinder Azimuth (TF'O+AZJ) )°) vs Centre td Centre Separafion X15 tt/in~ I 250 500 LJ ~--~ 500 750 180 1Q-05J 750 1000 1Q-23J 1Q-06 1000 - 1250 1250 15D0 Travelling Cylinder Azimuth (TFO+AZI) ~°~ Ys Centre to Centre Separation X250 ft/ink 1500 1750 SECTION DETAILS 1750 2000 Sec MD Inc Azi ND +N/-S +FJ-W DLeg TFace VSec Target 2000 2500 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 2500 3000 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 3000 3500 3 1630.00 32.00 34.92 1564.49 285.55 199.35 2.50 34.92 348.25 4 1910.00 32.00 34.92 1801.94 407.21 284.28 0.00 0.00 496.63 3500 5000 5 2518.20 56.33 34.92 2234.96 752.06 525.02 4.00 -0.01 917.19 5000 6500 6 3875.01 56.33 34.92 2987.22 1677.96 1171.34 0.00 0.00 2046.36 7 4033.21 50.00 34.92 3082.02 1781.73 1243.78 4.00 179.98 2172.91 6500 8000 8 4133.21 50.00 34.92 3146.30 1844.54 1287.63 0.00 0.00 2249.52 10-101 T1~Top WSAK) REFERENCE INFORMATION 8000 9500 94855.06 50.00 34.92 3610.30 2297.95 1604.17 0.00 0.00 2802.49 9500 11000 104955.06 50.00 34.92 3674.58 2360.76 1648.02 0.00 0.00 2879.09 Coordinate (N/E) Reference: Well Plan 10-101 (20'E of 10-06), Tme North Vertical (TVD) Reference: Original Plan RKB ~ 80.SOft (Nordic 3) 11000 _ -- - -_ - 12500 Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Original PWn RKB ~ 80.30ft (NOrtlic 3) Caleuation Method: Minimum Curvature NAD 27 ASP Zone 4 : WELL DETAILS: Plan 10-101 (20'E of 10-06) ANTI-COLLISION SETTINGS Ground Level: 52.30 IMerpolalion Method: MD Imenral: 60Stations +NIS +EI-W Northing Easting Latittude Longitude Depth Range From: 28.00 To 4955.06 0.00 0.00 5984298.78 528464.52 70°22'5.476N 149°467.323W Maximus Range:2064.9 Reference: Plan: 10-West (wp04) 330 \r-' ColnoCOPhillips Company; ConocoPhiltips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1Q Pad Site Error: O.OOft Reference Well: Plan 1Q-101 (20'E of 1Q-06y Welt Error: O.OOft Reference Wellbore 1Q-West (NEWS 6 & 5) Reference Design: 1 O-West (wp04) Halliburton Company Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: NALLIBURTON terry Dtril{iny Ssrvia~s Well Plan 10-101 (20'E of 10-06) Original Plan RKB @ 80.30ft (Nordic 3) Original Plan RKB @ 80.30ft (Nordic 3) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1Q-West (wp04) 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 2,064.90ft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Dat® 10/14/2005 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1Q-West (wp04) (1Q-West (NEWS 6 & 5)) CB-GYRO-SS Camera based gyro single shot 800.00 4,955.06 1 O-West (wp04) (1 O-West (NEWS 6 & 5)) 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 1Q Pad 1Q-01 - 1Q-01 - 1Q-01 3,589.22 3,400.00 450.68 136.64 314.04 Pass -Major Risk 1Q-02 - 10-02 - 1Q-02 1,537.16 1,500.00 218.28 32.80 185.48 Pass -Major Risk 1 Q-02 - 1 O-02A - 1 Q-02A 1,547.52 1,500.00 218.50 33.12 185.38 Pass -Major Risk 10-02 - 1Q-02APB1 - 1Q-02AP61 1,547.52 1,500.00 218.50 33.12 185.38 Pass -Major Risk 1 Q-03 - 1 Q-03 - 1 Q-03 2,781.59 2,550.00 200.75 67.89 132.86 Pass -Major Risk 10-04 - 1Q-04 - 10-04 1,743.24 1,600.00 244.91 42.86 202.05 Pass -Major Risk 1Q-05 - 1Q-05 - 1Q-05 540.19 550.00 42.47 11.09 31.38 Pass -Major Risk 1 Q-06 - 1 Q-06 - 1 Q-06 488.72 500.00 19.92 9.18 10.74 Pass -Major Risk 1 Q-07 - 1 Q-07 - 1 Q-07 437.95 450.00 81.07 8.87 72.19 Pass -Major Risk 1 Q-07 - 1 O-07A - 1 O-07A 437.95 450.00 81.07 8.87 72.19 Pass -Major Risk 10-07 - 10-07A PB1 - 1Q-07A PB1 437.95 450.00 81.07 8.87 72.19 Pass -Major Risk 10-08 - 1Q-08 - 1Q-08 437.03 450.00 141.22 7.73 133.49 Pass -Major Risk 1 Q-08 - 1 Q-08A - 1 O-08A 441.94 450.00 141.30 7.81 133.49 Pass -Major Risk 1Q-21 - 1Q-21 - 1Q-21 101.09 100.00 377.35 2.09 375.26 Pass -Major Risk 10-22 - 1Q-22 - 10-22 2,411.91 2,350.00 115.99 64.13 51.86 Pass -Major Risk 1Q-23 - 10-23 - 1Q-23 336.29 350.00 67.14 6.06 61.08 Pass -Major Risk 1Q-26 - 1Q-26 - 1Q-26 531.01 550.00 153.18 9.62 143.56 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 10/142005 9:24:38AM Page 2 of 2 .COMPASS 2003.11 Build 48 ORIGINAL °'°'~ !~'°V~ 1~,.~ J .~...~.. ConocoPhillips Alaska lnc. (~4'est Sak) Alaska State Planes 4 Well: IQ-West (wp04) Date: 14Oct-OS Nad 27 Coordinates Vsec Plane 34.92° SVY MD Inc Aziro. SSTVll TVD N/S E/W ~ Y DLS V.S. Comments # (ft) (Dee) (Deg) (ft) (ft) (ft) ([t) (ft) {ft) °1100ft (ft) Tie-On 0 0.00 0.00 -80.30 0.00 0.00 N 0.00E 538464.520E 5984298.760 N .0.00 0.00 SHL ~ 1574ft FNL & 1160ft FEL -Sec 26 - T12N - 1 100 0.00 0.00 19-70 100.00 0.00 N 0.00E 528464.520E 5984298.760 N 0.00 0.00 2 200 0.00 0.00 119.70 200.00 0.00 V 0.00E 528464.520E 5984298.760 N 0.00 0.00 3 300 0.00 0.00 219.70 300.00 0.00 N 0.00E 528464.520E 5984298.760 N 0.00 0.00 4 350 0.00 .0.00 269.70 350.00 0.00 N 0.0(1 E 528464.520E 5984298.760 N 0.00 0.00 KOP ~ 350ft MD, 350ft TVD - Build ~ 2.50°/100fi 5 400 1.25 34.92 319.69 399.99 0.45 N 0.31E 528464.830E 5984299208 N 2.50 0.55 6 500 3.75 34.92 419.59 499.89 4.02 N 2.87 E 528467.313E >9843(12.794 N 2.50 4.91 7 604 6.25 '-34.92 519.20 599.50 11.17 N ' 7.80E 528472.274E 5984309.458 N 2.50 13.62 8 744 8.75 34..92 _ 618.34 698.64 21.87 N ' 15.27E 528479.704E 5984320.686 N 2.50 26.67 9 $04 11.25 34.9$ 716.81 797.1( 36.11 N 25.21E 528489.588E 5984334.960 N 2.50 44.04 10 400 13.75 34.92 814.43 894:73 53.85 N 37.60 ~ 528501.908E 59843>2.750 N 2.50 65.68 11 14(10 76.25 34.93 911.02 99132 75.07 N 52.41E 528516.640E 5984374.024 N 2.50 91.56 12 1]00 18.75 34.92' 1006.38 1086.68 99.73 N 6):62 E 528533.756E 5984398.741 N 2.50 12L63 13 1200 21.25 34.92 1100.34 1180.64 127.77 N 89.20E 528553.224E 59$4426.854N 2.50 155.82 14 1304 23.75 34:92 1192.72 1273.02 159.14 N 111.10E 528575.006E 5984458.310 N 2.50 194.09 15 1400 26.25 34:42 1283.35 1363:65 193.79 N 135.29E 528599.062 E .5984493.04$ N 2.50 . 236.35 16 1504 28.75 34,92 1372.04 1452.34 231.65 N 161.72E 528625.345E 598453L002 2.50 282.52 17 160(1 31.25 34.92 1458.64 1538.94 272.65 N 190.34E 528653.805E 5984572.100 2.50 332.51 18 1630 32.00 3492 1484.19 1564.44. 285.55 N 199.35E 528662.762E 5984585.034 N 2.50 348.25 Sail ~ 32° Inc : 1630ft MD, 1564ft TVD 19 1663' 32.00 34.92 1512.04 .1592.30 299.80 N 209x0 E 528672.655 E 5984599.322 N 0.00 365.63 Base Permafrost 20 1704 32.00 34.92 1543.54 1623.$4 315.96 N 220.58E 528683.876 E 5984615.524 N 0.00 385.34 _ _ 21 1$06 32.00 ' 34.92 1628.35 1708,65 359.41 N 250.91E 528714.041E 59$4659.086 N 0.40 438.33 22 1$89 32.00 34.92 1704.00 1784.36 398.17 N 277.98E 528740.952E 5984697:946 N 0.00 485.64 10 3/4" CSG ~ 1175ft FNL & 882ft FEL -Sec 26 -' 23 1900 32.00 34.92" 1713.15 1793.45 402.86 N 281.25E 528744.207E 5984702.647 N 0.00 491.32 24 1410 32.00 34.92 1721.64 180134 407.21 N 284.28 E, 528747.226E .5984707.007 N 0.00 ' 496.63 Build ~ 4°/100ft to 56.33° Inc - 1910ft MD, 1802ft 25 2000 35.60 . 34.92 1796.41 . 1876.71 448.25 N 312.94E 528775.719E 5984748.153 4.00 546.68 26 2104 39.60 34.92 1875.62 1955.92: 498.27 N 347.85E 528810.443E 5984798.294 N 4.00 607.68 27 2200 43.60 .34.92 1950.39 2430:69' 552.70 N 385,&S E 528848.228E 5984852.866 4.00 674.06 28 230(1 47.60 34.92 2020.34 2100;64 611.27 N 426.74E 528888.889E 5984911.588 4.00 745.49 29 2400 51.60 34.92. 2085.14 2165.44 673.70 N - 470.32E 528932.228E 5984974.178 4.00 821.63 30 2500: 55.60 '- 34.92: 2144.47 2224.77 739.69 N 516;38 E 528978.034E >985040:332 N 4.00 902.16 31 2518 56.33 34.92 2154.66 2234.96 752.06 N 525.02E 528986.623E 5935052 737 N 4.00 917.19 Sail ~ 56.33° Inc : 2518ft MD, 2235ft TVD 32 2600 56.33 34.92 2200.01 2280.31 807.88 N 563.98E 529025.368E 5985108.693 N 0.00 ' 985.26 33 27(10 56.33 34.92 2255.45 2335.75 876.12 N 611.61E 529072.738E 5985177.108 N 0.00 1068.48 34 2800 56.33 34.92 2310.89 2391.19 944.36 N 65925E 529120.109E 5985245.523 N 0.00 1151.70 35 2894 56.33 _ 34.92 _ 2363.00 - 2443.30 - 1008.49 N -- 704.02E - 529164.628E 5985309.818 N - 0.00 1229.91 Ugnu C _ _-_ 36 2900 56.33 34.92 2366.34 2446.64 1012.60 N ' 706.89 F 529167.480E 5985313.937 N 0.00 1234.93 _- . 37 3000 56.33 34.92 2421.78 2502.08 1080.84 N 754.52E 529214.851E 5985382.352 N 0.011 1318.15 38 3100 56.33 34.92 2477.23 2557.53 1149.08 N 802.16E 529262.222E 5985450.767 N 0.00 1401.37 39 3200 56.33 34.92 2532.67 26(2.97 1217.32 N 849.79E 529309.542E 5985514.182 N 0.00 1484.59 40 3300 56.33 34.92 2588.11 2668.41 1285.56 N' 897.43E 529356.963 E 5985587.596 N 0.00 1567.81 41 3400 56.33 34.92 2643.56 2723.86 1353.80 N 945.06E 529404.334E 5985656.011 N 0.00 1651.04 42~ 3473 56.33 34.92 2684.00 2764.30 1403.58 N 979.81E 529438.890E 5985705.917 N 0.00 ]711,74 Ugnu B 43 3500 56.33 . 34.92 2699.00 2779.30 1422.04 N 992.70E 529451.705E 5985724.426 N 0.(10 1734.26 44 3600 56.33 34.92 2754.44 2834.74 1490.28 N 1040.33E 529499.076E 5985792.840 N 0.0(1 1817.48 45 3700 56.33 34.92 2809.89 2890.19 1558.52 N 1087.97E 529546.447E 5985861255 N 0.00 1900.70 46 3800 56.33 34.92 2865.33 2945.63 1626.77 N 1135.60E 529593.817E 5985939.670 N 0.00 1983.93 47 3875 56.33 34.92 2906.92 2987.22 - 1677.96 N 1171.34E 529629.355E 5985980.995 N 0.00 2046.36 Drop (nj 4°/100ft to 50° Inc, 3875ft MD, 2987ft TV L 48 3900 55 33 34.92 - 2920.95 300125 - 1694.91 N I (83.17 E 529641.119E - 5985997 984 N 4.00 - 2067.03 -- - -- 49 3943 53.60 34.92 2946.00 306.30 1723.66 N 103.24 E 529661.082E 598606 814 N 4.00 2102.10 K13 1 50 4000 - 51.33 - 34.92 -- 2980.66 i 3060.96 - - 1760.66 N - - 129.07 E - 529686.766E 5986063 906 N - - 1.00 2147.22 - J 51 4033 50.00 34.92 3001.72 3082.02 ]781.73 N 1243.78E 529701.393E 5986085.028 N 4.00 2] 72.91 _ - -.. Sail ~a, 50°Inc & 34.92°Azi : 4033ft MD, 3082ft TVl 52 4100 50.00 34.92 3044.65 3124.95 1823.67 N 1273.06E 529730.513E 5986127.079 N 0.00 2224.07 53 4133 50.00 34.92 3066.00 3146.30 1844.54 N' 128263E 529745.000E 5986148.000 N 0.00 2249.52 Top WSAK ~ 270ft FSL & 129ft FWL -Sec 24 - T 54 4136 50.00 34.92 3068.00 3148.30 1846.49 N 1288.99E 529746.357E 5986149.959 N 0.00 2251.90 55 4200 50.00 34.92 3108.92 318922 188b.48 N 1316.91E 529774.120E 5986190.051 N 0.(10 2300.67 56 4247 50.00 34.92 3139.00 3219.30 1915.87 N ] 337.43E 529794.524E 5986219.5 ] 6 N 0.00 2336.5 I West Sak B 57 4300 50.00 34.92 3173.20 3253.50 1444.30 N 1360.76E 529817.727E 5986253.023 N 0.00 2377.27 Page 1 of 2 R09E • C72N - R09E - T3 + 385 (Surface CSG) - 10 3/4" TVD • 2N - R09E, 4133ft MD, 3146ft TVD -West Sak D - 1Q-101 TI ~°~^'''~ N ....... `tii ~ .~.... °i~....~ .}+~r~~ i SVY # MD (ft) Inc (Deg) 9zim. (Deg) SSTVD (ft) TVD (tt) N/S (ft) E/V1' (ft) X (ft) Y (ft) DLS °/100ft V.S. (ft) Comments 58 59 4384 4400 50.00 50.00 34.92 _34.92 3227.00 3237.48 3307.30 3377.78 2001.87 N 2012.11 N 1397.46E 1404.61 E 529854.224E 529861.334E 5986305.727 N 5986315.995 N 0.00 0.00 2441.39 2453.88 West Sak A3 60 61 62 4500 4510 4600 50.00 50.00 50.00 34.92 34.92 34.92 3301.76 3308.00 3366.04 3382.06 3388.30 3446.34 2074.92 N 20R 1.02 N 2137.73 N 1448.46E 1452.72E 1492.31E 529904.941E 529909.175E 529948.549E 5986378.966 N 5986385.080 N 5986441.938 N 0.00 0.00 0.00 . 2530.48 2537.92 2607.09. West Sak A2 63 64 _ 65 4700 4800 4826 50.00 50.00 50.00 34.92 34.92 34.92 3430.32 3494.59 3511.00 3510.62 3574.89 3591.30 2200.54 V' 2263.36 N ?279.39 N 1536.17E (580.02 l 1591.21 E 529992.156E 530035.763E 530046.893E 5986504.910 N 5986567.882 N 5986583.953 N 0.00 0.00 0.00 2683.69 276029 2779.85 66 67 68 4855 4900 4955. 50.00 50.00 50.00 34.92 34.92 34.92 3530.00 3558.87 3594.28 3610.30 3639.17 3674.58 2297.95 N 2326.17 N 2360.76 N 1604.17E 1623.87E 1648.02E 530059.782 E 530079.370E 530103.390E 5986602.567 N 5986630.853 N 5986665.539 N 0.00 Q00 0.00 2802.49 2836.90 2879.09 Base West Sak BHL ~ 787ft FSL & 489ft FWL -Sec 24 - T12N - 1 109E • Page 2 of 2 • 10-101 Drilli • 13 1 2" Open Hole / 10 3/4" Casing 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" Open 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 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 1 Q-101 Drilling Hazards Summary prepared by TJB 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: NEWS Client: ConocoPhillips Alaska, Inc. Revision Date: 10/14/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,663' MD (1,592' TVD) Sehl~nhp~ 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 1,689' MD. Lead Slurry Minimum pump time: 190 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x (1663' - 80') x 3.50 (250% excess) = 2015.1 ft3 0.3637 ft3/ft x (1689' - 1663') x 1.30 (30% excess) = 12.3 ft3 109.2 ft3 + 2015.1 ft3+ 12.3 ft3 = 2136.6 ft3 2136.6 ft3 / 4.45 ft3/sk = 480.1 sks Round up to 490 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 130 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3637 ft3/ft x (1889' - 1689') x 1.30 (30% excess) = 94.6 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 94.6 ft3 + 43.2 ft3 = 137.8 ft3 137.8 ft3/ 2.52 ft3/sk = 54.7 sks Round up to 60 sks BHST = 35°F, Estimated BHCT = 58°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 1,689' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 1,889' MD (1,784' TVD) 4 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 7 388 55.4 90.4 Tail Slurry 5 27 5.4 95.8 Drop Top Plug 5.0 100.8 Displacement 7 159 22.7 123.5 Slow Rate 3 15 5.0 128.5 MUD REMOVAL Recommended Mud Properties: 9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint throughout tail cement ORIGINAL ~- Tree: (2) Vetco 4-1/8 x 5ksi valves Tubing Hanger: Vetco, with 3- '/s', EUE 8rd box down. 1Q-101 Proposed Surface Location: Eastings:528,465 ~ Northings:5,984,299 Pad Elevation: 50.3' AMSL Wellhead: Vetco M6228 Lower Bowl Nordic Rig 3 Floor @ 0' Elevation: 80.3' AMSL Conductor: 20" x 34" Insulated, set at 110' Cement retainer and plug across casing shoe Fluid: Drilling mud ,_ Fluid: Diesel in tubing and annulus 3'/Z ', 9.3#, L80 EUE 8rd Mod Tubing @ +/-1600' MD TD 13?/Z" hole Shoe of 10 3/<", 45.5#, L-80 BTC Casing @ 1889' MD, 1784' TVD TD 8-1 /2" hole / ~- @ 4,955' MD, ~ 3,675' TVD ,~~ r ~ r ~~,~a ~. .~__ Cement Plug(s) across hydrocarbon bearing zones ConocoPhilli 5 1 Q-101 FEL 3 Sheet 1 of 1 p We I I Design modified by TJB Alaska 10/14/2005 R SHARON K. ALLSUP-DRAKE.'. 1'114 CONOCOPHILLIPS ( /B~_ ATO1530 ~y/ k;~ 700 G ST. DATE. [- 62-14/311 ANCHORAGE AK 99501: f ~y'~q- ~ / ~~ /~ PAY TO TWE ~~ (~ ~I~I~SM1.~` 1 ~~~ $ lW, OC/ ORDER OF f A ~~ f0~ DOLLARS U ~ ~ ~~ a ~~' ' ' CHASE ChastrManhattan Bank USA, N.A: Valid Up TO 5000 D01I8(S ~~ 200 WM1Re CWy Center Dc. Newark,'DE 19711 ~~ / IIIP MEMO ---_---------- x:03 L LO0 L44~:2 L84? L90?9 276~~' L L L4 • C TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~ ~ ~ ~" I ~=' I 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 25.005(fj, all (PH) 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 produce/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 SAKOIL - 490150 Well Name: KUPARUK RIV UNIT 1Q-101 Program EXP Well bore seg ^ PTD#:2051560 Comp any CONOCOPHILLIPS ALASKA INC Initial Class/Type EXP f PEND _GeoArea 890 Unit 1116D OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached- - - - - Yes - - - - _ .. 2 Lease numberappropriate___ -__-__._ Yes_______ _____________.__.___. 3 Uniquewefl-name andnumbe[ - - -- -- - - - - ---- -- - Yes -- - ~- - --- --- -- - ---- ~-- -- -- - 4 Well locaied in a_defined pool- . _ - _ Yes - _ KUPARUK RIVER, WE$T SAK OIL - 490150; this is a West Sak-delineation well.- . - - - - - 5 Well located proper distance from drilling pnit_boundary- - _ - _ . - Yes _ _ - _ There shall be no_restrictions as to well spacing except that no pay shall be opened-in a well. closer than_ 500 - . - 6 Well located proper distance from other wells- - - _ . - Yes . - - . _ feet to an external property line_tyhere-ownership or landownership-changes.- As proposed, this well complies. - 7 Sufficientacreageavailablein-dril_lingunit-___-__-___---------- ------- -Yes_____. -__._. 8 If deviated, is-wellboreplat-included____________ _____________ _________Yes_.__ -_ .-.--.-_-_. 9 Operator onlyaff_ectQdparty-------------- ------------ ---------Yes----.-- ----------.--. 10 Ope[atorhasappropriate-bondinfQrce________________________ _________Yes___.___ _._.._. ___._..__.___..__..-.._-__-_--__.._-.. 11 Pe[mitcanbeissuedwithoutcopservationorder-___ ___ _________ ____ ____Yes_-__-__ -__-_-_____-________-__ Appr Date 12 Permit. can be issued without administrative-approval _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - _ _ _ - _ _ , _ _ . _ _ - _ _ _ _ _ - - _ _ - SFD 10/2412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by_ Injection Order # (put.l9# in_comments)-(For- NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ _ _ _ . . - _ - - _ - _ - - _ _ _ . _ - - _ - _ - - .. - - . 15 All wells_within 114_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - _ _ _ - _ _ _ _ _ , _ _ _ - _ _ _ _ _ - _ 16 Pre-produced injector, duration-of pre production less_ than 3 months. (For service well- only) . - NA- - - - - - - - - - - - - - - - 17 ACMP-Finding of Consistency_hasbeenissued_forthisproject- --------- -------- NA_-__-__ l)rilledfrom existing pad_-__.-____-__--_,_____.-_.__.__._____-_.-._.-_ Engineering 18 Conductor string-P-rovided ~ - Yes - - - 19 Surface casing_protectsallkn4wnUSDWs____._._____._ _.__.__-_ NA_._-_.- Allaquifers exempted, 40CFR_147.102_(b)(3).____-_,.__ ______ ____________ ___-_ 20 CMT-vol_adequate-to circulate_onconductor-&surf-csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ Yes . - _ _ _ . - _ _ _ . _ - - _ .. _ 21 CMT-vol adequate_to tie-in long string tosurf csg_ - - - - _ - - .. _ N_A_ - 8-112" hole section is_ planned to be plugged.- Well proposed to be suspended._ - - 22 CMT-will cover all known-productivehorizon_s_-___-----.________ _________Yes_-__-__ -__.__--__-.____-_ ._-_______-___ ._ 23 Casing designs adequate for C, T,6&-permafrost------------------ ---- - --Yes-----.- -------,--_-------- -._--------------,--------------------- 24 Adequate tankage-or reserve pit - - - _ -Yes .. Rig is_equipped with steel-pits. No r_eserve_pitplanned. All waste to-approved disposal wells. 25 Ifa-re-drill,has-a-1.0-403 forabandonmenibeenaRproved__- _-______ .-_-_____ NA___-_-_ _--_-____.____ _________________________.-_ _.______ .__.__.._ 26 Adequate wellbore separationproposed _ __ _ _ _ _ _ _ __ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ . _ Proximity analysis perf_o[med. Traveling cylinder path calculated, Gyros possible, _ _ - _ _ - . _ _ _ _ _ - - - _ - _ 27 If_diverterlequired, does it meet regulations- _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ - _ - _ _ _ .Yes _ _ _ _ . _ _ . _ _ . Appr Date 28 Drilling fluid_prQgram schematic & equip list adequate_ - Yes - _ - - . Maximum expect formation pressure 8.6 EMW. _MWplanned up to 9.5 ppg, TEM 10!2512005 2g BOPES, do they meet regulation _ _ _ - _ . _ Yes _ 3K confguration proposed with-1. set VBRS and 1 setfixed DP rams, , _ 30 BOPE_press rating appropriate; test to-(pu_t psig in comments)- - Yes - - MASP calculated at 1152 psi, 3000-psi_BOP testproposed_ - - _ - - , - 31 _C_hcke_manifoldcomplieswlAPI_RP-53 (May 84)____________ _____ __--_. _Yes.__-__- - .____-__-_-_- 32 Work will occur without operation shutdown.__.___--_--_-__-___ -__.__ .Yes-__-_- _--_-____-__________________________________..__ _-___-____._____ 33 Is presence-ofH2Sgas_probable__ .-_--__________________ -._..__-_ No_-__- _- WS hasnot.beenactive_at1Qpad._-____.__-____.- 34 Mechanical_conditionofwellswithinAORyerifiedGFo[servicewellonly)_--_- -___--._NA________ _________________________________________-._---_---.-___.__.-_.- Geology 35 --- Permit_can be issued w/o hydrogen sulfide measures . _ Yes - - - - - - West Sak pool has not been produced or_received injection at 1Q-Pad. 36 Data-presented on potential overpressurezones_ _ _ . - - - Yes _ - - - - Expected reservoirpressure is 8,3_to 8.6ppg EMW; will be drilled with 9.2.9.5 ppg_mud. , _ _ - - Appr Date 37 Seismic-analysis of shallow gas.zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ _ - - - NA_ _ _ - _ _ - _ Twenty-one wells-h_ave been drilled from KRU 1Q-Pad.- _ _ _ _ - _ _ _ . _ _ _ . _ _ - _ - _ _ _ _ _ . _ _ - _ . SFD 10124l2005 I 38 Seabed condition surYe_y_(if off-shore) _ - NA_ _ _ - 39 -Contact namelphonefor weekly progress_reports [explorafory only]- - _ - - _ - - Yes - - _ Tam Brasfield - 907-285-6377. - _ - - _ - _ Geologic Date: Engineering Date P lic Date Mud log and cuttings waived as Ugnu No.1, located about 1.6 miles NW has a mud log and samples from 40'to 9428'. Commissioner: Commission r: C mr loner ~~~' lC~~~~ ~~ti~~ l0-~5-0 " >~ ~o z6 O ~~~ • Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History fife 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 io chronologically . organize this category of information. lq-lOl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Thu Mar 16 15:38:00 2006 Reel Header Service name .............LISTPE Date . ...................06/03/16 Ori9in ...................STS Reel Name...... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................06/03/16 Origin ...................STS Tape Name...... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW-000404666 M. HANIK P. WILSON MWD RUN 10 Mw-000404666 SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRYCK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE • ~13~~~ scientific Technical services scientific Technical Services 1Q-101 500292328200 ConocoPhillips Alaska, Inc. Sperry Sun 16-MAR-06 MWD RUN 2 MWD RUN 3 Mw-000404666 Mw-000404666 T. MCGUIRE T. MCGUIRE PETE WILSON PETE WILSON 26 12N 9E 1574 1161 .00 81.80 52.00 CASING DRYLLERS Page 1 ~~s~s~ • lq-lOl.tapx BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 20.000 115.0 2ND STRING 13.500 20.000 115.0 3RD STRING 8.500 10.750 1823.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS AND REFERENCE MEASURED DEPTH (MD)UNLESS OTHERWISE NOTED. 2. MWD RUNS 1&2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. MWD RUN 3 IS DIRECTIONAL WITH DGR, EWR-4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND AZIMUTHAL LITHO-DENSITY (ALD). FAILURE OF THE ACOUSTIC CALIPER (ACAL) TOOL (INCORPORATED IN THE CTN) RESULTED IN USE OF THE ALD HOLE SIZE INDICATOR FOR PROCESSING CTN DATA. AREAS OF ALD NON-ROTATION USE A FALL-BACK VALUE OF BIT SIZE (8.5") FOR CTN PROCESS- ING. 4. VERTICAL RESISTVITY ENHANCEMENT (VRE) PROCESSING WAS PERFORMED ON RESISTIVITY DATA FROM 3700'MD TO 4954'MD, AND OUTPUT IS PRESENTED AS MWD RUN 99. 5. MWD DATA IS CONSIDERED PDC PER E-MAIL FROM M. WERNER OF CONOCOPHILLIPS ALASKA, INC. TO R. KALISH OF SPERRY DRILLING SERVICES DATED 1/05/06. 6. MWD RUNS 1-3 REPRESENT WELL 1Q-101 WITH API#: 50-029-23282-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5000'MD, 3724'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (EWR). TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SS MATRIX, VARIABLE HOLE (SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATE (NEUTRON). CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). VEXP = SMOOTHED INVERSION MODELING-ENHANCED PHASE RESISTIVITY (XS SPACING). VESP = SMOOTHED INVERSION MODELING-ENHANCED PHASE Page 2 lq-lOl.tapx RESISTIVITY (S SPACING). VEMP = SMOOTHED INVERSION MODELING-ENHANCED PHASE RESISTIVITY (MED SPACING). VEDP = SMOOTHED INVERSION MODELING-ENHANCED PHASE RESISTIVITY (DEEP SPACING). MEXP = SMOOTHED FORWARD-MODELED PHASE RESISTIVITY (QC CURVE) XS SPACING. MESP = SMOOTHED FORWARD-MODELED PHASE RESISTIVITY (QC CURVE) S SPACING. MEMP = SMOOTHED FORWARD-MODELED PHASE RESISTIVITY (QC CURVE) MED SPACING. MEDP = SMOOTHED FORWARD-MODELED PHASE RESISTIVITY (QC CURVE) DEEP SPACING. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RoP 120.5 5000.0 RPx 167.0 4955.5 RPS 167.0 4955.5 FET 167.0 4955.5 RPD 167.0 4955.5 RPM 167.0 4955.5 GR 174.5 4963.5 NPHI 1735.5 4904.5 NCNT 1735.5 4904.5 FCNT 1735.5 4904.5 PEF 1744.5 4917.5 DRHO 1744.5 4917.5 RHOB 1744.5 4917.5 RDVR 3700.0 4954.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 1 120.5 1298.0 2 1298.0 1831.0 3 1831.0 5000.0 10 3700.0 4954.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Page 3 1q-lOl.tapx optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HRS 4 1 68 28 8 NPHI MWD PU 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD G/CM 4 1 68 52 14 VEXP MWD OHMM 4 1 68 56 15 First Last Name Servi ce Unit Min Mdx Mean Nsam Reading Reading DEPT FT 120.5 5000 2560.25 9760 120.5 5000 ROP MWD FT/H 0 1518.06 151.793 9760 120.5 5000 GR MWD API 17.33 142.78 72.9888 9579 174.5 4963.5 RPX MWD OHMM 1.16 1657.9 15.8155 9498 167 4955.5 RPS MwD OHMM 0.78 1828.24 24.2024 9498 167 4955.5 RPM MWD OHMM 0.39 2000 38.7193 9498 167 4955.5 RPD MWD OHMM 0.3 2000 50.4808 9498 167 4955.5 FET MWD HRS 0.1 103.11 1.06374 9498 167 4955.5 NPHI MWD Pu 13.664 91.0053 40.6149 6339 1735.5 4904.5 FCNT MwD CNTS 448 2254 820.224 6339 1735.5 4904.5 NCNT MWD CNTS 102005 179539 128585 6339 1735.5 4904.5 RHOB MwD G/cM 0.691 2.709 2.12726 6347 1744.5 4917.5 DRHO MWD G/CM -2.976 0.338 0.0206165 6347 1744.5 4917.5 PEF MWD G/CM -0.2 13.41 2.1305 6347 1744.5 4917.5 VEXP MWD OHMM 2.28 39.072 7.14281 2509 3700 4954 First Reading For Entire File..........120.5 Last Reading For Entire File...........5000 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI6.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Type ................LO Page 4 • • lq-lOl.tapx Previous File Name.......sTSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 120.5 1298.0 RPM 167.0 1249.0 FET 167.0 1249.0 RPD 167.0 1249.0 RPX 167.0 1249.0 RPS 167.0 1249.0 GR 174.5 1257.0 LOG HEADER DATA DATE LOGGED: 16-Nov-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 1298.0 TOP LOG INTERVAL (FT): 120.0 BOTTOM LOG INTERVAL (FT): 1298.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: 12.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 EWR4 ELECTROMAG. RESIS. 4 59672 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 115.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD vlscoslTY (s): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Native/Spud Mud 9.50 120.0 9.2 400 .0 3.700 68.0 3.802 66.0 2.800 68.0 5.300 68.0 Data Format specification Record Page 5 • lq-lOl.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ...........,60 .lIN Max frames per record .............Undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel • DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 GR MWDO10 API 4 1 68 8 3 RPX MWDO10 oHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWDO10 OHMM 4 1 68 20 6 RPD MWDO10 OHMM 4 1 68 24 7 FET MWDO10 HRS 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 120.5 1298 709.25 2356 120.5 1298 ROP MWDO10 FT/H 9.04 1518.06 185.101 2356 120.5 1298 GR MWDO10 API 24.5 111.85 63.5878 2166 174.5 1257 RPX MWDO10 OHMM 1.16 99.2 27.774 2165 167 1249 RPS MWDO10 OHMM 0.78 462.1 50.9145 2165 167 1249 RPM MWDO10 OHMM 0.66 2000 102.804 2165 167 1249 RPD MWDO10 OHMM 0.39 2000 145.785 2165 167 1249 FET MWDO10 HRS 0.1 5.5 1.06568 2165 167 1249 First Reading For Entire File..........120.5 Last Reading For Entire File...........1298 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Typpe ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: Z DEPTH INCREMENT: .5000 FILE SUMMARY Page 6 • lq-lOl.tapx VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 1249.5 1782.5 FET 1249.5 1782.5 RPS 1249.5 1782.5 RPX 1249.5 1782,5 RPM 1249.5 1782.5 GR 1257.5 1790.0 RoP 1297.0 1831.0 LOG HEADER DATA DATE LOGGED: 17-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 1831.0 TOP LOG INTERVAL (FT): 1298.0 BOTTOM LOG INTERVAL (FT): 1831.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 13.8 MAXIMUM ANGLE: 35.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 EWR4 ELECTROMAG. RESIS. 4 59672 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 13.500 DRILLER'S CASING DEPTH (FT): 115.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 144.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.700 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.322 76.5 MUD FILTRATE AT MT: 2.100 68.0 MUD CAKE AT MT: 4.100 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units ......... .. ... ..... Datum specification Block sub-type...0 Page 7 • lq-lOl.tapx Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPx MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MwD020 oHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HRS 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1249.5 1831 1540.25 1164 1249.5 1831 ROP MWD020 FT/H 0 255.18 118.917 1069 1297 1831 GR MWD020 API 17.33 107.03 67.2362 1066 1257.5 1790 RPx MWD020 OHMM 7.52 93.4 24.2211 1067 1249.5 1782.5 RPS MWD020 OHMM 7.81 260.46 36.3849 1067 1249.5 1782.5 RPM MWD020 OHMM 7.85 513.24 52.0223 1067 1249.5 1782.5 RPD MWD020 OHMM 8.89 636.43 57.2335 1067 1249.5 1782.5 FET MWD020 HRS 0.4 7.88 1.72452 1067 1249.5 1782.5 First Reading For Entire File..........1249.5 Last Reading For Entire File...........1831 File Trailer Service name... .......STSL2B.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Type .. .............Lo Previous File Name.......sTSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY 4 header data for each bit run in separate files. 3 .5000 VENDOR TOOL CODE NCNT FCNT NPHI RHOB DRHO PEF GR RPM FET RPD START DEPTH 1735.5 1735.5 1735.5 1744.5 1744.5 1744.5 1793.0 1823.0 1823.0 1823.0 STOP DEPTH 4904.5 4904.5 4904.5 4917.5 4917.5 4917.5 4963.5 4955.5 4955.5 4955.5 Page • 1q-101.tapx RPX 1823.0 4955.5 RPS 1823.0 4955.5 OP 1830.5 5000.0 $ LOG HEADER DATA DATE LOGGED: 23-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5000.0 TOP LOG INTERVAL (FT): 1831.0 BOTTOM LOG INTERVAL (FT): 5000.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 37.6 MAXIMUM ANGLE: 58.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 216787 CTN COMP THERMAL NEUTRON 1844674407370955 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Po~nt ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units ......... .. ... ..... Datum Specification Block sub-type...0 8.500 1823.0 Fresh water Gel 9.25 48.0 9.4 18500 .0 .300 78.0 .240 99.0 .200 78.0 .330 78.0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RoP MWD030 FT/H 4 1 68 4 2 GR Mwo030 API 4 1 68 8 3 Page 9 lq-lOl.tapx RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MwD030 HRS 4 1 68 28 8 NPHI MWD030 Pu 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MwD030 CNTS 4 1 68 40 11 RHO6 MwD030 G/cM 4 1 68 44 12 DRHO MwD030 G/CM 4 1 68 48 13 PEF MWD030 G/CM 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1735.5 5000 3367.75 6530 1735.5 5000 ROP MWD030 FT/H 0.7 1462.23 144.896 6340 1830.5 5000 GR MWD030 API 21.2 142.78 77.1973 6342 1793 4963.5 RPX MWD030 OHMM 1.17 1657.9 10.2523 6266 1823 4955.5 RPS MWD030 OHMM 1.27 1828.24 12.8984 6266 1823 4955.5 RPM MWD030 OHMM 0.39 1866.67 14.3118 6266 1823 4955.5 RPD MwD030 OHMM 0.3 2000 16.4019 6266 1823 4955.5 FET MwD030 HRS 0.2 103.11 0.950544 6266 1823 4955.5 NPHI MWD030 Pu 15.11 97.53 40.6203 6339 1735.5 4904.5 FCNT MWD030 CNTS 448 2254 820.224 6339 1735.5 4904.5 NCNT MWD030 CNTS 102005 179539 128585 6339 1735.5 4904.5 RHOB MWD030 G/CM 0.691 2.709 2.12726 6347 1744.5 4917.5 DRHO MWD030 G/CM -2.976 0.338 0.0206165 6347 1744.5 4917.5 PEF MwD030 G/CM -0.2 13.41 2.1305 6347 1744.5 4917.5 First Reading For Entire File..........1735.5 Last Reading For Entire File...........5000 File Trailer Service name... .......STSLI6.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MEXP 3700.0 4954.0 vEXP 3700.0 4954.0 Page 10 • • 1q-101.tapx VESP 3700.0 4954.0 VEMP 3700.0 4954.0 VEDP 3700.0 4954.0 MESP 3700.0 4954.0 MEMP 3700.0 4954.0 MEDP 3700.0 4954.0 LOG HEADER DATA DATE LOGGED: 15-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: EWR Programs DOWNHOLE SOFTWARE VERSION: VRE DATA TYPE (MEMORY OR REAL-TIME): Post-Prot TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 13.500 DRILLER'S CASING DEPTH (FT): 1823.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): .00 MUD VISCOSITY (S): .0 MUD PH: .O MUD CHLORIDES (PPM): 0 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 vExP MWD099 OHMM 4 1 68 4 2 VESP MWD099 OHMM 4 1 68 8 3 Page 11 ~: • lq-lOl.t x VEMP MWD099 OHMM 4 1 68 l2 4 VEDP MWD099 OHMM 4 1 68 16 5 MEXP MWD099 OHMM 4 1 68 20 6 MESP MWD099 OHMM 4 1 68 24 7 MEMP MWD099 OHMM 4 1 68 28 8 MEDP MWD099 OHMM 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3700 4954 4327 2509 3700 4954 VEXP MWD099 OHMM 2.28 39.072 7.14281 2509 3700 4954 VESP MWD099 OHMM 2.29 131.205 8.813 2509 3700 4954 VEMP MWD099 OHMM 2.546 127.469 9.33752 2509 3700 4954 VEDP MWD099 OHMM 2.7 167.955 10.0069 2509 3700 4954 MEXP MWD099 OHMM 2.413 36.124 7.00618 2509 3700 4954 MESP MWD099 OHMM 2.515 89.157 8.44107 2509 3700 4954 MEMP MWD099 OHMM 2.857 99.794 8.86724 2509 3700 4954 MEDP MWD099 OHMM 3.077 99.576 9.35545 2509 3700 4954 First Reading For Entire File..........3700 Last Reading For Entire File...........4954 File Trailer Service name... .......STSLIB.005 Service SUb LeVel,Name... version Number. ........1.0.0 Date of Generation.......06/03/16 Maximum Physical Record..65535 File Type ................LO Next Flle Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................06/03/16 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comment5 .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date . ...................06/03/16 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 12 • lq-lOl.tapx gage 13 r ConocoPhillips Alaska, Inc FINAL WELL EPORT MUDLOGGIN DATA .~ .~~ 1Q-101 ~ . A~ e,~~ 2~s- iS~ ,.: _ _ . __ - ~ ~ _y..._,~.... ..__~_. t. aw..~ ! ~r'„I r.~.~ .. t tys .-.?a .::;~~ . ~ ~ 3~'..7 t.F.¢"~ ' ,~~ ' ,'~`,3'{,.~"4~+~c!'`. Provided by: T _ ~ Compiled by: Brian O'Fallon Fletcher England Date: 11 /28/05 • ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA 1 Q-101 C, Provided by: [~ EPOCH Approved by: Bryn Clark Compiled by: Brian O'Fallon Fletcher England Date: 11 /28!05 Distribution: ~: ~~~~~~~ 1Q-101 • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT &CREW ..................................•---•-----------------------------------------......-------•--•-•-2 1.1 Equipment Summary ........................................................................................................................... ..2 1.2 Crew ...................................................................................................................................................... ..2 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 ................................................................................................................................. ..6 3.3 Gas Samples ........................................................................................................................................ 13 3.4 Connection Gases ................................................................................................................................ 13 3.5 Sampling Program /Sample Dispatch ...........................................................................•---------........... 14 4 PRESSURE /FORMATION STRENGTH DATA ..................................................................................... 15 4.1 Formation Integrity/Leak Off Tests ...................................................................................................... 15 4.2 Wireline Formation Tests ..................................................................................................................... 15 4.3 Pore Pressure Evaluation Introduction -•----•---••-•---•--.....--•-•------•-• ......................................................... 15 4.4 Pore Pressure Evaluation Conclusions ............................................................................................... 16 • 4.5 Pore pressure evaluation ..................................................................................................................... 20 5 DRILLING DATA ....................................................................................................................................... 21 5.1 Survey Data .................................................•--------•-------•-•------............................................................... 21 5.2 Bit Record ...........................................................................................•--•-•-•--------••-•-------------................. 24 5.3 Mud Record .......................................................................................................................................... 25 6 MORNING REPORTS .............................................................................................................................. 26 Enclosures 2"/100' Formation Log (MD) 2"/100' Drilling Dynamics Log 2"/100' Gas Ratio Log 2"/100' LWD / Lithology Log LJ ~~~~~ 1 ~i~I'lOCO~'1i~~1~S 1 Q-101 MUDLOGGING EQUIPMENT & CREW 1.1 Eauipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 WITS feed to QUADCO 1831'-TD No gas readings only when flow diverted from possum belly. Gas values over 250 units misre resented on RW* Effective Circulatin Dens' ECD From S err -Sun 0 Be in ECD data after FIT: 1851'-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 O tical encoder on draw-works 0 No problems, no missing data 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 collectionldistribution 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 S ud-912' Download 456-1830', WITS 1831'-TD Pit Volumes, Pit Gain/Loss From QUADCO S ud-912' Download 456-1830', WITS 1831'-TD Pum Pressure From QUADCO S ud-912' Download 456-1830', WITS 1831'-Tp RPM From QUADCO S ud-912' Download 456-1830' WITS 1831'-TD Tor ue From QUADCO S ud-912' Download 456-1830' WITS 1831'-TD QUADCO computer was placed online in Epoch unit during drilling of the surface hole, after IP phone installation in Epoch Unit. WITS communication between QUADCO and Epoch Rigwatch Computer was subsequently setup after surface. Surface data was therefore downloaded from the QUADCO computer. The QUADCO system had begun recording data beginning from 456' but most sensors appeared to be online for data acquisition beginning at 912'. QUADCO data for the remaining footage for the surface hole, from 912' to 1830', is also suspect as depth was not accurately recorded and it was necessary to adjust data to actual slides and rotated footage. Epoch WITS output to QUADCO included ditch gas only, and input from QUADCO included flow out, total mud volume and seven pit volumes including trip tank, gain-loss, pump pressure, and top drive rpm and torque. ECD data was acquired from Sperry Sun and utilized to generate pore pressure charts and estimate pore pressure. Pore pressure is evaluated in section 4 of this report. Sperry Sun did not measure ECD forthe surface hole. ~ EPC)CH • • • ~O('i'1l~~IpS 1 Q-101 *Gas values over 250 units recorded on Rigwatch while drilling the well were later changed to correlate with data recorded from the Total Gas Analyzer (THA). The voltage output from the THA to the DAC box computer, from which the Rigwatch computer received data, was 0-10 volts. The DAC computer suppressed voltage over 2.5 volts. The problem did not occur until the last day of drilling when gas readings over 250 units were first encountered. The solution to the problem was to change to a voltage output of 0-1 volts from the THA. [~ ~PCJC;H 3 • • • Gcxto~iPhitip5 1 Q-101 1.2 Crew Unit Type Arctic Series 10 Skid Unit Number ~ ML012 Mudloggers Years Da~s Sample Catchers Years Days Technician Days Trainees Days Brian O'Fallon 18 9 Jeff Porcianko <1 9 Howard Lam 4 Fletcher En land 5 9 Todd Baham 2 5 'Years experience as Mudlogger .2 Days at wellsite between spud and total depth of well Additional Comments Technician required to work on DAC box EPOCH 4 • • • ~Of'1O1~O~'11~~IP5 1 Q-101 • 2 WELL DETAILS 2.1 Well Summary • • Well: 1 Q-101 API Mdex ~: 029-23282-00 fie d: West Sak Surface Co-0rdinates: Lat: 70d-22'-4.42"N Long: 149d46'18.56"W SEC 24 T12N R9E 1574' FNL 1161' FWL Borough: North Slope Primary Target Depth: 4154' MD State: Alaska TD Depth: 5000' MD (3724'TVD) Rig Name /Type: Nordic Carta #3 /Arctic Triple Suspension Date: None Primary Target: West Sak "D" and "B" License: Spud Date: 11115105 Ground Elevatwn: 52' Completion Date: 11/28/05 RT Elevation: 81.8' Completion Status: Cement Plug Secondary Target Depth: Ugnu C: 2983'MD Classification: ExQloration TD Date: 11!23/05 TD Formation: Colville Days Testing: NONE Days Drilling: 9 2.2 Hole Data Maximum De Mud Shoe th FIT Hole Section MD ft TVDSS ft TD Formation Weight IPP9 Deviation ~°i~~ Coring Casingt Liner MAD TVDSS tpP9) Conductor 122 -~ Colville Gr NA 0 -- 20" - - NA 131!2' 1830 -1669 Colville Gr 9.5-9,8 36.93 10'/." 1823 -1664 12.4 8 1@" 5000 -3642 Colville Gr 9.2-9.4 45.12 - NA NA NA NA AdditionaF Comments A 13 %" surtace hole was directionally drilled to 1830' with 9.5-9.8 spud mud. Due to concern about not building enough angle, it was decided ~ 1297' to pull out of the hole and increase the bend in the mud motor and re-orient same. Further drilling and sliding resulted in too much angle being built- The solution was to backream several stands as needed to wipe out any excess dogleg. Wiper trips and the surtace cement job went smoothly. The 8'/z" hole section was drilled to 5000' with no significant problems. Severa{ brief slides were necessary for directional hale. The section was drilled without requiring any wiper trips, althcugh each stand was back reamed prior to each connection. Mud weight was maintained between 9.2 to 9.4, and no connection gases were recorded. Logging was commenced after a wiper trip, and tools went to bottom without problems. Three logging runs were performed, a combo run, a drill pipe conveyed pressure run, and a side wall coring run. A second wiper trip was performed after the drill pipe conveyed run. Wiper gases were 324 units prior to logging, and 589 units afterthe drll pipe conveyed log. Trip gas prior to plugging the well was only 50 units. ~:Pn~,u 5 ~tlt'IOCQ~'i1M~1~]S 1 Q-101 • 3 GEOLOGICAL DATA C] 3.1 Lithostratis~raphv Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geologist. PROGNOSED ACTUAL WIRELINE PICK HIGH/LOW FORMATION MDRT ft TVDSS ft MDRT ft TVDSS ft (ft) Permafrost - - - - Surface T3 NA -1316 1402 -1300 +16 Base Permafrost 1665 -1514 1671 -1538 -24 Casing Point 1886 -1701 1830 -1670 +31 Ugnu C 2888 -2359 2983 -2399 -40 Ugnu B 3471 -2683 3485 -2683 0 K13 Marker 3943 -2946 3917 -2927 +19 West Sak D Sand 4133 -3066 4154 -3074 -8 West Sak C Shaie NA NA 4240 -3131 NA West Sak B Sand 4247 -3139 4275 -3153 -14 West Sak A4 Sand NA NA 4321 -3183 NA West Sak A3 Sand 4385 -3228 4397 -3233 -5 West Sak A2 Sand 4511 -3532 4523 -3315 -28 West Sak Al Sand NA NA 4711 -3441 NA Base West Sak 4858 -3532 4883 -3560 -28 TD 4955 -3594 5000 -3642 +52 CtN"tOrC0~11~~1~15 1 Q-101 • 3.2 Mudlog Summary Permafrost to T3 First Returns 115' to 1402' MD (-33' to -1300' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 1620 15.2 191 23 0 3.4 The permafrost zone above the T3 is characterized by massive conglomerate and conglomeratic sand at the surface down to 300', and interbedded sand, siltstone, claystone, and conglomerate, and some minor coal and volcanic tuff, 300'-1402'. The relative percentage of pebbles and granules in the sands decreases gradually with depth from approximately 1070' to the T3 marker. The composfion of the sands were largely derived from metamorphics, including quartz, predominant in the finer fractions, and dark brown to dark gray to amber to gray and minor green and red silicate grains, predominant in the coarse, pebble, and granule fraction. Pebbles and granules are commonly 5-20 mm up to 30 mm in length or diameter. Pyrite coats many of the grains, especially the coarser fraction and is locally common as loose clusters. "Woody" plant and other organic clasts and matter are common as well. The relative amounts of the pyrite and organic matter peaks to as much as 10% each in the samples between 360' and 450', and then variably decreases to slulht amounts above the T3. Clays or claystone was brownish gray to gray, sometimes silty grading to siltstone, and with trace to slight amounts of organic fines and matter. Clays were interbedded or grading to, and as a matrix in, sands and conglomerates. • Alight brown aphanitic tuff was observed in the 1140-1200' sample, very distinctive and over 10% of the sample. Fragments were hard but moderately soluble, and it believed that the tuff was bedded rather than a constituent of a conglomerate. T3 to Casing Point 1402' to 1830' MD -1300' to -1670' TVDSS Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 273 16.5 130 42 1 11.8 The base of the Permafrost is included in this section and was encountered at an estimated 1671'MD, as lower resistivity in sands below this point probably reflects a transition from ice to water (Section 4.4 : Pore Pressure Evaluation Conclusions). Casing point was selected 370' below the T3, in ant~ipation of a dayey interval (below the permafrost), but with casing tally the more prevailing factor. This section included interbedded sand, claystone, some conglomerate, and some coal. Sands were noticeably less conglomeratic than overlying sands and pyrite had diminished to only traces. Composfions were similar other than 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 some organic claystone associated with the coals. The coal, lignite grading to a 'woody' peat and carbonaceous shale (organic claywith carbonaceous partings), occurred between 1690 and 1780'. EPOCH 7 ~~'11~fIpS'i 1Q-101 • Surface Casing to top Ugnu C 1830' to 2983' MD f-1670' to -2399' TVDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 321 11.3 142 29 0.5 10.6 The interval includes mostly sand, some conglomeratic, and some interbedded siltstone and shale. 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 mostlysubangularto angular. Some coarse grains and pebbles were rounded. Sorting varied from well sorted with slight clay matruc and grains dominantly in the medium to coarse range, to moderately and poorly sorted with increased matrix and grading to sittstone, claystone, or conglomerate. Samples from 1920' to 2040' were very conglomeratic. Composition was 405°l0 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 choritization in part), black, amber to brown, and minor red. Traces of `woody' matter and locally minor coal clasts or thinly bedded coal were also noted. Locally minor calcite, and minor hard silica cemented fine to medium grain supported sandstone, were noted. claystone was mostly medium gray to medium light gray, some with brownish hues as slightly organic, to locally very organic and grading carbonaceous shale. Textures were slightly silty 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 2740 to 2850' claystone often graded to organic claystone and carbonaceous shale, with some minor coal at the base of this interval. Siltstone was overall less organic than claystone, 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 top Ugnu B 2983' to 3485' MD f-2399' to -2683' TVDSSI Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maxmum Minimum Avera e 208 23.2 152 134 0 27.2 This section includes sand, conglomeratic sand and conglomerate, claystone, siltstone, some carbonaceous shale and coal, and minor ash fall tuff. Sands were medium gray to light gray,. fine to coarse grained, especially medium, with slighfly scattered pebbles in the Ugnu °C°, a few more pebbles after 3170', and mostly conglomeratic sometimes grading to conglomerate after 3330' to just above a coal at 3420'. 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 matrix and grading to siltstone, claystone, and conglomerate. Composition 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. claystone and siltstone were light gray to white to medium gray, some slightly organic with brownish hues, to locally variabty organic and grading grayish brown organic claystone and carbonaceous shale. Tracesto slight mica silts and fines contributed to a slightly sparkly luster overall, to sometimesvelveiy luster in siltstone.Traces • to slight carbonaceous silts and fines prevailed throughout, to occasional flakes and partings, especially in ~~~~~ 8 ~~I~~I~ 1Q-101 • 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 siltstone. Two coals were noted, a possible thin zone at 3170', and a prominent coal between 3420 and 3450'. The lower coal was a brownish black to dusky brown, lignite to subbitiminous, and often with organic rich clay partings and grading to carbonaceous shale. Top Ugnu B to K13 Marker 3485' to 3917' MD (-2683' to -2927' NDSS) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 221 21.0 157 103 2 53.7 This interval included sand, some conglomeratic, siltstone, claystone, and minor carbonaceous shale, with sand prevailing from the top of the Ugnu "B" to 3580', and interedded claystone, siltstone, and generally poorly sorted sands down to the K13 Marker. The upper "Ugnu B" sands were medium gray overall, with fine to coarse lower grains, especally medium, and scattered coarse fragments and grains. Grains were subangular to angular, well to moderately sorted, and mostly grain supported in a light gray to white clay matrix. Composition of the grains included 55% clear to translucent quartz, and 45% gray to amber to brown to dark gray to black to green silicates (including chert), siliceous lithics, and trace coal lithics. The lower sands were medium dark gray to brownish gray overall, with medium upper to very fine grains, and • scattered coarse grains and fragments to trace granules. Sands are moderately well sorted, with dominantly fine to medium lower grains in a slight clay matroc, to poory sorted and grading claystone, siltstone, or conglomerate. Composition of the grains is similar to the upper sands. claystone and siltstone was light gray to medium gray some with faint brownish hues interbedded with the upper sands. The lower section was generally more organic and often light brownish gray to brownish gray. Some incipient fissilty in siltstone but rare in claystone. Again, slight carbonaceous and trace mica fines and sills were prevalent throughout, with locally increasing carbonaceous matter and organic clay content to grading carbonaceous shale. Occasional firm calcareous siltstone was noted. K13 Marker to West Sak D Sand 3917' to 4154' MD -2927' to -3074' NDSS Drill Rate fti'hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 266 19.9 137 177 14 36.5 This was a very clayey section and included claystone, siltstone, some sand, possibly conglomeratic in part, and minor carbonaceous shale. Minor amount of pebbles and granules were possibly slough from above. The claystone was brownish gray to light gray to medium gray, mostly soluble and soft in sample with some incipient fissilty on slightly firm pieces with structure preserved. Slight carbonaceous sits and fines and trace to slight micas continued through this section. Commonly grades to siltstone and very fine to fine grained sandstone or sand, with occasional thin beds of carbonaceous shale. The sample from 3930 to 3960 contained abundant shell fragments. • [~ EPOCH 9 ~~~~~~~ 1Q-101 r~ • West Sak D Sand to West Sak C Shale 4154' to 4240' MD (-3074' to -3131' NDSS} Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 212 35.4 161 657 93 333 The first West Sak sand was readily identified by an abrupt gas show exhibiting heavy hydrocarbons, while above it was logged only minor methane gas with beginning traces of ethane. The West Sak "D"was brownish gray to medium gray overall, fine upper to very fine lower grains and scattered medium lower, subangular to subrounded, well sorted, grain supported, and friable with a slight clay and silt matruc, to gradationally poorly sorted with increasing silt and clay matrix, while occasionally grading to sittstone or claystone. Traces of sandstone were firm with a calcareous clay matruc, and specks and partings of organic matter oriented along laminar contacts was 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 chloritization. Porosity appears to be fair to poor, but typical of oil producing West Sak Sands. The samples had a strong odor and abundant droplets and dispersions of thick amber brown free oil in the samples. Fluorescence is 100% dull gold to orange-yellow, with a slow dull gold to dull yellow thin streaming cut. West Sak C Shale to West Sak B Sand 4240' to 4275' MD (-3131' to -3153' TVDSS} Drill Rate ftJhr Total Gas units Maximum Minimum Avera a Mabmum Minimum Avera e 186 39.7 135 125 39 78.4 The West Sak "D" fines downward to the West Sak "C" Shale, a 35' variably silty claystone and mudstone interval above the West Sak "B". West Sak B Sand to West Sak A4 4275' to 4321' MD (-3153' to -3183' TVDSS} Drill Rate ft/hr Total Gas units Mabmum Minimum Avera a Maximum Minimum Avera e 175 33.3 155 605 68 412 The West Sak "B" is brownish gray to medium gray overall, fine upper to very fine lower and scattered medium lower grains, subangular to subrounded,moderately well to well sorted, mostly grain supported, and friable with a clay and silt matrix, overall fining downward with interbedded siltstone and claystone. Composition and other characteristics are similar to the West Sack "D". The samples had a strong odor with abundant free oil droplets and dispersions,100% otlfluorescence which was overall brighter than the "D", in part due to an increased oil contamination of the mud. Cut was a fast streaming from loose sand to a slow ooze on consolidated pieces. West Sak A4 to West Sak A2 4321' to_4523' MD (-3183'_to -3315'_TVDSS} Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 325 27.8 156 392 62 195 This section combines the West Sak A4 and West Sak A3 as both intervals are similar. This section includes • intebedded siltstone, claystone, and sand. The A4 and A3 sands are moderately to poorly sorted with a day and ~;l'4CH 10 ~+O~CO~11~~1~5 1 Q-101 silt matrix and poor estimated porosity, developed primarily over the intervals 4356-4375' for the A3,and 4465- 4475' for the A2, as is indicated by minor show gas and slight increased resistivity. The character and composition of the grains remains similar to the "D° and °B" sands except overall finer grains and increased matroc. Sample fluorescence remains high but diminishing after the base 4fthe West Sak B, although noticeably higher relative to higher gas. claystone and siltstone are brownish gray to light brownish gray with medium gray to light gray and off white 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. Sl~ht 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. Rare grades to carbonaceous shale. Some greasy luster in lighter colored claystone could indicate was tuffaceous and derived in part from ash fall tuff. West Sak A2 Sand to West Sak Al Sand 4523' to 4711' MD (-3315' to -3441' TVDSS) Drift Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 256 29.5 105 318 105 184 The section continues as with the overlying interval with siltstone and claystone occasionally grading to or with thin beds and laminations of poorly developed very fine to fine grained sand. The character of the claystone and siltstone remains similar to the above interval. The top of the interval, the West Sak A2 Sand, has some of the better developed of the poorly developed sands, and minor show gas and slight resistivity increases persist from 4528' to 4635', with perhaps the best sand at 4555-4565'. Sample fluorescence diminishes with depth but remains at about 20% of the sample at the base of the interval. A tight gray to white ash fall tuff at the base of this interval is easily identified in samples with its bright yellow mineral fluorescence and mostly greasy luster. The light gray color appeared to be from some clay contamination, and the texture was often silty to grainy from primarily quartz grains. West Sak Al Sand to Base West Sak 4711' to 4883' MD -3441' to -3560' NDSS Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maxmum Minimum Avera e 268 22.1 170 611 86 180 This is a very silty interval often grading to very fine grained sand or silty claystone. The base of the West Sak appeared to be a well developed medium to fine grained sand in samples, a conclusion supported by high show gas and sample fluorescence, but not supported by high gamma and disappointing resistivity. Perhaps the sand was largely matrix supported and the clays washed out in samples. The siltstone and very fine grained sandstone was medium gray to light gray to brownish gray, soft to friable, very clayey, mostly coarse silt and scattered very fine sand grains, to mostly very fine to fine sand grains. The sands typically had a light gray clay matrix, while the siltstone had a light gray to light brown clay matrix due weathering of organics. Silt grains included mostly quartz and minor dark gray to dark brown to green silicates and carbonaceous silts. Sand grains included 75% quartz, and 25% brown to black to green to gray grains of mostly silicates and some carbonaceous fines. Samples had 20-40% dull to moderate orange yellowto yellow fluorescence, an instantaneous cut on sand grains, to slow streaming to slow blooming cut with clay matrix. The basal sand, from 4855' to 4883', was medium light gray, with medium to fine, subangular to subrounded grains, especially medium lowerto fine upper. Grain composition remained similarto othersandsasdescribed in the paragraph above. Samples had a slight odor, and 80°lo even, dull to moderately dull yellow fluorescence ~~~~H 11 C+~oaoPhilli~s ~ Q-~ o~ . on unconsolidated sand, with an instantaneous milky yellow cut. Traces of oil stain were observed on some sandy clays with yellowy fluorescence and a slow streaming cut. Base West Sak to TD 4883' to 5000' MD (-3560' to -3642' TVDSS) Drill Rate fflhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 216 15.9 170 614 91 215 Another show sand of similar character and composition to the basal West Sak occurred from 4920930', but with increasing angular grains, and is associated with some hard calcareous sandstone with angular grains, and white grainy calcareous tuff with angular grains and angular pebbles of quartz. The 4890'-4920' sample had only 20°!o fluorescence, while the 4920'950' sample had 80°~ fluorescence on mostly unconsolidated sarxis, same fluorescence and cut as the basal West Sak sand above. Claystone below the sand was medium gray to medium light gray, mostly with brownish hues, and s{ight{y to very silty grading to siltstone and very fine to fine clayey sand. Slight carbonaceous fines and silts prevailed throughout. Grains were mostly quartz, and some green to gray to brown to dark gray silicates. • ~ ~PC~~H 12 ~+Ot"1'tl~~f~l5 1 Q-101 • • • 3.3 Gas Samples 1 unit = 0.05% Methane Equivalent Sam le De th Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=0.05 M.E. (PPm} (PPm} (PPm} (PPm} (PPm} (PPm} (PPn-} 1 reuse NA 2 reuse NA 3 1500 6 1203 4 1754 14 2785 5 2010 16 3010 6 2257 8 1695 7 2500 6 1201 8 2769 14 2953 9 3000 19 3771 10 3250 13 2681 11 3500 100 18689 12 3751 39 6080 13 4000 23 4541 14 4178 349 59916 366 119 94 10 9 15 4251 75 14195 88 38 27 4 16 4291 600 112275 1012 572 541 233 222 65 17 4471 392 67062 764 811 586 669 430 292 18 4568 268 45766 555 644 449 620 551 280 19 4729 174 25864 313 279 243 265 342 307 20 4750 104 13256 144 158 175 234 333 340 21 4864 611 98970 1879 1367 1265 783 933 437 22 4928 614 96774 1937 1768 1403 1245 1249 792 23 4950 195 26410 421 371 336 314 342 250 24 5000 225 30391 509 388 375 328 437 399 3.4 Connection Gases 1 unit = 0.05% Methane Equivalent De th Units C1 C2 C3 C4 C5 feet m m m m m None Recorded C~ ~;PC~~H 13 COO~Ii~~~~15 1 Q-101 r~ I~ ~ U 3.5 Sampling Program /Sample Dispatch Set T e / Pu ose Fre uenc Interval Dis atched to Bayview Warehouse Unwashed Biostratigraphy 60' ' 115' -1500` MD ' ' ConocoPhilfips Alaska, Inc. ABV 100 A 30 - 5000 MD 1500 8105 Eleusis Drive Set owner: CPAI 10' Shows Anchorage. AK 99502 Attn: D. P .McCracken Bayview Warehouse Unwashed Biostratigraphy 60' ' 115' -1500` MD ' ' ConocoPhillips Alaska, Inc. ABV 100 B 30 MD 1500 - 5000 8105 E~usis Drive Set owner: BP 10' Shows Anchorage, AK 99502 Attn: D. P .McCracken Bayview Warehouse Washed, screened & dried 60' 115' -1500` MD ConocoPhil6ps Alaska, Inc. ABV 100 C Reference Samples 30' 1500' - 5000' MD slos Eleusis Drive Set owner: CPAI 10' Shows Anchorage, AK 99502 Attn: D. P .McCracken Bayview Warehouse Washed, screened & dried 60' 115' -1500` MD ConocoPhillips Alaska, Inc. ABV 100 D Reference Samples 30' 1500' - 5000' MD 8105 Eleusis Drive Set owner: BP 10' Shows Anchorage, AK 99502 Attn: D. P 'ski/M. McCracken Bayview Warehouse Washed, screened & dried 60' 115' -1500` MD ConocoPhillips Alaska, Inc. ABV 100 E Reference Samples 30' 1500' - 5000' MD 8105 Eleusis Drive Set owner: AOGCC 10' Shows Anchorage, AK 99502 Attn: D. P .McCracken Isotube gas samples 250, Is~ech Latxxatories Inc F Routine intervals and and spots of 1500' - 5000` MD 1308 ParMand Court si nificant eaks above g p interest Champaign, IL 61821 back round G Onsite Samplex Samples 60' ' 115' -1500` MD ' To on-site geologist 30 MD 1500 - 5000 Sample frequency was locally altered according to drill rate constraints and zones of interest. ~1 ~1'O~H 14 CQC1dC~OP~'I1~~1~5 1 Q-101 • ~, • 4 PRESSURE /FORMATION STRENGTH DATA 4.1 Formation Inte rit /Leak Off Tests Eauivalent mud weight (EMW) is calculated from rotary table MD NDSS FIT /LOT FORMATION {ft) (ft) (ppg EMV1~ 1850' -1686' 12.4 LOT (Leak Off Test} in bold italics. 4.2 Wireline Formation Tests HYDRO STATIC DEPTH TVD TVDSS Before After F Press Mobil' PPG Calc Formation 3716 2894 2812 1435 1428 1273 936 8.55 U nu A 3875 2984 2902 1486 1475 1313 574.8 8.55 D-Sand 4157 3159 3077 1581 1568 1416 25.4 8.70 D-Sand 4178 3173 3091 1583 1570 1416 11.5 8.67 D-Sand 4188 3179 3097 1587 1574 1417 79.1 8.66 D-Sand 4194 3183 3101 1588 1576 1420 10.8 8.67 D-Sand 4215 3196 3114 1596 1575 1570 1.3 9.54 D-Sand 4279 3237 3155 1619 1604 1447 4.2 8.60 B Sand 4284 3241 3159 1606 1597 1449 13.7 8.68 B Sand 4315 3262 3180 1629 1612 1463 46.4 8.71 B Sand 4361 3293 3211 1648 1631 1482 36.9 8.74 A4 4468 3362 3280 1679 1669 DRY A3 4469 3363 3281 1675 1665 DRY A3 4528 3401 3319 1708 1696 DRY A2 4531 3904 3822 1709 1694 DRY A2 4558 3420 3338 1719 1689 1583 0.6 8.99 A2 4628 3466 3384 1740 1730 DRY A2 4629 3467 3385 1742 1730 Lost Seal A2 4630 3468 3386 1739 1729 Lost Seal A2 4860 3625 3543 1836 1813 1666 3.3 8.92 Al 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 Circulating Density (ECD) Hole Conditions (HC) Connection Gas (CG) Pressure Test Wireline (PT) Quantitative Methods The primary indicators used for pore pressure evaluation were gas trends and Wireline 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, PDC bits, and the absence of clean shale ~~~~~ 15 COI'1000~'11~~1~?S 1Q-101 • 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. The lack of connection gas indicates, ECD was easily well over pore pressure, and mud weights always higher as well. 4.4 Pore Pressure Evaluation Conclusions 1) Surface Hole -13 1/2" (115' to 2510') Pore pressure throughout the surface hole probably maintained a constant at approximately 8.6 ppg. DXC vs TVD was not plotted, as there was no ECD measurement provided for this interval. Resistivity values for sand trails off after 1671' (1620' TVD), below the base of the permafrost. Gas, which had been showing a slight upward trend, did not increase noticeably below the permafrost, suggesting no change in pore pressure. RES AND GAS VS ND -13.5" 10000 1000 • 100 10 2) 8'h" hole (1830'to 5000', Total Depth) • RES x GAS Pore pressure measured from wireline varied from between 8.55 ppg to 8.99 ppg, except for an anomalous reading of 9.54 at 4214' It is unknown to the author what effect regional production depletions or injections has on this well. MW was maintained at 9.2 to 9.4 while drilling this section, and ECD varied from 9.7 to 11.0, overall increasing with depth. ECD data was measured downhole, continuously while drilling (MWD), and provided by Sperry-Sun. No connection gases were noted. • The DXC data appears to be quite random. The 8.7 trendline was established utilizing wireline measurements relative to DXC shale data points in proximity to the sands measured, and what appears to ~1 ~:POCH 16 0 200 400 600 S00 1000 1200 1400 1600 18D0 2000 ,. COt'1QC0~11~~1p5 1 Q-101 • be a relatively "normal" trend above the Ugnu "C". Most sand DXC data points lie below the trend line, in the 0.7 to 0.95 range across the plot, except for a very porous wet sand drilled with a fresh bit just below the casing. The shale points tend to plot above the trend line above the Ugnu "C" Sand until gradually mostly below the line after the West Sak "C" Shale. However, "shaly" points from below casing to above the Ugnu "C" Sand are very scattered, and the "normal" trend more closely represents sand data points. Some shale points to observe are those just above the Ugnu "C" Sand, capping the West Sak "D" Sand, and throughout the West Sak "C" shale, These data points are also quite random. Values in the West Sak "C" Shale, for instance, vary from 0.76 to 1.48. Oftentimes the "Shaly" points, especially clusters of "shaly" points can be identified by low gas readings. Below the Ugnu "C" Sand, with higher (methane) gas associated with sands, and especially below the top of the West Sak "D", with oil saturating the sands, high gas readily separates sands from the "shaley" zones. These zones are identified as "shaley" in that pure shale (or claystone) is rare, variably sandy or silty, or with clays composed or illite, smectite, kaolinite, or weathered organics, as well as other variations. The RES plot appears to be a better indicator of pore pressure trends, as shale points appear to be trending lower with depth, especially through the West Sak, where pressures increased in the A sands (to 8.99 and 8.92). The normal "8.7" trend appears to follow a gradual decrease in RES with depth, while pore pressure increases are associated with sharper decreases. In conclusion, a lack of connection gas indicates pressures remained consistently below the 9.2-9.4 mud weights, probably between 8.5 and 9.0, overall trending downward with depth. The pressure reading at 4214' of 9.54, is an anomaly with perhaps confined pressures in a tight zone. RES data appears to be a better trend indicator than DXC data, and a trend line on the DXC plot would have been difficult to establish without wireline data. • 2 1.8 1.6 1.4 1.2 1 0.8 0.6 0.4 0.2 • DXC VS ND - 8.5" ~~ ~P4CH • DXC ^ PTS -8.7 17 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 i• i• Conoao`Phillips ~Q_~o~ DXC AND GAS VS ND - 8.5" G 1.8 1.6 1.4 1.2 1 0.8 0.6 0.4 0.2 0 ~' .~` `~' ~ . ~.~ ~, .~. • • ~ • • yy[ \C ~r • • ~ .~ yy • • •• • • •• ~ ~ M 2 • *~ • • • • s • • • x x • ~ .d 2181' ~ ~i'cc~:ia6.,p„ n ,i l jb` 1500 1750 2000 2250 2500 2750 3000 3250 RES VS TVD - 8.5" 1000 100 3500 3750 • DXC X GAS • RES i• 10 EPOCH 18 1 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 looo 100 Cdl'1000~'11~~Ip5 1 Q-101 RES AND GAS VS ND - 8.5" ------ • RES z GAS • 10 ~~ EPOCH 19 1 F i i ~-Ti i i r i I 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 r~ 4.5 Pore pressure evaluation ~;: • • ~CIII"tt]-C)D~11~~1rJ5 1 Q-101 Primary Secondary Interval To s Pore Pressure EMW T d Source of Formation Interval Lithology ° (/°) Lithology ° (/°) MD ft TVDSS ft Min Max Trend ren Indicators Quantitative Estimate Permafrost Sd 60% CI st 30% 115 +57 8.6 8.6 Flat BG RES Base Permafrost Sd 60°lo GI st 30% 1671 -1538 8.6 8.6 Flat BG RES To U nu "C" Sd 50% CI st 40% 2983 -2399 8.55 8.7 Sli ht U BG RES, DXC To West Sak Sd 30% CI st 40% 4154 -3074 8.7 9.0 Sli ht U BG RES, DXC Base West Sak Sd 40% Sltst 30% 4883 -3560 9.0 9.0 Flat BG RES, DXC Total De th 5000 -3642 - 9.0 - - - NOTE: Clyst = ClaystonelClay, Sd =Sand, Sltst = Siltstone, Sh =Shale, Sst =Sandstone ~ ~Pa~~ 20 ~~~~~~~ 1Q-101 5 DRILLING DATA 5.1 Survey Data • Measured Depth ft Incl. o Azim. o True Vertical Depth ft Northings ft Eastings ft Vertical Section ft Dogleg Rate o/100ft 30 0.00 0.00 30.00 0.00 N 0.00E 0 0 100 0.34 346.26 100.00 0.20 N 0.05 W 0.14 0.49 122 0.45 333.45 121.70 0.34 N 0.10 W 0.22 0.66 173 0.76 319.95 172.80 0.78 N 0.41 W 0.41 0.66 264 0.77 334.61 263.99 1.80 N 1.06 W 0.87 0.21 354 4.52 14.44 353.88 5.78 N 0.44 W 4.49 4.4 445 8.25 20.85 444.30 15.36 N 2.78E 14.18 4.17 535 7.51 21.07 533.45 26.88 N 7.19E 26.16 0.82 630 7.13 25.90 627.68 37.98 N 12.00E 38.01 0.76 719 8.12 38.05 715.89 47.90 N 18.29E 49.74 2.12 847 9.05 38.15 842.28 62.91 N 30.06E 68.79 0.73 941 9.36 39.40 935.66 74.71 N 39.54E 83.89 0.39 987 9.58 39.28 980.58 80.50 N 44.29E 91.36 0.49 1033 10.25 41.04 1025.83 86.54 N 49.39E 99.23 1.6 1082 12.08 42.20 1074.27 93.68 N 55.75E 108.73 3.73 1126 12.78 43.33 1117.24 100.63 N 62.18E 118.11 1.68 1169 12.54 43.62 1159.37 107.50 N 68.b9 E 127.47 0.57 1221 12.45 44.41 1209.64 115.51 N 76.43E 138.47 0.38 1265 13.83 44.13 1252.15 122.62 N 83.36E 148.26 3.17 1310 15.81 43.93 1296.48 131.05 N 91.51E 159.84 4.33 1355 21.34 40.61 1338.39 141.51 N 100.94E 173.81 12.72 1401 23.93 38.48 1381.14 155.26 N 112.27E 191.58 5.86 1403 24.05 38.39 1383.16 155.97 N 112.83E 192.47 5.86 1435 24.25 37.16 1411.9? 166.18 N 120.74E 205.38 1.72 1466 24.20 37.58 1440.24 176.29 N 128.46E 218.08 0.58 1496 24.83 37.13 1468.17 186.42 N 136.19E 230.81 2.14 1527 25.57 37.68 1495.33 196.56 N 143.95E 243.58 2.59 1558 28.06 36.07 1523.84 208.10 N 152.59E 257.98 8.13 1590 30.60 36.19 1551.76 220.77 N 161.84E 273.67 7.92 1623 32.55 36.12 1579.51 234.54 N 171.91E 290.71 5.99 1637 32.40 36.46 1591.28 240.58 N 176.34E 298.2 1.71 ~Pac~ 21 CU~1'1000~11~f1p5 1 Q-101 • • .] Measured Depth (ft) Incl. o f) Azim. o f) True Vertical Depth f ft) Northings fft) Eastings f ft) Vertical Section (ft) Dogleg Rate (°/100ft) 1666 32.08 37.17 1615.81 252.96 N 185.61E 313.66 1.71 1686 31.86 37.68 1633.03 261.50 N 192.14E 324.4 1.71 1717 32.74 37.44 1659.28 274.65 N 202.26E 340.98 2.86 1761 35.26 37.49 1695.71 294.15 N 217.20E 365.53 5.74 1823 36.93 38.01 1745.56 322.89 N 239.46E 401.83 2.75 1832 37.16 38,09 1752.50 327.01 N 242.68E 407.05 2.75 1860 37.93 38.31 1774.94 340.57 N 253.35E 42428 2.75 1902 37.58 38.00 1808.45 360.98 N 269.38E 450.19 4.94 1998 41.52 35.65 1882.46 409.91 N 305.96E 511.25 4.39 2092 45.03 34.21 1950.31 462.30 N 342.52E 575.13 3.92 2187 47.78 33.00 2015.90 519.68 N 380.63E 643.99 3.03 2282 49.13 33.00 2079.22 579.61 N 419.54E 715.41 1.41 2377 51.30 31.76 2140.07 641.31 N 458.66E 788.39 2.50 2472 58.04 29.28 2194.70 707.72 N 497.73E 865.21 7.44 2565 58.25 29.79 2244.14 776.94 N 53b.94 E 944.42 0.52 2660 56.92 29.06 2294.99 846.69 N 576.29E 1024,14 1.54 2754 55.34 28.16 2347.17 914.94 N 613.52E 1101.40 1.87 2848 54.50 32.78 2401.14 981.13 N 652.45E 1177.96 4.13 2942 53.53 34.21 2456.50 1044.71 N 694.52E 1254.18 1.60 2983 53.57 34.77 2480.84 1071.86 N 713.17E 1287.12 1.11 3038 53.62 35.52 2513.24 1107.79 N 738.46E 1331.06 1.11 3134 56.06 37.19 2568.53 1170.98 N 785.00E 1409.51 2.91 3224 54.53 36.98 2619.91 1230.16 N 829.73E 1483.64 1.70 3321 56.66 38.24 2674.98 1293.86 N 878.82E 1563.96 2.43 3419 56.44 37.50 2728.64 1357.98 N 928.68E 1645.09 0.67 3485 55.49 37.26 2765.77 1401.66 N 962.05E 1700.00 1.47 3509 55.14 37.17 2779.42 1417.37 N 973.98E 1719.71 1.47 3592 56.83 39.25 2825.86 1471.42 N 1016.55E 1788.40 2.91 3609 57.18 39.66 2835.02 1482.31 N 1025.51E 1802.46 2.91 3699 56.51 39.82 2884.59 1540.66 N 1074.03E 1878.08 0.75 3799 5529 39.48 2940.21 1603.92 N 1126.45E 1959.95 1.27 3894 53.73 38.30 2995.53 1664.30 N 1175.16E 2037.34 1.92 3916 53.37 37.75 3008.63 1678.26 N 1186.08E 2055.05 2.61 3989 52.18 35.87 3052.90 1724.91 N 1221.00E 2113.28 2.61 4087 50.38 34.29 3113.82 1787.08 N 1264.68E 2189.27 2.24 4140 49.95 34.31 3148.00 1820.93 N 1287.77E 2230.24 0.80 [~ EPOCH 22 CQR'K7-G~O~'t1~~IpS 1Q-101 • • • Measured Depth (ft} 'no i' (} mom' (} True Vertical Depth (ft) Northings (ft} Eastings (ft) Vertical Section (ft} Dogleg Rate (°l10Qft) 4153 49.85 34.32 3156.41 1829.18 N 1293.40E 2240.23 0.80 4180 49.63 34.33 3173.71 184b.06 N 1304.92E 2260.66 0.80 4233 49.22 34.26 3208.33 1879.46 N 1327.70E 2301.09 0.79 4275 48.90 34.20 3235.59 1905.44 N 1345.38E 2332.51 0.79 4275 48.90 34.20 3235.86 1905.69 N 1345.55E 2332.81 1.23 4321 49.34 33.73 3265.96 1934.54 N 1364.98E 2367.58 1.23 4370 49.81 33.23 3297.93 1965.83 N 1385.67E 2405.09 1.23 4394 49.48 33.06 3313.28 1980.96 N 1395.55E 2423.15 1.52 4464 48.48 32.56 3359.49 2025.60 N 1424.33E 2476.23 1.52 4525 49.01 33.01 3399.45 2063.90 N 1449.00E 2521.75 1.04 4557 49.30 33.24 3420.42 2084.21 N 1462.25E 2545.99 1.04 4653 48.12 33.08 3483.72 2144.54 N 1501.68E 2618.03 1.24 4710 47.31 32.72 3522.08 2179.96 N 1524.59E 2660.18 1.48 4746 46.80 32.48 3546.84 2202.37 N 1538.92E 2686.77 1.48 4839 45.92 31.91 3610.45 2258.82 N 1574.46E 2753.4 1.06 4883 45.54 31.47 3641.50 2285.92 N 1591.19E 2785.2 1.11 4933 45.12 30.96 3676.57 2316.26 N 1609.58E 2820.6 1.11 PROJECTED SURVEY TO TOTAL D EPTH 5000' 5000 45.12 30.96 3723.93 2357.04 N 1634.05E 2868.04 0 ~1 EPOCH 23 C 5.2 Bit Record • •- ~~~~~~~ 1Q-101 Depth In Total Bit Aug' WOB PP Bit Make Type Jets / TFA MD / Footage Hrs ROP (Klbs) RPM (PSi) Wear BHA TVDSS ft ft/hr 131/2" Hole 1 BHI MX-1 3x20, 1x13 / 115 1182 10.19 116 12 45 1350 1-1 (rerun as #2) 1 1.050 1rr1 BHI MX-1 3x20, 1x13 1297 533 5.10 105 21 35 1630 1-1-CT-G-E-I--TD 2 /1.050 8'/z" Hole 2 HYC DSX147GVW 6X12/0 663 1830 3170 26.33 120 5 63 1478 2-2-BT-SO-X-1- 3 . ER-TD ~~~~H 24 i • c~l,~i~~ ~ 1 Q-101 5.3 Mud Record Contractor :MI Mud Tvpe :Spud Mud in Surface. FLOPRO NT from 1850' (after LOT) to TD, Date Depth MW ECD VIS s~ t PV YP Gels FL cc FC Sots °!° OIW Ratio Sd °!° pH CI mlll Ca ml/I 13'/z" section 11/15105 461 9.5 10.16 120 25 42 22/27/30 nc / 5 /95 0.25 9.2 400 80 11 /16!05 717 9.5 -- 120 25 42 22/27/30 2/ 5 /94 0.5 9.2 400 80 11 /17/05 1830 9.7 - 144 47 52 24/31 /37 14 1 / 6 Tr/93 0.3 9.2 400 80 11 /18/05 1830 9.8 - 252 47 50 16!25/48 5.8 2l 7.5 /93 0,3 9.0 400 80 11/19/05 1830 9.8 - 57 27 12 4/6/7 6.6 2/ 7.5 /93 0.25 7.3 400 60 8'/z" sect ion 11!20/05 1830 9.8 10.07 55 25 14 7!9!10 7.6 2l 7.5 /93 0.25 8.3 400 90 11 /21 /OS 2727 9.8 10.06 55 25 14 7/9/10 7.6 1 / 7.5 /94 nil 8.3 400 90 11 /22/05 4152 9.2 10.39 64 18 44 19/24/25 4.4 11 6 /94 8.2 17300 130 11!23/05 4532 9.3 - 58 15 31 12/17/18 6.6 1/ 7 /93 0.75 8.5 18000 360 11/24/05 5000 9.3 - 58 15 31 12/17/18 6.6 2/ 7 /93 0.5 8.5 18000 360 11 /25/05 5000 9.3 - 58 10 28 14/16!16 21 21 7 /93 0.5 7.3 15000 360 11/26/05 5000 9.3 -- 43 10 28 11/15/16 7.0 2/ 7 /92 - 9.0 15000 100 Abbreviations MW =Mud Weight Gets =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 ~~~~~ 25 ~~~~~~ 1Q-101 • lJ MORNING REPORTS ~1 EI'C~~H 26 • • • ~or~c~caPhiilips ~Q-~o~ Report for: Wilson / Pederson Mark Woods Date: 11/16/05 Time: 0415 I7rillinn ParamPtPrs Current Depth: 717' Operation: Survey Yesterdays Depth: 115' 24 hr Footage: 602' ROP: Current: 80 Max: 1620 Tor ue: Current: Max: WOB: Current 6 Max: 22 RPM: Current: Max: PP: Current: Max: Lag: Strokes: 1715 Time: 12.8 Circulation: Strokes: 1815 Time: 13.5 ECD: Current: Max: Mi~ri Prnnartioc MW: 9.5 FV: 120 PV: 25 YP: 42 FL: -- Gels: 22/27/30 Sol: 5 pH: 9.2 CI- 400 Ca+' 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 5u Max: 21 u De the 627' C~ac i=vantc 'eaks Tri Gas De h TG C1 C2 C3 C41 C4N C51 C5N NA Connection Gas De th TG C1 C2 C3 C4f C4N C51 C5N None De th TG C1 C2 C3 C41 C4N C51 C5N No. Depth TG C1 C2 C3 C41 C4N C51 C5N 1 250 4u 832 - - - - - - 2 500 Su 930 - - - - - - 3as Sam les Lithologies: Current: 80% sand / conglomeratic sand, 20% claystone Last 24 hrs: Sand, conglomerate, claystone Pickup 5" DP and HWDP; cond mud; RU wireline; PU BHA; tag up @ 73'; Opperational Summary: clean out to 145'; drill 145' to 215'; POOH; PU collars; RIH; drill to 717' at report time taking gyros at each connection. Calibrations: Tested THA and Chromatograph, okay Failures: none ~Con~oPhi~p~ 1Q-101 • Report for: Wilson / Pederson Mark Woods Date: 11/17/05 Time: 0330 Ilrillinn Paramctcrc • Current Depth: 1500' Operation: Drilling Yesterdays Depth: 717' 24 hr Footage: 783' ROP: Current: 105 Max: 476 Torque: Current: Max: WOB: Current 17 Max: 39 RPM: Current: Max: PP: Current: Max: Lag: Strokes: 3430 Time: 22.9 Surf-Surf: Strokes: 3730 Time: 24.9 ECD: Current: Max: nn~irl Drnr.crficc MW: 9.7 FV: 144 PV: 28 YP: 52 FL: 14 Gels: 24/31/37 Sol: 6 pH: 9.2 CI- 400 Ca`+ 80 Ditch Gas: Current 10u Max: 23u Depth: 810' Background: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data 3as Events Depth TG C1 C2 C3 C41 C4N C51 C5N 'eaks Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N 18u Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N None No. Depth TG C1 C2 C3 C41 C4N C51 C5N 3 1500 6u 1203 - - - - - - gas Sam les Lithologies: Current: 60% claystone, 40°lo sand. Last 24 hrs: Sand, claystone, conglomerate, siltstone. Operational Summary: Drill to 1297'. POOH to increase bend in mudmotor. RIH. Drill to 1500' at report time. Backreaming as needed to wipe out excess dogleg. Calibrations: Tested THA and Chromatograph, okay • Failures: none Cono~oP~r~lip~ 1Q-101 Report for: Wilson / Pederson Mark Woods Date: 11/18/05 Time: Drilling Parameters Current Depth: 1830' Operation: Rig up for casing Yesterdays Depth: 1500' 24 hr Footage: 330' ROP: Current: na Max: 273 Tor ue: Current: na Max: WOB: Current: na Max: 28 RPM: Current: na Max: PP: Current: na Max: Lag: Strokes: na Time: Surf-Surf: Strokes: na Time: ECD: Current: na Max: Mud Properties • • MW: 9.8 FV: 252 PV: 47 YP: 50 FL: 5.8 Gels: 16/25/48 Sol: 7.5 pH: 9.0 CI-~ 400 Ca++~ 80 Background: na Max Gas: 42u @ 1713 r_~~ F~.o.,t~ MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Current De th TG C1 C2 C3 C41 C4N C51 C5N eaks To: Reason: Wiper Gas De th TG C1 C2 C3 C41 C4N C51 C5N 32u Connection Gas De th TG C1 CZ C3 C41 C4N C51 C5N None No. De th TG C1 C2 C3 C41 C4N C51 CSN 4 1754 14u 2785 - - - - - - Gas Sam les Lithologies: Current: Out of hole. Last 24 hrs: Sand, conglomerate sand, claystone, siltstone, carbonaceous shale, coal, tuff Drill to surface TD 1830'/1751'ND. Circ hole clean w hi vis weighted sweep. Operational Summary: Wipe hole to 634'. TIH. Pump hi vis weighted sweep. POOH. LD BHA. Prepare for running 10-3/4" casing. Calibrations: Calibrated THA and Chromatograph Failures: none Daily Cost: $2935.00 ~ort~''hillip 1Q-101 • Report for: Wilson !Pederson Mark Woods Date: 11/19/05 Time: 0400 Current Depth: 1830' Operation: Nipple Down Yesterdays Depth: 1830' 24 hr Footage: 0' Drilling Parameters ROP: Current: na Max: Torque: Current: na Max: WOB: Current: na Max: RPM: Current: na Max: PP: Current: na Max: La Strokes: na Time: Surf-Surf: Strokes: na Time: ECD: Current: na 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 Current Background: na Max Gas: na r~~ G..e.,+~ De th TG C1 CZ C3 C41 C4N C51 C5N yaks Tri Gas De th TG C1 C2 C3 C41 C4N C51 CSN 8u Connection Gas De h TG C1 C2 C3 C41 C4N C51 C5N None No. De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les Lithologies: Current: Out of hole. Last 24 hrs: No new formation. Operational Summary: Run and cement 10-3t4" surface casing. Nipple dawn diverter. Calibrations: Failures: none • Daily Cost: $2935.00 Canoctillis 1Q-101 • Report for: Wilson / Pederson Mark Woods Date: 11/20/05 Time: 0300 Current Depth: 1830' Operation: Test BOP's Yesterdays Depth: 1830' 24 hr Footage: 0' Drilling Parameters ROP: Current: na Max: Torque: Current: na Max: WOB: Current: na Max: RPM: Current: na Max: PP: Current: na Max: La Strokes: na Time:. Surf-Surf: Strokes: na Time: ECD: Current: na Max: Mud Properties • MW: FV: PV: YP: FL: Gels: Sol: pH: CI-~ Ca`+~ MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Current Background: na Max Gas: na ~ C:ac Fvantc De th TG C1 C2 C3 C41 C4N C51 C5N yaks Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N na Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N na No. De th TG C1 C2 C3 C41 C4N CSl C5N Gas Sam les Lithologies: Current: Out of hole. Last 24 hrs: No new formation. Operational Summary: Nipple up BOP's. Change out top rams to 5" DP. Test BOP's to 250/3000 psi. Calibrations: Checked THA and Chromatograph, okay. Failures: none Daily Cost: $2935.00 Cor~r~coP~hillips 1Q-101 Report for: Wilson 1 Pederson Mark Woods Date: 11/21/05 Time: 0400 Drilling Parameters • r~ LJ Current Depth: 1830' Operation: Drill shoe track Yesterdays Depth: 1830' 24 hr Footage: 0' ROP: Current: 0 Max: Torque: Current: 2600 Max: WOB: Current: 0 Max: RPM: Current: 38 Max: PP: Current: 1160 Max: La Strokes: 1800 Time: 15.3 Surf-Surf: Strokes: 2180 Time: 18.5 ECD: Current: 10.06 Max: Mud Properties Background: 0 Max Gas: 0 Gas Events MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Current MW: 9.8 FV: 55 PV: 25 YP: 14 FL: 7.6 Gels: 7/9/10 Sol: 7.5 pH: 8.3 CI" 400 Ca++~ 90 De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks To: Reason: Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N na Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N na No. Depth TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les Lithologies: Current: na Last 24 hrs: No new formation. Operational Summary: Continue testing BOP's. PU and MU BHA and single in 15 jts DP. RIH to 1710. Circulate. Test casing. Begin drilling shoe track at report time. Calibrations: THA and Chromatograph calibrated. Failures: none Daily Cost: $2935.00 • Report for: Wilson / Pederson Mark Woods Date: 11 /22/05 Time: 0400 • • Drilling Parameters ~onocil~i~xs 1Q-101 Current Depth: 2727' Operation: Drilling Yesterdays Depth: 1830' 24 hr Footage: 897' ROP: Current: 146 Max: 420.9 Tor ue: Current: 2316 Max: 5143 WOB: Current: 9.1 Max: 39.0 RPM: Current: 34 Max: 67 PP: Current: 1517 Max: 1944 La Strokes: 2400 Time: 13.2 Surf-Surf: Strokes: 3000 Time: 16.5 ECD: Current: 10.39 Mud Properties MW: 9.2 FV: 64 PV: 18 YP: 44 FL: 4.4 Gels: 19/24/25 Sol: 6 pH: 8.2 Cf~ 17300 Ca'~+ 130 Background: 15 Max Gas: 29 ~ 2686 C~ac Fvcntc MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Current De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks To: Reason: Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N na Connection Gas De th TG C1 C2 C3 C41 C4N C51 CSN none No. De th TG C1 C2 C3 C41 C4N C51 CSN 5 2010' 16 3D10 - - - - - - 6 2257' 8 1695 - - - - - - 7 2500' 6 1201 - - - - - - Gas Sam les Lithologies: Current: 50% claystone, 40% sand, 10% siltstone. Last 24 hrs: Sand, claystone, conglomeratic sand, siltstone, trace coal. Operational Summary: Drill shoe track and 20' new hole to 1850'. LOT = 12.4 ppg EMW. Change over to F1oPro mud system. Drill and slide ahead to 2727 at report time. Calibrations: THA and Chromatograph tested, okay. Failures: none Daily Cost: $2935.00 ~Conoccilipr~ 1 Q-101 Report for: Wilson / Pederson Curt • • Date: 11/23/05 Time: 0400 Current Depth: 4532' Operation: Drilling Yesterdays Depth: 2727' 24 hr Footage: 1805' Drilling Parameters ROP: Current: 147 Max: 324 Torque: Current: 4600 Max: 7900 WOB: Current: 12 Max: 38 RPM: Current: 50 Max: 77 PP: Current: 1616 Max: 1990 Lag: Strokes: 3500 Time: 20.6 Surf Surf: Strokes: 4550 Time: 26.7 ECD: Current: MW: FV: PV: YP: FL: Gels: Sol: pH: Cl- Ca +~ Mud Properties NO MUD REPORT AVAILABLE AT REPORT TIME MW Change: Mud Lass event: ata Current Background: 150 t;ac Fuanfic Depth: From: Depth: Volume: Max Gas: 465 To: Reason: Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N na Connection Gas De th 200u 4154 C:ac ~amnlac No. Depth TG C1 C2 C3 C41 C4N C51 CSN 8 2769' 14 2953 - - - - - - 9 3000' 19 3771 - - - - - - 10 3250' 13 2681 - - - - - -- 11 3500' 100 18689 -- - - - - - 12 3751' 35 6080 - - - - - - 13 4000' 23 4541 - - - - - - 14 4178' 650 59916 366 119 94 10 9 - 15 4251' 75 14195 88 38 27 4 - - 16 4291' 602 112275 1012 572 541 233 222 65 17 4475' 392 67062 860 811 586 669 430 292 Lithologies: Current: 40% claystone, 30% siltstone, 20% sand, 10% carbonaceous shale. Last 24 hrs: Sand, claystone, conglomeratic sand, siltstone, carbonaceous shale, coal. Operational Summary: Drill and slide to 4532' at report time. Calibrations: THA and Chromatograph tested, okay. Failures: none Daily Cost: $2935.00 Conocof~rli • 1 Q-101 Report for: Wilson / Pederson Curt • • Date: 11/24/05 Time: 0400 Current Depth: 5000' Operation: Breakdown BHA Yesterdays Depth: 4532' 24 hr Footage: 468' Drilling Parameters ROP: Current: 144 Max: 269 Torque: Current: 7486 Max: 9123 WOB: Current: 14 Max: 27 RPM: Current: 67 Max: 76 PP: Current: 1874 Max: 2275 Lag: Strokes: 4050 Time: 22.8 Surf-Surf: Strokes: 5250 Time: 29.4 ECD: Current: Mud Properties MW: 9.3 FV: 15 PV: 15 YP: 31 FL: 6.6 Gels: 12/17/18 Sol: 7 H: 8.5 Cf~ 18000 Ca+` 360 MW Change: Mud Loss event: Gas Data Current Background: na r_~~ G~.o.,+~ C`_~c Comnloc Depth: From: Depth: Volume: Max Gas: 503 @ 4865 To: Reason: Trip Gas Depth TG C1 C2 C3 C41 C4N C51 CSN na Wiper Gas 324 Connection Gas Depth none No. Depth TG C1 C2 C3 C41 C4N C51 C5N 18 4568 268 45766 555 644 449 620 551 280 19 4729 174 25864 313 279 243 265 342 307 20 4750 104 13256 144 158 175 234 333 340 21 4864 611 98970 1879 1367 1265 783 933 437 22 4930 614 96774 1937 1768 1403 1245 1249 792 23 4950 195 26410 421 371 336 314 342 250 24 5000 225 30391 509 388 375 328 437 399 Lithologies: Current: Out of hole. Last 24 hrs: Sand, claystone, siltstone, carbonaceous shale, tuff. Drill and slide to TD of 5000'MD/3724'TVD, arculate hole clean, pull out of Operational Summary- hole into casing backrearr~ng as needed, trip in hole, wash last stand to ' bottom, circulate hole clean, 324 units max wiper gas, pull out of hole, handling BHA at report time. Calibrations: THA and Chromatograph tested, okay. Failures: none Daily Cost: $2935.00 • Report for: Wilson / Pederson Curt Date: 11/25/05 Time: 0330 Drilling Parameters nvccilli 1Q-101 Current Depth: 5000' Operation: Trip Out Yesterdays Depth: 5000' 24 hr Footage: 0' ROP: Current: Max: Tor ue: Current: Max: WOB: Current: Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Mud Properties MW: 9.3 FV: 58 PV: 10 YP: 28 FL: 21 Gels: 14/16/16 Sol: 7 pH: 7.3 C{- 15000 Ca++~ 380 MW Change: Mud Loss event: Gas Data Current Background: na (sae Fvantc Depth: From: Depth: Volume: Max Gas: 9.7 _ @ 2000 To: Reason: Trip Gas Depth TG C1 C2 C3 C41 C4N C51 CSN na Wi er Gas na Connection Gas De th none C.3ac Camnlnc No. De h TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Out of hole. Last 24 hrs: No new formation. Operational Summary: Lay down BHA, rig up Schlumberger logging tools, begin logging. Calibrations: THA and Chromatograph tested, okay. Failures: none Daily Cost: $3435.00 C~notof~hil~ips 1Q-101 • • • Report for: Wilson / Pederson curt Date: 11 /26/05 Time: 0400 Drilling Parameters Current Depth: 5000' Operation: Logging Core Samp. Yesterdays Depth: 5000' 24 hr Footage: 0' ROP: Current: Max: Torque: Current: Max: WOB: Current: Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Mud Properties MW: 9.3 FV: 43 PV: 10 YP: 28 FL: 7 Gels: 11/15/1fi Sol: 7 pH: 9.0 CI-~ 15000 Ca+~`~ 100 Background: na Max Gas: na ~ C~ac Fvantc MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Current To: Reason: Trip Gas De th TG C1 C2 C3 C41 C4N C51 CSN na Wi er Gas na Connection Gas Depth none vas Sam ies No. Depth TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Out of hole. Last 24 hrs: No new formation. Operational Summary: Currently togging Calibrations: THA and Chromatograph tested, okay. Failures: none Daily Cost: $2,655.00 ~oncx~Philli 1 -101 (~ • Report for: Wilson / Pederson curt Date: 11/27/05 Time: 0430 Current Depth: 5000' Operation: Tripping Out Yesterdays Depth: 5000' 24 hr Footage: 0' Drilling Parameters • MW: FV: PV: YP: FL: Gels: Sol: pH: Cf Ca~+ Mud Properties No Mud Report Available At Report Time ROP: Current: Max: Torque: Current: Max: WOB: Current: Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Current Background: na Max Gas: 589 @ 5480 r_~~ F~.o.,+~ Trip Gas Depth TG C1 C2 C3 C41 C4N C51 CSN na Wi er Gas na Connection Gas De th none Gas Samples No. Depth TG C1 C2 C3 C41 C4N C51 CSN Lithologies: No new samples taken since TD. Current: Last 24 hrs: Operational Summary: Run in the hole to shoe, circulate bottoms up, circulate at 3570, top drive up, wash down from 4897,pump sweep, pull out of hole. Calibrations: THA and Chromatograph tested, okay. Failures: none • Daily Cost: $2,655.00 • C~notaf~hil~ips 1Q-101 Report for: Wilson / Pederson Curt Date: 11/28/05 Time: 0430 Current Depth: 5500' Operation: Pull out of hole Yesterdays Depth: 5500' 24 hr Footage: 0' Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current: Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Mud Properties No Mud Report Available At Report Time MW: FV: PV: YP: FL: Gels: Sol: pH: Cl- Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Current Background: na Max Gas: @ • Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N 45 4780 Wi er Gas na Connection Gas Depth none vas Samples No. Depth TG C1 C2 C3 C41 C4N C51 C5N • Lithologies: No new lithology. Current: Last 24 hrs: Operational Summary: Circulate bottoms up, Pull out of hole. Calibrations: THA and Chromatograph tested, okay. Failures: none Daily Cost: $2,655.00 WELL LOGS ~~ • Schlum6erger Fluid Analysis on Bottomhole MDT Samples ConocoPhillips Fieltl: West Sak We11:1Q-101 Black Oil PVT Study Report Prepared for Dennis Wegener ConocoPhillips • Standard Conditions Used: Pressure: 14.696 psis Temperature: 60°F Prepared by: Stefan Smuk Schlumberger WCP Oilphase-DBR 16115 Park Row, Suite 150 Houston, Texas, 77084 (281)285-6370 Date:3/29/2006 ~~~~! ~ ~ "1.00? • ~ ~ ~S. ~~,~missiArF X11! ~~'= SO-G2g -23a$2 -vu -oo .~~~ i~~ .;~ ~,,: rt #200500199 dos =~s~ ~ ~~ aY2 Client: ConocoPhillips Field: West Sak S hl b Well: 1 Q-101 Sand: West Sak B c um er er Installation: - Job #: 200500199 Table of Contents List of Figures ................................................................................................... .................................................. 2 List of Tables .................................................................................................... .................................................. 3 EXECUTIVE SUMMARY ................................................................................... .................................................. 5 Objective 5 Introduction 5 Scope of Work .................................................................................................... .................................................. 5 Results 5 PVT Study Data. Duality. Check Summary ................................................................. .................................................. ~ Sequence oiEvents ............................................................................................. .................................................. ~ Chain ofSamp/e.Custady ..................................................................................... .................................................. ~ RESULTS AND.DISC.USSIONS ......................................................................... .................................................. a Fluids Preparation.andAnalysis ............................................................................ .................................................. B Reservoir Fluid.Analysis ...................................................................................... .................................................. 6 PVT Analysis oo. Sample.l..Dfi C;. Cylinder. CS 6.1.1792-QA;. Depth 429311. M D ................ .................................................. 36 Constant Composition.Fxpansion at.Tres .................................................................... .................................................. 36 Reservoir Oil Viscesity.at.Tres .................................................................................. .................................................. 38 Single-Stage Separation.Test ................................................................................... .................................................. a0 Viscosity Analysis on.Sample.1.06.C ...................................................................... .................................................. 4a Reservoir Oil Viscosity. at.Tres .................................................................................. .................................................. 44 Reservoir Oil Viscosity.at.15Q'F ................................................................................ .................................................. 46 • Reservoir Oil Viscosity. at 9U F .................................................................................. .................................................. 48 Reservoir Oil Viscosity at 5lt°F ................................................................................. .................................................. 50 Density at Various. Temperatures .............................................................................. .................................................. 52 Appendix A: Nomenclature..and.Definitions .................................................. .................................................. 55 Appendix B: Molecular.Weights.and.Densities.Used .................................. .................................................. 5s Appendix C: E.QU.IPMENT ................................................................................ .................................................. 57 Fluid Preparation.and.Yalidation ........................................................................... .................................................. 5~ Fluid Volumetric.(PVTl and.Viscasityfquiproent ..................................................... .................................................. 57 Appendix D: PRO.CED.URE ............................................................................... .................................................. so Fluids Preparation.and.Validation ......................................................................... .................................................. so Constant Composition fxpaasian Pcocedwe .......................................................... .................................................. 60 Differential Vaporization Procedure ...................................................................... .................................................. 60 Multi-Stage Separation.Test ................................................................................. .................................................. so Liquid Phase Viscosity.and.DensityMeasurements.DuringllV.Step .......................... .................................................. 6~ Stock-Tank Oil.(STDJ.Viscosityand.Density.Measurements ..................................... .................................................. si Asphaltene, Wax.and.Sultur.ContentMeasurements ............................................... .................................................. si SAR(P)A Analysis ................................................................................................ .................................................. 62 High-Temperatwe High.Pressurefiltration.Tes[ .................................................... .................................................. 62 • WCP Oilphase-DBR 1 Job #:200500199 Client: ConocoPhillips Field: West Sak hl s b Welt: 1 Q-101 Sand: West Sak B um erger c Installation: - Job #: 200500199 List of Figures Figure 1: Stock Tank Dil. Chromatogram (Sample.l..DS- ............................................. .................................................. i 5 Figure 2: k-Plot.forEquilihrium.Check.ISarople.1.051 ................................................ .................................................. 15 Figure 3: Stock Tank Oil. ChromatogramlSample.l..D61 ............................................. .................................................. ie Figure 4: k-Plot..forEquilihrium.Check.ISarople.1.061 ................................................ .................................................. is Figure 5: Stock Tank Dil. Chromatogram (Sample.l..g9- ............................................. .................................................. 2~ Figure 6: k-Plot.forEquilihrium.Check.ISarople.1.Q91 ................................................ .................................................. 21 Figure 7: Stock Tank Oil. Chromatogram (Sample.l...10- ............................................. .................................................. 2a Figure 8: k-Plot.for Equilihrium.Check.ISarople.1.1.0) ................................................ .................................................. 2a Figure 9: Stock Tank Dil.Chromatogram (Sample.]...11.- ............................................. .................................................. z~ Figure 10:k-Ploifor.Equilibrium.Check.(Sample.1.11- ......................................_...... .................................................. z~ Figure 11: Stock.Tank.Oil.Chromatogram.ISarople.1.Q5.CI ......................................... .................................................. 3t Figure 12: k-Plotfor.Equilibrium.Check.(Sample.1.05.C- ........................................... .................................................. 3t Figure 13: Stock.iank.Oil.Chromatagram.ISarople.1.Q6.CI ......................................... ... 3a Figure l4:k-Plot for.Equilibrium.Check(Sample.l.Ofi.CI . . ................ 3a Figure 15: ConstantCompositiao.Expansion.at.67.0".F.-.Relative.Valume .................... .................................................. 37 Figure 16: Reservoir Fluid Viscosity 6Z'F ................................................................ .................................................. 39 Figure 17: Reservoir. FluidViscasityt6Z°F ............................................................... .................................................. a5 Figure 18: Reservoir Fluid Viscosity.150.°.F ............................................................... .................................................. a7 Figure 19: Reservoir. Fluid Viscosity 90°F ................................................................ .................................................. as Figure 20: Reservoir Fluid Viscosity 50°F ................................................................ .................................................. 5i Figure 21: STO D.ensity.vs..Iemperature .................................................................. .................................................. 53 Figure 22: Simulated Monaphysical.Density at.3000. psia.vs..Temperature .................. .................................................. 5a • WCP Oilphase-DBR 2 Job #:200500199 • Client: ConocoPhillips Well: 1 Q-101 Field: Sand: West Sak West Sak B Sehlumberger Installation: - Job #: 200500199 List of Tables Table 1: Well and.Sample.Identification ........................................................................ ........................ to Table 2: Well Position Data ....................................................................................... ........................ t0 Table 3: Sampling and .Transfer Summary ...................................................................... ........................ t t Table4:ReservoirF.luid.Properties .............................................................................. ........................ t2 Table 5: Stock-Tenk.O.il.Properties .............................................................................. ........................ t2 Table6:C30+Camposition,.GOR,'API,.by.Zero.-Flash.(Sample.l..05) ................................................ ............................ t3 Table 7: Calculated.Fluid.Properties ............................................................................................ ............................ to Table 8: C30+Cnmpositian,.GOR,'API,.by.Zero-Flash.(Sample.]..Ofi) ................................................ ............................ is Table 9: Calculated.fluid.Praperties ............................................................................................ ............................ t~ Table10:C30+Composition,.G.Oit,.°API,byZero-Flash.(Sample.1.Q9) ............................................... ............................ is Table1l:Calculated.Fluid.Properties ........................................................................................... ............................ zo Table 12:C30+Composition,.G.O.R,.'API,byZero-Flash.(Sample.1.1..0) ............................................... ............................ z2 Table 13: Calculated Fluid.Properties ........................................................................................... ............................ z3 Table 14: C30+ C.omposition,. G.O.R,.'API, byZero-Flash.(Sample .1,1.1- ............................................... ............................ 25 Table 15: Calculated. Fluid.Properties ........................................................................................... ............................ 2s Table 16: Calculated Synthetic.Gas.Composition ........................................................................... ............................ zs Table 17: Physical. Composition. of ihe.Syn. Gas Prepared io. the lah ................................................ ............................ 2e Table 18: C30+ C.omposition,.G.O.R,.'API, byZero-Flash.(Sample.1.QS.C- ............................................ ............................ 2s Table 19: Calculated.Fluid.Properties ........................................................................................... ............................ 30 Table 20: C30+ Composition,. G.OR,. °API, by Zero-F.lash.(Sample.1.Q6.C- ............................................ ............................ 32 Table 21: Calculated. Fluid. Properties ........................................................................................... ............................ 33 Table 22: Summary.nf.Results.of.Sample.1.Ob.C ............................................................................. ............................ 35 • Table 23: Constant Compositiao.Expansion. at.67.0°F.(Sample.1.06. C) ............................................... ............................ 3s Table 24: Reservoir. Fluid Viscosity liZ°F ....................................................................................... ............................ 3s Table 25:Single-Stage Separatoo.o.testYapor&.LiquidProperties ................................................. ............................ at Table 26:Single-Stage Separator.Test.Vapor.Compasition.(rool.°1n- ................................................. ............................ a2 Table27:Single-StageSeparatar7estitesidual.Lignid.Composition.(mol.°1°) ................................... ............................ a3 Table 28:Reservoir. Fluid Viscosity b7°F ....................................................................................... ............................ as Table 29: Reservoir. FluidViscasity.150".F ...................................................................................... ............................ as Table30:ReservoirFluidYiscosity90°F ....................................................................................... ............................ as Table 31: Reservoir Fluid Viscosity 50°F ....................................................................................... ............................ 50 Table 32: STO Density. vs..temperature ......................................................................................... ............................ 53 Table 33: Simulated. Monaphysical.Density. at3000.psis.vs..tempereture ......................................... ............................ 5a • WCP Oilphase-DBR 3 Job #:200500199 Client: ConocoPhillips Well: 10-101 Field: Sand: West Sak West Sak B ~chlumberger Installation: - Job #: 200500199 EXECUTIVE SUMMARY • • Objective To evaluate the composition and phase behavior of the bottomhole fluid samples collected during the modular formation dynamics testing (MDT). Introduction At the request of ConocoPhillips, Oilphase-DBR has conducted a fluid analysis study on bottomhole fluid samples collected during the modular formation dynamics testing (MDT) of Well 10-101 drilled in the field West Sak. Scope of Work • Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for one Conduct the quick API check and water content check on the STO samples. • Conduct preliminary evaluation on bottomhole hydrocarbon samples that include single-stage flash Gas-Oil Ratio (GOR-, reservoir fluid composition, stock-tank oil (STO) and monophasic fluid • Select a representative sample for de-emulsification. • Use de-emulsified sample for PVT study. • Transfer 200 cc de-emulsified sample to another cylinder and saturate it with syn gas. For this condittioned sample, • Conduct a Constant Composition Expansion (CCE) test at the reservoir temperature. • Conduct asingle-stage separation test at the specified conditions. • Also conduct viscosity measurements of the oil at the reservoir temperature. Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon and water samples: • Six bottomhole samples were used for validation purposes. They were homogenized at the reservoir conditions for one day and heated for another day without rocking in vertical position. • Sample 1.01 was pushed out from the top of the cylinder and it was clear water-look without any trace of oil. We recommend to get the GWR and gas composition, water analysis if needed but should it be just filtrate, then blowdown. • For the quick API check, sample 1.05, 0.9440 @ 60 F, API: 18.4, water content: 1.0% from top; sample 1.09, 0.9475 Q 60 F, API: 17.8, water content: 1.9% from top; sample 1.10, 0.9476 Q 60 F, API: 17.8, water content: 1.7% from top; sample 1.11, 0.9485 @ 60 F, API: 17.8, water content: • The zero flash GOR of the hydrocarbon samples was determined to be from 117 - 133 SCF/STB, and the STO density to be from 0.945 - 0.948 g/cc. • Sample 1.10 was chosen for the de-emulsification. After the de-emulsification, lab collected 60 cc water and 30 cc mixture of sediment and oil from the bottom of the cylinder. Lab stopped draining out the sediment from the bottom since there is no clear cut between sediment and oil after that 30 cc push out. The BS&W from the top is 0.5%. The remaining sample volume isn't enough for the • Sample 1.05 was chosen for the de-emulsification. After the de-emulsification, lab collected 180 cc water and sediment from the cylinder bottom. The top sample was used for the testing but the Pb was 896 psia at 72°F. Apparently the sample lost some gas during the sampling due to the high WCP Oilphase-DBR 4 Job #:200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Installation: - Job #: 200500199 • Sample 1.05 was saturated with syn gas to reach a Pb close to the reservoir pressure. However, this conditioned sample was unfortunately contaminated at C10 and C11 residue from the transfer cylinder. That contamination may be the rinse solvent used by a 3rd party. With client's approval, sample 1.06 was used to replace sample 1.05. The prelim testing the de- emulsification were conducted. 250 cc water and sediment were drained out from the bottom and the BSW from top is nil. Then we transferred 200 cc 1.06 from CSB 14332-QA to CSB 11797-OA and pushed out another 15 cc from the original cylinder. That 15 cc STO had no water and sediment. After that, we saturated that 200 cc in CSB 11797-QA with syn gas and re-verified the composition. The conditioned sample is valid for further PVT testing. Subsequently, conditioned sample 1.06 was used for ful{ PVT study. The following are the results of the reservoir fluids: The bubble point pressure at reservoir temperature was determined to be 1,399 psia. The reservoir fluid viscosity of conditioned sample 1.06 was measured to be 150.7 cP at bubblepoint pressure and 152.0 cP at the initial pressure. The stock tank oil viscosity at 67°F was measured as 708.9 cP. • FLASHING OPERATION CUMULATIVE GOR API GRAVITY Gas Relative Density (air=1) FVF at Pres/Tres FVF at Psat/ires ero Flash 173 18.1 0.610 1.051 1.051 Separator Test 171 18.4 0.609 1.049 1.049 WCP Oilphase-DBR Job #:200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Installation: - Job #: 200500199 Quality Assurance Process Oilphase-DBA 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 iQHSEI requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE 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. aj Establish quality of measurement during data generation. bj 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 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. 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.:200500199 Laboratory Records: 200500199 Data Quality Data Reporting Suyu Ye Meisong Yan Data Quality Engineer Project Engineer Overall Report Quality Clay Young Clay Young Oilphase-DBR Operation Manager, NGC • WCP Oilphase-DBR 6 Job #:200500199 • Client: Well: Installation: Sequence 12/06/05 12/09/05 12/09/05 12j09/05 12/12/05 12/29/05 01/25!06 01/31/06 02/14/06 03/08/06 03/29/06 ConocoPhillips Field: West Sak 1Q-101 Sand: West Sak B Schlumberger - Job #: 200500199 ~f Events Samples arrived and client was informed. Project work scope discussed. Work agreement approved. Prelim PVT tests request for five samples issued. Quick API check results were sent to client via a-mail. Sample PVT prelim results sent via a-mail. PVT testing scope approved by client Pb result for sample 1.05 was reported to client PVT testing postponed due the low Pb of the sample 1.05 Revised testing plan approved by client PVT testing results sent to client Chain of Sample Custody The samples collected from the well 1 Q-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. • WCP Oilphase-DBR 7 Job #:200500199 • Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Installation: - Job #: 200500199 RESULTS AND DISCUSSIONS Fluids Preparation and Analysis Six bottomhole samples collected during MDT operations were transferred to Oilphase-DBR. One sample from the D Santl of well 10-101 was recovered, along with five B-Sand samples. The well and formation data with their respective reservoir conditions for 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 1-day of homogenization, sample validation tests were conducted to evaluate the validity of the samples. Some sample-quality issues were observed, making the received fluids unrepresentative for use in PVT analysis as received. The reservoir fluid and stock-tank oil properties for all the samples are presented in Tables 4 and 5. Reservoir Fluid Analysis The gas and liquid from zero flash were subjected to chromatography and their compositions were determined. These compositions were recombined mathematically according to single-stage flash Gas-Oil Ratio (GOR) to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Table 6, 8, 10, 12 and 14. 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 7, 9, 11, 13 and 15. Sample 1.01, when pushed out from the top of the cylinder, appeared clear, without any traces of oil. • Sample 1.10 was chosen for the de-emulsification. After the de-emulsification, the laboratory collected 60 cc water and a 30-cc mixture of sediment and oil from the bottom of the cylinder. Drainage of sediment was stopped after 30 cc, because no progressive clarificaton of the oil was evident. The BS&W from the supernatant oil was 0.5°!°. Due to limited sample volume in sample 1.10, sample 1.05 was chosen for demulsification prior to continuing with PVT testing. After the demulsification, 180 cc of water and sediment were drained. The water content from the top of the cylinder was 0.2 wt%, while the water content from the bottom was 5.2 wt%. The top part of sample 1.05 was considered valid for the PVT testing. However, during the CCE testing on de-emulsified sample 1.05 at the field-report temperature (72 °F-, the saturation point was found to be 896 psia. This was close to the reported sampling pressure of 915 psia, which is inconsistent with expected saturation point of 1450 psia. Therefore, sample 1.05 may have been depleted during sampling and was in fact not representative for further testing. After discussing with client, an equation of state simulation was used to predict the composition of gas depleted from sample 1.05. A synthetic gas mixture was prepared. 200 cc of the supernatant from 1.05 was transferred to another cylinder, and the BS&W was measured. The BS&W was zero. The transferred liquid was 'saturated' with the synthetic gas to the specified reservoir pressure, for use in PVT analysis. The conditioned sample 1.05 had a bubble point of 1390 psia at 67°F. However, a compositional check revealed a possibility of contamination with C10 and C11, possibly from asolvent-rinse performed by a third party. • WCP Oilphase-DBR 8 Job #: ZOOri00199 • CIieM: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Installation: - Job #: 200500199 After discussion with the client, sample 1.05 was blown down and sample 1.06 was used to replace sample 1.05. De-emulsification was conducted. The laboratory drained out 250 cc water and sediment, and checked the water content from the top, which was nil. 200 cc was transferred and verified to contain zero water and sediment. Finally, as with sample 1.05, sample 1.06 was 'saturated' with a synthetic gas at Tres & Pres. The bubble point of this revised fluid was measured to be 1399 psia. The composition of this revised fluid was measured and further PVT testing was conducted. • WCP Oilphase-DBR 9 Job #: 20Q50U199 CIieM: ConocoPhillips Field: West Sak Well: 1Q-101 Sand: West Sak B Sch~umberger Installation: - Job #: 200500199 Table 1: Well and Sample Identitlcation • Client: ConocoPhillips Job# 200500199 Field: West Sak Well: 1Q-101 Sample ID Chamber # Zone Sampling Date Opening Pres. Reservoir Conditions in the field Pressure Temperature Depth ~psia/°F) (psia) (°F) 1ft) 1.01 MPSR 1399 D Sand 25/11/2005 6515 /100 1,417 72 4188 1.05 MRSC 242 B Sand 26/11/2005 6515 /100 1,450 67 4293 1.06 MRSC 242 B Sand 11/26/05 0:00 6515 /100 1,450 67 4293 1.09 SPMC 255 B Sand 26/11/2005 6515 /100 1,450 67 4293 1.10 SPMC 233 B Sand 26/11/2005 6515 /100 1,450 67 4293 1.11 SPMC 162 B Sand 26/11/2005 6515 /100 1,450 67 4293 Table 2: Well Position Data Well Name Strat Name Latitude Longitude X Loc Y Loc 1Q -101 SURFACE 70.367893064 -149.771816043 1668496.76 5984050.34 1 Q -101 WEST SAK D 70.372893257 -149.761299336 1669783.72 5985884.93 1Q -101 WEST SAK B 70.373103083 -149.760874219 1669835.58 5985961.64 1 Q -101 WEST SAK A3 70.373307475 -149.760473542 1669885.31 5986037.09 1 Q -101 WEST SAK A2 70.373533681 -149.760040087 1669938.45 5986120.22 WCP Oilphase-DBR 10 Job #:200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Installation: - Job #: 200500199 I aide 3: sampling antl I ranster summary • • Sample ID Chamber # Opening conditions in the field Transfer Cylinder ID Closing conditions in the field Opening conditions in the Lab Water Content Before De-emulsi. Transferred Sample Volume (psia/°F~ (psia/°F) (psia/°F) (wt%~ (cc- ~, 1.01 MPSA 1399 6515 /100 CSB 14326-QA 15/61 415/73 N/A 420 1.05 MRSC 242 6515 /100 CSB 14312-QA 215/61 1015/73 1.0 600 1.06 MRSC 242 6515 /100 CSB14332-QA 215/61 1000/72 N/D 600 1.09 SPMC 255 6515 /100 SSB 18140-QA 6015/61 6515/73 1.9 240 1.10 SPMC 233 6515 /100 SSB 11281-MA 6015/61 6515/73 1.7 230 1.11 SPMC 162 6515 /100 SSB 11878-QA 6015/61 6515/73 1.6 240 WCP Oilphase-DBR 11 Job #:200500199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Installation: - Job #: 200500199 I aide 4: Keservoir rluia rropernes • Zero Flash Saturation Molar Mass of Monophasic Sample ID Cylinder# Depth GOR* Bo** Pressure monophasic fluid*** at Tres fluid contamination Ift) Iscf/stb) (psia) % (w/w) 1.05 CSB 14312-QA 4,293 119 896 275.2 - 1.06 CSB 14332-QA 4,293 117 278.6 - 1.09 SSB 18140-QA 4,293 133 272.4 - 1.10 SSB 11281-MA 4,293 120 274.5 - 1.11 SSB 11878-QA 4,293 122 280.5 - 1.05 C**** CSB 7798-QA 4,293 175 1390 239.0 4.1 1.06 C**** CSB 11797-QA 4,293 173 1.051 1399 244.9 - * Flasher) aas vnlnma Isrfl oar harral of stork tank linuiri Cal Rn°F ** Volume of live ail at it's bubble point pressure per flashed stock tank liquid volume @ 60°f *** Calculated from oil-based mud contamination in STO **** Conditioned sample. Saturated with syn gas. Table 5: Stock-Tank Oil Properties STO Properties Sample ID Cylinder # Depth Molar Mass Density API*** Unknown Contamination Iftl 19/cc) % Iw/wl 1.05 CSB 14312-QA 4,293 364.3 0.9448 18.3 - 1.06 CSB 14332-QA 4,293 367.7 0.9469* 17.9 - 1.09 SSB 18140-QA 4,293 373.3 0.9472 17.9 - 1.10 SSB 11281-MA 4,293 364.2 0.9453* 18.2 - 1.11 SSB 11878-QA 4,293 376.3 0.9480 17.8 - 1.05 C** CSB 7798-QA 4,293 347.1 0.9404* 19.0 4.2 1.06 C** CSB 11797-OA 4,293 356.0 0.9458* 18.1 - *After the de-emulsification ** Conditioned sample. Saturated with syn gas. ***Oilphase-DBR's calculation is API =141.5/Density -131.5. WCP Oilphase-DBR 12 Job #: 200''.100799 • Client: ConocoPhillips Field: West Sak Welt: 10-101 Sand: West Sak B Schlumberger Table 6: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.05) Sample 1.05; Cylinder CSB 14312-QA; Depth 4293 ft. MD • Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.76 0.30 0.00 0.00 0.01 0.08 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.02 0.63 0.00 0.00 0.02 0.16 Methane 16.04 89.81 96.21 0.00 0.00 1.44 24.69 Ethane 30.07 1.84 1.05 0.00 0.00 0.03 0.27 Propane 44.10 1.26 0.49 0.02 0.13 0.04 0.22 I -Butane 58.12 1.62 0.48 0.03 0.19 0.06 0.27 N -Butane 58.12 0.77 0.23 0.02 0.16 0.04 0.17 I -Pentane 72.15 1.03 0.25 0.06 0.33 0.08 0.31 N -Pentane 72.15 0.36 0.09 0.02 0.12 0.03 0.11 C6 84.00 0.68 0.14 0.23 1.00 0.24 0.78 M-C-Pentane 84.16 0.09 0.02 0.03 0.12 0.03 0.09 Benzene 78.11 0.01 0.00 0.01 0.04 0.01 0.03 Cyclohexane 84.16 0.04 0.01 0.03 0.15 0.03 0.11 C7 96.00 0.26 0.05 0.39 1.47 0.39 1.11 M-C-Hexane 98.19 0.08 0.01 0.06 0.21 0.06 0.16 Toluene 92.14 0.02 0.00 D.03 0.13 0.03 0.10 C8 107.00 0.18 0.03 0.44 1.49 0.43 1.12 E-Benzene 106.17 0.01 0.00 0.03 0.10 0.03 0.07 M/P-Xylene 106.17 0.01 0.00 0.03 0.11 0.03 0.08 0-Xylene 106.17 0.00 0.00 0.03 0.12 0.03 0.09 C9 121.00 0.09 0.01 0.60 1.81 0.59 1.35 C10 134.00 0.05 0.01 1.02 2.77 1.01 2.06 C11 147.00 0.00 0.00 1.40 3.47 1.38 2.58 C12 161.00 0.00 0.00 1.95 4.42 1.92 3.29 C13 175.00 0.00 0.00 2.30 4.78 2.26 3.55 G14 190.00 0.00 0.00 3.07 5.89 3.02 4.38 C15 206.00 0.00 0.00 2.76 4.87 2.71 3.62 C16 222.00 3.05 5.00 3.00 3.72 C17 237.00 2.88 4.43 2.84 3.29 C18 251.00 2.99 4.34 2.94 3.22 C19 263.00 2.90 4.01 2.85 2.98 C20 275.00 2.67 3.54 2.63 2.63 C21 291.00 2.73 3.42 2.69 2.54 C22 300.00 2.69 3.27 2.65 2.43 C23 312.00 2.01 2.35 1.98 1.75 C24 324.00 2.18 2.45 2.14 1.82 C25 337.00 2.18 2.36 2.14 1.75 C26 349.00 1.77 1.85 1.75 1.38 C27 360.00 2.22 2.25 2.19 1.67 C28 372.00 1.94 1.90 1.91 1.41 C29 382.00 1.55 1.48 1.52 1.10 C30 394.00 1.72 1.59 1.69 1.18 C31 404.00 1.27 1.14 1.25 0.85 C32 415.00 1.43 1.26 1.41 0.93 C33 426.00 1.14 0.98 1.13 0.73 C34 437.00 0.91 0.76 0.89 0.56 C35 445.00 0.61 0.50 0.60 0.37 C36+ 940.00 44.60 17.28 43.88 12.85 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.19 364.31 275.22 MOLE RATIO 0.2566 0.7434 WCP Oilphase-DBR Job #: 200500199 • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlum4erger Table 7: Calculated Fluid Properties Sample 1.05; Cylinder CSB 14312-QA: Depth 4293 ft. MD • • Pro erties Flashed Gas Flashed Liquid Monophasic fluid Cn+ Composition Mass % Mole % Mass °k Mole % Mass % Mole C7+ 0.85 0.14 99.61 98.08 98.03 72.95 C12+ 0.00 0.00 95.51 86.11 93.98 64.01 CZO+ - - 73.62 48.36 72.44 35.95 C30+ - - 51.67 23.50 50.84 17.47 C36+ - - 44.60 17.28 43.88 12.85 Molar Mass C7+ 100.45 369.99 369.85 C12+ 167.18 404.09 404.09 C20+ - 554.57 554.57 C30+ - 800.91 800.91 C36+ - 940.00 940.00 Density C7+ - 0.9466 - C12+ - 0.9559 0.9559 C20+ - 0.9976 0.9976 C30+ 1.0553 1.0553 C36+ 1.0814 1.0814 Fluid at 60°F 0.9448 Gas Gravity (Air =1) 0.593 Dry Gross Heat Content (BTU/scf) 1,056 Wet Gross Heat Content~BTU/scf 1,037 OBM Contamination Level (wt°k- - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 364.31 364.31 940.00 Density ~g/cm3) 0.9448 - 1.0814 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stbl 119 - STO Density (g/cm3) 0.9448 - STO API Gravity 18.3 - OBM Density Ig/cm3) X60°F - WCP Oilphase-DBR 14 Job #: 200500199 • i• • Client: ConocoPhillips Field: West Sak Well: t Q-101 Sand: West Sak B Schlumberger Figure 1: Stock Tank Oil Chromatogram (Sample 1.05) Sample 1.05; Cylinder CSB 14312-DA; Depth 4293 ft. MD N~ z 1.5 t 0.5 a 0 s -0.5 -1 -1.5 -2 -4 -3 -2 WCP Oilphase-DBR t 0 t 2 3 F 75 Job #:200500199 5 10 15 20 15 30 35 mirk Figure 2: k-Plot for Equilibrium Check (Sample 1.051 Sample 1.05; Cylinder CSB 14312-QA; Depth 4293 ft. MD • • • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 8: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.06) Sample 1.06; CViinder CSB 14332-QA; Depth 1450 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 1.28 0.49 0.00 0.00 0.02 0.13 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.51 0.92 0.00 0.00 0.02 0.23 Methane 16.04 91.17 96.61 0.00 0.00 1.41 24.57 Ethane 30.07 1.35 0.77 0.00 0.00 0.02 0.19 Propane 44.10 0.75 0.29 0.01 0.09 0.02 0.14 I -Butane 58.12 0.98 0.29 0.03 0.16 0.04 0.19 N -Butane 58.12 0.46 0.13 0.02 0.12 0.03 0.12 I -Pentane 72.15 0.70 0.16 0.06 0.31 0.07 0.27 N -Pentane 72.15 0.28 0.06 0.03 0.13 0.03 0.11 C6 84.00 0.58 0.12 0.15 0.67 0.16 0.53 M-G-Pentane 84.16 0.08 0.02 0.02 0.08 0.02 0.07 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.04 0.01 0.03 0.11 0.03 0.09 C7 96.00 0.26 0.05 0.22 0.84 0.22 0.64 M-C-Hexane 98.19 0.08 0.01 0.06 0.23 0.06 0.18 Toluene 92.14 0.04 0.01 0.04 0.16 0.04 0.12 C8 107.00 0.20 0.03 0.42 1.44 0.42 1.08 E-Benzene 106.17 0.01 0.00 0.04 0.12 0.04 0.09 M/P-Xylene 106.17 0.02 0.00 0.04 0.14 0.04 0.10 0-Xylene 106.17 0.01 0.00 0.04 0.13 0.04 0.10 C9 121.00 0.11 0.02 0.58 1.76 0.57 1.32 C10 134.00 0.07 0.01 1.02 2.81 1.01 2.10 C11 147.00 0.01 0.00 1.36 3.40 1.34 2.53 C12 161.00 0.00 0.00 1.86 4.24 1.83 3.16 C13 175.00 0.00 0.00 2.35 4.94 2.31 3.68 C14 190.00 0.00 0.00 2.62 5.07 2.58 3.78 C75 206.00 0.00 0.00 3.05 5.44 3.00 4.06 C16 222.00 2.81 4.66 2.77 3.47 C17 237.00 3.06 4.75 3.01 3.54 C18 251.00 2.84 4.16 2.79 3.10 C19 263.00 3.00 4.19 2.95 3.12 C20 275.00 2.99 4.00 2.94 2.98 C21 291.00 2.70 3.41 2.66 2.54 C22 300.00 2.62 3.21 2.58 2.39 C23 312.00 2.33 2.75 2.30 2.05 C24 324.00 2.31 2.62 2.28 1.96 C25 337.00 1.97 2.15 1.94 1.61 C26 349.00 2.07 2.19 2.04 1.63 C27 360.00 1.90 1.94 1.87 1.45 C28 372.00 1.95 1.93 1.92 1.44 C29 382.00 2.00 1.92 1.97 1.43 C30 394.00 1.61 1.51 1.59 1.12 C31 404.00 1.36 1.23 1.33 0.92 C32 415.00 1.30 1.15 1.28 0.86 C33 426.00 1.14 0.99 1.12 0.74 C34 437.00 0.96 0.80 0.94 0.60 C35 445.00 1.20 0.99 1.18 0.74 C36+ 948.00 43.84 17.01 43.16 12.68 Total 700.00 100.00 100.00 100.00 700.00 100.00 MW 17.00 367.75 278.55 MOLE RATIO 0.2543 0.7457 WCP Oilphase-DBR Job #:200500199 • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlamberger Table 9: Calculated Fluid Properties Sample 1.06; Cylinder CSB 14332-QA; Depth 1450 ft. MD • Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.94 0.16 99.71 98.52 98.17 73.51 C12+ 0.00 0.00 95.84 87.25 94.35 65.06 C20+ - - 74.26 49.80 73.10 37.14 C30+ - - 51.40 23.68 50.61 17.66 C36+ - - 43.84 17.01 43.16 12.68 Molar Mass C7+ 101.55 372.18 372.03 C12+ 171.64 403.95 403.95 C20+ - 548.29 548.29 C30+ - 798.40 798.40 C36+ - 948.00 948.00 Density C7+ - 0.9483 - C12+ - 0.9568 0.9568 C20+ - 0.9978 0.9978 C30+ 1.0584 1.0584 C36+ 1.0872 1.0872 Fluid at 60°F 0.9469 Gas Gravity (Air =1 ~ 0.587 Dry Gross Heat Content (BTU/scfl 1,036 Wet Gross Heat Content (BTU/scf 1,018 OBM Contamination Level (wt°kl - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 367.75 367.75 948.00 Density 19/cm31 0.9469 - 1.0872 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 117 - STO Density (g/cm3) 0.9469 - STO API Gravity 17.9 - OBM Density Ig/cm3)0360°F - WCP Oilphase-DBR Job #: 200500199 Client: ConocoPhilli s Field: WestSak Well: 111-101 Sand: WestSak B P Schlumberger Figure 3: Stock Tank Oil Chromatogram (Sample 1.06) Sample 1.06; Cvlinder CSB 14332-QA; Depth 1450 ft. MD FIDt A, (F:@1~ ATAW05001AA4CY14332 P) Noml. JOB 200500199 CONOCO PHILLIPS 1.06 CSB 14332-QA 250 RF FLASH CYLINDER 2(10 150 100 50 ~' U ~ ,~,m ~ m m o~N,,~~N,~rmm C ~ lD U7 NNNNNNNNyN~`("ky~~ p 0 ~ ~ C u® t`u ~ 0] ~~ o c U U c ~ c ~ ~ ~Ucccc~~cc~~~~~-t~~~ ~~ F ~ ~o~ ~ ~ ~ c ~ _- ---_ - y O 111 0 35 mi 0 5 10 15 20 25 30 • • WCP Oilphase-DBR 16 Job #: 200500199 Figure 4: k-Plot for Equilibrium Check (Sample 1.061 Sample 1.06; Cylinder CSB 14332-QA; Depth 1450 ft. MD • Client: ConocoPhillips Field: WestSak Well: 10-101 Sand: West Sak B Schlomberger Table 10: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.09) Sample 1.09; Cylinder SSB 18140-QA; Depth 4293 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.48 0.19 0.00 0.00 0.01 0.05 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 2.32 1.42 0.00 0.00 0.04 0.40 Methane 16.04 89.42 95.76 0.00 0.00 1.60 27.13 Ethane 30.07 1.74 1.00 0.00 0.00 0.03 0.28 Propane 44.10 1.11 0.43 0.02 0.15 0.04 0.23 I -Butane 58.12 1.36 0.40 0.03 0.20 0.05 0.26 N -Butane 58.12 0.66 0.20 0.03 0.17 0.04 0.17 I -Pentane 72.15 0.92 0.22 0.07 0.34 0.08 0.30 N -Pentane 72.15 0.34 0.08 0.02 0.13 0.03 0.11 C6 84.00 0.70 0.14 0.24 1.07 0.25 0.81 M-C-Pentane 84.16 0.10 0.02 0.03 0.11 0.03 0.09 Benzene 78.11 0.01 0.00 0.01 0.04 0.01 0.03 Cyclohexane 84.16 0.04 0.01 0.03 0.15 0.03 0.11 C7 96.00 0.29 0.05 0.39 1.50 0.38 1.09 M-C-Hexane 98.19 0.09 0.02 0.05 0.21 0.05 0.15 Toluene 92.14 0.02 0.00 0.03 0.13 0.03 0.09 C8 107.00 0.20 0.03 0.43 1.51 0.43 1.09 E-Benzene 106.17 0.01 0.00 0.03 0.10 0.03 0.07 M/P-Xylene 106.17 0.01 0.00 0.03 0.11 0.03 0.08 0-Xylene 106.17 0.00 0.00 0.03 0.12 0.03 0.09 C9 121.00 0.10 0.01 0.61 1.87 0.60 1.35 C10 134.00 0.05 0.01 1.01 2.80 0.99 2.01 C11 147.00 0.00 0.00 1.37 3.49 1.35 2.50 C12 161.00 0.00 0.00 1.91 4.43 1.88 3.17 C13 175.00 0.00 0.00 2.38 5.09 2.34 3.64 C14 190.00 0.00 0.00 2.84 5.59 2.79 4.00 C15 206.00 0.00 0.00 2.68 4.85 2.63 3.48 C76 222.00 2.96 4.97 2.90 3.56 C17 237.00 2.82 4.44 2.77 3.18 C18 251.00 2.89 4.29 2.84 3.08 C19 263.00 2.80 3.98 2.75 2.85 C20 275.00 2.71 3.68 2.67 2.64 C21 291.00 2.50 3.21 2.46 2.30 C22 300.00 2.58 3.22 2.54 2.30 C23 312.00 2.06 2.46 2.02 1.77 C24 324.00 1.98 2.28 1.94 1.63 C25 337.00 2.09 2.31 2.05 1.66 C26 349.00 1.76 1.89 1.73 1.35 C27 360.00 1.90 1.97 1.86 1.41 C28 372.00 1.77 1.77 1.74 1.27 C29 382.00 1.73 1.69 1.70 1.21 C30 394.00 1.19 1.13 1.17 0.81 C31 404.00 1.11 1.02 1.09 0.73 C32 415.00 1.23 1.11 1.21 0.80 C33 426.00 1.00 0.87 0.98 0.63 C34 437.00 0.62 0.53 0.61 0.38 C35 445.00 0.57 0.48 0.56 0.34 C36+ 955.00 47.45 18.55 46.61 13.29 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.18 373.27 272.39 MOLE RATIO 0.2833 0.7167 WCP Oilphase-DBR 19 Job #:200500199 • • • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Scblumberger Table 11: Calculated Fluid Properties Sample 1.09: Cylinder SSB 18140-QA: Depth 4293 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole G7+ 0.93 0.16 99.60 97.95 97.83 70.25 C12+ 0.00 0.00 95.54 85.81 93.84 61.50 C20+ - - 74.26 48.17 72.93 34.53 C30+ - - 53.17 23.69 52.22 16.98 C36+ - - 47.45 18.55 46.61 13.29 Molar Mass C7+ 100.27 379.52 379.34 C12+ 168.51 415.58 415.58 C20+ - 575.38 575.38 C30+ - 837.85 837.85 C36+ - 955.00 955.00 Density C7+ - 0.9491 - C12+ - 0.9584 0.9584 C20+ - 0.9996 0.9996 C30+ 1.0545 1.0545 C36+ 1.0740 1.0740 Fluid at 60°F 0.9472 Gas Gravity (Air =11 0.593 Dry Gross Heat ContentlBTU/scf) 1,045 Wet Grass Heat Content (BTU/scf 1,027 OBM Contamination Level (Wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 373.27 373.27 955.00 Density (g/cm3) 0.9472 - 1.0740 Single Stage Flash Data Original STO De-Contaminated GOB (scf/stbl 133 - STO Density (g/cm3) 0.9472 - STO API Gravity 17.9 - OBM Density (g/cm3) Q60°F - WCP Olilphase-DBR k~ Job #: 2~',r00199 • Client: ConocoPhillips Field: WestSak Well: 1 Q-101 Sand: West Sak B Schlumberger Figure 5: Stock Tank Oil Chromatogram (Sample 1.09) Sample 1.09; Cylinder SSB 18140-QA; Depth 4293 ft. MD Norm. 250 iID1 A, (F' 121DATA'005001991CY18140.D1 200 JOB 200500199 CONOCO PHILLIPS 1.09 SS 18140-QA 15o RF FLASH CYLINDER 100 50 ~[1 U N ~ ~ m m Rirvrvmv~fD~Wr`~,c~t*imn m e um ~ ° ~_ ~ c cUUCCUCC~UU~ c c c=c U c ~ ~ m ~XU ~ U U U ` c ~~ ~~ T ,,~y ~, 11 ' ~ II I ' ~ `~ ~ ` t( it w y ~ (` c I,l ,i_111 1WI ~OIL k~,~, ., . ~., ~k.,r~ fl l ' fflllllllJ . 0 0 5 10 15 20 25 30 35 • • Figure 6: k-Plot for Equilibrium Check Sample 1.09) Sample 1.09; Cylinder SSB 18140-QA; Depth 4293 ft. MD 2 1.5 1 0.5 6 Y 0 s 0.5 1.5 I -2 l WCP Oilphase-DBR • C3 • nC4 • C6 . C7 . cfi • C9 • C10 - - _ -4 -3 -2 1 0 1 2 21 Job #: 200500199 • Client: ConocoPhillips Field: WestSak Well: 1 Q-101 Sand: West Sak B Schlumberger Table 12: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.10) Sample 1.10; Cylinder SSB 11281-MA: Depth 4293 ft. MD • Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) Wi % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.53 0.21 0.00 0.00 0.01 0.05 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.01 0.62 0.00 0.00 0.02 0.16 Methane 16.04 90.07 96.37 0.00 0.00 1.46 24.93 Ethane 30.07 1.80 1.03 0.00 0.00 0.03 0.27 Propane 44.10 1.21 0.47 0.02 0.19 0.04 0.26 I -Butane 58.12 1.53 0.45 0.04 0.22 0.06 0.28 N -Butane 58.12 0.75 0.22 0.02 D.14 D.03 0.16 I -Pentane 72.15 1.00 0.24 0.07 0.35 0.08 0.32 N -Pentane 72.15 0.37 0.09 0.03 0.14 0.03 0.13 C6 84.00 0.69 0.14 0.21 0.89 0.21 0.70 M-C-Pentane 84.16 0.09 0.02 0.03 0.12 0.03 0.09 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.04 0.01 0.03 0.14 0.03 0.10 C7 96.00 0.28 0.05 0.32 1.22 0.32 0.92 M-C-Hexane 98.19 0.08 0.01 0.06 0.21 0.06 0.16 Toluene 92.14 0.02 0.00 0.02 0.06 0.02 0.05 C8 107.00 0.19 0.03 0.37 1.28 0.37 0.95 E-Benzene 106.17 0.01 0.00 0.07 0.25 0.07 0.19 M/P-Xylene 106.17 0.01 0.00 0.05 0.17 0.05 0.13 0-Xylene 106.17 0.00 0.00 0.02 0.07 0.02 0.05 C9 121.00 0.10 0.01 0.52 1.58 0.52 1.17 C10 134.00 0.07 0.01 1.04 2.82 1.02 2.09 C11 147.00 0.05 0.01 1.35 3.34 1.33 2.48 C12 161.00 0.09 0.01 1.86 4.21 1.83 3.13 C13 175.00 0.00 0.00 2.36 4.90 Z.32 3.64 C14 190.00 0.00 0.00 2.69 5.16 2.65 3.82 C15 206.00 0.00 0.00 3.10 5.48 3.05 4.06 Ct6 222.00 3.09 5.06 3.04 3.75 C17 237.00 2.91 4.47 2.86 3.31 C18 251.00 3.07 4.45 3.02 3.30 C19 263.00 2.93 4.06 2.88 3.01 CZO 275.00 2.91 3.85 2.86 2.85 C21 291.00 2.61 3.26 2.57 2.42 C22 300.00 2.81 3.41 2.77 2.53 C23 312.00 2.23 2.60 2.19 1.93 C24 324.00 2.35 2.64 2.31 1.96 C25 337.00 2.05 2.21 2.01 1.64 C26 349.00 1.90 1.98 1.87 1.47 C27 360.00 1.79 1.81 1.76 1.34 C28 372.00 1.96 1.92 1.93 1.42 C29 382.00 2.D1 1.92 1.98 1.42 C30 394.00 1.44 1.33 1.41 0.99 C31 404.00 1.64 1.48 1.61 1.10 C32 415.00 1.23 1.08 1.21 0.80 C33 426.00 1.20 1.03 1.18 0.76 C34 437.00 1.08 0.90 1.06 0.67 C35 445.00 0.63 0.52 0.62 0.38 C36+ 939.00 43.89 17.03 43.18 12.62 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.16 364.24 274.47 MOLE RATIO 0.2587 0.7413 WCP Oilphase-DBR Job #: 200500199 • • • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schf~mberger Table 13: Calculated Fluid Properties Sample 1.10; Cylinder SSB 11281-MA: Depth 4293 ft. MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass °1° Mole % Mass °f° Mofe % Mass % Mole C7+ 1.03 0.17 99.62 98.06 98.02 72.74 C12+ 0.09 0.01 95.73 86.77 94.18 64.33 C20+ - - 73.73 48.97 72.53 36.31 C30+ - - 51.11 23.36 50.29 17.32 C36+ - - 43.89 17.03 43.18 12.62 Molar Mass C7+ 105.71 370.02 369.86 C12+ 161.25 401.84 401.83 C20+ - 548.35 548.35 C30+ - 797.05 797.05 C36+ - 939.00 939.00 Density C7+ - 0.9472 - C12+ - 0.9558 0.9558 C20+ - 0.9974 0.9974 C30+ 1.0576 1.0576 C36+ 1.0852 1.0852 Fluid at 60°F 0.9453 Gas Gravity (Air= 1) 0.593 Dry Gross Heat ContentlBTU/scfl 1,057 Wet Gross Heat Content IBTU/scf 1,038 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 364.24 364.24 939.00 Density Ig/cm3) 0.9453 - 1.0852 Singlo Stage Flash Data Original STO De-Contaminated GOR Iscf/stbl 120 - STO Density (g/cm31 0.9453 - STO API Gravity 18.2 - OBM Density (g/cm3) CQ360°F - WCP Oilphase-DBR Job #:200500199 • Client: ConocoPhillips Field: West Sak Well: 1 Q-10t Sand: West Sak B Schlumberger Figure 7: Stock Tank Oil Chromatogram (Sample 1.10) Sample 1.10; Cylinder SSB 11281-MA; Depth 4293 ft. MD fID1 A. (E 1HPl:HE~~1?V~4iab0F001991i,r11"L81 D) Norm. 250 200 JOB 200500199 CONOCO PHILLIPS 1.10 SSB 11281-MA RF FLASH CYLINDER ~w ~m 50 ULQ Ol O~ N N[D^ ~MRSP E~ d C C v ut l0 n W .-[V (v rvlm`!tP`lfVf`l~~ 1`TTm~ ~m rv m ~ i UOOO ` < OOOC~ ~w~ ~• m $rm ~ ~ U U c c U c c ~ m c , ~ c~ ~r~ ~ ~ n ll -_- '. ~ ~.~_,n~,...ree ,.~ ltl.: II i ~ ~l I ' 1G 16 ZO Z5 30 36 • • Figure 8: k-Plot for Equilibrium Check (Sample 1.10) Sample 1.10; Cylinder SSB 11281-MA; Depth 4293 ft. MD z 1.5 1 0.5 6 0 a s -0.5 -t -1.5 -2 -4 WCP Oilphase-DBR F 24 Job #: 200500199 -3 -2 -1 0 1 2 3 • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Scblumberger Table 14: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.11) Sample 1.11; Cylinder SSB 11878-QA; Depth 4293 ft. MD • Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) Wi % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.45 0.18 0.00 0.00 0.01 0.05 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.05 0.65 0.00 0.00 0.02 0.17 Methane 16.04 89.50 96.19 0.00 0.00 1.47 25.69 Ethane 30.07 1.79 1.03 0.00 0.00 0.03 0.27 Propane 44.10 1.22 0.48 0.01 0.10 0.03 0.20 I -Butane 58.12 1.57 0.47 0.03 0.17 0.05 0.25 N -Butane 58.12 0.77 0.23 0.02 0.13 0.03 0.16 I -Pentane 72.15 1.05 0.25 0.06 0.30 0.07 0.29 N -Pentane 72.15 0.88 0.21 0.06 0.30 0.07 0.28 C6 84.00 0.85 0.17 0.23 1.03 0.24 0.80 M-C-Pentane 84.16 0.09 0.02 0.02 0.10 0.02 0.08 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.04 0.01 0.03 0.13 0.03 0.10 C7 96.00 0.27 0.05 0.32 1.27 0.32 0.94 M-C-Hexane 98.19 0.09 0.02 0.05 0.20 0.05 0.15 Toluene 92.14 0.02 0.00 0.03 0.14 0.03 0.10 C8 107.00 0.18 0.03 0.39 1.39 0.39 1.02 E-Benzene 106.17 0.01 0.00 0.03 0.09 0.03 0.07 M/P-Xylene 106.17 0.01 0.00 0.03 0.10 0.03 0.08 0-Xylene 106.17 0.00 0.00 0.03 0.11 0.03 0.08 C9 121.00 0.09 0.01 0.55 1.70 0.54 1.25 C10 134.00 0.05 0.01 0.93 2.62 0.92 1.92 C11 147.00 0.01 0.00 1.29 3.30 1.27 2.42 C12 161.00 0.00 0.00 1.80 4.22 1.77 3.09 C13 175.00 0.00 0.00 2.26 4.87 2.23 3.57 C14 190.00 0.00 0.00 2.47 4.90 2.43 3.59 C15 206.00 0.00 0.00 2.83 5.18 2.79 3.79 C16 222.00 2.88 4.89 2.84 3.58 C17 237.00 2.76 4.39 2.72 3.22 C18 251.00 2.86 4.30 2.82 3.15 C19 263.00 2.80 4.00 2.75 2.93 C20 275.00 2.72 3.72 2.67 2.73 C21 291.00 2.53 3.27 2.49 2.40 C22 300.00 2.60 3.26 2.55 2.39 C23 312.00 2.12 2.55 2.08 1.87 C24 324.00 1.97 2.29 1.94 1.68 C25 337.00 2.13 2.38 2.10 1.75 C26 349.00 1.94 2.09 1.91 1.53 C27 360.00 2.03 2.12 1.99 1.55 C28 372.00 1.99 2.01 1.96 1.47 C29 382.00 1.99 1.96 1.96 1.44 C30 394.00 1.42 1.36 1.40 1.00 C31 404.00 1.59 1.48 1.57 1.09 C32 415.00 1.22 1.11 1.20 0.81 C33 426.00 1.23 1.08 1.21 0.79 C34 437.00 0.96 0.83 0.95 0.61 C35 445.00 0.43 0.36 0.42 0.27 C36+ 960.00 46.33 18.16 45.57 13.31 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.24 376.34 280.45 MOLE RATIO 0.2670 0.7330 WCP Oilphase-DBR Job #:200500199 • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Scblumberger Table 15: Calculated Fluid Properties Sample 1.11; Cylinder SSB 11878-I1A; Depth 4293 ft. MD • • Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.86 0.15 99.60 97.97 97.98 71.85 C12+ 0.00 0.00 95.88 86.77 94.30 63.60 C20+ - - 75.20 50.04 73.96 36.68 C30+ - - 53.19 24.39 52.32 17.88 C36+ - - 46.33 18.16 45.57 13.31 Molar Mass C7+ 100.09 382.60 382.45 C12+ 168.98 415.82 415.82 C20+ - 565.51 565.51 C30+ - 820.72 820.72 C36+ - 960.00 960.00 Density C7+ - 0.9499 - C12+ - 0.9584 0.9584 C20+ - 0.9976 0.9976 C30+ 1.0536 1.0536 C36+ 1.0776 1.0776 Fluid at 60°F 0.9480 Gas Gravity iAir=li 0.595 Dry Gross Heat Content (BTU/scf) 1,061 Wet Gross Heat Content (BTU/scf 1,043 OBM Contamination Level (vvt°~) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 376.34 376.34 960.00 Densityig/cm3i 0.9480 - 1.0776 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 122 - STODensity (g/cm3) 0.9480 - STO API Gravity 17.8 - OBM Density (g/cm3) C~60°F - WCP Oilphase-DBR 26 Job #: 200500199 • Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Figure 9: Stock Tank Oil Chromatogram (Sample 1.11) Sample 1.11; Cylinder SSB 11878-QA; Depth 4293 ft. MD Nome. vio+a rr ~z~oarano5ao+aa+cr+s~eoi 250 200 JOB 200500199 CONOCO PHILLIPS 1.11 SSB 11878-QA RF FLASH CYLINDER +~ +oo U m _o o ~`+m mmno n O ~ M.m y I(] ~ fVYNU ~ ~ UIJU CC (i iJ v ~ T o rv m V U U c U `> ~ c c c ~~-t-U c~~ (~(~ p~t ~., l t ~ L t c - c~ il ~ I , l l ' I ~ ~~ ~~ m~~~__ c ~ ~ ~ C~vU c . ~ i ,_._ ~- aMM.-.a,~µ 11~~11L, Ill!I!l 0 0 5 +0 15 so z5 ao • Figure 10: k-Plotfor Equilibrium Check (Sample 1.11) Sample 1.11; Cylinder SSB 11878-QA; Depth 4293 ft. MD 1.5 0.5 Y O O! s -0.5 1.5 -2 • C3 • IC4 • nC4 5 • C6 ~ C7 • C8 s-C~- 4 3 2 1 0 1 2 3 F WCP Oilphase-DBR 27 Job #:200500199 Client: ConocoPhillips Field: West Sak Well: 1 D-101 Sand: West Sak B Schlumberger Table 16: Calculated Synthetic Gas Composition Table • • Composition MOLE Carbon Dioxide 0.14 Hydrogen Sulfide Nitrogen 2.21 Methane 97.28 Ethane 0.23 Propane 0.06 I -Butane 0.04 N -Butane 0.02 I -Pentane 0.01 N -Pentane 0.00 C6 0.01 Total 100.00 17: Physical Composition of the Syn Gas Prepared in tl Composition MOLE Carbon Dioxide 0.17 Hydrogen Sulfide 0.00 Nitrogen 2.19 Methane 97.32 Ethane 0.25 Propane 0.03 I-Butane 0.02 N -Butane 0.00 I-Pentane 0.00 N -Pentane 0.00 C6 0.00 Total 100.00 ie Lab WCP Oilphase-DBR 28 Job #: 200500199 • C • Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 D-101 Sand: West Sak B Contaminated 4.2 STO Basis, wt% Contaminated 4.1 RF Basis, wt% Table 18: C30+ Composition, GOR, °API, by Zero-flash (Sample 1.05 C) Sample 1.05 C; Cylinder CSB 7798-11A; Depth 4293 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.92 0.35 0.00 0.00 0.02 0.12 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.05 0.63 0.00 0.00 0.02 0.21 Methane 16.04 91.68 96.84 0.00 0.00 2.13 31.71 Ethane 30.07 1.56 0.88 0.00 0.00 0.04 0.29 Propane 44.10 0.90 0.35 O.D1 0.07 0.03 0.16 I -Butane 58.12 1.16 0.34 0.02 0.10 0.04 0.18 N -Butane 58.12 0.55 0.16 0.01 0.06 0.02 0.09 I -Pentane 72.15 0.75 0.18 0.04 0.19 0.06 0.18 N -Pentane 72.15 0.22 0.05 0.02 0.08 0.02 0.07 C6 84.00 0.52 0.10 0.19 0.77 0.20 0.56 M-C-Pentane 84.16 0.07 0.01 0.02 0.09 0.02 0.06 Benzene 78.11 0.01 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.03 0.01 0.03 0.11 0.03 0.07 C7 96.00 0.19 0.03 0.27 0.99 0.27 0.67 M-C-Hexane 98.19 0.06 0.01 0.05 0.17 0.05 0.11 Toluene 92.14 0.02 0.00 0.01 0.02 0.01 0.01 C8 107.00 0.12 0.02 0.37 1.20 0.36 0.81 E-Benzene 106.17 0.01 0.00 0.01 0.03 0.01 0.02 M/P-Xylene 106.17 0.01 0.00 0.01 0.02 0.01 0.02 0-Xylene 106.17 0.01 0.00 0.11 0.35 0.11 0.24 C9 121.00 0.07 0.01 0.66 1.88 0.64 1.27 C10 134.00 0.08 0.01 2.37 6.15 2.32 4.14 C11 147.00 0.03 0.00 3.99 9.43 3.90 6.34 C12 161.00 0.00 0.00 1.81 3.90 1.77 2.62 C13 175.D0 0.00 O.DO 2.19 4.35 2.14 2.92 C14 190.00 0.00 0.00 2.36 4.32 2.31 2.90 C15 206.00 0.00 0.00 2.73 4.59 2.66 3.09 C16 222.00 2.68 4.19 2.62 2.82 C17 237.00 2.59 3.80 2.53 2.55 C18 251.00 2.74 3.79 2.67 2.55 C19 263.00 2.63 3.47 2.57 2.34 C20 275.00 2.62 3.31 2.56 2.22 C21 291.00 2.43 2.90 2.38 1.95 C22 300.00 2.31 2.68 2.26 1.80 C23 312.00 2.11 2.35 2.06 1.58 C24 324.00 2.08 2.23 2.03 1.50 C25 337.00 1.96 2.02 1.91 1.36 C26 349.00 1.75 1.74 1.71 1.17 C27 360.00 1.71 1.65 1.67 1.11 C28 372.00 1.86 1.74 1.82 1.17 C29 382.00 1.80 1.63 1.75 1.10 C30 394.00 1.71 1.51 1.67 1.01 C31 404.00 1.56 1.34 1.52 0.90 C32 415.00 1.42 1.19 1.39 0.80 C33 426.00 1.26 1.D2 1.23 D.69 C34 437.00 1.18 0.93 1.15 0.63 C35 445.00 1.16 0.90 1.13 0.61 C36+ 895.00 43.19 16.75 42.19 11.27 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.95 347.14 239.01 MOLE RATIO 0.3275 0.6725 WCP Oilphase-DBR 29 Job #: 200500199 • • Client: ConocoPhillips Field: West Sak Schlumberger Well: 10-101 Sand: West Sak B Contaminated 4.2 STO Basis, wt% Contaminated 4.1 BF Basis, wt% Table 19: Calculated Fluid Properties Sample 1.~5 C: Cylinder CSB 7798-QA: Depth 4293 ft. MD Properties Flashed Gas Flashed Liquid Monophasic fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.70 0.12 99.72 98.72 97.42 66.43 C12+ 0.00 0.00 91.83 78.29 89.70 52.65 C2O+ - - 72.10 45.89 70.43 30.86 C3O+ - - 51.47 23.65 50.28 15.90 C36+ - - 43.19 16.75 42.19 11.27 Molar Mass C7+ 102.53 350.65 350.51 C12+ 161.00 407.19 407.19 C2O+ - 545.47 545.47 C3O+ - 755.55 755.55 C36+ - 895.00 895.00 Density C7+ - 0.9417 - C12+ - 0.9584 0.9584 C2O+ - 0.9976 0.9976 C3O+ 1.0518 1.0518 C36+ 1.0822 1.0822 Fluid at 60°F 0.9404 Gas Gravity (Air =1 ~ 0.585 Dry Gross Heat ContentlBTU/scf) 1,041 Wet Gross Heat Content (BTU/scf 1,023 Contamination Level (Wt%- 4.2 STO Basis 4.1 Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 347.14 347.14 895.00 Density (g/cm3) 0.9404 - 1.082 Single Stage flash Data Original STO De-Contaminated GOR (scf/stb) 175 N/D STO Density (g/cm3i 0.9404 N/D STO API Gravity 19.0 N/D Contamination Density (g/cm3) Q N/D WCP Olilphase-DBR Job #: Z00rrOO199 • Client: ConocoPhillips Field: WestSak Schlumberger Well: 10-101 Sand: West Sak B Contaminated 4.2 STO Basis, wt% Contaminated 4.1 BF Basis, wt% Figure 11: Stock Tank Oil Chromatogram (Sample 1.05 C) Sample 1.05 C; Cylinder CSB 7798 QA; Depth 4293 ft. MD (ID1 A, !E 'WP~HE~~4l0ATaV70500199GE%79d Dt Norm. 250 200 150 100 ~ U ~ ~ ~ ~ r` W m ~ryN ryNNNN~ o U UU ~ UU ~ 50 N a m m U UUUUU U c`-' ~ ~ C FT ^ rv U V U C C C C CCCCCCC C CCC C I I, ~T ~ J OJ $ ~L~ O I U U C C C . C.12 U C -7~ 0 0 5 10 15 2p 25 30 35 m. • Figure 12: k-Plot for Equilibrium Check (Sample 1.05 C) Sample 1.05 C; Cylinder CSB 7798-QA; Depth 4293 ft. MD 2.5 2 1.5 1 n 0.5 Y s o 0.5 _1 -1.5 -2 -4 3 2 1 0 1 2 3 F • WCP Oilphase-DBR 31 Job #: 200500199 • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Scblumberger Table Z0: C30+ Composition, GOR, °API, by Zero-Flash Sample 1.06 C) Sample 1.06 C; Cvlintler CSB 11797-QA; Depth 4293 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid Ig/moles WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxitle 44.01 1.79 0.72 0.00 0.00 0.04 0.24 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.86 0.54 0.00 0.00 0.02 0.18 Methane 16.04 86.22 94.92 0.00 0.00 2.04 31.16 Ethane 30.07 2.33 1.37 0.00 0.00 0.06 0.45 Propane 44.10 1.63 0.65 0.02 0.19 0.06 0.34 l -Butane 58.12 2.08 0.63 0.03 0.20 0.08 0.34 N -Butane 58.12 0.92 0.28 0.02 0.12 0.04 0.17 I -Pentane 72.15 1.27 0.31 0.07 0.33 0.09 0.32 N -Pentane 72.15 0.56 0.14 0.03 0.16 0.04 0.15 C6 84.00 0.94 0.20 0.16 0.66 0.17 0.51 M-C-Pentane 84.16 0.14 0.03 0.02 0.09 0.02 0.07 Benzene 78.11 0.02 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.06 0.01 0.03 0.11 0.03 0.08 C7 96.00 0.39 0.07 0.23 0.84 0.23 0.59 M-C-Hexane 98.19 0.13 0.02 0.06 0.22 D.O6 0.16 Toluene 92.14 0.08 0.02 0.12 0.45 0.12 0.31 C8 107.00 0.27 0.05 0.42 1.41 0.42 0.96 E-Benzene 106.17 0.01 0.00 0.04 0.14 0.04 0.09 M/P-Xylene 106.17 0.02 0.00 0.03 0.11 O.D3 0.07 0-Xylene 106.17 0.01 0.00 0.03 0.11 0.03 0.08 C9 121.00 0.16 0.02 0.57 1.67 0.56 1.13 C10 134.00 0.11 0.01 1.03 2.73 1.00 1.84 C71 147.00 0.01 0.00 1.38 3.34 1.34 2.24 C12 161.00 0.00 0.00 1.90 4.19 1.85 2.82 C13 175.00 0.00 0.00 2.41 4.90 2.35 3.29 C14 190.00 0.00 0.00 2.79 5.23 2.73 3.51 C15 206.00 0.00 0.00 3.05 5.27 2.98 3.54 C16 222.00 2.89 4.64 2.83 3.12 C17 237.00 3.17 4.76 3.09 3.20 C18 251.00 3.10 4.40 3.03 2.96 C19 263.00 3.07 4.16 3.00 2.79 C20 275.00 3.02 3.91 2.95 2.62 C21 291.00 2.99 3.65 2.91 2.45 C22 300.00 2.69 3.19 2.62 2.14 C23 312.00 2.52 2.87 2.46 1.93 C24 324.00 2.36 2.59 2.30 1.74 C25 337.00 2.20 2.32 2.15 1.56 C26 349.00 2.17 2.21 2.12 1.46 C27 360.00 2.15 2.13 2.10 1.43 C28 372.00 2.13 2.03 2.08 1.37 C29 382.00 2.13 1.98 2.07 1.33 C30 394.00 2.03 1.84 1.99 1.23 C31 404.00 1.55 1.36 1.51 0.92 C32 415.00 1.47 1.26 1.44 0.85 C33 426.00 1.36 1.14 1.33 0.76 C34 437.00 1.18 0.96 1.15 0.65 C35 445.00 1.06 0.84 1.03 0.57 C36+ 941.00 40.35 15.27 39.39 10.25 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.66 356.01 244.92 MOLE RATIO 0.3283 0.6717 WCP Oilphase-DBR Job #: 200500199 • Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlamberger Table 21: Calculated Fluid Properties Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD • Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 1.41 0.25 99.67 98.34 97.34 66.13 C12+ 0.01 0.00 95.71 87.10 93.45 58.50 C20+ - - 73.34 49.56 71.60 33.29 C30+ - - 49.00 22.67 47.84 15.23 C36+ - - 40.35 15.27 39.39 10.25 Molar Mass C7+ 101.08 360.82 360.50 C12+ 169.31 391.19 391.19 C20+ - 526.77 526.77 C30+ - 769.42 769.42 C36+ - 941.00 941.00 Density C7+ - 0.9474 - C12+ - 0.9560 0.9560 C20+ - 0.9987 0.9987 C30+ 1.0675 1.0675 C36+ 1.1065 1.1065 Fluid at 60°F 0.9458 Gas Gravity IAir =1) 0.610 Dry Gross Heat Content (BTU/scf) 1,072 Wet Gross Heat Content (BTU/scf 1,053 OBM Contamination Level (wt°k) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 356.01 356.01 941.00 Density Ig/cm3) 0.9458 - 1.1065 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stbl 173 - STO Density (g/cm3) 0.9458 - STO API Gravity 18.1 - OBM Density (g/cm3) Q60°F - WCP Oilphase-DBR 33 Job #: 200500199 • Client: ConocoPhillips Field: WestSak Well: 1 Q-101 Sand: West Sak B Schlumberger Figure 13: Stock Tank Oil Chromatogram (Sample 1.06 C) Sample 1.06 C: Cvlinder CSB 11797-DA: Depth 4293 ft. MD FID1 h„ iF921 D4?a4Ju5001p91CNt'Q7RD) Noim. JOB 200500199 CONOCO PHILLIPS 1.06 (conditioned) SSB 11797-QA ~ RF FLASH CELL 200 150 1~ dd N U cc 50 ~~ m m m o m N ~,~ ti m m o~Nmau~tflr~m~ M 0 C U7 ~ NNNNNNN IN~"Pl~~-~~ N ~ ; 7 ~ C p 3 yXN N Ol ~jUUUUUUUUU`-'=U~~~ ~ T p m~ 4 T~ O U U U C C C C C C C C CC C C C C~~ ~° ~ UNadXU U ~ c c~ c CC ~ C~ cU~pc [ c i I ~~ 1 1 I 0 3 30 35 mi 0 5 10 15 20 2 • z 1.5 1 a 0.5 Y s o -0.5 15 • iC4 • C3 • nG4 - - • ACAS • C6 ~ C7 • CB • C9 • C10 -4 3 -2 1 0 1 F Figure 14: k-Plot for Equilibrium Check (Sample 1.Oti C- Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD WCP Oilphase-DBR 34 2 3 Job #: 200500199 Client: ConocoPhillips Field; West Sak Well: 10-101 Sand: West Sak B Schlumberger Table 22: Summary of Results of Sample 1.06 C Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD • • Reservoir Conditions: Pressure: 1450 psia Temperature: 67 °F Summary of Fluid Properties: Bubble Point Pressure At Tres 1,399 psia Gas-Oil Ratio Single-stage Flash: 173 scf/stb Total Differential Liberation: scf/stb Total Separator Flash: 171 scf/stb Properties atli0°F STO °API Gas Gravity (Average) Single-stage STO: 18.1 0.610 Differential Liberation STO: Separator STO: 18.4 0.609 Pro ernes at Reservoir Conditions Viscosity: 152.0 cP Compressibillity (Col: 6.0 10 s/psi Density: 0.9216 g/cc Pro ernes at Saturation Conditions Viscosity: - cP Compressibillity ICoI: 6.0 10"6/psi Density: 0.9213 g/cc Formation Volume Factor @Pres & Tres ~Psat & Tres Single-stage Flash: 1.051 1.051 Total Differential Liberation: Total Separator Flash: 1.049 1.049 Note: Standard conditions are 14.696 psia and 60°F WCP Oilphase-DBR 35 Job #: 200ri00199 Client: ConocoPhillips weu: 1 n-101 PVT Analysis on Sample 1.06 C; Cylinder CSB 11797-OA; Depth 4293 ft. MD Constant Composition Expansion at Tres The CCE study was initiated by charging asub-sample of saturated or conditioned live reservoir fluid 1.06 into the PVT cell at a reservoir temperature of 67.0°F and at a pressure of 5,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 23. The pressure-volume 1P-V~ plots of the CCE data are presented in Figure 15. 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 1,399 psia at the reservoir temperature of 67.0 °F. Also, calculated relative volume and oil compressibility is presented in Table 23. As seen in the table, the compressibility of this oil is 6.0 x 10e-6 1/psia at the saturation pressure. Fie{d: West Sak Schlumberger Sand: West Sak B Table 23: Constant Composition Expansion at 67.0°F (Sample 1.06 C) Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD • Pressure (psia) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % Liquid (VlNtotal) Liquid Density (g/cm3) Y Function Compressibility (10"s/psia) 1 5015 0.9836 0.9367 3.3 2 4015 0.9872 0.9333 3.9 3 3015 0.9915 0.9293 4.6 4 2515 0.9939 0.9270 5.0 5 2015 0.9965 D.9246 5.5 6 1815 0.9976 0.9236 5.fi 7 1715 0.9981 0.9230 5.7 8 1615 0.9987 0.9225 5.8 Pi 1459 0.9997 0.9216 6.0 Pb 1399 1.0000 100.0 100.0 0.9213 6.0 11 1386 1.0017 100.0 99.8 5.6 12 1352 1.0063 99.9 99.3 5.5 13 1276 1.0179 99.8 98.0 5.4 14 1148 1.0419 99.6 95.6 5.2 15 961 1.0921 99.3 90.9 5.0 16 696 1.2184 98.9 81.2 4.6 17 424 1.5324 98.5 64.3 4.3 18 231 2.2276 98.2 44.1 4.1 WCP Oilphase-DBR 36 Job #:200500199 • Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Figure 15: Constant Composition Expansion at 67.0°F -Relative Volume Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD • 2.4 2.2 2.0 - 1.8 a d ~_ E 1.6 a 0 w a °C 1.4 1.2 1.0 0.8 ~ 0 1000 2000 3000 Pressurelpsia- 4000 5000 6000 WCP Oilphase-DBR 37 Job #: 200500199 Client ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 67°F. These values as a function of selected pressure steps are summarized in Table 24. The liquid phase viscosity values are graphically presented in Figure 16. 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 24: Reservoir Fluid Viscosity 67°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD • • Pressure Viscosity ~ Tres (psia) (cP) 1 5032 293.3 2 4495 267.5 3 4001 245.4 4 3533 225.4 5 3033 204.8 6 2505 186.3 7 2049 170.0 8 1868 164.5 9 1643 157.7 Pi 1450 152.0 Pb 1399 150.7 2 1183 165.1 3 1089 171.6 4 937 186.7 5 727 206.2 6 557 243.0 STO 14.696 788.6 WCP Oilphase-DBR 38 Job #:200500199 Client ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Scblumberger Figure 16: Reservoir Fluid Viscosity 67°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD soo soo 700 soo ~ 500 a .~ 0 v y 400 300 200 • 100 • 0~ 0 1000 2000 3000 Pressure (psia! 4000 5000 6000 WCP Oilphase-DBR 39 Job #:200500199 Client. ConocoPhiflips Field: West Sak We{I: 1 Q-101 Sand: West Sak B schlumberger Single-Stage Separation Test Single-stage separation test results are presented in Tables 25 - 27. The fluid properties (i.e., GOR, density and oil formation volume factor) are presented in Table 25. Multi-stage separation test conditions are: STAGE 1 65 psia 150 °F STAGE STO 14.696 psia 60 °F As seen in Table 25, the GOR value obtained from the multi-stage separation test is 171 SCF/STB and the formation volume factor is 1.049. The compositional analyses of separator gas and tank gas are summarized in Table 26 and the composition of tank liquid is tabulated in Table 27. The total tlry gross heat content of the separation gases is calculated to be 1,074 BTUfscf whereas the total wet gross heat content is calculated to be 1,055 BTU/scf. C~ WCP Oilphase-DBR 40 Job #; 200500199 • Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Table 25: Single-Stage Separation Test Vapor & Liquid Properties Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD • a) Calculated, at 60°F (air=1 j 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 PROPERTY STAGE Pb STAGE t STAGE STO ressure (psia) 1399 65 14.696 Temperature (°F) 67 150 60 Liq. Dan (g/cm3) 0.9214 0.9332 0.9438 Vap. Gravity° 0.610 0.594 Vap. M,M 17.68 17.20 Vap Heat Val.° 1075 1057 GOR° 157 14 GOR° 155 14 Sep. FVF° 1.049 1.013 1.000 Residual oil density at standard conditions 0.9438 g/cc Sep gas gravity (average) S9 = ERjSgj/ERj 0.609 Where: R: GOR (scf gas/bbl of oil at STD conditions), j: separator stages Sep gas gross heating value (a~ L° =ERA*L°~R~ 1074 BTU/scf (dry basis) Where: R: GOR (scf gas/bbl of oil at STD conditionsi, j: separator stages SEPARATION TEST SUMMARY Total Separation Test GOR 171 Separation Test STO Gravity 18.4 Separation Test FVF 1.049 a) scf gaslbbl of condensate at STD conditions bi Fluid volume at Psat & TreslFluid volume at STD WCP Qilphase-DBR 41 Job #;200500199 • Client: ConocoPhillips Well: 1Q-101 Field: West Sak Sehlumberger Sand: West Sak B Table 26: Single-Stage Separator Test Vapor Composition ~mol %) Sample 1.06 C; Cylinder CSB 11797-QA; Deqth 4293 ft. MD • • Component IgJmol) ole STA E 1 E STO Carbon Dioxide 44.01 0.58 0.53 Hydrogen Sulfide 34.08 0.00 0.00 Nitrogen 28.01 0.62 0.23 Methane 16.04 94.77 96.60 Ethane 30.07 1.34 0.98 Propane 44.10 0.75 0.40 I -Butane 58.12 0.76 0.32 N -Butane 58.12 0.33 0.18 I -Pentane 72.15 0.34 0.17 N -Pentane 72.15 0,17 0.11 C6 84.00 0.17 0.16 M-C-Pentane 84.16 0.02 0.04 Benzene 78.11 0.00 0.01 Cyclohexane 84.16 0.01 0.02 C7 96.00 0.05 0.09 M-C-Hexane 98.19 0.02 0.03 oluene 92.14 0.02 0.02 C8 107.00 0.03 0.05 E-Benzene 106.17 0.00 0.00 M/P-Xylene 106.17 0.00 0.01 0-Xylene 106.17 0.00 0.00 C9 121.00 0.01 0.02 C10 134.00 0.00 0.01 C11 147.00 0.00 0.00 C 12 161.00 0.00 0.00 C13 175.00 0.00 0.00. C14 190.00 O.DO 0.00 C15 206.00 0.00 0.00 C16 222.00 0.00 0.00 C17 237.00 0.00 0.00 C18 251.00 0.00 0.00 C 19 263.00 0.00 0.00 C20 275.00 0.00 0.00 C21 291.00 0.00 0.00 C22 300.00 0.00 0.00 C23 312.00 0.00 0.00 C24 324.00 0.00 0.00 C25 337.00 0.00 0.00 C26 349.00 0.00 0.00 C27 360.00 0.00 0.00 C28 372.00 0.00 0.00 C29 382.00 0.00 0.00 C30 394.00 0.00 0.00 C31 404.00 0.00 0.00 C32 415.00 0.00 O.OD C33 426.00 0.00 0.00 C34 437.00 0.00 0.00 C35 445.00 0.00 0.00 C36+ 934.00 0.00 0.00 Total 100.00 100.00 MW 17.68 17.20 Relative Density lair=1 ~ 0.610 0.594 ry ross Heat ontent /sc 1075 105 WCP Oilphase-DBR 42 Job #: 200500199 • • Client ConocoPhillips field: West Sak Well: 1D-1D1 Sand: West Sak B Schlumberger Table 27: Single-Stage Separator Test Residual Liquid Composition (mol °1°) Sample 1.06 C; Cylinder CSB 11797-OA; Depth 4293 ft. MD MP ENT MW (g/mol) Resi ual Liquid (mol %) Carhon 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 0.13 I -Butane 58.12 0.15 N -Butane 58.12 0.11 I -Pentane 72.15 0.28 N -Pentane 72.15 0.15 C6 84.00 0.67 M-C-Pentane 84.16 0.08 Benzene 78.11 0.02 Cyciohexane 84.16 0.11 C7 96.00 0.79 M-C-Hexane 98.19 0.21 Toluene 92.14 0.45 C8 107.00 1.41 E-Benzene 106.17 0.13 M/P-Xylene 106.17 0.11 0-Xylene 106.17 0.11 C9 121.00 1.71 C10 134.00 2.78 C11 147.00 3.38 C12 161.00 4.22 C13 175.00 4.91 C14 190.00 5.04 C15 206.00 5.44 C16 22200 4.65 C17 237.D0 4.77 C18 251.00 4.19 C19 263.00 4.36 C20 275.00 3.92 C21 291.00 3.44 C22 300.00 3.30 C23 312.00 3.17 C24 324.00 2.50 C25 337.00 2.15 C26 349.00 2.30 C27 360.00 2.08 C28 372.00 2.02 C29 382.OD 1.88 C30 394.00 1.87 C31 404.00 1.42 C32 415.00 1.35 C33 426.00 1.16 C34 437.00 1.00 C35 445.00 1.00 C36+ 934.00 15.08 Total 10D.00 354.5 WCP Oilphase-DBR 43 Job #:200500199 . Client: ConocoPhillips Field: West Sak Schlumber er Well: 1Q-101 Sand: West Sak B Viscosity Analysis on Sample 1.06 C Reservoir Dil Viscosity at Tres Per client's request, the monophysical liquid phase viscosity was repeated at the reservoir temperature of 67°F. These values as a function of selected pressure steps are summarized in Table 28. The liquid phase viscosity values are graphically presented in Figure 17. 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 L..LLI., ....:..,s This time, the viscosity results were reduced but still within the measurement tolerance. The piston chosen for this viscosity testing ranges from 100 - 2000 cP. And based on the manufacturer, the error bar is about +j- 1 °jo of the highest range. The dead oil viscosity at 67°F was also reduced but again it's within the measurement error. Table 28: Reservoir Fluid Viscosity 67°F Sample 1.06 C; Cylinder CSB 11797-OA; Depth 4293 ft. MD lI 1' u Pressure Viscosity @ Tres (psia- (cP) 4011 227.7 3547 212.5 3041 195.8 2544 179.0 2050 161.6 15 759.8 WCP Oilphase-DBR 44 Job #: 200500199 • Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Scblumberger Figure 17: Reservoir Fluid Viscosity 67°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD • • soa goo soo 500 a •~ 400 0 v N_ 300 200 100 0 0 WCP Oilphase-DBR 1000 2000 3000 Pressure ipsia) 45 4000 5000 Job #:200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumber~er Reservoir Oil Viscosity at 150°F The liquid phase viscosity was measured at the reservoir temperature of 150°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 18. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint, which cannot be just determined by this viscosity test. Table 29: Reservoir Fluid Viscosity 150°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD Pressure Viscosi @ Tres (psia) ICP) 5524 27.0 4977 25.3 4492 24.0 3989 22.5 3523 21.1 3018 19.5 2518 18.3 15 44.5 • • WCP Oilphase-DBR 46 Job #: ZOOr.~00199 Client: ConocoPhillips Field: West Sak Well: 10-101 Sand: West Sak B Schlumberger Figure 18: Reservoir Fluid Viscosity 150°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD 45 40 35 a v y 30 0 v 25 i • 20 WCP Oilphase-DBR 15 ~ 0 1000 2000 3000 4000 5000 6000 Pressurefpsia) 47 Job #:200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Reservoir Oil Viscosity at ~°F The liquid phase viscosity was measured at the reservoir temperature of 90°F. These values as a function of selected pressure steps are summarized in Table 30. The liquid phase viscosity values are graphically presented in Figure 19. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint, which cannot be just determined by this viscosity test. Table 30: Reservoir Fluid Viscosity 90°F Sample 1.06 C; Cylinder CSB 11797-OA; Depth 4293 ft. MD Pressure Viscosity @ Tres (Psia) IcPI 5461 123.2 4997 114.3 4504 105.6 4040 96.9 3526 88.4 3030 81.2 2519 73.7 2000 67.5 15 264.5 • • WCP Oilphase-DBR 98 Job #:200500199 • CIieM: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Figure 19: Reservoir Fluid Viscosity 90°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD 1000 a •y 100 0 v _N 7 • 10 2000 4000 Pressure (psia) 6000 8000 WCP Oilphase-DBR 49 Job #:200500199 CIieM: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Reservoir Dil Viscosity at 50°F The liquid phase viscosity was measured at the temperature of 50°F. These values as a function of selected pressure steps are summarized in Table 31. The liquid phase viscosity values are graphically presented in Figure 20. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint, which cannot be just determined by this viscosity test. Table 31: Reservoir Fluid Viscosity 50°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD Pressure Viscosity @ Tres (psia) (cP) 5560 500.5 4925 456.1 4576 433.5 4027 398.5 3530 366.8 3041 335.9 2524 307.1 2037 283.4 15 1650.0 • • WCP Oilphase-DBR 50 Job #: 200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Figure 20: Reservoir Fluid Viscosity 50°F Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD • 1850 1650 1450 1250 ~ 1050 .y O V 850 650 450 250 50 0 1000 2000 3000 4000 5000 6000 Pressure (psial • WCP Oilphase-DBR 51 Job #:200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Density at Various Temperatures The STO density was measure at four difference temperatures - 50°F, 67°F, 90°F and 150°F. The results were listed in Table 32. We also wanted to measure the monophysical density at 3000 psia and tour difference temperatures - 50°F, 67°F, 90°F and 150°F but ran out of sample volume. Hence, we combined the full PVT data from the reservoir temperature - 67°F and our in-house simulation software - PVTPro to obtain the calculated monophysical densities at those temperatures. The results were listed in Table 33. Table 32: STO Density vs. Temperature Sample 1.06 C; Cylinder CSB 11797-OA; Depth 4293 ft. MD Tem erature STO density (°F) (g/cc) 50 0.9504 67 0.9444 90 0.9349 150 0.9115 • • WCP Oilphase-DBR 52 Job #: 200500199 CIieM: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Figure 21: STO Density vs. Temperature Sample 1.06 C; Cylinder CSB 11797-QA; Depth 4293 ft. MD 0.955 0.950 0.945 0.940 ~ 0.935 v e +r 'H 0.930 d 9 r '~ 0.925 0.920 0.915 0.910 0.905 0 • WCP Oiilphase-DBR 20 40 60 80 100 Temperature (°F) ~3 120 140 160 Job #:200500199 CIieM: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Temperature Mono hysical density 1°FI 19/cc) 50 0.9324 67 0.9293 90 0.9249 150 0.9129 Table 33: Simulated Monophysical Density at 3000 psia vs. Temperature Sample 1.06 C; Cylinder CSB 11797-OA; Depth 4293 ft. MD 0.935 • ~ 0.925 v ~o Figure 22: Simulated Monophysical Density at 3000 psia vs. Temperature Sample 1.06 C; Cylinder CSB 11797-OA; Depth 4293 ft. MD 0.930 e d 9 r y 0.920 • 0.915 Schlumberger 0.910 ~ 40 60 80 100 120 Temperature 1°F- 140 160 WCP Oilphase-DBR 54 Job #:200500199 • CIieM: ConocoPhillips Well: 1 Q-101 Field: Sand: West Sak West Sak B Schlumber er Installation: - Job #: 200500199 Appendix A: Nomenclature and Definitions API Gravity American Petroleum Institute gravity 69 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 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. • WCP Oilphase-DBR 55 Job #: 200500199 Client: Well: Installation: ConocoPhillips 10-101 Field: West Sak Sand: West Sak B Job #: 200500199 Schlumberger • • Appendix B: Molecular Weights and Densities Us Components MW Density I9/cc) C02 44.01 0.827 H2S 34.08 0.993 N2 28.013 0.808 C 1 16.043 0.300 CZ 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 C10 134 0.782 C11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 C 15 206 0.836 C 16 222 0.843 C17 237 0.851 C18 251 0.856 C 19 263 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 ed WCP Oilphase-DBR 56 Job #:200500199 Client: ConocoPhillips Well: 10-101 Field: Sand: West Sak West Sak B Schlumberger Installation: - Job #: 200500199 Appendix C: EQUIPMENT Fluid Preparation and l/alidation 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 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 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 Fluid l/olumetric IPVTJ and Viscosity Equipment • WCP Oilphase-DBR 57 Job #: 200~.~00199 Client: ConocoPhillips Well: 1 Q-101 Field: Sand: West Sak West Sak B Schlumberger Installation: - Job #: 200500199 The preliminary saturation pressure, constant composition expansion (CCE-, differential vaporization (DV), multi- stage separation tests (MSST) are measured using apressure-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 The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with ahigh-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 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 A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. • WCP Oilphase-DBR 58 Job #:200500199 Cliem: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Scbiumberger Installation: - Job #: 20050D199 The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation ~OHSPj due to changes in the temperature, pressure andlor 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 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. C7 WCP Oilphase-DBR 59 Job #:200''x00199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Sehiumberger Installation: - Job #: 200500199 fluids Preparation and l/alidation Appendix D: PROCEDURE 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 (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 PUT cell. The measured pressure and volume data are then used to compute live oil compressibility above the bubblepoint pressure and relative oil volumes over Differential l/aporization 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 (DU) 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 • WCP Oilphase-DBR 60 Job #: 200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schlumberger Installation: - Job #: 200500199 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. Amulti-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 • 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 ViscosityandDensityMeasurements 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 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 ISTOI 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 tlensitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. Asphaltene, Waxand Sulfur Content Measurements Asphaltene content of stock-tank oil samples is conducted using the IP-143 (French Institute of Petroleum) procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil. Wax content of the STO is measured using UOP (Universal Oil Product) 46-64 procedure. The sulfur content of the STO is measured using ASTM D 2494 procedure.. All other STO analysis were measured according to WCP Oilphase-DBR 61 Job #; 200500199 Client: ConocoPhillips Field: West Sak Well: 1 Q-101 Sand: West Sak B Schiumberger Installation: - Joh #: 200500199 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 The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were ca{culated throughout the procedure to assure accurate data. High-Temperature High Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. WCP Oilphase-DBR 62 Job #:200500199
