The URL can be used to link to this page

Home My WebLink About206-1061. 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 10878'feet None feet true vertical 3716' feet None feet Effective Depth measured 10790'feet None feet true vertical 3714' feet None feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 2243' MD 1845' 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 - 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 108' ~~~ SUSPENDED ~~ ~ measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-106 50-029-23315-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL025662, ADL0380058 Kuparuk River Field/ West Sak Oil Pool KRU 1J-133 Plugs Junk measured Length Production Liner 10846" Casing 3716'10873' 3689' 108'Conductor Surface Intermediate 20" 13-3/8" 80' 3719' 2224' 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 8:35 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 11:07:12-08'00' 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 1J-133 (PTD 206-106) 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 1J-133 (PTD 206- 106). 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 11:07:33-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn Casing Strings Casing Description CONDUCTOR Insulated String O... 20 String ID ... 19.124 Top (ftKB) 28.0 Set Depth (f... 108.0 Set Depth (TVD) ... 108.0 String Wt... 94.00 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 13 3/8 String ID ... 12.415 Top (ftKB) 30.0 Set Depth (f... 3,718.9 Set Depth (TVD) ... 2,225.0 String Wt... 68.00 String ... L-80 String Top Thrd Buttress Thread Casing Description INTERMEDIATE String O... 9 5/8 String ID ... 8.835 Top (ftKB) 27.2 Set Depth (f... 10,873.0 Set Depth (TVD) ... 3,716.1 String Wt... 40.00 String ... L-80 String Top Thrd BTCM Tubing Strings Tubing Description Tubing - Kill String String O... 4 1/2 String ID ... 3.958 Top (ftKB) 23.5 Set Depth (f... 2,244.1 Set Depth (TVD) ... 1,845.3 String Wt... 12.60 String ... L-80 String Top Thrd IBT-Mod Completion Details Top (ftKB) Top Depth (TVD) (ftKB)Top Incl (°)Item Description Comment Nomi... ID (in) 23.5 23.5 -0.06 HANGER TUBING HANGER 4.500 Notes: General & Safety End Date Annotation 8/13/2006 NOTE: WELL SUSPENDED Comment Well Config: - 1J-133, 3/7/2012 3:17:29 PM Schematic - Actual TD (1J-133), 10,878 NTERMEDIATE, 27-10,873 SURFACE, 30-3,719 TUBING SHOE, 2,243 CONDUCTOR Insulated, 28-108 HANGER, 24 Annotation Depth (ftKB) End Date Annotation Rev Reason: WELL REVIEW Last Mod ... osborl End Date 3/7/2012 KUP KB-Grd (ft) 32.00 Rig Release Date 8/13/2006 Annotation End Date 1J-133 H2S (ppm) Date... TD Act Btm (ftKB) Well Attributes Wellbore API/UWI 500292331500 Field Name WEST SAK Well Status INJ Max Angle & MD Incl (°) 89.47 MD (ftKB) 10,830.56 “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:susSTS250908103746 Well Pressures (psi): Date Inspected:9/6/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:8/13/2006 Tubing:0 IA:0 OA:160 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Matt Miller Date AOGCC Notified:9/3/2025 Type of Inspection:Subsequent Well Name:KUPARUK RIV U WSAK 1J-133 Permit Number:2061060 Wellhead Condition Normal signs of rust from being outside, valves turned easily. Seperated from flowline Surrounding Surface Condition slight subsidence around cellar casing. Clean area Condition of Cellar Water in cellar was clean with no sheen, trash or debris Comments Gauges were all in good condition and verified with digital gauge. Location verified By plot map. Supervisor Comments Photos (2) attached Suspension Approval:Completion Report 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_1J-133_photos_ss Page 1 of 1 Suspended Well Inspection – KRU 1J-133 PTD 2061060 AOGCC Inspection Rpt # susSTS250908103746 Photos by AOGCC Inspector S. Sullivan 9/6/2025 Suspended Well Inspection Review Report InspectNo: susBDB200517130518 Date Inspected: 5/16/2020 Inspector: Brian Bixby Type of Inspection: Subsequent Well Name: KUPARUK RIV U WSAK 1J-133 Date AOGCC Notified: 4/27/2020 Permit Number: 2061060 Operator: ConocoPhillips Alaska, Inc. Suspension Approval: Completion Report - Operator Rep: Roger Winter Suspension Date: 8/13/2006 Wellbore Diagram Avail? ❑� Location Verified? o❑ Photos Taken? ❑� If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: 0 Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ OA: 190 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 in covered in snow. Comments Location Verified with As -Built Pad Map Supervisor Comments Site should be free of snow and ice for suspended well inspection. Photos (2) - Friday, June 5, 2020 _ y r t § t § . ,.,. • F � �. .. \ 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? 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): 10878 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: 6/12/2020 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 3714 COMMISSION USE ONLY NA Tubing Grade:Tubing MD (ft): None None 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 25662, 380058 3716 206-106 P.O. Box 100360, Anchorage, Alaska 99510 50-029-23315-00 ConocoPhillips Alaska, Inc Length Size KRU West Sak 1J-133NA Kuparuk River Field / West Sak Oil Pool 10790 L-80 TVD Burst 2243 MD 108 2224 3716 108 3719 20 13.375 80 9.62510846 3689 Perforation Depth MD (ft): 10873 None 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 4.5 None m n P 66 t l Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 5:28 pm, Jun 12, 2020 320-256 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: 2020-06-12 15:31:49 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conoco phillips.com DSR-6/12/2020 ADL0025661 DLB X DLB 06/15/20 -00 DLB 10-404 VTL 6/17/20 X Comm. 6/18/2020 dts 6/17/2020 JLC 6/17/2020 RBDMS HEW 6/18/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 12 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 1J-133 (PTD 206-106) Dear Commissioner Chmielowski, ConocoPhillips Alaska Inc. hereby submits a request for renewal of the suspension status of Kuparuk River Unit West Sak well Silvertip 1J-133 (PTD 206-106) 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 Well bore is not perforated. - 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 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: 2020-06-12 15:31:27 Foxit PhantomPDF Version: 9.7.0 jan.byrne@c onocophillips .com Casing Strings Casing Description CONDUCTOR Insulated String O... 20 String ID ... 19.124 Top (ftKB) 28.0 Set Depth (f... 108.0 Set Depth (TVD) ... 108.0 String Wt... 94.00 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 13 3/8 String ID ... 12.415 Top (ftKB) 30.0 Set Depth (f... 3,718.9 Set Depth (TVD) ... 2,225.0 String Wt... 68.00 String ... L-80 String Top Thrd Buttress Thread Casing Description INTERMEDIATE String O... 9 5/8 String ID ... 8.835 Top (ftKB) 27.2 Set Depth (f... 10,873.0 Set Depth (TVD) ... 3,716.1 String Wt... 40.00 String ... L-80 String Top Thrd BTCM Tubing Strings Tubing Description Tubing - Kill String String O... 4 1/2 String ID ... 3.958 Top (ftKB) 23.5 Set Depth (f... 2,244.1 Set Depth (TVD) ... 1,845.3 String Wt... 12.60 String ... L-80 String Top Thrd IBT-Mod Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 23.5 23.5 -0.06 HANGER TUBING HANGER 4.500 Notes: General & Safety End Date Annotation 8/13/2006 NOTE: WELL SUSPENDED Comment Well Config: - 1J-133, 3/7/2012 3:17:29 PM Schematic - Actual TD (1J-133), 10,878 NTERMEDIATE, 27-10,873 SURFACE, 30-3,719 TUBING SHOE, 2,243 CONDUCTOR Insulated, 28-108 HANGER, 24 Annotation Depth (ftKB) End Date Annotation Rev Reason: WELL REVIEW Last Mod ... osborl End Date 3/7/2012 KUP KB-Grd (ft) 32.00 Rig Release Date 8/13/2006 Annotation End Date 1J-133 H2S (ppm) Date... TD Act Btm (ftKB) Well Attributes Wellbore API/UWI 500292331500 Field Name WEST SAK Well Status INJ Max Angle & MD Incl (°) 89.47 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 10:32:42 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conocophillip s.com By Samantha Carlisle at 8:09 am, May 20, 2020 SFD 5/21/2020 SFD 5/21/2020 VTL 5/26/20 ADL025661 DSR-5/20/2020 RBDMS HEW 5/21/2020 -00 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 10:32:24 Foxit PhantomPDF Version: 9.7.0 jan.byrne@c onocophillips. com # $$$ $$$ %&'( %&$$$ %!($$$ $$$ $$$ ) # $$$ !!" $$$ # %&'( ! %&$$$ !$% %!($$$ $# $$$ & $$$ ) '()( # * $$$ #" $$$ !# %&'( % %&$$$ $%! %!($$$ !$%& $$$ $$$ ) '* * * # +, -., (, - $$$ " $$$ !# %&'( !# %&$$$ $ %!($$$ $#! $$$ & $$$ ) '*/ + %&'( %!( %&'( # %,( +# ++ +$$$ % ( !# !# & 0 ' 0 0 # -. /&0 ) "!"& 12 ++ " #=#44943*30104*0/6 # %+=#44-9 19.*. !& 6&%$&9 0*#19.*4 > &9 41#49*/ >?$!<D&9 09054 !%> $ 9 0.#1. D!<& 905 %&'( ) 3/ 14 ")$$$ /+/( ) !"%" ' '1. )%&( ! "!"& ) 231244 56%+( $$$ #+%&'( * * 7 #!!# )+ . 5 "8 /" #%,( % "%&'( $!#& STATE OF ALASKA AL. ...KA OIL AND GAS CONSERVATION COIL,...iSSION REPORT OF SUNDRY WELL OPERATIONS I Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Suspend well inspect IV 2.Operator Name 4.Well Class Before Work. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206-106 3.Address. 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23315-00 7 Property Designation(Lease Number): 8 Well Name and Number: ADL 25662,380058 KRU West Sak 1J-133 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 10878 feet Plugs(measured) None true vertical 3716 feet Junk(measured) None Effective Depth measured 10790 feet Packer(measured) None true vertical 3714 feet (true vertical) None Casing Length Size MD ND Burst Collapse CONDUCTOR IN: 80 20 108 108 1530 520 SURFACE 3689 13.375 3719 2224 5020 2260 INTERMEDIATE 10846 9.625 10873 3716 5750 3090 SCANNED .l LIL I 'Y 2015 Perforation depth: Measured depth: None RECEIVED True Vertical Depth: None JUN 3 0 2015 Tubing(size,grade,MD,and TVD) 4.5, L-80, 2243 MD, 1845 TVD ,+raOGCC Packers&SSSV(type,MD,and TVD) None 1'� l.1 V 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA _ NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25 070,25.071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service 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 17 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 n1878conocophillips.com Printed Name MJ Loveland Title WI Project Supervisor Signature P one:659-7043 Date 7 f , VTi— 7-!q` /5— RBD4 JUL 1 1015 Form 10-404 Revised 5/2015 Submit Original Only 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 1J-133 (PTD 206-106) 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 1J-133 (PTD 206-106). 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 1J-133 Field/Pool: KUPARUK RIVER/WEST SAK Permit#(PTD): 206-106 Sundry 310-417 API Number: 50-029-23315-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 8/13/2006 Surface Location: 1622' FSL, 2296' FEL Section: 35 Township: 11N Range: 10E Nearest active pad or road: KRU DS1J Meridian: UMIAT Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: good Location cleanup needed: none Pits condition: Backfilled Surrounding area condition: good - Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: none Samples taken: None Access road condition: good Photographs taken (#and description): 3 of well and surrounding 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: good Rat Hole: NA Wellhouse or protective barriers: Yes Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: IA= 25 psi, OA= 0 psi Wellhead Photos taken (#and description): 3 of well and surrounding area Work Required: None Operator Rep (name and signature): Perry Greenwood AOGCC Inspector: Johnnie Hill Other Observers: Cody Warfield Inspection Date: 6/27/2015 AOGCC Notice Date: 6/25/2015 Time of arrival: 1505 Time of Departure: 1510 Site access method: Truck 1., KUP 1J-133 ConocoPhillips �" Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Well Status Incl)) MD(ftKB) Act Mtn(ftKB) = cmomHuthps ? 500292331500 WEST SAK INJ 89.47 10,830.56 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Rebase Date • Welt Config -1J-133 3!72012 3:17:29 PM 32.00 8/132006_ Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date _ Rev Reason:WELL REVIEW osborl 3/7/2012 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 28.0 108.0 108.0 94.00 H-40 WELDED SIB Insulated Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 133/8 12.415 30.0 3,718.9 2,225.0 68.00 L-80 Buttress Thread HANGER.24 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth)TVD)...String Wt...String...String Top Thrd INTERMEDIATE 9 5/8 8.835 27.2 10,873.0 3,716.1 40.00 L-80 BTCM Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(/...Set Depth(TVD)...String Wt...String...String Top Thrd Tubing-Kill String 4 1/2 3.958 23.5 2,244.1 1,845.3 12.60 L-80 IBT-Mod Completion Details :y Top Depth f (TVD) Top Inst Nomi... yTop(11KB) (ftKB) (°) Kern Description Comment ID(in) 23.5 23.5 -0.06 HANGER TUBING HANGER 4.500 Notes:General&Safety ) -- , End Date Annotation 8/13/2006 NOTE:WELL SUSPENDED 4 i .1 CONDUCTOR Insulated, 2&109 ; TUBING 52,23 �/ 2,OE. 9% 111 f II SURFACE._ I I 30.3.719 a4 i J NTERMEDIATE, 27-10.973 Ti)(IJ-1331 10978 0 0 o 0 0 0 0 epe9 v + + + N NI- 0 �C N + r W W 3 3 3 3 M ! Z ce w -+- -+- -+- -+- -+- -+- OO+OL S z 59 s, u. 0 X r_ _ _ _ _ \� X Q 1 cd,_, .. N J_d rn o Ln F-a m OHO I - O ff d -�- _I 1- -t- I- E_'4- 00+8 S I z Q J CL ®'t I W M a- Q J -I .-�Qi -1- -.- 00+9 $ M^®Oc. MQ®E p �Ir 20 I a (nVI U Z M®® µ0®� 0z QC r, "OM Z P.3 C>®n I Y < -+- -+- -+ ®� I - -- -+- 00+4 S Z (n al o oOO�n W 0U) /Z/� Q d- MI®^ d' J Y. NS Cr N Loa: W J O z J �Wa1 0 N®Q eai�®I� 3 O o m mea- MOS ® O -;- -�- + m -I- -;- 00+Z s �[) m N�® YQ ^®O NOO ®� Z Z COco _ NO®�p �®Qm N 0®m0 N m N OO ®Nm r 0) J O®Q� N OO ®�c 1 M®Q N - b fX 26 0 N 0® L%- u-) �Z] I ®Q N0®O1� a I H y) a �o m aow® NC>®0 El 0 Cl VU �� 6d !O®O � Z Z 0-7 M Co)LI o N _1- _ + _+_ f-jrj' _+_ OO+Z NO oNid M �� r aj a < 1La, ad o tI ® _�_ 4- 4- 00+1, N o o ti t t pi:11\1'11 6 •- i Lg 1 I 0 5 U re + -i- -+}^.. 11 -i- 4 -+- 00+9 N I II � U a l CO ® II zm + -+ I ± I I T- -+- -+- 00+9 N u I ..---"\ ii 5 + \ , /-I-- rE 3 US O r I � � + 4- oo+oL N III II o + II-+- -+- -+ OO+ZL N o II . - , • -7::: „4:'• ' ' • ,.. . ,i : J " t - f , . . ! ., , r e �1 fa ''..' ' . ' '.9.,, 1:;.'. ', ',,..: :,,, �.�' ii.t);.,, , ,,- t� tV rte ijj ,�.b.� ',1:.:::',,,,:,, ,..Ffrd j 4,v i p r; `r...i J'. M -0 4 '' .i, ; ', .,,,....4.:;1,',;, y �t 4 ' f fl �' / • e, , , , 0 •";41,i 11': of Or F P Lit �L i 1:-.7'::::''` (.. • j. iA c cm "-� Edi , ! -r,� , (C to 1 ` i'... 4 1' 4('j'-11,' 0' N �H Om �, o ,��; "• � � ..'..; F,, c•"' O i OQM � o o m a� r • r t 0 .- ItD N M V) 'ry A1._ �1I C d _y cam t W //�� . I E E cv • i # Cl) i 'tee .'' 'I.,.' •,,.. :..,,--' li'l.` ..:,.1,::'., a) I \ , 0 41 CO �� i> ,_� , N O ; ...16. ( :-, r�. ?k ', o , 1/41 J Q Q C6 Q)C3 c ' j !,_ CO p -- .Q 0 �� .. ! OV O �- e =� . '1- './1i �►a s � �. I . 001C (192 ° 111 /{� - r, V gyp; . . t •T"- 0 Li_) .r--- P 01 is ,. i ...,11 ;•;i ' ',...:-•<.*;11-.' , \ 4\. 0 N L t • , 1-.. 4 `X4" 1 , . 1.. �q 'i� O - c f 1 1 J-133 PTD 6-106 _ ©ConocoPhillips Iaska, Inc Thisphoto is co ri hted b ii, 1 J pYg . 3u , ooeonoco-Phiilips Alaska bitnc. and cant Lease•, or rblishe lM without e�cpr- - *4 ;...; of Cc no , ' ' 11".' k ,„ ilop ---1-1-044 I riw r- — r �- ria. p Sm v 7. t p d f 4xz ..5 ..,a • 4. ! x 4 3i a / ..07°. - l4t." y , . , , ,A, ,, ...104.. .. ,., , ,.„ ,1,,..,444........ s �" {? V , • 47 • 4610 .tea... * • 0 -- e a a. .- .110 to ��, a r Y ` 1. • ivy Irr .5 ,}.� i/� } r fttr :51,:,..1k,,,'I-1,, d 15 ate ' V 3 +�f w t S t r x•. C " GI ,'.., % �' /�.e1 i 4 I + i ,;4.6,,,,,,;,, y, �+}�,?[ r� i, Fra. U f 1.CO X '\^ , AP M T l t P3 I. ' ' P q �t'4. %` ' .! O (v O _ � 11 i , i , At N ,fi Q —1O ;fwJ O ° c r laity f 1 H ..-_-= u) (,) u) - 0_ _c .- (T3 (y) Q_ OQ ,. , ......„...„ . .O O :_ f•/� iPI:ir SCD Q — O (n rsa wren,. + �• .. mit ti :k ,' * -- 4 * moo' O }_ S b� r sr* + 2n r '� • , r O fir' 7 ■■ ;� O W= t o d t r'' V' 4. r p O m ' 1 tC .3"j ti ! r � � NM"' i , H s . AX III r IS of N G 1� A? � Z f y J i• y �a� ' d, CO o Th a - i 1 : ' • t C C • ... , . 'a L . . � t ..:..,„4 k 's � . 1 , ,, „ ,1 _,, ,.....1 ., k .&. . .si' iiii_ k 3 • ,' X14.1',; et Y f1 1 � ,C}tJ"BR IpX k a ; *w • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 06/27/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc Well Name: 1J-133 Oper.Rep: Perry Greenwood PTD No.: 206-106 Oper.Phone: Location Verified? Yes Oper.Email: If Verified,How? LAT/LONG - Onshore/Offshore: Onshore Suspension Date: 08/13/06 Date AOGCC Notified: 06/25/15 " Sundry No.: Well Completion Report - Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 ' Photos Taken? Yes IA 0 OA 0 SCANNED AUG 1 92015 Condition of Wellhead: good and clean-no well house Condition of Surrounding Surface Location: good clean gravel/celler little water Follow Up Actions Needed: none Comments: Attachments: Photos(3) REVIEWED BY: p Insp.Supry J n r— -7116(6" Comm PLB 06/2014 2015-0627_Suspend_KRU_1J-133jh.xlsx }yF .# ... .�,. iii „yli i s .p ' ''4 1,04,1,6,„ .. -r. afr .; • s rx 11 a�k yf raj y t 6r:-Of �• i'' 4Y Y i i1 . . 4 1. r' b 1.1 +; 4 4..., .. . 1 g, ;;.,.., 7 ' - ..:'”:4 iAmiuiennilillilln• k I" it 1s _ li I. U " •• o � it b 1 •4a ; k • o r 7 C'1 oo _ en • IlIli i 1 .E- �i ii y r JJJ ggg0 U g,y1,zIS rn E-1 . N 11 I' ^'� .4,v� aa � - __ ` o � i • k r . . . , r Frs. 1 . , - ..,,,,t, it .. f M a __ t r��I 11 rn Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ,~ Q ~j Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: wo-sided IIIII11111111111111 ~~ DIGITAL DATA ~skettes, No. ^ Other, No/Type: BY: Maria Date: ~ Project Proofing BY: Maria Date: Scanning Preparation ~ x 30 = BY: Maria Date: Al Production Scanning Re,~a~~eeded iiiiiiiii~uium OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Nan-Scannable) ^ Logs of various kinds: ^ Other.: ~~ U /s/ Illlllllllllll IIIII S a /s/ Y ~ I _~ + ~,O =TOTAL PAGES O 0 w (Count does not include cover sheet) U /s/ 1111111111111111111 Stage 7 Page Count from Scanned Fite: ~~ (Count does include cover heet) Page Count Matches Number in Scanning Pr paration: _~ES _ BY: Maria Date: ~l / Stage 7 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO lsl NO "iiiuimmwuii ReScanned BY: Maria Date: /s/ Comments about this file: o~,~~,~~e~~ed iuumuuumu 10/6/2005 Well History File Cover Page.doc • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/28/10 Inspector: Bob Noble Operator: CPA Well Name: KRU 1J -133 Oper. Rep: Ian Ives PTD No.: 206 -106 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? ier (specify in commei Onshore / Offshore: Onshore Suspension Date: 08/13/06 Date AOGCC Notified: 08/27/10 Sundry No.: Well Completion Rpt Type of Inspection: Initial " Wellbore Diagram Avail.? No Well Pressures (psi): Tubing 0 Photos Taken? Yes IA 0 OA 150 Condition of Wellhead: Location verified with plot plan. Wellhead looked good with all lines blinded with gauges. Guard around wellhead. Red fluid in cellar. Sample was taken and I will include results with report. Condition of Surrounding Surface Location looked good. Location: Follow Up Actions None Needed: Attachments: Photos (4) REVIEWED BY: Cellar Water Sample Analysis Insp. SuprvJ >;e J01I41 Comm PLB 08/2010 2010- 0828_Suspend_KRU_1J- 133_bn.xls . • Kuparuk Laboratory Report of Analysis Report Date: 08/29/10 To: NSK Problem Wells �l (J -133 / PrO 2.6G -100 Sample Description: DS 1J Miscellaneous Water Sample ID AB73130 Sample point D1JMISW Well Num 133 Loc Descriptor Cellar water Collection Date 08/28/10 Collection Time 00:00 Analysis Unit Result Appearance - -- See Comments Appearance: pink hue, single phase, no sheen, minor solids on bottom, dead mosquitoes floating on surface. Specific gravity: 1.0010 FTIR: Nothing detected besides water. Toluene extraction quick test: color does migrate too toluene phase. Comments: Sample is fresh water. The pink color is probably due to the presence of a water soluble dye but its concentration is so low that it was not detectable. If there are any questions regarding this data, please call KLS at 659 -7214. Completed By: MA Reviewed By: JA Suspended Well Inspection — KRU 1J -133 PTD 2061060 Photos by AOGCC Inspector B. Noble 8 -28 -2010 _. a►• a 7 It r l ails is �� = �� ___„........_ ,... ID — . y e O p . -- ' - . ' ri k { 411 .141044141/4. ° :. ...110F 71111.101MMO, .ft • KRU 1 J -133 Suspended Well Inspection 8 -28 -10 bn 1 • • . ,-..-s- ilt ' ,,,- '.' '91, . IP — - * ' , ' \ - .. 4 ...- J •�v. a x r N, ; ... . _ C k t 1 4 I' • i • KRU 1J -133 Suspended Well Inspection 8 -28 -10 bn 2 • • 911/A oT n[1 SEAN PARNELL, GOVERNOR ALASKA OIL AND =AS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 O Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J -133 Sundry Number: 310 -417 Dear Ms. Loveland: StANNED JAN ;;. 2,01 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 I day of January, 2011. Encl. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 /'! Iv D December 11, 2010 2Q1� 4iaska Oi ®E Gas C Cans. Commission dnchorg,s 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 1J -133 (PTD 206 -106) 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 1J -133 (PTD 206 -106) per 20 AAC 25.110. The well was visually inspected September 28, 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 is on an active pad. CPAI request the renewal of the suspension because the well is being held for future West Sak development. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, c„,„ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures . STATE OF ALASKA CA V ALASKWIL AND GAS CONSERVATION COMMISSO t ,��I ‘-� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend — • Plug Perforations r Perforate r Rill Tubing T Time Extensior Operational Shutdown R - Sus Well l • Y fl OP I p• r Stimulate r Alter casing r I�wa„ Su s�aew SiOh 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206 -106 ' 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 23315 - 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 I✓ 1J - 133 • 9. Property Designation: 10. Field /Pool(s): ADL 25662 & 380058 Kuparuk River Unit Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10878 ' 3716 10790' 3714' NONE NONE Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108' 108' SURFACE 3689 13.375 3719' 2225' INTERMEDIATE 10845 9.625 10873' 3716' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE ✓ NONE Kill String 4.5 L - 80 2243 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) NONE NONE 12. Attachments: Description Summary of Roposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r 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. I 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 KI n Title: WELL INTEGRITY SUPERVISOR Signature / 77 , 04 , 1yc .,� ° Phone: 659 -7043 Date / a _ // / v Commission Us my Sundry Number: ' O -4\ i Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED IV D — DEC I 4 MO Subsequent Form Required: /VcA.... - .— + "-- AIasks Chi St has Cons. Commission 0 7horenoi fr / APPROVED BY / Approved by: R : , ∎ s JAN 0 6 20 . OMMISSIONER THE COMMISSION Date: / �I ! • 3 • // f i /. ,7 Form 10-403 Revised 1/2010 Submit in Ddplicate 1-TRIGINit\ /0 • • ConocoPhillips West Sak 9 -5/8" Injector 1J-133 Dual Lateral Intermediate 4 -1/2" Kill String Set .L So Below Permafrost @ as yy M O J IV 13.3/8" Casing Shoe, L -80, BTC set a 37 /9'MD, 2,225' TVD 9.5/8" Casing Shoe, 40.0#, L -80 BTC @ 10S0 MD, 37T ' TVD Set up for B-Sand Drill Out (84 deg Inc) Ow. TINU (having Noe Baker Oil Thole 2008 Wert Sak Dual Lateral Intermediate - InJ.ctor bun Jun. fl 200e ram NT' mac D. Kuck maMNn N..: 0 vpe NU Ina ~ - ~ti ..~< ~ . ~ F ,~^ ~ ~,~, .~ . ~,: `~. ~~` .~ ~:;E ~ ~. , 3...: ~+: MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfitm_Marker.doc • `~ . • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 .~;;i`_~ si .. _. , .. Dear Mr. Maunder: 6~- ~O ~O ~.~' . `~' `3~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15`~ and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~`, 28;~ and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~,- ~~ MJ Loveland . SEP 0 2 2009 Al~~k~ 0~1 ~ C~s C~ns..Gorrxr~ission Aneho~~ ConocoPhillips Well Integrity Projects Supervisor • ~ ~~~ ~ °'~ ~~f`~ ~ •,: k 4~~ `*` x _ i<,z~ ~.. . ~:: ~_ f ~<~ ~, ? (~~1~ ConocoPhillips Alaska Inc. ~°~I~;':x~ ~}~~ f`,~ ~=,e~~ ~;~~t~ ~;s~~t°3~~cc=€~~ ~iSte~¢-Fa~p.s,~a~<,.7 Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor ~ , Corrosion inhibitor/ sealant date bbls ft - al ___.. 1J-03 50029230020000 2U10240 22" N/A 22" N/A 4.1 8/29/2009 1 J-09 50029230060000 2010440 28" N/A 28" N/A 6.2 8/29/2009 1J-10 50029230100000 2010710 12" N/A 12" N/A 2.3 8/29@009 1J-133 50029233150000 2061060 3' N/A 3' N/A 23.8 8/30/2009 3G-24 50103201450000 1901340 18" N/A 18" N/A 5.1 8/30/2009 1A-19 50029221110000 1901610 30" N/A 30" N/A 3.8 8/30/2009 2Z-04 50029209650000 1830860 19" ~ N/A 19" N!A 3.5 8/30/2009 2Z-05 50029209560000 1830760 12" N/A 12" N/A 2.1 8/30/2009 2Z-07 50029209460000 1830640 9" N/A 9" N/A 8.5 8/30/2009 2Z-15 50029213620000 1851080 9" N/A 9" N/A 2.8 2Z-21 50029218770000 1881250 3' N/A 3' N/A 19.6 8/30/2009 1J 3G 1A 8~ 2ZPAD 13 ~,~" DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2061060 Well Name/No. KUPARUK RIV U WSAK 1J-133 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23315-00-00 MD 10878 ND 3716 Completion Date 8/13/2006 Completion Status SUSP Current Status SUSP UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken fro m Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt 14182 LIS Verification 3700 10878 Open 10/19/2006 LIS Verification fr~D C Lis 14182 Induction/Resistivity 3700 10878 Open 10/19/2006 NPHI, NCNT, FET, GR, RHOB,ROP ~D D Asc Directional Survey 0 10878 Open 10/19/2006 '~pt~ 14222 LIS Verification 3700 10878 Open 11/9/2006 Lis Verification NPHI, ', NCNT, FCNT, GR, RHOB, ', w/Graphics C Lis 15010 Induction/Resistivity 3700 10878 Open 4/17/2007 LIS Veri, NPHI, NCNT, FCNT, FET, GR, RHOB, ~, DRHO, ROP w/Graphics EMF, CGM, PDF Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /~j Chips Received? ~L Analysis ~~ Received? Comments: Interval Start Stop Sent Received Daily History Received? Formation Tops Sample Set Number Comments ~N ~/ N DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2061060 Well Name/No. KUPARUK RIV U WSAK 1J-133 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23315-00-00 MD 10878 ND 3716 Co p etion Date 8/13/2006 Completion Status SUSP Current Status SUSP UIC Y Compliance Reviewed By: Date: ~1~1 WELL LOG TRAl'~1SMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-133, C~ April 17, 2007 AK-MW-4528227 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 1J-133: LIS & Digital Log Images: 50-029-23315-00 ~.~R ~ ~ 200 3 ~ ~~ mss, ~ 1 CD Rom ~~N~~ SEF ~ " 2008 C ~G- ~ /Sb/d ~t.~6- 106 r WELL LOG TRANSMITTAL • To: State of Alaska October 26, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-133, AK-MW-4528227 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 315-00 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 1 Date: Signed: Note: This data replaces any previous data for well 1J-133. ~~~~~~~ ~ ~~(~~~ • • 13-Sep-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-133 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Surrey: Window /Kickoff Survey Projected Survey: 28.00' MD 0.00' MD (if applicable) 10,878.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~ -ld ~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-133, October 2, 2006 AK-MW-4528227 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 315-00 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: ~{ ( ~, ~~~ Sued: :~~ _~~_. _ e ConocoPhillips August 31, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1J-133 Dear Commissioner: • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RECEIVED SAP p ~ 2006 Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk West Sak wells 1 J-133. We have installed a kill string and intend to return to this well in the future. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ~ < <t _-._ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RE~E1~/ED - STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM SIGN S E P 0.5" D06 WELL COMPLETION OR RECOMPLETION REPORT AND LUG 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended ~ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Wet I ff1iSS101? Development [~nchorag>l~loratory ^ Service ^~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc, 5. Date Comp., Susp., orAband.: August 13, 2006 12. Permit to Drill Number: 206-106 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 30, 2006 13. API Number: 50-029-23315-00 ' 4a. location of Well (Governmental Section): Surface: 1622' FSL, 2296' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: August 9, 2006 14. Well Name and Number: 1J-133 At Top Productive Horizon: 742' FNL, 2250' FWL, Sec. 12, T10N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 1118' FNL, 2227' FWL, Sec. 12, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 10790' MD / 3714' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558917 • y- 5945436 Zone- 4 10. Total Depth (MD + ND): t 10878' MD / 3716' ND • 16. Property Designation: ADL 25662 & 380058 TPI: x- 563530 y- 5937830 Zone- 4 Total Depth: x- 563510 • - 5937454. Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 6582' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP 80TTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.6# H-40 28' 108' 28' 108' 42" 2s2 sx AS1 13.375" 68# L-80 28' 3719' 28' 2224' 16" 687 sx Class G, 221 sx Class G 9.625" 40# L-80 28' 10873' 28' 3716' 12.25" s28 sx Class G 4.5" 12.6# L-80 24' 2244' 24' 1847' kill string 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET none none ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.j 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". c0(f ~'i_ET10N • O~TE NONE Form 10-407 Revised 12!2003 CONTINUE C~I~gS~ ~ ~\' ~ L i~' w ~f. s',Q~ v ' ` ~,f Y w ^~rj`o6' ~~ 2s. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-133 Top West Sak B 10501' 3694' Base West Sak B 10878' 3716' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na Ran Thomas Titie: Greater Kuoaruk Area Drilling Team Leader Si ~~3 ~ /©6 - " gnature hone G-N 3 p Date ~ ~, 5 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 Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersibie, 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 • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/25/2006 Timc: 10:16:09 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1 J-133, True North Site: Kuparuk 1J Pad Ve rtical (TVD) Re ferences 1J-133 109.0 ~1ell: 1 J-133 Section (VS) Reference: Well (O.OON,O.OOE,180-OOAzi) W eilpath: 1 J-133 Su rvey Calculation Method: Minimum Curva ture I)b: Oracle Field: Kuparuk River Unit ~ North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea level Geomagnetic Model: bggm2005 We1L 1J-133 Slot Name: Well Position: +N/-S -484.80 ft Northing: 5945435.86 ft Latitude: 70 15 41.490 N +E/-W 123.06 ft Easting : 55891 6.78 ft • Longitude: 149 31 25.426 W Position Uncertainty: 0.00 ft - - ~ Wellpath: 1J-133 Drilled From: Well Ref. Point ~ i 500292331500 Current Datum: 1J-133: Height 109.00 ft Tie-on Depth: Above System 28.00 ft Datum: Mean Sea Level ~ Magnetic Data: 7/25/2006 Declination: 24.02 deg Field Strength: 57565 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath - -~ Date: 12/18/2004 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft I 50.00 1007.00 1J-133 gyro (50.00-1007.00) CB-GYRO-SS __-- Camera based gyro single shot -I 1040.85 10830.56 1 J-133 (1040.85-10830.56) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ' --- Survey - - -- MD Incl Azim TYD Sys 1'Vll V'%ti EIVV MapN ,tilapE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945435.86 558916.78 TIE LINE 50.00 0.28 350.37 50.00 -59.00 0.05 -0.01 5945435.91 558916.77 CB-GYRO-SS 100.00 0.35 340.36 100.00 -9.00 0.32 -0.08 5945436.18 558916.70 CB-GYRO-SS 171.00 0.51 353.65 171.00 62.00 0.84 -0.19 5945436.69 558916.58 CB-GYRO-SS 262.00 0.64 90.35 261.99 152.99 1.23 0.27 5945437.10 558917.05 CB-GYRO-SS ' 354.00 3.26 138.53 353.94 244.94 -0.73 2.52 5945435.15 558919.31 CB-GYRO-SS 446.00 6.91 135.98 445.56 336.56 -6.67 8.10 5945429.25 558924.93 CB-GYRO-SS 538.00 9.44 132.03 536.62 427.62 -15.70 17.55 5945420.30 558934.45 CB-GYRO-SS 630.00 12.38 128.11 626.95 517.95 -26.84 30.92 5945409.26 558947.91 CB-GYRO-SS i 730.00 16.28 132.84 723.82 614.82 -43.00 49.64 5945393.26 558966.75 CB-GYRO-SS j 821.00 17.93 134.26 810.79 701.79 -61.45 69.03 5945374.96 558986.28 CB-GYRO-SS 914.00 19.30 133.32 898.92 789.92 -81.98 90.46 5945354.60 559007.87 CB-GYRO-SS 1007.00 22.05 133.89 985.93 876.93 -104.63 114.23 5945332.13 559031.81 CB-GYRO-SS i 1040.85 24.06 128.78 1017.07 908.07 -113.36 124.19 5945323.48 559041.84 MWD+IFR-AK-CAZ-SC t 1132.98 24.82 128.03 1100.95 991.95 -137.04 154.06 5945300.04 559071.89 MWD+IFR-AK-CAZ-SC 1226.29 28.27 134.87 1184.43 1075.43 -164.71 185.16 5945272.62 559103.21 MWD+IFR-AK-CAZ-SC j 1318.59 31.59 137.23 1264.41 1155.41 -197.89 217.08 5945239.70 559135.38 MWD+IFR-AK-CAZ-SC 1411.20 38.92 134.75 1339.99 1230.99 -236.23 254.26 5945201.65 559172.86 MWD+IFR-AK-CAZ-SC 1504.42 39.95 135.11 1411.99 1302.99 -278.05 296.18 5945160.17 559215.10 MWD+IFR-AK-CAZ-SC 1597.97 44.34 137.69 1481.34 1372.34 -323.53 339.41 5945115.03 559258.68 MWD+IFR-AK-CAZ-SC I 1691.06 45.78 137.71 1547.09 1438.09 -372.26 383.76 5945066.65 559303.40 MWD+IFR-AK-CAZ-SC 1782.87 52.52 137.00 1607.11 1498.11 -423.30 430.79 5945015.98 559350.83 MWD+IFR-AK-CAZ-SC 1875.06 52.01 138.27 1663.53 1554.53 -477.17 479.92 5944962.51 559400.37 MWD+IFR-AK-CAZ-SC 1968.38 58.07 135.94 1716.98 1607.98 -533.12 531.99 5944906.96 559452.88 MWD+IFR-AK-CAZ-SC 2060.47 59.87 137.36 1764.45 1655.45 -590.51 586.15 5944850.01 559507.48 MWD+IFR-AK-CAZ-SC 2153.86 63.79 140.21 1808.54 1699.54 -652.44 640.35 5944788.51 559562.15 MWD+IFR-AK-CAZ-SC 2246.28 68.20 142.60 1846.13 1737.13 -718.42 692.97 5944722.95 559615.29 MWD+IFR-AK-CAZ-SC 2338.88 68.35 144.58 1880.41 1771.41 -787.65 744.03 5944654.13 559666.88 MWD+IFR-AK-CAZ-SC ~~ 2431.48 72.87 145.82 1911,15 1802.15 -859.36 793.85 5944582.82 559717.26 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ' Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1 J Pad Nell: 1J-133 Wellpath: 1J-133 Dafc: 3/25/2006 Co-urdinatc(NE) Reference: Vertical (11`D) Reference: Sec~tiun~~SlReference: Sun~c~~ l~alculation Method: 'l'ime: 10:16'09 Pale: 2 Well: 1 J-133, Ttue North 1.~-133- 109.0 Well (0-OON,O.OOE,180:OOAzi) Minimum Curvature llb: Oracle tiur~ ev MD Inc! Aim 7 ~ I) ........ ...Sys TVll V!S E;1~~ ~lap~ ~~1apE Too! ft deg deg ft ft ft ft ft ft 2523.29 76.08 142. 52 1935. 73 1826.73 -931 .05 845. 64 5944511. 54 559769.59 MWD+IFR-AK-CAZ-SC 2615.85 76.74 141. 24 1957. 48 1848.48 -1001 .83 901. 18 5944441. 21 559825.68 MWD+IFR-AK-CAZ-SC ~ 2709.54 76.68 141. 26 1979. 01 1870.01 -1072 .94 958. 25 5944370 .55 559883.30 MWD+IFR-AK-CAZ-SC 2801.61 75.60 142. 43 2001. 07 1892.07 -1143 .23 1013. 47 5944300 .71 559939.07 MWD+IFR-AK-CAZ-SC ~ 2894.63 77.41 142. 40 2022. 77 1913.77 -1214 .90 1068. 64 5944229. 47 559994.79 MWD+IFR-AK-CAZ-SC ~ 2987.01 78.20 142. 72 2042. 29 1933.29 -1286 .59 1123. 53 5944158. 22 560050.24 MWD+IFR-AK-CAZ-SC ~ i 3079.63 77.93 142. 44 2061. 44 1952.44 -1358 .56 1178. 60 5944086. 69 560105.86 t MWD+IFR-AK-CAZ-SC 3172.05 76.35 140. 32 2082. 01 1973.01 -1428 .96 1234. 82 5944016. 74 560162.63 MWD+IFR-AK-CAZ-SC 3264.66 72.15 139. 23 2107. 15 1998,15 -1497 .00 1292. 36 5943949. 16 560220.69 MWD+IFR-AK-CAZ-SC 3357.71 70.75 139. 71 2136. 75 2027.75 -1564 .05 1349. 69 5943882. 57 560278.54 MWD+IFR-AK-CAZ-SC 3449.33 74.50 142. 99 2164. 11 2055.11 -1632 .33 1404. 26 5943814 .72 560333.64 MWD+IFR-AK-CAZ-SC 3543.20 77.30 144. 42 2186. 98 2077.98 -1705 .70 1458. 14 5943741 .78 560388.08 MWD+IFR-AK-CAZ-SC 3634.16 77.80 141. 51 2206. 59 2097.59 -1776 .59 1511. 63 5943671 .32 560442.12 MWD+IFR-AK-CAZ-SC 3684.81 77.49 140. 89 2217. 43 2108.43 -1815 .15 1542. 64 5943633 .01 560473.42 MWD+IFR-AK-CAZ-SC 3793.68 75.79 141. 05 2242. 58 2133.58 -1897 .43 1609. 34 5943551 .26 560540.76 MWD+IFR-AK-CAZ-SC ~ 3887.48 74.77 141. 02 2266. 42 2157.42 -1967 .97 1666. 39 5943481. 18 560598.35 MWD+IFR-AK-CAZ-SC 3976.09 74.82 142. 09 2289. 66 2180.66 -2034 .94 1719. 55 5943414 .63 560652.03 MWD+IFR-AK-CAZ-SC 4070.48 75.77 142. 80 2313. 62 2204.62 -2107 .32 1775. 20 5943342 .70 560708.24 MWD+IFR-AK-CAZ-SC 4164.01 76.34 143. 73 2336. 16 2227.16 -2180 .06 1829. 49 5943270 .39 560763.09 MWD+IFR-AK-CAZ-SC 4256.56 76.60 144. 04 2357. 81 2248.81 -2252 .75 1882. 53 5943198 .12 560816.69 MWD+IFR-AK-CAZ-SC 4349.92 76.80 145. 36 2379. 29 2270.29 -2326 .90 1935. 03 5943124 .39 560869.76 MWD+IFR-AK-CAZ-SC 4442.65 76.97 145. 81 2400. 33 2291.33 -2401 .41 1986. 07 5943050 .29 560921.38 MWD+IFR-AK-CAZ-SC 4535.85 78.34 146. 88 2420. 26 2311.26 -2477 .19 2036. 52 5942974 .92 560972.42 MWD+IFR-AK-CAZ-SC 4628.69 78.73 146 .37 2438. 71 2329.71 -2553 .17 2086. 57 5942899 .34 561023.06 MWD+IFR-AK-CAZ-SC 4721.60 78.93 148 .10 2456. 71 2347.71 -2629 .82 2135. 90 5942823 .09 561072.98 MWD+IFR-AK-CAZ-SC 4814.07 79.49 150 .77 2474. 03 2365.03 -2708 .02 2182. 09 5942745 .25 561119.78 MWD+IFR-AK-CAZ-SC 4907.41 79.80 150. 58 2490. 80 2381.80 -2788 .08 2227. 06 5942665 .56 561165.37 MWD+IFR-AK-CAZ-SC 4999.62 80.48 150. 72 2506. 59 2397.59 -2867 .26 2271. 58 5942586 .73 561210.51 MWD+IFR-AK-CAZ-SC 5091.53 80.36 150. 50 2521. 89 2412.89 -2946 .23 2316. 06 5942508 .12 561255.60 MWD+IFR-AK-CAZ-SC I 5185.11 79.62 150. 01 2538. 16 2429.16 -3026 .24 2361. 78 5942428 .48 561301.94 MWD+IFR-AK-CAZ-SC 5278.40 79.31 148. 23 2555. 21 2446.21 -3104 .95 2408. 85 5942350 .15 561349.62 MWD+IFR-AK-CAZ-SC ~ , 5369.69 78.44 147. 18 2572. 83 2463.83 -3180 .67 2456. 71 5942274 .81 561398.06 MWD+IFR-AK-CAZ-SC 5462.80 77.05 146. 18 2592. 59 2483.59 -3256 .70 2506. 68 5942199 .18 561448.63 MWD+IFR-AK-CAZ-SC 5556.28 76.22 146 .14 2614. 20 2505.20 -3332 .24 2557. 33 5942124 .05 561499.86 MWD+IFR-AK-CAZ-SC 5649.23 75.28 146 .17 2637. 08 2528.08 -3407 .06 2607. 51 5942049 .63 561550.61 MWD+IFR-AK-CAZ-SC 5739.82 75.90 146 .52 2659. 62 2550.62 -3480 .10 2656. 13 5941976 .98 561599.80 MWD+IFR-AK-CAZ-SC 5831.94 75.34 146 .41 2682. 50 2573.50 -3554 .48 2705. 43 5941903 .00 561649.67 MWD+IFR-AK-CAZ-SC 5926.88 74.76 147. 57 2706. 99 2597.99 -3631 .39 2755. 40 5941826 .48 561700.24 MWD+IFR-AK-CAZ-SC '~, 6017.91 74.14 148. 58 2731. 40 2622.40 -3705 .83 2801. 77 5941752 .42 561747.19 MWD+IFR-AK-CAZ-SC 6109.67 74.82 149. 44 2755. 95 2646.95 -3781 .62 2847. 29 5941677 .00 561793.30 MWD+IFR-AK-CAZ-SC 6201.81 75.27 149. 86 2779. 73 2670.73 -3858 .44 2892. 27 5941600 .54 561838.87 MWD+IFR-AK-CAZ-SC 6291.01 74.90 150 .78 2802. 69 2693.69 -3933 .32 2934. 95 5941526 .00 561882.13 MWD+IFR-AK-CAZ-SC 6388.10 74,95 151 .62 2827. 94 2718.94 -4015 .47 2980. 12 5941444 .21 561927.93 MWD+IFR-AK-CAZ-SC ~ 6479.13 75.52 151 .98 2851. 14 2742.14 -4093 .05 3021. 71 5941366 .97 561970.13 MWD+IFR-AK-CAZ-SC 6572.65 75.82 151 .80 2874. 29 2765.29 -4172 .97 3064. 40 5941287 .39 562013.44 MWD+IFR-AK-CAZ-SC 6665.46 76,41 152 .01 2896. 56 2787.56 -4252 .45 3106. 83 5941208 .25 562056.49 MWD+IFR-AK-CAZ-SC ' 6758.16 76.77 150 .77 2918. 06 2809.06 -4331 .61 3150. 01 5941129 .44 562100.28 MWD+IFR-AK-CAZ-SC 6850.12 78.10 150 .00 2938 .06 2829.06 -4409 .64 3194. 37 5941051 .77 562145.24 MWD+IFR-AK-CAZ-SC 6944.64 78.30 150 .03 2957 .39 2848.39 -4489 .78 3240. 61 5940972 .00 562192.10 MWD+IFR-AK-CAZ-SC 7035.75 78.37 149 .95 2975. 81 2866.81 -4567 .05 3285. 24 5940895 .09 562237.33 MWD+IFR-AK-CAZ-SC 7132.14 79.11 150 .03 2994. 64 2885.64 -4648 .91 3332. 52 5940813 .61 562285.25 MWD+IFR-AK-CAZ-SC '. 7222.20 79.49 149 .16 3011. 36 2902.36 -4725 .23 3377. 31 5940737 .65 562330.62 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/25/2006 7 ime: 10:16:09 I'a~c: 3 Field: Ku panik River Uni t Co-ordinatc(NE) Reft•rcncr. Well: 1J-133, Tr ueNorth Site: Ku paruk 1J Pad Veeticut{TVD)Refercucc: 1.~-133- 109.0 N'elJ: 1J- 133 Sectio n(VS)Refe rcncc: Welf(0-OON,O.OOE,180.OOAzi} ~~'etlpath: 1 J- 133 Surve y Calculatia ~n 1lcthud: Minimum Curvature llb: Oracle Sunc~ ill) Lrcl Aunt _ ___ TVD tips ll~I l N1S E/W _-- WlapA' ~tapE liwl ~ ft dey de g ft ft ft ft ft ft I 7315.23 79.19 148 .37 3028. 57 2919. 57 -4803.40 3424. 71 5940659 .86 562378.64 MWD+IFR-AK-CAZ-SC 7405.42 79.80 147 .77 3045. 01 2936. 01 -4878.66 3471. 61 5940584 .98 562426.12 MWD+IFR-AK-CAZ-SC 7499.74 79.74 147 .30 3061. 76 2952. 76 -4956.98 3521. 44 5940507 .06 562476.55 MWD+IFR-AK-CAZ-SC 7590.46 78.32 147 .31 3079. 02 2970. 02 -5031.93 3569. 54 5940432 .50 562525.24 MWD+IFR-AK-CAZ-SC 'i 7685.78 78.42 147 .22 3098. 24 2989. 24 -5110.46 3620. 03 5940354 .37 562576.33 I MWD+IFR-AK-CAZ-SC ~ 7776.74 77.37 146 .98 3117 .31 3008. 31 -5185.13 3668. 34 5940280 .08 562625.22 MWD+IFR-AK-CAZ-SC 7869.80 76.92 147 .10 3138 .02 3029. 02 -5261.26 3717. 70 5940204 .35 562675.17 MWD+IFR-AK-CAZ-SC 7957.10 76.54 147 .57 3158 .06 3049. 06 -5332.79 3763. 56 5940133 .19 562721.58 MWD+IFR-AK-CAZ-SC 8050.97 75.47 147 .79 3180 .76 3071. 76 -5409.76 3812. 26 5940056 .61 562770.88 MWD+IFR-AK-CAZ-SC 8146.37 74.45 149 .27 3205. 51 3096. 51 -5488.34 3860. 35 5939978 .42 562819.58 MWD+IFR-AK-CAZ-SC 8239.28 74.45 150 .09 3230. 42 3121. 42 -5565.60 3905. 54 5939901 .52 562865.37 MWD+IFR-AK-CAZ-SC 8332.35 74.44 150 .61 3255. 38 3146. 38 -5643.52 3949. 90 5939823 .95 562910.33 MWD+IFR-AK-CAZ-SC ~ 8424.10 74.13 150 .63 3280. 23 3171. 23 -5720.48 3993. 23 5939747 .34 562954.25 MWD+IFR-AK-CAZ-SC 8518.29 74.30 150 .33 3305. 85 3196. 85 -5799.35 4037. 89 5939668 .83 562999.53 MWD+IFR-AK-CAZ-SC 8610.47 74.50 151 .74 3330. 64 3221. 64 -5877.03 4080. 88 5939591 .50 563043.12 MWD+IFR-AK-CAZ-SC , ~ 8703.09 75.76 151 .50 3354. 41 3245. 41 -5955.79 4123. 43 5939513 .08 563086.28 MWD+IFR-AK-CAZ-SC 8795.82 76.21 152 .20 3376. 87 3267. 87 -6035.12 4165. 87 5939434 .10 563129.34 MWD+IFR-AK-CAZ-SC 8888.52 77.04 154 .42 3398 .32 3289. 32 -6115.69 4206. 38 5939353 .86 563170.47 MWD+IFR-AK-CAZ-SC 8981.54 76.73 155 .62 3419 .42 3310. 42 -6197.80 4244. 63 5939272 .05 563209.36 MWD+IFR-AK-CAZ-SC ~: i 9076.49 77.60 156 .15 3440 .52 3331. 52 -6282.30 4282. 46 5939187 .86 563247.84 i MWD+IFR-AK-CAZ-SC 9166.59 77.92 157 .19 3459 .62 3350. 62 -6363.15 4317. 33 5939107 .29 563283.34 MWD+IFR-AK-CAZ-SC 9260.66 78.48 158 .92 3478 .86 3369. 86 -6448.56 4351. 74 5939022 .16 563318.42 MWD+IFR-AK-CAZ-SC 9353.73 78.67 160 .14 3497 .29 3388. 29 -6534.02 4383. 64 5938936 .96 563350.98 MWD+IFR-AK-CAZ-SC 9444.02 78.43 161 .44 3515 .22 3406. 22 -6617.59 4412. 76 5938853 .63 563380.75 MWD+IFR-AK-CAZ-SC 9535.15 76.99 162 .26 3534 .61 3425. 61 -6702.19 4440. 49 5938769 .25 563409.15 MWD+IFR-AK-CAZ-SC ~i 9628.51 76.55 164 .26 3555 .98 3446. 98 -6789.22 4466. 67 5938682 .44 563436.00 MWD+IFR-AK-CAZ-SC 9722.09 76.53 165 .59 3577 .77 3468. 77 -6877.10 4490. 34 5938594 .77 563460.35 MWD+IFR-AK-CAZ-SC 9809.85 79.33 168 .26 3596 .12 3487. 12 -6960.68 4509. 74 5938511 .35 563480.41 MWD+IFR-AK-CAZ-SC ~I 9902.40 82.39 171 .20 3610 .82 3501. 82 -7050.57 4526. 02 5938421 .59 563497.38 MWD+IFR-AK-CAZ-SC 9995.33 82.08 174 .11 3623 .38 3514. 38 -7141.88 4537. 79 5938330 .39 563509.87 MWD+IFR-AK-CAZ-SC 10088.64 81.37 175 .03 3636 .81 3527. 81 -7233.80 4546. 53 5938238 .54 563519.32 MWD+IFR-AK-CAZ-SC 10181.67 81.07 178 .26 3651 .01 3542. 01 -7325.57 4551. 91 5938146 .83 563525.42 MWD+IFR-AK-CAZ-SC 10275.55 81.64 178 .51 3665 .12 3556. 12 -7418.35 4554. 52 5938054 .08 563528.76 MWD+IFR-AK-CAZ-SC i 10368.23 83.32 180 .72 3677 .25 3568. 25 -7510.22 4555. 14 5937962 .23 563530.10 MWD+IFR-AK-CAZ-SC 10459.02 82.19 180 .38 3688 .70 3579. 70 -7600.28 4554. 27 5937872 .17 563529.94 MWD+IFR-AK-CAZ-SC ~ ~ 10553.57 84.74 182 .56 3699 .47 3590. 47 -7694.17 4551. 86 5937778 .28 563528.26 MWD+IFR-AK-CAZ-SC j 10644.74 85.98 183 .31 3706 .84 3597. 84 -7784.92 4547. 21 5937687 .50 563524.31 MWD+IFR-AK-CAZ-SC 10737.29 86.77 184 .08 3712 .69 3603. 69 -7877.09 4541. 25 5937595 .29 563519.08 MWD+IFR-AK-CAZ-SC 10830.56 89.47 184 .55 3715 .75 3606. 75 -7970.04 4534. 24 5937502 .31 563512.80 MWD+IFR-AK-CAZ-SC 10878.00 89.47 184 .55 3716 .19 3607. 19 -8017.33 4530. 48 5937454 .99 ~ 563509.41 ~ PROJECTED to TD ConocPh[ii s Time Lo Summa Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 07/29/2006 06:00 07:15 1.25 MIRU MOVE DMOB P Move all modules off 1J-156, pipeshed, rockwasher, boilers, motors, pump room & its. 07:15 08:15 1.00 MIRU MOVE DMOB P Move substucture off 1J-156. 08:15 10:30 2.25 MIRU MOVE MOB P Spot substructure on 1J-133. 10:30 12:00 1.50 MIRU MOVE MOB P Lay matting boards & spot pits. 12:00 12:30 0.50 MIRU MOVE MOB P PJSM on rig move safety. Spot pump com lex & lower w/ its. 12:30 13:00 0.50 MIRU MOVE MOB P Spot & lower motor complex. 13:00 13:30 0.50 MIRU MOVE MOB P Spot & lower boiler complex. 13:30 14:00 0.50 MIRU MOVE MOB P Spot rock washer. 14:00 14:30 0.50 MIRU MOVE MOB P Spot pipe shed #1 & wash water tank. 14:30 15:00 0.50 MIRU MOVE MOB P Spot #2 pipe shed & lower w/ #1, release eak trucks. 15:00 16:30 1.50 MIRU MOVE MOB P Work on rig acceptance check list, service lines & wire ties, cellar pump, drain hoses, stairways & handrails, well sign & permits, pumps alignment, plugs & caps, H2O, skate, all tools put awa & all berms in lace. 16:30 19:15 2.75 MIRU DRILL OTHR P (Accept rig @ 1630 hrs. 7-29-2006)Nipple up diverter stack, turn buckles, Koomey & knife valve lines, diverter line=134' from center of well, off rig power on hi-line power @ 17:30. 19:15 21:30 2.25 MIRU DRILL PULD P PJSM & hazzard assesment on P/U drill pipe. Install mouse hole, Drift & ick u 105 'ts. 5" d . 21:30 22:00 0.50 MIRU DRILL OTHR P Perform diverter test w/ toolpusher. (Witness test waived by John Crisp AOGCC) Start 3000 psi Close 2200psi 22:00 00:00 2.00 MIRU DRILL PULD P Picking up 5" drill pipe. 07/30/2006 00:00 00:15 0.25 108 108 MIRU DRILL SFTY P PJSM on pick up 5" drill pipe, BHA & ri in u wire line for ro. 00:15 00:30 0.25 108 108 MIRU DRILL PULD P Pick up BHA from beaver slide. 00:30 01:30 1.00 108 86 SURFA DRILL PULD P Make up bit, motor, stab, float sub, xo,s & 1 stand hwdp. Tagged cement 86'. 01:30 01:45 0.25 86 86 SURFA DRILL OTHR P Flooded conductor, no leaks. Pressure tested surface lines to 3500 si. a _.._ _~_ ~.._.. .,...._ ._ _. ~ _ ~_._.~_~...------ ~ P~g~ a oaf 'tom Time Lo s Date From To Dur th E. De th Phase Code Subcode .,OM 07/30/2006 01:45 02:00 0.25 86 108 SURFA DRILL DRLG P Drill out cement from 86' to 108' 50 r m 500 m 600 si. 02:00 03:45 1.75 108 224 SURFA DRILL DRLG P Drlg. from 108' to 224'. ADT 1.68 ART 1.68. 03:45 05:30 1.75 224 224 SURFA DRILL PULD P Rack back 2 stands HWDP, make up pressure drop sub, 3 jts. nonmag flex dc,s from shed, UBHO sub & XO. 05:30 06:00 0.50 224 224 SURFA DRILL OTHR P Rig up wire line unit for gyro surveys. 06:00 12:00 6.00 224 540 SURFA DRILL DRLG P Drlg. from 224 MD to to 540 MD (TVD 539') ADT 3.33 ART 1.49 AST 1.84 P/U 68k S/O 68k TQ 2k, GYRO every stand. 12:00 00:00 12.00 540 1,435 SURFA DRILL DRLG P Drlg. from 540' MD to 1435' MD (TVD 1359') P/U 87k S/O 81 k ROT 80k TQ on 6k TQ off 4k Max gas 66 units ADT 6.97 ART 2.0 AST 4.97, Last GYRO 1,022', Ri down GYRO E ui. 07/31/2006 00:00 09:30 9.50 1,435 2,482 SURFA DRILL DDRL P Drlg. from 1435' MD to 2482 MD (1924 TVD) ADT=6.79 AST=3.89 ART=2.93 P/U 94k S/O 75k ROT 83k TQ 5-7k. @ 2345 tt~t? 1882' TVD had 1378 units back to surface, 09:30 12:00 2.50 2,482 1,001 SURFA DRILL TRIP P Flow check. BROOH 50 rpm 800 GPM 2800 psi from 2482 to 1001 MD w/ no roblems. 12:00 12:15 0.25 1,001 700 SURFA DRILL SFTY P PJSM=Pull 3 stands DP. 12:15 13:30 1.25 700 0 SURFA DRILL TRIP P Lay down ghost reamer, pull 6 stands HWDP 1 stand dc,s. 13:30 13:45 0.25 0 0 SURFA DRILL OTHR P Drain motor-clean & grade bit. 13:45 14:00 0.25 0 0 SURFA DRILL OTHR P Break motor-reset bend to 1.15 deg. 14:00 14:15 0.25 0 0 SURFA DRILL OTHR P Orient motor. 14:15 14:45 0.50 0 0 SURFA DRILL OTHR P Clean & clear rig floor. 14:45 16:30 1.75 0 2,390 SURFA DRILL TRIP P RIH to 2390'. 16:30 16:45 0.25 2,390 2,482 SURFA DRILL UREM P Wash & ream to bottom @ 2482'. 16:45 00:00 7.25 2,482 3,130 SURFA DRILL DDRL P Drlg. from 2482' MD 1924' TVD to 3130' MD 2070' TVD. (ADT 5.06 ART 3.36 AST 1.70 P/U 93k S/O 70k ROT 78k TO on 9k TO off 4k. 08/01/2006 00:00 00:15 0.25 3,130 3,130 SURFA DRILL SFTY P PJSM on Drilling ahead and Back Reamin . 00:15 07:30 7.25 3,130 3,736 SURFA DRILL DDRL P Drill 16" hole w/ 1.15 motor bend f/ 3,130' to 3,736' MD / 2,228' TVD (606'), ADT= 6.04 hrs, AST= 4.75 hrs, ART= 1.29 hrs, WOB 20-25K, 100-110 RPM, 764 gpm @ 2700 psi, Up 110K, Dn 62K, Rot 80K, TQ 10.5K on / 8K off, Max as 88 units. Pp~~~ ~ cap ~ Time Lo s Date From To Dur th E. De th Phase Code Subcode Z fJM 08/01/2006 07:30 11:00 3.50 3,736 1,095 SURFA DRILL TRIP P Monitor well- Static, Back Ream out of hole f/ 3,736' to 1,095'. (Note; Circ Btm's up while back reaming 3 stands very slow at 825 gpm -Staged flow rate down to 550 gpm on the way out of hole - Hole cleaned up very nicely while back reamin 11:00 12:15 1.25 1,095 725 SURFA DRILL TRIP P POOH on elevators to Ghost reamer 725' & La down same. 12:15 13:00 0.75 725 60 SURFA DRILL TRIP P POOH w/ HWDP & Flex collars. 13:00 13:30 0.50 60 60 SURFA DRILL OTHR P Down load MWD. 13:30 15:30 2.00 60 SURFA DRILL PULD P Lay down Stabs, Float sub, UBHO, MWD, Break Bit, Flush motor with water & la down same. 15:30 16:00 0.50 SURFA DRILL OTHR P Clear & Clean rig floor. 16:00 18:00 2.00 SURFA CASIN( RURD P Rig to run 13-3/8" Casing. 18:00 18:30 0.50 SURFA CASIN( SFTY P PJSM w/All rig personnel, Casing crew. 18:30 20:15 1.75 0 1,216 SURFA CASIN( RNCS P Run Floaf Shoe, 2 jts, Float collar, 1- jt, Circ thru same, Run 13-3/8", 68#, L-80, BTC Casin to 1,216' 20:15 21:00 0.75 1,216 1,216 SURFA CASIN( OTHR NP Casing collars began hanging up on diverter pitcher nipple. Drain diverter and Inspect same. Attempt to pull diverter over to side- No Good. Began pulling casing over to one side to let collars ass b on eve 'oint. 21:00 00:00 3.00 1,216 2,510 SURFA CASIN( RNCS P Continue to run 13-3/8" casing to 2,510' at midni ht. 08/02/2006 00:00 01:45 1.75 2,510 3,725 SURFA CASIN( RNCS P Finish running 13-3/8" casing, Pick up Han er and land casin 3,725'. 01:45 02:45 1.00 3,725 3,725 SURFA CEME~ CIRC P Circ Btm's up with Franks fill up tool, Stage rate up to 7.0 bpm @ 430 psi, U 220K, Dn 92K. 02:45 03:15 0.50 3,725 3,725 SURFA CEME~ RURD P Rig down Frank's fill up tool, Rig up Dowell cement head. 03:15 05:30 2.25 3,725 3,725 SURFA CEME~ CIRC P Finish conditioning mud for cement= Wt.9.0 ppg, Vis 39, PV 12, YP 5, Held PJSM with all personnel for cement rocedure. ~_ ~ __-._ ®_e~~. ,___ _ ~ . , ..~ ~~. ~.~.~®e~ ~..._ _~.~.. Time Logs Date From To Dur th E. De th Phase Code Subcode .,OM 08/02/2006 05:30 09:30 4.00 3,725 3,718 SURFA CEME~ DISP P Pump cement per plan. Pumped 50 bbls of CW100, Followed by 50 bbls 10.5 ppg Mud Push with red bye. Dropped bottom plug, began mixing and pumping Articset Lite lead slurry. Pumped 562.4 bbls at 10.7 ppg, 687 sks, Yeild 4.60 ft/sk, at 7.4 bpm, at 90 psi. Followed by Tail cement: 96.6 bbls of DeepCrete, 221 sks, 12.0 ppg, Yield 2.46 ft/sk, at 5.7 bpm @ 130 psi. Shut down and dropped btm plug. Kick plug out with 20 bbls of fresh water. Turned over to rig pumps and displaced cement with 520.5 bbls (Total 540.5 bbls), 5169 stks, at 7.5 bpm, 75 spm @ Initial pressure 500 to final 950 psi at 7.5 bpm. Reciprocated pipe 10' every 1 minutes until cmt around shoe -then pipe got very sticky and getting stuck stuck off hanger (Unable to get pipe back down on depth -Pick up 7' to get hanger out of landing ring area (Shoe @ 3,718.93'). Observed red dyed in mud push after pumping 285.2 bbls mud. Slowed rate down to 30 spm (3.0 bpm) @ 650 psi at 5120 stks. Bumped plug with 1200 psi, held 5 mins. Check floats, Floats held-OK. CIP at 09:15 hrs 8/2/06. Had full returns through out job with 171.0 bbls cmt returns to surface. Shoe at 3,718' MD, Float collar at 3,639'. 09:30 09:45 0.25 3,718 3,718 SURFA CASIN( SFTY P Held PJSM on setting Casing on Slips. 09:45 12:00 2.25 SURFA CASIN( OTHR P Flush & drain diverter, Blow down cement line, Rig down cement head, Vacuum out 13-3/8" casin for cut off. 12:00 18:00 6.00 SURFA CASIN( NUND T PJSM, Clean cellar with Super Suckers, Center casing, Set slips- No Good -Landing .ring flipped up, Remove slips, Center landing ring and weld same. 18:00 18:30 0.50 SURFA CASIN( NUND P Set slips on 13-3/8" casing w/ 60K over, Cut casing, Lay down landing 'oint. 18:30 19:30 1.00 SURFA CASIN( OTHR P PJSM, Clear & clean rig floor, Lay down casin tools. 19:30 20:45 1.25 SURFA CASIN( NUND P PJSM, Nipple down Diverter system & remove under flow lines. 20:45 22:45 2.00 SURFA CASIN( NUND P Install & weld Starter head for wellhead, PJSM, Rig & Lay down 4 stands HWDP f/derrick. 22:45 00:00 1.25 SURFA DRILL PULD P Let wellhead cool, Pick up 5" Drill pipe and stand back same. 08/03/2006 00:00 00:15 0.25 SURFA DRILL SFTY P PJSM on picking up drill pipe and pipe shed safety. Staying focused on task at hand. m ~~ ~®~ ~e ~ -~ _~~ *~~~~a~` Time Lo s Date From To Dur th E. De th Phase Code Subcode -0M 08/03/2006 00:15 07:00 6.75 SURFA DRILL PULD P Pick up 234 jts 5" drill pipe and stand back in derrick. 07:00 08:00 1.00 SURFA RIGMN SVRG P Derrick Inspection, Clear rig floor. 08:00 09:45 1.75 SURFA WELCT NUND P Test weld on wellhead to 1800 psi f/ 10 min., Install wellhead, Test same to 5000 f/ 10 min. 09:45 10:45 1.00 SURFA WELCT NUND P Nipple up ROPE. 10:45 12:00 1.25 SURFA WELCT NUND P Change lower 7-5/8" Rams to 9-5/8". 12:00 12:30 0.50 SURFA WELCT NUND P PJSM, Install Pitcher nipple, Turn buckles, Air u boots. 12:30 18:30 6.00 SURFA WELCT ROPE P Rig & Test all BOPE to 250 psi Low & 3000 psi High, No failures -Good tests, AOGCC Chuck Shieve waived test, Rig down test equip., Set wear bushin . 18:30 21:15 2.75 0 115 SURFA DRILL PULD P Make up 12-1/4" GeoPilot BHA #3 as er S er -Sun. 21:15 22:15 1.00 115 115 SURFA DRILL PULD P Program MWD tools. 22:15 22:30 0.25 115 115 SURFA DRILL PULD P PJSM, Load R.A. Sources. 22:30 00:00 1.50 115 1,510 SURFA DRILL TRIP P RIH, Pick up 12-1/4" Spiral Ghost reamer 1,510' behind Bit. 08/04/2006 00:00 00:15 0.25 1,510 1,510 SURFA DRILL SFTY P PJSM on tripping in hole. 00:15 00:30 0.25 1,510 1,788 SURFA DRILL TRIP P RIH to 1,788', Break in GeoPilot bearin s 00:30 01:15 0.75 1,788 3,635 SURFA DRILL TRIP P RIH to 3,548', Break Circ, Wash down & Ta Float collar lu s 3,635'. 01:15 01:45 0.50 3,635 3,635 SURFA DRILL CIRC P Circ Btm's up for casing test at rate of 650 gpm @ 1130 psi, Up 120K, Dn 55K, Rot 85K. 01:45 02:30 0.75 3,635 3,635 SURFA CASIN( DHEQ P Rig & Test 13-3/8" Casing to 3000 psi f/ 30 min. on Chart -Good Test. 02:30 05:00 2.50 3,635 3,718 INTRM1 DRILL DRLG P Drill float collar @ 3639', Cement, Shoe 3718'. 05:00 05:15 0.25 3,718 3,756 INTRM1 DRILL DDRL P Drill 20' new hole f/ 3,736' to 3,756'. 05:15 05:45 0.50 3,756 3,756 INTRM1 DRILL CIRC P Change over to 8.9 ppg LSND mud. 05:45 06:45 1.00 3,756 3,718 INTRM1 RIGMN RGRP T Attempt to perform LOT- No Good, 3-1/2"x 6" Varible bore rams failed. 06:45 09:15 2.50 3,718 3,718 INTRM1 RIGMN WOEQ T Continue to Circ hole clean and build volume while waiting for Halliburton storm acker to Chan a rams. 09:15 10:45 1.50 3,718 3,718 INTRM1 RIGMN WOEQ T Continue to wait on HaNiburton Storm acker. 10:45 12:00 1.25 3,718 3,718 INTRM1 RIGMN RGRP T Unload and Make up 13-3/8" Storm packer, RIH & Set @ 95', Test same to 1000 si- OK. ~'~ ~~ ~~ . ,~®. _ _ e~ .._...... ~._ _..__ _® _ ~ Time Lo s Date From To Dur th E. De th Phase Code Subcode .,OM 08/04/2006 12:00 14:15 2.25 3,718 3,718 INTRM1 RIGMN RGRP T PJSM, Change out top pipe rams f/ 3-1/2"x 6" Varibles to 5" rams, Test 5" rams to 250 psi low and 3000 psi High each 5 min. tests, on chart. Note; One complete element was missing from one side of the varible rams -appears to be in hole. Element is made of rubber and aluminum. 14:15 14:45 0.50 3,718 3,718 INTRM1 RIGMN RGRP T Pull out of hole and lay down 13-3/8" Strom acker. 14:45 15:30 0.75 3,718 3,718 INTRM1 DRILL LOT P Rig & Perform Leak off test w/ 440 psi, 8.9 ppg mud, 2,224' TVD= 12.7 ppg EMD. 15:30 16:00 0.50 3,718 3,718 INTRM1 DRILL DHEQ T Down link to GeoPilot, Work on GeoS an on ri floor. 16:00 00:00 8.00 3,718 4,307 INTRM1 DRILL DDRL P Drill 12-1/4" hole w/ Sperry-Sun GeoPilot f/ 3,756' to 4,307' MD / 2,369' TVD (551'), 5/15K WOB, 90 to 140 RPM, Up 118K, Dn 60K, Rot 86K, TO On /Off 6-13K / 5-11 K, Ave ECD's 9.2 ppg, Max gas 73 units, Drilling down stand w/ 450 gpm @ 850 psi, Back reaming stand w/ 750 gpm @ 1300 psi, Drilled several hard spots f/ 3,793' to 4,307'. 08/05/2006 00:00 12:00 12.00 4,307 5,558 INTRM1 DRILL DDRL P Drill 12-1/4" hole w/ Sperry-Sun GeoPilot f/ 4,307' to 5,558' MD / 2,621' TVD (1,251'), 15/25K WOB, 130 RPM, Up 120K, Dn 70K, Rot 95K, TQ On 10-12K/ Off 10K, Ave ECD's 9.6 ppg, Max gas 90 units, Drilling down stand w/ 450 to 750 gpm @ 950 to 1650 psi, Back reaming stand w/ 850 gpm @ 2000 psi, Drilling several hard spots, Pump Hi-vis weighted sweep @ 4,925' showed 35% increase in cuttings over shakers. 12:00 00:00 12.00 5,558 6,348 INTRM1 DRILL DDRL P Drill 12-1/4" hole w/ Sperry-Sun GeoPilot f/ 5,558' to 6,348' MD / 2,817' TVD (790'), WOB 10/25K, 100-130 RPM, Up 145K, Dn 68K, Rot 95K, TO On 10-16K/ Off 10-11 K, Ave ECD's 9.6 ppg, Max gas 57 units, Drilling down stand w/ 450 to 750 gpm @ 950 to 1650 psi, Back reaming stand w/ 850 gpm @ 2000 psi, Drilling several hard spots, Pump Hi-vis weighted sweep @ 6,125' showed 15% increase in cuttin s over shakers. 08/06/2006 00:00 00:15 0.25 6,348 6,348 INTRM1 DRILL SFTY P PJSM orrdrilling ahead (Hazzard assessment on all tasks I ~.~... _ ~.._ _~ -- ~ ~w ~._m ~m ._~..~..._. ~~„I» ~ of Y`'....i Time Logs ~ Date From To Dur th E. De th Phase Cade Subcode OM 08/06/2006 00:15 12:00 11.75 6,348 7,385 INTRM1 DRILL DDRL P Drill 12-1/4" hole w/ Sperry-Sun GeoPilot f/ 6,348' to 7,385' MD / 3,044' TVD (1,037'), WOB 20/25K, 100-130 RPM, Up 140K, Dn 75K, Rot 104K, TQ On 14-15K! Off 10-12K, Ave ECD's 9.8 ppg, Max gas 72 units, Drilling down stand w/ 650 gpm @ 1620 psi, Back reaming stand w/ 850 gpm @ 2000 psi, Pump Hi-vis weighted sweep @ 7,035' showed 15% increase in cuttin s over shakers. 12:00 00:00 12.00 7,385 8,514 INTRM1 DRILL DDRL P Drill 12-1/4" hole w/ Sperry-Sun GeoPilot f/ 7,385' to 8,514' MD / 3,305' TVD (1,129'), WOB 15/30K, 100-130 RPM, Up 150K, Dn 77K, Rot 106K, TQ On 12-15K/ Off 10-14K, Ave ECD's 9.9 ppg, Max gas 112 units, Drilling down stand w/ 550 to 650 gpm @ 1500 to 1620 psi, Back reaming stand w/ 825 to 850 gpm @ 2000 psi, Pump Hi-vis weighted sweep @ 8,035' showed very little increase in cuttin s over shakers. 08/07/2006 00:00 00:15 0.25 8,514 8,514 INTRM1 DRILL SFTY P PJSM on drilling ahead (Hazzard assessment on all tasks 00:15 12:00 11.75 8,514 9,567 INTRM1 DRILL DDRL P Drill 12-1/4" hole w/ Sperry-Sun GeoPilot f/ 8,514' to 9,567' MD / 3,540' TVD (1,053'), ADT= 5.1 hrs, WOB 20/30K, 100 RPM, Up 165K, Dn 75K, Rot 112K, TQ On 15-20K/ Off 12-15K, Ave ECD's 9.9 ppg, Max gas 423 units, Drilling down stand w/ 458 gpm @ 1010 psi, Back reaming stand w/ 825 to 850 gpm @ 2000 psi, Pump Hi-vis weighted sweep w/ very little increase in cuttin s over shakers. 12:00 12:15 0.25 9,567 9,567 INTRM1 DRILL SFTY P PJSM on making connections, Pinch oints, Etc. 12:15 18:30 6.25 9,567 9,793 INTRM1 DRILL DDRL P Drill 12-1/4" hole w/ Sperry-Sun GeoPilot f/ 9,567' to 9,793' MD / 3,594' TVD (226'), ADT= 3.40 hrs, WOB 15/35K, 100 RPM, Up 160K, Dn 81 K, Rot 117K, TQ On 15-21 K/ Off 12-14K, Ave ECD's 9.7 ppg, Max gas 78 units, Drilling down stand w/ 510 gpm @ 1160 psi, Back reaming stand w/ 830 gpm @ 2400 psi. Decision was made to POOH with Geo-Pilot due to not bein able to et desired build rate 18:30 20:15 1.75 9,793 9,477 INTRM1 DRILL CIRC T Pump Hi-vis weighted sweep and Back Ream out of hole slow to 9,477' while circ sweep out, Sweep showed very little increase in cuttin s over shakers. 20:15 20:30 0.25 9,477 9,383 INTRM1 DRILL TRIP T Monitor well, Attempt to POOH on elevators f/ 9,477' to 9,383' - No good, Hole ullin ti ht ans swabbin . P~~ 7 ~t ,l3 1~ -_ Time L~ Date From To Dur ~ th E. De th Phase Code Subcode T M 08/07/2006 20:30 00:00 3.50 9,383 6,976 INTRM1 DRILL TRIP T Back Ream out of hole f/ 9,383' to 6,976' w/ 830 gpm @ 2400 psi, 130 RPM, TO 13-15K, Pulling speed 40-45 ft/min., No roblems. 08/08/2006 00:00 01:45 1.75 6,976 4,847 INTRM1 DRILL TRIP T Cont to BROOH from 6,976' to 4,847', BROOH at 130 rpm's, 190 spm, 805 gpm at 2,100 psi with 10-12K ft-Ibs for ue 01:45 03:00 1.25 4,847 3,640 INTRM1 DRILL TRIP T POOH on elevators from 4,847' to 3,640', (13 3/8" shoe at 3,718'), no roblems POOH on elevators 03:00 03:30 0.50 3,640 3,640 INTRM1 DRILL OWFF T Monitored well at the shoe and well was static, pumped dry job and blew down to drive 03:30 04:30 1.00 3,640 1,510 INTRM1 DRILL TRIP T POOH with BHA #3 from 3,640' to host reamer at 1,510' 04:30 05:00 0.50 1,510 1,510 INTRM1 DRILL PULD T Drained BOP stack and pulled ghost reamer to surface, recovered both VBR ram inserts on top of ghost reamer alon with wear bushin , LD same 05:00 06:00 1.00 1,510 89 INTRM1 DRILL TRIP T POOH from 1,510'to 89', stood back HWDP, jars and NMFDC's POOH to MWD tools 06:00 06:30 0.50 89 89 INTRM1 DRILL PULD T Held PJSM and removed radioactive sources 06:30 08:15 1.75 89 89 INTRM1 DRILL PULD T Plug into and download MWD tool 08:15 09:30 1.25 89 0 INTRM1 DRILL PULD T Fin POOH LD 12 1/4" Geo-Pilot BHA #3 09:30 10:00 0.50 0 0 INTRM1 DRILL PULD T Re-installed wear bushing 10:00 13:45 3.75 0 410 INTRM1 DRILL PULD T PU and MU 12 1/4" BHA #4 RIH to 410', MU new 12 1/4" bit #3 on 8" motor with 1.5 deg bend, 8" DM\RES\GR\PWD\HC I M\Density\Neut ron and pulser, held PJSM then loaded radioactive sources, RIH with NMFDC's HWDP and 'ars to 410' 13:45 15:15 1.50 410 3,652 INTRM1 DRILL TRIP T RIH with BHA #4 from 410' to 3,652', PU wt 110K, do wt 60K 15:15 16:15 1.00 3,652 3,652 INTRM1 RIGMN SVRG P Held PJSM then slip and cut 78' of drlg line 16:15 16:30 0.25 3,652 4,116 INTRM1 DRILL TRIP T RIH with BHA #4 from 3,652' to below cs shoe to 4,116' 16:30 17:00 0.50 4,116 4,116 INTRM1 DRILL DHEQ T Attemted to test MWD and was unable to eta ood test on MWD tool. 17:00 19:00 2.00 4,116 410 INTRM1 DRILL TRIP T Monitored well- static, POOH on elevators from 4,116' to BHA #4 at 410' 19:00 20:00 1.00 410 92 INTRM1 DRILL PULD T POOH standing back HWDP, jars and 1 std of NMFDC's POOH to 92' ~~ ~~ ~ t 1 d ~ ® ~ _~.._ ~ .~.~ Time Logs Date From To Dur 5~ th E. D_e th Phase Code Subcode T M 08/08/2006 20:00 23:00 3.00 92 38 INTRM1 DRILL PULD T Plugged into MWD and trouble shoot tool, unable to get good comm with tool, LD into pipe shed and cunt to trouble shoot both MWD tools, determined new Nuetron tool with new battery on pulser and original HCIM tool LD worked ok. 23:00 00:00 1.00 38 118 INTRM1 DRILL PULD T Began MU BHA #5, changed out 8" RES\GR\PWD, sleeve type stabilizer, HCIM and neutron tool 08/09/2006 00:00 01:15 1.25 118 409 INTRM1 DRILL PULD T Held PJSM then Fin MU BHA #5 RIH from 118' to 409', loaded radioactive sources then RIH with 1 std of NMFDC's, HWDP and 'ars to 409' 01:15 07:00 5.75 409 9,793 INTRM1 DRILL TRIP T RIH with BHA #5 from 409' to 4,209', tested MWD at 500 gpm at 735 psi and tool ck'd ok, cont to RIH from 4,209' and lost down wt at 5,414', washed down 2 stds from 5,414' to 5,600' at 300 gpm, 700 psi at 55 rpm's and 10K ft-Ibs torque, cont to RIH from 5,600' to 9,675' filling pipe every 20 stds and no problems, precautionary washed down from 9,675' to btm at 9,793' (118') with no problems, washed down at 600 gpm at 1,700 psi, 60 rpm's and 10K ft-Ibs torque, rot wt 102K, u wt 160K, do wt 74K 07:00 12:00 5.00 9,793 10,072 INTRM1 DRILL DDRL P Directionally drilled 12 1/4" hole per directional plan from 9,793' to 10,072' MD/3,634' TVD (279'), ART .76 hrs, AST 1.38 hrs, ADT 2.14 hrs, 10-15K wob, 60 rpm's, 143 spm, 606 gpm, off btm pressure 1,500 psi, on btm 1,750 psi, off btm torque 10K ft-Ibs, on btm 14K ft-Ibs, rot wt 108K, up wt 158k, do wt 65k, 9.3 ppg mw, ave ECD 9.6 ppg, ave BGG 30 units, max as 67 units 12:00 22:00 10.00 10,072 10,878 INTRM1 DRILL DDRL P Directionally drilled 12 1/4" hole per directional plan from 10,072' to 10,878' MD/3,715' TVD (806'), (9 5/8" csg pt) ART 2.3 hrs, AST 2.92 hrs, ADT 5.22 hrs, 5-15K wob, 60 rpm's, 143 spm, 606 gpm, off btm pressure 1,450 psi, on btm 1,650 psi, last 2 stds drilled had increased pump rate to 167 spm, 708 gpm, off btm pressure 1,800 psi, on btm 1,930 psi, off btm torque 14.5K ft-Ibs, on btm 14K ft-Ibs, rot wt 107K, up wt 158k, do wt 65k, 9.3 ppg mw, ave ECD 9.8 ppg, ave BGG 40 units, max as 220 units, 'ar hrs 77.13 22:00 22:30 0.50 10,878 10,878 INTRM1 DRILL CIRC P Took SPR's and pumped 65 bbl weighted (2# over MWj hi vis sweep and circ hole to clear bit and BHA. ~. _ ~e® ~ ~. _ ~ ..~. '~~ ~ o~ ~ Time Los ~~~ -- Da From To Dur R'~pth E. De th Phase Code Subcode T OM 08/09/2006 22:30 00:00 1.50 10,878 10,601 INTRM1 DRILL REAM P Backreamed out of hole slow from 10,878' to 10,601' while circ out sweep, BROOH at 195 spm, 830 gpm at 2,350 psi, 80 rpm's with 10K ft-Ibs torque, had 20% increase in cuttings back from sweep, ave 9.3 ppg MW in and 9.6 ppg mw out after sweep was out of hole 08/10/2006 00:00 08:30 8.50 10,601 3,715 INTRM1 DRILL REAM P Cont to BROOH from 10,601' to 3,715' (9 5/8" csg shoe @ 3,718'), BROOH at 190 spm, 806 gpm at 2,500 psi, 80 rpm's with 10K ft-Ibs torque, 9.3 ppg mw in, ave 9.4 to 9.5 ppg mw out, no roblems BROOH to shoe. 08:30 09:30 1.00 3,715 3,715 INTRM1 DRILL CIRC P Pumped 60 bbl wt'd hi vis sweep (2# over mw) and circ hole clean at 3,715', had a good increase in cuttings back from sweep and circ 3X btms up and was clean at the shakers, circ hole at 806 mat 2,500 si 09:30 09:45 0.25 3,715 3,715 INTRM1 DRILL OWFF P Monitored well-static then pumped dry 'ob 09:45 11:00 1.25 3,715 409 INTRM1 DRILL TRIP P POOH on elevators from 3,715' to BHA at 409' 11:00 12:15 1.25 409 103 INTRM1 DRILL PULD P POOH LD 5 jts HWDP, jars and 3 8" NMFDC's POOH to 103' 12:15 14:15 2.00 103 103 INTRM1 DRILL PULD P Held PJSM then removed radioactive sources, down loaded MWD 14:15 16:30 2.25 103 0 INTRM1 DRILL PULD P Fin POOH from 103' and LD remainder of BHA #5, cleared ri floor 16:30 16:45 0.25 0 0 INTRM1 DRILL PULD P Pulled wear bushing 16:45 18:45 2.00 0 0 INTRM1 CASIN( RURD P RU Doyon's 9 5/8" csg handling e ui ment alon with Franks fill u tool 18:45 19:00 0.25 0 0 INTRM1 CASIN( SFTY P Held PJSM with rig crew and tong o erator on the runnin of 9 5/8" cs 19:00 00:00 5.00 0 1,575 INTRM1 CASIN< RNCS P Began to RIH with 9 5/8", 40#, L-80 BTC-M csg, RIH with 41 jts to 1,575', MU shoe track and running bowspring and turbolizer centralizers er ro ram 08/11/2006 00:00 03:00 3.00 1,575 3,700 INTRM1 CASIN( RNCS P Cont RIH with 9 5/8" csg from 1,575' to 3,700', (13 3/8" csg shoe at 3,718') RIH an add. 51 jts of csg, 97 total in the hole 03:00 03:45 0.75 3,700 3,700 INTRM1 CASIN( CIRC P Circ 1 csg volume at 3,700', staged pump rate up to 70 spm, 7 bpm at 350 psi, st up wt no pump 160K, do wt 52K, st up wt with pump on 153K, do wt 60K, no mud losses while circ hole at the shoe. _.... €~~ `iCt oaf ~~ ~ Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 08/11/2006 03:45 12:30 8.75 3,700 10,873 INTRM1 CASIN( RNCS P Cont RIH with 9 5/8" csg from 3,700' to 10,873', RIH with an add. 188 jts and 1-10' pup jt, (284 jts total) washed down csg while RIH due to drag at 4,885', 4,925', 5,235', 5,575', 6,565' and 8,390', was able to cont RIH to 10,873' with no problems, ran 35 roller centralizers from 3,588' to 2,295' (jts # 191 thru 225), st wt up 240K, do wt 80K, had ood returns while RIH 12:30 13:15 0.75 10,873 10,873 INTRM1 CASIN( RNCS P Spaced out landing jt with 2-pup jts then tagged btm at 10,878', used bowspring centriizers on pup jts to center landing jt in the stack, PU to settin de th of 10,873' 13:15 15:00 1.75 10,873 10,873 INTRM1 CEME~ CIRC P Circ btms up thru ftll up tool cond. mud for cementing, staged pump rate up to 7 b mat 500 si with no losses 15:00 15:30 0.50 10,873 10,873 INTRM1 CEME~ RURD P RD Franks fill up tool and MU Dowell cement head. 15:30 18:30 3.00 10,873 10,873 INTRM1 CEMEI~ CIRC P Fin circ and cond. mud for cementing, circ hole at 7 1/2 bpm at 450 psi, reciprocated pipe with a st wt up of 265K and do wt of 90K, cond mud from 9.5 ppg, 62 vis, 10 PV and 27 YP and cond mud to 9.05 ppg, 38 vis, 10 PV and 10 YP, held PJSM with Dowell, ASRC vac truck drivers and rig crew on cementin o erations 18:30 19:45 1.25 10,873 10,873 INTRM1 CEMEf~ DISP P Dowell pumped 10 bbls of CW 100 at 8.3 ppg then pressure tested lines to 3,500 psi. Cont to pump an additional 40 bbls of CW 100 (50 total) then pumped 78 bbls of 10.5 ppg Mud Push, ave 5 bpm at 200 psi. Dropped btm plug, then mixed and pumped 328 bbls (828 sxs) of DeepCrete tail cement at 12.5 ppg and 2.25 yield with additives, ave 6.3 bpm at 300 psi, reciprocated pipe and had full returns while pumping cement, shut down and dro ed to lu . 19:45 22:00 2.25 10,873 10,873 INTRM1 CEME~ DISP P Dowell pumped 20 bbls of water behind plug then turned over to the rig and rig cont. to displace cement with 9.7 ppg brine, ave 7 bpm while displacing cement, initial pressure was 300 psi, max pressure was 925 psi, with 10 bbls to pump slowed rate to 3.5 bpm at 500 psi and bumped plug on talc displacement (818 bbls). Reciprocated pipe till 21:15 hrs with 100 bbls of cmt out of shoe and began to loose do wt, had full returns throughout job, bumped plugs to 1,500 psi, CIP at 21:45 hrs, checked floats and floats held, talc TOC at 6,140'. P~~~: `~~ of ~~ Time Lo s Hate From Tn I~ur .nth F f?anth Phase Cerie Suhr`nde T M 08/11/2006 22:00 22:30 0.50 10,873 10,873 INTRM1 CEMEI~ RURD P RD cmt head and lines. 22:30 23:30 1.00 10,873 10,873 INTRMI WELCT NUND P Drained stack and ND BOP's, PU same 23:30 00:00 0.50 10,873 10,873 INTRM1 WELCT EQRP P RU WACH's csg cutter and prepared to set 9 5/8" cs sli s 08/12/2006 00:00 02:00 2.00 0 0 INTRM1 WELC7 EQRP P Set 9 5/8" csg slips with 75K st wt, made cut on csg using WACH's cutter, LD cut-off jt and installed MB-222 ack-off. 02:00 03:00 1.00 0 0 INTRM1 WELCT NUND P Set stack down and NU same, tested pack-off to 2,500 psi for 10 min and ck'd ok. 03:00 04:00 1.00 0 0 INTRM1 RPCOh OTHR P RU on 13 3/8" x 9 5/8" OA and performed LOT to 10.3 ppg EMW with 150 psi and 9.0 ppg MW at 2,224' TVD and pumped a total of 20 bbls water down annulus. Sim-Op: RU to run 4 1/2" kill string and held PJSM on runnin of same. 04:00 06:30 2.50 0 2,214 INTRM1 RPCOh RCST P RIH with 4 1/2" kill string to 2,214', RIH with 72 jts of 4 1/2", 12.6#, L-80, IBTM tb to 2,214' 06:30 07:30 1.00 2,214 2,244 INTRM1 RPCOh HOSO P MU Vetco Gray tbg hanger with TWC installed &RIH landing kill string at 2,244', st wt up 53K, do wt 53K, blk wt 35K, RILDS, tested upper and lower body seals to 5,000 psi for 10 min each. 07:30 09:30 2.00 2,244 2,244 INTRM1 RPCOh OTHR P Fin. flushing OA with 230 bbls of fresh water, ave 2 bpm at 725 psi, Sim-Op: removed hyd lines, choke and kill lines on BOP stack, cleaned pollution pan under rig floor, RD Geo-Span unit and cunt to clean mud its 09:30 12:00 2.50 2,244 2,244 INTRM1 RPCOh NUND P ND BOP stack and removed lifting Yoke from below annular 12:00 15:00 3.00 2,244 2,244 1NTRM1 RPCOh NUND P Held PJSM, then removed BOP stack from cellar for ins ection 15:00 17:00 2.00 2,244 2,244 INTRM1 RPCOh NUND P NU Vetco Gray 13 3/8" 5M x 4 1/8" 5M tree w/o actuator valve, tested both tree and void to 5,00 psi each for 10 min and tested ok, ulled TWC 17:00 18:45 1.75 2,244 2,244 INTRM1 RPCOh FRZP P RU Little Red on 13 3/8" x 9 5/8" annulus (OA) and freeze protected with 135 bbls of diesel to 2,260', ave 2 bpm at 650 si 18:45 19:45 1.00 2,244 2,244 INTRM1 RPCOh FRZP P RU Little Red on 4 1/2" x 9 5/8" (IA) and freeze protected well with 170 bbls of diesel to 2,244', pumped down backside taking returns up tbg till good diesel was back at surface, ave 5 bpm at 500 si. 19:45 20:00 0.25 0 0 INTRM1 RPCOh SFTY P Held PJSM with rig crew on LD DP out of mousehole ~. ~~ ®m ~ ~~. ~ m_.~._...-~® ~ ~ _.m~~ ~~~ 9~ ca 13 Time Los Date From To Dur th E. De th Phase Code Subcode OM 08/12/2006 20:00 00:00 4.00 0 0 INTRMI RPCOh PULD P Began LD 5" DP out of derrick, LD 47 stds 141 'ts 08/13/2006 00:00 04:45 4.75 0 0 INTRMI RPCOh PULD P Fin LD 5" DP out of the derrick, LD 67 stds 201 Jts ,cleared ri floor 04:45 06:00 1.25 0 0 INTRM1 RPCOh OTHR P Held PJSM then changed out Sperry Sun's Geo-Span from rig floor, fin cleanin mud its and rock washer. 06:00 08:00 2.00 0 0 INTRM1 WELCT EQRP P RU lubricator and installed Vetco Gray BPV, RD lubricator and scaffolding. Secured well and Released Rig @ 08:00 hrs 8/13/06 for rig to perform summer maintenance e ~®m ~ e ~€~~ 't3 ~t t Re: 1J-133 Intermediate Displacement subject: Re: 1.1-1 ~:3 Intermediate Displacement >C~rom: Thomas Maunder <tom maundcr(a~,admin.state.ak.us> Date: Wed, 26 Jul 2006 10:08:28 -O~00 To: "Rcitly~, .Patrick J" <Patric.k.J.Rcill~r(aconocuphillips.com> Pat, This is not a problem and a good idea. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC c~aCo - ~ Reilly, Patrick J wrote, On 7/26/2006 9:37 AM: Tom, The permit application indicated that we would displace the cement in the intermediate with mud. However, we have decided that displacing with kill weight brine with corrosion inhibitor would be better. With your approval, we would like to make that change. Thanks. Here is the current permit application text. 1. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud to 6,640' MD / 2,898' TVD. (500' MD above the Ugnu C sand). Pressure test casing to 3,000 psi for 30 minutes and record results. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilly(a~conocophillips.com «Patrick.J.Rei(ly~conocophillips.com.vcf» 1 of 1 7/26/2006 2:18 PM ~ ~ ~ ~~ s~ J~~~'I AI.A3SA OIL A1QD (iA.s COI~TSERQATIOI~T COMI~'IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSK/, GOVERNOR ~ ~ 333 W. 7~" AVENUE, SUITE 100 j ANCHORAGE, ALASKA 99501-3539 1 PHONE (907) 279-1433 FAX (907) 27&7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-133 ConocoPhillips Alaska, Inc. Permit No: 206-106 Surface Location: 1622' FSL, 2296' FEL, SEC. 35, Tl 1N, RlOE, UM Bottomhole Location: 1301' FNL, 2446' FWL, SEC. 13, TlON, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this~day of July, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Chairman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIt~J PERMIT TO DRILL R l~S 20 AAC 25.005 RECEIVED JUL 2 4 2oQ6 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone ^/ 1c. Speci 1~ 13 ~ ~$$:COI1S. COfi11T11SS10t1 Coalbed Methane ^ AnC~ ales ^ Shale Gas i~i 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-133 3. Address: P.O. Box 100360 Anch e, AK 99510-0360 6. Proposed Depth: MD: 16365' TVD: 3688' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1622' FSL, 2296' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25662 & 380058 West Sak Oil Pool Top, of Productive Horizon: 518' F L, 2156' FWL, Sec. 12, T10N, R10E, UM ~ 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 7/31 /2006 Total Depth: ~~ ! ~ ~ ~ ~~~ ~5' 1301' FNL, 2446' FWL, Sec. 13, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558917 y- 5945436 Zone- 4 10. KB Elevation (Height above GL): 4O' RKB feet 15. Distance to Nearest t.~ -\~ Well within Pool: none , 16. Deviated wells: Kickoff depth: 300 ft. Maximum Hole Angle: g2° deg 17. Maximum Anticipated Pressures in psig (see 20 a,P,C 25.035) Downhole: 1681 psig Surface: 1270 psig 18. Casing Program i if Setting Depth Quantity of Cement Size icat ons Spec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 108' 108' 282 sx AS 1 16" 13.375" 68# L-80 BTC 3666' 40' 40' 3706' 2225' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10650' 40' 40' 10690' 3703' 810 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 5675' 9875' 3607' 16365' 3688' see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 BOP Sketch Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ~ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature '~' Phone Z~S 6~~(J Date ?/Z~f/~~ Pr r haron All u D e Commission Use Only Permit to Drill (F' Number: d0 b ° ~ ~ ~ API Number °~ rr\\ 50- ~~'1 ~ d~~ ~ S ~ V Permit Approval Date: ~ •~~ ' ~ See cover fetter for other requirements Conditions Of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales: l`Il~~~ ~c.rrc~~c-~va`~~ `p C~ Samples req'd: Yes ^ No Mud log req'd: Yes ^ No [~ Other: 300 Q~~` ~~~ ~5~. H2S measures: Yesc^ No [[~ Tonal svy req'd: Yes ~ No ^ ~'O~ ~ o ~pE Sv~rj r`~~ ~: s~1~.-a~~~ag T ~ S P E~ E~'°o ~ ~ : ~. X103 ~o c~Ss ~~~ 4DC\'cc~ DATE: ~~~~p APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 o R ~ ~ L Submit in Duplicate -tg • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~E~EIVED JUI. Y 2006 Alaska Oil as Cons. Commission Anr•.hnr~no 1 a. Type of Work: Drill Q Redrill Re-entry ^ 1 b. Current Well Class: Exploratory Development O' ultiple Zone ^ Stratigraphic Test ^ Service ^ Developmen as ^ Single Zone a 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single ell Bond No. 59-52-180 11. Well Name and Number: 1J-133 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 16365' ~ ND: 688' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Go'vernmental Section): Surface: 1622' FSL, 2296' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ADL 25662 380058 West Sak Oil Pool ' Top ~~ roductive~ rD~izo~, ~fya4 r NL, 2156' FWL, Sec. 12, T10N, R10E, UM S. Land Use Permit: ALK 47 & 2177 13. Approximate Spud Date: 7/31/2006 Total Depth: , 1301' FNL, 2446' FWL, Sec. 13, T10N, R10E, UM ~ 9. Acres in Pro rty: 2560 14. Distance to ~ Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558917 y- 5945436 Zone- 4 10. KB EI ation (Heigh Bove GL): 40' RKB 15. Distance to N crest t?-~o Well within Pool: none , p ~. ~, 16. Deviated wells:: Kickoff depth: 300 ft. Maximum Hole Angle: 92° g 17. aximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1681 psig - Surface: 1270 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica pec ons Top Bottom c, f. or sacks Hole Casing Weight Grade Coupling L ng MD ND MD ND (including stage data) 40" 20" 62.5# H-40 Welde 40' 40' 108' 108' ~ 282 sx AS 1 16" 13.375" 68# L-80 BTC 6 40' 40' 3706' . 2225' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 B 1 50' 40' 40' 10690' 3703' 810 sx DeepCRETE 8.5 5.5" 15.5# L-80 BTCM 56 75' 3607' 16365' ~ 3688' • slotted liner .~ 19 PRESENT WELL CONDITION U (TO be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): (me a i Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length ize Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner - refer to 1 F-01A Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commissio Representative: Date: 22. I hereby certify that the for going is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` ~o~.._,.~,__' Phone Z6S'~6$3v Date ~ /'~y~p 6 Pr r d b har n All u- k Commission Use Only Permit to Drill Number: ~ - ~~ r~ API Number: 50- dZq' Z 33 ~S' ~ Permit Approval Date: See cover letter for other requirements Condition f approval : / Samples required Yes ^ No [~ Mud log required Yes ^ No ^~ Hydrogen sulfide measures Yes ^ No 0' Directional survey required Yes [~ No ^ Othe . X \ .~~~T~ APPROVED BY pproved by: `~l'L`~' ~C~ THE COMMISSION Date: 1 QV ' - r ~ / i Form 10-401 Revised 06/2004 ~ ®~ ~ t ` iS7~ 7• z//c~ $u mit in D~p il~St~6 X Conoco~illips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com July 14, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1J-133 and 1J-133 Li JUG. ~ ~ 20(~ Alaska Oil & has ~£ol~s. ~~mrrli,~;t~~ Rnchc~raga Dear Commissioners: °k 4 ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a dual lateral horizontal well in the West Sak "B"and "D" sands. The main bore of the well will be designated 1J-133, and the lateral bore of the well will be designated 1J-133L1, yy After we set intermediate casing, we will move to another well and return to this well in the next two years. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of ZJ-133 is July 31, 2006. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader • App~n for Permit to Drill, Well 1J-133 Revision No.O Saved: 14-Jul-06 Permit It -West Sak Well #1J-133 Application for Permit to Dill Document M~ x i m i x p WWII Vp1~Q Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ ............................................................................................................. 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 Surface Hole Mud Program (extended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) .................................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals .................................................... 5 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 1J-133 PERMIT IT Page 1 of 7 Printed: 14-Jul-06 Ap~n for Permit to Drill, Well 1 J-133 Revision No.0 Saved: 14-Jul-06 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................•-•-••-•---............................-•--•--........................................ 5 13. Proposed Drilling Program ......................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 7 15. Attachments ............................................................................................................... 7 Attachment 1 Doyon I S West Sak 2004 3ksi BOP Configuration .................. Error! Bookmark not def!ned. Attachment 2 Directional Plan .................................................................................................................. 7 Attachment 3 1,320' Scan ..........-•--~-•• ........................................................................'............................... 7 Attachment 4 Drilling Hazards Summary ................................................................................................... 7 Attachment S CemCADE Summary ...................................................................................:......................... 7 Attachment 6 Well Schematic .................................................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005 (~ Each welt nzzzst be identified Uv a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040('h). For a well with multiple well branches, each branch must similarly be iderati~ed by a unigzze name and ~iI'I ratzrnber• Irv adding a st{ffix to tlae taante designated for the well by tlae operator and to the number assi~aed to the welt by the conarrtission. The well for which this Application is submitted will be designated as 1J-133. 2. Location Summary Requirements. of 20 AAC 25.005(c)(2) An application fnr a Permit to Drill must be accompanied b3' each oj~the following items, except fcrr an item calreacly on file with the corrtrrtission and ideratif' ied in the applu~ation: (2) a plat identifying the property and the property s owners and showing (A)the coordinates of the proposed location of the well czt the surface, at the top of each ohjective formation, and at total depth, referenced to governmental section Braes. (B} the coordinates of the proposed locatr,'ora of the well at tlae surface, referenced to the state plane coordinate s~+stern,for this state its muiratairaed by the National Geodetic Survey in the National (Jceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of ouch objective formation czrad at total depth; Location at Surface 1,623' FSL, 2,296' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL Northings: 5,945,435 Eastings: 558,916 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 4,518' FNL, 2,156' FWL, Section 12, T10N, R10E Sak ~~B" Sand ASP Z 4 NAD 27 C d Measured Depth, RKB: 10,288 one oor inates Northin s: 5 938 052 Eastin 433 s: 563 Total Vertical Depth, RKB: 3,673 g , , g , Total Vertical Depth, SS: 3,552 Location at Total Depth 1,301' FNL, 2,446' FWL, Section 13, T10N, R10E di ASP z 4 NAD 27 c Measured Depth, RKB: 16,365 one oor nates Northin s: 5 931 993 Eastin 777 s: 563 Total Vertical Depth, RKB: 3,688 g , , g , Total Vertical Depth, SS: 3,567 1J-133 PERM/T!T Page 2 of 7 Printed: 14-Jul-O6 and (I)} other inji~nnation required by ?0 A.4C 25.D~D(h}; Ap~n for Permit to Drill, Well 1J-133 Revision No.O Saved: 14-Jul-06 Requirements of 20 AAC 25.050(b) If a K+ell is to be intentionally deviaiec~ the application for a Permit to Drill (form 1 D-401) must (1 } include a plat, drawn to a suitable scale, showing the path of the proposed wellbore,, including all ad_ jacent tvellbr~res bvithin 2DD feet oj'any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) fin- all wells within _'DD feet of the prol~zosed tivellbore (A) list the names oj'the operators of those wells, to the extent that those narncs are b•nown or diseoverahle in public~records, and show that each named operator Ttas been furnished a copy of the application by certi_fed mail; or (S) state that the applicant is the only c{ffected owner, The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) ~~n application.far a Permit to Drill natest be accompanied t?v each of tFze following items, ea-cept frig an item already on fie with the commissiarx and identified ira the application: (3) a diagram and description of the blowout prevention eguipmeni (HOPE) as required by ZD .2.2C 2S.U33, ZD ~tAC Z5. D36, or '0.4.4C 25. D37 as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-133. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill mzrst b_e accamprznied by each c f the, following iterrts, except for an item already an file with the commission and identified in tha application: (4) information ozx drillirxg hazards, including (A) the maximum clnwnltole pressure that may be encaurxterea' criteria used to determine it, and maximum potential surface pressure based on ez methane gradient; - The expected reservoir pressure in the West Sak sands in the 1J-133 area is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,270 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 3,736'. The MPSP is: MPSP = (3,736 ft)(0.45 - 0.11' psi/ft) =1,270 psi - {?3) data on potential gas zones; The well bore is not expected to penetrate any gas zones. anil (C) data concerning potential causes of hole problems such as abnormally geo r3rc _rsured strata, last circulation zones, and zones that have a propensity t'or di ferential stiekzng; Please see Attachment 2: 1J-133 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each c f the firllawing itenxs, except ffir an item already on file with tfie commissiona and ident~ed in the application: (S) a description of the prrocedure for conducting formation integrify tests, as required under 2D.24C 24.03D(f}; 1J-133 PERMIT IT Page 3 of 7 ` Printed: 14-Jul-O6 App~n for Permit to Drill, Well 1 J-133 Revision No.O Saved: 14-Jul-06 1J-133 will be completed with 9-5/8" casing landed at the top of the West Sak "B" sand. ~ The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConcocoPhillips 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 I~ridl must be accompanied by each of the, following items, except for arz item alr'eculy on fzle with the commission carad identified in the application: (Cr,) a complete proposed casing and cementing program us required by 20 fLAC 'S. 03Q and cz description of anv slotted liner; pre perforated liner, orsereen to be instcalled,• Casing and Cementing Program See also Attachment 3: Cement Summary o e op C bg Size Weight Length AID/TVD ~ MD/TVD OD (in) (in) (Ib/ t) Grade Connection ~) (ft) (f~) Cement Pro ram 20" 40" 62.5 H-40 Welded 80 40' / 40' 108' / 108' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,666 40' / 40' 3,706' / 2,225 700 sx ArcticSet Lite Lead, 220 sx De CRETE Tail Cement Top planned @ 6,140' -5/ " 12-1/4" 40 L-80 BTCM 10 650 40' / 40' 703' 10 690' / 3 MD / 2,898' TVD. Cemented , , , w/ 810 sx Dee CRETE 5-1/2 8-1/2" B Sand Lateral 15.5 L-80 BTCM 5 675 875' / 3 607' 9 16 365' / 3 688 Slotted-no cement slotted (1J-133) ~_..__ , , , , , - slotted 8-1/ Band Lateral (17-133 Ll) 15.5 L-80 BTCM 6,581 9,775' / 3,590' 16,356' / 3,622 Slotted-no cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) Arz application for a Permit Eo I?rill naaast be accompanied by each of tlae following items, except fvr an item already onrfile with the commission and identified in the application: (: j ca diagram and description of the diverter systertt as required by 20 A~tC 25.03.5, unless this r-equiremertt is waived by the corttrnissian under 20 A~4C 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1J- 133. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) ~n application, for a Permit to Drill must be accompanied by each of floe fallorvirag ztems, ea-cept for an item already rnz file with the commission and ideratifzed in the application: (8j ez drilling fluid program, including a diagram and description of the drilling fluid system, ccs required by 20 fL1C 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Palue Final Value Initial Value Final Yalue Density (ppg) 8.5 9.2 9.2 9.6 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50-70 50-70 30-50 30-50 cP) Plastic Viscostty 20-45 20-45 15-20 15-20 (Ib/100 sB pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 1J-133 PERMIT IT Page 4 of 7 ^ ~ ~ ~ ~ ` ! ~ ~ Printed: 14-Jul-O6 • Ap~n for Permit to Drill, Well 1J-133 Revision No.0 Saved: 14-Jul-06 API Filtrate NC-8.0 NC-8.0 5.0-7.0 5.0-7.0 cc /30 min)) *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4"Casing Shoe to Intermediate _ Casing Point Initial Value Densi (p~ 9.0-9.1 Funnel Viscosity 45-60 (seconds) Plastic Viscostiy 12-18 (lb/100 s~ Yield Point 26-35 (cP) API Filtrate 4-6 (cc / 30 min)) Chlorides (m /l) <500 pH 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value Density (ppg) 9.0 Plastic Viscostiy 15-25 (lb/100 s Yield Point 1 &-28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200psi & 1 SO° Oil /Water Ratio 80:20 Electrical >600 Stability 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 Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a z'erntit to Drill must be accornpanied by each of the,fniknving items, except for arz item already on file with the commission attd ident~ed in the application: {`9) fcrr an exploratory or stratigraphic test well. u tabulcttian setting out the depths of predicted abnormally geo ~resstrred sputa as required by '0 AAC 25.(133(/); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An cappticcztion,for aPerrnit to DrilX must be accornpanied by each ofthe following items, except. for an item alreuczy on fzle with the cnrnrnission and identified ira the alrplicatiort: ("10) for an exploratnrry~ or str-atigruphic test well, ca seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application far a Permit to Drill m;zst be accornpanied by each of the,Trllcnving items, except for art item already on fzle with the cornn:ission and identified in the application: ("11).for• a welC drilledfrom art ofrshore platform, rnolrile bottom founded structure, jack-up rig, or floating drilling vessel,.an analysis of seabed conditions as required by 20 A.2C25.067(C?); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applicution.for a Permit to Drill must be acenrnpuntett by each of the f+~llowing items, exeept.for an item calrr:ucty on f le with the camnaission and identified irr the azlplicatuua: (12) evidence .showing that the requirements of 20 AAC 25.025 {Bonding}have been metj Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 1J-133 PERMIT IT Page 5 of 7 ^ ~ ^ ~ ~ ~ ~ Printed: 14-Jul-O6 App~n for Permit to Drill, Well 1J-133 Revision No.O Saved: 14-Jul-06 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) Art applicatior~a for a Permit to Drill must be accompanied by each of the following items, except for- an item already on fzle ~vzth the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Insta111anding ring on conductor. 2. Move in /rig up Doyon Rig 15. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,706' 1VID / 2,225' TVD. as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. 6. PU 12-1/4" drilling assembly, with MWD, LWD & PWD. 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, recording results. 8. Directionally drill to 9-5/8" casing point at 10,690' MD / 3,703' TVD, the prognosed top of the B sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud to 6,640' MD / 2,898' TVD. (500' MD above the Ugnu C sand). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. 12. Run freeze protect string. ~~-~t(j ~ ~J~j\a~S ~ ~,j~~Dw QEcr,~~~pe,°~ ,~n 13. Nipple down BOPE, nipple up tree and test. Pull BPV. ,tl ,'t(a~ Q~~~~~®~ 14. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 15. Set BPV and move rig off, (A rig will return in the next two years to finish the well) 16. Move in /rig up a drilling rig TBD. -~-~. t-{p3 ~~v\~ ~'O ~~~~S~~e.~ ~'J v3C-`' 17. Install and test 13-5/8" x 5,000 psi BOP's as described. above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. ~ aS 18. Remove freeze protect string. 19. PU 8-1/2" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top.of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 20. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud.. Perform formation integrity test to leak off, recording results. 21. Directionally dri118-1/2" hole to TD at +/- 16,365' MD / 3,688' TVD as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. Run USIT _log for_cement bond. r- 24. PU and run 5-1/2" slotted liner. 25. Land liner, set liner hanger @ +/- 9,875' MD / 3,607'. POOH. ORIGINAL 1J-133 PERMIT IT Page 6 of 7 Printed: 14-Jul-06 • Ap~n for Permit to Drill, Well 1 J-133 Revision No.0 Saved: 14-Jul-06 Note: Remaining operations are covered under the IJ-133 Ll Application for Permit to Drill, and are provided here for information only. ~________~ 26. Run and set Baker WindowMaster whipstock system, at window point of 9,775' MD / 3,590' TVD, the top of the "D" sand. 27. Mi118-1/2" window. POOH. 28. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 29. Drill to TD of "D" sand lateral at 16,365' MD / 3,688' TVD, as per directional plan. 30. POOH, back reaming out of lateral. POOH. 31. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 32. PU and run 5-1/2" slotted liner. 33. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 34. Release hanger running tool. POOH. 35. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 36. POOH, laying down drill pipe as required. 37. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 38. Nipple down BOPE, nipple up tree and test. Pull BPV. 39. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 40. Set BPV and move rig off. 41. Rig up wire line unit. Pull BPV. 42. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. Shut well in. 43. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.OOS (c)(14) An application fire a Permit to Drill mustc be czccompcznied Zay each ofthe fallowing items, except for an ifern rxlready on fate tivitlt the commission and identified in the application: (14J a general description of how the operator plans to dispose of drilling rraxtd arad cuttings and a statement of whether the operator intends to request authorization under 2Q .1,4C 25.f18t1. jor an anrttzlar disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1 J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 1,320' Scan Attachment 3 Drilling Hazards Summary Attachment 4 CemCADE Summary Attachment S Well Schematic 1J-133 PERMIT IT Page 7 of 7 n ~ ~ ~ A ' ~ f Printed: 14-Jul-06 • ~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-133 -Slot 1J-133 1J-133 Plan: 1J-133 (wp06) Proposal Report 17 January, 2006 Al..~..RTID Sperry Drilling Services ORIGINAL ._ a ,°, c ~ ~y M G 3 ~ ~ ~ ~ ; w Y y ~ 7 O ~ ~~a~-M a f0 ~ M ~ C. p,C d~ z Y Yaa~ a C LL ocn?~~n. ~ a` m w j ~ ~ w N N r b ~ Ul 01 N ° 0." W ~ ' ~ w . d U ~ J ch y ~ @~ y d~ao` ~ .M- \` ` C ~ GU[D , 'Aq ~UfaQ J ~M~ vie- H :: ', ~ Y 1 F N 77 7 FCC N C C C M~ Q Q ~ ~ Z~G11A ~ ', lr ~ NM~M 010101~S~C[ f~C1 IL di-Yf-»7Y55~ W 0 QMwM ~o~ow •• W ~' ~ ~ '~ : L~~ OMNnMiO"MOf T o m n N O aD ~ 0 0 n Z C ~ ~ n tp M O ~ . N a O n fV ~p s ~ ^. O of „ M N M O ~O p O. N 3 M ~ tD a _ ---- ~ --- ____ 3 o e H b r .~ e F - - - M ---- eM- 0 a 3 M r boo / ~ ip ~ a i ~ / F I ~ ~ G / ~ _ ~ N / F- _ M r )Zi A N r to / _ _ _ _ _ _ _ _ _ _ _ _ _ c ~ N ,~ M ~ m o ~ ~ c M 0C dmn~m O~ev Q'i 1~~ N NMipnmm Of 00 U ~ ~ 000 Z O G~" S S ~ O w O ~ L O O O O O O O O O 0 0 0 0 0 0 0 0 0 0 0 ~ U1 M w A a~mnuim t~~~n on of D ~ t0 Of N QI OI fp M T of n N~O ~D N W ~N Now N n 1p N M M ~ N N M M M M M ~~~~ ° U y Z~NM~}hlO nao m r~ O (/ ~ 2 r N M 1~0 ~ N b N Z N LL N ~ O MOf E ~ b ~ > F = O N ~ m M N W ~ c ' og8 ~ ~ ~ ~ W N Q ~ F v 068 M ~ \ ~ o ~ ~ w ~ E ~ ~ 1 LL ~ ~ \ b ~ \ \ C \ C ~: 046 000111 " \ \ \ 7 O ~ J ~ C \ I` ~ in p \~ O \\ n ~ w ~~ ~' ~ ~ oJC.p LL ~ U ~ ~ ~ ' ~ ~ ~ r ~ A w N ey \ ~ ~ tip ~ O ~ c N V ~ ~ \~~ \ 1 ~ \ \ M ~\ ~~ ~ ~ p ~ c U C e6 °~ ~ ~ ~ f ~'. ~'.~',~ ~ ~ ~ n ~ 3 ° - ~ ~ ~ ~ ~ ~ ~ o ~ O ~ ~ ~ M ~ . \\ \ \ \` \\ F 7 ao ~ v_ A c_ 1 \ \ \ ` r J ~ ~ ~ \~ ~ ~~ G U ~+ o n O c ~ ~ A y _ ~ S C U \\~ ~ \ \\ \~~ ~ ~ ` ~~ ~ \\ \\ ~ ~ ~ ~ ~ ` ~ C \~ ~, V { ~ ~ ~ ~I ''. ~ ~i ~ ~ ~ :~ ~ ~ ~ '. ' . \ ~ \~ y p~ r W ~ a°o o ~ V ~ \ ~ \ ,\ \ ~ : ~ : ~ in N ~ V \ ~ \ \ ~ ~: ~ ' ~ ~ ~ w \ \ ~ ' ~ 1 7 m \ ~ 7 ~ \ ~ \: m C .C ~ ~ \ ~ C U ~ m \ \ M _ ~, ~<< N 0.+ M O \~ u ~ ^ °Ol w p °d~s N - - - - - - - - - - - - ' - - - - - - - - _ O N c~ LL ~ ~ ~ ~ I ~ ~ ~ 0 0 " O N " N 0 " n M s ° N z " Q ~ f ~ s 9l ~ °o /j O " 0 r C p O O o O{ 111 N o Z O O ~ G O O O " ~ O N ~ O J LL p ~ n m U ~ Nw _ m ~ O o O ~_ r o Q 0 0 eO " r o ~ C O o U o ~ ~ ~ (6 U ~ ; N O O " N ~ ~ O " r ~ > M a~ orv o '~' J N O ~ O m ~ ~ r O a Z ~ O y ~ N W N Q ~ d J ~ N N N O J ~ r J F U ~m o =~~ p o~ o J C~ W m >W ~ > ~ C ~ rM o o " z~ r > " > O W O + o 0 z + o 0 " n y~ ~' 1 ' ~ ~; ~ ~ ~ ~ 0 ' m ~ Y Y U V A U a ~ W ~~ / ~ ~ ~ S / U d ~' ~ , i ~ ~ / / _ 1 / / / S ~ j~ „N,~ 1 ~ .i 4J ~ i ~ y i " ' + M it i i i , ~ ~ I - ~: ~.: i :: i , ?_, ~'. ~! a i.~ i.~' , SHL ~ 1623 ft FSL 8 2296 ft FEL - ~- T11 N - R10 ~ Project: Kuparuk River Unit KO 00 ft M0, 3008 ND - Build ~ 2.5°/10 Site: Kuparuk 1J Pad - - - Well: Plan 1J-133 Continue Build @ 4°I100ft , 702ft MD, 700ft ND Wellbore: 1J-133 _ _ Plan: 1J-133 (wp06) /.-/ --~---------------- Sail@47.6°Inc:1644ft MD,1511ftND ~~°_____________________ __ Continue Build@4.5°/100ft,1844ftMD,1646ft ND ___________________________ Sail~76.7°Inc8141.3°Azi:2499ftMD,1948ftND 1A1 133/8" Casing ~ 169ft FNL 8 7428 FEL -Sec 2 - T10N - R10E: 3706ft MD, 2225ft D -1500 ___ ---"- ~` - - - _ _ Continue Tum @ 3°I100ft , 3999ft MD, 2292ft ND -2250 ' - - - - - - - - - - Sail ~ 76.7°Inc 8 148.9°Azi : 4245ft MD, 2349ft N T M Continue Build ~ 3°/100ft , 8788ft MD, 3391ft N -3750 ~ imuths to Tn,~e rJoen gnetic North: 25.07° ,~p9 Magnetic Field Strength: 57537.1 nT -4500 Dip Angle: 80.71 ° Date: 9/15/2003 Model: BGGM2004 -5250 Sail @ 80°Inc 8 175.9°Azi : 9675ft MD, 3573ft ND -6000 ;~50 Continue Build @ 3°/100ft , 10135ft MD, 3653ft ND 1J-133 T1 (D-top) (wp06 -- ~/ -6750 --' Sail @ 85° Inc : 10302ft MD, 3674ft ND 176° - ' ~ / - _ _ _ _ _ _ - ' 9 SIS" CSG - 917ft FNL 8 2184ft FWL -Sec 10 - T10N - R10E : 10690ft MD, 3704ft -7500 Continue Build @ 3°/100ft , 10562ft MD, 3697ft ND - - - - - _ _ _ - - " ---------- 176° _-- c 1J-133 T2 (wp06 180° CASING DETAILS -8250 ~ ~ 180° °o ~ ~ No TVD MD Name Size ~r 1 ° 1 2225.00 3706.03 13 3/8" 13-3/8 v 176 2 3703.8010689.68 9 5/8" 9-5/8 -9000 +vc 1J-133 T3 (wp06 ~ 3 3688.0016364.83 5 1/2" 5-1 /2 . r - - o -'- ' z ---_ - 174° -9750 ~ Drillers Target - defines a corridor `~ _ _ _ _ _ - _ _ _ _ _ -- 172 with allowable deviation from plan 1J-,33 T4 (wp°6 - - - - - - ~ ~ of +/- 50ft while in production zone ,0500 , 179, WELL DETAILS: Plan 1J-133 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 1J-133 T5(wp06 0.00 0.00 5945435.87 558916.79 70°15'41.49N149°31'25.425W 1J-133 1J-133 T6 Toe (wp06 177° 1J-133 L1 (wp06) @ 16356'MD ___ ______ 1J-133(wp06)@16365'MD HALLlBUA70N Sperry Drillias Services - ' BHL : 1301ft FNL 8 2446ft FWL -Sec 13 - T10N - R10E : 16365ft MD, 3688ft TVD ' -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 '` ~ ~ ~ ~ ~ " Halliburton Energy Servic es HA6.ji~j[Bt3F~Tt7M ~.~ON10CQ ~ II~~i ~35 Planning Report -Geographic --~ ~ ~ °- ~ S~tsy tlriilfng Services Database: EDM 2003.91 Single UserDb Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-133 Design: 1J-133 (wp06) 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 Plan 1J-133 -Slot 1J-133 Well Position +N/-S 0.00 ft Northing: 5,945,435.87 ft Latitude: 70° 15' 41.490" N +E/-W 0.00 ft Easting: 558,916.79 ft Longitude: 149° 31' 25.425" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-133 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2004 9/15/2003 25.07 80.71 57,537 __ _ ____ __ Design 1 J-133 (wp06) Audit Notes: Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/-S (ft) (ft) 40.00 0.00 Tie On Depth: +E/-W (ft) 0.00 Direction (°) 180.00 40.00 1/17/2006 3:39:09PM Page 2 of 10 ~~~~~~ ~~: COMPASS 2003.11 Build 48 yf ~ ~Halliburton Energy Services • Ccx~c}coP'~'tlr s I~A>~.>L.~BUaTOn~ Planning Report -Geographic - - _ - glaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Doyon 15 - RKB @ 121 AOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 - RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-133 Design: 1J-133 (wp06) 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) (°) 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0:00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 702.06 10.05 128.00 700.00 -21.66 27.72 2.50 2.50 0.00 128.00 1,644.41 47.62 136.26 1,511.00 -335.15 344.66 4.00 3.99 0.88 10.00 1,844.41 47.62 136.26 1,645.81 -441.90 446.79 0.00 0.00 0.00 0.00 2,498.71 76.74 141.30 1,948.05 -874.57 821.25 4.50 4.45 0.77 10.00 3,998.71 76.74 141.30 2,292.14 -2,013.92 1,734.20 0.00 0.00 0.00 0.00 4,244.98 76.74 148.89 2,348.70 -2,210.34 1,871.27 3.00 0.00 3.08 90.85 8,788.13 76.74 148.89 3,390.65 -5,996.24 4,156.33 0.00 0.00 0.00 0.00 9,675.01 80.00 175.86 3,572.64 -6,816.12 4,415.56 3.00 0.37 3.04 85.87 9,775.01 80.00 175.86 3,590.00 -6,914.34 4,422.67 0.00 0.00 0.00 0.00 10,135.01 80.00 175.86 3,652.51 -7,267.95 4,448.27 0.00 0.00 0.00 0.00 10,301.68 85.00 175.86 3,674.26 -7,432.71 4,460.19 3.00 3.00 0.00 0.00 10,561.68 85.00 175.86 3,696.92 -7,691.04 4,478.89 0.00 0.00 0.00 0.00 10,689.68 88.84 175.86 3,703.80 -7,818.50 4,488.12 3.00 3.00 0.00 0.00 10,849.13 90.20 180.45 3,705.13 -7,977.82 4,493.26 3.00 0.85 2.88 73.48 11,151.68 90.20 180.45 3,704.06 -8,280.35 4,490.90 0.00 0.00 0.00 0.00 11,246.17 88.84 177.96 3,704.85 -8,374.82 4,492.22 3.00 -1.44 -2.63 -118.73 11,846.17 88.84 177.96 3,717.00 -8,974.31 4,513.57 0.00 0.00 0.00 0.00 12,060.46 88.34 173.70 3,722.27 -9,187.92 4,529.14 2.00 -0.23 -1.99 -96.69 12,501.27 88.34 173.70 3,735.00 -9,625.90 4,577.48 0.00 0.00 0.00 0.00 12,698.67 91.99 172.18 3,734.43 -9,821.76 4,601.74 2.00 1.85 -0.77 -22.68 12,999.36 91.99 172.18 3,724.00 -10,119.47 4,642.63 0.00 0.00 0.00 0.00 13,358.52 90.26 179.15 3,716.96 -10,477.30 4,669.74 2.00 -0.48 1.94 103.85 15,131.59 90.26 179.15 3,709.00 -12,250.16 4,695.96 0.00 0.00 0.00 0.00 15,238.35 91.01 177.15 3,707.82 -12,356.85 4,699.40 2.00 0.70 -1.87 -69.40 16,364.84 91.01 177.15 3,688.00 -13,481.78 4,755.34 0.00 0.00 0.00 0.00 1/17/2006 3:39:09PM Page 3 of 10 COMPASS 2003.11 Build 48 ~~IG1NAl. r ~ ~ ~r- Hallibu rton Ener gy Serv ices HA 1 ~BU L RTC3tV COC1{3CCM~'11~~iS Planning Report - Geographic µ___M°~ . .. -~-~ --rv--T~~ sparrry Drilling Sarrvices Database: EDM 2003.11 Sin gle User Db Local Co-ordinate Reference: Well Plan 1J- 133 -Slot 1J-133 Company: ConocoPhillips Al aska (Kuparuk) TVD Reference: Doyon 15 -R KB @ 12LOOft (Doyon 15 (81+40)) Project: Kuparuk River Un it MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1 J Pad North Reference: True , Weil: Plan 1J-133 Survey Calculation Method: Minimum Cu rvature Wellbore: 1 J-133 Design: 1J-133 (wp06) _~ Planned Survey 1J-133 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ftl (ft) (ft) (ft) (ft) (°/100ft) (ft) 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 5,945,435.87 558,916.79 0.00 0.00 SHL @ 1623 ft FSL 8~ 2296 ft FEL - Sec 35 - T11 N - R10E 100.00 0.00 0.00 100.00 -21.00 0.00 0.00 5,945,435.87 558,916.79 0.00 0.00 200.00 . 0.00 0.00 200.00 79.00 0.00 0.00 5,945,435.87 558,916.79 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 5,945,435.87 558,916.79 0.00 0.00 • KOP @ 300 ft MD, 300ft ND -Build @ 2.5°/100ft 400.00 2.50 128.00 399.97 278.97 -1.34 1.72 5,945,434.54 558,918.52 2.50 1.34 500.00 5.00 128.00 499.75 378.75 -5.37 6.87 5,945,430.55 558,923.71 2.50 5.37 600.00 7.50 128.00 599.14 478.14 -12.07 15.45 5,945,423.92 558,932.34 2.50 12.07 700.00 10.00 128.00 697.97 576.97 -21.44 27.44 5,945,414.65 558,944.39 2.50 21.44 702.06 10.05 128.00 700.00 579.00 -21.66 27.72 5,945,414.43 558,944.68 2.50 21.66 Continue Build @ 4°/100ft , 702ft MD, 700ft TVD 800.00 13.93 130.83 795.79 674.79 -34.63 43.38 5,945,401.58 558,960.44 4.00 34.63 900.00 17.90 132.46 891.94 770.94 -52.88 63.83 5,945,383.49 558,981.03 4.00 52.88 1,000.00 21.88 133.52 985.95 864.95 -76.10 88.69 5,945,360.47 559,006.07 4.00 76.10 1,100.00 25.87 134.27 1,077.37 956.37 -104.17 117.84 5,945,332.63 559,035.44 4.00 104.17 1,200.00 29.87 134.82 1,165.76 1,044.76 -136.97 151.14 5,945,300.10 559,068.99 4.00 136.97 1,300.00 33.86 135.26 1,250.67 1,129.67 -174.32 188.43 5,945,263.04 559,106.56 4.00 174.32 1,400.00 37.85 135.61 1,331.70 1,210.70 -216.05 229.51 5,945,221.64 559,147.97 4,00 216.05 1,500.00 41.85 135.91 1,408.46 1,287.46 -261.96 274.21 5,945,176.09 559,193.01 4.00 261.96 1,600.00 45.84 136.16 1,480.56 1,359.56 -311.81 322.28 5,945,126.62 559,241.47 4.00 311.81 1,644.41 47.62 136.26 1,511.00 1,390.00 -335.15 344.66 5,945,103.45 559,264.03 4.00 335.15 Sail ~ 47.6° Inc : 1644ft MD, 1511ft TVD -Permafrost 1,700.00 47.62 136.26 1,548.47 1,427.47 -364.83 373.05 5,945,074.01 559,292.65 0.00 364.83 1,800.00 47.62 136.26 1,615.88 1,494.88 -418.20 424.11 5,945,021.04 559,344.12 0.00 418.20 1,844.41 47.62 136.26 1,645.81 1,524.81 -441.90 446.79 5,944,997.52 559,366.99 0.00 441.90 Continue Build @ 4.5°/100ft , 1844ft MD, 1646ft TVD 1,877.81 49.10 136.61 1,668.00 1,547.00 -459.99 463.99 5,944,979.57 559,384.32 4.50 459.99 T3 1,900.00 50.08 136.83 1,682.39 1,561.39 -472.29 475.58 5,944,967.36 559,396.01 4.50 472.29 2,000.00 54.52 137.75 1,743.52 1,622.52 -530.43 529.22 5,944,909.64 559,450.09 4.50 530.43 2,100.00 58.97 138.58 1,798.34 1,677.34 -592.73 584.97 5,944,847.78 559,506.32 4.50 592.73 2,200.00 63.42 139.33 1,846.50 1,725.50 -658.82 642.49 5,944,782.16 559,564.35 4.50 658.82 2,300.00 67.88 140.03 1,887.72 1,766.72 -728.27 701.41 5,944,713.18 559,623.81 4.50 728.27 2,400.00 72.34 140.68 1,921.74 1,800.74 -800.66 761.39 5,944,641.27 559,684.35 4.50 800.66 2,498.71 76.74 141.30 1,948.05 1,827.05 -874.57 821.25 5,944,567.84 559,744.78 4.50 874.57 Sail ~ 76.7°Inc & 141.3°Azi : 2499ft MD, 1948ft ND 2,500.00 76.74 141.30 1,948.35 1,827.35 -875.55 822.04 5,944,566.86 559,745.58 0.00 875.55 2,600.00 76.74 141.30 1,971.29 1,850.29 -951.50 882.90 5,944,491.39 559,807.03 0.00 951.50 2,700.00 76.74 141.30 1,994.22 1,873.22 -1,027.46 943.77 5,944,415.92 559,868.48 0.00 1,027.46 2,712.10 76.74 141.30 1,997.00 1,876.00 -1,036.65 951.13 5,944,406.79 559,875.91 0.00 1,036.65 K15 2,800.00 76.74 141.30 2,017.16 1,896.16 -1,103.42 1,004.63 5,944,340.45 559,929.93 0.00 1,103.42 2,900.00 76.74 141.30 2,040.10 1,919.10 -1,179.37 1,065.49 5,944,264.98 559,991.38 0.00 1,179.37 3,000.00 76.74 141.30 2,063.04 1,942.04 -1,255.33 1,126.36 5,944,189.51 560,052.83 0.00 1,255.33 3,100.00 76.74 141.30 2,085.98 1,964.98 -1,331.29 1,187.22 5,944,114.03 560,114.28 0.00 1,331.29 1/?7/2006 3:39:09PM Page 4 of 10 COMPASS 2003.11 Build 48 °+,~-' ~Halliburton Energy Services ~ HAL~.tgl3q'T©N ~OiK?Gt~~11~11p5 Planning Report -Geographic -~ ------ Alaska Sperry ttrilling Serri~es Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Weil: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-133 Design: 1J-133 (wp06) Planned Survey 1J-133 (wp06) MD Inclination Azimuth ND (ft) (°) (°) (ft) Map Map SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (ft) (ft) (ft) (ft) (°l100ft) (ft) 3,200.00 76.74 141.30 2,108.92 1,987.92 -1,407.25 1,248.08 5,944,038.56 560,175.73 0.00 1,407.25 3,300.00 76.74 141.30 2,131.86 2,010.86 -1,483.20 1,308.95 5,943,963.09 560,237.18 0.00 1,483.20 3,400.00 76.74 141.30 2,154.80 2,033.80 -1,559.16 1,369.81 5,943,887,62 560,298.63 0.00 1,559.16 3,500.00 76.74 141.30 2,177.74 2,056.74 -1,635.12 1,430.67 5,943,812.15 560,360.08 0.00 1,635.12 3,600.00 76.74 141.30 2,200.68 2,079.68 -1,711.07 1,491.54 5,943,736.68 560,421.53 0.00 1,711.07 3,700.00 76.74 141.30 2,223.62 2,102.62 -1,787.03 1,552.40 5,943,661.21 560,482.98 0.00 1,787.03 3,706.03 76.74 141.30 2,225.00 2,104.00 -1,791.61 1,556.07 5,943,656.65 560,486.68 0.00 1,791.61 13 3/8" Casing @ 169ft FNL 8 74 2ft FEL -Sec 2 - T10N - R10E: 3706ft MD, 2225ft ND - T3+ 550 (Surface Casing) - 13 3!8" 3,800.00 76.74 141.30 2,246.56 2,125.56 -1,862.99 1,613.26 5,943,585.74 560,544.43 0.00 1,862.99 3,900.00 76.74 141.30 2,269.49 2,148.49 -1,938.94 1,674.13 5,943,510.27 560,605.88 0.00 1,938.94 3,998.71 76.74 141.30 2,292.14 2,171.14 -2,013.92 1,734.20 5,943,435.77 560,666.53 0.00 2,013.92 Continue Turn @ 3°l100ft , 3999ft MD, 2292ft ND 4,000.00 76.74 141.33 2,292.43 2,171.43 -2,014.90 1,734.99 5,943,434.79 560,667.32 2.96 2,014.90 4,100.00 76.71 144.42 2,315.40 2,194.40 -2,092.49 1,793.72 5,943,357.67 560,726.66 3.00 2,092.49 4,200.00 76.72 147.50 2,338.38 2,217.38 -2,173.13 1,848.20 5,943,277.47 560,781.76 3.00 2,173.13 4,244.98 76.74 148.89 2,348.70 2,227.70 -2,210.34 1,871.27 5,943,240.45 560,805.12 3.00 2,210.34 Sail ~ 76.7°Inc 8< 148.9°Azi : 4245ft MD, 2349ft ND 4,300.00 76.74 148.89 2,361.32 2,240.32 -2,256.18 1,898.94 5,943,194.82 560,833.15 0.00 2,256.18 4,400.00 76.74 148.89 2,384.26 2,263.26 -2,339.52 1,949.24 5,943,111.90 560,884.09 0.00 2,339.52 4,500.00 76.74 148.89 2,407.19 2,286.19 -2,422.85 1,999.54 5,943,028.97 560,935.03 0.00 2,422.85 4,600.00 76.74 148.89 2,430.12 2,309.12 -2,506.18 2,049.83 5,942,946.04 560,985.97 0.00 2,506.18 4,700.00 76.74 148.89 2,453.06 2,332.06 -2,589.51 2,100.13 5,942,863.11 561,036.92 0.00 2,589.51 4,800.00 76.74 148.89 2,475.99 2,354.99 -2,672.84 2,150.43 5,942,780.18 561,087.86 0.00 2,672.84 4,900.00 76.74 148.89 2,498.93 2,377.93 -2,756.18 2,200.72 5,942,697.26 561,138.80 0.00 2,756.18 5,000.00 76.74 148.89 2,521.86 2,400.86 -2,839.51 2,251.02 5,942,614.33 561,189.74 0.00 2,839.51 5,100.00 76.74 148.89 2,544.80 2,423.80 -2,922.84 2,301.32 5,942,531.40 561,240.68 0.00 2,922.84 5,200.00 76.74 148.89 2,567.73 2,446.73 -3,006.17 2,351.61 5,942,448.47 561,291.63 0.00 3,006.17 5,300.00 76.74 148.89 2,590.67 2,469.67 -3,089.51 2,401.91 5,942,365.54 561,342.57 0.00 3,089.51 5,400.00 76.74 148.89 2,613.60 2,492.60 -3,172.84 2,452.21 5,942,282.62 561,393.51 0.00 3,172.84 5,500.00 76.74 148.89 2,636.53 2,515.53 -3,256.17 2,502.50 5,942,199.69 561,444.45 0.00 3,256.17 5,600.00 76.74 148.89 2,659.47 2,538.47 -3,339.50 2,552.80 5,942,116.76 561,495.40 0.00 3,339.50 5,700.00 76.74 148.89 2,682.40 2,561.40 -3,422.83 2,603.10 5,942,033.83 561,546.34 0.00 3,422.83 5,800.00 76.74 148.89 2,705.34 2,584.34 -3,506.17 2,653.39 5,941,950.90 561,597.28 0.00 3,506.17 5,900.00 76.74 148.89 2,728.27 2,607.27 -3,589.50 2,703.69 5,941,867.97 561,648.22 0.00 3,589.50 6,000.00 76.74 148.89 2,751.21 2,630.21 -3,672.83 2,753.99 5,941,785.05 561,699.17 0.00 3,672.83 6,100.00 76.74 148.89 2,774.14 2,653.14 -3,756.16 2,804.28 5,941,702.12 561,750.11 0.00 3,756.16 6,200.00 76.74 148.89 2,797.08 2,676.08 -3,839.49 2,854.58 5,941,619.19 561,801.05 0.00 3,839.49 6,300.00 76.74 148.89 2,820.01 2,699.01 -3,922.83 2,904.88 5,941,536.26 561,851.99 0.00 3,922.83 6,400.00 76.74 148.89 2,842.94 2,721.94 -4,006.16 2,955.17 5,941,453.33 561,902.93 0.00 4,006.16 6,500.00 76.74 148.89 2,865.88 2,744.88 -4,089.49 3,005.47 5,941,370.41 561,953.88 0.00 4,089.49 6,600.00 76.74 148.89 2,888.81 2,767.81 -4,172.82 3,055.77 5,941,287.48 562,004.82 0.00 4,172.82 6,640.05 76.74 148.89 2,898.00 2,777.00 -4,206.20 3,075.91 5,941,254.26 562,025.22 0.00 4,206.20 Ugnu C 6,700.00 76.74 148.89 2,911.75 2,790.75 -4,256.16 3,106.06 5,941,204.55 562,055.76 0.00 4,256.16 6,800.00 76.74 148.89 2,934.68 2,813.68 -4,339.49 3,156.36 5,941,121.62 562,106.70 0.00 4,339.49 6,900.00 76.74 148.89 2,957.62 2,836.62 -4,422.82 3,206.66 5,941,038.69 562,157.65 0.00 4,422.82 7,000.00 76.74 148.89 2,980.55 2,859.55 -4,506.15 3,256.95 5,940,955.77 562,208.59 0.00 4,506.15 7,100.00 76.74 148.89 3,003.49 2,882.49 -4,589.48 3,307.25 5,940,872.84 562,259.53 0.00 4,589.48 1/17/2006 3:39:09PM Page 5 of 10 COMPASS 2003.11 Build 48 ORIGINAL ` ~ Halliburton Ener Services C+anocaPhitli s gy ll-~~-`~r~ufaTC~pv Pl i R hi --~--- ---- - ~ ~--~--~~ rt G ann ng eograp c epo - Alaska ~Pe~m- Drilifng Sa~r+rfces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 Company: ConocoPhillips Alaska (Kuparu k) ND Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-133 Design: 1J-133 (wp06) ', Planned Survey 1 J-133 (wp06) Map Map MD Inclination Azimuth ND SSND +N/-S +E/.U1/ Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) Ift) (ft) (ft) (°/100ft) (ft) 7,200.00 76.74 148.89 3,026.42 2,905.42 -4,672.82 3,357.55 5,940,789.91 562,310.47 0.00 4,672.82 7,300.00 76.74 148.89 3,049.35 2,928.35 -4,756.15 3,407.84 5,940,706.98 562,361.41 0.00 4,756.15 7,400.00 76.74 148.89 3,072.29 2,951.29 -4,839.48 3,458.14 5,940,624.05 562,412.36 0.00 4,839.48 7,500.00 76.74 148.89 3,095.22 2,974.22 -4,922.81 3,508.44 5,940,541.12 562,463.30 0.00 4,922.81 7,600.00 76.74 148.89 3,118.16 2,997.16 -5,006.15 3,558.73 5,940,458.20 562,514.24 0.00 5,006.15 7,700.00 76.74 148.89 3,141.09 3,020.09 -5,089.48 3,609.03 5,940,375.27 562,565.18 0.00 5,089.48 7,800.00 76.74 148.89 3,164.03 3,043.03 -5,172.81 3,659.33 5,940,292.34 562,616,13 0.00 5,172.81 7,900.00 76.74 148.89 3,186.96 3,065.96 -5,256.14 3,709.62 5,940,209.41 562,667.07 0.00 5,256.14 7,943.77 76.74 148.89 3,197.00 3,076.00 -5,292.62 3,731.64 5,940,173.11 562,689.37 0.00 5,292.62 Ugnu B 8,000.00 76.74 148.89 3,209.90 3,088.90 -5,339.47 3,759.92 5,940,126.48 562,718.01 0.00 5,339.47 8,100.00 76.74 148.89 3,232.83 3,111.83 -5,422.81 3,810.22 5,940,043.56 562,768.95 0.00 5,422.81 8,200.00 76.74 148.89 3,255.77 3,134.77 -5,506.14 3,860.51 5,939,960.63 562,819.90 0.00 5,506.14 8,222.83 76.74 148.89 3,261.00 3,140.00 -5,525.16 3,872.00 5,939,941.70 562,831.52 0.00 5,525.16 Ugnu A 3 ;~ 8,300.00 76.74 148.89 3,278.70 3,157.70 -5,589.47 3,910.81 5,939,877.70 562,870.84 0.00 5,589.47 8,400.00 76.74 148.89 3,301.63 3,180.63 -5,672.80 3,961.11 5,939,794.77 562,921.78 0.00 5,672.80 8,500.00 76.74 148.89 3,324.57 3,203.57 -5,756.14 4,011.41 5,939,711.84 562,972.72 0.00 5,756.14 8,600.00 76.74 148.89 3,347.50 3,226.50 -5,839.47 4,061.70 5,939,628.91 563,023.66 0.00 5,839.47 8,700.00 76.74 148.89 3,370.44 3,249.44 -5,922.80 4,112.00 5,939,545.99 563,074.61 0.00 5,922.80 8,788.13 76.74 148.89 3,390.65 3,269.65 -5,996.24 4,156.33 5,939,472.90 563,119.50 0.00 5,996.24 Continue Build @ 3°/100ft , 8788ft MD, 3391ft ND 8,800.00 76.77 149.25 3,393.37 3,272.37 -6,006.15 4,162.26 5,939,463.04 563,125.52 2.99 6,006.15 8,900.00 77.01 152.32 3,416.06 3,295.06 -6,091.14 4,209.79 5,939,378.43 563,173.70 3.00 6,091.14 8,984.96 77.24 154.93 3,435.00 3,314.00 -6,165.33 4,246.58 5,939,304.54 563,211.07 3.00 6,165.33 K13 9,000.00 77.28 155.38 3,438.32 3,317.32 -6,178.65 4,252.75 5,939,291.27 563,217.34 2:99 6,178.65 9,100.00 77.59 158.44 3,460.08 3,339.08 -6,268.43 4,291.01 5,939,201.80 563,256.30 3.00 6,268.43 9,200.00 77.93 161.49 3,481.28 3,360.28 -6,360.23 4,324.48 5,939,110.27 563,290.49 3.00 6,360.23 9,300.00 78.31 164.53 3,501.86 3,380.86 -6,453.81 4,353.07 5,939,016.93 563,319.80 3.00 6,453.81 9,400.00 78.72 167.57 3,521.78 3,400.78 -6,548.91 4,376.69 5,938,922.03 563,344.16 3.00 6,548.91 9,500.00 79.16 170.59 3,540.96 3,419.96 -6,645.26 4,395.28 5,938,825.83 563,363.50 3.00 6,645.26 9,600.00 79.63 173.60 3,559.37 3,438.37 -6,742.61 4,408.79 5,938,728.61 563,377.77 3.00 6,742.61 9,675.01 80.00 175.86 3,572.64 3,451.64 -6,816.12 4,415.56 5,938,655.16 563,385.12 3.00 6,816.12 Sail @ 80°Inc & 175.9°Azi : 9675ft MD, 3573ft ND 9,700.00 80.00 175.86 3,576.97 3,455.97 -6,840.66 4,417.34 5,938,630.63 563,387.09 0.00 6,840.66 9,775:01 80.00 175.86 3,590.00 3,469.00 -6,914.34 4,422.67 5,938,557.00 563,393.00 0.00 6,914.34 WSAK D @ 80 - 1J-13 3 T7 (D-top) (wp06) -1J-133 DD Polygon (wp06) 9,800.00 80.00 175.86 3,594.34 3,473.34 -6,938.89 4,424.45 5,938,532.47 563,394.97 0.00 6,938.89 9,900.00 80.00 175.86 3,611.70 3,490.70 -7,037.11 4,431.56 5,938,434.32 563,402.85 0.00 7,037.11 10,000.00 80.00 175.86 3,629.07 3,508.07 -7,135.34 4,438.67 5,938,336.16 563,410.72 0.00 7,135.34 10,100.00 80.00 175.86 3,646.43 3,525.43 -7,233.56 4,445.78 5,938,238.00 563,418.60 0.00 7,233.56 10,135.01 80.00 175.86 3,652.51 3,531.51 -7,267.95 4,448.27 5,938,203.64 563,421.36 0.00 7,267.95 Continue Build @ 3°/100ft , 10135ft MD, 3653ft ND 10,137.83 80.08 175.86 3,653.00 3,532.00 -7,270.71 4,448.47 5,938,200.88 563,421.58 3.00 7,270.71 WSAK C 1/17/2006 3:39:09PM Page 6 of 10 COMPASS 2003.11 Build 48 OR161NAL ~H llib En i ~ t S , ' a ur on ergy erv ces HAI..L.tBUi~TI'd ~t)f1t]LO ~ 11~~i~S Planning Report -Geographic ~~-~--~-----~----~~--~-~~~----~~~- Alaska gP'snY !trilling SaPrvices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 Company: ConocoPhiilips Alaska (Kuparuk) TVD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1 d Pad North Reference: True Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-133 Design: 1J-133 (wp06) Planned Survey 1J-133 (wp06) - --- - __ - - Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 10,200.00 81.95 175.86 3,662.71 3,541.71 -7,331.96 4,452.90 5,938,139.67 563,426.49 3.00 7,331.96 10,287.79 84.58 175.86 3,673.00 3,552.00 -7,418.91 4,459.20 5,938,052.78 563,433.46 3.00 7,418.91 Top B-Sand @ 10288ft MD, 3673ft TVD - 518ft FNL 8 2156ft FWL -Sec 12 - T10N - R10E - WSAK B @ 85 10,300.00 84.95 175.86 3,674.11 3,553.11 -7,431.04 4,460.07 5,938,040.66 563,434.44 3.00 7,431.04 10,301.68 85.00 175.86 3,674.26 3,553.26 -7,432.71 4,460.19 5,938,039.00 563,434.57 3.00 7,432.71 Sail @ 85° I nc : 10302ft MD, 3674ft TVD 10,400.00 85.00 175.86 3,682.83 3,561.83 -7,530.40 4,467.27 5,937,941.37 563,442.41 0.00 7,530.40 10,500.00 85.00 175.86 3,691.55 3,570.55 -7,629.76 4,474.46 5,937,842.08 563,450.37 0.00 7,629.76 10,561.68 85.00 175.86 3,696.92 3,575.92 -7,691.04 4,478.89 5,937,780.84 563,455.29 0.00 7,691.04 Continue Build @ 3°l1 00ft , 10562ft MD, 3697ft TVD 10,600.00 86.15 175.86 3,699.88 3,578.88 -7,729.15 4,481.65 5,937,742.76 563,458.34 3.00 7,729.15 10,689.68 88.84 175.86 3,703.80 IZ/ 3,582.80 -7,818.50 4,488.12 5,937,653.47 563,465.51 3.00 7,818.50 9 5!8" CSG - 917ft FNL & 2184ft """ FWL -Sec 7.n - T 10N - R10E : 10690ft MD, 3704ft TVD - 9 5!8" 10,700.00 88.93 176.16 3,704.00 3,583.00 -7,828.79 4,488.84 5,937,643.18 563,466.31 2.99 7,828.79 10,800.00 89.78 179.03 3,705.12 3,584.12 -7,928.69 4,493.03 5,937,543.33 563,471.29 3.00 7,928.69 10,849.13 90.20 180.45 3,705.13 3,584.13 -7,977.82 4,493.26 5,937,494.21 563,471.89 3.00 7,977.82 10,900.00 90.20 180.45 3,704.95 3,583.95 -8,028.68 4,492.86 5,937,443.35 563,471.90 0.00 8,028.68 11,000.00 90.20 180.45 3,704.60 3,583.60 -8,128.68 4,492.08 5,937,343.36 563,471.90 0.00 8,128.68 11,100.00 90.20 180.45 3,704.25 3,583.25 -8,228.68 4,491.30 5,937,243.37 563,471.90 0.00 8,228.68 11,151.68 90.20 180.45 3,704.06 3,583.06 -8,280.35 4,490.90 5,937,191.69 563,471.91 0.00 8,280.35 11,200.00 89.51 179.18 3,704.19 3,583.19 -8,328.67 4,491.06 5,937,143.38 563,472.44 3.00 8,328.67 11,246.17 88.84 177.96 3,704.85 3,583.85 -8,374.82 4,492.22 5,937,097.25 563,473.96 3.00 8,374.82 11,300.00 88.84 177.96 3,705.94 3,584.94 -8,428.61 4,494.13 5,937,043.49 563,476.30 0.00 8,428.61 11,400.00 88.84 177.96 3,707.97 3,586.97 -8,528.52 4,497.69 5,936,943.61 563,480.64 0.00 8,528.52 11,500.00 88.84 177.96 3,709.99 3,588.99 -8,628.44 4,501.25 5,936,843.73 563,484.98 0.00 8,628.44 11,600.00 88.84 177.96 3,712.02 3,591.02 -8,728.36 4,504.81 5,936,743.86 563,489.32 0.00 8,728.36 11,700.00 88.84 177.96 3,714.04 3,593.04 -8,828.27 4,508.37 5,936,643.98 563,493.66 0.00 8,828.27 11,800.00 88.84 177.96 3,716.07 3,595.07 -8,928.19 4,511.93 5,936,544.11 563,498.00 0.00 8,928.19 11,846.17 88.84 177.96 3,717.00 3,596.00 -8,974.31 4,513.57 5,936,498.00 563,500.00 0.00 8,974.31 1 J-133 T2 (wp06) 11,900.00 88.71 176.89 3,718.15 3,597.15 -9,028.08 4,515.99 5,936,444.26 563,502.84 2.00 9,028.08 12,000.00 88.48 174.90 3,720.59 3,599.59 -9,127.79 4,523.14 5,936,344.62 563,510.77 2.00 9,127.79 12,060.46 88.34 173.70 3,722.27 3,601.27 -9,187.92 4,529.14 5,936,284.54 563,517.24 2.00 9,187.92 12,100.00 88.34 173.70 3,723.41 3,602.41 -9,227.21 4,533.48 5,936,245.29 563,521.88 0.00 9,227.21 12,200.00 88.34 173.70 3,726.30 3,605.30 -9,326.57 4,544.44 5,936,146.03 563,533.62 0.00 9,326.57 12,300.00 88.34 173.70 3,729.19 3,608.19 -9,425.92 4,555.41 5,936,046.78 563,545.37 0.00 9,425.92 12,400.00 88.34 173.70 3,732.07 3,611.07 -9,525.28 4,566.37 5,935,947.52 563,557.11 0.00 9,525.28 12,500.00 88.34 173.70 3,734.96 3,613.96 -9,624.63 4,577.34 5,935,848.26 563,568.85 0.00 9,624.63 12,501.27 88.34 173.70 3,735.00 3,614.00 -9,625.90 4,577.48 5,935,847.00 563,569.00 0.00 9,625.90 1J-133 T3 (wp06) 12,600.00 90.17 172.94 3,736.28 3,615.28 -9,723.94 4,588.96 5,935,749.06 563,581.25 2.00 9,723.94 12,698.67 91.99 172.18 3,734.43 3,613.43 -9,821.76 4,601.74 5,935,651.35 563,594.78 2.00 9,821.76 12,700.00 91.99 172.18 3,734.38 3,613.38 -9,823.08 4,601.92 5,935,650.04 563,594.98 0.00 9,823.08 12,800.00 91.99 172.18 3,730.91 3,609.91 -9,922.09 4,615.52 5,935,551.15 563,609.35 0.00 9,922.09 12,900.00 91.99 172.18 3,727.45 3,606.45 -10,021.10 4,629.12 5,935,452.26 563,623.72 0.00 10,021.10 12,999.36 91.99 172.18 3,724.00 3,603.00 -10,119.47 4,642.63 5,935,354.00 563,638.00 0.00 10,119.47 1J-133 T4 (wp06) 1/17/2006 3:39:09PM Page 7 of 10 COMPASS 2003.11 Build 48 ORIGINAL Halliburton Ener Services CQt1000~'11~~i S gy HaL ter..~~-a~c~~t Pl i R t G hi ------ -~~-- ann ng epor - eograp c ,~~ Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-133 Design: 1J-133 (wp06) Planned Survey 1J-133 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section ~, (ft) (°) (°) (ft) (ft1 (ft) (ft) (ft) (ft) (°1100ft) (ft) 13,000.00 91.98 172.19 3,723.98 3,602.98 -10,120.11 4,642.71 5,935,353.36 563,638.09 2.00 10,120.11 13,100.00 91.50 174.13 3,720.93 3,599.93 -10,219.34 4,654.61 5,935,254.23 563,650.77 2.00 10,219.34 13,200.00 91.02 176.07 3,718.73 3,597.73 -10,318.95 4,663.14 5,935,154.71 563,660.07 2.00 10,318.95 13,300.00 90.54 178.02 3,717.36 3,596.36 -10,418.80 4,668.30 5,935,054.91 563,666.01 2.00 10,418.80 13,358.52 90.26 179.15 3,716.96 3,595.96 -10,477.30 4,669.74 5,934,996.42 563,667.91 2.00 10,477.30 13,400.00 90.26 179.15 3,716.77 3,595.77 -10,518.78 4,670.35 5,934,954.96 563,668.85 0.00 10,518.78 13,500.00 90.26 179.15 3,716.32 3,595.32 -10,618.77 4,671.83 5,934,855.00 563,671.11 0.00 10,618.77 13,600.00 90.26 179.15 3,715.87 3,594.87 -10,718.75 4,673.31 5,934,755.03 563,673.37 0.00 10,718.75 13,700.00 90.26 179.15 3,715.42 3,594.42 -10,818.74 4,674.79 5,934,655.07 563,675.63 0.00 10,818.74 13,800.00 90.26 179.15 3,714.98 3,593.98 -10,918.73 4,676.27 5,934,555.10 563,677.89 0.00 10,918.73 13,900.00 90.26 179.15 3,714.53 3,593.53 -11,018.72 4,677.75 5,934,455.14 563,680.15 0.00 11,018.72 14,000.00 90.26 179.15 3,714.08 3,593.08 -11,118.71 4,679.23 5,934,355.18 563,682.41 0.00 11,118.71 14,100.00 90.26 179.15 3,713.63 3,592.63 -11,218.69 4,680.71 5,934,255.21 563,684.68 0.00 11,218.69 14,200.00 90.26 179.15 3,713.18 3,592.18 -11,318.68 4,682.19 5,934,155.25 563,686.94 0.00 11,318.68 14,300.00 90.26 179.15 3,712.73 3,591.73 -11,418.67 4,683.67 5,934,055.29 563,689.20 0.00 11,418.67 14,400.00 90.26 179.15 3,712.28 3,591.28 -11,518.66 4,685.14 5,933,955.32 563,691.46 0.00 11,518.66 14,500.00 90.26 179.15 3,711.83 3,590.83 -11,618.65 4,686.62 5,933,855.36 563,693.72 0.00 11,618.65 14,600.00 90.26 179.15 3,711.39 3,590.39 -11,718.63 4,688.10 5,933,755.39 563,695.98 0.00 11,718.63 14,700.00 90.26 179.15 3,710.94 3,589.94 -11,818.62 4,689.58 5,933,655.43 563,698.24 0.00 11,818.62 14,800.00 90.26 179.15 3,710.49 3,589.49 -11,918.61 4,691.06 5,933,555.47 563,700.50 0.00 11,918.61 14,900.00 90.26 179.15 3,710.04 3,589.04 -12,018.60 4,692.54 5,933,455.50 563,702.76 0.00 12,018.60 15,000.00 90.26 179.15 3,709.59 3,588.59 -12,118.59 4,694.02 5,933,355.54 563,705.02 0.00 12,118.59 15,100.00 90.26 179.15 3,709.14 3,588.14 -12,218.57 4,695.50 5,933,255.57 563,707.29 0.00 12,218.57 15,131.59 90.26 179.15 3,709.00 3,588.00 -12,250.16 4,695.96 5,933,224.00 563,708.00 0.00 12,250.16 1J-133 TS (wp05) 15,200.00 90.74 177.87 3,708.41 3,587.41 -12,318.54 4,697.74 5,933,155.64 563,710.31 2.00 12,318.54 15,238.35 91.01 177.15 3,707.82 3,586.82 -12,356.85 4,699.40 5,933,117.34 563,712.27 2.00 12,356.85 15,300.00 91.01 177.15 3,706.74 3,585.74 -12,418.42 4,702.47 5,933,055.81 563,715.82 0.00 12,418.42 15,400.00 91.01 177.15 3,704.98 3,583.98 -12,518.28 4,707.43 5,932,956.00 563,721.56 0.00 12,518.28 15,500.00 91.01 177.15 3,703.22 3,582.22 -12,618.14 4,712.40 5,932,856.19 563,727.31 0.00 12,618.14 15,600.00 91.01 177.15 3,701.46 3,580.46 -12,718.00 4,717.36 5,932,756.38 563,733.05 0.00 12,718.00 15,700.00 91.01 177.15 3,699.70 3,578.70 -12,817.86 4,722.33 5,932,656.57 563,738.80 0.00 12,817.86 15,800.00 91.01 177.15 3,697.94 3,576.94 -12,917.72 4,727.29 5,932,556.76 563,744.55 0.00 12,917.72 15,900.00 91.01 177.15 3,696.18 3,575.18 -13,017.58 4,732.26 5,932,456.95 563,750.29 0.00 13,017.58 16,000.00 91.01 177.15 3,694.42 3,573.42 -13,117.44 4,737.22 5,932,357.14 563,756.04 0.00 13,117.44 16,100.00 91.01 177.15 3,692.66 3,571.66 -13,217.31 4,742.19 5,932,257.33 563,761.78 0.00 13,217.31 16,200.00 91.01 177.15 3,690.90 3,569.90 -13,317.17 4,747.15 5,932,157.52 563,767.53 0.00 13,317.17 16,300.00 91.01 177.15 3,689.14 3,568.14 -13,417.03 4,752.12 5,932,057.72 563,773.27 0.00 13,417.03 16,364.84 91.01 177.15 3,688.00 3,567.00 -13,481.78 4,755.34 5,931,993.00 563,777.00 0.00 13,481.78 BHL : 1301ft FNL & 2446ft FWL -Sec 13 - T10N - R10E : 16365ft MD, 3688ft TVD - 5 1/2" -1J-133 T6 Toe (wp06) 1/17/2006 3:39:09PM Page 8 of 10 COMPASS 2003.11 Build 48 ORIGINAL ~ -'` •Hallib rton Ener Services ~ r ~tN~~COPI'1lIl~35 gy u NA~~tBUaTC7N i hi Pl R t G °~-~-----------~~-°----~ ann ng epor eograp - c Alaska Spsrr~ D~tliing Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-133 -Slot 1 J-133 Company: Conoco Phillips Alaska (Kuparuk) TVD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-133 Design: 1J-133 (wp06) ~ Geologic Targets 1J 133 ', TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,735.00 1J-133 T3 (wp06) -9,625.90 4,577.48 5,935,847.00 563,569.00 - Point 3,590.00 1J-133 DD Polygon (wp06) -6,914.34 4,422.67 5,938,557.00 563,393.00 - Polygon Point 1 -50.00 0.00 5,938,556.61 563,343.01 Point 2 15.44 -903.77 5,937,653.47 563,415.51 Point 3 40.89 -2,059.58 5,936,498.00 563,450.00 Point 4 104.80 -2,711.16 5,935,847.00 563,519.00 Point 5 169.95 -3,204.74 5,935,354.00 563,588.00 Point 6 223.29 -5,335.42 5,933,224.00 563,658.00 Point 7 282.66 -6,567.04 5,931,993.00 563,727.00 Point 8 382.67 -6,567.83 5,931,993.00 563,827.00 Point 9 323.29 -5,336.21 5,933,224.00 563,758.00 Point 10 269.96 -3,205.52 5,935,354.00 563,688.00 Point 11 204.81 -2,711.95 5,935,847.00 563,619.00 Point 12 140.90 -2,060.36 5,936,498.00 563,550.00 Point 13 115.45 -904.55 5,937,653.47 563,515.51 Point 14 50.00 0.00 5,938,557.39 563,442.99 3,590.00 1J-133 T1 (D-top) (wp06) -6,914.34 4,422.67 5,938,557.00 563,393.00 - Point 3,709.00 1J-133 T5 (wp06) -12,250.16 4,695.96 5,933,224.00 563,708.00 - Point 3,688.00 1J-133 T6 Toe (wp06) -13,481.78 4,755.34 5,931,993.00 563,777.00 - Point 3,717.00 1J-733 T2 (wp06) -8,974.31 4,513.57 5,936,498.00 563,500.00 - Point 3,724.00 1J-133 T4 (wp06) -10,119.47 4,642.63 5,935,354.00 563,638.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diamete r (ft) lft) (") (") 3,706.03 2,225.00 13-3/8 16 10,689.68 3,703.80 9-5/8 12-1 /4 16,364.83 3,688.00 5-1/2 8-1l2 1/17/2006 3.39:09PM Page 9 of 10 COMPASS 2003.11 Build 48 ~'~~~~ > ~C-1'~t~CU~'11 ~ ~! r35 Alaska Database: EDM 2003.11 S ingle User Db Company: ConocoPhillips Alaska (Kuparuk Project: Kuparuk River U nit Site: Kuparuk 1 J Pad Well: Plan 1J-133 Wellbore: 1 J-133 Design: 1J-133 (wp06) Prognosed Formation Intersection Points Measured Ve Depth Inclination Azimuth D 1,644.41 47.62 136.26 1 1,877.81 49.10 136.61 1 2,712.10 76.74 141.30 1 3,706.03 76.74 141.30 2 6,640.05 76.74 148.89 2 7,943.77 76.74 148.89 3 8,222.83 76.74 148.89 3 8,984.96 77.24 154.93 3 9,775.01 80.00 175.86 3 10,137.83 80.08 175.86 3 10,287.79 84.58 175.86 3 Halliburton Energy Services ~ }-fALI..IBURTOr~ Planning Report -Geographic - --- Sperry drilling Serviaars Local Co-ordinate Reference: Well Plan 1 J-133 -Slot 1 J-133 TVD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature rtical epth +N/-E +E/-W ft) (ft) (ft) ,511.00 -335.15 344.66 ,668.00 -459.99 463.99 ,997.00 -1,036.65 951.13 ,225.00 -1,791.61 1,556.07 ,898.00 -4,206.20 3,075.91 ,197.00 -5,292.62 3,731.64 ,261.00 -5,525.16 3,872.00 ,435.00 -6,165.33 4,246.58 ,590.00 -6,914.34 4,422.67 ,653.00 -7,270.71 4,448.47 ,673.00 -7,418.91 ( 4,459.20 Name Permafrost T3 K15 T3+ 550 (Surface Casing) Ugnu C Ugnu B Ugnu A K13 WSAK D @ 80 WSAK C WSAK B @ 85 1/17/2006 3.~39:09PM Page 10 o!f 10 \ ~ E_s ~ ~ [ ~; E COMPASS 2003.11 Build 48 __~ it • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-133 1 J-133 Anticollision Summary 17 January, 2006 ~~~ Sperry 1?rl~ng Services Or:!GINAL 0 m N p ~ ~ (//T s ~ o ~ y C ~ ? o N ~ I g E3~Am a A C1nU~K I ~ b y f E g W 9 ~ p Q ~ 9 .d.. F Y O I M ~ o m ~ ~ i n _ ~ yet f ~ ~ f O ~ N °' ~ I c ? w` c t ~ I `o ~ w3 I U N I U I I I o ~ I H; O N I 3 ~ a„ r J i ~ ?~ a o O m ~ J ~ ~ ' H V a ~ rn W _ A 3 ~ a ° ~ ~ °' p o ."qq~ O N ~ W m M _ _ _ _ _ _ _ _ _ _ _ _ a d -- p y ue Vl Q ~ N C ~ L ~ 20 N ;S a u~= 3 + N ° N ~ O z° 3 0 ~ _ ~p m ~ ~ .-. ~ I O / "c a ~ i 3 ° ~ I I ~, ~~" ° ~ 4 n a ~ d~~~ ~ ~~` ~ ~ ~~ H ~ E' A o ~._~.~~_~__ F ~°~e eN.. -4y ~ a oLE~ o ems'- ` ~ ~ ~~. .. a~ rc c \ ~ ..l .- ~ ~0 3 ~1 ~ \ '~ .~ t ~ a N ~ ~~ ~ Y U ~ ' ~ ,~ J ~ yQ G :., ~, ~f ~ ~(. - ~~ L, ~ ",1'. ~ ~ f ~~ W ~ ~ s s ' / _ / i ~ c~ 3 ~ ~ ~ .~ ' * ~,~,', xx 4 O ~N ~ ~ 3 ~ ~~. b 3 ~/ ~ °o / ,~,~ ~ c4~^y i - 1~ 13 ~~ I a~~ '°.x a r O i ~ a , ~ ^ M ~ O r ~/ a ' ~ ~ / o // N N 0 m J 3 6 ~ ~ 3 O O 3 3 3 3 ~ H ~ 1- f H H uoo.o ~nono.~H~a~P~a°oa~na ~.~omno~o neo N eD n aD r~ O~ T l~ O r~ ~ eC h ~oorui~a.io u.ua~rv.=o~oaa~vi~o:~o~o.- n~mwww~omn~~nno<mmm°m~°e'rvn° ~ooooooOmOmoeeooro°n°TOmoNOOo u a°nomo~oomovo ~° .- ~ m m o00 ~ yo°e v°io °o neeeeooooeeeeeeoooeeee ~ oooriaoeoviovieo.ieoi vio.i c.,icrc.,ierc Q a.vamoa w 30 mnry°.^.i~~~^e ~gi~m~ra°.H ~.°-°a`, r. ~o tio. a.., am 00 ~oor~a~•~^a~~d$$$$$$'a 'a 'aaavaaa F ~' N 30 ~ea~N~rono ^°F m °9 °' og ~~°°~° ~~ oho ~Oe°e°o oeeca°m r`"-~°mw°nm^ee~g".~rn~H'''oo°1 ~^ c MMamD~ W mddT tV ea ebid V V V ~nht`~~mm1. ~,. 1.n ~1.~nn N N CQ L _0 O U E 0 `"gin°~r°-°o°o°o °O<°o~~m°w °n .°,mm««'oo -o cv<nnnnmwwmmmmmmma°"o a°ommmmmm ~°o° ovan `O ~vn "'°m m.~wna~n ~onmm~~~~~.-~~~~wwwwwwww O O O O O O O O O O O O O O O O O O O O O O O O ~[1 O N O N N r O N~ I~ O O O O O O O O O N M Q N (OO ~~ N~ I~ ~ ~ ~ ~ N N N N th V~ cD ~ m O~ .- ~ ~ ~ ~ ~ ~ ~ ~ 111111 IIIII 11Illllllll 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o ~n o ~n o u> o ~n o u> o u~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N I~ O~~ t~ O N N I~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ N N N N M O N t0 i~ D1 m O~ N c'1 V u'~ ~p I~ O \, N ~. ~~v\~~ ~ ~, r o „ ~ J ` #.\ ,~ 1 t ~ \_ ~~ x th ° 1 O. ~~;~ ~ ~ ~ 3 ~~\ i .'° , 9 ~ ~. ' , '~ , \ • r ~ ~ ! ~ ` N . ~ ~ l ' ~ 1~ ,~ ~. y Y r" -~ ~ o 3 ~_ ~ ~ ~ y - _ ~` p r : ~ ~ ~ ; 1 ~~'~' ~ - ---- _ , - ~ 1 ~` ~ N .-. _ r ~ ~~' ` \ , G ~ .... _,, , 3 ~ o \ a fl ~ ~ \ . ~ ~ OD N ~ r ~ 7 ~ rY °+ _~ ~ 0 0 vi D O ~~°°~ o~oF vi~o~ Z ~YOY~ 0 'C~R' F ~ i°'~'' z ao~o~ Z 3o°v~iof W d d d d U C C C C r = a,dmd« z ~~~~~ IWi K K R' R' ~ W d' W pm« rt zZ?°3 _ o ~ r A o u U c`-'u y L ~ O ~ N N U ~ ~r-' ~Halliburton Energy Services ~ HA-Lt_tE3tJtr'~TCtN Cf~'tOCOPFIl~IIpS Anticollision Report -~~- ---W------ ~------~~ffi~ ,q~~ Sperry Oriiliing Services Company: CohocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-133 Well Error: O.OOft Reference Wellbore 1J-133 Reference Design: 1J-133 (wp06) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan 1J-133 -Slot 1J-133 Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) True Minimum Curvature 2.00 sigma EDM 2003.T1 Single User Db Reference Datum Reference 1J-133 (wp06) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refers Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,832.48ft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 1/17/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 40.00 800.00 1J-133 (wp06) (1J-133) CB-GYRO-SS Camera based gyro single shot 800.00 16,364.83 1J-133 (wp06) (1J-133) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/17/2006 3:54:57PM Page 2 of 3 COMPASS 2003.118ui1d 4& .+~3 ~ ~ ~ > '~r-' • Halliburton Energy Services ~ ~AL~I~~.~Q CC)f'tOCQPh1~~tpS Anticollision Report -- - ------~- - -~- Alaska Sperry Drilling Serviass Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 Project: Kuparuk River Unit ND Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15.(81+40)) Reference Site: Kuparuk 1 J Pad MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-133 Database: EDM 2003.11 Single User Db Reference Design: 1J-133 (wp06) Offset ND Reference: Reference Datum 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 1J Pad 1J-14 - 1J-14 - 1J-14 657.17 650.00 202.66 12.09 190.57 Pass -Major Risk Plan 1J-103 -Plan 1J-103 - 1J-103 (wp01) BHI 351.97 350.00 620.62 7.34 613.28 Pass -Major Risk Plan 1J-120 -Plan 1J-120 - 1J-120 (wp01) 357.84 350.00 260.68 7.22 253.46 Pass -Major Risk Plan 1J-122 -Plan 1J-122 - 1J-122 (wp02) 404.13 400.00 221.57 8.68 212.90 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1 J-23 E Lat - 1 J-23 345.86 350.00 200.43 7.42 193.01 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 Pilot - 1J-23 F 345.86 350.00 200.43 7.42 193.01 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat - 1J-23 345.86 350.00 200.43 7.42 193.01 Pass -Major Risk Plan 1J-124 -Plan 1J-124 - 1J-124 (wp01) BHI 441.18 450.00 180.94 9.49 171.45 Pass -Major Risk Plan 1J-127 -Plan 1J-127 - 1J-127 (wp02) 359.54 350.00 120.71 7.68 113.03 Pass -Major Risk Plan 1J-127 -Plan 1J-127 L1 - 1J-127 L1 (wp02) 359.54 350.00 120.71 7.68 113.03 Pass -Major Risk Plan 1J-127 -Plan 1J-127 L2 - 1J-127 L2 (vvp02) 359.54 350.00 120.71 7.68 113.03 Pass -Major Risk Plan 1J-129 -Plan 1J-129 - iJ-129 (wp02) 397.31 400.00 81.23 8.64 72.58 Pass -Major Risk Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) 446.94 450.00 61.90 9.72 52.18 Pass -Major Risk Plan 1J-132 -Plan 1J-132 - 1J-132 (wp02) 498.59 500.00 22.11 10.73 11.39 Pass -Major Risk Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) 9,799.95 9,799.96 0.65 3.79 -3.13 FAIL - No Errors Plan 1J-135 -Plan 1J-135 -Plan 1J-135 (wp01) 767.79 750.00 36.10 14.64 21.46 Pass -Major Risk Plan 1J-136 - 1J-136 - 1J-136 (wp03) 466.30 450.00 61.37 10.04 51.34 Pass -Major Risk Plan 1J-136 - 1J-136 L1 - 1J-136 L1 (wp03) 466.30 450.00 61.37 9.82 51.56 Pass -Major Risk Plan 1J-137 - 1J-137 - 1J-137 (wp03) 416.02 400.00 80.34 8.65 71.69 Pass -Major Risk Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp03) 416.02 400.00 80.34 8.65 71.69 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1 J-73 E L 345.68 350.00 217.43 7.42 210.01 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Kuparuk - 1J-73 W L 345.68 350.00 217.43 7.42 210.01 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Pilot - 1J-173 Pilot (v 345.68 350.00 217.43 7.42 210.01 Pass -Major Risk Plan 1J-174 -Plan 1J-174 - 1J-174(vvp01) 310.96 300.00 203.76 6.62 197.15 Pass -Major Risk Plan 1J-176 -Plan 1J-176 - 1J-176 (wp01) 312.10 300.00 177.53 6.21 171.32 Pass -Major Risk Plan 1J-178 -Plan 1J-178 - 1J-178 (wp01) 312.25 300.00 158.48 6.21 152.27 Pass -Major Risk Plan 1J-180 -Plan 1J-180 - 1J-180 (wp01) 312.41 300.00 148.21 6.21 142.00 Pass -Major Risk Plan 1J-182 - 1J-182 - 1J-182 (wp05) 360.97 350.00 148.39 7.70 140.69 Pass -Major Risk Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) 360.97 350.00 148.39 7.49 140.90 Pass -Major Risk Plan 1J-184 - 1J-184 - 1J-184 (wp09) 311.77 300.00 158.36 6.74 151.63 Pass -Major Risk Plan 1J-184 - 1J-184 L1 - 1J-184 L1 (wp09) 311.77 300.00 158.36 6.74 151.63 Pass -Major Risk WSP-06 -WSP-06 -WSP-06 392.90 400.00 222.29 10.15 212.13 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 394.63 400.00 164.67 11.29 153.38 Pass -Major Risk WSP-08 -WSP-08 -WSP-08 411.08 400.00 108.57 11.99 96.58 Pass -Major Risk WSP-09 -WSP-09 -WSP-09 497.70 500.00 54.96 12.70 42.26 Pass -Major Risk WSP-10 -WSP-10 -WSP-10 668.13 650.00 19.55 5.37 14.17 Pass -Major Risk WSP-11 -WSP-11 -WSP-11 907.44 900.00 20.95 6.05 14.91 Pass -Minor 1/10 WSP-12 -WSP-12 -WSP-12 1,066.78 1,050.00 52.71 26.60 26.11 Pass -Minor 1/10 WSP-13 -WSP-13 -WSP-13 1,147.38 1,100.00 87.37 23.33 64.04 Pass -Major Risk WSP-14 -WSP-14 -WSP-14 1,293.38 1,250.00 117.46 27.07 90.39 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/17/2006 3:54:57PM Page 3 of 3 COMPASS 2003.11 Build 48 ~~~ °~ o ~: o ~M O ~~ L 1 r .. Q _~ ~_ ~ _ .N ~ O L = Q~ .~_ Q. 3Ea~~ c O~~' ~ N _ ~ C C N r O ~ ~ ~ r,d ~ ~ r ~ C fN/1 ~ •~ ~ W ~ ~ C ~ ~ ' O 0~ L O ~ ~ ~ a Z ~> fq Q ~/1 I ~ I ~ l __yy~~ 10 ~ (Y 1 2 M M ~ ~ r 1 d+ "7 Q ti / H a_ ' ~ ~ ~ ~, , 3 3r ~ _ M tt .- ~ ~ ~ °o N O O N i r ~ N r Q ~ ~ N r ~ N U N ~ ~ ~ r Lf) ~ : C N ~ ~ '- N t0 d O c0 ~ O ~ N M ~ N r O. N Ch ~ ~ (n~~lf) O Y N J ~ Q o !'' H _ ~MCO(V C ~ ~ ~ (0 ~ ~ Z~Oin ~ _ ~ / G1 d M M 0 M O ~ C~ O M M M~-~ Q. ~~ i ~ 3 Z ~ ~ C OO O coaiv O 7 3~~M ~ Q U ~( OM M ~ R M C. fl - ~ ~ a O(D Q O O O . p~ p 3 YY ~?~ >>owo ~ °D _ ~~ C NOO o N M M ~' d ~ ~ O N d O ` Z ~ N M a n o~ ~ ~~~ 1~-133 ~Iling H ~~ (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate ~ Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low 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 Intermediate Hole Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced • drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment 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 Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud 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, backreamin 1J-133 Drilling Hazards Summary 7/14/2006 10:35 AM CemCADE Preliminary Job Design 13 3/8" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 6/22/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2634207 Mobile: (907) 748-6900 email: martin13@slb:com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,644' MD (1,511' TVD) Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,906' MD. Lead Slurrv Minimum pump time: 270 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1644' - 80') x 3.50 (250% excess) = 2302.4 ft3 0.4206 ft3/ft x (2906' - 1644') x 1.35 (35% excess) = 716.6 ft3 81.5 ft3+2302.4 ft3+716.6 ft3= 3100.5 ft3 3100.5 ft3 / 4.45 ft3/sk = 696.7 sks Round up to 700 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 200 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3706' - 2906') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520.7 ft3 520.7 ft3/ 2.47 ft3/sk = 210.8 sks Round up to 220 sks BHST = 49°F, Estimated BHCT = 65°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 (bbll (mint < Top of Tail at 2,906' MD < 13 3/8", 72.0# casing in 16" OH TD at 3,706' MD (2,225' TVD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 552.2 78.9 112.2 DeepCRETE 6.0 92.9 15.5 127.7 Drop top plug 0.0 0.0 5.0 132.7 Water 5.0 20.0 4.0 136.7 Switch to rig 0.0 0.0 5.0 141.7 Mud 7.0 513.9 73.4 215.1 Slow & bump plug 3.0 9.0 3.0 218.1 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 6/22/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com I I I Previous Csg. < 13 3/8", 72.0# casing at 3,706' MD < Top of Tail at 6,140' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 10,690' MD (3,703' TVD) CemCADE Preliminary Job Design 9-5/8" Intermediate Casing reliminary Job Design based on limited input data. For estimate purposesonly. ~Chlun~beri Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed 4550' MD annular length. Tail Slurry Minimum thickening time: 270 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 4550' x 1.25 (25% excess) = 1781.3 ft3 0.4257 ft3/ft x 80' (Shoe Joint) _ 34.1 ft3 1781.3 ft3 + 34.1 ft3 = 1815.4 ft3 1815.4 ft3/ 2.25 ft3/sk = 806.8 sks Round up to 810 sks BHST = 87°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 75.0 15.0 40.0 DeepCRETE 6.0 323.3 53.9 93.9 Drop top plug 0.0 0.0 5.0 98.9 Water 5.0 20.0 4.0 102.9 Switch to rig 0.0 0.0 5.0 107.9 Mud 7.0 775.5 110.8 218.7 Slow & bump plug 3.0 9.0 3.0 221.7 MUD REMOVAL Recommended Mud Properties: 8.8 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 ? 19-22, TY ? 22-29 Centralizers: Recommend Schedule ?? 6210 - 7010 3 per 2 joints ?? 7010 - 8090 1 per joint ?? 8090 - 8730 3 per 2 joints ?? 9170 - 10610 3 per 2 joints ?? 10610 - 10680 2 per joint !~~4 4 . 0 V D Tubing, Special Drift to +l- 500' MD DB Nipple, set at+/- 500' MD GLM, Camco, 4112" x 1" KBMG 13-3/8" Casing Shoe, ~ GLM, Camco, 4-112" x 1" KBMG 68#, L-80, BTC set ~ 3706' MD, 2225' TVD CMD Sliding Sleeve, cal DB Nipple Tubing String / 4112" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift Locating Seal AaBemdy 4.75" Seal OD 7" % &518"ZXP Liner Top Piker wkh Hokl Downs Casing Sealbore F 4.75" ID Assembly 7" X 9-518" ZXP Liner Top ~- Packer with Hold Downs 7.500" Tieback Ext. ID 6.278" Tool Body ID •~ Casing Sealbore Receptacle 4.75" ID, 5.75" OD 20' Length ~f~ Orienting Profile Automatic Alignment of LEM Positive Latching Collet Indicates Correct Location Seal Bore for Lateral Isolation - 3.688" ID I Access Window h Positive La[eral Access Via ' \ Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.688" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 2' Length 7" X 9-518" ModN'B' HOOK Hancer Seal Bor< Jsa°ID Lateral Entry ModukILEM) OrknBng Profik ConocoPhillips West Sak 9-518" Injector 1 J-133 Dual Lateral Completion B-sand Window 'D' Sand Lateral at 9775' MD, 3590' TVD / St/2" 15.SM, BTC, L-00 Slotted Dner J.833" Drill \~ 3.958" ID /~v` 7" X 9-518" ZXP Liner Top Packer 7" X 9-518" Flex L Liner Hanger 1 Packer Assembly at Liner Hanger +/- 9750' MD Casing Sealbo 4.75" (g u ea«er Nv9nea coos. rnis ao<vment mar nor be br any means ekdronic or mxnanicat inavain9 ana reum.al ayarem now «nown or nereaner mee 3.562" DB Nipple Seal Assembly 4.75" Seal OD 3.875" ID 5712" Bent Jdnt As Planned ri.~ X~{16MR ES Baker Oil Tools With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tod Skiing I nstalled Installed (3.00" Lateral Drift) (2.50" ID Mainbor e Drift) 'GS' Profile for Coil Connector f Running/Retrieving ~ ~ ' (1.00'Length) I Snap lNSnap Out ~ Positive Locatkg ti r Back Pressure Valve Collet (1.60' Length) Lateral Isolation" .~ Flow-Thru SwivN Seals (1.25' Length) tlraulic H ~ Lateral Diverter ~ Ram i ~''~ ~~ y p I.; Disconnect IsolatioN Mainbore' (1.50' Length) Diverter Sleeve ~~ GS Spear ~- (1.50• Length) Lateral Isdaeon ~ I Seals 6.85 n Approz OAL' ~ I 'Jars may be required in highly deviatetl 19' Diverter Length 19' Sleeve Lergth or deep apphwbons Is approx kngthl. 5112" Guide Shoe 5-112" Casing Shoe, 15.5#, L-80 BTCM Set @ 76356' MD, 3622' TVD ~5-133 'B' Sand Lateral 5112" 15.5#, BTC, L-80 Slotted liner Every Other Joint 51/2" Eccentric Guide Shce 9-518" Casing Shoe, 40.0#, L-80 BTC ~ 10690' MD, 3703' TVD (84 deg inc) wnole or in part, in any loan or ,. by any intormarion atonee talon Irom Baker Nu9nea Inc. Eauioment Specifications 7" X 9-518" HOOK Hanger Mainbore Drift: 7.00" inbore Drill, with diverter: 6.25' moral ik, no diverter or LEM: 6.28" Lateral Dri w/diverter, no LEM: 5.12" LaterallM ~ bore Diverter 0D: 8.50" 4-112' ateral Entry odule Mainbore Drift: 3.68" Mainbore Drift, isolation sleeve: 2.50" Lateral ift, cal coil diverter: 3.00" O of Diverter and Sleeve: +/- 3.60" rverter and Sleeve Length: +l- 79' 5-112" Casing Shoe, 15. ,BTCM Set ~ 16365' MD, 36 ' TVD Wesr Bak Dual Lateral Complarlon -Injector JuIY 16, 2008 ,rn ~~ Marc D. Kuck ti"NI01 Ne.: o • • ~ • SHARON K. ALLSUP-DRAKE 1 f49 CONOCOPHItLIPS ATO 4530 / ~ ANCHORAGE AK 99501 DATE ( ~~~ 56-1551/441 ORDER OFE ~/ 1 ~G C.'~ / ~ ~ 15f 1~~ [~ 1 "'~~ C~ ~ /V(.' l~'~ ~, ® ~~~(-~ / / /L~ B ,p, _~ 1/~`~.."t~ccll (( ~ LH-~' ~D~ - D LLARS Lt l`""~ ,.azR. 1PMOt'galnChaSE ~ ~ Valid Up To 5000 Dollars ~ JPMorgan Chase Bank; N.A. Columbus, OH MEMO - ~/ ~:044L~55LL~:528747L907927n'iL49 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~u ~~'' r! 3 3 PTD# Z-~~lo " ld ~o Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) ,Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both welt name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed ~ Well for name of well) until after jCom any Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompany NameZrnust contact the Commission to obtain advance approval of such water well testing program. Rev: !/25!06 C:\j ody\transmittal_checkl ist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL • 490150 _Well Name: KUPARUK RIV U WSAK 1J-133 Program SER Well bore seg ^ PTD#:2061060 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER ! PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ Administration 1 Pe[mitfeeattached____________________________ ______ _________Yes_ ___--_-._ - -- - 2 Lease number appropriate_ _ _ _ _ - _ _ _ _ _ _ _ Yes _ _ _ _ _ -- - - 3 Uniquewell_nameandnumber___________________________- .__._--_Yes_ _____.-___-_-.-_----. ---------------------------------------------------- 4 Well located in a_defnedpool______________________________ _________Yes_ _____KuparukRiver,West_SakOilPool-490150,-gcyernedby 004066--__--__-__-___-__--_ 5 Well located proper distance from drilling unit_boundary- - - - - - - - - - - - - Yes Well is more than_ 500 feet from an external property line. - - - - _ _ - - _ _ ... - - . - - .. - - . - - - ... - - - - 6 Well located proper distance from other wells- _ - - _ - - - Yes _ _ - - - - . CO 4068, Rule 3_ no restrictions as to well spacing exce t that no_ a shall be o _ened in a well closer P PY p 7 Sufficient acreage available in_drillinq unit_ _ - - - - Yes - than 500 feet to_an external_property/ine where ownership_or landownership changes, _ . - - - _ _ _ _ - 8 Ifdeviated,is-wellboreplat_included_________ Yes_ __________________________ - - 9 Operator only affected Party Yes - - - 10 Operator bas.appropriatebondinforce----------- -- -- ----- -------~-Yes- -- - .-...---------..- ._. --- ---- ....-------------- ----- ------ ---- 11 Permit_canbeissuedwjthoutconseruationorder______ _----------- -----_-Yes- _-______-_-__--_-__-_________-_ Appr Date 12 Pe[mitcanbeissuedwithoutadminist(ative_appr_ova-I__-__- --------- --------Yes- __---_--_-----__-__-.__---_--___----_-----__-____-_ SFD 7!2112006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put Ip# in-comments).(F4r- Yes . - - - - - -Area Injection Order No.-26 - - 15 All wells within 1!4_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ .. - . No wells within 114 mile radius. _ _ . - - . - - _ - _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ - - _ -- 16 Pre-produced injector: duratjon ofpre-production Less than 3 mpnths (For service well only) - -Yes - _ - - - - KRU 1J-Pad-injection wellsa[e-typically pre-produced 30-45 days for cleanup-- - - - - - - - - - - - - - - - - - - - - - 17 Nonconven, gas conforms io AS31,05,030~.1.A),(~2.A-D) - , _ - - NA_ ---------------------------------------------------------------------- Engineering 18 Conducto[~tring-provided - Yes 19 Surface-casing.protects all knownUSDWs_-_--_--------------- _-_--_-NA__ __-__Allaquifersexempted40CFR147.102(b)(3),_________-___--__--_____-_--__--__-__ 20 CMT_voladequate_tocirculate.onconductor&surf_csg________________ ________Yes- _-_---_----_____--_-.--_ _-_______--__ __ __--_---_-----_____--_--_---__ 21 CMT_vol adeguate_to tie-in long string to surf csg- - - - - - - - - - - - - - - No_ All hydrocarbons to_ be_covered. Annular_disposal_may be-proposed: - _ - - _ - - - _ - . _ - - 22 CMT_willcoverallknown_p[oductiyehonzons_-_-_______--_ _---__-No_- -__-..Slottedliner completion planned____________________________________ ___ 23 Casing designs adequate for C,TB&_permafrost__---,---- Yes- ------------------- ------------------.------------------------------ 24 Adequate tankage_o_r reserve pit - - - - _ _ - - - -Yes - _ _ _ - . -Rig js_equipped with steel-pits.. No- reserve_pRplanned, All waste to approved annulus_or disposal wel_L_ 25 IF_a_re-drill, has-a-10.403 for abandonment been approved - - - - - - - - - - - - - - - - - - - - NA- - - - -- - 26 Adequate wellbore separatjon.p[opgsed- - - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - -Yes . _ - . - ..Proximity analysis perfom?ed: Traveling cylinder plot_ineluded. _ Gyros_possible. _ - - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ - - _ 27 If diverterrequired,doesitmeetregulations-------------_-_--____ ____-__Yes- ____________________- -- - - - - - Appr Date 28 Drilling flujd-program schematic & equip list adequate- - - - - - ---- - - - Yes Maximum expected formation pressure 8,6_EMW._ Planned MW up ko-9,0 ppg, _ - - _ - - _ _ _ _ _ _ _ _ - - _ _ - - _ TEM 7!2512006 29 BOPEs,_do they meet_regulation - - - Yes - - - - - - - - 30 BOPS-press rating appropriate; test to_(put psig in comments)- - ... - . - - - . Yes - MASP calculated at 1270 psi. 3K eguipment set up and test press_ure_planned- - - - - - - - - - - - - - - - - - - - - 31 Choke_manifoldcomplieswlAPI_RP-53(M_ay84)____________________ ________YeS_ --_--_ 32 Work willoccurwithoutoperationshutdown----------------------- --------Yes- --__---___-__--_--_.--__-._ 33 Ispresence_ofH2Sgas-probable--------------------------- --------jJo__ -_---H2Shasn9tbeenrep4rtedon1Jpad,.--..--.----__________------------_- -- 34 Mechanical condition of wells within AOR verified (Forservice well onlya - - - - - . - _ - - - Yes - There are no wells within 114 _m_ile of_this well in the West Sek, _ - _ _ _ - - - . - - Geology 35 Permitcan be issued w/o hydrogen-sulfide measures - _ - _ - _ - - - Yes No H2S has been measured in_W._ Sak weI_Isdrilled-to the south from 1J-Pad- - - - - - - - - - - - - - - - - - - - - - - ,36 Data_presented on potential overpressure zones _ _ Yes - - - _ _ - _ Expected [es.-pressure is 8,6_ppg EMW; will be drilled with 9.0 ppg oil-based_ mud. Mud weight will be Appr Date 37 Seismic analysis of shallow gas zones- - - - - - - - - - - - ----- - - - - - NA_ adjusted as needed. Hydrates may be encountered; mud program notes use of up to 9.6 ppg. mud- if this occurs, SFD 7121/2006 38 Seabed condition survey_(ifofl-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ Mud program notes use of 9.6 ppg mud_ if hydrates are_encounte[ed, - _ _ . - _ _ 39 Contact namelphone for weekly_progress reports [exploratory only] - - - - - - - - - - - - - - - - NA_ _ - - _ _ - - _ - . _ Geologic Engineering P ~ Date: Date Date West Sak B Sand in ector I Commissioner: Commissioner: C missio • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efforl has been made io chronologically organize this category of information. • • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Oct 25 09:53:09 2006 Reel Header Service name .............LISTPE Date .....................06/10/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date.... ...............06/10/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 W-0004528227 P. ORTH M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1J-133 500292331500 ConocoPhillips Alaska, Inc. Sperry Drilling Services 25-OCT-06 MWD RUN 5 W-0004528227 T. GALVIN M. THORNTON 35 11N l0E 1622 2296 109.00 81.00 ~~ - /b~ ~ Kiaaa • WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3719.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 3 AND 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). MWD RUN 3 ALSO INCLUDED GEO-PILOT ROTARY-STEERABLE BHA (GP) NO DATA WERE ACQUIRED DURING MWD RUN 4 DUE TO A TOOL FAILURE. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-5 REPRESENT WELL 1J-133 WITH API#:50-029-23315-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10878'MD/3716'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 (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC • • ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12.25" BIT MUD WEIGHT: 8.9-9.3 PPG MUD SALINITY: 200 PPM CHLORIDES FORMATION WATER SALINITY: 5000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE s File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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 NPHI 3700.0 10768.0 NCNT 3700.0 10768.0 RPS 3700.0 10818.0 FCNT 3700.0 10768.0 RPD 3700.0 10818.0 FET 3700.0 10818.0 RPM 3700.0 10818.0 RPX 3700.0 10818.0 GR 3701.0 10826.0 RHOB 3717.5 10785.0 DRHO 3717.5 10785.0 PEF 3717.5 10785.0 ROP 3736.5 10878.5 s BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH s MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 3700.0 9793.0 5 9793.0 10878.5 • • REMARKS: MERGED MAIN PASS. 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 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 FONT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3700 10878.5 7289.25 14358 3700 10878.5 FCNT MWD CNTS 601.99 6823.52 1151.95 14137 3700 10768 NCNT MWD CNTS 134338 285293 179920 14137 3700 10768 RHOB MWD G/CM 0.578 2.999 2.1554 14136 3717.5 10785 DRHO MWD G/CM -1.75 0.787 0 .0626085 14136 3717.5 10785 RPD MWD OHMM 1.21 2000 13.9728 14237 3700 10818 RPM MWD OHMM 5.09 2000 13.3652 14236 3700 10818 RPS MWD OHMM 1.45 1572.46 12.5562 14236 3700 10818 RPX MWD OHMM 1.6 64.34 11.1635 14236 3700 10818 FET MWD HOUR 0.06 81 1.25184 14237 3700 10818 GR MWD API 17.99 139.05 76.9565 14251 3701 10826 PEF MWD BARN 0.02 7.68 1.73713 14136 3717.5 • • 10785 ROP MWD FT/H 0.12 1227.72 293.935 14285 3736.5 10878.5 NPHI MWD PU-S 3.77 98.39 33.5616 14137 3700 10768 First Reading For Entire File..........3700 Last Reading For Entire File...........10878.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation .......06/10/25 Maximum Physical R ecord..65535 File Type ......... .......LO Previous File Name .......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log hea der data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 3700.0 9749.5 FET 3700.0 9750.0 RPX 3700.0 9749.5 NPHI 3700.0 9699.0 FCNT 3700.0 9699.0 RPM 3700.0 9749.5 RPD 3700.0 9750.0 NCNT 3700.0 9699.0 GR 3701.0 9757.0 PEF 3717.5 9716.0 DRHO 3717.5 9716.0 RHOB 3717.5 9716.0 ROP 3736.5 9793.0 LOG HEADER DATA DATE LOGGED: 07-AUG-06 SOFTWARE • • SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9793.0 TOP LOG INTERVAL (FT) 3736.0 BOTTOM LOG INTERVAL (FT) 9793.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.1 MAXIMUM ANGLE: 80.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124274 EWR4 ELECTROMAG. RESIS. 4 78633 CTN COMP THERMAL NEUTRON 10658563 ALD Azimuth. Litho-Den 10718130 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3719.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 56.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.370 93.2 MUD FILTRATE AT MT: 3.400 75.0 MUD CAKE AT MT: 2.400 75.0 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 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 • • FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 3700 9793 6746.5 12187 9793 FCNT MWD030 CNTS 601.99 2859.8 1102.44 11999 9699 NCNT MWD030 CNTS 134338 215203 177954 11999 9699 RHOB MWD030 G/CM 0.578 2.661 2.14118 11998 9716 DRHO MWD030 G/CM -1.75 0.253 0.0498176 11998 9716 RPD MWD030 OHMM 1.21 2000 13.1029 12101 9750 RPM MWD030 OHMM 5.14 2000 12.4187 12100 9749 .5 RPS MWD030 OHMM 1.45 1572.46 11.618 12100 9749 .5 RPX MWD030 OHMM 1.6 58.82 10.3387 12100 9749 .5 FET MWD030 HOUR 0.06 81 1.05549 12101 9750 GR MWD030 API 17.99 139.05 75.7287 12113 9757 PEF MWD030 BARN 0.02 7.68 1.7453 11998 9716 ROP MWD030 FT/H 0.12 1227.72 308.151 12114 9793 NPHI MWD030 PU-S 9.52 98.39 34.2398 11999 9699 First Reading For Entire File..........3700 Last Reading For Entire File...........9793 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/25 Maximum Physical Record..65535 File Type ................LO First Reading 3700 3700 3700 3717.5 3717.5 3700 3700 3700 3700 3700 3701 3717.5 3736.5 3700 • 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.......06/10/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 9699.5 NCNT 9699.5 FONT 9699.5 RHOB 9716.5 DRHO 9716.5 PEF 9716.5 RPM 9750.0 RPX 9750.0 RPS 9750.0 RPD 9750.5 FET 9750.5 GR 9757,5 ROP 9793.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10768.0 10768.0 10768.0 10785.0 10785.0 10785.0 10818.0 10818.0 10818.0 10818.0 10818.0 10826.0 10878.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den 09-AUG-06 Insite 66.37 Memory 10878.0 9793.0 10878.0 79.3 89.5 TOOL NUMBER 124274 78633 10507496 10718128 • 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 Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FCNT MWD050 NCNT MWD050 RHOB MWD050 DRHO MWD050 RPD MWD050 RPM MWD050 RPS MWD050 RPX MWD050 FET MWD050 GR MWD050 PEF MWD050 ROP MWDO50 NPHI MWD050 12.250 3719.0 Lignosulfanate 9.20 54.0 9.3 100 4.4 2.900 75.0 2.560 86.0 3.400 75.0 2.400 75.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 CNTS 4 1 68 4 2 CNTS 4 1 68 8 3 G/CM 4 1 68 12 4 G/CM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 OHMM 4 1 68 28 8 OHMM 4 1 68 32 9 HOUR 4 1 68 36 10 API 4 1 68 40 11 BARN 4 1 68 44 12 FT/H 4 1 68 48 13 PU-S 4 1 68 52 14 First Last • • Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9699.5 10878.5 10289 2359 9699.5 10878.5 FCNT MWD050 CNTS 707.2 6823.52 1429.84 2138 9699.5 10768 NCNT MWD050 CNTS 152105 285293 190954 2138 9699.5 10768 RHOB MWD050 G/CM 1.796 2.999 2.23522 2138 9716.5 10785 DRHO MWD050 G/CM -0.076 0.787 0.134389 2138 9716.5 10785 RPD MWD050 OHMM 5.61 54.12 18.9012 2136 9750.5 10818 RPM MWD050 OHMM 5.09 62.17 18.7222 2137 9750 10818 RPS MWD050 OHMM 4.87 74.87 17.8672 2137 9750 10818 RPX MWD050 OHMM 4.72 64.34 15.8324 2137 9750 10818 FET MWD050 HOUR 0.22 37.52 2.36419 2136 9750.5 10818 GR MWD050 API 43.82 125.05 83.9128 2138 9757.5 10826 PEF MWD050 BARN 0.66 3.63 1.69127 2138 9716.5 10785 ROP MWD050 FT/H 4.07 632.78 214.612 2171 9793.5 10878.5 NPHI MWD050 PU-S 3.77 89.82 29.7552 2138 9699.5 10768 First Reading For Entire File..........9699.5 Last Reading For Entire File...........10878.5 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/10/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE .7 Date .....................06/10/25 Origin ...................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 i Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 14 13:18:02 2006 Reel Header Service name ....... ......LISTPE Date ............... ......06/09/14 Origin ............. ......STS Reel Name .......... ......UNKNOWN Continuation Number ......01 Previous Reel Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Tape Header Service name ....... ......LISTPE Date ............... ......06/09/14 Origin ............. ......STS Tape Name .......... ......UNKNOWN Continuation Number ......01 Previous Tape Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Physical EOF' Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: W-0004528227 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-133 500292331500 ConocoPhillips Alaska, Inc. Sperry Drilling Services 14-SEP-06 MWD RUN 5 W-0004528227 T. GALVIN M. THORNTON 35 11N l0E 1622 2296 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3719.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE ao(~ ~o~ ~ <<,,xa • PRESENTED. 4. MWD RUNS 3 AND 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL) MWD RUN 3 ALSO INCLUDED GEO-PILOT ROTARY-STEERABLE BHA (GP) NO DATA WERE ACQUIRED DURING MWD RUN 4 DUE TO A TOOL FAILURE. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-5 REPRESENT WELL 1J-133 WITH API#:50-029-23315-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10878'MD/3716'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 (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12.25" BIT MUD WEIGHT: 8.9-9.3 PPG MUD SALINITY: 200 PPM CHLORIDES FORMATION WATER SALINITY: 5000 PPM CHLORIDES FLUID DENSITY:. 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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 STARS DEPTH STOP DEPTH NPHI 3700.0 10768.0 NCNT 3700.0 10768.0 RPS 3700.0 10818.0 FCNT 3700.0 10768.0 RPD 3700.0 10818.0 FET 3700.0 10818.0 RPM 3700.0 10818.0 RPX 3700.0 10818.0 GR 3701.0 10826.0 RHOB 3717.5 10785.0 DRHO 3717.5 10785.0 PEF 3717.5 10785.0 ROP 3736.5 10878.5 C~ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3700.0 9793.0 MWD 5 9793.0 10878.5 REMARKS: MERGED MAIN PASS. 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 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 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3700 10878.5 7289.25 14358 3700 10878.5 FCNT MWD CNTS 601.99 6823.52 1151.95 14137 3700 10768 NCNT MWD CNTS 134338 285293 179920 14137 3700 10768 RHOB MWD G/CM 0.578 2.999 2.1554 14136 3717.5 10785 DRHO MWD G/CM -1.75 0.787 0.0626085 14136 3717.5 10785 RPD MWD OHMM 1.21 2000 13.9728 14237 3700 10818 RPM MWD OHMM 5.09 2000 13.3652 14236 3700 10818 RPS MWD OHMM 1.45 1572.46 12.5562 14236 3700 10818 RPX MWD OHMM 1.6 64.34 11.1635 14236 3700 10818 FET MWD HOUR 0.06 81 1.25184 14237 3700 10818 GR MWD API 17.99 139.05 76.9565 14251 3701 10826 PEF MWD BARN -0.12 7.68 1.73704 14136 3717.5 10785 ROP MWD FT/H 0.12 1227.72 293.935 14285 3736.5 10878.5 NPHI MWD PU-S 3.77 98.39 33.5616 14137 3700 10768 First Reading For Entire File..........3700 Last Reading For Entire File...........10878.5 File Trailer Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Next File Name........, STSLIB.001 1.0.0 06/09/14 65535 LO STSLIB.002 Physical EOF File Header Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/09/14 Maximum Physical Record..65535 File Type .............. ..LO 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 3700.0 9749.5 FET 3700.0 9750.0 RPX 3700.0 9749.5 NPHI 3700.0 9699.0 FONT 3700.0 9699.0 RPM 3700.0 9749.5 RPD 3700.0 9750.0 NCNT 3700.0 9699.0 GR 3701.0 9757.0 PEF 3717.5 9716.0 DRHO 3717.5 9716.0 RHOB 3717.5 9716.0 ROP 3736.5 9793.0 LOG HEADER DATA DATE LOGGED: 07-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9793.0 TOP LOG INTERVAL (FT) 3736.0 BOTTOM LOG INTERVAL (FT) 9793.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.1 MAXIMUM ANGLE: 80.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124274 EWR4 ELECTROMAG. RESIS. 4 78633 CTN COMP THERMAL NEUTRON 10658563 ALD Azimuth. Litho-Den 10718130 s 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 Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 12.250 3719.0 Lignosulfonate 9.00 56.0 9.7 200 4.6 s 2.900 75.0 2.370 93.2 3.400 75.0 2.400 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FONT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3700 9793 6746.5 12187 3700 9793 FCNT MWD030 CNTS 601.99 2859.8 1102.44 11999 3700 9699 NCNT MWD030 CNTS 134338 215203 177954 11999 3700 9699 RHOB MWD030 G/CM 0.578 2.661 2.14118 11998 3717.5 9716 DRHO MWD030 G/CM -1.75 0.253 0.0498176 11998 3717.5 9716 RPD MWD030 OHMM 1.21 2000 13.1029 12101 3700 9750 RPM MWD030 OHMM 5.14 2000 12.4187 12100 3700 9749.5 RPS MWD030 OHMM 1.45 1572.46 11.618 12100 3700 9749.5 RPX MWD030 OHMM 1.6 58.82 10.3387 12100 3700 9749.5 FET MWD030 HOUR 0.06 81 1.05549 12101 3700 9750 GR MWD030 API 17.99 139.05 75.7287 12113 3701 9757 PEF MWD030 BARN -0.12 7.68 1.7452 11998 3717.5 9716 ROP MWD030 FT/H 0.12 1227.72 308.151 12114 3736.5 9793 NPHI MWD030 PU-S 9.52 98.39 34.2398 11999 3700 9699 First Reading For Entire File..........3700 Last Reading For Entire File...........9793 File Trailer Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/09/14 Maximum Physical Record..65535 File Type .............. ..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..... ..06/09/14 Maximum Physical Record..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 9699.5 10768.0 NCNT 9699.5 10768.0 FCNT 9699.5 10768.0 RHOB 9716.5 10785.0 DRHO 9716.5 10785.0 PEF 9716.5 10785.0 RPM 9750.0 10818.0 RPX 9750.0 10818.0 RPS 9750.0 10818.0 RPD 9750.5 10818.0 FET 9750.5 10818.0 GR 9757.5 10826.0 ROP 9793.5 10878.5 LOG HEADER DATA DATE LOGGED: 09-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10878.0 TOP LOG INTERVAL (FT) 9793.0 BOTTOM LOG INTERVAL (FT) 10878.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.3 MAXIMUM ANGLE: 89.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124274 EWR4 ELECTROMAG. RESIS. 4 78633 CTN COMP THERMAL NEUTRON 10507496 ALD Azimuth. Litho-Den 10718128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 • 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 Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3719.0 Lignosulf onate 9.20 54.0 9.3 100 4.4 2.900 75. 0 2.560 86. 0 3.400 75. 0 2.400 75. 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWDO50 CNTS 4 1 68 4 2 NCNT MWDO50 CNTS 4 1 68 8 3 RHOB MWDO50 G/CM 4 1 68 12 4 DRHO MWDO50 G/CM 4 1 68 16 5 RPD MWDO50 OHMM 4 1 68 20 6 RPM MWDO50 OHMM 4 1 68 24 7 RPS MWDO50 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWDO50 HOUR 4 1 68 36 10 GR MWDO50 API 4 1 68 40 11 PEF MWDO50 BARN 4 1 68 44 12 ROP MWDO50 FT/H 4 1 68 48 13 NPHI MWDO50 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9699.5 10878.5 10289 2359 9699.5 10878.5 FONT MWDO50 CNTS 707.2 6823.52 1429.84 2138 9699.5 10768 NCNT MWDO50 CNTS 152105 285293 190954 2138 9699.5 10768 RHOB MWDO50 G/CM 1.796 2.999 2.23522 2138 9716.5 10785 DRHO MWDO50 G/CM -0.076 0.787 0.134389 2138 9716.5 10785 RPD MWDO50 OHMM 5.61 54.12 18.9012 2136 9750.5 10818 RPM MWDO50 OHMM 5.09 62.17 18.7222 2137 9750 10818 RPS MWDO50 OHMM 4.87 74.87 17.8672 2137 9750 10818 RPX MWDO50 OHMM 4.72 64.34 15.8324 2137 9750 10818 FET MWDO50 HOUR 0.22 37.52 2.36419 2136 9750.5 10818 GR MWDO50 API 43.82 125.05 83.9128 2138 9757.5 10826 PEF MWDO50 BARN 0.66 3.63 1.69127 2138 9716.5 10785 ROP MWDO50 FT/H 4.07 632.78 214.612 2171 9793.5 10878.5 NPHI MWDO50 PU-S 3.77 89.82 29.7552 2138 9699.5 10768 First Reading For Entire File..........9699.5 Last Reading For Entire File...........10878.5 J • • File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/09/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/09/14 Origin ...................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