Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
201-220
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-02-13_22583_KRU_1C-135_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22583 KRU 1C-135 50-029-23053-00 Caliper Survey w/ Log Data 13-Feb-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 201-220 T38520 2/21/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.21 09:58:22 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-02-12_22582_KRU_1C-135_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22582 KRU 1C-135 50-029-23053-00 Coil Flag 12-Feb-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 201-220 T38510 2/16/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.16 12:49:32 -09'00' 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 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?N/A Yes No 9. Property Designation (Lease Number):10. Field: N/A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,700'11,544' Casing Collapse Conductor Surface Scab Liner 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng SSSV: 516' MD / 515' TVD - Packer: 7,173 MD / 3,757' TVD Perforation Depth MD (ft): 7,273' - 11,670' 7,159' 4 1/2" 3,765' - 3,753' 4/1/2024 11,670'4,511' 3 1/2" 3,753' 3,758'5 1/2" Tubing Grade: Packer: BAKER SC1-R 76B2-40 PACKER SSSV: CAMCO 2.875" DS NIPPLE 16" 7 5/8" 82' 7,252' 7,188' 117' 3,766' 117' 7,285' ConocoPhillips Alaska, Inc Length Size Proposed Pools: L-80 TVD Burst 7,126' MD Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025649 / ADL0025650 201-220 P.O. Box 100360, Anchorage, Alaska 99510 5002923053-0000 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7,207' & 7,156' Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Brennen Green / Roger Mouser N1927@conocophillips.com 907-943-1055 W.I. Field Supervisor Other: SC Repair KUPARUK RIV U WSAK 1C-135 KUPARUK RIVER WEST SAK OIL 3,753' m n P 2 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-087 By Kayla Junke at 2:24 pm, Feb 15, 2024 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.02.15 07:25:05-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green VTL 02/21/2024 X 10-404 50-029-23053-00-00 SFD SFD 2/23/2024 DSR-2/15/24 X Photo document all steps of repair. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.02.26 11:38:22 -09'00'02/26/24 RBDMS JSB 022724 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 15 February 2024 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval from ConocoPhillips Alaska, Inc. for well KRU 1C-135 (PTD 201-220) to repair the surface casing leak that is estimated to be at 63”. Please contact me or my alternate, Roger, at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E= n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2024.02.15 07:25:35-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. KUPARUK WELL 1C-135 (PTD 201-220) SUNDRY NOTICE 10-403 APPROVAL REQUEST February 15, 2024 This application for Sundry approval for Kuparuk well 1C-135 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow (~63”). ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps (with photo documentation): 1. Secure the well as needed with mechanical plug in the tubing. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to ~24’. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to Injection. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:11,366.0 1C-135 9/2/2003 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SECURE W/ RBP @ 7158' ME, CLOSE CMU'S @ 7046' & 7151' 1C-135 2/14/2024 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: 6'4" Surf CSG patch, from mandrel hanger, 9 5/8" API 40, .395 wall 1/23/2007lmosbor Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 35.0 117.0 117.0 62.50 api5L0B Welded SURFACE 7 5/86.8732.77,285.2 3,766.1 29.70 L-80 BT&C SCAB LINER 2013 5 1/2 4.95 29.1 7,188.0 3,758.3 15.50 L-80 IBTM LINER 2001 4 1/2 3.96 7,159.1 11,670.0 3,753.1 12.60 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.5 Set Depth … 7,126.0 Set Depth … 3,750.0 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT-ABM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.15HANGER 10.812 VECO GRAY TUBING HANGER CWCT-F6H TBPV 4" Type "H" Vetco Gray CWCT- F6H 3.938 516.4 514.8 8.22 NIPPLE 4.520 CAMCO 2.875" DS NIPPLE Camco "DS" 2.875 7,046.83,735.1 77.25 SLEEVE C 4.180 BAKER CMU SLIDING SLEEVE, Closed 12/10/23 Baker "CMU"2.812 7,087.63,743.4 79.22 XO - Reducing 3.500 3-1/2", 9.3#, L-80, IBT AB Modified Box x 2-7/8 EUE 8rd Pin Crossover 2.441 7,097.4 3,745.2 79.66 GAUGE4.825 BAKER DOWNHOLE GAUGE CARRIER CentriliftPG0413 57700 2.441 7,107.23,746.980.06 LOCATOR4.220 BAKER GBH-22 LOCATOR SUB w/3' SPACEOUT Baker GBH-22 80-40 2.990 7,108.03,747.080.09 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSEMBLY Baker H02- 67262- 06 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,155.93,754.5 82.22 RBP 2-7/8" PARAGON II PARAG ON CPP2 87059 2/13/2024 0.000 7,199.03,759.5 84.38 FISHTWO 2-7/8" PARAGON II CENTER PACKER ELEMENTS 2/12/2024 0.000 7,206.93,760.284.65 IBP RETRIEVABLE BRIDGE PLUG. 1.375" JDC FN. 2.13" OD ELEMENT BAKER 00025 01- 000 12/16/2023 0.000 11,544.03,755.5 90.58 FISH 2.31" XX PLUG PUSHED TO 11,544' CTMD 4/20/2013 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,133.6 3,751.2 81.11 XO - Reducing 3.500 3-1/2", 9.3#, L-80, 8rd EUE-AB Mod Box x 2-7/8", 6.5#, L-80 8rd EUE-AB Mod Pin Crossover 2.440 7,151.13,753.881.96 SLEEVE-C3.690 BAKER CMU w/BX PROFILE Closed 2/14/24 Baker H810-79- 3842 2.310 7,175.4 3,756.983.29 XO THREAD 3.760 2-7/8",6.5#, L-80 8rd EUE-AB Mod Box x 3-1/2", 9.3#, L-80, 8rd EUE-AB Mod Pin Crossover 2.380 7,176.9 3,757.1 83.38 LOCATOR 4.220 BAKER GBH-22 LOCATOR SUB Baker 80 -40 H03-35339- 00 2.990 7,172.6 3,756.6 83.14 PACKER 5.090 BAKER SC1-R 76B2-40 PACKER 4.000 7,177.4 3,757.2 83.40 MILLOUT 5.500 MILLOUT EXTENSION 5.000 7,197.9 3,759.3 84.34 XO Reducing 5.500 CROSSOVER 5.5 x 4.5 4.500 7,228.5 3,762.1 85.41 SLEEVE-C 5.900 BAKER CMD NON-ELASTOMER SLIDING SLEEVE w/DS PROFILE - CLOSED 3.430 7,233.13,762.4 85.57 XO Reducing 4.500 CROSSOVER 4.5 x 44.000 7,265.5 3,764.886.11 XO Increase 4.000 CROSSOVER 4 x 4.5 4.500 11,614.93,753.991.04XO Reducing 4.500 CROSSOVER 4.5x4" 4.000 11,648.23,753.4 90.86 XO Increase 4.000 CROSSOVER 4x5" 5.000 11,648.93,753.4 90.86 XO Reducing 5.000 CROSSOVER 5x3.5"3.500 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,273.0 11,670.0 3,765.3 3,753.1 WS D, 1C-135 12/20/2001 99.0 SLOTS Perfs thru slotted liner 1C-135, 2/15/2024 7:21:23 AM Vertical schematic (actual) LINER 2001; 7,159.1-11,670.0 SHOE; 11,668.5-11,670.0 FISH; 11,544.0 SLOTS; 7,273.0-11,670.0 SURFACE; 32.7-7,285.2 FLOAT SHOE; 7,283.7-7,285.2 SLEEVE-C; 7,228.5-7,233.1 IBP; 7,206.9 FLOAT COLLAR; 7,199.8- 7,201.1 SCAB LINER 2013; 29.1- 7,188.0 MILLOUT; 7,177.4-7,197.1 SEAL ASSY; 7,177.7-7,188.0 LOCATOR; 7,176.9-7,177.7 PACKER; 7,172.6-7,177.4 LINER RUNNING TOOL; 7,161.1-7,172.6 RBP; 7,155.9 SLEEVE-C; 7,151.1-7,155.2 SBE; 7,113.6-7,132.4 SEAL ASSY; 7,107.9 LOCATOR; 7,107.1 GAUGE; 7,097.4 SLEEVE C; 7,046.8 PORT COLLAR; 1,011.4-1,013.8 NIPPLE; 516.4 CONDUCTOR; 35.0-117.0 HANGER; 32.7-36.0 HANGER; 29.1-33.4 HANGER; 25.5 Capillary String; 0.000 KUP PROD KB-Grd (ft) 34.99 RR Date 12/20/200 1 Other Elev… 1C-135 ... TD Act Btm (ftKB) 11,700.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292305300 Wellbore Status PROD Max Angle & MD Incl (°) 93.63 MD (ftKB) 8,037.60 WELLNAME WELLBORE Annotation Last WO: End Date 4/4/2013 H2S (ppm) 240 Date 8/12/2016 Comment SSSV: Nipple C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-12-16_23005_KRU_1C-135_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23005 KRU 1C-135 50-029-23053-00 Coil Flag 16-Dec-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 201-220 T38257 1/5/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.05 14:21:51 -09'00' . RECEIVED STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMPSION DEC 1 1 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ RPPG D MBE TrtmtE 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 201-220 3.Address: P. O. Box 100360,Anchorage, Stratigraphic❑ Service ❑ 6.API Number: Alaska 99510 50-029-23053-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1C-135 ADK 25649,ADL 25650 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,700 feet Plugs measured None feet true vertical 3,753 feet Junk measured 11544 feet Effective Depth measured 11,668 feet Packer measured 7,173 feet true vertical 3,753 feet true vertical 3,757 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 feet 16 " 117' MD 117 TVD SURFACE 7,253 feet 7 5/8" 7,285' MD 3766 TVD SCAB LINER 7,159 feet 5 1/2 " 7,188' MD 3758 ND 1 0112 Perforation depth Measured depth 7273-1.1674g- 116,7/3 eet True Vertical depth 3765-3753 feet Tubing(size,grade,measured and true vertical depth) 3.5" L-80 7,126' MD 3,750'TVD Packers and SSSV(type,measured and true vertical depth) PACKER= BAKER SC1-R 7662-40 7,173'MD 3,757'ND SSSV: = NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: SCANNED AN 2 4 2fUg 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 447 148 197 — 259 Subsequent to operation: Shut-In — — — — 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development El Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 317-381 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr.Wells Engineer If: 12/11/L7 Contact Phone: (907)265-6471 Authorized Signature: W - -' Date: 12Ii i/L7 Form 10-404 Rev ed 4/201! ,.� A�_ ` v M. Submit Original Only A Vrt 1/7 //f R .7AS U L., ; i, ,dial/ • • • IC- 190 - IC- 135 RPPG D MBE TREATMENT DTTMSTAJOBTYP SUMMARYOPS 11/2/17 MISC. RIH WITH GAMMA RAY, CCL, E-FIRE AND 5' GUN, LOG CAPACITY FROM 8650'TO 8450' CORRECT DEPTH TO 8653.55', SUSTAINMENT PICK UP TO 8496.8' RKB, SHOOT FROM 8500'-8505' RKB, POOH CONFIRM GUNS FIRED. RDMO JOB COMPLETE. 11/11/17 MISC. Performed full-bore RPPG treatment pumping 213 bbls of CAPACITY —0.75 ppg RPPG placing 6776#of RPPG into formation SUSTAINMENT followed by 55 lbs of crystal seal. Displaced with 5 bbls seawater, 120 bbl diesel. KUP ilOD 1C-135 Con©coPhillips 4 Well Attrib Max Angle D TD Alaska..crit: Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cuv,,,d4PFIUhps 500292305300 WEST SAK PROD 93.63 8,037 60 11,700.0 .,.., Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 10-135,12111/201711 52 57 AM SSSV:Nipple 240 8/12/2016 Last WO: 4/4/2013 34.99 12/20/2001 Verpral.sdwmadc iaowa)). Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 11,366.0 9/2/2003 Rev Reason:OPENED CMU,PULL SLIP-STOP pproven 11/13/2017 8 10B-JET PUMP,SET SLIP-STOP 8 8B-JET HANGER,25.5 I Casing Strings II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 117.0 117.0 62.50 api5LOB Welded Li Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...°Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 32.7 7,285.2 3,766.1 29.70 L-80 BTBC 1i �k Casing Description (in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I.. Grade Top Thread : SCAB LINER 2013 5 1/2 4.950 29.1 7,188.0 3,758.3 15.50 L-80 IBTM k Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) I 29.1 29.1 0.18 HANGER 5-1/2 x 11"CASING MANDREL HANGER 4.950 ti 1 ,� 7,113.6 3,748.0 80.31 SBE BAKER 20'80-40 SBE 4.000 CONDUCTOR;35.0-117.0 ► 7,133.6 3,751.2 81.11 XO-Reducing 3-1/2",9.30,L-80,8rd EUE-AB Mod Box x 2-7/8", 2.440 i 6.5#,L-80 8rd EUE-AB Mod Pin Crossover j 7,151.1 3,753.8 81.96 SLEEVE-C BAKER CMU w/BX PROFILE 2.310 NIPPLE;516.4 (CMU POSSIBLY PARTIALLY CLOSED-OPENED 9/3/2017) 7,176.9 3,757.1 83.38 LOCATOR BAKER GBH-22 LOCATOR SUB 2.990 7,177.7 3,757.2 83.42 SEAL ASSY BAKER 20'SEAL ASSEMBLY(ALL SEAL SUBS) 2.990 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread • LINER 2001 41/2 3.958 7,159.1 11,670.0 3,753.1 12.60 SLHT Liner Details SLIP STOP;7,098.0Nominal ID ,ea Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SLEEVE;7,048. JET PUMP;7,047.0 l-\e 1 7,172.6 3,756.6 83.14 PACKER BAKER SC1-R 7662-40 PACKER 4.000 ® 7,177.4 3,757.2 83.40 MILLOUT MILLOUT EXTENSION 5.000 It 7,197.9 3,759.3 84.34 XO Reducing 'CROSSOVER 5.5 x 4.5 4.500 1 7,228.5 3,762.1 85.41 SLEEVE-C BAKER CMD NON-ELASTOMER SLIDING SLEEVE 3.430 'TI w/DS PROFILE-CLOSED I 7,233.1 3,762.4 85.57 XO Reducing CROSSOVER 4.5 x 4 4.000 GAUGE;7,097.4 ow.. 7,265.5 3,764.8 86.11 XO Increase CROSSOVER 4 x 4.5 4.500 11,614.9 3,753.9 91.04 XO Reducing CROSSOVER 4.5x4" 4.000 it 11,6482 3,753.4 90.86 XO Increase CROSSOVER 4x5" 5.000 LOCATOR;7,107.1 MIK 11,648.9 3,753.4 90.86'XO Reducing CROSSOVER 5x3.5" 3.500 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection SEAL ASSY;7,1079 ri ar ?, TUBING WO 31/2 2.992 25.5 7,126.0 3,750.0 9.30 L-80 IBT-ABM Completion Details i Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des Com (in) ` I 25.5 25.5 0.15 HANGER VECO GRAY TUBING HANGER CWCT-F6H TBPV 4" 3.938 Type"H" 0 O 516.4 514.8 8.22 NIPPLE CAMCO 2.875"DS NIPPLE 2.875 7,046.8 3,735.1 77.25 SLEEVE BAKER CMU SLIDING SLEEVE(Open 11/9/17) 2.812 7,087.6 3,743.4 79.22 XO- 3-1/2",9.3#,L-80,IBT AB Modified Box x 2-7/8 EUE 8rd 2.441 Reducing Pin Crossover 00`' 7,097.4 3,745.2° 79.66 GAUGE BAKER DOWNHOLE GAUGE CARRIER 2.441 1 1 ® 60 7,1072 3,746.9° 80.06 LOCATOR BAKER GBH-22 LOCATOR SUB w/3'SPACEOUT 2.990 t,,•,,,t, 7,108.0 3,747.0• 80.09 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 I 1Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) z I Top(ND) Top Incl SCAB LINER 2013;28.1-7,188.0 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) Al 7,046.0 3,734.9 77.21 SLIP STOP 31/2 SLIP STOP 11/9/2017 1 7,047.0 3,735.1 77.26 JET PUMP 31/2 AVA STYLE NOGG(WITH FRUEDENBERG 11/9/2017 0.000 PACKING)88 RATIO JET PUMP SN:AR-1013 W/ AVA SEALS(96"OAL) 11,544.0 3,755.5 90.58 FISH '2.31"XX PLUG PUSHED TO 11,544'CTMD 4/20/2013 0.000 Perforations&Slots j Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,273.0 11,670.0 3,765.3 3,753.1 WS D,1C- 12/20/2001 99.0 SLOTS Perfs thru slotted liner 135 Notes:General&Safety I IEnd Date Annotation 1/23/2007 NOTE:6'4"Surf CSG patch,from mandrel hanger,9 5/8"API 40, 395 wall ' 1 8/6/2008 NOTE:WORKOVER SURFACE;32.7-7,285.2 8/13/2008 NOTE:View Schematic w/Alaska Schematic9.0 SLOTS;7,273.0-11,670.0 FISH;11,544.0 1 LINER 2001;7,159.1-11,6700 • 0 0 SOF T 4*P.' I%j7.cv THE STATE Alaska Oil and Gas 41. 1+� �-''�a Of Conservation COInmissi®n � : - �, 333 West Seventh Avenue of *�,P- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov John PeircesmileS EP (1 1 2Q I7 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-135 Permit to Drill Number: 201-220 Sundry Number: 317-381 Dear Mr. Peirce: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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, aie.1. Cathy . Foerster Commissioner DATED this-/-/e -/day of August, 2017. RBDMS Li--AN 3 0 2017 STATE OF ALASKA AUG 0 8 ?O17 ALASKA OIL AND GAS CONSERVATION COMMISSION o✓s Fie AOG7/ , APPLICATION FOR SUNDRY APPROVALS ! 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: RPPG D MBE TrtmtE 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development 1=1 , 201-220 3.Address: Stratigraphic ❑ Service 0 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23053-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1C-135 " Will planned perforations require a spacing exception? Yes 0 No 0 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649,ADL 25650 • Kuparuk River Field/West Sak Oil Pool , 11. PRESENT WELL CONDITION SUMMARY ' Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,700' - 3,753' ' 11668 ' 3753 NONE 11,544 Casing Length Size MD TVD Burst Collapse Conductor 82' 16" 117' 117' Surface 7,253' 8" 7,285' 3,766' Scab Liner 7,159' 6" 7,188' 3,758' Liner 4,511' 5" 11,670' 3,753' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7273-11670 . 3765-3753 3.500" L-80 7,126' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=BAKER SC--R 7662-40 PACKER ` 7173=MD and 3757 TVD 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0' Service 0 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineergi / Contact Email: John.W.Peirce@cop.com g AAe .„ _ " •~ Date: 8! 712 Contact Phone: (907)265-6471 Authorized Signature: '/ 'r'�—_� / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No tr Spacing Exception Required? Yes ❑ No i Subsequent Form Required: l U -7�1 U 4 RBDMS AAUG3 0 2017 APPROVED BY Approved by: � �67 _� COMMISSIONER THE COMMISSION Dpte:g_zi—/7 fiq lip I7-, L v-r-t_ S 0r' ; s' � I IN A Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate KUPOD 1C-135 ConocoPhillips) 8 Well Attribu Max Angl D TD Us:Alaska, '.: Wellbore APIIUWI Field Name Wellbore Status ncl(°) MO(ftKB) Act Btm(ftKB) CorwctiltNirps < 500292305300 WEST SAK PROD 93.63 8,037.60 11,700.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-136 7/26/2017 10:20.17 AM SSSV:Nipple 240 8/12/2016 Last WO: 4/4/2013 34.99 12/20/2001 Vertical schematic)eotual). Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 11,366.0 9/2/2003 Rev Reason PULL ERODED OV FROM pproven 6/25/2017 POGLM,SET NEW POGLM HANGER;255-, i J Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 117.0 117.0 62.50 api5LOB Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len0. Grade Top Thread SURFACE 7 5/8 6.875 32.7 7,285.2 3,766.1 29 70 L-80 BT&C Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SCAB LINER 2013 5 1/2 4.950 29.1 7,188.0 3,758.3 15.50 L-80 /BTM 1, ,? Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 29.1 29.1 0.18 HANGER 5-1/2 x 11"CASING MANDREL HANGER 4.950 _n_."._ 1 7,113.6 3,748.0 80.31 SBE BAKER 20'80-40 SBE 4.000 CONDUCTOR,3s.a11ZaJ il � 7,133.6 3,751.2 81.11 XO-Reducing 3-1/2",9.3#,L-80,8rd EUE-AB Mod Box x 2-7/8", 2.440 6.58,L-80 8rd EUE-AB Mod Pin Crossover 1 7,151.1 3,753.8 81.96 SLEEVE-C BAKER CMU w/BX PROFILE(CLOSED) 2.310 NIPPLE;516.4 7,176.9 3,757.1 83.38 LOCATOR BAKER GBH-22 LOCATOR SUB 2.990 1 7,177.7 3,757.2 83.42 SEAL ASSY BAKER 20'SEAL ASSEMBLY(ALL SEAL SUBS) 2.990 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len g...Grade Top Thread LINER 2001 41/2 3.958 7.159.1 11,670.0 3,753.1 12.60 SLHT Liner Details r t Nominal ID ILTop(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SLEEVE;7,046.8. -t 7,172.6 3,756.6 83.14 PACKER BAKER SC1-R 76B2-40 PACKER 4.000 POGLM;7,097.0 i 1 `I` ' 'II 1 7,177.4 3,757.2 83.40 MILLOUT MILLOUT EXTENSION 5.000 7,197.9 3,759.3 84.34 XO Reducing CROSSOVER 5.5 x 4.5 4.500 7,228.5 3,762.1 85.41 SLEEVE-C BAKER CMD NON-ELASTOMER SLIDING SLEEVE 3.430 w/DS PROFILE-CLOSED I(tlt° 7,233.1 3,762.4 85.57 XO Reducing CROSSOVER 4.5x4 4.000 7,265.5 3,764.8 86.11 XO Increase CROSSOVER 4 x 4.5 4.500 GAUGE;7,097.4 ,: ' 11,614.9 3,753.9 91.04 XO Reducing CROSSOVER 4.5x4" 4.000 ill 11,648.2 3,753.4 90.86'XO Increase CROSSOVER 4x5" 5.000 11,648.9 3,753.4 90.86 XO Reducing CROSSOVER 5x3.5" 3.500 LOCATOR;7,107.1II Tubing Strings Irk Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(/blit) Grade Top Connection TUBING WO 31/2 2.992 25.5 7,126.0 3,750.0 9.30 L-80 IBT-ABM SEAL Assn 7,107.9 i. Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Corn (in) f[1 25.5 25.5 0.15 HANGER VECO GRAY TUBING HANGER CWCT-F6H TBPV 4" 3.938 1Type..H.. 516.4 514.8 8.22 NIPPLE CAMCO 2.875"DS NIPPLE 2.875 H 0 7,046.8 3,735.1 77.25 SLEEVE BAKER CMU SLIDING SLEEVE(Open 3/22/15) 2.812 7,087.6 3,743.4 79.22 XO- 3-1/2",9.38,L-80,IBT AB Modified Box x 2-7/8 EUE 8rd 2.441 Reducing Pin Crossover ►t .,1 7,097.4 3,745.2 79.66 GAUGE BAKER DOWNHOLE GAUGE CARRIER 2.441 7,107.2 3,746.9 80.06 LOCATOR BAKER GBH-22 LOCATOR SUB w/3'SPACEOUT 2.990 i1:t r 7,108.0 3,747.0 80.09 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 r. r r Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl 11 Ta Top(ftKB) (ftKB) (°) Des Com Run Date 'DO( D(in) 7,047.0 3,735.1 77.26 POGLM 2.79"POGLM ON CS LOCK(OAL-53 5",5/16"OV 6/23/2017 0.313 SCAB LINER 2013 29.1-7,188.0 INSTALLED(NO LATCH),28-1/4"FROM F.N.OF 21 LOCK TO TOP OF VLV,V-PACKING STACK ON • i TOP&6 AVA SEALS ON BTM) ' 11,544.0 3,755.5 90.58 FISH 2.31"XX PLUG PUSHED TO 11,544'CTMD 4/20/2013 0.000 Perforations&Slots I ( Shot Den Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date ft) Type Corn 7,273.0 11,6700 3,765.3 3,753.1 WS D,1C- 12/20/2001 99.0 SLOTS Perfs thru slotted liner 135 Notes:General&Safety End Date Annotation 1/23/2007 NOTE:6'4"Surf CSG patch,from mandrel hanger,9 5/8"API 40,.395 wall I 8/6/2008 NOTE:WORKOVER ' ! 8/13/2008 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;32.7-7,285.2 SLOTS;7,2730-11,670.0 FISH;11,544.0 LINER 2001;7,159.1-11,670.0 1 E • • RPPG Treat dual 'D' Sand MBE's from 1C-190 to 1C-184, and from 1C-190 to 1C-135 1C-190 is a single 4.5", L-80, horizontal monobore West Sak D sand injector that supports 1C-184 producer to the east and 1C-135 producer to the west. An initial Matrix Bypass Event (MBE) occurred 1/16/15 in the D sand from 1C-190 injector to 1C-184. A 4/27/15 IPROF identified an MBE at -8300' RKB. On 9/5/15, perfs were shot at 8300 - 8305' RKB, and on 9/21/15 CT pumped 2,709 lbs of Crystal Seal to the D MBE. 1C-190 was returned to PWI for-5 months with the MBE sealed. On 1/13/16, a 1C-90 CT FCO was done to 9375' and WHIP fell from 1000 psi (220 BWPD) to 120 psi (600 BWPD) and 1C-184 WC% spiked to 90%. 1C-190 was SI 2/6/16 due to a reopened D MBE. On 4/27/16 a CT Crystal Seal retreatment was pumped to place 3,135 lbs of Crystal Seal to the MBE at 8300' RKB. This treatment only lasted -2 months before the treatment broke down. On 9/21/16, an MBE retreatment was pumped with 30 bbls Equiseal Gel and 2,200 lbs of Crystal Seal, but this treatment only lasted until Nov 2016. As a result, 1C-184 and 1C-190 were SI. 1C-190 was returned to injection in Nov 2016 to support 1C-135 until another MBE occurred in Feb 2017 from 1C-190 to 1C-135 which has resulted in long term SI of 1C-190. On 4/2/17, CT FCO removed gel from 1C-190. A 4/3/17 1C-190 IPROF found a new MBE at -8505'. The MBE previously treated at 8300' RKB does not appear open, but this might be due to all flow entering the very dominant new MBE at 8505' RKB. It is proposed that 1C-190 be perforated at 8500 - 8505' RKB at the new MBE, and that a fullbore RPPG treatment be pumped to the MBE at -8505' RKB. Procedure 1) Coil Tubing: RIH with perf gun to perforate a 5' interval with large holes across the D MBE at -8500 - 8505' RKB, to enable better passage of RPPG slurry through the slotted liner to the MBE. 2) Pumping: If 1C-184 and 1C-135 producers are online, shut-in these wells as 1C-190 RPPG job is about to begin. This should help mitigate excessive vacuum of RPPG slurry while pumping it to the MBE(s). RU Mixing Van and pumping equipment on 1C-190. Fullbore pump RPPG slurry into 1C-190 at a steady rate in 1.0 - 1.5 bpm range in 3% KCL Water or Seawater. Add 1 - 4 mm mesh RPPG to the make up water at a steady 0.7 - 0.8 ppg slurry concentration in the mixing van. Continue pumping at steady rate and slurry concentration until the WHIP eventually reaches -800 psi, and then swap from RPPG slurry to pumping 88 bbls Seawater Spacer, followed by 41 bbls Diesel freeze protection to 2500' TVD, followed by Shutdown. This technique intends to leave maximum treating pressure acting on the MBE(s) near Frac pressure at shutdown to ensure that the MBE(s) are well packed with RPPG. Wait 2 days for the swelling RPPG particles to fully crosslink in the MBE to form stout amalgamated non-flowing crosslinked gel before returning 1C-184 or 1C-135 to production. r Y • Coil Tubing: 2) RIH with jet swirl nozzle and tag top of RPPG in 1C-190, then jet down through RPPG and fill to as deep as possible to shear and mechanically break any RPPG remaining in the well, and to uncover all the perforation intervals to injection. Maintain 1:1 returns to tanks during FCO. POOH. RD CTU. Return 1C-190 to PWI service and return either 1C-184 or 1C-135 to production to evaluate treatment results. If treatment results look good, bring on the remaining producer and evaluate treatment results. WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. AD! ., lID WellHistoryFile# Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Other # Yes No Yes No Yes No Maps # Mud Logs # - General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC _Librarian@admin.state.ak.us oF j� s, THE STATE Alaska Oil and Gas F.; '' -� ALAsKA AS Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 OF ALAS Main: 907.279.1433 2 L a 2D '�3 Fax: 907.276.7542 NED Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. c}4 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1C -135 Sundry Number: 313 -009 Dear Mr. Toomey: 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, Cathy P. oerster Chair DATED this day of January, 2013. Encl. • STATE OF ALASKA AIWA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well W ' Change Approved Program r Suspend r Rug Perforations fl Perforate r" Pull Tubing - Time Extension E Operational Shutdown r Re -enter Susp. Well r- Stimulate r Alter casing rw - Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r✓ • Exploratory r 201 -220 3. Address: Stratigraphic r Service r ` 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23053 -00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes I No r7 1 C -135 • 9. Property Designation (Lease Number): 10. Field /Poo1(s): ADL 25650, 25649 Kuparuk River 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): 11700- 3753 •11668' 3753' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 117' 117' SURFACE 7256 7.625 7285' 3766' LINER 7155 5.5 7184' 3758' RECEIVED / 7Ns10,J AOGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 7273'- 11670' 3765' -3753' 3.5 L - 7144 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SC1 -R PACKER MD= 7173 TVD =3757 ' SSSV - CAMCO 'DS' Landing Nipple MD= 517 TVD =515, 12. Attachments: Description Summary of Proposal r • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development J7 . Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/1/2013 • Oil P / Gas r WDSPL E 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: Ian Toomey © 263 -4773 Email: Ian.A.Toomev( conocophillios.com Printed Name n oomey Title: Wells Engineer Signature C_ - Phone: 263 -4773 Date /-1/ - / Commission Use Only Sundry Number311QD9 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test 1 Mechanical Integrity Test r Location Clearance r Other: 6 0 p f is 5 l' RBDAAS JAN 2 8101 Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: (] APPROVED BY / /3 Approved by: a it COMMISSIONER THE COMMISSION Date: / --fig - ! 3 ,Approve is valid for 12 months from the date of approval. t M At t / 1 Submit Form and Attachments in Duplicate , V v ! / r l ►3 pry /� • • ConocoPhillips RECEIVED Alaska JAN 1 12013 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 AOGCC January 10, 2013 ry , Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak Well 1C -135 (PTD# 201 -220). Producing well 1C-135 was drilled and completed in December 2001. It first came on production in May 2002 as a West Sak D -sand surface powered jet -pump producer. In November 2002, it was temporarily converted to water injection to try to increase bottom -hole pressure. It remained on water injection for 5 months until March 2003 at which time it was converted back to a jet -pump producer. In September 2003, the well was approved for the first MI injection of a West Sak well at 1C pad. Although plans were to "huff and puff' this well with cyclic MI slugs, after the first 4 month MI slug, it was converted back to a jet -pump producer. In 2008, a workover was done to install an inner string of 5 -1/2" casing within the 7- 5/8" surface casing to comply with an internal policy that we must have two barriers between any energized fluid (power fluid or gas lift) and the formation. The wells re- completed with a 3 -1/2" IBTM jet - pump completion. On August 11, 2011 the OA pressure suddenly equalized with the IA pressure and the well was shut -in. In October 2011 the jet -pump was pulled and the CMU sliding sleeve at 7077' RKB was closed and the well failed a MIT -IA. A plug was set in the CMU sliding sleeve at 7157' RKB and the well passed a MIT -T and passed a CMIT -IA X OA. The proposed workover will pull the 3 -1/2" IBTM tubing, pull the 5 -1/2" BTCM casing, install new 5 -1/2" BTCM casing and re- complete the well with a new 3 -1/2" IBTM jet -pump completion. This Sundry is intended to document the proposed change to the casing as well as request approval to workover the well. If you have any questions or require any further information, please contact me at 263 -4773. Sincerely, Ian Toomey Wells Engineer CPAI Drilling and Wells i KUP • 1C-135 ConocoPhillips 0 1 Well Attributes Max Angle & MD TD Alaska Inc W ellbore API /UWI F Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292305300 WEST SAK PROD 93.63 8,037.60 11,700.0 ° Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date Well coring. - 1c - 135, 1/25l201 z 9 3 sz am SSSV: Nipple 120 9/16/2010 Last WO: 8/6/2008 34.99 12/20/2001 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 11,366.0 9/2/2003 Rev Reason: PULL PRONG ninam i 1/25/2012 Casing Strings & Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd HANGER, 25 CONDUCTOR 16 15.062 35.0 117.0 117.0 62.50 api5L. Welded TUBING, 28 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 32.7 7,285.2 3,765.9 29.70 L - 80 BTBC _, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER Workover 5 1/2 4.950 29.1 7,183.9 3,757.9 15.50 L -80 BTCM Liner Details Top Depth (TVD) Top Inc' Nonni... Top (ft)(B) (ftKB) Comment Item Description Comment ID (in) 29.1 29.1 -0.63 HANGER Casing Mandrel Hanger 4.950 119 i . r / fi r 7 3 80 SBE 80-40 SEAL BORE w /5" BTC pin X pin 4.000 7,156.9 3,754.5 82.91 - SLEEVE CMU'BX', w/ 2.812" X PROFILE (CLOSED) 2.812 CONDUCTOR, _ 7,173.2 3,756.7 83.48 SEAL ASSY 80-40 SEAL ASSEMBLY 3.000 35 - 117 Casing Description String 0... String ID ... Top (ftKB) Set Depth (5... Set Depth (TVD) ... String Wt... String ... String Top Thrd 2 - LINER Original 41/2 3.958 7,159.1 11,670.0 3,753.1 12.60 SLHT Liner Details Top Depth - (TVD) Top Intl Nonni... NIPPLE, 517 Top (ftKB) (5K8) (°) Item Description Comment ID (in) . 7,172.6 3,756.6 83.45 PACKER BAKER SC1 -R 7682 -40 PACKER 4.000 7,228.5 3,762.1 85.57 SLEEVE LINER BAKER CMD NON - ELASTOMER SLIDING SLEEVE - OPEN 3.430 pp 7,265.5 3,764.7 86.11 XO 4 TO 4.5 CROSSOVER 4 x 4.5 4.500 II I II Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 25.5 7,143.5 3,752.5 9.30 L -80 IBTM g Completion Details Top Depth GAUGE, 7,031 .. j (TVD) Top Inc! Nonni... ® 5 t, Top (ftKB) (ftKB) E) Item Description Comment ID (in) 25.5 25.5 -0.67 HANGER TUBING HANGER 3.938 ® 517.1 515.0 6.12 NIPPLE CAMCO 'DS' LANDING NIPPLE 2.875 7,031.5 3,731.5 76.51 GAUGE ZIEBEL GAUGE CARRIER 2.992 SLEEVE - D. 7,076.8 3,741.2 78.70 SLEEVE -C CMU DS SLIDING SLEEVE (CLOSED 10/3/11) 2.812 7,077 ;!. 7,124.7 3,749.7 80.52 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 Perforations & Slots l a Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh -. Type Comment 7,273 11,670 3,765.1 3,753.1 WS D, 1C -135 12/20/2001 99.0 SLOTS Perfs thru slotted liner SEAL ASS 5 11 Notes: General & Safety End Date Annotation 1/23/2007 NOTE: 6'4" Surf CSG patch, from mandrel hanger, 95/8" API 40, .395 wall 8/13/2008 NOTE: View Schematic w/ Alaska Schematic9.0 Oi LINER i Workover, - 28 -7,184 SURFACE, 33 -7,285 SLOTS, 7.273- 11,670 LINER Original, 7,159-11,670 TD (1C-135), 11,700 • • 1C-135 West Sak Producer. Rig Workover (PTD #: 201 -220) Current Status 1C -135 is currently shut in. On August 11, 2011 the OA pressure suddenly equalized with the IA pressure and the well was shut -in. In October 2011 the jet -pump was pulled and the CMU sliding sleeve at 7077' RKB was closed and the well failed a MIT -IA. A plug was set in the CMU sliding sleeve at 7157' RKB and the well passed a MIT -T and passed a CMIT -IA X OA. Scope of Work The proposed workover will pull the 3 -1/2" IBTM tubing, pull the 5 -1/2" BTCM casing, install new 5 -1/2" BTCM casing and re- complete the well with a new 3 -1/2" IBTM jet -pump completion. This Sundry is intended to document the proposed change to the casing as well as request approval to workover the well. General Well info MASP: 825 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure/TVD: 1200 psi at 7157' MD (3755' TVD) SBHP taken on 1/20/12 (have requested to obtain an updated SBHP) Wellhead type /pressure rating: Grey Gen II, 11" 5K btm x 4- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT Results: MIT -T: passed October 11, 2011 MIT -IA: failed on October 3, 2011 CMIT -IA X OA: Passed on October 14, 2011 Well Type: Producer Estimated Start Date: February 1, 2013 Production Engineer: Dana Glessner /David Lagerlef Workover Engineer: Ian Toomey (263 - 4773 / Ian.A.Toomey@ conocophillips.com) Pre -Rig Work Request 1. Obtain new SBHP. 2. Open both CMU sliding sleeves. 3. Set BPV. Proposed Procedure 1. MIRU Nordic 3. 2. Pull BPV. Load well with 8.6 ppg seawater. Ensure well is dead. Set BPV. ND tree. 3. NU 11" 5M BOP. Install blanking plug. Pressure test BOP including annular to 250/3500 psi. Pull blanking plug and BPV. 4. MU landing joint, BOLDS, POOH standing back tubing, and spooling Tec Wire. 5. RU and POOH with the 5 -1/2" inner casing string. '1/4*-' .. 1C -135 ConocoPhillips As- Planned C +. Nipple, 2.875" DS i a i 1 m 4 y Tubing — 3 - 9.3 #, L -80, IBTM 4 s 1k 1 1 3 -1/2" CMU, 2.813" DS 1 1 J 3 , e Tubing — 2 -7/8" 6.5 #, L -80, EUE 8rd ABMOD I i I SBE I J 2 -7/8" CMU, 2.25" DS e 11:14— SC -1 Packer NW Mill -out Extension I i 1 Jt 4 -1/2" 11.6# L -80 4-1/2" CMD, 3.43" AF I;; I II. Slotted Liner I I; I. =' I Date: September 29`", 2011 1 Drawn By Ian Toomey 4- 1/16 t A 10 8 C 0 I D 4 4 4-11°-T5\11.45: '/I �.�....,U..... 4- 1/16 -SM 3 C800108 -07 " 3 11 - 5M 4- 1/16 -5 5M o M \ \81F:r \` \\ • 3 -1 8 -5M GV / / . / - �.�� / C800108 -03 L • 'W. A 'EN F 10 -3/4 X 4.909 MCA X • tot IZ 1AJ G. %%1111 4 -1/2 IBTM SUSP. ! n 2- 1/16 -5M GV n C2280053 -1 • S \� ��� \��` mil v 1�1 �V` mV ill=„, 1e1 C1195070 -2 n 2- 1/16 -SM GV a ���� 1."'"'--;i, �� �5� � C1900078 - 2 5 -1/2 HANGER � IM 2 , t .a r _]� SAME AS 1D -141 Ni (EXISTING) \; ��\,\ \ , �\ I,Y u ': I:1.1\ (EXISTING)4 ■■ I, I ..= 1 1 NOTE: IN ORDER TO USE THESE EQUIPMENT IN THIS 2EN - 012 vetcog PLATFORM(1C -135) EXISTING CASING HANGER NECK C800101 -4 HAVE TO BE CUT BY 5.25" FROM THE TOP __ ASSEMBLY /SWE ' .. a' e "` " S " CONOCO PHILLIPS, 1C -135 B. B. O .. CSG PROGRAM, 16 X 7 -5/8 X MOVAFFAGH MOW n 5 - 1/2 X 4 - 1/2 C/W ONE 1/4 H. HE G 1 THIS IS A GENERIC DRAWING. H. HE BY LINE FOR I -WIRE AMMO REFER TO DASH NUMBERED PARTS wrz NOTES: LIST FOR ADDITIONAL INFORMATION. 03 A P RI. 2008 ®g WI= CEN2008 -034 IRj Do NOT WALE 0000MG EN2008 -0341 wee 100 NA 1 0000 1 n 1 PRINT SCALE: 1 =8 A I B n C I D • • -- Proposed Procedure Continued— 6. PU and RIH with 7 -5/8" casing scrapper on 3 -1/2" tubing to the top of the SC1 -R packer. POOH laying down the tubing. 7. RU E -Line. RIH with memory 40 -arm caliper, gyro and GR. POOH and RD E -Line. 8. RIH with 5 -1/2" BTCM inner casing string. Sting into SC1 -R, mark the pipe, PU and circulate in corrosion inhibited seawater. Space out and land 5 -1/2" casing. RILDS. PT 5 -1/2" X 7 -5/8" annulus 4 to 2500 psi 9. RIH with 3 -1/2" IBTM tubing with SCC. Sting into SBE, mark the pipe, PU and circulate in corrosion inhibited seawater. Space out and land 3 -1/2" completion. RILDS. PT tubingand_IA to 2500 psj. 10. Set BPV. ND BOP. NU tree and pressure test to 5000 psi. 11. RDMO Nordic 3. Post -Riq Work request: 1. RU CTU: Open lower CMU and load OA with diesel freeze protect. Close lower CMU. Open upper CMU and install jet pump. RD CTU. 2. Return to production. II ~ '~ E ~~, ~ , STATE OF ALASKA - `-``''~ ALASKA OIL AND GAS CONSERVATION COMMISSION , „ REPORT OF SUNDRY WELL OPERATI~~i~N~$ - .._. 1. operations Pertormed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^ Aiter Casing Q PuII Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development 0 Exploratory ^ 201-220 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23053-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 91' 1C-135 8, Property Designation: 10. Field/Pool(s): ADL 25650, 25649 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11700' feet true vertical 3753' - feet Plugs (measured) Effective Depth measured 11668 feet Junk (measured) true vertical 3753' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 117' 16" 117' 117' SURFACE 7285' 7-5/8" 7285' 3766' PRODUCTION 7093' 5.5" 7184' 3758' SLOTTED LINER 4497' 4.5" 11670' 3753' Perforation depth: Measured depth: 7173'-11670' true vertical depth: 3756'-3753' ~~~~ ~~~ ~, p) ~~~~ Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7144' MD. Packers & SSSV (type & measured depth) Baker SC1-R pkr-- 7172' Camco'DS' nipple @ 51T 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 386 125 133 -- 261 Subsequent to operation 368 130 115 -- 286 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 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: 308-259 Contact Brett Packer @ 265-6845 Printed Name Brett Packe Title Wells Engineer 9~~ 3~ob-- ~~ Signature i~ Phone: 265-6471 Date Pre red b haron Allsu Drak 263-4612 Form 10-404 Revised 04/2006 S ~~ S~~ ~ 200 Z~' o7y Submit Original nd ly 4• ~~~ ConocoPfiiliips r?Ci'Se..:. I - PATCH,1 - HANGER, 26 - TUBING, 26 - 0 117 NIPPLE. S'~] KU P ~ 1 C-135 Nellbore APVUWI Fieltl Name Well Status Inclination (°) MD (flK8) Total Depth (RKB) 500292305300 WEST SAK PROD 93.63 8,037.60 I 11,700.0 merit ~.H2S (ppm) (Date Innotation ''End Date KBGrtl (ft) iRig Release Date SSSV: Nipple ~I 120 I 7/1/2008 (Last WO: 8/6!2008 34.99 12/20/2001 ~ \nnotation De h ftKB ErM Date 1 ) Annotation Entl Date act Tag: 11 ,366 0 .I 9/2/2003 (Rev Reason: WORKOVER 8/73/2008 Casing Strings :acingDescription __ _ OD(in) --- -- ID (in) Top (flK8) Set Depth (ft... Set Depth (TVD)(ft... Wl(Ibs/... Grade - Top Connectir ~ONDUCTOR 16 15.062 0.0 117.0 117.0 i 62.50 apiSL 0-B ;acing Description OD (in) ID (in) Top (flK8) Set Depth (fl... Set Depth (TVD) (fl... WI (Ibs/... Grade Top Connectk _INER Workover 5 1/2 4.950 0.0 7.183.9 3.757.9 15.50 L-80 I BTCM 7,147.51X0 ( Cross-Over Sub, S"BTC pin X 3/112" EUE pin 2.970 7,156.9 SLEEVE 3 1/2", CMU'BX', w/2.812" X profile (closed position) 2.812 7,173.21SEAL ASSY 80-40 Seal Assembly 3.000 .Casing Description OD (in) ID (in) Top (flK8) Set Depth (R... Set Depth (TVD) (R... Wt (Ibs/... Grade Top Conn ection SURFACE __ 75/8 6.875 0.0 7,283.0 3,765.7 29.70 ~ L-80 BT&C Casing Description OD(in) ID (in) Top (RKB) ( Set Depth (R... 11Set Depth (TVD)(fl._ .Wt (Ibs/... Grade Top Connection LINER Original 4 1/2 3.958 ~ 7,159.1 ~ 11 670 0 I 3,753.1_ 12 60 SLHT Liner Details ___ Top (RKB) ~'. Rem Descriptio n Comment ID (in) /,1/26~PACKER ~IBAKER SC1-R 7682-40 PACKER 4.000 ~ 7,228.5 SLEEVE LINER BAKER CMD NON-E LASTOMER SLIDING SLEEVE -OPEN '~ 3 430 CAMCO'DS' LANDING NIPPLE Ziebel Gauge Cartier CMU DS Sliding Sleeve SLEEVE. 7.077 SEAL ASSY, 7.125 LINER Workover,- - 0-],1&1 PLUG, ],213 SURFACE, 0-7,2631 Slaneq _ _ ],273-11,670 MANDREL HANGER; 9 5/8" API 40, .395" V7 PLUG IPB set PRE WORKOVER Ions rep Btm smog Btm (fND) (TVD1 D n (1tKB) (kK8) 1RK61 Tvae Zona (sho.. NER Original, 7,15911,6]0 ~ --yy TD (1 C-135), ~j 11,700 • 1 C-135 Workover Events • DATE SUMMARY 4/5/08 PRE RWO T& IC-POT & PPPOT (PASSED ) 7/11/08 PULLED 3" JET PUMP (SN#: PH-1043; 9A RATIO) ON CS LOCK USING 2.125" OIL JARS AND 3" GUTTED JD PULLING TOOL FROM CMU @ 7070' CTMD. PULLED 12K# OVER AND PUMP CAME FREE (IGS IMPACT TOOL RECORDED 5400#). PUMPED 100 BBLS OF S.D. DOWN IA TO CONFIRM CMU OPEN. 7/12/08 DRIFT W/ 2.67" CENT. @ 7070' SLM. JOB IN PROGRESS. 7/13/08 RUN PDS CALIPER @ 7070' SLM TO SURFACE. GOOD DATA. JOB COMPLETE. 7/14/08 PERFORMED 30 MIN SBHP @7096' SLM=1444 PSI, 74 DEG F. 10 MIN GRADIENT STOP MADE @ 6763' SLM=1400 PSI. JOB COMPLETE. 7/25/08 SET 2.5" BAKER IBP AT 7213' WITH MAXTRAC TRACTOR CONVEYANCE. ~_~... OVERALL LENGTH OF PLUG IN HOLE IS 11.05'. FISHING NECK IS 1.375" JDC. 5500# TO PULL RELEASE. PRESSURE TESTED IBP WITH L S PUflLLel.~l~,~~~ DIESEL HOLDING 1500 PSI FOR 30 MINUTES. BLED BACK TO 50 PSI. RESET tBPV AND REMOVED SCAFFOLDING. READY FOR RIG. 8/12/08 RIH WITH A 3.5" SHIFTING TOOL AND OPEN CMU @ 7077' MD & 7157' MD.PUMPED 120 BBLS OF DIESEL DOW_N_OA AND SHIFTED CMU CLO~.EQ: AND PERFORM MIT-OA.PUMPED 3Q,~LS DOWN ~AAND HIFTf D.~~JJ. CLOSED AND PERFORM MIT-IA.POOH AND LEFT BOTH CMU IN THE ~L~SEQ. POSITION.( MIT ON OA & IA PASSED).JOB IN PROGRESS 8/13/08 RIH WITH BAKER 2 13" ,,, D OVERSHOT AND FISH IBP FROM 7213' CTMD, LOST 1 OF THE 6" RUBBER ELEMENTS DOWN HOLE. JOB COMPLETE. READY FOR CONCENTRIC COIL. 8/18/08 MIRU. BOPE Test. RIH. Currently at 6,500' CTMD. 8/19/08 Continued Sand Vac operations from 8/18/08. Total depth achieved at time of report end was 9150' ctmd with trace amounts of sand in returns. (( IN PROGRESS )) 8/20/08 Continue sand vac operations from 8/19/08, total depth achieved at time of report end was 11347' ctmd, up to 1/2 cup sand per 5 gal. fluid returns every 15 min. (( in progress )) 8/21/08 Complete CCT FCO down to TD Cat 11.686' ctmd. Liq~,jt sand in returns during the final 500' of well, POOH and RDMO. (((Job complete))). ~onocoPhilips Time Log & Summary Wefiv7eev Web Reyvx#ing Report _ ___ - Well Name: 1C-135 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: ~.~~4A s:o0:0_ 0 AM_ - Rig Release: 8/5/2008 11:59:00 PM Time Lois _ Date From To Dur S De~h E Depth Phase Code 5ubcode T Comment 7/27/2©D8 24 hr Summarv Test tree and void, RU and freeze protect well 3R-21with 80 bbls diesel, allow to u-tube, RDMO 3R-21, start ri move to 1C Pad. 07:30 08:30 1.00 MIRU MOVE MOB P Move rig off 3R pad, shuffle rig mats onto Oliktok Road. 08:30 09:30 1.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 09:30 10:30 1.00 MIRU MOVE MOB P Move rig from 3R access road to 12 acre ad. 10:30 14:00 3.50 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 14:00 17:00 3.00 MIRU MOVE MOB P Move rig from 12 acre pad to 3K access road. 17:00 18:30 1.50 MIRU MOVE MOB P Hold rig for CPAI STP change out, stand b with crew. 18:30 19:30 1.00 MIRU MOVE MOB P Move rig from 3K access road to just north of 3C access and road failed. 19:30 22:30 3.00 MIRU MOVE MOB P Jack up and shore up rig, back onto mats. Standb 22:30 00:00 1.50 MIRU MOVE MOB P Wait on road repair and rig mat lacement, stand b with crew. 7/28/2008 Move rig from 3R Pad to KIC turn off, enroute to 1C Pad. 00:00 06:00 6.00 MIRU MOVE MOB P Cont wait on road repair and rig mat placement, north of 3C access road, stand b with crew. 06:00 08:00 2.00 MIRU MOVE MOB P Cont moving rig to 3C access road. 08:00 13:00 5.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 13:00 18:00 5.00 MIRU MOVE MOB P Cont moving rig from 3C access road to KCS "Y". 18:00 20:00 2.00 MIRU MOVE MOB P Hold rig for CPAI CPF's change out, stand b with crew. 20:00 23:00 3.00 MIRU MOVE MOB P Cont moving rig from KCS "Y" to KCC. 23:00 00:00 1.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 7!29/2008 Continue to Move rig from KIC turn off, enroute to 1C Pad on rig mats. 00:00 01:30 1.50 MIRU MOVE MOB P Move rig on mats from KCC to KIC intersection. 01:30 07:30 6.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 07:30 08:00 0.50 MIRU MOVE MOB P Move rig on mats from KIC towards 1 C Pad access. 08:00 11:30 3.50 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. ~'~€~~ 2 of ~a • l .Time Logs Date From To_ Dur_ _S. Depth_E, De th Phase Code Subcode T _ Comment _ 11:30 12:00 0.50 MIRU MOVE MOB P Continue to move rig on mats from KIC towards 1 C Pad access. 12:00 13:00 1.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 13:00 13:30 0.50 MIRU MOVE MOB P Continue to move rig on mats from KIC towards 1C Pad access. 13:30 15:00 1.50 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 15:00 15:30 0.50 MIRU MOVE MOB P Continue to move rig on mats from KIC towards 1C Pad access. 15:30 16:30 1.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 16:30 17:00 0.50 MIRU MOVE MOB P Continue to move rig on mats from KIC towards 1C Pad access. 17:00 19:00 2.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 19:00 19:30 0.50 MIRU MOVE MOB P Continue to move rig on mats from KIC towards 1C Pad access. 19:30 23:30 4.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 23:30 00:00 0.50 MIRU MOVE MOB P Continue to move rig on mats from KIC towards 1C Pad access. 7/30/2008 Continue to Move rig on to 1 C Pad on rig mats. Accept Nordic 3 rig @ 0600 hrs 7/3012008. Load tree and 13 5/8 BOPE. MIRU and berm up. RU kill lines and take on kill fluid. Lub out BPV and Open up well 75 psi SITP, 75 psi SIIAP. PT lines to 2,500 psi and reverse circ w/ 474 bbls 9.6 ppg brine w/ safe tube. confirm well dead. Set BPV, RD lines and ND Tree. Install 13 5/8 BOPE. 00:00 04:00 4.00 MIRU MOVE MOB P Move mats ahead of rig, stand by with crew. 04:00 05:00 1.00 MIRU MOVE MOB P Continue to move rig on mats from KIC towards 1 C Pad access. 05:00 06:00 1.00 MIRU MOVE MOB P Move rig on to 1C Pad. 06:00 12:00 6.00 COMPZ RPCOM RURD P Acce t Nordic 3 riq (a) 0600 hrs 7/30/2008. Load new tree and 13 5/8" BOP Stack in cellar. Install Xover on flow nipple. Install containment in cellar. Spot rig over well. RU hardline. Load pits with 9.6 ppg brine. Spot cuttings tank and Mud Lab. NU lines to tree in cellar. 12:00 15:00 3.00 COMPZ WELCTL CIRC P Pull BPV, Line up to reverse circ. IA press = 75 psi Tubing = 75 psi. Pressure test lines 2500 psi. Reverse circulate 474 bbls 9.6 ppg brine w/ SafeLube down the annulus, through the CMU taking returns up the tubing until 9.6 brine returnng at surface. Shut down, SICP - 0 SITP 0 well dead. 15:00 15:30 0.50 COMPZ RPCOM OWFF P Monitor well for flow 15:30 18:30 3.00 COMPZ RPCOM OTHR T Blow down hardline to Tiger tank and foamed up tank. Foam carried by 18 MPH winds w/ 31 MPH gusts. Clean u affected area. 18:30 21:00 2.50 COMPZ RPCOM NUND P RD lines, ND Tree, Install blanking lu and Prep hanger to pull outer han er bushin . ~~rie 2 of & r~ r~ Time Lo s g--- -- _- -- --- -- - Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 00:00 3.00 COMPZ RPCOM NUND P _ NU 13 5/8 BOPE 7/31 /2008 Continue to NU BOPE and change out LPR's rams to 2.875 x 7" VBR's. Test BOP Rams @ 250/3,000 psi and Annular @ 250/2,500 psi. 24 hr notice was given to AOGCC @ 15:00 hrs on 7/27/08 and updated @ 18:10 hrs on 7/29/08 to Lou Grimaldi and 2nd update was given @ 18:30 on 7/30/08 and Witness of test was waived @ 19:10 hrs on 7/30/08 by Jeff Jones. Pull blanking plug and BPV. MU landing jt. Unland hanger and pull to floor. Circ 306 bbls @ 5 bpm @ 450 psi. Pooh laying down 3.5" Decompletion string f/ 7,150' t! 4,347'. 0 Losses to date. 00:00 01:30 1.50 COMPZ RPCOM NUND P Change out lower Pipe rams to 2.875 x 5.5 VBR's 01:30 12:30 11.00 COMPZ WELCTL BOPE P Test BOPE to 250/3,000 psi. Lower VPR would not test. Change out lower VPR to 3 1/2". Retest 250/3000 Annular 250! 2500 psi. Witnessing waived by Jeff Jones AOGCC 1910 hrs 7/30/2008. 12:30 16:00 3.50 COMPZ RPCOM PULD P olua. Pull BPV. Set isolatlion sleeve. BOLDS. Attempt to pull, hanger would not release. Pulled 200K max. 167k + TD 35K. Worked up and down. Applied steam to wellhead and hanger pulled loose. Pulled han er to ri floor. 80K u wt. 16:00 17:00 1.00 COMPZ RPCOM PULD P Attempt to circulate to clean hole. Side isolation sleeve leaked. Break out and LD tubing hanger. MU head in. 17:00 19:00 2.00 7,190 7,150 COMPZ RPCOM CIRC P Circulate hole volume 524 bbls @ 5 b m 450 si and monitor well. 19:00 00:00 5.00 7,150 4,347 COMPZ RPCOM PULD P Pooh from 7,150' to 4,347' 60k up wt. 8/01 /2008 Continue to Pooh laying down 3.5 Prod. string f/ 4,347'. Change UPR's and LPR's and test -witness waived by Jeff Jones @ 10:00 hrs on 8-1-08. Rack and Tally 5.5" inner liner. MU seal assy and Rih w! 5.5 15.5# L-$0 BTCM inner liner to 4,693' 00:00 08:00 8.00 4,347 0 COMPZ RPCOM PULD P Continue to Pooh laying 3.5" Prod. strip f/ 4,347'. Lay down seal assembl . 08:00 12:00 4.00 COMPZ WELCTL BOPE P Clean and arrange rig floor. Change out pipe rams putting 2 7/8"x 5 1/2" variable rams on bottom and 3 1/2" rams in to .Set test lu . 12:00 14:30 2.50 COMPZ WELCTL BOPE P Retest both sets rams (Lower 2 7/8"x 5 1/2") (Upper 3 1/2"). Witnessing of test waived by Jeff Jones 1000 hrs 8/1/2008. 14:30 19:00 4.50 COMPZ RPCOM OTHR P Rack, strap and drift 5 1/2' casing and all 'ewel in i e shed 19:00 00:00 5.00 0 4,693 COMPZ RPCOM PULD P Mu seal ass and Rih PU 5.5" 15.5# L-80 Inner liner assy to 4,693'. up wt 80k and do wt 65k 8/02/2008 Continue to Rih w! 5.5 15.5# L-80 BTCM inner liner Pu and Rih w/ Storm PKR and set and test. ND BOP. BOLDS, pull packoff, ND TBG &CSG Spool, cut mandrel and dress. NU New CSG &TBG Spool. NU ROPE and shell test 250/3,000 si. Pull Storm PKR. Rih w/ 5.5" inner liner f/ 6,458' t/ 7,150'. 00:00 02:00 2.00 4,693 6,458 COMPZ RPCOM PULD P Continue to Rih w/ 5.5" 15.5# L-80 BTCM Inner liner f/ 4,693' t/ 6,458'. u wt 100k do wt. 70k ~~~ 3 0# 6 r~ r~ ~ Time Logs _ _ _ _ _ _ _ Date From To Dur S. Depth_ E. De th Phase Code Subco e T Comment __ ~I 02:00 04:00 2.00 6,458 6,556 COMPZ RPCOM OTHR P MU Storm Packer and Rih on 3 1/2 DP to 98' and set w/ Bottom of seal ass 6 556'. PT ~ 1,000 psi for 10 minutes. Release off and Pooh w/ settin tool. 04:00 06:00 2.00 6,556 COMPZ RPCOM NUND P Held PJSM, ND BOPE 06:00 14:30 8.50 COMPZ RPCOM OTHR P PJSM. BOLDS, pull pack off, ND tubin head~ack rip up and movee 'T mats so lower valve will clear. RU cut saw, cut 7 5/8" mandrel off 5.25". Install new Vetco-Gray 5 1/2" casing head and new tubing head NU 11" x_ 13 5/8" DSA to new tubin head. 14:30 21:00 6.50 COMPZ RPCOM NUND P NU BOP, body test 250/3000 psi. Witnessing of body test waived by Jeff Jones 11:30 am 8/2/2008. 21:00 23:00 2.00 6,556 6,458 COMPZ RPCOM OTHR P PJSM, Pull Storm Pkr, LD 23:00 00:00 1.00 6,458 7,150 COMPZ RPCOM PULD P RU and Rih w/ 5.5" CSG f/ 6,458' U 7,150'. UP wt 103k, DN 72k. 8/03/2008 Locate @ 7,176' and Space out MU hanger and Spot 120 bbls Corrosion inhibited 9.6 ppg fluid on IA. Land hanger and RILLDS. PT to 2,500 psi. Unland hanger, Pull seal assy and Pooh to 7,046' and MU Storm acker Rih to 7,144' w/Storm acker 98'. Set and test. ND BOPE and well head to install ack off. 00:00 02:30 2.50 7,150 7,186 COMPZ RPCOM HOSO P Locate @ 7,176' w/ mule shoe 7,186' space out 2.75' and PT to 500 psi. PU and Space out, install han er and MU Landin JT. 02:30 03:30 1.00 COMPZ RPCOM CIRC P Reverse circ and spot 120 bbls 9.6 ppg Corrosion inhibited fluid @ 4 b m 430 si. 03:30 04:30 1.00 7,183 COMPZ RPCOM OTHR P Drain stack and Land hanger w/ 3' of space out off top of packer Cal 7.176 and bottom of seal ass 7 183'. 103k Up wt, 72k Dn wt, 35k Block wt. RILLDS. Remove landing jt. Sliding sleeve 7,157', SBE f/ 7,128' t/ 7,148'. 04:30 05:00 0.50 7,183 COMPZ RPCOM DHEQ T Attempt to test 5 1/2" x 7 5/8" failed. Communication between 7 5/$" and 16" conductor. No seals or packoff desi ned into news stem. 05:00 12:30 7.50 COMPZ RPCOM DHEQ T Shut down waiting on orders. 12:30 15:00 2.50 7,183 7,046 COMPZ RPCOM PACK T PJSM. MU landingjt. BOLDS. Pull han er and LD. Pull 3 ~ti s of 5 1/2", casing LD_,MU Storm Packer for 7 5/8" x 5 1/2" and IH on 3 jtc 3 1/2" drilpi~e set (a. 98' and release. _ POOH standing. back 1 stand of drill i e. 15:00 17:30 2.50 COMPZ WELCTL NUND T ND BOP stack. 17:30 00:00 6.50 COMPZ RPCOM OTHR T PJSM, 13emove well head. Bevel Mandrel han er and fit New Pack off. ~~ #~ar1a 4 of & r~ Time Lois Date From To Dur S. Depth E. Depth Phase Code Subcod_e T Comment 8/04/2008 _ 2a hr Summary Continue to install pack off and NU well head and NU BOPE. Shell Test BOPE to 250/3,000 psi. Witness of test waived by Jeff Jones 1645 hrs on 8-3-08. Recover storm pkr and Rih w/ 5.5" Inner Liner and Land. RILDS and PT 5.5" x 7.626" IA to 2,500 psi for 30 minutes chart. Load Pipe shed w/ 3.5" Completion string. MU 3.5" Com letion strin and Rih t/ 570'. 00:00 02:30 2.50 COMPZ RPCOM OTHR T Install pack off. 02:30 03:00 0.50 COMPZ RPCOM SFEO T Pressure test Pack off to 3,000 psi. 03:00 12:00 9.00 COMPZ RPCOM NUND T NU Well head. Install new cable on Bridge Crane in cellar. NU BOPE and flow nipple. Set test plug and shell test BOPE. Witnessing waved b Jeff Jones 1615 hrs 8/3/2008. 12:00 13:30 1.50 COMPZ RPCOM PULD T PJSM, Pull Storm Packer and LD. 13:30 14:30 1.00 COMPZ RPCOM DHEQ T RU and run 5 1/2' casing stinging back into seals .7183'. Land han er, RILDS. Up wt = 103K Dwn wt. = 72K. 14:30 15:30 1.00 COMPZ RPCOM DHEQ P RU test egui~ment and test 7 5/8" x_ 5 1/2" annulus to 2500 si and chart .~ for 30 min. 15:30 20:30 5.00 COMPZ RPCOM OTHR P Load pipe shed with 3 1/2" completion. Load pits with 9.6 ppg brine ull out of its to ~ack u ri . 20:30 21:00 0.50 COMPZ RPCOM SFTY P Held PJSM w/ Ziebel, Baker and Rig crew. 21:00 22:00 1.00 0 306 COMPZ RPCOM PULD P PU and MU 3 1/2 Completion e ui ment and Rih t/ 306' - 4.7" OD GLM w/ .25" OD TEC wire unable to fit in 4.9" ID -GLM was round and not oblong, no clearance for TEC wire. 22:00 23:00 1.00 COMPZ RPCOM WOOR T Contact Engineer and explain situation. Wait for decisions to be made. 23:00 00:00 1.00 306 570 COMPZ RPCOM PULD P La down GLM and Continue to Rih w/ 3 1/2 Com I~ etion to 570' Up wt 35k„ Dn wt 35k 8/05/2008 Continue to Rih w/ 3.5" Completion string to 7,128'?. Stab into SBE and Space out 3' off of SBE w/ locator @ 7,125'. Land hanger and PT tbg @ 2,500 psi for 15 min. and IA @ 3,500 for 30 min. and charted. Set TWC, ND BOPE and NU Tree and Orient valves. PT Tree Pull TWC and Install BPV. Pull rig off and Clean Cellar. Release Nordic Ri 3 23:59 hrs on 8-5-08 00:00 09:00 9.00 570 COMPZ RPCOM PULD P Continue to Rih w/ 3.5 Completion - Gathering Up & Down weights every 1,000' along w/ taking gauge readin s same time. 09:00 12:00 3.00 COMPZ RPCOM HOSO P Locate to of SBE (a) 7128'. Sat down @ 7148'. Space out 3', mule shoe depth @ 7143'. Up wt = 80K, down wt = 53K. PU MU pup joints (2x2', 1x10'), MU hanger, splice tech wire. '^'ag~ 5 of 6 Time Lo s ~ Date __ From To Dur S De th E. D e p th Phase Code Subcode T Comment ' 12:00 13:00 1.00 _ _ _ _ _ COMPZ __ RPCOM CIRC P _ Circulate 20 bbl of inhibited brine down the tubing followed by 50 bbl of 9.6 brine. Land hanger, seals at 7128'. 13:00 15:30 2.50 COMPZ RPCOM DHEO P RU lines. Test tubing 2500 psi/15 min, bleed tubing to 1750 psi. Test IA to 3500 si/30 min. 15:30 16:00 0.50 COMPZ RPCOM PULD P LD landing jt, pull iso sleeve, set TWC. 16:00 18:30 2.50 COMPZ RPCOM NUND P ND BOPE 18:30 20:00 1.50 COMPZ RPCOM NUND P NU Tree and re orient tree valves 20:00 20:30 0.50 COMPZ RPCOM SFEO P PT Void to 5,000 psi and hold for 10 minutes. 20:30 21:00 0.50 COMPZ RPCOM OTHR P Dress tree and RU to PT Tree 21:00 21:30 0.50 COMPZ RPCOM SFEO P PT Tree 250/5,000 psi and hold for 10 minutes 21:30 22:30 1.00 COMPZ RPCOM OTHR P Pull TWC and Install BPV 22:30 00:00 1.50 COMPZ MOVE DMOB RD in preparation in moving rig. Jack up and pull off well. Clear T mats from 1C-135. Clean and prep cellar for rig release. Final pressures TBG 0 psi; IA 0 psi; OA 150 psi. Release Nordic Rig 3 from 1C-135 as of 23:59 hrs on 8-5-08 F~age b of 5 ~~~1~ ~ Cis ~1~~~~5~~;', ALASSA OIL A1~TD (zA.S COI~TSERQA'1`IO1~T COMI~IISSIOI~T Brett Packer Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Kuparuk River Field, West Sak River Oil Pool, 1 C-135 Sundry Number: 308-259 d ~ - ~` s zoos ~ ~~ANN~~ 1UL ~ Dear Mr. Packer: 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. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~da of Jul , 2008 ~- Y Y c;nair Encl. ~ ~ ~.~ g~ v~,o • STATE OF ALASKA • i ,~L ~ ~. LCQB ~I' ALASKA OIL AND GAS CONSERVATION COMMISSION i'~~ `~ ~' APPLICATION FOR SUNDRY APPRO~(~ ~~~ ~, ~~ ~ _ ~- ~ ~~. .-~ ~. +~~ 20 AAC 25.280 /. -' 1. Type of Request: Abandon ^ ~ Suspend ^ Operational Shutdown ^ 0 Perforate ^ Waiver ^ Other ^ Alter casing ~,yvtRepair well Q Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q ~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q Exploratory ^ 201-220 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23053-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Welt Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ^~ 1C-135 ' 9. Property Designation; 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650, 25649' RKB 91' • Kuparuk River Field /West Sak Oil Pool , 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured):. Junk (measured): 11700' ~ 3753' 11366' Casing Length Size MD TVD Burst Collapse CONDUCTOR 117' 16" 117' 117' SURFACE 7285' 7-5/8" 7285' 3766' SLOTTED LINER 4497' 4.5" 11670' 3753' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7173'-11670' 3756'-3753' 3-1/2" EUE8RDMOD 7164' Packers and SSSV Type: Packers and SSSV MD (ft) SC1-R pkr= 7172' Camco 'DS' nipple @ 492' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat July 27, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Engineer Signature !~~ ~ ~~ Phone 265-6845 ~/ Date ~/LZ~l 4 Commission Use Onl Sundry N~nber: Conditions of approval: Notify Commission so that a representative may witness • Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ `~*`~~ Q~~~~ Other: 3~~ ~~~ ~~ ~'S~ Subsequent Form Required: ~y-~ ~ APPROVED BY ~~~~, Approved by: OMMI R THE COMMISSION Date: ~(/ (/~f vv Form 10-403 Revised 06/2006 ~./ ~-~ Submit in Duplicate ~~~ • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 22, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: • r. ~,, ;~ ~~~~~d~ ~~..~~~ ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak Well 1C-135 (PTD# 201-220). Producing well 1C-135 was drilled and completed in December 2001. It first came on production in May 2002 as a West Sak D-sand surface powered jet-pump producer. In November 2002, it was temporarily converted to water injection to try to increase bottom-hole pressure. It remained on water injection for 5 months until March 2003 at which time it was converted back to a jet-pump producer. In September 2003, the well was approved for the first MI injection of a West Sak well at 1 C pad. Although plans were to "huff and puff' this well with cyclic MI slugs, after the first 4 month MI slug, it was converted back to a jet-pump producer and has remained as a jet-pump producer ever since. A recent discovery of severe casing corrosion in two Tarn jet-pumped wells had raised concern for the possibility of similar corrosion issues in West Sak jet-pumped wells. 1C-135 is one of the four West Sak single casing jet-pumped wells along with 1C-170, 1C-178, and 1C-184. Subsequent to the corrosion discovery at Tarn, apro-active workover on 1 C-170 to pull the tubing and inspect the casing revealed that we are not seeing the same corrosion issues similar to what was seen at Tarn. Nevertheless, new internal policy now dictates that we must have two barriers between any energized fluid (power fluid or gas lift) and the formation. Thus, the four West Sak single casing jet-pumped wells were shut-in until such time that an inner string of 5%Z" casing can be installed within the 75/a" surface casing. 1 C-135 is the first of the four wells to be worked over in this fashion. The proposed workover will pull the 3'/z° 8rd EUE tubing, install an inner string of 5%2' BTCM casing and re-complete the well with a 3'/2" IBTM jet-pump completion. This Sundry is intended to document the proposed change to the casing structure as well as request approval to workover the well. r The current SBHP is 1444 psi as measured on 7/14/08. This equates to an EMW of 7.4 ppg at mid-pert. An IBP will be set in the liner below the packer to isolate the well from the formation and 9.6 ppg brine will be used as a workover fluid. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, -~....~- Brett Packer Wells Engineer CPAI Drilling and Wells West Sak 1 C-135 • General Workover Procedure PTD 201-220 Pre-Riq Work 1. Pull jet-pump, confirm CMU is open. (DONE) 2. Run caliper tog from CMU at 7083' RKB to surface. (DONE) 3. Obtain SBHP. (DONE) 4. Set 2'/z" IBP in liner at 7213' RKB below the SC1-R packer. Perform a pressure test and drawdown test on the IBP. CMIT to 2500 psi. 5. Set BPV. 6. Prepare location for arrival of Workover Rig. General Workover Procedure 1. Verify Sundry approval acquired. 2. MIRU Nordic #3. 3. Pull BPV. Load hole with 9.6 ppg brine. Set BPV. ND tree. 4. NU BOPE. Install blanking plug. Pressure test BOPE to 250/3000 psi • The current SBHP is 1444 psi at 7126' RKB (3750' TVD) as measured on 7/14/08 which equates to 7.4 ppg at mid-pert depth of 3760' TVD. An IBP will be set in the liner to isolate the formation. Kill weight fluid is expected to be 7.4 ppg at a mid-pert depth of 3760' TVD. 9.6 ppg brine will be used during this workover. The calculated maximum anticipated surface pressure assuming a gradient of 0.1 psi/ft is 1069 psi.) 5. Pull 3'/z" tubing. 6. With 2000' of tubing pulled, set storm packer at +/-100'. ND BOP and tubing head. Install new Vetco Gray 11 ", 5M casing spool to accommodate the new 5'/z" casing and new 11 ", 5M tubing head for the new 3'/s" IBTM tubing. Pressure test packoff to 5000 psi. NU BOP and pressure test below blind ram to 250/3000 psi. 7. Pull storm packer. Continue POOH laying down 3'/z" completion. 8. RIH w/ 5'h" BTCM inner casing string. Sting into SBE, mark pipe, pull up and circulate in corrosion inhibited 9.6 ppg brine. Space out and land 5'/2" casing. RILDS. PT 5'/s" x 75/a" annulus to 2500 psi. 9. RIH w/ 3'/" IBTM tubing w/ SCC. Sting into SBE, mark pipe, pull up and circulate in corrosion inhibited 9.6 ppg brine. Space out and land 3'/2" completion. RILDS. PT tbg and IA to 2500 psi. Shear the SOV. 10. Set 2-way check. ND BOPE. NU tree and pressure test to 5000 psi. 11. Pull 2-way check, freeze protect with diesel. 12. Set BPV and RDMO workover rig Post-Riq Work 1. Pull BPV 2. RU Slickline: Set catcher sub below bottom GLM. Pull the SOV and replace w/ a DV. Retrieve the catcher sub. 3. RU CTU: Open lower CMU and load OA with diesel freeze protect. Close lower CMU. Pull IBP at 7213' RKB. Set jet-pump in upper CMU. 4. Return to production. ~~i~~~ • Wel I: 1 C-135 2008 RWO PROPOSED COMPLETION API: 500292305300 PTD: 201-220 Wellhead: Gray Gen II X-mas Tree: 4-1/8", 5K psi Lift Threads: 4.909" MCA BPV: 4" 'H' • Tubing = 3'/", 9.3 ppf, L-80, IBT-Mod w/ SCC • 2.875" DS-nipple at 500' • Ziebel Downhole Gauge • Baker 3.5" CMU w/ 2.812" DS profile at XXXX' • Baker locator w/ 17' seal assy. at XXXX' • Casing = 5'/=',15.5 ppf, L-80, BTCM. • Crossover from 5'/",15.5# BTCM. • SBE • CMU w/ 2.812" X profile at XXXX' • Baker 80-40 S-22 Locator w/ 10' seals Directional Max Incline: 93.6° @ 8038' Max Dogleg: 14.4° @ 9173' Fill at: TD: 11 Conductor: 16", 62.5#, AP15L 0-B at 117' Surface Casino: 7.625", 29.7#, L-80 at 7283' New Inner Casino: 5.5", 15.5#, L-80 BTCM Ziebel Downhole Gauge/Carrier Sliding sleeve forjet pump. • Crossover to 5.5" BTCM SBE ~ SC1-R PKR Gas Lift Mandrels: MD TVD Tvoe Q 0 3205 2300 3.5" KBG2-9, 1" 6890 3685 3.5" KBG2-9, 1" Last Updated: 22-Jul-08 .700' RKB Updated by: JBP • Con~coPhlii~~ Aia$ka, inc. 1 C-135 _ API: 50029: TueiNG SSSV Type: Nipple (0-7164, OD:3.500, ID:z.ssz) Annular Fluid: Reference Lo SURFACE __ LastTa :11366 (o-7za3, Last Ta Date: 9/2/20 OD:7.625, W, 29.70) Casin String -ALL NIP (492-493, Descri ti0n OD:3.500) CONDUCTOR ~~ SLEEVE-0 (7083-7084, OD:5.495) PUMP (7083-7084, OD:3,430) Gas LiN andrel/Dummy Valve 1 (7118-7116, OD:5.390) ~~ SEAL (7164-7172, OD:3.980) PKR (7172-7173, OD:5.090) SLOTTED ~-------- LINER (7173-11670, OD 4.500) Ped (7173-11670) SLEEVE-0 I_ (7229-7230, - `- SHOE - I ;11668-11669, OD 4.500) Ref LogDate: _ TD: 11700 f_tK Max Hole An le: 94 de a To Botton 10 0 117 5 0 7283 Sottom TVD ----- 7164 3755 St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO 1 7118 3749 CAMCO KBUG-M CAMCO DMY 1.0 BK-5 0.000 0 F' i- !, n !0 31700# . i-:eld Other lu s e ui .etc. -COMPLETION Depth TVD Type DescriQtion ___ 1 1 __ PATCH INSTALLED 6'4" SURFACE CASING PATCH, MEASURED FROI MANDREL HANGER; 9 5/8" API 40, .395" WALL 492 491 NIP CAMCO'DS' NIPPLE WITH 2.975" NO GO PROFILE I 7067 3739 GAUGE SENTRY PRESSURE GAUGE DISCHARGE -OUTSIDE TUBIN 7083 3742 SLEEVE-O BACK CMU W/2.813" NO GOPROFILE - OPENED 2/16/2007 7083 3742 PUMP JET PUMP #PH-1043 9A RATIO, #9 NOZZLE, #9 THROAT -set 7131 3751 GAUGE BAKER SENTRY PRESSURE GAUGE (INTAKE) 7164 3755 SEAL BAKER 80-40 S-22 LOCATOR SEALS 7172 3756 PKR Other plu s e ui ., et DETAIL .) - LINER c De th TVD T e _ _ Descri lion 7173 3756 SLOTTED LINER PPCO SLOTTED LINER W/TOOLS 7229 3762 SLEEVE-O BAKER CMD NON-ELASTOMER SLIDING SLEEVE -OPEN 11668 3753 SHOE • KRU OD Angle 20/2001 Angle Rev R Last l 1 C-135 api5L liner 3.958 3.430 3.958 YV~~~ ~V ~~ - ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open H©le/Mechanical Logs and/or Tubing (nspection(Caliper/ MTT~ The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal fetter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907j 245-6952 1) Caliper Report 2) v1 C as /_~v ~/ 6~a3 Signed Print Name: ~~a~~~ JllL ~ ~ 200$ Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RQ SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAX: (907)245-88952 E-WAIL: ~_ ^'~~f ~="3 ^~ .~5 ?^°- ~ WEBSITE r~r'~ 13-Ju1.08 1G135 1 Report/ EDE 50.029-23053-00 C:\Documents and SettingslOwner\Desktop\Ttansmit_Conoco.doc • • fl~emory Mult'aFinger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Wetl: 1C-135 Log Date: July 13, 2008 Field: Kuparuk Log No.: 8695 State: Alaska Run No.: 1 API No.: 50-029-23053-00 Pipet Desc.: 3.5" 9.3 1b. L-80 EUE 8rd MOD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvt.: 7,093 t=t. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the CAMCO DS Nipple ~ 492'. This log was run to assess the condition of the tubing logged with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing logged is in good to fair condition, with a maximum recorded penetration of 35% in joint 24 (782'). A line of pits broadening into a line corrosion is recorded from 150' to 1,280'. Other damage recorded appears mostly in the forms of isolated pitting and some areas of general corrosion. No areas of significant cross-sectional wall loss (> 6°k) or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS : Line Corrosion (35°r6) Jt. 24 ~ 782 Ft. (MD) Line Corrosion (34%) Jt. 30 @ 993 Ft. (MD) Line Corrosion (33°~) Jt. 33 ~ 1,088 Ft. (MD) Line Corrosion (32%) Jt. 23 ~ 769 Ft. (MD) Line Corrosion (30%) Jt. 19 C~ 626 Ft. (MDj MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (> 6%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded #hroughout the tubing logged. Field Engineer: K. Miller Analyst: HY. Yang Witness: C. Kennedy ProActive Diagnostic Services, Inc. j P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 v.~c ab)-~~ ~ ~~l0~3 • Correlation of Recorded Damag Pipe 1 3.5 in (26.8' - 7068.9') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 1 C-135 Kuparuk ConocoPhilips Alaska, Inc. USA July 13, 2008 . Approx. Tool De viation ^ A pprox. Borehd e Profil e 1 z ~ 27 so8 5(~ 1590 7 ~ 2373 10O 3159 ~ v '--' ;_ ~ ~ •- Z s c 125 3942 ~o p 15(~ 4723 175 5504 200 -- 6286 225 7069 0 5 0 1 00 Da mage P rofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 225 • • ___ PDS Report Overview z ~~. Body Region Analysis Well: 1C-135 Survey Date: July 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anat st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8rd MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) penetration body ;:,yu~„; metal loss body 200 150 ,~ 100 50 0 0 to 1 to 10 to ZO to 40 to over 1% 10% 20% 40% 85% 85% Number of 'oints anal sed total = 228 pene. 0 47 145 36 0 0 loss 69 159 0 0 0 0 Damage Configuration (body ) 100 80 60 40 20 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 131 95 8 28 0 0 Damage Profile (% wall) ~ penetration body ~ metal loss body 0 50 100 1 48 98 148 198 Bottom of Survey= 225 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd MOD Well: 1C-135 Body Wall: 0.254 in Feld: Kuparuk Upset Wall: 0.254 in Company: ConoooPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 13, 2008 Joint No. Jt. Depth (Ft) I'~.~n. Utsc~t Ilrn.) Pen. Body (Ins.) I'c~n. `% ~1c~6i1 I~~" °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 27 t) 0. 3 1 ~ ' 2.97 1.1 58 a 0.0 ~) (~ 2.97 Pu 1.2 67 t) 0.02 7 I .96 Pu 1.3 77 t) 0.02 ~~ t) 2.9 Pu 2 87 U 0.05 1U _' .94 Iso a ed ittin 3 118 l) 0.06 ~' ~ 2.95 Isolat d ittin 148 U 0.0 1 ti 2.94 Line of its. 5 180 U 0.06 Z4 :.' .94 Line of its. 211 l) 0.05 Zt) ~' 2.96 ine of its. 7 243 t) 0. 25 ? 2. 4 Lin of its. 8 73 t) 0.06 ~'-1 Line corrosion. 305 t) 0.05 ? I 2.96 ine of its. 10 335 U 0.06 ~'Z 2 94 Lin of its. 11 66 l1 0.06 Z S _' 2.94 Line cor osion. 1 39 t) 0.06 ?4 _' 2.95 Line of 'ts 13 29 i) 0.07 Z~l 2.94 Line of its. 14 461 t) 0.06 _~5 i 2.94 Line cor io . 14.1 492 t ~ 0 U ~ t 2.88 CAMCO DS Ni e ith 2.975" No Go Pro le 15 494 t) 0.06 ~'S 2.94 Line corrosion. 16 25 U 0.07 17 i 2 97 Line corrosion. 17 557 t) 0.07 ZE> -t .96 ine corrosion. 18 88 U 0.06 14 a 2.96 Lie rrosio . 19 620 l) 0.08 3t) S 2.95 ine corrosion 20 651 l) 0.06 _'S t 2.93 Line corrosion. 2 682 t) 0.06 ~ "; _' i e r 'on. 22 714 U 0.08 al) _' 2.94 Line corrosion. 23 745 t) 0.08 S? i 2.94 Line corrosio . 24 777 O 0.09 t5 ~ 2.95 Line corrosion. 5 80 U 0.07 ?~ ~ 2.95 Line corrosi n. 26 840 t~ 0.07 ?2~ ~ 2.94 Line corrosion. 7 70 U 0.07 Z7 i 5 ine c rr ion. 28 902 !) 0.07 28 -1 2.94 Line corrosion 9 933 U 0.07 ~(> 2.95 Lin corrosio . 30 964 t) 0.09 >4 •1 2.94 Line corrosion. 31 996 t) .07 ?tf -3 .95 Line corrosion. 32 1027 U 0.08 3U -1 2.95 Line corrosion. 33 1059 U 009 ~ ~ -1 2.93 Line Corr Sion. 34 1090 t) 0.07 ZS 2.95 Line corrosion. 5 11 1 U 0.05 Zl) 2.95 Line corrosio . 36 1152 tt 0.06 25 ~ 2.95 Line corrosion. 37 1183 t) 0.07 ~8 1 2 94 Line rrosion. 38 1215 U 0.05 Z 1 ~' 2.93 Line corrosion. 39 1246 U 0 04 1' ~ 2.9 Line rrosion. 40 1277 t) 0.04 I' -1 2.94 Shallow ittin . 41 130 U .05 1') 2.94 Shal ow itUn . 42 1340 t) 0.05 2u 2.94 Shallow ittin . 43 1371 U 0.05 1 ~~ 2.94 hallow ittin . 44 1402 tt 0.04 15 ! 2.93 Shall w itti 45 1433 tt 0.05 '~t 2.92 Sh Ilow itUn . 46 1465 ? 0.04 ~ ~ ~ 2.94 Shallow ittin , Penetration Body Me~il Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd MOD Well: 1C-135 Body Wall: 0.254 in Field: Kuparuk Upset Wafl: 0.254 in Company: ConocoPhiAips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 13, 2008 Joint No. Jt. Depth (Ft.) I'<~n. Upset (Ins.) Pen. Body (Ins.) I'cn. % Ul~•t,~l I vss ,~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 47 1496 tl 0. 3 13 2.96 Shallow i ti 48 1528 U 0.04 15 s 2.95 Shallow it>in . 49 1559 tl 0.04 17 _' 2.94 Shallow ittin . 50 1590 It 0.04 17 _' .96 Shallow item . 51 1622 (I 0.05 1 ~) ~ 2.91 Shal ow itUn . 1653 U 0.04 5 2 .96 Shal ow itUn . 53 1684 U 0.03 13 ~ 2.95 Shallow itUn . 54 1715 tl 0.04 14 _' .94 Shallow ittin . 55 1747 U 0.04 14 3 2.95 Shall w i tin . 56 1778 U 0.04 1 (i 2 2. 5 Shallo ittin . 57 1810 U 0.03 13 :.' 2.94 Shallow it6n . 58 1841 tl 0.03 1 S 2.93 Shallow itUn . 59 1873 U 0.03 I Z ~ 2.96 60 1904 tt 0.04 17 2 2.95 Shallow itUn . 61 1936 tt 0.03 1:3 ~ 2 95 Shallow ittin . 62 1967 tl 0.04 14 Z 2.95 Shallow itUn . 63 19 8 U 0.02 ~) .' 2 95 64 2029 U 0.03 11 ? 2.9 65 2061 U 0. 3 12 I .94 66 2091 tl 0.04 14 s 2.95 Shallow 'tUn . 7 2123 U 0.04 15 .94 Shallow ittin . 68 2154 U 0.04 17 2.95 Shallow itU 69 2184 U 0.03 13 295 Shallow itrin . 70 2216 0 0.04 1(~ I 2.96 Shallow itun . 71 2247 0 17 Z 2.95 Salto ittn . 72 2279 tl 0.03 1 t _' 2.94 Shallow itUn . 73 2310 t~ 0.05 1 ~1 2 94 Shal w itUn . 74 2342 U 0.04 16 1 2.94 Shallow ittin . 75 373 U 0.04 14 _' 2.95 Shallow itfin 76 2405 O 0.03 12 1 2.95 77 436 U 0.05 19 2.96 Shallow itti 78 2468 U 0.04 17 ! 2.93 Shallow itlin . 79 2499 tl 0. 3 1 ~ 2.96 Shallow itU 80 2530 U 0.04 17 I 2.95 Shallow itUn . 81 256 U 0.04 17 I 2.95 Shallow itU 82 2593 a 0.03 11 2.95 83 2625 U 0 03 12 I 2.95 84 2656 ~1 0.04 16 I 2.93 Shallow ittin . 85 2688 11 0.04 14 I 2.95 Shallow itfin . 86 2719 0 0.04 15 l 2.94 Shallow ittin . 87 2750 0 0. 3 1:~ 2.94 Shallow it' 88 2782 ll 0.04 14 I 2.94 Shallow itUn . 89 2813 tl 0.02 ~~ it 2.91 Pittin in t. 90 2844 It 0.03 I t 1 2.94 Shallow itUn . 91 28 6 tl 0.04 14 1 .92 Shallow ittin . 92 2907 ~ ~ 0.03 I I I 2.93 9 2939 II 0.02 ~~ 2.95 94 2970 U 0.03 1O ~' 2.93 95 3002 ~? 0.03 Li ? 4 S Ilow it'n . 96 3033 ~ ~ 0.03 1 1 ~' 2.93 _ Penetration Body Metal Loss Body Page 2 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd MOD Well: 1C-135 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company. ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 13, 2008 Joint No. Jt. Depth (Ft.) I't~n. lll~,a~t (lns.) Pen. Body (Ins.) Pc~n. `ib Mct;+l 1cn~ ~. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3065 t) 0.04 I V 3 Shallow itGn 98 3096 t) 0.03 I " 2.92 99 3127 t) 0.04 14 2.94 hallow ittin 100 3159 t) 0.03 1 1 ' 2.95 1 1 3190 U .0 1O ? 2.92 102 222 t) 0.03 11 ~ .93 103 253 U 0.0 15 ~ 2.94 Shallo 'tsin . 104 3285 U 0.03 1 ~' _' .94 105 3316 U 0.03 12 1 2.94 106 3348 U .04 17 ? 2.95 Shallow ~t4n . 107 3379 U .0 11 .96 108 3410 ~~ .04 17 ? 2.96 Shall w itUn . 109 3442 ~) 0.03 I i I 2.94 Shallow ittin . 110 3473 U 0.02 ~~ 2.9 111 3 4 t) .03 1 U 1 2.96 112 3535 I ~ 0.0 ~) 2.95 113 566 U 0.04 15 I 2.95 low itiin . 11 3597 t ~ 0.03 1 1 I .93 115 3629 tl 0.02 7 _' 2.94 116 3660 l1 0 03 I 1 I 2.93 117 3692 t~ 0.07 ~'t?' _' 2.94 Isdated ittin 118 3723 U 0.03 I O I .93 119 3754 t) 0.04 I5 .' 2.94 Shallow it~n . 120 3786 t) 0.03 13 ? 2.94 Shallow ittin . 1 3 7 ' 4 122 3849 ~ ~ 0.02 t3 _' 2.94 123 3880 t ~ 0.02 ~3 .' 2.94 124 3910 a 0.04 17 I 2.91 Shallow ittin . 125 3942 U 0.0 4 I 2.93 Shallow itti 126 3973 t) 0.04 15 I 2.94 Shallow itUn . 127 4005 n .04 16 I 2.93 Shallow 't 128 4036 n 0.04 14 ~ 2.95 Shallow ittin . 129 4068 a 0.03 12 I 2.93 130 4099 t) 0.03 1 1 1 2.95 131 4130 t) 0.02 9 _' 2. 5 132 4162 t ~ 0.03 1 Z 1 2.94 1 3 4193 t~ 0.03 l ~ 2.93 Shallow ~tUn . 134 4225 U 0.04 I b I 2.93 Shallow ~tUn . 135 4256 U 0.03 12 t~ 2.93 Shallow it'n . 136 4286 t) 0.03 1 ~' 1 2.92 137 43 8 t) 0.03 1 1 1 .94 138 4349 I ~ 0.03 13 ~ 2.94 Shallow itti 139 4381 a 0. 4 14 1 2.93 Shallow 'ten . 140 4412 t I 0.03 I Z 1 2.95 141 4443 U 0.04 15 ~ 2. Sh Ilow itUn . 142 4475 t> 0.03 11 I .94 14 4506 U 0.03 1 Z 1 2.94 Shallo itti 144 4537 t~ 0.04 14 I 2.92 Shallow itUn . 14 4567 i) .0 s3 I 2.95 146 4598 ~. ~ 0.03 I ~ ~ 2.92 Penetration Body Metal Loss Body Page 3 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd MOD Well: 1 C-135 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 13, 2008 Joint No. Jt. Depth (Ft.) Pc~n. Ul~~c~t (lns.l Pen. Body (Ins.) Pen. % ~tct.~l Los °4> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 147 4630 n 0.04 14 2.94 Shallow iton . 148 4660 t? 0.03 11 I .92 149 4692 tt 0.04 14 ,' 2.92 Shallow iton . 1 4723 tt 0.06 22 _' 2.93 Isolated 'ttin 1 1 4754 U 0.06 12 ~' 2.94 Isolated ittin 152 4786 c) 0.04 15 1 2.92 Shallow iton 153 4817 tr 0.03 13 U 2.91 Shalo iton . 154 4848 U 0.05 1 £i I 2.93 Shallow iton . 155 4880 U 0.03 12 1 2.93 156 4911 U 0.03 1 Z 1 2.9 57 4942 O 0.0 10 1 2.93 158 4974 (I 0.03 11 2.93 1 9 004 t I 0.02 9 2.94 160 5036 tl 0.04 17 I 2.93 Shallow iton . 161 5067 tI 0.03 11 2.93 162 5097 c 1 0.03 1 1 2.91 163 5129 (t 0.03 11 1 2.92 64 5160 a 0.03 1 Z _' .94 165 5192 a 0.05 ZO I 2.94 Shallo ion . 166 5223 t t 0.02 ~~ I 2.93 167 5255 a 0.03 13 I 2.93 Shallow iton . 168 5286 U 0.04 1 ~ I 2.93 Shallow itUn . 169 5317 U 0.03 11 _' 2.92 170 5349 U 0.04 16 I 2.93 Shallow ito 1 1 5379 U 0. 3 1~ 1 3 172 5411 t ~ 0.03 12 2.93 173 5442 t t 0.03 1 1 2.94 174 5474 U 0.05 2tt I 2.91 Isolated ittin 175 5504 t 1 0.03 1 ~ I 2.95 176 5535 tI 0.02 ~) ? 2.93 177 5565 U 0.03 1:3 I 2.93 Shallow iton . 178 5596 t I 0.02 ' 2.93 179 5628 tI 0.03 1I Z 2.93 180 5659 U 0.03 11 1 2.94 181 5691 (1 0.03 11 ~ 2.94 182 5722 tI 0.04 1-1 I 2.94 Shallow iton . 183 5753 t) 0.04 1.1 Z 2.92 Shallow iton . 184 5785 t t 0.03 I 1 2.93 185 5816 U 0.02 9 _' .93 186 5847 t) 0.03 1 1 _' 2.93 187 5879 a 0.04 14 1 2.91 Shallow ittin . 188 5910 0 0.03 1 ~' 1 2.91 189 942 t) 0.02 9 I 2.9 190 5973 t t 0.02 9 ? 2.93 191 6005 t t 0.02 ~) I 2.95 192 6036 a 0.04 14 2 2.94 Shallow iton . 193 6067 t t 0.02 8 ~' 2.94 194 6099 t t 0.02 ~) 2.91 195 6129 i t 0.03 I Z ~ .93 196 6161 ~ ~ 0.03 ': I _' 2.93 ®Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd MOD Well: 1C-135 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 13, 2008 Joint No. Jt. Depth (Ft.) f'c~n. tll,~c~l (Irn.) Pen. Body (Ins.) I'c~n. °S, Met~il Lutis ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 197 6192 ~) 0.03 13 2.91 Sha I w itUn . 198 6223 U 0.03 12 2.93 199 6255 ~~ 0.03 11 _' 2.94 200 6286 l) 0.03 1(1 .93 201 b317 O 0.03 l0 2.94 202 6349 l) 0.02 FS O 2.93 203 6380 U 0.03 1O _' 2.94 204 641 (1 0.04 14 ? 2.92 Shallow itUn . 205 6443 U 0.02 ') 1 2.93 206 6474 U 0.02 £3 Z 2.93 207 506 ~ 1 0.0 2. 5 208 6536 ~~ 0.03 1 i I 2.94 Shallow 't6n . 209 6568 t ~ 0.0 ~, 2.94 210 6599 a 0.01 r, 2.95 211 6630 (~ 0.03 11 ~ .94 212 6662 ~ ~ 0.02 ') _' 2.94 213 6692 a 0.02 t3 2 2.93 214 6723 t~ .02 ') ' .93 215 6755 ~ 1 0.03 t O 1 2.94 216 6785 ~~ 0.03 11 _' 2.94 217 6817 a 0.03 1 u _' 2.93 218 6848 (~ 0.03 11 ? 2.92 219 6879 ~ ~ 0.02 ? .92 220 6911 a 0.02 ~~ -3 2.94 2 1 694 0 0. 13 3 2.94 Shallow itUn . 222 6974 ~~ 0.04 16 ~' 2.92 Shallow itlin . 22 7006 ~> 0.03 1 ,? 2.93 Shallow ~tUn . 224 7037 i~ 0.03 !~! _' 2.94 Lt. De osits. 225 7069 ~ ~ 0.02 2.95 Penetration Body Metal Loss Body Page 5 PDS Report Cross Sections ~ ~~ .. Well: 1C-135 Survey Date: July 13, 2008 Feld: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, fnc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE 8rd MOD _ _ Analyst: HY. YdnQ Cross Section for Joint 24 at depth 782.133 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 14 ° Finger 24 Penetration = 0.09 ins Line Corrosion 0.09 ins. = 35°h Wall Penetration HIGH SIDE = UP ~ ~S PDS Report Cross Sections Wet-: 1C-135 Survey Date: July 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8rd MOD Analyst: HY. Yang Cross Section for Joint 30 at depth 993.143 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 19 ° • U Finger 24 Penetration = 0.086 ins Line Corrosion 0.09 ins. = 34% Wall Penetration HIGH SIDE = UP ConocoPhillips Alaska, Inc. KRU 1C-135 1 C-'135 API: 500292305300 Well T : PROD An le TS: d TUBING (a716a, OD.3.~ SSSV Type: Nipple Orig Com letion: 12/20/2001 Angle ~ TD: 91 deg @ 11700 , iD:z.9sz) Annular Fluid: Last W/O: Rev Reason: Set JET PUMP Reference L Ref L Date: Last U ate: 8/14!2007 SURFACE Last Ta : 11366 CTMD TD: 11700 ftK6 (x7263, ~ Last Ta Date: 9/2/2003 Max Hole A le: 94 d 8038 v vtie ioj Ces'n Strip -ALL STRI NGS NIP (492-493, Descri lion Slze To Bottom ND Wt Grede Thread 00:3.500) CONDUCTOR 16.000 0 117 117 62.50 api5L 0-B SURFACE 7.625 0 7283 3766 29.70 L-80 BT&C Tubi Strip -TUBING - - Size To Bottom ND Wt Grade Thread 3.500 0 7164 3755 9.30 UESrdMO Pertorations Summa Interval TVD Zone S~tus Ft SPF Date T e Comment 7173 - 11670 3756 - 3753 WS D 4497 99 1220/2001 Slotted Perfs thru slotted liner SLEEVE-O (7083-7084 6 Lift M a e1sJVeIVes , 00:5.495) PUMP St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt (7oe3ao64, 1 7118 3749 CAMCO KBUG-M CAMCO DMY 1.0 BK-5 0.000 0 4/7/2002 1 00:3.430) ~ 1. PT 1, A to 3000#. Held Oth r I s ui . tc. - COMPLET O De th T Deecri lion ID Gas Lirt -- -- Z 1 1 PATCH INSTALLED 6'4" SURFACE CASING PATCH, MEASURED FROM MANDREL HANGER' 9 5/8" API 40, .395" WALL 0.000 ind"~~D~n"'y varve 1 . 492 491 NIP CAMCO'DS' NIPPLE WITH 2.975" NO GO PROFILE 2.875 (71187119, 7067 3739 GAUGE SENTRY PRESSURE GAUGE DISCHARGE -OUTSIDE TUBING 0.000 00:5.390) 7083 3742 SLEEVE-O BACK CMU W/2.813" NO GO PROFILE -OPENED 2/162007 3.430 7083 3742 PUMP JET PUMP #PH-1043, 9A RATIO, #9 NOZZLE, #9 THROAT -set 5/32007 0.000 7131 3751 GAUGE BAKER SENTRY PRESSURE GAUGE INTAKE 0.000 7164 3755 SEAL BAKER 80-40 S-22 LOCATOR SEALS 3.000 7172 3756 PKR 4.000 Ot r l s i .etc. - N ETAI De th T Descri Lion ID 7173 3756 SLOTTED LINER PPCO SLOTTED LINER W/TOOLS 3.958 7229 3762 SLEEVE-O BAKER CMD NON-ELASTOMER SLIDING SLEEVE -OPEN 3.430 sEAL 11668 3753 SHOE 3.958 (7164-7nz, 00:3.980) PKR (7172-7173, 00:5.090) SLOTTED LINER (717311670, 00:4.500) PCrt (7173-11670) SLEEVE O - 1 - (7229-7230, 00.5495) SHOE 1166811669, 00:4.500) I - ~ ~ . . Conoc~illips Alaska RECEIVED APR 1 8 Z007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 16, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 a 0 l- :;2.;J-O Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~ ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ~prl , Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1 C-25 119-031 9'4" 0.8 14" 4/14/2007 3.8 4/15/2007 1C-119 201-139 25'6" 4.8 16" 4/14/2007 5.4 4/15/2007 1C-121 201-080 11' 2.0 18" 418/2007 8.6 4/15/2007 1C-131 201-185 12' 1" 1.8 16" 4/8/2007 6.8 4/1512007 1C-135 201-220 11' 1.3 10" 4/8/2007 2.4 4/15/2007 1 C-172 203-095 10' 8" 1.5 18" 4/14/2007 6.6 4/15/2007 1 H-02 193-008 14'6" 2.0 4/5/2007 3.3 4/15/2007 1 H-09 193-029 11" n/a 11" n/a 4.9 4/1512007 1 H-17 192-130 20" n/a 20" n/a 7.5 4/15/2007 Kuparuk Field A 116 2007 . ~/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEI\/ED N 3 1 2007 Alaska Oil & G·. f' as 1..005. Commission Anchorage January 30, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 :iCANNED FEB 0 1 2007 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. welllC-135 (PTD 201-220). The reports record the completion of the surface casing excavation, inspection, and repair on the well. . Please call Jerry Dethlefs or MJ Loveland at 659-7043 or Marie McConnell or Perry Klein at 659-7224 if you have any questions. Sincerely, ~c~ Jerry Dethlefs Well Integrity Projects Supervisor . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 201-220/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23053-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 91' 1C-135 8. Property Designation: P I ,.,ø? 10. Field/Pool(s): Kuparuk River Unit Aþc... ,~-¡'cff~ ).Ç't,r;O Kuparuk River Field / West Sak Oil Pool , 11. Present Well Condition Summary: Total Depth measured 11700' feet true vertical 3753' feet Plugs (measured) Effective Depth measured 11366 feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 117' 16" 117' 117' SURFACE 7192' 7-5/8" 7283' 3766' RECEIVE[) Perforation depth: Measured depth: 7173-11670 slotted liner JAN 3 1 200! true vertical depth: 3756-3753 4Iask:, Oil & Gas Cons. Commission Tubing (size, grade, and measured depth) 3-1/2" , EUE8RDMOD, 7164' MD. Anchorage Packers & SSSV (type & measured depth) pkr= pkr= 7172' SSSV= NIP SSSV= 492' 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 Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubina Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A jf C.O. Exempt: 306-339 Contact Jerry Dethlefs / MJ Loveland Printed Name »'QVeland 0 ---"2-_ Title Well Integrity Proj. Supv. Signature ¿;IC - ~~ Phone ?.s:7-?oý"3 Date 1/30/07 ....../-.-; " P amn AII~IJn-DrAke 263-4612 / -[;:7 RBDMS aFt FE8 0 ! 2007 h~ ~I> (' "3("? ....0........ . .I f,t1rJ. Form 10-404 Revised 04/2004 (\ S~ngmal ~ . 1 C-135 DESCRIPTION OF WORK COMPLETED SUMMARY . .' Date Event Summary 1/18/2007 Cutout 9' 7" of conductor. Did not cutoff landing ring at top of conductor. Cleaned up pipe for inspection. 1/23/2007 Install SC Patch, Initial T/I- SilO. Purged N2 across IA. Assist welders install patch. Welded two 6" wedding bands and MT (passed). Welded 70" patch. ( API 40 9 5/8" .395" wall) Total patch lengt 1/25/2007 MITIA ( Post SC patch) - Passed. Initial T/I=SIIO. Pressured up IA to 3000 psi with 4 bbls diesel. Start MITIA T/'= S1I3000. 15 min reading T/I = S1I2950. 30 min reading T/I = SII 2950. 45 min reading T/I= S1/2950. 60 min reading T/I= S1/2950. Bled IA to 0 psi. Final T/I= SilO. Wrapped exposed SC wI Denso paste and Denso wrap. 1/27/2007 Conductor Installation, T/I= SilO. Install and weld 151" section of62.5 #, API Gr B Conductor. Final T/'= SilO. l- . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 [907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection[Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1 ] 1 Report 2] 1 Report 3] 1 Report 4] 5] 6] 7] Signed: Print Name: 1C - 135 MTT Log 8-Sep-06 dO' - é)[)Ò V 1 C - 178 MTT Log 8-Sep-06 Ð03 - ûi..{ I 1 C - 184 MTT Log 8-Sep-06 :)03-0 iiC¡ .sÇANiMEK) ~: (\;1 --- c.,~ í "; h I/l e fllo 1 VI /1 Q(A RECEIVED OCT 0 4 2006 .~ ,# ''''''._n__ __.... ____._ r- ".,_.. . Date: 4,laska Oil & Gas Cons. Commission Anchorage PRoACTIVE DIAGNOSTIC SERVICES. INC., 130 W.INTERNATIONAl AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245~8952 E-MAil: PDSANCHORAGE@MEMORYlOG.COM WEaSITE : WWW.MEMORYlOG.COM D:lOO ]DSANC-20061Z _ WordlDisbibUlionl Tran.miltal_ Sheel.1 Transmil_ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: ConocoPhillips Alaska, Inc. September 8, 2006 6601 1 3.5" 9.3 Ib EUE 8rd MOD Tubing 7.625" 29.7 Ib BTC L-80 Production Casing 16" 62.5 lb. api5LO-B Conductor Pipe Well: 1C-135 Field: Kuparuk state: Alaska API No.: 50-029-23053-00 Top Log Intvl.: Surface Bot. Log Intvl.: 180 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 180 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 117 Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log ofthis well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3-112" tubing and 7-5/8" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (173'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3-1/2" tubing, 7-5/8" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval 0' -180'. A log plot of the entire log interval, plus a detailed section of the interval showing damage is included in this report. The Delta Metal (%) curve in these plots refers to total metal surrounding the MTT tool and the results show one interval of metal loss in this log interval from the mandrel hanger to 6.5' below the mandrel hanger. A maximum of -16% circumferential metal loss is recorded in the interval between 0' and 6.5'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3-1/2",7-5/8" and 16" pipe. If all of the metal loss is specific to the 7-5/8" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3-1/2" tubing or 16" conductor. I Field Engineer: N. Kesseru Analyst M. Lawrence & J. Burton Witness: T. Sandon I T/77497 RECEIVED PDS({~:' !ren~¡or'/toº, corn ProL\ct!\/2 Diaanostic Servìces< - . 565-'9D85 OCT 0 4 Z006 565-1369 F·rnaH; 6.59-231 ':1- 659-~23C7 Fax: 80 I.... 880 ~ Oil & Gas Cons. Commission Anchorage I I I I I I I I I I cl2s. Magnetic Thickness To og (8Hz Pass) PnoAcrivE DIAq""""ïc SEmII""" INC. - m_ d\warrior\data\1 c-135\1 c135. db Kuparuk/1C135/run1!u8a.1 2 scale Tue Sep 1210:54:082006 by Calc Sondex Warrior V7.0 Depth in Feet scaled 1150 Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: I r:-,... -.. '" ".,... 2 -6.8 MTTP01 (rad) MTTP12 (rad) o Line Speed (ftlmin) -200 aw. Tr~ ~ I I ¡ I a ,. ! «"-<11II" - 7-518" Casif)! Collar f-- 16% M8talELOSS ! I u__ < ' , Jt. 1 ---- --- 20 W', tf:i3-~/2"~( -- ~~Ollar -~ ~"ti Pup Jt. 1.1 :';:1IZ' COlla;'*Ff7-S/8" Ca,;ng Collar I I Pup Jt. 1.2 - 3-1/2" Collar-- - ~'I __ PupH3 ~ ~-=r1!~'IIÇ~I~ ~ ~..~'*''"' ¡:;n I I I I I I I I it - -ll I <:\1 I ~- -- I- ------ " f--- - ..- c·---- ,-- - .. - Jt. 2 " ~- 80 'i r-5/8" CaSing Collar 3-1/2" Collar ---- , T I I I -- - 12 3.2 - - -'" :-- - - _.~. I I I I I I I I I I I I I I I I I I I ')1 1\ I 100 Jt 3 ductor I-- 1 120 -~ -·-1---- ---- -- ----_.-- ~- Casing Collar , , 1 I I r ... I [!I... ~ Jt. 4 -- 140 ....f.- ~ - ~ - E: -- I I-- ~.~- I t ~ - « ,¿ ";] I .. J "j¡ 'i 160 ~ '>- ? 1 õ:FÞ -1 - r ";F -t'" - ....._.- -- --- -.-- I---.f--_. 1--- -~ - 11 ~7-5!8" Casing Collar -I' Jt 5 ;;;:- - t ?- - I ;.. =-- I - -. ---~-- ------- 1- -- -- ~Metal Loss (%) .---- ~ 180 ;} :;g. - 50 2 MTTP01 (rad) 12 0 Une Speed (ftlmin) -200 -6.8 MTTP12 (rad) 3.2 I I I I I I I I I I I I I I I I I I I cfa6. PnoAcrivE DIAq""""1c SERvicES, iNC. Detail of Recorded Metal s Feature 0' - 6.5' Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: d\warrior\data\1 c-135\1 c135. db Kuparuk/1C135/run1/u8a.1 2 scale Tue Sep 1210:54:082006 by Calc Sondex Warrior Vl.O Depth in Feet scaled 125 -50 o - Delta Metal Loss (%) 50 Line Speed (ftlmin) -200 2 -6.8 MTTP01 (rad) MTTP12 (rad) 12 3.2 o Y&a ndre I Han 3J!2" COII~jF 0 I I I ¡:;: , ' 1:::1- 16% Metal Loss \,.." ~ Þi~I~: Þ; ( ') '" [),. ::> ;:"::Þ--:::::::: ~ ¿ ¡~:1 ( I~: . < (S /' D < (I <::: /'" ;; l:> .----;> (:::> r '/' ~þ +-7-5/8:'Casir"Cûllar '7 <::J; :r; ~~, ;C~~: f RJ~;'~ I I ~ : þ [~~., ~ ':1:.,,' ~ -1tJ IrT~~l:::::::>., :1, I C '<¡-".:::::>::: :~~ ::-:;;; r- !_,~- '"-:'; ~,.¡ ~\."'" I )II~( ': \ t }2 ).) +- Indication of Clean 7-5/8" caSinß' I <~S ¡'¿f\ > < <. ( -65' be'iW ¥andrel Hanger) I ,Þ { ! j Þ :; {{ I_L__. __ <: S'! f?> I / c) ~{ (~/::. r I 1 ~; 1\ & i r ~ ~ ~: Ìí' ';~þ. II I I ":;~-I~~,.I(~ r::> ,þ ~ ..;!;;::)~;:::> l~ ~t> I :; " /" ?" - -- If ': " I ';::::~ ) '::) .,. ;> / <.-' 1/ --I " 10 ,-> 5 I i c~ <:: <~ I Š 1 C~O= ~I t:~;: SF") i !?> l.:;:~ JÞI'~' > I~:;;~ ::, ¡~> > < > <þ!~~ < > , ;> ",¡¡> ( -':¿" <:~? <: '> (;¡ ç ~, [ ~~ I? I ~ (:~=) ~~{~ <~ II) )? <;~ ~~ > ~ I}r~~ i~~r~~ JL)! c ,:1 r~Ç ~~~ ~ r~, I~¡>;~ I t~- (I \.,,! (J . I) "þ ('_ <; I¡~=;*, MTTP01 (rad) MTTP12 (rad) ,1- .>"" "- _.._~ ~ ) I 3-1/2" Jt. 1 -50 Delta Metal Loss (%) 50 -200 2 12 Line Speed (ftlmin) -6.8 3.2 I I I I I I I I I I I I I I I I I I I TUBING (0-7164, 00:3,500, 102,992) SURFACE (0-7283, 007625, WL29 70) SLEEVE-C (7083-7084, 005495) Gas Lift on<talOummy Valve 1 (7118-7119, 005390) SEAL (7164-7172, 003980) PKR (7172-7173, 005,090) SLOTTED LINER (7173-11670, 004500) Perf (7173-11670) SLEEVE-O (7229-7230, 005495) SHOE (11668-11669, 004500) KRU 1 C-135 API 500292305300 SSSV Type Nipple Annular Fluid' Ref Lo Date: TD: 11700 ftKB : 94 de 8038 Bottom TVD Wt Grade Thread 117 117 62,50 api5L O-B 7283 3766 29,70 L-80 BT&C Thread Desert ion PPCO SLOTTED LINER WfTOOLS ID 3,958 BAKER CMD NON-ELASTOMER SLIDING SLEEVE - OPEN 3.430 3958 Deser! ion CAMCO 'OS' NIPPLE WITH 2,975" NO GO PROFILE SENTRY PRESSURE GAUGE DISCHARGE - OUTSIDE TUBING BACK CMU W/2.813" NO GO PROFILE CLOSED 9/2/2003 BAKER SENTRY PRESSURE GAUGE INTAKE BAKER 80-40 S-22 LOCATOR SEALS JD 2875 0.000 3.430 0,000 3.000 4,000 . . FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 MJ Loveland Well Integrity Proj. Supv. ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK9951 0 -...-~~- .......... ,~...~-,......,.-- Re: Kuparuk River Field, West Sak Oil Pool, lC-135 Sundry Number: 306-339 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thiS¥- day of October, 2006 Encl. 00 /- 0.]0 . Conoc;pí,illips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 . RECË\VEO OC1 0 3 '{dÛb . " C_$S\GU (n&üascons. . l\\as¥.8 \ þ.,nc"otage Dear Mr. Maunder: Enclosed please find the 1 0-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well1C-135 (201-220). The request is for approval to pro actively excavate and inspect production casing for external corrosion and repair if needed. Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. Ã'µ MJ~d Problem Well Supervisor Attachments . IJ"ìð Iðj~. !"'¡ '"\ RECEIVED STATE OF ALASKA ALASKA O/LAND GAS CONSERVATION COMMISSION OCT 0 320Gb APPLICATION FOR SUNDRY APPROVAL AI k Oil & Gas Cons. Commission 20 MC 25 280 . as a 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 - Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchoraç¡e, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes fJ No [2] 1C-135 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit ¡t Þ (,. Z. 'S (,.e;-o ,ó/:> þ- J .OÞ RKB 91' Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4. Current Well Class: Development 0· Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill Number: 201-220. 6. API Number: 50~029-23053-00 8. Well Name and Number: 12. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 11700' 3753' 11366 Casing Length Size CONDUCTOR 117' 16" SURFACE 7192' 7-5/8" MD TVD Burst Collapse 117' 117' 7283' 3766'· 6890 psi 4790 psi Other: ~\;¡;('. .t:~\,)~L\-c\~'C)~~\W;::\.~~ ,~_~~~~ C_tJ.5?\-~ . ~ 1:::\ '( \ _ '\ - ~r '-. " \' ro\c, eJa'--'-' I-^<è"-\o.\-= Z 7' <"'G.". \.--" ~ """~ ""~.... 5'_"">lFo"" R",;""" '-\1:\'-\ r /I.. R8DMS BFl OC1 05 1006 (1j/J A'/~ ~ I /...~ \ Approved by: rr... rx I 10', .. 1/ ^ Form 10-403 Revised 06/2006 lJT\ I t W A L Perforation Depth TVD (ft): 3756-3753 Tubing Size: ." 3.;.1/2" Perforation Depth MD (ft): 7173-11670 slotted liner Packers and SSSV Type: pkr= SSSV= NIP 13. Attachments: Description Summary of Proposal 121 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Operations: 11/1/06 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correC7'to the best of m nowledge. Printed Name MJ Loveland / Signature ..$/ k.d~ / ' Commission Use Only Packers and SSSV MD (ft) pkr= 7172' SSSV= 492' Date: 14. Well Class after proposed work: Exploratory 0 Development [2] 16. Well Status after proposed work: Oil 121 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone 659-0743 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 lONER APPROVED BY THE COMMISSION Tubing Grade: EUE8RDMOD Tubing MD (ft):. . 7164' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Jerry Dethlefs / MJ Loveland Well Integrity Proj. Supv. ~ /01. 9' /ð<'( , Date Sun~ry Number: ~3q n_l.. ..:2. ,"'1 UO - ~<C Date: I{)-¥~ !. Submit í!J...Duplicate 41 ..;,..., .7 ~"'i \0 r~I" . . ConocoPhiIlips Alaska, Inc. Kuparuk We1l1C-135 (PTD 201-220) SUNDRY NOTICE 1 0-403APPROV AL REQUEST September 29, 2006 This application for Sundry approval for Kuparuk (WestSak) well1C-135 is for the proactive J inspection and possible repair of the production casing near surface. This well is a single casing surface powered jet pump well that has no surface casing. It was completed in 2001 and has been on surface power jet pump lift since 2004. This well is in an area that has a recent rash of production casing leaks to surface. 1 C-135 has shown no signs or indications of a production casing leak however ConocoPhillips requests approval to pro actively excavate ~ 10', cut a window in the conductor and inspect the production casing in this well. If damage is present a patch will be installed. With approval, inspection and possible repair of the production casing will require the following general steps: 1. Safe-out the well aS1.1eeded with a tubing tail plug. 2. Remove the floor grate and equipment rrom around the wellhead. 3. Install nitrogen purge equipment for the conductor (and IA if needed) so that hot work may be conducted in a safe manner. 4. Cut away the conductor casing and remove cement around surface casing for inspection. A window will be cut in approximately the top ten feet of conductor to provide access to the production casing for inspection. Notify AOGCC Inspector for opportunity to inspect. 5. CP AI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 6. If a patch is required, QA/QC will verify the repair for a final integrity check. 7. Install anti-corrosion coating as specified by CP AI Corrosion Engineer. 8. Replace the conductor and fill the void with cement and top offwith sealant. 9. Backfill as needed with gravel around the wellhead. 10. Remove plugs and return the well production. 11. Pile 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 9/29/2006 Lrwu: ~UIlUl;Urllllllp~ CJi..\.,i:1Vi:1UUlJ (X, l'-~palJ llUJ~""'LJ -.- ~ Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 'fo: Lou Grimaldi <Iou _grimaldi@admin.state.ak.us>, John Spaulding <john_spaulding@admin.state.ak.us>, John Crisp <john_crisp@admin.state.ak.us>, Jeff Jones ¡<jeff jones@admin.state.ak.us>, Chuck Scheve <chuck _ scheve@admin.state.ak.us>, Jim Regg <jim_regg@admin.state.ak.us> - All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <N1878@conocophillips.com> tom maunder@admin.state.ak.us Nš-ï<-weiy-ulntegri ty Proj <N1878@conocophillips. com> , 90gcc prudhoe bay@admin.state.ak.us Subject: Date: From: To: CC: \~-\~ç ~a \ - d-d-G SCANNED JUN 272006 Tom: I donlt remember how much of our plans we have shared with you on excavating and repairing wells at lC & ID pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-activelyl' excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «lC and 1D Casing Repair List AOGCC.xls» «SPE-I00432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 IC and ID Casing Repair List Content-Type: application/vnd.ms-excel Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword lof2 6/26/20067:51 AM PRIORITY 1 2 3 4 5 ) 6 7 8 9 10 11 d~\ '-d-"d.(J 12 13 ~ 14 15 16 ) ---, NAME 1C-121 1 C-131 1 0-1 09 1 0-111 10-120 -. - - -... ---.. 1 D-121 1·0-127 1··- .... -- .--.- --..---.- ...-.. . ... : 1 D-132 I i......_...... .......-.....-.--....-.-.................... ·'·-..-......1 I 1 0-136 I ..~_._......~........._.._.~~._....~_.._......~._.n._._.......", o. I 1D-137 I·· .. .................-..-........-.-.--.. ....-....._- , 1 0-138 10-139 1 C-119 Ir-_____··__~- ._.....---"";"'"':"_-::-:_~---:-:_._,_________~_~_._. tC-135 I -........ ......."._..:._...,_.ë".":""-~-' .......... ...c·..········1 1D4.35 ' ~....,.....,.._..~....~.._...:.;..~-_..:....._.. --..........-.! 10-141 ¡ ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates TYPE PTD# I LEAK DEPTH (ft) __".__._n_.__ n___ _"0.'.__._"'____"._.___. - -------..--.----- --....------..-- INJ 201-080 4 INJ 201-185 -I 7 -------- - -,- I I INJ 197 -235 5* - - INJ 198-166 5* INJ 197-221 7 Gas Lift 197-181 None Gas Lift 198-1 09 None INJ 198-121 5 -...- INJ 200-046 None - -,_.~ INJ 200-047 None INJ 200-048 8 .. - INJ 200-049 None -- - INJ 201-139 16 Jet Pump 201-220 None ESP 197 -184 None Gas Lift 200-112 None COMMENTS I STATUS Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. Notes: 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 1D-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc .~ ,-..., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPOR~ C?F~UNDRY WELL OPERATIONS, uJA~ i-" (J,-L 1. Operations Peñ~rmed: Abandon OSu~pen(f 0 ' Ope~tion StlutdormO . PeHoråte' 'O'Våíîance ,0 Annul~r Disp. 0' Altèrc~§¡ng '. . b' R~þa¡r;V;èn, 'b ,:'. .:é¡J~'PèrfOraìi~~$' 'Cr : s~ù¡atê'[l'. ' ":<'l!ít,I~:E:~I1$iOh' '0 ,Otþ~Ì' ,0 , "ChangeA~prhvedJ?(oQï~~(J,: '~UlrtùRlì}~'~;:a:.::':~;~q~te;~~:~~."tf.'. .' ,~7~2t~'~~~~n.~~:IIY~n.tJ. ~::::~~~:e~laska, Inc. '~::C~!:f:W~~~~~~~;" ':o:~~~:trt';<'1 5. Permit to ~:~~~:o~ber: 3. Address: ' . . .£!\I 'c' :0. ,s~r;,.\Çe 0' 0.' 6. API Number: P. O. Box 100360 . , ' 50-029-23053-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 91' 1C-135 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE Perforation depth: 10. FieldiPool(s): West Sak Oil Pool measured 11700' feet true vertical 3753' feet measured 11668 feet true vertical 3753 feet Length Size MD 117' 16" 117' 7192' 7-5/8" 7283' Plugs (measured) Junk (measured) Burst TVD Collapse 117' 3766' Measured depth: 7173-11670 RECEIVED MAY 2 8 2004 Alaska Oil & Gas C 6ns Com' . Anch . mISSIon Drage true vertical depth: 3757 - 3753 Tubing (size, grade, and measured depth) 3-1/2" , EUE8RDMOD, 7164' MD. Packers & SSSV (type & measured depth) pkr= pkr= 7172' sssv= NIP sssv= 492' 12. ,StimUI~tiòh or cemèntSql,Jeøìe sumr:nary:" ' Intervals treated (rneasufed) 'N/A 13. . Tt~'atment:øescrìptions 'including volCimes' L\~ed and final pressure: Repfe.!>e.~~ij¥.è,D¡í¡Jy;AYe.fíi\iêPrg¡;l,~tioi} Q( 'hjection Data 0ì1~Bb1' " \ 'QäS'-Mcf ,"..., ' "', . Wâtêr,BbI,' "Oá$inq Prè$$ure Pnortowellopèratibn¿~'(:) ,,' Sl.!þ~eql,JÍ7ot 190~(ati9r:1 ;171, 1?Q3 . . . . 96 , 1,4. Atlà6hffieñts , , '15. Wèlj'Ø!a§s .aItér:prbposE!i)Wp,rk: Copies of LOgs and Surveys run- ' Explòr<}t9ry [j' De~loproeht 0 S,Elrvice 0 Dai,ly Report of Well Operations _X 16. Well Status ~fter prpposedv.i9rk: .' QiI~ G~sD WAG 0 GINJO WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact James T. Rodgers @ 659-7226 p~nted Na'¿:/þ R~D~~ten~en Signature ~ 1)( ~ -J 105 :Túbinq Pressure; 2100 1~ WDSPLD Production Engineering TeChnician} A/'" 659-7535 Date ~11ð'Y' 0 R , G' N A L RBDMS ~~IT IN ~ICqT~ 2004 Title Phone Form 10-404 Revised 2/2003 . Permit to Drill \ q JfV1-- ~G (J i DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 2012200 Well Name/No. KUPARUK RIV U WSAK 1C-135 Operator CONOCOPHILLIPS ALASKA INC MD 11700 ",.-- lVD 3753 F ~_. n~__~n - - - Completion Date 12/19/2001 /' Completion Status 1-01L Current Status WAGIN 5pc.vl ) (:) (ú'~" ~ (} ~ I API No. 50-029-23053-00-00 ~----~)~ --- REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Directional Survey Yes ~ Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset Med/Frmt Number C I...f1428 Logl Data Type '1-ED I I I I ! I ~ I i JßÐ D i I ..Gg ¡ ""ËtJ D I¿; I +.w. C I ! I I I~ ~ ^4~1 IL., u..\~~~~~~ t'^""'~ Name Log Log Scale Media . ... n n nn... nn nn ~665LISY~ri~q~iiPQ- 4ré$šÙr~ .;H16 6441$.Yêti~B~t!RD~. viôj~9#9¡iP.t9~IØ.......... . .. .. ............. .. . .. . ... ..... .... .......... . . . ..- ....... . vt1427$eeNóte$< Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y @ Chips Received? ~ ~ Analysis Received? ,Y/N ---.I ------- --- - -- -- --- - . - 5 5 1 7l ~ 0 - (( 7 ù~ c.. o.n-l () t ~ ~ l Run No 1 Blu 1 0 1 102 1 0 1 102 1 100 1 103 (data taken from Logs Portion of Master Well Data Maint) Interval OH I Start Stop CH 103 10350 Case _un. Received Comments ----~---------'." 12/6/2002 Digital Well Logging Data / ¡ Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity PB 1 7083 open) 5/8/2003 10297 Open 3/20/2002 7083 Open 5/8/2003 11635 Open 3/20/2002 11610 Case 3/25/2003 11700 Case 12/6/2002 Sample Set Number Comments [PIN @/N PB1 Digital Well Logging Data / : Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity ---"-- Interval Start Stop Sent Blu Blu Received Daily History Received? _u--- --~ - Formation Tops DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2012200 Well Name/No. KUPARUK RIV U WSAK 1C-135 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23053-00-00 MD 11700 lVD 3753 Completion Date 12/19/2001 Completion Status 1-01L Current Status WAGIN UIC Y Comments: Compliance Reviewed By: ~ Date: ;;¿ [-7:'- -l.tft¡- ~.. '- -c.c .. . _--no ~ ALt~r~ OIL AND ~T:;~g~S~~~:;;ON COMMIS~ ~ REPORT OF SUNDRY WELL OPERATIONS - [] , Su~pëhd 'DbperãÙbn$hÙdb~'in' "0' ,'pert&åteO 'Variance' DÄ~nularö,sP.O 0 Repa,ir .well 0 Plug Perforations ,0 ,°, St¡mi.Jlat~ 0 Time Extension 0 " O~her ,0 '0 Pull Tubing 0 Perforate New Pool ,0 , Re-enter Suspended Well 0 , 4.'Ctirr~nt Well Status: ',.' '5. Permit to Drill Number: De~:elop~ent '0 ,Exploratory 0 201.220 I , :S~ratigraphic' 0 "Service 0 6. API Number: 50-029-23053-00 ()¡¿ .¡, ð úJ A Alter Casing , ,pl:wn..g~:1-BProved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (tt): RKB 91' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Tubing (size, grade, and measured depth) Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE Perforation depth: 9. Well Name and Number: 1 C-135 10. FieldiPool(s): West Sak Oil Pool measured 11700' feet true vertical 3753' feet measured 11668 feet true vertical 3753 feet Length Size MD 117' 16" 117' 7192' 7-5/8" 7283' Plugs (measured) Junk (measured) TVD Burst Collapse 117' 37661 Measured depth: 7173-11670 true vertical depth: 3757 - 3753 3-1/2" , EUE8RDMOD, 7164' MD. (I t" Packers & SSSV (type & measured depth) pkr= pkr= 7172' SSSV= NIP SSSV= 492' ',12. Stimuli:ltion or ~ement squeeze' sumr:n¡:try: " " InterVqls tr~atect '(me¡asureq) , , , ' , , .. ,,',' T~~atmentdescriptionsincludingvolumesusedandfinalpre~~Ür~:~',":'.", :",:":",,, ,,; ::,',', ',' :',::;', ,',', ,'>, , , 13. ' , , '~,eprës~ntative Pa,ily Average Production or Injection Data 'Oil-Bbl':": '" ',' .. :,,""',"Gas~Mcf,,"',"',',," ::'" ", Water-Bbl':', ':' ,Casiri Pressure "2$5",';,:,":"':':" :~9;::",:""':",:,::'",' ,1'24,' " , , " " , , , , " : "",' ,',"":' "," '1334 ,: ",-..- "" .' ," :,' " ' "", ' ' ", ,', , ' ,:-':" 15.,Wel,~:~I~~~,:atte~,'prop6sed work: :.', ' ,: ,',',:,::'" ,::,,:,', ","~XPlorat~~ ,',D'::"',:',De~elopment 0 : 'Service' 0 ',16; WeM'$t~tu~ aft~r'proposed work: ' ' '",',ÒnD:,::::, , 'Gas 0 , ,,\NÂ~QJ,':, GINJD WiNJO 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: .'N/A' " " , , , 1698 25 ,Tubin Pressure' "3'95,:, ' , , ' , ~786, " : Prio~ to well operatiqh Subsequent to operation. ':'14.' Att~chm~'nts' ": , ' , Copies of Lbgs'ë:lnd,S~rvey~ run - ' " Daily R~port of Well ()perations --.:.x Contact ,::'wDs'PLD" Production Engineering Technician 659- 7535 Date o/:J. o/Ø3 Title Phone' 'n~'~ ORIGI~LAI'- Form 10-404 Revised 2/2003 . SUBMIT IN DUPLICATE c'..", ',< 1 C-135 ,," ~." ¡:SCRIPTION OF WORK COMPLETED It SUMMARY Date Event Summary 09/19/03 ConinienGed:WAG I;QR .Injec~ioo . ,".: ;. ,.', ." ~~;]j;;,B~'fD¡3~ ;::)J:~ it;;: i;~5c~i~,;tJ: t ,. ',-.' ". ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 fr~5 ~ /78~ (1) D /& Ic~ ;,1 ;:Type òf Request: '. Abandon ',(0 " ' J.' :SÙsp'cnd' 0 ' Repair well 0 Pull Tubing 0 Alter casing 0 " Change,a~proved program' ,0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 91' , ÖÞèmtìa~'s~utdöWri:,¡u 0' . PerlarcHeO Variance~ DAnnularDìs~. 0 '" :Plu~ 'p~iforat!o~s : 0.: ,Stimulate' 0 Time Extension 0 'Other 0 ,Perl~rat~, N~~ ,P:60!".: ,,:0 ',', , , Re~l1ter Suspended Well" " 0 '4. Current Well Class: ,: :' ': ' ", . ' " 5. Permit to Drill Number: , : . ,:' öev~¡?~m~:~~'#,' ~ExpI~~tOry 0 ", 201-220 Stratig,¡'~Phi~:' ,:.0' . ,Se.rvice, D?dß¡ 6. API Number: , '., ,':~, ',: ," ,:,: ",,:,' , ~ '-f 50-029-23053-00 9. Well Name and Number: 1 C-135 10. FieldlPool(s): West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): E~ect,ive Depth M~, (ft): ,Effecti~e D,ep'~~ ,!.\'D ,,(~): Plugs ,(measured):, Junk (measured): 37531 :,'.:':,'>:1.166~3.'::,' :-:,::375.3)'::'" ,:,;:::, :::,": ' , " ' Length Size MD Burst 8. Property Designation: ,¡:¡,i,:,,:;:::i'~HP~æ~~i~~:~:8D¡t 11. Total depth MD (ft): 11700' Casing CONDUCTOR SURFACE 7-5/8" 117' 7283' ....:" 117' 7192' 16" . ., , , " Perforation Depth MD (ft): Perforation Depth TVD (ft): 7173~.:.1.1670.::-:. .":' .". 3756-"3753"::.:.::.: . .. :;:.." . . Packers and SSSV Type: Packers and SSSV MD (ft) pkr::: pkr= 7172' SSSV= NIP SSSV::: 492' 12. Attachments. Descnptlon Summary of Proposal ,0 :":1,~~,)rv'øu",c~~s.,:~:a,ft~,r:p'r'opOS~d ~o, r~:::, , :' 6~tan~~~~~~~nk~~g;am' O~oP S~eroh Ö' ' Ex¡,IQ~¡;;;Yn -, ':Q~~~oPment 0 ' ~~~~~'!:6~;:t~:s:' , ,>081;5I03'1:~~tl:"0Q~:~~~r iilqpo;:t"[j' ' -piugged n ,,16.Verb~IAp'pr?,v.al,: "r~) ?j~l Date: 08/01/03', ,:'W~(?<::,>0 ' 'ßIN'~ ,'0 ' 'WINJ 0', Tom .tv1aunder . ,ICJ;-, I, ,,'''., , , ji. ,I hØreby.'certifythatthe foregoing :is true a~d co~r.ed to th,e.',be.st of,myk~:oWlei;i~e.,,: .. Pri~~~~ Naf!l~. Robert "0 ~ hristens" n" . .. ... :.. :.' Tubing Size: 3-1/2" Tubing Grade: EUE8RDMOD Tubing MD (ft): 7164' , , ' serviGe,':' ~ :, , , " AÞa~d6n~d ,:'0 WD$PL.,O', Signature ::Con'tact: . "Title: ''Phone: 659-7535 JeffSpenc~Ù @ 6S.9-7~~26 ' Production Engin~ering 'Techhici,an Date: 08/03/03 ' Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . .. a. .3...- ,,1- Plug Integrity D BOP Test 0 Mechanical Integrity Test D Location Clearance 0 Other: "OLIS;\-«~\"S.Ç>¡¿\ ~~"\~~'J~~\'40~. \ ~ ~\O¡¡~û\ Z003 Subsequent Form Required: Approved by: ,~ COMMISSIONER BY ORDER OF THE COMMISSION Date: , /; (03 Form 10-403 Revised 2/2003 . OR\G\NI\\ SU8~0IT,t~¡ 9lJ~~ 1~;~1JÏiËI. j"\¡,'~.~,' . ,~ .," ", ~ 1C-135 DESCRIPTION SUMMARY OF PROPSAL f ConocoPhillips Alaska Inc. requests approval to change the approved program for West Sak well 1 C-135 from Oil production to Water Alternating Gas (M I) injection service for a period of approximately 2 months after which the well will be returned to Oil production service. The main objective of this producer is to determine if the slotted liner provides enough structural support to the drilled wellbore such that production (under WAG injection) continues uninhibited with lllimitedil sand production. This project will be integral in deciding whether positive sand control is a requirement in DS-1J West Sak Development that is planned for 2003. The method of testing formation integrity is described below. We intend to simulate and ascertain the effect of water and miscible gas on the formation stability during break-through. This will be determined by producing this D-sand only, horizontal wellbore for a period at a drawdown similar to West Sak's Phase 2 producers (completed). This will establish a production base line and define initial deliverability of a single D-sand horizontal producer. Water has been injected into the same wellbore to saturate the producing interval near the wellbore, altering the hydrocarbon/water saturations and potentially altering the formation matrix stability. The volume of water and the duration of injection has been determined to be 1,000 BWPD for 2 months (160,000 BW). We will then produce the well bore and closely monitor the overall well bore and pump performance, at drawdown conditions similar to the I'base-line" production (Completed). Thus far the wellbore has not catastrophically failed, we woullike to proceed with additional testing utilizing Miscible Gas injectant followed by a production period, and perhaps another WAG cycle. Throughout the testing, we will be monitoring performance and formation stability. If the wellbore fails, we intend to recomplete the well as a horizontal producer with sand control. The well has a large enough slotted liner to allow a smaller diameter Baker Excluder screen to be installed. The well has been drilled with a tangent especially designed for a,future recompletion of this producer with an ESP estimated to be sometime in 2004. ;' ,"'" "", iIf!I, '&~' ./,' ..~I"" ,t.". ~'1111 ,t.. 1C-135 was completed as a 3-1/211 Horizontal Oil producer on Dec. 20, 2001. The targeted West Sak D zone was encountered between 7123' - 11700' md. The 7-5/811 production casing Inner Annulus is isolated utilizing a Baker SC1 R Packer Assembly at 7173' md. The Ultrasonic Imager Log obtained 12/18/01 indicates good cement integrity from 6930' md to the top of the 0 sand at 7123' md (3700' - 3750' tvd). ~: II.' ." , ", , ..' '" , . "" ,," I iI Re: 1C-135 (PTD# 2012200) 10-403/10-404 ( ( " Subject: Re: 1C-135 (PTD# 2012200) 10-403/10-404 Date: Fri, 1 Aug 2003 08:15:46 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom A passing State Witnessed MIT was completed 12/13/02. Thank you for the verbal approval. You'll have the 10-403 in hand early next week. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Tom Maunder <tom_maunder@admin.state.ak.us> 08/01/2003 07:53 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: 1 C-135 (PTD# 2012200) 10-403/10-404 MJ, 1 C-135 was one of the wells described in ConocoPhillips application for the WS SSEOR pilot project. As you note, that pilot project was Administratively approved by the Commissioners on July 21. With this particular well, the only issue possibly outstanding would be a verification that the well has passed a MIT. I would expect that given that this well has changed service several times recently that an MIT has been likely conducted within the past several months. You have approval to convert the well as outlined in the application for SSEOR. We look forward to the receiving the 403 in a few days. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: > Tom' , > > 1C-135 (PTD# 2012200) is ConocoPhillips' West Sak Huff and Puff project > well. In Sept 2002, ConocoPhillips submitted a 10-403 to convert this well > from a producer to a water injection well (Approval # 302-299) then sent > subsequent 10-404's (12/3/02 & 3/26/03) when we swapped it back and forth > between producing and injecting. It is currently an oil producer and we > would now like to convert it to a WAG injector. We have the following > SSEOR project approval from Randy Ruedrich and Sarah Palin for EOR > injection into the West Sak formation. > 1 of 2 8/5/2003 10:24 AM Re: 1 C-135 (PTD# 2012200) 10-403/10-404 ,II ;11 ¡ ~^ > GKA submitted a request to the Alaska Oil and Gas Conservation Commission > (AOGCC) for Administrative Action under Area Injection Order No. 28 (Rule > 9) and Conservation Order No. 406 (Rule 13) and in accordance with 20 AAC > 25.450 for approval of a Small Scale Enhanced Oil Recovery Pilot Project in > the West Sak Oil Pool (WS-SSEOR). The request was delivered to the AOGCC on > June 18, 2003. Yesterday on July 21,2003, we met with the AOGCC Chair > Sarah Palin and AOGCC Commissioner Randy Ruedrich to review the proposed > Pilot Project. Late that same afternoon we received Administrative > Approvals No. 406.1 and AIO 28.01 allowing the project to move forward into > the execution phase. The WS-SSEOR Pilot Project is approved for a period of > three years, until August 31 2006, and we anticipate first MI injection by > the end of the month. > > We request verbal approval for the 10-403 for well 1 C-135 (PTD# 2012200) to > convert the well to a WAG injection well. The actual 10-403 and supporting > documentation will be in the mail by the end of the week followed by the > 10-404 when it is actually converted. > > Please let me know if you have any questions or would like any additional > information to support a verbal approval. > > Thank you > > MJ Loveland > > Problem Well Supervisor > ConocoPhillips Alaska Inc. > (907) 659-7224, (See attached file: tom_maunder.vcf) !"..""""'..............'.."""..".................'......"""""""""......."....'..""""""""""""""'"...""""""""",.",..,""""""""""""""""""""'"""""""""""""""""""""",,"n,""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""'"""""""""""""""""""""""""""""""""" '.,'.".".,[",',---",'"'",~,,.,,'"',',."""", ',",'.,','"',',""'"',"""""",._,,,",~""'.'",, .,,',',',," ","""',"",'-,',~,,, '" "',,,',",,'~,"", ',',""",',' ,'~,,",' ,-,","-,',',",'-,', ,-",'""'",.".,'"","....,."'..'.".,,: .1 Tom Maunder <tom maunder@admin.state.ak.us> ! I Sr. Petroleum Engineer : . Alaska Oil and Gas Conservation Commission I --,--"""",'" '"---~ '~-, ' " , ~_.~J 2 of2 8/5/2003 10:24 AM Re: 1q-135 (PTD# 2012200) 10-403/10-404 . , ( ( Subject: Re: 1 C-135 (PTD# 2012200) 10-403/10-404 Date: Fri, 1 Aug 2003 08:15:46 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom A passing State Witnessed MIT was completed 12/13/02. Thank you for the verbal approval. You'll have the 10-403 in hand early next week. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Tom Maunder <tom_maunder@admin.state.ak.us> 08/01/200307:53 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: 1 C-135 (PTD# 2012200) 10-403/10-404 MJ, 1 C-135 was one of the wells described in ConocoPhillips application for the WS SSEOR pilot project. As you note, that pilot project was Administratively approved by the Commissioners on July 21. With this particular well, the only issue possibly outstanding would be a verification that the well has passed a MIT. I would expect that given that this well has changed service several times recently that an MIT has been likely conducted within the past several months. You have approval to convert the well as outlined in the application for SSEOR. We look forward to the receiving the 403 in a few days. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: > Tom; > > 1C-135 (PTD# 2012200) is ConocoPhillips' West Sak Huff and Puff project > well. In Sept 2002, ConocoPhillips submitted a 10-403 to converl this well > from a producer to a water injection well (Approval # 302-299) then sent > subsequent 10-404's (12/3/02 & 3/26/03) when we swapped it back and forlh > between producing and injecting. It is currently an oil producer and we > would now like to converl it to a WAG injector. We have the following > SSEOR project approval from Randy Ruedrich and Sarah Palin for EOR > injection into the West Sak formation. > 1 of 2 8/1/20038:13 AM R,e: 1Ç-135 (PTD# 2012200) 10-403/10-404 .. ( ,( > GKA submitted a request to the Alaska Oil and Gas Conservation Commission > (AOGCC) for Administrative Action under Area Injection Order No. 28 (Rule > 9) and Conservation Order No. 406 (Rule 13) and in accordance with 20 MC > 25.450 for approval of a Small Scale Enhanced Oil Recovery Pilot Project in > the West Sak Oil Pool (WS-SSEOR). The request was delivered to the AOGCC on > June 18, 2003. Yesterday on July 21,2003, we met with the AOGCC Chair > Sarah Palin and AOGCC Commissioner Randy Ruedrich to review the proposed > Pilot Project. Late that same afternoon we received Administrative > Approvals No. 406.1 and AIO 28.01 allowing the project to move forward into > the execution phase. The WS-SSEOR Pilot Project is approved for a period of > three years, until August 31 2006, and we anticipate first MI injection by > the end of the month. > > We request verbal approval for the 10-403 for we1l1C-135 (PTD# 2012200) to > convert the well to a WAG injection well. The actual 10-403 and supporting > documentation will be in the mail by the end of the week followed by the > 10-404 when it is actually converted. > > Please let me know if you have any questions or would like any additional > information to support a verbal approval. > > Thank you > > MJ Loveland > > Problem Well Supervisor > ConocoPhillips Alaska Inc. > (907) 659-7224, (See attached file: tom_maunder.vcf) ,......,..............,........,............. ............ .................... """"""",""""...."........... ................,......., .......................................................... .",.........,.........,....... ,"""""""""""""""""""""""""""""""""""""""""""""""""""""""""""'.............................,.........,..............,.......,....................,..........,..........,......,.........,..............,...........................,..,..,...........................................................................,.................,........,........."""""""""""""""""""""""""""""........, ¡ Tom Maunder <tom maunder@admjn.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of2 8/1/20038:13 AM Schlumbepger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well Job# - -- Log Description Date SBHP SURVEY INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE SCMT US IT INJECTION PROFILE PRESSITEMP SURVEY 04/18/03 04/17/03 04/07/03 04/08/03 04/09/03 04/18/03 04/01/03 04/24/03 04/23/03 SIGNEC2¥@ L~r:J NO. 2765 Company: Field: BL Color 05/05/03 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk -~" CD 1 1 ,-. RECEIVED DATE: . . 0 8 20 (\ 3 ~AAr . V ,AJaß1(a Ot: & Gas Cons. Cornrnise«>n An ch oreg e 1 1 1 1 1 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (' STATE OF ALASKA ( ALA::'KA OIL AND GAS CONSERVATION COMMISSI()l~ REPORT OF SUNDRY WELL OPERATIONS '1. Operations pcirfonncd: Opcratioh shutdown_' .. Pull tubing - 2. Name of Operator Philli s Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 1704' FNl, 4255' FEL, Sec. 12, T11N, R10E, UM At top of productive interval 1646' FNL, 2170' FWL, Sec. 13, T11N, R10E, UM At effective depth At total depth 735' FNL, 2077' FEL, Sec. 24, T11 N, R 1 OE, UM 12. Present well condition summary Total depth: measured true vertical 11700 feet 3753 feet Effective depth: measured true vertical Casing CONDUCTOR SURFACE Liner Length 117' 7192' 4497' Size 16" 7-5/8" 4-1/2" .'..Stìm~ll~üe- .' Alter casing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 562030,5968531) (asp's 564294, 5958960) Plugs (measured) 7173 feet 3756 feet Junk (measured) Cemented 325 sx AS I 650 sx AS Lite, 255 sx Class G slotted liner Perforation depth: measured 7173,-:,,1t~?'~~:, ;, ::';';--:: ,,'" ',,", " " , , , , , .. , "n , """, ' " .,' ".. ' " , " , '" ." " "" , , truevertical,37q6'~3753' :',',,:, ,';:::,::':":,::,' ",:',: ",,' ,",' , ".. , n' 3-1/2.;,9,3#>I:U~ØRDMO[>'T~g, "7164' MD. Packers & SSSV (type & measured depth) @ 7172' MD., CAMCO 'OS' NIPPLE WITH 2.975~,NO GO PROFILE @ 492',MD~ 13. Stimulation or cement squeeze summary Intervals treated (measured) , N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl 875 Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Oil ~X G'as_, Suspended- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Production Eng¡;;eering Supervisor Robert D. Christensen Tubing (size, grade, and measured depth) Prior to well operation RBDMS BFl Form 10-404 Rev 06/15/88 . ORIGINAL Plugging- ' Perforate....;.. Repélir well - OtherjX WINJto OIL 6. Datum elevation (DF or KB feet) RKB 91 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 C-135 9. Permit number / approval number 201-220 / 10. API number 50-029-23053 11. Field / Pool Ku aruk River Field/W est Sak Oil Pool Measured Depth 117' 7283' 7173' True vertical Depth 117' 37661 3757' .. ' , , , , , ' .. '" " , , , , , 465 Casinç¡ Pressure 750 ,238 Tubinç¡ Pressure ,24~8 691 Service - Questions? Call Jeff Spencer 659-7226 D;~e a~~~~~ 65M535 f~ECEIVED MAR 2 a 2003 (~.. ~\ AJa~ka O¡.¡ & Gas Cons. cOlnri11~MF IN DUPLICATE Anchor~6 1 1 C-135 " ESCRIPTION OF WORK COMPLETELli SUMMARY Date Event Summary ',' " " " , , , ',' ' , " :ij.9Î2003 Compeleted 160,000 barrel Water Injection cycle on 02127/03. Returned to production as a " " c'"," Water Lifted (Jet Pump) Producer on 03/09/03. , ' /', "i"',,"ig""rn,",.~í,,"'¡":~'(",i,.'I""I,',',i"otf¡",.""".,.):".,¡i',I,",I,~,.",,¡,!"".:;¡'W,i,' , y~ "'~ oj' "" '"'II. (, 'I' :[, '" 'I': , Ii, ,í,' !' ~ !,i I) '1\, ',! Il' :.~ ,:¡,,;ii,a('~"f""¡'\'.i"",:, ~ """,,': .f'}, J ~ it \",i ~ ,j~ $ \~.* I 03/19/03 Schl.bepgep NO. 2705 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~- Well Job# Log Description Date BL Color CD 2T -27 - 1B-12 1C-135 1D-12 - 1F-19 - 1H-O7 TEMPERATURE LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG LEAK DETECTION LOG 01/01/03 03/04/03 02126/03 03/05/03 02108/03 02115/03 1 1 1 1 1 1 -~ ~ REG~EO SIGN :--. - l~ DATE: MAn 252003 .Aja!ka 0;1 & Gas Cons. Comm~n Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. AnchOf!ge Re: Jet Pumped Wells Subject: Re: Jet Punlped Wells From: "NSK Problem Well Supv" <n 1617@}conocophillips.eonl> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: Tom Maunder <tom_maunder@Jadnlin.state.ak.us> CC: "n 1617" <n 1617@!eonoeophillips.eonl> Tom: 1 requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: 1C-123 (PTD 2010840) was recently S1 for high watercut - -,-~C~135. (PTD 2012200) is a huff and puff well and was recently put on water In]ectl0n cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2L-313 (PTD 1982190) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2N-303 (PTD 2001690) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. 1 hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder < tom maundE:rrI~'admin. state. ak. us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails fr h'l b om aWl e ack regarding the wells out there on jet pumps. Would you please pro'lide an updated listing of the wells presently on jet pumps in greater KRU?? Thanks in advance. To I, '\ :1 I. '.. '( ( MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder f CXt"J\~ Conoco/Phillips Inc. Petroleum Engineer ~ t .. \ 1 C Pad 'ði i.~d 1C-135 FROM: Jeff Jones \; KRU Petroleum Inspector Kuparuk River Field NON. CONFIDENTIAL "..~ DATE: December 13, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well 1 C-135 Type Inj. S TV.D. 3756 Tubing 0 0 0 0 Interval I P.T.D. 2012200 Type test P Test psi 1500 Casi ng 2150 2750 2750 2750 P/F P Notes: Pretest pressures obseved 15 min. & stable. Monobore injector rate: 1000 BBUday Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING Type Test L",-\c:> ~~~ ~~"-õ~ctbt'ëffãl M= Annulus Monitoring \1-...)(~:..\\. \'\~~ û..~kr-l= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey r rv1 V= Required by Variance A= Temperature Anomaly Survey \ ~(Iça;> W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details December 14, 2002: I traveled to Conoco/Phillips InC.IS (CPI) monobore water injection well lC-l35 to witness an initial MIT. John Arens was the CPI representative for the test, which was performed in a safe and proficient manner. The pretest pressures were monitored and' found to be stable and the standard annulus pressure test was then performed with the well passing the MIT. This well is a producer converted to an injector and although the well is injecting 1000 BBLS/ day the tubing indicates a vacuum. Summary: ¡witnessed a successful MIT on CPl's water injection well lC-135 in the Kuparuk River Field. M.I.To's performed: 1 Number of Failures: Q Attachments: Wellbore schematic 1 Total Time during tests: 1.5 cc: MIT report form 5/12/00 LG. MIT KRU 1C-135 12-13-02 JJ.xls 12/18/2002 .. ~ ( 12/17/Ø2 r 1-øp P.øøs " ConocoPhUUpa AJaak8. Inc. KRU 1 C..135 TUBING 1C.13S (0.7164, API: 500292305300 Well TvD8: INJ Anole fD TS: deft Œi) 00..3.500. SSSV Type: Nipple Orlg 1212012001 Angle CD TO: i1 degG 11700 1D:2.æ2 COmoletlon: Annular Fluid: L.I$1 W/O: Rev Reason: CT to 11.800' SU~ACE CTMD NOTAG (G.~ Reference I.oa: Ref Loa Date: Last UDdBte: 11/2912002 00:7.625. Last Tag: TO: 11700 flKB Wt29.70) LsstTsQ Date: Max HOle Mole: ~ dðO @ 8038 Casing String. ALL STRINGS De&Crløtlol'l Size ToD Bottom TVD Wt Grade Thread B CONDUCTOR 16.000 0 117 117 62.50 øpl5L O-B SURFACE 7.625 a 7283 3766 29.70 1..80 BT&C Tublna Strlna . TUBING Size I Top I Bottom I TVD I Wt I Grade I Th r..d 3.500 I 0 I 7164 L 3755 I 9.30 EUE8rdMOa SlEEVE.C Perforations Summary (7083-70S4, Interval I TVD I ZOne I Status I Ft IsPFI Oato I TYøe I Comment 00:5.495) 7173.11670 I 3156.3753 I WSD I 144971 99 112120/20011 Slotted IPerls thru siottecliiner Gas Lift Mandrols/Valve. St MO TVO Man Man VMft V Type VOD Latch Pon TRO Date Vlv Mtr TvDO Run Cmnt , 7116 3749 CAMCO K6UG-M CAMCO DMY 1.0 BK-5 0.000 a 417/2002 en 1. PT {JA to 3000# Hold GæUfl Other OlUð8 oaulD. Gte. . LINER ' : De'CtlÞtlon 10 mdraUDurrrny DoDth TVD Tvue Valve 1 7173 3756 S~O1TEO PPCO SLOTTED LINER WrrOOLS 3.958 . LINER (711~7119. 7229 3762 SLEEVE-Q BAK~R CMD NON.ELASTOMER SLIDING SLEEVE. OPEN 3.430 00:5.390) 11668 3753 SHOE 3.956 Other :Jluas I¡IQUID.. etç. . JEWELRY Depth ¡VO TVDO OesçrtDtlon ID II 492 491 NIP CAMCO 'OS' NIPPLE WITH 2.97$" NO GO PROFILE 2.875 7067 3739 GAUGE SENTRY PRESSURE GAUGE (DISCHARGE - OUTSIDE TUBING) 0.000 7083 3742 SI.EEVE-c BACK CMU WI2.813" NO GO PROFILE - CLoseD "(151200'2 3.430 1131 3751 GAUGE BAKER SENTRY PRESSURE GAUGECINTAKE) 0.000 7164 3755 SEAL eAKe~ $040 $.22 LOCATOR SEALS 3.000 7172 3756 PKR 4.000 SEAL (7164-7172. 00:3.980¡ PKR (7.1.~7173. 00:5.090) SLOTTED LINER II I (7173-11670, ~ 00:4.500) ~ Perf ~ ~ (7173-11670) ~ ~ ;:;:; - = I = = :::::~ = = == = = t= = t-- §. = == ~ I t= æ = ~ ;::: = ~ == SLEEVE.O ~ (7229-7ZJO. O0;5.~951 --. :::::: == SHOE ;;:;; I ;:;.;;..;.. (11668-11669, = OD:4.50D) == I - J I ,~ 1íRCH 1"0 +ïLt~ (Y} IT" K~~ \ c." 3S"" l J.. - I ~- 0 ~ ~ J . ~t s ,:1 III .~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 22, 2001 RE: MWD Fonnation Evaluation Logs: 1C-135, AK-MM-11196 ~o 1 ~~~O J /-L/a 7 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 lC-135: Digital Log Images 1 CD Rom RECE\VED DEC 06 2002 Alaska 01'1 &: Gas Cons. Commission Anchorage ~ 1,1 ~ aO/-~dO / I '--l fÇ). D WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I November 22,2001 RE: MWD Formation Evaluation Logs: IC-135 PBI, AK-MM-11196 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 lC-135 PBl: Digital Log Images 1 CD Rom RECE\VEO DEC 06 LOOL Aiaska 01'1 &. Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown- Pull tubing - 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 1704' FNL, 4255' FEL, Sec. 12, T11N, R10E, UM At top of productive interval 1646' FNL, 2170' FWL, Sec. 13, T11N, R10E, UM At effective depth At total depth 735"FNL, 2077' FEL, Sec. 24, T11N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURFACE Liner Size 16" Length 117' 7192' 4497' 7-5/8" 4-1/2" Perforation depth: measured 7173' - 11670' ,..,..' , true verticaI375ß~~ß7qá' .. .. Stimulate -' Alter casing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 562030,5968531) (asp's 564294, 5958960) 11700 feet 3753 feet Plugs (measured) 7173 feet 3756 feet Junk (measured) Cemented 325 sx AS I 650 sx AS Lite, 255 sx Class G slotted liner Tubing (size, grade, and measured depth) , ',",.., , " " " " 3-1/2",9.3#, EUEBRDMOD Tbg@71t?4o'MQ.: Plugging - Periorate - Repair well - Other _X OIL to WINJ 6. Datum elevation (DF or KB feet) RKB 91 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1C-135 9. Permit number I approval number 201-220/ 10. API number 50-029-23053 11. Field I Pool Ku aruk River Field/West Sak Oil Pool Measured Depth 117' 7283' 7173' True vertical Depth 117' 3766' 3757' :RECEIVED DEC 0 5 2002 " " .. '~~ka OU& Gas Gons. Commission AnchQrage , Packers & SSSV (type & measured depth) " @1172'MD. CAMCO 'OS' NIPPLE WITH 2.975" NO GO PROFILE @ 492' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured)NIA. ,...' Treatment description including volumes used and final pressure 14. Oil-Bbl '4$,8' Representative Daily Averaqe Production or Injection Data Gas-Met Water-Bbl ,2qS1 Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X ,Qil- G~s-,- Suspended- 17. I herebJ7rt~ th~ f~~9~~.:~~r,~,~t to thH best of my knowledge. Signed K~ ~~ Title Production Engineering Supervisor Robert D. Christensen Form 10-404 Rev 06/15/88 . """\ to! II í , l I: 01, ",.,<' I: Casing Pressure 24~O ' ,.service -,X WINJ Questions? Call Jeff Spencer 659-7226 Date / o/~ L. Prepared b Robert Christensen 659-7535 DEC ~ 5 2002 ~o q n M S B F l L,.". SUBMIT IN DUPLICATE 1 C~135 DESCRIPTION OF WORK COM PLETED SUMMARY Date Event Summary 11/30/2002ICommençed temporary Water InJection. . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon- Suspend- Alter casing - Repair well - Change approved program Þ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 1704' FNL, 4255' FEL, Sec. 12, T11N, R10E, UM At top of productive interval 1646' FNL, 2170' FWL,S~c. 13, T11N,H10E, UM At effective depth Operational shutdown - , Plugging- Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service- (asp's 562030,5968531) Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (OF or KB feet) AKB 91 feet 7. Unit or Property name Othe Kuparuk Unit 8. Well number 1 C-135 9. Permit number I approval number 201-220 10. API number At total depth 735'FNL,2077'FEL, Sec. 24, T11N, A10E,UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURFACE Liner Length 117' 7192' 4497' Size 16" 7-5/8" 4-1/2" Perforation depth: ¡,.",~,.ro~asured .'. ,,7173' - 11670' true vertical'" ,,'37Þ!3'~'3753" , "', Tubing (size, grade, and measured depth (asp's 564294, 5958960) 11700 feet 3753 feet , 7173 feet 3756 feet Plugs (measured) Junk (measured) Cemented 325 sxAS I 650 sx AS Lite. 255 sx Class G ,slotted liner, ,;-.! " "p,." .,' 3-1/2",9.3#, EUE8RDMOD Tbg @ 7164' MD. , , Packers & SSSV (type & measured depth) @ 7172' MD. 50-029-23053 11. Field I Pool Kuparuk River Field/W est Sak Oil Pool Measured Depth 117' 7283' 7173' True vertical Depth 117' ,"'3,76,6i, : 37:fJ7' , "!;',"l,, .. ,,'.,"'" """"',""""." .;,~ ' "1;",;,"["'" ~".Þ f '~,,;l ",I P. d, CAMCO 'OS' NIPPLE WITH 2.975" NO GO PROFILE @ 492' MD. 13. Attachments Description summary of proposal _X Detailed operations 'program - 14. Estimated date for commencing operation 15. Status of well classification as: " " , " , " '" n NarneofapþrQver, " ' "Date approved Servi\-;e_XWater Injector " , 17, I hereby ~: IIh foregoing is I e and coffeello the besl of my knowledge, Queslions? Call Jeff Spencer 659-7226 Signed ~~ . uction Engineering Technician Date 0/1 ~/ð Z. Robert D, Christensen ;;"',"""'1,,""""';:';"" Pre ared b 'Røbert,Qhr/stensen 659-7535 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 10- l..)o L/ 'Kf(JiNAL SIGNED BY " ";'1/101 Seamount , 6.lrprqpo~al wélsyerballyaþprovèd Approved by order of the Commission Form 10-403 Rev 06/15/88 . Oil- BOP sketch - Gas- Suspended - Commissioner n ~ ! i~, II ) "r, (\' , -.- ,-.- i! ,I J I ~ ~ if ¡ , P, ,J,,""'; ::, ',i, 'I," 'I L ,jï,)~"-il ïl,r"'\,i '.."",., "'.",) , ~.._. a"",' ,ì .! ,I"",.", SUBMIT IN TRIPLICATE 1 C-135 DESCRIPTION SUMMARY PROPOSAL ConocoPhillips Alaska Inc. requests approval to change the approved program for West Sak well 1 C-135 from Oil prodUction to temporary Water injection service for a period of approximately 2 months after which the well will be returned to Oil production service. The main objective of this producer is to determine if the slotted liner provides enough structural support to the drilled wellbore such that production ( und,er "Vaterflood) continues uninhibited with "limited" $andproductìon.Thisproj~t wi,1I b~ìnt~gralindecidingwhether positive sand control isa requirementinPS-1JWestSak Developmeritthatis planhedfor 2003. ThemethodoftestingforfTléltiorrintegriWisd~scrib\3cJbelow. . . ""e)ntenqtQ:§imylélt~~nd ,~$9êrtê.,i.nthêefteçtof'w~t~r qrltheJqrmation stabjlity du ring break- through,ThisWiU.'bed~termined.by:prQdÜcing thisD-sandÓnly,hoJizorital wellborefor:a' .. period at a drawdown similar to West Sakis Phase 2 producers (completed). This will establish a production base line and define initial deliverability of a single D-sand horizontal producer. Subsequently, water will be injecteq into the same wellbore to saturate, the producing interval near the wellbore, altering the hydrocarbon/water saturations and potentially altering the formation matrix stability. The volume of water and the duration of injection has been determined to'be 1,000 BWPD for 2 months (160,000 BW). We will then produce the wellbore and closely monitor the overall wellbore :and pump performance, at draw,down conditions similar to the IIbase-linell production. " , . If th~ wellbore does not catastrophically'fai , we will proceed with additional testing, perhaps another water cycle. Throughout the testing, we will be monitoring performance and formation stability. ' If the wellbore faiis, we intend to recomplete the well as a horizontal producer with sand control. The well has a large enough slotted liner to allow a smaller diameter Baker Excluder screen to be installed. The well has been drilled with a tangent especially designed for a futur~ recompletion of this producer with an ESP, estimated to be sometime in 2004. . 1 C-135 was completed as a 3-1/211 Horizontal Oil producer on Dec. 20, 2001. The'targeted West Sak 0 zone was encountered between 7123' -11700' md. The 7-5/811 production casing Inner Annulus is isolated utilizing a Baker SC1 R Packer Assembly at 7173' md. The Ultrasonic Imager Log obtained 12/18/01 indicates good cement integrity from 6930' md to the top of the D sand at 7123' md (3700' - 3750' tvd). . ~PHILLIPS Ala~Ka Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY TUBING (0-7164, 00:3.500, 10:2,992) SURFACE (0-7283, 00:7.625, Wt29.70) SLEEVE-O (7083-7084, 00:5.495) GasUft ¡ndrel/Oummy Valve 1 (7118-7119, 00:5.390) SEAL (7164-7172, 00:3.980) PKR (7172-7173, 00:5.090) SLOTTED LINER (7173-11670, 00:4.500) Perf (7173-11670) SLEEVE-O (7229-7230, 00:5.495) SHOE (11668-11669, 00:4.500) II ...-...... -1 . ) ..'..'.. ." " ... :~ :' ':,: ::." .'.... "t'~j"~m"'@'I:~iW:"'@ '. ~ 'r::¡";"r § i_- ;f.~; ~-= -'" .... '- = ,".'...,.'. ~ ===...:-'. ==1-:.' =þ..' === === == == == == == == == .-- 1='....' ~.,,"..', I. . I I ( KRU 1C-135 1C-135 API: 500292305300 SSSV Type: Nipple Anç¡le @. TS: deQ @. Angle @ TO: 91 deg @ 11700 Well Type: PROD Orig 12/20/2001 Completion: Last W/O: Ref Loç¡ Date: TO: 11700 ftKB Max Hole AnQle: 94 deQ @. 8038 Rev Reason: Add PERFS by ImO Last Update: 8/14/2002 Annular Fluid: Reference LoQ: Last TaQ: Last TaQ Date: CasinQ StrinQ - ALL STRINGS Description Size CONDUCTOR 16.000 Wt 62.50 Grade api5L O-B L-80 Top 0 Bottom 117 TVD 117 7.625 29.70 SURFACE TubinQ String - TUBING Size I Top I Bottom I TVD I Wt I Grade I 3.500 I 0 I 7164 I 3755 I 9.30 ~UE8rdMOd Peñorations Summary Interval I TVD I Zone I Status I Ft SPFI Date Tvpe I Comment 7173 -11670 I 3756 - 3753 I WS 0 I 14497 99 112/20/2001 Slotted I Perfs thru slotted liner GásLiffMandrelsNalyes" , "," ,. , ",' " St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Mfr Type Run 1 7118 3749 CAMCO KBUG-M CAMCO DMY 1.0 BK-5 0.000 0 4/7/2002 1. PT /fA to 3000#, Held Other (pluQs. equip.. etc. - LINER Depth TVD Type Description 7173 3756 SLOTTED PPCO SLOTTED LINER WrrOOLS LINER 7229 3762 SLEEVE-O BAKER CMD NON-ELASTOMER SLIDING SLEEVE - OPEN 11668 3753 SHOE øtl1ør( j'Qgsleâùh);;øtèJ~JEWËLR!tt . Depth TVD Type 492 491 NIP 7067 3739 GAUGE 7083 3742 SLEEVE-O 7083 3742 PUMP 7283 3766 0 7131 3751 7164 3755 7172 3756 ii..,.\>~::','.:'.:", """"":","":""""::"~;'/::.'.', Description CAMCO 'OS' NIPPLE WITH 2.975" NO GO PROFILE SENTRY PRESSURE GAUGE (DISCHARGE - OUTSIDE TUBING) BACK CMU W/2.813" NO GO PROFILE - OPENED 5/2/02 3" R.C. JET PUMP {2.85" X 4.52') W/2.813" BAKER CAY. & CAMCO D.S. PROFILE set 5/2/02 BAKER SENTRY PRESSURE GAUGE (INTAKE) BAKER 80-40 S-22 LOCATOR SEALS GAUGE SEAL PKR .. Thread BT&C Thread VIY Cmnt (1 ) "', ", "'.... ',.":'~, .',,':, ID 3.958 3.430 3.958 "'."',',':'.',:,',,. : .:.:. ..,'~~ ID 2.875 0.000 3.430 0.000 0.000 3.000 4.000 " :Þ:~ " " ~ , ,I , ':i ;~ (r ( Schlumberger Company: PHILLIPS ALASKA. INC. 0 z I- -.J Z ~ :J a: Ñ w w C\I a.. > ~ 0 a: cð -.J ~ -.J Cf):J Z I a: LL ~ <t - 0 a.. ~ Z ~ ~ ~ Cf) :5 <t Z Cf)O a.. - LO - I- M -.J < "7 -.J 0 0 I 0 ..-- a.. -.J 1 C-135 KUPARUK RIVER UNIT NORTH SLOPE Borough: FINAL ALASKA ULTRASONIC IMAGER LOG Elev.: KB. 90.5 ft G.L. 60.8 ft D.F. 90.5 ft MEAN SEA LEVEL Elev.: Oft DRILL FLOOR 90.5 ft above Perm. Datum DRILL FLOOR Section 12 Township 11N Range 10E .. >. .. c: c: ~ .Q ~ C:-ö1a..:.: E 8 ~ .§ ~ 8 Lo in Date Run Number Depth Driller Schlumberger Depth Bottom Log Interval Top Log Interval Casing Fluid Type Salin' Densi Fluid Level BIT /CASING/TUBI NG STRING Bit Size From To Casin ITubin Size Wei ht Grade From To Maximum Recorded Temperatures Logger On Bottom Time Unit Number Location Recorded B Witnessed B Well: Field: County: ,5!~; ,,\~(I ':":'~'þ A$iWii,' ¥::W ""i~~ ':;\:.11'" ',',',w,',',.,',1J" ~:~~' , 'if:O-:I' "<~'1', :,'¡'X~! ..',',,:,ß,~,',"',',~. ';t~;i ':,',:~,&,',"," .';;>~1~ ';;;~t!:W 18-DEC-2001 1706 FNL & 1022' FWL AT SURFACE Permanent Datum: Log Measured From: Drilling Measured From: API Serial No. 50-029-23053-00 18-Dec-200 1 1 11700 ft 11700 ft 7180 ft 5000 ft BRINE 8.8 Ibm/ aJ 9.875 in 7.625 in 29.7Ibm/ft L-80 Oft 7283 ft 18-Dec-2001 5:00 2196 PRUDHOE BAY R. LEPINE R. BOWl E '. " 000 " " ,',', '," ~~ --' 100 ~" :::0,... .. .. , ,y' í "fl' -:;f' I ¿:o1" & ~;~ ,~ ~ - ~,. /5 - ..5o..Y! , ,..," ,iÚ. I ~~'!.<r .:.., ~, vV: ~... ' .~ , , . w,::'.> , .~- ",þ. --- -, r.' T. , ."" ." ,., - ,- ~ "'.,¿j ~~ ~H 2,6 MRAY I '1)'" "" I " ~ ,,-~" ":'~")R .VH. =~ '"b. 4 " '" ~ ~ , " " , , " , " , " " " , '" , " " " , , , " " " .~ '0 '. 4 " .., .. .. , .. ~ .....,--, ~R .. ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 May 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1C-135 & 1C-135PB1 (201-220) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the West Sak well1C-135 and 1C-135PB1. If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Sincerely, ~~1\ t' l .- , \ . '\ 'C" " , ..,.' r') ',' :. ~,,"J; UK\b\N, \- R. Thomas Kuparuk Drilling Team Leader P AI Drilling J.r"~~~,,^, ," ","""',~ (,""1 \""" ,:¡ 'Ii, !.~! , t.!I"" l ß, ~~f ¡... IJ",', ".. /1 t' ~r ~I '~r ' ,'" 'If ),,' ~ 'I' ~ ' , 'Ii,~" ,~"",,' RT/skad ,;/ '1" " I!,' ' \ ",.. Ji,~...," ',.,Iff ,n"".. ,,' , 'I "',1,1" , ^- ':'.¡f ..:. U (){" Alaska 0':0 " '" 1/J & ~'",('. n U'GI.;!I , arr~ ", Anch;ra;¿ l;ommi$SW:i' ( STATE OF ALASKA ~',' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned D Service 0 2. Name of Operator 7. Pennit Number Phillips Alaska, Inc. V~~ 201-220 / 3. Address ~.... v~ r 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 $.~ 50-029-23053-00/50-029-23053-70 4. Location of well at surface 9. Unit or Lease Name 1701' FNL, 1022' FWL, Sec. 12, T11 N, R1OE, UM (ASP: 562031,5968531) r ~n¡T~::-;::1f~--' Kuparuk River Unit At Top Producing Interval I U'"',rL.J:! i~ 10. Well Number OATS 1646' FNL, 2170' FWL, Sec. 13, T11 N, R1OE, UM (ASP: 563225, 5963321) ~ ~; I? fo'.L, 1C-135 & 1C-135 PB1 At Total Depth ~'~ ' 11. Field and Pool ~ ELt; 736' FNL, 2079' FEL, Sec. 24, T11 N, R10E, UM (ASP: 564294, 5958960) ~ -' West Sak Oil Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. -¡""" Kuparuk River Field RKB 91' MD AMSL ADL 25650 & 25649 ALK 468 12. Date Spudded 13. Date TD. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions November 30, 2001 December 14, 2001 December 19, 2001 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11700' MD / 3753' TVD 11668' MD I 3753' TVD YES 0 No 0 N/A feet MD 1950' 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 120' 24" 325 sx AS 1 7.625" 29.7# L-80 Surface 7285' 9.875" 650 sx AS Lite, 255 sx Class G 4.5" 12.6# L-80 7173' 11670' 6.75" slotted liner 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7164' 7173' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 9,2002 Water Jet Lift Oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 5/13/2002 4 hours Test Period> 203 17 241 100 118 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 304 psi 2225 24-Hour Rate> 1167 137 60 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. :!"'" ", 11 '[\:'r "~. ~ \ k ! f\ l ' ii' C) fJ :' to"" ,\, I, ,,' "",., , " N/A j I '¡ " '" ..,' \ : ! ¡ \~ j.-:, \.1 ,\, '".",' \ I / \ -. / '",.,'!:: ,'!, ;-", r, t, ;'" ( ,.' il' ,I :," ,.,.. "," '0.".. '" '"" ¡[~.,~Z: ~;k3 ~I' ':'\'1"""- ,p,...,.., ",-,""~ ,.. ,f',': ',;~.,),;"" uudI!J¡::;.~nw ',,"':<ho:,:~o;~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate RBDMS BFL MAY 3 I 2002 (gf 29. \ GEOLOGIC MARKERS 30. .\ .,( FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME West Sak D West Sak Base 7123' 11700' 3750' 3753' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826 Signed ~c-.-......c-=- \.~..)- - R. Tho"Js -- Title KuDaruk Drillina Team Leader Date '$/2. 2 (0 z Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~ ...... ~ <PHILLlPS~~ I rD. "V" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/28/2001 11/29/2001 11/30/2001 12/1/2001 12/2/2001 12/3/2001 12/4/2001 ( (' PHilliPS ALASKA INC. Operations Summary Report 1C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 06:00 - 18:00 18:00 - 00:00 00:00 - 12:00 12:00 - 18:00 18:00 - 21 :30 21 :30 - 23:30 23:30 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 - 07:30 07:30 - 00:00 00:00 - 11 :30 11 :30 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 00:00 00:00 - 09:30 09:30 - 10:30 10:30 - 14:30 14:30 - 00:00 00:00 - 09:30 09:30 - 11 :00 11 :00 - 16:00 16:00 - 00:00 00:00 - 00:30 00:30 - 08:00 08:00 - 09:00 09:00 - 17:30 17:30 - 20:00 20:00 - 21 :00 12.00 MOVE 6.00 DRILL 12.00 MOVE 6.00 MOVE 3.50 MOVE 2.00 MOVE 0.50 DRILL 3.50 DRILL 2.50 DRILL 1.50 DRILL 16.50 DRILL 11.50 DRILL 1.50 DRILL 1.00 DRILL 0.50 DRILL 9.50 DRILL 9.50 DRILL 1.00 DRILL 4.00 DRILL 9.50 DRILL 9.50 DRILL 1.50 DRILL 5.00 DRILL MOVE MOVE RIRD MOBMIR OTHR MOBMIR OTHR MOBMIR OTHR MOBMIR OTHR MOBMIR PULD SURFAC PULD SURFAC DRLG SURFAC PULD SURFAC DRLG SURFAC DRLG SURFAC WIPR OTHR WIPR DRLG DRLG CIRC WIPR DRLG DRLG CIRC WIPR SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC 8.00 DRILL DRLG SURFAC 0.50 RIGMNT RGRP SURFAC 7.50 DRILL 1.00 CASE 8.50 CASE 2.50 CASE 1.00 CASE DRLG SURFAC CIRC SURFAC OTHR SURFAC Page 1 of 9 Start: 11/28/2001 Rig Release: 12/20/2001 Rig Number: 3 Spud Date: 11/29/2001 End: 12/20/2001 Group: Description of Operations Moving Rig & Camp from 3H-pad to 1C-pad. 15.8 miles. Nipple up Diverter-Spot rig over well-set in rig components. (Accept rig @ 1800 hrs. 11 /28/2001) Hang tree in cellar-rig up diverter lines. Continue nipple up diverter-service top driv e-change saver sub & reset torque Load 4" d p. Pick up 4" dp & stand in derrick. Load 4" hwdp in shed-Mount new monitor on rig. Stand Back 4" hwdp-run gyro in dry hole-fill hole-check stack for leaks. Make up bha. Make up bha-upload mwd. Drilling from 120' to 258'. POH wI hwdp-pick up drlg. assembly. Drlg. & surveys from 258' to 1428'. Drlg. & surveys from 1428' to 2469'. Pump Sweep. Wiper trip to shoe-hole in good condition. Full service to rig & top drive. Wiper trip to bottom. Drlg. & surveys from 2469' to 3618'. Drlg. & surveys from 3618' to 4552'. Circ. bottoms up for wiper trip. I Wiper trip-hole tight & swabbing-pump out. Drlg. & surveys from 4552' to 5594'. Drlg. & surveys from 5594' to 6541', CBU for wiper trip. Wiper trip to 4500' & back to bottom-pump 0 ut hole swabbing. Drlg. & surveys from 6541' to 7015'. Repair pump #2 [liner seal], cir - cond w/ pu mp # 1 move pipe. Cont to dir drlg to surface hole td of 7304' md / 3765' tvd. Circulate & cond for csg. Back ream ooh w/ dir drlg assmby. Initially pumping 80 spm - reduced to 50 spm [3 bpm ] to reduce losses. Occasional swabbing. Checking for flow as dictated by hole. Drag ging 10 - 30k Ibs over throughout. Lost a to tal of 25 bbl mud on trip out. NOTE: Ck jt count correct / bha tool count correct. On drlg out drillers found end of conductor @ 1 38' rkb / mwd log I data indicates 140' rkb. I- OTHR SURFAC Con t to do w n loa d m w d & I d b h a . Bit gag e s 5" under @ 8.375" w/ 8.440" stablizer a 1/16 " under, polished up only OTHR SURFAC C I e a n u p f I 0 0 r, pre par e top u rea m i n g b h a . Printed: 1/18/2002 2:06:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/4/2001 12/5/2001 12/6/2001 ( (' Page 20f 9 PHilliPS ALASKA INC. Operations Summary Report 1 C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 From - To Hours Code Sub Phase Code 20:00 - 21 :00 1.00 CASE OTHR SURFAC 21 :00 - 22:00 1.00 CASE OTHR SURFAC 22:00 - 00:00 2.00 CASE OTHR SURFAC 00:00 - 03:00 3.00 CASE OTHR SURFAC 03:00 - 04:30 04:30 - 09:00 09:00 - 15:30 15:30 - 17:00 17:00 - 17:30 17:30 - 00:00 00:00 - 03:30 03:30 - 10:00 10:00 - 10:30 10:30 - 14:30 1.50 CASE OTHR SURFAC 4.50 CASE CIRC SURFAC 6.50 CASE OTHR SURFAC 1.50 CASE 0.50 CASE 6.50 CASE RURD SURFAC SFTY SURFAC PUTB SURFAC 3.50 CASE RUNC SURFAC 6.50 CEMEN CIRC SURFAC 0.50 CEMEN SFTY SURFAC 4.00 CEMEN DISP SURFAC Start: 11/28/2001 Rig Release: 12/20/2001 Rig Number: 3 Spud Date: 11/29/2001 End: 12/20/2001 Group: Description of Operations Pu / mu bha [strap all]. Strap in hole [2250' @ midnight]. Continue to rih w/ hole opener to 6600' [circ ulating bu each 1800' run] where started to pu drag. Wash ream light resistance 6600' to 7304' m d, no fill no significant obstructions. Circulate / condition work pipe minimum amt Reduce yp to 16 & pv to 25, will further a djust rheology after csg on bottom. Pooh wI cleanout assmby, no drag, hole too k 10 bbl fluid over calculated. Hole opener /3 pt reamer in gage [9.975"] & IBS in gag e @ 9.625". Clean floor & ru to run surface csg. Pjsm & ops briefing. Pu mu shoe track [85.5'], Baker Locking fro m float collar down & rih w/ same. Utilize Wx Iamb Sure-Seal float equip. Pu addition al jt & ck float equip. Continue to pu 7.625 " x 29.5 Ib x L-80 x BT&C as per csg detail. Installed bow-type centralizers, 10' above shoe [stop collar], jt #2, @ float collar [sto pring], & over next 30 collars [ to 5920' ]. Filling each jt, break circulation @ 2558', t hen each 50 jts [2130']. @ rpt time csg run ning depth is 4900'. Continue to rih wI a total of 170 jts 7.625" c sg [string wt = 200k Ibs]. Last 5 jts taking weight, cir down using franks fill-up tool [di d not use setdown ring]. Mu csg hanger on last jt & Idg jt w/ stack centralizer to csg h anger. Circulate down landing csg hanger i n well hd profile. Csg Idged @ 7284' rkb , float collar @ 7199'. Cir cond mud staging up to 5 bpm / 650 psi [good cir w/ full retrurns]. Csg stuck during land out, pu to 230k w/ no movement @ sho e, continue to work pipe w/ hanger pulled ab ove sealing area of well hd, noted minor pip e movement w/ pull of 30 - 35 k Ibs over pul I. Continue cir - cond reducing yp from 16 t 0 9. Pjsm. Ld franks fill up tool & mu dowell cm t hd. Batch mix tail cmt, chem wash, & 50 bbl spacer. Pu on csg string, csg broke fre e @ 216k Ibs [?20k over string wt], continue to cir - work pipe w/ hanger 4' above well hd sealing sealing area. Press test lines to 3500 psi. Dowell cmted 7.625" csg as follows: Pumpe d 60 bbl CW 100 chem wash [pt lines to 350 Printed: 1/18/2002 2:06:27 PM ( (' Page 3 of 9 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 Date 12/6/2001 Sub From - To Hours Code Code Phase 10:30 - 14:30 4.00 CEMEN DISP SURFAC 14:30 - 16:30 2.00 CASE NUND SURFAC 16:30 - 17:30 1.00 CASE OTHR SURFAC 17:30 - 18:30 1.00 CASE NUND SURFAC 18:30 - 21 :30 3.00 CASE OTHR SURFAC 10:30 -11:00 21 :30 - 00:00 2.50 WELCT NUND SURFAC 1217/2001 00:00 - 05:00 5.00 CASE NUND SURFAC 05:00 - 06:30 1.50 CASE NUND SURFAC 06:30 - 10:30 4.00 WELCT BOPE SURFAC 12/8/2001 11 :00 - 12:30 1.50 WELCT TRIP 0.50 WELCT OTHR SURFAC SURFAC 12:30 - 20:00 7.50 WELCT TRIP 1.00 WELCT CIRC SURFAC SURFAC 20:00 - 21 :00 21 :00 - 00:00 3.00 WELCT TRIP 00:00 - 01 :00 1.00 WELCT TRIP 01 :00 - 02:00 1.00 WELCT TRIP SURFAC SURFAC Start: 11/28/2001 Rig Release: 12/20/2001 Rig Number: 3 Spud Date: 11/29/2001 End: 12/20/2001 Group: Description of Operations 0 psi] @ 600 psi I 6.2 bpm, then 52 bbl 10. 2 weighted spacer @ 550 psi / 6.2 bpm. Dro p bottom plug. Pump 650 sx [474 bbl] of Ie ad ARTICSET liTE CMT B-809 [ 10.7 ppg, w tr = 20.2 gal/sx, 4.45 cft / sx, ASL Blend, a dds. = proprietary]. Press / rates max - mi n - avg = 700 - 500 - 550 psi, 6.5 - 5.7 - 6. 3 bpm. FOLLOW W/ 255 sx [44 bbl] tail LAR CH Gas Bloc cmt [15.8 ppg, wtr = 3.07 gal / sx, yield = 1.2 cft / sx.-- Dry adds: 0053 = 3%, DO65 = .3% , SOO1 = .5%, all BWOC, wet phase: DO47 = 0.2 & D600G - Latex = 2.0 gal/ sx blend] Press I Rates max - m on - avg = 1100 - 700 - 800 psi / 3 - 5 - 5 b pm. Drop top plug & displace w/ 331 calcul ated bbl 9.4 ppg mud. Press / rates max - min - avg = 1310 - 700 - 1250 psi 15.8 - 2.4 - 5.5 bpm. Plug hit 13 strokes over, bump ed from 1250 to 2500 psi holding for 15 min, bled off, plugs held good. Full returnes t hroughout. 47 bbl [59sx] 10.7 ppg cmt to su rface. CIP @ 1410 hrs. Rd cmt hd, pull Idg jt, wash - jet out diver & well head areaseal area. Inst. csg hanger pack off, test to 5k psi. Nd diverter. Install tbg hanger W/ bushing [13 3/8 x 10 3 14"] & test to 5k psi. Pull tbg hanger used as running tool. Set test plug & nu 11" x 5000 psi bope [inco mplete]. Complete nu bope. Change out pipe rams to 4", rig service. Testing Bope to 250 I 3500 psi 5 min each & annular to 3000 psi 5 min each. Necessary to repeat test on hydraulic controlled tds u pper "kelly" valve. Set in wear bushing & rig down test equip. Pjsm on pu bha-mwd & Iwd tools. Rih w/ bha, make surface cks on Iwd I mwd t ools. Continue to rih w/ 4" dp to 960', slowl y pass through tam tool, observed slight m ovement on weight indicator. Continue w/ trip in to tag float collar @ 719 9' [tally 7198']. Brk circulation. Attempt csg test, pumping in csg @ 200 -300 psi 20 spm [< 1 bpm], pu mped 3.5 bbl away. Pooh for Tam Collar shifting tool. Incomplet e @ rpt time. Complete tooh for Tam collar shifting tool. SURFAC R i h wIt a m s h i f t too I . Printed: 1/18/2002 2:06:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ( PHilliPS ALASKA INC. Operations Summary Report 1C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 Date From - To Hours Code Sub Phase Code 12/8/2001 02:00 - 03:00 1.00 WELCT OTHR SURFAC 03:00 - 04:00 SURFAC 04:00 - 05:00 SURFAC 05:00 - 05:30 0.50 WELCT OTHR SURFAC 05:30 - 06:30 1.00 WELCT TRIP SURFAC 06:30 - 07:00 0.50 RIGMNT RSRV SURFAC 07:00 - 10:00 3.00 CASE OTHR SURFAC 12/9/2001 10:00 - 12:30 12:30 - 14:00 14:00 - 15:30 15:30 - 16:30 16:30 - 00:00 06:00 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 20:00 20:00 - 21 :30 21 :30 - 00:00 2.50 CASE OTHR SURFAC 1.50 CASE CIRC SURFAC 1.50 WELCT OTHR SURFAC 1.00 DRILL 7.50 DRILL CIRC PROD DRLG PROD 9.00 DRILL DRLH PROD 1.00 DRILL CIRC PROD 2.00 DRILL TRIP PROD 2.00 RIGMNT RSRV PROD 1.50 DRILL TRIP PROD 2.50 DRILL DRLH PROD Page 4 of 9 Start: 11/28/2001 Rig Release: 12/20/2001 Rig Number: 3 Spud Date: 11/29/2001 End: 12/20/2001 Group: Description of Operations Shift Tam Collar closed & press test to 1000 psi. Pooh wI tam Shifting tool. Press test csg to 3000 psi /30 min [charted ] . Ld Tam Tool. Pu I Rih wI bha to mwd I Iwd equip. Rig Service. Cont to rih wI dir bha, rotate [15 rpm] throu gh TAM collat @ 1010' [observed weight fluc tuations to 5k Ibs - not much different than previous trip where collar opened]. @ 1100' press test csg to 1000 psi. Continue trip t 0 tag float collar as per tally @ 7199'. Drlg float collar [ 7199'], 83' of good cmt in shoe track, float shoe [ 7283'], cleaned ou t cmt I mud to 7305' [9.875" td] & drlg to 73 20' for FIT. Cir cond mud for FIT. Pull up into csg. Conduct F. I. T. as follows. Mud wt = 9.1 psi, tvd 3765', pumped 31.5 gal fluid to imp ose a stablized 590 psi. Required 4 attempt s to obtain good test. Rec estimated 40 gal fluid due to secondarily applying 590 psi. H eld stablized 590 psi for 5 minutes. Cal., EMW = 9.1 pIg + {[590 psi] / [3765 x .052] } = 12.1 pIg emw X - out mud to BARADDIL - N mud. Dir drill horizon section 7320' - 8006' [3762' tvd]. Weights up - down - rot = 104 - 52 - 74k Ibs. P press @ 278 glm 2050 psi. Rot rpm = 60 - 70, motor rpm = 214. Torque on / off bottom 7700 / 7400 ft-Ibs. ast 1 hr + art 4 = adt 5.0 hrs Drlg ecd 10.44 - 10.88 pIg emw. Dir drill horizon section 8006' - 9345 [3750' tvd]. Weights up - down - rot = 100 - 55 - 74k Ibs. P press @ 278 glm 2200 psi. Rot rpm = 60 - 70, motor rpm = 214. Torque on / off bottom 9000 / 8000 ft-Ibs. Pump weighted sweep / requested to cir sam pies by geo-scientist. Allow samples to mi grate up hole w/ sweep then pull one stand & pu tds to max heigth to protect 20 slide 0 n bottom. Trip up to shoe, no problems PJSM Replace I inspect teflon slide plates on tds torque tube. General Inspection of tds & crown area. Rih to restriction 9045', wash - ream to td [ moderate to light resistance]. Dir drill horizon section 9345 - 9522 [3750' tvd]. Weights up - down - rot = 104 - 55 - 7 Printed: 1/18/2002 2:06:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/9/2001 12/10/2001 12/11/2001 ( (: PHilliPS ALASKA INC. ,~r~)¡F r' ,t ~ i ,l F, D' ¿I \¡. .... &~ ,{ ~ ~# I '" ~'"'] ~ .~" Operations Summary Report ,\'"" ;'¡ , 'Ìt.r'I!., "co.,,; ,',:,~ /\;1:/ 1C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 Page 5 of 9 ,'-'.i;:'~~!~~~L:I;:':"<""'- ,'", ,., ::"::,-.Sþ,uä lffirie~"+1i129/2001 Start: 11/28/200{\h;,"êrfd~e 12/20/2001 Rig Release: 12/20/2001 Group: Rig Number: 3 Sub From - To Hours Code Code Phase 21 :30 - 00:00 00:00 - 06:00 06:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 17:00 17:30 - 00:00 00:00 - 01 :00 01:00 - 01:30 01 :30 - 02:00 02:00 - 08:00 08:00 - 09:00 09:00 - 21 :30 2.50 DRILL DRLH PROD 6.00 DRILL DRLH PROD 9.00 DRILL DRLH PROD 0.50 DRILL 1.00 DRILL 0.50 DRILL OTHR PROD TRIP PROD DRLH PROD 6.50 DRILL DRLH PROD 1.00 DRILL DRLH PROD 0.50 DRILL TRIP 0.50 DRILL 6.00 DRILL CIRC TRIP 1.00 DRILL TRIP 12.50 DRILL PROD PROD PROD PROD DRLG PROD Description of Operations 1k Ibs. P press @ 298 glm 2350 psi. Rot r pm = 60 - 70, motor rpm = 229 Torque on / off bottom 9000 I 8000 ft-Ibs. adt 17.25 hrs = ast 2.25 hrs + art 15.0 hrs Dir drill horizon section 9522 - 10349' [375 9' tvd]. Weights up - down - rot = 104 - 55 - 71k Ibs. P press @ 298 glm 2350 psi. Ro t rpm = 60 - 70, motor rpm = 229 Torque on I off bottom 9000 I 8000 ft-Ibs. Continue to drlg Horizonal section 9800 - 10 349' [3759']. Problems holding inclination h orizonal. Deviated out of 18' target corrido r 9800' md [3760' tvd] & was never able to g et back up to the desired zone. Inclination could be built but would not hold in rotation & would fall un expectantly I rapidly in slid e mode. Discuss option wI PPCO Engineering. Pooh to 9175' [3755'tvd] for oh sidetrack. Establishing ledge for sidetrace from 9155 to 9175' md, departed from original well bo re @ ? 9178' md. Tie on survey used is 912 7' md [3756' tvd]. Dir drill horizon side track section 9175 - 9 333' [3757' tvd]. Weights up - down - rot = 90 - 60 - 70k Ibs. P press @ 278 g/m 2250 psi. Rot rpm = 60 - 70, motor rpm = 215 T orque on I off bottom 7500 I 6500 ft-Ibs. R esistivity running 60 - 80 ohms in sidetrack. Dir drill horizon section 9333' - 9383 [3754' tvd]. Weights up - down - rot = 100 - 55 - 74k Ibs. P press @ 278 g/m 2200 psi. Rot rpm = 60 - 70, motor rpm = 214. Torque on I off bottom7000 I 6200 ft-Ibs. Back ream to 9037', wash - ream back to td 70 rpm, 2250 psi 1240 gpm. Work pipe off bottom 1800 psi I 200 gpm. Clean floor, adjust brakes, x-out wash pipe , change filters in tds gear box, adjust tds c ompensators, service gripper assembly & re place solinoid in gripper control box. Rih to 9335', did not orient I rotate into sid e track. Did not observe bit going into new hole. Ck located in sidetrack wI survey. C ontinue in hole to bottom @ 9383'. Dir drill horizon section 9383' -10111 [3758' tvd]. Weights up - down - rot = 100 - 45 - 70k Ibs. Pump press @ 278 g/m 2200 psi. Rot rpm = 60 - 70, motor rpm = 214. Torque on I off bottom 6200 I 6000 ft-Ibs. Numer ous motor stalls & high torque values coinci ding wI stablizer [6.5'] contact wI hard spo Printed: 1/18/2002 2:06:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/11/2001 ( \ ," ( Page 6 of 9 PHilliPS ALASKA INC. Operations Summary Report 1 C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 09:00 - 21 :30 12.50 DRILL DRLG PROD 21 :30 - 22:00 0.50 DRILL CIRC PROD 22:00 - 00:00 2.00 DRILL TRIP PROD 12/12/2001 00:00 - 03:00 3.00 DRILL TRIP PROD 03:00 - 06:00 3.00 DRILL PULD PROD 12/13/2001 06:00 - 06:30 06:30 - 07:30 07:30 -11:00 11 :00 - 12:30 12:30 - 14:30 14:30 - 20:00 20:00 - 21 :00 21:00 - 21:30 21 :30 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 04:00 04:00 - 11 :00 11 :00 ~ 13:30 13:30 - 17:30 17:30 - 23:00 23:00 - 00:00 0.50 RIGMNT RSRV PROD 1.00 DRILL TRIP PRD.D 3.50 DRILL PROD TRIP 1.50 RIGMNT RSRV PROD 2.00 DRILL TRIP PROD 5.50 DRILL DRLG PROD 1.00 DRILL DRLH PROD 0.50 DRILL 1.00 LOG TRIP PROD DEOT PROD 1.50 DRILL TRIP PROD 2.50 DRILL 1.50 DRILL PROD PROD TRIP TRIP 7.00 DRILL TRIP PROD 2.50 DRILL 4.00 DRILL 5.50 DRILL CIRC PROD DRLH PROD DEOT PROD 1.00 DRILL OTHR PROD Start: 11/28/2001 Rig Release: 12/20/2001 Rig Number: 3 Spud Date: 11/29/2001 End: 12/20/2001 Group: Description of Operations ts Resistivity = 60 - 100 ohms. Held 0 ps / planning meeting: current drlg activity, liner material accounting, liner displaceme nt to brine & as so logisitics. Cir I clean sidetrack section of hole. Pooh NOTE: Bit Photes e-mailed to s mck eever. Complete TOOH. DL MWD & LD MM. PU new M Motor/ bit #3, orient/scribe tools. Up load MWD & RIH w/ BHA. Service Rig. Continue in hole. Rotate slowly through TA M collar @ 15 rpm. Check TAM collar with p ressure test (250 psi! 5 min, bled down to 1 50 psi). Test MWD. Continue to RIH to 7,220'. Fill pipe every 1 0 stds. Break circulation @ 2 BPMI 360 psi. RU pump in sub on string and continue to circulate. Cut & Slip drilling line. Service Rig. Continue to RIH to 10,011' ; Wash & ream ti ght spot @ 7,883' & 9,470'. Check sidetrac k hole w/ mwd survy @ 9,307'. Did not rot at e/orient to aquire sidetrack. Dir drill from 10,011' to 10,349' [3755' TVD] Dir drill horizon section 10,349' - 10413' [3 753' TVD]. Weights up - down - rot = 100 - 52 - 70k Ibs. P press @ 278 glm 2050 psi. Rot rpm = 60 - 70, motor rpm = 214. Torque on / off bottom 7700 17400 ft-Ibs. Pooh to 9968'. Relog 9968 - 9913', Resistivity values muc h higher & Gamma Ray moderately higher th an originally logged. Pooh for Iwd tool x-out. [incomplete @ rpt ti me]. Continue to pooh to bha. Down load logging tools, x-out Iwd, Mu bha & rih 8 stands, rot through tam collar - soft press test same, shallow test mwd / Iwd. Rih to 9900': filling pipe every 10 stands, brk cir @ 7200', ck sidetrack w/ survey @ 9 310'. Ops / planning meeting @ 0900 hrs - subject liner to brine displacement. Re-Iog 9982 -10413. Dir Drlg 10413 - 10738 [3750' tvd]. Pooh to 9874', MAD pass zones [pulling out] 10487 - 10203' & 10075 - 9856' , pumping 250 gpm I 1590 psi / pulling 120 fph. Evaluate logs & confer wI PPCO engineering - Geo-science. Determine tools working co Printed: 1/18/2002 2:06:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: (. ( PHilliPS ALASKA INC. Operations Summary Report 1 C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 Page 7 of 9 Start: 11/28/2001 Rig Release: 12/20/2001 Rig Number: 3 Spud Date: 11/29/2001 End: 12/20/2001 Group: Date From - To Hours Code Sub Phase Code 12/13/2001 23:00 - 00:00 1.00 DRILL OTHR PROD 12/14/2001 00:00 - 00:30 0.50 DRILL TRIP PROD 00:30 - 06:00 5.50 DRILL DRLH PROD 06:00 - 07:00 1.00 RIGMNT RGRP PROD 12/15/2001 07:00 - 14:00 7.00 DRILL DRLG PROD 14:00 - 16:00 2.00 DRILL CIRC PROD 16:00 - 22:30 6.50 DRILL TRIP PROD 22:30 - 00:00 1.50 WELCT BOPE PROD Description of Operations rrectly. Rih to 10738' wash / reaming last stand to t d. Dir Drilled from 10,738' [3764' tvd] to 11,19 6' [3753' tvd]. TDS hydraulic control safety valve unexpect edly closed while drilling. Opended valve m anually and continued to circulate at slow r ate. Troubleshoot problem and found leaking hydraulic control line. Repair same. Dir drill from 11,190' to TD of 11,700' [3754 'TVD]. Parameters: Wts up-dwn-rot = 100 - 30 - 74k Ibs, Torque on - off bottom = 760 0 - 6700 ft-Ibs, 1850 psi I 6.1 bpm Circulate, take final survey, pump sweep an d C BU. POOH for reamer run. No over pulls on way out. Drain stack, pull wear bushing, set test plug & test bope 3500 - 300 psi 5 min each, ann ular test press 300 psi. Replace upper & I ower kelly valves, retest same good. Complete bope test. 3500 / 300 psi 5 min, annular to 3000 psi. Replace defective & te st upper / lower kelly valves. TIH w/ hole opener [bha]& 4' dp. Picking up 12 stands [1 ea 4" hwdp of & 2 ea 4.75" d c, 7 jts hwdp on top w/ one stand 4' dp for well control @ surface. Wash & ream tight zones from 7751'. through sidetrack @ 100 0 hrs [did not observe same]. Continue to w ash real tight zones to td of side track @ 11 707' [tally] , no correction madeto TD. Cir / cond pump 25 bbl hi vis / weighted swe ep. Displace hole w/ 470 bbl new mud. Pooh standing back string [incomplete @ rpt time]. Pooh standing back string. Id 3 jts flex pipe , jars & 2 stablizers & hole opener. All tool s in gage / no damage. Drain stack & clean floor. Pull wear bushin g. Set test plug, x-out lower pipe rams to 2 .875" & test 3500 / 300 psi 5 minutes. Pull test plug & install wear bushing. Cut & slip drlg line & ser rig - tds. PJSM running liner & rig up floor - tools fo r Ii n e r. Run 4.5" slotted liner assmby as per progra m { detailed on "1C-135 slotted Liner detail dated 12/16/2001"}. Note: Ops - Planning meeting on hole displacement / vac trk ava ilability - contingenecy if short & fluid disp osition. 19:00 - 21:30 2.50 CASE CIRC CMPL TN 21 :30 - 00:00 2.50 CASE OTHR CMPL TN 12/16/2001 00:00 - 04:00 4.00 CASE OTHR CMPL TN 00:00 - 04:00 04:00 - 19:00 04:00 - 05:00 05:00 - 07:00 07:00 - 08:00 08:00 - 13:00 4.00 WELCT BOPE CMPL TN 15.00 CASE OTHR CMPL TN 1.00 WELCT BOPE CMPL TN 2.00 RIGMNT RSRV CMPL TN 1.00 CASE SFTY CMPL TN 5.00 CASE PUTB CMPL TN Printed: 1/18/2002 2:06:27 PM ~ ..... ~ ~'PHILLiPS) lœ ."".. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/16/2001 12/17/2001 12/18/2001 12/19/2001 ( (" PHilliPS ALASKA INC. Operations Summary Report 1 C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 13:00 - 14:00 14:00 - 14:30 14:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 03:00 03:00 - 05:30 05:30 - 07:00 07:00 - 09:00 09:00 - 10:30 10:30 - 11 :00 11 :00 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 07:30 07:30 - 10:00 10:00 - 14:00 14:00 - 16:30 16:30 - 00:00 00:00 - 09:30 09:30 - 13:00 13:00 - 15:30 1.00 CASE OTHR CMPL TN 0.50 CASE 6.50 CASE SFTY CMPL TN OTHR CMPL TN 1.00 CASE OTHR CMPL TN 2.00 CASE RUNL CMPL TN 3.00 CASE RUNL CMPL TN 2.50 CASE OTHR CMPL TN 1.50 CASE CIRC CMPLTN 2.00 CASE OTHR CMPL TN 1.50 CASE CIRC CMPLTN 0.50 CASE OTHR CMPLTN 13.00 CASE OTHR CMPL TN 2.00 CASE OTHR 0.50 LOG SFTY 5.00 LOG OTHR 2.50 CMPL TN TRI P 4.00 CMPL TN PULD 2.50 CMPL TN OTHR CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN 7.50 CMPLTN RUNT CMPLTN 9.50 CMPL TN RUNT CMPL TN 3.50 CMPL TN SOHO CMPL TN 2.50 CMPLTN CIRC CMPLTN Page 8 of 9 Start: 11/28/2001 Rig Release: 12/20/2001 Rig Number: 3 Spud Date: 11/29/2001 End: 12/20/2001 Group: Description of Operations Ru false rotary table & tools for running 2.8 75" Hydrill 511 interstring tbg. PJSM - running 511 interstring. Running cup assemby & 147 its + 21.27' [pu ps] of 2.875" 511 interstring as per progra m - Baker service Representative. Mu packer to liner string, interstring to sett ing tool. Continue to rih wI liner assmby on 4" dp {in complete @ rpt time}. Rih wI liner on 4' dp wI 12 stands of weight ed assembly on top, tag td @ 11710', no cor recti on made to td of 11700'. Brk cir, drop ball & set pkr @ 7173' rkb Nor dic 3. Hydraulic set pkr in 3 stages wI final press of 3100 psi.Ck wI set down of 20k Ib s & over pull of 15k Ibs. Press test ann to 1000 psi good [set down 5k Ibs]. Pu to neut ral & press - shear off pkr wI 1500 psi annul ar pressure. Break cir, pump 30bbl push pill, & disp oh x 4.5" slottled liner annulus wI 587 bbl [158 bbl over calculated] 8.8 ppg kcl brine, 3250 psi I 8 bpm. Discharge old mud to trucks, clean pits for 2nd disp & take on add 290bbl 8.8 ppg brin e. Reposition interstring to displace 2.875 x 4. 5' slotted liner & displace wI 511 bbl [162 b lover calculated] 8.8 ppg kcl brine. NO TE: To this point have displace w/1128 bbl b rine or 2.63 x total hole volume. Rd cir lines, drain up tds, & monitor hole st at i c. Pooh laying down all tublar goods. [incompl ete @ rpt time]. 0 Continue to Id dp from well bore. PJSM before running US IT log. Running US IT log. Rig down sws. RIH wI 4" dp. Lay Down 4" dp. Rig up to run com pit ion-Change upper pipe r ams to 3.5"-pull wear ring-set test plug-test upper pipe rams 250-4000#. Rig up baker control line-PJSM-running 3.5" completion. Run in Hole wI completion as per program to 7131' . Rig up lines-break circ.-tag SBR @ 7152'-op en bleeder-continue down to 7172'-tag no-go Space out wI pups below top it. Pump hi vis sweep-Chase sweep wI filtered brine @ 10 bpm. Î" Printed: 1/18/2002 2:06:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/19/2001 12/20/2001 ( (' PHILLIPS ALASKA INC. Operations Summary Report 1C-135 1 C-135 ROT - DRILLING n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 15:30 - 16:30 16:30 -19:30 19:30 - 20:30 20:30 - 00:00 00:00 - 02:30 02:30 - 05:00 05:00 - 06:30 06:30 - 10:00 10:00 - 11 :00 1.00 CMPL TN OTHR CMPL TN 3.00 CMPL TN SOHO CMPL TN 1.00 CMPL TN DEOT CMPL TN 3.50 CMPL TN NUND CMPL TN 2.50 CMPL TN NUND CMPL TN 2.50 CMPL TN FRZP CMPL TN 1.50 CMPL TN OTHR CMPL TN 3.50 CMPL TN OTHR CMPL TN 1.00 CMPL TN OTHR CMPL TN Page 9 of 9 Start: 11/28/2001 Rig Release: 12/20/2001 Rig Number: 3 Spud Date: 11/29/2001 End: 12/20/2001 Group: Description of Operations Splice tech wire & attach penetrator. Land hanger-60k up-45k down-rilds-rig up to pump down annulus-test upper & lower seal s in hanger to 5k 15 mins. Thaw out kill line-test annulus to 2500# 15 mins.-pressure to 3450 to shear valve-break down lines-lay down landing it. Install BPV-nipple down bope-nipple up tree N/U tree-pull bpv-install 2 way check-test n eck seal/api ring area-test tree 250-5000 15 mins. ok. Pull 2 way check. Rig up tree to kill manifold-test lines wI air pressure-freeze protect wI 113 bbls. diesel- allow diesel to swap-80 psi on tbg. Pick up lubricator-install bpv. Secure well-finish cleaning pits-ready rig fo r move. Move off well-remove diverter from 1 c-135-c lean up well head area.(Release rig from 1C -135 @ 1100 hrs. 12/20/2001. Printed: 1/18/2002 2:06:27 PM ~¡ " ~ \ (fit,:;.: .,,\1. ~1';I'" ". , '- !"," :',~ -'¡¡'I '~ ".'.' ",c\) ",ìt.:I"::;:'-ii?I:"~ ' ", II"T' ,,' ~,- '1',~',.. .,'" '," '\.j'~" 27-Dec-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-135PB 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: ' MD Window / Kickoff Survey , MD Projected Survey: 10,350.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RE(~E "lED DEC 2 8 2001 Alaska on & Gas Cons. uÞmrm$SIOI Ancl:'tDTage ~'~' Kuparuk River Unit North Slope, Alaska Kuparuk 1C, Slot 1C-135 1C-135 MWD Job No. AKMM11196, Surveyed: 14 December, 2001 SURVEY REPORT 27 December, 2001 Your Ref: API 500292305300 Surface Coordinates: 5968530.55 N, 562030.50 E (70° 19' 28.3928" N, 149029' 49.2612" W) Surface Coordinates relative to Project H Reference: 968530.55 N, 62030.50 E (Grid) Surface Coordinates relative to Stucture Referance: 10.91 N, 341.47 W (True) Kelly Bushing: 90.5Oft above Mean Sea Level c- spel'I'Y-SUI'1 DRILLING. SERVices A Halliburton Company ,.,- RECEIVED DFC 2 8 2001 Alas~a Oil & Gas Cons. Commøor. An~age Survey Ref: svy9742 Sperry-Sun Drilling Services . Survey Report for 1C-135 MWD Your Ref: AP/500292305300 Job No. AKMM11196, Surveyed: 14 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (It) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9127.33 91.110 173.080 3663.95 3754.45 7224.90 8 1279.25 E 5961316.47 N 563369.42 E 7224.90 Tie On Point 9155.00 91.250 172.720 3663.38 3753.88 7252.35 S 1282.67 E 5961289.05 N 563373.07 E 1.396 7252.35 Window Point 9173.28 88.960 172.550 3663.34 3753.84 7270.48 S 1285.01 E 5961270.94 N 5633,75.56 E 12.562 7270.48 9222.68 86.920 171.190 3665.12 3755.62 7319.35 S 1291.99 E 5961222.13 N 563382.95 E 4.962 7319.35 9267.87 89.510 171.670 3666.53 3757.03 7364.01 S 1298.72 E 5961177.53 N 563390.05 E 5.829 7364.01 - ~- 9317.04 92.090 173.070 3665.84 3756.34 7412.73 S 1305.25 E 5961128.86 N 563396.98 E 5.970 7412.73 9362.51 92.640 173.560 3663.96 3754.46 7457.85 S 1310.54 E 5961083.79 N 563402.64 E 1.619 7457.85 9411.59 90.000 174.630 3662.83 3753.33 7506.65 S 1315.58 E 5961035.03 N 563408.09 E 5.804 7506.65 9457.26 90.370 174.070 3662.68 3753.18 7552.10 S 1320.08 E 5960989.62 N 563412.96 E 1.470 7552.10 9507.61 88.520 172.990 3663.17 3753.67 7602.13 S 1325.75 E 5960939.64 N 563419.05 E 4.254 7602.13 9544.32 90.180 173.550 3663.59 3754.09 7638.58 S 1330.05 E 5960903.23 N 563423.65 E 4.772 7638.58 9602.34 89.940 173.780 3663.53 3754.03 7696.24 S 1336.46 E 5960845.62 N 563430.53 E 0.573 7696.24 9647.38 H9.8AG 174.530 3663.60 3754.10 7741.058 1341.04 E 5960800.85 N 563435.49 E 1.671 7741.05 9703.62 91. 170 174.260 3663.08 3753.58 7797.02 S 1346.54 E 5960744.93 N 563441.44 E 2.343 7797.02 9742.63 90.800 174.180 3662.41 3752.91 7835.82 S 1350.46 E 5960706.16 N 563445.69 E 0.970 7835.82 9793.70 90.430 175.730 3661.86 3752.36 7886.69 S 1354.95 E 5960655.33 N 563450.60 E 3.120 7886.69 9833.97 89.880 176.440 3661.76 3752.26 7926.87 S 1357.70 E 5960615.18 N 563453.68 E 2.230 7926.87 9886.04 89.690 178.380 3661.95 3752.45 7978.88 S 1360.06 E 5960563.18 N 563456.46 E 3.744 7978.88 9932.45 88.520 179.490 3662.68 3753.18 8025.28 S 1360.92 E 5960516.80 N 563457.71 E 3.475 8025.28 9951.57 88.650 178.570 3663.15 3753.65 8044.39 S 1361.24 E 5960497.69 N 563458.19 E 4.858 8044.39 9997.71 88.460 176.210 3664.31 3754.81 8090.46 S 1363.34 E 5960451.64 N 563460.67 E 5.130 8090.46 ", 10047.25 90.370 174.180 3664.82 3755.32 8139.82 S 1367.49 E 5960402.31 N 563465.23 E 5.626 8139.82 --=-- 10091.45 90.490 173.650 3664.49 3754.99 8183.77 S 1372.18 E 5960358.40 N 563470.28 E 1.229 8183.77 10141.37 90.550 172.850 3664.03 3754.53 8233.34 S 1378.04 E 5960308.88 N 563476.56 E 1.607 8233.34 10186.48 90.310 172.820 3663.69 3754.19 8278.10 S 1383.67 E 5960264.17 N 563482.55 E 0.536 8278.10 10235.72 90.860 169.790 3663.19 3753.69 8326.76 S 1391.11 E 5960215.57 N 563490.40 E 6.254 8326.76 10280.46 90.370 168.450 3662.71 3753.21 8370.69 S 1399.56 E 5960171.71 N 563499.20 E 3.189 8370.69 10328.33 90.620 165.680 3662.30 3752.80 8417.34 S 1410.27 E 5960125.15 N 563510.30 E 5.810 8417.34 10374.04 90.060 163.830 3662.03 3752.53 8461.44 S 1422.29 E 5960081.15 N 563522.68 E 4.229 8461.44 10425.81 89.820 161.190 3662.08 3752.58 8510.81 S 1437.85 E 5960031.91 N 563538.65 E 5.121 8510.81 '-- ,_m"- --- --" "- ,- " 27 December, 2001 - 12:13 Page 2 of 4 DrlllQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 1C-135 MWD Your Ref: AP/500292305300 Job No. AKMM11196, Surveyed: 14 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10467.46 89.320 160.810 3662.39 3752.89 8550.19 S 1451.41 E 5959992.65 N 563552.53 E 1.508 8550.19 10521.90 89.260 158.550 3663.07 3753.57 8601.24 S 1470.31 E 5959941.76 N 563571.86 E 4.153 8601.24 10562.20 89.380 156.230 3663.55 3754.05 8638.44 S 1485.80 E 5959904.69 N 563587.66 E 5.764 8638.44 10615.29 89.200 154.020 3664.20 3754.70 8686.59 S 1508.13 E 5959856.72 N 563610.38 E 4.176 8686.59 10660.24 89.450 151 .400 3664.73 3755.23 8726.53 S 1528.74 E 5959816.95 N 563631.32 E 5.855 8726.53 -~/ 10709.80 90.490 149.790 3664.76 3755.26 8769.71 S 1553.07 E 5959773.98 N 563656.01 E 3.867 8769.71 10754.97 91.230 148.460 3664.08 3754.58 8808.47 S 1576.24 E 5959735.41 N 563679.50 E 3.369 8808.47 10810.51 91.290 147.890 3662.86 3753.36 8855.65 S 1605.52 E 5959688.47 N 563709.17 E 1.032 8855.65 10848.78 91.910 148.750 3661.79 3752.29 8888.20 S 1625.61 E 5959656.09 N 563729.53 E 2.770 8888.20 10897.28 90.060 147.880 3660.96 3751.46 8929.47 S 1651.08 E 5959615.04 N 563755.34 E 4.215 8929.47 10943.72 89.200 147.730 3661.26 3751.76 8968.77 S 1675.83 E 5959575.94 N 563780.41 E 1.880 8968.77 10997.34 89.940 148.920 3661.66 3752.16 9014.40 S 1703.98 E 5959530.55 N 563808.94 E 2.613 9014.40 11038.44 89.080 149.060 3662.01 3752.51 9049.62 S 1725.15 E 5959495.50 N 563830.40 E 2.120 9049.62 11089.21 89.880 149.880 3662.47 3752.97 9093.35 S 1750.94 E 5959451.99 N 563856.55 E 2.256 9093.35 11133.33 89.690 150.000 3662.64 3753.14 9131.53 S 1773.04 E 5959413.98 N 563878.96 E 0.509 9131.53 11181.48 90.490 151.130 3662.56 3753.06 9173.47 S 1796.71 E 5959372.25 N 563902.97 E 2.875 9173.47 11228.30 90.680 150.880 3662.08 3752.58 9214.42 S 1819.40 E 5959331.49 N 563926.00 E 0.671 9214.42 11276.89 89.690 149.650 3661.93 3752.43 9256.61 S 1843.50 E 5959289.50 N 563950.45 E 3.249 9256.61 11323.70 89.450 149.190 3662.28 3752.78 9296.91 S 1867.31 E 5959249.40 N 563974.60 E 1.108 9296.91 11370.46 90.490 151.290 3662.30 3752.80 9337.50 S 1890.52 E 5959209.00 N 563998.14 E 5.012 9337.50 11418.26 90.370 151.070 3661.94 3752.44 9379.37 S 1913.56 E 5959167.31 N 564021.53 E 0.524 9379.37 11465.57 89.020 150.340 3662.20 3752.70 9420.63 S 1936.71 E 5959126.25 N 564045.02 E 3.244 9420.63 '- 9459.92 S 1959.32 E 5959087.15 N 564067.95 E 11510.91 88.400 149.820 3663.22 3753.72 1.785 9459.92 11556.73 91 .420 151.210 3663.29 3753.79 9499.80 S 1981.87 E 5959047.46 N 564090.83 E 7.255 9499.80 11601.94 91.350 150.400 3662.20 3752.70 9539.25 S 2003.91 E 5959008.19 N 564113.20 E 1.798 9539.25 11622.17 90.860 150.100 3661.81 3752.31 9556.81 S 2013.95 E 5958990.71 N 564123.38 E 2.840 9556.81 11700.00 90.860 150.100 3660.64 3751.14 9624.28 S 2052.74 E 5958923.57 N 564162.73 E 0.000 9624.28 Projected Survey -- -- H- - -- 27 December, 2001 - 12:13 Page 3 of 4 DrillQuest 2.00.09.003 Kuparuk River Unit Sperry-Sun Drill i ng Services Survey Report for 1C-135 MWD Your Ref: AP/500292305300 Job No. AKMM11196, Surveyed: 14 December, 2001 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to AKB = 90.5' (MSL). Northings and Eastings are relative to 1706' FNL, 1022' FWL. Magnetic Declination at Surface is 26.035" (27-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1706' FNL, 1022' FWL and calculated along an Azimuth of 180.0000 (True). "'- Based upon Minimum Curvature type calculations, at a Measured Depth of 11700.0Of1., The Bottom Hole Displacement is 9840.76f1., in the Direction of 167.9600 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9127.33 9155.00 11700.00 3754.45 3753.88 3751.14 7224.90 S 7252.35 S 9624.28 S Survey tool program for 1 C-135 MWD ~,~ From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 27 December, 2001 - 12:13 To Measured Vertical Depth Depth (ft) (ft) 11700.00 3751.14 1279.25 E 1282.67 E 2052.74 E Tie On Point Window Point Projected Survey Survey Tool Description MWD Magnetic (1C-135PB1 MWD) - ~- ---- Page 4 of 4 . North Slope, Alaska Kuparuk 1 C -------- . Drll/Quest 2.00.09.003 ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-135MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,127.33' MD Window / Kickoff Survey 9,155.00' MD Projected Survey: 11,700.00' MD (if applicable) If .".""".""".":,,,,,,.,:,~;;:.<,\.I:;\r::,::.,~',~'?",:'::",',,;:::c~:~:,,"~".i[..w","',')"""'" ',' ~~~":D,'.:'~~O" 27-Dec-01 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED 0 r-I'" r') ':\J t:. 8 2001 Alaska Oil & Gas "', ". JI ¡.. t;ons. 'vomrrIlSStor' i'"'InC"!Iorage ~{, ~. ~ j .<rß -::;:.- Kuparuk River Unit North Slope, Alaska Kuparuk 1 C, Slot 1 C-135 1C-135PB1 MWD Job No. AKMM11196, Surveyed: 10 December, 2001 RECE\VED SURVEY REPORT O:çt'. ? 0 "001 '"-.\-, '- U L 27 December, 2001 AlasKa on & Gas Cons. commtS8Kìf' Pu'1cOOrage Your Ref: API 500292305370 Surface Coordinates: 5968530.55 N, 562030.50 E (70° 19.28.3928" N, 149029' 49.2612" W) Kelly Bushing: 90.50ft above Mean Sea Level -- 5ipe!rT"}J-SU" DRILLING SERVices A Halliburton Company Survey Ref: svy9741 Sperry-Sun Drilling Services Survey Report for 1C-135PB1 MWD Your Ref: API 500292305370 Job No. AKMM11196, Surveyed: 10 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -90.50 0.00 O.OON O.OOE 5968530.55 N 562030.50 E 0.00 MWD Magnetic 175.77 1.060 244.280 85.26 175.76 0.715 1.46 W 5968529.83 N 562029.04 E 0.603 0.71 "=- 234.69 1.740 245.520 144.16 234.66 1.31 S 2.77W 5968529.21 N 562027.74 E 1.155 1.31 286.40 2.680 247.510 195.83 286.33 2.10 S 4.60W 5968528.41 N 562025.92 E 1.824 2.10 328.02 3.860 235.110 237.39 327.89 3.27 S 6.65W 5968527.22 N 562023.88 E 3.290 3.27 378.57 5.900 233.150 287.75 378.25 5.81 S 10.12 W 5968524.66 N 562020.42 E 4.048 5.81 421.02 7.560 234.550 329.91 420.41 8.735 14.15 W 5968521.70 N 562016.43 E 3.929 8.73 467.34 8.230 234.770 375.79 466.29 12.41 S 19.34 W 5968517.98 N 562011.27 E 1.448 12.41 511.83 8.150 235.350 419.82 510.32 16.045 24.53 W 5968514.30 N 562006.10 E 0.259 16.04 607.68 9.670 222.760 514.52 605.02 25.82 5 35.59 W 5968504.44 N 561995.13 E 2.571 25.82 701.10 13.330 210.650 606.06 696.56 40.85 5 46.41 W 5968489.32 N 561984.43 E 4.673 40.85 796.94 15.620 206.150 698.86 789.36 61.945 57.73 W 5968468.13 N 561973.28 E 2.660 61.94 890.52 15.570 204.580 788.99 879.49 84.67 S 68.51 W 5968445.31 N 561962.70 E 0.454 84.67 984.64 18.440 201.670 878.99 969.49 110.00 S 79.26 W 5968419.90 N 561952.15 E 3.180 110.00 1080.14 23.070 196.500 968.28 1058.78 142.00 5 90.16 W 5968387.81 N 561941.52 E 5.210 142.00 1174.13 25.780 192.270 1053.85 1144.35 179.635 99.74 W 5968350.10 N 561932.25 E 3.430 179.63 1268.12 26.650 191.110 1138.18 1228.68 220.29 5 108.14 W 5968309.37 N 561924.18 E 1.074 220.29 1363.20 29.030 189.670 1222.25 1312.75 263.96 S 116.13 W 5968265.64 N 561916.56 E 2.601 263.96 1458.37 32.000 187.050 1304.23 1394.73 311.77 S 123.10W 5968217.78 N 561909.98 E 3.419 311.77 1551.81 33.040 183.780 1383.02 1473.52 361.765 127.82 W 5968167.75 N 561905.67 E 2.186 361.76 -- 1646.70 36.980 179.500 1460.74 1551.24 416.145 129.28 W 5968113.36 N 561904.67 E 4.890 416.14 1741.40 39.940 175.170 1534.90 1625.40 474.935 126.47 W 5968054.59 N 561907.96 E 4.224 474.93 1836.26 44.060 171.540 1605.39 1695.89 537.945 119.05 W 5967991.65 N 561915.90 E 5.040 537.94 1930.05 48.880 169.000 1669.97 1760.47 604.92 5 107.50 W 5967924.76 N 561928.00 E 5.501 604.92 2025.27 52.700 168.460 1730.16 1820.66 677.26 S 93.08 W 5967852.55 N 561943.03 E 4.036 677.26 2119.88 56.110 169.840 1785.22 1875.72 752.81 5 78.62 W 5967777.12 N 561958.11 E 3.794 752.81 2214.43 61.640 169.540 1834.07 1924.57 832.40 5 64.13 W 5967697.64 N 561973.25 E 5.855 832.40 2309.54 65.430 166.360 1876.46 1966.96 915.635 46.32 W 5967614.56 N 561991.75 E 4.983 915.63 2402.09 65.420 164.430 1914.95 2005.45 997.08 5 25.10 W 5967533.30 N 562013.64 E 1.896 997.08 2496.69 66.720 164.340 1953.32 2043.82 1080.35 5 1.83W 5967450.22 N 562037.60 E 1.377 1080.35 27 December, 2001 - 11:26 Page 2 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1C-135PB1 MWD Your Ref: API 500292305370 Job No. AKMM11196, Surveyed: 10 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2592.72 66.440 163.860 1991.49 2081.99 1165.10 S 22.31 E 5967365.68 N 562062.44 E 0.543 1165.10 2687.11 69.360 165.670 2027.00 2117.50 1249.47 S 45.28 E 5967281.50 N 562086.10 E 3.567 1249.47 <~ 2780.86 69.960 165.100 2059.59 2150.09 1334.53 S 67.46 E 5967196.62 N 562108.99 E 0.857 1334.53 2878.24 69.890 165.780 2093.01 2183.51 1423.05 S 90.45 E 5967108.29 N 562132.71 E 0.660 1423.05 2972.06 69.350 165.810 2125.69 2216.19 1508.31 S 112.03 E 5967023.22 N 562155.00 E 0.576 1508.31 3067.24 68.960 165.770 2159.56 2250.06 1594.54 S 133.87 E 5966937.17 N 562177.54 E 0.412 1594.54 3161.57 68.630 166.420 2193.68 2284.18 1679.91 S 155.00 E 5966851.98 N 562199.38 E 0.731 1679.91 3256.18 68.760 166.540 2228.05 2318.55 1765.61 S 175.61 E 5966766.46 N 562220.70 E 0.181 1765.61 3351.07 70.470 165.390 2261.10 2351.60 1851.89 S 197.18 E 5966680.35 N 562242.98 E 2.130 1851.89 3445.96 69.870 165.550 2293.29 2383.79 1938.30 S 219.58 E 5966594.13 N 562266.09 E 0.652 1938.30 3540.4 7 70.070 164.590 2325.66 2416.16 2024.10 S 242.46 E 5966508.53 N 562289.68 E 0.978 2024.10 3635.30 68.240 164.540 2359.41 2449.91 2109.52 S 266.04 E 5966423.30 N 562313.97 E 1.930 2109.52 3729.67 68.110 164.930 2394.49 2484.99 2194.03 S 289.11 E 5966338.98 N 562337.73 E 0.408 2194.03 3824.24 70.150 164.070 2428.18 2518.68 2279.18 S 312.72 E 5966254.04 N 562362.05 E 2.318 2279.18 3918.98 70.540 164.220 2460.05 2550.55 2365.00 S 337.10 E 5966168.41 N 562387.14 E 0.438 2365.00 4014.08 70.350 164.450 2491.88 2582.38 2451.29 S 361.30 E 5966082.33 N 562412.05 E 0.303 2451.29 4108.35 70.070 163.880 2523.80 2614.30 2536.63 S 385.50 E 5965997.20 N 562436.95 E 0.642 2536.63 4203.45 70.420 163.920 2555.94 2646.44 2622.62 S 410.32 E 5965911.41 N 562462.48 E 0.370 2622.62 4298.02 69.940 163.160 2588.01 2678.51 2707.94 S 435.53 E 5965826.30 N 562488.40 E 0.911 2707.94 4392.90 68.640 163.070 2621.56 2712.06 2792.86 S 461.30 E 5965741.60 N 562514.87 E 1.373 2792.86 - 4483.63 68,840 162.330 2654.46 2744.96 2873.59 S 486.45 E 5965661.08 N 562540.68 E 0.791 2873.59 4582.70 68.850 162.640 2690.21 2780.71 2961.70 S 514.25 E 5965573.20 N 562569.22 E 0.292 2961.70 4677.22 69.090 162.870 2724.13 2814.63 3045.96 S 540.41 E 5965489.16 N 562596.07 E 0.341 3045.96 4769.19 66.310 162.010 2759.03 2849.53 3127.08 S 566.07 E 5965408.26 N 562622.40 E 3.144 3127.08 4864.90 66.240 161 .720 2797.53 2888.03 3210.35 S 593.35 E 5965325.22 N 562650.36 E 0.287 3210.35 4960.39 66.030 163.870 2836.17 2926.67 3293.76 S 619.17E 5965242.02 N 562676.88 E 2.071 3293.76 5055.86 66.630 164.320 2874.50 2965.00 3377.85 S 643.14E 5965158.13 N 562701.54 E 0.762 3377.85 5150.57 66.770 164.090 2911.96 3002.46 3461.55 S 666.81 E 5965074.63 N 562725.90 E 0.268 3461.55 5245.06 67.230 164.510 2948.88 3039.38 3545.28 S 690.35 E 5964991.10 N 562750.13 E 0.636 3545.28 5340.11 65,290 165.490 2987.15 3077.65 3629.32 S 712.87 E 5964907.25 N 562773.35 E 2.249 3629.32 '_.0_-- ._------ . 27 December, 2001 - 11:26 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1C-135PB1 MWD Your Ref: API 500292305370 Job No. AKMM11196, Surveyed: 1° December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5435.23 65.100 165.540 3027.05 3117.55 3712.92 S 734.47 E 5964823.83 N 562795.64 E 0.205 3712.92 5529.84 65.520 165.170 3066.57 3157.07 3796.08 S 756.20 E 5964740.85 N 562818.06 E 0.569 3796.08 ,,~ 5625.08 65.910 165.720 3105.74 3196.24 3880.11 S 778.02 E 5964657.00 N 562840.57 E 0.667 3880.11 5718.77 66.240 165.390 3143.74 3234.24 3963.04 S 799.38 E 5964574.25 N 562862.61 E 0.477 3963.04 5814.50 66.490 165.560 3182.12 3272.62 4047.94 S 821.38 E 5964489.54 N 562885.31 E 0.308 4047.94 5908.60 66.040 166.700 3219.99 3310.49 4131.57 S 842.03 E 5964406.09 N 562906.65 E 1.208 4131.57 6003.65 67.240 167.110 3257.68 3348.18 4216.55 S 861.80 E 5964321.26 N 562927.12 E 1.323 4216.55 6098.40 68.170 167.570 3293.63 3384.13 4302.09 S 881.01 E 5964235.89 N 562947.04 E 1.079 4302.09 6193.54 68.320 167.530 3328.89 3419.39 4388.37 S 900.06 E 5964149.77 N 562966.80 E 0.162 4388.37 6288.62 67.490 167.060 3364.65 3455.15 4474.31 S 919.43 E 5964063.99 N 562986.89 E 0.986 4474.31 6382.97 67.850 167.050 3400.50 3491.00 4559.37 S 938.98 E 5963979.10 N 563007.14 E 0.382 4559.37 6473.54 67.570 166.120 3434.85 3525.35 4640.89 S 958.42 E 5963897.75 N 563027.25 E 0.999 4640.89 6572.15 67.900 164.310 3472.22 3562.72 4729.12 S 981.71 E 5963809.71 N 563051.27 E 1.731 4729.12 6666.55 67.450 164.270 3508.08 3598.58 4813.18 S 1005.36 E 5963725.85 N 563075.61 E 0.4 78 4813.18 6761.38 67.370 163.710 3544.50 3635.00 4897.34 S 1029.51 E 5963641.89 N 56310Ç).45 E 0.552 4897.34 6856.21 67.050 163.540 3581.24 3671.74 4981.22 S 1054.15 E 5963558.22 N 563125.79 E 0.376 4981.22 6904.49 68.840 164.290 3599.37 3689.87 5024.21 S 1066.55 E 5963515.33 N 563138.54 E 3.977 5024.21 6949.93 69.760 165.400 3615.43 3705.93 5065.24 S 1077.66 E 5963474.39 N 563149.99 E 3.053 5065.24 6999.47 73.390 168.330 3631.09 3721.59 5111.00 S 1088.32 E 5963428.72 N 563161.03 E 9.228 5111.00 7045.79 77 .200 169.440 3642.84 3733.34 5154.95 S 1096.96 E 5963384.84 N 563170.03 E 8.546 5154.95 -- 7094.00 79.530 170.870 3652.56 3743.06 5201.47 S 1105.03 E 5963338.39 N 563178.48 E 5.639 5201.47 7140.81 81.400 171.930 3660.32 3750.82 5247.11 S 1111.93 E 5963292.81 N 563185.76 E 4.577 5247.11 7188.51 84.010 173.020 3666.38 3756.88 5294.02 S 1118.12 E 5963245.96 N 563192.34 E 5.923 5294.02 7236.55 85.690 175.380 3670.69 3761.19 5341.61 S 1122.96 E 5963198.40 N 563197.57 E 6.014 5341.61 7326.08 86.980 177.300 3676.41 3766.91 5430.77 S 1128.66 E 5963109.29 N 563204.01 E 2.580 5430.77 7373.44 90.980 179.410 3677.25 3767.75 5478.09 S 1130.02 E 5963061.99 N 563205.76 E 9.548 5478.09 7421.67 90.990 178.120 3676.43 3766.93 5526.30 S 1131.06 E 5963013.79 N 563207.20 E 2.674 5526.30 7468.14 90.430 177.790 3675.85 3766.35 5572.74 S 1132.71 E 5962967.37 N 563209.24 E 1.399 5572.74 7516.75 89.690 177.750 3675.80 3766.30 5621.31 S 1134.60 E 5962918.81 N 563211.53 E 1.525 5621.31 7563.71 90.310 176.740 3675.80 3766.30 5668.22 S 1136.86 E 5962871.93 N 563214.18 E 2.524 5668.22 ---- -. --- _u- ---- ---- 27 December, 2001 - 11:26 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1C-135PB1 MWD Your Ref: API 500292305370 Job No. AKMM11196, Surveyed: 10 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub.Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7612.76 91.850 176.540 3674.87 3765.37 5717.17 S 1139.74 E 5962822.99 N 563217.46 E 3.166 5717.17 7658.26 91.850 176.320 3673.41 3763.91 5762.56 S 1142.57 E 5962777.63 N 563220.66 E 0.483 5762.56 -.~ 7707.49 89.940 175.530 3672.64 3763.14 5811.66S 1146.07 E 5962728.57 N 563224.57 E 4.198 5811.66 7752.96 91.110 175.270 3672.22 3762.72 5856.98 S 1149.71 E 5962683.28 N 563228.59 E 2.636 5856.98 7802.08 91.170 174.630 3671.24 3761.74 5905.90 S 1154.03 E 5962634.39 N 563233.31 E 1.308 5905.90 7847.75 90.860 174.310 3670.43 3760.93 5951.35 S 1158.44 E 5962588.98 N 563238.09 E 0.975 5951.35 7896.82 90.310 173.890 3669.93 3760.43 6000.15 S 1163.48 E 5962540.22 N 563243.54 E 1.410 6000.15 7942.58 89.940 174.170 3669.83 3760.33 6045.67 S 1168.24 E 5962494.75 N 563248.67 E 1.014 6045.67 7991.21 91.480 174.470 3669.23 3759.73 6094.05 S 1173.05 E 5962446.40 N 563253.88 E 3.226 6094.05 8037.59 93.630 173.950 3667.16 3757.66 6140.15 S 1177.72 E 5962400.35 N 563258.94 E 4.769 6140.15 8088.09 91.230 174.820 3665.02 3755.52 6190.35 S 1182.66 E 5962350.18 N 563264.29 E 5.055 6190.35 8132.23 90.060 175.930 3664.52 3755.02 6234.35 S 1186.22 E 5962306.22 N 563268.21 E 3.654 6234.35 8181.49 88.280 175.540 3665.24 3755.74 6283.46 S 1189.88 E 5962257.14 N 563272.28 E 3.699 6283.46 8226.75 88.150 175.740 3666.65 3757.15 6328.57 S 1193.32 E 5962212.06 N 563276.09 E 0.527 6328.57 8275.99 88.460 175.290 3668.10 3758.60 6377.64 S 1197.17 E 5962163.03 N 563280.35 E 1.109 6377.64 8321.95 89.940 174.760 3668.75 3759.25 6423.42 S 1201.16 E 5962117.28 N 563284.71 E 3.420 6423.42 8370.60 89.880 175.250 3668.82 3759.32 6471.88 S 1205.39 E 5962068.85 N 563289.35 E 1.015 6471.88 8416.29 90.680 174.410 3668.60 3759.10 6517.39 S 1209.51 E 5962023.38 N 563293.84 E 2.539 6517.39 8457.80 90.800 174.410 3668.06 3758.56 6558.70 S 1213.55 E 5961982.11 N 563298.22 E 0.289 6558.70 8511.95 89.690 173.730 3667.83 3758.33 6612.55 S 1219.15 E 5961928.30 N 563304.26 E 2.404 6612.55 - 8556.40 89.510 174.470 3668.14 3758.64 6656.77 S 1223.71 E 5961884.13 N 563309.20 E 1.713 6656.77 8605.40 89.080 174.650 3668.74 3759.24 6705.54 S 1228.36 E 5961835.39 N 563314.25 E 0.951 6705.54 8647.82 90.120 172.980 3669.04 3759.54 6747.71 S 1232.93 E 5961793.26 N 563319.16 E 4.638 6747.71 8700.04 91.040 175.590 3668.51 3759.01 6799.67 S 1238.13 E 5961741.35 N 563324.79 E 5.299 6799.67 8742.14 91.600 175.270 3667.54 3758.04 6841.62 S 1241.48 E 5961699.43 N 563328.49 E 1.532 6841.62 8794.47 90.740 174.370 3666.47 3756.97 6893.72 S 1246.21 E 5961647.36 N 563333.65 E 2.379 6893.72 8847.86 91.170 174.990 3665.58 3756.08 6946.88 S 1251.16E 5961594.25 N 563339.04 E 1.413 6946.88 8889.75 90.800 175.490 3664.86 3755.36 6988.62 S 1254.63 E 5961552.54 N 563342.86 E 1.485 6988.62 8938.98 89.880 174.280 3664.57 3755.07 7037.65 S 1259.02 E 5961503.55 N 563347.65 E 3.088 7037.65 8984.32 89.880 174.470 3664.67 3755.17 7082.77 S 1263.46 E 5961458.47 N 563352.47 E 0.419 7082.77 -- q----- 27 December, 2001 - 11:26 Page 5 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1C-135PB1 MWD Your Ref: API 500292305370 Job No. AKMM111QS, Surveyed: 10 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9033.63 89.940 173.030 3664.74 3755.24 7131.78 S 1268.83 E 5961409.50 N 563358.24 E 2.923 7131.78 9078.78 90.430 174.180 3664.60 3755.10 7176.65 S 1273.86 E 5961364.67 N 563363.64 E 2.769 7176.65 .~ 9127.33 91.110 173.080 3663.95 3754.45 7224.90 S 1279.25 E 5961316.47 N 563369.42 E 2.663 7224.90 9173.78 91 .350 174.230 3662.95 3753.45 7271.05 S 1284.38 E 5961270.36 N 563374.94 E 2.529 7271.05 9223.04 91.230 172.980 3661.84 3752.34 7319.99 S 1289.86 E 5961221.47 N 563380.83 E 2.549 7319.99 9268.38 91.600 172.490 3660.72 3751.22 7364.95 S 1295.60 E 5961176.56 N 563386.93 E 1.354 7364.95 9315.90 90.920 172.000 3659.68 3750.18 7412.03 S 1302.01 E 5961129.54 N 563393.73 E 1.764 7412.03 9363.85 91.170 173.830 3658.80 3749.30 7459.60 S 1307.92 E 5961082.01 N 563400.04 E 3.851 7459.60 9411.97 90.610 174.600 3658.05 3748.55 7507.47 S 1312.77 E 5961034.19 N 563405.28 E 1.978 7507.47 9458.39 90.120 175.480 3657.76 3748.26 7553.71 S 1316.78 E 5960987.98 N 563409.68 E 2.170 7553.71 9505.50 90.860 179.640 3657.35 3747.85 7600.77 S 1318.79 E 5960940.94 N 563412.07 E 8.969 7600.77 9552.33 90.000 181.470 3657.00 3747.50 7647.59 S 1318.33 E 5960894.12 N 563412.01 E 4.318 7647.59 9602.96 89.390 183.760 3657.27 3747.77 7698.17 S 1316.02 E 5960843.52 N 563410.11 E 4.681 7698.17 9647.79 87.540 183.140 3658.47 3748.97 7742.90 S 1313.33 E 5960798.77 N 563407.79 E 4.352 7742.90 9697.93 86.860 184.460 3660.92 3751.42 7792.87 S 1310.01 E 5960748.78 N 563404.88 E 2.959 7792.87 9743.04 87.110 183.390 3663.30 3753.80 7837.81 S 1306.93 E 5960703.81 N 563402.17 E 2.433 7837.81 9791.57 87.170 179.750 3665.72 3756.22 7886.25 S 1305.60 E 5960655.36 N 563401.24 E 7.492 7886.25 9837.20 87.290 177.740 3667.92 3758.42 7931.81 S 1306.60 E 5960609.81 N 563402.62 E 4.408 7931.81 9887.52 87.360 173.140 3670.27 3760.77 7981.91 S 1310.59 E 5960559.75 N 563407.03 E 9.133 7981.91 9932.68 86.790 168.310 3672.58 3763.08 8026.40 S 1317.86 E 5960515.31 N 563414.66 E 10.756 8026.40 .- 9983.26 89.510 162.950 3674.21 3764.71 8075.35 S 1330.40 E 5960466.47 N 563427.61 E 11.878 8075.35 10027.58 89.260 161.680 3674.69 3765.19 8117.58 S 1343.86 E 5960424.36 N 563441.42 E 2.920 8117.58 10078.17 89.140 156.580 3675.39 3765.89 8164.83 S 1361.88 E 5960377.26 N 563459.82 E 10.083 8164.83 10123.00 91.720 154.760 3675.06 3765.56 8205.67 S 1380.34 E 5960336.57 N 563478.63 E 7.043 8205.67 10174.06 88.950 151.950 3674.76 3765.26 8251.30 S 1403.24 E 5960291.14 N 563501.90 E 7.727 8251.30 10215.33 90.120 149.840 3675.09 3765.59 8287.35 S 1423.31 E 5960255.25 N 563522.27 E 5.846 8287.35 10264.21 93.200 146.230 3673.68 3764.18 8328.79 S 1449.17 E 5960214.02 N 563548.47 E 9.705 8328.79 10350.00 93.200 146.230 3668.89 3759.39 8399.99 S 1496.78 E 5960143.21 N 563596.67 E 0.000 8399.99 Projected Survey u --_u- -.---. .-..--.. 27 December, 2001 - 11:26 Page 6 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1C-135PB1 MWD Your Ref: API 500292305370 Job No. AKMM11196, Surveyed: ~O December, 2001 . Kuparuk River Unit North Slope, Alaska Kuparuk 1 C All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 90.5' (MSL). Northings and Eastings are relative to 1706'FNL, 1022'FWL. Magnetic Declination at Surface is 26.035° (27 -Dec-01) .~-.-' The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1706'FNL, 1022'FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10350.00ft., The Bottom Hole Displacement is 8532.31ft., in the Direction of 169.897° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10350.00 3759.39 8399.99 S 1496.78 E Projected Survey Survey tool program for 1C-135PB1 MWD '- From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 10350.00 3759.39 MWD Magnetic .-.-..--- .- .-_. ..---- 27 December, 2001- 11:26 Page 7 of 7 DrillQuest 2.00.08.005 ( ( ?,."i.~\,-.~~<i;::~t;'..:. ~?(: .~.~,." ,<.?:.:~ U 27 -Oec-O 1 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1 C-135 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: ' 9,127.33'MO Window / Kickoff Survey 9,155.00' MD Projected Survey: 11 ,700.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED DEe 2 8 2001 Älaska 0;1 & Ga ," . , S vons. l.OmmìssfOr Ancr~rage '.. ',- DEFINITIVE "- Kuparuk River Unit North Slope, Alaska Kuparuk 1 C, Slot 1 C-135 1C-135 Job No. AKZZ11196, Surveyed: 14 December, 2001 --~ SUR V E Y R E P 0 R T 27 December, 2001 Your Ref: API 500292305300 Surface Coordinates: 5968530.55 H, 562030.50 E (70019' 28.3928" N, 149029'49.2612" W) Surface Coordinates relative to Project H Reference: 968530.55 N, 62030.50 E (Grid) Surface Coordinates relative to Stucture Referance: 10.91 H, 341.47 W (True) Kelly Bushing: 90.5Oft above Mean Sea Level -.." spa"""Y-5UI1 A Halliburton Company Survey Ref: svy9737 . Sperry-Sun Drilling Services . . Survey Report for 1C-135 Your Ref: API 500292305300 Job No. AKZZ11196, Surveyed: 14 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9127.33 91.110 172.020 3665.46 3755.96 7211.55 S 1353.71 E 5961330.44 N 563443.77 E 7211.55 Tie On Point 9155.00 91.250 172.720 3664.89 3755.39 7238.97 S 1357.38 E 5961303.05 N 563447.67 E 2.579 7238.97 Window Point 9173.28 88.960 171.440 3664.86 3755.36 7257.07 S 1359.90 E 5961284.97 N 563450.34 E 14.351 7257.07 -- 9222.68 86.920 170.080 3666.63 3757.13 7305.80 S 1367.82 E 5961236.31 N 563458.67 E 4.962 7305.80 ; 9267.87 89.510 170.490 3668.04 3758.54 7350.31 S 1375.45 E 5961191.86 N 563466.66 E 5.803 7350.31 -- 9317.04 92.090 171.950 3667.35 3757.85 7398.90 S 1382.95 E 5961143.34 N 563474.56 E 6.029 7398.90 9362.51 92.640 172.770 3665.48 3755.98 7443.92 S 1388.99 E 5961098.36 N 563480.97 E 2.170 7443.92 9411.59 90.000 173.840 3664.35 3754.85 7492.65 S 1394.71 E 5961049.68 N 563487.10 E 5.804 7492.65 9457.26 90.370 173.170 3664.20 3754.70 7538.03 S 1399.87 E 5961004.35 N 563492.64 E 1.676 7538.03 9507.61 88.520 171.990 3664.69 3755.19 7587.95 S 1406.38 E 5960954.48 N 563499.55 E 4.358 7587.95 9544.32 90.180 172.440 3665.10 3755.60 7624.32 S 1411.35 E 5960918.16 N 563504.82 E 4.685 7624.32 9602.34 89.940 172.670 3665.04 3755.54 7681.85 S 1418.87 E 5960860.69 N 563512.82 E 0.573 7681.85 9647.38 89.880 173.510 3665.11 3755.61 7726.56 S 1424.29 E 5960816.03 N 563518.60 E 1.870 7726.56 9703.62 91.170 173.160 3664.60 3755.10 7782.42 S 1430.81 E 5960760.23 N 563525.59 E 2.377 7782.42 9742.63 90.800 173.070 3663.93 3754.43 7821.14 S 1435.49 E 5960721.54 N 563530.59 E 0.976 7821.14 9793.70 90.430 174.630 3663.38 3753.88 7871.91 S 1440.96 E 5960670.82 N 563536.48 E 3.139 7871.91 9833.97 89.880 175.300 3663.27 3753.77 7912.03 S 1444.49 E 5960630.73 N 563540.34 E 2.153 7912.03 9886.04 89.690 177.460 3663.47 3753.97 7963.99 S 1447.78 E 5960578.80 N 563544.06 E 4.164 7963.99 9932.45 88.520 178.570 3664.19 3754.69 8010.36 S 1449.39 E 5960532.44 N 563546.05 E 3.475 8010.36 9951.57 88.650 177.940 3664.66 3755.16 8029.47 S 1449.97 E 5960513.34 N 563546.79 E 3.363 8029.47 ~> 9997.71 88.460 175.050 3665.83 3756.33 8075.50 S 1452.79 E 5960467.33 N 563549.99 E 6.275 8075.50 ~-_. 10047.25 90.370 172.900 3666.33 3756.83 8124.76 S 1457.99 E 5960418.12 N 563555.60 E 5.805 8124.76 10091.45 90.490 172.360 3666.00 3756.50 8168.60 S 1463.66 E 5960374.33 N 563561.63 E 1.251 8168.60 10141.37 90.550 171.610 3665.55 3756.05 8218.03 S 1470.62 E 5960324.96 N 563569.00 E 1.507 8218.03 10186.48 90.310 171.480 3665.21 3755.71 8262.64 S 1477.25 E 5960280.40 N 563576.00 E 0.605 8262.64 10235.72 90.860 168.060 3664.71 3755.21 8311.09 S 1485.99 E 5960232.03 N 563585.14 E 7.034 8311.09 10280.46 90.370 166.720 3664.23 3754.73 8354.75 S 1495.76 E 5960188.45 N 563595.27 E 3.189 8354.75 10328.33 90.620 164.010 3663.81 3754.31 8401.06 S 1507.85 E 5960142.24 N 563607.75 E 5.685 8401.06 10374.04 90.060 162.680 3663.54 3754.04 8444.85 S 1520.95 E 5960098.56 N 563621.21 E 3.157 8444.85 10425.81 89.820 159.690 3663.60 3754.10 8493.85 S 1537.65 E 5960049.70 N 563638.31 E 5.794 8493.85 _n_____- ---- ---------- 27 December, 2001 - 12:25 Page 2 of 4 DrlllOuest 2.00.09.003 4. ; Sperry-Sun Drilling Services . Survey Report for 1C-135 Your Ref: API 500292305300 - Jo~ No. AKZZ11196, Surveyed: 14 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10467.46 89.320 159.160 3663.91 3754.41 8532.84 S 1552.29 E 5960010.83 N 563653.27 E 1.749 8532.84 10521.90 89.260 156.980 3664.58 3755.08 8583.33 S 1572.61 E 5959960.51 N 563674.01 E 4.006 8583.33 10562.20 89.380 154.930 3665.06 3755.56 8620.13 S 1589.03 E 5959923.85 N 563690.73 E 5.095 8620.13 -" 10615.29 89.200 152.620 3665.72 3756.22 8667.75 S 1612.49 E 5959876.43 N 563714.58 E 4.364 8667.75 ~--- 10660.24 89.450 149.450 3666.25 3756.75 8707.07 S 1634.25 E 5959837.29 N 563736.67 E 7.074 8707.07 10709.80 90.490 147.610 3666.27 3756.77 8749.34 S 1660.12 E 5959795.23 N 563762.89 E 4.265 8749.34 10754.97 91.230 146.730 3665.60 3756.10 8787.29 S 1684.61 E 5959757.49 N 563787.69 E 2.545 8787.29 10810.51 91.290 146.170 3664.38 3754.88 8833.56 S 1715.30 E 5959711.47 N 563818.76 E 1.014 8833.56 10848.78 91.910 146.460 3663.31 3753.81 8865.40 S 1736.51 E 5959679.81 N 563840.24 E 1.788 8865.40 10897.28 90.060 145.960 3662.47 3752.97 8905.70 S 1763.48 E 5959639.74 N 563867.54 E 3.951 8905.70 10943.72 89.200 145.810 3662.77 3753.27 8944.14 S 1789.53 E 5959601.51 N 563893.90 E 1.880 8944.14 1 0997.34 89.940 147.010 3663.1 8 3753.68 8988.81 S 1819.19 E 5959557.09 N 563923.93 E 2.629 8988.81 11038.44 89.080 147.340 3663.53 3754.03 9023.34 S 1841.47 E 5959522.74 N 563946.50 E 2.241 9023.34 11089.21 89.880 148.270 3663.99 3754.49 9066.30 S 1868.52 E 5959480.00 N 563973.90 E 2.416 9066.30 11133.33 89.690 148.270 3664.15 3754.65 9103.83 S 1891.72 E 5959442.67 N 563997.41 E 0.431 9103.83 11181.48 90.490 149.880 3664.08 3754.58 9145.13 S 1916.47 E 5959401.57 N 564022.50 E 3.734 9145.13 11228.30 90.680 149.700 3663.60 3754.10 9185.59 S 1940.02 E 5959361.31 N 564046.39 E 0.559 9185.59 11276.89 89.690 148.470 3663.44 3753.94 9227.28 S 1964.99 E '5959319.83 N 564071.69 E 3.249 9227.28 11323.70 89.450 147.900 3663.79 3754.29 9267.05 S 1989.66 E 5959280.26 N 564096.70 E 1.321 9267.05 11370.46 90.490 149.710 3663.82 3754.32 9307.05 S 2013.88 E 5959240.47 N 564121.24 E 4.464 9307.05 -.,. 11418.26 90.370 149.530 3663.46 3753.96 9348.28 S 2038.05 E 5959199.43 N 564145.76 E 0.453 9348.28 11465.57 89.020 148.480 3663.71 3754.21 9388.84 S 2062.42 E 5959159.08 N 564170.45 E 3.615 9388.84 11510.91 88.400 148.080 3664.73 3755.23 9427.39 S 2086.25 E 5959120.72 N 564194.60 E 1.627 9427.39 11556.73 91.420 149.500 3664.80 3755.30 9466.58 S 2109.99 E 5959081.74 N 564218.67 E 7.283 9466.58 11601.94 91.350 148.530 3663.71 3754.21 9505.32 S 2133.25 E 5959043,18 N 564242.25 E 2.150 9505.32 11622.17 90.860 148.410 3663.32 3753.82 9522.56 S 2143.83 E 5959026.03 N 564252.97 E 2.494 9522.56 11700.00 90.860 148.410 3662.15 3752.65 9588.85 S 2184.60 E 5958960.08 N 564294.29 E 0.000 9588.85 Projected Survey -----'--.--- u_-- -- ---,---.. -_u_--- .------- 27 December, 2001- 12:25 Page 3 of 4 Dr/llOllest 2.00.09.003 -, .. Sperry-Sun Drilling Services Survey Report for 1 C-135 Your Ref: AP/500292305300 Job No. AKZZ11196, Surveyed: 14 December, 2001 . Kuparuk River Unit North Slope, Alaska Kuparuk 1 C All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to AKB = 90.5' (MSL). Northings and Eastings are relative to 1706' FNL, 1022' FWL. Magnetic Declination at Surface is 26.038° (24-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1706' FNL, 1022' FWL and calculated along an Azimuth of 180.000° (True). --. Based upon Minimum Curvature type calculations, at a Measured Depth of 11700.000., The Bottom Hole Displacement is 9834.56ft., in the Direction of 167.166° (True). ~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 9127.33 9155.00 11700.00 3755.96 3755.39 3752.65 7211.55S 7238.97 S 9588.85 S 1353.71 E 1357.38 E 2184.60 E Tie On Point Window Point - Projected Survey Survey tool program for 1C-135 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) -~ ~, --,- Survey Tool Description 0.00 0.00 11700.00 3752.65 AK-6 BP _IFA-AK (1C-135 PB1) ---~----- 27 December, 2001 - 12:25 Page 4 of 4 DrlllQuest 2.00.09.003 ,¡1 , ( .,"y¡";¡'ni::'.":Y'T:J.~:'I'""",, ~¡!::~"~'J' "'J"':ð""'"::1¡¡r'~:'r1~ D') U - . '0,6 27 -Dec-O 1 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1C-135PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: ' MD Window / Kickoff Survey , MD Projected Survey: 10,350.00' MD (if applicable) Please call me at 273-3545 if you have any questions o~ concerns. Regards, William T. Allen Survey Manager RECEI\/ED OFt' ') --v t:. 8 2001 ,i\lasJt" . . "a I,."I / 1~ (.;¡óh. ~n""".\::~,.:r~;:., "'\';¡~':":'J';"¡,~)¡.' , ':~H1;;: A ttachment( s) - .. .-1 D EFI N ITIVE ,,-. Kuparuk River Unit North Slope, Alaska Kuparuk 1C, Slot 1C-135 1C-135 PB1 Job No. AKZZ11196,. Surveyed: 10 December, 2001 -.. SURVEY REPORT 27 December, 2001 Your Ref: API 500292305370 Surface Coordinates: 5968530.55 N, 562030.50 E (70019' 28.3928" N, 149029' 49.2612" W) Kelly Bushing: 90.50ft above Mean Sea Level .--", i '--- SPE!r'r'Y-SUI'1 DRILLING SERVices A Halliburton Company Survey Ref: svy9736 . . J Kuparuk River Unit Measured Depth (ft) '- 0.00 175.77 234.69 286.40 328.02 378.57 421.02 467.34 511.83 607.68 701.10 796.94 890.52 984.64 1080.14 1174.13 1268.12 1363.20 1458.37 1551.81 1646.70 1741.40 1836.26 1930.05 2025.27 2119.88 2214.43 2309.54 2402.09 2496.69 -- --~~ .~ --- _n-- Incl. 0.000 1.060 1.740 2.680 3.860 5.900 7.560 8.230 8.150 9.670 13.330 15.620 15.570 18.440 23.070 25.780 26.650 29.030 32.000 33.040 36.980 39.940 44.060 48.880 52.700 56.110 61.640 65.430 65.420 66.720 Azim. 0.000 244.070 245.100 247.140 234.790 232.870 234.260 234.430 234.900 222.760 210.270 205.730 204.220 201.280 196.150 191.870 191.060 189.340 186.680 183.440 179.160 174.830 171.200 168.620 168.140 169.520 169.190 165.940 164.010 163.800 27 December, 2001 - 11:38 Sub-Sea Depth (ft) -90.50 85.26 144.16 195.83 237.39 287.75 329.91 375.79 419.82 514.52 Sperry-Sun Drilling Services Survey Report for 1C-135 PS1 Your Ref: API 500292305370 Job No. AKZZ11196, Surveyed: 1.0 December, 2001 Vertical Depth (ft) 0.00 175.76 234.66 286.33 327.89 378.25 420.41 466.29 510.32 605.02 606.06 696.56 698.86 789.36 788.99 . 879.49 878.99 969.49 968.28 1058.78 1053.85 1138.18 1222.25 1304.23 1383.02 1460.74 1534.90 1605.39 1669.97 1730.16 1785.22 1834.07 1876.46 1914.95 1953.32 1144.35 1228.68 1312.75 1394.73 1473.52 1551.24 1625.40 1695.89 1760.47 1820.66 1875.72 1924.57 1966.96 2005.45 2043.82 Local Coordinates Northlngs Eastlngs (ft) (ft) O.OON 0.718 1.338 2.138 3.318 5.868 8.818 12.528 16.188 26.00 8 41.075 62.24 8 85.04 8 110.448 142.51 8 180.21 8 220.90 8 264.60 8 312.448 362.46 8 416.858 475.638 538.58 5 605.49 8 677.745 753.21 5 832.72 5 915.838 997.11 8 1080.19 S O.DOE 1.46 W 2.76W 4.59W 6.63W 10.09 W 14.10 W 19.27 W 24.44 W 35.47 W 46.23 W 57.40 W 68.02 W 78.61 W 89.30 W 98.63 W 106.88 W 114.71 W 121.40 W 125.80 W 126.94 W 123.78 W 115.99 W 104.02 W 89.15 W 74.27 W 59.32 W 40.95 W 19.13 W 4.84E Global Coordinates Northlngs Eastlngs (ft) (ft) 5968530.55 N 5968529.83 N 5968529.20 N 5968528.39 N 5968527.18 N 5968524.61 N 5968521.62 N 5968517.87 N 5968514.16 N 5968504.26 N 5968489.10 N 5968467.84 N 5968444.95 N 5968419.46 N 5968387.31 N 5968349.53 N 5968308.78 N 5968265.02 N 5968217.12 N 5968167.06 N 5968112.67 N 5968053.92 N 5967991.03 N 5967924.22 N 5967852.09 N 5967776.76 N 5967697.37 N 5967614.42 N 5967533.32 N 5967450.44 N 562030.50 E 562029.04 E 562027.75 E 562025.93 E 562023.90 E 562020.46 E 562016.47 E 562011.33 E 562006.20 E 561995.25 E 561984.62 E 561973.62 E 561963.19 E 561952.81 E 561942.38 E 561933.36 E 561925.45 E 561917.98 E 561911.69 E 561907.70 E 561907.01 E 561910.66 E 561918.97 E 561931.49 E 561946.95 E 561962.46 E 561978.07 E 561997.12 E 562019.61 E 562044.27 E --_...._._----~----~ Page 2 of 7 Dogleg Rate (0/100ft) 0.603 1.155 1.824 3.286 4.048 3.929 1.447 0.234 2.514 4.717 2.665 0.437 3.182 5.204 3.442 1.001 2.642 3.428 2.171 4.890 4.224 5.040 5.512 4.031 3.794 5.856 5.023 1.896 1.389 Vertical Section 0.00 0.71 1.33 2.13 3.31 5.86 8.81 12.52 16.18 26.00 41.07 62.24 85.04 110.44 142.51 180.21 220.90 264.60 312.44 362.46 416.85 475.63 538.58 605.49 677.74 753.21 832.72 915.83 997.11 1080.19 . North Slope, Alaska Kuparuk 1 C Comment AK-6 BP IFR-AK --c ~ ~ DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1C-135 PS1 Your Ref: API 500292305370 Job No. AKZZ11196, Surveyed: 10 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2592.72 66.440 163.390 1991.49 2081.99 1164.72 S 29.72 E 5967366.12 N 562069.85 E 0.488 1164.72 -, 2687.11 69.360 165.130 2027.00 2117.50 1248.88 S 53.43 E 5967282.15 N 562094.25 E 3.534 1248.88 ,--. 2780.86 69.960 164.590 2059.59 2150.09 1333.74 S 76.39 E 5967197.49 N 562117.91 E 0.837 1333.74 2878.24 69.890 165.230 2093.02 2183.52 1422.05 S 100.20 E 5967109.38 N 562142.45 E 0.621 1422.05 2972.06 69.350 165.290 2125.69 2216.19 1507.10 S 122.58 E 5967024.52 N 562165.53 E 0.579 1507.10 3067.24 68.960 165.200 2159.56 2250.06 1593.12 S 145.23 E 5966938.69 N 562188.90 E 0.419 1593.12 3161.57 68.630 165.950 2193.68 2284.18 1678.29 S 167.14E 5966853.70 N 562211.51 E 0.820 1678.29 3256.18 68.760 166.110 2228.05 2318.55 1763.82 S 188.42 E 5966768.35 N 562233.49 E 0.209 1763.82 3351.07 70.470 165.140 2261.10 2351.60 1849.98 S 210.51 E 5966682.37 N 562256.29 E 2.041 1849.98 3445.96 69.870 165.060 2293.29 2383.79 1936.24 S 233.46 E 5966596.31 N 562279.95 E 0.637 1936.24 3540.47 70.070 163.990 2325.66 2416.16 2021.81 S 257.15 E 5966510.93 N 562304.35 E 1.085 2021.81 3635.30 68.240 164.030 2359.41 2449.91 2107.00 S 281.56 E 5966425.95 N 562329.47 E 1.930 2107.00 3729.67 68.110 164.580 2394.49 2484.99 2191.34 S 305.26 E 5966341.81 N 562353.86 E 0.558 2191.34 3824.24 70.150 163.890 2428.18 2518.68 2276.38 S 329.27 E 5966256.97 N 562378.58 E 2.262 2276.38 3918.98 70.540 163.770 2460.05 2550.55 2362.07 S 354.12 E 5966171.49 N 562404.13 E 0.429 2362.07 4014.08 70.350 163.810 2491.88 2582.38 2448.12 S 379.13 E 5966085.65 N 562429.86 E 0.204 2448.12 4108.35 70.070 163.400 2523.80 2614.30 2533.22 S 404.17 E 5966000.76 N 562455.60 E 0.506 2533.22 4203.45 70.420 163.080 2555.94 2646.44 2618.92 S 429.98 E 5965915.28 N 562482.11 E 0.486 2618.92 ~ 4298.02 69.940 162.670 2588.01 2678.51 2703.94 S 456.18 E 5965830.47 N 562509.01 E 0.651 2703.94 4392.90 68.640 162.420 2621.56 2712.06 2788.60 S 482.80 E 5965746.04 N 562536.33 E 1.392 2788.60 4483.63 68.840 162.030 2654.46 2744.96 2869.12 S 508.61 E 5965665.73 N 562562.81 E 0.457 2869.12 4582.70 68.850 162.090 2690.21 2780.71 2957.02 S 537.07 E 5965578.07 N 562591.99 E 0.057 2957.02 4677.22 69.090 162.240 2724.13 2814.63 3041.00 S 564.09 E 5965494.31 N 562619.71 E 0.294 3041.00 4769.19 66.310 161.610 2759.02 2849.52 3121.89 S 590.48 E 5965413.65 N 562646.77 E 3.088 3121.89 4865.90 66.240 161.140 2797.94 2888.44 3205.79 S 618.76 E 5965329.98 N 562675.74 E 0.451 3205.79 4960.39 66.030 163.510 2836.17 2926.67 3288.11 S 644.99 E 5965247.88 N 562702.65 E 2.304 3288.11 5055.86 66.630 164.070 2874.50 2965.00 0 3372.08 S 669.40 E 5965164.12 N 562727.75 E 0.827 3372.08 5150.57 66.770 163.780 2911.96 3002.46 3455.66 S 693.49 E 5965080.74 N 562752.53 E 0.318 3455.66 5245.06 67.230 164.150 2948.88 3039.38 3539.25 S 717.51 E 5964997.35 N 562777.24 E 0.606 3539.25 5340.11 65.290 165.030 2987.14 3077.64 3623.13 S 740.64 E 5964913.67 N 562801.06 E 2.210 3623.13 -__-0- ---'--____--On_--__-- - --_u_--------- ----- 27 December, 2001- 11:38 Page 3 of 7 DrillQucst 2.00.08.005 . . Sperry-Sun Drilling Services Survey Report for 1C-135 PS1 Your Ref: API 500292305370 Job No. AKZZ11196, Surveyed: 10 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) , (ft) (ft) (ft) (°/1 OOft) 5435.23 65.100 165.190 3027.05 3117.55 3706.57 5 762.82 E 5964830.41 N 562823.94 E 0.251 3706.57 ---.. 5529.84 65.520 164.730 3066.57 3157.07 3789.59 S 785.13 E 5964747.58 N 562846.93 E 0.626 3789.59 '- 5625.08 65.910 165.110 3105.74 3196.24 3873.41 5 807.72 E 5964663.95 N 562870.21 E 0.548 3873.41 5718.77 66.240 165.050 3143.74 3234.24 3956.165 829.77 E 5964581.38 N 562892.94 E 0.357 3956.16 5814.50 66.490 164.920 3182.11 3272.61 4040.87 5 852.49 E 5964496.87 N 562916.36 E 0.289 4040.87 5908.60 66.040 166.260 3219.99 3310.49 4124.305 873.92 E 5964413.62 N 562938.49 E 1.389 4124.30 6003.65 67.240 166.530 3257.68 3348.18 4209.105 894.45 E 5964328.98 N 562959.71 E 1.289 4209.10 6098.40 68.170 167.120 3293.62 3384.12 4294.46 S 914.43 E 5964243.79 N 562980.39 E 1.138 4294.46 6193.54 68.320 167.010 3328.89 3419.39 4380.58 5 934.21 E 5964157.84 N 563000.89 E 0.191 4380.58 6288.62 67.490 166.720 3364.65 3455.15 4466.38 5 954.23 E 5964072.21 N 563021.61 E 0.918 4466.38 6382.97 67.850 166.360 3400.50 3491.00 4551.25 S 974.54 E 5963987.51 N 563042.63 E 0.520 4551.25 6473.54 67.570 164.740 3434.85 3525.35 4632.40 S 995.45 E 5963906.54 N 563064.21 E 1.684 4632.40 6572.15 67.900 164.390 3472.22 3562.72 4720.375 1019.74 E 5963818.77 N 563089.22 E 0.469 4720.37 6666.55 67.450 163.700 3508.07 3598.57 4804.33 S 1043.74 E 5963735.01 N 563113.92 E 0.827 4804.33 6761.38 67.370 163.960 3544.50 3635.00 4888.42 5 1068.12 E 5963651.13 N 563139.00 E 0.267 4888.42 6856.21 67.050 163.470 3581.23 3671.73 4972.34 5 1092.64 E 5963567.42 N 563164.20 E 0.584 4972.34 6904.49 66.840 162.770 3600.14 3690.64 5014.85 5 1105.54 E 5963525.01 N 563177.45 E 1.403 5014.85 6949.93 69.760 164.910 3616.94 3707.44 5055.39 5 1117.28 E 5963484.57 N 563189.53 E 7.774 5055.39 ---.... 6999.47 73.390 166.710 3632.60 3723.10 5100.95 S 1128.79 E 5963439.10 N 563201.42 E 8.097 5100.95 7045.79 77.200 168.730 3644.36 3734.86 5144.72 S 1138.31 E 5963395.42 N 563211.30 E 9.243 5144.72 7094.00 79.530 170.600 3654.08 3744.58 5191.17 S 1146.78 E 5963349.04 N 563220.15 E 6.147 5191.17 7140.81 81.400 171.650 3661.83 3752.33 5236.785 1153.90 E 5963303.49 N 563227.65 E 4.566 5236.78 7188.51 84.010 172.830 3667.89 3758.39 5283.65 S 1160.29 E 5963256.67 N 563234.42 E 5.997 5283.65 7236.55 85.690 174.990 3672.20 3762.70 5331.225 1165.36 E 5963209.14 N 563239.89 E 5.682 5331.22 7326.08 86.980 176.320 3677.93 3768.43 5420.31 S 1172.13 E 5963120.11 N 563247.39 E 2.067 5420.31 7373.44 90.980 178.450 3678.77 3769.27 5467.60 S 1174.29 E 5963072.84 N 563249.94 E 9.568 5467.60 7421.67 90.990 177.160 3677.94 3768.44 5515.795 1176.13 E 5963024.67 N 563252.19 E 2.674 5515.79 7468.14 90.430 176.820 3677.36 3767.86 5562.195 1178.57 E 5962978.29 N 563255.01 E 1.410 5562.19 7516.75 89.690 176.760 3677.31 3767.81 5610.72 S 1181.30 E 5962929.78 N 563258.13 E 1.527 5610.72 7563.71 90.310 175.850 3677.31 3767.81 5657.58 S 1184.32 E 5962882.95 N 563261.55 E 2.345 5657.58 "-" "~ - . - . --" ----_.- .__on- 27 December. 2001- 11:38 Page 4 of 7 Drí/lQuest 2.00.08.005 ." Kuparuk River Unit Measured Depth (ft) '- 7612.76 7658.26 7707.49 7752.96 7802.08 7847.75 7896.82 7942.58 7991.21 8037.59 8088.09 8132.23 8181.49 8226.75 8275.99 8321.95 8370.60 8416.29 8457.80 8511.95 8556.40 8605.40 8647.82 8700.04 8742.14 Incl. 91.850 91.850 89.940 91.110 91.170 90.860 90.310 89.940 91.480 93.630 91.230 90.060 88.280 88.150 88.460 89.940 89.880 90.680 90.800 89.690 89.510 89.080 90.120 91.040 91.600 8794.47 - 90.740 8847.86 91.170 8889.75 90.800 8938.98 89.880 8984.32 89.880 Azim. 175.710 175.390 174.450 174.230 173.510 173.310 172.870 173.160 173.380 172.800 173.550 174.860 174.590 174.760 174.280 173.720 174.340 173.340 173.430 172.700 173.450 173.690 171.990 174.700 174.310 173.510 174.110 174.600 173.330 173.530 27 December, 2001- 11:38 Sub-Sea Depth (ft) 3676.39 3674.92 3674.15 3673.73 3672.76 3671.95 3671.45 3671.35 3670.74 3668.68 3666.54 3666.04 3666.75 3668.16 3669.62 3670.26 3670.34 3670.11 3669.58 3669.35 3669.66 3670.26 3670.56 3670.03 3669.06 3667.99 3667.10 3666.38 3666.09 3666.18 :",~c " Sperry-Sun Drilling Services Survey Report for 1C-135 PS1 Your Ref: API 500292305370 Job No. AKZZ11196. Surveyed: 10 December. 2001 Vertical Depth (ft) 3766.89 3765.42 3764.65 3764.23 3763.26 3762.45 3761.95 3761.85 3761.24 3759.18 3757.04 3756.54 3757.25 3758.66 3760.12 3760.76 3760.84 3760.61 3760.08 3759.85 3760.16 3760.76 3761.06 3760.53 3759.56 3758.49 3757.60 3756.88 3756.59 3756.68 Local Coordinates Northlngs Eastlngs (ft) (ft) 5706.49 S 5751.83 S 5800.86 S 5846.10 S 5894.93 S 5940.29 S 5989.00 S 6034.42 S 6082.71 S 6128.71 5 6178.80 S 6222.71 S 6271.76 S 6316.80 S 6365.79 S 6411.49 S 6459.88 S 6505.30 S 6546.54 S 6600.29 S 6644.41 S 6693.10 S 6735.19 S 6787.05 S 6828.94 S 6880.96 S 6934.03 S 6975.72 S 7024.67 S 7069.71 5 1187.93 E 1191.46 E 1195.82 E 1200.30 E 1205.55 E 1210.79 E 1216.69 E 1222.25 E 1227.95 E 1233.53 E 1239.52 E 1243.98 E 1248.51 E 1252.70 E 1257.41 E 1262.21 E 1267.27 E 1272.17 E 1276.95 E 1283.49 E 1288.85 E 1294.34 E 1299.62 E 1305.67 E 1309.71 E 1315.26 E 1321.01 E 1325.13 E 1330.31 E 1335.49 E Global Coordinates Northlngs Eastlngs (ft) (ft) 5962834.07 N 5962788.77 N 5962739.78 N 5962694.57 N 5962645.78 N 5962600.47 N 5962551.81 N 5962506.43 N 5962458.19 N 5962412.25 N 5962362.21 N 5962318.33 N 5962269.33 N 5962224.32 N 5962175.37 N 5962129.71 N 5962081.37 N 5962035.98 N 5961994.79 N 5961941.10 N 5961897.02 N 5961848.38 N 5961806.34 N 5961754.53 N 5961712.67 N 5961660.69 N 5961607.67 N 5961566.03 N 5961517.12 N 5961472.12 N 563265.56 E 563269.46 E 563274.23 E 563279.09 E 563284.73 E 563290.35 E 563296.65 E 563302.59 E 563308.69 E 563314.65 E 563321.05 E 563325.87 E 563330.81 E 563335.38 E 563340.48 E 563345.66 E 563351.12 E 563356.40 E 563361.52 E 563368.51 E 563374.23 E 563380.12 E 563385.75 E 563392.23 E 563396.61 E 563402.59 E 563408.78 E 563413.25 E 563418.83 E 563424.39 E Page 5 of 7 Dogleg Rate (o/100ft) 3.153 0.703 4.324 2.618 1.471 0.808 1.435 1.027 3.199 4.801 4.979 3.979 3.655 0.473 1.160 3.443 1.280 2.803 0.361 2.453 1.735 1.005 4.698 5.480 1.621 2.244 1.382 1.466 3.185 0.441 _Un-' --- Vertical Section 5706.49 5751.83 5800.86 5846.10 5894.93 5940.29 5989.00 6034.42 6082.71 6128.71 6178.80 6222.71 6271.76 6316.80 6365.79 6411.49 6459.88 6505.30 6546.54 6600.29 6644.41 6693.10 6735.19 6787.05 6828.94 6880.96 6934.03 6975.72 7024.67 7069.71 . North Slope, Alaska Kuparuk 1C Comment -~- ~ DrillQuest 2.00.08.005 '1 Sperry-Sun Drilling Services Survey Report for 1C-135 PB1 Your Ref: API 500292305370 Job No. AKZZ11196, Surveyed: 10 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9033.63 89.940 172.060 3666.26 3756.76 7118.63 S 1341.68 E 5961423.25 N 563430.98 E 2.984 7118.63 ~ 9078.78 90.430 173.210 3666.11 3756.61 7163.41 S 1347.47 E 5961378.53 N 563437.13 E 2.769 7163.41 _. 9127.33 91.110 172.020 3665.46 3755.96 7211.55 S 1353.71 E 5961330.44 N 563443.77 E 2.823 7211.55 9173.78 91.350 173.190 3664.46 3754.96 7257.60 S 1359.68 E 5961284.44 N 563450.13 E 2.571 7257.60 9223.04 91.230 171.910 3663.35 3753.85 7306.43 S 1366.07 E 5961235.66 N 563456.92 E 2.609 7306.43 9268.38 91.600 171.320 3662.23 3752.73 7351.27 S 1372.68 E 5961190.87 N 563463.90 E 1.536 7351.27 9315.90 90.920 171.090 3661.19 3751.69 7398.22 S 1379.94 E 5961143.99 N 563471.55 E 1.511 7398.22 9363.85 91.170 172.820 3660.31 3750.81 7445.69 S 1386.65 E 5961096.57 N 563478.65 E 3.645 7445.69 9411.97 90.610 173.560 3659.57 3750.07 7493.47 S 1392.36 E 5961048.85 N 563484.75 E 1.928 7493.47 9458.39 90.120 174.410 3659.27 3749.77 7539.63 S 1397.22 E 5961002.73 N 563490.00 E 2.114 7539.63 9505.50 90.860 178.910 3658.87 ' 3749.37 7586.64 S 1399.96 E 5960955.74 N 563493.13 E 9.680 7586.64 9552.33 90.000 180.600 3658.52 3749.02 7633.47 S 1400.17 E 5960908.91 N 563493.72 E 4.049 7633.47 9602.96 89.390 182.860 3658.79 3749.29 7684.07 S 1398.64 E 5960858.30 N 563492.61 E 4.623 7684.07 9647.79 87.540 182.440 3659.99 3750.49 7728.84 S 1396.56 E 5960813.52 N 563490.90 E 4.232 7728.84 9697.93 86.860 183.720 3662.44 3752.94 7778.84 S 1393.87 E 5960763.49 N 563488.63 E 2.888 7778.84 9743.04 87.110 182.760 3664.81 3755.31 7823.82 S 1391.33 E 5960718.50 N 563486.45 E 2.196 7823.82 9791.57 87.170 178.980 3667.23 3757.73 7872.27 S 1390.59 E 5960670.04 N 563486.12 E 7.780 7872.27 9837.20 87.290 177.110 3669.44 3759.94 7917.82 S 1392.15'E 5960624.51 N 563488.05 E 4.102 7917.82 --'-. 9887.52 87.360 172.380 3671.79 3762.29 7967.86 S 1396.75 E 5960574.51 N 563493.07 E 9.391 7967.86 9932.68 86.790 167.530 3674.09 3764.59 8012.26 S 1404.61 E 5960530.18 N 563501.30 E 10.800 8012.26 _. 9983.26 89.510 161.880 3675.73 3766.23 8061.00 S 1417.94 E 5960481.55 N 563515.03 E 12.391 8061.00 10027.58 89.260 160.760 3676.20 3766.70 8102.98 S 1432.14 E 5960439.69 N 563529.57 E 2.589 8102.98 10078.17 89.140 155.570 3676.91 3767.41 8149.92 S 1450.95 E 5960392.90 N 563548.76 E 10.261 8149.92 10123.00 91.720 153.640 3676.57 3767.07 8190.41 S 1470.17 E 5960352.57 N 563568.32 E 7.187 8190.41 10174.06 88.950 150.790 3676.27 3766.77 8235.57 S 1493.97 E 5960307.61 N 563592.49 E 7.783 8235,57 10215.33 90.120 148.410 3676.61 3767.11 8271.16 S 1514.85 E 5960272.19 N 563613.67 E 6.426 8271.16 10264.21 93.200 144.730 3675.19 3765.69 8311.93 S 1541.76 E 5960231.65 N 563640.91 E 9.814 8311.93 10350.00 93.200 144.730 3670.40 3760.90 8381.86 S 1591.22 E 5960162.13 N 563690.95 E 0.000 8381.86 Projected Survey --._. ...-- ---------------- 27 December, 2001 - 11:38 Page 6 of 7 DrfllQuest 2.00.08.005 . '.." Kuparuk River Unit Sperry-Sun Drilling Services Survey Report for 1C-135 PB1 Your Ref: API 500292305370 Job No. AKZZ11196, Surveyed: 1.0 December, 2001 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 90.5' (MSL). Northings and Eastings are relative to 170a'FNL, 1022'FWL. '-- Magnetic Declination at Surface is 26.050° (10-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1706'FNL, 1022'FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10350.00ft., The Bottom Hole Displacement is 8531.56ft., in the Direction of 169.251° (True). - Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10350.00 3760.90 8381.86 S 1591.22 E Projected Survey Survey tool program for 1C-135 PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 - --- 27 December, 2001- 11:38 To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 10350.00 3760.90 AK-6 BP _IFR-AK -- --~ ----------- Page 7 of 7 . North Slope, Alaska Kuparuk 1 C '-"-, ~, ".-.- --- DrillQuest 2.00.08.005 it ,Ii ~ " dOIF;<~D WELL LOG TRANSMITf AL To: State of Alaska March 13, 2002 Alaska Oil and Gas Conservation Co. Attn.: Lisa W eepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 RE: MWD Fonnation Evaluation Logs IC-I35 PBI, AK-MM-11196 1 LDWG fonnatted Disc with verification listing. API#: 50-029-23053-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. J\nchorage, Alaska 99518 Signe~ ~ Date: RECEIVED r;:!,~p I) 0 ':\OO? I, \. \ L '- - Alaska Oil & Gas Cons. Commission Anchorage II' ~, ( aO "'d~Õ WELL LOG TRANSMITf AL To: State of Alaska March 13, 2002 Alaska Oil and Gas Conservation Co. Attn.: Lisa W eepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 RE: MWD Formation Evaluation Logs 1 C-135, AK-MM-11196 1 LDWG formatted Disc with verification listing. API#: 50-029-23053-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: S peny- Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Sign~ ' (~r; l p.-, Date: RECEIVED r",! ~~ r) 'Î 0 ':'OO? .: ,t \ L L - Alaska Oil & Gas Cons. Commission Anchorage ~~ Sc___epgep NO. 1725 01 /15/02 Alaska Oil & Gas Cons Corom Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD Color Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Company: 2P-415A PRESSfTEMP STATION LOGS 12/24/01 1 1 2P-417 STATIC BOTTOM HOLE PRESS SURVEY 12/13/01 1 1 2P-420 PRESSfTEMP STATION LOGS 12/23/01 1 1 1C-135 22010 USIT 12/18/01 1 1 R-36 22009 USIT 12/27/01 1 2N-348 22011 SCMT 12/09/01 1 2P-420 22008 SCMT 12/22/01 1 . ~(;t:1 Vf-I ób 1- ddb ~O 1-0(0'1 ao'-'~~ aol-~ðO õ<OI.aa4 ¿;1, 0 ) - 1'--1 d -6 l) )-1 ~~ ~- Field: Well Job# Log Description Date BL Sepia SIGNE&- ~-(~~ DATE: .!AU 2.5 200L Alaska Oil & Gas Cons. Cornmi88ion Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Anchorage l~e: 1 C-135 - Change in Diverter / BOP Configuration . r ( ;1: ~ Subject: Re: 1 C-135 - Change in Diverter I BOP Configuration Date: Tue, 27 Nov 2001 09:21 :43 -0900 From: "Steve McKeever" <smckeev@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> ~Ð\-d-d-U Spud will be late tomorrow, or early Thursday. Also, I mentioned to you a couple of weeks ago this comic Roy D. Mercer. I put a few of his numbers on a CD for you. I'll drop it off over there later today or tomorrow Steve McKeever Drilling Engineer Phillips Alaska, Inc. 907.265.6826 office 907.265.1535 fax 907.275.0369 pager smckeev@ppco.com "It's a little-known scientific fact that if you drink a heavy beer while eating pizza, you'll explode." -Mike Doogan Tom Maunder <tom_maunder@admin.state.ak.us> 11/27/01 08:53 AM To: Steve McKeever/PPCO@Phillips cc: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Subject: Re: 1 C-135 - Change in Diverter / BOP Configuration Steve, Thanks for the information. What you have submitted with the email is sufficient. No sundry will be needed. Please be sure that your rig supervisor contacts the Slope Inspector in advance of . function/pressure testing so he may witness. When is spud planned? Tom Maunder Steve McKeever wrote: > Hello Tom 1of3 11/28/01 10:41 AM ~e: 1C-135 - Change in Diverter / BOP Configuration .... . ~~. ~ > > We are hoping, with the Commission's approval, to use diverter and BOP > equipment other than that which was permitted for upcoming well 1 C-135, > Permit # 201-220. > > As you may recall, our permit application specified that we would use the > combination diverter / BOP stack similar to what we have used with Nabors > 245 on recent West Sak production wells. But, due to the rig time that > would be required to assemble the 13-5/8" BOP stack, we would like to use > a more standard diverter system, and an 11'-5,000 psi standard BOP system. > Attached please find schematics of these systems, as well as a revised > General Procedure for the well. > > (See attached file: Diverter and BOP Info Gen /I Nordic 3.pdf) > > If these changes meet with the approval of the Commission, can you please > so indicate by return e-mail? Additionally, I'd appreciate it if you could > let me know if this change would necessitate the filing of a Sundry > Application/ > > Thanks > > Steve McKeever > > > > > > > > > "/t's a little-known scientific fact that if you drink a heavy beer while > eating pizza, you'll explode." > -Mike Doogan > > Drilling Engineer Phillips Alaska, Inc. , 907.265.6826 office 907.265.1535 fax 907.275.0369 pager smckeev@ppco.com ------------------------------------------------------------------------ Name: Diverter and BOP > Info Gen " Nordic 3.pdf > Diverter and BOP Info Gen /I Nordic 3.pdf Type: Acrobat ( application/pdt) > Encodmg:base64 (See attached file: tom_maunder.vcf) (, Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission ----- 2 of3 11/28/01 10:41 AM ( ~Vffi1VŒ (ID~ !A\~!A\~[(!A\ ( ALAS IiA 0 IL AND GAS COlWSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. "fTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. .PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit lC-135 Phillips Alaska, Inc. Permit No: 201-220 Sur Loc: 1706' FNL, 1022' FWL, Sec. 12, TIIN, RI0E, UM Btmhole Loc. 742' FNL, 2107' FEL, Sec. 24, TIIN, RI0E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been for this well bore. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit lC_must comply with the requirements and limitations of 20 MC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 MC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to wítness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. bs;nCerelY, 0uA~' ~ Cammy chsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 21st day of November, 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 C-135 location tops II'" 'I ,~ Subject: 1 C-135 location tops Date: Tue, 20 Nov 2001 10:44:31 -0900 From: 'Todd J Mushovicll <tmushov@ppco.com> To: tom_maunder@admin.state.ak.us, steve_davies@admin.state.ak.us CC: IISharon Allsup-Drakell <sallsup@ppco.com>, "Patricia A Godfreyll <pagodfr@ppco.com>, IISteve McKeever" <smckeev@ppco.com> Mr. Davies and Mr. Maunder, Here is the location information for the top of productive interval (West Sak 11011 Sand). 1899 FNL, 2141 FWL, See 13, T11N, R10E, UM Northings: 5,963,076.98 Eastings: 563,197.48 Measured depth, RKB 7361.7' Total Vertical Depth, RKB 3796.7' Total Vertical Depth, SS 3705.6' Sorry for the confusion. Todd J. Mushovic Drilling Engineer Phillips Alaska Inc. (907) 265-6974 - office (907) 240-5740 - cellular tmushov@ppco.com 1 of 1 11/20/01 12:35 PM PHILLI( 3 Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: anallar@ppco.com November 16, 2001 Commissioner Cammy Oechsli Taylor Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, lC-135 Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production well, a horizontal well in the West Sak "D" sand. This well will also be used for some short term injection testing. The well will be designated 1C-135. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of lC-135 is Wednesday, November 28, 2001. If you have any questions or require any further information, please contact Steve McKeever at 265- 6826. Sincerely, ~e Chuck Mallary GKA Drilling Engineering Supervise ORIGINAL RECE\VED NOV 1 6 2001 ,..0\\ & G8 ConI. eommi&ion And\OI898 ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL )M~ J1 \ \ ¡,;¡) '"' .ð\ I (~ 20 AAC 25.005 , ¡en 1 a. Type of work: Drill LtI Redrill U 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil ~ Re-entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone Gth) Multiple Zone 0 2. Name of Operator 5. Datum elevation (OF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB = 91.1 feet AMSL Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P.O. Box 100360 Anchorage, AK 99510-036( ADL 25649/25650 ALK 467/46~ 4. Location of well at surtace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1706' FNL, 1022' FWL, Section 12, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 13 8. Well number Number FN~~~' FWL, Section...~T11N, R10E, UM 1C~ ¡f..-/35' Jb #59-52-180 At total depth U41' ..i1:> 9. Approximate spud date Amount 742' FNL, 2107' FEL, Section 24, T11N, R1OE, UM November 28, 2001 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 2107' @ TD feet 1C-133, 33' @ 500' feet 2560 11695' MD 13766 'lVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300' MD Maximum hole angle 910 Maximum surface 1328 psig At total depth (TVD) 1746 psig 18. Casing program SettinQ Depth size Specifications Top Bottom Quantity of Cement Hole CasinQ WeiQht Grade Couplinq Lenqth MD TVD MD TVD (include staqe data) 24" 16" 62.5# API5L Weld 120' 30.3' 30.3' 147' 147' 282 sx AS 1 9.875" 7.625" 29.7# L-80 BTCM 7332' 30.3' 30.3' 7362' 3796' 650 sx AS Lite & 240 sx Class G 6.75" 4.5" 12.6# L-80 NSCT 4595' 7100' 3,765' 11695' 3766' slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface 0 RECEIVED NOV 1 6 2001 Pertoration depth: measured AI8a Oil & Gas Cons. CommIssion true vertical Anchorage 20. Attachments Filingfee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program -.0 Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21, ',he"'bY celliIT: Ih Cp"p;:he besl 01 my knowledge ~~~S?C~Sœ~MAJe~2~6~ Date /(, ð J ,leD J Signed u} """ "" Vi' V' Title: Drilling Engineering Supervisor C.R. Mallarv / ,..., hv.c::.tt:J¡I/t:J¡ . ~ /- ( Commission Use Onl\ Permit Number API number -- Approval date 1) lad 'n J See cover letter ;201- 7-2D 50- oW,'" 2- 3053- ð(~ for other requirements Conditions of approval Samples required 0 Yes ~ No Mud log required I 0 Yes EY No Hydrogen sulfide measures 0 Yes ~ No Directional survey required Æ( Yes 0 No Required working pressure for BOPE 0 2M; 0 3M; 0 5M; 0 10M;D ~ 7¡,SCC) fS\~(J.V' ~S\- Other: Original Signed By by order of , I ~~) I oj Approved by Commissioner the commission Date - - . I , / . ORIGINAL Form 10-401 Rev. 12/1/85. Submit in triplicate ( ~, APi.' 'tion for Permit to Drill, We1l1C-135 ~ Revision No.O Saved: 16-Nov-O1 Permit It - West Sak Well #1 C-135 Application for Permit to Drill Document MoximizE We-II VQlu~ Table of Contents 1. Well Name..... ......... ....................... .................... .................................................. ......2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Sum mary ................................................................................. ..................2 Requirements of 20 AAC 25.005(c)(2) """"""""""""""""""""""""""""".........................................2 Requirements of 20 AAC 25.050(b)........................................................................................................ 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c)(3) ................................................. ........................ .......................... 3 4. Dri II i ng Hazards Information ................................ ............................................. ...... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................4 6. Casing and Cementi ng Program .............................................................................4 Requirements of 20 AAC 25. 005( c)(6) ................................................................................................... 4 7. Diverter System Information.............. ................... ........................ .............. ............4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program................................. ...... ..... ........................................... ......5 Requirements of 20 AAC 25.005(c)(B) ...................................................................................................5 Surface Hole Mud Program .................................................................................................................... 5 Lateral Mud Program .............................................................................................................................. 5 Abnormally Pressured Formation Information ........................................................... 6 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................6 9. Seism ic Analysis.......................................... ...... ..................... ............. ............. .......6 Requirements of 20 AAC 25.005 (c)(10) ..............,.................................................................................6 10. Seabed Condition Analysis............... ................... ................... ........ ......... ..... ... .......6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................6 11. Evidence of Bond i ng................................ ............ .................... ......................... .... ....6 ORIGINAL 1C-135 PERMIT IT.doc Page 1 of 8 Printed: 16-Nov-O1 (' APt" "\tion for Permit to Drill, We1l1C-135 , Revision No.O Saved: 16-Nov-O1 Requirements of 20 AAC 25.005 (c)(12) ..........................................."...................................................6 12. Proposed Dri Iii ng Program... ...... ........ ....... ..... ................. .................... ................. ... 6 Requirements of 20 AAC 25.005 (c)(13) .................................................................,..............................6 13. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) """""""""""""""""""""""""""""""""""""""""'"...........7 14. Attachments............................................................................. .... ................. ........ ... 8 Attachment 1 Directional Plan (12 pages) .............................................................................................8 Attachment 2 13-5 Diverler / BOP System Schematic (1 page)............................................................ 8 Attachment 3 Diverler Spool Drawing (1 page) .....................................................................................8 Attachment 4 Drilling Hazards Summary (1 page) ................................................................................ 8 Attachment 5 Formation Integrity Test Procedure (1 page) .................................................................. 8 Attachment 6 Cement Loads and CemCADE Summary (1 page)......................................................... 8 Attachment 7 Well Schematic (3 pages)................................................................................................8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by ð unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 2.5-1)40(b}. For a well with multiple well branches~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by t/7e operator and to the numb!~r assigned to the well by t/7e commission. The well for which this Application is submitted will be designated as 1C-135. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applk,;ation for a PelïJ7ìt to Dn!1 must be accompimied by each of'the following Item5~ exŒpt for an item already on file with tfle commiS5ion and identified in the application: (2) a plat Identif'ying the property and the propertY~<j owners and !:117owing (A)the coordinates of the proposed location of the well at the Sl1rt;lce~ at the top of'each objective formation and at total depth! refenmced tv governmental section lines. (8) the coordinates of the proposed locatkm of the well at the surfacel referenced to the state plane coordinate system for thLc:; state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Admini..<;tration,: (C) the prop°f:¡-ed depth of the well at the top of each objective fonnaUon and at total depth; Location at Surface I 1706' FNL, 1022' FWL, Section 12, T11N R10E, UM NGS Coordinates RKB Elevation 91.1' AMSL Northings: 5,968,531 Eastings: 562,031 Pad Elevation 60.8' AMSL Location at Top of Productive Interval West Sak "D" Sand NGS Coordinates Northings: 5,963,242 949' FSL, 2162' FWL, Section 12, T11N, R10E, UM Eastings: 563,194 Measured De th RKB: Total Vertical De th RKB: Total Vertical De th 55: 7195 3784 3693 Location at Total De th NGS Coordinates Northings: 5,958,954 Eastings: 564,266 UM 11 695 3766 3675 and ORIGINAL 1C-135 PERMIT IT.doc Page 2 of 8 Printed: 16-Nov-O1 ,( ( APi."" "tion for Permit to Drill, Well 1 C-135 , Revision No.O Saved: 16-Nov-O1 (0) ot/7er information requtred by 20 MC 25.050(bJ/ Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviate~ the application for a PermIt to Dnll (Form 10-401) must (1) include a pla~ drawn to a suitable scalel showing the path of the proposed wellbore, including all adjacent wellbores v,¡ithin 200 feet of any portion of tl7e proposed we/~' Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list tl7e names of the operators of those wells, to the extent that those names are known or discoverable in public record~ and show tl7at eacl7 named operator has been fumisl7ed a copy of tl7e application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application (or a Permit to Drill must be accompanied by each of the following Items~ except for an Item already on tìle with the commission and Identified in the application: (3) a diagram and description of the blowout prevention equipment (80PE) as required by 20 AAC 25. 03~ 20 MC 25. OJ~ or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete well lC-135. Please see Attachment 2: 13-5 Diverter / BOP System Schematic. One of the spacer spools used in the stack arrangement is a combination diverter spool and spacer spool. Please see Attachment 3. Nordic Rig #3 is equipped with a 3" x 5,000 psi choke manifold with two chokes, one hydraulically operated, and one manually operated. The accumulator is a 160 gallon, 6 station unit. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pel7mt to 01111 must be accompanied by each of the following Item5~ exl.:"ept for an item already on file with the commiS"sion and identIfied in the application: (4) infamlation on drill¡ì7g hazards, including (A) the maximum downhole pressure that may be enColinterec¿ criteria {)!:Jì:?d to determlÌ7e it and maximum potential surfcìæ pres'.'iure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby WS1-0l well. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 1330 psi, calculated thusly: MPSP =(3797 ft)(0.46 - 0.11 psi/ft) =1328 psi (8) data on potential gas zones/' The well bore is not expected to penetrate any gas zones. and (C) data conceming potential causes o1l1OIe problems 5'uä¡ a5" abnormally geo-pressured stratal loS"t ärculation zones/ and ZO/7t}S that 17¿we a propensity for differential sticking; Please see Attachment 4: Drilling Hazards Summary. ORIGINAL 10-135 PERMIT IT. doc Page 3 of 8 Printed: 16-Nov-O1 ( Ap~" "'tion for Permit to Drill, We1l1C-135 \ Revision No.O Saved: 16-Nov-O1 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Pem7it to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and IdentIfied in the application: (5) a description of the procedure for conductJi7g formation integrity tes~ as required under 20 AAC 25,O30(f),' lC-135 will be completed with 7-5/8" surface casing landed in 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 is Attachment 5 to this document. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.0J~ and a desCliption of any slotted line~ pre- perforated line/; or screen to be installed,' Casing and Cementing Program See also Attachment 6: Cement Summary Hole Top Stm Csg/Tbg Size Weight Length MO/TVO MO/TVO 00 (in) (in) (lbltt) Grade Connection (ti) (to (to Cement ProQram 16 24 62.5 H-40 Welded 120 30 / 30 147 / 147 Cemented to surface with 225 cf ArcticSet 1 7-5/8 9-7/8 29.7 L-80 BTCM 7,332 30 / 30 7,362/ 3,797 Cemented to Surface with 650 sx ASLite Lead, 240 sx Class G Tail 4-1/2 6-3/4" 12.6 L-80 NSCT / 4,595 7,100/ 3,765 11,695 / 3766 Siotted- no slotted Lateral IBT cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An appliœtion for a Permit to Drill must be accompanied by each of the following item;,~ except for an item already on file with the commission and Identified in the application: (7) a diagram and description olthe diverter system as required by 20 AAC 25.03.~ lJl7le.s:"i tl7is requirement is waived by the commission under 20 MC 2.5.03.5(h)(2); A combination 13-5 BOP stack / diverter system will be used in the drilling of 1C-135. Please see diagrams in Attachment 2 and Attachment 3. ORIGINAL 1C-135 PERMIT IT doc Page 4 of 8 Printed: 16-Nov-O1 (" A~. ~tion for Permit to Drill, Well 1 C-135 Revision No.O Saved: 16-Nov-O1 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item:,~ except for an item already on file with the commission and Identified in the application: (8) a drilling flUId program, including a diagram and description of the drilling fluid system, as reqllked by 20 AAC 25,033/ Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program Spud to Base of Permafrost Base of Permafrost to 9-718" Hole TO Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 ~9.4 <9.4* 9.4* Funnel Viscosity (seconds) 150-200 150-200 150 75 Yield Point(cP} 30-60 30-60 20-40 18-30 Plastic Viscostiy (lb1100 sf) 8-15 11- 22 15-30 15-30 10 second Gel Strength (lb1100 10-30 10-25 10-25 10-25 sf) 10 minute Gel Strength (lb1100 25-55 25-55 20-40 20-40 sf) pH 8-9 8-9 8-9 8-9 API Fl1trate(cc} 8-15 6 5-6 5-6 Solids (%) 5-8 5-8 5-8 6-11 *9.8 ppg if hydrates are encountered Lateral Mud Program B sand lateral Initial Value Final Value Density 1""""" 1 8.9-9.0 8.9-9.0 Funnel Viscosity (seconds) 45-60 45-60 Yield Point 18-25 18-25 {cP} Plastic Viscostiy (lb1100 sf) 8-14 8-14 Tau 0 4-7 4-7 BID sand laterals Initial Value Final Value Chlorides 13-15K 13-15K oH 8-8.5 8-8.5 API filtrate <6 <6 **HTHP filtrate <10 <10 MBT <2.5 <2.5 ***Solids ppb <12 <12 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. This drilling fluid system of Nordic Rig 3 consists of: (2) Emsco F-1000 mud pumps, a 700 barrel surface mud system consisting of (4) 175 barrel working pits, with a 40 barrel pill pit included, a 50 barrel trip tank, (3) tandem Geolograph / Swaco Shale Shakers, (1) poor boy degasser, (1) vacuum degasser, (1) mixing hopper, mixing jets and agitators, PVT System with flow sensor, visual and audio alarms, and a low pressure pump and piping system. The mud system of the rig will be supplemented with a Baroid Solids control unit that has a Derrick shale shaker, two hydraulic Derrick centrifuges, and approximately 100 barrels of tankage. Further information about the mud system of Nordic 3 is on file with the Commission. ORIGINAL 1 C-135 PERMIT IT.doc Page 5 of 8 Printed: 16-Nov-O1 ( A¡;( 1tion for Permit to Drill, We1l1C-135 \ Revision No.O Saved: 16-Nov-O1 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the follow/fIg items/ except for an item already on file wIth the commission and Identified in the application: (9) for an exploratory or stratigraphic test well a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25. 033(f)/' Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application' (10) for an exploratOlY or stratigraphic test well a 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. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applkation for a Permit to Dnll must be accompanied by each of the following Items, except for an Item already on file with the comrnission and identified in the applìcation: (11) ('or ð well drilled tram an offshore platform, mobile battom..f'ounded structure, jack-up rig, or floating drilling vessel an analysi..c; of seabed conditions a8 required by 20 MC Z5:061(b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dr/II must be accompanied by each of the l'óllowing ltem5~ except tbr an item already on file with the mmmis..sion and identified /fl the application: (12) evidence 511owing that the requirements of 20AAC 25:025 {Bondingjhave been met~. Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill ml/st be accompanied by each of'the fallowing items, except for an item already 0/7 file wIth the commi::,:;ion and Identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 7, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 147' RKB. Weld landing ring on conductor. Install Vetco Gray Gen II wellhead. 2. Move in / rig up Nordic #3. Install Diverter / BOPE and function test. 3. Spud and directionally drill 9-7/8" hole to casing point at +/- 7,362' MD / 3,796' TVD as per directional plan. Run MWD, LWD tools as required for directional monitoring and data gathering. Casing point to be horizontal in the West Sak D-sand. 4. Run and cement 7-5/8", 29.7#, L-80, BTC Mod casing to surface. Displace cement with mud and perform stage job or top job if required. Note: Port collar to be run @ +/- 1000' MD. 5. Remove 16" Diverter line, install blind flange, activate and test BOP's to 3500 psi (annular preventer to 2500 psi) Notify AOGCC 24 hrs before test. 6. Rig up and run USIT cement evaluation tool from float collar to surface. ORIGiNAL 1 C-135 PERMIT IT.doc Page 6 of 8 Printed: 16-Nov-O1 ( Arl,'.' 1tion for Permit to Drill, Well 1 C-135 , Revision No.O Saved: 16-Nov-O1 7. PU 6-3/4" PDC Bit and directional BHA. RIH, clean out cement to top of float equipment, pressure test casing to 3500 psi for 30 minutes and record results. 8. Drill out cement and between 20' and 50' of new hole. Perform m to 12.0 ppg EMW and record results (ECD's estimated not to exceed 11.5 ppg) 9. Change over to clean BaraDril'N drilling mud. Directionally drill 6-3/4" hole to TD at +/- 11,695' MD / 3,766' 1VD as per directional plan. 10. POOH and lay down MWD, LWD and PWD tools. 11. Pick up and rack back weight pipe as needed for liner running. 12. RIH with 6-3/4" hole opener and ream entire open hole. 13. Circulate and condition hole to run liner. Displace to clean BaraDril'n fluid. 14. PU and run 4-1/2" Slotted Liner. (run liner with 2-7/8" inner wash string). 15. Land liner, set liner packer @ +/- 7,100' MD / 3,765' 1VD and displace drilling mud at 10 bpm with minimum 870 bbls 3% KCL brine weighted to 8.8 ppg. POOH. 16. PU and RIH with 3-1/2" tubing, with CMD open. 17. Sting into seal bore extension and space out. Displace well to clean 8.8 ppg KCI brine. 18. Sting back into seal bore extension and land tubing. 19. Install back pressure valve. Nipple down BOP stack. Install production tree and pressure test same. 20. Pull BPV. Freeze protect well by pumping diesel down annulus, circulating through sliding sleeve, then allowing diesel to U-tube into tubing through choke. 21. Rig up wireline and close sliding sleeve. Set plug in profile in sliding sleeve. 22. Using diesel, pressure test tubing and annulus to 3500 psi for 30 minutes. 23. Install back pressure valve, and release Nordic Rig #3. Post Rig Wo~ 1. Pull back pressure valve. 2. Rig up wireline and remove plug from profile in sliding sleeve. 3. Install Weatherford jet pump and open sliding sleeve. 4. Install back pressure valve and move off. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a PermIt to Drill mustc be accompanied by each of the following Item.<i¡ except for an item already on file with the c:vmmission and identified in the application: (14) a general description of how the operator plans to dispo!;,'"e of drilling mud and cuttings and a statement of whether the operator intends to request authorization imder 20 AAC 25'.080 for an annular difJposal 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 lC 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 lC Pad or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to request authorization for the use of this well for annular disposal operations. ORIGINAL 1C-135 PERMIT IT.doc Page 7 of 8 Printed: 16-Nov-O1 ( Apl¡t": 'tion for Permit to Drill, We1l1C-135 ( Revision No.O Saved: 16-Nov-O1 14. Attachments Attachment 1 Directional Plan (12 pages) Attachment 2 13-5 Diverter / BOP System Schematic (1 page) Attachment 3 Diverter Spool Drawing (1 page) Attachment 4 Drilling Hazards Summary (1 page) Attachment 5 Formation Integrity Test Procedure (1 page) Attachment 6 Cement Loads and CemCADE Summary (1 page) Attachment 7 Well Schematic (3 pages) ORIGINAL 1C-135 PERMIT ITdoc Page 8 of 8 Printed: 16-Nov-O1 16' 158.00 MD 158.00 TVD - :::J CJ) ~ .- .- ()) II ro :::.::: a: ..c Õ. OJ 0 (ii u '-E OJ > DrillQuest 2.00.09.006 Eastings Scale: 1 inch = 2000ft Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1C-135 (wpO2) N -.*~ < ~ bq, ~ø 0 Reference is TRUE North 2000 4000 6000 3HL: )( =. Si)?()3(),,'f' E ,~ Y .. '/;C~~;.'~:~,-ìS/ ~~ 0 (17G!)¡:NL,~~(\:>2'f~WL. ~;EC.':>,T11N.F~('Ej Well: Current Well Properties Plan: 1C-135 -2000 ;'H>L'.;;'>;';~:':';:.: Horizontal Coordinates: Ref. Global Coordinates: 5968530.52 N, 562030.36 E Ref. Stucture Referance: 10.88 N, 341.61 W Ref. Geographical Coordinates: 70° 19' 28,3926" N, 149° 29' 49.2652" W 1706' FNL & 1022' FWL, SEC. 12 - T11N - R10E RKB Elevation: , North Reference: Units: 91.1Oft above Mean Sea Level True North Feet (US) SHL. X.. ~'f'2(X'C'.3W E ó; Y .= 595;553G.5?' N (l?W';::NL (, ;02;-;',,",'[.. -SEC ;2.¡¡,N-i=];OE) 0 Begin Oir @ 3.00/1001t (in 9-718" Hole): 300,OOft MD, 300.00ft TVO Continue Dir @ 3.00/10OfI : 633,33ft MO, 631.64ft TVO Increase in Oir Rate @ 4.5°/10Oft: 1049.75ft MO, 1033.94ftTVO 1100 spe""""y-sul1 DRILLING. SERV,Ic:ES A Halliburton Company End Dir, Start Sail @ 67.00° : 2217.09ft MO, 1869.85ft TVO ............,/ ----I:!"'--' --n_""_"" .......,......... "'h"_h""" h_- ~()(). 2200 K-j' :~-- h" . i ,.j' ",;," '. ~X.'~"T'!f; ------- 3300 " ""~...' -===- l,.';~':; !:.j".".,,;-. . ----- -"'~"">;"-h,."¡"!S;'"U --- "~';'<,"¡~ 0 1100 2200 Scale: 1 inch = 11 OOft 3300 ",' . ,',',' éf '. <,<,)," 'ò~,,\-.¡Q .(., ,~@ ,:þ\' , ,'I . ,,:>7>':14>' .c'.,,".c' ,,:>'7>~~,~ c":"""" O\\':1\,>Jì ,"".', , <é-~ò~b.~ <,',-"..,",", \~ ev':V'::;'>" ,r;ØJ ,.,.~;,;;~~()()'Çj ~()\)'Çj 4-1/2' Liner " . , 11695.111MD 3766,JH TVD "'_m""'h'" Begin Ojr @ 3.0°/10011 (in 9-7/8' Hole): 300,0011 MO, 300,0011 TVO Continue Ojr @ 3.0°/10011: 633.3311 MO, 631.6411 TVO Increase in Ojr Rate @ 4.5°/10011: 1049.7511 MO, 1033,9411 TVO End Dir, Start Sail @ 67,00": 2217.0911 MO, 1869.8511 TVO -4000 The Following 200' is a designed 'T ANGENT' lor PUMP PLACEMENT I I / 3~O / en 0) c ..c t 0 Z Begin Dir @ 8.5°/10011: 6926.5911 MO, 3710,0011 TVO End Ojr, Slart Sail @ 81.08° : 7193.33ft MD, 3783,77ft TVD Begin Oir @ 8.5°/10011 : 7206,82ft MO, 3785.8611 TVO 7-fj18" Csg 7362.5ft MD 3196.7ft TVO :':,,'<~F..'" :H""'U. :.".-,:"""",;"', :"[~.' ,:':;!\,"I;j(,I,i:;i!!;,,'./i:';(,.':".!¡¡,:';; -6000 7-518" Csg PI, Start Sail @ 90.90° (in 6-3/4" Hole): 7362.4811 MD. 3796.7211 TVO 3777,2 - õ 0 0 C\I II ..c u ,!:; ~;:');:;'~,C, ';;,cX':':~,'.>; :::;::i 1.."1; !; L';",';: ,f!: r;C,' " \'S~ (. ;';:;' ,"'¡, ;;f:(' ,¡, ,':. '. . '; .'C;:' -8000 ','.. End Ojr, Slart Sail @ 89.60° ; 10324,5711 MO, 3756,5511 TVO OJ (ii u en H'!rL,"'-"J' ~;C).:';il:,"'L, ~';,:c :'~I"':i' \,~?;;" L,~:):':';-;è'; :;:.:",;,~."1:,. 4-1/2" Liner 11695.1ftMO 3766.111TVD ~0Ò~ òes\~~\1<€ -10000 7> ...(1 ~ \S ç\r ~~~~~\)~ç O\\dJI(\.'~~Q 0 0'. 2000" ,c\;' 4000 ~\O~,\O \ 'ò<S Q~ \~\Q ..""" ,(',." e«o~~ \ @ ',?>1" @'ò ",.."" ,:" ~\Q "'\'" ~ßi \ 0\\ -"Q' # -(II(\. !('o." ~Q .",' ..J.:"",' ° 1(\." ,~\>' .. ~\~ # "" ~ S :l'ò'?>' o\\çfS f>I(\. .f)'" ':,',," .."" ~Çj ~:1<Z: \ ~~.'.I"~<O' -',..?"...~...~.....~..,".'.""'v."'->~~'.'~:'\..~"'~"" ..,",.g¡).',.,~,:l.g ,ú"V Q' ~ "'. "" ~I """, -' '~ "" -"Q, \ ,,~ò 1? O\\."Q, .':;"",.""".. 9' ..."'. , v ~,?>. .~ -~ "'. ,,','F A"" v^" " ~ r{D" -+ - 1\ ~eo,\'ò'" ./;"'-,~">,' . ,,:>,-7J:c#>,/-, ,," \ I L 1'fJ' ~~:;~~.~&:. <', \<S vS~~~0'i.1 ç,(;<~'~~;~ '; --\ -=:/= ,'.<,c,:' 1":>~\ti, ""'"r.,' ~-"o.><- - / -.'.'-' - ~~ú' ',<C,":::'" ^,,-,:,.<:' 6000 4400 5500 7700 8800 6600 , .., h ...., moo ..OO. . ':::<:<. ;".". hD;';'..<' ,.;>j.,.....>~ 0 -2000 . ..-...... -40(, -6000 -8000 ~ -10000 .. , ...~ ,. ':"~'..,,. . 9900 C ::0 ~ - ~ ~ §: r--- --. Ku°f{ Ff'IJlêr Unit ..'..' ..f!I"rt .' lope, Alaska K'!PlfUk 1 C, Slot 1 C-135 C~135 (C-14) - 1C-135 (wpO2) Revised: 1 November, 2001 PROPOSAL REPORT 1 November, 2001 -. Your Ref: per Mike Werner wi Phillips Surface Coordinates: 5968530.52 N, 562030.36 E (70019' 28.3926" N, 149029' 49.2652" W) Surface Coordinates relative to Project H Reference: 968530.52 N, 62030.36 E (Grid) Surface Coordinates relative to Stucture Referance: 10.88 N, 341.61 W (True) Kelly Bushing: 91.10ft above Mean Sea Level 5per"'-'Y-SU" ~ï3ÜikkIœ:~~:::::~:jj~~ S2T~ A h..U&.n1t&t éi>rnÞÓ"'!o' Proposal Ref: pro9676 Sperry-Sun Drilling Services Proposal Report for Plan 1C-135 (C-14) -1C-135 (wp02) Your Ref: per Mike Werner wI Phillips Revised: 1 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings . ç~stings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -91.10 0.00 0.00 N 0.00 E 5968530.52 N . 562030.36 E 0.00 8HL: X = 562030.36' E & Y = 5968530.52' N 100.00 0.000 0.000 8.90 100.00 0.00 N 0.00 E.59ô8£30.52tN 562030.36 E 0.000 0.00 158.00 0.000 0.000 66.90 158.00 0.00 N jjjpO E ,5968st3.D.52N 562030.36 E 0.000 0.00 16" Conductor 200.00 0.000 0.000 108.90 200.00 0.00 N ~:i~~~::~~~~;~:;~ ~ 562030.36 E 0.000 0.00 -- 300.00 0.000 0.000 208.90 300.00 0.00 N... 562030.36 E 0.000 0.00 Begin Dir @ 3.0° ¡100ft (in 9-,. ,/ Hal 300.00ft MD, 300.00ft TVD 400.00 3.000 236.000 308.85 2.17W 5968529.04 N 562028.20 E 3.000 1.46 500.00 6.000 236.000 408.53 8.67W 5968524.60 N 562021.73 E 3.000 5.85 600.00 9.000 236.000 507.67 19.49 W 5968517.21 N 562010.98 E 3.000 13.15 633.33 10.000 236.000 540.54 24.05 W 5968514.10 N 562006.44 E 3.000 16.23 Continue Dir @ 3.00/1O0ft : 633.33ft MD, 631.64ft TVD C 700.00 11 .278 227.644 606.07 23.85 S 33.67 W 5968506.39 N 561996.89 E 3.000 23.85 ::0 800.00 13.523 218.330 794:84 39.62 S 48.15 W 5968490.51 N 561982.54 E 3.000 39.62 900.00 16.013 211.742 891.53 60.52 S 62.66 W 5968469.48 N 561968.20 E 3.000 60.52 - - C':) 1000.00 18.651 206.930 .' 986.99 86.52 S 77.16 W 5968443.37 N 561953.91 E 3.000 86.52 1049.75 20.000 20S¡OOO .'. 1033.93 101.32 S 84.36 W 5968428.51 N 561946.84 E 3.000 101.32 Increase in Dir Rate @ 4.5°/1 OOft : - - 1 049.75ft MD, 1 033.94ft TVD ~ 1100.00 21 989.82 1080.92 117.77 S 91.22 W 5968412.00 N 561940.12 E 4.500 117.77 1200.00 24.;999 ~ 193.012 .... 1081.68 1172.78 155.60 S 102.39 W 5968374.08 N 561929.26 E 4.500 155.60 r--- 1300.00 . 28;;7007.,187.357 1170.89 1261.99 200.03 8 110.23 W 5968329.58 N 561921.79 E 4.500 200.03 1400.00 .. 32.601182.923 1256.91 1348.01 250.78 S 114.68 W 5968278.80 N 561917.76 E 4.500 250.78 -. 1500.00 .'. .' 36.620 179.354 1339.21 1430.31 307.54 S 115.72 W 5968222.04 N 561917.19 E 4.500 307.54 1600.00 40.728 176.408 1417.27 1508.37 369.95 S 113.34 W 5968159.64 N 561920.09 E 4.500 369.95 1700.00 44.898 173.918 1490.62 1581.72 437.64 S 107.55 W 5968092.00 N 561926.43 E 4.500 437.64 1800.00 49.115 171.770 1558.80 1649.90 510.18 S 98.40 W 5968019.54 N 561936.18 E 4.500 510.18 1900.00 53.368 169.880 1621.39 1712.49 587.148 85.93 W 5967942.69 N 561949.29 E 4.500 587.14 2000.00 57.647 168.189 1678.01 1769.11 668.02 8 70.23 W 5967861.94 N 561965.66 E 4.500 668.02 2054.05 59.968 167.342 1706.00 1797.10 713.20 8 60.42 W 5967816.85 N 561975.83 E 4.500 713.20 Base Permafrost 1 November, 2001- 11:08 Page 2 of 9 DrillQuest 2.00.09.006 C ::0 - ~ C) - ~ r-- Kuparuk River Unit Measured Depth (ft) 2100.00 2200.00 2217.09 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3261.92 3300.00 3400.00 3500.0 3600.0 3700.0 3800.0 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 Incl. 61.946 66.261 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 "'7.000 0... .uoO 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 67.000 Azim. 166.652 165.233 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 .....165:000 . . n.... . 165.090 1 ()5.00Q 165.000 . /165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 165.000 Sub-Sea Depth (ft) 1728.31 1771.97 1778.75 1811.15 1850.22 1889.29 1928.37 1967.44 2006.51 2045.59 2240.95 2280.03 2319.10 2358.17 2397.25 2436.32 2475.39 2514.46 2553.54 2592.61 2631.68 2670.76 2709.83 2748.90 2787.98 Vertical Depth (ft) 1819.41 1863.07 1869.85 1902.25 1941 .32 1980.39 2019.47 2058.54 2097.61 213E>..69 2332.05 2371.13 2410.20 2449.27 2488.35 2527.42 2566.49 2605.56 2644.64 2683.71 2722.78 2761.86 2800.93 2840.00 2879.08 Sperry-Sun Drilling Services Proposal Report for Plan 1C-135 (C-14) -1C-135 (wp02) Your Ref: per Mike Werner wI Phillips Revised: 1 November, 2001 Local Coordinates Northings Eastings (ft) (ft) 752.34 S 839.58 S 854.74 S 928.46 S 1017.37 S 1550.86 S 1639.77 S 1728.68 S 1783.74 S 1817.60S 1906.51 S 1995.42 S 2084.34 S 2173.25 S 2262.17 S 2351.08 S 2439.99 S 2528.91 S 2617.82 S 2706.74 S 2795.65 S 2884.56 S 2973.48 S 3062.39 S 3151.31 S 161.04E 184.86 E 208.68 E 223.44 E 232.51 E 256.33 E 280.16 E 303.98 E 327.81 E 351.63 E 375.46 E 399.28 E 423.10 E 446.93 E 470.75 E 494.58 E 518.40 E 542.23 E 566.05 E 589.87 E Global Coordinates Northingsçastings (ft) . . (ft) 5967777..78 N 5~()1p9Œ'Z3 N 675.6QN 5967424.62 N 5967335.90 N 5967247.19 N 5967158.48 N 5967069.76 N 5966981.05 N 5966892.34 N 5966803.62 N 5966748.69 N 5966714.91 N 5966626.19 N 5966537.48 N 5966448.77 N 5966360.05 N 5966271.34 N 5966182.62 N 5966093.91 N 5966005.20 N 5965916.48 N 5965827.77 N 5965739.05 N 5965650.34 N 5965561.63 N 5965472.91 N 5965384.20 N 561985.20 E 562007.78 E 562011.94 E 562032.30 E 562056.86 E 562081.42 E 562105.97 E 562130.53 E 562155.09 E 562179.65 E 562204.21 E 562228.77 E 562253.33 E 562268.53 E 562277.88 E 562302.44 E 562327.00 E 562351 .56 E 562376.12 E 562400.68 E 562425.24 E 562449.80 E 562474.35 E 562498.91 E 562523.47 E 562548.03 E 562572.59 E 562597.15 E 562621.71 E 562646.26 E Dogleg Rate e/100ft) 4.500 4.500 4.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section 752.34 839.58 854.74 928.46 1017.37 1106.29 1195.20 1284.11 1373.03 1461.94 1550.86 1639.77 1728.68 1783.74 1817.60 1906.51 1995.42 2084.34 2173.25 2262.17 2351 .08 2439.99 2528.91 2617.82 2706.74 2795.65 2884.56 2973.48 3062.39 3151.31 North Slope, Alaska Kuparuk 1 C Comment End Dir, Start Sail @ 67.00° : 2217.0 MD, 1869.85ft TVD --, Top K-15 ~'. 1 November, 2001 - 11:08 Page 3 of 9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan 1C-135 (C-14) - 1C-135 (wp02) Your Ref: per Mike Werner wi Phillips Revised: 1 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings.. J;~s~il1gs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 4900.00 67.000 165.000 2827.05 2918.15 3240.22 S 59652Q5A8 N 562670.82 E 0.000 3240.22 5000.00 67.000 165.000 2866.12 2957.22 3329.13 S 59652061¡Z;Z N562695.38 E 0.000 3329.13 5100.00 67.000 165.000 2905.20 2996.30 3418.05 S596~118.06N 562719.94 E 0.000 3418.05 5200.00 67.000 165.000 2944.27 3035.37 3506.96 S5965029.34-N 562744.50 E 0.000 3506.96 -=- 5300.00 67.000 165.000 2983.34 3074.44 3595.88 S5964940.63 N 562769.06 E 0.000 3595.88 ~ ~, 5400.00 67.000 165.000 3022.42 3113.52 3684.79 S ..ž32.82Uæ 5964851.91 N 562793.62 E 0.000 3684.79 5500.00 67.000 165.000 3061.49 3152.59 3773]0 S .. 756.65 E 5964763.20 N 562818.17 E 0.000 3773.70 5590.89 67.000 165.000 3097.00 3188.10 3854.51 S E 5964682.57 N 562840.49 E 0.000 3854.51 Top Ugnu C 5600.00 67.000 165.000 3100.56 3191.663~62.62S 780.47 E 5964674.49 N 562842]3 E 0.000 3862.62 5700.00 67.000 165.000 3139.63 3230.733951.5Sir5 804.29 E 5964585.77 N 562867.29 E 0.000 3951.53 5800.00 67.000 165.000 !!+040.45 S 828.12 E 5964497.06 N 562891.85 E 0.000 4040.45 5900.00 67.000 165.000 ..4129.36 S 851.94 E 5964408.34 N 562916.41 E 0.000 4129.36 6000.00 67.000 165.000 4218.27 S 875]7 E 5964319.63 N 562940.97 E 0.000 4218.27 C 6100.00 67.000 165.000 4307.19 S 899.59 E 5964230.92 N 562965.53 E 0.000 4307.19 ::J::I 6200.00 67.000 165.000 4396.10 S 923.42 E 5964142.20 N 562990.08 E 0.000 4396.10 - ,....,;;;;,. 6251.19 ......1........6..q,...;.qoo 39$5.00 3446.10 4441.61 S 935.61 E 5964096.79N 563002.65E 0.000 4441.61 TopUgnuB ~ ~ 6300.001f35.pOO 3374.07 3465.17 4485.02 S 947.24 E 5964053.49 N 563014.64 E 0.000 4485.02 - - 6381.71165.000 3406.00 3497.10 4557.67 S 966.71 E 5963981.00 N 563034.71 E 0.000 4557.67 Top Ugnu A ;æ: 6400.0. . .000.... 3413.15 3504.25 4573.93 S 971.07 E 5963964.77 N 563039.20 E 0.000 4573.93 ~ 6500.065.000 3452.22 3543.32 4662.84 S 994.89 E 5963876.06 N 563063.76 E 0.000 4662.84 -- r-- 3491.29 3582.39 4751.76S 1018]1 E 5963787.35N 563088.32E 0.000 4751]6 . 3530.37 3621.47 4840.67 S 1042.54 E 5963698.63 N 563112.88 E 0.000 4840.67 The Following 200' is a designed 'TANGENT' for PUMP PLACEMENT 6757.93 67.000 165.000 3553.00 3644.10 4892.18 S 1056.34 E 5963647.24 N 563127.10 E 0.000 4892.18 K-13 Shale 6800.00 67.000 165.000 3569.44 3660.54 4929.58 S 1066.36 E 5963609.92 N 563137.44 E 0.000 4929.58 6900.00 67.000 165.000 3608.51 3699.61 5018.50S 1090.19E 5963521.20N 563161.99E 0.000 5018.50 6926.59 67.000 165.000 3618.90 3710.00 5042.14 S 1096.52 E 5963497.62 N 563168.52 E 0.000 5042.14 Begin Dir @ 8.5°/1O0ft: 6926.59ft M 371 O.OOft TVD 7000.00 70.701 170.388 3645.40 3736.50 5109.00 S 1111.07 E 5963430.88 N 563183.62 E 8.500 5109.00 7100.00 75.978 177.347 3674.09 3765.19 5204.16S 1121.21E 5963335.81N 563194.55E 8.500 5204.16 7193.33 81.076 183.552 3692.67 3783]7 5295.54 S 1120.45 E 5963244.42 N 563194.54 E 8.500 5295.54 End Dir, Start Sail @ 81.08° : 7193.3 MD, 3783.77ft TVD 7195.48 81.076 183.552 3693.00 3784.10 5297.668 1120.32E 5963242.30N 563194.43E 0.000 5297.66 TopWestSakD 1 November, 2001 - 11:08 Page 4 of 9 DrillQuest 2.00,09.006 Sperry-Sun Drilling Services Proposal Report for Plan 1C-135 (C-14) -1C-135 (wp02) Your Ref: per Mike Werner wi Phillips Revised: 1 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7200.00 81.076 183.552 3693.70 3784.80 5302.12S 1120.04E 596323'Z,84N 563194.19E 0.000 5302.12 7206.82 81.076 183.552 3694.76 3785.86 5308.84 S 1119.62 E 5963231:11 N 563193.83 E 0.000 5308.84 Begin Dir @ 8.5°/100ft : 7206.82ft M 3785.86ft TVD 7300.00 86.964 178.223 3704.47 3795.57 5401.43 S 1118121 E "..S963:138.52N 563193.18 E 8.500 5401.43 7361.72 90.882 174.733 3705.63 3796.73 5463.00 S ..1122100 E '.5963076.98 N 563197.48 E 8.500 5463.00 TARGET (Heel): Continue C-, 8.5°/100ft : 7361.72ft MD, 3,. J.73ft TVD 7362.48 90.902 174.672 3705.62 3796.72 5463.76 S 22.07 E 5963076.22 N 563197.56 E 8.500 5463.76 7-5/8" Csg Pt, Start Sail @ 90.900 (in 3/4" Hole): 7362.48ft MD, 3796.72ft TVD 7-5/8" Casing 7400.00 90.902 174.672 3705.03 3796;'11.3,5501.11 S 1125.55 E 5963038.90 N 563201.35 E 0.000 5501.11 7500.00 90.902 174.672 3703.45 4~5þ . . 5600.67 S 1134.84 E 5962939.42 N 563211.46 E 0.000 5600.67 7600.00 90.902 174.672 3701.88:;£18 5700.22 S 1144.12 E 5962839.95 N 563221.56 E 0.000 5700.22 7700.00 90.902 174.672 , BZOQ130 3791',40 5799.78 S 1153.41 E 5962740.47 N 563231.67 E 0.000 5799.78 7800.00 90.902 174.6723698JPß3789.83 5899.34S 1162.69E 5962641.00N 563241.78E 0.000 5899.34 a .. ....... 7900.00 90.902 17.4;672. 3897.15 3788.25 5998.89 S 1171.98 E 5962541.52 N 563251.89 E 0.000 5998.89 ~ 8000.00 90.9021741672 3695.58 3786.68 6098.45 S 1181.26 E 5962442.05 N 563261.99 E 0.000 6098.45 - .....,. ,...... ,....;;;;",. 8100.00....,.. .. '. '9..0.9,02......,'.',."...... '.',.".",+..i,...,',.4...... .6rg 3694.00 3785.10 6198.00 S 1190.55 E 5962342.57 N 563272.10 E 0.000 6198.00 ~ ~ 8200.00 ..., 90.902 ... 174.672... 3692.43 3783.53 6297.56 S 1199.83 E 5962243.10 N 563282.21 E 0.000 6297.56 - - 8300.00 '90:902174.672 3690.85 3781.95 6397.11 S 1209.12 E 5962143.62 N 563292.32 E 0.000 6397.11 ~ 8400.00' , 90,902 74,672 3689.28 3780.38 6496,67 S 1218.40 E 5962044,14 N 563302.42 E 0,000 6496,67 -. 8500.00 . 90.902 174.672 3687.70 3778.80 6596.22 S 1227.69 E 5961944.67 N 563312.53 E 0.000 6596.22 r-- 8600.00 90.902 174.672 3686.13 3777.23 6695.78 S 1236.97 E 5961845.19 N 563322.64 E 0.000 6695.78 8700.00 90.902 174.672 3684.55 3775.65 6795.34 S 1246.26 E 5961745.72 N 563332.75 E 0.000 6795.34 8800.00 90.902 174.672 3682.98 3774.08 6894.89 S 1255.54 E 5961646.24 N 563342.85 E 0.000 6894.89 8900.00 90.902 174.672 3681.41 3772.51 6994.45 S 1264.83 E 5961546.77 N 563352.96 E 0.000 6994.45 9000.00 90.902 174.672 3679.83 3770.93 7094.00 S 1274.11 E 5961447.29 N 563363.07 E 0.000 7094.00 9100.00 90.902 174.672 3678.26 3769.36 7193.56 S 1283.40 E 5961347.82 N 563373.18 E 0.000 7193.56 9200.00 90.902 174.672 3676.68 3767.78 7293.11 S 1292.68 E 5961248.34N 563383.28 E 0.000 7293.11 9300.00 90.902 174.672 3675.11 3766.21 7392.67 S 1301.97 E 5961148.87 N 563393.39 E 0.000 7392.67 1 November, 2001 - 11:08 Page 5 of 9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan 1C-135 (C-14) - 1C-135 (wp02) Your Ref: per Mike Werner wi Phillips Revised: 1 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings .E~stings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) .(ft) (°/1 OOft) 9400.00 90.902 174.672 3673.53 3764.63 7492.22 S 1311 .25 E 5961 049,,39 N .563403.50 E 0.000 7492.22 9500.00 90.902 174.672 3671.96 3763.06 7591.78 S 1320.54 E 5960949;92 N 563413.61 E 0.000 7591.78 9600.00 90.902 174.672 3670.38 3761.48 7691.34 S 1329.82 E.. 5960850.44N 563423.71 E 0.000 7691.34 . . 9700.00 90.902 174.672 3668.81 3759.91 7790.89 S 1339:11 E.. 5960Þ50.96N 563433.82 E 0.000 7790.89 .~ 9751 .23 90.902 174.672 3668.00 3759.10 7841.90S .1843:86 E . 591)0700.00 N 563439.00 E 0.000 7841 .90 TARGET (Begin Turn SE): [ . Dir 4.00/1O0ft: 9751.23ft MD, 3ï~;j.1 Oft TVD Target - 1 C-135 (D Turn SE), Curren Target 9800.00 90.794 172.724 3667.28 3758.38 ...7t3~0.3~~~ 1349.22 E 5960651.58 N 563444.75 E 4.000 7890.36 9900.00 90.570 168.730 3666.09 375!;~ 9 '.'..7989;03'5 1365.33 E 5960553.05 N 563461.68 E 4.000 7989.03 10000.00 90.343 164.736 3665.29 375 9 8086.34 S 1388.27 E 5960455.94 N 563485.42 E 4.000 8086.34 10100.00 90.115 160.743 3664.89 .8%5 9 8181.81S 1417.94 E 5960360.71 N 563515.88 E 4.000 8181.81 10200.00 89.885 156.749 3664. 755i.9 8274.99 S 1454.18 E 5960267.83 N 563552.89 E 4.000 8274.99 10300.00 89.657 756.39 8365.42 S 1496.82 E 5960177.76 N 563596.28 E 4.000 8365.42 10324.57 89.601 3756.55 8387.16 S 1508.26 E 5960156.11 N 563607.89 E 4.000 8387.16 End Dir, Start Sail @ 89.60° : C 1 0324.57ft MD, 3756.55ft TVD 3665.97 3757.07 8453.63 S 1543.93 E 5960089.95 N 563644.11 E 0.000 8453.63 =0 3666.67 3757.77 8541.73 S 1591.22 E 5960002.23 N 563692.13 E 0.000 8541. 73 - - 3667.37 3758.47 8629.84 S 1638.51 E 5959914.52 N 563740.15 E 0.000 8629.84 ~ 10700.00 ,89:601 51.775 3668.07 3759.17 8717.95 S 1685.81 E 5959826.81 N 563788.17 E 0.000 8717.95 - - .-., ~ 10800.00... 89.601 .775 3668.76 3759.86 8806.05 S 1733.10 E 5959739.09 N 563836.19 E 0.000 8806.05 10900.00... . 89.601 151.775 3669.46 3760.56 8894.16 S 1780.39 E 5959651 .38 N 563884.21 E 0.000 8894.16 11000.00 89.601 151.775 3670.16 3761.26 8982.27 S 1827.69 E 5959563.67 N 563932.23 E 0.000 8982.27 r--- 11100.00 89.601 151.775 3670.85 3761.95 9070.38 S 1874.98 E 5959475.95 N 563980.25 E 0.000 9070.38 11200.00 89.601 151.775 3671.55 3762.65 9158.48 S 1922.27 E 5959388.24 N 564028.27 E 0.000 9158.48 11300.00 89.601 151.775 3672.25 3763.35 9246.59 S 1969.57 E 5959300.53 N 564076.29 E 0.000 9246.59 11400.00 89.601 151.775 3672.94 3764.04 9334.70 S 2016.86 E 5959212.81 N 564124.31 E 0.000 9334.70 11500.00 89.601 151.775 3673.64 3764.74 9422.81 S 2064.15 E 5959125.10 N 564172.33 E 0.000 9422.81 11600.00 89.601 151.775 3674.34 3765.44 9510.91 S 2111.44 E 5959037.39 N 564220.35 E 0.000 9510.91 1 November, 2001 - 11:08 Page 6 of 9 Dri//Quest 2.00.09.006 Kuparuk River Unit Measured Depth (ft) 11695.07 Incl. Azim. Sub-Sea Depth (ft) 3675.00 Vertical Depth (ft) 3766.10 Sperry-Sun Drilling Services Proposal Report for Plan 1C-135 (C-14) -1C-135 (wp02) Your Ref: per Mike Werner wI Phil/ips Revised: 1 November, 2001 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates NorthingsEastings (ft) . (ft) Dogleg Rate (0/100ft) 89.601 151.775 9594.67 S 2156.40 E 564266.00 E 0.000 All data is in Feet (US) unless otherwise stated. Directions and coordinates are reiative1þTrüe Ng Vertical depths are relative to RKB = 91.1' (MSL). Northings and Eastings are relative tÓ"';1]OO~FNL, The Dogleg Severity is in Degrees per 100 feet (US). .............. ... .... .... Vertical Section is from -1700'FNL, 1000'FWL and calculated along an A4imuth 01180.000° (True). Based upon Minimum Curvature type calculations, at a Measu The Bottom Hole Displacement is 9834.01 ft., in the Direc" Comments 0 ::0 - - ~ - ~ r--- Measured Depth (ft) 6331; 1049}75 2217:09 6700.00 6926.59 7193.33 7206.82 7361.72 . O:()O 300~00 631.64 1033.94 1869.85 3621.47 3710.00 3783.77 3785.86 3796.73 0.00 N 0.00 N 16.22 S 101.32 S 854.74 S 4840.67 S 5042.14 S 5295.54 S 5308.84 S 5463.00 S ïnates Eastings (ft) 0.00 E 0.00 E 24.05 W 84.36 W 25.49 W 1042.54 E 1096.52 E 1120.45 E 1119.62 E 1122.00 E 11695.07ft., 7rue): Comment SHL: X = 562030.36' E & Y = 5968530.52' N Begin Dir @ 3.0°/1 OOft (in 9-7/8/1 Hole): 300.00ft MD, 300.00ft TVD Continue Dir @ 3.00/100ft : 633.33ft MD, 631.64ft TVD Increase in Dir Rate @ 4.5°/1 OOft : 1 049.75ft MD, 1 033.94ft TVD End Dir, Start Sail @ 67.00° : 2217.09ft MD, 1869.85ft TVD The Following 200' is a designed 'TANGENT' for PUMP PLACEMENT Begin Dir @ 8.5°/100ft : 6926.59ft MD, 371 O.OOft TVD End Dir, Start Sail @ 81.08° : 7193.33ft MD, 3783.77ft TVD Begin Dir @ 8.5°/100ft : 7206.82ft MD, 3785.86ft TVD TARGET (Heel): Continue Dir @ 8.5°/100ft: 7361.72ft MD, 3796.73ft TVD Vertical Section 9594.67 North Slope, Alaska Kuparuk 1 C Comment PBHL (Toe) : 11695.07ft MD, 3766.1 TVD 4-1/2/1 Liner Target - 1 C-135 (D-Toe), Cu~t Tar -, 1 November, 2001 - 11:08 Page 7 of 9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan 1C-135 (C-14) - 1C-135 (wp02) Your Ref: per Mike Werner wI Phillips Revised: 1 November, 2001 Kuparuk River Unit Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comments (Continued) 7362.48 3796.72 5463.76 S 1122.07 E 9751.23 3759.10 7841.89 S 1343.86 E 10324.57 3756.55 8387.17 S 1508.26 E 11695.07 3766.10 9594.67 S 2156.40 E Formation Tops Formati on Plane Pro f i (Below Well Origin) Measured Vertic Sub-Sea Dip Dip Dir. Depth (ft) Deg. Deg. (ft) <::) ::0 - - ~ - - ~ ....... 1706.00 2187.00 3097.00 3355.00 3406.0C 2'~54.aB ;;1797.10 1706.00 261.92 2278.10 2187.00 5Qa.89 3188.10 3097.00 251.19 3446.10 3355.00 6381.71 3497.10 3406.00 6757.93 3644.10 3553.00 7195.48 3784.10 3693.00 North Slope, Alaska Kuparuk 1 C Comment 7-5/8" Csg Pt, StâìW,§aiL@¡90.9Qo (iric6-3/4" Hole): 7362.48ft MO, 3796.72ft TVD TARGET'TûlÎtSE):Begiri Dif'@ 4.00/100ft : 9751.23ft MD, 3759.1 Oft TVD End Oir1 . . ... .......60ó :1 0324.57ft MO, 3756.55ft TVD PBHL (rQß);.l~~e95.MD, 3766.10ftTVD --. t ion Poi n t Northings Eastings Formation Name (ft) (ft) 713.20 S 60.42 W Base Permafrost 1783.74 S 223.44 E TopK-15 3854.51 S 778.30 E Top Ugnu C 4441.61 S 935.61 E Top Ugnu B 4557.67 S 966.71 E Top Ugnu A 4892.18 S 1056.34 E K-13 Shale 5297.66 S 1120.32 E Top West Sak 0 -- 1 November, 2001 - 11:08 Page 8 of 9 DrillQuest 2.00.09.006 C ::x:J - - c-> ~ - :æ: ~ r--- Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Sperry-Sun Drilling Services Proposal Report for Plan 1C-135 (C-14) - 1C-135 (wp02) Your Ref: per Mike Werner wI Phillips Revised: 1 November, 2001 Casing Detail Target Shape Point Point Point North Slope, Alaska Kuparuk 1 C .--, Target Type Current Target Current Target Current Target- <Surface> <Surface> 7000.00 <Surface> <Surface> 3736.50 158.00 7362.48 11695.07 158.00 3796.72 3766.10 Targets associated with this wellpath Target Name 1 C-135 (D Turn SE) 1 November, 2001 - 11:08 16" Conductor 7-5/8" Casing 4-1/2" Liner Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3759.10 7841.90 S 1343.86 E Mean Sea Level/Global Coordinates: 3668.00 5960700.00 N 563439.00 E Geographical Coordinates: 70° 18' 11.2595" N 149029' 10.0778" W 3797.10 5382.94 S 1117.18E Mean Sea Level/Global Coordinates: 3706.00 5963157.00 N 563192.00 E Geographical Coordinates: 70° 18' 35.4459" N 1490 29' 16.6772" W 3766.10 9594.67 S 2156.40 E Mean Sea Level/Global Coordinates: 3675.00 5958954.00 N 564266.00 E Geographical Coordinates: 70° 17' 54.0176" N 149028' 46.3985" W Page 9 of 9 DrillQuest 2.00.09.006 (" Sperry-Sun Anticollision Report (' Company: Phillips Alaska Inc. Date: 11/1/2001 Time: 11 :47:03 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 1C Pad Co-ordinate(NE) Reference: Well: Plan 1C-135 (C-14), True North Reference Well: Plan 1C-135 (C-14) Vertical ([VD) Reference: 1C-135 (C-14) @ 91.00 91.0 Reference Wellpath: 1 C-135 ( C-14) Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 30.20 to 11696.04 ft Scan Method: Trav Cylinder North Maximum Radius: 1366.58 ft Error Surface: Ellipse + Casing Survey Program for Definitive Well path Date: 10/10/2001 Validated: No Planned From To Survey ft ft 30.20 700.00 700.00 11696.04 Version: Toolcode 14 Tool Name Planned: 1C-135 (wp02) V1 Planned: 1C-135 (wp02) V1 CB-GYRO-SS Camera based gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Casing Points MD TVD Diameter Hole Size ft ft in in 11692.78 3766.20 9.625 12.250 Summary Name 95/8" <------------------- Offset Wellpath -------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1 C Pad 1 C-03 1 C-03 V1 300.00 300.00 189.25 6.61 182.64 Pass: Major Risk Kuparuk 1 C Pad 1 C-04 1 C-04 V1 393.08 400.00 201.46 8.77 192.69 Pass: Major Risk Kuparuk 1 C Pad 1C-10 1C-10 V1 1471.91 1600.00 282.23 43.39 244.51 Pass: Major Risk Kuparuk 1C Pad 1C-117 1C-117V1 707.20 700.00 264.10 12.92 251.22 Pass: Major Risk Kuparuk 1 C Pad 1C-119 1 C-119 VO 614.60 600.00 237.02 11.55 225.52 Pass: Major Risk Kuparuk 1 C Pad 1C-121 1C-121 V1 708.60 700.00 202.99 13.78 189.25 Pass: Major Risk Kuparuk 1 C Pad 1 C-123 1 C-123 V5 707.32 700.00 174.52 13.77 160.79 Pass: Major Risk Kuparuk 1 C Pad 1C-127 1 C-127 V5 803.26 800.00 119.50 16.16 103.52 Pass: Major Risk Kuparuk 1 C Pad 1C-131 1C-131 V1 Plan: 1C-131 702.81 700.00 61.61 14.76 46.96 Pass: Major Risk Kuparuk 1 C Pad 1C-133 1 C-133 V6 500.10 500.00 33.23 9.04 24.26 Pass: Major Risk Kuparuk 1 C Pad 1C-14 1C-14 VO 199.99 200.00 183.16 4.52 178.63 Pass: Major Risk Kuparuk 1 C Pad 1C-15 1C-15 VO 299.98 300.00 231.10 6.27 224.84 Pass: Major Risk Kuparuk 1 C Pad 1C-18 1C-18 VO 300.00 300.00 228.47 6.12 222.36 Pass: Major Risk Kuparuk 1 C Pad 1 C-21 1 C-21 VO 36.00 36.00 199.12 No Offset Stations Kuparuk 1 C Pad Plan 1C-137 (Y14) 1C-137 (Y-14) VO Pia 399.34 400.00 31.05 7.93 23.13 Pass: Major Risk Kuparuk 1 C Pad Plan: 1C-129 1C-129 VO Plan: C-Sand 401.65 400.00 90.67 9.26 81.41 Pass: Major Risk Kuparuk 1 C Pad Plan: 1C-125 1C-125 V2 Plan: 1C-125 609.77 600.00 153.97 11.65 142.45 Pass: Major Risk Kuparuk 1 D Pad 1 D-02 1 D-02 V9 8335.52 5500.00 580.58 212.72 386.47 Pass: Major Risk Kuparuk 1D Pad 1 D-05 1 D-05 V4 11333.14 5600.00 921.15 245.74 702.49 Pass: Major Risk Kuparuk 1 D Pad 1 D-1 05 1D-105 V27 7593.54 5600.00 819.95 229.29 593.54 Pass: Major Risk Kuparuk 1 D Pad 1 D-1 05 1D-105A V28 6746.57 6500.00 211.78 215.58 27.06 Pass: Major Risk Kuparuk 1 D Pad 1 D-11 1D-11 Gyro VO Out of range Kuparuk 1 D Pad 1 D-11 1D-11V10 Out of range Kuparuk 1D Pad 1D-117 1D-117V2 9617.58 4600.00 1133.33 204.57 928.63 Pass: Major Risk Kuparuk 1 D Pad 1D-12 1 D-12 V2 10300.00 5200.00 457.93 220.10 266.08 Pass: Major Risk Kuparuk 1 D Pad 1 D-141 1D-141 VO 11663.27 5100.00 772.74 298.61 513.98 Pass: Major Risk Kuparuk 1D Pad 1 D-141 1D-141 WPs V4 Plan: 1D 11652.97 5100.00 770.73 273.05 527.07 Pass: Major Risk Kuparuk 1 D Pad 1 D-141 1 D-141L 1 VO 11663.27 5100.00 772.74 298.61 513.98 Pass: Major Risk Kuparuk 1 D Pad 1 D-141 1D-141L1PB1 VO 11663.27 5100.00 772.74 298.61 513.98 Pass: Major Risk Kuparuk 1D Pad 1D-141 1D-141L2PB2VO 11663.27 5100.00 772.74 298.61 513.98 Pass: Major Risk Kuparuk 1 D Pad 1D-141 1D-141PB1 VO 11663.27 5100.00 772.74 298.61 513.98 Pass: Major Risk Kuparuk 1 D Pad 1 D-28 WPS 1D-28 WPS V4 Plan: 1D- 11660.30 5200.00 793.90 282.20 665.64 Pass: Major Risk Kuparuk 1 D Pad 1 D-28WPS 1 D-28WPS VO Plan: 1 D-211664.66 4800.00 905.42 272.94 782.01 Pass: Major Risk Kuparuk 1 D Pad 1 D-32 1D-32 V4 11659.04 4700.00 1051.94 251.54 866.56 Pass: Major Risk Kuparuk 1 D Pad Plan 1D-18 (C-15) 1D-18 (C-15) VO Plan: 10418.42 5200.00 878.28 205.67 716.98 Pass: Major Risk Kuparuk 1 D Pad Plan 1D-19 (C12) 1D-19 (C-12) VO Plan: 10142.52 5100.00 365.38 198.40 172.85 Pass: Major Risk ORIGINAL -135 (C-14) \VEIL DETAILS 'Nf-S 'EI-W Northing Easting Lalitude Longitude 10.90 -341.64 5968530.52 56203036 70"19'2839JN 149"29'49.265W 107 100 80 60 40 20 0 20 40 C) :::0 - - ~ - - <: )::::.. r--- ANTI-COLLISION SETTINGS 101 Interpolation Method:,\1D 'A Depth Range From: 30.20 Maximum Range: 1366,58 SURVEY PROGRAM Ih Fm Depth To Surv"yiPlan Tool 60 80 100 107 Interval: 100_00 To: 11696.04 Reference: Plan: IC-B5 (wp02) 120 '.00 700.00 PIannaI: I C -135 (wpO2) V I 11696,04 Planned: IC-135 (wpO2) VI CB-GYRO-SS MWD+IFR-AK.C,v'-SC P/¡q¡. . lel:?9 (¡el:?9j 270 \ \ \ . \ ~ . \ ~ \ ~ ~. ~~ -------- :n:akd By: Dav" EgOOahI J¡""k.:d: Plan: IC-135 (wpO2) (Plan IC-135 (C-14 YIC-135 (C-14» Dal": "vi"w"",: pprow~: I)-dl<: 111112001 0 \c-\" ()C-\") mMPA.W DETAlI.' WIJ 1.1',\111 Dn,VI.' 1""1",'-"""1..- ,I~ ""'"'" II'."~ ( ('-1,1 ) RO"- 1«1 I.."" II',I'~ ( '-.1< ) -" 'Jim ')).,.,. .....,_.. ~k"'.J: ~i..nun n"""", L':: ~l= ~~~\~~1~' ~"'" fn« S<rl",~. Ell"'" ' ""-'" W""",,~j,,"'.J: Ruk.,"'-", \'s..-..~", ."\'k 11,7\-!' ""r" Onrn "'"""r .s " '1),\\' 1'"." 1\1) ",., "'" """ From Colour 0 200 400 600 800 1 000",- 150a?' - 20Ø(J ~ ~OO ,,000 ,:;:,"! 6000 '--- 7000 £; 8000 Ü 9000 60 i 10000 ?t: 11000 . 12000 ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 " 5000 6000 7000 8000 9000 10000 11000 12000 13000 / ) / ~ 180 SL'C MD Inc Azi I 3020 0.00 0.00 2 300,00 0.00 23(,,00 ~ 63330 10.00 2J(..()O 4 1049.70 20.00 205,00 5 2217.04 67.00 IC>5.00 6 6926.66 67,00 165.00 7 7193.86 81.05 183.63 8 720535 81.05 18.1.63 9 7361.71 90.90 174.68 10 9752,01 90.90 174.(08 II 1032550 89.m 151.78 12 11696.04 89.60 151.78 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [40ft/in] Dal": Dal":- LEGEND - IC-03 (IC-03). Major Risk IC-04 (IC-04), Major Risk - IC-IO(IC-IO).MajorRisk - IC-117(IC-117).MajorRisk "'~.- IC-119(1C-119).MajorRisk - IC-121 (lC-121). Major Risk IC-123 (lC-123). Major Risk IC-127 (IC-127). Major Risk - IC-131 (IC-I3\). Major Risk IC-133 (IC-133). Major Risk - IC-14 (IC-14). Major Risk - IC-15(IC-15).MajorRisk - IC-18 (IC-18). Major Risk - IC-21 (IC-21), Major Risk - PlanIC-137(YI4)(lC-137(Y-14»).Major Plan: IC-129(IC-129).MajorRisk Plan: IC-125 (IC-125). Major Risk I D-02 (I D-02). Major Risk - ID-05(ID-05).MajorRisk - ID-1O5(ID-1O5J.MajorRisk - ID-1O5(ID-1O5A).MajorRisk ID-II (ID-II Gyro). Major Risk - ID-II (ID-I I). Major Risk - I D-117 (I D-II7). Major Risk ID-12 (lD-12). Major Risk - ID-141 (ID-141). Major Risk ID-141 (1D-141 WPs).MajorRisk - 1D-141(ID-141L1),MajorRisk - 1D-141 (ID-141L1PBI).MajorRisk - ID-141 (lD-141L2Pß2). Major Risk - ID-141 (lD-14IPßI).MajorRisk I D-28 WPS (I D-28 WPS). Major Risk - I D-28WPS (1D.28WPS). Major Risk-. - I D-32 (I D-32). Major Risk' - Plan 1D-18 (C-15 )(1D-18 (C-15)). (is - Plan 1D-19 (CI2) (lD-19 (C-12». MaJur Risk - IC-135(("-14) - IC-135 (wp02) 90 Draft Plan (wpO2) wi: 1 D-l 05 = !\:I\VD 1 D-IO5A = J\:lWD+IFR+Caz 1 C-135 = j\:l\VD+1 FR+Caz SE!ïION DErAILS l\'D IN'-S II".W IJLq '1 L,ce \"SL'I: TJI~d .'°,20 0.00 0.00 O.IJ() 0.00 0.00 3m.oo 000 O.IXI O.lX) 2](,,00 O.lX) (,31.(,1 -1(..22 -24.05 l(~ 21(..<~ 10.56 10.13.89 -10 I.J I -)(43(, .1.(JO 30q~ 80.1(, 18M.81 -854.7.1 -25.49 4.50 .111.1«1 ~28.35 .1710.00 -5042.24 10%.55 oJJ() I)", SIS'),'}7 3783.96 .52'J{"O7 112fJ..15 8.50 54.81 5412,)(4 3785.75 .5307.40 1119.1>3 O.()IJ 0.00 542).75 .17%.7.1 .54(,3.00 1122.00 8.50 -42.58 5S76.1)~ .1759,00 .7)(42.71 IJ4H,.1 1).fX) 0.01) 7'14(,.4'} (,.1.15(IJTtlmSI) 3751,.44 -83~jU 3 151)8.1).1 4.1)0 -'I.ll(, ~514M 376(..00 -'}595,6') 215(,.17 'I.I~I o.fX) '}8.14,'}S IC"-1.15 (I>-l..e) 13-5 ¿.verter I BOP System Schematic West Sak Multilateral Wells, Vetco Gray Gen II Wellhead System, Nordic Rig 3 7 6 5 4 3 ~ 0 Center Line of 1611 Diverter Line 2 7-5/8" Casing 16" Casing I I I I I 1 ¡ I I I I I I KEY: 1. Landing Ring, 16" x 13-5/8", Vetco Gray, with 7-518" Casing Landed, Vetco Gray. 2. Well Head, 10-3/4" Vetco Gray Quick Connect Bottom x API 13-5/8" 5000 psi Flange Up, Vetco Gray. 3. Diverter Spool, 13-5/8" x 13-5/8" 5000 psi top and bottom with API 16-3/4",5,000 psi side outlet, Vetco Gray. 4. Single Ram BOP, 13-5/8" x 5000 psi, with pipe rams, Nordic 5. Drilling Spool, 13-5/8" x 5000 psi, wI 2 Side Outlets, Nordic 6. Double Ram BOP, 13-5/8" x 5000 psi, with Pipe Rams on Top and Blind Rams on Bottom, Nordic 7. Annular BOP, 13-5/8" x 5000 psi, Hydril GK, Nordic 8. Choke Valve, Manual Operation, 4-1/16" x 5,000 psi, Nordic 9. Choke Valve, Hydraulically Operated, 4-1/16" x 5,000 psi, Nordic 10. Kill Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nordic 11. Kill Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nordic 12. XO Spool: 16"-API5K x 16".ANSI150# RF - Vetco 13. Divert Line Knife Valve, Hydraulically Operated, 16", Nordic ORIGINAL prepared by Steve McKeever 11/14/01 --( ( EFSO 16-3/4" 5,000# BX162 Ø10.50 1 $& I $'~ Lf) r-- r-- ~ 0 c.o 0 N ROTATING FLANGE 13-5/8" 5,000# ax 160 (2 PLACES) 0 ~ r 0 0 r<J N EFSO 3-1/8" 5,000# R35 (2 PLACES) r Ø26.50 l 0 0 r--- ~ QUOTE: 1976 ORIGINAL DA TE: 01/05/01 DWG. UPDATE AS PER GUST. RQST.: 06/01/01 ACADEMY PETROLEUM [NDU~TRIE~ EDMONTON, ALBERTA, CANADA TE~ (7B~ 466 6360 FAX: (780) 466 6380 DWG. NAME: DRilLING SPOOL 13.63-5.000# ROT. MAIN LAYOUT F'lLE: DRSP RT 13 CW ErSOS DATE: 06/01/01 OR! G! NAiBB Vetco Gray l , ( lC-135 Drilling Hazards Summarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 9-7/8" Open tlole / 7-5/8" Ca~al Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Hazard Abnormal Reservoir Pressure Stuck Pi pe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Moderate Low Low Moderate Miti ation Strate Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted swee s run ravel isolation strin . Diverter drills, increased mud weight. 4" Liner Interval Risk Level Low Moderate Low Moderate Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole 0 ener Decreased mud wei ht Reduced urn rates, Mud rheolo ,LCM Trip speeds, Proper hole filling (use of trip sheets, Pum in out ORIGINAL 1 C-135 Drilling Hazards Summary prepared by Steve McKeever 11/14/01 PHIlUPS PHILLIPS A{aSka, Inc. m A Subsidiary of PHilLIPS PETROLEUM COMPANY (' FORMATION INTEGRITY TEST PROCEDURE Kuparuk River Unit Drilling Operations 1. After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to the test pressure specified in the well plan (usually 3000 psi or 3500 psi) for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the PAl LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. 3. Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. 6. On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If a pre-specified (may be 16.0 ppg) EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT. 7. At leak off pump 3 bbls of mud into formation prior to shutting down the pump. 8. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. ORIGINAL PAl FIT LOT Procedure.doc Page 1 of 1 4/26/01 Schlumbe rger Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic #3 Location: West Sak Client: Phillips Alaska, Inc. Revision Date: 11/15/2001 Prepared by: Chris Avant Location: Anchorage, AK Phone: (907) 265-6067 Mobile: (907) 223-8808 email: CAvant@slb.com 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 800' above the West Sak formation. Lead Slurry Minimum pump time: 250 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg, Class G + 50%0124, 9%(BWOW)044, 0.6%046, 30%053, 1.5%S1, 1.5%079, 0.5%065 - 4.44 ft3/sk < TOC at Surf ace Previous Csg. < 16", 62.6# casing at 158' MD < Base of Permafrost at 2,054' MD (1,797' lVD) < Top of Tail at 6,500' MD < Top of West Sak at 7,195' MD < 75/8",29.7# casing in 9 7/8" OH TO at 7,362' MD (3,796'lVD) . Mark of Schlumberger 0.9513 fe/ft x (158') x 1.00 (no excess) = 0.2148 ft3/ft x (2054' - 158') x 3.50 (250% excess) = 0.2148 ft3/ft x (6500' - 2054') x 1.35 (35% excess) = 150.3 fe + 1425.4 fe + 1289.3 fe = 2865 fe / 4.44 fe/sk = Round up to 650 sks 150.3 ft3 1425.4 ft3 1289.3 fe 2865fe 645.3 sks Have 180 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 160 min. (pump time plus 90 min.) 15.8 ppg Class G + 0.5%S1, 0.2%046, 0.3%065, 0.4%0167 - 1.17 ft3/sk 0.2148 ft3/ft x (7362' - 6500') x 1.35 (35% excess) = 0.2578 ft3/ft x 80' (Shoe Joint) = 250 fe + 20.6 fe = 270.6 ft3/ 1.17 fe/sk = Round up to 240 sks 250fe 20.6 ft3 270.6 fe 231.3 sks BHST = 78°F, Estimated BHCT = 79°F. (BHST calculated using a gradient of 2.4°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW 1 00 6 60 10.0 10.0 Drop Bottom Plug 3.0 13.0 MudPUSH XL 6 50 8.3 21.3 Lead Slurry 6 514 85.7 107.0 Tail Slurry 6 50 8.3 115.3 Drop Top Plug 3.0 118.3 Displacement 6 314 52.3 170.6 Slow Rate 3 20 6.7 177.3 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.2 ppg MudPUSH* XL, Pv:::: 17-21, T y :::: 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Well # 1 C-135, AFE #AK 0220 West Sak Lateral (" )duction Well Planned Completion Schematic Sheet 1 of 3: Casing String Details ptf .LIPS Alaska, Inc. A SuÖSi(1ìary of PH¡tUPS PETROLEUM CO¡',,1PA1\iY Nordic Rig 3 RKB @ 0' Eastings: 562,030.64 Northings: 5,968,530.63 Elevation: 91.1' AMSL Tubing Head Assy, (497-0055) Vetco-Gray Gen II for Single Completion, API 13-5/8" 5000 psi Flange up x Vetco 13-5/8" Female Overshot Bottom Landing Ring: ~ Vetco-Gray, 16" Weld on Bottom x 13-5/ 8" Male Overshot Top (497-0020???) .. Casing Hanger: (497-0030) Vetco-Gray, with 7-5/8", 29.7#, BTC pin down x Acme box up Port Collar: (485-7080) TAM, 7-5/8",29.7#, L-80, BTC Pin Set @ +1- 1,000' MD Conductor Casing, 16",62.5#,- API 5L (205-7875 ???) @ +/- 147' MD Centralization: Weatherford 7-5/8" x 10-1/2" Bowspring (1) on each collar from 6000' to Float Collar (1) on a stop collar in the middle of the joint below the float collar (1) on a stop collar in the middle of the joint above the float shoe (1) on each of the three collars above and below the port collar ~ (x) Joints Casing: (463-4825) 7-5/8",29.7#, L-80, BTCM 'III( Float Collar: Weatherford Model 402, 7-5/8", 29.7#,BTCM (463-4827) Joint with Float Shoe (2) Joints Casing: 7-5/8", 29.7#, L-80, BTCM (463-4828) Joint with Thread Locked Box ... ~ ~ Float Shoe: ~ Weatherford Model 303, 7-5/8", 29.7#, BTCM TD 9-7/8" Hole: (463-4826)Joint with Float Shoe 7,362' MD / 3,796' TVD 1C-135 Planned Completion Schematic Sheet 1 of 3: Casing String Details prepared by Steve McKeever November 15,2001 Well # 1C-135, AFE #AK 0220 West Sak Lateral Production Well Planned Completion Schematic Sheet 2 of 3: Lateral Liner Details See Sheet 1 for Casing Details Top of Lateral Liner: +1- 7,100' MD I 3,765' TVD Suñace I Production Casing 7 -5/8" 29.7# L.80 BTC Mod Set @ 7,362' MD 13,796' TVD PHilliPS Alaska, Inc. A s~m:~'¡d!(jfY (if PHILL.iPS PETROLEUM GOMFf~,NY (1) Set Shoe Assembly, consisting of: (1) Set Shoe, Baker Model 'GPV', 5.560" Max OD,S", 18# SLHT Box (492-1550) (1) Crossover, 4" SLHT Box x 5" SLHT Pin (PAl supplied, 492-1915) (1) Joint Tubing, 4", 9.5#, L-80, SLHT (PAl supplied, 492-1220) (1) Crossover, 4-1/2", 12.6#, NSCT Box x 4", 9.5#, SLHT Pin (PAl supplied, 500-3030 ) (x) Joints 4.1/2" Slotted Pipe, 4-1/2", 12.6#, L-80, NSCT (PAl supplied, 500-1970) (1) Crossover joint or pup, Blank, 4-1/2", 12.6#, L-80, NSCT pin x IBTM Box (PAl supplied, ---) (x) joints, 4-1/2" Blank Pipe, 4-1/2", 12.6#, L-80, IBTM (PAl supplied, 474-9695) (1) Crossover Sub, 4", 9.5#, SLHT box x 4-1/2", 12.6#, IBT Pin (PAl supplied, ---) (1) Joint Tubing, 4", 9.5#, L-80, SLHT (PAl supplied, 492-1220) (1) Crossover, 4-1/2", 11.6#, SLHT Box x 4", 9.5#, SLHT Pin (PAl supplied, 492-1525) (1) Sliding Sleeve, Baker Model 4-112" 'CMD', w/3.43"ID, 4-1/2",11.6# SLHT Box x Pin (492-1510) (1) Joint 4-1/2" Blank Pipe, 4-1/2",11.6#, L-80, SLHT (PAl supplied, 475-5030) ASN Change w/out Central izer??? (1) Crossover Sub, 5-1/2", 17#, SLHT Box x 4-1/2", 11.6# SLHT Pin (PAl supplied, 481-1695) (1) Packer Assembly (496-9670), Baker, consisting of: (1) Mill Out Extension, Baker, is' Long, 5-1/2", 23# SLHT pin x pin (1) Packer, Baker Model'SC1-R' (76B2-40), 7-5/8",24-29.7#, w/ 5-1/2", 17#, SLHT box down. D-Sand Lateral 6-3/4 II Open Hole TD: 11,695' MD 13,766' TVD ----------------------------------------- ----------------------------------------- ------------------------------------------ ----------------------------------------- Centralizers: 4-1/2" x 5-3/4" Rigid Straight Blade on every other joint in open hole 1C-135 Planned Completion Schematic Sheet 2 of 3: Lateral Liner Details prepared by Steve McKeever November 14,2001 Well # 1C-135, ~....: #AK 0220 West Sak Lateral Production Well Planned Completion Schematic Sheet 3 of 3: Tubing String Details ( PHilliPS Alaska, Inc. Þ. ~;ub$:d¡:~ry of PHLUPS PETHOU,:',UM CGMF'f\NY Tree Assembly, (497-0080) Vetco Gray Gen II, API 13-5/8 - 5000 psi Flange Down x 4-1 I 16" 5000 Studded Top, with Penetrators Tubing Head Assembly, Vetco Gray 16" Conductor: +/- 147' MD TAM Port Collar: +/- 1,000' MD /1,000' TVD Top of Lateral Liner: +/- 7,100' MD / 3,765' TVD 7-5/8" Shoe: 7,362' MD / 3,796' TVD Nordic Rig 3 RKB @ O' Eastings: 562,030.64 Northings: 5,968,530.63 Elevation: 91.1' AMSL Tubing Hanger, (11" Body: 493-3005,13-51 8" Reducer Bushing: 499-6540) 4-1/2", Vetco Gray wi 4.909" MCA Top Connection, 4-1/2", 12.6#, L-80 NSCT box down. (1) Crossover, 4-1/2", 12.6# NSCT Pin x 3-1/2", 9.3# EUE 8rd pin., bucked up to hanger L-_) (1) Handling Pup, 4 ft long, 3-1/2", 9.3# EUE 8rd Modified, bucked up to hanger (ASN 319-1966 ???) (x) Joints 3-1/2" Tubing (1) Profile Nipple, 3-1/2" Cameo 'OS' wI 2.875" No-Go Profile, EUE 8rd, set at +1- 500' MO (NO go for this profile is larger than tubing drift diameter) (477-4830 ???) Tubing String: 3-1/2", 9.3#, l-SO, EUE Srd AB Modiifed (423-1660) (x) Joints Tubing (1) Control Line / TEC wire for Sentry Gauge, held in place with Canon clamps on every coupling (---) (1) Pressure Gauge, Discharge, Baker Sentry (---) (1) Sliding Sleeve with Profile, Baker 'CMU' sliding sleeve wI 2.813" Cameo No-Go profile, EUE 8rd box x pin. (477-6760 ???) with (1) Jet Pump installed after rig release, Weatherford, 3" Reverse Circulation, #10 Nozzle, #11 Throat, with top XO to CAMCO Lock. (1) Joint Tubing (1) Gas Lift Mandrel, CAMCO 3-1/2" x 1" Model KBG-2-9 (---) , with dummy valve installed. 3-1/2" IBT Pin x Pin, with 6 foot 3-1/2" XO Pups, top and bottom. (1) Joint Tubing (1) Pressure Gauge, Intake, Baker Sentry (---) (1) Locator Seal Assembly: (461-3435) 3-1/2" Baker GBH-22 '80-40' wI 12' of Seals and Locator, 3-1/2" x 6' L-80 Handling Pup (455-3185) installed on top. EUE 8rd AB Mod Box up. with INDEXING MULE SHOE ON BOTTOM. landed 4 feet above fully inserted position. ------------------------- ------------------------ ------------------------- ------------------------ ------------------------- ------------------------ ------------------------- D-Sand Lateral 6-3/4 " Open Hole TD: 11695' MD / 3766' TVD 1C-135 Planned Completion Schematic Sheet 3 of 3: Tubing String Details prepared by Steve McKeever November 15, 2001 ORIGINAL -t -'e-r American Express@ Cash Advance Draft 182 -~- Issued by Integrated Payment System, Inc. Englewood, Colorado Payable at Norwest Bank of Grand junction - DowntOwn. NA Grand junction. Colorado PERIOD ENDING C-(JELL ¡f- \ c. -- \ '~~ I: ~ 0 2 ~ DOL, 0 0 I: :I 5 '" 0 ~ ? 5 000 5 :I b II" 0 ~ 8 2 (" ~. TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSNDTTAL LETTER WELL NAME ,<:£11. / c - /35 CHECK 1 STANDARD LETTER DEVELOPMENT I DEVELOPMENT REDRILL EXPLO RA TI 0 N INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) / ANNULAR.9l'.SPOSAL ~NO ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . " Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (SO -70/80) from records, data and logs acquired for well (name on permit). Annular disposal h. as I}ot been requested. .. ,£:._--- ,H~ lv£./I b ~ 'J ... J Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. ". . ANNULUS / ~YES+ SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved" ,subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. /é. -I 55-PROGRAM: exp - dev -- redrll C GEOLAREA ADMINISTRATION 1. Pennit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Pennit can be issued without conservation order. . . . . . . . DATE 12. Pennit can,be issued without administrative approval.. . . . . J/,¡C¡'D/ 13. Canpermitbeapprovedbefore15-daywait........... 14. Conductor string provided . . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . 16. CMT vol adequate to drculate on conductor & suñ csg. . . . . 17. CMT vol adequate to ,tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 1D-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to ~'C) psig. , 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdbwn. . . . . . . . . . . 29. Is presence of H25 gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued wlo hydrogen sulfide measures. . . . ,. 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . APPR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . L,b II. f . 01, 34. Contact name/phone for weekly progress reports {explorato ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate frèshwater; or cause drilling waste. " to surface;" ' (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annuiar COMMISSION: Rþ~C: WM~ . -8~ s ,~ '-... JM WELL PERMIT CHECKLIST FIELD & POOL APPR DATE APPR DATE serv wellbore seg _ann. disposal para req- UNIT# 6/,// ~() ON/OFF SHORE 0/1. ..5t<-.-:.-F<t..<-<>- /..?C4 -/>«.;.,.... ~ AbL C>2$(4.? --t'i?P (j¡?r.:)c/VL Irtx- ~ ~ 1/~4 4-td .-r: 7:>. ':-N /I DL (.:- -ZÇ"6S-0, .ÁÀ:- ) iI y,N N y/ N, . N N N )N oJ N '{ N ~~ . ~ $ ",,~"d"<-<ë.\"" \>\,,~~ (Y}N '(Y) N~""<' ~c t ~~~\({ ~\-\- ~ ~ ~ Y N I....\c."':tCè.. Q\>~~~\.ct~ ~'(~~M.t..~' N Y N N N ~~ t.~~~ \~%- ~~\ 36aa ~, ,~ ~~('f"~,~ N . ~ N . . Y @ \<..~~ '~~~'-3'\>~~ ~t ~~f'\.~~"'~~C3..\~~~. ~ Y N only) Y N ~~~~\~'~",<:"~f:.A\ ~~":>~\~\të a~~\r.-..',> ~€..\\, , ~ ~ Þb~ ~c ~~~ ~\>~~~~ ~({\\. 0"- "-...o\:' c.\~~ ~~~'\ ~~:J~,.ttJ rc;r~ .htomm~nts/frltt~ctil~s: .¿.jG¡>¡-¿s$;J .:5 " . ú\, 1(f,"'d¡.,lz "It. ;:.cg()Q rt~Ary ~(t<J7/lk.: '.'. '. ' . ' ðf Dl q Jß Iti.~ It£,.: /JÎto D c¡"e / !Z¿-5:¡sI1l'"7(y / bll..e-,,--h,,'w¿(//::¿Vi) b ;$4'/ ¿.j~lIILl:>t~ / /11wi." t9,e/Ø~Ú>-hV7 5/~/ï-¿~~4.f/T1.J~, /t.lL".Dr ,.ðl> c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -4 ~ ;0 t - -4 m - Z -4 ,J: en :Þ ;0 m » ( ( ( Well H ¡story File APPENDIX Infonnation of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. ( Sperry-Sun Drilling Service? LIS Scan UtiliLY ~;Revisio!1: 3 ~' LisLib $Revision: 4 $ Sat Mar 09 16:46:16 2002 Reel Header Service name.... ...... ...LISTPE Date.....................O:::/03/(I~ Oriqin...................STS Reel Name................UNKNOIrJN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments..... ........... .STS LIS Tape Header Service name.............LISTPE Date.....................02/03/09 Origin...................S'l'S Tape Name................UNKNOWN Continuation Number.... ..01 Previous Tape Name..... ..UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit - West Sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA LfOB NUMBER: LOGGING ENGINEER: OPERArrOR v\1I'I'NESS: MWD RUN 1 AK-MM.-11196 cT. SACK D. HElM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MM-11l96 R. MCNEILL R. BOWIE N SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUStlING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD ( WelLing Library. Scientific Technical Services W.Üting Library. Scientific Technical Services 1C-135 500292305300 PHILLIPS Alaska, Inc. SpE~rry Sun 09-MAR-02 MWD RUN 3 AK-MM.-11196 J. SACK R. BOWIE MWD RUN 4 AK-MM-11196 R. FRENCH H. BOWIE MWD RUN 6 AK-MM-1l196 R. MCNEILL R. BOWIE 12 UN 10E 1706 1022 .00 90.50 60.80 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 147.0 9.875 7.625 7283.0 # REMARKS: aOJ-ddO /Of.o<.ot.1 ,( ~. ;\1.1. DE ?THS P\RE TRUE VERTI CAL DE PTHS (TVD) UNLESS OTHERWISE STATED. H1^lD RUNS 1 - (3 ,I\RE DIRECTION,A.L WIT¡-j DUAL GAivu'-lA RI\Y (DGR) UTILIZING GEIGER J,!LiEL~;:::R T¡'}E;:E: DETE:CTORS ?;¡C E:L~:>:TRO¡,I;::,,':=¡<:::lE; l':.:':.'¡;: RESISTIVITY PHASE ~ :: Eì'iR,j.l . 3. MWD RUN 2 NO fOOTAGE DRILLED AND IS NOT PRESENTED. 4. G.I\HMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 7269' MO, 3765' TVD TO 7283' MD, 3766' TVD. 5. GAP IN RATE OF PENETRl,TION (SROP) FROM 9155' 1010, 3755' TVD TO 9175' MD, 375 IS DUE TO PERFORMING OFEN I-IOLE SIDETRACK. 6. RESISTIVITY DATA FROM 9968' MD, 3756' TVD TO 10356' MD, 3754' TVD WAS OBTAINED WHILE RUNNING IN THE HOLE FOR MWD RUN 6 DUE TO A TOOL FAILURE ON MWD RUN 5. 7. 1C-135 IS TIED INTO lC-135PBl AT THE KICKOFF POINT. THIS WELL KICKS OFf FROM 1C-135PB1 AT 9155' MD, 3755' TVD. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. DATED 01/04/02. AUTHORIZED BY GKA GEOSIENCE GROU ALL MWD LOG HEADER DATA RETAINS 'rHE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 6 REPRESENT WELL 1C-135 WITH API # 50-029-23053-00. THIS WELL REACHED A TOTAL DEPTH OF 10700' MD, 3753' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMM}\ RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SH.ALLOW SPl\CING ) SESP = SMOOTHED PHASE SHALLOW SPACING) SEMI' = SMOOTHED PHASE MEDIUM SPACING) SEDF = SMOOTHED PHASE DEEP SPACING) SFXE "" SMOOTHED FORMATION EXPOSURE TIME SHI FT DERIVED RESISTIVITY ( S¡'UFT DERIVED RESISTIVITY ( SlUE"!' DEJUVED RESISTIVITY ( $, File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/03/09 Maximum Physical Record..65535 File Type................LO Previous File Name. ......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE: GR FET RPD RPM RPS 1 clipped curves; all bit runs merged. .5000 ST1-\RT DE PTH 102.5 137.0 137.0 137.0 137.0 STOP DEPTH 11635.0 11642.0 11642.0 11642.0 11642.0 ( '~ ROP 137.0 138.5 11,)-\2.0 11699.5 :;;. ?:'~ ,~ ~" BASELINE CURVE FOR SHIFTS: C~RVE SHIFT DATA ¡MEASURED DEPTH) --------- EQUIV.I\LENT UNSHI FTED DEPT¡-; --------- E.;ê"SELHJE DE PTH " .;' # DATA SOURCE TOOL CODE HER(:;ED PBU MWD HI,'JD !'-1WD !'-1WD !'-1ltJD $ 1001:::.5 10413.5 !'-1ERGE Bl\SE 7305.0 9155.ll 10012. II 1 04 L~. (, 11699.5 BIT RUN NO 1 .3 4 5 6 MERGE TOP 102.5 7305.5 S1155.5 # RE!'-1ARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.. ... ...... ..Undefined Absent val\Je......................-999 Depth Units....................... Datum Speci fication Blocl( sub-type... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 .3 RPX MWD OH!'-1M 4 1 68 12 4 I\PS !'-1WD OHMM 4 1 68 16 5 RPM MWD OH.MM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD FIR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 102.5 11699.5 5901 23195 102.5 11699.5 ROP MWD FT/¡-¡ 0.02 1324.24 1'71.409 23084 138.5 11699.~'¡ GR MWD ¡\FI 11.62 146.6 67.7561 ;~~3066 102.5 11635 RPX MWD OHMM 0.63 2000 31.9989 23011 137 11642 RPS MWD OHMH 0.24 2000 50.2823 23011 137 11642 RPM MWD OHMM 0.48 2000 66.1035 23011 137 11642 RPD MWD OHMM 0.41 2000 62.12e4 23011 137 11642 FET MWD HR 0.13 105.97 1.9152 23011 137 11642 First Reading For Entire File..........102.5 Last Reading For Entire File...........11699.5 File Trailer Service name..... .... ....STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/03/09 Maximum Physical I\ecord..65535 File'I'ype................LO Next File Name...........STSLIB.OO2 Physical EOF Cc,mment Rec,:>rd FI LE HEADER FILE ì\!UMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: II fILE SUHMARY VENDOR TOOL CODE START DEPTH GR 102.5 RPM RPS RPD FET RPX ROP t. :'1:/"; Header Service name.............STSLIB.OO2 3ervi~e Sub Level Name... 'iersio:, Number...........l.O.O Date of Generation.......O2/03/09 >!a:,:imc.:~i'l ~!-li-si~a!- Rec:r:L. 65535 File Type................LO Previous File ~arne.......STSLI5.001 ? 1 .5000 137.0 137.0 137.0 137.0 137.0 1 3 1:-1. :, $ iI LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'rD DRILLER (F'1'): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (E"l'): BIT ROTATING SPEED (RPM): HOLE INCl.INATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 7269.0 7262.5 7262.5 7262.S 7262.5 7262.5 7305. I) TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CA.8ING 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 (OIIMM) A'I' TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULA'l'ING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): tI REMARKS: $ i( 04-DEC-01 Insite 4.05.5 66.16 Memory 7305.0 .0 85.7 TOOL NUMBER PB02315HWRG6 PB02315HWRG6 9.875 7283.0 Water 9.40 60.0 8.0 300 4.0 Based 5.000 4.070 4.500 5.300 72.0 90.0 72.0 72.0 I( ,., ~, ;; ~ata format Specification Record :=.'ata Recor.-d T,:::cpe.................JI Data Specification Eloc~~ Type.... .I~I Lc":::1'Jin'J Directi,:,n.................L.',::,'"rl O~,ti.:al 1::--J deç,th ,...:ni ~s. . . . . . . . . . . :ee",= Data Reference Point............. .Undefined Fl.-3me Sr:'3c:Lr¡;;).....................61:' .ll]¡ Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O 13R RPX RPS RPM RPD FET HWDOIO HWD010 MWDO10 MWD010 MWD010 MWD010 HWD010 Units FT FT/H ,lI, PI OHMM OHMM OHMM OHMM HR Size Nsam Rep Code Offset Channel 4 1 68 0 1 4 1 68 4 4 1 68 8 ~ 4 1 68 12 4 4 1 68 16 5 4 1 68 20 6 4 1 68 24 7 4 1 68 28 8 Name Service Order DEPT ROP First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 102.5 7305 3703.75 14406 102.5 7305 ROP MWD010 FT/H 0.1 1309.05 159.362 14334 138.5 7305 GR MWD010 API 11.62 146.6 68.3708 14334 102.5 7269 RPX MWD010 OHMM 0.63 543.8~) 29.3949 14252 137 7262.5 RPS HWD010 OHMM 0.24 2000 40.2968 14252 137 7262.5 RPM MWD010 OI-IMM 0.61 2000 62.6494 14252 137 72,62.5 RPD MWD010 OHMM 0.41 2000 54.946 l425~~ 137 7262.5 FE'l' MWDOI0 HR 0.13 6.93 0.607011 14252 137 72 62.5 First Reading For Entire File..........l02.5 Last Reading For Entire Fi1e...........7305 File Trailer Service name.............STSLIB.O02 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/03/09 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO3 Physical EOF File Header Service name.... .........STSLIB.OO3 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......O2/03/09 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OO2 Comment Record FILE HEADER FI LE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS 3 header data for each bit run in separate files. 3 .5000 START DEPTH 72 63.0 7263.0 STOP DEPTH 9155.0 9155.0 ~. 'I~ :, ~":': 7263.0 7263.0 9155.0 9155.0 9155.0 9155.0 9155.0 "~¡::T :.(p~ 7263.0 7269.5 7305.5 ';R KOt' .;. # LOG HE."-.DER DAT,I\. DATE LOGGED: SOfT'i-JARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (E'T): TOP LOG INTERVAL, (FT): BOTTOM l,oG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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): HUD PH: HUD CHLORIDES (PPM): fLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DECìF) MUD AT MEASURED TEMPERl-\TURE (MT): MUD AT MJ!..X CIRCULA'rING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE 1:>"1' MT: II NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL S1'ANDOFF (IN): EWR FRE(.¿UENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ¡[ ~l 10-DEC-:)1 Insite 4.05.5 66.16 Memory 9155. C¡ 86.8 93.2 TOOL NUMBER PBOO2324HAGR4 PBOO2324HAGR4 6.750 Water 9.00 44.0 9.0 15000 3.6 Based .340 .274 .280 .420 68.0 86.0 68.0 68.0 Name Service Order Units Size Nsa.m Rep Code Offset Channel DEPT F'I' 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OJ-IMM 4 1 68 24 7 { { :C~:T ;,!¡IJDO30 HR 4 1 68 ,~ 0 ~. Co' 8 First. L.3 S:. ,:a:Tte Se:-vice U,Üt ¡-'1in Ì"1a:,: Hean Nsam ;:;:'eaciir:q Readi:',,:; DEPT FT 7 26~", 9155 82(19 3785 -¡' 263 ~'.L::::: ROP ì'iHDO30 FT/H 73 509.1::.: 19~). OOe 3700 -:]1)5. 5 ?1 :::~, -'. '-"..I' '3R ]\.jHD030 API -) ¡ .71 E:6. Bl 6::).0996 3'772 7::':69.5 9155 RP;-: M"v-JDO 3 0 OHMM O. 83 1835.83 36. 0073 3,8,5 7263 9155 RPS ¡-"1ND030 OHHI'-'! 1 05 1839.23 67 6551 3785 7263 9155 RP!'-! Hír>JD030 OHNM O. 48 2000 77 458'1 3785 7263 9155 RPD MWD030 OHMH 1 11 2000 76. 244 3785 7263 9155 FET ¡-"MD030 HR 0.18 105. 97 :2. 9597<:) 3785 7263 ~ì155 First Reading For ~ntire File..........7263 Last Reading For Entire File...........9155 File Trailer Service name.... ....... ..STSL1B.003 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.......02/03/09 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... ..........STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03/09 Haximum Physical Record..55535 File Type................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUHBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP ~.; 4 header data for each bit run in separate files. 4 . :)000 START DE PTH 9155.~) 9155.5 9155.5 9155.5 9155.5 9155.5 917 5.0 STOP DEPTH 996'7.5 9967.5 9967.5 9967.5 9967.5 9960.5 10012.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (IVIEMORY OR REAL-TIHE): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (F"I'): BIT ROTATING SPEED (RPH): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: ll-DEC-01 Insitr" 4.05.5 66.16 Memory 10012.0 88.5 92.6 II ( ;OOL STi'\.ING (TOP TO BOTTOH) VENDOR TOOL CODE TOOL TYPE DGR DU,I:\,L G.I:\.HHA R}\Y ::¡"¡R.:! ELECTROHAG. RE:SIS. .:j $ BOREHOLE }\ND c.r..SING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): ii BOREHOLE CONDITIONS HUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (3): ¡V¡UD 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): II TOOL STANDOFF (IN): EWR FREQUENCY (HZ): II REMARKS: $ II Data Format Specification Record Data Record Type..................O Data Specifi.cation Block Type..... (1 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 Spec:ifi.cation Block sub-type... 0 Name DEFT ROF GR RFX RFS RPM RFD FET Se.cvice Order Units Size Nc,am FT 4 1 FT/H 4 1. API 4 :1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 HR 4 1 f\ep Code 68 68 68 68 68 68 68 68 MWD040 MWD040 MWD040 MWD040 MTrifDO 40 MWD040 MWD040 lit TOOL ~~Uì.1é:E;, PE:I:ìCì:::'3:::':¡H;:',I:;~'; FE::,:'O:::3::::¡ !-P,I:;;;;'! 6.750 ¡'Ja t e],- :::-,35 ""j 9.2CI 43.0 8.4 14500 3.6 .340 .255 .280 68. (I 93.0 .370 68.0 68.0 Offset 0 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 0 \,, First Last Name Service Unit tvliíì tvlax Mean Nsam Reading Reading DEFT FT 9155.5 10012 9583.75 1714 9155.5 10012 ROP. MWD040 FT/H 0 800.33 158.412 1675 9175 10012 GR MWD040 API 41.06 88.01 66.8348 1611 9155.5 9960.5 RFX MWD040 OHM~1 9.19 H36.79 43.0784 1625 9155.5 9967.5 RPS MWD040 OHMM 19.05 2000 82.4002 1625 9155.5 9967.5 RFM MWD040 OI-lMM 25.95 265.42 79.8179 1625 9155.5 9967..5 RFD MWD040 OI-lMM 32.05 1'79.21 76.4786 1625 9155.5 9967.5 FET MWD040 HR 0.21 8.95 1.49854 1625 9155.5 9967.5 First Reading For Entire File..........9155.5 Last Reading For Entire File...........10012 File Trailer Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPD FET RPX ROP ( See/ice name.............STS;'IE.'J':'c; Service Sub Level Name... -/ersi':'fI Number...........1.0.': ~'3.t.e c'f Ger!e.ë3ti.::>n...... .0;::/,:13/(1('; Maximum Physical Record..65535 F_ile TYt.:.e................LO Next File Name....... ... .ST8LIB.005 Physical EOF File Header Service name.... ........ .8T8LI8.005 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation.......02/03/09 Maximum Physical Record..65535 File Type................LO Previous File Name... ... .8T8LIB.004 5 5 .5000 ST.ART DE PTH 9961.0 9968.0 9968.0 9968.0 9968.0 9968.0 1001;;:.5 STOP DEPTH 10359.5 10356.0 10356.0 10356.0 10356.0 10356.0 10413.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIHE): 'I'D DRILLER (FT): TOP I~OG INTERVAL (FT): BOTTOH LOG INTERVAL (FT): BIT ROTATING SPEED (RPH): HOLE INCLINATION (DEG HINIHUH ANGLE: HAXIHUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL C1l\MJVIA RAY ELECTROMAG. RESIS. 4 # 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 L088 (C3): RESISTIVITY (OHMM) A'r TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULJ-\TING TERMPERATUfŒ: MUD FILTRATE AT MT: it 12-DEC-01 Insite 4.05.5 66.16 Memory 10413.0 90.3 90.9 TOOL NUMBER PBO02324HAGR4 PBO02288GR4 6.750 Water 9.10 42.0 8.6 13100 3.2 Based .350 .297 .300 68.0 81. 2 68.0 ( ( :'1UD C'-':Ü:::: ,,\1' 1<1': ~ ':;,-', ,~ ": . ,- ,EU1'RON TOOL 1,!.u.TRI;': : Hl\TRI:--: DENSI TY: HOLE CORRECTION [IN): ~ TOOL STANDOFF (IN): EWR FREQUENCY (HZ): p REHARKS: $ " Data Format Specification Record Data Record Type..................O Data Specification Block Tyve.....O Logging Direction.. ... ..... .......Down Optical log depth units.......... .Feet Data Reference Point........ ......Undefined Frame Spacing.... .... ........,.. ..60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Uni.ts....................... Datum Specification Block sub-type...O Service Order Units FT FT/I-! l\PI OHMM OHMM OHMM OHMM HR Size Nsam Rep Code Offset Channel 4 1 68 0 1 4 1 68 4? 4 1 68 8 3 4 1 68 12 4 4 1 68 16 5 4 1 68 20 6 4 1 68 24 7 4 1 68 28 8 I'-Iame DEPT Rap GR RPX RPS RPM RPD FET MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 First La:'.:>t Name Servi.ce Unit Min Max Mean Nsam Reading Reading DEPT FT 9961 10413 10187 905 9961 10413 Rap MWD050 FT/H 2.12 500.05 167.385 802 10012.5 10413 GR MWD050 API 46.43 100.24 74.5391 798 9961 10359.5 RPX MWD050 OHMM 1.1.09 73.19 26.S:z:L4 777 9968 10356 RPS ¡V¡WD050 OHMM 18.4 152.86 44.9078 777 9968 10356 RPM MWDO50 OHM,M 23.42 143.97 ~)6.282 777 9968 10356 RPD MWD050 OHMM 29.32 139.27 69.5811 rn 9968 10356 FET MWD050 HE 17.94 39.04 21.f3706 777 9968 10356 First Reading For Entire File..........9961 Last Reading For Entire File...... ... ..10413 File Trailer Service name.............STSLIB.OO5 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/03/09 Maximum Physical Record..65535 File Type................LO Next File Name....... ....STS11B.006 Physical EOF File Header Service name... .... ......STS118.006 Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation.......02/03/09 Maximum Physical Record..65535 File Type................LO Previous File Name... ....STSL1B.005 ( C..~':¡:;lìent Re<:>=,.[o::: FJ:LE: i-ŒADER FILE NiJpiEER: ç :::':'.I:,;'j ;.f'¡¡::: ( header data for each bit run in separate files. 6 .5000 Cu:"ves and loq ~IT RUN ¡WHBER: ¡-:'E PTH INCREHENT: # i-~ILE SüHl"1."'.RY VENDOR TOOL CODE RPD RPJ'.'¡ RPS ST.ART DE PTH 10356.5 10356.5 10356.5 10356.5 10356.5 10360.0 10413.5 STOP DEPTJi 1164~.CI 11 6,1 ~. CI 11612.(1 11642.0 11642.0 11635.0 11699.5 RPX FET GR ROP Co ~' II LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (HEMORY OR REAL-TIHE): TO DRILLER (F'r): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: II TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELEC'rROMA(~. RESIS. 4 $ II BOREHOLE AND CASING DA.TA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDI'l'IONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): ~1UD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT 'rEMPERA'rURE (DEGF) ~1UD AT MEASURED TEMPERATURE (MT): MUD NI' MAX CIRCULJ-\'I'ING 'I'E:RMPERA'l'UFŒ: ¡VIUD FILTRATE AT MT: MUD CAKE I\T MT: II NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ if Data Format Specification Record Data Record Type..................O Data Speci.Ucation Block Type..... 0 Logging Direction..... "" ........Down Optical log depth units...........Feet Data Reference Point............ ..Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined 14-DEC-(n Insite 4.05.5 66.16 Memory 11700.0 88.4 91. 9 TOOL NUHBER PBO02288GR4 PBO02288GR4 6.750 Water 9.00 40.0 8.4 15000 3.4 Based .200 .170 72.0 85.8 72.0 72.0 .220 .280 ( ~ ,;bsent value......................-999 :Je9th Units....................... :Jatum Specification Block sub-type...O RPS RP1'-! RPD FET MI-JDO60 HI-JDO60 ¡V¡VJDO 6 Ci Hí'JDO60 t--1WD060 Ivlí-JDO60 MWDO60 Units Si=e Nsam Re9 Code Offset Channel FT '1 1 68 1:'1 FT/H 4 1 68 .] AFI 4 1 68 B OHH}! 4 1 68 1;::: OHH}1 4 1 68 16 OHMH 4 1 68 20 OHHH 4 1 68 24 HR 4 1 68 28 -- Name Service Order DEFT ROP GR RFX .¡ 5 6 7 8 First Last Name Service Unit Hin Hax Mean Nsam Readin<;J Reading DEPT FT 10356.5 11699.5 11028 2687 10356.5 11699.5 ROP MWD060 FT/H 1. 21 1324.24 212.963 2573 10413.5 11699.5 GR MWD060 API 44.35 94.36 66.6901 2551 10360 11635 RPX MWD060 OHMM 14.84 2000 35.1847 2572 10356.5 11642 RPS MltilD060 OHMM 24.5 2000 61.3798 2572 10356.5 11642 RPM MWD060 OHMM 29.58 285.39 62.8355 2572 10356.5 11 6 L1:2 RPD MWD060 OJ-!MM 33.84 167.1 69.8374 2572 10356.5 11642 FET MWD060 HR 0.34 1f3.45 1.86165 2572 10356.5 11642 First Reading For Entire File..........10356.5 Last Reading For Entire File.... .......11699.5 File Trailer Service name.............STSLIB.OO6 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03/09 Maximum Physical Record..65535 File Type................l,O Next File Name....... ....STSLIB.OO7 Physical EOF Tape Trailer Service name......... ....LISTPE Date.....................O2/03/09 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.....................O:2/03/09 Origin...................S'1'8 Reel Name................lJNKNO'\.\TN Continuation Number......O1 Next Reel Narne...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ~ Spí?L:-j'-Sun Dr-lIllO,] :;,:",,:-\"j'::E'~~ L1 S Scan Util it::; $RE:visic,r,: .3 :? LisLib $Revision: 4 $ Tue Mar 05 16:21:542002 Reel Header Service name............. LISTPE. Date.....................O2/03/05 Oriqin...................STS Reel Name................UNJ{NOhìJ'J Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.. ...... .........STS LIS Tape Header Service name.............LISTPE Date.....................O2/03/05 Oriqin...................STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS '~ WELL NAJVIE: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DJ\TE: it JOB DATA - West: Sak ,TOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1. AK-MM-11196 ,J. SACK O. HElM }} SURFACE LOCA.'rION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOE: GEOUND LEVEL: MSL 0) # WELL CASING EECORD ( Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services lC-l.35 PBl 500292305370 PHILLIPS Alaska, Inc. Sperry Sun OS-MAR-O:? MWD RUN .3 AK-MM-11196 c1. SACK R. BOWIE 12 UN 10E 1706 1022 .00 29.70 60.80 1ST STEING 2ND STRING 3RD STEING PRODUCTION STEING OPEN HOLE CASING DEILLEES BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 147.0 9.875 7.625 7283.0 # RF.,MARKS : 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - .3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLEH. TUBE DETECTORS J\ND ELEC'I'ROMI\GNET'IC WAVE dO/-¿;¿ó<O I Ololo 5 ( ~ RESISTIVITY PHASE ~ (EWR4: . 3. HI'iI=:' Run:::: NO FOOT,Ll.GE DRILLED ,'",1'1[\ IS NOT PRESE]')TE'.L". ,¡. C;PJ,1HP-. R.A.Y IS LOGGED BEHIND CASING FROìV! 7269' MD, 3765' TVD TO 7283' MD, 3766' TVD. ¡- .) . Mj,m DATA IS CONSIDERED PDC PER THE E-MlU.L FROM D. SCmJP-.RTZ OF PHILLIPS ALASKJI" INC. DATED 01/04/0:~. AUTHORIZED BY GKA GEOSIENCE GROU ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 3 REPRESENT WELL 1C-135PB1 WITH API # 50-029-23053-70. THIS WELL REACHED A TOTAL DEPTH OF 10350' MD, 3761' TVD. SROP = SMOOTHED RATE OF PENETRATION 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 $ File Header Service name.............S'rSLIB.OO1 Service Sub Level Name... Version Numbe..r...........l.0.0 Date of Generation.......02/03/05 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: H FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS :1 c.U..pped curves; all b:Lt .runs merged. .5000 RPX ROP $ START DEPTH 102.5 137.0 137.0 137.0 137.0 137.0 138.5 STOP DEPTH 10297.5 10304. 5 10304.5 10304.5 10304.5 10304.5 10349.5 H BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 3 MERGE TOP 102.5 7305.5 MERGE BASE 7305.0 10349.5 H REMARKS: MERGED ~~IN PASS. $ H ,t' ~ ~ ~a~a ~ormat Specification Reco~d Data Record TY1-=.,e..................O ~iata Specification Blc,d: Type.... .C) Logging Direction..... ..... .......Down Optical log depth units...........Feet Data Reference Point... ...... .... .Undefi~ed Frame Spacing.....................6CI .:CHi !'-'la:': frames per record.............lir¡defirJe,j Abserlt value......................-999 Depth Units....................... Datum Specification Block sub-type...O c;R RP>Z RPS RPM RPD FET HWD MWD J-.11'W MWD MWD MWD MWD Units FT FT/H API OHMM OHM.M. OHM.M OHMM HR Size Nsam Rep Code Offset Channel 4 1 68 0.1 4 .1 68 4 4 .1 68 8 4 1 68 12 4 1 68 16 4 1 68 20 4 1 68 24 4 1 68 28 " Name Service Order DEPT ROP 4 5 6 '7 8 Fi.rst Last Narlìe Service Unit !v!in Max M.ean Nsam Reading Reading DEPT FT 102.5 10349.5 5226 20495 102.5 10349.~) ROP MWD FT/H 0.1 1309.05 169.029 204;?3 138.5 10349.5 c;R M.WD API 1,1.62 146.6 68.1195 20391 102.5 10297.5 RPX MWD OHMM 0.63 1835.83 30.1407 20336 137 10304.5 RPS MWD OHMM 0.24 2000 45.3937 20336 137 10304.5 RPM MWD OHMM 0.48 2000 63.3354 20336 137 10304.5 RPD MWD OHM.M. 0.41 2Ç)OO 57.641~,i 20336 137 10304.5 FET MWD HR 0.1:2 105.97 1.08837 20336 137 10304.5 First Reading E~r Entire File. .........102.5 Last Reading For Entire File...........1O349.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation. ......02/03/05 M.aximum Physical Record..65535 rile Type................LO Next File Name...........STSLIB.002 Physical EOr tile Header Service name... ..........STSLIB.OO2 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......02/03/05 Maximum Physical Record..65535 File Type................LO Previous rile Name..... ..STSLIB.OO1 Comment Record FILE HEADER E'ILE NUMBER: RAW M.WD Curves and log BIT RUN NUMBER: DEPTH INCREM.ENT: # FIl,E SUM.MARY VENDOR TOOL CODE GR RPX FET 2 header data for each bit run in separate files. 1 .5000 START DEPTH 102.5 137.0 137.0 STOP DEPTH 7269.0 7262.5 7262.5 ii' It :'.::'D 137.0 137.0 7262.5 ;;PS 7262.5 7262.5 '~FJ'1 ROP 137.0 138.5 7305.(1 " ;;, ;' LOG HEADER OAT;', DATE LOGGED: SOFT~.gARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: Dl\TA TYPE (HEMORY OR REAL-TIHE) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOH LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIHUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAlv1MA RAY EWR4 ELECTROMAG. RESIS. 4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (3): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERA,TURE (MT): MUD AT MAX CIRCULATING TERMPERl\TURE: MIJD FILTRA'U: A'T' MT: HUD CAKE AT HT: 11 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Recc)L"d 'I'ype..................O Data Specification Block Type.....O Logging Direction...... ...........Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ( CI4 -DEC-I:'1. Insite 4.05.5 66.16 Memory 7 30~"). 0 .0 85.7 TOOL NUMBER PBO2315HWRG6 PB02315HWRG6 9.875 7283.0 Water 9.40 60.0 8.0 300 4.0 Based 5.000 4.070 4.500 5.300 72.0 90.0 72.0 72.0 Name Service Order Un,i ts Size Nsam Rep Code Offset Channel DEPT FT 4 .1 68 0 1 ROP MWDOI0 FT/H 4 1 68 4 2 GR MWDOIO API 4 1 68 8 3 RPX MWDOIO OHMM 4 1 68 12 4 RPS MWDOIO OHMM 4 1 68 16 5 RPM MWDOIO OHMM 4 1 68 20 6 RPD MWDOIO OI-IMM 4 1 68 24 7 FET MWDOIO I-IR 4 1 68 28 8 ( ~ Fi cst L33-;-, >Jame Ser\'ice Unit Ì"lin I'la:-: Hean Nsam Readinq :;;;eacii:',=: D~PT FT 102.,<) 730S 3703.75 14406 1,)2. 5 -:- 3':'~ ROE' ¡--¡i,mOll:) FT/H ll. ] ] 3U9. CIS 159.362 14334 Uf'-. '" -:-JI_'::, ~. GR HWDCi10 At'l 11. 6::: 146. 6 6S.j'j()8 14 :,:Jj 4 10;;:.5 '726':.' RFY Mí~DO10 OHMJvI O. 63 5.13. 85 29.3949 14252 137 ;262.5 RPS HWDO10 OHHH O. 24 2000 40.2968 14:252 137 7:262.5 RPM HWDO10 OHI'1M O. 61 2000 62.6494 142,52 137 7262.5 RPD M¡~D01 0 OHHM O. 41 2000 54 946 14252 137 7262 :, FET !'WJDOIO HR O. 13 6. 93 O. 607011 14 252 137 7262 ;) First Reading For Entire Filo....... ...102.5 Last Reading For Entire File...........7305 file Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/03/05 Haximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.003 Physical EOF File !-leader Service name... ......... .STSLI8.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03/05 Haximum Physical Record..65535 File Type................LO Previous File Name... ....STSLIB.002 Comment Record FILE HEADER FILE NUMBER: I~AW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 3 .5000 ST]\RT DEPTH 7263.0 7263.0 7263.0 7263.0 7263.0 7269.5 7305.5 s'rOPDE PTH 10304.5 10304.5 10304.5 10304.5 10304.5 10297.5 10349.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILl,ER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: lO-DEC-01 Insite 4.05.5 66.16 Memory 10350.0 86.8 93.2 # TOOL STRING (TOP TO BOTTOM) ( \'::,N DO~ TOOl. CODE DGR E\',::Z.:J 7001 TYPE DUAL G.r\}!J'F\ RJ\Y ELECTROHl\'J. RESI S. ,1 - :::O?.EHOLE l\ND CASING Dì\TA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): " BOREHOLE CONDITIONS HUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEt-'¡PERNI'URE (DEGF) MUD AT MEASURED TEMPERATUFŒ (MT): MUD AT MAZ CIRCULATINC~ TERM PERATURE: MUD FIl,TRATE AT MT: MUD CA!'Œ AT MT: it NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): it TOOL STANDOFF (IN): EWR FREQUENCY (HZ): i! REMARKS: $ it Data Format Specification Record Data Record 'rype..................O Data Spec:L f:Lcation Block Type..... 0 Logging Direction... ... '" ........Down Optical log depth units........ ...Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Unj.ts....................... Datum Specification Block sub-type...O ( '1'00.1 :\lUJ'.¡S::~:-;, FBOO:232.:J!-L'\GR'; PEOn:.:' -',<: ,1 H:'\GR¿, 6.750 I'¡rater Eas,?j <).0,:, 44. I:, 9.0 15000 3.6 .340 .274 69..0 86.0 68.0 6f3.0 .280 .420 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT F'T 4 .1 6¡:3 0 1 ROP MWDO30 FT/H 4 1 68 4 ? GR MWDO30 API 4 1 68 8 3 RPX MWDO30 OHMM 4 1 68 12 4 RPS MWDO30 OHMM 4 1 68 16 5 RPM MírIJD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit ]vIin tvlax Mean Nsam Reading Reading DEFT FT 7263 10349.5 8806.25 6174 7263 10349.5 ROP MWD030 FT/H 0.4 941. 83 191.'785 6089 7305.5 10349.5 GR MWD030 API 37.71 104.14 67.5246 6057 7269.5 10297.5 RPX MWD030 OHMM 0.83 1835.tU 31. 8877 6084 7263 10304.5 RFS MWD030 OHMM 1. 05 1839.23 57.3336 6084 7263 10304.5 RPM MWD030 OI-IMM 0.48 2000 64.9423 6084 7263 10304.5 RPD MWD030 OHMM 1.11 2000 63.9:;56 6084 7263 10304.5 FET MWD030 HR 0.L2 105.97 2.21596 6084 7263 10304.5 First Reading For Entire File..........7263 Last Reading For Entire file...........10349.5 File Trailer Service name.............STSLIB.003 ( Service Sub Level Name... -.,rersion Number...........l.O.O ~a~e of Generation.......O2/03/05 Maximum Physical Record..65535 File Type............... .LO Nex~ File Na~e.... ..... ..STSL!~.~G~ Physical Eor T ar,e T ro3 i 1 er Service name..... ..... ...LISTPE Date.....................O2/03/0~') Oriqin...................STS To3¡::,e Name................UNKNOWN Continuation NUlnber...... 01 Ne:-:t Tape Name........... UNKNO1\7N C::omments.................STS LIS Writing Library. Reel Trailer Service name... ...... ....LISTPE Date.....................O2/03/05 Origin...................STS Reel Name................UNKNOWN Continuation Number...... en Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Physical EOr Physical Eor End Of LIS File ( Scientific Technical Services Scientific Technical Services
